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Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov October 2, 2021 0U(ULF2SVWDG FF0U'HUULFN9DQDQG0V$VKOH\*LOEHUW (PHUDOG+RXVH//& 32%R[ $QFKRUDJH$. Re: Location Clearances Umiat 18 (PTD #2130140) Umiat 23H (PTD #2130200) Dear Mr.2SVWDG: On April 12, 2021 the Alaska Oil and Gas Conservation Commission (AOGCC) received the final Well Completion Reports for the plugging and abandonment of both the Umiat 18 well and the Umiat 23H well. An aerial inspection for the final location clearance was completed on September 6, 2021 and copies of the AOGCC inspector’s reports are attached. Each drill site was found to be in compliance with onshore location clearance requirements as stated in 20 AAC 25.170. The AOGCC requires no further work on the subject wells or locations at this time. However, (PHUDOG+RXVH//& remains liable if any problems were to occur with these wells in the future. Sincerely, Jessie L. Chmielowski Daniel T. Seamount, Jr. Jeremy M. Price Commissioner Commissioner Chair, Commissioner Daniel Seamount Digitally signed by Daniel Seamount Date: 2021.10.28 14:18:58 -08'00' Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.10.28 15:03:46 -08'00' Jeremy Price Digitally signed by Jeremy Price Date: 2021.10.28 15:21:03 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission 2) LI TO: Jim Regg Ci cl DATE: 9/6/2021 P. I. Supervisor FROM: Austin McLeod SUBJECT: Location Clearance Petroleum Inspector Umiat 23H , Emerald House LLC PTD 2130200 9/6/2021: 1 met with Emerald House LLC representative Sonny Kula to witness the location inspections of three wells that had been cut off and buried this past winter — Merlin 1, Umiat 18, and Umiat 23H. We traveled to Umiat 23H via helicopter. The helicopter hovered close to the ground so pictures could be taken. We flew around the vicinity finding nothing out of the ordinary or disturbances on the tundra. Attachments: Pictures (2) 2021-0906—Location Umiat-23H am.docx Page 1 of 2 2021-0906_Location_Umiat-18_am.docx Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO:Jim Regg DATE:9/6/2021 P. I. Supervisor FROM:Austin McLeod SUBJECT:Location Clearance Petroleum Inspector Umiat 18 Emerald House LLC PTD 2130140 9/6/2021:I met with Emerald House LLC representative Sonny Kula to witness the location inspections of three wells that had been cut off and buried this past winter – Merlin 1, Umiat 18, and Umiat 23H. We traveled to Umiat 18 via helicopter. The helicopter hovered close to the ground so pictures could be taken. We flew around the vicinity finding nothing out of the ordinary or disturbances on the tundra. Attachments:Pictures (2) 2021-0906_Location_Umiat-18_am.docxPage 2 of 2Location Clearance – Umiat 18 (PTD 2130140)Photos by AOGCC Inspector A. McLeod9/6/2021 2021-0906_Location_Umiat-23H_am.docx Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO:Jim Regg DATE:9/6/2021 P. I. Supervisor FROM:Austin McLeod SUBJECT:Location Clearance Petroleum Inspector Umiat 23H Emerald House LLC PTD 2130200 9/6/2021:I met with Emerald House LLC representative Sonny Kula to witness the location inspections of three wells that had been cut off and buried this past winter – Merlin 1, Umiat 18, and Umiat 23H. We traveled to Umiat 23H via helicopter. The helicopter hovered close to the ground so pictures could be taken. We flew around the vicinity finding nothing out of the ordinary or disturbances on the tundra. Attachments:Pictures (2) 2021-0906_Location_Umiat-23H_am.docxPage 2 of 2Location Clearance – Umiat 23H (PTD 2130200)Photos by AOGCC Inspector A. McLeod9/6/2021 AAlaska Oil and Gas CConservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov October 29, 2021 Mr. Leonard Sojka Malamute Energy, Inc. 7701 Golden Valley Road Golden Valley, MN 55427 Re: Rescission of an Erroneously Issued Letter Location Clearances: Umiat 18 (PTD #2130140) and Umiat 23H (PTD #2130200) Dear Mr. Sojka: On October 27, 2021, the Alaska Oil and Gas Conservation Commission (AOGCC) issued a letter to your company, Malamute Energy, Inc. (Malamute), regarding the location clearances for the above-referenced Umiat wells. The letter also notified you that Malamute remains liable with these wells in the future. After issuing the notice, we subsequently determined it was erroneously issued since Emerald House took over the Umiat leases in January 2021. Therefore, we are rescinding the October 27th letter and have re-issued a correct letter to Mr. Erik Opstad of Emerald House. We apologize for this error and misunderstanding. If you have any questions, please do not hesitate to contact Ms. Grace Salazar, AOGCC Special Assistant, at (907) 793-1221 or grace.salazar@alaska.gov. Sincerely, Jeremy M. Price . Chair, Commissioner Jeremy Price Digitally signed by Jeremy Price Date: 2021.10.29 10:19:46 -08'00' Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov October 27, 2021 Mr. Leonard Sojka cc. Mr. Derrick Van and Ms. Ashley Gilbert Malamute Energy, Inc. 7701 Golden Valley Road Golden Valley, MN 55427 Re: Location Clearances Umiat 18 (PTD #2130140) Umiat 23H (PTD #2130200) Dear Mr. Sojka: On April 12, 2021 the Alaska Oil and Gas Conservation Commission (AOGCC) received the final Well Completion Reports for the plugging and abandonment of both the Umiat 18 well and the Umiat 23H well. An aerial inspection for the final location clearance was completed on September 6, 2021 and copies of the AOGCC inspector’s reports are attached. Each drill site was found to be in compliance with onshore location clearance requirements as stated in 20 AAC 25.170. The AOGCC requires no further work on the subject wells or locations at this time. However, Malamute Energy, Inc remains liable if any problems were to occur with these wells in the future. Sincerely, Jessie L. Chmielowski Daniel T. Seamount, Jr. Jeremy M. Price Commissioner Commissioner Chair, Commissioner Dan Seamoun t Digitally signed by Dan Seamount Date: 2021.10.27 14:10:43 -08'00' Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.10.27 14:18:27 -08'00' Jeremy Price Digitally signed by Jeremy Price Date: 2021.10.27 14:33:11 -08'00' 2021-0906_Location_Umiat-23H_am.docx Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO:Jim Regg DATE:9/6/2021 P. I. Supervisor FROM:Austin McLeod SUBJECT:Location Clearance Petroleum Inspector Umiat 23H Emerald House LLC PTD 2130200 9/6/2021:I met with Emerald House LLC representative Sonny Kula to witness the location inspections of three wells that had been cut off and buried this past winter – Merlin 1, Umiat 18, and Umiat 23H. We traveled to Umiat 23H via helicopter. The helicopter hovered close to the ground so pictures could be taken. We flew around the vicinity finding nothing out of the ordinary or disturbances on the tundra. Attachments:Pictures (2) 2021-0906_Location_Umiat-23H_am.docxPage 2 of 2Location Clearance – Umiat 23H (PTD 2130200)Photos by AOGCC Inspector A. McLeod9/6/2021 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3.Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: Top of Productive Interval: 9.Ref Elevations: KB: 17. Field / Pool(s): GL: BF: Total Depth: 10.Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- TPI: x- y- Zone- 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore:21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 (ft MSL) 22.Logs Obtained: 23. BOTTOM 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: Oil-Bbl: suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary Date of Test: Flow Tubing Gas-Oil Ratio:Choke Size:Water-Bbl: PRODUCTION TEST Per 20 AAC 25.283 (i)(2) attach electronic information CASING WT. PER FT.GRADE TOP SETTING DEPTH MD TOP CEMENTING RECORDSETTING DEPTH TVD HOLE SIZE AMOUNT PULLED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG WAG Gas BOTTOM SIZE DEPTH SET (MD) PACKER SET (MD/TVD) TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, to production or injection? YesNo 25. 26. Was hydraulic fracturing used during completion?YesNo SIZE DEPTH SET (MD) TUBING RECORD t each interval open (MD/TVD of Top and Bottom; Perforation Number; Date Perfd): ACID, FRACTURE, CEMENT SQUEEZE, ETC. PACKER SET (MD/TVD) BOTTOM WT. PER FT.GRADE TOP SETTING DEPTH MD TOP CEMENTING RECORDSETTING DEPTH TVD HOLE SIZE AMOUNT PULLEDBOTTOM CASING, LINER AND CEMENTING RECORD Obtained: on, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, esistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation Acronyms may be used. Attach a separate page if necessary List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, onal or Inclination Survey: Yes (attached) No 13.Water Depth, if Offshore:21.Re-drill/Lateral Top Window MD/TVD: it electronic information per 20 AAC 25.050 (ft MSL) ion of Well (State Base Plane Coordinates, NAD 27):11.Total Depth MD/TVD: 19.DNR Approval Number: x- y-Zone- x- y-Zone-12.SSSV D 20.epth MD/TVD:Thickness of Permafrost MD/TVD: pth: x- y-Zone- ion of Well (Governmental Section):8.Date TD Reached:16.Well Name and Number: oductive Interval:9.Ref Elevations: KB: 17.f Field / Pool(s): GL: BF: pth:10.Plug Back Depth MD/TVD: 18.Property Designation: ss:7.Date Spudded:15.API Number: or Name:6.Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: Status:OilSPLUG OtherAbandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory WINJ WDSPLNo. of Completions: ____________________ Service Stratigraphic Test WAG G Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Samantha Carlisle at 9:11 am, Apr 12, 2021 1 Emerald House, LLC P.O. Box 112212, Anchorage AK 99511 1,031' FSL, 4,026' FEL, Sec 32-T1N-R1W, U.M. 1,457' FWL, 1,002' FSL, Sec 32-T1N-R1W, U.M. 436' FNL, 895' FEL, Sec 32-T1S-R1W, U.M. 732474.00 732,678 735,622 5631271.00 5,631,244 5,630,797 5 5 5 04/04/2021 02/15/2014 03/09/2014 23.00 575.00 3' Below GL 4,100' / 986' N/A N/A 213-020 / 321-113 50-287-20029-00-00 Umiat #23H Field (Umiat) FEDAA84141 N/A 972'/929' N/A Schlumberger Vision Service RM Composite Log (GR, Res, Den, Nue) 13-3/8" 66 J-55 0 91 0 91 20" 127 SX (21 bbl) Permafrost N/A 7-5/8" 29.7 L-80 0 1968 0 1260 9-7/8" 336/27 sx (629/32 bbl) N/A 4-1/2" 12.6 L-80 2064 3994 1246 986 6-3/4" Slotted Liner N/A Top of Slotted Liner: 2062' MD / 1246' TVD Bottom of Slotted Liner: 3994' MD / 986' TVD 3-1/2" 1858 N/A N/A N/A 03/20/2014 Artificaial Lift (Electrical Submersible Pump) 03/20/2014 644.00 0 0 N/A N/A 27 02250038.50 ✔ ✔ RBDMS HEW 4/14/2021 Abandonment Date 4/4/2021 HEW xG SFD 4/20/2021 FSL BJM 7/28/21 MDG 5/18/2021 T1N DSR-4/14/21 598 SFD 4/20/2021 463 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Contact Phone: General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). INSTRUCTIONS Authorized Name: Authorized Title: Authorized SignatureZ'DWH: 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Formation at 7': If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base TVD Well tested? Yes No No Sidewall Cores: 30.countered):FORMATION TESTS d summarize lithology and presence of oil, gas or water (subm and all subsequent laboratory analytical results per 20 AAC 2 Yes No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment N/A 0 0 980 980 Nanushuk 230 230 Upper Grandstand 369 369 Middle Grandstand 597 597 Lower Grandstand 722 722 Torok 1038 1038 2600 2515 Tested perforatred interval from Top of Slotted Liner: 2062' MD / 1246' TVD to bottom of Slotted Liner: 3994' MD / 986' TVD Lower Grandstand Tested the well for a total of 140 hours with a total of 644 bbls produced. 4 seperate build up, flowing periods and shuts-ins were completed Vice President Erik Opstad 10 March 2021 Tom Boyd taboydusa@gmail.com713-202-5078 Final P&A Schematic, Dir Surveys, P&A Ops Summary, P&A Photos Cement & P-test Rpt, Wireline Rpt ✔✔ ✔ Drill Floor to Sea Level 596' Drill Floor to Ground Level 21' Ground Level to SL 575' Tundra surface Note: Schematic not to scale. No.Umiat #23H 1 Proposed lower Grandstand B-sand Horizontal Slotted Liner ESP Completion 2 Update to WP#9 3 Update to Actuals 4 Actual Umiat #23H Permanent P&A 5 6 7 8 9 10 11 12 13 14 Z. Sayers Z. Sayers ADL # 392301 API No. 50-287-20029-00 Comments/DateRev. by Z. Sayers PTD #213-020 T. Boyd Spud Date: 2-15-2014 P&A Date: 4-4-2021 Lease: AA-084141 (BLM) 20" Hole 9-7/8" Hole 6-3/4" Hole TD -4,100' MD 986' TVD ----------Base Permafrost +/-801' ------- 13-3/8" Conductor 7-5/8" Surface Casing 1,968' MD 1,260' TVD Baker ESP Pump 1,848' MD 4-1/2" Slotted Production Tubing Perforations 1,448' to 1,451' 697' to 700' UMIAT #23H - AS COMPLETED P&A Umiat #23H P&A Emerald House Daily Operational Summary Tom Boyd and Rob Berube March 20, 2021 x Umiat Weather: Temp -29, Wind N/5 x HSSE: No Injuries, No Spills, No Incidents. Animal Tracks observed. No interactions with wildlife. No Wildlife observations. Working day tours only with travel/support from Merlin-#1 x Travel to Umiat #23H. 2-Way Check valve from both well with Bryan Imholte of Vault PC (Photos Below). Pressure remained at 0 psi after 2-Way Check was removed. Well head was secured prior to departure. Install 1502 hammer union connections of the wing valves and IA valves. x Shut down for night (SDFN) UMIAT #23H Initial Site Visit UMIAT #23H Initial Site Visit UMIAT #23H Pull BPV Umiat #23H P&A Emerald House Daily Operational Summary Tom Boyd and Rob Berube March 21, 2021 x Umiat Weather: Temp -22, Wind E/12 x HSSE: No Injuries, No Spills, No Incidents. Animal Tracks observed. No interactions with wildlife. No Wildlife observations. Working day tours only with travel/support from Merlin-#1 x Plan Umiat P&A project. Work with Cruz, MagTec, Alaska E-Line, Cameron, FMC, Lynden, Halliburton, Vault PC, and Emerald House personnel. Umiat #23H P&A Emerald House Daily Operational Summary Tom Boyd and Rob Berube March 22, 2021 x Umiat Weather: Temp -29, Wind ESE/3 x HSSE: No Injuries, No Spills, No Incidents. Animal Tracks observed. No interactions with wildlife. No Wildlife observations. Working day tours only with travel/support from Merlin-#1 x Duck Ponds below all equipment Umiat #23H P&A Emerald House Daily Operational Summary Tom Boyd and Rob Berube March 23, 2021 x Umiat Weather: Temp -13, Wind ESE/5 x HSSE: No Injuries, No Spills, No Incidents. Animal Tracks observed. No interactions with wildlife. No Wildlife observations. Working day tours only with travel/support from Merlin-#1 x Duck Ponds below all equipment Umiat #23H P&A Emerald House Daily Operational Summary Tom Boyd and Rob Berube March 24, 2021 x Umiat Weather: Temp -11, Wind S/5 x HSSE: No Injuries, No Spills, No Incidents. Animal Tracks observed. No interactions with wildlife. No Wildlife observations. Working day tours only with travel/support from Merlin-#1 x Duck Ponds below all equipment x Prepare for Umiat 23H Cementing operation x Move Halliburton Tool Trailer from Umiat #18 to Umiat #23H. x Move Wireline Unit and Crane, filled Cement Herc Pods to Umiat #23H. x Send Arctic Cutting Box with Cement Rinsate to Hilcorp Milne Point for Class 1 disposal. x Prepare for Umiat #23 P&A Operations. Umiat #23H P&A Emerald House Daily Operational Summary Tom Boyd and Rob Berube March 25, 2021 x Umiat Weather: Temp -9, Wind NNW/11 x HSSE: No Injuries, No Spills, No Incidents. Animal Tracks observed. No interactions with wildlife. No Wildlife observations. Working day tours only with travel/support from Merlin-#1 x Duck Ponds below all equipment x Haul Wireline Unit and Boom truck to Umiat #23H x Finish Rig up Halliburton Bush House on Umiat #23H x Move Halliburton Iron Connex from Umiat #18 to #23H x Haul in full cement Herc Pods to Umiat #23H x Move Arctic Cutting Box from Mile 56 Staging area to Merlin #1 well Umiat #23H P&A Emerald House Daily Operational Summary Tom Boyd and Rob Berube March 26, 2021 x Umiat Weather: Temp -20, Wind N/4 x HSSE: No Injuries, No Spills, No Incidents. Animal Tracks observed. No interactions with wildlife. No Wildlife observations. Duck Ponds below all equipment Working day tours only with travel/support from Merlin-#1 x Conduct PJSM at Umiat #23H x Rig up Halliburton Cement Bush House and Alaska E-Line equipment. x Run in the hole with 1.7” Gauge Ring to 1,470’, could not work deeper. Fluid level at +/- 650’. Wipe off all wellbore fluids from gauge ring with Absorbent pads. x Trouble shoot frozen valves and continue to line up equipment. UMIAT #23H Wireline Rig Up UMIAT #23H Wireline Rig Up UMIAT #23H Wireline Run in Hole Umiat #23H P&A Emerald House Daily Operational Summary Tom Boyd and Rob Berube March 27, 2021 x Umiat Weather: Temp -34, Wind S/7 x HSSE: No Injuries, No Spills, No Incidents. Animal Tracks observed. No interactions with wildlife. No Wildlife observations. Duck Ponds below all equipment Working day tours only with travel/support from Merlin-#1 x PJSM for Cement truck rig up, testing, and pumping operations at Umiat #23H x Fill surface lines and tree with Mineral Oil (LVT). Test surface lines to 250 psi low and 2,000 psi low. Hold for 5 min. Good test. x Pump 10 bbls of LVT down tubing (with IA closed) at 0.75 bbl/min 600 psi. x Open IA and close tubing. Pump 23 bbls of LVT down annulus at 1.5 bbl/min, 430 psi x PJSM for wireline and perforating operations. x Rig up and run-in the hole with 1.56" guns, 3 ' long, loaded with 6 shots per foot, total of 18 shots. Perforate tubing below collar. Perforations from 1,448' - 1,451'. POOH with wireline. Observed all shots fired. R/D wireline. x Shut down for night. Return to Merlin camp. On return back to camp, Pisten Bulley suffered mechanical failure. A team from Merlin camp, came out to change Alternator. Return to Merlin camp UMIAT #23H Wireline Rig Up UMIAT #23H Perforation Log UMIAT # 23H Spent Perforation Guns Umiat #23H P&A Emerald House Daily Operational Summary Tom Boyd and Rob Berube March 28, 2021 x Umiat Weather: Temp -36, Wind S/4 x HSSE: No Injuries, No Spills, No Incidents. Animal Tracks observed. No interactions with wildlife. No Wildlife observations. Duck Ponds below all equipment Working day tours only with travel/support from Merlin-#1 x PJSM for Cement truck rig up, cementing, and pumping operations on Umiat #23H x Open Tubing and close IA. Pump the Umiat #23H cement job as follows. x Stop pumping x Equalize Tubing and IA. 525 psi on both gauges. Complete cement report available in Umiat #23H Appendix. x Shut down for night. Cum Vol bbls Pressure Psi Rate bbl/min Begin pumping 12 ppg cement 10 20 1 20 143 2.5 30 240 2.64 40 368 2.67 50 440 2.56 Begin pumping 14 ppg cement 60 486 2.6 70 459 2.62 80 119 1 90 442 2.3 100 400 1.77 110 380 1.6 120 379 1.25 122 383 1.46 132 444 1 Displace 4" Nerf Wiper Ball 12 584 1 UMIAT #23H Cementing Spread UMIAT #23H Cementing Spread UMIAT #23H Prime pump with Diesel Umiat #23H P&A Emerald House Daily Operational Summary Tom Boyd and Rob Berube March 29, 2021 x Umiat Weather: Temp -9, Wind NE/23 x HSSE: No Injuries, No Spills, No Incidents. Animal Tracks observed. No interactions with wildlife. No Wildlife observations. Duck Ponds below all equipment Working day tours only with travel/support from Merlin-#1 x PJSM for Wireline operations on Umiat #23H x Position wireline unit and boom truck to run gauge ring and perforate well x 0 psi observed on Tubing and IA x Make up and RIH with 1.70" gauge ring. Tag up below crown valve. Found Ice Plug in tree. x Cover tree with Hercalite and apply heat. x Work tool string through tree and down to 813'. Could not work deeper x POOH and found tool covered with cement (see picture). x PJSM for Pressure testing operations x Pressure test tubing with diesel. Pressure up with cement unit to 1,724 psi, fell to 1,683 psi in 30 min. Good test for AOGCC and BLM criteria x AOGCC test limits have the following pass/fail criteria: 1,500 psi pressure test with a maximum 10% loss in 30 minutes x BLM test limits have the pass/fail criteria: 1,000 psi test with a maximum 10% loss in 10 minutes x Pressure test Annulus (IA) with diesel. Made several attempts to pressure test at +/- 1,500 psi but pressures fell by more than 10% before 30 minutes. Fail on AOGCC test criteria x Pressure test as per BLM Onshore Order No.2. Initial Pressure 1,000 psi, 10-minute Final Pressure 919 psi (less than 10% loss) Good Test – Pass. Complete Pressure Test results available in Umiat #23H Appendix. x Secure well and Shut down for night. UMIAT #23H Cement covered wireline tool Umiat #23H P&A Emerald House Daily Operational Summary Tom Boyd and Rob Berube March 30, 2021 x Umiat Weather: Temp -36, Wind S/4 x HSSE: No Injuries, No Spills, No Incidents. Animal Tracks observed. No interactions with wildlife. No Wildlife observations. Duck Ponds below all equipment Working day tours only with travel/support from Merlin-#1 x PJSM for Pressure testing operations on Umiat #23H x Pressure test annulus with diesel. Test failed 5 times x On 3-30-2021, 09:30, E. Opstad and T. Boyd discussed the failed P-test on the Umiat #23H with the BLM Bryan McLellan, Mel Rixse. They gave Emerald House a waiver of the positive test because of a successful BLM P-test, the observed 'green' cement on the wireline tool. Emerald House will attempt another test today when the cement had more time to develop compressive strength. x Pressure test Annulus (IA) with diesel. Made 5 attempts to pressure test at +/- 1,500 psi but pressures fell in excess of 10% before 30 minutes. Complete Pressure test results available in Umiat #23H Appendix x PJSM for Wireline operations on Umiat #23H x Rig up and run in hole with 1.56" guns, 3 ' long, loaded with 6 shots per foot, total of 18 shots (0.370" shot diameter) x Perforate tubing below collar with 350 psi pressure applied to the tubing. Perforations from 697' - 700'. Upon firing guns, observed immediate pressure loss on tubing. x POOH with wireline. Observed all shots fired. R/D wireline. x Secure well and Shut down for night UMIAT #23H Perforating Tubing UMIAT #23H Pressure Testing Umiat #23H P&A Emerald House Daily Operational Summary Tom Boyd and Rob Berube March 31, 2021 x Umiat Weather: Temp -13, Wind NE/21 x HSSE: No Injuries, No Spills, No Incidents. Animal Tracks observed. No interactions with wildlife. Approximately 25 Ptarmigan observed. Duck Ponds below all equipment Working day tours only with travel/support from Merlin-#1 x Open Tubing and IA. Pump the Umiat #23H cement job as follows: Pump down tubing while holding 350 psi to 500 psi pressure on annulus. Pump 2 bbls of Diesel followed by lead cement consisting of 30 bbls (105 sx) of 14.0 lb/gal VariCem 1.629 cuft/sk at 1 bbl/min 540 psi. See Halliburton cement report x Observe cement returns at surface tank. Close IA. Pressure up on tubing to 1,950 psi. Pressure bled to 1,650 psi in 4 minutes. Open IA and pump cement in mixing tub and lines down tubing, circulating out IA. Pump 1bbl of water to clear lines to tree. x Close in IA and Tubing. 0 psi on both gauges. x SDFN. Umiat #23H P&A Emerald House Daily Operational Summary Tom Boyd and Rob Berube April 1, 2021 x Umiat Weather: Temp -16, Wind NE/15 x HSSE: No Injuries, No Spills, No Incidents. Animal Tracks observed. No interactions with wildlife. Approximately 20 Ptarmigan observed. Duck Ponds below all equipment Working day tours only with travel/support from Merlin-#1 x Hot Work Permit for cutting activities Umiat #23H P&A Emerald House Daily Operational Summary Tom Boyd and Rob Berube April 2, 2021 x Umiat Weather: Temp -34, Wind S/6 x HSSE: No Injuries, No Spills, No Incidents. Animal Tracks observed. No interactions with wildlife. No wildlife observations. Duck Ponds below all equipment Working day tours only with travel/support from Merlin-#1. Hot Work Permit for welding activities x PJSM for rig down of wellhead and equipment on Umiat #23H x Remove cellar grating from around wellhead and prep for tree removal x Hot Work Permit for cutting activities x Remove tree and begin cutting window in conductor and cellar for Umiat #23H x Shut down for the night Umiat #23H P&A Emerald House Daily Operational Summary Tom Boyd and Rob Berube April 3, 2021 x Umiat Weather: Temp -35, Wind E/10 x HSSE: No Injuries, No Spills, No Incidents. Animal Tracks observed. No interactions with wildlife. No wildlife observations. Duck Ponds below all equipment Working day tours only with travel/support from Merlin-#1. Hot Work Permit for welding activities x Travel to Umiat #23H. PJSM for cutting tree from Umiat #23H x Cut window through Conductor, Casing and Tubing. Encountered Water and Mineral Oil while cutting surface casing string x Remove Wellhead with Conductor/Casing Stub. BLM Inspector Quinn Sawyer present on location. x Found Cement Top in tubing down 12', found Cement Top in tubing/casing annulus down 24'. x Mix and top off wellhead stub with 8.5 cu/yds of concrete x Continue to remove equipment from Umiat project and bring to Merlin location x Shut down for night UMIAT #23H Cut Window in Conductor/Casing UMIAT #23H Removal of Wellhead Umiat #23H P&A Emerald House Daily Operational Summary Tom Boyd and Rob Berube April 4, 2021 x Umiat Weather: Temp -13, Wind NE/21 x HSSE: No Injuries, No Spills, No Incidents. Animal Tracks observed. No interactions with wildlife. No wildlife observed. Duck Ponds below all equipment Working day tours only with travel/support from Merlin-#1 x PJSM for welding on abandonment marker plate and removing cellar for Umiat #23H. x BLM (Quinn Sawyer) observed hard cement at surface and struck cement top with steel bar. x Weld on Abandonment Plate (leave weep-hole as per BLM regulations) x Pull cellar. BLM confirm that stub is 3' below ground level x Fill cellar hole with Gravel x Remove all debris and equipment from location x Return to Merlin #1 UMIAT #23H Cement Top Struck by Iron Bar UMIAT #23H Abandonment Plate UMIAT #23H Cellar Removal UMIAT #23H 3' Below Ground UMIAT #23H Cellar filled with Gravel UMIAT #23H Final Survey Location Clean Cementing Program Page 1 JOB PROGRAM FO-GL-HAL-CMT-0200 REV2 Customer Name: Emerald House Customer Representative: Tom Boyd Halliburton Representative: Savannah Afoa Date: 03/26/2021 Well Name: Umiat 23H Job: Plug to Abandon Rig: Fullbore Country/District: USA/Alaska VIDA ID: H032373 All information in this report is provided subject to the terms and conditions which govern the services provided by Halliburton. Halliburton personnel use their best efforts in gathering information and their best judgment in interpreting it, but any interpretation, research, analysis or recommendation furnished by Halliburton are opinions based upon inferences from measurements and empirical relationships and assumptions, which inferences and empirical relationships and assumptions are not infallible, and with respect to which professionals in the industry may differ. Accordingly, HALLIBURTON IS UNABLE TO GUARANTEE THE ACCURACY OF ANY CHART INTERPRETATION, RESEARCH ANALYSIS, OR JOB RECOMMENDATION and any interpretation or recommendation is not for use of or reliance upon by any third party. The customer has full responsibility for any of its decisions which are based on the information provided in this report. Well Name: Umiat 23H Cementing Program Page 2 Wellbore Schematic Proposed schematic. Well Name: Umiat 23H 06/01/2017 Pre Job Cementing Program Pre-Job Pre-Job Check List: 1. Cover all contingencies and lessons learned 2. Ensure equipment needed for the job is job-ready 3. Job calculations are finalized. (review final numbers with Co. Rep and Technical Professional) 4. Lab reports have been received, reviewed and approved 5. Correct volume of bulk cement is scaled and mixed according to lab reports and load sheets. 6. Additional chemicals/equipment to bring to the job: a. QTY (1) 4” wiper ball b. Manifold to pre-load wiper ball c. MMCR for washup Well Name: Umiat 23H Cementing Program Page 4 Engineer’s Pump Schedule Job #1 Objective: Pump 55 bbl of 12 ppg lead cement followed by 66 bbl of 14 ppg tail cement down 3-1/2” Tubing to bullhead into 4-1/2” slotted liner and annulus to plug and abandon any hydrocarbon-bearing zone. The 7-5/8” surface casing was set at 1968’ MD with the 4-1/2” slotted liner top at 1858’. Calculations use a TD of 4,040’ inside 6-3/4” open hole. Drop wiper ball and displace down to top perforation at TBD depth. Calculations from customer are below: Tubing volume: (1,858’ – 1,500’) x .0085 = 3 bbls Annular volume (1,858’ – 1,500’) x .0340 = 21 bbls Open Hole volume: (4,040’ – 1,858’) x .0433 = 97 bbls TOTAL Max Volume: = 121 bbls Event/Stage Amount Rate Requested Density Yield Water Rq. Total Water bbls bpm Quantity ppg ft3/sk gal/sk bbls Start Job ***Pre Pump Iron Inspection. Verify and communicate all valves are lined up to pump*** Fill Lines 5 0.5 5 bbl 8.34 0 0 5 Low Pressure Test *Test eKO's 1500 psi* High Pressure Test 4000 psi *Reset Kick Outs to 3500 psi – max allowable injection pressure = 3750 psi Pump Heated Water Ahead 10 3-5 10 bbl 8.34 - - 10 Mix and Pump Lead Cement w/ 4.7 ppb LCM Pre-Blended 55 3-5 125 sks 12 2.5 14.808 44 Mix and Pump Cement w/ 6.8 ppb LCM Pre-Blended 66 3-5 230 sks 14 1.629 8.2 45 Drop 4” Wiper Ball 5 3-5 5 bbl 8.34 - - 5 Displace TBD 3-8 TBD 8.34 TBD Unsting from float collar and circulate remaining cement and wiper ball to surface Wash-Up w/ MMCR 50 ***Adjust rates as needed for job*** End Job Estimated Job Pump Time TBD Total HAL Water for Job (Not including Wash Up) TBD Well Name: Umiat 23H 06/01/2017 Pre Job Cementing Program Page 5 Engineer’s Pump Schedule Job #2 Objective: Pump 60 bbl of 14 ppg VariCem down 3-1/2” Tubing through tubing punch at ~ 1400’ MD up the 7-5/8” x 3-1/2” annulus. Volume is based on cementing entire tubing and annulus to surface. Event/Stage Amount Rate Requested Density Yield Water Rq. Total Water bbls bpm Quantity ppg ft3/sk gal/sk bbls Start Job ***Pre Pump Iron Inspection. Verify and communicate all valves are lined up to pump*** Fill Lines 5 0.5 5 bbl 8.34 0 0 5 Low Pressure Test *Test eKO's 1500 psi* High Pressure Test 4000 psi *Reset Kick Outs to 3500 psi – max allowable injection pressure = 3750 psi Pump Water Ahead 10 3-5 10 bbl 8.34 - - 10 Mix and Pump Cement w/ 7.2 ppb LCM Pre-Blended 60 3-5 210 sks 14 1.629 8.2 41 Clear lines and tree 5 3-5 5 bbl 8.34 - - 5 Unsting from float collar and circulate remaining cement and wiper ball to surface Wash-Up w/ MMCR 50 ***Adjust rates as needed for job*** End Job Estimated Job Pump Time 1:00 Total HAL Water for Job (Not including Wash Up) 61 Well Name: Umiat 23H Cementing Program Page 6 Risk Assessment Risk Associated with Task Consequences Mitigation Responsible Party Pumping LCM through slotted liner and tubing punches May prematurely bridge off Run PW to ensure LCM will pass restrictions without issue. There is a 15% risk with the 14 ppg cement through the slotted liner, but pressure should mitigate this. If cement plugs the tubing perfs, reverse circulate to clear tubing. Engineer Snow trail to location Limited water transports as well as containment for washup and returns Ensure enough equipment is on location for water and washup/returns Supervisor Well Name: Umiat 23H 05/21/2020 Cementing Program Page 7 Cement Lab Report (PILOT) Lab Results- Plug Technology, Houston - NAL Region Job Information Request/Slurry 2673372/1 Rig Name Date 02/MAR/2021 Submitted By Savannah Afoa Job Type Plug to Abandon Bulk Plant Prudhoe Bay, AK USA Customer Emerald House Location Greater Prudhoe Bay Well Umiat 23H Well Information Casing/Liner Size 3.5 in Depth MD 4040 ft BHST 16°C / 60°F Hole Size Depth TVD 986 ft BHCT 16°C / 60°F Pressure Drilling Fluid Information Mud Supplier Name Mud Trade Name Density 8.3 lbm/gal Cement Information - Plug Design Cement Properties Slurry Density 14 lbm/gal Slurry Yield 1.6 ft3/sack Water Requirement 8.16 gal/sack Total Mix Fluid 8.16 gal/sack Water Source Field (Fresh) Water Water Chloride Slurry Comments 14 ppg pilot testing for Umiat 23H and Umiat 18 Pilot Test Results Request ID 2673372/1 API Fluid Loss, Request Test ID:38038517 04/MAR/2021 Test Temp (degF) Test Pressure (psi) Test Time (min) Meas. Vol. Calculated FL (<30 min) Conditioning time (min) Conditioning Temp (degF) 60 1000 3 44 278 30 60 API Rheology, Request Test ID:38038518 04/MAR/2021 Temp (degF) 300 200 100 60 30 6 3 Cond Time (min) Cond Temp (degF) 60 (up) 108 98 87 80 74 56 22 30 60 60 (down) 108 101 92 88 83 53 40 30 60 60 (avg.) 108 100 90 84 79 55 31 30 60 PV (cP) & YP (lbs/100ft2): 58.58 62.08 (Least-squares method) PV (cP) & YP (lbs/100ft2): 27.75 80.25 (Traditional method (300 & 100 rpm based)) Generalized Herschel-Bulkley 4: YP(lbf/100ft2)=0.01 MuInf(cP)=213.87 m=1 n=0.2 Free Fluid API 10B-2, Request Test ID:38038519 04/MAR/2021 Con. Temp (degF) Cond. Time (min) Static T. (F) Static time (min) Incl. (deg) % Fluid 60 30 60 120 45 0 Well Name: Umiat 23H 05/21/2020 Cementing Program Page 8 No FF, No Settling API Rheology, Request Test ID:38038520 04/MAR/2021 Temp (degF) 300 200 100 60 30 6 3 60 (up) 65 60 49 40 34 23 19 60 (down) 65 58 52 45 40 30 25 60 (avg.) 65 59 51 43 37 27 22 PV (cP) & YP (lbs/100ft2): 40.12 31.75 (Least-squares method) PV (cP) & YP (lbs/100ft2): 21.75 43.25 (Traditional method (300 & 100 rpm based)) Generalized Herschel-Bulkley 4: YP(lbf/100ft2)=7 MuInf(cP)=17.92 m=1 n=0.28 Mixability (0 - 5) - 0 is not mixable, Request Test ID:38038521 04/MAR/2021 Mixability rating (0 - 5) Avg rpm mixing under load (~12,000) Blend addition time (sec) @ 4,000 RPM 4 12000 0 Well Name: Umiat 23H 05/21/2020 Cementing Program Page 9 Thickening Time - ON-OFF-ON, Request Test ID:38038514 04/MAR/2021 Test Temp (degF) Reached in (min) 70 Bc (hh:min) Start Bc Stirring before stop (mins) Static Period (min) 60 15 4:32 9 45 15 Well Name: Umiat 23H 05/21/2020 Cementing Program Page 10 UCA Comp. Strength, Request Test ID:38038515 09/MAR/2021 End Temp (degF) Pressure (psi) 50 psi (hh:mm) 100 psi (hh:mm) 500 psi (hh:mm) 1000 psi(hh:mm) 8hr CS (psi) 12 hr CS (psi) 16 hr CS (psi) 24 hr CS (psi) 48 hr CS (psi) End CS (psi) 60 3000 9:43 11:48 20:31 33:46 20 104 264 651 1374 1369 Well Name: Umiat 23H 05/21/2020 Cementing Program Page 11 UCA Comp. Strength, Request Test ID:38038516 10/MAR/2021 End Temp (degF) Pressure (psi) 50 psi (hh:mm) 100 psi (hh:mm) 500 psi (hh:mm) 1000 psi(hh:mm ) 8hr CS (psi) 12 hr CS (psi) 16 hr CS (psi) 24 hr CS (psi) 48 hr CS (psi) 72 hr CS (psi) End CS (psi) 49 3000 14:44 18:00 34:12 61:31 0 21 65 229 766 1131 1146 49 degrees was as cold as we could get Emerald House Alaska District, Alaska For: Tom Boyd Date: Monday, March 29, 2021 Umiat 23 Plug to Abandon SO#907052087 Job Date: Sunday, March 28, 2021 Sincerely, Jared Miller Legal Notice Disclaimer: All information in this report is provided subject to the term s and conditions which govern the services provided by Halliburton. Halliburton personnel use their best efforts in gathering information and their best judgment in interpreting it, but any interpretation, r esearch, analysis or recommendation furnished by Halliburton are opinions based upon inferences from measurements and empirical relation ships and assumptions, which inferences and empirical relationships and assumptions are not infallible, and with respect to which pro fessionals in the industry may differ. iCem 3D Displacement results are used to understand how fluids intermix during a cement job. Simu lation and 3D displacement results are not intended as and should not be used as a replacement for bond logs in determining top of cement. Current 3D model calculations are known to model more volume than the input volume for standard cases due to known calculation improvements required. For rotational cases, the modeled volume will be impacted by the same calculations impacting the standard cases, as w ell as additional constraints imposed to make the calculation time required operationally feasible. Therefore, until further notice, 3D displacement results should not be used for replacement of a bond log, or used as an identifier of top of cement. HALLIBURTON IS UNABLE TO GUARANTEE THE ACCURACY OF ANY CHART INTERPRETATION, RESEARCH ANALYSIS, OR JOB RECOMMENDATION and any interpretation or recommendation is not for use of or reliance upon by any third party. The customer has full responsibility for any of its d ecisions which are based on the information provided in this report. © 2019 Halliburton. All rights reserved. Customer: Emerald House Job: Umiat 23 Plug to Abandon SO#907052087 Page 3 (v. 5.1.101.0) Created: Monday, March 29, 2021 Table of Contents 1.0 Real-Time Job Summary .............................................................................................................................. 4 1.1 Job Event Log ................................................................................................................................................................................................................................ 4 2.0 Attachments ................................................................................................................................................. 7 2.1 Umiat 23 - LVT Injection Testing and Pressure Testing.png .......................................................................................................................................................... 7 2.2 Umiat 23 - Pressure Test.png ........................................................................................................................................................................................................ 9 2.3 Umiat 23 - Pressure Test with Variables.png .............................................................................................................................................................................. 10 2.4 Umiat 23 - LVT Inj. Testing and Pressure Test with Variables.png .............................................................................................................................................. 11 2.5 Umiat 23 - Plug 1 Cement Job.png .............................................................................................................................................................................................. 12 2.6 Umiat 23 - Plug 1 Cement Job with Variables.png ...................................................................................................................................................................... 13 Customer: Emerald House Job: Umiat 23 Plug to Abandon SO#907052087 Page 4 (v. 5.1.101.0) Created: Monday, March 29, 2021 1.0 Real-Time Job Summary 1.1 Job Event Log Seq. No. Activity Graph Label Date Time Pressure Recirc Density Pump Rate Volume Comments (psi) (ppg) (bbl/min) (bbl) 1 Depart from Service Center or Other Site Depart from Merlin 1 to Umiat 23 3/27/2021 07:30:00 2 Arrive At Loc Arrive at Umiat 23 3/27/2021 09:00:00 3 Rig-up Lines Rig-up and Spot Equipment 3/27/2021 09:30:00 4 Safety Pre Job Safety Meeting 3/27/2021 13:30:00 -45.41 0.00 0.00 0.00 5 Pump Spacer 1 Pump LVT Down Into Tubing 3/27/2021 14:00:38 -30.91 0.00 0.00 0.01 Pump 5.6 bbl LVT into Tubing 6 Pump Spacer 1 Pump LVT into IA 3/27/2021 14:12:14 0.10 0.00 0.00 4.06 Pump 1.4 bbl into IA 7 Test Lines Low Pressure Test 3/27/2021 14:19:00 723.22 0.00 0.00 5.01 8 Test Lines High Pressure Test 3/27/2021 14:23:06 2247.74 0.00 0.00 5.01 9 Pump Spacer 1 Pump LVT into Tubing 3/27/2021 14:28:59 -27.10 0.00 0.00 5.01 Pump 5 bbl into Tubing. Total LVT pumped into Tubing 10.6 bbl. 10 Pump Spacer 1 Pump LVT Down Down IA 3/27/2021 14:36:58 -22.86 0.00 0.00 9.78 Pump 22 bbl LVT down IA. Total pumped down IA 23.4 bbl. 11 Depart Location Depart Umiat 23 for Merlin 1 3/27/2021 17:30:00 12 Arrive at Next Location/Parking Area from Job Arrive at Merlin 1 from Umiat 23 3/27/2021 21:30:00 Pisten Bully used for transporting personnel broke down. Had to wait until alternator arrived and replaced before departing to Merlin 1. 13 Call Out Call Out 3/27/2021 22:00:00 Requested on location time: 09:30 14 Depart Shop for Location Depart Merlin 1 for Umiat 23 3/28/2021 08:00:00 15 Arrive at Location from Service Center Arrive at Umiat 23 3/28/2021 09:30:00 Requested time On Location (HH:MM) : 9:30 Customer: Emerald House Job: Umiat 23 Plug to Abandon SO#907052087 Page 5 (v. 5.1.101.0) Created: Monday, March 29, 2021 Equipment : Cementing Unit - Bush House, Iron Connex, Power Connex 1 Herc Skid - 3018I, 3018B Personnel: 1 Service Leader - Jared Miller 1 Operator - Dalton James 1 Operator Assistant - Chan Poonian 16 Pre-Rig Up Safety Meeting Pre-Rig Up Safety Meeting 3/28/2021 09:45:00 17 Rig-Up Equipment Rig-Up Equipment 3/28/2021 09:50:00 18 Rig-Up Completed Rig-Up Completed 3/28/2021 11:45:00 19 Pre-Job Safety Meeting Pre-Job Safety Meeting 3/28/2021 13:30:00 Assumed Open Hole OD (in): 6.75 TD (ft): 4100 Top of Assumed Open Hole (ft): 1858 Tubing Diameter (in): 3.5 OD / 2.992" ID Tubing Depth (ft): 1858 Perforation Depth (ft): 1448' to 1451' Previous Casing Depth (ft): 1858' Previous Casing ID (in): 6.875" 20 Pump Spacer Pump Diesel Ahead to Verify Injection 3/28/2021 13:47:56 60.61 0.00 0.00 0.00 Fluid Type: Diesel Total Volume Pumped (bbl): 2.1 21 Other Water Analysis 3/28/2021 14:27:00 74.79 0.00 0.00 0.00 Water Temp (degrees F): 69 pH: 7 Chlorides (ppm): <250 Alkalinity (ppm): 180 Hardness (ppm): 250 Iron (ppm): 0 22 Start Job Start Job 3/28/2021 14:46:17 58.42 7.89 0.00 0.03 23 Mix Cement Mix Cement 3/28/2021 14:56:06 -35.63 8.89 0.00 2.05 Issues with mud balance plugging off with LCM. Rebuilt mud balance with new seals. 