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Home My WebLink About218-0271. 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): 10,050 N/A Casing Collapse Structural Conductor Surface 2,260psi Intermediate Production 4,760psi Liner 7,500psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Casey Morse Contact Email:Casey.Morse@hilcorp.com Contact Phone:(907) 777-8322 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Other: CT, N2 11/7/2025 10,050'3,264' 4-1/2" 6,030' See schematic See schematic 6,998' Perforation Depth MD (ft): 4,887 - 4,984 6,998' 4-1/2" 4,713 - 4,792 5,921'9-5/8" 30" 13-3/8" 450' 1,292' MD 5,020psi 450' 1,291' 450' 1,292' Length Size Proposed Pools: L-80 TVD Burst 4,664 6,870psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018730 218-027 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20681-00-00 Hilcorp Alaska, LLC Trading Bay Unit M-22 AOGCC USE ONLY 8,430psi 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 6,030 5,288 5,027 1,760psi 5,530 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: 2025.10.23 18:36:36 - 05'00' Dan Marlowe (1267) 325-663 By Grace Christianson at 4:13 pm, Oct 23, 2025 DSR-10/30/25 10-404 * BOPE test to 3500 psi. 48 hour notice to AOGCC. MGR31OCT25 A.Dewhurst 24OCT25JLC 10/31/2025 11/03/25 Steelhead M-22 Coil Cement & Add Perf Well Name:Trading Bay Unit M-22 API Number:50-733-20681-00-00 Current Status:Shut In Gas Producer Leg:Leg A2 Regulatory Contact:Juanita Lovett Permit to Drill Number:218-027 First Call Engineer:Casey Morse Office: 907-777-8322 Cell: 603-205-3780 Second Call Engineer:Eric Dickerman Office: 907-564-4061 Max Expected BHP:2261 psi @ 5,025 TVD 0.45 psi/ft gradient to bottom proposed perf Max Potential Surface Pressure:1760 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Well History: M-22 was drilled in 2018 targeting the D sands within the Middle Kenai Gas Pool of the McArthur River Field. The well was not successful in the initial D6 sand completion, and in late 2021 a RWO attempted to recomplete the well uphole. The workover had several attempts to circulate cement behind the 9-5/8 casing. While punching holes in the casing to establish circulation, the well began flowing at 4MMcfd gas. The upper circulation holes were bridged over with dual packer as part of the 4-1/2 completion, and the well was placed on production flowing only from the punch holes at 5010-5015. Assuming this gas was originating from the D-4 sands, perforations were added in the 2 distinct upper and lower D-4 sands to increase flow. This resulted in the well loading up with sand and water. The well has remained shut in since. The well behavior through the 2021 RWO indicated annular isolation either from cement stringers or otherwise. This is evidenced by the dry gas production from the punch holes at 5010-5015 water inflow only after subsequent perforations. Likely, the dry gas was coming from the nearby D-4 lower sand. The well flooded with water only after adding perforations in both D-4 sands, which brough the upper and lower sand on at the same time. Subsequent completions at the nearby offset wells on Steelhead Platform have since confirmed the D-4 upper sand to be a high water and sand producer. The objective of this program is to utilize coil to squeeze the open perforations with cement, shut off the water and sand, then selectively reperforate to return the well to production. Well Notes: 9-5/8 casing tested to 3500 psi under PTD 218-027 SI WHP Tbg: 185 psi, IA: 420 psi Last SL tagged fill at 4780 MD on 12/27/21 Sail angle / max inclination: build angle of ~18 degrees down to ~4,000. Well builds towards horizontal from 4000-7000 reaching max inclination of 45 degrees at the CICR ~5300. SSSV: TRSV at 454 Coil Tubing Procedure: 1. MIRU Fox Energy offshore Coiled Tubing and pressure control equipment 2. PT lubricator to 250psi low / 2,500psi High. (Note: Notify AOGCC 48 hours in advance of test) 3. MU fill cleanout BHA 4. RIH cleaning out fill to top of cement retainer/cement (±5280 MD) 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. MU cement nozzle BHA 6. RIH to bottom ±5280 and lay in viscous gel pill from below perforations to prevent cement setting up in the wellbore below the perforations 7. PUH to 5015 and lay in 22 bbls 15.3ppg cement with retarder Steelhead M-22 Coil Cement & Add Perf a. 9.4 bbls to fill 9-5/8 to 4887 b. 9.3 bbls to fill 9-5/8 x 12.25 open hole annular to 4887 c. 3 bbls excess, trying not to bring cement up into the tubing tail @ 4664 d. This places cement top at ±4715 prior to squeeze 8. Perform hesitation squeeze. Do not squeeze more than 12 bbls to avoid over-displacing cement at top perf 9. RBIH to TD and circulate excess gel and cement from wellbore while holding pressure on choke to keep cement in place 10. Trap pressure on well for >12 hrs to allow cement to cure 11. Repeat steps 6-10 until pressure stabilizes during hesitation squeeze and / or cure time 12. RIH w/ coil and N2 lift to blow the well dry 13. RDMO coil tubing Eline Procedure: 14. MIRU E-line and pressure control equipment 15. PT lubricator to 250psi low / 2500psi high 16. RIH and perforate sands from ±4650 - ±5280 MD (±4535 - ±5025 TVD) 17. RDMO E-line. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Standard Well Procedure Nitrogen Operations 4. Coil Tubing BOP stack _____________________________________________________________________________________ Updated By: JLL 12/06/23 SCHEMATIC McArthur River Field Well: M-22 Last Completed: 10/16/21 PTD: 218-027 API: 50-733-20681-00 Isolated Jewelry A 6651 5,789 3.958 6.125 GLM #5 SMO-1 B 6,698 5,811 3.810 5.560 X-Nipple C 6,741 5,831 3.725 5.020 XN-Nipple (CAT Standing Valve removed 1/12/2019) D 6,785 5,851 6.060 7.360 3.67 of 7.375 tieback seals on 9.6 seal assembly 6,786 5,851 7.380 8.300 Baker UniFlex Pro Liner Hanger w/10 Sealbore 7.380 ID E 6,812 5,859 3.290 5.820 Baker Fluid Loss Control Valve F 6,821 5,880 3.476 4.000 Top of Blank Pipe 7,599 5,981 3.476 4.000 Bottom of Blank Pipe 7,599 5,981 3.476 4.870 Top of Baker Excluder 2000 screens 8,662 6,012 3.476 4.870 Bottom of Baker Excluder 2000 screens 8,662 6,012 3.476 4.870 Top of BakerWeld screens 10,017 6,029 3.476 4.870 Bottom of BakerWeld screens G 10,045 6,029 2.260 5.000 Wellbore Isolation Valve 10,050 6,029 5.070 Round Nose Float Shoe TD:10,050 MD / 6,029 TVD 30 RKB: MSL = 160 RKB to Seafloor 345 F 2 3 4 E 5 6 A B Punch 5010 13-3/8 9-5/8 Punch 4600 1 TOC 6300 MD, CBL Punch 5315 C D 9-5/8 DV tool at 3995 G 8-1/2 Open Hole D-4 D-4 Lwr X FLCV X XN CASING DETAIL Size Wt Grade Conn ID Top Btm 34 x 30 Conductor 30 Surf 450 13-3/8 68 L-80 BTC 12.415 Surf 1,292 9-5/8 47 L-80 DWC/C 8.681 Surf 6,998 TUBING DETAIL 4-1/2 12.6 L-80 Supermax 3.998 Surf 4,664 4-1/2 12.6 L-80 Supermax 3.998 5,810 6,795 4 Blank Pipe 11 P-110 Seal Lock HT 3.476 6,821 7,599 4 Screens 11 P-110 Seal Lock HT 3.476 7,599 10,050 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status D4 4,887 4,907 4,713 4,730 20 11/27/21 Open D4 Lower 4,964 4,984 4,776 4,792 20 11/27/21 Open PRODUCTION LATERAL DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status D-6 7,969 10,050 5,992 6,029 2,081 10/09/21 Isolated JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 74.30 74.30 Hanger 1 454 454 3.813 5.965 SSSV Halliburton NE TRSV Slim 2 4,494 4,368 3.980 8.250 DLH Retrievable Packer (58k release) 3 4,607 4,471 3.980 8.250 DLH Retrievable Packer (58k release) 4 4,625 4,487 3.950 5.190 X-Nipple 5 5,288 5,027 9-5/8 Cement Retainer 6 5,530 5,186 9-5/8 CIBP GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 1,628 1,625 3.95820 Dome 784 10/14/2021 2 2,729 2,680 3.95820 Dome 758 10/14/2021 3 4,448 4,325 3.95824 Orifice 10/14/2021 _____________________________________________________________________________________ Updated By: CDM 10/22/25 SCHEMATIC Proposed McArthur River Field Well: M-22 Last Completed: 10/16/21 PTD: 218-027 API: 50-733-20681-00 Isolated Jewelry A 6651 5,789 3.958 6.125 GLM #5 SMO-1 B 6,698 5,811 3.810 5.560 X-Nipple C 6,741 5,831 3.725 5.020 XN-Nipple (CAT Standing Valve removed 1/12/2019) D 6,785 5,851 6.060 7.360 3.67 of 7.375 tieback seals on 9.6 seal assembly 6,786 5,851 7.380 8.300 Baker UniFlex Pro Liner Hanger w/10 Sealbore 7.380 ID E 6,812 5,859 3.290 5.820 Baker Fluid Loss Control Valve F 6,821 5,880 3.476 4.000 Top of Blank Pipe 7,599 5,981 3.476 4.000 Bottom of Blank Pipe 7,599 5,981 3.476 4.870 Top of Baker Excluder 2000 screens 8,662 6,012 3.476 4.870 Bottom of Baker Excluder 2000 screens 8,662 6,012 3.476 4.870 Top of BakerWeld screens 10,017 6,029 3.476 4.870 Bottom of BakerWeld screens G 10,045 6,029 2.260 5.000 Wellbore Isolation Valve 10,050 6,029 5.070 Round Nose Float Shoe TD:10,050 MD / 6,029 TVD 30 RKB: MSL = 160 RKB to Seafloor 345 F 2 3 4 E 5 6 A B Punch 5010 5015 (sqz) 13-3/8 9-5/8 Punch 4600 1 TOC 6300 MD, CBL Punch 5315 C D 9-5/8 DV tool at 3995 G 8-1/2 Open Hole D-4 (sqz) D-4 Lwr (sqz) X FLCV X XN CASING DETAIL Size Wt Grade Conn ID Top Btm 34 x 30 Conductor 30 Surf 450 13-3/8 68 L-80 BTC 12.415 Surf 1,292 9-5/8 47 L-80 DWC/C 8.681 Surf 6,998 TUBING DETAIL 4-1/2 12.6 L-80 Supermax 3.998 Surf 4,664 4-1/2 12.6 L-80 Supermax 3.998 5,810 6,795 4 Blank Pipe 11 P-110 Seal Lock HT 3.476 6,821 7,599 4 Screens 11 P-110 Seal Lock HT 3.476 7,599 10,050 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status D sands ±4,650 ±5,280 ±4,535 ±5,025 Proposed D4 4,887 4,907 4,713 4,730 20Squeezed D4 Lower 4,964 4,984 4,776 4,792 20Squeezed PRODUCTION LATERAL DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status D-6 7,969 10,050 5,992 6,029 2,081 10/09/21 Isolated JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 74.30 74.30 Hanger 1 454 454 3.813 5.965 SSSV Halliburton NE TRSV Slim 2 4,494 4,368 3.980 8.250 DLH Retrievable Packer (58k release) 3 4,607 4,471 3.980 8.250 DLH Retrievable Packer (58k release) 4 4,625 4,487 3.950 5.190 X-Nipple 5 5,288 5,027 9-5/8 Cement Retainer 6 5,530 5,186 9-5/8 CIBP GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 1,628 1,625 3.95820 Dome 784 10/14/2021 2 2,729 2,680 3.95820 Dome 758 10/14/2021 3 4,448 4,325 3.95824 Orifice 10/14/2021 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.) 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Λϲ͕ϲϲϭ͕WKK,ŶŽƌĞĐŽǀĞƌǇ͘ZŝŐĚŽǁŶWŽůůĂƌĚƐůŝĐŬůŝŶĞ͘ůĞĞĚϰϴϬƉƐŝƚƵďŝŶŐƉƌĞƐƐƵƌĞƚŽƉƌŽĚƵĐƚŝŽŶƚŽŚĞĂĚĞƌ ƉƌĞƐƐƵƌĞŽĨϳϱƉƐŝ͘ZŝŐƵƉƚŽĐŝƌĐƵůĂƚĞĚŽǁŶĂŶŶƵůƵƐƚĂŬŝŶŐƌĞƚƵƌŶƐƚŽƉƌŽĚƵĐƚŝŽŶ͘WƵŵƉŝŶŐϲй<>ĚŽǁŶƚƵďŝŶŐ͕ ďĂƚĐŚŵŝǆŝŶŐ<>ĂŶĚƐŚŝƉƉŝŶŐƚŽƌŝŐƉŝƚƐ͘WƵŵƉϰϯϬďďůŶŽĨůƵŝĚƌĞƚƵƌŶƐƚŽƐƵƌĨĂĐĞ͕ĐŝƌĐƉƌĞƐƐƵƌĞϱϬϬƉƐŝĂƚϮ͘ϱ ďƉŵ͘ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ ,<ϰϬϰ ϵͬϮϳͬϮϭ &ƵƚƵƌĞ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ϱϬͲϳϯϯͲϮϬϲϴϭͲϬϬͲϬϬ ϮϭϴͲϬϮϳ tĞůůEĂŵĞ DͲϮϮ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ϬϵͬϯϬͬϮϬϮϭͲdŚƵƌƐĚĂǇ ŽŶƚ͘ĐŝƌĐƵůĂƚŝŶŐϲй<>ΛϮ͘ϱWD͕ƉƵŵƉƚŽƚĂůŽĨϱϮϱďďůƐ͕;ΕϱϱďďůƐŽǀĞƌŚŽůĞǀŽůƵŵĞͿƐƵƌĨĂĐŝŶŐŶŽƌĞƚƵƌŶƐ͘ ^ŚƵƚĚŽǁŶΘŵŽŶŝƚŽƌĞĚƉƌĞƐƐƵƌĞƐ͕ďƵŝůƚΘĨŝůůĞĚƐƵƌĨĂĐĞƚĂŶŬƐǁͬϲй<>͕ĚŝƐĐƵƐƐĞĚŽƉƚŝŽŶƐǁŝƚŚĞŶŐŝŶĞĞƌ͘ ĞĐŝƐŝŽŶŵĂĚĞƚŽƉƵůůtͬ>ƉůƵŐΘDŽďĞŽƵƚͲůŝŶĞƚŽƐĞƚ/WŝŶƚƵďŝŶŐ͕/ƉƌĞƐƐƵƌĞĐĂŵĞƵƉƚŽϯϱϱƉƐŝ͕ƚƵďŝŶŐ ƚͬϵϴƉƐŝ͕ďůĞĞĚ/ƚŽϵϬƉƐŝΘdƵďŝŶŐƚŽϱϬW^ŝ͘Zͬhǁͬů͕ŵĂĚĞƵƉĞƋƵĂůŝǌĞƌƉƌŽŶŐ͘Z/,ǁͬĞƋƵĂůŝǌĞƌƉƌŽŶŐƚͬϲϲϲϮΖ ĞƋƵĂůŝǌĞƉƌĞƐƐƵƌĞ͕WKK,͘Z/,ǁͬ'^ƚͬϲϲϲϮΖ͕ůĂƚĐŚΘƉƵůůƐƚŽƉ͘Z/,ǁͬ'^ƚͬϲϲϲϯΖ͕ĂƚƚĞŵƉƚƚŽůĂƚĐŚƉĂĐŬͲŽĨĨ ƉůƵŐ͕ƵŶĂďůĞƚŽůĂƚĐŚ͕WKK,ƐŚĞĂƌĞĚ͕ƌĞͲƉŝŶ'^͘Z/,ǁͬ'^ƚͬϲϲϲϯΖ͕ůĂƚĐŚƉĂĐŬͲŽĨĨƉůƵŐ͕ĂƚƚĞŵƉƚƚŽũĂƌĨƌĞĞϭ 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tĞůůWĞƌŵŝƚEƵŵďĞƌ ϱϬͲϳϯϯͲϮϬϲϴϭͲϬϬͲϬϬ ϮϭϴͲϬϮϳ tĞůůEĂŵĞ DͲϮϮ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ϭϬͬϬϯͬϮϬϮϭͲ^ƵŶĚĂǇ ŽŶƚ͘WKK,ǁͬĞͲůŝŶĞ͘ZͬƐĂŵĞ͘ůĞĂƌĨůŽŽƌ͘WƵůůŚĂŶŐĞƌƚŽĨůŽŽƌƵƉǁƚϳϴŬ͕ĚŶǁƚϲϯŬ͕ůͬĚŚĂŶŐĞƌ͕ƉƌĞƉƚŽůͬĚϰ ϭͬϮΗƐƵƉĞƌŵĂǆĐŽŵƉůĞƚŝŽŶ͘WKK,ůͬĚϰϭͬϮΗƐƵƉĞƌŵĂǆĐŽŵƉůĞƚŝŽŶƚͬϰϳϮϬΖ͕ĨŝůůŝŶŐϭϬďůƐĞǀĞƌǇϭϱũŽŝŶƚƐ͘ZĞƐƉŽŶĚ ƚŽŐĂƐĂůĂƌŵ͕ĐŚĞĐŬǁĞůů͕ŶŽĨůŽǁ͕ƐĞĐƵƌĞǁĞůů͕ΘŵƵƐƚĞƌǁŚŝůĞƉƌŽĚƵĐƚŝŽŶĐŚĞĐŬĞĚĂƌĞĂΘĐůĞĂƌĞĚĂůĂƌŵ͘ŝƌĐƵůĂƚĞ ŚŽůĞǀŽůƵŵĞ͕Λϰ͘ϱďƉŵ͕ϭϭϱƉƐŝ͘ƐŚƵƚĚŽǁŶ͕ŶŽƌĞƚƵƌŶƐ͕ΘŽŶǀĂĐ͘ŽŶƚ͘WKK,ůͬĚϰϭͬϮΗƚƵďŝŶŐĨͬϰϳϮϬΖƚͬϮ͕ϯϲϯΖ͘ ŽŶƚ͘WKK,ůĂǇŝŶŐĚŽǁŶϰϭͬϮΗƉƌŽĚƵĐƚŝŽŶƚƵďŝŶŐƚŽƐƵƌĨĂĐĞ͘ZĞĐŽǀĞƌĞĚƚŽƚĂůϭϴϰ:ƚƐ͕ϱ'>D͘ƵƚŽĨĨũŽŝŶƚс ϭϴ͘ϮϱΖ͘^ƉŽƚĂŶĚƌŝŐƵƉůĂƐŬĂͲůŝŶĞƵŶŝƚ͘Z/,ǁŝƚŚϴ͘ϮϲϴΗŐĂŐĞƌŝŶŐͬ:ƵŶŬďĂƐŬĞƚƚŽϱ͕ϭϬϬΖ͕ƐĞƚĚŽǁŶĂŶĚ ŽďƐĞƌǀĞĚŽǀĞƌƉƵůůƐ͘WKK,͕ŝŶƐƉĞĐƚƚŽŽůƐ͕ƚŽŽůƐĚƌǇ͕ĐŚĞĐŬũƵŶŬďĂƐŬĞƚ͕ŶŽƐŽůŝĚƐƌĞĐŽǀĞƌĞĚ͘Z/,ǁŝƚŚϴ͘ϮϲϴΗŐĂƵŐĞ ƌŝŶŐĂŶĚũƵŶŬďĂƐŬĞƚ͘ǁŽƌŬŐĂŐĞƌŝŶŐĨƌŽŵϱ͕ϭϬϬΖƚŽϱ͕ϱϱϬΖ͕WKK,ǁŝƚŚ'Zͬ:͕ŝŶƐƉĞĐƚĂŶĚĞŵƉƚǇďĂƐŬĞƚ͕ŶŽ ƌĞĐŽǀĞƌǇ͘ƌĞĂŬĚŽǁŶͲůŝŶĞŐĂŐĞƌŝŶŐƚŽŽůƐ͘ ϭϬͬϬϰͬϮϬϮϭͲDŽŶĚĂǇ tŽƌŬŽŶͲůŝŶĞƉĞƌƐŽŶŶĞůĐŚĂŶŐĞŽƵƚ͕ǁŽƌŬŽŶƌŝŐŵĂŝŶƚ͘ΘŚŽƵƐĞŬĞĞƉŝŶŐ͕ĨŝůůŚŽůĞΘĐĂůĐƵůĂƚĞĨůƵŝĚůŽƐƐĞƐΛϴϰ W,͘ZͬhĞͲůŝŶĞ͕Wͬh/W͕ƌŝŚƚͬϱϱϯϬΖΘƐĞƚƉůƵŐ͕ŐŽŽĚŝŶĚŝĐĂƚŝŽŶŽĨƐĞƚ͕WKK,͘KK,ǁŝƚŚǁŝƌĞďƵƚŶŽƚŽŽůƐ͕ ĂƉƉĞĂƌƐŝƚŵĂǇŚĂǀĞƉĂƌƚĞĚĂƚƌŽƉĞƐŽĐŬĞƚ͘&ŝůůŚŽůĞΘƌŝŐƵƉƚŽƚĞƐƚ/W͘dĞƐƚ/WƐĞƚΛϱ͕ϱϯϬΖƚŽϭ͕ϲϬϬƉƐŝĨŽƌϯϬ ŵŝŶŐŽŽĚ͘ZͬhĞͲůŝŶĞΘZ/,ǁͬ>ƚŽŽůƐ͘>ŽŐĨƌŽŵϱ͕ϱϯϬƚŽϯ͕ϳϳϬ͘ZŝŐŵĂŝŶƚĞŶĂŶĐĞĂŶĚĚĞƌƌŝĐŬŝŶƐƉĞĐƚŝŽŶǁŚŝůĞ ƚƌĂŶƐƉŽƌƚŝŶŐ<Ͳ>ŝŶĞƐĞƚƚŝŶŐƚŽŽůĨŝƐŚŝŶŐƚŽŽůƐĨƌŽŵ<ĞŶĂŝ͘WŝĐŬƵƉĂŶĚŵĂŬĞƵƉƐĞƚƚŝŶŐĨŝƐŚŝŶŐĂƐƐĞŵďůǇ͘ϰ ϭϭͬϭϲΗKKǀĞƌƐŚŽƚǁŝƚŚϭϭϭͬϭϲΗŐƌĂƉƉůĞΛϳ͘ϭϲΖůŽŶŐ͘Z/,ǁŝƚŚĨŝƐŚŝŶŐƚŽŽůƐ͕ƉŝĐŬŝŶŐƵƉϯϭͬϮΗWϭϭϬ͕ϭϮ͘ϵϱW,ϲ ǁŽƌŬƐƚƌŝŶŐƚŽϱ͕ϱϬϭΖ͘ϲϰ<ƵƉϱϮ<ĚŶǁƚ͘ZŝŐƵƉƚŽĐŝƌĐǁĞůůĨƌŽŵ&/tƚŽϲй<>͕ƌĞƚƵƌŶŝŶŐ&/tƚŽƉƌŽĚƵĐƚŝŽŶ͘ ϭϬͬϬϱͬϮϬϮϭͲdƵĞƐĚĂǇ ŝƐƉůĂĐĞ&/tǁŝƚŚϲй<>͕ƌŝŶŐƉƵŵƉƐŽŶΛϭ͘ϱWDΛϱϬϬƉƐŝ͕ƚĂŬŝŶŐƌĞƚƵƌŶƐƚŽƉƌŽĚƵĐƚŝŽŶ͕ƐƚĂŐĞƉƵŵƉƐƵƉƚŽ Ϯ͘ϱďƉŵΛϭ͕ϬϬϬƉƐŝ͕&WнϮ͘ϲďƉŵΛϭ͕ϭϰϬƉƐŝ͘tŽƌŬŽǀĞƌĨŝƐŚƚŽϱ͕ϲϭϬΖ͘ƌĞĂŬĚŽǁŶĐŝƌĐƵůĂƚŝŶŐƚŽŽůƐ͕ĐŚĞĐŬ ĐƌŽǁŶŽͲŵĂƚŝĐ͘WKK,ǁŝƚŚĨŝƐŚŝŶŐƚŽŽůƐ͕ďƌĞĂŬĚŽǁŶĨŝƐŚŝŶŐƚŽŽůƐ͕ͲůŝŶĞƌĞĐŽǀĞƌǇϭϳ͘ϭϬΖďĞůŽǁŽǀĞƌƐŚŽƚ͘ZĞƚΛ ϱ͕ϲϮϳΖĚƉŵ͘ZĞŵŽǀĞƐƚƌŝƉƉŝŶŐŚĞĂĚ͕ŝŶƐƚĂůůƐŚŽŽƚŝŶŐĨůĂŶŐĞ͕ƌŝŐƵƉǁŝƌĞůŝŶĞ͕ƚĞƐƚůƵďϮϱϬͬϮ͕ϱϬϬƉƐŝ͕'ŽŽĚ͘Z/, ǁŝƚŚͲ>ŝŶĞϰΖdŝƚĂŶŐƵŶƐ/ZͲϮϭϬϳͲϰϱϬϭϳ͘Ϭ,Dyϰ΀ϭϯ΁͘ŽƌƌĞůĂƚĞƚŽ>ůŽŐ͕ƐŚŽŽƚǁŝƚŚƚŽƉƐŚŽƚΛϱ͕ϯϭϱΖ ďŽƚƚŽŵƐŚŽƚΛϱ͕ϯϭϵΖǁŝƚŚϱϬϬƉƐŝŽŶĐĂƐŝŶŐ͕ŶŽďůĞĞĚŽĨĨ͕ƉƌĞƐƐƵƌĞƵƉƚŽϭ͕ϬϬϬƉƐŝ͕ƐĂŵĞƌĞƐƵůƚ͕ƉƌĞƐƐƵƌĞƵƉƚŽ ϭ͕ϱϬϬƉƐŝ͕ŶŽďůĞĞĚŽĨĨ͘WKK,ǁŝƚŚͲůŝŶĞ͘ůůƐŚŽƚƐĨŝƌĞĚ͘ZĞͲĚƌĞƐƐŐƵŶƐ͕WƌĞƐƐƵƌĞĐĂƐŝŶŐƚŽϮ͕ϱϬϬƉƐŝ͕ŶŽďůĞĞĚŽĨĨ͘ Z/,ǁŝƚŚϰΖdŝƚĂŶĐĂƐŝŶŐŐƵŶƐ͕ŽƌƌĞůĂƚĞƚŽ>ůŽŐ͕ĨŝƌĞŐƵŶƐǁŝƚŚƚŽƉƐŚŽƚΛϱ͕ϯϭϱΖǁŝƚŚϱϬϬƉƐŝŽŶǁĞůů͕ƉƌĞƐƐƵƌĞ ĚƌŽƉƉĞĚƚŽϭϬϬƉƐŝǁŚĞŶƐŚŽƚ͕ƉƵŵƉϭ͘ϱďďůΛ͘ϱďƉŵΛϰϬϬƉƐŝ͘WKK,ǁŝƚŚĐĂƐŝŶŐŐƵŶƐ͘ƌĞƐƐͲůŝŶĞƚŽŽůƐǁŝƚŚ dŝƚĂŶĐĂƐŝŶŐŐƵŶƐ͕Z/,ĐŽƌƌĞůĂƚĞƚŽ>ƐŚŽŽƚǁŝƚŚƚŽƉƐŚŽƚΛϰ͕ϲϬϬďŽƚƚŽŵƐŚŽƚΛϰ͕ϲϬϰΖĐďů͘WKK,͕ůĂǇĚŶŐƵŶƐ͘ ,ŽůĞƐƚĂŶĚŝŶŐĨƵůů͘ŚĂŶŐĞŽƵƚůƵďƌŝĐĂƚŽƌƚŽϳΗ͕dĞƐƚƚŽϭ͕ϱϬϬƉƐŝ͕ŐŽŽĚ͘DĂŬĞƵƉƌĞƚĂŝŶĞƌƐĞƚƚŝŶŐƚŽŽůƐ͕Z/,ǁŝƚŚ dƌŝƉŽŝŶƚϵϱͬϴΗŵƚ͘ƌĞƚĂŝŶĞƌ͕ĐŽƌƌĞůĂƚĞƚŽ>ƐĞƚĂƚϱ͕ϯϬϬΖ͕WKK,͘ZŝŐĚŽǁŶůĂƐŬĂͲ>ŝŶĞ͘EŝƉƉůĞĚŽǁŶƐŚŽŽƚŝŶŐ ĨůĂŶŐĞ͕ŶŝƉƉůĞƵƉƐƚƌŝƉƉĞƌƐƉŽŽů͘ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ ,<ϰϬϰ ϵͬϮϳͬϮϭ &ƵƚƵƌĞ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ϱϬͲϳϯϯͲϮϬϲϴϭͲϬϬͲϬϬ ϮϭϴͲϬϮϳ tĞůůEĂŵĞ DͲϮϮ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ϭϬͬϬϲͬϮϬϮϭͲtĞĚŶĞƐĚĂǇ ŽŶĨŝƌŵƉĞƌĨƐĂďŽǀĞƌĞƚĂŝŶĞƌΛϰ͕ϲϬϬ͕ƉƵŵƉŝŶƚŽǁĞůů͕ƉƵŵƉĞĚĂǁĂǇĂƚ͘ϱWD͕ΛϱϬϬƉƐŝ͘DĂŬĞƵƉĐĞŵĞŶƚ ƐƚŝŶŐĞƌĂƐƐĞŵďůǇ͘Z/,ǁŝƚŚϯϭͬϮΗǁŽƌŬƐƚƌŝŶŐ͕ĚƌŝĨƚŝŶŐǁŝƚŚϮ͘ϳϱΗĚƌŝĨƚƚŽϰ͕ϭϬϲΖ͘ŽŶƚŝŶƵĞZ/,ǁŝƚŚƐƚŝŶŐĞƌ͕ ĚƌŝĨƚŝŶŐƉŝƉĞĨƌŽŵĚĞƌƌŝĐŬƚͬϱ͕ϮϴϴΖĚƉŵ͕ƚĂŐƌĞƚĂŝŶĞƌ͕ƐĞƚϮϬ<ŽŶƌĞƚĂŝŶĞƌ͕ϲϬ<ƵƉϰϴ<ĚŶ͘ZŝŐƵƉƚŽĐŝƌĐ͕ĐŝƌĐůŽŶŐ ǁĂǇƵŶƚŝůƉůƵŐŐĞĚŽĨĨĂŶĚƌĞǀĞƌƐĞƚŝůůŝƚƉůƵŐƐŽĨĨ͕ƌŽĐŬŝŶŐďĂĐŬĂŶĚĨŽƌƚŚƚŽĞƐƚĂďůŝƐŚĐŝƌĐƵůĂƚŝŽŶ͘ŝƌĐůŽŶŐǁĂǇ ƵŶƚŝůƉůƵŐŐĞĚŽĨĨ͕ƌŽĐŬŝŶŐƐǁŝƚĐŚŝŶŐƚŽƌĞǀĞƌƐŝŶŐ͕ĂŶŶƵůƵƐĂƚƚĞŵƉƚŝŶŐƚŽĐůĞĂƌKďĞƚǁĞĞŶƉĞƌĨƐƚŽĐĞŵĞŶƚ͘ ƐƚĂďůŝƐŚĐŝƌĐƵůĂƚŝŽŶĂƚϭďƉŵůŽŶŐǁĂǇΛϱϱϬƉƐŝ͕ĐŝƌĐĂŶŶƵůĂƌďŽƚƚŽŵƐƵƉ͕ŝŶĐƌĞĂƐĞƉƵŵƉƌĂƚĞƚŽϭ͘ϱďƉŵ͕ ƉƌĞƐƐƵƌĞŝŶĐƌĞĂƐĞĚƚŽϳϱϬƉƐŝ͕ďƌŽŬĞďĂĐŬƚŽϲϱϬƉƐŝ͘ĐŝƌĐĂŶŶƵůĂƌďŽƚƚŽŵƐƵƉ͕ŝŶĐƌĞĂƐĞƚŽϭ͘ϳϱWD͕ƉĂĐŬĞĚŽĨĨ͕ ůŽƐƐƌĞƚƵƌŶƐ͕ƌŽĐŬĨƌŽŵůŽŶŐƚŽƌĞǀĞƌƐĞĐŝƌĐ͕ĂĚũƵƐƚŝŶŐƉƵŵƉƌĂƚĞĂƐŶĞĞĚĞĚƚŽŵĂŝŶƚĂŝŶĐŝƌĐƵůĂƚŝŽŶ͘ŽŶƚŝŶƵĞ ĐŝƌĐƵůĂƚĞKƚŚƌŽƵŐŚƉĞƌĨƐƚŽĐůĞĂŶĨŽƌĐĞŵĞŶƚ͘/ŶĐƌĞĂƐŝŶŐƉƵŵƉƌĂƚĞƐĂƐƉĞƌĨƐĂůůŽǁ͕Λϭ͘ϱďƉŵсϱϮϱƉƐŝǁŝƚŚ ůŽƐƐĞƐнͲϭϳй͘ ϭϬͬϬϳͬϮϬϮϭͲdŚƵƌƐĚĂǇ ŽŶƚŝŶƵĞĐŝƌĐƵůĂƚŝŶŐĐĂƐŝŶŐĂŶŶƵůƵƐƚŽĐůĞĂŶĨŽƌĐĞŵĞŶƚũŽď͘DĂǆƌĂƚĞĂĐŚŝĞǀĞĚϮ͘ϱďƉŵ͕Λϭ͕ϬϬϵƉƐŝ͘ƉůƵŐŐĞĚŽĨĨ͕ ĂůƚĞƌŶĂƚĞĐŝƌĐĂŶĚƌĞǀĞƌƐĞĐŝƌĐĂƚůŽǁĞƌƌĂƚĞƐƚŽŵĂŝŶƚĂŝŶĐŝƌĐƵůĂƚŝŽŶ͘ŽŶƚŝŶƵĞĐŝƌĐƵůĂƚŝŶŐĐĂƐŝŶŐĂŶŶƵůƵƐƚŽĐůĞĂŶ 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tĞůůWĞƌŵŝƚEƵŵďĞƌ ϱϬͲϳϯϯͲϮϬϲϴϭͲϬϬͲϬϬ ϮϭϴͲϬϮϳ tĞůůEĂŵĞ DͲϮϮ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ϭϭͬϮϳͬϮϬϮϭͲ^ĂƚƵƌĚĂǇ ƌĞǁĂƐƐĞŵďůĞƐĂŶĚŽďƚĂŝŶƐƉĞƌŵŝƚƐ͕d'^D͘^ƉŽƚĞͲůŝŶĞĞƋƵŝƉŵĞŶƚŽŶDͲϮϮ͘WƌĞƐƐƵƌĞƚĞƐƚůƵďƌŝĐĂƚŽƌƚŽϮϱϬƉƐŝ ůŽǁͬϭϱϬϬƉƐŝŚŝŐŚ͘ƌŵĂŶĚZ/,ǁŝƚŚϮϬΖϯͲϯͬϴΗ,ŐƵŶ͘ŽƌƌĞůĂƚĞƚŽŽƉĞŶŚŽůĞůŽŐĂŶĚƐĞŶĚƚŽƚŽǁŶĨŽƌ ĐŽƌƌĞĐƚŝŽŶ͘DĂŬĞĐŽƌƌĞĐƚŝŽŶ;нϯΖͿĂŶĚƉĞƌĨŽƌĂƚĞϰ>ŽǁĞƌĨƌŽŵϰϵϲϰͲϰϵϴϰΖ͘^/dWƐƚĂǇŝŶŐĨůĂƚĂƚϴϮϬƉƐŝ͘WKK,͘ ƌĞĂŬŽĨĨĨƌŽŵƌŝƐĞƌĂŶĚůĂǇĚŽǁŶŐƵŶ͘ůůƐŚŽƚƐĨŝƌĞĚ͘ƌŵĂŶĚZ/,ǁŝƚŚϮϬΖϯͲϯͬϴΗ,ŐƵŶ͘ŽƌƌĞůĂƚĞƚŽŽƉĞŶŚŽůĞ ůŽŐƐĂŶĚƐĞŶĚƚŽƚŽǁŶĨŽƌĐŽƌƌĞĐƚŝŽŶ͘KŶĞƉƚŚ͘WĞƌĨŽƌĂƚĞϰĨƌŽŵϰϴϴϳͲϰϵϬϳΖ͘^/dWĨůĂƚĂƚϴϮϮƉƐŝ͘WKK,͘ƌĞĂŬ ŽĨĨĨƌŽŵƌŝƐĞƌĂŶĚůĂǇĚŽǁŶŐƵŶ͘ůůƐŚŽƚƐĨŝƌĞĚ͘ZŝŐĚŽǁŶĞͲůŝŶĞĂŶĚƚƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶ͘WƌĞƉĂƌĞƚŽ ŵŽďŝůŝǌĞƚŽĞůƵŐĂ͘ Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 12/29/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL TBU M-22 (PTD 218-027) Perforation Record 11/27/2021 Please include current contact information if different from above. 37' (6HW Received By: 12/29/2021 By Abby Bell at 12:57 pm, Dec 29, 2021 1 Guhl, Meredith D (CED) From:McLellan, Bryan J (CED) Sent:Thursday, October 14, 2021 12:19 PM To:Katherine O'connor Cc:Juanita Lovett; Wade Hudgens - (C); Regg, James B (CED) Subject:RE: M-22 PTD: 218-027 RWO Sundry Katherine, You are correct. You do not need to test the lower packer and squeezed perfs between packers because those are in the same pool as the other proposed perfs. You can proceed with testing the upper packer and completion according to your original plan, which includes a MIT‐T and combo MIT TxIA to 1500 psi. You still need to provide the AOGCC inspectors 48 hrs notice to witness these tests. I’ve copied Jim Regg so that he can pass the message to his inspectors if they decide to witness these tests. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250‐9193 From: Katherine O'connor <Katherine.Oconnor@hilcorp.com> Sent: Thursday, October 14, 2021 12:04 PM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Cc: Juanita Lovett <jlovett@hilcorp.com>; Wade Hudgens ‐ (C) <whudgens@hilcorp.com> Subject: M‐22 PTD: 218‐027 RWO Sundry Hey Bryan As we discussed on the phone, testing the casing below the packer is not necessary as all the perforations are within the same pool (step 16e). We would like to go forward with the original plan to test the tubing & casing against the plug when setting the packer (steps 16a‐d). Thanks! Katherine The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Reviewed By: P.I. Supry 16MZ-_�Z,I BOPE Test Report for: TRADING BAY UNIT M-22 - Comm Contractor/Rig No.: Hilcorp 404 ' PTD#: 2180270 DATE: 10/9/2021 Inspector Austin McLeod - Insp Source Operator: Hilcorp Alaska, LLC Operator Rep: Ed Hooter Rig Rep: Chad Johnson Inspector Type Operation: WRKOV Sundry No: Test Pressures: Inspection No: bopSAM21101208t328 Rams: Annular: Valves: MASP: Type Test: WKLY 321-445 -- ---- - --- — Related [ns No: 250/3000 250/3000 - 250/3000 - 578 p TEST DATA MISC. INSPECTIONS: MUD SYSTEM: P/F ACCUMULATOR SYSTEM: _ 0 _ NA P/F 0 Visual Alarm Ball Type Time/Pressure P/F Location Gen.: -P_ Trip Tank NA NA System Pressure 3000 P Housekeeping: P Pit Level Indicators P P Pressure After Closure 2100 P PTD On Location P Flow Indicator NA NA ' 200 PSI Attained 35 P Standing Order Posted P Meth Gas Detector P P Full Pressure Attained 181 P Well Sign P H2S Gas Detector P P ' Blind Switch Covers: All stations P ' Drl. Rig - P MS Misc NA NA Nitgn. Bottles (avg): -_1900 _-" P - Hazard Sec. P "_ NA Kill Line Valves 2 2-1/16 ACC Misc 0 NA Misc NA 0 NA BOP Misc FLOOR SAFTY VALVES: Number of Failures: 0 Remarks: 3-1/2 & 4-1/2 joints. BOP STACK: Quantity P/F Upper Kelly _ 0 _ NA Lower Kelly 0 NA Ball Type - 3 - _P - Inside BOP 1, P FSV Misc 0 NA Number of Failures: 0 Remarks: 3-1/2 & 4-1/2 joints. BOP STACK: CHOKE MANIFOLD: Quantity Size P/F Quantity P/F Stripper 0 NA No. Valves 11 P Annular Preventer -1 13-5/8 - - P Manual Chokes -- 1 P #1 Rams --1 '_2-7/80-1/2 P _ _ Hydraulic Chokes I P #2 Rams I " Blinds P CH Misc 0 NA #3 Rams 0 _ NA _ #4 Rams 0 NA #5 Rams 0 _ NA INSIDE REEL VALVES: #6 Rams 0 NA (Valid for Coil Rigs Only) Choke Ln. Valves 1 2-1/16 P Quantity P/F HCR Valves _ -2 2-1/16 P - Inside Reel Valves 0- NA Kill Line Valves 2 2-1/16 P " Check Valve 0 NA BOP Misc 0 NA Test Results Test Time 4 From:Katherine O"connor To:McLellan, Bryan J (OGC) Cc:Juanita Lovett; Davies, Stephen F (OGC); Aras Worthington Subject:RE: [EXTERNAL] Re: M-22 PTD: 218-027 RWO Sundry Date:Thursday, October 7, 2021 8:41:25 AM Attachments:image002.png image003.png Hey Bryan Thank you. All the perforations are within the same pool. Governed by CO228 & 228A We’re still have circulation through the perforations, albeit at a low rate, so are still trying to clean the hole enough to be confident in the ability to cement. Thanks Katherine From: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Sent: Wednesday, October 6, 2021 4:47 PM To: Katherine O'connor <Katherine.Oconnor@hilcorp.com> Cc: Juanita Lovett <jlovett@hilcorp.com>; Davies, Stephen F (CED) <steve.davies@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com> Subject: RE: [EXTERNAL] Re: M-22 PTD: 218-027 RWO Sundry Katherine, You have approval to continue with your remedial cementing attempts through the block squeeze at 5010’, but we will need to ensure your cementing plan is adequate to isolate between perf intervals if multiple pools will be open. Can you tell me where the pool boundaries are in this well? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Katherine O'connor <Katherine.Oconnor@hilcorp.com> Sent: Wednesday, October 6, 2021 1:23 PM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Cc: Juanita Lovett <jlovett@hilcorp.com> Subject: RE: [EXTERNAL] Re: M-22 PTD: 218-027 RWO Sundry Hey Bryan Sorry was just sending that for a general visual aid. Attached is a copy of the CBL. Aras came a talked about how to handle sundry changes going forward. Thanks for understanding. Currently we are running in hole to sting into the retainer and attempt to get circulation. If we are unable to get circulation across the entire zone (or it plugs off during circulation), we will swap to doing 2-3 different block squeezes in an attempt to isolate the gas sands from the water drive sands. We will know whether we have circulation sometime late this evening. Below is the basic procedure for your approval: Attempt to get injection into lower perforations at ±5300’ MD. If the rig can get injection, then inject ±20 bbls of cement to isolate lower zone for a block squeeze POOH Move uphole and punch at ±5010-5015’ MD, to try and isolate upper three reservoir zones Set retainer at ±4995’ MD Attempt to get circulation from 5010’ MD to 4600’ MD If unable to get circulation across entire interval, attempt to inject into lower perfs at 5010’ MD Block squeeze lower zones with ±20bbls of cement Move uphole, attempt to inject into upper most perforations at 4600’ MD If you can inject, block squeeze perforations w/ ±20bbls of cement WOC to gain 500 psi compressive strength Mill out extra plugs/retainers, leaving deepest one downhole. Continue to step 14 of sundry. Thank you Katherine From: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Sent: Wednesday, October 6, 2021 12:15 PM To: Katherine O'connor <Katherine.Oconnor@hilcorp.com> Cc: Juanita Lovett <jlovett@hilcorp.com> Subject: RE: [EXTERNAL] Re: M-22 PTD: 218-027 RWO Sundry Hi Katherine I can’t really read the CBL. It’s way too blurry. Could you send it in a file instead of screenshot? Are you requesting any approvals here? Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Katherine O'connor <Katherine.Oconnor@hilcorp.com> Sent: Wednesday, October 6, 2021 10:41 AM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Cc: Juanita Lovett <jlovett@hilcorp.com> Subject: RE: [EXTERNAL] Re: M-22 PTD: 218-027 RWO Sundry Hey Bryan We ran the CBL to see if there was fill and based on the results I shrunk the interval we want to submit from ~4100’ – 5450’ MD to 4600’ MD - 5315’ MD. Overall there didn’t look to be too much sloughing behind pipe, but the CBL got notably messier below ~5200’ MD. These new punches still give us cement coverage for all the intended reservoir perforations. Cement retainer is now set at 5300’ MD. Screenshot of CBL, with overlay of intended perf zones (purple) and casing punches (red). Thanks Katherine From: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Sent: Saturday, October 2, 2021 9:07 AM To: Katherine O'connor <Katherine.Oconnor@hilcorp.com> Subject: [EXTERNAL] Re: M-22 PTD: 218-027 RWO Sundry Sounds good. Sent from my iPhone On Oct 1, 2021, at 8:51 AM, Katherine O'connor <Katherine.Oconnor@hilcorp.com> wrote: Hi Bryan Quick update for a small change to sundry 321-445. Slickline was unable to pull the GLV to get circulation in the well (step 1.c) so EL rigged up and punched the tubing @ 6582’ MD. We will also be circulating with FIW now in case we are unable to keep the hole full. We will swap to 6% KCl before we punch holes in the casing to cement (do not want anything but KCl to touch reservoir sands). Circulating the well now to RU BOPs. Thanks Katherine O’Connor CIO Operations Engineer Katherine.oconnor@hilcorp.com W: (907) 777-8376 C: (214) 684-7400 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received thismessage 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 phonenumber 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 toensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect itssystems or data. No responsibility is accepted by the company in this regard and the recipient should carry out suchvirus and other checks as it considers appropriate. <10-403 Trading Bay Unit M-22 - Approved - Sundry_321-445_091021.pdf> The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic Service 6.API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): McArthur River Field / Middle Kenai Gas Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10,050'N/A Casing Collapse Structural Conductor Surface 2,260 psi Intermediate Production 4,760 psi Liner 7,500 psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:Katherine.oconnor@hilcorp.com Contact Phone: (907) 777-8376 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Other: G/L Completion / N2 Operations 6,030'10,045'6,029'578 psi 3,264'4-1/2" 5,921'9-5/8" 10,050'6,030' 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. 