24 Pump Lead Cement Pump Lead Cement 3/28/2021 15:42:35 90.89 11.86 0.30 2.08 Sacks Loaded (sk): 125 Total Volume (bbl): 55 Customer: Emerald House Job: Umiat 23 Plug to Abandon SO#907052087 Page 6 (v. 5.1.101.0) Created: Monday, March 29, 2021 Density (lb/gal): 12.0 Yield (cuft/sk): 2.5 Water Req. (gal/sk): 14.808 25 Pump Tail Cement Pump Tail Cement 3/28/2021 16:13:34 507.64 13.88 2.64 65.45 Sacks Loaded (sk): 230 Total Volume (bbl): 66 Density (lb/gal): 14.0 Yield (cuft/sk): 1.629 Water Req. (gal/sk): 8.2 26 Pump Water Pump Water Behind 3/28/2021 16:47:28 44.62 -0.37 0.00 123.99 Total Volume (bbl): 1 Pump 1 bbl Water to clear cement from lines to pump diesel displacement 27 Drop Bottom Plug Launch Wiper Ball 3/28/2021 16:50:11 448.73 8.00 0.00 124.56 Fluid Pumped: Diesel Volume Puimped (bbl): 12 28 Pre-Rig Down Safety Meeting Pre-Rig Down Safety Meeting 3/28/2021 17:00:00 203.83 7.77 0.95 132.87 29 Shutdown Shutdown 3/28/2021 17:05:39 463.75 7.85 0.63 136.56 30 Rig-Down Equipment Rig-Down Equipment 3/28/2021 17:14:43 247.54 7.94 0.00 136.57 31 Rig-Down Completed Rig-Down Completed 3/28/2021 19:30:00 32 Depart Location for Service Center or Other Site Depart Location for Merlin 1 3/28/2021 19:45:00 33 Other Materials Used on Job 3/28/2021 21:35:00 2 Bags Citric Acid 4" Wiper Ball 34 Other Thank You For Using Halliburton Cement! 3/28/2021 21:40:00 Customer: Emerald House Job: Umiat 23 Plug to Abandon SO#907052087 Page 7 (v. 5.1.101.0) Created: Monday, March 29, 2021 2.0 Attachments 2.1 Umiat 23 - LVT Injection Testing and Pressure Testing.png Customer: Emerald House Job: Umiat 23 Plug to Abandon SO#907052087 Page 8 (v. 5.1.101.0) Created: Monday, March 29, 2021 Customer: Emerald House Job: Umiat 23 Plug to Abandon SO#907052087 Page 9 (v. 5.1.101.0) Created: Monday, March 29, 2021 2.2 Umiat 23 - Pressure Test.png Customer: Emerald House Job: Umiat 23 Plug to Abandon SO#907052087 Page 10 (v. 5.1.101.0) Created: Monday, March 29, 2021 2.3 Umiat 23 - Pressure Test with Variables.png Customer: Emerald House Job: Umiat 23 Plug to Abandon SO#907052087 Page 11 (v. 5.1.101.0) Created: Monday, March 29, 2021 2.4 Umiat 23 - LVT Inj. Testing and Pressure Test with Variables.png Customer: Emerald House Job: Umiat 23 Plug to Abandon SO#907052087 Page 12 (v. 5.1.101.0) Created: Monday, March 29, 2021 2.5 Umiat 23 - Plug 1 Cement Job.png Customer: Emerald House Job: Umiat 23 Plug to Abandon SO#907052087 Page 13 (v. 5.1.101.0) Created: Monday, March 29, 2021 2.6 Umiat 23 - Plug 1 Cement Job with Variables.png Customer: Emerald House Job: Umiat 23 Plug to Abandon SO#907052087 Page 14 (v. 5.1.101.0) Created: Monday, March 29, 2021 Emerald House Alaska District, Alaska For: Tom Boyd Date: Friday, April 02, 2021 Umiat 23 Plug to Abandon Plug 2 SO#0907035993 Job Date: Wednesday, March 31, 2021 Sincerely, Jared Miller Legal Notice Disclaimer: All information in this report is provided subject to the term s and conditions which govern the services provided by Halliburton. Halliburton personnel use their best efforts in gathering information and their best judgment in interpreting it, but any interpretation, research, analysis or recommendation furnished by Halliburton are opinions based upon inferences from measurements and empirical relationships and assumptions, which inferences and empirical relationships and assumptions are not infallible, and with respect to which pro fessionals in the industry may differ. iCem 3D Displacement results are used to understand how fluids intermix during a cement job. Simu lation and 3D displacement results are not intended as and should not be used as a replacement for bond logs in determining top of cement. Current 3D model calculations are known to model more volume than the input volume for standard cases due to known calculation improvements required. For rotational cases, the modeled volume will be impacted by the same calculations impacting the standard cases, as w ell as additional constraints imposed to make the calculation time required operationally feasible. Therefore, until further notice, 3D displacement results should not be used for replacement of a bond log, or used as an identifier of top of cement. HALLIBURTON IS UNABLE TO GUARANTEE THE ACCURACY OF ANY CHART INTERPRETATION, RESEARCH ANALYSIS, OR JOB RECOMMENDATION and any interpretation or recommendation is not for use of or reliance upon by any third party. The customer has full responsibility for any of its d ecisions which are based on the information provided in this report. © 2019 Halliburton. All rights reserved. Customer: Emerald House Job: Umiat 23 Plug to Abandon Plug 2 SO#0907035993 Page 3 (v. 5.1.101.0) Created: Friday, April 02, 2021 Table of Contents 1.0 Real-Time Job Summary .............................................................................................................................. 4 1.1 Job Event Log ................................................................................................................................................................................................................................ 4 2.0 Attachments ................................................................................................................................................. 6 2.1 Umiat 23 - Plug 2 - Entire Job Graph with Variables.png .............................................................................................................................................................. 6 2.2 Umiat 23 - Plug to Abandon Plug 2 - Job Graph.png ..................................................................................................................................................................... 8 Customer: Emerald House Job: Umiat 23 Plug to Abandon Plug 2 SO#0907035993 Page 4 (v. 5.1.101.0) Created: Friday, April 02, 2021 1.0 Real-Time Job Summary 1.1 Job Event Log Seq. No. Activity Graph Label Date Time Pressure Recirc Density Pump Rate Volume Comments (psi) (ppg) (bbl/min) (bbl) 1 Call Out Call Out 3/30/2021 21:30:00 Requested on location time: 8:30 2 Depart Shop for Location Depart Merlin 1 for Umiat 23 3/31/2021 07:30:00 3 Arrive at Location from Service Center Arrive at Location from Service Center 3/31/2021 08:30:00 Requested time On Location (HH:MM) : 8:30 Equipment : Cementing Unit - Bush House, Power Connex, Iron Connex, 1 Herc Pod - 3018 A and 3018 H Personnel: Service Leader - Jared Miller Service Operator - Dalton James Operator Assistant - Chan Poonian 4 Pre-Job Safety Meeting Pre-Job Safety Meeting 3/31/2021 16:00:00 44.38 0.00 0.00 0.00 Tubing OD (in): 3.5 Tubing ID (in): 2.992 Perforation Depth (ft): 700 Pipe Diameter (in): 7.625 Pipe Weight (lb/ft): 29 Pipe Grade: L-80 5 Pump Water Start Job 3/31/2021 16:13:33 -10.97 0.00 0.00 0.01 6 Other Water Analysis 3/31/2021 16:30:00 -6.04 14.08 0.00 0.00 Water Temp (degrees F): 60 pH: 7 Chlorides (ppm): <250 Alkalinity (ppm): 150 Hardness (ppm): 180 Iron (ppm): 0 7 Pump Spacer Pump Water Ahead 3/31/2021 16:46:00 -162.44 14.03 0.00 0.00 Fluid Type: Water Total Volume Pumped (bbl): 5 8 Pump Water Pump Water Ahead 3/31/2021 16:46:22 307.80 14.02 0.00 0.00 9 Pump Lead Cement Pump Lead Cement 3/31/2021 16:50:00 397.12 14.02 1.52 4.50 Sacks Loaded (sk): 350 Customer: Emerald House Job: Umiat 23 Plug to Abandon Plug 2 SO#0907035993 Page 5 (v. 5.1.101.0) Created: Friday, April 02, 2021 Total Volume (bbl): 102 Calculated Volume for IA and Tubing (bbl): 29.16 Total Volume Pumped (bbl): 40 (Pumped the remainder of cement in mix tub and steady flow) Density (lb/gal): 14.0 Yield (cuft/sk): 1.629 Water Req. (gal/sk): 8.2 10 Pump Cement Pump Cement 3/31/2021 16:50:30 466.96 14.03 1.48 0.04 14# CMT 11 Start Squeeze Start Squeeze - Cement to Surface - Close in IA 3/31/2021 17:17:25 437.61 13.93 1.02 29.16 12 Shutdown Shutdown 3/31/2021 17:19:38 1437.88 13.87 0.00 29.66 13 Start Squeeze Start Squeeze 3/31/2021 17:22:17 1318.31 13.94 0.00 29.66 14 Shutdown Shutdown 3/31/2021 17:22:49 1614.54 13.93 0.00 29.76 15 Pump Cement Pump Cement 3/31/2021 17:23:58 1018.81 13.92 0.07 29.76 16 Pump Water - Start Pump Water - Behind 3/31/2021 17:31:13 535.08 0.24 1.39 39.24 Operator opened valves to wrong displacement tank and wasn't actually pumping water. 17 Pump Water Pump Water Behind 3/31/2021 17:32:55 329.96 2.75 1.32 41.78 Total Volume (bbl): 1 18 Shut In Well End Job - Shut In Well 3/31/2021 17:33:16 295.46 0.24 0.00 42.16 19 Rig-Down Equipment Rig-Down Equipment 3/31/2021 17:45:00 20 Rig-Down Completed Rig-Down Completed 3/31/2021 20:45:00 21 Depart Location for Service Center or Other Site Depart Umiat 23 for Merlin 1 3/31/2021 21:00:00 22 Other Materials Used on Job 3/31/2021 21:30:00 Citric Acid - 10 bags (500 lb) MMCR - 5 Gallons 23 Other Thank You For Using Halliburton Cement! 3/31/2021 21:35:00 Customer: Emerald House Job: Umiat 23 Plug to Abandon Plug 2 SO#0907035993 Page 6 (v. 5.1.101.0) Created: Friday, April 02, 2021 2.0 Attachments 2.1 Umiat 23 - Plug 2 - Entire Job Graph with Variables.png Customer: Emerald House Job: Umiat 23 Plug to Abandon Plug 2 SO#0907035993 Page 7 (v. 5.1.101.0) Created: Friday, April 02, 2021 Customer: Emerald House Job: Umiat 23 Plug to Abandon Plug 2 SO#0907035993 Page 8 (v. 5.1.101.0) Created: Friday, April 02, 2021 2.2 Umiat 23 - Plug to Abandon Plug 2 - Job Graph.png Customer: Emerald House Job: Umiat 23 Plug to Abandon Plug 2 SO#0907035993 Page 9 (v. 5.1.101.0) Created: Friday, April 02, 2021 Emerald House For: Tom Boyd Date: Tuesday, March 30, 2021 Umiat 23 IA Pressure Test SO# 0907035993 Job Date: Tuesday, March 30, 2021 Sincerely, Jared Miller Legal Notice Disclaimer: All information in this report is provided subject to the term s and conditions which govern the services provided by Halliburton. Halliburton personnel use their best efforts in gathering information and their best judgment in interpreting it, but any interpretation, research, analysis or recommendation furnished by Halliburton are opinions based upon inferences from measurements and empirical relationships and assumptions, which inferences and empirical relationships and assumptions are not infallible, and with respect to which pro fessionals in the industry may differ. iCem 3D Displacement results are used to understand how fluids intermix during a cement job. Simu lation and 3D displacement results are not intended as and should not be used as a replacement for bond logs in determining top of cement. Current 3D model calculations are known to model more volume than the input volume for standard cases due to known calculation improvements required. For rotational cases, the modeled volume will be impacted by the same calculations impacting the standard cases, as well as additional constraints imposed to make the calculation time required operationally feasible. Therefore, until further notice, 3D displacement results should not be used for replacement of a bond log, or used as an identifier of top of cement. HALLIBURTON IS UNABLE TO GUARANTEE THE ACCURACY OF ANY CHART INTERPRETATION, RESEARCH ANALYSIS, OR JOB RECOMMENDATION and any interpretation or recommendation is not for use of or reliance upon by any third party. The customer has full responsibility for any of its d ecisions which are based on the information provided in this report. © 2019 Halliburton. All rights reserved. Customer: ACCUMULATE ENERGY Job: Umiat 23 IA Pressure Test SO# 0907035993 Page 3 (v. 5.1.101.0) Created: Tuesday, March 30, 2021 Table of Contents 1.0 Real-Time Job Summary .............................................................................................................................. 4 1.1 Job Event Log ................................................................................................................................................................................................................................ 4 2.0 Attachments ................................................................................................................................................. 5 2.1 Umiat 23 - IA Pressure Testi - 3.30.2021.png ................................................................................................................................................................................ 5 2.2 Umiat 23 - IA Pressure Test - 3.30.2021.png ................................................................................................................................................................................. 7 2.3 Umiat 23 - Verifying Pressure Drop in Tubing After Perf.png ....................................................................................................................................................... 8 2.4 Umiat 23 - Verifying Pressure Drop After Perforations.png .......................................................................................................................................................... 9 Customer: ACCUMULATE ENERGY Job: Umiat 23 IA Pressure Test SO# 0907035993 Page 4 (v. 5.1.101.0) Created: Tuesday, March 30, 2021 1.0 Real-Time Job Summary 1.1 Job Event Log Seq. No. Activity Graph Label Date Time Pressure Comments (psi) 1 Record Pressure Pressure Test 3/30/2021 16:19:26 1547.64 2 Record Pressure Record Pressure 3/30/2021 16:23:05 1313.19 3 Record Pressure Record Pressure 3/30/2021 16:24:05 1604.78 4 Record Pressure Record Pressure 3/30/2021 16:29:42 1431.48 5 Record Pressure Record Pressure 3/30/2021 16:30:29 1593.75 6 Record Pressure Record Pressure 3/30/2021 16:43:39 1409.56 7 Record Pressure Record Pressure 3/30/2021 16:44:36 1620.58 8 Record Pressure Record Pressure 3/30/2021 16:54:18 1422.28 9 Record Pressure Record Pressure 3/30/2021 16:55:18 1610.61 10 Record Pressure Record Pressure 3/30/2021 17:28:01 1333.17 11 End Job End Job 3/30/2021 17:29:37 -2.87 12 Pressure Down Tubing Pressure Down Tubing - Applyh 500 psi to Tubing 3/30/2021 18:21:30 1010.06 Apply 500 psi to tubing. Wireline shoots perfs, confim pressure bleed from tubing into IA. 13 Record Pressure Record Pressure - Conformation of Pressure Drop After Perf's 3/30/2021 18:22:38 165.26 Customer: ACCUMULATE ENERGY Job: Umiat 23 IA Pressure Test SO# 0907035993 Page 5 (v. 5.1.101.0) Created: Tuesday, March 30, 2021 2.0 Attachments 2.1 Umiat 23 - IA Pressure Testi - 3.30.2021.png Customer: ACCUMULATE ENERGY Job: Umiat 23 IA Pressure Test SO# 0907035993 Page 6 (v. 5.1.101.0) Created: Tuesday, March 30, 2021 Customer: ACCUMULATE ENERGY Job: Umiat 23 IA Pressure Test SO# 0907035993 Page 7 (v. 5.1.101.0) Created: Tuesday, March 30, 2021 2.2 Umiat 23 - IA Pressure Test - 3.30.2021.png Customer: ACCUMULATE ENERGY Job: Umiat 23 IA Pressure Test SO# 0907035993 Page 8 (v. 5.1.101.0) Created: Tuesday, March 30, 2021 2.3 Umiat 23 - Verifying Pressure Drop in Tubing After Perf.png Customer: ACCUMULATE ENERGY Job: Umiat 23 IA Pressure Test SO# 0907035993 Page 9 (v. 5.1.101.0) Created: Tuesday, March 30, 2021 2.4 Umiat 23 - Verifying Pressure Drop After Perforations.png Emerald House For: Tom Boyd Date: Tuesday, March 30, 2021 Umiat 23 Pressure Test / SO#907035993 Job Date: Tuesday, March 30, 2021 Sincerely, Jared Miller Legal Notice Disclaimer: All information in this report is provided subject to the term s and conditions which govern the services provided by Halliburton. Halliburton personnel use their best efforts in gathering information and their best judgment in interpreting it, but any interpretation, research, analysis or recommendation furnished by Halliburton are opinions based upon inferences from measurements and empirical relationships and assumptions, which inferences and empirical relationships and assumptions are not infallible, and with respect to which professionals in the industry may differ. iCem 3D Displacement results are used to understand how fluids intermix during a cement job. Simu lation and 3D displacement results are not intended as and should not be used as a replacement for bond logs in determining top of cement. Current 3D model calculations are known to model more volume than the input volume for standard cases due to known calculation improvements required. For rotational cases, the modeled volume will be impacted by the same calculations impacting the standard cases, as well as additional constraints imposed to make the calculation time required operationally feasible. Therefore, until further notice, 3D displacement results should not be used for replacement of a bond log, or used as an identifier of top of cement. HALLIBURTON IS UNABLE TO GUARANTEE THE ACCURACY OF ANY CHART INTERPRETATION, RESEARCH ANALYSIS, OR JOB RECOMMENDATION and any interpretation or recommendation is not for use of or reliance upon by any third party. The customer has full responsibility for any of its d ecisions which are based on the information provided in this report. © 2019 Halliburton. All rights reserved. Customer: Emerald House Job: Umiat 23 Pressure Test / SO#907035993 Page 3 (v. 5.1.101.0) Created: Tuesday, March 30, 2021 Table of Contents 1.0 Real-Time Job Summary .............................................................................................................................. 4 1.1 Job Event Log ................................................................................................................................................................................................................................ 4 2.0 Attachments ................................................................................................................................................. 5 2.1 Umiat 23 All Pressure Testing with Variables.png ......................................................................................................................................................................... 5 2.2 Tubing Pressure Test.png .............................................................................................................................................................................................................. 6 2.3 IA Pressure Testing.png ................................................................................................................................................................................................................ 7 Customer: Emerald House Job: Umiat 23 Pressure Test / SO#907035993 Page 4 (v. 5.1.101.0) Created: Tuesday, March 30, 2021 1.0 Real-Time Job Summary 1.1 Job Event Log Type Seq. No. Activity Graph Label Date Time Source Pressure 1 Pump A Rate Comments (psi) (bbl/min) Event 1 Pressure Up Tubing Pressure Up Tubing - Start 3/29/2021 22:18:47 USER 74.16 0.48 Event 2 Pressure Up Tubing 30 min Tubing Pressure Test - Begin 3/29/2021 23:42:47 USER 1726.89 0.44 Begin 30 min Pressure Test for AOGCC / Begin 15 min Pressure Test for BLM Event 3 Pressure Test 15 min Pressure Test for BLM - End 3/29/2021 23:57:47 USER 1680.22 0.00 End of Tubing Pressure Test for BLM Event 4 Pressure Test 30 min Tubing Pressure Test - End 3/30/2021 00:12:47 USER 1684.09 0.00 End of 30 min Pressure Test for AOGCC. Event 5 Pressure Test Attempt to Pressure Test - IA 3/30/2021 00:40:17 USER 61.84 0.00 Possible Ice Plug in Manifold - put heater on manifold to see if pressure drops off Event 6 Pressure Up Annulus Attempt to Pressure Up Annulus 3/30/2021 01:10:35 USER -8.30 0.15 Trying to locate ice plug in manifold. Apply heat to free ice plug. Event 7 Pressure Test Pressure Test IA - Begin 3/30/2021 01:58:59 USER 8.02 1.15 Ice Plug Free in Manifold Able to Pump Into IA. Event 8 Pressure Test Pressure Test 3/30/2021 02:43:01 USER 1830.56 0.00 Event 9 Pressure Test IA Pressure Test for BLM - Begin 3/30/2021 03:07:10 USER 1061.59 0.00 Event 10 Pressure Test Pressure Test 3/30/2021 03:12:10 USER 1006.58 0.00 Event 11 Pressure Test IA Pressure Test for BLM - End 3/30/2021 03:17:10 USER 966.39 0.00 Event 12 Pressure Test Pressure Test for AOGCC - Begin 3/30/2021 03:45:42 USER 1784.31 0.00 Event 13 Pressure Test Pressure Test for AOGCC - End 3/30/2021 04:01:07 USER 1410.19 0.00 Customer: Emerald House Job: Umiat 23 Pressure Test / SO#907035993 Page 5 (v. 5.1.101.0) Created: Tuesday, March 30, 2021 2.0 Attachments 2.1 Umiat 23 All Pressure Testing with Variables.png Customer: Emerald House Job: Umiat 23 Pressure Test / SO#907035993 Page 6 (v. 5.1.101.0) Created: Tuesday, March 30, 2021 2.2 Tubing Pressure Test.png Customer: Emerald House Job: Umiat 23 Pressure Test / SO#907035993 Page 7 (v. 5.1.101.0) Created: Tuesday, March 30, 2021 2.3 IA Pressure Testing.png U.mv -z3�+ Regg, James B (CED) Pr)-�N 2-1302-c)c) From: Sawyer, Quinn M <gsawyer@blm.gov> Sent: Sunday, April 4, 20214:14 PM ( 7 To: Regg, James B (CED); Jones, Jeffery B (CED) Cc: McLellan, Bryan J (CED) Subject: Umiat 23H P+A Attachments: IMG_6502jpg; IMG_6504jpg; IMG 6513 jpg; IMG_6488jpg Jeff/Jim, Emerald House finished their P+A job on Umiat 23H today. As requested I measured their cutoff location which was 3' below tundra level. After cut-off I measured the depth from cut-off to cement top as follows: in tubing 12', in IA 24', and in OA 2'. The cement was topped up and left with heat applied for the evening. This morning I checked the hardness of the cement by pounding it with a pry bar. It was hard across the entire surface. The surface casing and tubing were cut slightly below the conductor casing, so you cannot see the separate annuli once the cement was topped off. The marker plate that was welded on is 3/8" thick and contains all required information, as you can verify from the attached photo. Currently the cellar is being backfilled and mounded with gravel. Please feel free to contact me if you have any questions or concerns. Quinn Sawyer BLM Inspector (907) 312-6201 2021-0404 Surface Abandonment — Umiat 23H BLM photos—Email Page 2 of 2 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6.API Number: 7.If perforating:8.W ell 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): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): Casing Collapse Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.W ell Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15.W ell 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: Contact Phone: Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: Perforation Depth MD (ft): TVD BurstMDLength Size Perforation Depth TVD (ft): Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): approval: Notify Commission so that a representative may witness Sundry Number: BOP Test Mechanical Integrity Test Location Clearance ection MIT Req'd? Yes No ption Required? Yes No Subsequent Form Required: COMMISSION USE ONLY Contact Name: Contact Email: Contact Phone: Date: e: certify that the foregoing is true and the procedure approved herein will not rom without prior written approval. gnature: me: Date for 15.W ell Status after proposed work: Operations:OIL WINJ WDSPL Suspended proval:Date:GAS WAG GSTOR SPLUG Representative:GINJ Op Shutdown Abandoned nts: Proposal Summary Wellbore schematic13.W ell Class after proposed work: ations Program BOP Sketch Exploratory Stratigraphic Development Service SSSV Type:Packers and SSSV MD (ft) and TVD (ft): pth MD (ft):Perforation Depth TVD (ft):Tubing Size:Tubing Grade:Tubing MD (ft): quest: Abandon Plug Perforations Fracture Stimulate Reppair Well Operations shutdown Suspend Perforate Other Stimulate Pulll Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: er Casing ___________________ ame:4.Current Well Class:5.Permit to Drill Number: Exploratory Development Stratigraphic Service 6. API Number: g:8.W ell Name and Number: ation or Conservation Order governs well spacing in this pool? perforations require a spacing exception?Yes No esignation (Lease Number):10. Field/Pool(s): D (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): g CollapseTVDBurstMDLengthSize PRESENT WELL CONDITION SUMMARY Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 7:38 pm, Mar 07, 2021 321-113 Emeral House LLC. P.O. Box 112212 Ancgorage AK 99511 213-020 50-287-20029-00 N/A Umiat #23H AA-084141 Umiat Unit AA95544 4,100 1,960 4,100 1,960 0 Conductor 91 13-3/8 91 91 5,020 2,260 Surface 1,968 7-5/8 1,968 1,260 6,890 4,790 Production 2182 4-1/2 4,040 1,986 N/A N/A N/A Slotted Liner N/A 3-1/2"L-80 1,858 Baker ZXP Liner Top Packer 1,858' MD, 1,260' TVD 03/15/2021 Erik Opstad Vice President Erik A. Opstad Digitally signed by Erik A. Opstad Date: 2021.03.07 12:07:18 -09'00'3-7-2021 Tom Boyd TABoydUSA@gmail.com 713-202-5078 ✔ ✔ ✔ ✔✔ ✔ ✔ -00 DLB DSR-3/8/21 X 983' DLB AOGCC Site Inspection in Fall of 2021. X X Anchorage DLB 10-407 983' DLB DLB 03/08/2021 X Notify BLM and AOGCC BJM 3/11/21 Photo document as described Cementing program to be approved by AOGCC before commencing cementing operations. Submit daily reports to AOGCC once operations commence. Comm q 3/15/21 dts 3/15/2021 JLC 3/15/2021 RBDMS HEW 3/16/2021 Emerald House, LLC P.O. Box 112212, Anchorage, Alaska 99511-2212 +1 907-244-5210 | +1 907-602-8937 UMIAT #23H PLUG AND ABANDONMENT CURRENT STATUS: Well Temporarily Abandoned, Operations Suspended 3/15/2014 x Wellbore filled with 6.8 ppg, LVT-200 Mineral Oil x 4” BPV set in Tubing Hanger x Tree filled with Diesel and tested to 1,500 psi x 0 psi observed with gauges on Tree and OA x Tree Valve Handles Removed x Tree Draped with Herculite (As per BLM) WELL IDENTIFICATION: x Well: Umiat 23H x API No: 50-287-20029-00 x PTD – 213-020 x Lease: AA-084141 (BLM) x North Slope, Alaska WELL DATA: Drill Floor to Sea Level 596' Drill Floor to Ground Level 21' Ground Level to SL 575' Well Depth: 4,100’ MD, 986’ TVD PBTD: 1,858’ MD, 1,260’ TVD Baker ZXP Liner Top Packer (Slotted Liner) MPSP: Maximum Potential Surface Pressure = 0 psi (see Mud Wt Chart) WELL CONSTRUCTION: See wellbore schematic (Attached) CORRELATION LOG: N/A OBJECTIVE: Re-enter Wellbore and execute Permanent P&A and restore drill site as per regulations. COMMENTS: The well Umiat #23H was spud on 2/15/2014. The operator on record was Linc Energy. The lease was reassigned to Malamute Energy shortly afterwards. Later, a resignation of Unit (Form 3160-5) was filed on 2/11/2021, designating Emerald House, LLC as Unit Operator. In that regard, Emerald House will Permanently abandon the Umiat #23H and restore the location as per relevant Federal and State Regulations. WELL HISTORY: The Umiat #23H well has 13-3/8” J-55, Conductor was set at 91’. It was spud on 2/15/2014 by the Kuupik #5 Drilling Rig. A 9-7/8” directional assembly was used and at 382’ this string became stuck. After recovering the drillstring, drilling resumed. The 9-7/8” hole section (Surface) was directionally drilled to 1,968’ MD, 1,260’ TVD. Upon reaching TD, the crew back-raeamed out of the hole picked up a logging BHA to conduct a MAD pass from 1,980’ to 246’. 7-5/8” L-80, 29.7 PPF, was run and set on bottom at 1,968’ MD. This Surface casing was cemented with a 112 bbls of Lead slurry, (11.0 ppg “LiteCrete”, Yield 1.87 cu-ft/sx, Top @ Surface and Bottom @ 1,594’) and 32.2 bbls of Tail (15.8 ppg, Class ‘G’, Yield 1.16 cu-ft/sx, Top @ 1,594’, Bottom @ 1,968’). The cement was displaced with 85.9 bbls of 8.0 ppg Versaclean. Cement returns were observed at surface by a representative from the BLM. Plugs bumped and held successfully. BOPE was installed and tested to 250 psi low and 1,500 psi high (BLM witness). The casing and 20’ of new formation was drilled out with a 6-3/4” assembly to 1,280’ TVD (2,000’ MD) and an FIT was conducted to 11.0 ppg (EMW) The 6-3/4” hole was successfully drilled to TD at 4,100’ MD. A 4-1/2" Slotted Production Liner, (L-80, 12.6 ppf, IBT-Mod) was run in the hole. A Baker ZXP Liner Top Packer was set with the Slotted Liner at: Top MD = 1,858', Bottom MD = 4,040', TVD = 1,986' A Baker Electric Submersible Pump (ESP) Completion Assembly was run with 3- 1/2" Production Tubing, (L-80, 8Rnd). With the pump at 1,848’ MD. A flow test and pressure build up was conducted on the well. After the tests all produced fluids were pumped back into the reservoir by way of the IA PROPOSED OPERATIONS – Permanently P&A: 1. Inspect Well Head, valves and gauges. Record any pressure. Pump out cellar. (Note: cellar may be filled with frozen water. Confirm status of cellar and tree prior to mobilization. Valve handles may have been removed, bring out if necessary) 2. Remove BPV in tubing. Confirm tree is not frozen, function all valves and test to 250/1,500 psi 3. R/U Pollard wireline lubricator, (test to 250/1,500 psi) and 4. Make dummy run with 1.5” gauge to as deep as possible. (Note: See attached Directional Surveys - @ 1,500’ there is 72 degrees inclination). POOH. Make up and run 2.8 gauge ring and run as deep as possible. (Note: ESP Pump at tubing tail approximately 1848’). POOH and RIH with tubing punch and perforate tubing as deep as possible above ESP Pump. POOH and R/D Pollard. (Note: Be prepared for possible u-tube in- balance once perforating tubing). 5. R/U Halliburton pumping unit to tubing and annulus. Test lines to 250/4000 psi. Open flow-path to annulus and attempt to inject into slotted liner at 1858’-4040’ (MD). Record rate and pressure. Maximum allowable injection pressure 3,750 psi. If injection cannot be established, contact office 6. Close in annulus and open tubing. Pump down tubing, establish injection rate and pressure into slotted liner. Record and notify office if there are any problems. TUBULAR SIZE ID (in) bbl/ft LENGTH VOLUME (bbls) Conductor 13-3/8 12.415 0.1497 91.0 13.62 Surface 7-5/8 6.875 0.0459 1,260.0 57.83 Liner 4-1/2 3.958 0.0152 2,182.0 33.17 Tubing 3-1/2 2.997 0.0087 1,858.0 16.16 Annulus 3-1/2 x 7-5/8 0.0340 1,858.0 63.17 Open Hole 6-3/4 6.750 0.0443 2,182.0 96.66 UMIAT #23H WELLBORE VOLUME CALCULATIONS 7. R/U to pump cement into tubing. Mix and pump cement into tubing (with annulus isolated). The objective is to bullhead (inject) cement into liner/open-hole to effectively plug any hydrocarbon bearing formation in the wellbore. (See Halliburton Cementing Program for cement design). Maximum volume of cement is 1000 psi a. Tubing volume: (1,858’ – 1,500’) x .0087 = 3 bbls b. Annular volume (1,858’ – 1,500’) x .0340 = 21 bbls c. Open Hole volume: (4,040’ – 1,858’) x .0433 = 97 bbls TOTAL Maximum Volume = 121 bbls 8. Once the cement fills the tubing and reaches the ESP this flowpath will bridge over. The remaining cement will travel through the tubing punch and fill the annulus and 6-3/4’ horizontal hole. 9. Drop wiper ball into tubing and displace to 200’ above tubing perforation. Shut in wellbore. 10. Shut down and monitor pressures. Wash up lines and WOC. Allow cement compressive strength to develop. 11. R/U Pollard wireline. Make gauge run and tag top of cement. POOH. Pressure test tubing and annulus to 1,000 psi 12. RIH with tubing punch and perforate tubing above top of cement. POOH. Rig down wireline. 13. R/U to pump cement into tubing. Mix and circulate cement into tubing (with annulus open) the volume is dependent upon depth of perforation. The objective is to circulate cement to surface and fill entire wellbore, tubing and annulus with cement. Assuming perforation at 1,400’: Annular volume = +/- 48bbls, Tubing volume = +/- 12 bbls. (See Halliburton Cementing Program for cement design). Displace surface lines and tree with water (+/- 0.5 bbls) 14. Shut down and monitor pressures. Wash up lines and WOC. 15. Check for trapped pressure. Cut off tree and associated jewelry 3’ below original ground level. 16. Fill casing / tubing with cement if not at stub level. Record TOC prior to filling. Take pictures. 17. Notify BLM to inspect cut-off. 18. Weld on ¼” marker plate with Company, PTD, Well Name, API #. As Per AOGCC guidelines and verbal from BLM. (20 AAC 25.120) 19. Pull cellar box and backfill hole with gravel. Berm to account for settling (Pile approx. 6’ atop well). 20. Clean location of debris. (Have Emerald House Environmental Lead inspect / Approve) (test each separately and chart / 30 min) Rig up jumper line between tubing and IA so Cement top will equalize. Notify AOGCC to witness tag and pressure test. (what is displacement fluid?) Provide photos of site clearance to AOGCC. Notify AOGCC also. 1500 psi Tag with smaller OD tool so it is more likely to get past stringers. 0.443 Photo-document before and after each step, from step 14 through step 20. BJM Notify AOGCC to witness cement quality in annulus before topping off with cement. CURRENT WELLBORE SCHEMATIC Drill Floor to Sea Level 596'Referenced to Kuukpik #5 Drilling Rig Drill Floor to Ground Level 21'5K Wellhead Assembly w/ 3½" Tubing Hanger Ground Level to SL 575'4" 'H' BPV Tundra surface Note: Schematic not to scale. No.Umiat #23H 1 Proposed Lower Grandstand B-sand Horizontal Slotted Liner ESP Completion - 9/27/2013 2 Update to WP#9 - 10/30/2013 3 Update to Actuals - 3/15/2014 4 5 6 7 8 9 10 11 12 13 14 Z. Sayers Z. Sayers ADL # 392301 API No. 50-287-20029-00 Comments/DateRev. by Z. Sayers PTD #213-020 Maximum Hole Angle: 102 Maximum Dog Leg: 8 Lease: AA-084141 (BLM) Spud Date: 2-15-2014 20" Hole 9-7/8" Hole 6-3/4" Hole TD -4,100' MD 986' TVD---------- Base Permafrost +/- 801' ---------- 13-3/8" Conductor 91' 7-5/8" Surface Casing 1,968' MD 1,260' TVD Baker ESP Pump 1,848' MD 4-1/2" Slotted Production Liner PROPOSED P&A SCHEMATIC Drill Floor to Sea Level 596'Referenced to Kuukpik #5 Drilling Rig Drill Floor to Ground Level 21'5K Wellhead Assembly w/ 3½" Tubing Hanger Ground Level to SL 575'4" 'H' BPV Tundra surface Note: Schematic not to scale. No.Umiat #23H 1 Proposed Lower Grandstand B-sand Horizontal Slotted Liner ESP Completion - 9/27/2013 2 Update to WP#9 - 10/30/2013 3 Update to Actuals - 3/15/2014 4 5 6 7 8 9 10 11 12 13 14 Maximum Hole Angle: 102 Maximum Dog Leg: 8 Lease: AA-084141 (BLM) Spud Date: 2-15-2014 Z. Sayers Z. Sayers ADL # 392301 API No. 50-287-20029-00 Comments/DateRev. by Z. Sayers PTD #213-020 20" Hole 9-7/8" Hole 6-3/4" Hole TD -4,100' MD 986' TVD---------- Base Permafrost +/-801' ---------- 13-3/8" Conductor 91' 7-5/8" Surface Casing 1,968' MD 1,260' TVD Baker ESP Pump 1,848' MD 4-1/2" Slotted Production Liner Tubing Perforations p 848 MD848 MD1,848' MD1 plug #1 Plug#2 THE STATE "ALASKA GOVERNOR MICHAEL J. DUNLFAVY June 29, 2020 Ms. Shauna McMahon Environmental Program Specialist III Alaska Department of Environmental Conservation Spill Prevention, Prevention and Response Program 410 Willoughby Avenue, Suite 303 P.O. Box 111800 Juneau, Alaska 99811-1800 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Re: Docket No: OTH-20-040 Malamute Energy, Inc.'s wells Umiat 18 (PTD 213-014) and 23H (PTD 213-020) Dear Ms. McMahon: Malamute Energy, Inc. (Malamute) requested that the Alaska Oil and Gas Conservation Commission (AOGCC) provide the following information to you. Both the Umiat 18 well (Umiat 18) and the Umiat 23H well have been suspended. A suspended well is one that has been plugged to prevent the flow of fluids in the well but is not deemed fully plugged and abandoned in accordance with AOGCC regulations. One of AOGCC's regulatory requirements for wells in a suspended status is periodic inspection of the well to ensure fluid movement is still restricted and the well is in good mechanical condition. Malamute is in compliance with these suspended well inspection requirements (the most recent inspections were conducted On July 6, 2019, for Umiat 23H and August 2, 2019, for Umiat 18). Those inspections showed no surface pressure on the tubing or the annulus of the well, which indicates that the wells are incapable of flow. If you have any questions on this matter please contact Mr. Guy Schwartz (¢uv.schwartzaalaska.gov or 907-793-1226) or Mr. Dave Roby (dave.robv(d),alaska.gov or 907-793-1232). Sincerely, Je2emy M. Price Chair, Commissioner cc: Mr. Leonard Sojka Malamute Energy, Inc. Page I of 1 Roby, David S (CED) From: Schwartz, Guy L (CED) Sent: Thursday, June 25, 2020 10:17 AM To: Davies, Stephen F (CED); Roby, David S (CED) Subject: FW: Umiat - DEC pollution liability insurance Attachments: 2015 11 19 -Well 18 Linc inspection report.pdf,, 2015 11 19_Well 23H Linc inspection report.pdf, 2019 8 5-Umiat #18 inspection report.pdf; 2019 8 5-Umiat #23H inspection report.pdf; 2019 6 28 -Renaissance Umiat Cert of Fin Resp_.pdf, 2020 6 23_Draft AOGCC letter to DEC.docx Can you look at this? I am not sure it is quite that simple to change the Potential for flow. Didn't we have to look at this in the original C plan? Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(sl. It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guv schwartzCaloska aovv). From: Leonard Sojka <leonard@malamuteenergy.com> Sent: Tuesday, June 23, 2020 7:06 AM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Subject: Umiat - DEC pollution liability insurance Good morning Guy, Annually, Malamute has had to procure pollution liability insurance for the two Umiat wells, in order to obtain the attached Certificate for Financial Responsibility from the Alaska Department of Environmental Conservation ("DEC"). hi that the pollution liability insurance premium is very expensive and the liability insurance serves no effective purpose, this year I asked DEC whether their regulations applied to the two wells, in that the two wells were zero pressure, no -flow. DEC replied that since the wells were not P&A's, the regulations applied. I then suggested that since the wells were zero pressure no -flow, that perhaps the regulations should take this into consideration. Shauna at DEC responded "My supervisors suggest you reaching to Alaska Oil & Gas Conservation Commission to validate the zero pressure, no -flow well status you mentioned in the letter. If AOGCC provides a letter documenting the zero pressure no -flows status, that could be a consideration in the Financial Responsibility submittal." In 2015, Linc Energy filed well inspection reports (attached) for each well, which indicated that the wells had zero pressure hi 2019, Malamute filed well inspection reports (attached) for each well, indicating that the wells had zero pressure. So, will the AOGCC send a simple letter to DEC, confirming that the Umiat wells are zero pressure no -flow? Attached is an AOGCC draft letter to DEC, in case that makes the process easier. Thank you, Leonard STATE OF ALASKA • A*KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon LJ Plug Perforations= Fracture Stimulate Pull Tubing Li Operations shutdown Performed: Suspend j J Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Reddll ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: _Inspection_ 0 2. Operator Linc Energy Operations, Inc 14. Well Class Before Work: 5. Permit to Drill Number 5 -7i 0 Name: %11 elopmem ❑ Exploratory ❑✓ Stratigraphic❑ Service ❑ 213-014 3. Address: 3000 C Street, Sure 103 6. API Number: Anchorage, AK 99503 50-287-20028-00 a 7. Property Designation (Lease Number): 8. Well Name and Number: C /� C IVEU FEDAA-081726 umiat #18 G C G 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): lExplorato 2 3 2015 Llmiat f t 11. Present Well Condition Summary: I A OGCC lJ Total Depth measured 1445 feet Plugs measured l true vertical 1444 feet Junk measured feet Effective Depth measured feet Packer measured feel true vertical feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 96 13-378" 96 96 5020 2260 Surface 1445 9-5/8" 1445 1444 5750 3090 Intermediate Production Liner FEB 0 2 2616 Perforation depth Measured depth 775 feel �•�+'- True Vertical depth 775 feet Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 906 906 Packers and SSSV (type, measured and true vertical depth) WA 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl F— Ga Mot Water-Sbi Casing Pressure Tubing Pressure Prior to well operation: 0 1 0 1 0 1 0 Subsequent to operation: 0 0 1 0 10 10 14. Attachments (raquked per 20 ruC 2sA70, 25071, a 25.203) 15. Well Class after work: Daily Report of Well Operations Exploratory ❑� ' Development ❑ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Ej Gas Lj WDSPL Lj Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP Q r SPLUG ❑ 17. 