9/21/2021 4-1/2" Daniel E. Marlowe See schematic 6,998' Perforation Depth MD (ft): 7,969 - 10,050 6,998' See schematic Tubing Grade:Tubing MD (ft): 5,992 - 6,029 Perforation Depth TVD (ft): 30" 13-3/8" 450' 1,292' 450' 1,291' 450' 1,292' 12.6 / L-80 & 11 / P-110 TVD Burst 10,050' 6,870 psi 8,430 psi Tubing Size: MD 5,020 psi 218-027 50-733-20681-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC Trading Bay Unit M-22 CO 228A COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018730 Authorized Signature: Operations Manager Katherine O'Connor PRESENT WELL CONDITION SUMMARY Length Size N/A Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Meredith Guhl at 11:41 am, Sep 03, 2021 321-445 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.09.03 11:31:38 -08'00' Dan Marlowe (1267) DSR-9/3/21 Rig 404 BOP test to 3000 psi CT BOP test to 3000 psi. X BJM 9/10/21 Combo MIT TxIA and MIT-T (steps 16.c and 16.e) to 1500 psi - Provide AOGCC 48 hrs notice to witness. X DLB 09/03/2021 X 10-404 dts 9/10/2021 JLC 9/10/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.10 15:29:40 -08'00' RBDMS HEW 9/13/2021 Well Work Prognosis Well Name:Trading Bay Unit M-22 API Number:50-733-20681-00-00 Current Status:Shut In Gas Producer Leg:Leg A2 Estimated Start Date:9/21/21 Rig:HAK 404 / Coil Tubing Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett Permit to Drill Number:218-027 First Call Engineer:Katherine O’Connor Office: 907-777-8376 Cell: 214-684-7400 Second Call Engineer:Karson Kozub Office: 907-777-8434 Cell: 907-570-1801 Estimated Bottom Hole Pressure:675 psi @ 5,992’ TVD Based upon current SITP in M-22 Maximum Expected BHP:1,048 psi @ 4,692’ TVD Based on 2018 RFT data from M-22 Maximum Potential Surface Pressure: 578 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Well History: M-22 is a grassroots well drilled in 2018 targeting the D6 sands. It was completed as a 4.5” gas producing gas lifted well. The well was not successful and only ever produced ~300 scfs for 2 months cumulatively. It has not produced or been online since late 2018. The objective of this program is to recomplete the well uphole into the shallower Grayling gas sands around 4400’ – 5400’ MD. Per the CBLs run during drilling in 2018, there is no cement behind casing at these depths due to the original cement job plugging off. In recompleting this well, a remedial cement job will be attempted, and then a 4-1/2” gas lift completion re-run. Last Casing Test: x 9-5/8” casing tested to 3500 psi under PTD 218-027 Safety Concerns: x Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. x Consider tank placement based on wind direction and current weather forecast (venting methane and Nitrogen during this job) x Ensure all crews are aware of stop job authority (Review Standard Well Procedure – Nitrogen Operations) top MD bot MD Size ID bbls/ft. Ft. volume bbls 3-1/2” work string 3-1/2” 2.75” 0.007 9-5/8” casing 0 5500 9-5/8” 47# 8.681”0.073 5500 403 12.25” open hole x 9-5/8” annulus 4100’ (punch) 5450’ 9-5/8” 47# x 12.25” OH 9.625” 0.056 1350 76 9-5/8” casing x 3-1/2” work string 0 4100’ 3-1/2” WS x 9- 5/8” 47# 8.681” 0.061 4100 252 Procedure: 1. RU SL pressure test lubricator 250psi low/1,500psi high a. RIH and set TTP in X nipple at 6698’ MD (this plug is to assist circulation) b. Pressure test TTP with production gas to ensure it’s set c. Pull GLV from GLM #6 d. RD SL GLM #5 @ 6651' md? Well Work Prognosis 2. MIRU HAK 404 3. Circulate well with 6% KCl 4. Set BPV, ND Tree, NU BOPEs 5. Test BOPEs to 250psi low/3000psi high (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 6. Monitor well to ensure its static, pull BPV 7.RU EL pressure test lubricator 250psi low/1,500psi high a. RIH and make tubing cut above packer ±5800’ MD b. RD EL 8. Unseat hanger and pull tubing a. Laying down the SSSV and GLM’s b. Send jewelry to town to get inspected for re-run 9. RU Eline pressure test lubricator 250psi low/1,500psi high a. Set 9-5/8” CIBP ±5500’ MD. b. Fluid pack well with 6% KCL as needed c. PT CIBP to 1500 psi ensure hard bottom d. Run CBL from CIBP to ±3800’ MD to get a picture of what well looks like behind 9-5/8” casing e. Perf casing ±5450’ MD with big hole charges. Pump to verify injectivity. f. Monitor fluid levels - may see fluid losses from hydrostatic column in casing being greater than reservoir pressure g. Perf casing 4100’ MD. h. Set cement retainer at 5400’ MD. 10. RU HAL cement pumps a. Test lines to 250psi low/4,500psi high 11. RIH stinging into cement retainer. Attempt circulation using 6% KCl. Circulation path is down work string, up through casing & casing by work string backside. 12. Circulate minimum bottoms up volume (bottoms up volume is 366 bbls) tracking returns a. Pump at max rate, this will help clean hole with minimal fallout b. 730 bbls FIW (this is 2x bottoms up) c. 20 bbl fresh water spacer d. Pump ±161 bbl of cement TOC ±4100 MD (this is ~2x volume cement needed) e. Work string volume water f. Unsting with ~11 bbls of cement in WS to lay on top of cement retainer g. Slowly pick up above cement and circulate clean (leaving ~11 bbls of cement on top of retainer as plug), circulating excess cement to surface 13. WOC to gain >500 psi of compressive strength 14. RU E-line CBL Logging tool. RIH and Log 5200’ MD - TOC. 15. RIH with 4-1/2” gas lift completion (live valves), SSSV, plug, and two packers (will straddle upper tubing punch). See proposed schematic for details and set depths. 16. Set Packer / Pressure test completion: a. Pressure up and set packers b. Test tubing against plug in X nipple to ш1,500psig and chart for 30 minutes. c. Test IA to 1,500 psi and chart for 30 minutes (This will pressure up tubing also). d. Pull prong and plug in X-Nipple. 17. Set BPV. NU tree, test same. 18. RD HAK 404 19. MIRU Coil tubing 20. Test BOP’s to 250psi low/3000psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). a. Blow the well dry with N2 b. Returns taken to the production header Test 16.b not req'd by AOGCC since test 16.e will test tbg. Log up to at least 3800' md. bjm 16.e. Pressure test tubing, pkr and casing below packer to 1500 psi for 30 min. Chart and provide AOGCC inspectors 48 hrs notice to inspect. - bjm Well Work Prognosis c. RD Coil tubing 21. RU E-line and perforate per program. 22. Turn over to production. 23. Schedule SVS testing with AOGCC as per regulations Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Wellhead Diagram 4. BOP Stack 5. Standard Well Procedure – Nitrogen Operations 6. Flow Diagrams 7. Coil Tubing BOP stack 8. BOP Test procedure 9. RWO Sundry Revision Change Form _____________________________________________________________________________________ Updated By: MJQ 1/14/2019 SCHEMATIC McArthur River Field Well: M-22 Last Completed: 6/22/2018 PTD: 218-027 API: 50-733-20681-00 TD: 10,050’ MD / 6,029’ TVD 30” RKB: MSL = 160’ RKB to Seafloor 345’ 3 4 5 6 7 8 18/19 9/10 11 12 13 13-3/8” 9-5/8” 1 2 14 15 16 17 9-5/8” DV tool at 3995’ 8-1/2” Open Hole 13 114 15555 16 17 X XN FLCV CASING DETAIL Size Wt Grade Conn ID Top Btm 34” x 30” Conductor 30” Surf 450’ 13-3/8” 68 L-80 BTC 12.415” Surf 1,292’ 9-5/8” 47 L-80 DWC/C 8.681” Surf 6,998’ TUBING DETAIL 4-1/2” 12.6 L-80 Supermax 3.998” Surf 6,795’ 4” Blank Pipe 11 P-110 Seal Lock HT 3.476” 6,821’ 7,599’ 4” Screens 11 P-110 Seal Lock HT 3.476” 7,599’ 10,050’ PRODUCTION LATERAL DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status D-6 7,969’ 10,050’ 5,992’ 6,029’ 2,081’ 6/15/18 OH Screen Completion JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item Hanger 1 447’ 447’ 3.813” 5.965” SSSV – Halliburton NE TRSV Slim 2 1,649’ 1,646’ 3.958” 6.125” GLM #1 – SMO-1 3 3,099’ 3,031’ 3.958” 6.125” GLM #2 – SMO-1 4 4,389’ 4,270’ 3.958” 6.125” GLM #3 – SMO-1 5 5,547’ 5,200’ 3.958” 6.125” GLM #4 – SMO-1 6 6,651’ 5,789’ 3.958” 6.125” GLM #5 – SMO-1 7 6,698’ 5,811’ 3.810” 5.560” X-Nipple 8 6,741’ 5,831’ 3.725” 5.020” XN-Nipple (CAT Standing Valve removed 1/12/2019) 9 6,785’ 5,851’ 6.060” 7.360” 3.67’ of 7.375” tieback seals on 9.6’ seal assembly 10 6,786’ 5,851’ 7.380” 8.300” Baker UniFlex Pro Liner Hanger w/10’ Sealbore 7.380” ID 11 6,812’ 5,859’ 3.290” 5.820” Baker Fluid Loss Control Valve 12 6,821’ 5,880’ 3.476” 4.000” Top of Blank Pipe 13 7,599’ 5,981’ 3.476” 4.000” Bottom of Blank Pipe 14 7,599’ 5,981’ 3.476” 4.870” Top of Baker Excluder 2000 screens 15 8,662’ 6,012’ 3.476” 4.870” Bottom of Baker Excluder 2000 screens 16 8,662’ 6,012’ 3.476” 4.870” Top of BakerWeld screens 17 10,017’ 6,029’ 3.476” 4.870” Bottom of BakerWeld screens 18 10,045’ 6,029’ 2.260” 5.000” Wellbore Isolation Valve 19 10,050’ 6,029’ 5.070” Round Nose Float Shoe -00 DLB _____________________________________________________________________________________ Updated By: KO 09/02/21 PROPOSED McArthur River Field Well: M-22 Last Completed: FUTURE PTD: 218-027 API: 50-733-20681-00 Isolated Jewelry A 6651’ 5,789’ 3.958” 6.125” GLM #5 – SMO-1 B 6,698’ 5,811’ 3.810” 5.560” X-Nipple C 6,741’ 5,831’ 3.725” 5.020” XN-Nipple (CAT Standing Valve removed 1/12/2019) D 6,785’ 5,851’ 6.060” 7.360” 3.67’ of 7.375” tieback seals on 9.6’ seal assembly 6,786’ 5,851’ 7.380” 8.300” Baker UniFlex Pro Liner Hanger w/10’ Sealbore 7.380” ID E 6,812’ 5,859’ 3.290” 5.820” Baker Fluid Loss Control Valve F 6,821’ 5,880’ 3.476” 4.000” Top of Blank Pipe 7,599’ 5,981’ 3.476” 4.000” Bottom of Blank Pipe 7,599’ 5,981’ 3.476” 4.870” Top of Baker Excluder 2000 screens 8,662’ 6,012’ 3.476” 4.870” Bottom of Baker Excluder 2000 screens 8,662’ 6,012’ 3.476” 4.870” Top of BakerWeld screens 10,017’ 6,029’ 3.476” 4.870” Bottom of BakerWeld screens G 10,045’ 6,029’ 2.260” 5.000” Wellbore Isolation Valve 10,050’ 6,029’ 5.070” Round Nose Float Shoe TD: 10,050’ MD / 6,029’ TVD 30” RKB: MSL = 160’ RKB to Seafloor 345’ D-4 F 3 4 5 6 7 E 8 9 A B Cement 4100’ - 5800’ MD 13-3/8” 9-5/8” Punch 4100’ 1 2 TOC 6300’ MD, CBL Punch 5450’ C D 9-5/8” DV tool at 3995’ G 8-1/2” Open Hole D-4 Lwr D-7 D-2 X FLCV X XN CASING DETAIL Size Wt Grade Conn ID Top Btm 34” x 30” Conductor 30” Surf 450’ 13-3/8” 68 L-80 BTC 12.415” Surf 1,292’ 9-5/8” 47 L-80 DWC/C 8.681” Surf 6,998’ TUBING DETAIL 4-1/2” 12.6 L-80 Supermax 3.998” Surf ±4,600’ 4-1/2” 12.6 L-80 Supermax 3.998”±5,800’6,795’ 4” Blank Pipe 11 P-110 Seal Lock HT 3.476” 6,821’ 7,599’ 4” Screens 11 P-110 Seal Lock HT 3.476” 7,599’ 10,050’ PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status D4 ±4,867 ±4,907 ±4,697’ ±4,730’ ±40’ Future Proposed D4 Lower ±4,964 ±4,984 ±4,776’ ±4,792’ ±20’ Future Proposed D7 ±5,249 ±5,279 ±4,999’ ±5,021’ ±30’ Future Proposed D2 ±4,679 ±4,719 ±4,536’ ±4,571’ ±40’ Future Proposed PRODUCTION LATERAL DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status D-6 7,969’ 10,050’ 5,992’ 6,029’ 2,081’ 6/15/18 Isolated JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item Hanger 1 ±447’ ±447’ 3.813” 5.965” SSSV – Halliburton NE TRSV Slim 2 ±1,650’ ±1,647’ 3.958” 6.125” GLM #1 3 ±2,800’ ±2,748’ 3.958” 6.125” GLM #2 4 ±3,900’ ±3,795’ 3.958” 6.125” GLM #3 5 ±4,000’ ±3,892’ 3.990” Packer 6 ±4,500’ ±4,374’ 3.990” Packer 7 ±4,550’ ±4,420’ 3.810” 5.560” X-Nipple 8 ±5,400’ ±5,104’ 9-5/8” Cement Retainer 9 ±5,500’ ±5,168’ 9-5/8” CIBP -00 DLB Steelhead Platform M-22 BHTA, Bowen, 4 1/16 5M FE X 7'’-5SA Bowen top Valve, swab, WKM-M, 4 1/16 5M FE, HWO, T-24 Valve, lower master, WKM-M, 4 1/16 5M FE, HWO, T-24 Valve, wing, WKM-M, 2 1/16 5M FE, HWO, T-24 Valve, SSV, WKM-M, 3 1/8 5M FE, w/ Omni 15'’ operator Steelhead Platform M-22 26 x 13 3/8 x 9 5/8 x 4 1/2 Tubing hanger, SME-CCL, 13 5/8 x 4 ½ EUE 8rd lift and susp, w/ 4'’ Type H BPV profile, w/ 2- 1/2npt CCL ports, 6 ¼ extended neck Adapter, Seaboard, EN-2CCL, 13 5/8 5M stdd btm x 4 1/16 5M rotating flange top, w/ 2- ½ npt CCL ports Starting head, Seaboard, S-22-AP-8, 20 ¾ 3M FE x 28'’ BW bottom w/ 2- 2 1/16 5M SSO Multi-bowl, Seaboard SMB- 22, 13 5/8 5M x 20 ¾ 3M, prepped w/ 13 3/8 PP bottom, 4- 2 1/16 5M SSO 28'’ 13 3/8'’ 9 5/8'’ 4 ½’’ Valve, upper master, WKM-M, 4 1/16 5M FE, HWO, T-24 BOP Stack Rig 404 Shaffer SL 13 5/8 5M 2 7/8-5.5 variables Blinds 2.26' Riser 13 5/8 5M FE X 13 5/8 5M FE 4.54' 2.83' Choke and Kill valves 2 1/16 5M Mud Cross 4 1/16 5M EFO 4.30' Hydril GK 13 5/8-5000 DSA 4 X 2DSA 4 X 2Spacer spool 13 5/8 5M X 13 5/8 5M ? ? HILCORP ALASKA, LLC SwacoSuperchokeBlooey LineTo Gas BusterInlet Coiled Tubing BOP 05/21/2020 SWAB VALVE MASTER VALVE Hilcorp Flow DiagramFluids Pumped Fluids ReturnedValve Open Valve ClosedGate Valve Ball ValveButterfly Valve Lo Torq ValveAutomatic Choke Manual ChokePressure Gauge Knife ValveChoke LineP PIT SYSTEM SucƟon SHAKER SHAKER CHOKE MANIFOLDGAS BUSTER Panic LineC12 C13 C15 C14 C16 A B C4 C5 C6 C7 C2 C10 C9 C11 C8 C3 P C1 C 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. Rig 404 BOP Test Procedure Attachment #1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Rig 404, WO Program – Oil Producers, Gas Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with kill weight fluid. x Note: Fluid level will fall to a depth that balances with reservoir pressure. x Shoot fluid levels as needed. 3) Confirm that well is static. Initial Test (i.e. Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won’t pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) Fill well with KWF if the fluid is not to surface b) ND tree with no BPV Inspect and prepare BPV profile to accept a 2-way valve, or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand, or MU landing (test) joint to lift-threads d) For ESP wells - Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and / or a penetrator leaks, notify Operations Engineer (Hilcorp), Mr. Bryan McLellan (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) Rig 404 BOP Test Procedure Attachment #1 f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn’t hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger (or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests (i.e. Test Plug can be set in the Tubing-head) 1) Remove wear bushing. a) Use inverted test plug to pull wear busing. MU to joint of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same- RIH with test plug on joint of tubing. Install a pump-in sub w/ test line plus an open TIW or lower Kelly valve in top of test joint w/ open IBOP. 3) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE (after 2-way check or test plug is set) 1) Fill stack and all lines with rig pump- install chart recorder on test line connected to pump-in sub below safety valve and IBOP in test joint assembly. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder (test pressures will be indicated in Sundry). 3) Referencing the attached schematics test rams and valves as follows. a) Close 1 st valve on standpipe manifold (PM1), close valves 8,10 &11 on choke manifold and close the annular preventer, open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and xxx psi (see sundry) high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank and open annular. b) Close pipe rams and open annular preventer, close safety valve and open IBOP on test joint, close outside valve on kill side of mud cross (K2), open PM1, close valves 5,7 & 9 on choke manifold, open valve 10 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack, test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. d) Close manual and super choke / open valves 7 & 9 on choke manifold. Bleed pressure from step b or c recording change and stabilization. If passes after 5 minutes, bleed off pressure back to tank. e) Close inside valve (K1) / open outside valve on kill side of mud cross (K2), close valves 2,4 & 6 / open valves 5,7 & 9 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. f) Close valves 1 & 3 / open valves 4 & 6 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. Rig 404 BOP Test Procedure Attachment #1 g) Close HCR (CL2) open valves 2,4 & 6 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. h) Close inside valve (CL1) / open outside valve (HCR) on choke side of mud cross. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. i) Ensure all pressure is bled off- open pipe rams and pull test joint leaving test plug / 2-way check in place. Close blind rams and attach test line to valve 11 on choke manifold, close valve 1,2 & 3 / open valve 11 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. j) Test additional floor valves (TIW or Lower Kelly Valve) and IBOPs as necessary. STANDARD TEST PROCEDURE OF CLOSING UNIT (ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record “Accumulator Pressure”. It should be +/- 3,000 psi. 3) Close Annular Preventer, the Pipe Rams, and HCR. Close 2 nd set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read “10 bottles at 2,150 psi”). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre- charge pressure of 1,000 psi). 7) Turn on the electric pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually +/- 30 seconds. 8) Once 200 psi pressure build is reached, turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/- 3,000 psi). Note: Make sure the electric pump is turned to “Auto”, not “Manual” so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format. Document both the rolling test and the follow up tests. Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well: Trading Bay Unit M-22 (PTD 218-027)Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Sec Page Date Procedure Change New 403Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date DATE 2/06/2019 Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 DATA TRANSMITTAL TBU M-22 218-027 CD: Leak Detect Log with ACX M-22 ACX_1ODEC18_ProcessedLog M -22 -ACX -1 ODEC18-PFOcessedLog M-22 ACX_10DECI8_ProcessedLog_img M-22_ACX _10DEC78_Report_RevA M-22 ACX_IODECI8_ProcessedLog.diis 2 150 27 RECEIVED FEB 0 6 2019 AOGCC 1/15f201910:32APA LA5File 1,727 KB 1/15/2019 1 U3 AM PDF Document 5,783 KB 1/151201910:33AM TIFF Fite 34,N5 KB 1/1512019 10:33 AM PDF Document 1,875 KB 1/15/2919 1033 AM HIS File 12,995 KB 30 34 1 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: TBU M-22 50-733-20681-00-00 McArthur River Field Kenai Peninsula Borough, Alaska May 5, 2018 – June 15, 2018 Provided by: Approved by: John Serbeck Compiled by: Allen Odegaard Josh Dubowski Distribution Date: June 28, 2018 TBU M-22 1 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ................................................................................................ 2 1.1 Equipment Summary ...................................................................................................................... 2 1.2 Crew ............................................................................................................................................... 2 2 GENERAL WELL DETAILS ................................................................................................................... 3 2.1 Well Objectives ............................................................................................................................... 3 2.2 Hole Data ........................................................................................................................................ 3 2.3 Daily Activity Summary ................................................................................................................... 4 3 GEOLOGICAL DATA ........................................................................................................................... 10 3.1 Lithostratigraphy ........................................................................................................................... 10 3.2 Lithology Details ........................................................................................................................... 10 3.2.1.1 Tyonek Formation .............................................................................................................. 10 3.3 Sampling Program ............................................................................................................................... 24 4 Drilling Data ......................................................................................................................................... 25 4.1 Surveys ................................................................................................................................................ 25 4.2 Bit Record ............................................................................................................................................ 29 4.3 Mud Record .................................................................................................................................. 30 4.4 Drilling Progress ........................................................................................................................... 32 DAILY REPORTS ....................................................................................................................................... 33 Enclosures 2” / 100’ Formation Log (MD/TVD) 5” / 100’ Formation Log (MD/TVD) 2” / 100’ Drilling Dynamics Log (MD/TVD) 2” / 100’ Gas Ratio Log (MD/TVD) 2” / 100’ LWD Combo Log (MD/TVD) Final Data CD TBU M-22 2 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type /Position Total Downtime Comments Ditch gas QGM Agitator (Mounted in possum belly) Flame ionization total gas & chromatography. 0 hrs. -- Effective Circulating Density (ECD) Baker Hughes 0 hrs. — Hook Load / Weight on bit RigWatch 0 hrs. — Mud Flow In RigWatch 0 hrs. — Mud Flow Out RigWatch 0 hrs. — Mudlogging Unit Computer System HP Compaq Pentium 4 (X2, DML & RigWatch) 0 hrs. — Pit Volumes, Pit Gain/Loss RigWatch 0 hrs. — Pump Pressure RigWatch 0 hrs. — Pump stroke counters RigWatch 0 hrs. — Rate of Penetration RigWatch 0 hrs. — RPM RigWatch 0 hrs. — 1.2 Crew Mud Logging Unit Type: Arctic Mud Logging Unit Number: ML030 Logging Geologists Years1 Days2 Sample Catchers Years Days2 Allen Odegaard 21 46 Ralph Winkleman 27 22 Josh Dubowski 10 36 Paul Webster 39 14 Jessie Lewing 0 8 *1 Years’ experience as Logging Geologist *2 Days at wellsite between rig up and rig down of logging unit. TBU M-22 3 2 GENERAL WELL DETAILS 2.1 Well Objectives M-22 is a gas production well planned to be drilled in a north-easterly direction from the Steelhead platform. A 17.5” hole will be drilled to about 1300’, a 12.25” hole will be drilled to about 7,200’ (where the lateral will begin), and a 8.5” production lateral will be drilled to approximately 9,400’. A 7” 29# L-80 DWC/C production liner will be run, cemented, and perforated based on data obtained while drilling the interval. The well will be completed with a 3-1/2” ESP completion. The well very closely followed the planned directional path. The intermediate section began with a 4° inclination at 1,321’ MD/1,301’ TVD and immediately began to build to 17.67° at 2,000’ MD / 1985.48’ TVD. Inclination was held between 17°-18° until 4465’ MD / 4340.84’ TVD and was built up to 56.56° by 5694’ MD / 5281.07’ TVD. Angle was held until 6220’ MD / 5570.76’ TVD and the rig began building again until 7450’ MD / 5978.11’ TVD when 88° was reached. Angle was held between 88° and 89.72° until TD at 10,050’ MD / 6030.28’ TVD. Operator: HILCORP ALASKA, LLC Well Name: M-22 Field: McArthur River Field County: Kenai Peninsula Borough State: Alaska Company Representatives: Shane Hauck, Marvin Rogers, Rance Pederson, Rick Brumley Location: Surface Coordinates 1149' FNL, 559' FWL, Sec 33, T9N, R13W, SM, AK Mud Line Elevation 160’ AMSL Rotary Table Elevation 187’ AMSL Classification: Development - Gas API #: 50-733-20681-00-00 Permit #: 218-207 Rig Name/Type: Steelhead / Triple Spud Date: May 5, 2018 Total Depth Date: June 12, 2018 Total Depth: 10,050’ Primary Targets: D-6, D-6 Mid, & D-Main Sands (TVD 5,768’ – 5,919’) Total Depth Formation: Tyonek Completion Status: — LWD-MWD Services. Baker Hughes Intec Directional Drilling Baker Hughes Intec Drilling Fluids Service Halliburton / Baroid Wireline Logging Service — 2.2 Hole Data Hole Section Max Depth TD Formation MW ppg Dev oinc Casin g Dia Shoe Depth FIT ppg MD (ft) TVD (ft) MD (ft) TVD (ft) 17½” 1,321’ 1,319.27’ Beluga 9.2 4.0 13 3/8" 1,293’ 1,291.33’ 12.5 12.25” 7,018’ 5,925.51’ Tyonek 9.65 73.43 9 5/8” 7,000’ 5,926.03’ 12.0 8.5” 10,050’ 6,030.28’ Tyonek 9.2 89.45 4” X X — TBU M-22 4 2.3 Daily Activity Summary April 29, 2017 Rig up unit, install new gas equipment. April 30, 2017 Troubleshooting gas equipment. May 1, 2017 Continue troubleshooting gas equipment. THA repaired and getting new chromatograph shipped out from office. May 2, 2017 Continued rigging up. Offloaded drill pipe & upright tanks from boat. Started picking up pipe. May 3, 2017 Pick up HWDP and 5" DP; performed rig inspection with OSHA; tested mud lines T/ 3700 psi. May 4, 2017 Continued rigging up. Filled Upright tanks. Offloaded 13 3/8" casing. Filled stack to diverter. May 5, 2017 Filled stack & changed leaking valves on the diverter, pressure tested Bakers BPA unit. Started P/U BHA #1 to drill out conductor. RIH tagged TOC @ 463'. Displaced conductor to Spud Mud. Shut down pumps preparing to drill out cement. May 6, 2017 Drilled ahead from 463' to 485' MD. Circulated 1.25 BU. Float check, well static. TOOH T/ surface. Laid down BHA #1. Picked up BHA #2 to drill surface hole. Finished P/U BHA and started drilling ahead T/745' and lost all returns, lined up to LCM pills and began pumping them down hole, once first pill was out of the bit we established circulation at a slow pump rate, shut down pumps and fill hole from the top and started timing loss rate, loss rate went from 90 bbls down to 13.5 bbls per/hr while pumping over the top of the hole. Continued to monitor losses while spotting multiple pills. May 7, 2017 Continued batching up Spud Mud. Lost circulation while circulating off bottom. Held PJSM prior to drilling ahead. Drilled ahead from 745' to 896' MD. May 8, 2017 Drilled from 896' T/1,301', pumped BU and then pumped a Hi-Viscosity sweep with LCM. Circulated another BU, pumped out two stands & then TIH back to bottom, spotted a Hi-Viscosity LCM pill on bottom, TOOH on elevators T/730' & slow pumped through loss circulation area T/688'. Spotted another Hi-Viscosity LCM pill F/688'-T/587'. Pumped OOH into conductor due to swabbing, TOOH to tools, down loaded MWD, L/D BHA #2. May 9, 2017 Finished L/D BHA. R/U 13 3/8" casing equipment. RIH