1 hereby certify that the foregoing is true and cared to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: Contact Shawn Trasky Email Shawn.traskyallncenergV. com Printed Name Shawn Trasky TiBe Environmental Project Manager Signature ���-ti_.. l ,./�� Phone 907-375-2615 Date 1120/2015 Fomr 10-404 Revised 52015 orC, /L - 3-1 i �" NU Y 4 106 Submit Original Only ✓ ,/ / �.�/.rte �BDMs;�� y 0 URC EIIERGY Linc Energy Operations, Inc. 3000 "C' Street, Suite #103 Anchorage, Alaska 99503 November 19, 2015 Alaska Oil and Gas Conservation Commission 333 West Ph Ave., Suite 100 Anchoraqe, Alaska 99501 0 RE: Sundry Application (Well Suspension) Well: Umiat #18 (Existing Exploratory Oil Well) TRS: SWNW, T1S, R1W, Section 3, Umiat Meridian Dear Chairman Foerster, RECEIVED NOV 2 3 2015 AOGCC Linc Energy Operations, Inc. hereby applies for a Sundry Approval to continue the Suspension of the Umiat #18 Oil Exploration Well. Linc is currently evaluating the future utility of this wellbore based on the results of the flow testing initiated on April 21, 2013. Some options that will be evaluated for the future exploration seasons include a workover to pull tubing and recomplete the existing perforated interval, a workover to pull tubing and perforate a new interval in the Lower Grandstand or a rotary side track. Linc is also looking at other possible artificial lift methods other than the insertable PCP Pump that was run in the well for the 2012-13 18 was inspected, ere were rain cover looked to be in good condition. The top of cellar box is 6 feet from ground level and there is a 24 inch wide ditch around cellar box. The ditch is full of water (no sheen) and the back fill settled an average 18 inches deep. There is a ply wood top cover on the cellar. The cellar box is water tight and the water level in the cellar could not be determined. There were no visible weeps at flange connections. A gauge was installed on tree cap and open valves gauge read zero, pulled plug on 7-5/8 x 3-1/2 annulus had zero pressure. All valves worked properly and the down hole pump connection and pack off looked good. Pertinent information attached to this application includes the following: 1) Form 10-404 Sundry Application 0 • 2) Photos of Well 18 3) Plat showing location of the well The following is Linc Energy's designated contacts for reporting responsibilities to the AOGCC: 1) Shawn Trasky 907-375-2615 If you have any questions or require further information, please contact Shawn Trasky at 907-375-2615. Sincerely, Shawn Trasky Environmental Project Manager r r <?. �o 4. -400F VI `t ...J! ,r ♦,.fi r...,; i t �, �. �� ss � x 1 0' 8 t /i � I � AKAA 004141 ` j ti a Gln rr i• 1. ) _ . j4^ ` •Ai , ��✓ �'�Y►17 3�Iitlt(i i5 f` j 16� :� / Seab t1` ?011' ( 't�.• '� 1 rr� /. �` % Seabeeyt"1.14 •6 w, r+}AG.... .... ,1 rr rr.j.....X �e P_-+ :A'a'u^•^ { IL ADL 380720 7 ��..� Vr, fir+ •'� � � `{` � '� � ;r/ � � � r r! e� r�.MayHusk-y t l �► ��,..+++ , ""rte—' � , Saco 011,41 Aufirlr � ` � Nin ~'r.� I ��. i�♦ Case:-AKAR• 01436 �, •'b� '1`C r'' f {';�� TraCt NPR-AMI-L-OOS id!r,ti ♦��.' i �.. �� e 0 i I � ; , j ,Candial • 2013/2014 Well Locations 1/4 mile buffer from N �I �� e 2012/2013 Well Locations `' 1' abandoned wells • Legacywelis ERERGY 1, Existing Gravel Roads Existing Gravel Pads Umiat Infield Overview Map ® Federal Lease Boundary Northeast NPR-A, North Slope, Alaska NPR-A Boundary NAD03_UTM Zona 5 0 0.25 0.5 7 Q State of Alaska Lease November 2015 Mile Figure 1 STATE OF ALASKA ION AL ''OIL AND GAS CONSERVATION COM RE.iRT OF SUNDRY WELL OPERATIONS 1. Operations Abandon L1 Plug Perforations LJ Fracture Stimulate Li Pull Tubing Operations shutdown Li Performed: Suspend Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ er Srs1cw ; 4Zr1( 2. Operator Linc Energy Operations, Inc 4. Well Class Before Work: 5. Permit o Drill Number: 1• a f'. ^'� Name: Development 1:1Exploratory Stratigraphic ❑ Q Service F]16. 213-020 3. Address: 3000 C Street, Sute 103 API Number: Anchorage, AK 99503 50-287-20029-00 ' 7. Property Designation (Lease Number): 8. Well Name and Number: .. FEDAA84141 ' Umial #23H 1 ' A r. ( 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Ex lorato Umiat (jP Q1 11. Present Well Condition Summary: Total Depth measured 4040 • feet Plugs measured None feel true vertical 986 • feet Junk measured None feet Effective Depth measured 4040 feet Packer measured None feet Ince vertical 986 feet true vertical None feet Casing Length Size MD TVD Burst Collapse Structural Conductor 91 13-3/8" 91 91 3450 1950 Surface 1968 7-5/8" 1968 1260 6890 4790 Intermediate None None None None None None Production 1858 3-12" 1858 1266 10160 10540 Liner 2182 4-12" 4040 986 WA (slotted) N/A (slotted) Perforation depth Measured depth N/A feet True Vertical depth N/A feel Tubing (size, grade, measured and true vertical depth) 3-12", 9.30 L-80 1,858' MD, 1,266 TVD Packers and SSSV (type, measured and true vertical depth) None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Dairy Average Production or Injection Data Oil -Bbl Gas-Mcr Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: - 0 0 0 0 Subsequent to operation:1 0 0 0 0 0 14. Attachments (re4ulred per 20 AAC 25o70.25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations ❑' Exploratory❑✓ ' Development❑ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil LJ Gas LJ WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP Q ' SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Shawn Tresky Email Shawn.traskvCoNincenercv.com Printed Name Shawn Trasky Title Environmental Project Manager J �— ��J�.. Signature . Phone 907-375-2615 Date Form 10.404 Revised 52015 p� j • /S � R13DMS1' rl" Z 4 2015 Submit Original Only t L EIRERGY Linc Energy Operations, Inc. 3000 "C" Street, Suite #103 Anchorage, Alaska 99503 November 19, 2015 Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry Application (Well Suspension) Well: Umiat #23H (Existing Exploratory Oil Well) TRS: Sec. 32 T 1N, R 1W, Umiat Meridian Dear Chairman Foerster, :RECEIVED n'K232015 AOGCC Linc Energy Operations, Inc. hereby applies for a Sundry Approval to continue the Suspension of the Umiat #23H Oil Exploration Well. Linc is currently evaluating the future utility of this wellbore based on the results of the flow testing initiated on March 27, 2014. Some options that will be evaluated for the future exploration seasons include continued flow testing or a rotary side track. Linc is also looking at other possible artificial lift methods other than the ESP pump that was run in the well for the 2013-14 season. On August 17th, 2015 Well#23H was inspected. There were no viable leaks; the rain cover looked to be in good condition. The top of cellar box is 6 feet from ground level and there is a 24 inch wide ditch around cellar box. The grating on top of the cellar is in good shape. The cellar box is water tight and has approximately 4 feet of water in it. There were no visible weeps at flange connections. The 7-5/8 x 3-1/2 gauge read zero when -opened. The wing valve gauges read zero and the top cap gauge read zero. All valves, needle valves and gauges worked properly and the down hole pump electrical connection looked good. Pertinent information attached to this application includes the following: 1) Form 10-404 Sundry Application 2) Photos of Well 23H 3) Plat showing location of the well The following is Linc Energy's designated contacts for reporting responsibilities to the AOGCC: 1) Shawn Trasky 907-375-2615 If you have any questions or require further information, please contact Shawn Trasky at 907-375-2615. Sincerely, Shawn Trasky Environmental Project Manager _. y� �_�.. .- 4 Ca �.�. � i ' • � � � 11 ,, ! ! eye 8' AKA4' 004141 1 ,r. fro -at 02 i Sea e�1 r'7� r• 4!Seebee V' ,J 6 O _ .• f. t .••Irjq .'yY P'��+ 7A5'�_�td1 Tf�•• ' ADL 390720 /�V! ♦ _ i �� !% ABCOt1 ml'ItfIM�� I ,fir � __� :''kr� ..+ ,F_,•-'"►� ��� ,Y 40 001 r � � ., .. •heel,,. r Y TfillCt: NPR -AA -L-00S10 • 2013/2014 Well Locations,., 1l4 mile buffer from N • 2012/2013 Well Locations 3' "r abandoned wells O U nC • Legacy Wells ERERGY 1, Existing Gravel Roads = Existing Gravel Pads Umiat Infield Overview Map PFederal Lease Boundary Northeast NPR -A, North Slope, Alaska NPR -A Boundary NADe3 UTM lore 5 QStale of Alaska Lease November2015 0 o.zs o.s 1M+le Figure 1 Malamute Energy, Inc. August 5, 2019 Alaska Oil and Gas Conservation Commission 333 West 7`" Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry Application (Well Suspension) Well: Umiat #18 (Existing Exploratory Oil Well) TRS: SWNW, TIS, RIW, Section 3, Umiat Meridian Commissioner Chmielowski, Malamute Energy, Inc. hereby applies for a Sundry Approval to continue the Suspension of the Umiat #18 Oil Exploration Well. Umiat well #18 was inspected on August 2, 2019. Malamute believes that the inspection procedures and documentation are sufficient to complete the five year inspection requirement (one year early). Therefore, the next inspection of well #18 would be five years hence in 2024: • The top of the cellar box is 6 feet from ground level; there is a 24 inch wide ditch around the cellar box. The cellar box appears to be in good condition, with no visible leaks. • The grating on top of the cellar is in good condition, and is covered with plywood. • The cellar box contains approximately 1.5 feet of water. All valves to the pressure gauges were in working order and protected from the environment for continued service. There were no visible weeps at flange connections. Umiat #18 is a "no flow well." The pressure gauge readings were as follows: 0 9-5/8" x 3-1/2" annulus 0 psi 0 3-1/2" Tubing (Top) 0 psi 0 3-1/2" tubing (Wing) 0 psi As required, this well inspection report includes Form 10-404 Sundry Application, photos of well #18 and a plat showing the location of the well Sincerely, Leonard Sojka President Malamute Energy, Inc. Designated contact for reporting responsibilities to the AOGCC. 612-245-9913 Page] of3 Page 2 of 3 0 psi on 3-1/2" bore with all valves open. 0 PSI on the 9-5/8" x 3-1/2" annulus with all corresponding valves open Page 3 of 3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon LJ Plug Perforations LJ Fracture Stimulate LJ Pull Tubing LJ Operations shutdown LJ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Inspection O 2. Operator Malamute Energy, Inc. 14. Well Class Before Work: 5. Pemrit to Drill Number: Name: Development ❑ Exploratory Stratigraphic ❑ Service ❑ 213-014 - Suspended Well 3. Address: PO Box 27131, 7701 Golden Valley Road 6. API Number: Golden Valley, MN 55427 50-287-20028-00 7. Property Designation (Lease Number): S. Well Name and Number: FEDAA-081726 umial #18 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Ex lorato Umiat); undefined oil 11. Present Well Condition Summary: Total Depth measured 1445 feet Plugs measured feet true vertical 1444 feet Junk measured feet Effective Depth measured feet Packer measured feet true vertical feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 96 13-3/8" 96 96 5020 2260 Surface 1445 9-5/8" 1445 1444 5750 3090 Intermediate Production Liner Perforation depth Measured depth 775 feet True Vertical depth 775 feet Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 906 906 Packers and SSSV (type, measured and true vertical depth) N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments (requiem per 20 rwC 25.070, 25.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations ❑' Exploratory I] Development E] Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑+ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Authorized Name: Leonard Sojka Contact Name: Same Authorized Title: President Contact Email: Ieonard(i1malamuteenerov corn CC �u Authorized Si nature: Dab 8/5/2019 Contact Phone: 612-245-9913 Form 10-404 Revised 4/2017 Submit Original Only 1�— r A 084141 '.�� t'`- -- ,•-:� �✓ ,A 2002-L-014 ta * � •18 1.11i5r tT� \ti Y Sea. If 1BA• 'r.......••� I , Seabee 1�[ r CPO mi .04 Cake.-AKAA.; 081716 Track HPR,A X91 -L-005 �,�!•0'4,, e 2013/2014 Well Locations e 2012/2013 Well Locations e Legacy Wells '�. Existing Gravel Roads Q Existing Gravel Pads Federal Lease Boundary �. NPR -A Boundary 1/4 mile buffer from '•..r abandoned wells -t ADL 390720 `e 7 V ' N Malamute Energy, Inc. Umiat Infield Overview Map Northeast NPR -A, North Slope, Alaska NAD63 UTM Zona 5 0 0.25 0.5 1 November 2015 Mlle Fwd: AOGCC Test Witness Notification Request: Inspection, No Rig, Umiat #18, Umiat Alaskax 3 messages Tim Flynn <Tim.Flynn@ak-dc.com> Thu, Aug 1, 2019 at 12:58 PM To: "leonard@malamuteenergy.com" <leonard@malamuteenergy.com> FYI, have a safe flight Leonard. Sent from my iPhone Begin forwarded message: Date: August 1, 2019 at 7:45:04 AM AKDT To: Tim Flynn <Tim.Flynn@ak-dc.com> Subject: Re: AOGCC Test Witness Notification Request: Inspection, No Rig, Umiat #18, Umiat Alaskax AOGCC Inspectors are busy with other priority work so I am waiving witness of Umiat 18 suspended well inspection. Please send photos that document all requirements of the inspection including the well cellar and well sign. Sent via the Samsung Galaxy S8 Active, an AT&T 5G Evolution capable smartphone Malamute Energy, Inc. August 5, 2019 Alaska Oil and Gas Conservation Commission 333 West 7'h Ave. Suite 100 I Anchorage, Alaska 99501 RE: Sundry Application (Well Suspension) Well: Umiat #23H (Existing Exploratory Oil Well) TRS: Sec. 32 T 1N, RI W, Umiat Meridian Commissioner Chmielowski, Malamute Energy, Inc. hereby applies for a Sundry Approval to continue the Suspension of the Umiat #23H Oil Exploration Well. Umiat well #23H was inspected on July 6, 2019. Malamute believes that the inspection procedures and documentation are sufficient to complete the five year inspection requirement (one year early). Therefore, the next inspection of well #23H would be five years hence in 2024: • The top of the cellar box is 6 feet from ground level; there is a 24 inch wide ditch around the cellar box. The cellar box appears to be in good condition, with no visible leaks. • The grating on top of the cellar is in good condition, and is covered with plywood. • The cellar box contains approximately 4 feet of water. This water level is consistent with the previous (2015) well inspection report. • All valves to the pressure gauges were in working order and protected from the environment for continued service. There were no visible weeps at flange connections. 111411MAM • Umiat #23 is a "no flow well'. The pressure gauge readings were as follows: 0 7-5/8" x 3-1/2" annulus 0 psi 0 3-1/2" Tubing (Top) 0 psi 0 3-1/2" tubing (Wing) 0 psi As required, this well inspection report includes Form 10-404 Sundry Application, photos of well #23H and a plat showing the location of the well Sincerely, Leonard Sojka President Malamute Energy, Inc. Designated contact for reporting responsibilities to the AOGCC. 612-245-9913 Page 1 of 3 :,:�, .� a, =. . 0 psi on the 7-5/8" x 3-1/2" annulus with all valves open 0 psi on the 3-1/2" bore 0 psi on the 3-1/2" bore wing waive Page 3 of 3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon LJ Plug Perforations Fracture Stimulate LJ Pull Tubing LJ Operations shutdown Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Inspection 2. Operator Malamute Energy, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory 0 Stratigraphic ❑ Service ❑ 213-020 - Suspended Well 3. Address: PO Box 27131, 7701 Golden Valley Road 6. API Number: Golden Valley, MN 55427 50-287-20029-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDAA-084141 Umiat #23H 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Ex lorato Unniat ; undefined oil 11. Present Well Condition Summary: Total Depth measured 4040 feet Plugs measured none feet true vertical 986 feet Junk measured none feet Effective Depth measured 4040 feet Packer measured none feet true vertical 986 feet true vertical none feet Casing Length Size MD TVD Burst Collapse Structural Conductor 91 13-3/8" 91 91 3450 1950 Surface 1968 7-5/8" 1968 1260 6890 4790 Intermediate none none none none none none Production 1858 3-12" 1858 1266 10160 10540 Liner 2182 4-1/2" 4040 986 NN/A (slotted) NN/A (slotted) Perforation depth Measured depth N/A feet True Vertical depth N/A feet Tubing (size, grade, measured and true vertical depth) 3-12", 9.3# L-80 1858' MD, 1266' TVD Packers and SSSV (type, measured and true vertical depth) None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure F— Prior to well operation:0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments (requires par 20 AAC 25.070, 25. Wi, 8 25.283) 15. Well Class after work: Daily Report of Well Operations ❑' Exploratory ❑' Development ❑ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑+ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Authorized Name: Leonard Sojka Contact Name: Same Authorized Title: Contact Email: leonardAmalamuteenerov.com ,. -_,Prresident Authorized Signature v Dat( 8/5/2019 Contact Phone: 612-245-9913 Form 10-404 Revised 42017 Submit Original Only Will 711111 8 AKAR 084141,' 1 ((may _ t• { j� „"�. - --•�` { 1 �t lFt-A2002rIL-0111111, �� ( ..// �^�J / g,f I.' - } ;•�s..r e.. ��..� 'ly(' •',1 i.1. 34t� ,.\ 1�;-,. ., `!•: 18 iii is ti'.id D so f`. ' r._�- : 1. f �\ ASA '� • .� v. / e2` Sea �e1f , JBa• +....... •' -��r ,« , Seabees y'"f `� 6 { t •-.' Iyy • -ITS _ .!f< • r�� !1♦ • •" • . ....-_' r?l •iE•✓�? ���. ,r. �• / 'ADL 390720 00 fril}k-#Artlkll Ca*e:•AKAR , ItI2 Trott NPR,A:,091rL �w�'yrc �+►���tif_ � ' r'f . i • 2013/2014 Well Locations 1/4 mile buffer from • 20122013 Well Locations a .r abandoned wells N Malamute Energy, Inc. ® Legacy Wells Existing Gravel Roads Q Existing Gravel Pads Urniat Infield Overview Map Federal Lease Boundary Northeast NPR -A, North Slope, Alaska r. NPR -A Boundary NA083_ mm Zone 5 0 0.25 0.5 7 November 2015 ane.. .eMile ."k STATE OF ALASKA Department of Environmental Conservation Prevention, Preparedness and Response Program Financial Responsibility P.O. Box 111800 Juneau, Alaska 99801-1795 Phone: 907-465-5233 Fax: 9107-465-5245 CERTIFICATE FOR PROOF OF FINANCIAL RESPONSIBILITY No. 18-261-165-001 Owner/Operator: Owner: Renaissance Umiat, LLC Operated by Malamute Energy, Inc. FacilityNessel: Umiat Crude Oil Y Facility Location: Lat: 69.36 N, Lone: 152.14 W 2000 bbls Storage Capacity Noncrude Oil Y There is no oil stored at Umiat_ This application has been made in the name of - Address: P.O. Box 27131, Golden Valley, Minnesota 55427 This applicant has met the minimum requirements for acceptance of proof of financial ability to respond to oil spill damages as required by Alaska Statute 46.04.040 and regulations at 18 AAC Chapter 75, Article 2. Approval expires: June 30, 2020 Approved Prised 01112 ****** See certificate requirements under regulations at 18 AAC 75.240 ****** Approved by: / ✓ ZA u: vLt" �;i7 Z� t — Shauna, McMahon Financial Responsibility Program Effective date: June 28, 2019 June 27, 2019 ME STATE °'ALASKA GOVERNOR MICHAEL J. DUNLLAVV Malamute Energy, Inc. P.O. Box 27131 Golden Valley, Minnesota 55427 Dear Leonard: Department of Environmental Conservation PREVEN ZION. PREPAREDNESS AND RESPONSE PROGRAM Financial Responsibility Unk PO BOX 11 1800 Juneau, AK 99811-1800 Moln: 907.465.5233 Fox: 907.465,5245 dec.aloska.gov AM/ /d&alayka. u.Po/dr�r/jjr/avwlinann-n/rut(finanzr+l tai pwibilrnIUAn4-1arfr The financial responsibility application in the name of Malamute Energy, Inc. has been filed in accordance with Alaska Statute 46.04.040 and regulations at 18 AAC Chapter 75, Article 2, for the Umiat Based on the proof of financial responsibility that was submitted the approved is valid until 6/30/2020. Approval certificates are enclosed. Please ensure that the certificates are available for inspection at Umiat An application for renewal of the certificate should be submitted to this office at least 30 days, but no earlier than 90 days, before the current proof of financial responsibility expires. Sincerely, Shauna McMahon Environmental Program Specialist III Financial Responsibility Unit Dec.spar.pprp.ind.fr@alaska.gov Phone: 907-465-5233, Fax: 907-465-5245 Enclosures: 18 261 165-001 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED AUG 0 6 2019 1. Operations Abandon LJ Plug Perforations LJ Fracture Stimulate LJ Pull TubingLJ 'rations Shutdown Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Inspection 0 2. Operator Malamute Energy, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory [ Stratigraphic ❑ Service ❑ 213-020 - Suspended Well 3. Address: PO Box 27131, 7701 Golden Valley Road 6. API Number: Golden Valley, MN 55427 50-287-20029-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDAA-084141 Umiat#23H 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Exploratory Urniat ; undefined oil 11. Present Well Condition Summary: Total Depth measured 4040 feet Plugs measured none feet true vertical 986 feet Junk measured none feet Effective Depth measured 4040 feet Packer measured none feet true vertical 986 feet true vertical none feet Casing Length Sae MD TVD Burst Collapse Structural Conductor 91 13-3/8" 91 91 3450 1950 Surface 1968 7-5/8" 1968 1260 6890 4790 Intermediate none none none none none none Production 1858 3-12" 1858 1266 10160 10540 Liner 2182 4-12" 4040 986 NN/A (slotted) NN/A (slotted) Perforation depth Measured depth N/A feet True Vertical depth N/A feet Tubing (size, grade, measured and true vertical depth) 3-12", 9.3# L-00 1858' MD, 1266' TVD Packers and SSSV (type, measured and true vertical depth) None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Md Waler-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments (required per 20 AAC 25.070, 25W1, s 25.283) 15. Well Class after work: Daily Report of Well Operations Exploratory E] Development❑ Service ❑ Strafigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSPI] SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Authorized Name: Leonard Sojka Contact Name: Same Authorized Title: Contact Email: leonard(a)malamuteeneray co,n —President v�� Authonzetl S' nature: Dat, 8(5/2019 Contact Phone: 612-245-9913 Form 10404 Revised 42017 c RBDMSAus 0 7 2019 Submit Original Only Malamute Energy, Inc. August 5, 2019 Alaska Oil and Gas Conservation Commission 333 West 7s' Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry Application (Well Suspension) Well: Umiat #23H (Existing Exploratory Oil Well) TRS: Sec. 32 T IN, RIW, Umiat Meridian Commissioner Chmielowski, Malamute Energy, Inc. hereby applies for a Sundry Approval to continue the Suspension of the Umiat #23H Oil Exploration Well. Umiat well #23H was inspected on July 6, 2019. Malamute believes that the inspection procedures and documentation are sufficient to complete the five year inspection requirement (one year early). Therefore, the next inspection of well #23H would be five years hence in 2024: • The top of the cellar box is 6 feet from ground level; there is a 24 inch wide ditch around the cellar box. The cellar box appears to be in good condition, with no visible leaks. • The grating on top of the cellar is in good condition, and is covered with plywood. • The cellar box contains approximately 4 feet of water. This water level is consistent with the previous ( 15) well Inspection report. • All valves to the pressure gauges were in working order and protected from the environment for continued service. There were no visible weeps at flange connections. There were no leaks around any flanges or valves. • Umiat #23 is a "no flow well'. The pressure gauge readings were as follows: 0 7-5/8" x 3-1/2" annulus 0 psi 0 3-1/2" Tubing (Top) 0 psi 0 3-1/2" tubing (Wing) 0 psi As required, this well inspection report includes Form 10-404 Sundry Application, photos of well 423H and a plat showing the location of the well Sincerely, .4��#CLI Leonard Sojka President Malamute Energy, Inc. Designated contact for reporting responsibilities to the AOGCC. 612-245-9913 Pagel of3 Page 2 of 0 psi on the 7-5/8" x 3-1/2" annulus with all valves open 0 psi on the 3-1/2" bore 0 psi on the 3-1/2" bore wing walve Page 3 of 3 ^,•.ji ij 1 (.�f .� ...y 6 t I ` t , r tj� AKAA 084141, �11CL',NPR�A M"-Oii i •t t �• � int Com; sr I 9 l 'r-„`��t ♦ I r }„ /r✓.� t 1 R9""'� ....-.i'v.'/� -n.�s m Qt a .,� r �Ir/ y i-,�:a.r•M_�:. •.. •t, t I ' 1 1 r �. AU. _ !�- •r _ � ra ' 1 ''�. rF .•.ti e2' Seabee -1 ie. - I__l� . � �•i1 . - •4fF," Seabee I .... ; • ..(.A's 6 r 'AOL 34orm r { .. O Husky • r' I . Irn� 1 All Ntb, J I UMIAT Ca14•: AKAA O8ty26 Tract NPR,AAM L-0OS '' 1, F Ir jile • 20132014 Well Locations 1/4 mile buffer from 4 N • 20122013 Well Locations • abandoned wells Malamute Energy, Inc. e Legacy Wells �.. Existing Gravel Roads Umlat Infield Ovemlew Map Existing Gravel Pads Federal Lease Boundary NPR -A Boundary Nodhsasl NPA -A, North Sbpe. AYaka "OW -Urs zon s Nwemb.,2015 0 0.25 05 1 Schwartz, Guy L (CED) From: Schwartz, Guy L (CED) Sent: Friday, August 9, 2019 9:11 AM To: 'Leonard Sojka' Cc- 'Tim Flynn'; Regg, James B (DOA) Qim.regg@alaska.gov) Subject: Umiat 18 and 23H Inspections (PTD 213-014, 213-020) Leonard, I am reviewing your 10-404 suspended well inspection reports on both Umiat 18 and 23H. Both indicate that there is substantial water in the cellars. I discussed with you earlier this summer about having to remove water in cellars and told you to be prepared to pump out any water found. It appears that this did not happen. We have had at least two incidents in the last couple of years causing hydrocarbon spills due to ice expanding against wellhead valves (IA and OA valves) during the freeze -thaw cycles. The valve flanges or welds become compromised and will leak any diesel or freeze protect fluid. Since these are remote wells the leaks could go undetected for years. Malamute Energy must come up with a plan to address this ASAP. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 1 or (Guv schwartz@alaska aovl. h N .\ s Schwartz, Guy L (CED) From: Schwartz, Guy L (CED) Sent: Tuesday, August 13, 2019 9:18 AM To: 'Tim Flynn'; Leonard Sojka Cc: Regg, James B (CED) Subject: RE: Umiat 18 and 23H Inspections (PTD 213-014, 213-020) Tim, Thanks for the clarification. If there is no danger of the IA/OA valves being compromised with freeze thaw cycles the current water levels in the cellars are acceptable. The conductor valve shown in the picture of Umiat 23 is not an issue as it is used for cement returns only on the surface casing. I will file the additional pictures and this email in our well folders. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226) or (Guv schwartz@alaska aov). From: Tim Flynn <Tim.Flynn @ak-dc.com> Sent: Monday, August 12, 2019 11:32 AM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov>; Leonard Sojka <leonard@malamuteenergy.com> Cc: Regg, James B (CED) <jim.regg@alaska.gov> Subject: RE: Umiat 18 and 23H Inspections (PTD 213-014, 213-020) Guy, With my visit to Umiat last week I was able to gain a good understanding of the wells and their current status. The wells are a unique design in that both wellheads are above ground level (6+ feet above ground level) and encased in a steel cellar. I have investigated the water levels in both wells and there is a common level that regardless of pumping water out returns to the same levels. Umiat #23 is in a bog with ground water surrounding the outside of the steel well cellar. It is assumed that the water in Umiat #23 is from a leak at the base of the steel cellar allowing ground water to enter. There is no noticeable breach in the conductor of the well. Umiat #18 is also in a bog and has had very little water reported in the cellar. It is assumed that the few inches of water is from snow melt over the winter months. For both Umiat #18 and Umiat #23, both wellheads are substantially above any known water level and all valves to IA and OA's for both wells are in good working order. At this time, based on no expected damage to the well with historically similar water levels, Malamute does not plan to pump any further water from the cellars. Thank you Timothy Flynn Project Manager Alaska Drilling and Completions 907 317 5504 Tim.flvnn@ak-dc.com Alaska Drilling ,Completions From: Schwartz, Guy L (CED) <guy.schwartz@alaska.eov> Sent: Friday, August 9, 2019 9:11 AM To: Leonard Sojka <leonard@malamuteenergy com> Cc: Tim Flynn <TIm.Flynn@ak-dc com>; Regg, James B (CED) <jim.rese@alaska.eov> Subject: Umiat 18 and 23H Inspections (PTD 213-014, 213-020) Leonard, I am reviewing your 10-404 suspended well inspection reports on both Umiat 18 and 23H. Both indicate that there is substantial water in the cellars. I discussed with you earlier this summer about having to remove water in cellars and told you to be prepared to pump out any water found. It appears that this did not happen. We have had at least two incidents in the last couple of years causing hydrocarbon spills due to ice expanding against wellhead valves (IA and OA valves) during the freeze -thaw cycles. The valve flanges or welds become compromised and will leak any diesel or freeze protect fluid. Since these are remote wells the leaks could go undetected for years. Malamute Energy must come up with a plan to address this ASAP. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office ?) _02_ Form 3160-5 UNITED STATES FORM APPROVED (June 2015) OMS No.1004-0137 DEPARTMENT OF THE INTERIOR Expires:January 31,2018 BUREAU OF LAND MANAGEMENT 5.Lease Serial No. M-084141 SUNDRY NOTICES AND REPORTS ON WELLS 6 If Indian,Allonee or Tribe Name Do not use this form for proposals to drill or to re-enter an N/A abandoned well.Use Form 3160-3(APD)for such proposals. SUBMIT IN TRIPLICATE•Other Instructions on page 2 7.If Unit of CA/Agreement,Name and/or No. I.Type of Well N/A Oil WellGm Wellg.Well Name and No. ® 0 0Other Umiat#23H 2.Name oCOperetor Malamule Ene 9.API Well No. rgy,Inc 50-287-20029-00 31.Address PO Box 27131,7701 Golden Valley Road, 3b.Phone No.(include area code) 10.Field and Pool or Exploratory Area Golden Valley,MN 55427 (612)245-9913 Exploratory(Umlal) 4.Location of Well(Footage,Sec..T.,R..M.,or Surrey Description) I I.Country or Parish,State 1,032'FSL,1,254'FWL,Sec 32(Y:5,630,992,X:1,872,503 NAD 83,ASP5)TIN,RIW, North Slope Borough,AK 12.CHECK THE APPROPRIATE BOX(ES)TO INDICATE NATURE OF NOTICE,REPORT OR OTHER DATA TYPE OF SUBMISSION TYPE OF ACTION ❑Notice of Intent ❑Acidize ❑Deepen ❑Production(Start/Resume) ❑Water Shut-Off ❑Ater Casing ❑Hydraulic Fracturing ❑Reclamation ❑Well Integrity ❑Subsequent Report 0 Casing Repair 0 New Construction p Recomplete ❑Other ❑Change Plans ❑Plug and Abandon m Temporarily Abandon ❑Final Abandonment Notice ❑Convert to Injection ❑Plug Back ❑Water Disposal 13. Describe Proposed or Completed Operation:Clearly state all pertinent details,including estimated starting date of any proposed work and approximate duration thereof If the proposal is to deepen directionally or recomplete horizontally,give subsurface locations and measured and true venial depths of all pertinent markers and zones.Attach the Bond under which the work will be performed or provide the Bond No on file with BLM/BIA.Required subsequent reports must be filed within 30 days following completion of the involved operations.If the operation results m a multiple completion or recompletion in a new interval,a Form 3160-4 must be lied once testing has been completed.Final Abandonment Notices must be filed only after all requirements,including reclamation,have been completed and the operator has determined that the site is ready for final inspection.) Request to extend temporary abandonment of Umiat Well#23H. The well was Inspected August 17,2015.The well was In good condition and no Issues were found.(photos attached) Malamute remains In contact with BLM field employee,Richard Kemnhtz.Richard is often on site and notifies Malamute of any Issues. See attached Operations Summary. Malamute requests extension of the temporary abandonment status for Umiat Well#15 and Well#23H.Both wells still hold potential to be economically and technically beneficial es Malamute works to develop the Umiat Oil Field.Data from both walls is being used In on-going technical evaluation and proposed research relating to producing oil from permafrost,stress Geld evaluation,and reservoir compartmentalization.Re-entry of either well could occur as a part of these Investigations.Given the cost of drilling wells at Umlat's remote location,Malamute believes It Is prudent to fully utilize the existing wells prior to plugging and abandonment.Neither the 518 nor the N23H will flow without assistance and the environmental risk posed by these wells Is very tow.Each well will be visually Inspected during the summer of 2018 or 2019. SCANNED MAY 2 3 2018 14.I hereby certify that the foregoing is true and correct. Name(Printed/Typed) Leonard Sojka President Tulle Signature Date 03/30/2018 •— ,THE SPA E FOR FEDERAL OR STATE OF10E USE ved by i_ . Broach Chief, Energy and Minera Date v/1/3 3 Conditi• '"of approval,if any, Cached.Approval of this notice does not warrant or certify the applicant holds or equitable title to those rights in the subject lease Oran which • le entitle the appli conduct operations thereon. Tide 18 U.S.0 Section 1001 and Title 43 U S.0 Section 1212,make it a crime for any person knowingly and willfully to make to any department or agency of the United States any false,fictitious or fraudulent statements or representations as to any matter within its jurisdiction. (Instructions on page 2) • • • Bureau of Land Management BLM 1.4,_ CONDITIONS OF APPROVAL FOR SUNDRY NOTICE—NOTICE OF INTENT ; ' '` Malamute Energy, Inc. `�`6. ''' r Umiat 23H-Temporarily Abandon Wellbore 'r'` This Form 3160-5 Notice of Intent to temporarily abandon the Umiat 23H well is approved, subject to the following conditions of approval. Project Specific Requirements _ 1. Temporary Abandonment [TA] status is granted for one yeareffective date is March 30, 2018. 2. Subsequent requests for TA status shall be made prior to the expiration of the previous approval. This is specified in 43 CFR 3162.3-4(c). 3. Should abnormal pressures be discovered on any subsequent inspection of this well, this office shall be notified within 24 hours of discovery. 4. Any undesirable events are subject to the requirements of NTL-2007-01-Alaska. Notification Requirements: All notifications and changes to the submitted Notice of Intent must be reported verbally or in writing to the following contact listed below at the BLM Alaska State Office, Branch of Energy: Name Position Email Work Phone Jessie Chmielowski Sr. Petroleum Engineer ichmielowskiablm.gov (907)271-4190 Mutasim Elganzoory Petroleum Engineer melganzoory@ablm.gov (907)271-4224 /iti0, April 16, 2018 ,Mutasim Elga ,.00ry Date BLM, Petroleu, Engineer i • Photos of Welt 23H—obtained from Richard Kemnitz 9/17/15 .444,- d 4 fi ,x€ •+ 7 - ' su.�r4'- w.a t, ,k F : . •44-1-t, --- ,it,r,-,:-..,..4„,....1 ,..- oe;:... 41,,‘,„ ..m•-.,, 41111/4, + t� ,,t..TMe 4 4 sem(t /� as 'y �'b''4i- � �+j'a'"'kt"�"�"�� g". ., t=,. + 0. ., °:•n J. 4,..t,—...--,tx 1Sc ti«t �S 'Y""-0,* r q Y I x,' a w ` b� ti 1, , g k '" 4 4. r,ly1 ,. ' gy�p6. ' `.4d'. �,. N\ ,t�' � ASF v/z=t' "'�1,,..4.4.4/.''''';,,,„, ' p ç �`"4� CP, a ,,i';::,i „:77,4",' ' yts" \ ," > �t. ,, w ae* ., , ,, 5 t '' I x" ;+Pyo -y�� d , j ,P;y • i >P r .xc. Y �' x1. �' ate:*`^e`4"),,—:_ ''' i m ,v.,, t. ! ! Umiat#23H Malamute Energy Operations Summary—Suspension as of May 2014 1. Fill wellbore w/6.8 ppg completion fluid(LVT-200 mineral oil). 2. Rig down ESP drive skip and surface whip. 3. Set BPV in tubing hanger. 4. Rig down Master Valve. 5. RD/MO Kuukpik k5 rig. 6. Nipple up Full Tree. 7. Fill tree w/Diesel for freeze protect and test to 1,500 psi. 8. Confirm all pressure 0 psi.Secure tree with gauges installed on IA and tubing. 9. Install permanent grating in well cellar. 10. Drape tree w/Herculite per BIM requirements and secure. 11. Rig down and suspended operations on Umiat 23H as of May 2014. • . : • --- -- - 's, ' milk- tral WI iiti 1 . 1,04,-„„.,,,,i.;•,:ik . %ft'''-''''4,41:'-i3,eftte- ;' ,i, f,'t'., . ' U rr i a t it 2 3 H , . ....Kam . '',,,,,,, 41,,,T-4,,w,....:.,rf,,,,,-,....-.:;•,,-;:.;, lt45Matri:,r, ' , • , .r.e.' %.",:‘4,•?:',-;::.;:;:',"", B.s,epyrowtet,Lot , t'', *- c,2,1'!.',,-;:•••,,,4:1,,z..--,,,,,rit,,,,,-,44; •Tel,44,10,,, Y -0.1.,...2,. , •AS Drilled -44".• s, '• • - ''':,,,,:,.'.4.1.-A,•1:2,4 40°1.,-.!..-„„ __ GL PI'AMISt2 t. ' * I 10G MO NW AMR AII III LI. DITDCL 31Cf ,/. 1150 if II A/A /A TT keine r mr r $044 if IAD 0100 . ....-* 4 kW , .-..... ,4 IV ND 4 Ion 4 TIT T ITU,VIC , .... I-S/St *1404040 *140 AN 011..• /A 191 ',1 AM•MS ws CASIVGMBING DATA t 44741:4a40'.(W1.0,11.44.K. -= V.T. 3. 4 T T 1, Cenor s n , 011.0441 I' 43/r 44 ss' 0 .0 Tk i T, 1.414e. i sir /I 7 SAA 011/Am , ;I A I . y•air IAA 140 In mos ism IAA• AIM ' II/A 1 1 frnM., i Tr ii 140 / I 0 nil 5/4 . AA A/W , CEMENT DATA .... 1 tt 14: . ,,,, , k ere , '.."'` ,. ' ' rs.”..ese 2V SO LW IAA , a In . Al no 0.1, 1.054. 4.4 4•0044rov 2.44,0 1144 III , LW , 0 kelma NI Ora* 5.401. OM 14.4 114 COMPLETION.1 SPY StlatisuUtY 1 '' . ..,,,„,-_, ..,..1,1,,..,,,,141,44„. 6..7-77-w..,,,,1,A-1,„,,t-„,,i,,,,,.,„-='—'• --''il°:.;',,;;.=..140 -'7,, , ,, . A !A t 114 4.044. 4 441.•PPM Va./034 4 1414.14.1,44 T ........, 4 ,..-. "..- 1444 9 4/11/1044 T -,. . ..,,...... ,,,,....,.,, ,•7% ,444. -elfo..t.,..z,,..:,:.:'.- : '.,':2,,,i.dit3 1.'4'.4..A Kiel— sg—iti.." . tA , r.:...--craz=,.....rmnar....... _ ........„ 7 1 ' VI , . .A., ,A, --„ morn ' :14.0.4.00441444 4,, An•r. 4 r ,071.1,40,Mr TVD , ,. *iit. — EMI= 1-lir LP,1,144'MD,SSW ND , Mill Slane*UNA/ : t 4 sk\....1,, IP uki 41":', 1 r—T 4, L; ri 4)Ta ----------------------- ----------- --------- -Aart ..65tear km ICA [1.47r US.13W1001 1.4itr,.../ Iv t J IC ousucyser VW 11;,;.„,..„...... Well Name U04.0 PM WELL HISTORY DESCRIPTION DATE _ ITEIASEP BP: Spud Det. 2/13/2011 9127/2013 E.Sayer! 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(.) w a < o 0 Q R U .+ J N d _ U E 5 aE N co EE ,°' C.7 a M 0 U 0 0 d • i Release of Confidential Data Coversheet Well Name: UMIAT 23H PTD: 213-020 E-Set: 24189, 24190, 24289 ✓ Physical data labeled with PTD, E-Set# Conf. entry: various ✓ Import CD data to RBDMS ✓ Confidential (incomplete) entry in Well Data List notes port to DigLogs via E-Set tab IN Scan labeled data V/Apply OCR text recognition V ave to Well Log Header Scans New "complete" entry in Well Data List notes Logged by: Meredith Guhl Fully logged: 4/25/2016 • • Guhl, Meredith D (DOA) From: Decker, Paul L(DNR) Sent: Monday, April 25, 2016 9:09 AM To: Guhl, Meredith D (DOA) Cc: Bettis, Patricia K (DOA); Davies, Stephen F (DOA) Subject: RE: Umiat 23H, PTD 213-020, Extended Confidentiality? Meredith, No, DNR has not received a request for extended confidentiality on the subject well. Regards, -Paul From:Guhl, Meredith D (DOA) Sent: Monday,April 25, 2016 7:34 AM To: Decker, Paul L(DNR)<paul.decker@alaska.gov> Cc: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov>; Davies, Stephen F (DOA)<steve.davies@alaska.gov> Subject: Umiat 23H, PTD 213-020, Extended Confidentiality? Hello Paul, Has Linc Energy Operations requested extended confidentiality for Umiat 23H, due for release after April 20, 2016? Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Suite 100,Anchorage,AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 1 t . 1 STATE OF ALASKA AleA OIL AND GAS CONSERVATION COM ION REQ SRT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations L Fracture Stimulate ❑ Pull Tubing H Operations shutdown Performed: Suspend Perforate ❑ Other Stimulate 1E1 Alter Casing ❑ Change Approved Program Plug for Redrill erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: S43fc^.Ce-•( L4--1( 2 2.Operator Linc Energy Operations, Inc 4.Well Class Before Work: 5. Permit to Drill Number: 5:45(JI.4;1 fit-. Name: Development ❑ Exploratory ❑✓ 213-020 ' 3.Address: 3000 C Street,Sute 103 Stratigraphic❑ Service [ 6.API Number: Anchorage,AK 99503 50-287-20029-00 ' 7.Property Designation(Lease Number): 8.Well Name and Number: FEDAA84141 ` Umiat#23H ar i if W> 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Exploratory (Umiat) , Uo&-cyyLQc Cl 0v 2 11.Present Well Condition Summary: OGCL Total Depth measured 4040 ' feet Plugs measured None feet true vertical 986 - feet Junk measured None feet Effective Depth measured 4040 feet Packer measured None feet true vertical 986 feet true vertical None feet Casing Length Size MD TVD Burst Collapse Structural Conductor 91 13-3/8" 91 91 3450 1950 Surface 1968 7-5/8" 1968 1260 6890 4790 Intermediate None None None None None None Production 1858 3-1/2" 1858 1266 10160 10540 Liner 2182 4-1/2" 4040 986 N/A(slotted) N/A(slotted) Perforation depth Measured depth N/A feet True Vertical depth N/A feet Tubing(size,grade,measured and true vertical depth) 3-1/2",9.3# L-80 1,858'MD, 1,266'TVD Packers and SSSV(type,measured and true vertical depth) None 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 2 Exploratory El ' Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑✓ i SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Contact Shawn Trasky Email Shawn.traskyt lincenergy.com Printed Name Shawn Trasky Title Environmental Project Manager Signature /Zr,, 1 ' �� Phone 907-375-2615 Date /'L,,J( � ' Form 10-404 Revised 5/2015 /6 RBDMS Nov4 215 Submit Original Only • 111, • RECEIVED 0 1111C NOV 2 3 2015 EI1ERGY AOGCC Linc Energy Operations, Inc. 3000 "C" Street, Suite#103 Anchorage, Alaska 99503 November 19, 2015 Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry Application (Well Suspension) Well: Umiat#23H (Existing Exploratory Oil Well) TRS: Sec. 32 T 1N, R 1W, Umiat Meridian Dear Chairman Foerster, Linc Energy Operations, Inc. hereby applies for a Sundry Approval to continue the Suspension of the Umiat #23H Oil Exploration Well. Linc is currently evaluating the future utility of this wellbore based on the results of the flow testing initiated on March 27, 2014. Some options that will be evaluated for the future exploration seasons include continued flow testing or a rotary side track. Linc is also looking at other possible artificial lift methods other than the ESP pump that was run in the well for the 2013-14 season. On August 17th, 2015 Well#23H was inspected. There were no viable leaks; the rain cover looked to be in good condition. The top of cellar box is 6 feet from ground level and there is a 24 inch wide ditch around cellar box. The grating on top of the cellar is in good shape. The cellar box is water tight and has approximately 4 feet of water in it. There were no visible weeps at flange connections. The 7-5/8 x 3-1/2 gauge read zero when opened. The wing valve gauges read zero and the top cap gauge read zero. All valves, needle valves and gauges worked properly and the down hole pump electrical connection looked good. Pertinent information attached to this application includes the following: 1) Form 10-404 Sundry Application 2) Photos of Well 23H 3) Plat showing location of the well i • The following is Linc Energy's designated contacts for reporting responsibilities to the AOGCC: 1) Shawn Trasky 907-375-2615 If you have any questions or require further information, please contact Shawn Trasky at 907-375-2615. Sincerely, Shawn Trasky Environmental Project Manager 4 4111 • 014. � gg IA i1 Wiz"' an..'r' t- N � i 3 0) ; ,1 1 a x u' Z`:.:1 .1 CO m ` til CO d o t4 � >W Y C > l �, y, '4 66J W O Z —{ �� �t 41I M r, c Z in' 41 o " Z 12) #{' x S y D .. N L1 X N -' C N ♦�i�f q►I q .-µ. a.,,,. O O ♦ N ♦1 q N ♦ .., . co 0 r • Z •,. -. - q'qqf fff►««�t V I GSA ._ - f .'i .. .. * i • uta".# 4.,,,..:.,,,,z4,..- ^� s..�� \ ,,.,,,r;:..,, 'Cc.,,)--�� a tea- R. uc0 E o in T) `*Ilk iifgf - .. _ O i E _c N _. as s �� s iCI ,— CO ...444 11 �l i .. ♦ .,. „,. .., . �� v ,.,, _, .,,, ,, .,,,, l ;.-,„ c c > Pr � � 03 .�� f (6 ,!‘1? 'O w "O Ng L U 0 -cs C N -77, OJ J d ,:il a 1 u> > rn a Y ' � ' 1ti) -Ll f0 2 (0 Cc cu in .. 'r to Z__l N N U C C N Q O E o o a) x 'x (,) a CO '•`. N N J W W LL Z (4 t • • C) 0O :�s • • Bettis, Patricia K (DOA) ? 1� / 3 -(1 () From: Colombie,Jody J (DOA) Sent: Friday,July 31, 2015 2:14 PM To: Seamount, Dan T (DOA); Foerster, Catherine P (DOA); Bettis, Patricia K (DOA);Wallace, Chris D (DOA) Cc: Carlisle, Samantha J (DOA); Singh, Angela K (DOA) Subject: FW: Linc/Jim Hutchinson/Contact Information Attachments: Jim Hutchinson.vcf Angela, please update books. Thank you! fyi From: Parker, Kyle [mailto:KParker@crowell.com] Sent: Friday, July 31, 2015 2:12 PM To: Colombie, Jody J (DOA) Cc: Mayberry, David Subject: Linc/ Jim Hutchinson / Contact Information Good afternoon,Jody. I spoke with Jim Hutchinson, senior counsel with Linc based in Houston,just after lunch today. Jim is going to prepare a letter formally updating AOGCC, DNR and DEC with the new point of contact for Linc, Michael Mapp. Jim will also include his contact information on the communication (I have included his information here too). Jim said he will have that out to everyone on Monday. I will follow-up with him to make sure this is done first thing Monday morning our time. Have a good weekend. See you soon. Thank you.—Kyle. Jim Hutchinson Linc Energy Counsel (713)580-6600 Work (713) 580-6606 Direct'Work (281)224-4472 Mobile jim,hutchinsonclincener€gy.corri 1000 Louisiana Street Suite 1500 Houston,Texas 77002 1 • • Bettis, Patricia K (DOA) I" ± 3 --ork,3 From: Bettis, Patricia K (DOA) Sent: Friday,July 31, 2015 11:10 AM To: Colombie,Jody J (DOA) Cc: Regg, James B (DOA);Wallace, Chris D (DOA) Subject: FW: Limc Energy contacts: Umiat Wells DEC just forwarded this email to me. Hopefully, Kyle Parker can provide a more definite contact. Patricia From: Geoff MacKenzie [mailto:geoff.mackenzie@lincenergy.com] Sent: Friday,July 31, 2015 10:00 AM To: Evans, Mike R (DEC)<mike.evans@alaska.gov> Cc: Shawn Trasky<shawn.trasky@lincenergy.com>; anna.kohl@hdrinc.com; Byron Brooks <byron.brooks@lincenergy.com> Subject: Limc Energy contacts Hi Mike Michael Mapp just spoke to me and asked that I supply contact details relating to our works in Alaska. We are currently performing a range of tasks related to continued environmental studies on the Umiat Project. Our primary contact in Anchorage is Shawn Trasky(Environmental Project Manager). Shawn is currently on maternity leave but will be returning from 08 September. In her absence, Anna Kohl from HDR is assisting us with project management support. An Environmental Engineer from our Australian office will be in Anchorage for two weeks from next Monday and if required he could also meet with you. For contact details going forward I would use: 1) Shawn Trasky(907 351 3566) or Anna Kohl (907 727 9436) 2) Zac Scotton (HSEC Advisor—Houston)+1713 580 6600 3) Geoff MacKenzie -contact details below. The email addresses are with this email. cheers • Geoff MacKenzie Manager Safety & Environment P +61 7 3229 0800 M +61 437 774 255 E geoff.mackenzie@lincenergy.com 1 • S 'egg disclaimer Notice: The message and attachments} contained in this e mail are intenIiiillik... -''.' ---,;.•••11•Alitt'i"AllE",'-.hillivoof,40•4ile..4,•K'•.:•'4- _ II ded for the named recipients} only. It may contain privileged or confidential information or information which is exempt from.disclosure under the applicable laws..If you are not the intended recipient, you must not read, print, retain, copy, distrbute,forward or take any action in relance on it or its attachment(s). If you have received or have been forwarded this e-mail in error, please notify us immediately by return e-mail ore mail Iinc@ilincenergv.com and delete this message from the computer in its entirety. Internet communications cannot be guaranteed to be secure and error free as the information could be intercepted, corrupted, lost, arrive late or contain viruses. The sender and this Company therefore do not accept any liability or responsibility of whatsoever nature in the context of this message and its attachments) which arises as a result of Internet transmission.Opinions,conclusions,representations,views and such other information in this message that do not relate to the official business of this Company shall be understood as neither given nor endorsed by it. 2 `' 0 • Bettis, Patricia K (DOA) ?1-.6 a)3 —o 9,D From: Shawn Trasky <shawn.trasky@lincenergy.com> Sent: Monday, May 04, 2015 7:56 AM To: Bettis, Patricia K (DOA) Cc: Guhl, Meredith D (DOA) Subject: RE: Linc Contact for Umiat 18 and 24H Wells (PTD 213-014 and 213-020) I will be the contact for anything related to oil and gas. 3000 C Street, Suite 103 Anchorage, AK 99503 907-375-2615 907-868-8881 fax Shawn.trasky@lincenergy.com Shawn Trasky 11 0 Environmental NEPA Coordinator 1) 907-375-2615 M 907-306-2129 E shawn.trasky@lincenergy.com Disclaimer Notice: The message and attachment(s) contained in this e-mail are intended for the named recipients) only. It may contain privileged or confidential information or information which is exempt from disclosure under the applicable laws. If you are not the intended recipient, you must not read, print, retain,copy, distribute,forward or take any action in reliance on it or its attachment(s). If you have received or have been forwarded this e-mail in error, please notify us immediately by return e-mail or e-mail linc©lincenergy.com and delete this message from the computer in its entirety. Internet communications cannot be guaranteed to be secure and error-free as the information could be intercepted, corrupted, lost, arrive late or contain viruses. The sender and this Company therefore do not accept any liability or responsibility of whatsoever nature in the context of this message and its attachment(s) which arises as a result of Internet transmission.Opinions,conclusions, representations,views and such other information in this message that do not relate to the official business of this Company shall be understood as neither given nor endorsed by it. From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Friday, May 01, 2015 1:40 PM To: Shawn Trasky Cc: Meredith Guhl (meredithguhl@gmail.com) Subject: Linc Contact for Umiat 18 and 24H Wells (PTD 213-014 and 213-020) Good afternoon Shawn, Linc Energy Operations Inc. needs to provide a current contact for correspondence concerning the Umiat 18 and Umiat 24H exploratory wells. This update should include mailing address, email address, telephone and fax numbers. Patricia Bettis 1 • Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettisCalaska.gov. 2 c 13-020 • • Linc Energy Operations, Inc. Alaska Division (11)- ' EDERGY 3000 C Street, Suite 103 Anchorage, Alaska 99503 Phone: (907) 868-8660 Fax:(907) 868-8881 DATA TRANSMITTAL Date: January 22, 2015 To: Attn: Meredith Guhl, Geologist From: Dave Boyer, Petroleum Geologist Alaska Oil&Gas Conservation Commission Linc Energy Operations, Inc. 333 W.7th Ave., Suite 100 3000 C Street, Suite 103 Anchorage, AK 99501 Anchorage, AK 99503 Phone: (907) 793-1235 Phone:(907) 375-2623 Cell.: (907)887-1387 TRANSMITTAL DESCRIPTION Missing Umiat 18 Best DT* Final Result Wireline Log and Canrig 5" MD Mudloq - 2 3)—\ In accordance with Alaska Statute AS 38.05.035 (a)(8)(C) and Alaska Administrative Code 11 AAC 96.220, Linc Energy Operations Inc. requests that confidentiality be extended to the information described herein and submitted with this transmittal. Qty. Description 1. Schlumberger Best DT* Final Result Log (Custom Sonic Processing)for Umiat 18 2. Canriq 5" Measured Depth Mudloq Format for Umiat 18--- 2.31-k. RECEIVED ��----' .14,1\1 9 2 2015 Received By: Angela IC. Jifgh Date: AOGCC Returned to Linc Energy Operations, Inc. Date: Accepted By: 463 FSL T1N MDG 5/18/2021 • • 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes No If yes, list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if needed, Permafrost-Top 0 0 and submit detailed test information per 20 AAC 25.071. Permafrost-Base 980 980 Nanushuk 230 230 Tested perforated interval from Top of Slotted Liner:2,062'MD/1,246'TVD to bottom of Slotted Liner: 3,994'MD/986'TVD. Lower Grandstand Upper Grandstand 369 369 Tested the well for a total of 140 hours with a total of 644 bbls produced.4 separate build up,flowing periods and shut-ins were completed. Middle Grandstand 597 597 Lower Grandstand 722 722 Torok 1038 1038 Formation at total depth: 2,600 2,515 Torok 31. List of Attachments: As Drilled Schematic, Final Surveys,MW vs.Depth Chart,Operations Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Zach Sayers Email:_Zach.Sayers(a7lincenergy.com Printed Name: Zach Sayers Title: Drilling Manager-North America i cISignature: G —� Phone: 713-580-6612 Date: 7 /9 7/ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 b: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 • • RECEIVEU MAY 192014 (;) (AERGY AOGCC Linc Energy Operations, Inc. 3000 "C" Street, Suite #103 Anchorage, Alaska 99503 May 19th, 2014 Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Well Completion Report Well: Umiat#23H (Existing Exploratory Oil Well) TRS: SWSW, TIN, R1W, Section 32, Umiat Meridian Dear Chairman Foerster, Linc Energy Operations Inc. hereby submits a Well Completion or Recompletion Report and Log for well Umiat #23H, an onshore Exploratory Oil well on BLM land 1 mile north of the Umiat Camp Runway. Please find attached information as required by 20 AAC 25.070 (3) for your review. Pertinent information attached to this submission includes the following: 1) Form 10-407 Well Completion or Recompletion Report and Log 2) Operations Summary 3) Actual Wellbore Diagram 4) Mud Weight vs Depth Chart 5) Conductor As-Built The following are Linc Energy designated contacts for reporting responsibilities to the Commission: 1) Drilling and Completions Zach Sayers, Drilling Engineer (907) 375-2603 2) Geologic Data and Logs David Boyer, Geologist (907) 375-2623 • • In accordance with Alaska Statute AS 38.05.035 (a)(8)(C) and Alaska Administrative Code 11 AAC 96.220, Linc Energy Operations, Inc. requests that confidentiality be extended to the information described herein and submitted with this transmittal. If you have any questions or require further information, please contact either Zach Sayers, Drilling Manager at (713.580.6612) or David Boyer, Senior Geologist at (907.375.2623). Sincerely, ,Army Zach Sa - - c� Drilling Manager— North America 463 FSL T1N MDG 5/18/2021 • • • 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS TiNAME MD TVD Well tested? T Yes No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if needed, Permafrost-Top 0 0 and submit detailed test information per 20 AAC 25.071 Permafrost-Base 980 980 Nanushuk 230 230 Tested perforated interval from Top of Slotted Liner:2,062'MDI 1,246'TVD to bottom of Slotted Liner: 3,994'MD/986'TVD. Lower Grandstand Upper Grandstand 369 369 Tested the well for a total of 140 hours with a total of 644 bbls produced.4 separate build up,flowing periods and shut-ins were completed. Middle Grandstand 597 597 Lower Grandstand 722 722 Torok 1038 1038 Formation at total depth. 2,600 2,515 Torok 31. List of Attachments: As Drilled Schematic,Final Surveys,MW vs. Depth Chart,Operations Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Zach Sayers Email: Zach.Sayersa.lincenergy.com Printed Name: Zach Sayers Title: Drilling Manager-North America Signature: �e.i Phone: 713-580-6612 Date: Sit 7r7/ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1b: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal.Water Supply for Injection,Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26 (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain) Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30. Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 • • Pad: Umiat#23H Ice P.-,. -ci Umiat #23H s Lease: AA-084141(BL Tree Connection: Well Type: Exploration Base of Permafrost: 801'MD/793'TVD GL: 575'AMSL ‘ / 7. •? HOLE DATA RIG RKB: 596'AMSL 1 O e tc I "° g '•._ p(MD) Btm(MD) Top(ND) Btm(TVD) Mud Wt Max angle RKB-GL: 21' �, n _,„ia,_ ,_-,ft. ft ft a ft type ppg deg Conductor 20" 0' 91 0' 91 N/A N/A 0° 13-3/8" ---Surface 9-7/8"9-7/8" 0' 1968 0' 1260 OBM 8 100° 91'ND Production 6-3/4" 1858 4040 1266 986 OBM 7.5 102 FIT=10.1 ppg LOT=10.6 ppg CASING/TUBING DATA ..wiiiiiiilaiiiiiitiiiiiiiiiiiiiiiiiliiiiiiiiiiMiliiiiii"' al Conductor CIO681-55 -PE 12.415" 0 91 0' Surface El 29.7 1-80 BTC MOD 6.875" 0' 1968 0' Production rila 2.6 L-80 I8T-MOD 3.958" 1858 4040 N/A Tubing ® 9.3 L-80 8 Rd 2.958" 0' 1858 N/A CEMENT DATA ,„Mil MIR Vol . - _ _-. ail® Conductor CZ Permafrost 23'(AL) 100' 15.7 0.93 43 260 Surface In Permafrost 23'(GLI 1,594' 11.0 1.87 Surface ® Class G 1,594' 1968 15.8 1.16 COMPLETION JEWELRY SUMMARY Item Description Depth ID OD Install Date it - ft in in - 1 Tubing Hanger Proposed 2 Baker ZXP LTP Proposed 3 Baker ESP Pump 1848 Proposed 4 5 6 7 IIIII 7 MI L. 1,280'ND Lower 1' Grandstand,928' VD FIT=11.0 ppg 971'MD,928'ND - -- 40";.tri's iiA-�t,>. 4-1/2"LTP,1,858'MD,1,260' 4-1/2" Slotted Liner 3 11 7 2 Base LGS 1,370'MD,1,260'TVD 7-5/8" TOE TO 4,040'MD/986'ND TO:1,968'MD/1,260'TVD ---- DATE REVISED BY: WELL HISTORY DESCRIPTION Well Name Umiat tt23H 9/27/2013 Z.Sayers Proposed Lower Grandstand B-sand Horizontal Slotted Liner ESP Completion Spud Date 2/15/2014 10/30/2013 Z.Sayers Update to WP#9 API No. 50-287-20029-00 3/15/2014 Z.Sayers Update to Actuals PTD 213-020 Max Hole Angle 102 Max Dogleg 8 • UMIAT#23H UMIAT #23H Depth MW Feet ppg Mud Weight vs. Depth 0.0 7.7 0.0 97.0 7.7 -UMIAT#23H 300.0 7.8 ._ 382.0 7.8 704.0 7.9 1024.0 7.9 1285.0 7.9 1280.0 8.0 1257.0 7.3 996.0 7.5 L 986.0 7.7 a 600.0 8.2 To 8.3 8.3 j 8.3 3 - 8.4 8.5 - 8.5 8.6 - 8.8 8.9 1200.0 - 9.0 9.2 Lateral section 6.5 7.5 8.5 9.5 Mud Weight(ppg) • • UMIAT #23H Mud Weight vs. Depth 0.0 -UMIAT#23H 600.0 M a a U u N H 1200.0 — Lateral section 6.5 7.0 7.5 8.0 8.5 9.0 9.5 Mud Weight(ppg) • • Linc Energy Operations • EIIERGY 2014 Exploration Project Well #23H, Umiat, Alaska 23H Summary of Operations: 1-28 to 3-28-14 PTD No. 213-020 (All depths RKB unless labeled otherwise) 1/28/14: Set Matting Boards on 23H pad. Move sub-base onto location with Steigers. 1/29/14: Continue rigging up on 23H. Spot Mats, move sub-base, attempt to raise derrick. 1/30/14: Remove faulty hydraulic cylinder from below derrick. Send to Anchorage for testing and rebuild. Continue RU of remaining loads to 23H pad. 1/31/14: Hook up degasser, Line up mud pre-mix lines. Worked on a containment berm and organized pad 23H. 2/01/14: Complete installation of modified nipple on well head. Started the nipple up of the diverter. 2/02/14: Set starting flange onto wellhead. 2/03/14: Perform Mock Spill Drill with Environmental regulators. Flange up Diverter on well conductor pipe. 2/04/14: Transfer Drill Pipe from Seabee Pad to 23H. Move GCI communication Trailer to 23H. Continue to rig up Pason system, energize#1 boiler. 2/05/14: Continue waiting on raising hydraulic ram to arrive. Wire in and test dewatering house. Prep boiler#2 for insulation. Install flow line. 2/06/14: Continue waiting on raising hydraulic ram to arrive. Troubleshoot and fire up #2 boiler. Connect rig electrical interconnects. 2/07/14: Installed raising ram. Raised rig floor. Stacked modules up on top of sub-base. 2/08/14: Stacked modules up on top of sub-base. Rigged up interconnects. Set pipe shed in place. 2/09/14: Rigged up pipe shed. Raised derrick. Rigged up gas-buster. Performed general housekeeping around the rig. 2/10/14: Rig up top drive torque rail, service loop, and kelly hose. Set Drill Cool units in place. 2/11/14: Nippled up hydril, pitcher nipple, and flow line. Continue rigging up rig. Final Well Report Page 1 • • • Linc Energy Operations 2014 Exploration Project Well #23H, Umiat, Alaska 2/12/14: Load pipe shed with 58 jts 4-1/2" drill pipe and 19 jts of HWDP. Set support offices around the rig. Repaired mud pumps. 2/13/14: Removed and replaced #3 fluid end on #1 mud pump. Shut down heavy equipment operations due to extreme cold temperatures. 2/14/14: Hydro-test pit system. Pick up drill pipe and rack back in the derrick. Test diverter system. 2/15/14: Spud well 23H @ 18:45 hrs on 2/15/14. Mud pump discharge damper failed. Repair discharge damper and replace swabs/liners in #1 mud pump. 2/16/14: Drill to 300' to facilitate picking up logging tools. Make up logging tools. Shallow hole test LWD tools. 2/17/14: Make up 9 7/8" build assembly. Drill ahead to 382' MD. Pull tight and stuck at 308' MD. Work pipe. 2/18/14: Jar and work stuck pipe. Lay down fishing jar. Continue working pipe with no result. 2/19/14: Preventative maintenance on rig equipment. Prepare rig floor and pipe shed for fishing operations. 2/20/14: Fish radioactive source out of ADN-6. Back off pipe and NMDC from drilling assembly. Screw into,jar free, and retrieve drilling assembly. 2/21/14: Lay down fishing tools and fish. Service rig. Cut drilling line. Pick up drilling assembly. 2/22/14: Drill 9 7/8" hole to 583' MD. Shut down to repair HPU coupling. 2/23/14: Repair HPU. Continue drilling 9-7/8" hole to 1,025' MD. 2/24/14: Trip in the hole with new bit. Drill ahead in build section from 1,031' MD to 1,160' MD. 2/25/14: Drill ahead from 1,160' to 1,390' MD.Trip out 4 stands and run back in with HWDP for push pipe. Drill from 1,390' to 1,490' MD. 2/26/14: Change out swab on #2 mud pump. Drill and land surface section in pump tangent from 1,490' to 1,713' MD. Final Well Report Page 2 • • Linc Energy Operations • 2014 Exploration Project Well #23H, Umiat, Alaska 2/27/14: Drill ahead from 1,713' to 1,787' MD. Troubleshooting SCR room for high heat. Drill from 1,787' to 1,894' MD. 2/28/14: Drill ahead from 1,894' to section TD of 1,980' MD. Back ream out of hole in preparation for upcoming logging job. 3/01/14: Pick up logging BHA. Trip in hole from 373' to 1,980' MD. MAD pass from 1,980' to 246' MD. Lay down logging BHA. 3/02/14: Make Up 7-5/8" casing and run in hole to TD 1,980' MD. Circulate and condition mud in preparation for surface cement job. 3/03/14: Rig up and pump surface cement. Cement returns observed at surface by BLM rep 1)' //4C7 /// Justin Miller. Pump 112 BBL 11 PPG Litecrete. Pump 32.2 BBL 15.8 PPG Class G / Cement. Drop top plug. Displace with rig 85.9 BBL 8.0 PPG Versaclean. Cement back to surface 40 BBL into displacement. Bump plug 85.9 BBL into displacement. i-45.9 BBL cement back to surface. Cement in place at 02:44 hrs. Bump plug and pressure to 1700 psi for 15 minute casing pressure test. Good. Bleed off and check floats. Good. Nipple down diverter and line. Nipple up BOPE. 3/04/14: Continue to nippling up BOPE. Lay down 4-1/2" drill pipe. 3/05/14: Continue laying down 4-1/2" drill pipe. Test BOP equipment to 250 psi low, 1,500 (7t� psi high for 10 minutes each test. BLM test witness Justin Miller. AOGCC witness waived by Guy Schwartz. 3/06/14: Service rig. Make up 6-3/4" drilling BHA. Shallow test LWD. Run in hole to 1,786' MD. 3/07/14: Run in hole from 1,786' to 1,876' MD. Drill out shoe track and 20' of new formation to 2,000' MD. Perform FIT to 11.0 ppge. Swap drilling fluids to production system. Drill ahead from 2,000' to 2,287' MD. 3/08/14: Drill from 2,287' MD to a total depth of 2,973' MD. 3/09/14: Drill from 2,973' MD to a total depth of 4,100' MD. Begin to backream out of hole. 3/10/14: Backream out From 4,100' to 775' MD. Circulate bottoms up on first three stands. Hole clean. Trip in hole to TD. 3/11/14: Backream out From 4,100' to 700' MD. Cut and Slip Drill Line. Trip out of hole, and lay down BHA. Final Well Report Page 3 • • Linc Energy Operations 2014 Exploration Project Well #23H, Umiat, Alaska 3/12/14: Pick up 4-1/2" slotted liner and 2-3/8" inner string. Run in hole with 4-1/2" slotted liner. 3/13/14: Ream liner down on drill pipe. Set liner at 4040' MD. Liner top at 1,858' MD. Trip out, lay down inner string. 3/14/14: Continue to trip out of hole with 2-3/8" inner string. Lay down Baker equipment. Swap upper ram from 4" fixed to 3 1/2" fixed. Test BOPE. 3/15/14: Run 3 1/2 tubing string to just above liner top. Rig up slickline. Run in and swab well with slickline swab assembly. 3/16/14: Swab well with slickline swab-cup assembly. 3/17/14: Swab well in with slickline swab-cup assembly. Trip out from swabbing run. Pick up, ESP completion assembly. 3/18/14: Swab well in with slickline swab-cup assembly. Trip out from swabbing run 3/18/14: Pick up ESP completion assembly. Run ESP completion. Nipple down BOPE. 3/19/14: OPE. Nipple down BOPE, Nipple up tree.. Install ESP power/communication cord. 3/20/14: Pressure test PTS hardline. Flow test well. 3/21/14: Shut in for well bore for buildup rate data. Flow test well. ie/ 3/22/14: Flow test well. 3/23/14: Flow test well. Shut in for well bore for buildup rate data. Flow test well. 3/24/14: Flow test well. Shut in for well bore for buildup rate data. 3/25/14: Shut in for reservoir build up data. 3/26/14: Shut in for reservoir build up data. .I' 3/27/14: Shut in for reservoir build up data. Pump produced fluids into IA back into lj'` � reservoir. Install BPV in tubing spool. `1` 7/ 3/28/14: Pump produced fluids into IA back into reservoir. 6 (e- Final Well Report Page 4 • r • • • DATE CLOCK 'TUBING TUBING STATIC DIFF. METER LIQUID TANK TANK TANK WATER' OIL MUD COMMENTS TEMP PRESS. I/A DHP PRESS. PRESS. TEMP METER TOTAL GAIN FLOW CUT API WEIGHT MM/DD/YY HH/MM F prig t psi(g) psi(g) BBL BBLS BBLS INTO % _ 3/20/2014 12:58 Open the well to PTs 0 17 shut 0 60 0 0 1 0 n/a 0 1:00 32 17 in n/a 9 0 60 0 0 1 0 n/a 7.3 1:30 32 19 268 10 0 53 6 22 6 1 0 n/a 7.3 2:00 Tank started with 16 Ms. 32 21 266 16 0 56 15 33 10 1 0 n/a 7.3 2:30 cut heater off in separotor 30 23 264 14 0 70 20 38 5 1 0 n/a 7.2 _ 3:00 LTV INCREASES IN SAMPLE 36 21 261 16 0 59 28 45 7 1 0 n/a 7.2 3:30 31 20 258 14 0 55 37 56 11 1 0 n/a 7.0 400 31 18 254 13 0 52 46 64 8 1 0 n/a 6.9 4:30 turn heater on 38 20 250 13 0 62 57 73 9 1 0 n/a 6.9 5:00 32 18 245 12 0 62 71 82 9 1 0 n/a 6.9 5:30 33 18 239 12 0 64 85 89 7 1 0 n/a 7.0 6:00 37 17 236 11 0 65 97 96 7 1 0 n/a 7 6:30 38 18 231 12 0 65 109 103 7 1 0 n/a 7 7:00 35 17 231 11 0 62 120 108 5 1 0 n/a 7 730 37 19 229 12 0 64 129 115 7 1 0 38 7 _ _ 8:00 _ _ 29 20 228 11 0 62 141 121 6 1 0 n/a 7 8:30 27 20 225 11 0 62 153 126 5 1 0 37 7 9:00 30 18 223 11 0 64 162 131 5 1 0 37 7 9:30 28 17 224 10 0 62 172 136 5 1 0 37 7 15:00 26 19 221 10 0 62 180 142 6 1 0 37 7 10:30 25 20 220 12 0 65 188 147 5 1 0 37.5 7 11:00 28 19 220 11 0 66 195 151 4 1 0 37.5 7 11:30 pump goes down @ 11:27 32 9 0 10 0 66 202 154 3 1 0 37.5 7 3/21/2014 12:00 pump back on line @ 11:46 22 9 223 2 0 70 202 154 0 1 0 37.5 0 12:30 making 1%h20 27 20 217 11 0 67 210 159 5 1 1 37.5 7 1:00 made tank corrections 1.754 per inch. 29 17 217 10 0 67 218 165 6 1 1 37.5 7 1:30 fluid rate decreasing. 27 22 217 14 0 70 223 168 3 1 1 37.5 7 2:00 fluid rate increased to 5.25 27 23 220 14 0 70 234 173 5 1 1 37.5 7 2.30 no water to surface. 27 23 204 15 0 70 244 178 5 1 0 37.5 7 3.00 still making 2%mud. 26 22 201 14 0 70 255 184 6 1 0 37.5 7 3.30 checked the tanks for open valves. 25 21 199 13 0 68 264 189 5 1 0 37.5 7 400 rates decreased to 3 bls. 25 20 195 11 0 68 271 192 3 1 0 37.5 7 4:30 still making 1%mud. 25 20 195 12 0 67 278 196 4 1 0 37.5 7 5:00 28 19 193 12 0 70 285 199 3 1 0 37.5 7 5;10 Well shut in@tree • r LINC ENERGY WELL 23H SECOND FLOWBACK DATE CLOCK TUBING TUBING STATIC DIFF. METER LIQUID TANK 11NK Tank WATER (WWI Mud Tank'Tank Tank Tank Tank Tank Tanks 7-14 COMMENTS TEMP PRESS. I/A PRESS. PRESS. TEMP METER TOTAL ,.111 flowing % Weight empty MM/DDM' I171/ISBN F PsW psi(g) psi(g), BBL BBLS BBLS into 1 2 3 4 5 6 this:. time 321/2014 5:04 Start pump up 30 10 0 4 0 100 0 0 0 4 0 1.e 0 201 70 46 257 282 0 trace of 5:30 24 7 0 ( 10 0 87 0 0 _ 0 4 0 n/a 0diesel in all 6:00 5:42 Liquid to surface Ramp pump up 29 19 0 '2 { 11 0 61 8 3 3 4 0 7.0 6:30 31 17 0 r': l 11 0 76 12 5 2 4 0 37.5 6.9 7;00 31 19 0 _r.,2 12 , 0 70 167 2 4 0 7.2 7:30 30 23 0 17 0 60 19 10 3 4 0 7.0 _ 8:00 28 _ 24 0 - 17 0 60 21 15 5 4 0 37 9 7.0 8:30 jill 29 29 0 22 0 56 25 15 0 4 0 7.0 9:00 5%Mud in the water cut 28 21 015 0 54 29 19 4 4 0 7.0 _ 9:30 Light trace of gas to surface. 29 26 0 19 0 50 39 22 3 4 0 -f 7.0 10:00 api 37.5 29 25 0 18 0 48 46 22 0 4 0 6.9 10:30 7%Of solids in the water cut. 29 24 0 ' 18 0 46 55 26 4 4 0 6.9 11:00 14410i61Bt 110 1;,d 29 23 0 `1i 15 0 44 63 35 9 4 0 7.0 11:30 3%mud 27 22 0 -1F 15 - 0 52 _ 69 36 - 1 4 0 7.0 322/2014 12:00 No•as to surface 27 22 0 -1/7 14 0 58 74 40 4 4 0 7.0 12:30 3%mud 27 22 0 .-1:' 15 0 60 80 43 3 4 1 00 api 37.5 3/3% 26 21 0 14 0 64 86 45 2 4 0 7.1 1 30 WT.#7.1 no traces algae 24 21 0 14 0 68 91 49 4 4 0 7.1 2:00 Took the_4 hour o8$.M M. 24 20 0 12 0 68 96 51 2 4 0 _ .. 7.1 2:30 23 17 0 10 0 67 100 52 _ 1 4 0 7.1 3:00 5%mud in sam•le 22 15 0 6 _ 0 _ 70 102 54 2 4 0 7.1 3:30 15 14 0 5 0 64 102 56 0 4 0 .. 0 , 4:00 4:15 inc.pump rate,getting returns. 13 13 0 5 0 64 102 56 0 4 0 0 4:30 5%mud in sam le 23 39 0 1 L 28 0 60 115 61 5 4 0 0 5:00 25 33 0 1` 25 0 60 131 68 7 4 0 7.0 , , 5.30 23 21 0 1` 7 0 64 142 71 3 4 0 7.0 6.00 API 37 22 20 0 IL 6 0 63 142 71 0 4 0 7.0 6:30 Obtained samipe for Lino 22 22 0 1- 11 0 69 152 77 6 4 0 7.0 7:00 21 18 0 1' 11 0 69 15581 4 4 0 7.0 7:30 25 25 0 .1r 13 0 62 168 89 8 4 0 7.0 8:00 API 37 27 29 0 '1,: 14 0 64193 96 7 4 0 7.0 8:30 26 30 0 ':1,. 21 0 64 201 103 7 4 0 7.1 9.00 wheatherford is ullin sam les 24 34 0 1: 25 0 48 209 106 3 4 0 n/a 9:30 24 39 0 •1: 30 _ 0 50 217 111 5 4 0 n/a 10:00 27 37 0 %1:' 29 0 56 230 117 6 4 0 n/a 10.30 25 36 0 "1-: 27 0 50 241 121 4 4 0 n/a _ 11:00 27 36 0 1- 28 0 48 253 126 5 4 0 n/a 11.30 28 36 0 '-.- 28 0 46 262 129 3 4 0 n/a • 12:00 We resume testing. 30 36 0 29 0 46 273 135 6 4 0 7.1 12.30 31 36 0 30 _ 0 50 283 140 - 5 4 0 7.1 13:00 30 36 0 30 0 58 295 144 4 4 0 70 • 13:30 29 37 0 30 060 306 149 5 4 0 7 0 14:00 29 39 0 29 0 64 318 154 5 4 0 7.0 14'30 27 37 0 30 0 62 328 159 5 4 0 7.0 15'00 25 38 0 29 0 60 340 163 4 4 0 7.0 • 15.30 27 38 0 29 0 48 352 169 6 4 0 7.0 16.00 Good and steady flow 28 37 0 29 0 46 363 173 4 4 0 7.0 • • 16:30 30 37 0 30 0 44 374 178 5 4 0 7.0 17:00 28 37 0 ^ 30 0 43 397 182 4 4 0 7.0 17:30 Trace of mud. 28 37 0 30 0 40 397 186 4 4 0 38 7.0 18.00 28 37 0 30 0 52 409 192 6 4 0 7.0 18.30 28 38 0 30 0 56 421 196 4 4 0 7.0 19:00 25 38 0 _ 30 0 60 435 201 5 4 0 38 7.0 19:30 24 38 0 - 30 0 62 443 205 4 4 0 7.0 20:00 3%mud in the sample point. 26 38 0 30 0 57 453 210 5 4 0 7.0 3/22/2014 20:30 , 26 38 0 ' 31 0 48 466 215 5 4 0 38 7.0 21.00 29 21 0 15 0 45 475 219 4 4 0 7.0 2110 , API 38.1%mud. 28 22 0 14 0 44 480 221 2 4 0 7.0 22.00 Took the 4 hour oil sample. 29 20 013 0 58 484 222 1 4 _ 0 38 7 0 22:30 28 20 0 '^`."...... 12 0 61 487 226 0 4 0 7 0 - 2300 , 24 21 0 12 0 50 490 226 04 0 7.0 23:30 25 22 0 13 0 60 493 229 3 4 0 38 7.0 3/23/2014 0:00 Good flow with no leaks. 24 20 0 11 0 64 497 231 2 4 0 7.0 0:30 , 23 20 0 11 0 65 499 231 0 4 0 7.0 1:00 24 18 0 10 0 68 502 235 4 4 0 38 7.0 1'.30 27 19 0 12 0 54 505 236 1 4 0 7.0 2:00 26 17 0 10 0 50 507 238 2 4 0 7.0 2:30 Heater by the safety valve went out. 22 19 0 11 0 60 509 240 2 4 0 37 7.0 3:00 21 20 0 12 0 60 512 242 2 4 0 7.0 3:30 23 18 0 - 10 0 62 514 243 1 4 0 7.0 4:00 24 17 0 11 0 60 516 245 0 4 0 36.8 7.0 4:30 27 17 0 10 0 62 518 245 0 4 0 7.0 5.00 Swapped heater for safety valve. 29 16 0 9 0 62 519 247 2 4 0 70 5:30 29 18 0 11 0 50 520 247 0 4 0 37.5 7.0 6:00 29 14 0 9 0 62 523 249 2 4 0 7.0 6:30 Baker increased pump rate. 29 17 0 7 0 66 524 250 1 4 0 7.0 7:0028 22 0 13 0 64 525 251 1 4 0 37.6 7.0 7-30 24 15 0 11 0 68 528 254 3 4 0 7.0 8:00 25 19 0 11 0 66 528 254 0 4 0 7.0 8:30 22 11 0 10 0 54 531 256 2 4 0 37.1 7.0 9:00 MIIIII 27 10 150 11 0 64 532 257 1 4 0 7 0 9:30 120 9:45 100 10:00 90 10:15 50 10:30 30 10-45 10 11:00 15 11:15 0 11:30 5 12:00 0 12:30 0 13:00 Install a new guage -- 13'30 14:00 14:30 15'00 15:30 installed new 1500 8 guage 16:00 1 --- 16.30 1 17:00 1 17:30 1 ---' :9 18:00 1 i 0 18:30 10 19:00 10 19:30 10 20:00 10 20:30 10 21:00 .. 10 _ 21:30 10 _ 22:00 _ 10 22:30 10.32pm Opened the well. 23 _ 10 0 5 100 534 0 0 0 0 0 201 70 46 257 282 0 23:00 29 12 0 6 68 541 14 14 0 -1 7.0 14 23:30 29 31 0 2 64 544 14 0 0 7.0 14 3242014 0:00 8%mud in the sample port. 28 29 0 30 72 548 15 1 0 7.0 15 0:30 43 36 0 26 78 553 21 6 0 371 7.0 21 1:00 58 38 0 35 76 558 221 0 7.0 1;3061 37 D 28 73 563 26 4 0 7.0 26 2:00 56 33 D 19 70 568 28 2 0 371 7.0 28 2:30 54 36 0 34 64 576 31 3 0 7.0 31 3:00 49 36 0 28 58 581 33 2 0 7.0 33 3:30 51 35 0 31 65 586 36 3 0 36 6 7.0 36 4:00 59 35 0 31 69 591 38 2 0 7.0 38 4:30 56 28 0 28 70 598 43 5 0 7.0 _ 43 5:00 59 29 0 29 65 603 43 0 0 36 6 7.0 43 5:30 50 32 0 24 62 607 474 0 7.0 47 6:00 48 33 0 30 66 611 49 2 0 7 0 _ 49 6'30 54 26 0 19 68 616 52 3 0 366 7.0 52 7:00 56 34 0 12 70 620 54 2 0 7.0 54 7:30 55 35 0 24 69 626 56 2 0 7.0 56 8:00 53 31 0 29 71 630 58 2 0 36 9 7.0 58 8:30 58 33 0 27 71 634 613 0 7.0 61 9:00 58 29 0 28 72 639 63 2 0 7.0 63 9:30 46 37 0 31 76 643 ' 663 0 37 5 7.0 56 10:00 43 28 0 28 76 647 68 2 0 7.0 68 10:30 41 36 0 28 68 652 71 3 0 7.0 71 11;00 43 34 0 29 61 656 71 0 0 37 5 7.0 71 11;30 37 27 0 18 56 660 75 4 0 7.0 75 12:00 37 35 0 29 60 663 772 0 7.0 77 1730 , 39 25 0 20 54 667 79 2 0 37.9 7.0 79 13;00 37 37 0 31 54 670 81 2 0 7.0 81 13:30 36 29 0 .. 19 52 674 85 4 0 7.0 85 14:00 43 36 0 '.53 30 52 677 87 2 0 37.9 7.0 87 14:30 41 26 0 - 26 51 681 87 0 0 7.0 87 15:00 48 35 0 82 29 50 684 91 4 0 6.9 91 15;30 28 33 0 28 48 687 921 0 37 9 6.9 92 16;00 45 26 0 19 48 691 94 2 0 6.9 94 16;30 43 35 0 1:.. 30 50 694 97 3 0 7.0 97 17;00 32 29 0 1e 26 48 697 1003 0 37 2 7.0 99 17;30 37 28 0 - 29 61 701 1033 0 7.0 103 18:00 29 34 0 27 58 704 103 0 0 7.0 _ 103 18;30 33 27 0 26 50 707 107 4 0 37 7 7.0 107 19:00 32 37 0 :'1�2. 30 46 711 1070 0 7.0 107 19:30 33 34 0 28 60 714 109 2 0 7.0 109 20:00 32 24 0 20 62 717 112 3 0 37 3 7.0 112 20:30 32 36 0 29 65 720 112 0 0 7.0 112 21:00 32 34 0 29 67 723 1142 0 7.0 114 21:30 32 28 0 22 64 726 116 2 0 3, 7.0 116 22:00 33 36 0 26 60 729 1193 0 7 0 119 • • 22:30 30 32 0 27 0 62 733 121 3 6 0 7.0 121 23:00 Shut in Well(d11 OOpm 32 13 0 12 0 62 736 123 2 6 0 36.6 TO 123 23:15 0 0 23:30 0 0 23:45 0 0 3252014 0:00 0 0 0:15 0 0 0:30 0 0 0:45 0 0 1:00 0 0 1:15 0 0 1:30 Monitoring down hole and surface psi. 0 0 1:45 0 0 200 0 0 215 0 0 2:30 0 0 2:45 0 0 3:00 0 0 3'15 0 0 3:30 0 0 3:45 0 0 4:00 0 0 4:15 0 0 _ 4:30 0 0 4:45 0 0 5:00 0 0 5:15 0 0 5:30 0 0 5:45 0 0 6:00 0 0 6:15 0 0 6:30 0 0 6:45 0 0 7:00 0 0 7:15 0 0 7:30 0 0 7:45 0 0 8:00 0 0 `4 8:15 0 0 8:30 0 0 8:45 0 0 ilk 9:00 0 0 9:15 0 0 9:30 0 0 9:45 0 0 10:00 0 0 10:15 0 0 10:30 0 0 10:45 0 0 11:00 0 0 11:15 0 0 11:30 0 0 11:45 0 0 12:00 0 0 1215 0 0 _ 1230 0 0 • • 12:45 0 0 13:00 0 0 13:15 0 0 13:30 0 0 13'45 0 0 14:00 0 0 14.15 0 0 14:30 0 0 1445 0 0 15:00 0 0 15:15 0 0 _ 15:30 0 0 15:45 0 0 16:00 0 0 16:15 0 0 16:30 0 0 16:45 0 0 17:00 0 0 17'.15 0 0 17'.30 0 0 17:45 0 0 18:00 0 0 18:15 0 0 18:30 0 0 18:45 0 0 19:00 0 0 19:15 0 0 19:30 0 0 19:45 0 0 20:00 0 0 20:15 0 0 20'.30 0 0 20'.45 0 0 21'.00 0 0 21:15 0 0 21:30 0 0 __ 21:45 0 0 22:00 0 0 t 22:15 0 0 22:30 0 0 22.45 0 0 23:00 0 0 23:15 0 0 P?1 23:30 0 10 "•1 _ 23:45 0 10 0:00 0 10 0:15 0 10 0:30 0 10 " 0:45 0 10 1:00 0 10 1.15 0 10 1'.30 0 10 _ 1'45 0 10 2:000 10 2:30 0 10 _ti. i 2:30 0 10 SEM • • 2:45 _ 0 10 t 3:00 0 10 3:15 0 10 3:30 0 10 3:45 0 10 4:00 0 10 --- 4:15 0 10 t,. 4 30 0 10 4'.45 0 11 "i 5'.00 0 12 5'.15 0 13 5'.30 0 13 5'.45 _ 0 13 ---- 6:00 0 13 6 15 Start of very hi flow rate n/a n/a 6:30 n/a n/a 6.45 n/a n/a 7:00 n/a n/a 7:30 n/a n/a 8.00 n/a n/a 8:30 n/a n/a 9:00 n/a n/a _ -- - 9'.30 Stop high flow,shut in well, n/a n/a ...__.... 10:00 blow down IA thru flare 0 100 10:15 .,on:tor:nq down hole and surface i.-.. 0 50 10:30 0 0 10.45 0 0 - 11:00 0 0 11:15 0 0 _ - 1,30 0 0 11.45 0 0 _: 12:00 0 0 _ 201 70 46 257 282 194 Tanks 7-14 12:15 0 0 k MUD have trace of 12:30 0 0 T Tank diesel from 12:45 0 0 _ Pressure Test 13:00 0 0 13'.15 0 0 -- 13'.30 0 0 _... __..__.. 13:45 0 0 14:00 0 0 14:15 0 0 14:30 0 0 -- 14:45 0 0 15:00 0 0 15:15 0 0 15'30 0 0 _--- 15:45 0 0 16:00 0 0 16:15 0 0 16:30 0 0 16'.45 0 0 17:00 0 0 - 17:15 0 0 —_-- ---- 17:30 0 0 1745 0 0 16:00 0 0 • • 18.15 0 0 pigmy 18:30 0 0 __ 18:45 0 0 19:00 0 0 19:15 0 0 19:30 0 10 19:45 10 20 2000 10 20 ";.. 2015 10 20 20:30 10 20 20.45 10 20 21.00 30 20 21.15 30 20 21:30 30 20 21:45 30 20 22:00 20 20 22:15 20 20 22:30 20 20 22:45 20 20 23:00 30 20 23:15 30 20 23:30 30 20 23:45 30 20 0:00 40 20 _0:15 40 20 0:30 40 20 0:45 40 20 1:00 40 20 1:15 40 20 1:30 40 20 1:45 40 20 2:00 40 20 2. 2:15 40 _ 20 2:30 40 20 2:45 30 10 3:00 30 10 3.15 30 0 3'30 30 0 3:45 30 0 _ 4:00 30 0 4:15 30 0 4:30 30 0 4.45 30 0 1 5:00 30 0 5:15 30 0 5:30 30 0 21 5:45 30 0 7.: . 6:00 _ 8:15 8:30 6:45 7:00 2014 Linc Energy Zach Sayers [UMIAT 1#23H WELL TESTING SUMMARY] This document contains a summary of the completion design, an overview of the methodology behind the testing procedure, and a summary of the well tests completed. Confidential This document and its contents are confidential to the person to whom it is provided and should not be copied or distributed in whole or in part or disclosed by such person to any other person without Linc Energy Ltd prior written consent. 0 2014 Linc Energy Ltd OLIDcGY Contents Confidential 0 Contents 1 1. Completion Design 2 2. Methodology: 6 3. Operation• 6 Flow Period 1: 6 Testing Procedure. 6 Results: 6 Flow Period 2: 8 Testing Procedure. 8 Results: 8 Flow Period 3: 10 Testing Procedure. 10 Results: 10 Flow Period 4: 11 Testing Procedure- 11 Results: 11 Confidential 1 • f.n 1. Completion Design The production section was completed with a slotted liner and a liner top packer. The slot size was chosen due to the micron size of the reservoir sand and the understanding that the sandstone was competent. The slot width was 3,175 microns. 4 Rows per foot 3" Centers - - - - • 0.125" x 2.5" slots \ 1 • 32 slots per foot • 4.5" 12.6ppf L-80 base pipe — 2.5- / Slots , — Row _ _J _1 1 H . 1 i 1 Figure 1: Slotted Liner Design A Liner Top Packer(LTP)was placed at the top of the slotted liner to create a pack off on the annulus. The prevented cuttings beds, and produced solids from being produced through the annular area, and forced flow to go through the slots. Baker ZXP Liner Top Packer 4-1/2" Slotted Liner 3.958,, gimm in. ammo in am= IMMO GOMM MINIS 4- INIII IMI SIM= 11 IMMO - MEIN 11 =MN 11111111M1 .4116...1111.;4 :.*. Figure 2: Liner Top Packer Display Confidential 2 S 0LIOC ERERGY The ESP was lowered to the bottom of the well in a deeper True Vertical Depth (TVD)than the reservoir. Using a mid- reservoir depth of 985'TVD and assuming the gradient of 38 API oil (6.95 ppge)the pump had 101.5 psi of hydrostatic head above it from reservoir. Umiat - 23H Interpreted Measured Depth Cross-Section 3 X le/VD 2-5 25: 225 2 X - 1-5 Goad manor satiny pr..safe, 15: . 12.5 .M.....4...-ow Ix -5 _ If,:l'017.' ' Gilyst:co SW, 23 0 -25 -SO -75 Vermal Extheeattor. 5x -KO . -- -12$ Lapeoted DASINVOir Piessare -150 • 6.11 pre!2560.032,4627 pei -175 ;:f....,2..".M . 7.7..4.Derz "...,...=-.:::. 4:".".frl. I ill:: -30C T WIT • -35 1:a, . ... .. .. . ... . . . .... .... . . . . '•-,., 3,44,...f-.7:.:14.-Lar 54.44 _. . ' -525 ..,.. . -550 4..1417 a. -575 19 9-' .• -600 . -625 . ESP Pump -650 • , ! -675 in' il 1266'/VD C72C5 7.) 450I SX 1000 1500 2 X: 2500 3000 35X Measured Depth Figure 3: ESP Placement Relative to Geology Confidential 3 QLII1C ENERGY The tubing was left open (without a production packer)on the tubing x casing annulus. This allows direct communication between the tubing and the IA. GL: 575'AMSL 1 RIG P68: 596'AMSL t= RKB•GL: 21' 13.3/8" • 91'TVD FIT=10.1 ppg ' LOT=10.6 ppg 1.280'TVD Lower Grandstand r' FIT=11.O ppb 971'MD,928'ND 44/2"LIP,1,858'MD,1,260' 4.1/2•• Slotted Liner 3 1.774 2 Base LGS r+:'.>'44' ..• 1,370'MD,1,260'ND Baker CSI:1,848'620/12607-5/B" TOI TD:4,040 M0/966 TVD TD:1,966 MD/1,260 TVO Figure 4: Wellbore Schematic Wellbore Capacities: 1,858'of 3-1/2"9.3#Tubing and 7-5/8"29.7#casing annulus(0.0340 bbl/ft): 63 Bbl 1,858'of 3-1/2"9.3#Tubing capacity(0.0087 bbl/ft): 16 Bbl 2,100' of 4-1/2" 12.6#Liner capacity(0.0152 bbl/ft): 31 Bbl 2,100' of 4-1/2"x 6-3/4"OH capacity(0.0246 bbl/ft): 52 Bbl Total Well Capacity: 162 Bbl Confidential 4 ounc EOERGY It is also noted that the ESP had a degasser installed. This propelled solution gas from reservoir fluids to the IA. IA pressures, bleed off methods, and monitoring will be discussed in the specific testing sections. Gas Vent Port ■ Separation Chamber Guide Vane Inducer or NAVA Intake f I laJJt Figure 5-1 Rotary Gas Separator Figure Gas Separator Figure 5: ESP Gas Separator Confidential 5 ( Lin 2. Methodology: The well testing was performed using an Electrical Submersible Pump (ESP) because the reservoir was assumed to be under-pressured, meaning it could not sustain flow naturally to surface. The pump selected allowed for a wide array of flow rates and fluid compositions. Given the assumed reservoir conditions,the ESP chosen could operate from 75 BOPD to 3,000 BOPD. Once the pump was in hole and surface power was connected,the tubing was hard line connected to a test separator,then routed to a series of 400 bbl upright tanks. A total of four flow and build-up test periods were performed all at different rates and pressures. A minimum intake pressure of 150 psi at the pump was chosen to avoid drawing the reservoir down below 50 psi tubing pressure at the sand face. 3. Operation: Four separate flowing and build up periods were completed. Each of these sequences will be discussed in detail below: Flow Period 1: Testing Procedure: Ensured 0 psi is on IA. Closed IA valve. Fluid level on the IA before turning on the pump was calculated at 390'TVD static. The motor was turned on and held. It is important to note that from 23:25 till 23:45 on 3/20/2014 the generator supplying power to the Variable Speed Drive (VSD) skid went down, subsequently the motor and communication to down hole gauges was halted. Power was restored at 23:45, and the motor was brought back to previous speeds. The flowing period continued until 5:00 AM on 3/21/2014 (a total of 15.75 hrs of flowing). At 5:00 AM the tubing was shut in and the IA remained shut in. The well was shut in till 17:15 3/21/2014 (a total of 12 hrs shut-in). Results: 550 500 - 450 -+-Intake Pr enure: 400 1 350 _ 300 —Linear(Intake Presage 250 - 200 - 150 1200 13130 14130 1500 1600 1700 1800 1990 2000 2100 2290 2300 0130 1:00 290 390 4:00 5:00 Figure 6: Test 1 Intake Pressure Confidential 6 • tinc MER6V 550 - 500 __411011111111111.aimem . epell..e18.