with 13 3/8" surface casing. T/ 600', circulated @ 3.5 bbls/min conditioning mud for cement job, lost 5 bbls while circulating. Continued TIH T/928', circulated BU while conditioning mud again for cement job @ 3.5 bbls/min & lost 16 bbls while circulating. TIH to bottom. Landed and circulated BU. P/O monitored well for 10 mins. Determined static loss rate @ 6 bph. Drained the stack. May 10, 2017 R/D Weatherford. M/U 5" DP handling equipment. RIH T/1293' & stung into 13 3/8" surface casing. R/U cementers & mixed spacer. Broke circulation at 0530 pumped @ 1 bpm for 30 mins. Broke again at 0630 TBU M-22 5 and pumped for 30 mins (prior to cement). Held PJSM on rig floor for cement job, Started cement job by pumping 8 bbls of water with red dye and pressure tested cement line to 500 psi low and 3,500 psi Hi, lined mud pumps up to 10 ppg space and pumped 136 bbls, followed by 399 bbls of 12 ppg lead cement, followed by 14 bbls of 13 ppg tail cement and chased with 21.5 bbls; rig down cementers; begin nippling down diverter. May 11, 2017 Nipple down diverter, installed multi-bowl & started nippling up BOP stack while mixing mud. R/U Pollard wireline to log cement temperature survey, R/D Pollard. Continued nippling up BOPs & mixing mud. May 12, 2017 Continued nippling up BOPs; begin testing BOPs. May 13, 2017 Function tested BOPs, R/D test equipment, cleared & cleaned rig floor, Held PJSM & started P/U & M/U drill out assembly BHA #3. RIH T/shoe track, circulated BU. Cut & slip drill line. Drilled float collar & 20' of new hole. Performed FIT to 12.5ppg EMW. Rig up & run gyro tool. May 14, 2017 Continue drilling up float from 1210 to 1213. Continue reaming down to 1250’ tag cement, tag shoe at 1288 to 1290.92. Drilled new hole from 1290.92 to 1321.08. Displace mu to 9.0 ppg and overboard old mud. Perform FIT to 12.5 EMW. R/U and RIH with wireline, installed BOP cradle, moved BPA to lower deck. POOH with wireline and R/D same. TOOH to surface and lay down BHA. P/U BHA #4 as per Baker hands. Download MWD and shallow test. Shallow test flow rate too high for shakers, screen down two more times until shallow test of 650 GPM was obtained. Install nuclear source and trip in hole to 1305’. Stage up pumps and condition mud. Drill ahead from 1321’ to 1389’ at report time. May 15, 2017 Continue drilling 12.25” hole from 1389’ to 1857’. Pump 50bbl high viscosity sweep with 50% increased returns. Ream out of hole from 1857’ to 1305’. Trip back in hole, tag 12’ of fill on bottom. Pick up and back ream to 1825’ then wash and ream back to bottom. Continue drilling ahead until report time. May 16, 2017 Continue drilling 12.25” hole from 2268’ to 2799’. Change out swab on mud pump #1 cylinder #3. Circulate and condition mud, pump high viscosity sweep with a 25% increase in returns. Back ream from 2799’ to 1840’ with no signs of packing off. Trip back in hole on elevators to 2705’. Wash and ream to bottom and continue drilling ahead until report time. May 17, 2017 Continue drilling 12.25” hole from 2994’ to 3842’. Pump sweep and circulate bottoms up with 75% increased returns. Pump out of hole to 3630’ at report time. May 18, 2017 Continue pulling out of hole, back reaming through tight spots from 3555’ to 3410’. Change out swabs in pump #1. Continue back reaming out of hole from 3410’ to 1280’. Circulate and condition at the shoe. Flow check (good) then pull out of hole to 1001’. Troubleshooting issue with breaking connection. May 19, 2017 Continue pulling out of the hole and lay down the BHA. Replace swabs in mud pump #2 while rigging up closed mud system. Pick up BHA and run in hole. Ream to bottom from 3746’ to 3842’ and continue drilling ahead. May 20, 2017 Continue drilling ahead from 4128’ to 4316’. Pump 25bbl weighted high viscosity sweep and work pipe. Back ream out of hole to 3846’. Trip back in hole to 4225’ then wash and ream down to bottom. Continue drilling ahead to 4970’ at report time. TBU M-22 6 May 21, 2017 Continue drilling to 5244’ and circulate well clean and swap vac totes. Continue drilling down to 5263’. Take survey and downlink tool home. Circulate 30 bbl low viscosity sweep and work pipe. Back reaming out of the hole at report time. May 22, 2017 Continue back reaming out of hole to 4320’. Circulate two bottoms up while working pipe. Service top drive, draw-works and adjust breaks. Trip in hole to 5173’ then wash to bottom. Drill ahead to 5743’ then pump 30bbl hi viscosity sweep followed by a 50bbl weighted sweep. Back ream out of hole to 5540’. Pump out of hole to 5160’, working through tight spots as per company rep. Trip back in to bottom and continue drilling ahead. May 23, 2017 Continue drilling 12.25” to 6092’. Work stuck pipe, set drilling jars off at 60k over pull then 180k straight pull. Trap 20k torque in string. Spot 75bbl NXS 7% lube pill around BHA. Pipe free with 160k over pull and 20k torque in string. Circulate NXS lube pill out of hole and work pipe from 6092’ to 6029’. Back reaming out of the hole at report time. May 24, 2017 Circulate bottoms and work pipe from 1278’ to 1190’. Blow down top drive and monitor well for 10 minutes (static). Trip out of hole and lay down BHA. Service draw-works, blocks, washpipe, crown and ST-80 roughneck. Mobilize BHA, service mud pumps, C/O crown windsock, post jarring derrick inspection, clean flow line of obstruction and drain vacuum RVT tank. Pick up BHA 36 as per Baker Hughes, trip in hole to 1334’, shallow pulse test then run in hole. Work through tight spot at 5230, tag up at 5263’ and attempt to work through with no rotary or pump (fail). Pump through tight spot and continue to bottom. Drilling ahead at report time. May 25, 2017 Continue drilling 12.25” intermediate hole to 6540’. Pump 60bbl high viscosity sweep, 50% increased cuttings return. Pump out of hole from 6540’ to 6090’ then trip back to bottom. Continue drilling ahead to 6828’ and pump 51bbl sweep. Drill to 6975’ and circulate to look for gas. Continue drilling to TD at 7018’. Pump 44bbl sweep and circulate hole clean. May 26, 2017 Circulate bottoms up while working pipe from 6950 to 7005. Back ream out of hole to 6155. Pump 65bbl hi viscosity sweep and work pipe. 50% increased cuttings return. Back ream out of hole to 5489. Pump 45bbl hi viscosity sweep and work pipe. Flow check well. Pump out of hole and lay down bad joint from top of stand 21. Circulate bottoms up at 2650 to check MWD tools and establish flow rate after washout was located. Pump out of hole to shoe and monitor well (-0.2bbls per ½ hour). Trip out of hole to 605 and monitor well at BHA. Lay down BHA #5 as per baker and rig up Schlumberger wireline to run CBL. May 27, 2017 Finish rigging up SLB wireline and 58’ of tools and test. Run in hole with wireline to 1289’, come out and rig down wireline. Remove wear bushing, make up stack washing tool, wash hanger profile / BOP stack. Blow down choke/T/D, kill lines, drain BOP stack back into mud pits. Rig up to test BOP’s. Install test joint, plug in place, fill up with filtered inlet water from pill pit, perform body test, leak on south blind ram door seal. Drain BOP stack, de-energize koomey unit, open door, inspect door seal, change out door seal and body test BOP stack. Test BOP as per AOGCC regulations with Adam Earl. Lay down test tool and rig down testing equipment. Install wear bushing, change out saver sub and reset torque wench to the factory settings. Pick up BHA #7 as per BHI, shallow test tools. Had to change out screens to get correct flow rate. May 28, 2017 Continue picking up BHA #7 as per Baker. Trip in hole to 1268’ and circulate bottoms up. Cut and slip 111’ of drilling line. Inspect hook-load sensor and calibrate block height. Run in hole to 2579’ and conduct open hole logs as per Baker MWD/DD. Conduct single point tests at 1269’, 1515’, 1593’, 1619’, TBU M-22 7 1703’, 2165’, 2510’, 2579’. Conduct stretch tests at 1200’ and 2500’. RFT points @ 2579.4' TF=235 & 180, 2591.4' TF=138, 2620.4 TF=139, 2746.4' TF=10, 2648' TF=8 good test 527psi, 2812.4' TF=358, 2854.4' TF=358, 2867' TF=358,18. Pump out of hole from 2890’ to 1703’. RFT @ 1703’. Continue pumping out of hole from 1703’ to 1267’. Circulate bottoms up and monitor well. Trip out of hole to 607’ and monitor well at BHA. Continue racking back HWDP and laying down BHA at report time. May 29, 2017 Pick up MWD Testtrak/Ontrak BHA. Shallow test tool at 89’. Run in hole to 607’. Trip in holr to 3416’ and circulate bottoms up. Wash down from 3416’ to 4395’. Circulate high viscosity sweep with 50% increased cuttings. Conduct stretch test from 4674’ to 4624’. Conduct single point logs with RFT sensor. Wash down to 5248’. Wash and ream down from 5248’ to 5438’. Log RFT at 5358.1’, 5335’. Reaming and washing down to 6097’. Circulate bottoms up. Wash and ream to bottom. Circulating hole clean at report time. May 30, 2017 Circulate 58bbl high viscosity/walnut sweep with 100% increased cuttings at shakers. Trip out of hole to 4960’ and circulate bottoms up. Conduct open hole RFT tests per baker directional/mwd, from 4787',4784' 4231' 4229, 4107'. Continuing RFT tests at report time. May 31, 2017 Pump out of hole from 2918’ to 1269’. Spot 85bbl 10.7ppg LCM pill from 2500’ to 1800’. Monitor well for 10 minutes at 1269’. Trip out of hole and lay down BHA per Baker rep. De-energize koomey, remove 2- 7/8x5.5 uppers and install 9-5/8” solid body rams. Close ram doors, energize koomey and change out packing on drawworks. Rig up BOP testing equipment and test 9-5/8” uppers then rig down testing equipment. Rig up casing equipment while monitoring well (-1.0bbls per hour). Run 9-5/8” casing, bakerlocked the shoe and float equipment assembly, putting centralizers in place as per running order tally. Circulate at 1289’ then continue running casing. June 1, 2017 Continue running 9-5/8” casing. Haliburton rep witness make up ES cementer – 15ft/min while running in hole. Continue running in hole and circulate bottoms up at 5132’. Finish running casing to bottom, rig down Volant tool and bails rigging up 9-5/8” spyders and long bails. Rig up cement head. Circulate hole clean for cement job thinning down the viscosity while Desco cleared the floor of casing equipment. Fill iso tanks with mud from the pits. June 2, 2017 Dropped bypass plug, pumped 1stage of cement, 171 bbls/ lead @ 12.5 ppg, 59 bbls of tail @14.9 ppg. Dropped landing plug, started pumping w/rig , working pipe, lost circulation @ 3100 strokes and packing off, could not land it after packing off. Pressured up to 2830psi to open up ES cementer, established circulation, circulate bottoms up @ 2250 strokes. Pumped 40 bbl/high viscosity sweep and continue circulating, preparing for stage 2 of cement job. Pumped 5bbl of h20 rig pumped 60 bbls of 10 ppg spacer, HES pumped 228bbl of 12ppg cement, dropped closing plug HES pumped 5bbls of h2o, rig pumped 284.8bbl and bumped plug @ 800psi landed plug tool shifted @ 1500psi cip. Suck out the stack and rig down the cementing equipment. Nipple down well head to install emergency slips on 9 5/8'' casing. Clean out flow box and deflated the riser air boots, split the well head and pick up stack and riser. De-energized Koomy unit, had 340k on the 9 5/8'' when emergency slips were set. Emergency slips set @ 23:50 June 3, 2017 Finish working on rig vacuum and vacuumed out old mud from landing joint. Continued to clean pits and shakers, offload old mud. Backed out landing joint to drain last little bit of mud. Rig down spyder elevators, started cutting casing in well room and continue cleaning pits. Lay down landing joint and rig down Weatherford casing tools. Installed 9 5/8” packoff, nipple up BOP’s, tested packoff. Change out bails and handling equipment from casing run. Make up test plug and test upper pipe rams. Install wear bushing and lay down test equipment. Flooded lines, shut the blinds and tested casing to 3550psi. It held for 3 minutes then bled off to 2870psi after 30 minutes. Checked all surface equipment for leaks, TBU M-22 8 none found. Pick up BHA #9 as per Baker rep. Run in hole, tag cement at 3989’ then displace to H2O and circulate for drilling out cement plug and cement. June 4, 2017 Continue drilling cement from 4001’ to 4002’, monitor well for 10 minutes (static). Trip out of hole, change out bit from PDC to roller cone and run back in hole to 3695’ and then wash to bottom. Drilled up DV collar from 4000’ to 4004.5 and continue chasing cement plug to bottom. Run in hole to 4909’ chasing plug and running into stringers along the way. Circulate bottoms up at 4909’ to clean the hole up for initial casing PSI test. Pull out of hole to 4817’ for space out for PSI test. Rigged up to test 9-5/8” casing. Closed top rams and opened the kill line, pressuring up up the backside and down the drill pipe. Took 60 strokes to pressure up to 3590psi at 13:48 and held to 13:57 3567psi. – good test. Drill cement from 4909’ until report time. June 5, 2017 Continue drilling cement to 6237’ then pump a high viscosity sweep (300 viscosity). Large amount of rubber returns to the shakers. Continue drilling cement down to top of baffle at 6916.10’, lay down single and rig up to test casing. Test 9-5/8” casing to 3500psi for 30 minutes. 7.2 bbls pumped and 8.4 bbls bled back. Rig down test equipment and continue drilling the baffle to 6975’, float collar was at 6956’, circulate hole clean then begin pumping out of hole to 4312. Circulate two bottoms up, pump dry job and trip out of hole. June 6, 2017 Lay down BHA and service top drive, crown and draw-works. Rig up E-line and run CBL. Rig down E- line, clean mud pits, shaker pits, mix new mud, clean upper well room. Pick up BHA #11 and trip in hole to 700’, fill pipe and test MWD. Run in hole to 6854’ and fill pipe. Cut and slip 94’ of drilling line, re- calibrate block height. Washed down to 6975’ then drill cement to 6998’. Set down 4K on shoe. Weight condition and circulate to weight up and viscosity up new mud. Change out MWD stand pipe sensor and mud pump #2 PRV. Drill out 9-5/8” casing shoe and rat hole to 7006’ at report time. June 7, 2018 Drill 8.5” production hole from 7011’ to 7038’. Perform FIT to 12.0 EMW (good). Pump 50bbl high viscosity spacer sweep. Displace mud at 8bbl/min, build new mud, clean pits, off-load old mud to iso tank. Continue drilling ahead until 7574’. Pump 44bbl high viscosity sweep and circulate until hole clean. Short trip out to 7003’. Service and inspect top drive after rough drilling. Circulate at the shoe while doing a weekly derrick inspection and transferring old mud out of the pits to the upright tanks. June 8, 2018 Continue drilling 8.5” production hole from 7574’ to 8046’. Inspect top drive for broken tie wire. Pump 9.5ppg high viscosity sweep with 150% increased cuttings return. Drilling ahead at 8392’ at report time. June 9, 2018 Continue drilling 8.5” production hole to 8525’ then pump 45bbl high viscosity sweep with a 175% increase in cuttings. Continue drilling ahead to 8801’, pump 45bbl high viscosity sweep with 100% increased returns and begin pulling out of the hole on elevators. Pull through tight spots at 7727’, 7680’ and 7670’ at 25K over. Circulate bottoms up at 6920’, flow check well (static), pump dry job and blow down top drive. Trip out of hole, racking back drill pipe. Lay down BHA, pick up a single and make up to collars, rack back in derrick, pick up another single and 6’pup joint and make up to MWD. Pick up and check bit, downlink MWD, rack back MWD in derrick. Calculate displacement = 82.1 bbls, actual = 91.2 bbls for trip out of hole. Pick up stand from derrick, remove wear ring, close blind rams, pick up stack washer, flush well head bowl, come up flush stack working string up and down at 17 BPM. Function annular, lower pipe rams, upper pipe rams 2 times each, flushing between each function, remove stack washer. Picking up BHA #12 at report time. June 10, 2018 Continue picking up BHA #12 and 48 joints of 5” drill pipe. Single in hole to 2024’, fill up pipe, test MWD then continue running in hole. Rig up BOP testing equipment and function test BOP’s. Test #1 annular, TBU M-22 9 CMV's 1,2,3,12,13,14, dart valve, Demco kill, low/250 high/3500, test #2 upper rams, TIW, CMV's 4,5,6,hcr kill, upper IBOP, low/250 high/3500 test# 3 CMV's 7,8,9 manual kill, test #4 cmv's 10,11 low/250 high/3500, test #5 super choke and manual choke control bleed off 1500 psi, test #6 HCR choke low/250 high/3500, test #7 manual choke low/250 high/3500, test #8 lower pipe rams low/250 high/3500 / witnessed by AOGCC Brian Bixby. Break test joint from test plug, install new seals on test plug, run in hole, set test plug, remove test joint, fill stack with water, test blind rams 250/3500psi each. Rig down test equipment, blow down top drive, choke and kill. Service top drive, draw-works and inspect top drive with multiple personnel. Trip in hole to 5240’, fill pipe, continue tripping into hole to 6945’ and circulate bottoms up. Continue running in hole to 7044’, single in with one stand and 6 joints of HWDP. Run in hole to 7580’, wash and ream to 7875’ then run in hole to 8644’. Wash and ream to 8779’ and circulate. June 11, 2018 Continue drilling 8.5” production hole to 9111’ and pump 45bbl high viscosity sweep with 75% increased cuttings and 200 strokes late. Back ream stand clean, shut down to change out broken bolts on top drive. Continue drilling ahead to 9306’. Back ream a stand to clean up hole and change out top drive bolts and tighten loosed bolts and broken tie wire. Pump 45bbl high viscosity sweep and continue drilling ahead to 9492’ and pump 9.7 high viscosity nut plug sweep at 9306’ with a 90% increase in cuttings and 20bbls late. Continue drilling ahead, pumping a .7 high viscosity nut plug sweep at 9490’ with a 100% increase in cuttings and 20bbls late. Drilling ahead at 9651’ at report time. June 12, 2018 Continue drilling 8.5” production hole to 9684’ and pump a 45bbl high viscosity sweep with 125% increase in returns. Back ream stand clean and change out broken bolts on top drive, change out swivel packing. Pump 45bbl high viscosity sweep and continue drilling to 9779’. Pump 45bbl high viscosity sweep with 100% increase in returns. Continue drilling 8.5” production hole to 10,050’ and pump a 45bbl high viscosity sweep with 100% increase in return cuttings and 10bbls late. Pump another sweep with 60% increase in cuttings and 10bbls late. Flow check (static). Trip out of hole to 6940’ on elevators with tight spots at 7755’ and 7752’. Circulate and condition. Inspect and service top drive, tighten bolts on grabber dies. Trip in hole to 9874’ then wash and ream to bottom, working through tight spot at 7186. Circulating at report time. June 13, 2018 Pumped 45bbl high vis sweep with 100% increased returns and 350 strokes late. Displace open hole volume with 9.2ppg mud. Trip out of hole with no tight spots. Circulate bottoms up at the shoe and prepare mud pits for FIW and off load old mud to upright tanks. Displaced 9-5/8” casing with 8.6ppg FIW, hole losing 2bbls per hour. Monitor well while cleaning surface equipment, trip tanks 1 & 2, build 430bbls of 6% KCl brine and clean shaker room pits. Lay out completion screen ready for strap/talley/drift. Finish strapping liner screens and blanks, fill three iso tanks from pits for displacement, build baraklean pill. Line up and start displacement with 40bbl caustic pill, chase with 40bbl baraklean pill, chase with 6% KCl brine. Had issue with mud pump #2 during displacement, swap over to mud pump #1. June 14, 2018 Trip out of hole to surface, worked on mud pump #2, cleaned out suction manifolds and checked valve seats. Lay down BHA and rack back all HWDP in derrick. Make up tools and BHA, racked back hanger in derrick. Rig up Weatherford to run screens and completion. Service rig for running in hole, work on mud pump #1 cleaning out suction manifold and checking valve seats. Review running order, check safety joint ready and run in hole with liner screens as per tally. Weatherford casing services make seal lock HT connections to 3800’. Run in hole picking up joints 1x1 from skate to 2650’, rig up H/P line to pump FIW to production. Picked up total of 34 x 4” Bakerweld screens, 27 x 4” Excluder2000 screens, 18 x 4” blank screens. Pick up baker tools and rig up false table, change out elevators and prep for running 2-7/8” inner string. TBU M-22 10 3 GEOLOGICAL DATA 3.1 Lithostratigraphy Tops picked by Hilcorp Geologists FORMATION PROGNOSED ACTUAL MD (ft) TVD (ft) SSTVD (ft) MD (ft) TVD (ft) SSTVD (ft) D-3 4,856’ 4,684’ -4,524’ 4,856’ 4,687’ -4,527’ D-4 5,225’ 4,982’ -4,822’ 5,223’ 4,980’ -4,820’ D-6 7,000’ 5,928’ -5,768’ 6,999’ 5,921’ -5,761’ D-6 Mid 7,125’ 5,955’ -5,795’ 7,186’ 5,960’ -5,800’ D-6 Main 7,309’ 5,979’ -5,819’ 7,576’ 5,981’ -5,821’ 3.2 Lithology Details Lithology descriptions of all Kenai Group and Mesozoic rock cuttings samples started immediately after drilling out the surface conductor, then continued as per pre-set plans and procedures, and modified when directed by the Hilcorp operations geologist. The Kenai Group of Alaska’s Cook Inlet Basin, which includes the Sterling, Beluga, Tyonek, Hemlock and West Foreland Formations, was deposited by a variable-energy fluvial system within a large closed fore- arc basin. The characteristic sedimentary stratigraphy consists of dominant massive to thinly bedded sandstone and claystone-siltstone, generally abundant thin inter-beds of air fall and re-deposited volcanic ash, minor beds of basal or modal conglomerate and extensively-distributed thin beds of coal and carbonaceous rocks. Gradational upward-fining sequences and bi-modal distribution zones are abundant within sandstone sections. Note that in Canrig’s Lithology Descriptions, the special modifying term “tuffaceous” was created to address the pervasive presence and diversity of soft-sediment volcanogenic- origin rocks in the Cook Inlet area. Though generally applied to significantly ash-rich clay-silt-sand lithologies, its wide use in descriptions may include discernible micro-shard concentrations of disaggregated volcanic glass to vitric air fall volcanic ash to smectite-bentonite clays derived from devitrified ash to rare layers of vitric ignimbrite. 3.2.1.1 Tyonek Formation The entire logged well was drilled in the Tyonek Formation The Tyonek formation is a series of alternating tuffaceous sandy siltstones, tuffaceous siltstones, sand and clay with occasional coal and carbonaceous shales. The tuffaceous siltstones are typically medium gray with pale brown and olive hues to medium dark gray with pale olive to very pale brown hues. They are easily friable to friable with a crumbly to pulverulent tenacity and often display bit curled to a rare platy cuttings habit. Typically have a dull to earthy luster with a silty to gritty texture and have a massive structure TBU M-22 11 The sands are typically medium gray to medium gray with pale olive hues to yellowish brown to grayish brown. Grain size is typically lower medium to lower fine to occasionally lower coarse and trace 2-4mm grains. They are typically sub-rounded to rounded to sub-angular with moderate to poor sorting and are sub spherical to trace sub discoidal. The sands are typically comprised of translucent smoky gray to transparent quartz and trace lithics. Ranges from unconsolidated to easily friable to trace amounts of firm clasts. The coals are typically black to very dark gray to occasionally matte black. They display brittle to crumbly to dense tenacity with hackly to conchoidal to irregular fracture. They usually display flakey to an occasional wedge-like cuttings habit. Luster is often vitreous to earthy to slightly waxy with a matte texture. 