----r1111116.411101111440111110111111111411111‘01111611, 450 400 350 Discharge Presvre 300 --- 250 —Linear @6charae Pressure] --- 200 150 12:00 13:00 14:00 15:00 16:00 17:00 1810 1910 20:00 21:00 22:00 23:00 0:00 1:00 2:00 3:00 4:00 5:00 Figure 7: Test 1 Discharge Pressure 550 -- 500 --- 450 —+—Intake Presue: 400 350 — —,— —Linear(intake Presque) 300 - 250 -- 200 150 —7- 5:00 6:00 7:00 890 910 10:00 1110 12:00 13:00 1410 15:00 1610 1710 Figure 8: Test 1 Shut-in Period Intake Pressure A total of 200 bbls of oil were produced this flow period. Confidential 7 • 9111111111111111111 ounc MERCY Flow Period 2: Testing Procedure: Ensured 0 psi is on IA. Closed IA valve. The motor was turned on at 17:15 3/21/2014 The flowing period continued until 8:00 AM on 3/23/2014(a total of 38 hrs pumping). At 8:00 AM the tubing was shut in and the IA was checked for pressure. It was discovered that the IA had a total of 150 psi of pressure built up.The IA was bled off to 0 psi, and then closed in. The well was shut in till 22:30 3/23/2014 (a total of 12 hrs shut-in). Results: 250 -- stake Prezure: 225 — near jmtace Pressure:1 200 - ____���. ter• _— _.—___._.__._.__._._.___.. ■ 175- - 150 1790 1810 1900 2090.' 21'00 220023'90 090 190 210 300 410 590 900 710 890 910 1090 1190 1290 1310 1410 1510 1690 1710 1810 1910 2900 211D 2290 2390 090 190 290 300 400 510 690 710 810 Figure 9: Test 2 Intake Pressure Confidential 8 WS o 545 525 505 l 485 1111441111.1.11111111111111.1111111411.1..1.1.11.11.11.1.111Lrodir —0—Discharge Pressure: 445 425 i 17001811019902000 21902290 2390 090 190 200 300 400 5110 600 7110 800 900100311.110121101300 14:0015,3016330170180019L020130 21:0022110 23110 000 100 200 3110 4:00 500 6110 700 8110 Figure 10: Test 2 Discharge Pressure 250 225 Intake Presure: Bled off pressure from IA —Linear(Intake Prere:) zoo 175 150 125 8:00 990 1000 1100 1200 1390 14:00 1500 16110 1700 18:00 19:00 20:00 21:00 Figure 11: Test 2 Shut-in Period Intake Pressure A total of 250 bbls of oil were produced this flow period. Confidential 9 • FA Flow Period 3: Testing Procedure: Ensured 0 psi is on IA. Open IA valve to atmospheric pressure for the entirety of the test. The motor was turned on at 22:30 3/23/2014. The flowing period continued until 23:00 on 3/24/2014 (a total of 24 hrs). The pressures during this 24 hr flowing period were stable at an average of 164 psi. At 23:00 the tubing was shut in and the IA was closed in. The well was shut in till 07:00 3/26/2014 (a total of 32 hrs shut-in). Results: 250 225 .ntak a Pr essure: 200 —Linear(Intake Pressure:) — 175 150 125 22:00 23110 0:00 1110 2:00 3:00 400 5:00 6:00 7:00 8:00 900 10:00 11:00 1200 13:00 1400 15110 16:00 17310 1800 1900 2000 21:00 22:00 23:00 Figure 12: Test 3 Intake Pressure 600 575 550 f 0ischargePresture: 525 L500 _ . - - 475 450 425 400 2200 2300 0:00 100 200 3310 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 Figure 13: Test 3 Discharge Pressure 250 225 200 _ _ y�.- —z —.—k�ePres,.e. 175.F . _ — —linear(intake Premix") 150 125- 2300 000 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 18:00 1900 2000 2100 2290 2310 010 100 200 300 430 510 600 7110 300 Figure 14: Test 3 Shut-in Period Intake Pressure A total of 123 bbls of oil were produced this flow period. Confidential 10 • ERERGY Flow Period 4: Testing Procedure: Ensured 0 psi is on IA. The IA valve was closed during this short flowing test. The intake pressure limitation prior to pumping was reduced to 100 psi. This was in an effort to establish an upper limit to the flowing ability of the reservoir. The motor was turned on at 07:00 AM 3/26/2014. The flowing period continued until 09:09 on 3/26/2014(a total of 2 hrs of flow). The pressures during this 24 hr flowing period were stable at an average of 164 psi. At 09:09 the tubing was shut in and the IA remained closed in. The well was shut in till 10:00 AM 3/27/2014(a total of 24 hrs shut-in). Results: 250 225 _»._ntakePressure; 200 -Linear{intake Pressure:) 175 150 125 _ 100 75 700 8:0 920 Figure 15: Test 4 Intake Pressure 600 500 � —♦—Discharge F reseure: 400 300 200 7110 SAO 9: Figure 16: Test 4 Discharge Pressure 250 225 zao Bled off pressure from IA — _ - ktakePresure: I 175 1111Pr.'–A010.11.1..111mn'n.— —Linear(Intake Pressure) 15050 125 100 — $00 900 1000 11110 1200 1300 14110 1500 WOO 17= WOO 19110 20110 2100 2200 2500 020 100 200 300 420 500 600 7110 800 9110 1000 Figure 17: Test 4 Shut-in Period Intake Pressure A total of 71 bbls of oil were produced this flow period. Confidential 11 • • 0 Linc ENERGY Sctimitergir Umiat#23 Survey Geodetic Report (Det Survey) Report Date April 08.2014.07:22 AM Survey 1009 Computation: Melenum Curvature/Lubinski Chem: Lex Vertical Section Admits 100000`(True North) Field Umiat verticalRe Sectionreneurn: R 000 otary eA/c0001 8bucture I bloc UmMt 42311 I 11mW 027H TVD Reference Saturn- Rotary Table Well Umiat e23H 190 Reference Elevation 5960008 above MSL Borehole. Umlet 42311 Ground EMvatbn: 575.0008 above MSL APM. 502872002800 Magnetic Declination: 18,225' Survey Name: UmMI 423 Total Greedy Field Strength: 1001 8797mgn(980665 Based) Survey Dae. February 28.2014 Gravey Model. GARM Ton/AHD/DO 1 ERD Ratio: 156.154°/3186 474 8 1 6.21312.516 Total Magnetic Field Strength: 57446377 nT Coordinate Reference System: NAD27 Alaska State Plane.ZOO.05,US Feel Magnetic D1p Angle 80 015° Location Lal/Long. N 69.23 39.79297'.W 132°11'46 74931- Declination DateFebruary 13,2014 ocanan Grid N/E v/X: 14 5631271 000 BUS.E 732474.000 WS Magnetic Declination Moder: 8GGM 2013 CRS Grld Convergence Angle: 1.6884' North Reference: Truo North Grid Scale Factor' 0 9999614 Grid Convergence Used: 0 0000" Version I Paten: 2.710430 Total Corr Mag Ncrit-cine North. 10.2251° Local Coord Referenced To: Structure Reference Point MD Comments Mel 430,True TVDSS 190 VSEL AND Closure 446 EW CRS Northing Basting Latitude Longitude MI IY Cl 181 181 161 ml NU 144 fill 7/10081 18051 16081 CI (1 RTE 0.00 000 0.00 -59800 0.00 0.00 000 000 0.00 000 WA 5631271.00 732474.00 6939438894 -15219631925 5 21 00 0.00 0.00 -577.00 21.00 000 0 00 000 0 00 000 000 5631271.50 732414,00 69 39438694 152.19631925 10000 0.24 1984 -498.00 100.00 0.03 017 017 016 006 031 563127116 73247405 69.39438737-152.19631981 20000 055 1984 -398.00 200 00 0 15 0.86 0 86 0 81 029 0 31 563127182 73247427 69.39438918-152.198318% 253.80 0 72 1984 -34421 253 79 0 25 1 46 1 46 1.38 050 0 31 5631272.39 73247446 6939439070.152 19631540 3000D 238 71.57 -298.02 29998 114 2.65 246 1.95 150 430 5631273,00 73247545 6939439221-152.19630758 313.58 295 7460 -28446 31354 171 3.28 300 213 211 436 5631273.19 73247601 6939439270 152.19630290 385.99 567 8828 .21227 38573 7.02 8.82 8.08 273 761 4.25 5631273.96 732481.53 6939439440-152.19628023 400 00 6 39 88 77 -196 34 399 66 8.48 10 32 952 177 9.10 3 71 5631274,04 732483.02 69.39439451 -152.19624663 44824 8.17 89 98 .150 49 447 51 14.49 16 43 15 48 283 15 22 3.71 563127428 732489.12 69.39439467-152.19621123 50000 4029 9326 -9910 4%.60 22.71 24 73 2365 2 57 2351 4.22 563127426 73249742 69.39439395-152.19613690 506.10 1054 9356 -9340 50460 2380 25.83 2474 250 24.61 422 563127423 732498.52 6939439377-152.19612836 571,00 12.99 9661 .2987 56813 36.98 39.06 37.80 129 37.18 389 563127341 73251113 69.39439047-152.19602618 60000 14.52 W 98 .170 59630 43.87 45.96 4462 042 4462 539 5631272.73 732518.59 69.39138807-152.19597314 832.29 16.23 99.16 29.43 627 43 52 43 54.52 53.09 .0 86 53.08 5 39 5631271.70 732527,06 69.39438458.152.19590746 695.00 20.35 10033 8896 686.96 72.10 74.19 7259 7.21 72.47 6.60 5631268.92 132546.56 69.39437542-152.19575710 70000 2065 100.54 9364 69164 73.85 75.94 7433 -4.53 74.19 8 t5 563128886 73254829 69.39437455-152.19574374 756.85 2405 102.56 146.03 744.03 9538 97.48 9570 -667 95.29 6.15 563126484 732569.50 69.39436270-15219558012 800.00 2675 10231 18519 783.19 113.98 116.07 114.17 -12 81 113 44 6.23 563126148 732587.77 69.39435177 752.19543928 81665 27.80 102.22 20016 796.16 121.61 123.79 121.66 -1451 12089 623 5631260.06 732595.36 6939434729.152 19538075 877.50 31.97 101.41 25214 850.74 151.87 154 01 151.% -20.68 150.56 6.91 5631254 76 73262510 69.39433042-152 19515134 900.00 3333 101.90 271 68 869.68 161.00 16614 164.09 -23.14 162.45 6.14 5631252.66 732637.06 69 39432372.152.19505913 940.63 35.78 102.69 305.14 903.14 187.03 18919 187.08 38.05 184.97 6.14 563124842 732659.70 6939431030.152 19488451 100000 39,21 10114 35224 95024 22313 22532 223.15 35.88 220.28 5.86 5631241 83 73269523 6039428944 -15219481056 1001.33 39.29 10172 353.27 951.9 223.91 22616 223.99 -35.85 221.11 5.86 563124168 73269606 693942%97-15219160116 1063.19 42.90 10184 399.88 997.% 26461 26682 284.61 .44.15 260.90 9.84 563123455 73273608 6939426629-15219429546 1100.% 45.38 102.18 42629 1024.29 29023 29245 290.23 -4949 285.96 679 5631229.96 132761.30 69.39425171 -15219410090 1124.52 47,04 10239 44326 4041.26 301.91 310.15 307.91 -5316 303.27 6.78 5631226,70 73271870 69.39424142-15219396682 118619 6162 10275 48344 108144 354.63 356.91 354.63 -6344 348.91 7.44 5631217.87 732924.62 69.39421359.152 19361280 120000 5254 10264 49193 1089.93 365.51 36781 385.S2 -6583 359.54 8.66 5631215.79 732835.31 89.39420105-152.18353037 124711 55.66 10227 519.55 1117.55 40363 40596 403.65 -74.06 39680 666 563120867 73287379 69.39418457-15219324137 130000 5926 10137 548.00 1146.00 44819 450.54 448.22 -63.18 44043 6.95 5631200.83 73291667 69.39415963-15219290290 130926 59.89 10122 552.68 1150.68 456.17 458.53 456.20 -84.75 44826 695 5631199.50 732924.55 69.39415538-152.19284217 1366.30 8331 10597 579.81 1177 RI 506.33 50869 506.37 -9440 49740 6.01 5631191.30 73297404 69.39412898-15219246030 140000 6537 10067 594.40 119240 53670 53907 536.74 -100.15 527.32 6.10 563118643 73300.02 69.39411325-152.18222896 1424.84 66.88 10080 60.46 120246 55941 56118 55946 -19442 549.63 6.10 5631182.82 733026.44 89.39410158-152.19205592 • 148427 70.85 10067 62588 1223% 614.83 61720 614.68 -114.74 60408 668 5631174.11 733081.17 69.39407337-152.19163356 Drilling Office 2.7.1043.0 Umiat\Umiat#23H1Umiat M23H\Umiat 1723H\Umiat#23 4/8/2014 7:30 AM Page 1 of 3 • • Gommern'e MO Intl A811 True TVDSS TVD VSEL 610 Closure 54S EW OLS Northing Eating LetIN4e Longitude M1 (1 PI 887 I#1 883 MI (M Mt MI F710061 MUM MOS) mi M 150000 71.98 100,81 630.90 1220,90 629.73 632.11 629.79 -11752 618.73 723 5631171.76 733095.89 6939406577-152.19151994 1515.39 75,24 101.21 64370 1241.70 673.27 67585 673.33 -125.84 66146 713 5831164,71 733138,86 69.39464304 -152.19118844 1600.00 7950 100.38 655.84 1253.64 726,54 720.53 726.60 -135.81 713.80 795 563115628 733191.48 69,39401578-152.19078251 1822.12 81.23 100.05 659.34 1257,34 748.34 750.74 74841 -139.60 736.26 795 563115305 73321303 69.39400520.152,19061604 1700.00 8741 99.32 66705 1265.05 82580 828.20 82586 -15271 811.61 7.99 563114227 733289.73 89,39396958.152.19002378 1703,53 87.69 99.29 66720 1265.20 829.33 831.72 829,38 -153.28 815.10 7.99 5631141,80 733293.22 69.39396802-152.18999678 1729.47 89.09 98.60 667.92 1265.92 85525 857.65 855.30 -157.31 840.71 6.52 563113853 733318.94 69.39395700-152.18979811 179082 89.66 9981 668.59 1266.59 916.59 919,00 916,63 467.13 90126 2.18 5631130.51 733379.78 69.39393017.152,18932841 180000 89.75 99.82 668.64 1286.64 925.77 928.18 925,81 -188.69 910.31 0,97 5631129.21 733388.85 69.39392589-152.18925824 1852.66 9026 99.86 66864 1266.64 97863 981.04 978,86 -17772 862.39 0.97 5631121.71 733441.17 69.39390120-152.18085426 1900.00 93.36 99.09 667,15 1265.15 102514 1028.15 1025.77 -185,48 1008.88 6.78 5631115.33 733487.85 69.39388000-152.18849383 190416 93.66 99.01 668.87 1264.87 103029 1032.70 1030.32 -186.19 1013.35 8.78 5631114.75 733492.36 69.39387804-152.18846897 195900 95.91 9030 66149 1259.49 1094.48 109691 1094,50 -195.88 107883 386 663110696 73355600 69.39385161 -15218794655 1997.52 96.91 97,99 658.31 1256.31 112281 1125.25 1122.82 -199.88 1104.88 366 5637103.77 733584.25 69,39394062-152,18774698 200000 97.10 98.01 858,01 1256.21 112527 1127.71 1125.19 -200.22 1107.33 7.65 563110350 733586.70 69.39383969-152.18773008 2060.57 101.72 98.39 648.11 1246.11 1184.98 1187,45 1184.98 .208.73 1166.45 7.65 5631096,73 733646.05 69.39381639-152.18727144 210000 104.52 98.11 63916 1237.16 122338 1225.85 1223,36 -214.25 1204.45 7.14 5637092,34 733684.19 69.39380132-152.18697670 212361 10620 9794 632,90 123090 1248.11 1248.61 124811 -217.42 1227.00 7,14 5631089.93 733706.82 69.39370263-152.18688185 2188.51 11059 97.74 61243 1210,43 1307.64 1310.18 1307,84 -225,82 1287.99 6.77 5631083.23 733768,03 69.39376965-152,18832876 2200.00 110.60 97,58 608.38 1206.36 1318,38 1320.94 1318.38 -227.26 1298.65 1.31 5631082.11 733778.73 69,39376573.152.18624608 2253.08 11064 96.84 589.69 1187.69 1368.00 1370.62 1368,01 -23349 1347.94 1.31 5631977,33 733828.18 69.39374867-152.18586179 230000 11125 97.82 572.92 1170.92 1411.78 1414.44 1411.79 -239.08 1301,40 2.34 563107302 733871.78 69.39373338 452,18552668 231508 111.44 98.14 567.43 1165,43 142582 1426.49 1425,84 -241.03 1405.32 234 563107148 733885.75 69.39372804-152.18541872 237821 11222 100.36 543.95 1141,95 7484.41 1487.09 148442 -230.45 1463.14 349 5631063.78 733943.83 69.39370229 152.18497019 2400.00 11208 10034 535.74 1133,74 1504.59 150727 1504.60 -254.00 148300 0.63 5631060.74 73398378 69.39369237-152.18481620 244170 111.82 100.31 520.15 1118,15 154326 1545,94 1543.28 -261.01 1521.05 0.63 5631054.93 734002.01 69.39367341 -152.18452107 2500,00 100.23 100.93 500.19 1098.19 1598.02 1600.71 1596.04 -271.10 1574.87 623 563104642 734058.11 69.39364579.152.18410357 250381 10800 100.87 499.00 1087.00 1601,65 1604.33 1601.66 .27179 1578.43 623 5831045.84 734059.69 69.39364391 -152.18407600 2567.55 106.37 93.51 480.17 1076.17 1682.54 1665.22 1662.55 .282.61 1638.35 3.37 5631036.79 734119.90 69.39361431 -151.18361123 2600.00 106.33 99.81 471.04 1069.04 1893,67 1696.36 1693.68 -287.84 1689.05 0.91 5631032.47 734150,73 69.39360002-152.18337314 2629.40 10629 100,09 462.78 1060,78 1721.89 1724.58 1721.90 -252.72 1696,84 0.91 563102641 734178.66 69.39358668-152,18315758 268928 103.91 99,20 447.18 104518 1779.70 1781,39 1779.71 .302.40 1753.63 4.23 5631020.42 734235.91 69,39356019-152,18271554 270000 103.46 99.16 444,64 1042.64 1790.11 179280 1790.12 -304.06 1764.11 4.21 5831019.06 734246.23 69.39355584-152.19263579 275828 101.10 98.96 432.68 1030,68 184509 1847.79 184511 -312.72 1818.41 4.21 5631012,00 734300.76 69.39363195.152.18221460 2800.00 101.08 99.54 424,27 1022.27 1887,99 1890.69 1888,01 -319.62 1860.78 1.30 5631006,36 734343.29 69.39351308-152.18188618 1818.14 10107 99.75 421.17 1019.17 1903.83 1906.53 1903.85 -322.27 1876.38 1,30 5631004.17 734358.98 69,39350582-151.18170504 288128 10068 100.82 408.88 110988 196780 1970.50 1987.82 -333.69 193932 1,72 5630994.60 734422,13 69.39347457.152.18127685 2900.00 10065 130,92 40541 1003.41 198619 1988.90 195621 -337.16 1957,38 0.53 563099167 734440.39 69.39348508-152,18113673 2940.55 10060 121,13 397,93 98593 2026.04 202675 2026.05 -34478 1996.50 053 563098520 73447971 69,39344424.152,18083331 3000.00 9794 99.75 388,36 98636 2081.71 2087,42 2084.72 35541 2054.20 502 583097628 734537.69 69.39341515 152.18038582 3005.38 9772 99.63 387.62 98562 2090.04 209275 2090.05 356.31 2059.45 502 5630975.54 734542.97 69.39341270-152.18034507 3073,83 95,43 99.71 379.80 877.80 2156.03 2160,75 2150.04 36773 212648 3.32 5630966.10 734610.31 89.39338144-152.17982517 3150.00 9434 100.82 37737 975.57 2184.11 2186.82 2184.12 -372.26 2152.16 4,76 5630962.32 734838,11 89,39336903.152.17962601 3135.17 92,88 101,13 375.35 973.35 211920 2221.92 221921 -378,79 2186.65 476 5630956.81 734670.77 69.39335116.152.17935653 3197.88 90.34 102.12 373.59 971.59 2281.86 2264.60 2281.86 -391.43 2248.04 4.35 5830945.99 734732.50 69.39331661 .152.17868236 320000 9026 102.12 373.58 971.58 2283.97 2288.72 2283.98 -391.87 2250.11 3.76 5830915.61 734734.59 69.39331539.15217886629 3262.63 87.91 102,21 374.68 972.56 234555 2349.34 2348.55 405,07 2311.32 3.76 563093422 734796.16 69.39327929.152.17839153 3300.00 66.81 102.54 376.30 974.30 238385 2388.67 2383,85 413,07 2347.79 308 5630927.30 734832.84 69.39325740-152.17810873 332427 86.09 102.75 37781 975.81 2408.04 2410.89 2408.04 418.37 237142 3.08 5630922.70 734856,62 69.39324290-152,17792541 3390.54 88.56 102.36 38090 978.90 2474.17 2477.09 2479.17 432,76 2436,03 377 5630910.22 73492162 69.39320353-152,17742431 3400.00 88.71 102.34 381.12 979.12 2483.62 2486.54 2483.62 434.78 244527 1.60 563090847 73493092 69.39319800-152,17735265 3455.68 8959 10221 381.95 979.95 253926 254223 253926 446.62 2499,68 180 5630898,24 734985.65 69.39316561 -152,17693068 350000 89.14 10178 381.44 980.44 2583.54 2588.53 2583.55 455.82 2543,02 142 563089031 73502924 6939314041 -152.17659451 3513.17 8900 101,65 382,66 980.66 2596.70 2599.70 2596.71 458,50 2556.91 142 5630888.02 73504221 69.39313309-152.17849451 3578.35 88,77 10140 383.93 981,93 266185 2664.87 2661,86 471.52 2619,77 0.52 5830876.89 735106.42 6.39309746.152.17599926 3800.00 88,71 101,17 38440 98240 268348 2686.51 2683.50 475.81 2640.96 045 563087322 735127.75 6.39308572 .152,17583472 363980 88,59 10161 395.34 983.34 272326 2726.30 2723.28 483.77 2879.97 045 583086642 735166.95 6939306393.152.17553237 370000 88.58 101,20 386.84 984.84 2783.42 2713648 2783.45 495,67 2738.96 0.68 5630856.26 73522826 69.39303136-152.17507483 370600 88.56 105,16 3176,99 964.99 278942 279248 2789.45 496.84 2744.84 068 563085527 735231.18 69.39302818-151.17503919 3769.36 90,00 101.06 387.78 985.78 2852.76 285584 285279 60904 2807.01 2.28 5630844.90 73529487 69.35299476.152.17454704 3800.00 90,07 10169 367.77 985.77 2883.39 288848 2883.43 -514.93 2837.08 0.25 5630839.90 73532490 69.39267865-152.17431383 Drilkng Office 2.7.1043.0 UmiaHUmiat#23H\Umial#23H\Umiat#23HtUmiat#23 4/8/2014 7:30 AM Page 2 of 3 • 1111 Commis MD loot Halm True 19058 TVD VSEL AHO Closure PM EW DLS Northing EasBrg Latitude Longitude (81 11 Cl 181 18) f9 181 465 m 5 ) 19) 0100111 051 must C) Cl 3832.73 90.14 101 13 387.71 985.71 291812 291921 2916.16 -521.24 296919 025 54130834.54 73535719 69 39296138-152.17406474 3895.68 89.48 100 30 387 92 985.92 2979.06 2982.16 2979 10 -532 94 2931 05 I.66 5630924 67 735419.36 E9 39292934 -152.17358503 390000 8952 10026 387,95 98595 298338 2986.48 2983.42 -533.71 2935.70 1.28 5630824.02 73542363 69.39292723-152.17355207 3952.31 90.03 99.83 388.16 98616 3035.69 3038.78 3035.73 -542.84 2966.90 1.28 5630816.42 73547338 69.39290225-152.17315259 4000.00 90.06 9910 188.12 986.12 3063.38 3086.47 3083.42 -550.68 3033.84 153 563080996 735522.63 69.39288077-152.17278775 4017.89 9007 98 83 388 10 996.10 3101.26 3104.36 3101.30 -55347 3051.52 1 53 5630807 76 735540.37 69.39287313-152.17265070 4062.62 90.00 99.48 38807 986.07 3145.99 3149.09 3149.02 -590.59 3095.86 1.46 563080188 73558472 69.39285364-152.17230820 4100.00 9000 9946 388.07 98607 3183.37 318647 318340 -566.74 313254 000 563079682 735E21.76 69.39283678-152.17202225 Survey Error Modal ISC WSA Rev 0•"3-0 95.000%Confidence 2.7955 sgma Surrey program. Description Part From IAD To EDU Frog 8540 Bix Casing Diameter survey Toot Type Borehole/Survey till ml 191 llnl fin) 0.000 23.000 Act Stns 9875 7.625 SLB MWD-INC ONLY•Deptn Umat 02300 Umia1923 23.0 1424270 Am Stns 9875 7.525 SLB MWD-trC_ONLY Umia18238/Uma1023 1424270 1464270 805515. 9875 7.625 3LB_MWDSTD Umiat023H/Uma1023 1484270 1997.520 Act Sins 9875 7.025 SLB MWD-INC ONLY Umat 4230 l Ulniet 023 1997.520 2188.510 Act Stile 6 750 4.500 SLB MWD-STD Unlol#230/Umal 423 2188.510 2315090 Am Se. 6750 4.500 SIB MWD-190Umat#23H/Unhet#23 2313090 2378710 Act Stns 6.750 4.500 SIB_MW0STD Umbt#23H/Umisi#23 2375 210 2441 700 Act Shin 6.750 4.300 SLB MWD-19C_08417 Umlet 023HI threat 023 2441700 2503810 Am54ru 5750 4.500 SLB_MWDSTD Umiet023H/Llmat023 2503810 2629400 Am Stns 6.759 4.500 SLB MWD-INC ONLY Umat023H/Metal 023 2629.400 2689280 Act SMt 6.750 4.500 SLB_MWDSTD Umiat#73H/Umie1#23 2889.280 2816.140 Act Stns 6.750 4.500 SLB MWD-1NC_ONLY Umal1123H/Umiet023 2816.140 2940.550 Am Stns 8750 4500 SLB MWD-STD umiet 023H/theist 023 2940.550 3197.580 Acl Stns 8 750 4.500 SLB MWD4NC_ONLY Unset 0238/Umiat 823 3197.880 3262 630 Am Stip 6750 4.500 SLB MWD-STD Umlat#239/Urns)023 3262.630 3324.270 Act Stns 6.750 4.500 SLB_MWD-INC ONLY Usual 42314/Umie1023 3324270 3455690 Act Stns 6.750 4.500 SLB MWD-STD Umiet 023117 Lomat 023 3455.690 3576350 Am5t86 6750 4.500 SLB MWD-1NC ONLY Umiat#23H/Uma1023 3578.350 4011890 Am Sins 6 750 4.500 SLB MWD500 Umat 62311/Untie)823 4017.890 4062 620 48 Stns 6750 4.500 SLB MWD-INC ONLY Umat 112361 Unmet 823 4062620 4100000 Act Stns 8750 4.500 SLB SLIND0TREND U role 1123H/Unlei023 Legal Description: 9 Surface 1030 5 FSI 4026.0 FEL$32 115 81 W UM 56312718000 7324474 000 900 463 ESL 995 FEL 32 TIN RI WUM 5630796.820 715621 760 Final Definitive Survey Verified and Sloped-c" All targets and/or well position objectives have bean achieved 0 Ye, 0 No 1 have checked to the beat of my ability Mat the following data is correct: O Surface Coordinates (]. Decarod4M b Convergence 111 Survey Tool Codes SLB DE'. - Client Representative: Als. -4/441114fIS- Date: �J�4.1 Drilling Office 2.7 1043.0 Umiat\Umiat#23H\Umiat#230\Umiat#231-0Umiat#23 41812014 7:30 AM Page 3 of 3 • 0 ' . NCONDUCTOR LOCATION 1 1 -- 1- ilam j� NADO3 ASP ZONES / 32 • 33 1'(J , I LA1.697'38,41"N t��...,� F����y�TI IIS SURVEY LONG 1.8 2,503.41"W 1 t/U _ Y-5,630,982 ��\Sl�1N i X-1,872 1'5 // i \ \ \ \\ \ 1 �,// //// , ,\ \,� _re' " LAT"59'2,:39 80'N _$7P" LONG"15291'46,74"W *:., //1/4/ 1(/ /" \ \ , ,.`` L.".. / Y"5,637,271 - --/:6";1 W Q / + ' '/�_ X"732.471 A,! ilk / + 50'1.4° .4r^ ` N69°23'40.34" / a a P i�r•—-111.11.111-t!----- G GRAPHIC SCALE I/= tN_#m f= W152 11'55.05" �`-` LOCATE) PRIATE)ARY LOCATION '' LOCATE)WITHIN 3I O °'� YF°`$' 66 1 PROTRACTED SEC.32, a' ^� --:-..,„7,- 1.�"" // ! j�,� se, 1 PROPOSED ICE PAD TIN.PF.S,L,M. 1 Inch=100 ft. ' / Jrj6P"-. j N IS t. j / 1254'F.W.:. VICINITY MAP t"=1MILE / I r T /Cf� t. N69°23'39 37 W152°12'02.96" � WEU.,23H\ 11. /% s , �o' J/ NOTES: /-! 9°! ji'\ 2 / 1.ELEVATORS SHOWN ARE / NAVD 88 PER GEOID 20120 N69°23'37,56" DOMED FROM CPS7 , r W152°11'52.29" OESER VA TON j y100 7' UMIAT EXPLORATORY PROGRAM $ID / WELL 23H AS STAKED ,\ \ \i \ \ ;11—_'T7 i y' SECTION 32,11N.Rt W,U.hl. \\\ '\ `�`i I / ...,&A,tro tilt \ / �_.J�..�E .YY71�4 ,IL � �-� DICE ROAD • e,OF 1 Of AL PR E___________/ rri �i+.Kenneth W. A e y: Cn Y T �Y 5 'DATE. OCT 10,2013 ' i,/,IrF;..,.. LS-B535 1 SHEET t OF 1 #-k .{re5 1111 ^FE88198W3.;,,.-,_ FIELD BO01(. 11-060 /4 1Lttt\0h..," ( LEGEND ) DRAWING NAME 11-DOOA STAKED •6060. SURVEYOR'S CERTIFICATE • CCNDJCIOR SURFACE LOCATION DRAWN JLS — 5300'1"Street I HEREBY CERTIFY THAT AM PROPERLY cho REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE - -57-` MAJOR CONTOUR CHECKED. ,NN AneNE .Alaska 99518 STATE OF ALASKA ANO THAT THIS CERTIFICATION IS LIMITED TO THE WELL CONDUCTOR LOCATION ONLY.ALL MINOR CONTOUR GRID. N/A PHONE. (907)212-5°51 Ar (307)212908.. OTHER INFORMATION SHOWN IS APPROXIMATE. N. ISCALE'. 1".100' , Ntp./Y.wN.LOUNSOUM!INC.cpm 4 • • RECEIVED NOV 18 2014 EllERGY AOGCC Linc Energy Operations, Inc. 3000 "C" Street, Suite #103 Anchorage, Alaska 99503 May 19th, 2014 Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Well Completion Report Well: Umiat#23H (Existing Exploratory Oil Well) TRS: SWSW, T1 N, R1 W, Section 32, Umiat Meridian Dear Chairman Foerster, Linc Energy Operations Inc. hereby submits a Well Completion or Recompletion Report and Log for well Umiat #23H, an onshore Exploratory Oil well on BLM land 1 mile north of the Umiat Camp Runway. Please find attached information as required by 20 AAC 25.070 (3) for your review. Pertinent information attached to this submission includes the following: 1) Form 10-407 Well Completion or Recompletion Report and Log 2) Operations Summary 3) Actual Wellbore Diagram 4) Mud Weight vs Depth Chart 5) Conductor As-Built The following are Linc Energy designated contacts for reporting responsibilities to the Commission: 1) Drilling and Completions Zach Sayers, Drilling Engineer (907) 375-2603 2) Geologic Data and Logs David Boyer, Geologist (907) 375-2623 • • In accordance with Alaska Statute AS 38.05.035 (a)(8)(C) and Alaska Administrative Code 11 MC 96.220, Linc Energy Operations, Inc. requests that confidentiality be extended to the information described herein and submitted with this transmittal. If you have any questions or require further information, please contact either Zach Sayers, Drilling Manager at (713.580.6612) or David Boyer, Senior Geologist at(907.375.2623). Sincerely, Zach Sa - - Drilling Manager— North America STATE OF ALASKA . ALlikA OIL AND GAS CONSERVATION CO SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑✓ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: _1 Service ❑ Stratigraphic Test ❑ 2.Operator Name: 5. Date Comp.. Susp.,or 12. Permit to Drill Number: Linc Energy Operations, Inc. Aband.: 3/20/2014 213-020 3.Address: 6. Date Spudded: 13.API Number: 3000 C Street,Suite 103,Anchorage.AK 99503 2/15/2014 50-287-20029-00-00 4a. Location of Well(Governmental Section): 7. Date TD Reached: 14.Well Name and Number: Surface: 1,031'FSL,4,026' FEL.Sec 32-T1N-R1W,U.M. 3/9/2014 Umiat#23H Top of Productive Horizon: 8.KB(ft above MSL): 598 15. Field/Pool(s): 1457'FWL, 1002'FSL, Sec 32-T1 N-R1 W,U.M. GL(ft above MSL): 575 Total Depth: 9. Plug Back Depth(MD+TVD): Exploratory(Umiat) 436'FNL,895 FEL;Sec 32-T1S-R1W, U.M. 3,995'/986' 4b.Location of Well(State Base Plane Coordinates, NAD 27): 10.Total Depth(MD+TVD): 16. Property Designation: Surface: x- 732,474 y- 5,631,271 Zone- 5 4.100'/986' FEDAA84141 TPI: x- 732,678 y- 5,631,244 Zone- 5 11. SSSV Depth(MD+TVD): 17. Land Use Permit: Total Depth: x- 735,622 y- 5,630,797 Zone- 5 N/A N/A 18. Directional Survey: Yes Q No ❑ 19.Water Depth; if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 972'/929' 21.Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: Schlumberger Vision Service RM Composite Log(GR, Res, Den, Nue) N/A 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASINGFr. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 13-3/8" 68 J-55 0 91 0 91 20" 127 sx(21 bbl)Permafrost N/A 7-5/8" 29.7 L-80 0 1968 0 1,260 9-7/8" 336/27 sx(629/32 bbl) N/A 24.Open to production or injection? Yes ❑✓ No ❑ 25. TUBING RECORD If Yes,list each interval open(MD+TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3-1/2" 1858 N/A Top of Slotted Liner: 2,062'MD/1,246'TVD Bottom of Slotted Liner: 3,994'MD/ 986'TVD 26. ACID, FRACTURE,CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes❑ No ❑✓ RECEIV ED DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED N/A N/A NOV 18 2014 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 3/20/2014 Artificial Lift(Electrical Submersible Puma) Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 3/20/2014 140 Test Period -644 0 0 N/A N/A Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 27 0 24-Hour Rate 225 0 0 38.5 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No❑✓ Sidewall Cores Acquired? Yes ❑ No ❑I If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. N/A Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Submit original only • s 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? , Yes f No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if needed, Permafrost-Top 0 0 and submit detailed test information per 20 AAC 25.071. Permafrost-Base 980 980 Nanushuk 230 230 Tested interval from Top of Slotted Liner:2,062'MD/1,246'TVD to bottom of Slotted Liner: 3,994'MD/986'TVD. Lower Grandstand Upper Grandstand 369 369 Tested the well for a total of 140 hours with a total of 644 bbls produced.4 separate build up,flowing periods and shut-ins were completed. Middle Grandstand 597 597 Lower Grandstand 722 722 Torok 1038 1038 Formation at total depth: 2,600 2,515 Torok 31. List of Attachments: As Drilled Schematic, Final Surveys, MW vs. Depth Chart,Operations Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Zach Sayers Email: ZaCh.Sayers IIncenergy.Com Printed Name: Zach Sayers Title: Drilling Manager-North America ,/ Signature: Phone: 713-580-6612 Date: I((/ / 17 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item lb: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 A 0 • Umiat #23H .� Tubing Hanger: 3-1/2"I: .. Lease: AA-084141(BLM Tree Connection: t lf, Well Ty. tion Base of Permafrost: 801'MD/793'TVD GL: 575'AMA I 2 i a HOLE DATA �G "� �� RIG RKB: 596'AMSL 1 t,, Hole Section Size Top(MD) Btm IMD p(TVD) Btm(TVD) Mud Wt Max angle RKB-GL: 21' x., - in ft ft.... ft ft type ppg deg Conductor 20" 0' 91 0' 91 N/A N/A 0° 'a 13-3/8" . 0 Surface 9-7/8" 0' 1968 0' 1260 OBM 8 100° y,4 91'TVD '�`t Production 6-3/4" 1858 4040 1266 986 OBM 7.5 102 i'is, FIT=30.1 ppg LOT=10.6 ppg CASING/TUBING DATA loHole Section Size Wt Grade Conn ID Top(MD) Btm(MD) TOC :+✓ - in lb/ft - - in ft ft ft - Conductor 13-3/8" 68 1-55 PE 12.415" 0' 91 0' eta Surface 7-5/8" 29.7 L-80 BTC-MOD 6.875" 0' 1968 0' Production 4-1/2" 12.6 L-80 IBT-MOD 1958" 1858 4040 N/A • L.c 1, Tubing 3 1/2" 9.3 L-80 8 Rd 2.958" 0' 1858 N/A V; CEMENT DATA 4"1 Conductor Permafrost 23'IGL) 100' 15.7 0.93 43 260 Surface ®.. Permafrost 23(GL) 1,594' 11.0 1.87 Surface ® Class G 1,594' 1968 15.8 1.16 L COMPLETION JEWELRY SUMMARY vrj 1 Tubing Hanger Proposed I 2 Baker ZXP LTP Proposed 3 Baker ESP Pump 1848 Proposed 4 5 6 7 1/ 1,280'ND Lower Grandstand f, FIT=11.0 ppg y:. 971'MD,928'WO i_> u. „ 'e".i4-1/2"LTP,1,858'MD,1,260' ',eF'airk-x fL 4-12".._._. / Slotted Liner 3 w di . 2 ,70'MD,1,260'TVD 7-5/8" TOE TD:4,040'MD/986'TVD TD:1,968'MD/1,260'ND DATE REVISED BY: WELL HISTORY DESCRIPTION Well Name Umiat B23H 9/27/2013 Z.Sayers Proposed Lower Grandstand B-sand Horizontal Slotted Liner ESP Completion Spud Date 2/15/2014 10/30/2013 Z.Sayers Update to WPU9 API No. 50-287-20029-00 3/15/2014 Z.Sayers Update to Actuals PTD 213-020 Max Hole Angle 102 Max Dogleg 8 • S - • UMIAT#23H Depth MW UMIAT #23 H Feet ppg Mud Weight vs. Depth 0.0 7.7 0.0 97.0 7.7 UMIAT#23H 300.0 7.8 382.0 7.8 704.0 7.9 1024.0 7.9 1285.0 7.9 1280.0 8.0 1257.0 7.3 996.0 7.5 $ - L 986.0 7.7 . 600.0 v 8.2 0 175 8.3 8.3 8.3 8.4 8.5 8.5 8.6 8.8 8.9 1200.0 9.0 9.2 ateral section 6.5 7.5 8.5 9.5 Mud Weight(ppg) \-, -- '-ytz.'b\ it RI CI U ii. ciP j < Q o� ♦ I I CC 1 a ' r G Z W "'� \ a. f1O^ N �O �t / N O N LLX —I J N = CO p 3 ri N w w �W o 0 0 8 z. z M 6 � H —' 8 - ' .' N O N o n 7 Z nu r .., flb ) ,<tVMN co g Amain .- < 0 2 I� c� N N v �y:� J a w pp�� 1- w Q a EE Q 2 N N 4 H Z N N O O Z M h p W ZOO a 2 I K K S ¢ U 8 ink>X z;p>X a3ap� . 2 .- J� \ y LL in 0 C7 0 ^z O r a V 0 J 4.1 / t i' i i 4.,Q,, .":.----,„.---, '''''Y '''.-------,:-.'-----.. . ce cc ix7 t ` `f :fesO O O o _ QCD •W � _ ,` wzoP � � o� V. o Z mss I o' 0 • C*, a poll / Q Z3 up s 2°� p g U CI .� --" N 3 07 0 w 9 - s d g 70 \ ----, H so. y /\ 1xs i �i N Ow �_�\`�`-� a_ "i------- --_.-� '1 Iii Z' li I ' O O ss\ Z;� OOW g % � %%%%%%%%vk,„, a a ; i "I W as v o ^.z�' I . 1 'H U] o.mit ,U-,g II A : uj x92 Lft x '[ •� -. II F, - >LLZ x s\t J S i Linc Energy Operations EIIERGY 2014 Exploration Project Well #23H, Umiat, Alaska 23H Summary of Operations: 1-28 to 3-28-14 PTD No. 213-020 (All depths RKB unless labeled otherwise) 1/28/14: Set Matting Boards on 23H pad. Move sub-base onto location with Steigers. 1/29/14: Continue rigging up on 23H. Spot Mats, move sub-base, attempt to raise derrick. 1/30/14: Remove faulty hydraulic cylinder from below derrick. Send to Anchorage for testing and rebuild. Continue RU of remaining loads to 23H pad. 1/31/14: Hook up degasser, Line up mud pre-mix lines. Worked on a containment berm and organized pad 23H. 2/01/14: Complete installation of modified nipple on well head. Started the nipple up of the diverter. 2/02/14: Set starting flange onto wellhead. 2/03/14: Perform Mock Spill Drill with Environmental regulators. Flange up Diverter on well conductor pipe. 2/04/14: Transfer Drill Pipe from Seabee Pad to 23H. Move GCI communication Trailer to 23H. Continue to rig up Pason system, energize #1 boiler. 2/05/14: Continue waiting on raising hydraulic ram to arrive. Wire in and test dewatering house. Prep boiler#2 for insulation. Install flow line. 2/06/14: Continue waiting on raising hydraulic ram to arrive. Troubleshoot and fire up #2 boiler. Connect rig electrical interconnects. 2/07/14: Installed raising ram. Raised rig floor. Stacked modules up on top of sub-base. 2/08/14: Stacked modules up on top of sub-base. Rigged up interconnects. Set pipe shed in place. 2/09/14: Rigged up pipe shed. Raised derrick. Rigged up gas-buster. Performed general housekeeping around the rig. 2/10/14: Rig up top drive torque rail, service loop, and kelly hose. Set Drill Cool units in place. 2/11/14: Nippled up hydril, pitcher nipple, and flow line. Continue rigging up rig. Final Well Report Page 1 • • UMIAT #23H Mud Weight vs. Depth 0.0 UMIAT#23H 600.0 — _ s .. 0. ar To U Y G) d al 7 It r-- 1200.0 _. Lateral section 6.5 7.0 7.5 8.0 8.5 9.0 9.5 Mud Weight(ppg) • Linc Energy Operations 2014 Exploration Project Well #23H, Umiat, Alaska 2/12/14: Load pipe shed with 58 jts 4-1/2" drill pipe and 19 jts of HWDP. Set support offices around the rig. Repaired mud pumps. 2/13/14: Removed and replaced #3 fluid end on #1 mud pump. Shut down heavy equipment operations due to extreme cold temperatures. 2/14/14: Hydro-test pit system. Pick up drill pipe and rack back in the derrick. Test diverter system. 2/15/14: Spud well 23H @ 18:45 hrs on 2/15/14. Mud pump discharge damper failed. Repair discharge damper and replace swabs/liners in #1 mud pump. 2/16/14: Drill to 300' to facilitate picking up logging tools. Make up logging tools. Shallow hole test LWD tools. 2/17/14: Make up 9 7/8" build assembly. Drill ahead to 382' MD. Pull tight and stuck at 308' MD. Work pipe. 2/18/14: Jar and work stuck pipe. Lay down fishing jar. Continue working pipe with no result. 2/19/14: Preventative maintenance on rig equipment. Prepare rig floor and pipe shed for fishing operations. 2/20/14: Fish radioactive source out of ADN-6. Back off pipe and NMDC from drilling assembly. Screw into,jar free, and retrieve drilling assembly. 2/21/14: Lay down fishing tools and fish. Service rig. Cut drilling line. Pick up drilling assembly. 2/22/14: Drill 9 7/8" hole to 583' MD. Shut down to repair HPU coupling. 2/23/14: Repair HPU. Continue drilling 9-7/8" hole to 1,025' MD. 2/24/14: Trip in the hole with new bit. Drill ahead in build section from 1,031' MD to 1,160' MD. 2/25/14: Drill ahead from 1,160' to 1,390' MD.Trip out 4 stands and run back in with HWDP for push pipe. Drill from 1,390' to 1,490' MD. 2/26/14: Change out swab on #2 mud pump. Drill and land surface section in pump tangent from 1,490' to 1,713' MD. Final Well Report Page 2 . Linc Energy Operations 2014 Exploration Project Well #23H, Umiat, Alaska 2/27/14: Drill ahead from 1,713' to 1,787' MD.Troubleshooting SCR room for high heat. Drill from 1,787' to 1,894' MD. 2/28/14: Drill ahead from 1,894' to section TD of 1,980' MD. Back ream out of hole in preparation for upcoming logging job. 3/01/14: Pick up logging BHA. Trip in hole from 373' to 1,980' MD. MAD pass from 1,980' to 246' MD. Lay down logging BHA. 3/02/14: Make Up 7-5/8" casing and run in hole to TD 1,980' MD. Circulate and condition mud in preparation for surface cement job. 3/03/14: Rig up and pump surface cement. Cement returns observed at surface by BLM rep Justin Miller. Pump 112 BBL 11 PPG Litecrete. Pump 32.2 BBL 15.8 PPG Class G Cement. Drop top plug. Displace with rig 85.9 BBL 8.0 PPG Versaclean. Cement back to surface 40 BBL into displacement. Bump plug 85.9 BBL into displacement. 45.9 BBL cement back to surface. Cement in place at 02:44 hrs. Bump plug and pressure to 1700 psi for 15 minute casing pressure test. Good. Bleed off and check floats. Good. Nipple down diverter and line. Nipple up BOPE. 3/04/14: Continue to nippling up BOPE. Lay down 4-1/2" drill pipe. 3/05/14: Continue laying down 4-1/2" drill pipe. Test BOP equipment to 250 psi low, 1,500 psi high for 10 minutes each test. BLM test witness Justin Miller. AOGCC witness waived by Guy Schwartz. 3/06/14: Service rig. Make up 6-3/4" drilling BHA. Shallow test LWD. Run in hole to 1,786' MD. 3/07/14: Run in hole from 1,786' to 1,876' MD. Drill out shoe track and 20' of new formation to 2,000' MD. Perform FIT to 11.0 ppge. Swap drilling fluids to production system. Drill ahead from 2,000' to 2,287' MD. 3/08/14: Drill from 2,287' MD to a total depth of 2,973' MD. 3/09/14: Drill from 2,973' MD to a total depth of 4,100' MD. Begin to backream out of hole. 3/10/14: Backream out From 4,100' to 775' MD. Circulate bottoms up on first three stands. Hole clean. Trip in hole to TD. 3/11/14: Backream out From 4,100' to 700' MD. Cut and Slip Drill Line. Trip out of hole, and lay down BHA. Final Well Report Page 3 • • Linc Energy Operations 2014 Exploration Project Well #23H, Umiat, Alaska 3/12/14: Pick up 4-1/2" slotted liner and 2-3/8" inner string. Run in hole with 4-1/2" slotted liner. 3/13/14: Ream liner down on drill pipe. Set liner at 4040' MD. Liner top at 1,858' MD. Trip out, lay down inner string. 3/14/14: Continue to trip out of hole with 2-3/8" inner string. Lay down Baker equipment. Swap upper ram from 4" fixed to 3 1/2" fixed. Test BOPE. 3/15/14: Run 3 1/2 tubing string to just above liner top. Rig up slickline. Run in and swab well with slickline swab assembly. 3/16/14: Swab well with slickline swab-cup assembly. 3/17/14: Swab well in with slickline swab-cup assembly. Trip out from swabbing run. Pick up ESP completion assembly. 3/18/14: Swab well in with slickline swab-cup assembly. Trip out from swabbing run 3/18/14: Pick up ESP completion assembly. Run ESP completion. Nipple down BOPE. 3/19/14: Nipple down BOPE. Nipple down BOPE, Nipple up tree. Install ESP power/communication cord. 3/20/14: Pressure test PTS hardline. Flow test well. 3/21/14: Shut in for well bore for buildup rate data. Flow test well. 3/22/14: Flow test well. 3/23/14: Flow test well. Shut in for well bore for buildup rate data. Flow test well. 3/24/14: Flow test well. Shut in for well bore for buildup rate data. 3/25/14: Shut in for reservoir build up data. 3/26/14: Shut in for reservoir build up data. 3/27/14: Shut in for reservoir build up data. Pump produced fluids into IA back into reservoir. Install BPV in tubing spool. 3/28/14: Pump produced fluids into IA back into reservoir. Final Well Report Page 4 • • F LINO ENERGY WELL 239 SECOND FLOWBACK DATE CLOCK TUBING TUBING STATIC DIFF. METER I.IQLID TANK Took WATER Mud Tank Tank Tank Tank Tank Tank T 4 COMMENTS TEMP PRESS. U PRESS. PRESS. TEMP METER TOTAL flowing % Weight em MM/DUM' HIUMM F prig psi(g) psi(g) BBL BBLS into 1 2 3 4 5 6 this time 3121/2014 5'.04 Start pump up 30 10 4 0 100 0 0 4 0 0 201 70 46 257 282 0 trace' of 5 30 24 7 10 0 87 0 0 4 0 n'a 0 'diesel in all 6'.00 5:42 Liquid to surface Ramp pump up 29 19 11 0 61 8 3 4 0 7.0 6.30 31 17 .' _ 11 0 76 12 5 4 0 37 5 6.9 7:00 31 19 12 0 70 16 7 4 0 7.2 7:30 30 23 17 0 60 19 10 4 0 7.0 - 8:00 28 24 17 0 60 21 15 5 4 0 7.' 7.0 _ 8:30 80%mud -.MIN 29 29 , 22 0 5625 15 0 4 0 7.0 9:00 5%Mud in the water cut 28 21 15 0 54 29 19 4 4 0 7.0 9:30 Light trace of gas to surface 29 26 19 0 50 39 22 3 4 0 7.0 _ 10:00 api 37.5 29 25 18 0 48 46 22 0 4 0 6.9 10:30 3%Of solids in the ware'r,5 29 24 18 0 46 55 26 4 4 0 8.9 11:00 , 100%Oil,no solids. 29 23 15 0 44 63 35 9 4 0 7.0 11:30 3"1 27 22 15 0 52 69 36 1 4 0 7.0 322/2014 12:00 Nit- 27 22 14 0 58 74 40 4 4 0 7.0 12.30 3%mud 27 22 15 0 60 80 43 3 4 0 37 5 7.0 1:00 api 37 5 3/3% 26 21 14 0 64 86 45 2 4 0 7.1 1:30 WT.#7.1 no traces of qas. 24 21 14 068 - 91 49 4 4 0 7.1 2.00 Took the 4 hour oil sample. 24 20 12 0 68 96 51 2 4 0 37 5 7.1 2:30 4.111 23 17 10 0 67 100 52 1 4 0 7.1 3:00 5%mad in sam le 22 15 6 0 70 102 54 2 4 0 7.1 330 15 14 5 0 64 102 56 0 4 0 0 0 4'.00 4.15 inc.pump rate,getting returns. 13 1321: 5 0 64 102 56 0 4 0 0 4'.30 5%mud in sample 23 39 9t'' 28 0 60 115 61 5 4 0 0 5:00 WI.#7.1 API 37.0 25 33 25 0 60131 68 7 4 0 37 7.0 5:30 23 21 11 7 0 64 142 71 3 4 0 7.0 6.00 API 37 22 20 5 6 0 63 142 71 0 4 0 37 7.0 6:30 Obtained samlpe for Line 22 22 11 0 89 152 77 6 4 0 7.0 7:00 21 18 1 11 0 69 155 81 4 4 0 7.0 7:30 25 25 17. 13 0 62 168 89 8 4 0 7.0 8:00 API 37 27 29 4' 14 0 64 193 96 7 4 0 37 7.0 8:30 26 30 21 0 84 201 103 7 4 0 7.1 9:00 wheathedord isullin samples 24 34 25 0 48 209106 3 4 0 n/a ..9:30 24 39 30 0 50 217 111 5 4 0 n/a _ _ 10:00 27 37 29 0 56 230 117 6 4 0 n/a 10:30 25 36 27 0 50 241 121 4 4 0 n/a 11:00 27 36 28 0 48 253 126 5 4 0 n/a 11:30 28 36 28 0 46 262 129 3 4 0 n/a 12:00 We resume testing 30 36 29 046 273 135 6 4 0 7.1 12:30 31 36 30 0 50 203 140 5 4 0 7.1 13:00 30 36 30 0 58 295 144 4 4 0 7.0 13:30 29 37 30 0 60 306 149 5 4 0 7.0 14:00 29 39 29 0 64 _ 318 154 5 4 0 38 7.0 14:30 27 37 30 0 62 328 159 5 4 0 7.0 15:00 25 38 29 0 60 340 163 4 4 0 7.0 15:30 27 38 29 0 48 352 169 6 4 0 7.0 16:00 Good and steady flow 28 37 29 _ 0 46 363 173 4 4 0 7.0 • 16:30 30 37 0 30 0 44 374 178 5 4 0 7.0 17:00 , 28 37 0 - 30 0 43 397 182 4 4 0 7.0 17:30 Trace of mud. 28 37 0 30 0 40 397 186 4 4 0 38 7.0 18:00 28 37 0 30 0 52 409 192 6 4 0 7.0 ' 18:30 28 38 0 30 0 56 421 196 4 4 0 7.0 19:00 25 38 0 30 0 60 435 201 5 4 0 38 7.0 19:30 24 38 0 30 0 62 443 205 4 4 0 7.0 20:00 3%mud in the sample point. 26 38 0 30 0 57 453 210 5 4 0 7.0 3/22/2014 20:30 26 38 0 31 0 48 466 215 5 4 0 38 7.0 21:00 29 21 0 15 0 45 475 219 4 4 0 7.0 -�-- 21:30 API 38.1%mud. 28 22 0 14 0 44 480 221 2 4 0 7.0 22:00 Took the 4 how oil sample. 29 20 0 13 0 58 484 222 1 4 0 38 7.0 22:30 28 20 0 : 12 0 61 487 226 0 4 0 7.0 23:00 24 21 0 12 0 50 490 226 0 4 0 7.0 23:30 25 22 0 13 0 60 493 229 3 4 0 38 7.0 3/23/2014 0:00 Good flow with no leaks. 24 20 0 11 0 64 497 231 2 4 0 7.0 0:30 23 20 0 11 0 65 499 231 0 4 0 7.0 1:00 24 18 0 10 0 68 502 235 4 4 0 38 7.0 1:30 27 19 0 12 0 54 505 236 1 4 0 7.0 2:00 26 17 0 10 0 50 507 238 2 4 0 7.0 2:30 Heater by the safety valve went out. 22 19 0 11 0 60 509 240 2 4 0 37 7.0 3:00 21 20 0 12 0 60 512 242 2 4 0 7.0 3:30 23 18 0 10 0 62 514 243 1 4 0 7.0 4:00 24 17 0 11 0 60 516 245 0 4 0 36.8 7.0 4,30 27 17 0 10 0 62 518 245 0 4 0 7.0 5:00 Swapped heater for safety valve. 29 16 0 9 0 62 519 247 2 4 0 7.0 5:30 29 18 0 11 0 50 520 247 0 4 0 37.5 7.0 6:00 29 14 0 9 0 62 523 249 2 4 0 7.0 6:30 Baker increased pump rate. 29 17 0 7 0 66 524 250 1 4 0 7.0 7:00 28 22 0 13 0 64 525 251 1 4 0 37.6 7.0 7:30 24 15 0 11 0 68 528 254 3 4 0 7.0 8:00 25 19 0 ' 7 11 0 66 528 254 0 4 0 7.0 8:30 22 11 0 8.. : 10 0 54 531 256 2 4 0 37.1 7.0 9:00 27 10 150 11 0 64 532 257 1 4 0 7.0 9:30 120 9:45 100 10:00 90 10:15 50 10:30 30 10:45 10 11:00 15 11:15 20 11:30 45 12:00 50 12:30 50 13:00 install a new guage 0 1# _ 13:30 0 14:00 0 14:30 0 15:00 0 15:30 Metalled new 1500#guage 0 16:00 10 _ 16:30 10 17:00 10 17:30 10 18:00 10 • I ! • L - 18:30 10 19:00 10 19:30 10 20:00 10 20:30 10 21:00 10 21:30 10 22:00 10 22:30 10.32pm Opened the well. 23 10 0 5 0 100 534 0 0 0 0 0 201 70 46 257 282 0 23:00 29 12 0 6 0 68 541 14 14 0 371 7.0 14 23:30 29 31 0 2 0 64 544 14 0 0 7.0 14 3/24/2014 0:00 8%mud in the sample port. 28 29 0 30 0 72 548 15 1 0 7.0 15 0:30 43 38 0 26 0 78 553 21 6 0 1 7.0 21 1:00 58 38 0 35 0 76 558 22 1 0 7.0 22 1;30 61 37 0 28 0 73 563 26 4 0 7.0 26 2:00 56 33 0 19 0 70 568 28 2 0 7.0 28 2:30 _ 54 36 0 34 0 64 576 31 3 0 7.0 31 3:00 _ 49 36 0 28 0 58 581 33 2 0 7.0 33 3:30 51 35 0 31 0 65 586 36 3 0 36.6 7.0 36 4:00 59 35 0 31 0 69 591 38 2 0 7.0 38 4:30 56 28 0 28 0 70 598 43 5 0 7.0 43 5:00 59 29 0 29 _ 0 65 603 43 0 0 7.0 43 5:30 50 32 0 ,..: 24 0 62 , 607 47 4 0 70 47 6:00 48 33 0 30 0 66 611 49 2 0 7.0 49 6:30 54 26 0 ('�� 19 0 68 616 523 0 7.0 52 7:00 56 34 0 11 12 0 70 620 54 2 0 7.0 54 7:30 55 35 0 24 0 69 626 56 2 0 7.0 56 8:00 53 31 0 29 0 71 630 58 2 0 7.0 58 8:30 58 33 0 27 0 71 634 61 3 0 7.0 61 9:00 58 29 0 28 0 72 639 63 2 0 7.0 63 9:30 46 37 0 16 31 0 76 643 66 3 0 7.0 56 10:00 43 28 0 28 0 76 647 68 2 0 7.0 68 10:30 41 36 0 28 0 68 652 71 3 0 7.0 71 11;00 43 34 0 _ 29 0 61 656 71 0 0 7.0 71 11;30 37 27 0 18 0 56 660 75 4 0 7.0 75 12:00 37 35 0 29 0 60 663 77 2 0 7.0 , 77 12;30 39 25 0 20 0 54 667 79 2 0 3:6 7.0 79 13;00 37 37 0 31 0 54 670 81 2 0 7.0 81 13:30 36 29 0 19 0 52 674 85 4 0 7.0 85 14:00 43 36 030 0 52 677 87 2 0 37.9 7.0 87 14:30 41 26 0 `;it( 26 0 51 681 87 0 0 7.0 87 15:00 48 35 0 "'1(. 29 0 50 684 91 4 0 6.9 91 15;30 28 33 0 '9(. 28 0 48 687 92 1 0 37 9 6.9 92 16;00 45 26 0 111, 19 0 48 691 94 20 8.9 94 16;30 43 35 0 911 30 0 50 _ 694 97 3 0 7.0 97 17;00 32 29 0 61t�. 26 0 48 697 100 3 0 7.0 99 17;30 37 28 0 29 0 _ 61 701 1033 0 7.0 103 18:00 29 34 0 27 0 58 704 103 0 0 7.0 _ 103 18;30 33 27 0 26 0 50 707 107 4 0 37 r 7.0 107 19:00 32 37 0 30 0 46 711 107 0 0 7.0 107 19:30 33 34 0 28 0 60 714 109 2 0 7.0 109 20:00 32 24 0 20 0 62 717 112 3 0 37 3 7.0 112 _ 20:30 32 36 0 29 0 65 720 112 0 0 7.0 112 21:00 32 34 0 "_1 C. 29 0 67 723 114 2 0 7.0 114 21:30 32 28 0 .5;- 22 0 64 726 116 2 0 366 7.0 116 22:00 33 36 0 „..... 26 0 60 729 119 3 0 7.0 119 i 4 22.30 30 32 0 27 0 62 733 121 3 6 0 7.0 121 2100 Shut in Well @11:00pm 32 13 0 12 0 62 736 123 2 6 0 36.6 7.0 123 23:15 0 0 23:30 0 0 23:45 0 0 '1,7. 3/25/2014 0:00 0 0 0:15 0 0 0:30 0 0 0:45 0 0 1:00 0 0 1:15 0 0 1:30 Monitoring down hole and surface psi. 0 0 1.45 0 0 _-- 2:00 0 0 2:15 0 0 230 0 0 245 0 0 3:00 0 0 3:15 0 0 3:30 0 0 3:45 0 0 4:00 0 0 4:15 0 0 4:30 0 0 4:45 0 0 5:00 0 0 5:15 0 0 5:30 0 0 i 5:45 0 0 _ 6:00 0 0 6:15 0 0 6:30 0 0 6:45 _ 0 0 1 7:00 0 0 a __......._.. 7:15 0 0 7:30 0 0 7:45 0 0 8;00 0 0 8:15 0 0 8:30 0 0 8:45 0 0 --- 9:00 0 0 9:15 0 0 9:30 0 0 9:45 0 0 _ 10:00 0 0 10:15 0 0 10:30 0 0 10:45 0 0 _ --- 11:00 0 0 11:15 0 0 11:30 0 0 11:45 0 0 12:00 0 0 12:15 0 0 12:30 0 0 • • !vt- • 12:45 0 MN 13:00 0 13:15 0 13:30 0 13:45 0 14:00 0 14:15 0 14:30 0 14:45 0 15:00 0 15:15 0 15:30 15:45 0 16:00 0 <(, 16:15 0 ( 16:30 0 (' 16:45 0 2(' 17:00 0 ( 17:15 0 20 17:30 0 20 17:45 0 18:00 0 ( 18:15 0 2(' 18:30 - 0 (' 18:45 0 (- 19:00 0 2( 19:15 0 2( 19:30 0 -2( 19:45 0 20:00 0 20:15 0 20:30 0 20:45 0 21:00 0 2115 0 21:30 0 21:45 0 22:00 0 22:15 0 22:30 0 '2 22:45 0 2' 23:00 0 2' 23.15 0 23:30 10 23:45 10 21 0:00 10 2 0:15 10 2 0:30 10 0:45 10 1:00 10 1:15 10 1:30 10 1:45 10 2.00 10 2:15 10 y 2:30 10 2 • • 2:45 0 10 3:00 0 10 3:15 0 10 3:30 0 10 3:45 0 10 4:00 0 10 4:15 0 10 4:30 0 10 4'45 0 11 5:00 0 12 515 0 13 5:30 0 13 5:45 0 13 6:00 0 13 6:15 Start of very hi flow rate n/a n/a - 6:30 n/a n/a 6:45 n/a n/a 7:00 n/a n/a 7:30 n/a n/a - 8:00 n/a n/a 8:30 n/a n/a n/v 9:00 n/a n/a "11/a 9:30 Stop high Tow,shut in well, n/a n/a 10:00 blow down IA thru flare 0 100 10:15 Monaorinq down hole and surface ps: 0 50 10:30 0 0 _ "_ 10:45 0 0 11:00 0 0 11:15 0 0 11,30 0 0 11:45 0 0 12:00 0 0 201 70 46 257 282 194 Tanks 7-14 12:15 0 0 MUD have trace of 12:30 0 0 Tank diesel from 12:45 0 0 Pressure Test 13:00 0 0 13:15 0 0 13.30 0 0 101 13:45 0 0 1400 0 0 1415 0 0 1430 0 0 14'45 0 0 1500 0 0 1515 0 0 15:30 0 0 - _ 15:45 0 0 1600 0 0 16.15 0 0 16.30 0 0 16'45 0 0 17.00 0 0 17.15 0 0 17'.30 0 0 ----_- 1745 0 0 1800 0 0 • • 18:15 0 0 18:30 0 0 18:45 0 0 19:00 0 0 19:15 0 0 19:30 0 10 19:45 10 20 20:00 10 20 _ _ 20:15 10 20 20.30 _ 10 20 20.45 10 20 21'.00 30 20 21:15 _ 30 20 -- 21:30 30 20 21:45 - 30 20 22:00 _ 20 20 22:15 20 20 22:30 20 20 22:45 20 20 ., 23:00 30 20 23:15 30 20 23:30 30 20 23:45 30 20 0:00 40 20 0:15 40 20 0:30 40 20 -- 0:45 40 20 e- •...... 1:00 40 20 1:15 40 20 1:30 40 20 1:45 40 20 2i' 2:00 40 20 :'2( 2:15 40 20 2:30 40 20 2:45 30 10 3:00 30 10 3:15 30 0 3:30 30 0 3:45 30 0 4:00 30 0 4:15 30 0 4:30 30 0 4:45 30 0 5:00 _ 30 0 5:15 30 0 5:30 30 0 5:45 30 0 6:00 6:15 6:30 6:45 7:00 • ' } . . _... 2414 Linc Energy Zach Sayers [ UMIAT #23H WELL TESTING SUMMARY] This document contains a summary of the completion design, an overview of the methodology behind the testing procedure, and a summary of the well tests completed. Confidential This document and its contents are confidential to the person to whom it is provided and should not be copied or distributed in whole or in part or disclosed by such person to any other person without Linc Energy Ltd prior written consent. 2014 Linc Energy Ltd OlInc MERCY Contents Confidential 0 Contents 1 1. Completion Design 2 2. Methodology: 6 3. Operation• 6 Flow Period 1: 6 Testing Procedure• 6 Results: 6 Flow Period 2: 8 Testing Procedure- 8 Results: 8 Flow Period 3: 10 Testing Procedure• 10 Results: 10 Flow Period 4: 11 Testing Procedure• 11 Results: 11 Confidential 1 .„. • 0 . . , 0LIOC ENERGY 1. Completion Design The production section was completed with a slotted liner and a liner top packer. The slot size was chosen due to the micron size of the reservoir sand and the understanding that the sandstone was competent. The slot width was 3,175 microns. 4 Rows per foot 3.,, Centers • 0.125" x 2.5" slots i I .1 [ [ 32 slots per foot 1 • L 4.5" 12.6ppf L-80 base pipe , 1 b 2.5- r r nFrr - — 1 / Slots L. L. L LLLLL — FFP PPP ' n , ii li r r r rrirr 1' Row 1 , 1, 1 1 1 1 h 11 1 , _ L - _. L Figure 1: Slotted Liner Design A Liner Top Packer(LIP)was placed at the top of the slotted liner to create a pack off on the annulus. The prevented cuttings beds, and produced solids from being produced through the annular area, and forced flow to go through the slots. Baker ZXP Liner Top Packer v.:,. ;• 4-1/2" 1 Slotted Liner 3.958" lien 1 All. IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIII Figure 2: Liner Top Packer Display Confidential 2 1111 OL OC EII�ERGY The ESP was lowered to the bottom of the well in a deeper True Vertical Depth (TVD)than the reservoir. Using a mid- reservoir depth of 985'TVD and assuming the gradient of 38 API oil (6.95 ppge)the pump had 101.5 psi of hydrostatic head above it from reservoir. Umiat - 23H Interpreted Measured Depth Cross-Section 34c 0'1VU A 2'5 .'S0 225 20C 15 Cox rosewo r grainy pry- - 125 �Craina:»nmroav sr+3sik l00 .5 7a7 UCIST CtryanogDu* 50 25 0 -25 -50 -75 Veti at Esau/erector. 5.-x -100 -125 Repeated toarro&Ptwsare ler x invesx ; -150 • 111 pp{•f25.0A52:327p.i -1T5 x -200 r Tre:L`,"- rye -2J- -2A.41a.;:T:s �F+ `3z�a'S Erma s..•r�4�1 -300 r IMT -3. : .>,..L1S.SmS . 16MS7VD _ '•jyr ax -425 .450 — ;- -475 r.<• -5x a -525 -55. lade LJd' 19.V" :;5C ' , ( ESP Pump • . 1266'IVD -'Sc 500 100J 1502 :JG: 2500 3XC 3500 4X2 ligatured Depth Figure 3: ESP Placement Relative to Geology Confidential 3 ., S io 4 , Cs) EflERGY The tubing was left open (without a production packer) on the tubing x casing annulus. This allows direct communication between the tubing and the IA. GL: 575'AMSL RIG RKB: 596'AMSL w. q 1 RKB.GL: 21' I .• 13-3/8" 1 '.. 91'TVD ;Y FIT=10.1 ppg °r" LOT=10.6 ppg d r.. rn i pY• Ya. w `T � 1.280'TVD 1 Lower Grandstand ,s jFIT=11.0 ppg 971'MD.928'IVO a• N ' pp .�� 4.1/2"ITP.1,858'MD.1.260' €; "`�: '.-L- 41/2' Sbtted Liner 4 rwr Base LGS 1.370'MD,1,260'TVD Baker ESP 1,548 MOf1,240 7-5/8" Ta 10:4,040 MD1913 TVD TD:1,956 MDJ1,164 TVD Figure 4: Wellbore Schematic Wellbore Capacities: 1,858' of 3-1/2"9.3#Tubing and 7-5/8"29.7#casing annulus(0.0340 bbl/ft): 63 Bbl 1,858'of 3-1/2"9.3#Tubing capacity(0.0087 bbl/ft): 16 Bbl 2,100'of 4-1/2" 12.6#Liner capacity(0.0152 bbl/ft): 31 Bbl 2,100' of 4-1/2"x 6-3/4"OH capacity(0.0246 bbl/ft): 52 Bbl Total Well Capacity: 162 Bbl Confidential 4 • CA) EIIERGY It is also noted that the ESP had a degasser installed. This propelled solution gas from reservoir fluids to the IA. IA pressures, bleed off methods, and monitoring will be discussed in the specific testing sections. N Gas Vent Port Separation f Chamber Guide Vane Inducer or NAVA I I I Intake Figure 5-1 Rotary Gas Separator Figure 5-2 Gas Separalor Figure 5: ESP Gas Separator Confidential 5 • EURO 2. Methodology: The well testing was performed using an Electrical Submersible Pump (ESP) because the reservoir was assumed to be under-pressured, meaning it could not sustain flow naturally to surface. The pump selected allowed for a wide array of flow rates and fluid compositions. Given the assumed reservoir conditions,the ESP chosen could operate from 75 BOPD to 3,000 BOPD. Once the pump was in hole and surface power was connected,the tubing was hard line connected to a test separator,then routed to a series of 400 bbl upright tanks. A total of four flow and build-up test periods were performed all at different rates and pressures. A minimum intake pressure of 150 psi at the pump was chosen to avoid drawing the reservoir down below 50 psi tubing pressure at the sand face. 3. Operation: Four separate flowing and build up periods were completed. Each of these sequences will be discussed in detail below: Flow Period 1: Testing Procedure: Ensured 0 psi is on IA. Closed IA valve. Fluid level on the IA before turning on the pump was calculated at 390'ND static. The motor was turned on and held. It is important to note that from 23:25 till 23:45 on 3/20/2014 the generator supplying power to the Variable Speed Drive (VSD) skid went down,subsequently the motor and communication to down hole gauges was halted. Power was restored at 23:45, and the motor was brought back to previous speeds. The flowing period continued until 5:00 AM on 3/21/2014 (a total of 15.75 hrs of flowing). At 5:00 AM the tubing was shut in and the IA remained shut in. The well was shut in till 17:15 3/21/2014 (a total of 12 hrs shut-in). Results: 550 500 450 400 ..._.. +—Intake Presre:__ 350 —Linear(kntare Presrc) 300 — 250 200 150 12:00 13:00 14:00 1500 16:00 17:00 18:00 19:00 2000 2100 22700 23700 0:00 1:00 2:00 3:00 4:00 5:00 Figure 6: Test 1 Intake Pressure Confidential 6 OLIDC 550 500 Ellaraliattlarlialfallniirpgiwwwwwim.ppimpirampipqmpopomesyar......r.1140.410111***1140,1401111~Ialalti 450 400 350 —6—DischergePressure: 300 250 —Linear(D&h.Le MEMO 200 150 1200 1390 14:00 15:00 1600 17130 1840 1400 2000 2100 22130 23130 000 100 21)0 390 400 1:00 Figure 7: Test 1 Discharge Pressure 550 500 450 —+—UtakePresum 400 —Liras(Intake Pressure:) i 350 300 250 200 _,��,__•� -- 150 5:00 600 7130 890 9:00 10:00 1190 1200 1300 1400 15130 161)0 1700 Figure 8: Test 1 Shut-in Period Intake Pressure A total of 200 bbls of oil were produced this flow period. Confidential 7 • • a • , „ car) �• EIIERGY Flow Period 2: Testing Procedure: Ensured 0 psi is on IA. Closed IA valve. The motor was turned on at 17:15 3/21/2014 The flowing period continued until 8:00 AM on 3/23/2014 (a total of 38 hrs pumping). At 8:00 AM the tubing was shut in and the IA was checked for pressure. It was discovered that the IA had a total of 150 psi of pressure built up.The IA was bled off to 0 psi, and then closed in. The well was shut in till 22:30 3/23/2014 (a total of 12 hrs shut-in). Results: 250 _... .. Mare Pr�.�e 225 —Gneer onvice Pressure:} 280 _ _. ... 11 175 150 125 1790 MO MO 20370 2190 2290 MOD 070 1110 270 390 490 5110 6O0 7O0 8O0 990 1090 11110 1200 1300 1400150016001720MOO 190020110210022002390 000 L90 290 390 4110 590 6110 7310 860 Figure 9: Test 2 Intake Pressure Confidential 8 CEnERGY 545 525 485 506 iscr�arge r rescue: �[] 445 425 1703180019002000210022/3023:00 000 100 200 300 400 500 600 700 800 90010001100120013:00140015001600170018001900200021:0022.032300 0:00 100 100 300 4:00 500 600 700 800 Figure 10: Test 2 Discharge Pressure 250 _ —w—k :s xak e P r eure: 225 Bled off pressure from IA —Linear(intrkePress/re) zao 175 — -- 150 125 8:00 990 10:00 1100 12:00 13:00 14:00 15:00 16110 17110 18:00 1900 2C:X 21 Figure 11: Test 2 Shut-in Period Intake Pressure A total of 250 bbls of oil were produced this flow period. Confidential 9 • C") ENERGY Flow Period 3: Testing Procedure: Ensured 0 psi is on IA. Open IA valve to atmospheric pressure for the entirety of the test. The motor was turned on at 22:30 3/23/2014. The flowing period continued until 23:00 on 3/24/2014 (a total of 24 hrs). The pressures during this 24 hr flowing period were stable at an average of 164 psi. At 23:00 the tubing was shut in and the IA was closed in. The well was shut in till 07:00 3/26/2014 (a total of 32 hrs shut-in). Results: 250 225 IntakePrezve 200 R —linear(Intake Prmra) 175 i 150 - 125 22:00 2300 0.130 1:00 2110 3:00 4:00 590 6.00 7:00 8.00 9:00 10:00 1100 1200 1390 14:00 15:00 1600 1720 18:00 1900 2000 21:00 22:00 2390 Figure 12: Test 3 Intake Pressure 600 575 550 -f-Diert ergePreskire: 525 1 500 475 450 425 400 2200 2300 000 100 290 300 4:00 500 600 700 800 9:00 10:00 11:00 12:00 1300 1400 1500 16:00 17:00 18:00 1900 2020 21:00 22:00 23:00 Figure 13: Test 3 Discharge Pressure 250 225- 200 - - . i 175 -.-ntakePrestre: —Liar(61tke Primary) 150 125- 2300 0110 100 200 300 400 510 610 700 800 990 1000 1100 12-00 1300 1400 1500 16110 1700 1390 1990 2000 2100 2200 2300 000 100 220 300 400 500 600 700 800 Figure 14: Test 3 Shut-in Period Intake Pressure A total of 123 bbls of oil were produced this flow period. Confidential 10 we EOERGY Flow Period 4: Testing Procedure: Ensured 0 psi is on IA. The IA valve was closed during this short flowing test. The intake pressure limitation prior to pumping was reduced to 100 psi. This was in an effort to establish an upper limit to the flowing ability of the reservoir. The motor was turned on at 07:00 AM 3/26/2014. The flowing period continued until 09:09 on 3/26/2014(a total of 2 hrs of flow). The pressures during this 24 hr flowing period were stable at an average of 164 psi. At 09:09 the tubing was shut in and the IA remained closed in. The well was shut in till 10:00 AM 3/27/2014(a total of 24 hrs shut-in). Results: 250 225 _,-make Dr assure: 200 —L.near .nuke Pre3 e:; -- _ 175 150 125 100 75 7:00 890 990 Figure 15: Test 4 Intake Pressure 600 Soo —0—Discharge Pressure: 400 Sao 200 790 890 990 Figure 16: Test 4 Discharge Pressure 250 - 225 - __ Bled off pressure from IA — 1� —.—ktakePrmire : Linear(intake Praire:) 150 125 100 890 990 1090 11:00 1290 1390 1490 1590 1690 1790 1890 1990 2090 2190 2290 2390 0:00 190 290 390 490 5.:00 690 790 890 990 1090 Figure 17: Test 4 Shut-in Period Intake Pressure A total of 71 bbls of oil were produced this flow period. 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Alaska Division l 3_ p 2-0 Cie) EiIERGY 3000 C Street, Suite 103 RECEN q Anchorage, Alaska 99503 2M 2S 1 Phone: (907) 868-8660 Fax:(907) 868-8881 2 1 2014 DATA TRANSMITTAL Date: May 21, 2014 To: Attn: Meredith Guhl, Geologist From: Dave Boyer, Petroleum Geologist Alaska Oil&Gas Conservation Commission Linc Energy Operations, Inc. 333 W.7th Ave., Suite 100 3000 C Street, Suite 103 Anchorage, AK 99501 Anchorage, AK 99503 Phone: (907) 793-1235 Phone:(907) 375-2623 Cell.: (907)887-1387 TRANSMITTAL DESCRIPTION Drilling Reports &Wellsite Geologist's Final Report for Umiat 23H Well; late 2013-early 2014 Core Analyses for Umiat 18 Well; missing digital WL & LWD files for Umiat 18 Well In accordance with Alaska Statute AS 38.05.035(a)(8)(C) and Alaska Administrative Code 11 AAC 96.220, Linc Energy Operations, Inc. requests that confidentiality be extended to the information described herein and submitted with this transmittal. Qty. Description 1. Umiat 23H Data (wellsite qeo files &and drilling reports: 8 items) --1* 2)-( 2. Umiat 18: Well Test Procedures (7 items) 3. Umiat 18: Dips 4. Umiat 18: HH-62919 SEM-Descriptions 5. Umiat 18: HH 62919cc1XRD 6. Umiatl8: Mudliftoff Test 7. Umiat 18: HH-62919 Conventional Core Data 8. Umiat 18: HH-62919 Profile 02-13-14 9. Umiat 18: HH-62919 Vertical Core Data 10. Umiat 18: AIT HDRS HGNS LEH Main Pass (.pdf) 11. Umiat 18: AIT HDRS HGNS LEH Main Pass (.las-open in Notepad) 12. Umiat 18: OBMT GPIT PPC MAST Main Pass Maxwell :-(Zw 13. Umiat 18: OBMT GPIT PPC MAST Repeat Pass Maxwell 14. Umiat 18: Sonic Scanner Print Run 1B 15. Umiat 18: Tie-In TCP3-APR-2013 REV3 16. Umiat 18: Triple Combo Print Run 1A 17. Umiatl8: hh-62929 cc sem images 18. Umiat 18: hh-63919 cc sem plates 19. Umiat 18: Final Sonic Scanner 20. Umiat 18: Sonic Scanner BestDT.dlis 1. Umiat 18: Sonic Scanner Final.pds Linc nergy Operations, Inc. Alaska Division MERCY 3000 C Street, Suite 103 T Anchorage, Alaska 99503 Phone: (907) 868-8660 Fax:(907) 868-8881 22. Umiat 18: RTP Combo Fax DU 3 16Mar13 172837.pds 23. Umiat 18: SARA (4 24. Umiat 18: SoF � 25. Umiat 18: SOXHLET 26. Umiat 18: Triple Combo Tool Sketch New Received By: ,, Date: Returned to Linc Energy Operations, Inc. Date: Accepted By: • 4111 'SHE STATS Y , 1, cL 333 Wes; Seventh Avenue GovsI NoR SL;AN PAP.NEI,i Anchorage, Alaska 99501-3572 Man: 907 J9.1433 (Q7.2/6 75!2 (3 ^ 0 Nick Scales Drilling Manager - Alaska Linc Energy Operations, Inc. 3000 C Street, Suite 103 Anchorage, AK 99503 Re: Exploratory Field, Exploratory Pool, Umiat#23H Sundry Number: 314-271 Dear Mr. Scales: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair DATED this 15-F day of May, 2014. Encl. FIVE STATE OF ALASKA APR s9014 �2 ALASKA OIL AND GAS CONSERVATION COMMISSION 0 APPLICATION FOR SUNDRY APPROVALS ►GCC 20 AAC 25.280 1.Type of Request: Abandor ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well❑ Change Approved Program ❑ Suspenc ❑., I Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension ❑ Operations Shutdowr ❑ Re-enter Susp.Welt❑ Stimulate❑ Alter Casing❑ Other. Plyybaek� ❑ 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Linc Energy Operations, Inc. Exploratory Q, Development ❑ 213-020 3.Address: Stratigraphic [1 Service ❑ 6.API Number: 3000 C Street,Suite 103,Anchorage,AK 99503 50-287-20029-00-00 7. If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? Umiat#23H Will planned perforations require a spacing exception? Yes Li No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDAA84141 - Exploratory(Umiat) . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 4,040 986 4,040 986 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 91 13-3/8" 91 91 3450 1950 Surface 1,968 7-5/8" 1,968 1,260 6890 4790 Intermediate Production 1,858 3-1/2" 1858 1266 10160 10540 Liner 2182 4-1/2" 4040 986 N/A(slotted) N/A(slotted) Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): NA NA 3-1/2" L-80 1,858 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A 12.Attachments: Description Summary of Proposal 2 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑✓ , Stratigraphic❑ Development ❑ Service ❑ 14.Estimated Date for 4/28/2013 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended 0- 16.Verbal Approval: Date: 4/28/2013 WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: Guy Schwartz GSTOR ❑ SPLUG Li 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Zach Sayers Email Zach.Savers(a�lincenercfy.com Printed Name Nick Scales Title Drilling Manager-Alaska Signature7iel Phone 907-375-2603 Date ,Lf /z /z'4 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\4-* - 27 \ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Si-4-- ye.,--1 6. ,r j chi c-.. !Z - AS 12-12 Za 4 C— ZS. /1 a (e) FIDDM MAY 8 2014 z/ Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: 97 77/ ) L, APPROVED BY Approved by: / COMMISSIONER THEuCOMMISSION Date: /— n R t 1 4 f I e at yLtachF•irencsSubmit Form and Form 10-403(Revised 10/2012) Ap I I a 12 months from t e to of approval. � Attachments in Duplicate • • RECEIVED APR 29 2014 0 AOGCC E11ERGY Linc Energy Operations, Inc. 3000 "C" Street, Suite #103 Anchorage, Alaska 99503 April 28th, 2014 Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry Application (Well Suspension) Well: Umiat #23H (Existing Exploratory Oil Well) TRS: SWSW, TIN, R1W, Section 32, Umiat Meridian Dear Chairman Foerster, Linc Energy Operations, Inc. hereby applies for a Sundry Approval to Suspend the Umiat #23H Oil Exploration Well. Linc is currently evaluating the future utility of this wellbore based on the results of the flow testing initiated on March 20th, 2014. Options for upcoming seasons include an additional flow test or a chemical stimulation. Pertinent information attached to this application includes the following: 1) Form 10-403 Sundry Application 2) Operations Summary 3) Wellbore Schematic 4) Tree Configuration The following are Linc Energy designated contacts for reporting responsibilities to the AOGCC: 1) Drilling and Completions Nick Scales, Drilling and Operations Manager (907) 375-2603 2) Geologic Data and Logs David Boyer, Geologist (907) 375-2623 • • If you have any questions or require further information, please contact either Nick Scales, Drilling Operations Manager at (907) 375-2623 or Zach Sayers, Senior Drilling Engineer at (907) 375-2621 . Sincerely, ,erg Nick Scales Drilling Manager- Alaska UMIAT #23H Linc Energy Operations Inc. Operations Summary — Suspension 1. Fill wellbore w/ 6.8 ppg completion fluid (LVT-200 mineral oil). 2. Rig down ESP drive skip and surface whip. 3. Set BPV in tubing hanger. 4. Rig down Master Valve. 5. RD/ MO Kuukpik #5 rig. 6. Nipple up Full Tree. 7. Fill tree w/ Diesel for freeze protect and test to 1,500 psi. 8. Confirm all pressure 0 psi. Secure tree with gauges installed on IA and tubing. 9. Install permanent grating in well cellar. 1o.Drape tree w/ Herculite per BLM requirements and secure. 11.Rig down and suspend operations on Umiat #23H. It • • • . LI Pad: Umiat#23H Ice PadOF y.` Tubing Ha . , ;„ •m�-M,4" "H"BPV M Umiat #23H Lease: AA-084141(BLM) Tc a Connection: I a Well Type: p••r.ti•n(ail: ) #mafrost: 801'MD/793'TVD GL: 575'AMSL HOLE DATA RIG RKB: 596'AMSL 1 Hole Section Size Top(MD) Btm(N to(TVD) Mud Wt Max an i RKB-GL: 21' y' * ft ft ft ft ;.. tYPe PP8 d ... ,�,,. - Conductor 20" 0' 91 0' 91 N/A N/A 0° 13-3/8" - - 'y:` Surface 9-7/8" 0' 1968 0' 1260 OBM 8 100° "c} 91'TVD Production 6-3/4" 1858 4040 1266 986 OBM 7.5 102 1. FIT=10.1 ppg LOT=10.6 ppg CASING/TUBING DATA . Conductor ®.... 68 1-55 PE 12 415" 0' 91 0' 0 Surface Ell 29.7 L-80 BTC-MOD 6.875" 0 1968 0' hil Production Fin 12.6 L-80 IBT-MOD 3.958" 1858 4040 N/A Tubing ® 9.3 1-80 8 Rd 2.958" 0' 1858 N/A '1k b.. CEMENT DATA .. .._ :i Conductor In Permafrost 23'(GL) 100' 15.7 0.93 43 260 Surface In Permafrost 23'(GL) 1,594' 11.0 1.87 Surface Ell Class G 1.594' 1968 15.8 1.16 COMPLETION JEWELRY SUMMARY fY•; 1 Tubing Hanger Proposed j:n 2 Baker ZXP LTP Proposed ;r` +f\ 3 Baker ESP Pump 1848 Proposed '3- — - '. 4 10. 5 d - ._- ri' 7 1: .-t Lik MO '4••''; 1,280'TVDEll Lower Grandstand Vs FIT=11.0 ppg 971'MD,928'TVD Y ,•{ y%. *._ 41/2"n7,1,85)3'MD,1,260' 4.1/2" Slotted Liner I. K 2 OrLGS ' .-v.. ' J.-4%k.' 0'MD,1,260'TVD 7-5/8" TOE TD:4,040'MD/986'TVD TD:1,968'MD/1,260'TVD DATE REVISED BY: WELL HISTORY DESCRIPTION Well Name Umiat 8236 9/27/2013 Z.Sayers Proposed Lower Grandstand B-sand Horizontal Slotted Liner ESP Completion Spud Date N/A 10/30/2013 Z.Sayers Update to WP#9 API No. 50-287-20029-00 3/15/2014 Z.Sayers Update to Actuals PTD 213-020 Max Hole Angle 102 Max Dogleg 8 • • • 3 I/8-5000 (R-35)n77 Ti X OTIS CONNECTOR ✓/ I ��� 3 1/8-5000 MOD 120 GV 404:,4= 1, 'o Ku v' 15.00' `V 381.00 mm) 80.28' (2039.1 mm) 46°)Ir41 Aro + AP (5*A\ 24.31" (617.5 mm) 43.12 1095.2 mm) �@jiler 3 1/8-5000 MOD 120 CV W/ ACTUATOR 1■11i :.1 11 28/2 (714,3 mm) d4LOAtia 3 1/8-5000 MOD 120 GV I �3 V V' 9.3 i" (236.5 mm) 111101 t l 00 12DM 1073862 . • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday,April 29, 2014 4:26 PM To: 'Zach Sayers' Subject: RE: Umiat#23H 10-403 - Suspend PTD#213-020 Zack, You have approval as outlined in sundry to suspend Umiat 23H. -7 v:py Guy Schwartz Senior Petroleum Engineer / AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). From: Zach Sayers [mailto:zachary.sayers@lincenergv.coml Sent: Monday, April 28, 2014 10:58 AM To: Schwartz, Guy L(DOA) Subject: Umiat #23H 10-403 - Suspend PTD #213-020 Guy, Please find the attached 10-403 Sundry for Suspension of Umiat#23H. Thank you, Zach Sayers III 0 Drilling Manager P +1 713 580 6636 Nt E zachary.sayers@lincenergy.com OL.JI1C 1000 Louisiana, Suite 1500 Houston TX 77002 (Q(RGY United States Disclaimer Notice: The message and attachment(s) contained in this e-mail are intended for the named recipient(s) only. It may contain privileged or confidential information or information which is exempt from disclosure under the applicable laws. If you are not the intended recipient, you must not read, print, retain, copy, distribute, forward or take any action in reliance on it or its attachment(s). If you have received or have been forwarded this e-mail in error, 1 S Schwartz, Guy L (DOA) From: Zach Sayers <zachary.sayers@lincenergy.com> Sent: Wednesday, April 30, 2014 12:37 PM To: Schwartz, Guy L(DOA) Subject: RE: Umiat#23H 10-403 - Suspend P10 #213-020 Future plans for Umiat#23H include re-testing of reservoir and possible work over of the completion. 23H has mechanical integrity and is in a prime reservoir location for future reservoir performance testing. Zach Sayers CI Drilling Manager P +1 713 580 6636 M E zachary.sayers@lincenergy.com 0E]QCU 1000 Louisiana, Suite 1500 nHouston TX 77002 EDERGi ppUnited States P Disclaimer Notice: The message and attachment(s) contained in this e-mail are intended for the named recipient(s) only. It may contain privileged or confidential information or information which is exempt from disclosure under the applicable laws. If you are not the intended recipient, you must not read, print, retain, copy, distribute, forward or take any action in reliance on it or its attachment(s). If you have received or have been forwarded this e-mail in error, please notify us immediately by return e-mail or e-mail linc@lincenergy.com and delete this message from the computer in its entirety. Internet communications cannot be guaranteed to be secure and error-free as the information could be intercepted, corrupted, lost, arrive late or contain viruses. The sender and this Company therefore do not accept any liability or responsibility of whatsoever nature in the context of this message and its attachment(s) which arises as a result of Internet transmission. Opinions, conclusions, representations, views and such other information in this message that do not relate to the official business of this Company shall be understood as neither given nor endorsed by it. From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, April 29, 2014 4:32 PM To: Zach Sayers Subject: RE: Umiat #23H 10-403 - Suspend PTD #213-020 Zack, I also need some justification for the suspension ... please send a short email response outlining future plans for the well. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, 1 UMIAT #23H Linc Energy Operations Inc. Operations Summary — Suspension 4 /30/ILI p 1. Fill wellbore w/ 6.8 ppg completion fluid (LVT-200 mineral oil). 2. Rig down ESP drive skip and surface whip. 3. Set BPV in tubing hanger. 4. Rig down Master Valve. 5. RD/ MO Kuukpik #5 rig. 6. Nipple up Full Tree. 7. Fill tree w/ Diesel for freeze protect and test to 1,500 psi. 8. Confirm all pressure 0 psi. Secure tree with gauges installed on IA and tubing. 9. Install permanent grating in well cellar. 10.Drape tree w/ Herculite per BLM requirements and secure. 11.Rig down and suspend operations on Umiat #23H. • • Schwartz, Guy L (DOA) From: Zach Sayers <zachary.sayers@lincenergy.com> Sent: Wednesday, April 30, 2014 12:37 PM To: Schwartz, Guy L(DOA) Subject: RE: Umiat#23H 10-403 - Suspend PTD#213-020 Future plans for Umiat#23H include re-testing of reservoir and possible work over of the completion. 23H has mechanical integrity and is in a prime reservoir location for future reservoir performance testing. Zach Sayers GI Drilling Manager P +1 713 580 6636 M E zachary.sayers@lincenergy.com 1000 Louisiana, Suite 1500 u Houston TTX 77002 €III 6% United States P Disclaimer Notice: The message and attachment(s) contained in this e-mail are intended for the named recipient(s) only. It may contain privileged or confidential information or information which is exempt from disclosure under the applicable laws. If you are not the intended recipient, you must not read, print, retain, copy, distribute, forward or take any action in reliance on it or its attachment(s). If you have received or have been forwarded this e-mail in error, please notify us immediately by return e-mail or e-mail linc@lincenergy.com and delete this message from the computer in its entirety. Internet communications cannot be guaranteed to be secure and error-free as the information could be intercepted, corrupted, lost, arrive late or contain viruses. The sender and this Company therefore do not accept any liability or responsibility of whatsoever nature in the context of this message and its attachment(s) which arises as a result of Internet transmission. Opinions, conclusions, representations, views and such other information in this message that do not relate to the official business of this Company shall be understood as neither given nor endorsed by it. From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, April 29, 2014 4:32 PM To: Zach Sayers Subject: RE: Umiat #23H 10-403 - Suspend PTD #213-020 Zack, I also need some justification for the suspension ... please send a short email response outlining future plans for the well. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, 1 without first saving or forward. it, and, so that the AOGCC is Pare of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). From: Schwartz, Guy L(DOA) Sent: Tuesday, April 29, 2014 4:26 PM To: 'Zach Sayers' Subject: RE: Umiat #23H 10-403 - Suspend PTD #213-020 Zack, 1 You have approval as outlined in sundry to suspend Umiat 23H. tt- 2,/ Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). From: Zach Sayers [mailto:zachary.sayers@lincenergy.com] Sent: Monday, April 28, 2014 10:58 AM To: Schwartz, Guy L(DOA) Subject: Umiat #23H 10-403 - Suspend PTD #213-020 Guy, Please find the attached 10-403 Sundry for Suspension of Umiat#23H. Thank you, Zach Sayers Ili 0 Drilling Manager P +1 713 580 6636 M E zachary.sayersIincenergy.com 01111 1000 Louisiana, Suite 1500 Houston TX 77002 EllERGY United States Disclaimer Notice: The message and attachment(s) contained in this e-mail are intended for the named recipient(s) only. It may contain privileged or confidential information or information which is exempt from disclosure under the applicable laws. If you are not the intended recipient, you must not read, print, retain, copy, distribute, forward or take any action in reliance on it or its attachment(s). If you have received or have been forwarded this e-mail in error, please notify us immediately by return e-mail or e-mail lint@lincenerov.com and delete this message from the 2 computer in its entirety. Internet comm ions cannot be guaranteed to be secure aerror-free as the information could be intercepted, corrupted, lost, arrive late or contain viruses. The sender and this Company therefore do not accept any liability or responsibility of whatsoever nature in the context of this message and its attachment(s) which arises as a result of Internet transmission. Opinions, conclusions, representations, views and such other information in this message that do not relate to the official business of this Company shall be understood as neither given nor endorsed by it. 3 • • Linc Energy Operations, Inc. Alaska Division .IECEIVED 0 ENERGY 3000 C Street, Suite 103 APR 2 5 2014 Anchorage, Alaska 99503 Phone: (907) 868-8660 Fax:(907) 868-8881 !'1 OGCC DATA TRANSMITTAL Date: April 25, 2014 To: Attn: Meredith Guhl, Geologist From: Dave Boyer, Petroleum Geologist Alaska Oil&Gas Conservation Commission Linc Energy Operations, Inc. 333 W. 7th Ave., Suite 100 3000 C Street, Suite 103 Anchorage, AK 99501 Anchorage, AK 99503 Phone: (907) 793-1235 Phone:(907) 375-2623 Cell.: (907)887-1387 TRANSMITTAL DESCRIPTION LWD Final Logs (2 runs: prints & DVD); Mudlog and Show Reports (hard copy& DVD)from Umiat 23H Well; Wellsite Geologist's Final Report; "Dry" Cuttings (1 box) (washed in base oil); Wet Cuttings in bags (4 boxes). In accordance with Alaska Statute AS 38.05.035 (a)(8)(C) and Alaska Administrative Code 11 AAC 96.220, Linc Energy Operations, Inc. requests that confidentiality be extended to the information described herein and submitted with this transmittal. Qty. Description ( 1. Schlumberger LWD VISION (Resistivity, Gamma Ray) 200' to 4070' 12. Schlumberger LWD VISION (Neutron, Azimuthal Dens., Dens. Image) 200' to 4034' 1-1 1 b 3. Schlumberger LWD Sonic VISION (Delta-T Compressional) 200' to 1890' L4. Schlumberger Directional Survey Service 0 to 4100' 5. Dry Well Cuttings (washed in base oil) 130' to 4100' (1 box) 6. Canriq Formation Mudlog 2"=100' (MD &TVD color prints) 7. Canriq Drillling Dynamics Log 2"=100' (MD &TVD color prints) q 8. Canriq LWD Combo Log 2"=100' (MD &TVD color prints) 211 I 9. Canrig Gas Ratio Log 2"=100' (MD & TVD color prints) ,10. Canrig LAS Data, TIF, and Final Report on CD ROM 11. Final Well Report(hardcopy in binder: includes all items on the list) 12. Wellsite Geologist's Final Field Report 13. Wet Well Cuttings (4 boxes from 160-4100' (T.D.)) Received B : Date: q j( / .a. a/a.e_ Returned to Linc Energy Operations, Inc. Date: Accepted By: • 111 Schlumberger RD Drilling&Measurements 2525 Cambell Street.Suite 400 APR 2 5 2014 Anchorage AK 99503 /y�y Tel(907)273-1700 AOi ` Fax(907)561-8317 w��/ CONFIDENTIAL c 2 / 020 c2q«o Date: 12-Mar-2014 Well Name: Umiat 23H O LINGER Company: LINO Energy NO API Number: 50-287-20029-00 AFE Number: 343 ANR 2 0 2016 Field: Umiat Rig: Kuukpik #5 • • Schlumberger Date: 12-Mar-2014 Well Name: Umiat 23H Company: LINC Energy. API Number: 50-287-20029-00 AFE Number: 343 Location: N 5631271.00 ft US, E 732474.00 ft US Field: Umiat Rig: Kuukpik#5 Drilling and Measurements Field Support: Operations Manager, Ankur Prakash Field Service Manager, Carolina Pena Drilling and Measurements Field Crew: Cell Manager, Matthew Schumacher Cell Engineer Garnet Abrams SERVICES PROVIDED Services Services Dates Depth Intervals VISION*(Resistivity, Gamma Ray) 17-Feb-14 to 10-Mar-14 200 feet to 4070 feet VISION*(Neutron,Azimuthal Density, Density Image) 03-Mar-14 to 10-Mar-14 200 feet to 4034 feet sonicVISION(Delta-T Compressional) 17-Feb-14 to 01-Mar-14 200 feet to 1890 feet Directional Survey Service 17-Feb-14 to 10-Mar-14 0 feet to 4100 feet OPERATING STATISTICS Total MWD Pumping Time: 219.53 hours Total LWD Pumping Time: 219.53 hours Total MWD Time Below Rotary: 422.00 hours Total LWD Time Below Rotary: 422.00 hours Total MWD Depth Interval: 3800 feet Total LWD Depth Interval: 3800 feet Total MWD Runs: 5 Total LWD Runs: 5 JOB PERFORMANCE Directional The final MWD survey point was located at 4062.62 feet with an inclination of 90.00 degrees and an azimuth of 99.48 degrees. The final drilled depth MD and TVD: Measured Depth: 4100.00 feet True Vertical Depth: 986.07 feet Schlumberger • • Formation Evaluation 9,875 inch Surface Section: The surface hole section was drilled out of the conductor to a measured depth of 1980.00 feet in three runs. The first run used a Motor,ARC,Telescope, SonicVISION,and ADN6 and was drilled until the BHA became stuck at 379 feet. The radioactive source was successfully fished and then the BHA was also successfully fished. Run 2 removed the SonicVISION and ADN from the BHA and was drilled to 1025 feet when a bit trip was made. Run 3 used the same BHA and was used to drill to the section TD at 1980 feet. After pulling out of the hole, Run 4 was done as a MAD pass run using Telescope,ADN6 and SonicVISION. 6.75 inch Production Section: The production section of the well was drilled from 1980 feet to 4100 feet in one run using a BHA with PD475, Impulse and ADN4. Gamma Ray, Resistivity, Density and Porosity were supplied in real time and recorded mode. Impulse Gamma Ray was used for real time geosteering decisions. Innovation The Schlumberger MWD team was successfully able to demodulate real-time data at a rate of 6 bits per second during all sections of the well. We would like further encourage the use of ECD measurements to enable informed decisions about drilling practices. The Gamma Ray was used for Geosteering in the production section and this demonstrated the value of Real-time logs. These logs were effectively distributed to the client onsite, and via InterAct. This section was completed successfully and without incidents in only one run. Schlumberger Oilfield Services — Drilling & Measurements appreciates the opportunity to provide LINC Energy with MWD and LWD services. 