1,321’ to 10,050' MD (-1,159' to -5,870' TVDSS) Tuffaceous Claystone (1321' - 1380') = medium gray to light medium gray with dark brown to black hues; curdy to clumpy consistency; irregular to earthy fracture; nodular to platy cuttings habit; dull to earthy luster; moderate cohesiveness; poor adhesiveness; silty to gritty texture; overall thick structure interbedded with thin sands and coals. Tuffaceous Claystone (1380' - 1460') = dark medium gray to medium gray with dark brown to pale black hues; clumpy to lumpy consistency; irregular to earthy fracture; nodular to slightly platy cuttings habit; dull to earthy luster; moderate cohesiveness; poor to moderate adhesiveness; silty to gritty texture; overall thick structure interbedded with thin sands and moderate sized coals. Tuffaceous Claystone (1460' - 1520') = medium gray with dark brown to black hues to dark medium gray; clumpy to lumpy tacky consistency; irregular to earthy fracture; nodular to slightly platy cuttings habit; dull to earthy luster; good to moderate cohesiveness; moderate to good adhesiveness; clayey to silty to smooth texture; overall thick structure interbedded with thickening tuffaceous sandstones and siltstones. Tuffaceous Sandstone / Sand (1520' - 1580') = light medium gray with dark brown to black to occasionally olive hues; unconsolidated to easily friable; upper fine to lower medium to occasionally very fine; well to moderate sorting; sub rounded to sub angular; sub discoidal to trace sub prismoidal; predominantly clear to translucent quartz. Tuffaceous Claystone (1580' - 1650') = medium gray with dark brown to black to dark medium gray; clumpy to lumpy to tacky consistency; irregular to earthy fracture; nodular to slightly platy cuttings habit; dull to earthy luster; good to moderate cohesiveness; moderate to good adhesiveness; clayey to silty to smooth texture; overall thick structure interbedded with thickening tuffaceous sandstones and tuffaceous siltstones. Coal (1650' - 1700') = grayish black to black; low grade, lignitic, silty, firm friable; irregular fracture; blocky to elongated, occasionally splintery fracture; very large to large cuttings common in sample; sparkling to greasy luster; abrasive to fibrous texture; no petroleum odor or sample fluorescence; no oil indicators. Tuffaceous Sandstone / Sand (1700' - 1760') = light medium gray with dark brown to black to occasionally olive hues; unconsolidated to easily friable; upper fine to lower medium to occasion- ally very fine grained; well to moderate sorting; sub-rounded to subangular; sub-discoidal to trace sub-prismoidal; predominantly clear to translucent quartz; trace lithic fragments. Tuffaceous Claystone / Tuffaceous Siltstone (1760' - 1820') = light gray to very light gray with light bluish gray secondary hues; poorly indurated to friable; lumpy to clumpy; malleable tenacity; hydrophilic nature masks fracture and cuttings habit; luster is dull to waxy; mostly clay grading to and thinly interbedded with siltstone and scattered very fine grained sandstone; moderately adhesive and cohesive; non calcareous. TBU M-22 12 Tuffaceous Siltstone / Tuffaceous Claystone (1820' - 1880') = light gray to very light gray with light bluish gray secondary hues; poorly indurated to friable; lumpy to clumpy; malleable tenacity; hydrophilic nature masks fracture and cuttings habit; luster is dull to waxy; mostly clay grading to and thinly interbedded with siltstone and scattered very fine grained sandstone; trace coal; moderately adhesive and cohesive; non-calcareous. Sand / Sandstone / Silty Sandstone 1800' - 1950') = light to very light gray; lower medium to upper fine grained; moderate to poor sorting; sub-angular to sub-rounded; poor to moderate sphericity; common clay cement in sandstone; predominantly clear quartz; polished to frosted to grinding surface abrasion; traces of white opaque quartz; often interbedded w 10% very fine grained sand grading to silt, and fine to very fine grained black carbonaceous material; non-calcareous. Sand / Tuffaceous Sandstone (1950' - 2030') = dark medium gray to medium gray with dark brown to olive hues; unconsolidated to easily friable to trace firm; lower medium to upper fine with coarse to very fine being moderately common; minor 2-5mm bit broken grains; sub angular to sub rounded; sub spherical to sub discoidal; poor to moderate sorting; quartz dominant; clear to translucent; dark lithics common and often well rounded; minor carbonaceous material; slightly calcareous; weak reaction to HCL. Tuffaceous Claystone / Coal (2030' - 2090') = dark medium gray to medium gray with dark brown to blackish hues; clumpy to tacky; pulverulent; earthy to irregular fracture; platy to semi scaly cuttings habit; dull to earthy luster; clayey to silty texture; thick to thin and interbedded with relatively large coal seams and thin sands; coals are sub bituminous to lignitic; platy to flaky; hackly to planar fracture; trace visible degassing. Tuffaceous Sandstone (2090' - 2170') = dark medium gray to medium gray with dark brown to blackish hues; easily friable to unconsolidated to trace firm; lower medium to upper fine with coarse to very fine being moderately common; sub rounded to sub angular; sub spherical to sub discoidal; moderate to poor sorting; quartz dominant; clear to translucent; dark lithics; minor carbonaceous material; slightly calcareous; grades to a silty sandstone and continues to fine down through the interval. Tuffaceous Claystone (2170' - 2260') = dark medium gray to medium brown with dark grey to black hues; clumpy to tacky to semi pasty; pulverulent; earthy to irregular fracture; platy to semi scaly cuttings habit; dull to earthy luster; silty to clayey texture; thick to thin and interbedded with relatively large coal seams and thin sands. Coal (2260' - 2280') = matte black to trace black with dark brown hues; sub bituminous to trace lignitic; platy to flaky; hackly to planar fracture; matte to slight resinous; trace visible degassing. Tuffaceous Claystone (2280' - 2340') = dark medium gray to medium grey with dark brown to black hues; clumpy to tacky; pulverulent to malleable; earthy to irregular fracture; platy to nodular to trace bit stacked cuttings habit; dull to earthy to semi waxy luster; silty to clayey texture; good cohesion and moderate to poor adhesion; thick to thin and interbedded with occasional large coal seams and thin sands. Coal (2340' - 2370') = matte black to trace black with very dark brown hues; sub bituminous; platy to flaky cutting habit; hackly to planar fracture; matte to slight resinous; trace visible degassing. Tuffaceous Claystone (2370' - 2450') = medium gray with dark brown to black hues to dark medium grey with trace olive hues; clumpy to lumpy to tacky; pulverulent to malleable; earthy to irregular fracture; platy to nodular cuttings habit; earthy to dull to semi waxy luster; silty to clayey texture; good cohesion and moderate to poor adhesion. Tuffaceous Siltstone (2450' - 2530') = medium light gray to brownish gray; poorly indurated to moderately hard; hard variety is light greenish gray; stiff to dense; crunchy to brittle in parts; massive to TBU M-22 13 equant cuttings; dull earthy luster; slightly cohesive; some very adhesive; earthy fracture; silty to gritty to clayey texture; massive homogeneous silt with common thin clay and sand; scattered angular black fine grained carbonaceous material; inter-beds with occasional thin coal seams; non calcareous. Tuffaceous Sandstone (2530' - 2610') = dark medium gray to medium gray with dark brown to blackish hues; easily friable to unconsolidated to trace firm to hard; lower medium to upper fine with common coarse to very fine grains; sub-rounded to sub-angular; sub- spherical to sub-discoidal; moderate to poor sorting; quartz dominant; clear to translucent; dark lithics; minor carbonaceous material; slightly calcareous; often grades to a silty sandstone; non-calcareous; apparent equal distribution between matrix and grain support; poor porosity and permeability. Tuffaceous Claystone (2610' - 2670') = medium gray with dark brown to black hues to dark medium grey with trace olive hues; clumpy to lumpy to tacky; pulverulent to malleable; earthy to irregular fracture; platy to nodular cuttings habit; earthy to dull to semi- waxy luster; silty to clayey texture; good cohesion and moderate to poor adhesion; non calcareous. Coal (2670' - 2700') = matte black to trace black with very dark brown hues; sub-bituminous; platy to flaky cuttings habit; hackly to planar fracture; matte to slightly resinous luster; trace visible degassing. Sand (2700' - 2790') = dark gray to medium gray to light gray, often trans- lucent to transparent grains; lower coarse to upper fine grained; sub- angular to sub-rounded to rounded; good to medium to poor to occasionally very poor sphericity; poorly sorted; polished to frosted to grinding surface abrasion; often vitreous; immature nature; no visible cement; dominantly hydrophilic clay matrix support; sands becoming interbedded within clays; composed of predominantly quartz with minor various lithic fragments; poor porosity and permeability; slightly calcareous. Tuffaceous Claystone (2790' - 2820') = medium gray with dark brown to black hues to dark medium grey with trace olive hues to trace pale yellowish brown clasts; clumpy to lumpy to tacky; pulverulent to malleable; earthy to irregular fracture; platy to nodular cuttings habit; earthy to dull to semi waxy luster; silty to clayey texture; good cohesion and moderate to poor adhesion. Coal (2820' - 2870') = matte black to trace black with very dark brown hues; sub bituminous; platy to flaky cutting habit; hackly to planar fracture; matte to slight resinous; trace visible degassing. Tuffaceous Claystone / Siltstone (2870' - 2930') = medium gray with dark brown to black hues to medium grey with trace olive to yellowish brown hues; clumpy to lumpy to semi stiff; malleable to pulverulent; irregular fracture; platy to nodular cuttings habit; earthy to dull to semi waxy luster; silty to clayey texture; good cohesion and moderate to poor adhesion; often grades coal (2930' - 2970') = matte black to moderate very dark brown with blackish hues; sub bituminous to lignitic; platy to flaky cutting habit; hackly to planar to sub conchoidal fracture; matte to slight resinous luster; minor visible degassing. Tuffaceous Claystone / Sandstone (2970' - 3110') = medium gray with dark brown to black hues to medium grey with trace olive to yellowish brown hues; clumpy to lumpy to semi stiff; pulverulent; irregular fracture; platy to nodular cuttings habit; earthy to dull to semi waxy luster; silty to clayey texture; moderate to poor cohesion and adhesion; grading towards a tuffaceous siltstone; the sandstones are easily friable to unconsolidated to trace firm; upper fine to lower medium with coarse to very fine being moderately common; trace bit broken 1-2mm grains; sub rounded to sub angular; sub spherical to sub discoidal; moderate to poor sorting; quartz dominant; clear to translucent; dark lithics; minor carbonaceous material; slightly calcareous; grades to a silty sandstone. Tuffaceous Sandstone (3110' - 3200') = dark brown to medium brown with yellowish black to reddish hues; unconsolidated to easily friable to trace firm; upper fine to upper coarse; sub rounded to sub angular; sub spherical to sub discoidal; moderate to poor sorting; clear to translucent quartz dominated; dark lithics and carbonaceous material common; firm clasts range from very to slightly calcareous; interbedded with moderate tuffaceous claystone and siltstone. TBU M-22 14 Coal (3200' - 3260') = matte black to moderate very dark brown to black; firm; sub-bituminous to lignitic; platy to flaky cuttings habit; hackly to planar to sub-conchoidal fracture; matte to slightly resinous luster; common visible degassing. Tuffaceous Sandstone (3260' - 3330') = dark brown to medium brown with yellowish black to reddish hues, rare pinkish grains observed; unconsolidated to easily friable to trace firm; upper fine to upper coarse grained; sub-round to sub-angular; sub-spherical to sub- discoidal; moderately to poorly sorted; clear, transparent to translucent quartz dominated; dark lithics and carbonaceous material common; firm clasts range from very to slightly calcareous; interbedded with moderate tuffaceous claystone and siltstone; trace to common off white to light gray ash observed in sample; moderately calcareous. Tuffaceous Siltstone (3330' - 3400') = medium gray to light gray, occasionally pink, off-white; poorly indurated; slightly malleable to sectile; mushy to pasty; tacky; non to slightly cohesive moderate to very adhesive; sub-earthy luster; silty to clayey to ashy texture; hydrophilic; composed of >90% silt and scattered various detrital material; interbedded with tuffaceous claystone, tuffaceous sandstone, and thin coal seams; moderately to very calcareous. Tuffaceous Sandstone (3400' - 3500') = dark brown to medium brown with yellowish black to reddish hues, rare pinkish grains; unconsolidated to easily friable to trace firm; upper fine to upper coarse grained, scattered very coarse grains throughout; polished to frosted to grinding surface abrasion; rounded to sub-rounded to sub-angular to very angular; sub-spherical to sub- discoidal; moderately to poorly sorted; clear, transparent to translucent quartz dominated; dark lithics and carbonaceous material common; firm clasts range from very to slightly calcareous; interbedded with moderate tuffaceous claystone and siltstone; trace to common off white to light gray ash observed in sample; moderately to very calcareous. Tuffaceous Siltstone (3500' - 3580') = medium gray to light gray, often off- off-white, trace pink; poorly indurated; slightly malleable to sectile; mushy to pasty; tacky; non to slightly cohesive moderate to very adhesive; sub-earthy luster; silty to clayey to ashy texture; hydrophilic; composed of >90% silt and scattered various detrital material; interbedded with tuffaceous claystone, tuffaceous sandstone, and very thin coal seams; moderately to very calcareous. Coal (3580' - 3620') = matte black to moderate very dark brown to black; firm; sub-bituminous to lignitic; platy to flaky cuttings habit, very large cuttings are common; hackly to planar to sub-conchoidal fracture; matte to slightly resinous luster; common visible degassing. Tuffaceous Sandstone (3620' - 3660') = medium brown with yellowish black to dark brown; unconsolidated to easily friable to trace firm; upper fine to lower coarse; sub angular to sub rounded; sub spherical to sub discoidal; moderate to poor sorting; clear to translucent quartz dominated; dark lithics and carbonaceous material common; grain supported. Tuffaceous Sandstone (3660' - 3740') = medium gray with dark brown to black hues to medium brown with black to dark grayish hues; easily friable to unconsolidated; lower fine to upper medium; sub angular to sub rounded; sub spherical to sub discoidal; moderate to poor sorting; clear to translucent quartz dominated; dark lithics and carbonaceous material common; typically grain supported but matrix supported clasts not uncommon; minor tuffaceous claystones and siltstones near the bottom of the interval. Tuffaceous Claystone (3740' - 3810') = medium gray with black to brownish hues to dark medium gray; clumpy to lumpy to semi stiff to tacky; malleable to pulverulent; irregular fracture; nodular to semi platy cuttings habit; earthy to dull to semi waxy luster; clayey to silty texture; moderate to poor cohesion and adhesion; tuffaceous siltstones common; typically blackish brown to blackish gray; crumbly; moderate amount of tuffaceous to unconsolidated sandstone. Coal (3810' - 3840') = matte black to moderate very dark brown with blackish hues; sub bituminous to lignitic; platy to flaky; hackly to planar; matte to slight resinous luster; minor visible degassing. TBU M-22 15 Tuffaceous Claystone (3840' - 3950') = dark medium gray with brownish hues to medium gray with black to dark brown hues; clumpy to lumpy to semi stiff to tacky; sectile to malleable to pulverulent; irregular fracture; nodular to semi platy cuttings habit to trace bit stacked; earthy to dull to semi waxy luster; clayey to silty texture; moderate cohesion and poor adhesion; overall thick and interbedded with very thin sands and the occasional thick coal. Coal (3950' - 3970') = matte black to moderate very dark brown with blackish hues; platy to flaky; hackly to semi planar; sub bituminous to trace lignitic; matte to slight resinous luster; visible degassing. Tuffaceous Sandstone (3990' - 4090') = medium gray with pale brown to off white hues to dark medium gray with brown to slightly olive hues; easily friable to unconsolidated; upper fine to lower medium with lower coarse and upper very fine semi common; sub angular to sub rounded; sub spherical to sub discoidal; poor to moderate sorting; clear to translucent quartz dominated; dark lithics and carbonaceous material common; typically grain supported but matrix supported clasts not uncommon; minor tuffaceous claystones and siltstones. Coal (4090' - 4130') = matte black to black to trace very dark brown with blackish hues; hackly to semi planar to trace sub conchoidal; platy to flaky; sub bituminous to trace lignitic; matte to slight resinous luster; visible degassing. Tuffaceous Sandstone (4130' - 4210') = dark medium brown with greyish hues to medium gray with brown to olive hues; easily friable to minor unconsolidated; lower very fine to upper medium with lower coarse and upper very fine semi common; trace 2-3mm grains; sub angular to sub rounded to rounded; sub spherical to sub discoidal; poor to moderate sorting; clear to translucent quartz dominated; dark lithics and carbonaceous material common; typically grain supported but matrix supported clasts not uncommon; minor tuffaceous claystones and siltstones. Tuffaceous Claystone / Sandstone (4210' - 4270') = dark medium gray with brownish hues to medium brown with black to dark brown hues; lumpy to semi stiff to tacky; sectile; irregular to trace planar fracture; nodular to semi platy to trace bit stacked cuttings habit; earthy to dull to semi waxy luster; clayey to silty texture; moderate cohesion and poor adhesion; interbedded with similar sized. Tuffaceous Claystone / Sandstone / Coal (4270' - 4320') = dark medium gray with brownish hues to medium gray with brown to olive hues; lumpy to stiff to tacky; sectile to malleable; irregular fracture; nodular to semi platy to trace bit stacked cuttings habit; earthy to dull luster; silty texture; interbedded with similar sized tuffaceous sandstones and thin to moderate coals. Coal (4320' - 4380') = matte black to black to trace very dark brown with blackish hues; hackly to semi- planar to trace sub-conchoidal; fibrous; platy to flaky; sub-bituminous to trace lignitic; matte to slight resinous luster; visible degassing. Tuffaceous Sandstone (4380' - 4480') = dark medium brown with greyish hues to medium gray with brown to olive hues; easily friable to minor unconsolidated; lower very fine to upper medium with lower coarse and upper very fine grained semi-common; trace to common 2-3mm grains; sub-angular to sub- rounded to rounded; sub-spherical to sub- discoidal; poorly to moderately sorted; clear to translucent quartz dominated; dark lithics and carbonaceous material common; interbedded with tuffaceous siltstone and claystone and minor coals; grain supported but matrix supported clasts not uncommon; moderately calcareous. Tuffaceous Siltstone (4480' - 4540') = very light gray to white, occasionally pink; poor to fair sorting; silt sized particles with scattered very fine upper sand grains; mushy; crumbly; irregular to earthy fracture; massive cuttings habit; dull luster; gritty texture; massive interbedded with and grading to tuffaceous sandstone; occasional micro-thin black coal stringers; very to moderately calcareous. Tuffaceous Claystone (4540' - 4610') = medium dark gray to brownish gray; poorly indurated; mushy to pasty; crumbly to stiff; fracture and cuttings properties masked by hydration of sample; non to slightly TBU M-22 16 cohesive; moderate to very adhesive; dull, earthy luster; silty to clayey to ashy texture; hydrophilic; grading to and thinly interbedded with tuffaceous siltstone and a very fine sandstone and thin coal seams; very to moderately calcareous. Coal (4610' - 4650') = black to matte black to trace very dark brownish black; hackly to semi-planar to trace sub- conchoidal; fibrous; platy to flaky; sub-bituminous to trace lignitic; matte to slight resinous luster; visible degassing. Tuffaceous Sandstone (4650' - 4730') = medium brown with greyish hues to dark medium gray with brown to olive hues; easily friable to minor unconsolidated to trace firm; lower very fine to upper medium with lower coarse and upper very fine semi common; sub angular to sub rounded to rounded; sub spherical to sub discoidal; poor to moderate sorting; clear to translucent quartz dominated; dark lithics and carbonaceous material common; typically grain supported with matrix supported clasts not uncommon; moderate amount of tuffaceous claystone with minor siltstones. Tuffaceous Claystone (4730' - 4780') = medium gray with dark brownish hues to medium brown with black to olive hues; lumpy to stiff to semi tacky; sectile to malleable; irregular fracture to trace planar; nodular to semi platy to minor bit stacked cuttings habit; earthy to dull luster; silty texture; relatively thick and interbedded with thin sands. Tuffaceous Claystone (4780' - 4820') = medium gray with dark brownish hues; lumpy to stiff; sectile to malleable; irregular fracture; nodular cuttings habit; earthy to dull luster; clayey texture. Coal (4820' - 4860') = matte black to black to trace very dark brown with blackish hues; hackly to semi planar to trace sub conchoidal; platy to flaky cuttings habit; sub bituminous to trace lignitic; matte to waxy luster; visible degassing. Tuffaceous Sandstone (4860' - 4930') = light medium grey with pale olive hues to medium grey with pale brown hues; easily friable to unconsolidated to trace firm; upper fine to lower medium with trace very fine; sub rounded to sub angular to rounded; sub spherical to sub discoidal; moderate sorting; clear to translucent quartz dominated; minor dark lithics and carbonaceous material; overall grain supported; minor tuffaceous claystones and siltstones. Tuffaceous Claystone (4930' - 4970') = dark medium gray with dark brownish hues; lumpy to stiff; sectile to malleable; irregular fracture; nodular to tabular to trace bit stacked cuttings habit; earthy to dull to semi waxy luster; clayey texture. Tuffaceous Sandstone / Claystone (4970' - 5070') = light medium grey with pale brown hues to medium grey with black to olive hues; easily friable to unconsolidated; lower medium to upper fine with moderate lower very fine to lower coarse; sub rounded to sub angular; sub spherical to sub discoidal; moderate sorting; clear to translucent quartz dominated; minor dark lithics and carbonaceous material; overall grain supported; moderate interbedded tuffaceous claystones and trace siltstones. Tuffaceous Sandstone (5070' - 5140') = light medium grey to pale olive to medium grey with pale brown hues; easily friable to unconsolidated to trace firm; upper fine to lower medium with trace very fine grained; sub-angular to sub- rounded to rounded; sub-spherical to sub-discoidal; moderate sorting; clear to translucent quartz dominated; minor dark lithics and carbonaceous material; overall grain supported; minor tuffaceous claystones and siltstones; moderately to very calcareous. Tuffaceous Claystone (5140' - 5190') = medium gray with dark brownish hues to medium brown with black to olive hues; lumpy to stiff to semi tacky; sectile to malleable; irregular fracture to trace planar; nodular to semi platy to minor bit stacked cuttings habit, often massive cuttings; earthy to dull luster; gritty to silty texture; relatively thick and interbedded with siltstone and thin sands; moderately to very calcareous. TBU M-22 17 Coal (5190' - 5240') = matte black to black to trace very dark brown with blackish hues; hackly to semi- planar to trace sub-conchoidal; platy to flaky cuttings habit; sub-bituminous to trace lignitic; matte to waxy luster; fibrous; visible degassing. Tuffaceous Sandstone / Claystone (5240' - 5320') = light medium grey with pale brown hues; easily friable to unconsolidated; lower medium to upper fine; sub rounded; sub spherical; moderate sorting; clear to translucent quartz dominated; minor dark lithics and carbonaceous material; overall grain supported; interbedded with minor tuffaceous claystones and siltstones and minor coal seams. Coal (5320' - 5360') = matte black to black to trace very dark brownish black; hackly to semi-planar to occasionally sub-conchoidal; platy to flaky cuttings habit; sub-bituminous to lignitic; matte to waxy luster; fibrous; visible degassing. Tuffaceous Siltstone / Tuffaceous Claystone (5360' - 5440') = light medium gray to light brown gray to pinkish gray; poor induration; slightly sectile to poorly malleable; clumpy to clotted; overall mushy to pasty; slimy; non to very slightly cohesive; moderately adhesive; sub-earthy fracture; sub- nodular cuttings habit; earthy luster; silty to clayey to ashy texture; massive gradational beds of silty clays composed of 50% tuffaceous silt, 50% tuffaceous clay; minor laminations of lignitic coal moderately to very calcareous. Tuffaceous Sandstone / Claystone (5440' - 5500') = light medium gray with pale grayish brown hues; easily friable to unconsolidated; lower medium to upper fine grains; sub-rounded; sub-spherical; moderate sorting; clear to translucent quartz dominated; minor dark lithics and carbonaceous material; overall grain supported; interbedded with minor tuffaceous claystones, siltstones, and coals; moderately to very calcareous. Tuffaceous Siltstone / Tuffaceous Claystone (5500' - 5570') = light medium gray with grayish brown, grayish pink; poor induration; slightly sectile to poorly malleable; clustered to clotted; overall mushy to pasty; slimy; non to very slightly cohesive; moderately adhesive; sub-earthy fracture; sub- nodular habit; earthy luster; silty to clayey to ashy textures; massive gradational beds of silty clays composed of 50% tuffaceous silt, 50% tuffaceous clay; minor beds of lignitic coal; moderately to very calcareous. Tuffaceous Sandstone (5570' - 5640') = light medium grey to grayish brown to olive gray with pale brown hues; easily friable to unconsolidated to trace firm; upper fine to lower medium with trace very fine grained, trace to common 2-3mm grains; sub-angular to sub- rounded to rounded; sub-spherical to sub- discoidal; moderately sorted; clear to translucent quartz dominated; minor dark lithics and carbonaceous material; overall grain supported; minor tuffaceous claystones and tuffaceous siltstones; moderately calcareous. Tuffaceous Siltstone / Tuffaceous Claystone (5640' - 5730') = light medium gray to light brown gray to pinkish gray; poor induration; slightly sectile to poorly malleable; clumpy to clotted; overall mushy to pasty; non to very slightly cohesive; moderately adhesive; sub-earthy fracture; sub-nodular cuttings habit; earthy luster; silty to clayey to ashy texture; massive gradational beds of silty clays composed of 50% tuffaceous silt, 50% tuffaceous clay; minor laminations of lignitic coal moderately calcareous. Tuffaceous Claystone (5720' - 5770') = dark medium gray with dark brownish hues to medium brown with black to olive hues; lumpy to stiff; sectile to malleable; irregular fracture to trace planar; nodular to semi platy to trace bit stacked cuttings habit; earthy to dull luster; silty texture; relatively thick and interbedded with thin sands. Tuffaceous Sandstone(5770' - 5850') = light medium grey with pale brown hues to dark medium gray with pale yellowish brown to olive hues; easily friable to unconsolidated to trace firmly friable; lower medium to upper fine with lower very fine to upper coarse common; sub rounded to sub angular to rounded; sub spherical to trace sub discoidal; poor to moderate sorting; overall clear to translucent quartz dominated; minor dark lithics and carbonaceous material; grain supported; minor tuffaceous claystone and siltstone. TBU M-22 18 Tuffaceous Claystone (5850' - 5890') = medium brown with black to olive hues; clumpy to stiff; sectile to malleable; irregular fracture to planar; nodular to semi platy cuttings habit; earthy to dull luster; silty to clayey texture; relatively thick and interbedded with thin sandstones. Tuffaceous Sandstone (5890' - 5990') = light medium grey with pale brown hues to dark medium gray with moderate brown to olive hues; easily friable to unconsolidated to trace firmly friable; sub spherical to trace sub discoidal; lower medium to upper fine with lower very fine to upper coarse common; poor to moderate sorting; sub rounded to sub angular to rounded; overall clear to translucent quartz dominated; minor dark lithics and carbonaceous material; grain supported; minor tuffaceous claystone and siltstone. Tuffaceous Claystone (5990' - 6020') = medium brown with black to olive hues; clumpy to stiff; sectile to malleable; irregular fracture; nodular to trace semi platy cuttings habit; earthy to dull luster; silty to clayey texture. Tuffaceous Sandstone (6020' - 6080') = medium gray to grayish brown to dark medium gray with pale brown hues; unconsolidated to easily friable; sub spherical; upper medium to lower fine; lower very fine to upper coarse common; poor to moderate sorting; sub angular to subrounded; clear to translucent quartz dominated; dark lithics and carbonaceous material common; grain supported. Tuffaceous claystone (6080' - 6120') = medium brown with black to olive hues; medium gray with dark brown hues; clumpy to stiff; sectile to malleable; irregular fracture; nodular to trace semi platy cuttings habit; earthy to dull luster; silty to clayey texture. Tuffaceous sandstone (6120' - 6220') = medium gray to grayish brown to dark medium gray with pale brown hues; unconsolidated to easily friable; lower medium to lower fine; to upper coarse common; poor to moderate sorting; sub spherical to trace sub discoidal; sub angular to subrounded to trace angular; clear to translucent quartz dominated; dark lithics and carbonaceous material common; grain supported. Sand (6220' - 6290') = medium gray with very dark brown to black hues to a salt and pepper appearance; unconsolidated to minor easily friable; lower coarse to upper fine with upper coarse to upper very fine common; poor sorting; sub angular to angular to sub rounded; sub spherical to minor sub prismoidal to sub discoidal; impact quartz common; overall dominated by clear to translucent quartz; dark lithics and carbonaceous material common; trace siltstone clasts; semi well indurated. Coal (6290' - 6330') = black to matte black to trace very dark brown with blackish hues; hackly to semi planar to trace sub conchoidal; matte to waxy luster; platy to flaky cuttings habit; sub bituminous to lignitic; visible degassing. Tuffaceous claystone / sandstone (6330' - 6420') = medium brown with black to olive hues; dark medium gray with pale brown hues; clumpy to stiff; sectile to malleable; irregular fracture; nodular to trace semi platy cuttings habit; earthy to dull luster; silty to clayey texture; tuffaceous sandstones are typically; easily friable to unconsolidated; lower medium to upper fine; to upper coarse common; poor to moderate sorting; sub spherical to trace sub discoidal; sub angular to subrounded to trace angular; clear to translucent quartz dominated; dark lithics and carbonaceous material common; grain supported. Sand / tuffaceous sandstone / siltstone (6420' - 6530') = medium gray with very dark brown to black hues to dark medium brown with black to reddish hues; unconsolidated to easily friable; lower coarse to upper fine with upper coarse to upper very fine common; poor sorting; sub angular to angular to sub rounded; sub spherical to minor sub prismoidal to sub discoidal; dominated by clear to translucent quartz; dark lithics and carbonaceous material common; minor siltstone clasts; semi well indurated. Coal (6530' - 6550') = black to matte black to trace very dark brown with blackish hues; hackly to semi planar to trace sub conchoidal; matte to waxy luster; platy to flaky cuttings habit; sub bituminous to lignitic; visible degassing. TBU M-22 19 Sand / tuffaceous sandstone / siltstone (6550' - 6650') = medium gray with very dark brown to black hues to dark medium brown with black to reddish hues; unconsolidated to easily friable; lower coarse to upper fine grained, occasionally upper coarse to upper fine, trace to common 2-3mm grains; poorly sorted; sub-angular to angular to sub- rounded; sub-spherical to minor sub- prismoidal to sub-discoidal; dominated by clear to translucent quartz; dark lithics and carbonaceous material common; minor siltstone clasts; semi- well indurated; moderately calcareous. Tuffaceous sandstone / conglomerate sand (6650' - 6740') = very light gray, with a salt and pepper appearance; upper coarse to lower medium grains with some very coarse to 2-3mm grains; sub-angular to sub-rounded; moderate sphericity; poorly sorted; frosted to grinding to polished surface abrasion, occasionally chipped or impacted grains; sub-spherical to minor sub-prismoidal to sub- discoidal; predominantly clear to trans- lucent quartz; common dark lithics and carbonaceous material; interbedded with tuffaceous siltstone; semi-well indurated; very to moderately calcareous. Sand / tuffaceous sandstone / siltstone (6740' - 6810') = light to medium to dark gray, some dark blackish brown hues, occasionally red to pinkish hues; unconsolidated to easily friable; lower coarse to upper fine grained, occasionally upper coarse to upper fine, trace to common 2-3mm grains; poorly sorted; sub-angular to angular to sub- rounded; sub-spherical to minor sub- prismoidal to sub-discoidal; dominated by clear to translucent quartz; frosted to polished surface abrasion; dark lithics and carbonaceous material common; minor siltstone clasts; semi- well indurated; very to moderately calcareous. Coal (6810' - 6870') = black to matte black to trace very dark brown with blackish hues; hackly to semi- planar to sub-conchoidal; matte to waxy luster; platy to flaky cuttings habit, often massive cuttings; sub- bituminous to lignitic; visible degassing. Sand (6870' - 6930') = medium gray with black to dark brown hues to dark medium brown with dusky reddish black hues; unconsolidated to easily friable; upper medium to upper fine with lower coarse to upper very fine common; poor to moderate sorting; sub angular to angular to sub rounded; sub spherical to minor sub prismoidal and sub discoidal; dominated by clear to translucent quartz; dark lithics and carbonaceous material common. Tuffaceous claystone (6930' - 7018') = dark grey to medium grey with dark blackish brown to dark olive hues; clumpy to lumpy; sectile to malleable to stiff irregular fracture; nodular to semi platy cuttings habit; earthy to dull luster; clayey to silty texture; moderate cohesion; poor adhesion; moderate unconsolidated sands to easily friable tuffaceous sandstones; minor coal. Tuffaceous Claystone / Siltstone (7018' - 7130') = overall brownish gray to light to medium olive gray; crumbly to slightly crunchy tenacity; irregular to earthy fracture; dominantly sub-planar to nodular cuttings habit; dull, earthy luster, occasionally sub- waxy; silty to smooth clayey texture; massive bedding, no visible structure; moderately to very calcareous; inter- bedded with unconsolidated sands to easily friable tuffaceous sandstones. Sand / Tuffaceous Sandstone (7130' - 7210') = pale yellowish gray to salt and pepper colored coarse grained sand and grain-supported clumps of medium- grained tuffaceous sandstone; quartz- dominated with lesser black and cream- colored lithics; fair sorting; rounded to sub-rounded to sub-angular; frosted, grinding to polished surface abrasion; vitreous; moderate to high sphericity; minor subangular clumps of light brown tuffaceous siltstone with occasional blown/black wavy micro-bedding; minor coal; moderately to very calcareous. Tuffaceous Claystone / Tuffaceous Siltstone (7210' - 7280') = brownish gray to light to medium olive gray; crumbly to slightly crunchy tenacity; irregular to earthy fracture; dominantly sub-planar to nodular cuttings habit; dull, earthy luster, occasionally sub- waxy; silty to smooth clayey texture; massive bedding, no visible structure; moderately to very calcareous; inter- bedded with unconsolidated sands to easily friable tuffaceous sandstones. TBU M-22 20 Sand / Tuffaceous Sandstone (7280' - 7350') = pale yellow-gray to salt and pepper colored coarse grained sand and grain-supported clumps of medium- grained tuffaceous sandstone; quartz- dominated with lesser black and cream- colored lithics; fair sorting; rounded to sub-rounded to sub-angular; frosted, grinding to polished surface abrasion; vitreous; moderate to high sphericity; minor subangular clumps of light brown tuffaceous siltstone with occasional blown/black wavy micro-bedding; slightly calcareous. Tuffaceous Claystone / Tuffaceous Siltstone (7350' - 7420') = brown-gray to light to medium olive gray; crumbly to slightly crunchy tenacity; irregular to earthy fracture; dominantly sub- planar to nodular cuttings habit; dull, earthy luster, occasionally sub-waxy; silty to smooth clayey texture; massive bedding, no visible structure; moderate to very calcareous; interbedded with unconsolidated sands to easily friable tuffaceous sandstones, coal. Coal (7420' - 7460') = black to brownish black; brittle to crunchy; blocky, earthy fracture; bit disaggregated; wedge-like cuttings habit; resinous to waxy to dull luster; abrasive texture; thin structure; weak to moderate outgassing observed. Coal (7460' - 7490') = black to matte black to trace very dark brown with blackish hues; platy to flaky cuttings habit; hackly to semi planar to trace sub conchoidal; matte to waxy luster; sub bituminous to minor lignitic; visible degassing. Coal (7490' - 7570') = black to matte black to trace very dark brown with blackish hues; platy to flaky cuttings habit; hackly to semi planar to trace sub conchoidal; matte to waxy luster; sub bituminous to minor lignitic; visible degassing; minor tuffaceous siltstone and sand; siltstone typically has a moderate amount of carbonaceous banding; thin interbedded sands are observed in the coals; often quartz dominated; sub rounded to angular; upper medium to lower fine; well sorted. Coal (7570' - 7660') = black to matte black to trace dark brown with blackish hues; platy to flaky cuttings habit; hackly to semi planar to minor sub conchoidal; sub bituminous to trace lignitic; matte to waxy luster; visible degassing; minor tuffaceous siltstone and sand with a moderate increase in the 7590 and 7620 samples; siltstone typically has a moderate amount of carbonaceous banding; crumbles easily; visible off gassing; thin interbedded sands are observed in the coals and unconsolidated; often quartz dominated. Carbonaceous Shale / Coal (7660' - 7760') = very dark brown to black with dark brownish hues to minor pale medium gray; very crumbly to pulverulent; irregular to earthy fracture; amorphous cuttings habit; dull to earthy luster; interbedded with devitrified ash and silt with trace sands; falls apart easily when prodded; moderate visible degassing; the coals are platy to flaky cuttings habit; hackly to semi planar to minor sub conchoidal; sub bituminous to trace lignitic; matte to waxy luster; visible degassing; sand content slightly increases down through the interval. Tuffaceous Claystone / Tuffaceous Siltstone (7760' - 7840') = brown-gray to light to medium olive gray; crumbly to slightly crunchy tenacity; irregular to earthy fracture; dominantly sub- planar to nodular cuttings habit; dull, earthy luster, occasionally waxy; silty to smooth clayey texture; massive beds, no visible structure; moderate to very calcareous; interbedded with unconsolidated sands to easily friable tuffaceous sandstones and coal. Carbonaceous Shale / Coal (7840' - 7910') = very dark brown to black with dark brownish hues to minor pale medium gray; very crumbly to pulverulent; irregular to earthy fracture; amorphous cuttings habit; dull to earthy luster; interbedded with devitrified ash and silt with trace sands; falls apart easily when prodded; moderate visible degassing; coals have a platy to flaky cuttings habit; hackly to semi-planar to minor sub- conchoidal; sub-bituminous to trace lignitic; matte to waxy luster; trace visible degassing. Tuffaceous Siltstone (7910' - 7970') = brownish gray to light to medium olive gray; tough and brittle, occasionally crumbly tenacity; earthy fracture; wedge-like to tabular cuttings habit; dull, earthy luster; dominantly silty but common slightly gritty texture observed; trace micro-thin carbonaceous laminae; trace to common white to off white volcanic ash scattered throughout sample; slightly calcareous. TBU M-22 21 Tuffaceous Sand / Conglomerate Sand / Conglomerate Sandstone (7970' - 8070') = clear to translucent to light gray to medium gray, trace red-orange, rare trace pale blue; predominantly unconsolidated; lower fine to upper very coarse grained, occasionally grading to pebbles; poorly to fairly sorted; sub- rounded to sub-angular to very angular; minor amounts light gray to light gray sandstone with slightly calcareous cement, very fine grained, sub-rounded to sub-angular, well sorted, interbedded with and occasionally grades to tuffaceous siltstone; often interbedded with carbonaceous shale; common white to off white volcanic ash scattered throughout sample; slightly calcareous. Sand / Sandstone (8060' - 8140') = pale medium gray to medium gray with off white hues; unconsolidated to easily friable to trace firm; upper very fine to lower coarse with very coarse semi common; moderate to poor sorting; sub rounded to angular to sub angular; sub spherical to trace sub prismoidal; grain supported; kaolinite to minor tuffaceous matrix; samples dominated by clear to translucent quartz with minor carbonaceous sediment and trace dark lithics; trace siltstone and claystone observed. Sand / Sandstone (8140' - 8230') = medium gray with off white hues to pale medium gray to medium grayish white; unconsolidated to easily friable to trace firm; lower fine to lower medium with upper coarse being semi common; moderate to poor sorting; sub rounded to angular to sub angular; sub spherical to trace sub prismoidal; grain supported to occasional easily friable matrix supported clasts; kaolinite to minor tuffaceous matrix; samples dominated by translucent to clear to trace milky white quartz with minor carbonaceous sediment and trace dark lithics; trace siltstone and claystone observed. Sand / Sandstone (8230' - 8310') = medium gray with off white hues to pale medium gray to medium grayish white; unconsolidated to easily friable to trace firm; upper fine to lower medium with lower coarse to upper very fine being common; moderate to poor sorting; sub rounded to angular to sub angular; sub spherical; grain supported to occasional easily friable matrix supported clasts; kaolinite to minor tuffaceous matrix; samples dominated by translucent to clear to trace milky white quartz; minor carbonaceous sediment and trace dark lithics; trace siltstone and claystone. Sand / Sandstone (8310' - 8410') = pale medium gray to medium grayish white to medium gray with off white hues; overall slight salt and pepper appearance; unconsolidated to easily friable; upper fine to lower medium with lower coarse to upper very fine being common; moderate to poor sorting; sub rounded to sub angular to angular; sub spherical to trace sub prismoidal; grain supported to occasional easily friable matrix supported clasts; kaolinite to minor tuffaceous matrix; samples dominated by translucent to clear to trace milky white quartz; minor carbonaceous sediment and trace dark lithics; trace siltstone and claystone. Sand / Sandstone (8410' - 8520') = pale medium gray to medium grayish white to medium gray with off white hues; overall slight salt and pepper appearance; unconsolidated to easily friable; upper fine to lower medium with lower coarse to upper very fine being common; moderate to poor sorting; sub rounded to sub angular to angular; sub spherical; dominated by translucent to clear to occasional milky white quartz; minor carbonaceous sediment and trace dark lithics; grain supported; moderate easily friable matrix supported clasts and often tuffaceous to minor kaolinite matrix; overall downward fining through the samples; trace siltstone and claystone. Tuffaceous Sandstone (8520' - 8610') = medium gray with blackish hues to dark medium gray; unconsolidated to easily friable; lower medium to lower fine; to upper coarse common; poor to moderate sorting; sub spherical to trace sub discoidal; sub angular to subrounded to angular; clear to translucent quartz dominated; grain to moderate tuffaceous matrix supported; moderate carbonaceous material and trace dark lithics; minor siltstones. Sand / Tuffaceous Sandstone / Conglomerate Sandstone (8610' - 8710') = pale medium gray to medium grayish white to medium gray with off white hues; overall slight salt and pepper appearance; unconsolidated to easily friable; upper fine to lower medium grained with lower coarse to upper very fine being common; moderate to poor sorting; sub-rounded to sub-angular to angular; sub-spherical; dominated by translucent to clear to occasional milky white quartz; minor carbonaceous sediment and TBU M-22 22 trace dark lithics; grain supported; moderate easily friable matrix supported clasts and often tuffaceous to minor kaolinite matrix, increasing matrix support with depth; interbedded with siltstone and claystone. Tuffaceous Siltstone (8710' - 8770') = brownish gray to light to medium olive gray; tough and brittle, occasionally crumbly tenacity; earthy fracture; wedge-like to tabular cuttings habit; dull, earthy luster; dominantly silty but common slightly gritty texture; trace micro-thin carbonaceous laminae; common white to off white volcanic ash scattered throughout sample; slightly to moderately calcareous. Sand / Sandstone (8770' - 8880') = very pale medium gray to medium grayish white to medium gray with off white to pale brown hues; minor slight salt and pepper appearance; unconsolidated to occasionally easily friable; upper fine to upper medium with lower coarse to upper very fine being common; moderate to poor sorting; sub rounded to sub angular; sub spherical; dominated by translucent to clear to occasional milky white quartz; minor carbonaceous sediment and trace dark lithics; grain supported; moderate easily friable grain to minor matrix supported; predominantly tuffaceous; trace siltstone and claystone. Sand / Sandstone (8880' - 8970') = medium grayish white to very pale medium gray to medium gray with off white to pale brown hues; salt and pepper appearance; unconsolidated to minor easily friable; upper medium to upper fine with upper coarse to lower very fine being common; poor to moderate sorting; sub rounded to sub angular; sub spherical to trace sub prismoidal; dominated by translucent to clear to occasional milky white quartz; minor carbonaceous sediment and trace dark lithics; grain supported; moderate easily friable matrix supported clasts; matrix is predominantly tuffaceous; minor tuffaceous claystone and siltstones. Sand / Sandstone (8970' - 9070') = very pale medium gray to medium gray with off white to pale brown hues; unconsolidated to easily friable; upper medium to upper fine; poor to moderate sorting; sub rounded to sub angular; sub spherical; dominated by translucent to clear quartz; minor carbonaceous sediment and trace dark lithics; grain supported; moderately easily friable grain supported to minor matrix supported clasts; matrix is predominantly tuffaceous; very to moderately calcareous; trace interbedded siltstone and claystone. Sand / Sandstone (9070' - 9190') = white to grayish white to very pale medium gray with occasional pale brown hues, scattered light red grains; salt and pepper appearance; unconsolidated to minor easily friable; upper medium to upper fine grained with upper coarse to lower very fine being common; poor to moderate sorting; round to sub-round to sub-angular to occasionally angular; sub-spherical to trace sub- prismoidal; dominated by translucent to clear grains occasional milky white quartz; minor carbonaceous sediment and trace dark lithics; grain supported; moderate easily friable grain supported to minor matrix supported clasts; matrix is predominantly tuffaceous; very to moderately calcareous; trace inter- bedded siltstone and claystone. Sand / Tuffaceous Sandstone / Conglomerate Sandstone (9190' - 9280') = pale medium gray to medium grayish white to medium gray, off white to white hues; overall slight salt and pepper appearance; unconsolidated to easily friable; upper medium to lower fine grained with lower coarse to upper very fine being common; moderate to poor sorting; sub-rounded to sub-angular to angular; sub-spherical; dominated by translucent to clear to occasional milky white quartz; minor carbonaceous sediment and trace dark lithics; grain supported; moderate easily friable matrix supported clasts and often tuffaceous; very calcareous; interbedded with trace siltstone and claystone. Sand / Tuffaceous Sandstone / Conglomerate Sandstone (9280' - 9380') = pale medium gray to medium grayish white to medium gray, off white to white hues, scattered trace red/pink to red-orange; overall slight salt and pepper appearance; unconsolidated to easily friable; upper medium to lower fine grained with lower coarse to upper very fine common; moderate to poor sorting; sub- rounded to sub- angular to angular; sub- spherical; dominated by translucent to clear to occasional milky white quartz; minor carbonaceous sediment and trace dark lithics; grain supported; moderate easily friable matrix supported clasts and often tuffaceous; very calcareous; interbedded with trace siltstone and claystone. TBU M-22 23 Sand / Sandstone (9380' - 9470') = medium gray to dark medium grayish white to very pale medium gray to medium gray with off white to pale brown hues; salt and pepper appearance; unconsolidated to easily friable; upper medium to upper fine with upper coarse to lower very fine being common; poor to moderate sorting; sub angular to sub rounded; sub spherical; dominated by translucent to clear to occasional milky white quartz; minor carbonaceous sediment and trace dark lithics; grain supported; moderate easily friable matrix supported clasts; predominantly tuffaceous; trace siltstone and claystone. Sand / Sandstone (9470' - 9550') = medium gray to dark medium grayish white to very pale medium gray to medium gray with off white to pale brown hues; salt and pepper appearance; unconsolidated to easily friable; lower coarse to upper fine with upper coarse to lower fine being common; poor to moderate sorting; sub rounded to sub angular; sub spherical to trace sub prismoidal; dominated by translucent to clear to occasional milky white quartz; minor carbonaceous sediment and trace dark lithics; grain supported; minor matrix supported tuffaceous clasts; trace siltstone and claystone. Sand / Sandstone (9550' - 9660') = medium gray to medium grayish white to very pale medium gray to medium gray with off white to pale brown hues; samples have an overall salt and pepper appearance; unconsolidated to easily friable; lower coarse to upper fine with upper coarse to lower fine being common; poor to moderate sorting; sub rounded to sub angular; sub spherical; dominated by translucent to clear quartz; minor carbonaceous sediment and trace dark lithics; grain supported; minor matrix supported tuffaceous clasts; trace siltstone and claystone. Sand / Sandstone (9660' - 9750') = very pale medium gray to medium gray dark medium gray with pale brownish hues; unconsolidated to easily friable; upper medium to upper fine; minor granule sized grains; poor to moderate sorting; sub angular to sub rounded to angular; sub spherical; dominated by translucent to clear quartz; minor carbonaceous sediment and trace dark lithics; grain supported; moderate easily friable matrix supported clasts; predominantly tuffaceous; interbedded with trace siltstone and claystone. Sand / Tuffaceous Sandstone / Conglomerate Sandstone (9750' - 9860') = pale medium gray to medium grayish white to medium gray, off white to white hues, trace red/pink, trace pale blue green; overall slight salt and pepper appearance; unconsolidated to easily friable; upper medium to lower fine grained with lower coarse to upper very fine common; moderate to poor sorting; sub- rounded to sub- angular to angular; sub- spherical; dominated by translucent to clear to occasional milky white quartz; polished to frosted to occasionally grinding surface abrasion; vitreous; minor carbonaceous sediment and trace dark lithics; grain supported; moderate easily friable matrix supported clasts and often tuffaceous; slightly to moderately calcareous; interbedded with tuffaceous siltstone and claystone. Sand / Sandstone (9860' - 9940') = very pale medium gray to medium gray dark medium gray with pale brownish hues; unconsolidated to easily friable; upper medium to upper fine grained, minor granule sized grains scattered through- out sample; poor to moderate sorting; sub-angular to sub-rounded to angular; sub-spherical; dominated by translucent to clear quartz; minor carbonaceous sediment and trace dark lithics; grain supported; moderate easily friable matrix supported clasts; predominantly tuffaceous; interbedded with trace siltstone and claystone. Sand / Tuffaceous Sandstone / Conglomerate Sandstone (9940' - 10050') = pale medium gray to medium grayish white to medium gray, off white to white hues, trace red/pink, trace pale blue green; overall slight salt and pepper appearance; unconsolidated to easily friable; upper medium to lower fine grained with lower coarse to upper