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Pump produced fluids into IA back into reservoir. Install BPV in tubing spool. EGG% gva'P 3/28/14: Pump produced fluids into IA back into reservoir. Pg 1 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, March 04, 2014 2:50 PM To: 'Zachary Sayers' Cc: 'Roby, David S (DOA) (dave.roby@alaska.gov)';Wallace, Chris D (DOA); 'Regg,James B (DOA) (jim.regg@alaska.gov)' Subject: RE: 23H PTD Condition 3 of approval pi— (3 -U Z o Zach, As follow-up to our phone conversation regarding produced fluids and reinjection in the Umiat 23H.. below is a response to your questions: 1. Are their specific regulations or a guidance document for the re-injection of produced fluids in an exploration project?The AOGCC does not have specific regulations regarding reinjection of produced fluids back into the same zone it came from (this applies to exploration wells only). We claim broad authority under our mandate to limit waste of the resource. By re-injecting the produced fluids back into the zone they may be recaptured at some point in the future if the prospect is commercialized. At many remote sites it makes no sense to haul a limited volume of oil to sell at a loss. By definition an exploration well is drilled both to determine if commercial volumes of oil exist and if it can be produced economically. 2. Does the AOGCC still classify the well as an exploratory producer, and not a class II injection well for the injection of produced fluids? By definition the reinjection of oil/produced fluids doesn't fall under Class II injection (or EOR for that matter) since the produced fluids are not waste.The well remains classified as exploration. The PTD will set conditions for reinjecting the fluids back into the well. 3. The BLM has requested that we separate the water from the test fluids and only inject the hydrocarbon. Will the AOGCC be alright for injecting fluids as produced without separating and processing?We prefer that the same fluids go back into the formation. Separation is not required. If same fluid is re-injected we know there are no compatability/formation damage issues. 4. Can Linc Energy get a variance on the MIT-IA of Umiat#18, as it is the IA that is perforated and we will be injecting into. If you need to use Umiat#18 for injection of produced fluids you will need to submit a sundry for that specific operation ... we can sort out the details then. The well is currently suspended. I don't think it is likely though as the horizontal well should be much better at receiving fluids. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office From: Zachary Sayers [mailto:zachary.sayers@lincenergy.com] Sent: Saturday, March 01, 2014 12:32 AM To: Schwartz, Guy L (DOA) Subject: RE: 23H PTD Condition 3 of approval • • Guy, The PTD additional conditions of approval state that the oil must be re-injected back into the original formation. Our plan was to use the exploration well itself(Umiat#23H). As we discussed some time ago, if something were to go wrong with that re-injection we plan to use Umiat#18 for an emergency back up so we don't strand tens of thousands of gallons of crude on the tundra. We are also on BLM land, so we have been trying to give them a heads up on our contingency. This has triggered a storm of questions about the operation and how the AOGCC views the operation. Can you please help me clarify the following: 1. Are their specific regulations or a guidance document for the re-injection of produced fluids in an exploration project? 2. Does the AOGCC still classify the well as an exploratory producer, and not a class II injection well for the injection of produced fluids? 3. The BLM has requested that we separate the water from the test fluids and only inject the hydrocarbon. Will the AOGCC be alright for injecting fluids as produced without separating and processing? 4. Can Linc Energy get a variance on the MIT-IA of Umiat#18, as it is the IA that is perforated and we will be injecting into. Thank you, -Zach Sayers Zachary Sayers II Contract Drilling and Completions Engineer P +1 907 375 2621 M +1 907 280 8492 E zachary.sayers@lincenergy.com 3000 "C" Street, Suite #103 Anchorage AK 99503 EIIERGY StatesUnited P +1 907868 8660 www.lincenergy.com F +1 907 868 8881 Disclaimer Notice: The message and attachment(s) contained in this e-mail are intended for the named recipient(s) only. It may contain privileged or confidential information or information which is exempt from disclosure under the applicable laws. If you are not the intended recipient, you must not read, print, retain, copy, distribute, forward or take any action in reliance on it or its attachment(s). If you have received or have been forwarded this e-mail in error, please notify us immediately by return e-mail or e-mail linc@lincenergv.com and delete this message from the computer in its entirety. Internet communications cannot be guaranteed to be secure and error-free as the information could be intercepted, corrupted, lost, arrive late or contain viruses. The sender and this Company therefore do not accept any liability or responsibility of whatsoever nature in the context of this message and its attachment(s) which arises as a result of Internet transmission. Opinions, conclusions, representations, views and such other information in this message that do not relate to the official business of this Company shall be understood as neither given nor endorsed by it. From: Schwartz, Guy L (DOA) [ iartzPalaska.gov] Sent: Wednesday, October 02, 2013 1:16 PM To: Zachary Sayers Subject: RE: 23H PTD Condition 3 of approval Zac, You would be allowed to inject produced oil down other wells in that field as long as they are the same formation. If Umiat 23H does lock up and need an alternate well you would be required to notify the Commission by writing (email ok). You would also be required to verify the alternate wells mechanical integrity and that the fluids would be confined to the target formation. 2 , • • Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: Zachary Sayers [ lir�ce�ieic�y.Loi i] Sent: Tuesday, October 01, 2013 4:52 PM To: Schwartz, Guy L(DOA) Subject: 23H PTD Condition 3 of approval Guy, Condition#3 of the approved PTD for Umiat#23H states: "Produced oil must be either re-injected back into the original formation or sold by an AOGCC approved custody transfer method per 20 AAC 25.228." We are looking into contingencies this season in the event that 23H packs off while re-injecting the produced fluid. If we are unable to re-inject all produced fluids into 23H, may we inject them down Umiat#18,or the next well (Umiat #25) if they are re-injected into the same formation? Please call if I need to clarify further(907) 375-2621. Thank you, Zachary Sayers Contract Drilling and Completions Engineer P M E zachary.sayerslincenergy.com 3000"es Street Suite#103 Anchorage AK 99503 United E(IERGY States P +1 907868 8660 www.lincenergy.com F +1 907 868 8881 Disclaimer Notice: The message and attachment(s) contained in this e-mail are intended for the named recipient(s) only. It may contain privileged or confidential information or information which is exempt from disclosure under the applicable laws. If you are not the intended recipient, you must not read, print, retain, copy, distribute, forward or take any action in reliance on it or its attachment(s). If you have received or have been forwarded this e-mail in error, please notify us immediately by return e-mail or e-mail linc@lincenerciv.com and delete this message from the computer in its entirety. Internet communications cannot be guaranteed to be secure and error-free as the information could be intercepted, corrupted, lost, arrive late or contain viruses. The sender and this Company therefore do not accept any liability or responsibility of whatsoever nature in the context of this message and its attachment(s) which arises as a result of Internet transmission. Opinions, conclusions, representations, views and such other information in this message that do not relate to the official business of this Company shall be understood as neither given nor endorsed by it. 3 • • 3 N PN)r. c[::tt': ) 6("Laf- rizo2..r3-07.-c ` ' 3 1/8-5000 (R-35) X OTIS CONNECTOR OMNI 0 10 �1 3 1/8-5000 MOD 120 GV 15.00" 0 O *,„=„ge (381.0 mm) `_ 741,111=7 80.28" (2039.1 mm) '*` i p .( lktin • O , ii,v4, ) . a sys . 44 .4.Lui 24.31" e (617.5 mm) et t. 43.12' (1095.2 mm) ��ifigr, ! � 3 1/8-5000 MOD 120 GV W/ ACTUATOR FhPIINI- o i. 28.12" (714.3 mm) Tr'_ d O O `•� 3 1/8-5000 MOD 120 GV i -f f_"" 13- + +7-4 *I OM 9.31" N,(171, ,~ ;' (236.5 mm) 1►. _41 1 0012DM 1073862 • . • _ ,1 'L7—ADAPTER 21 3 - 00-0 I 1j 20.31 TUBING HGR I 1 515.87 I 1.1 I I 11111 IA _i_IN ® III 10 LOCKDOWN SCREWS -i pLei -- ��if 1 ET�==== 1 1 1 - 11-5000 (R-541 'q' - O 1111' ' 2 1/16-5000 MOD 120 GV A . 26.41 4:30:,...11 i Cid.Li G 769 4764.5 1670.8u DI_ p..-..A AB, j ■ G)l •� ■ 1764.54 'r- _ O r I��_ ^ �� � � ■ i•.11,_ O 112 J O ■ G 13.28 # igi = # iui (337.311 �= I L _ i 0 TEST PORT �M,. i ,`� ! 10 LOCKDOWN SCREWS =sTiS - -- .�SSSS- �R. 11-5000 IR-541 '.' I� 1'.'l 2 1/16-5000 MOD 120 GV i ; 22.75 O 4: ' e. (577.85) O Ii. , Q (�� , .1 ,,,,,1in '—t; T-moo : is 9.15 �� iui !232.411 1=.� I �=l MP la 1 O 7 II i 1 i (ITEM II PART NUMBER II DESCRIPTION I 13 3/8 OD CASING I P164819 CASING HEAD ASSEMBLY 2 13-300-718 GEN 5 TUBING HEAD ASSEMBLY 3 P166043 7 5/8 CASING HANGER 7 5/8 OD CASING 4 12-150-0I7 7 5/8 PACKOFF ASSEMBLY 5 P1000042130 TUBING HANGER ASSEMBLY 6 02-510-456A TUBING HEAD ADAPTER ASSEMBLY 7 6118334-0005 BELL NIPPLE - 3 1/2 OD CASING 8 12-093-113 7 5/8 C-21 CASING HANGER N foINC EHIENOW — A_-' AS [ A ALASKA LOO 13 3/8 X 7 5/8 X 3 1/2 ALASKA QUOTE ED FXXXXX O REF:DM100042348 0012DM1080698 PRIVATE AND CONFIDENTIAL REVISIONS DESCRIPTION O THIS DOCOMENI Aro ALL THE INFORMATION CONTAINED HEREIN ARE THE A 02-26-13 CONFIDENTIAL AND EXCLUSIVE PROPERTY OF RIC 1ECHNCLOCIES O0 MAY NOT DRAY.NY EA REPRODUCED ROOTER O.OR WOE PUBLIC IN ANY MAKER PRIOR TO B 02-27-13 SURFACE WELLHEAD LAYOUT, H.DAO 02-26-13 EXPRESS AIIMORIIATION BY FMC IECHNOLOCIES.THIS GOIRU.7 IS anmer. hnologies ACCEPTED BY RECIPIENT PODS/JAW 10 AGREEMENT 10 rNE FORECOINC.RL GENERATION 5 WELLHEAD, DZ.M RO MUST BE RERRRED LPON DEM.. Z.MARQUEZ 02-26-13 MANUFRCTUER AGREES THAT ARTICLES MAGE IN ACCORDANCE N.THIS 11-5000 COMPLETION, �s,0„IEY,E, DOCUMENT SHALL BE CONSIDERED FMC TECMpLOCIEN DESIGN ANO THAT LINO ENERGY,ALASKA EASTERWOOD 02-26-13 DRAWING NUMBER IDENTICAL ARTICLES ER PARTS THEREOF SHALL NDi BE 4PNFOCTUED D M 10 0156406-2 0 FOR THE USE PRO E BY SS ROR T NAR OP ANY OTHER PERSON NtiHDUr THE PRIOR EXPRESS NRILiEN AUTMRIZITION BY FMC TECHNOLOGIES R.HAMILTON 02-26-13 M1111111=111111119111.1.111111111111.VM1111111.11I oF w�@\I/7", THE STATE Alaska Oil and Gas of 1LAsKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF Q. Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Nick Scales Drilling Manager Linc Energy Operations, Inc. 3000 C Street, Suite 103 Anchorage, AK 99503 Re: Exploratory Field, Exploratory Pool, Umiat#23H Linc Energy Operations, Inc. Permit No: 213-020 revised Surface Location: 1031' FSL, 4026' FEL, SEC. 32, T1N, R1W, UM Bottomhole Location: 554' FSL, 1327' FEL, SEC. 32, T1N, R1W, UM Dear Mr. Scales: Enclosed is the approved application for permit to drill the above referenced exploration well. This permit supersedes and replaces the permit previously issued for this well dated March 4, 2013. Linc Energy Operations Inc. (Linc) requests the following variances: 1) Lint's request for a variance to the requirements of 20 AAC 25.265 (c)(1) addressing the Safety Valve Systems regarding a surface safety valve (SSV) in the vertical run of the well's tree. Lint's proposal to place the SSV on the wing valve is APPROVED under 20 AAC 25.265(o)(1) 2) Lint's request to waive installation of a surface controlled subsurface safety valve (ScSSV) APPROVED under 20 AAC 25.265(d)(4). An ESP is being installed for artificial lift and as such a ScSSV is not required. Additional Conditions of Approval: 1) BOPE to be tested to 1500 psi (annular tested to 1500 psi). 2) 7 5/8"casing to be pressure tested to 1500 psi. 3) Produced oil must be either re-injected back into the original formation or sold by an AOGCC approved custody transfer method per 20 AAC 25.228. 4) BOPE testing interval shall be no more than 7 days. 5) Weekly drilling summary reports must be submitted to the AOGCC via email to Guy.Schwartz@alaska.gov. 6) Witnessed"No Flow"test required after stabilized production. 7) Shutdown configuration of the Umiat#23H wellbore must be approved by the AOGCC. S • All dry ditch sample sets submitted to the AOGCC must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the AOGCC's internal use. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy P. oerster Chair DATED this 0<.. day of December, 2013. I • • STATE OF ALASKA CONFIDENTIAL„, �:"�°” ALASKA OIL AND GAS CONSERVATION COMMISSION a"" 421PERMIT TO DRILL 20 AAC 25.005 1 a.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑ Service- Winj E Single Zone Q • 1c.Specify if well is proposed for: Drill ❑✓ Lateral ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply E Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry E Exploratory ❑' • Service- WAG ❑ Service-Disp ❑ Geothermal E Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket ❑' Single Well 101 11.Well Name and Number: Linc Energy Operations,Inc. Bond No.17s10143SV 9244998424 'Oka Umiat#23H 3.Address: 6.Proposed Depttt;_p 8/0.13' 12.Field/Pool(s): 3000 C Street,Suite 103,Anchorage,AK 99503 MD: -Wt., 0 TVD: 1,288 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Exploratory(Umiat) Surface: 1,031'FSL,4,026'FEL,Sec 32-TIN-R1W,U.M. , FEDAA84141 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1,031'FSL,4,026'FWL,Sec 32-TIN-R1W,U.M. N/A 3/15/2013 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 554'FSL,1,327'FEL,Sec 32-TIN-R1W,U.M. • 11,500.00 acres 1,025' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 598 feet• 15. Distance to Nearest Well Open Surface: x-732,474 y-5,631,271 - Zone-5 • GL Elevation above MSL: 575 feet, to Same Pool: N/A 16.Deviated wells: Kickoff depth: 360 feet , 17.Maximum Anticipated Pressures in psig(see 20 MC 25.035) Maximum Hole Angle: /i-, -90-degrees Downhole: 469 psi • Surface: 340 psi 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 20" 13.375" 68 J-55 PE 100' 0' 0' 100' 100' 241.4 c.f.(Conductor Csg) 9.875" 7.625" 29.7 L-80 BTC-MOD 2,200' 0' 0' 2,200' 1,210' 1,175 c.f.(Surface Csg) 6.75" 4.5" 12.6# L-80 IBT-MOD 1,650' 2,050' 1,251' 3,700' 890' Open Hole Slotted Liner ` 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/StructuralRELer Surface Intermediate y i Production NOV 0. 8 2013 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): AOM VC 20. Attachments: Property Plat ❑ ' BOP Sketch 0 Drilling Program ❑ . Time v.Depth Plot 0 Shallow Hazard Analysis Diverter Sketch 0. Seabed Report ❑ Drilling Fluid Program El 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Zach Sayers Contact Zachary.Savers(cDlincenergv.com Email Printed Name Nick Scales Title Drilling Manager-Alaska Signature ` Phone (907)375-2603 Date /tifS /30/g Commission Use Only Permit to Drill API Number Permit Approval ( / See cover letter for other Number: 213020 ' 50-287-20029-00-00 , Date: Al 7 1 (requirements. �/ r Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalb d ethane,gas hydrates,or gas contained in shales: 0 Other: '�",,. /�� // Samples req'd: Yes�NolD Mud log req'd:YesE No❑ +r Ste. I '�ws `'t eA(C..t , H25 measures: YesInal No❑y Directional svy req'd:YesJ No❑ d''''' '‘ L• ISpacin exception req'd: Yes❑ No Inclination-only svy req'd:Yes❑ No�"L'C l Q11 s AQp tneo �l U I��J APPROVED BY Approved by: / �p „(�,- COMMISSIONER THE COMMISSION Date: /2 '2 - /3 ORIGINAL 2 „1,,,ii,aft05 14' <27 -& Submit Form and Form 10-401(Revised 10/2012) This permit is valid for 24 months from the date of approval(2 AAC 25.005(g)) Attachments in Duplicate • • RECEIVED NOV 0. 8 2013 AOGCC ILI pc EIIERGY Linc Energy Operations, Inc. 3000 "C" Street, Suite#103 Anchorage, Alaska 99503 November 8th, 2013 Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Updated Application for Permit to Drill Well: Umiat#23H (Exploratory Oil Well) TRS: SWSW, T1 N, R1 W, Section 32, Umiat Meridian Dear Chairman Foerster, Linc Energy Operations, Inc. hereby submits an update to the approved Permit to Drill (PTD) for an onshore Exploratory Oil well on an ice pad in Umiat. The well will be drilled on BLM land under the authority of a current Oil & Gas (O&G) Exploration Lease (BLM Lease AA-084141) held by Renaissance Umiat, LLC. Linc plans to commence operations on approximately January 15th, 2014, employing the Kuukpik #5 drilling rig. A diverter system will be installed for drilling of the surface hole. After drilling the 9-7/8" surface hole, the 7-5/8" surface casing will be set at 2,200' MD / 1,210' TVD and tested to 1,500 psi. This will be done per BLM well safety requirements. The well will be horizontally drilled to 3,700' MD / 890' TVD.`/After drilling to TD and running a 4-1/2" slotted liner in the open hole, the well completed in the Lower Grandstand as a horizontal oil producer on ESP Artificial Lift Pump. Ajo Coco) No pressurized fluid is expected to reach surface due to the sub-normal pressure of the Umiat reservoir. Offset drilling information on wells drilled in Umiat showed a lack of reservoir energy sufficient to bring fluids to surface and was evidenced by the lack of fluid movement in wellbores such as Umiat#3, Umiat #4, Umiat #5, Umiat#6, Umiat#7, Umiat #9, and Umiat #10 which sat without any cement plug for over 50 years and no fluid came to surface. All oil production from the Umiat wells was achieved thru Artificial Lift. The Umiat reservoir has a low Gas-Oil Ratio (GOR) of around 70-100 scf/bbl. Drilling operations in many of the offset wells that produced oil was conducted with cable tool rigs and primary well control involved a volume of brine in the hole that did not reach back to surface. • • Linc requests the following variance requests for this well: 1) Variance to the requirements of 20 AAC 25.265(c)(1) addressing Well Safety Valve System requirements to have the surface safety below the tree. Linc Energy requests not to have a SSSV in the tubing due to the no flow status of the well. Instead, the surface safety valve will be located off of the wing valve along the flowline, installed during the well testing and removed when the well is shut- in. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Permit to Drill 2) Form 10-401 Permit to Drill (Public Copy) 3) As-Staked Plat 4) Drilling & Evaluation Summary 5) Proposed Well Schematic 6) Proposed Directional Survey 7) Proposed Drilling Fluids Program 8) Proposed Casing Design 9) Diverter Diagram The following are Linc Energy designated contacts for reporting responsibilities to the AOGCC: 1) Drilling and Completions Nick Scales, Drilling and Operations Manager (907) 375-2603 The AOGCC is requested to treat as confidential all information in the Permit to Drill (except the Public Information Copy) as information in these documents is drawn from research and data proprietary to Linc. If you have any questions or require further information, please contact either Nick Scales, Drilling Operations Manager at (907.375.2603) or Zach Sayers, Senior Drilling Engineer at (907.375.2621). Sincerely, Nick Scales Drilling Manager -Alaska • . ✓ w '----_3 1' 'a � w O��aZEs 4a4G6 v�i a � A z J °' ��'+',‘,..c.: z f eea m m m ;y a° t. !, 0 0 oaf ,;,�.�t <a j N �_10,44` Ct W TIV • om "±".. Z to �� p VI 4 CL Y + ry c z f o 5 u, Z ikoi sv `g, a ¢ w� —_`—I(`/ a`ZOO ❑ .�-�t� `� IWi 1 y N O N �' �/}w M W v N In Z Wo d J N N W W �W O M 3 O[L W C f 0 g 'J fWTc`T r-: •,TWr.4— Z N W O p C o NMrcics N� NN g.W0�7 Za4F L } U ry2hr NN�a J !- en; 6R co.L7, YV�' w O O= � �� � �� w �4� Mw>90 ui w 0 'S 3 U W 09 Q Z 1-,1I ZZN N 4�Z II 11 UOZ�.Nj� W2oC Q i W i [C U O O a0 OLr�ON Z ` , \ x ti ❑ ❑ O c7 6 U Z J JYX Z J J}X JLLF ^z 0 0 U O J W re ce L"--., � i-o o : N in cNi Z 0 p Z V \ 71 ct M � 9S� J 6a2 N IV C N Z+...._....O<S\. • 411111,''''''' ''''' . m 5 eh o W 'ONi O 3� a v CI zo O �' ~ U Z \ 0 M .,`. W f ; O Z a zo j>Z b .o ��i �F G A U �q Z OO ~` i t = ig 0 A ---...,..... .'^--- N 20 f"7 N O z0 `�� aJ "� , 01 N / O J 1 �� W W W ` 9S ..Z O w -7-1,_ / 0 s-.1:;(- a %ejw oma ``cLe,l $, • ti iE 7 U.r$ :LL• / cyy xz 7 C 0.4 d C ow $ /Ol m ._, u >9Q (k8 ZI • WM fn �Ya /7•• ~ G . QK // ` }z C w /!... ,zt y ••ar 00a2 fes' .••.(e.,..:- www m O 5 _ `1 • a E 67 Y EflI d Z i t 3 ►�i.Ydd�ad � ills; a M z• ° %i�Y.�w.i..�aY`,. i m " o a ��� r c No i r z � . d 1 =o } n o0 z i , , . , r i , I ; 4111 a y- >m m O B �a er • 3_. 9. is7: . m $, H I J W nz a1 I 4wwJ Umiat #23H OiW6Y 23H Drill and Evaluate Plan Summary _ ����� _ -TI* Type of Well: Exploration (Oil Well) 441 Surface Location: 1,031' FSL,4,026' FEL, Section ' ,T1N, R1W, (UM) x=732,474 y=5,631,271' NAD 27 Alaska Zone 5 Bottom Hole Location: 554' FSL, 1,327' FEL, Section 32,T1N, R1W, (UM) x=735,186 y=5,630,875' NAD 27 Alaska Zone 5 Pad/Location: Umiat#23H Ice Pad Rig: Kuukpik#5 Estimated Start Date: 1-15-2013 Operating days to complete: 36 t nibO MD: 3,700 • TVD: 1,288 Max Inc: 110 • KOP: 360 RKB: 598 Well Design: Shallow Horizontal Primary Objective: Oil sands in the Lower Grandstand Member of the Nanushuk Formation Mud Program: Hole Size: Mud Type: 9-7/8" VersaClean, LVT-200; Mineral Oil Based-Mud (MOBM);Oil-Water ratio (70/30) Density(ppg) LSYP PV Funnel Vis API Filtrate HPHT Oil/Water 8.0 10—12 20-30 45—70 <5 N/A 70/30 Hole Size: Mud Type: 6-3/4" EMS 6250, LVT-200; Mineral Oil Based-Mud (MOBM); Oil-Water ratio(100/0) Density(ppg) LSYP PV Funnel Vis API Filtrate HPHT Oil/Water 7.3 7- 10 17-28 45—70 N/A <5 100/0 Mud Chiller:The MOBM will be run thru a mud chiller to minimize thawing of the permafrost and the reservoir.The mud chiller will be used to chill the mud temperature down to as low as 40°F.This is being used to minimize thawing of the reservoir and potential permeability reductions due to thawed connate water in the reservoir. Linc Energy I 23H Drill and Evaluate Plan Summary LIDO ENERGY 23H Drill and Evaluate Plan Summary ?/LI)/13 Type of Well: Exploration (Oil Well) Surface Location: 734' FNL, 536' FWL, Section,5,T1N, R1W, (UM) x= 1,871,842 y= 5,629,206' NAD 83 Alaska Zone 5 Bottom Hole Location: 554' FSL, 1,327' FEL,Section 32,TAN, R1W, (UM) x=735,186 y=5,630,875' NAD''27 Alaska Zone 5 Pad/Location: Umiat#23H Ice Pad Rig:// Kuukpik#5 Estimated Start Date: 1-15-2013 Operating days to complete: 36 }IY' n4t7 MD: 3,700 TVD: 1,288 Max Inc: 110 KOP: 360 RKB: 598 Well Design: Shallow Horizontal Primary Objective: Oil sands in the Lower Grandstand Member of the Nanushuk Formation Mud Program: Hole Size: Mud Type: 9-7/8" VersaClean, LVT-200;Mineral Oil Based-Mud (MOBM); Oil-Water ratio (70/30) Density(ppg) LSYP 'PV Funnel Vis API Filtrate HPHT Oil/Water 8.0 10—12 20-30 45—70 < 5 N/A 70/30 Hole Size: Mud Type: 6-3/4" EMS 6250, LVT-200; Mineral Oil Based-Mud (MOBM); Oil-Water ratio (100/0) Density(ppg) LSYP PV Funnel Vis API Filtrate HPHT Oil/Water 7.3 7- 10 17 -28 45—70 N/A < 5 100/0 Mud Chiller:The MOBM will be run thru a mud chiller to minimize thawing of the permafrost and the reservoir.The mud chiller will be used to chill the mud temperature down to as low as 40°F.This is being used to minimize thawing of the reservoir and potential permeability reductions due to thawed connate water in the reservoir. Linc Energy I 23H Drill and Evaluate Plan Summary Zinc �. fR€RGY Evaluation Program: 9.875 in Hole Section: Logging Suite: MWD/LWD: MWD, Gamma, Resistivity, Density, Neutron Open Hole Logs: None. Cased Hole Logs: None. 6.75 in Hole Section: Logging Suite: MWD/LWD: MWD, Gamma, Resistivity, Density, Neutron Open Hole Logs: None. Cased Hole Logs: None. Casing/Tubing Program (All new casing): Hole Size Csg/Tbg OD Wt/ft Grade Conn Length Top Bottom 20" 13-3/8" 68# J-55 PE Bevel 100 ft 0/0 ft 100/ 100 ft 9-7/8" 7-5/8" 29.7# L-80 BTC-MOD 2,200 ft 0/0 ft 2,200/ 1,210 ft 6-3/4" 4-1/2" 12.6# L-80 IBT-MOD 1,650 ft 2,050/1,251 ft 3,700/890 ft Tubing 3-1/2" 9.2# L-80 IBT-MOD 2,050 ft 0/0 ft 2,050/ 1,251 ft Cementing Program: Conductor Lead Cement Hole Size Csg Size Type Density Yield %Excess Volume Est.TOC 20" 13-3/8" Arctic Set I 15.7 ppg 0.93 ft3/sx 150 43 bbl 23' (GL) Additives: 0.05 gal/sx Retarder Surface Lead Cement Hole Size Csg Size Type Density Yield %Excess Volume Est.TOC 9-7/8" 7-5/8" Permafrost 11.0 ppg 1.87 ft3/sx 250 174 bbl 23' (GL) Additives: 0.20% BWOB Antifoam,0.35% Fluid Loss,0.06 gal/sk Dispersant,0.10 gal/sk Accelerator Compressive Strength: 825 psi (24 hrs) Surface Tail Cement Hole Size Csg Size Type Density Yield %Excess Volume Est.TOC 9-7/8" 7-5/8" Class G 15.8 ppg 1.16 ft3/sx 35 35 bbl 1,594 Additives: 0.20% BWOC Antifoam,0.30% Dispersant,0.25% Fluid Loss,0.50%Accelerator Compressive Strength: 900 psi (24 hrs) Centralizer Program: Hole Hole Casing Depth(MD) Centralizer Type Centralizer Spacing Section Size Size 1 9-7/8" 7-5/8" 0—400 ft Semi-Rigid 1 per 3 joint from 100'to 400' 2 9-7/8" 7-5/8" 0—2,200 ft Semi-Rigid 1 per 1 joint from 400'to 2,200' 3 6-3/4" 4-1/2" 2,200—3,700 ft Polymer Gliders 1 per 1 joint from 2,200'to 3,700' Linc Energy I 23H Drill and Evaluate Plan Summary • • Linc E1IERGY Bit Program: BHA Hole Size Depth (MD) Bit Type Nozzle/ Flow Rate 1 9-7/8" 100—2,200 ft Smith XR+C 16/16/16/16; 500 gpm 2 6-3/4" 2,200—3,700 ft Smith XR20 Insert 14/14/14; 375 gpm Wellbore Survey Program: Hole Size Depth (MD) Survey Method Survey Frequency 9-7/8" 0—2,200 ft MWD Min. Every 100' 6-3/4" 2,200-3,700 ft MWD Min. Every 100' Perforating Program: Zone Method Top Bottom Total Gun SPF (MD) (MD) Footage Size Lower Grandstand (Oil Zone) Openhole N/A N/A N/A N/A N/A Mud Logging: HYDROCARBON DETECTION Total Hydrocarbon Analyzer(THA)via Flame Ionization Detection C1-05 GAS MEASUREMENTS Gas Chromatograph (GC)via Flame Ionization Detection GAS-IN-MUD MEASUREMENTS Quantitative Gas Measurement (QGM) Gas Trap CUTTINGS SAMPLES Collect every 30 ft (wet and dry)from surface to TD Collect every 10 ft (wet and dry) in zones of interest Rig Pit System: ACTIVE SYSTEM CAPACITY 520 Barrels (160 BBL Shaker, 70 BBL Degasser, 130 BBL Centrifuge, 80 BBL Volume, 80 BBL Suction) ADDITIONAL RIG TANKS 400 Barrels (4 each 100 BBL Pre-Mix Tanks) TRIP TANK 30 Barrels PILL TANK 30 Barrels GAS DETECTION Sierra Monitor(Digital) Fixed System Gas Detector for H2S and Methane,- 3 Station sensors, 1 at rig floor, 1 at bell nipple, 1 at shakers INSTRUMENTATION Pason (Pit Bull Model) Pit Volume Totalizer Drilling Waste Disposal: DRILL CUTTINGS Cuttings generated during drilling will be transferred by small cuttings bins to larger Shale Bins before being transported off location by Haul Trucks and disposed of at Prudhoe Bay Drillsite#4, an approved Class II Waste Facility; FLUIDS Fluids will be transported by Steiger and/or Tundra Bear ATV and brought to Prudhoe Bay Drillsite#4, an approved Class II Waste Facility. Linc Energy I 23H Drill and Evaluate Plan Summary • 0 zinc ERERGY Well Control Program: DIVERTER 21-1/4" 2M Diverter Spool, 16" Outlet and Line, 13-5/8" Annular BOPE 11" 5M Annular, Double Gate, Mud Cross,Single Gate KILL LINE 2" Line w/2 each 2" 5M Manual Valves CHOKE LINE 3" Line w/1 each 3" 5M Manual Valve, 1 each 3" 5M HCR CHOKE MANIFOLD 5M Choke Manifold, 2" Manual Choke, 2" Hydraulic Choke, 3" Inlet, 3" Panic Line, 3 each 3-1/8" and 13 each 2-1/16"valves (16 total) ACCUMULATOR 170 gallon reservoir, 12 each 15 gallon bottles, nitrogen backup, pneumatic and electric pumps DIVERTER LINE Length = 75' (Exit point on Drillside of Rig) BLOOIE LINE Length = 50' (Exit point on Drillside of Rig) REMOTE BOP CONTROL Located at Driller's Station Maximum Anticipated BHP 7.0 ppg x 0.052 x 1,288 ft=469 psi Maximum Anticipated Surface 455 psi—(0.10 psi/ft x 1,288 ft)=326 psi Pressure (MASP) Planned BOP Test Pressure earns ams 1,500/250 psi;Valves 1,500/250 psi;Annular 1,500/250 psi rT (10 min each) Casing Test Pressure(7-5/8") 1,500 psi for 30 min Offset Leak-Off/ Formation Integrity Data: Well Name Depth of Shoe Pressure(EMW) LOT or FIT Seabee Test Well#1 1,617' 11.5 ppg FIT Seabee Test Well#1 3,983' 15.3 ppg FIT Seabee Test Well#1 9,980' 17.6 ppg FIT Seabee Test Well#1 12,814' 20.0 ppg FIT Umiat#18 1,445' 12.8 ppg FIT Linc Energy I 23H Drill and Evaluate Plan Summary • • Co) EDERGY Leak-Off Test Procedure: 1.) Drill shoe track and drill 20' of new hole. Circulate and condition mud. 2.) Pull the drillstring into the shoe. 3.) Close the pipe rams and pump down the drillpipe at slow rates. 4.) Plot drillpipe pressure vs. cumulative volume pumped. The point"B" on the below graph is the leak-off pressure (LOP).The equivalent mud weight of that leak- off pressure is as below: LOT(EMW) = MW+ (LOP/(0.052 x Shoe TVD)) 0 Linc LEAK OFF TEST PROCEDURE EIIERGY c B V. 5 N V a A-Varies until system is pressured up. ---------- -----------------------— -- ----- B-Leak-off point. rti C- Injection pressure(rate dependent). D-Fracture closure pressure. Volume Pumped (Bbls) Linc Energy I 23H Drill and Evaluate Plan Summary 0 zinc ENERGY Umiat #23H - Well Planning Summary Pre-Rig Work: 1) Auger 20" conductor hole to 100'ft MD/TVD. 2) Install 13-3/8" 68#J-55 conductor to 100'ft MD/TVD. 3) Cement 13-3/8" conductor back to surface with 43 bbl of Arctic Set I cement. 4) Install 9.5' internal diameter cellar 9.5' below original ground level. 5) Perform rough and final cut of 13-3/8" conductor and prep same. 6) Make cut on 13-3/8"casing. NU 11" Starting Flange. Rig Operations: 1) MIRU Kuukpik#5. 2) Perform rough and final cut of 13-3/8" conductor and prep same. 3) Install 13-5/8" x 11" 5M Starting Flange. 4) NU 21-1/4" 2M Top x 11" 5M bottom DSA. NU 21-1/4", 2M diverter, 16" diverter knife valve, 16" diverter line, and 13-5/8" annular. 5) Function test annular and diverter valve. a. Notify AOGCC 48 hours before performing Diverter Function Test. 6) Mix and fill pits with 8.0 ppg Mineral Oil-based Mud (MOBM). 7) MU 9-7/8" bit and 4" drillpipe drilling BHA#1. 8) Cleanout to base of conductor at 100' MD/TVD. 9) Drill 9-7/8" hole from 100'to KOP at+/-400' MD/TVD. 10) Directionally drill 9-7/8" hole from 400'to TD at+/-2,200' MD. 11) CBU, Backream/Mad Pass out of hole to 400' MD. RIH to TD. 12) POOH. L/D drilling BHA#1. 13) MU 7-5/8"float track. RIH w/7-5/8" casing to TD. 14) Land 7-5/8" casing hanger in wellhead hanger profile. 15) RIH w/stab-in adapter on 4" drillpipe and stab-in to float collar. 16) RU cementers. Mix and pump 174 bbl of 11.0 ppg Permafrost lead cement and35_bbi_of 15.8 ppg Class G tail cement, bringing cement to surface. 17) Bump plug. Bleed off and check floats. 18) POOH w/4" drillpipe. 19) ND Diverter. NU 11"Wellhead. Test wellhead to 1,500 psi for 15 min. 20) NU 11" BOPE with blind rams, 2 sets of4 e-Kams and annular. yi3 21) Test BOPE to 250/1,500 psi for 10 min each (Annular to 250/1,500). e/41A-5 22) MU 6-3/4" bit and 4" drillpipe drilling BHA#2. 23) RU and pressure test 7-5/8" casing to 1,500 psi for 30 min. 24) Drill shoe track to 2,200' MD, and 20' of new formation to 2,220' MD. 25) POOH to casing shoe. 26) RU and perform LOT/FIT to 11.5 ppg EMW. 27) Drill from 2,220'to TD at+/-3,700' MD/890'TVD. Linc Energy I Umiat#23H—Well Planning Summary • zinc 28) Circulate and conditions hole. POOH. LD 4" drillpipe. c/ 29) RIH w/4-1/2" slotted liner to TD. Cid /Z,4MS 4; t �L `t 30) Displace MOBM to 7.0 ppg Mineral Oil Completion Fluid. 31) Set liner top packer. POOH. L/D liner running tool and 4" drillpipe. 32) RIH w/4-1/2"tubing, ESP,jewelry, and tubing hanger. 33) Land and test hanger to 1,500 psi for 10 min. 34) Run BPV. ND BOPE. NU Tree. Pull BPV. Run TWC.Test tree to 250/1,500 psi for 30 min. 35) Rig down and move out Kuukpik#5. Post-Rig Operations: 1) MIRU Baker ESP surface equipment Well Test Operations: 1) MIRU Well Test Unit. 2) RU Well Test Unit to Production Tree wing valve. 3) Flow test well for+/- 5 days. 4) Shutdown ESP. Shut-in well. 5) RD Well Test Unit. 6) RD and secure well. AvG.cc_ f „ro SKs�vs.S RN_ • Linc Energy I Umiat#23H—Well Planning Summary • • ._` P" iat' Tubing H' Umiat #23H - _ _, � ��. .......... . .. Lease: AA-084141(BL Tree Connection: I I. '1..,1 Well Type: r Base of Permafrost: 801'MD/793'TVD GL: 575'AMSL ` HOLE DATA RIG RKB: 598'AMSL 1 -, Hole Section ze p(MD) Btm( m - ax- RKB-GL: 23'(2'of ice) `i - in ft _..ft.-- ft ft type ppg de" Conductor 20" 0' 100' 0' 100' N/A N/A 0° 13-3/8" Surface 9-7/8" 0' 2200 "" ( 1176 OBM 8 100° 100'TVD Production 6-3/4" 2050 3700 1250 890 OBM 7.2 110 i FIT=10.1 ppg LOT=10.6 ppg CASING/TUBING DATA Conductor - 68 1-55 PE 12.415" 0100' 0' Surface - 29.7 L-80 BTC-MOD 6.875" 0' 2200 0' Production - 12.6 L-80 IBT-MOD 3.958" 2050 3700 N/A Tubing ® 9.3 L-80 TC II 2.958" 0' 2050 N/A CEMENT DATA 14 7Conductor - Permafrost 23'(GLI 100' 15.7 0.93 43 260 Ai fL ' Surface - Permafrost 23'(GL) 1,594' 11.0 1.87 Surface ® Class G 1,594' 2200 15.8 1.16 COMPLETION JEWELRY SUMMARY Item Description Depth ID OD Install Date # - ft in in - 1 Tubing Hanger Proposed 2 3 4 5 6 _ 7 - - 11\tt" 272'ND 2.. ppg Lower Grandstand 954'TVD 13.0 ppg IM.•�:..1."` 'r' W�ir+'..I,:' I'' / 4-1/2" Slotted Liner hSc x,iZ 4 , Base LOS 1,269'ND TOE TD:3,700'MD/890'TVD 7-5/8" TD:2,200'MD/1,176'TVD DATE REVISED BY: _ WELL HISTORY DESCRIPTION Well Name Umiat#23H 9/27/2013 Z.Sayers Proposed Lower Grandstand B-sand Horizontal Slotted Liner ESP Completion Spud Date N/A 10/30/2013 Z.Sayers Update to WP#9 API No. 50-287-20029-00 PTD 213-020 Max Hole Angle 110 Max Dogleg 7 • 0 V. 0 43 Oil"` O O 0006 700 OQ N ON 0 C 000.0)N7N MN.-N O ON QOD7N N N 7N Q l0 c m o 0 o.oCO0,oro000(0.d.ergCOCOoQ._M.0N0o7rN N NmN0,0,0r-N0,mQ CL t❑ OO 6 COQ WN.Q Q0.-W 66.-r c-6O W cd6 O ON N co CON�0(ON N o Y r r r r r r r CD OD 0 0 6 Ti.Q M N.-W co r r 0 N Q CO N r-0) W W r 0 0 CO 2 p Co Co N N N N N N N N N N N N N N N 0 0 00000000000 Q Z Co Co Co Co Co Co Co Co Co Co Co Co tri MM MCO Co CO 0i CO Co Co Cl CO Co CO CO C) MM Co Co MM Co MMM Co 08UlN00NNNNNNNN688880N0{ 0h00N000088N Q 10 V) 0 0 CO N 0 LC) 0 N0 8 O) Co W'„' O O OOONCO r Q QN 8COr Q W O)QNtA Qr NO 0-N Qt0 m 0-0,-0,000-0,0-,-0 C? 0 0 0 0000-NO W.-Qr 0.2(0,0 1000)c0.-N.-0,O CDN O) ON N Q 07(.00,0,Nr.- O Ti Q Q Ti Q Q O 6 Or M(n co 0 CV 0 0 C6 W co N Q O M co N O r co N�Q r Q6 ui on on O co N 6 w- r r r rrrc 0rnr-00Ti.06 Oir NN NN TN MN NQ O Q CO N CAN 0Co O CO d Q Q Q Q Q Q Q Q Q N N N b CO 0-r 01 0)00.-CON6MQQNO r 0-r CO m O)0T-T- -NQ W 6 6 6 N 6 6 N N N N N N N 6 6 N N 6 CO M CO M M M M M M co M co co co co co Q Q Q Q Q Q n co nn ON nnn0NNNnnnnnnnNNNNNnnn n nnnnnnnn0IN d d^O) 0, 0,0,0,001-N NN.-NCT ON r.-CO CON NQ CO CO CO Oi NN o MM M MMN CO r Nr r C a,--0) CO CO 0,0,W r 7 Mr CA QN 7,00 CDN 0C N 7 NN 0Q a)0- co 0-r 0-r NM NNNN CO 6iiOi 6 OOiOici 60 C6O r C04 W ui 0606OiCiC6 CV O d 2Q u 2 AIA R K O O 000000M MO)O.-O NOr Q CA NN Nr!N NMM' r 0-O)Q W NQ 0 MN0)M • d 0 0 000067 MCO VD000000N Q Nrcc,CO CD0077NM C, MMQ Q N NCO CO OOCO r O C 0 O 0000c-666M M tri MQQ QQQQ 0 QNN NNNN Co NNN NNNN NNN N d T er E m0 0 0000000000 0 000000 0 00000000 0 00000000000 J o 0 00000000000000000000000000 0 00000000000 c... 0 o Z 0 000 av v r r r 0-r r r r N.r r r r 0-r 000-0-r 0- 0-600016 CO CO o 00 CS) F. 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I I I I �I I 4x H / 0 7 W {V W to ( )OA1 w o 6 • N i 1i i i i i i i i i i i i i i i i i i i i ; ;i i QQ I RN 1il i i i j i i I 1 I i i i i I i i i j i I i i i Np i i i i j i ii ii ii i1! i i i i i ii i i 1 i i i i j 1 I i i i . j i i i T j ii i i i ii ii ii i i i UJ i i i i i i t, i i i i i i i i ; i i ; 1 I 1 1 1 1 1 1 1 1 I 1 I 1 1 I 1 I 1 1 1 1 1 1 I 1 1 I 1 1 I 11 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 j 1 1 1 1 I 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1 11 1 1 I I I I I II $ g HJk10N (iu) H_L lOS M� SWACO A Schlumberger Company Drilling Fluids Program LINC ENERGY OPERATIONS, INC. Well: Umiat 23H Linc Prepared by: Customer Approval: Name: Andy Lee Name: Zach Sayers Position: Project Engineer Position: Drilling Engineer Company: M-I SWACO Alaska Company: LINC Energy, Inc. Date: 9.13.2013 AFE#: Version: 1.0 Approver ID: Logit#: Version 1.0 Confidential Page 1 of 12 Mi SWACO • A Schlumberger Company Maintaining proper document control is critical with regard to the development of appropriate well design.No changes will be made without being supported by the appropriate documentation and described below in table. 1.7 1.0 9/13/2013 Draft version of purposed fluids plan for LINC's Umiat 23H 1.1 11/6/2013 Updated depths and fluid costs and formulations Project Summary: Umiat is located 140 miles southwest of Deadhorse resulting in additional logistical challenges.All product and equipment will be transported out of Deadhorse and brought to the staging area off the haul road at mile 359(near pump station 2)55 road miles south of Deadhorse;from there it will be transported by rolligon out to location. Umiat 23H will be drilled with Kuukpik Rig#5 to a total depth of 3,550' MD—1,288' TVD with a max angle of 90°. Umiat 23H will be completed as a slotted liner producer in the lower Grandstand B-sand and drilled in two intervals. The first interval will be drilled with a 9- 7/8" bit with M-I SWACO's VersaClean drilling fluids system.After drilling the surface interval to 1,8e01MD 7-5/8"casing ZLoP will be ran to TD and cemented. The second interval will be drilled with a 6-3/4" bit and M-I Swaco's EMS-6250 oil base drilling fluid system. Once a TD of 3,550' has been reached Umiat 23H will be completed with 4.5"slotted liner hung from 1,700'to 3,550' MD along with-4-.3'rproduction tubing to 1,690' MD. Version 1.0 Confidential Page 2 of 12 110 Mg SWACO ! A Schlumberger Company Mud Depth Weight Total Interval Casing Size Hole Size Casing Intervals Depth MD TVD Mud System (ppg) Days Cost 1111111M1 — onductor Depth 100' 7.625"OD 9.875" 0-2,094' 1,272' 7.5 ppg 6 $333,760 6.875"ID 094 bbls/ft VersaClean 4.5"OD 6.75" 3,581' 1,288' EMS-6250 7.5 ppg 6 $393,500 3.958"ID 044 bbls/ft , Completion 4.5"OD 3.958"ID .0152 bbls/ft 3,550' 1,288' LVT-200 2 $44,632 Total Total Cost Days *Cost does not reflect Engineering and Equipment charges* 14 $771,892 Version 1.0 Confidential Page 3 of 12 _, 41110 Mi SWACD A Schlumberger Company Surface Interval: 9.875" Hole, 0—2,094' MD, 1,272'TVD Lithology through this zone is a composite of small gravel in the upper sections with a grading downward to sand, clay, and siltstone in the lower zones with the base of the permafrost located at 801' MD. The surface section for Umiat 23H will be drilled with M-I SWACO's VersaClean Oil Base drilling fluid system. When bringing the fluid into the rig complete a full mud check and adjust the properties accordingly. Surface Interval: 0' —2,094 MD Drilling Fluid System VersaClean Key Products LVT-200, IMG-400, Lime,VersaCoat HF,VersaWet, Ecotrol RD, Calcium Chloride, M-I Wate,Truvis. Solids Control TBD Potential Problems Running gravel,unconsolidated sand,and clay.Unforeseen formation pressures, Hole Cleaning, Lost Circulation,Water intrusion from the formation. MUD PROPERTIES at 20 HTHP Fluid Depth MD Mud Wt. Loss Oil I Water (ft) (ppg) Funnel Viscosity PV LSYP (m1130min) Ratio 2,094' (8.0 45-70 20-30 10- 12 <5 70/30 NOTE:This program is provided as a guide only.Well conditions will always dictate fluid properties and product additions required for well-bore integrity. VersaClean Formulation 8.0 ppg(01W Ratio 70/30): LVT 200 .695 bbls Truvis 5.0—7.0 ppb Lime 4 ppb VersaCoat HF 5 ppb VersaWet 2 ppb Ecotrol RD (Dependent on fluid loss) Water 0.28 bbls/bbl Calcium Chloride(95%) 110 ppb(24% by weight) M-I Wate 17 ppb Version 1.0 Confidential Page 4 of 12 MiSWACO A Schlumberger Company Surface Interval Drilling Concerns: r Unforeseen Surface Gas—Gas hydrates may be encountered,take the proper precautions for such an occurrence. r Hole Cleaning—Gravel sizes that are larger than normal can contribute to poor hole cleaning. If encountered increase viscosity to assist with good hole cleaning. .- Washing out conductor shoe—Maintain low flow rates for the initial 200'of drilling to reduce the risk of washing out the conductor shoe. Surface Interval Fluid Operations: 1. Read all MSDS's on products that will be used throughout the surface interval. Have Drilling Fluids Specialist that's onsite give an interdiction to drilling with an oil base mud with all the crews. 