very fine common; moderate to poor sorting; sub- rounded to sub- angular to angular; sub- spherical; dominated by translucent to clear to occasional milky white quartz; polished to frosted to occasionally grinding surface abrasion; vitreous; minor carbonaceous sediment and trace dark lithics; grain supported; moderate easily friable matrix supported clasts and often tuffaceous; slightly to moderately calcareous; interbedded with trace tuffaceous siltstone and claystone. TBU M-22 24 3.3 SAMPLING PROGRAM Set Type and Purpose Interval Frequency Distribution A Washed and Dried Reference 1,321’ – 10,050’ 30’ Debra Oudean Hilcorp Alaska LLC 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 B Washed and Dried Reference 1,321’ – 10,050’ 30’ Debra Oudean Hilcorp Alaska LLC 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 Box 1: 1,321’ – 2,760’ Box 2: 2,760’ – 4,020’ Box 3: 4,020’ – 5,430’ Box 4: 5,430’ – 6,900’ Box 5: 6,900’ – 8,460’ Box 6: 8,460’ – 10,050’ TBU M-22 25 4 DRILLING DATA 4.1 SURVEYS Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 60.0 0.19 162.51 60.00 0.09 0.03 -0.08 0.32 120.0 0.22 151.64 120.00 0.29 0.11 -0.22 0.08 180.0 0.17 155.18 180.00 0.47 0.21 -0.35 0.09 240.0 0.11 170.67 240.00 0.61 0.25 -0.46 0.12 300.0 0.17 150.21 300.00 0.74 0.31 -0.56 0.13 360.0 0.44 152.22 360.00 1.03 0.46 -0.76 0.45 420.0 1.21 143.19 419.99 1.74 0.95 -1.22 1.30 480.0 2.22 141.68 479.96 3.16 2.05 -2.09 1.68 540.0 2.95 143.76 539.90 5.31 3.68 -3.42 1.23 600.0 3.19 143.53 599.82 7.90 5.58 -5.04 0.40 660.0 3.29 142.93 659.72 10.62 7.61 -6.73 0.18 720.0 3.41 143.18 719.62 13.42 9.72 -8.47 0.20 780.0 3.64 143.06 779.50 16.37 11.94 -10.30 0.38 840.0 3.74 142.95 839.38 19.45 14.26 -12.22 0.17 900.0 3.83 144.84 899.25 22.65 16.59 -14.23 0.26 960.0 3.95 143.23 959.11 25.95 18.98 -16.31 0.27 1,020.0 3.88 142.52 1,018.97 29.21 21.46 -18.33 0.14 1,080.0 3.83 143.45 1,078.83 32.44 23.88 -20.32 0.13 1,140.0 3.87 143.09 1,138.70 35.66 26.29 -22.34 0.08 1,200.0 4.00 144.58 1,198.56 38.99 28.72 -24.43 0.28 1,267.0 4.09 143.83 1,265.39 42.82 31.49 -26.85 0.16 1,337.73 3.46 138.64 1,335.97 46.46 34.39 -29.04 1.01 1,431.78 3.82 125.03 1,429.83 50.39 38.83 -30.89 0.99 1,528.27 5.77 115.07 1,525.98 54.29 45.85 -31.69 2.19 1,622.80 8.07 118.39 1,619.81 59.46 56.00 -32.42 2.47 1,718.23 11.91 122.33 1,713.78 67.91 70.21 -34.55 4.08 1,811.07 14.41 122.73 1,804.17 79.28 88.03 -37.94 2.69 1,905.92 16.54 122.32 1,895.58 92.88 109.37 -41.98 2.25 2,000.21 17.67 122.14 1,985.70 107.67 132.83 -46.27 1.20 2,094.63 17.67 122.28 2,075.66 122.95 157.08 -50.69 0.05 TBU M-22 26 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 2,189.32 17.60 122.41 2,165.90 138.30 181.31 -55.18 0.08 2,285.71 17.64 122.49 2,257.77 153.95 205.94 -59.81 0.05 2,379.60 17.61 122.70 2,347.26 169.27 229.89 -64.39 0.07 2,475.53 17.67 122.54 2,438.67 184.94 254.37 -69.08 0.08 2,570.42 17.65 123.03 2,529.09 200.52 278.57 -73.81 0.16 2,663.73 17.93 123.86 2,617.94 216.24 302.36 -78.82 0.40 2,758.64 18.36 124.12 2,708.13 232.76 326.87 -84.28 0.46 2,853.20 18.37 122.92 2,797.88 249.22 351.70 -89.56 0.40 2,949.67 18.26 123.00 2,889.45 265.71 377.14 -94.63 0.12 3,043.47 18.41 122.41 2,978.49 281.65 401.97 -99.43 0.25 3,138.75 18.36 122.50 3,068.91 297.78 427.32 -104.20 0.06 3,233.40 18.32 121.81 3,158.76 313.63 452.54 -108.77 0.23 3,329.38 18.34 121.54 3,249.87 329.48 478.23 -113.15 0.09 3,421.03 18.39 121.40 3,336.85 344.55 502.86 -117.24 0.07 3,516.47 18.38 120.90 3,427.42 360.12 528.62 -121.33 0.17 3,610.87 18.30 119.93 3,517.02 375.16 554.23 -125.00 0.33 3,707.75 17.46 116.68 3,609.22 389.28 580.40 -127.59 1.35 3,800.35 15.44 110.03 3,698.04 399.74 604.40 -127.70 2.98 3,895.29 14.15 97.72 3,789.85 405.63 627.78 -123.84 3.57 3,989.55 12.00 85.63 3,881.68 406.43 648.97 -116.19 3.68 4,084.20 12.15 76.87 3,974.24 403.41 668.49 -105.69 1.94 4,179.94 13.54 64.92 4,067.60 396.37 688.45 -91.32 3.12 4,276.24 15.25 49.05 4,160.91 383.29 708.24 -71.47 4.45 4,370.50 17.15 35.14 4,251.46 363.79 725.61 -46.69 4.57 4,465.48 20.68 25.18 4,341.32 337.14 740.81 -16.20 5.02 4,558.92 24.21 16.49 4,427.69 303.82 753.28 19.34 5.18 4,653.76 26.85 9.77 4,513.28 264.05 762.44 59.48 4.13 4,747.65 30.17 3.87 4,595.79 219.60 767.63 102.36 4.63 4,842.40 33.18 1.00 4,676.42 169.91 769.69 148.80 3.55 4,939.14 36.05 0.96 4,756.03 114.97 770.63 199.62 2.97 5,033.04 36.38 1.88 4,831.79 59.51 772.00 251.09 0.68 5,128.83 38.91 2.77 4,907.63 1.05 774.39 305.71 2.70 5,223.09 41.37 3.73 4,979.68 -59.60 777.85 362.78 2.69 5,318.69 45.67 4.51 5,048.99 -125.25 782.59 424.94 4.53 5,413.08 49.33 4.43 5,112.75 -194.62 788.01 490.78 3.88 5,507.23 52.03 4.44 5,172.40 -267.23 793.65 559.68 2.87 TBU M-22 27 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 5,601.10 54.41 4.81 5,228.60 -342.16 799.71 630.89 2.56 5,694.70 56.56 5.29 5,281.64 -418.98 806.50 704.12 2.34 5,790.72 56.48 5.76 5,334.60 -498.70 814.21 780.37 0.42 5,886.21 56.51 6.06 5,387.31 -577.90 822.41 856.35 0.26 5,980.45 56.52 6.54 5,439.30 -656.02 831.04 931.50 0.42 6,044.79 56.47 6.89 5,474.82 -709.31 837.31 982.91 0.46 6,125.73 56.78 8.91 5,519.34 -776.25 846.60 1,048.06 2.12 6,220.27 57.34 9.11 5,570.75 -854.62 859.03 1,124.94 0.62 6,313.13 58.05 9.39 5,620.38 -932.08 871.65 1,201.07 0.81 6,407.27 58.43 9.41 5,669.93 -1,011.05 884.72 1,278.76 0.40 6,503.20 58.67 10.06 5,719.98 -1,091.71 898.56 1,358.31 0.63 6,598.39 61.49 10.66 5,767.46 -1,172.86 913.40 1,438.69 3.01 6,693.69 63.39 10.92 5,811.55 -1,255.84 929.22 1,521.16 2.01 6.789.00 66.41 11.25 5.851.97 -1.340.53 945.81 1.605.50 3.18 6.883.51 69.68 12.20 5.887.30 -1.426.35 963.63 1.691.35 3.58 6.952.68 73.43 13.26 5.909.19 -1.490.34 978.09 1.755.84 5.61 7,071.61 77.48 14.69 5,939.05 -1,602.02 1,005.90 1,869.40 3.60 7,166.83 80.70 15.77 5,957.07 -1,692.22 1,030.46 1,961.95 3.56 7,256.21 84.45 16.63 5,968.62 -1,777.31 1,055.19 2,049.88 4.30 7,355.86 87.93 16.41 5,975.27 -1,872.58 1,083.68 2,148.64 3.50 7,449.98 88.58 16.05 5,978.14 -1,962.91 1,109.97 2,241.99 0.79 7,543.15 88.96 16.40 5,980.14 -2,052.34 1,136.00 2,334.43 0.55 7,638.59 88.16 15.94 5,982.54 -2,143.98 1,162.57 2,429.10 0.97 7,732.87 88.34 16.27 5,985.42 -2,234.52 1,188.71 2,522.58 0.40 7,829.49 88.25 16.63 5,988.29 -2,327.14 1,216.06 2,618.46 0.38 7,923.33 88.34 16.28 5,991.08 -2,417.10 1,242.63 2,711.59 0.39 8,012.80 87.97 16.12 5,993.97 -2,502.97 1,267.57 2,800.32 0.45 8,111.05 87.94 15.35 5,997.47 -2,597.48 1,294.20 2,885.74 0.78 8,206.40 88.46 13.40 6,000.47 -2,689.79 1,317.86 2,980.51 2.12 8,300.44 88.49 10.79 6,002.97 -2,781.70 1,337.56 3,073.52 2.77 8,395.32 88.43 10.16 6,005.52 -2,874.97 1,354.80 3,166.95 0.67 8,490.32 88.43 10.00 6,008.12 -2,968.47 1,371.42 3,260.37 0.17 8,583.83 88.53 9.78 6,010.60 -3,060.55 1,387.48 3,352.28 0.26 8,680.16 88.56 10.36 6,013.05 -3,155.37 1,404.31 3,447.01 0.60 8,767.13 88.34 10.72 6,015.40 -3,240.84 1,420.22 3,532.66 0.49 8,799.51 88.58 11.62 6,016.27 -3,272.60 1,426.49 3,564.61 2.88 TBU M-22 28 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 8,894.15 88.59 11.54 6,018.61 -3,365.28 1,445.48 3,658.10 0.09 8,988.85 88.37 11.11 6,021.12 -3,458.10 1,464.07 3,751.58 0.51 9,083.44 89.43 10.67 6,022.94 -3,550.97 1,481.94 3,844.85 1.21 9,177.89 89.57 11.16 6,023.76 -3,643.71 1,499.82 3,938.00 0.54 9,272.12 89.66 12.79 6,024.39 -3,735.88 1,519.37 4,031.21 1.73 9,364.98 89.51 14.17 6,025.33 -3,825.98 1,541.00 4,123.19 1.49 9,459.85 89.51 13.65 6,026.14 -3,918.06 1,563.81 4,217.45 0.55 9,554.82 89.69 13.86 6,026.80 -4,010.31 1,586.39 4,311.78 0.29 9,651.49 89.60 11.37 6,027.40 -4,104.64 1,607.50 4,407.54 2.58 9,746.03 89.72 10.41 6,027.96 -4,197.47 1,625.36 4,500.78 1.02 9,839.98 89.57 10.63 6,028.54 -4,289.84 1,642.51 4,593.33 0.28 9,935.44 89.57 12.13 6,029.26 -4,383.42 1,661.35 4,687.60 1.57 10,015.37 89.45 13.89 6,029.94 -4,461.29 1,679.34 4,766.86 2.21 10,050.00 89.45 13.89 6,030.28 -4,494.91 1,687.65 4,801.27 0.00 Note: Survey @ 10,050.00 is a projection to bit depth. Hilcorp Alaska LLC M-22 29 4.2 BIT RECORD BIT NO. SIZE TYPE S/N JETS/ TFA IN OUT Feet Drilled HRS AVE ROP (Ft/HR) CONDITION 1 17.5” Tri-Cone 12406548 3x18 / 1-22 475’ 485’ 10’ 0.42 395 1-1-n/a-n/a-0-I-n/a-BHA 2 17.5” HCC GTX-C1 5245469 0.739 485’ 1,301’ 816’ 14.47 94.3 1-1-n/a-n/a-2-I-n/a-BHA 3 12.25” Smith XR PD 6435 3x16 / 1x12 1,301 1,321’ 20’ 0.58 48.3 2-2-CT-N-E-I-NO-BHA 4 12.25” BHI KM633X 5225154 3x14, 3x20 1.3714 1,321’ 3,841’ 2,520’ 45.75 81.2 0-0-n/a-n/a-1-1/16-n/a-HP RR4 12.25” BHI KM633X 5225154 3x14, 3x20 1.3714 3,841’ 6,099’ 2,258’ 42.43 81.1 2-2-CT-N-2-3/16-CT-BHA 5 12.25” BHI PDC TD605SX 7040648 7x16 / 1.374 6,099’ 7,018’ 922’ 15.25 60.5 2-2-CT-G-X-I-BT-TD RR5 12.25” BHI PDC TD605SX 7040648 7x16 / 1.374 7,018’ 7,018’ — — — — 6 8.5” Smith PDC JHS967 0.773 7,018’ 7,018’ — — — 1-1-NO-A-X-I-NO-BHA 7 8.5” Mill Tooth Tri-Cone 5283478 3x16, 1x20 0.739 7,018’ 7,018’ — — — 1-1-NO-A-E-I-NO-BHA 8 8.5” BHI KMX524 5266639 2x16, 2x18 0.8897 7,018’ 8,801’ 1,783’ 32.40 68.4 0-0-NO-A-0-I-NO-RIG RR8 8.5” BHI KMX524 5266639 2x16, 2x18 0.8897 8,801’ 10,050’ 1,249’ 20.88 75.6 3-3-BT-A-3-I-CT-TD . Hilcorp Alaska LLC M-22 30 4.3 Mud Record Contractor: Halliburton Baroid Date Depth MD TVD MW (ppg) VISCOSITY (s/qt) PV YP Gels FL (cc) FC Sols (%) O/W Ratio Sd (%) ASG pH Ca++ Cl- Spud Mud 4/25/2018 450 450 9.2 90 15 35 — — — — — — — 8.9 — — 4/26/2018 450 450 9.2 125 23 41 35/44/0 12.5 3/0 4.8 0/95.0 — 3.204 9.8 20 350 4/27/2018 450 450 9.2 127 25 39 26/46/48 14.5 3/0 4.0 0/95.8 — 3.652 9.7 20 350 4/28/2018 450 450 9.2 128 25 40 25/44/46 14.5 3/0 4.0 0/95.8 — 3.652 9.7 20 350 4/29/2018 450 450 9.2 128 22 42 26/45/46 14.0 3/0 4.0 0/95.8 — 3.652 9.6 20 350 4/30/2018 450 450 9.2 124 27 37 17/40/44 14.0 3/0 4.0 0/95.8 — 3.652 9.7 20 300 5/1/2018 450 450 9.2 98 27 32 14/37/40 13.5 3/0 3.9 0/95.9 — 3.709 9.7 20 200 5/2/2018 450 450 9.2 92 26 32 15/31/39 14.0 3/0 3.9 0/95.9 — 3.707 9.7 20 300 5/3/2018 450 450 9.2 82 28 32 12/29/34 14.0 3/0 3.9 0/95.9 — 3.707 9.7 20 300 5/4/2018 450 450 9.2 70 26 30 11/28/33 13.0 2/0 3.9 0/95.9 — 3.703 9.6 — 600 5/5/2018 468 468 9.2 88 29 35 15/37/44 13.0 2/0 3.7 0/95.9 0.75 3.790 9.1 20 600 5/6/2018 745 745 9.25 79 29 34 9/29/33 10.4 2/0 4.5 0/95.2 0.75 3.431 8.9 — 500 5/7/2018 745 745 9.2 100 30 40 11/27/33 9.6 2/0 4.8 0/95.2 1.00 3.202 9.0 — 500 5/8/2018 1,301 1,298 9.2 65 28 27 7/18/24 8.7 2/0 6.2 0/93.6 1.25 2.700 8.6 — 400 5/9/2018 1,301 1,298 9.3 49 24 13 3/5/8 8.9 2/0 6.4 0/93.4 1.25 2.834 8.0 — 500 5/10/2018 1,301 1,298 8.85 59 18 16 7/15/19 9.8 2/0 3.7 0/96.1 0.50 2.700 8.8 — 500 5/11/2018 1,301 1,298 8.85 57 18 16 7/15/19 9.8 2/0 3.7 0/96.1 0.50 2.700 8.8 — 500 5/12/2018 1,301 1,298 8.85 57 18 16 7/15/19 9.8 2/0 3.7 0/96.1 0.50 2.700 8.8 — 500 ENVIROMUL 5/12/2018 1,301 1,298 9.0 41 8 12 6/8/10 6.6 1/0 3.5 0/96.0 — 2.918 9.8 200 11000 5/13/2018 1,301 1,298 9.0 51 10 14 12/14/17 4.8 1/2 3.1 0/95.9 — 3.088 10.3 80 11000 5/14/2018 1,333 1,321 9.05 55 10 25 12/15/17 5.5 1/2 3.2 0/95.8 0.25 3.227 9.9 80 12000 5/15/2018 2,144 2,100 9.0 45 10 18 8/10/12 5.1 1/2 3.0 0/96.0 1.10 3.161 9.9 60 12000 5/16/2018 2,800 2,755 9.1 43 9 18 7/9/11 5.4 1/2 3.4 0/95.5 0.75 3.218 10.1 60 13000 5/17/2018 3,808 3,660 9.0 40 9 17 6/8/10 5.4 1/2 3.4 0/95.5 0.50 2.875 10.1 40 13000 5/18/2018 3,842 3,694 9.0 40 10 17 6/8/10 4.6 1/2 3.3 0/95.5 0.75 2.877 10.0 40 13500 5/19/2018 4,026 3,873 9.1 46 12 19 6/8/11 4.5 1/2 3.2 1.0/93.1 0.75 2.617 9.6 40 33000 5/20/2018 4,786 4,582 9.3 47 14 20 5/7/8 3.7 1/2 4.6 2.0/91.0 0.75 2.779 10.0 40 30000 5/21/2018 5,263 4,956 9.45 53 17 20 6/7/9 3.0 1/2 5.6 3.0/89.0 0.50 2.812 9.7 40 31000 5/22/2018 5,765 5,319 9.55 58 20 25 8/10/13 2.2 1/2 6.0 3.0/88.5 0.75 2.868 10.2 40 33000 Abbreviations: MW = Mud Weight VISCOSITY = Funnel Viscosity PV = Plastic Viscosity YP = Yield Point Gels = Gel Strength FL = Water or Filtrate Loss FC = Filter Cake O/W = Oil to Water ratio Sols = Solids Sd = Sand content MBT = Methylene Blue Alk, Pm = Alkalinity, Mud pH = Acidity Cl = Chlorides Ca = Hardness Calcium nr = Not Recorded Hilcorp Alaska LLC M-22 31 Date Depth MD TVD MW (ppg) VISCOSITY (s/qt) PV YP Gels FL (cc) FC Sols (%) O/W Ratio Sd (%) ASG pH Ca++ Cl- ENVIROMUL 5/23/2018 6,099 5,504 9.6 61 21 28 8/12/15 2.6 1/2 6.8 3.0/88.0 0.50 2.802 9.9 40 29000 5/24/2018 6,145 5,530 9.6 61 22 29 9/12/13 2.0 1/2 6.8 3.0/88.0 0.50 2.802 10.0 40 29000 5/25/2018 6,984 5,928 9.6 60 18 30 9/12/15 2.2 1/2 6.6 3.0/88.0 1.00 2.808 9.7 40 31000 5/26/2018 7,018 5,940 9.65 55 15 26 7/10/12 3.0 1/2 7.2 3.0/87.5 1.00 2.763 10.0 40 30000 5/27/2018 7,018 5,940 9.65 55 15 26 7/9/12 3.2 1/2 7.2 3.0/87.5 1.00 2.763 9.9 40 30000 5/28/2018 7,018 5,940 9.55 50 16 21 7/9/12 3.2 1/2 6.8 3.0/88.0 1.00 2.714 9.9 40 29000 5/29/2018 7,018 5,940 9.55 51 15 24 7/12/15 3.4 1/2 7.3 3.0/87.6 0.75 2.617 9.5 40 27000 5/30/2018 7,018 5,940 9.55 47 13 21 7/12/16 3.6 1/2 7.4 2.5/88.1 0.75 2.605 9.5 40 26000 5/31/2018 7,018 5,940 9.45 48 13 20 7/9/11 4.2 1/2 6.7 2.5/88.8 0.75 2.602 9.1 40 26000 6/1/2018 7,018 5,940 9.55 48 12 20 5/10/11 4.2 1/2 7.3 2.5/88.1 0.75 2.606 7.1 40 27000 6/2/2018 7,018 5,940 9.50 48 11 18 5/9/10 4.2 1/2 6.9 2.5/88.5 0.75 2.622 7.0 480 27000 6/3/2018 7,018 5,940 9.70 48 11 18 5/9/10 4.2 1/2 6.9 2.5/88.5 0.75 2.970 7.7 480 27000 6/4/2018 7,018 5,940 9.70 48 11 18 5/9/10 4.2 1/2 6.9 2.5/88.5 0.75 2.970 7.7 480 27000 6/5/2018 7,018 5,940 9.70 48 11 18 5/9/10 4.2 1/2 6.9 2.5/88.5 0.75 2.970 7.7 480 27000 6/6/2018 7,018 5,940 9.05 48 12 20 14/25/45 4.0 1/2 2.2 0.0/95.0 0.00 2.943 11.4 340 34000 6/7/2018 7,575 5,975 9.05 42 9 20 14/25/45 4.0 1/2 2.9 0.0/94.6 0.25 2.628 10.4 340 30000 6/8/2018 8,276 6,005 9.10 44 10 25 9/11/14 3.7 1/2 3.4 0.0/94.2 0.10 2.611 10.5 160 29000 6/9/2018 8,801 6,016 9.15 46 12 26 9/11/14 3.4 1/2 3.4 0.0/93.8 0.10 2.606 10.4 100 34000 6/10/2018 8,801 6,016 9.20 47 11 25 8/11/13 3.5 1/2 3.5 0.0/93.4 0.10 2.602 10.6 80 33000 6/11/2018 9,398 6,025 9.25 44 10 21 6/8/10 3.0 1/2 4.4 0.0/93.1 0.10 2.601 10.4 40 32000 6/12/2018 10,050 6,030 9.15 44 10 25 10/13/15 3.1 1/2 3.7 0.0/93.8 0.10 2.603 10.2 60 30000 6% KCL Brine 6/13/2018 10,050 6,030 8.70 — — — — — — — — — — — — 30000 6/14/2018 10,050 6,030 8.75 — — — — — — — — — — — — 31000 Abbreviations: MW = Mud Weight VISCOSITY = Funnel Viscosity PV = Plastic Viscosity YP = Yield Point Gels = Gel Strength FL = Water or Filtrate Loss FC = Filter Cake O/W = Oil to Water ratio Sols = Solids Sd = Sand content MBT = Methylene Blue Alk, Pm = Alkalinity, Mud pH = Acidity Cl = Chlorides Ca = Hardness Calcium nr = Not Recorded Hilcorp Alaska LLC M-22 32 4.4 Drilling Progress 0 2000 4000 6000 8000 10000 12000 Depth Depth Hilcorp Alaska LLC M-22 33 DAILY REPORTS Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-2 REPORT FOR Shane Hauck / Rance Pederson DATE April 29, 2018 DEPTH 0' PRESENT OPERATION Rigging up TIME 23:59:59 YESTERDAY 0' 24 HOUR FOOTAGE 0' CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Rig up unit, install new gas equipment. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2,770.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-2 REPORT FOR Shane Hauck / Rance Pederson DATE April 30, 2018 DEPTH 0' PRESENT OPERATION Rigging up TIME 23:59:59 YESTERDAY 0' 24 HOUR FOOTAGE 0' CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Troubleshooting gas equipment CANRIG PERSONNEL ON BOARD 2 DAILY COST $2,770.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Shane Hauck / Rance Pederson DATE May 1, 2018 DEPTH 0' PRESENT OPERATION Rigging up TIME 23:59:59 YESTERDAY 0' 24 HOUR FOOTAGE 0' CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue troubleshooting gas equipment. THA repaired and getting new chromatograph shipped out from office. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2,770.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Shane Hauck / Rance Pederson DATE May 2, 2018 DEPTH 450' PRESENT OPERATION Rigging up TIME 23:59:59 YESTERDAY 450' 24 HOUR FOOTAGE 0' CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 450' MW 9.2 VIS 132 PV 25 YP 32 FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continued rigging up. Offloaded drill pipe & upright tanks from boat. Started picking up pipe. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2,770.00 REPORT BY Allen Odegaard Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Shane Hauck / Rick Brumley DATE May 3, 2018 DEPTH 450' PRESENT OPERATION Rigging Up TIME 23:59:59 YESTERDAY 450' 24 HOUR FOOTAGE 0' CASING INFORMATION 28" @ 463' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 450' MW 9.2 VIS 132 PV 25 YP 32 FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Pick up HWDP and 5" DP; performed rig inspection with OSHA; tested mud lines T/ 3700 psi. CANRIG PERSONNEL ON BOARD 1 DAILY COST $2922.50 REPORT BY Allen Odegaard Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Shane Hauck / Rick Brumley DATE May 4, 2018 DEPTH 450' PRESENT OPERATION Rigging Up TIME 23:59:59 YESTERDAY 450' 24 HOUR FOOTAGE 0' CASING INFORMATION 28" @ 463' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 450' MW 9.2 VIS 82 PV 28 YP 32 FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continued rigging up. Filled Upright tanks. Offloaded 13 3/8" csg. Filled stack to diverter. CANRIG PERSONNEL ON BOARD 1 DAILY COST $2,922.50 REPORT BY Allen Odegaard Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Shane Hauck / Rick Brumley DATE May 5, 2018 DEPTH 463' PRESENT OPERATION Rigging Up TIME 23:59:59 YESTERDAY 450' 24 HOUR FOOTAGE 13' CASING INFORMATION 28" @ 463' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 450' MW 9.2 VIS 70 PV 26 YP 30 FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Filled stack & changed leaking valves on the diverter, pressure tested Bakers BPA unit. Started P/U BHA #1 to drill out conductor. RIH tagged TOC @ 463'. Displaced conductor to Spud Mud. Shut down pumps preparing to drill out cement. CANRIG PERSONNEL ON BOARD 1 DAILY COST $2,922.50 REPORT BY Allen Odegaard Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Shane Hauck / Rick Brumley DATE May 6, 2018 DEPTH 745' PRESENT OPERATION Conditioning Well TIME 23:59:59 YESTERDAY 463' 24 HOUR FOOTAGE 282' CASING INFORMATION 28" @ 463' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 745' MW 9.25 VIS 79 PV 29 YP 34 FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 151 @ 743' 0 @ 491' 15 TRIP GAS n/a CUTTING GAS @ @ WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY n/a METHANE (C-1) @ @ CONNECTION GAS HIGH n/a ETHANE (C-2) @ @ AVG n/a PROPANE (C-3) @ @ CURRENT n/a BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 2u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Drilled ahead from 463' to 485' MD. Circulated 1.25 BU. Float check, well static. TOOH T/ surface. Laid down BHA #1. Picked up BHA #2 to drill surface hole. Finished P/U BHA and started drilling ahead T/745' and lost all returns, lined up to LCM pills and began pumping them down hole, once first pill was out of the bit we established circulation at a slow pump rate, shut down pumps and fill hole from the top and started timing loss rate, loss rate went from 90 bbls down to 13.5 bbls per/hr while pumping over the top of the hole. Continued to monitor losses while spotting multiple pills. CANRIG PERSONNEL ON BOARD 1 DAILY COST $3,202.50 REPORT BY Allen Odegaard Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Shane Hauck / Rick Brumley DATE May 7, 2018 DEPTH 896' PRESENT OPERATION Drilling Ahead TIME 23:59:59 YESTERDAY 745' 24 HOUR FOOTAGE 151' CASING INFORMATION 28" @ 463' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 896' MW 9.2 VIS 100 PV 30 YP 40 FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 82 @ 848' 1 @ 855' 24 TRIP GAS n/a CUTTING GAS @ @ WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY n/a METHANE (C-1) @ @ CONNECTION GAS HIGH n/a ETHANE (C-2) @ @ AVG n/a PROPANE (C-3) @ @ CURRENT n/a BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 3u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continued batching up Spud Mud. Lost circulation while circulating off bottom. Held PJSM prior to drilling ahead. Drilled ahead from 745' to 896' MD. CANRIG PERSONNEL ON BOARD 1 DAILY COST $3,202.50 REPORT BY Allen Odegaard Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Marvin Rogers / Rick Brumley DATE May 8, 2018 DEPTH 1,301' PRESENT OPERATION Laying Down BHA TIME 23:59:59 YESTERDAY 896' 24 HOUR FOOTAGE 405' CASING INFORMATION 28" @ 463' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 1,301' MW 9.1 VIS 61 PV 21 YP 26 FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 11 @ 1,277' 1 @ 855' 4 TRIP GAS n/a CUTTING GAS @ @ WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY n/a METHANE (C-1) @ @ CONNECTION GAS HIGH n/a ETHANE (C-2) @ @ AVG n/a PROPANE (C-3) @ @ CURRENT n/a BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 7u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Drilled from 896' T/1,301', pumped BU and then pumped a Hi-Vis sweep with LCM. Circulated another BU, pumped out two stands & then TIH back to bottom, spotted a Hi-Vis LCM pill on bottom, TOOH on elevators T/730' & slow pumped through loss circulation area T/688'. Spotted another Hi-Vis LCM pill F/688'-T/587'. Pumped OOH into conductor due to swabbing, TOOH to tools, down loaded MWD, L/D BHA #2. CANRIG PERSONNEL ON BOARD 1 DAILY COST $3,202.50 REPORT BY Allen Odegaard Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Marvin Rogers / Rick Brumley DATE May 9, 2018 DEPTH 1,301' PRESENT OPERATION Preparing to Pump Cement TIME 23:59:59 YESTERDAY 1,301' 24 HOUR FOOTAGE 0' CASING INFORMATION 28" @ 463' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 1,301' MW 9.1 VIS 65 PV 29 YP 30 FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS n/a CUTTING GAS @ @ WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY n/a METHANE (C-1) @ @ CONNECTION GAS HIGH n/a ETHANE (C-2) @ @ AVG n/a PROPANE (C-3) @ @ CURRENT n/a BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG n/a PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Finished L/D BHA. R/U 13 3/8" csg. equipment. RIH with 13 3/8" surface csg. T/ 600', circulated @ 3.5 bbls/min conditioning mud for cement job, lost 5 bbls while circulating. Continued TIH T/928', circulated BU while conditioning mud again for cement job @ 3.5 bbls/min & lost 16 bbls while circulating. TIH to bottom. Landed and circulated BU. P/O monitored well for 10 mins. Determined static loss rate @ 6 bph. Drained the stack. CANRIG PERSONNEL ON BOARD 1 DAILY COST $3,202.50 REPORT BY Allen Odegaard Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Marvin Rogers / Rick Brumley DATE May 10, 2018 DEPTH 1,301' PRESENT OPERATION Nipple Down Diverter TIME 23:59:59 YESTERDAY 1,301' 24 HOUR FOOTAGE 0' CASING INFORMATION 28" @ 463' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 1,301' MW 8.85 VIS 59 PV 18 YP 16 FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS n/a CUTTING GAS @ @ WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY n/a METHANE (C-1) @ @ CONNECTION GAS HIGH n/a ETHANE (C-2) @ @ AVG n/a PROPANE (C-3) @ @ CURRENT n/a BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 5u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY R/D Weatherford. M/U 5" DP handling equipment. RIH T/1293' & stung into 13 3/8" surface csg. R/U cementers & mixed spacer. Broke circulation at 0530 pumped @ 1 bpm for 30 mins. Broke again at 0630 and pumped for 30 mins (prior to cement). Held PJSM on rig floor for cement job, Started cement job by pumping 8 bbls of water with red dye and pressure tested cement line to 500 psi low and 3,500 psi Hi, lined mud pumps up to 10 ppg space and pumped 136 bbls, followed by 399 bbls of 12 ppg lead cement, followed by 14 bbls of 13 ppg tail cement and chased with 21.5 bbls; rig down cementers; begin nippling down diverter. CANRIG PERSONNEL ON BOARD 1 DAILY COST $3,202.50 REPORT BY Allen Odegaard Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Marvin Rogers / Rick Brumley DATE May 11, 2018 DEPTH 1,301' PRESENT OPERATION Nippling Up BOPs TIME 23:59:59 YESTERDAY 1,301' 24 HOUR FOOTAGE 0' CASING INFORMATION 28" @ 463' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 1,301' MW 8.85 VIS 57 PV 18 YP 16 FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS n/a CUTTING GAS @ @ WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY n/a METHANE (C-1) @ @ CONNECTION GAS HIGH n/a ETHANE (C-2) @ @ AVG n/a PROPANE (C-3) @ @ CURRENT n/a BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG n/a PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Nipple down diverter, installed multi-bowl & started nippling up BOP stack while mixing mud. R/U Pollard wireline to log cement temperature survey, R/D Pollard. Continued nippling up BOPs & mixing mud. CANRIG PERSONNEL ON BOARD 1 DAILY COST $3,202.50 REPORT BY Allen Odegaard Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Marvin Rogers / Rick Brumley DATE May 12, 2018 DEPTH 1,301' PRESENT OPERATION Testing BOPs TIME 23:59:59 YESTERDAY 1,301' 24 HOUR FOOTAGE 0' CASING INFORMATION 28" @ 463' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 1,301' MW 9.0 VIS 41 PV 8 YP 12 FL 6.6 Gels 6/8/10 CL- 11000 FC 1/0 SOL 3.5 SD — OIL 0.0 MBL — pH 9.8 Ca+ 200 CCI — MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS n/a CUTTING GAS @ @ WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY n/a METHANE (C-1) @ @ CONNECTION GAS HIGH n/a ETHANE (C-2) @ @ AVG n/a PROPANE (C-3) @ @ CURRENT n/a BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG n/a PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continued nippling up BOPs; begin testing BOPs. CANRIG PERSONNEL ON BOARD 1 DAILY COST $3,202.50 REPORT BY Allen Odegaard Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Marvin Rogers / Rick Brumley DATE May 13, 2018 DEPTH 1,321' PRESENT OPERATION Running Gyro Tool TIME 23:59:59 YESTERDAY 1,301' 24 HOUR FOOTAGE 20' CASING INFORMATION 28" @ 463' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 1,301' MW 9.0 VIS 51 PV 10 YP 21 FL 4.8 Gels 12/14/17 CL- 11000 FC 1/2 SOL 3.1 SD — OIL 0.0 MBL — pH 10.3 Ca+ 80 CCI — MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 34 @ 1304' 6 @ 1321' 14 TRIP GAS n/a CUTTING GAS @ @ WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY n/a METHANE (C-1) @ @ CONNECTION GAS HIGH n/a ETHANE (C-2) @ @ AVG n/a PROPANE (C-3) @ @ CURRENT n/a BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG n/a PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Function tested BOPs, R/D test equipment, cleared & cleaned rig floor, Held PJSM & started P/U & M/U drill out assembly BHA #3. RIH T/ shoe track, circulated BU. Cut & slip drill line. Drilled float collar & 20' of new hole. Performed FIT to 12.5ppg EMW. Rig up & run gyro tool. CANRIG PERSONNEL ON BOARD 1 DAILY COST $3,202.50 REPORT BY Allen Odegaard Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Marvin Rogers / Rick Brumley DATE May 14, 2018 DEPTH 1389 PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 1321 24 HOUR FOOTAGE 68 CASING INFORMATION 13.375" @ 1293' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 12.25 BHI KM633X 5225154 3x14, 3x20 1321' 68' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 83.8 @ 1385 2.9 @ 1334 46.3 69.04 FT/HR SURFACE TORQUE 6578 @ 1387 4518 @ 1321 5686.3 6236.57 AMPS WEIGHT ON BIT 12 @ 1388 0 @ 1321 0.4 6.92 KLBS ROTARY RPM 105 @ 1388 44 @ 1321 83.1 103.16 RPM PUMP PRESSURE 915 @ 1341 528 @ 1330 830.2 799.95 PSI DRILLING MUD REPORT DEPTH 1333 MW 9.05 VIS 55 PV 10 YP 25 FL 5.5 Gels 12/15/17 CL-12000 FC 1/2 SOL 3.2 SD 0.25 OIL 0.0/95.8 MBL pH 9.9 Ca+ 80 CCI MWD SUMMARY INTERVAL 1321' TO TD TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 34 @ 1354 5 @ 1376 18.7 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 7309 @ 135 216 @ 1373.00000 3604.8 CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 40u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 90% Tuffaceous Claystone 10% Coal PRESENT LITHOLOGY 90% Tuffaceous Claystone 10% Coal DAILY ACTIVITY SUMMARY Continue drilling up float from 1210 to 1213. Continue reaming down to 1250’ tag cement, tag shoe at 1288 to 1290.92. Drilled new hole from 1290.92 to 1321.08. Displace mu to 9.0 ppg and overboard old mud. Perform FIT to 12.5 EMW. R/U and RIH with wireline, installed BOP cradle, moved BPA to lower deck. POOH with wireline and R/D same. TOOH to surface and lay down BHA. P/U BHA #4 as per Baker hands. Download MWD and shallow test. Shallow test flow rate too high for shakers, screen down two more times until shallow test of 650 GPM was obtained. Install nuclear source and trip in hole to 1305’. Stage up pumps and condition mud. Drill ahead from 1321’ to 1389’ at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4490.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Marvin Rogers / Rance Pederson DATE May 15, 2018 DEPTH 2266 PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 1321 24 HOUR FOOTAGE 945 CASING INFORMATION 13.375" @ 1293' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 12.25" BHI KM633X 5225154 3x14, 3x20 1321' 1013' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 109.6 @ 1718 0.6 @ 1954 73.1 74.74 FT/HR SURFACE TORQUE 8152 @ 1604 4622 @ 2234 6567.7 7552.74 AMPS WEIGHT ON BIT 17 @ 2142 0 @ 1475 7.0 11.80 KLBS ROTARY RPM 123 @ 1473 58 @ 2211 95.8 96.24 RPM PUMP PRESSURE 1098 @ 2244 528 @ 1330 878.3 964.00 PSI DRILLING MUD REPORT DEPTH 2144' MW 9.00 VIS 45 PV 10 YP 18 FL 5.1 Gels 8/10/12 CL- 12000 FC 1/2 SOL 3.0 SD 1.10 OIL 0/96 MBL pH 9.9 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 447 @ 1783 3 @ 1478 96.0 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 110437 @ 1781 216 @ 1373 22754.4 CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 80u / 25u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous Claystone 60% Tuffaceous Sandstone 30% Coal 10% PRESENT LITHOLOGY Tuffaceous Claystone 50% Coal 50% DAILY ACTIVITY SUMMARY Continue drilling 12.25” hole from 1389’ to 1857’. Pump 50bbl high viscosity sweep with 50% increased returns. Ream out of hole from 1857’ to 1305’. Trip back in hole, tag 12’ of fill on bottom. Pick up and back ream to 1825’ then wash and ream back to bottom. Continue drilling ahead until report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4490.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Marvin Rogers / Rance Pederson DATE May 16, 2018 DEPTH 2993 PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 2267 24 HOUR FOOTAGE 726 CASING INFORMATION 13.375" @ 1293' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 12.25" BHI KM633X 5225154 3x14, 3x20 1321' 2685' 28.9 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 123.4 @ 2674 4.7 @ 2892 82.4 89.34 FT/HR SURFACE TORQUE 11480 @ 2857 5736 @ 2373 8119.9 8975.89 AMPS WEIGHT ON BIT 25 @ 2891 3 @ 2348 10.7 13.93 KLBS ROTARY RPM 112 @ 2587 70 @ 2891 98.9 95.68 RPM PUMP PRESSURE 1303 @ 2933 722 @ 2656 1094.3 1193.72 PSI DRILLING MUD REPORT DEPTH 2800 MW 9.1 VIS 43 PV 9 YP 18 FL 5.4 Gels 7/9/11 CL- 13000 FC 1/2 SOL 3.4 SD 0.75 OIL 0/95.5 MBL pH 10.1 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 609 @ 2684 9 @ 2519 102.6 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 157351 @ 2682 1895 @ 2892 24726.7 CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 45u / 45u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous Claystone 50% Tuffaceous Siltstone 30% Tuffaceous sandstone 10% Coal 10% PRESENT LITHOLOGY Tuffaceous Claystone 50% Tuffaceous Siltstone 30% Tuffaceous sandstone 10% Coal 10% DAILY ACTIVITY SUMMARY Continue drilling 12.25” hole from 2268’ to 2799’. Change out swab on mud pump #1 cylinder #3. Circulate and condition mud, pump high viscosity sweep with a 25% increase in returns. Back ream from 2799’ to 1840’ with no signs of packing off. Trip back in hole on elevators to 2705’. Wash and ream to bottom and continue drilling ahead until report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4490.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Marvin Rogers / Rance Pederson DATE May 17, 2018 DEPTH 3842 PRESENT OPERATION Pumping out of hole TIME 23:59 YESTERDAY 2994 24 HOUR FOOTAGE 848 CASING INFORMATION 13.375" @ 1293' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 3800.35 15.44 110.03 3698.04 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 12.25" BHI KM633X 5225154 3x14, 3x20 1321' 3533' 43.0 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 147.2 @ 3279 1.4 @ 3403 91.1 19.50 FT/HR SURFACE TORQUE 12757 @ 3789 7386 @ 3038 10112.5 10056.87 AMPS WEIGHT ON BIT 27 @ 3553 4 @ 3278 15.3 19.45 KLBS ROTARY RPM 114 @ 3771 55 @ 3551 101.8 110.54 RPM PUMP PRESSURE 1355 @ 3830 1038 @ 3078 1221.5 1247.76 PSI DRILLING MUD REPORT DEPTH 5/16/2018 MW 9.1 VIS 43 PV 9 YP 18 FL 5.4 Gels 7/9/11 CL- 13000 FC 1/2 SOL 3.4 SD 0.75 OIL 0/95.5 MBL pH 10.1 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 809 @ 3255 4 @ 3749 89.8 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 208960 @ 3255 227 @ 3748 22531.5 CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 37u / 37u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 30% Tuffaceous Claystone 30% Tuffaceous Sandstone 30% Tuffaceous Siltstone 10% Coal PRESENT LITHOLOGY 40% Tuffaceous Claystone 30% Tuffaceous Sandstone 30% Tuffaceous Siltstone DAILY ACTIVITY SUMMARY Continue drilling 12.25” hole from 2994’ to 3842’. Pump sweep and circulate bottoms up with 75% increased returns. Pump out of hole to 3630’ at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4490.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Marvin Rogers / Rance Pederson DATE May 18, 2018 DEPTH 3842 PRESENT OPERATION POOH TIME 23:59 YESTERDAY 3842 24 HOUR FOOTAGE 0 CASING INFORMATION 13.375" @ 1293' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 3800.35 15.44 110.03 3698.04 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 12.25" BHI KM633X 5225154 3x14, 3x20 1321' 3533' 43.0 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 3842 MW 9.0 VIS 40 PV 10 YP 17 FL 4.6 Gels 6/8/10 CL- 13500 FC 1/2 SOL 3.3 SD 0.75 OIL 0/95.5 MBL pH 10.0 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 8u / 8u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new footage drilled DAILY ACTIVITY SUMMARY Continue pulling out of hole, back reaming through tight spots from 3555’ to 3410’. Change out swabs in pump #1. Continue back reaming out of hole from 3410’ to 1280’. Circulate and condition at the shoe. Flow check (good) then pull out of hole to 1001’. Troubleshooting issue with breaking connection. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4490.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Marvin Rogers / Rance Pederson DATE May 19, 2018 DEPTH 4126 PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 3843 24 HOUR FOOTAGE 283 CASING INFORMATION 13.375" @ 1293' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4084.2 12.15 76.87 3974.24 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 12.25" BHI KM633X 5225154 3x14, 3x20 1321' 3842' 2521' 45.75 0-0-na-na-1-1-na HP 4RR 12.25" BHI KM633X 5225154 3x14, 3x20 3842' 283' 5.25 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 116.6 @ 3850 1.1 @ 4120 80.8 58.32 FT/HR SURFACE TORQUE 12341 @ 3966 8688 @ 3995 10592.3 10751.79 AMPS WEIGHT ON BIT 24 @ 4031 11 @ 3950 18.7 20.89 KLBS ROTARY RPM 110 @ 3846 71 @ 3941 100.9 102.54 RPM PUMP PRESSURE 1452 @ 3983 1134 @ 3849 1307.2 1288.78 PSI DRILLING MUD REPORT DEPTH 4026 MW 9.1 VIS 46 PV 12 YP 19 FL 4.5 Gels 6/8/11 CL- 33000 FC 1/2 SOL 3.2 SD 0.75 OIL 1.0/93.1 MBL pH 9.6 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 816 @ 3956 13 @ 4021 122.8 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 222546 @ 3956 3722 @ 4039 33151.4 CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 29u / 29u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous Claystone 40% Tuffaceous Sandstone 40% Tuffaceous Siltstone10% Coal 10% PRESENT LITHOLOGY Tuffaceous Sandstone 40% Tuffaceous Claystone 30% Coal 30% DAILY ACTIVITY SUMMARY Continue pulling out of the hole and lay down the BHA. Replace swabs in mud pump #2 while rigging up closed mud system. Pick up BHA and run in hole. Ream to bottom from 3746’ to 3842’ and continue drilling ahead. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4490.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Marvin Rogers / Rance Pederson DATE May 20, 2018 DEPTH 4970 PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 4126 24 HOUR FOOTAGE 844 CASING INFORMATION 13.375" @ 1293' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4842.4 33.18 1.00 4676.42 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4RR 12.25" BHI KM633X 5225154 3x14, 3x20 3842' 1127' 20.33 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 164.0 @ 4321 1.4 @ 4969 79.8 3.18 FT/HR SURFACE TORQUE 13220 @ 4159 9170 @ 4161 11161.7 10399.09 AMPS WEIGHT ON BIT 33 @ 4321 6 @ 4339 18.6 19.29 KLBS ROTARY RPM 122 @ 4242 88 @ 4836 104.1 118.23 RPM PUMP PRESSURE 1579 @ 4948 1049 @ 4320 1386.4 1468.92 PSI DRILLING MUD REPORT DEPTH MW 9.3 VIS 47 PV 14 YP 20 FL 3.7 Gels 5/7/8 CL- 30000 FC 1/2 SOL 4.6 SD 0.75 OIL 2/91 MBL pH 10.0 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1080 @ 4346 20 @ 4129 221.1 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 292744 @ 4345 4202 @ 4129 58389.9 CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 66u / 51u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous Claystone 40% Tuffaceous Sandstone 40% Tuffaceous Siltstone10% Coal 10% PRESENT LITHOLOGY Tuffaceous Claystone 50% Tuffaceous Sandstone 40% Tuffaceous Siltstone10% DAILY ACTIVITY SUMMARY Continue drilling ahead from 4128’ to 4316’. Pump 25bbl weighted high viscosity sweep and work pipe. Back ream out of hole to 3846’. Trip back in hole to 4225’ then wash and ream down to bottom. Continue drilling ahead to 4970’ at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4490.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Marvin Rogers / Rance Pederson DATE May 21, 2018 DEPTH 5263 PRESENT OPERATION Back reaming out of hole TIME 23:59 YESTERDAY 4970 24 HOUR FOOTAGE 293 CASING INFORMATION 13.375" @ 1293' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5223.09 41.37 3.73 4979.68 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4RR 12.25" BHI KM633X 5225154 3x14, 3x20 3842' 1420' 26.0 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 111.4 @ 5174 0.9 @ 4978 73.6 17 FT/HR SURFACE TORQUE 13749 @ 5234 10295 @ 4978 11890.6 11304 AMPS WEIGHT ON BIT 30 @ 5263 10 @ 5172 21.3 30 KLBS ROTARY RPM 124 @ 5020 101 @ 4982 114.7 116 RPM PUMP PRESSURE 1615 @ 5208 977 @ 5237 1485.9 1499 PSI DRILLING MUD REPORT DEPTH 5263 MW 9.45 VIS 53 PV 17 YP 20 FL 3.0 Gels 6/7/9 CL- 31000 FC 1/2 SOL 5.6 SD 0.50 OIL 3/89 MBL pH 9.7 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1508 @ 5185 18 @ 4988 339.3 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 409182 @ 5184 9474 @ 5080 89618.0 CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 10u / 10u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous Claystone 40% Tuffaceous Sandstone 30% Coal 30% PRESENT LITHOLOGY Tuffaceous Claystone 60% Tuffaceous Sandstone 40% DAILY ACTIVITY SUMMARY Continue drilling to 5244’ and circulate well clean and swap vac totes. Continue drilling down to 5263’. Take survey and downlink tool home. Circulate 30 bbl low viscosity sweep and work pipe. Back reaming out of the hole at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4490.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Shane Hauck / Rance Pederson DATE May 22, 2018 DEPTH 5915 PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 5263 24 HOUR FOOTAGE 652 CASING INFORMATION 13.375" @ 1293' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5886.21 56.51 6.06 5387.31 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4RR 12.25" BHI KM633X 5225154 3x14, 3x20 3842' 2072' 38.0 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 163.4 @ 5759 2.2 @ 5827 82.9 68 FT/HR SURFACE TORQUE 17128 @ 5647 9302 @ 5737 12319.9 11609 AMPS WEIGHT ON BIT 47 @ 5836 3 @ 5551 20.8 14 KLBS ROTARY RPM 125 @ 5915 82 @ 5738 115.5 125 RPM PUMP PRESSURE 1630 @ 5659 1101 @ 5738 1463.6 1536 PSI DRILLING MUD REPORT DEPTH 5765 MW 9.55 VIS 58 PV 20 YP 25 FL 2.2 Gels 8/10/13 CL- 33000 FC 1/2 SOL 6.0 SD 0.75 OIL 3/88.5 MBL pH 10.2 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 447 @ 5328 3 @ 5876 90.6 TRIP GAS 476u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 128497 @ 5327 487 @ 5876 26370.2 CONNECTION GAS HIGH ETHANE (C-2) 120 @ 5691 0 @ 5416 22.2 AVG PROPANE (C-3) 15 @ 5691 0 @ 5443 2.5 CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 23u / 33u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous Claystone 40% Tuffaceous Sandstone 40% Tuffaceous Siltstone 20% PRESENT LITHOLOGY Tuffaceous Claystone 70% Tuffaceous Sandstone 20% Tuffaceous Siltstone10% DAILY ACTIVITY SUMMARY Continue back reaming out of hole to 4320’. Circulate two bottoms up while working pipe. Service top drive, drawworks and adjust breaks. Trip in hole to 5173’ then wash to bottom. Drill ahead to 5743’ then pump 30bbl hi viscosity sweep followed by a 50bbl weighted sweep. Back ream out of hole to 5540’. Pump out of hole to 5160’, working through tight spots as per company rep. Trip back in to bottom and continue drilling ahead. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4490.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Shane Hauck / Rance Pederson DATE May 23, 2018 DEPTH 6096' PRESENT OPERATION Back reaming out of hole TIME 23:59 YESTERDAY 5915' 24 HOUR FOOTAGE 181' CASING INFORMATION 13.375" @ 1293' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6044.79 56.47 6.89 5474.82 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4RR 12.25" BHI KM633X 5225154 3x14, 3x20 3842' 6069' 2254' 40.33 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 112.6 @ 6030 5.4 @ 5922 96.0 102 FT/HR SURFACE TORQUE 17832 @ 6096 11153 @ 5916 13651.8 17832 AMPS WEIGHT ON BIT 31 @ 5988 4 @ 6028 18.2 26 KLBS ROTARY RPM 126 @ 5916 97 @ 5977 110.9 104 RPM PUMP PRESSURE 1707 @ 5995 1432 @ 5933 1569.6 1612 PSI DRILLING MUD REPORT DEPTH 6096 MW 9.6 VIS 61 PV 21 YP 28 FL 2.6 Gels 8/12/15 CL- 29000 FC 1/2 SOL 6.8 SD 0.50 OIL 3/88 MBL pH 9.9 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 289 @ 5966 6 @ 6082 63.5 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 92099 @ 5965 575 @ 6083 18690.8 CONNECTION GAS HIGH ETHANE (C-2) 95 @ 5965 1 @ 6075 15.3 AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 5u / 24u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous Sandstone 80% Tuffaceous Claystone 20% PRESENT LITHOLOGY Tuffaceous Sandstone 80% Tuffaceous Claystone 20% DAILY ACTIVITY SUMMARY Continue drilling 12.25” to 6092’. Work stuck pipe, set drilling jars off at 60k over pull then 180k straight pull. Trap 20k torque in string. Spot 75bbl NXS 7% lube pill around BHA. Pipe free with 160k over pull and 20k torque in string. Circulate NXS lube pill out of hole and work pipe from 6092’ to 6029’. Back reaming out of the hole at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4490.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Shane Hauck / Rance Pederson DATE May 24, 2018 DEPTH 6511 PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 6096 24 HOUR FOOTAGE 415 CASING INFORMATION 13.375" @ 1293' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6407.27 58.43 9.41 5669.95 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4RR 12.25" BHI KM633X 5225154 3x14, 3x20 3842' 6096' 2254' 40.33 2-2-CT-S-5-2-CT BHA 5 12.25" BHI 5 PDC TD60 7040648 6096' 415' 6.15 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 137.1 @ 6110 0.8 @ 6312 86.5 104 FT/HR SURFACE TORQUE 19671 @ 6120 143 @ 6114 12924.5 13227 AMPS WEIGHT ON BIT 29 @ 6097 1 @ 6198 11.4 8 KLBS ROTARY RPM 108 @ 6098 0 @ 6111 54.6 58 RPM PUMP PRESSURE 2095 @ 6124 1010 @ 6288 1812.1 1715 PSI DRILLING MUD REPORT DEPTH 6145 MW 9.6 VIS 61 PV 22 YP 29 FL 2.2 Gels 9/12/13 CL- 29000 FC 1/2 SOL 6.8 SD 0.50 OIL 3.1/87.9 MBL pH 10.3 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 544 @ 6363 3 @ 6146 123.2 TRIP GAS 264u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 177060 @ 6363 175 @ 6145 38328.2 CONNECTION GAS HIGH ETHANE (C-2) 177 @ 6333 2 @ 6097 36.0 AVG PROPANE (C-3) 23 @ 6363 0 @ 6478 5.5 CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 47u / 51u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous sandstone 40% Sand 30% Tuffaceous claystone 20% Coal 10% PRESENT LITHOLOGY Sand 50% Coal 50% DAILY ACTIVITY SUMMARY Circulate bottoms and work pipe from 1278’ to 1190’. Blow down top drive and monitor well for 10 minutes (static). Trip out of hole and lay down BHA. Service drawworks, blocks, washpipe, crown and ST-80 roughneck. Mobilize BHA, service mud pumps, C/O crown windsock, post jarring derrick inspection, clean flow line of obstruction and drain vac RVT tank. Pick up BHA 36 as per baker hughes, trip in hole to 1334’, shallow pulse test then run in hole. Work through tight spot at 5230, tag up at 5263’ and attempt to work through with no rotary or pump (fail). Pump through tight spot and continue to bottom. Drilling ahead at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4490.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Shane Hauck / Rance Pederson DATE May 25, 2018 DEPTH 7018' PRESENT OPERATION Circulating TIME 23:59 YESTERDAY 6511' 24 HOUR FOOTAGE 507' CASING INFORMATION 13.375" @ 1293' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6952.68 73.43 13.26 5909.19 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 12.25" BHI 5 PDC TD60 7040648 6096' 6096' 7018' 922' 15.25 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 207.9 @ 6807 1.2 @ 6970 67.4 55 FT/HR SURFACE TORQUE 19834 @ 7011 122 @ 6567 8825.9 16053 AMPS WEIGHT ON BIT 49 @ 6874 1 @ 6641 12.1 13 KLBS ROTARY RPM 73 @ 6626 0 @ 6722 36.5 52 RPM PUMP PRESSURE 2360 @ 6700 1301 @ 6832 1965.2 2179 PSI DRILLING MUD REPORT DEPTH 6984' MW 9.6 VIS 60 PV 18 YP 30 FL 2.2 Gels 9/12/15 CL- 31000 FC 1/2 SOL 6.6 SD 1.00 OIL 3/88 MBL pH 9.7 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 529 @ 6690 19 @ 6853 148.3 TRIP GAS 105u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 173275 @ 6689 3559 @ 6852 45709.8 CONNECTION GAS HIGH ETHANE (C-2) 165 @ 6983 2 @ 6928 45.3 AVG PROPANE (C-3) 35 @ 6982 0 @ 6949 10.2 CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 55u / 55u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous claystone 40% Tuffaceous Sandstone 40% Tuffaceous siltstone 10% Coal 10% PRESENT LITHOLOGY Tuffaceous claystone 70% Tuffaceous siltstone 20% Tuffaceous Sandstone 10% DAILY ACTIVITY SUMMARY Continue drilling 12.25” intermediate hole to 6540’. Pump 60bbl high viscosity sweep, 50% increased cuttings return. Pump out of hole from 6540’ to 6090’ then trip back to bottom. Continue drilling ahead to 6828’ and pump 51bbl sweep. Drill to 6975’ and circulate to look for gas. Continue drilling to TD at 7018’. Pump 44bbl sweep and circulate hole clean. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4490.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Shane Hauck / Rance Pederson DATE May 26, 2018 DEPTH 7018 PRESENT OPERATION Cement Bond Log TIME 23:59 YESTERDAY 7018 24 HOUR FOOTAGE 0 CASING INFORMATION 13.375" @ 1293' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 12.25" BHI 5 PDC TD60 7040648 6096' 7018' 922' 15.25 2-2-WT-N-0-I-CT TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 7018 MW 9.65 VIS 55 PV 15 YP 26 FL 3.0 Gels 7/10/12 CL- 30000 FC 1/2 SOL 7.2 SD 1.00 OIL 3/87.5 MBL pH 10.0 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new footage drilled DAILY ACTIVITY SUMMARY Circulate bottoms up while working pipe from 6950 t o 7005. Back ream out of hole to 6155. Pump 65bbl hi vis sweep and work pipe. 50% increased cuttings return. Back ream out of hole to 5489. Pump 45bbl hi vis sweep and work pipe. Flow check well. Pump out of hole and lay down bad joint from top of stand 21. Circulate bottoms up at 2650 to check MWD tools and establish flow rate after washout was located. Pump out of hole to shoe and monitor well (-0.2bbls per ½ hour). Trip out of hole to 605 and monitor well at BHA. Lay down BHA #5 as per baker and rig up slumberger wireline to run CBL. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4490.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Shane Hauck / Rance Pederson DATE May 27, 2018 DEPTH 7018 PRESENT OPERATION Circulating TIME 23:59 YESTERDAY 7018 24 HOUR FOOTAGE 0 CASING INFORMATION 13.375" @ 1293' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED RR5 12.25" BHI 5 PDC TD60 7040648 7018 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 7018 MW 9.65 VIS 55 PV 15 YP 26 FL 3.2 Gels 7/9/12 CL- 30000 FC 1/2 SOL 7.2 SD 1.00 OIL 3/87.5 MBL pH 9.9 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new footage drilled DAILY ACTIVITY SUMMARY Finish rigging up SLB wireline and 58’ of tools and test. Run in hole with wireline to 1289’, come out and rig down wireline. Remove wear bushing, make up stack washing tool, wash hanger profile / BOP stack. Blow down choke/T/D, kill lines, drain BOP stack back into mud pits. Rig up to test BOP’s. Install test joint, plug in place, fill up with filtered inlet water from pill pit, perform body test, leak on south blind ram door seal. Drain BOP stack, de-energize koomey unit, open door, inspect door seal, change out door seal and body test BOP stack. Test BOP as per AOGCC regulations with Adam Earl. Lay down test tool and rig down testing equipment. Install wear bushing, change out saver sub and reset torque wench to the factory settings. Pick up BHA #7 as per BHI, shallow test tools. Had to change out screens to get correct flow rate. CANRIG PERSONNEL ON BOARD 2 DAILY COST $4490.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Shane Hauck / Rance Pederson DATE May 28, 2018 DEPTH 7018 PRESENT OPERATION L/D BHA #7 TIME 23:59 YESTERDAY 7018 24 HOUR FOOTAGE 0 CASING INFORMATION 13.375" @ 1293' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED RR5 12.25" BHI 5 PDC TD60 7040648 7018 7018 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 5/27/2018 MW 9.65 VIS 55 PV 15 YP 26 FL 3.2 Gels 7/9/12 CL- 30000 FC 1/2 SOL 7.2 SD 1.00 OIL 3/87.5 MBL pH 9.9 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new footage drilled DAILY ACTIVITY SUMMARY Continue picking up BHA #7 as per Baker. Trip in hole to 1268’ and circulate bottoms up. Cut and slip 111’ of drilling line. Inspect hookload sensor and calibrate block height. Run in hole to 2579’ and conduct open hole logs as per Baker MWD/DD. Conduct single point tests at 1269’, 1515’, 1593’, 1619’, 1703’, 2165’, 2510’, 2579’. Conduct stretch tests at 1200’ and 2500’. RFT points @ 2579.4' TF=235 & 180, 2591.4' TF=138, 2620.4 TF=139, 2746.4' TF=10, 2648' TF=8 good test 527psi, 2812.4' TF=358, 2854.4' TF=358, 2867' TF=358,18. Pump out of hole from 2890’ to 1703’. RFT @ 1703’. Continue pumping out of hole from 1703’ to 1267’. Circulate bottoms up and monitor well. Trip out of hole to 607’ and monitor well at BHA. Continue racking back HWDP and laying down BHA at report time. CANRIG PERSONNEL ON BOARD 2 DAILY COST $4245.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Shane Hauck / Rick Brumley DATE May 29, 2018 DEPTH 7018 PRESENT OPERATION Circulating TIME 23:59 YESTERDAY 7018 24 HOUR FOOTAGE 0 CASING INFORMATION 13.375" @ 1293' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED RR5 12.25" BHI 5 PDC TD60 7040648 7018 7018 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 7018' MW 9.55 VIS 51 PV 15 YP 24 FL 3.4 Gels 7/12/15 CL- 27000 FC 1/2 SOL 7.3 SD 0.75 OIL 3/87.6 MBL pH 9.5 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 604u @ 6250' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 53u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new footage drilled DAILY ACTIVITY SUMMARY Pick up MWD testtrak/ontrak BHA. Shallow test tool at 89’. Run in hole to 607’. Trip in holr to 3416’ and circulate bottoms up. Wash down from 3416’ to 4395’. Circulate high vis sweep with 50% increased cuttings. Conduct stretch test from 4674’ to 4624’. Conduct single point logs with RFT sensor. Wash down to 5248’. Wash and ream down from 5248’ to 5438’. Log RFT at 5358.1’, 5335’. Reaming and washing down to 6097’. Circulate bottoms up. Wash and ream to bottom. Circulating hole clean at report time. CANRIG PERSONNEL ON BOARD 2 DAILY COST $4245.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Shane Hauck / Rick Brumley DATE May 30, 2018 DEPTH 7018 PRESENT OPERATION Running RFT tests TIME 23:59 YESTERDAY 7018 24 HOUR FOOTAGE 0 CASING INFORMATION 13.375" @ 1293' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED RR5 12.25" BHI 5 PDC TD60 7040648 7018 7018 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 7018' MW 9.55 VIS 47 PV 13 YP 21 FL 3.6 Gels 7/12/16 CL- 26000 FC 1/2 SOL 7.4 SD 0.75 OIL 2.5/88.1 MBL pH 9.5 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 81u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 6u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new footage drilled DAILY ACTIVITY SUMMARY Circulate 58bbl high vis/walnut sweep with 100% increased cuttings at shakers. Trip out of hole to 4960’ and circulate bottoms up. Conduct open hole RFT tests per baker directional/mwd, from 4787',4784' 4231' 4229, 4107'. Continuing RFT tests at report time. CANRIG PERSONNEL ON BOARD 2 DAILY COST $4245.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Shane Hauck / Rick Brumley DATE May 31, 2018 DEPTH 7018 PRESENT OPERATION Running 9-5/8" Casing TIME 23:59 YESTERDAY 7018 24 HOUR FOOTAGE 0 CASING INFORMATION 13.375" @ 1293' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 5/30/2018 MW 9.55 VIS 47 PV 13 YP 21 FL 3.6 Gels 7/12/16 CL- 26000 FC 1/2 SOL 7.4 SD 0.75 OIL 2.5/88.1 MBL pH 9.5 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new footage drilled DAILY ACTIVITY SUMMARY Pump out of hole from 2918’ to 1269’. Spot 85bbl 10.7ppg LCM pill from 2500’ to 1800’. Monitor well for 10 minutes at 1269’. Trip out of hole and lay down BHA per Baker rep. De-energize koomey, remove 2-7/8x5.5 uppers and install 9-5/8” solid body rams. Close ram doors, energize koomey and change out packing on drawworks. Rig up BOP testing equipment and test 9-5/8” uppers then rig down testing equipment. Rig up casing equipment while monitoring well (-1.0bbls per hour). Run 9-5/8” casing, bakerlocked the shoe and float equipment assembly, putting centralizers in place as per running order tally. Circulate at 1289’ then continue running casing. CANRIG PERSONNEL ON BOARD 2 DAILY COST $4245.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Shane Hauck / Rick Brumley DATE June 1, 2018 DEPTH 7018 PRESENT OPERATION Preping to pump cement TIME 23:59 YESTERDAY 7018 24 HOUR FOOTAGE 0 CASING INFORMATION 13.375" @ 1293' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 7018' MW 9.55 VIS 48 PV 12 YP 20 FL 4.2 Gels 5/10/11 CL- 27000 FC 1/2 SOL 7.3 SD 0.75 OIL 2.5/88.1 MBL pH 7.1 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 1129' @ BU CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new footage drilled DAILY ACTIVITY SUMMARY Continue running 9-5/8” casing. Haliburton rep witness make up ES cementer – 15ft/min while running in hole. Continue running in hole and circulate bottoms up at 5132’. Finish running casing to bottom, rig down Volant tool and bails rigging up 9-5/8” spyders and long bails. Rig up cement head. Circulate hole clean for cement job thinning down the viscosity while desco cleared the floor of casing equipment. Fill iso tanks with mud from the pits. CANRIG PERSONNEL ON BOARD 2 DAILY COST $4245.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Shane Hauck / Rick Brumley DATE June 2, 2018 DEPTH 7018 PRESENT OPERATION Rig down cementing equipment TIME 23:59 YESTERDAY 7018 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 7006' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 7018' MW 9.5 VIS 48 PV 11 YP 18 FL 4.2 Gels 5/9/10 CL- 27000 FC 1/2 SOL 6.9 SD 0.75 OIL 2.5/88.5 MBL pH 7.0 Ca+ 480 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 26u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new footage drilled DAILY ACTIVITY SUMMARY Dropped bypass plug, pumped 1stage of cement, 171 bbls/ lead @ 12.5 ppg, 59 bbls of tail @14.9 ppg. Dropped landing plug, started pumping w/rig , working pipe, lost circulation @ 3100 strokes and packing off, could not land it after packing off. Pressured up to 2830psi to open up ES cementer, established circulation, circulate bottoms up @ 2250 strokes. Pumped 40 bbl/high vis sweep and continue circulating, preparing for stage 2 of cement job. Pumped 5bbl of h20 rig pumped 60 bbls of 10 ppg spacer, HES pumped 228bbl of 12ppg cement, dropped closing plug HES pumped 5bbls of h2o, rig pumped 284.8bbl and bumped plug @ 800psi landed plug tool shifted @ 1500psi cip. Suck out the stack and rig down the cementing equipment. Nipple down well head to install emergency slips on 9 5/8'' casing. Clean out flow box and deflated the riser air boots, split the well head and pu stack and riser. deenergized Koomy unit, had 340k on the 9 5/8'' when emergency slips were set. emergerncy slips set @ 23:50 CANRIG PERSONNEL ON BOARD 2 DAILY COST $4245.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Shane Hauck / Rick Brumley DATE June 3, 2018 DEPTH 7018 PRESENT OPERATION drilling cement TIME 23:59 YESTERDAY 7018 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 6998' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 6 8.5" Smith 8 1/2 PDC JHS967 7x12 7018' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 7018' MW 9.7 VIS 48 PV 11 YP 18 FL 4.2 Gels 5/9/10 CL- 27000 FC 1/2 SOL 6.9 SD 0.75 OIL 2.5/88.5 MBL pH 7.7 Ca+ 480 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new footage drilled DAILY ACTIVITY SUMMARY Finish working on rig vacuum and vacuumed out old mud from landing joint. Continued to clean pits and shakers, offload old mud. Backed out landing joint to drain last little bit of mud. Rig down spyder elevators, started cutting casing in well room and continue cleaning pits. Lay down landing joint and rig down Weatherford casing tools. Installed 9 5/8” packoff, nipple up BOP’s, tested packoff. Change out bails and handling equipment from casing run. Make up test plug and test upper pipe rams. Install wear bushing and lay down test equipment. Flooded lines, shut the blinds and tested casing to 3550psi. It held for 3 minutes then bled off to 2870psi after 30 minutes. Checked all surface equipment for leaks, none found. Pick up BHA #9 as per Baker rep. Run in hole, tag cement at 3989’ then displace to H2O and circulate for drilling out cement plug and cement. CANRIG PERSONNEL ON BOARD 2 DAILY COST $4245.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Shane Hauck / Rick Brumley DATE June 4, 2018 DEPTH 7018 PRESENT OPERATION drilling cement TIME 23:59 YESTERDAY 7018 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 6998' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 6 8.5" Smith 8 1/2 PDC JHS967 7x12 0-0-NO-G-X-I-NO BHA 7 8.5" Smith II Tooth Tri-Cone 5283478 3x16, 1x14 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 7018' MW 9.7 VIS 48 PV 11 YP 18 FL 4.2 Gels 5/9/10 CL- 27000 FC 1/2 SOL 6.9 SD 0.75 OIL 2.5/88.5 MBL pH 7.7 Ca+ 480 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new footage drilled DAILY ACTIVITY SUMMARY Continue drilling cement from 4001’ to 4002’, monitor well for 10 minutes (static). Trip out of hole, change out bit from PDC to roller cone and run back in hole to 3695’ and then wash to bottom. Drilled up DV collar from 4000’ to 4004.5 and continue chasing cement plug to bottom. Run in hole to 4909’ chasing plug and running into stringers along the way. Circulate bottoms up at 4909’ to clean the hole up for initial casing PSI test. Pull out of hole to 4817’ for space out for PSI test. Rigged up to test 9-5/8” casing. Closed top rams and opened the kill line, pressuring up up the backside and down the drill pipe. Took 60 strokes to pressure up to 3590psi at 13:48 and held to 13:57 3567psi. good test. Drill cement from 4909’ until report time. CANRIG PERSONNEL ON BOARD 2 DAILY COST $4245.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Marvin Rogers / Rick Brumley DATE June 5, 2018 DEPTH 7018 PRESENT OPERATION Tripping out of hole TIME 23:59 YESTERDAY 7018 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 6998' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 7 8.5" Smith II Tooth Tri-Cone 5283478 3x16, 1x14 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 7/4/2018 MW 9.7 VIS 48 PV 11 YP 18 FL 4.2 Gels 5/9/10 CL- 27000 FC 1/2 SOL 6.9 SD 0.75 OIL 2.5/88.5 MBL pH 7.7 Ca+ 480 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new footage drilled DAILY ACTIVITY SUMMARY Continue drilling cement to 6237’ then pump a high vis sweep (300 vis). Large amount of rubber returns to the shakers. Continue drilling cement down to top of baffle at 6916.10’, lay down single and rig up to test casing. Test 9-5/8” casing to 3500psi for 30 minutes. 7.2 bbls pumped and 8.4 bbls bled back. Rig down test equipment and continue drilling the baffle to 6975’, float collar was at 6956’ circulate hole clean then begin pumping out of hole to 4312. Circulate two bottoms up, pump dry job and trip out of hole. CANRIG PERSONNEL ON BOARD 2 DAILY COST $4245.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Marvin Rogers / Rick Brumley DATE June 6, 2018 DEPTH 7018 PRESENT OPERATION Drilling cement TIME 23:59 YESTERDAY 7018 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 6998' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 7 8.5" Smith II Tooth Tri-Cone 5283478 3x16, 1x14 7018' 1-1-NO-A-E-1-NO BHA 8 8.5" BHI KMX524 5266639 2x16, 2x18 7018' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 6/5/2018 MW 9.7 VIS 48 PV 11 YP 18 FL 4.2 Gels 5/9/10 CL- 27000 FC 1/2 SOL 6.9 SD 0.75 OIL 2.5/88.5 MBL pH 7.7 Ca+ 480 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new footage drilled DAILY ACTIVITY SUMMARY Lay down BHA and service top drive, crown and draww orks. Rig up E-line and run CBL. Rig down E-line, clean mud pits, shaker pits, mix new mud, clean upper well room. Pick up BHA #11 and trip in hole to 700’, fill pipe and test MWD. Run in hole to 6854’ and fill pipe. Cut and slip 94’ of drilling line, re-calibrate block height. Washed down to 6975’ then drill cement to 6998’. Set down 4K on shoe. Weight condition and circulate to weight up and vis up new mud. Change out MWD stand pipe sensor and mud pump #2 PRV. Drill out 9-5/8” casing shoe and rat hole to 7006’ at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4490.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Marvin Rogers / Rick Brumley DATE Jun 07, 2018 DEPTH 7574 PRESENT OPERATION Derrick Inspection TIME 23:59 YESTERDAY 7018 24 HOUR FOOTAGE 556 CASING INFORMATION 9-5/8" @ 6998' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7449.98 88.58 16.05 5978.11 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 8 8.5" BHI KMX524 5266639 2x16, 2x18 7018' 556' 10.66 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 291.8 @ 7386 3.1 @ 7122 79.1 90 FT/HR SURFACE TORQUE 22935 @ 7263 14651 @ 7098 18345.4 16383 AMPS WEIGHT ON BIT 28 @ 7291 3 @ 7044 15.5 15 KLBS ROTARY RPM 121 @ 7493 50 @ 7019 102.7 118 RPM PUMP PRESSURE 2179 @ 7018 947 @ 7123 1546.6 1445 PSI DRILLING MUD REPORT DEPTH 7574 MW 9.05 VIS 42 PV 9 YP 20 FL 4.0 Gels 14/25/45 CL- 340 FC 1/2 SOL 2.9 SD 0.25 OIL 0/94.6 MBL pH 10.4 Ca+ 340 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 448 @ 7403 8 @ 7095 132.6 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 178165 @ 7403 2143 @ 7094 51854.0 CONNECTION GAS HIGH ETHANE (C-2) 261 @ 7478 4 @ 7094 84.0 AVG PROPANE (C-3) 51 @ 7478 0 @ 7123 17.1 CURRENT BUTANE (C-4) 5 @ 7470 0 @ 7252 0.3 CURRENT BACKGROUND/AVG PENTANE (C-5) 6 @ 7077 0 @ 7290 0.2 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 40% Coal 20% Sandstone 20% Claystone 20% Siltstone PRESENT LITHOLOGY 90% Coal 10% Siltstone DAILY ACTIVITY SUMMARY Drill 8.5” production hole from 7011’ to 7038’. Perform FIT to 12.0 EMW (good). Pump 50bbl high vis spacer sweep. Displace mud at 8bbl/min, build new mud, clean pits, offload old mud to iso. Continue drilling ahead until 7574’. Pump 44bbl high vis sweep and circulate until hole clean. Short trip out to 7003’. Service and inspect top drive after rough drilling. Circulate at the shoe while doing a weekly derrick inspection and transferring old mud out of the pits to the upright tanks. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4540.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Marvin Rogers / Rick Brumley DATE Jun 08, 2018 DEPTH 8392 PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 7574 24 HOUR FOOTAGE 818 CASING INFORMATION 9-5/8" @ 6998' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8300.44 88.50 10.79 6002.96 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 8 8.5" BHI KMX524 5266639 2x16, 2x18 7018' 1374' 26.5 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 111.8 @ 7609 3.1 @ 7814 59.5 62 FT/HR SURFACE TORQUE 23391 @ 8350 15458 @ 7712 19586.9 22249 AMPS WEIGHT ON BIT 38 @ 8047 5 @ 7862 20.2 19 KLBS ROTARY RPM 121 @ 7808 72 @ 7858 101.8 90 RPM PUMP PRESSURE 2010 @ 8288 944 @ 7862 1733.3 1904 PSI DRILLING MUD REPORT DEPTH 8276 MW 9.1 VIS 44 PV 10 YP 25 FL 3.7 Gels 9/11/14 CL- 29000 FC 1/2 SOL 3.4 SD 0.10 OIL 0/94.2 MBL pH 10.5 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 361 @ 7687 9 @ 7632 74.6 TRIP GAS 358u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 142551 @ 7687 673 @ 7631 28184.6 CONNECTION GAS HIGH ETHANE (C-2) 224 @ 7687 4 @ 8046 45.9 AVG PROPANE (C-3) 42 @ 7687 0 @ 8123 9.9 CURRENT BUTANE (C-4) 5 @ 7705 0 @ 8319 0.2 CURRENT BACKGROUND/AVG 54u / 48u PENTANE (C-5) 8 @ 7742 0 @ 7746 0.2 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 80% Sand/sandstone 10% Claystone 10% Siltstone PRESENT LITHOLOGY 80% Sand/sandstone 10% Claystone 10% Siltstone DAILY ACTIVITY SUMMARY Continue drilling 8.5” production hole from 7574’ to 8046’. Inspect top drive for broken tie wire. Pump 9.5ppg high vis sweep with 150% increased cuttings return. Drilling ahead at 8392’ at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4540.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Marvin Rogers / Rick Brumley DATE Jun 09, 2018 DEPTH 8801 PRESENT OPERATION Pick up BHA TIME 23:59 YESTERDAY 8392 24 HOUR FOOTAGE 409 CASING INFORMATION 9-5/8" @ 6998' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8680.16 88.56 10.36 6013.05 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 8 8.5" BHI KMX524 5266639 2x16, 2x18 7018' 8801' 1783' 32.4 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 298.5 @ 8779 5.5 @ 8773 66.4 157 FT/HR SURFACE TORQUE 25592 @ 8780 18513 @ 8470 22450.9 25016 AMPS WEIGHT ON BIT 30 @ 8787 7 @ 8769 20.7 27 KLBS ROTARY RPM 114 @ 8775 86 @ 8764 98.5 92 RPM PUMP PRESSURE 2040 @ 8599 1793 @ 8456 1930.8 1895 PSI DRILLING MUD REPORT DEPTH 8801 MW 9.15 VIS 46 PV 12 YP 26 FL 3.3 Gels 9/11/14 CL- 34000 FC 1/2 SOL 3.4 SD 0.10 OIL 0/93.8 MBL pH 10.4 Ca+ 100 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 71 @ 8573 16 @ 8768 47.6 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 26627 @ 8572 7288 @ 8768 18057.3 CONNECTION GAS HIGH ETHANE (C-2) 39 @ 8672 12 @ 8768 27.8 AVG PROPANE (C-3) 10 @ 8669 0 @ 8771 5.5 CURRENT BUTANE (C-4) 5 @ 8539 0 @ 8594 0.2 CURRENT BACKGROUND/AVG PENTANE (C-5) 6 @ 8682 0 @ 8741 0.2 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 80% Tuffaceous sandstone / sand 10% Claystone 10% Carbonaceous shale PRESENT LITHOLOGY 80% Tuffaceous sandstone / sand 10% Claystone 10% Carbonaceous shale DAILY ACTIVITY SUMMARY Continue drilling 8.5” production hole to 8525’ then pump 45bbl high vis sweep with a 175% increase in cuttings. Continue drilling ahead to 8801’, pump 45bbl high vis sweep with 100% increased returns and begin pulling out of the hole on elevators. Pull through tight spots at 7727’, 7680’ and 7670’ at 25K over. Circulate bottoms up at 6920’, flow check well (static), pump dry job and blow down top drive. Trip out of hole, racking back drill pipe. Lay down BHA, pick up a single and make up to collars, rack back in derrick, pick up another single and 6’pup joint and make up to MWD. Pick up and check bit, downlink MWD, rack back mwd in derrick. Calculate displacement = 82.1 bbls, actual = 91.2 bbls for trip out of hole. Pick up stand from derrick, remove wear ring, close blind rams, pick up stack washer, flush well head bowl, come up flush stack working string up and down at 17 BPM. Function annular, lower pipe rams, upper pipe rams 2 times each, flushing between each function, remove stack washer. Picking up BHA #12 at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4540.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Marvin Rogers / Rick Brumley DATE Jun 10, 2018 DEPTH 8801 PRESENT OPERATION Circulating TIME 23:59 YESTERDAY 8801 24 HOUR FOOTAGE 0 CASING INFORMATION 9-5/8" @ 6998' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED RR8 8.5" BHI KMX524 5266639 2x16, 2x18 8801' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8801 MW 9.2 VIS 47 PV 11 YP 25 FL 3.5 Gels 8/11/13 CL- 33000 FC 1/2 SOL 3.9 SD 0.10 OIL 0/93.4 MBL pH 10.6 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 383u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY no new footage drilled DAILY ACTIVITY SUMMARY Continue picking up BHA #12 and 48 joints of 5” drill pipe. Single in hole to 2024’, fill up pipe, test MWD then continue running in hole. Rig up BOP testing equipment and function test BOP’s. Test #1 annular, CMV's 1,2,3,12,13,14, dart valve, demco kill, low/250 high/3500, test #2 upper rams, TIW, CMV's 4,5,6,hcr kill, upper IBOP, low/250 high/3500 test# 3 CMV's 7,8,9 manual kill, test #4 cmv's 10,11 low/250 high/3500, test #5 super choke and manual choke control bleed off 1500 psi, test #6 HCR choke low/250 high/3500, test #7 manual choke low/250 high/3500, test #8 lower pipe rams low/250 high/3500 / witnessed by AOGCC Brian Bixby. Break test joint from test plug, install new seals on test plug, run in hole, set test plug, remove test joint, fill stack with water, test blind rams 250/3500psi each. Rig down test equipment, blow down top drive, choke and kill. Service top drive, drawworks and inspect top drive with multiple personnel. Trip in hole to 5240’, fill pipe, continue tripping into hole to 6945’ and circulate bottoms up. Continue running in hole to 7044’, single in with one stand and 6 joints of HWDP. Run in hole to 7580’, wash and ream to 7875’ then run in hole to 8644’. Wash and ream to 8779’ and circulate. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4640.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Marvin Rogers / Rick Brumley DATE Jun 11, 2018 DEPTH 9651 PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 8801 24 HOUR FOOTAGE 850 CASING INFORMATION 9-5/8" @ 6998' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9554.82 89.69 13.86 6026.54 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED RR8 8.5" BHI KMX524 5266639 2x16, 2x18 8801' 850' 15.00 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 173.1 @ 8803 1.3 @ 9330 74.4 39 FT/HR SURFACE TORQUE 26903 @ 9029 18652 @ 8802 23617.1 25587 AMPS WEIGHT ON BIT 27 @ 8801 1 @ 9173 17.4 17 KLBS ROTARY RPM 120 @ 9330 76 @ 9413 99.0 93 RPM PUMP PRESSURE 2145 @ 9015 993 @ 9173 1987.6 1939 PSI DRILLING MUD REPORT DEPTH 9398 MW 9.25 VIS 44 PV 10 YP 21 FL 3.0 Gels 6/8/10 CL- 32000 FC 1/2 SOL 4.4 SD 0.10 OIL 0/93.1 MBL pH 10.4 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 86 @ 8888 8 @ 9595 32.2 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 33312 @ 8869 3324 @ 9594 12162.0 CONNECTION GAS HIGH ETHANE (C-2) 46 @ 8890 7 @ 9397 20.7 AVG PROPANE (C-3) 13 @ 8886 0 @ 9615 5.4 CURRENT BUTANE (C-4) 6 @ 9325 0 @ 9350 0.1 CURRENT BACKGROUND/AVG 15u / 20u PENTANE (C-5) 8 @ 9209 0 @ 9414 0.2 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 80% Sand / Sandstone 10% Claystone 10% Carbonaceous Shale PRESENT LITHOLOGY 80% Sand / Sandstone 10% Claystone 10% Carbonaceous Shale DAILY ACTIVITY SUMMARY Continue drilling 8.5” production hole to 9111’ and pump 45bbl high vis sweep with 75% increased cuttings and 200 strokes late. Back ream stand clean, shut down to change out broken bolts on top drive. Continue drilling ahead to 9306’. Back ream a stand to clean up hole and change out top drive bolts and tighten loosed bolts and broken tie wire. Pump 45bbl high vis sweep and continue drilling ahead to 9492’ and pump 9.7 high vis nut plug sweep at 9306’ with a 90% increase in cuttings and 20bbls late. Continue drilling ahead, pumping a .7 high vis nut plug sweep at 9490’ with a 100% increase in cuttings and 20bbls late. Drilling ahead at 9651’ at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4640.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Marvin Rogers / Jessie Richardson DATE Jun 12, 2018 DEPTH 10050 PRESENT OPERATION Circulating TIME 23:59 YESTERDAY 9651 24 HOUR FOOTAGE 399 CASING INFORMATION 9-5/8" @ 6998' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10015.37 89.45 13.89 6029.94 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED RR8 8.5" BHI KMX524 5266639 2x16, 2x18 8801' 10,050' 1249' 20.9 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 198.6 @ 9968 2.4 @ 9776 78.6 13 FT/HR SURFACE TORQUE 26048 @ 9678 20440 @ 9680 23881.5 23872 AMPS WEIGHT ON BIT 20 @ 9704 3 @ 9870 16.7 8 KLBS ROTARY RPM 125 @ 10027 88 @ 9683 96.3 96 RPM PUMP PRESSURE 2048 @ 9924 1041 @ 10014 1927.1 1937 PSI DRILLING MUD REPORT DEPTH MW 9.15 VIS 44 PV 10 YP 25 FL 3.1 Gels 10/13/15 CL- 30000 FC 1/2 SOL 3.7 SD 0.10 OIL 0/93.8 MBL pH 10.2 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 75 @ 10020 9 @ 9682 37.8 TRIP GAS 617u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 29261 @ 10020 3369 @ 9682 14351.1 CONNECTION GAS HIGH ETHANE (C-2) 46 @ 10019 7 @ 9682 23.5 AVG PROPANE (C-3) 12 @ 9914 0 @ 9655 7.1 CURRENT BUTANE (C-4) 4 @ 9655 0 @ 9951 0.2 CURRENT BACKGROUND/AVG 30u / 30u PENTANE (C-5) 7 @ 10038 0 @ 9775 0.3 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 80% sand / sandstone 10% claystone 10% carbonaceous shale PRESENT LITHOLOGY 100 % sand / sandstone DAILY ACTIVITY SUMMARY Continue drilling 8.5” production hole to 9684’ and pump a 45bbl high vis sweep with 125% increase in returns. Back ream stand clean and change out broken bolts on top drive, change out swivel packing. Pump 45bbl high vis sweep and continue drilling to 9779’. Pump 45bbl high vis sweep with 100% increase in returns. Continue drilling 8.5” production hole to 10,050’ and pump a 45bbl high vis sweep with 100% increase in return cuttings and 10bbls late. Pump another sweep with 60% increase in cuttings and 10bbls late. Flow check (static). Trip out of hole to 6940’ on elevators with tight spots at 7755’ and 7752’. Circulate and condition. Inspect and service top drive, tighten bolts on grabber dies. Trip in hole to 9874’ then wash and ream to bottom, working through tight spot at 7186. Circulating at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4640.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Marvin Rogers / Clint Montague DATE Jun 13, 2018 DEPTH 10050 PRESENT OPERATION Displacing TIME 23:59 YESTERDAY 10050 24 HOUR FOOTAGE 0 CASING INFORMATION 9-5/8" @ 6998' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED RR8 8.5" BHI KMX524 5266639 2x16, 2x18 8801' 10,050' 1249' 20.9 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 6/12/2018 MW 9.15 VIS 44 PV 10 YP 25 FL 3.1 Gels 10/13/15 CL-30000 FC 1/2 SOL 3.7 SD 0.10 OIL 0/93.8 MBL pH 10.2 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 21u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new footage drilled. DAILY ACTIVITY SUMMARY Pumped 45bbl high vis sweep with 100% increased returns and 350 strokes late. Displace open hole volume with 9.2ppg mud. Trip out of hole with no tight spots. Circulate bottoms up at the shoe and prepare mud pits for FIW and off load old mud to upright tanks. Displaced 9-5/8” casing with 8.6ppg FIW, hole losing 2bbls per hour. Monitor well while cleaning surface equipment, trip tanks 1 & 2, build 430bbls of 6% KCl brine and clean shaker room pits. Lay out completion screen ready for strap/talley/drift. Finish strapping liner screens and blanks, fill three iso tanks from pits for displacement, build baraklean pill. Line up and start displacement with 40bbl caustic pill, chase with 40bbl baraklean pill, chase with 6% KCl brine. Had issue with mud pump #2 during displacement, swap over to mud pump #1. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4590.00 REPORT BY Josh Dubowski Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-22 REPORT FOR Marvin Rogers / Clint Montague DATE Jun 14, 2018 DEPTH 10050 PRESENT OPERATION RIH with production liner TIME 23:59 YESTERDAY 10050 24 HOUR FOOTAGE 0 CASING INFORMATION 9-5/8" @ 6998' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10015.37 89.45 13.89 6029.94 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED RR8 8.5" BHI KMX524 5266639 2x16, 2x18 8801' 10,050' 1249' 20.9 3-3-BT-3-I-CT TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10,050 MW 8.75 VIS PV YP FL Gels CL- 31000 FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new footage drilled. DAILY ACTIVITY SUMMARY Trip out of hole to surface, worked on mud pump #2, cleaned out suction manifolds and checked valve seats. Lay down BHA and rack back all HWDP in derrick. Pick up make up tools and BHA, racked back hanger in derrick. Rig up weatherford to run screens and completion. Service rig for running in hole, work on mud pump #1 cleaning out suction manifold and checking valve seats. Review running order, check safety joint ready and run in hole with liner screens as per tally. Weatherford casing services make seal lock HT connections to 3800’. Run in hole picking up joints 1x1 from skate to 2650’, rig up H/P line to pump FIW to production. Picked up total of 34 x 4” Bakerweld screens, 27 x 4” Excluder2000 screens, 18 x 4” blank screens. Pick up baker tools and rig up false table, change out elevators and prep for running 2-7/8” inner string. CANRIG PERSONNEL ON BOARD 2 DAILY COST $3685.00 REPORT BY Josh Dubowski