2. Ensure that all the rigs valves and seals are compatible with oil base drilling fluid. 3. Confirm that all rig pits and surface lines have been cleaned and blown down to prevent any contamination to the new oil base mud system. 4. Transferring base fluid from the storage tanks to the Rig—Before transferring any fluid from the storage tank uprights to the rig's pits ensure that a fluid transfer permit is filled out and all the proper precautions are in place before any transfers are made.After the fluid transfer is made confirm that the proper amount of fluid was transferred by strapping the storage tanks. The volume used will need to be tracked on a daily basis and recorded. 5. Build the initial surface volume in accordance with the VersaClean formula. Adjust rheology as necessary to target a LSYP of 10 for good hole cleaning. o Attempt to get the base oil as warm as possible before mixing any product. o The warmer the fluid is the fewer products are necessary to achieve the desired results. o Once finished with product additions start running drilling fluid through the mud cooler to lower the temperature of the drilling fluid, monitor properties closely and adjust as necessary. 6. While running in to drill out the conductor shoe you can expect ice and cement,this will not affect the drilling fluid but my cause an increase in flow over the shakers 7. While drilling the surface interval a cooling system will be used. If drilling fluid temperatures start to increase it may be necessary to pick up off bottom and circulate until the drilling fluid temperature lowers and stabilizes. 8. Keep drill solids as low as possible by running available surface equipment equipped with the recommended screen sizes, screen up when possible. 9. Always monitor volumes closely, if losses are seen consult the Company Representative, Driller and Drilling Engineer. Reference the fluid loss decision tree if needed. 10. Capture the drilling fluid temperature, amount of drilling fluid loss, and the results of any sweeps pumped in M-I SWACOS ONE-TRAX Reporting system. 11. Monitor the Modified HTHP using 5 micron alloxite disks at fluid temperature while drilling. Maintain HTHP fluid loss below 6.0 cc/30 min and <1.0 cc spurt loss.Adjust the fluid loss as needed with additions of ECOTROL RD if needed. When running the HTHP report the fluid loss as follows; 30 sec spurt loss+(2 x 30 minute fluid loss). Version 1.0 Confidential Page 5 of 12 MgSWACO A Schlumberger Company 12. When TD is achieved pump a high viscosity sweep and take a fluid calliper of the hole to assist in gauging the wash out%. 13. Once a high viscosity sweep is pumped at TD watch the bottoms-up cuttings closely. If the well does not readily clean up or if there are any excess of torque, drag, pick-up or slack-off weights pump a high viscosity/weighted sweep and observe bottoms up, continue to pump while rotating and reciprocating until the wellbore is clean. When a sweep is pumped at TD conduct a fluid calliper and calculate wash out%. 14. Do not lower YP before running 7-5/8 casing. After casing is landed lower YP per Schlumberger Cementers and conduct cement job. 15. Note the volumes of cement pumped along with the amount of fluid pumped to bump the plug in MI SWACO's reporting system. 16. After cementing clean pits, flush lines and start building the new EMS-6250 system in preparation for drilling the next interval. It's important that the pits are as clean as possible to prevent any excessive drill solids to become entrained in the fluid system. Version 1.0 Confidential Page 6 of 12 • Mi SWACO i A Schlumberger Company Production Interval: 6.75" Hole, 2,094'-3,581' MD, 1,288' TVD The Production interval will be drilled with a 6.75" bit while utilizing M-I SWACO's EMS-6250 drilling fluids system.The production interval of 23H will be drilled at a max angle of 90°. Pipe rotation and pump rate will be important to achieve good hole cleaning while drilling ahead. The EMS-6250 system will start out un-weighted, if the density needs to be increased while drilling ahead S-200 will be the weighting agent. 23H will be completed with a 4.5"slotted liner, if any LCM needs to be added consult the company representative for approval. Its recommended that no reservoir damaging products are used. Production Interval: 6.75" Hole, 2,094'—3,581' MD Drilling Fluid System EMS-6250 Key Products LVT-200,Truvis,Lime, Ecotrol RD, ECF-2743, Surewet, Polyswell Solids Control TBD Potential Problems Running gravel, unconsolidated sand,and clay.Unforeseen formation pressures,Hole Cleaning, Lost Circulation,Water intrusion from the formation. MUD PROPERTIES HTHP Fluid Depth MD Mud Wt. Loss Oil 1 Water (ft) (ppg) Funnel Viscosity PV LSYP (m1130min) Ratio 2,094'to 3,581' 7.3 45-70 17-28 7-10 <5.0 100/0 EMS-6250 Formulation 7.3 ppg(01W Ratio 100/0): LVT 200 .94 bbls Truvis 1 ppb Lime 2 ppb ECF-2743 22 ppb Ecotrol RD 1 ppb Surewet 2 ppb Polyswell .25 ppb S-200 As needed Version 1.0 Confidential Page 7 of 12 • MISWACO A Schlumberger Company Production Interval Drilling Concerns: Hole Instability—While drilling through shales take notice of the cuttings size and shape to ensure that there are no hole instability issues or indications of break out i.e. large angled calvings. - Lost Circulation—Monitor fluid volumes to detect any early signs of lost circulation, if lost circulation is encountered treat appropriately. sp Surge and Swab—Surge and Swab can increase the potential for wellbore instability, use proper drilling and tripping practices to try and mitigate this risk. Production Interval Fluid Operations: 1. Confirm that all MSDS's on products that will be used throughout the production interval have been reviewed. Have Drilling Fluids Specialist give an interdiction to drilling with an oil base mud with all the crews. 2. Confirm that all rig pits and surface lines have been cleaned and blown down to prevent any contamination to the new oil base mud system. 3. Transferring base fluid from the storage tanks to the Rig—Before transferring any fluid from the storage tank uprights to the rig's pits ensure that a fluid transfer permit is filled out and all the proper precautions are in place before any transfers are made.After the fluid transfer is made confirm that the proper amount of fluid was transferred by strapping the storage tanks.The volume used will need to be tracked on a daily basis and recorded. 4. The EMS-6250 base fluid will already contain the Surewet and Lime. This was pre mixed at the M-I Swaco Mud plant in Deadhorse to decrease the amount of product loads to Umiat. 5. After bringing fluid from the uprights into the pits, adjust rheology as necessary to target the LSYP at 7-9 for good hole cleaning and suspension properties. 6. Lab test results are as follows at 40° F: Num Temp Temp Pressure Pressure 600 300 200 100 6 3 Gel Gel PV YP Ty/YP F C psi bar rpm rpm rpm rpm rpm rpm 10 sec 10 min cp Ib/hsf 1 ( 40 4.0' 0 0 55:137L 30 23 14 13 13 13L 18 L 19 0.67 7. Monitor the HTHP(@165°F)&keep below 8.0 cc/30 min (using paper).Also run a Modified HTHP using a 5 micron alloxite disc, keeping fluid loss below 10.0 cc and spurt loss below 2.0 cc. 8. If weighing up the drilling fluid is required use S-200 to increase density. 9. If the mud weight needs to be increased past 11.5 ppg due to unforeseen hydrocarbons or pressures, barite sag could become an issue. (Barite sag is a reduction in the MW out due to the dynamic and static settling of barite) If the mud density is weighed up past 11.5 ppg avoid low pump rates and low drill string rotation. Make sure and run the VSST barite sag test. 10. Keep drill solids as low as possible by running available surface equipment equipped with the recommended screen sizes,start with 230's or 270's and screen up when possible. 11. If losses are seen, stopping losses needs to be the first priority. Monitor the severity and act appropriately, consult the LINC company rep before pumping any LCM. It's recommended that no LCM is pumped down hole that could Version 1.0 Confidential Page 8 of 12 • Mi SWACO A Schlumberger Company potentially damage the formation. A Well Commander circulating sub will be ran on the BHA to accommodate any lost circulation material that needs to be pumped down hole to stop losses. 12. Capture the results of any sweeps pumped in M-1 SWACOS ONE-TRAX Reporting system. 13. Upon reaching TD watch the bottoms-up cuttings closely. Circulate 3 bottoms up, pump a high viscosity / weighted sweep with max rpm and pump rate. At this time the BHA will be laid out at 90 degrees so rotation and pump rate will be essential to cleaning the hole. Ensure that the hole is clean and stable before pulling out of hole 14. No pre-treatment of drilling fluid will be necessary to bump the plug after pumping cement. Keep track of all losses and the amount of fluid required to bump the plug. 15. After cementing has commenced displace the well with a 20 bbl high viscosity spacer followed by LVT 200. Be prepared to over circulate to ensure that the completion fluid is clean. Version 1.0 Confidential Page 9 of 12 MiSWACO A Schlumberger Company Lost Circulation Decision Tree — Production Interval Losing fluid while drilling Measure rate of loss V 1 1 1 Seepage losses<20 bbl/hr Partial losses 20-60 Severe losses 60— bbl/hr 200 bbl/hr or total V - If fault related drill across If fault related drill across If fault related drill across fault 1-1.5 tfault 1-1.5 times the len length fault 1-1.5 times the length of thee the throwhrow before 9 treating losses of the throw before treating length of the throw before 1 - Spot 80 ppb pill: Squeeze high-fluid-loss pill: Spot 40 ppb pill*: Addingto active Note-Pill should be a minimum of 1.5 itmes the SAFECARB 20 12 SAFECARB 40 5 ppb 3-5 ppb SAFECARB length of thief zone SAFECARB 40 12 canbe o SAFECARB 250 5 ppb 40 added t No ppb No I SAFECARB 500 30 ppb FORM-A-BLOK NUT PLUG F 8 the active while success II..I► success drilling to help ppb reduce seepage losses. No 1 Spot plug: FORM-A-SET AK or Reverse Gunk Squeeze Version 1.0 Confidential Page 10 of 12 • Mi SWACO A Schlumberger Company Health,Safety&Environmental y Drilling crews should be instructed in the proper procedures for handling fluid products. y Personal Protective Equipment (PPE) charts should be posted in the pit room, the mud lab, & the office of the Drilling Forman. • PPE must be in good working order & be utilized as recommended by the PPE charts. Ensure a good stock of PPE is available prior to starting the well. • Product additions should be made with the intent to use the complete unit amounts of products (sacks, drums, cans), as much as possible in order to minimize inventory of partial units. • Ensure all MSDS sheets are up to date and readily available for workers to access for information. Review MSDS's regularly before completing tasks. r Ensure that all product stored outside is protected from the weather. r Do not store partial units(sacks)outside if possible. r Ensure that all liquid products are stored with the correct secondary containment. y When transferring fluids &/or cuttings from the rig to tanks, insure all hoses are properly secured and clear of any Ice that could be plugging them. Ensure that all fluid transfer forms have been completed in order to avoid spills. Do not use aluminum cam lock fittings when transferring brine or brine base mud. r Confirm that all drilling wastes are properly documented & manifested as per the Alaska Waste Disposal & Reuse Guide (Red Book).Any questions about drilling wastes should be directed to LINC Energy's company representative. Version 1.0 Confidential Page 11 of 12 • MISWACO • • A Schlumberger Company Oil Base Mud-Product Health and Safety Reference HMIS HAZARD RATINGS Product Function Health Flammability Reactivity PPE ALPINE DRILL BEADS Torque Reducer 1* 1 0 E CALCIUM CHLORIDE Weighting Agent 1* 1 0 E CITRIC ACID pH Modifier 1 0 0 E ECOTROL RD Fluid Loss Reducer 1* 1 0 E ECF-2743 Viscosifier 1* 0 0 E FORM-A-SQUEEZE Lost Circulation Material 1 1 0 E G-SEAL Lost Circulation Material 1 1 0 E HRP Viscosifier 2 1 0 J LIME Alkalinity 2 0 0 E LUBE 776 Lubricant 1 1 0 J LVT-200 Base Fluid 1 1 0 E M-I WATE Weighting Agent 1* 0 0 E M-I SEAL Lost Circulation Material 1* 1 0 E MIX II F,M,C Lost Circulation Material 1* 1 0 E PECAN NUT PLUG Lost Circulation Material 1* 1 0 E Polyswell LCM/Water Absorption 1 0 0 E SACK BLACK Filtration Control 2 1 0 E SAFECARB ALL GRADES Bridging Agent 1* 1 0 E SAFE-SURF 0 II Displacement Surfactant 2 2 0 J SUREWET Wetting Agent 1 0 0 J TRUVIS Viscosifier 1* 1 0 E VERSACOAT HF Wetting Agent/Emulsifier 1 2 0 E VERSATHIN HF Rheological Modifer 1 2 0 J VERSATROL Wellbore Stabilizer/Fluid Loss 2 1 0 E VERSAWET Emulsifier/Wetting Agent 1 1 0 E HMIS PERSONAL PROTECTIVE EQUIPMENT INDEX A-Safety Glasses B-Safety Glasses,Gloves C-Safety Glasses,Gloves,Synthetic Apron D-Face Shield,Gloves,Synthetic Apron E-Safety Glasses,Gloves,Dust Respirator F-Safety Glasses,Gloves,Synthetic Apron,Dust Respirator G-Safety Glasses,Gloves,Vapor Respirator H-Splash Goggles,Gloves,Synthetic Apron,Vapor Respirator I-Safety Glasses,Gloves,Dust and Vapor Respirator J-Splash Goggles,Gloves,Synthetic Apron,Dust and Vapor Respirator K-Air Line Hood or Mask,Gloves,Full Suit,Boots X-Consult your supervisor for special handling directions Version 1.0 Confidential Page 12 of 12 • • = v, _�LT .o ° qp L O O C g2 3, LI 03u 0( N C L 6 0 d - U W 01 H O N • n no o v 4 C u a = CU :a 71 O ` • hn _� V C co •c a v r� 0 ` a C D° -O eo Y 0 3 `t o Y °°- c z Lin w c O o m .o U u ▪ E a w E ° 0 8 a o p p O O WWC 0 O O ._ N N.i LD VD Wo .- .-i .-I ti rO .-1 2 0 0N C c ~ N O _ mO 00O U rriLU I W CO LL -o LL lL > LL Cil Li: ° O C N o II N >E N LnN Lm N N W ;E m m m m CO7 - E 6 a, O a m 2 O O o z Z E 0° •m 0^1gII W L'I N 7 °- O C O E -°_ 8 E • lfl t! 1• E w OI°o° L , U i 0 C 'C u 00•y) N '00 O �O• •f0 C m O .5 u u w .. .._ c ' C U Ln 0 0$ 'a`\'n ° 'a v at-• N 0 a x n a Q. G t O o L m > n�C 0k m ''' a= m v E � Qv 0' a °i m Do � O � .. m m .o ° ° 2 n aio m m U OI O m -- D_ LL ` 3 0 ',O U d LL W w L 2 LL O -0 `L W U 3 L1 L1 n `t ` x 0 N v� N D° " .v c F 0 :° N 3 t °° 3 a '� 0i m h m a d d O p E t- �, W 7• 4' .0.°/ 3 0, d • N .0 w w E W W i m v o. Y E c v u v ,� 0. 0 n ?� r v 'm c 0 m N o w 0 w a N v v-, a F E c E w t0' g o a 0. v .Q'w 0 w Do - -to to a z OD tow o Lcs •c vi vi to R ^ n u C 0. N 'a v N v " 'c v 0 0 o v 0 c v LL 3 .� v ` v r o 3 •0 'T, 0 Dov 0 w m Y E v y ° ° D, E o m u o m E v t. t• Do , E 4) w 0 a., w 00 m 0 0' o r r ° ~ o E W " c L r .o m , c 3 0 Ln } c c 0 " co 3 > C \ _ ° 0 °a t r E c 0 , u Lw u 5 m ._ o m m m ° N'� w E > E' 'w E '^ m > w �n j u E E i E :4 u �? 0 3 'w E vo n t o $ h 0 0 0 0 e 3 x u m u A r � LL E o z 2 o`o H w N m m � v_ ° N N i s c � LL v � .v n c o Y 'x Sc � x '" m c Y ° a a `o 0 3 3 ..1.5 Na•_D w N ^ ^ o _ c x c7 . m Ln 0 N c c +~ m c c E 3 c Z v 0C m La i+ O 0 00 o O 0 O O 411 ' 3 o a Q 2 2 = 3 o ¢ u 0 a 0 3 1 1, E o cE CI _ ryu to C o N U Q U Y� U Q U U U Q U 0 < 0 1't a C c C g Q C c C ' c c c C c C N to > m'1,4; 0° L° O° 0° 00 •y m 00 OD 00 0° 0° Ti.,eD 7 W W N O •w 01 G1 U! 01 01 01 0J U/ U 3 2 0 0 0 0 0 0 0 12000 0 0 0 • • UMIAT#23H Diverter Diagram 21.00'=Rig Floor / Flow Line 13-5/8" Annular �Ar ,, ,-. 21-1/4"x 13-5/8"DSA 11 n 16"Diverter Line — — — / 21-1/4" Diverter _ Spool 2M 16"Hydraulically Operated Knife Valve 21-1/4"Starting Flange 0.0'=Ground Level 0.0'=Top of Cellar 13-3/8"Conductor 4 -9.5'=Base of Cellar • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, November 27, 2013 8:56 AM To: 'Zachary Sayers' Subject: RE: Update to typo on re-submittal of 23H 10-401 Zach, Can you supply the new wellhead and production tree specs. Also, is tubing 3.5 or 4.5"for the well ? Both are listed in the program. Are you going to use VBR rams for the ram coverage? Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office From: Zachary Sayers [mailto:zacharv.savers lincenerav3 Sent: Thursday, November 21, 2013 5:18 PM To: Schwartz, Guy L (DOA) Subject: RE: Update to typo on re-submittal of 23H 10-401 Just following up on the updated application to see if you needed any additional information or clarification. Let me know if there is anything I can do. Thank you, -Zach Zachary Sayers 1 Contract Drilling and Completions Engineer P +1 907 375 2621 M +1 907 280 8492 E zachary.sayers©lincenergy.com 3000 "C" Street, Suite #103 Anchorage AK 99503 EIIERGYtes United +1 907x P868 8660 WWW lincenergy.com F +1 907 868 8881 Disclaimer Notice: The message and attachment(s) contained in this e-mail are intended for the named recipient(s) only. It may contain privileged or confidential information or information which is exempt from disclosure under the applicable laws. If you are not the intended recipient, you must not read, print, retain, copy, distribute, forward or take any action in reliance on it or its attachment(s). If you have received or have been forwarded this e-mail in error, please notify us immediately by return e-mail or e-mail lint©lincenergy.com and delete this message from the computer in its entirety. Internet communications cannot be guaranteed to be secure and error-free as the information could be intercepted, corrupted, lost, arrive late or contain viruses. The sender and this Company therefore do not accept any liability or responsibility of whatsoever nature in the context of this message and its attachment(s) which arises as a result of Internet transmission. Opinions, conclusions, representations, views and such other information in this message that do not relate to the official business of this Company shall be understood as neither given nor endorsed by it. 1 i • From: Zachary Sayers Sent: Thursday, November 14, 2013 1:06 PM To: Schwartz, Guy L (DOA) Subject: Update to typo on re-submittal of 23H 10-401 It was pointed out that page 7 of the re-submittal of the PTD has the wrong surface location. The 10-401 forms are all correct,the plat is correct,and the directional plan is correct. Just this page needs updating. Sorry for the confusion, 2 i • Bettis, Patricia K (DOA) From: Zachary Sayers [zachary.sayers@lincenergy.com] Sent: Monday, November 25, 2013 4:34 PM To: Bettis, Patricia K(DOA) Subject: RE: Umiat#23H: Permit to Drill Application My apologies. I rounded up for the permit from 6.8 ppge gradient to 7.0. Please use the higher value of 469 psi downhole, and 340 psi surface MASP. Thank you, Zachary Sayers llig Contract Drilling and Completions Engineer P +1 907 375 2621 Ni +1 907 280 8492 E zachary.sayers(@lincenergy.com ediAPAIEF .0:401.„,0,,,1,4111:'641111-Llittfrilbilrlittlittr" .: ..:1111 II � , Disclaimer Notice: The message and attachment(s) contained in this e-mail are intended for the named recipient(s) only. It may contain privileged or confidential information or information which is exempt from disclosure under the applicable laws. If you are not the intended recipient, you must not read, print, retain, copy, distribute, forward or take any action in reliance on it or its attachment(s). If you have received or have been forwarded this e-mail in error, please notify us immediately by return e-mail or e-mail linc@lincenergy.com and delete this message from the computer in its entirety. Internet communications cannot be guaranteed to be secure and error free as the information could be intercepted, corrupted, lost, arrive late or contain viruses. The sender and this Company therefore do not accept any liability or responsibility of whatsoever nature in the context of this message and its attachment(s) which arises as a result of Internet transmission. Opinions, conclusions, representations, views and such other information in this message that do not relate to the official business of this Company shall be understood as neither given nor endorsed by it. From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@lalaska.gov] Sent: Friday, November 22, 2013 11:41 AM To: Zachary Sayers Subject: Umiat #23H: Ptermit to Drill Application Good morning Zachary, On Form 10-401, Box 17, MASP is listed as 340 psi. In the Drill and Evaluate Plan Summary, page 4, the MASP is listed as 326 psi. Would you verify which number is correct? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist 1 r • • Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 9 • • Bettis, Patricia K (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday, November 14, 2013 1:17 PM To: Bettis, Patricia K(DOA) Subject: FW: Update to typo on re-submittal of 23H 10-401 Attachments: Updated Page 1 Umiat#23H.pdf Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office From: Zachary Sayers [mailto:zachary.sayers@lincenergy.com] Sent: Thursday, November 14, 2013 1:06 PM To: Schwartz, Guy L (DOA) Subject: Update to typo on re-submittal of 23H 10-401 It was pointed out that page 7 of the re-submittal of the PTD has the wrong surface location. The 10-401 forms are all correct,the plat is correct,and the directional plan is correct. Just this page needs updating. Sorry for the confusion, Zachary Sayers la 13 Contract Drilling and Completions Engineer P +1 907 375 2621 M +1 907 280 8492 E zachary.sayers@lincenergy.com 3000 "C" Street, Suite #103 Anchorage AK 99503 United States P +1 907 868 8660 �v iErit: Flt rqy UV, F +1 907 868 8881 Disclaimer Notice: The message and attachment(s) contained in this e-mail are intended for the named recipient(s) only. It may contain privileged or confidential information or information which is exempt from disclosure under the applicable laws. If you are not the intended recipient, you must not read, print, retain, copy, distribute, forward or take any action in reliance on it or its attachment(s). If you have received or have been forwarded this e-mail in error, please notify us immediately by return e-mail or e-mail linc@lincenergy.com and delete this message from the computer in its entirety. Internet communications cannot be guaranteed to be secure and error-free as the information could be intercepted, corrupted, lost, arrive late or contain viruses. The sender and this Company therefore do not accept any liability or responsibility of whatsoever nature in the context of this message and its attachment(s) which arises as a result of Internet transmission. Opinions, conclusions, representations, views and such other information in this message that do not relate to the official business of this Company shall be understood as neither given nor endorsed by it. 1 • zincUmiat #23H ERERGY 23H Drill and Evaluate Plan Summary Type of Well: Exploration (Oil Well) Surface Location: 1,031' FSL,4,026' FEL, Section 5,T1N, R1W, (UM) x=732 ,474 y= 5,631,271' NAD 27 Alaska Zone 5 Bottom Hole Location: 554' FSL, 1,327' FEL, Section 32,T1N, R1W, (UM) x=735,186 y= 5,630,875' NAD 27 Alaska Zone 5 Pad/Location: Umiat#23H Ice Pad Rig: Kuukpik#5 Estimated Start Date: 1-15-2013 Operating days to complete: 36 MD: 3,700 TVD: 1,288 Max Inc: 110 KOP: 360 RKB: 598 Well Design: Shallow Horizontal Primary Objective: Oil sands in the Lower Grandstand Member of the Nanushuk Formation Mud Program: Hole Size: Mud Type: 9-7/8" VersaClean, LVT-200; Mineral Oil Based-Mud (MOBM); Oil-Water ratio (70/30) Density(ppg) LSYP PV Funnel Vis API Filtrate HPHT Oil/Water 8.0 10—12 20-30 45—70 < 5 N/A 70/30 Hole Size: Mud Type: 6-3/4" EMS 6250, LVT-200; Mineral Oil Based-Mud (MOBM); Oil-Water ratio (100/0) Density(ppg) LSYP PV Funnel Vis API Filtrate HPHT Oil/Water 7.3 7- 10 17-28 45—70 N/A < 5 100/0 Mud Chiller:The MOBM will be run thru a mud chiller to minimize thawing of the permafrost and the reservoir.The mud chiller will be used to chill the mud temperature down to as low as 40°F. This is being used to minimize thawing of the reservoir and potential permeability reductions due to thawed connate water in the reservoir. Linc Energy I 23H Drill and Evaluate Plan Summary • • TRANSMITTAL LETTER CHECKLIST WELL NAME: V t'h i'/a F s23 4 PTD: 0c13 0 a Development Service /Exploratory Stratigraphic Test Non-Conventional FIELD: POOL: Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are Well Lo m also required for this well: gg g Requirements / Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, ✓ composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 5/2013 111/ S E a 0 ce To U ii o w w Q •m fl O i0o i- cn X 0' v >, I 2 ' '0 , c CO E 0 _, I 9 a c O 0) N 'p CO O. L c. U). • Or E c O1 ° c E, c' '3 3. m. 00 a) 3 c CD w w' a= c' (/) @ O = 0 0 @ O -'7". O. rT 00. : s 0, a ._ W. L 3 c) L N. c. U Oi -p : E p. a. 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(0 n a ti (n z .. 0 S 0 0 0 .3 .> 0 c� a a) a o °° 0 > > 3 c o 6 a a) m w w. ) �, m. o a E. ) 0 ai J E cr - - - E 0 a) 0 E E c 3 c c 't 1 1- 1 'w 0 a) > = a a p a () E :a 0) @ c is 0 tc a) a) a) 0 a a a a5 a) (0 0 - m 0 0 0, 2, 2 2 @, a. @ -a `° = O O, L, 0 0 a) CO a) a) 0 0 U @aJD55 (n 00aaU5aaZ cp (nUU' oU, aw ¢ wom, mU, �' E) M', 0- 0, (n, u) 0, LU °' COO .7 -N M N- (0 CO N- 00 0) O - N CO V• l0 CO n CO 0) O - N CO Nr 1 LO O N- CO 0) N co V L0 (0 r 00 0) F- rs- s- N- r- N N N N N N N N N N CO CO COCO) CO) I COCOCOCO) V O _.. co _.._ M r) I .. O O as N c .@. cV .d+ N w N O o no O 0 0 O G N O N 0 0 H W O co c cO.E 0 a N °- a) m 0 O J N c c C a m U W olQ a Cl- W < 0 < a a -R PV OF' I%% sA THE STATE Alaska Oil and Gas °fALASKA a®n ® ®nserVa >lnimissi®n 110 , *M GOVERNOR SEAN PARNELL 333 West Seventh Avenue X p. Anchorage, Alaska 99501-3572 ALASMain: 907.279.1433 Fax: 907.276.7542 Corri Feige General Manager Linc Energy Operations, Inc. 3000 C Street, Suite 103 Anchorage, AK 99503 Re: Exploratory Field, Exploratory Pool, Umiat#23H Linc Energy Operations, Inc. Permit No: 213-020 Surface Location: 1032' FSL, 1254' FWL, SEC. 32, TIN, R1W, UM Bottomhole Location: 1032' FSL, 3880' FWL, SEC. 32, TIN, R1W, UM Dear Ms. Feige: Enclosed is the approved application for permit to drill the above referenced exploration well. Linc Energy Operations Inc. (Linc) requests the following variances: 1. Lint's proposed well control equipment (standard BOPE instead of diverter) for drilling surface hole section (0-1800 ft md) is approved per 20 AAC 25.037 . Under-pressured hydrocarbon zones exist in the surface hole section and will be drilled with BOPE used as a diverter system only. Past drilling experience in the Umiat area has proven this is safe practice. 2. Lint's request for a variance to the requirements of 20 AAC 25.265 (c)(1) addressing the Safety Valve Systems (SVS) regarding a surface safety valve (SSV) in the vertical run of the well's tree. Lint's proposal to place the SSV on the wing valve is APPROVED under 20 AAC 25.265(o)(1). The surface drive progressive cavity pump (PCP) precludes having a SSV in the vertical run of the tree as the sucker rod is continuous from tree down to the pump and will not allow a SSV to close. Additional Conditions of Approval: 1. BOPE to be tested to 1500 psi(Annular tested to 1500 psi). 2. 7 5/8" casing to be pressure tested to 1500 psi. 3. Produced oil must be either re-injected back into the original formation or sold by an AOGCC approved custody transfer method per 20 AAC 25.228. 4. BOPE testing interval shall be no more than 7 days. 5. Weekly Drilling Summary reports must be submitted to the AOGCC via email to Guy Schwartz at Guy.Schwartz@alaska.gov. 6. Witnessed"No Flow"test required after stabilized production. 7. Shutdown configuration of the Umiat#23H wellbore must be approved by the AOGCC. • • This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, (04 0,4Cathy P. Foerster Chair DATED this L-1- day of March, 2013. cc: Department of Fish& Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMM . ON PERMIT TO DRILL 20 AAC 25.005 la.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service- Winj ❑ Single Zone 0 lc.Specify if well is proposed for: Drill E Lateral ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry ❑ Exploratory ❑✓ Service- WAG ❑ Service-Disp [I] Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 0 Single Well❑ 11.Well Name and Number: Linc Energy Operations,Inc. Bond No./ 3 101 85e 9244998424' ?I iojiv4i Umiat#23H • 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3000 C Street,Suite 103,Anchorage,AK 99503 MD: 3,550, TVD: 1,288° 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Exploratory(Umiat) Surface: 1,032'FSL,1,254'FWL,Sec 32-T1N-R1W,U.M.6 FEDAA84141 Top of Productive Horizon: 8. Land Use Permit: 13.Approximate Spud Date: 1,032'FSL,1,732'FWL,Sec 32-TIN-R1W,U.M. N/A 3/15/2013 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 1,032'FSL,3,880'FWL,Sec 32-T1N-R1W,U.M. 11,500.00 acres 1,025' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: - 598 feet 15. Distance to Nearest Well Open Surface: x-732,474 y-5,631,271 • Zone-5. GL Elevation above MSL: 575 feet to Same Pool: N/A 16.Deviated wells: Kickoff depth: 400 feet- 17. Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 90 degrees, Downhole: 469 psi ,, Surface: 340 psi 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 20" 13.375" 68 J-55 PE 100' 0' 0' 100' 100' 241.4 c.f.(Conductor Csg) 9.875" 7.625" 29.7 L-80 BTC-MOD 1,800' 0' 0' 1,800' 1,272' 875.4 c.f.(Surface Csg) 6.75" 4.5" 12.6# L-80 IBT-MOD 1,850' 1,700' 1,260' 3,550' 1,288' Open Hole Slotted Liner 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect. Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface - E ..IVE Intermediate Production Liner -EB 11 Z017 Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat 0 - BOP Sketch 0• Drilling Program 0 Time v. Depth Plot 0 2wrd Analysis❑✓ Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Program 0• 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Stan Porhola Contact stan.porhola(@lincenergy.com Email Printed Name Cord Feige Title General Manager-Alaska Signature / [� / Phone (907)868-8660 Date ////�- / Commission Use Only Permit to Drill API Number: Permit ApprovalSee cover letter for other Number: .,4 i3 O o�.v 50-„ �?-d.(:)0a9 -00 OcD Date: Li `i requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: Q Other: Samples req'd: Yes E No❑ Mud log req'd:Yes El No❑ Se, G 04..„..S,ent-74141 41 L- e L(G"' H2S measures: Yes Ef No❑ Directional svy req'd:Yes❑/ No❑ 11- Spacing exception req'd: Yes ❑ No LiInclination-only svy req'd:Yes❑ No0 .(L.orcZe.14off,s a I�pIre'U [ APPROVED BY / Approved by: d,/� )L__ COMMISSIONER THE COMMISSION Date: 3 - --- /3 ,� R4c13tad0 f ) This permit is val' for 24 months fromthe date of approval(20 AAC 25.005(9)) tta nts in Duplicate • • COZiDENTIAL RECEIVED EDERGY FEB 1 12013 AOGCC Linc Energy Operations, Inc. 3000 "C" Street, Suite #103 Anchorage, Alaska 99503 February 11, 2013 Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Application for Permit to Drill Well: Umiat#23H (Exploratory Oil Well) TRS: SWSW, T1 N, R1 W, Section 32, Umiat Meridian Dear Chairman Foerster, Linc Energy Operations, Inc. hereby applies for a Permit to Drill (PTD) for an onshore Exploratory Oil well on an ice pad in Umiat. The well will be drilled on BLM land under the authority of a current Oil & Gas (O&G) Exploration Lease (BLM Lease AA-084141) held by Renaissance Umiat, LLC. Linc plans to commence operations on approximately March 15th, 2013, employing the Kuukpik #5 drilling rig. No diverter system will be installed. Instead, a BOP system will be installed and tested to 1,500 psi before drilling out the conductor shoe. After drilling the 9-7/8" surface hole, the 7-5/8" surface casing will be set at 1,800' MD/ 1,272' TVD and tested to 1,500 psi. This will be done per BLM well safety requirements. The well will be horizontally drilled to 3,550' MD / 1,288' TVD. After drilling to TD and running a 4- 1/2" slotted liner in the open hole, the well completed in the Lower Grandstand as a _ horizontal oilproducer on PCP Artificial Lift Pump. No diverter system is proposed since the surface hole is the same as the production hole and the completion operations proposed would be best carried out with a BOPE in place of a Diverter in the unlikely event any gas bubbles migrate to surface. No pressurized fluid is expected to reach surface due to the sub-normal pressure of the Umiat reservoir. Offset drilling information on wells drilled in Umiat showed a lack of reservoir energy sufficient to bring fluids to surface and was evidenced by the lack of fluid movement in wellbores such as Umiat #3, Umiat #4, Umiat #5, Umiat #6, Umiat #7, Umiat #9, and Umiat #10 which sat without any cement plug for over 50 years and no • CONFIDENTIAL fluid came to surface. All oil production from the Umiat wells was achieved thru Rod Pump Artificial Lift. The Umiat reservoir has a low Gas-Oil Ratio (GOR) of around 70- 100 scf/bbl. Drilling operations in many of the offset wells that produced oil was conducted with cable tool rigs and primary well control involved a volume of brine in the hole that did not reach back to surface. Linc requests the following variance requests for this well: 1.) Variance to the requirements of 20 AAC 25.030(d)(2) addressing Casing and Cementing requirements to perform a formation integrity test on the conductor casing shoe if BOPE is installed on the conductor. The estimated fracture gradient of the conductor shoe at 100' MD/TVD is 10.6 ppg EMW, which is equal to 55 psi. Based on the sub-normal reservoir pressure of the Umiat reservoir and lack of reservoir energy to bring pressurized fluids to surface, a formation integrity test on the conductor would not be necessary. Instead, a test plug will be set in the base of the wellhead to isolate the conductor casing while testing the BOPE system. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Permit to Drill 2) Form 10-401 Permit to Drill (Public Copy) 3) NPRA Lease Map 4) Project Map 5) As-Staked Plat 6) Drilling & Evaluation Summary 7) Proposed Well Schematic 8) Anticipated Formation Tops 9) Proposed BHAs 10) Proposed Directional Survey 11) Proposed Directional Plan View 12) Proposed Directional Vertical Section 13) Proposed Drilling Fluids Program 14) Proposed Time-Depth Curve 15) Drilling Hazards Summary 16) Proposed Casing Design 17) Offset Mud Weight Data 18) Estimated Fracture Gradient 19) Kuukpik #5 Rig Layout 20) BOPE Diagram 21) Choke Manifold Diagram 22) CoRod BOPE Diagram 23) Shallow Hazard Analysis • CONFIDENTIAL The following are Linc Energy designated contacts for reporting responsibilities to the AOGCC: 1) Drilling and Completions Stan Porhola, Drilling and Completions Engineer (907) 868-8660 2) Geologic Data and Logs Dave Whitacre, Project Manager (907) 868-8660 The AOGCC is requested to treat as confidential all information in the Permit to Drill (except the Public Information Copy) as information in these documents is drawn from research and data proprietary to Linc. If you have any questions or require further information, please contact either Corri Feige, General Manager — Alaska at (907.868.8660) or Nick Scales, Drilling Operations Manager at (907.868.8660). Sincerely, Corri A. Feige General Manager - Alaska u -c-' t> 0`-' OvSQ v O 0 Pa \J ",) " {3 - 0 it� � Q -gn o o Q Q , n ... r0 � O , PI # : f ° , v 6 D'''oaDo a , , o 7o .,:� . y , 1 , , , t) 0 L) ''' U Pc0 0, =XI.,,a.0—4'Cl.Axv,vf q.d...,,z,m4m, 6 ,,,, o 0 0 j)''' C ..1.trAlt.''..;;;F:F.:,1),:r°'k',7,7:V:1:1a2;I"-'0°r '-.Ax:2x,t!,,PL.,r- ° �� 0 b� Via; s o v „„.,..�. ,jos ""7''' ''''' 9';' Eihll % G� r�, o r 1n.r. gm . p , °. . o� , ;zf.Ar. \ 60 CD D dp� co,, „X}9.Po+^ '.Pti'° . ��„1,vw° O �OO p ,0O to 1 .1 I r,, [,:z.„7.,, ^ c 0 (--Th_Nic"03 ,0 <7.•_0 ?c),, ,i,o;c) , 00 o a<)c) 0 0 •.:::—, 00 „:p O 00 (:,,c,-;\,,c) 0 00:r.;:-7 o c,„::. )• �,, ' c.4 'Y3 C\- 0 U'� c"c n ,gip g �`PcW ,r• . 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WL 3 � T01N � ����� A 4* K . • 101. 1 , .� t .°0 T01 S ?...„1/ ..• s.....„,, V <0 A. �CA 1 IN �� .� �, 5-56 ji rt. , �` ��" 1 576-\\N.,.._/>1 6 ' ��0��v �� �� s» <,\ 5ell 10 0 0 (� JW24t 0 Torrp- 89 O VICINITY MAP SCALE 1"= 1 MILE WELL 23 and 23H AS STAKED LOCATION LOCATED WITHIN CONDUCTOR AS STAKED LOCATIONS SECTION 32,T1 N,R1W, U.M. e • PROJECT LOCATION NAD83 ZONE 5, U.S. SURVEY FEET NORTH SLOPE WELL NORTHING EASTING LATITUDE LONGITUDE LOCATION STATE OF ALASKA0 ne 23 5,630,987 1,872,490 N69°23'38.36" W152°11'57.78" 1027'F.S.L. 1241'F.W.L. REVISION: REV 0 EnERGY 23H 5,630,992 1,872,503 N69°23'38.41" W152°11'57.41" 1032'F.S.L. 1254'F.W.L. NAD27 ZONE 5, U.S. SURVEY FEET DATE: Sept.4,2012 ` SHEET: 1 OF 1 g® " , 23 5,631,266 732,461 N69°23'39.75" W152°11'47.11" 1027'F.S.L. 1241'F.W.L. FIELD BOOK: 11-060 , l' 23H 5,631,271 732,474 N69°23'39.80" W152°11'46.74" 1032'F.S.L. 1254'F.W.L. DRAWING NAME: W23 As-Staked DRAWN: CC G m CHECKED. KWA Q`�CQ GRID: NA �"fngine0. .SCALE 1"=100' t • • CONFIDENTIAL Well Name: Umiat #23H Drill and Evaluate Plan Summary Type of Well: Exploration (Oil Well) Surface Location: 1,032' FSL, 1,254' FWL, Section 32,T1N, R1W, (UM) x= 732,474 y= 5,631,271' NAD 27 Alaska Zone 5 Bottom Hole Location: 1,032' FSL, 3,880' FWL, Section 32,T1N, R1W, (UM) x=735,099 y= 5,631,349' NAD 27 Alaska Zone 5 AFE Number: 315 Rig: Kuukpik#5 Estimated Start Date: 3-15-2013 Operating days to complete: 27 MD: 3,550 TVD: 1,288 Max Inc: 90 KOP: 400 RKB: 598 Well Design (conventional,slimhole,etc.): Shallow Horizontal PCP Pump Artificial Lift Primary Objective: Oil sands in the Lower Grandstand Member of the Nanushuk Formation Mud Program: Hole Size: Mud Type: 9-7/8" VersaClean, LVT-200; Mineral Oil Based-Mud (MOBM); Oil-Water ratio (70/30) Density(ppg) LSYP PV Funnel Vis API Filtrate HPHT Oil/Water 7.5 / 10-12 20-30 45-70 < 5 N/A 70/30 Hole Size: Mud Type: 6-3/4" VersaClean, LVT-200; Mineral Oil Based-Mud (MOBM); Oil-Water ratio (70/30) Density(ppg) LSYP PV Funnel Vis API Filtrate HPHT Oil/Water 7.5 / 10—12 20-30 45—70 < 5 N/A 70/30 Mud Chiller:The MOBM will be run thru a mud chiller to minimize thawing of the permafrost and the reservoir.The mud chiller will be used to chill the mud temperature down to as low as 40°F.This is being used to minimize thawing of the reservoir and potential permeability reductions due to thawed connate water in the reservoir. S r,,!:FIDENTIAL Evaluation Program: 9.875 in Hole Section: Logging Suite: MWD/LWD: MWD, Gamma, Resistivity, Density, Neutron Open Hole Logs: None. Cased Hole Logs: None. 6.75 in Hole Section: Logging Suite: MWD/LWD: MWD, Gamma, Resistivity, Periscope (Bed Boundary) Open Hole Logs: None. Cased Hole Logs: None. Casing/Tubing Program (All new casing): Hole Size Csg/Tbg OD Wt/ft Grade Conn Length Top Bottom 20" 13-3/8" - 68# J-55 PE Bevel 100 ft 0/0 ft 100/ 100 ft 9-7/8" 7-5/8" - 29.7# L-80 BTC-MOD 1,800 ft 0/o ft 1,800/1,272 ft 6-3/4" 4-1/2" 12.6# L-80 IBT-MOD 1,850 ft 1,700/1,260 3,550/1,288 ft Tubing 4-1/2" 12.6# L-80 TC-II 1,690 ft 0/0 ft 1,690/ 1,259 ft Cementing Program: Conductor Lead Cement Hole Size Csg Size Type Density Yield % Excess Volume Est.TOC 20" 13-3/8" Arctic Set I 15.7 ppg 0.93 ft3/sx 150 43 bbl 23' (GL) Additives: 0.05 gal/sx Retarder Surface Lead Cement Hole Size Csg Size Type Density Yield %Excess Volume Est.TOC 9-7/8" 7-5/8" Permafrost 11.0 ppg 1.87 ft3/sx 250 100 bbl 23' (GL) Additives: 0.20% BWOB Antifoam,0.35% Fluid Loss,0.06 gal/sk Dispersant,0.10 gal/sk Accelerator Compressive Strength: 825 psi (24 hrs) Surface Tail Cement Hole Size Csg Size Type Density Yield %Excess Volume Est.TOC 9-7/8" 7-5/8" Class G 15.8 ppg 1.16 ft3/sx 35 56 bbl 801' Additives: 0.20% BWOC Antifoam,0.30% Dispersant,0.25% Fluid Loss,0.50%Accelerator Compressive Strength: 900 psi (24 hrs) Centralizer Program: Hole Hole Casing Depth (MD) Centralizer Type Centralizer Spacing Section Size Size 1 9-7/8" 7-5/8" 0—1,800 ft Bow Spring 1 per 1 joint from 100' to 1,800' • ,AL Bit Program: BHA Hole Size Depth (MD) Bit Type Nozzle/ Flow Rate 1 9-7/8" 100—1,800 ft Smith GF05V Insert 11/11/11/10; 500 gpm 2 6-3/4" 1,800—3,550 ft Smith XR20TD Insert 8/8/8/9; 375 gpm Wellbore Survey Program: Hole Size Depth (MD) Survey Method Survey Frequency 9-7/8" 0—1,800 ft MWD Min. Every 100' Hole Size Depth (MD) Survey Method Survey Frequency 6-3/4" 1,800—3,550 ft MWD Min. Every 100' Perforating Program: Zone Method Top Bottom Total Gun SPF (MD) (MD) Footage Size Lower Grandstand (Oil Zone) Openhole N/A N/A N/A N/A N/A Mud Logging: HYDROCARBON DETECTION Total Hydrocarbon Analyzer(THA)via Flame Ionization Detection Cl-CS GAS MEASUREMENTS Gas Chromatograph (GC)via Flame Ionization Detection GAS-IN-MUD MEASUREMENTS Quantitative Gas Measurement(QGM)Gas Trap CUTTINGS SAMPLES Collect every 30 ft (wet and dry) from surface to TD Collect every 10 ft (wet and dry) in zones of interest Rig Pit System: ACTIVE SYSTEM CAPACITY 520 Barrels (160 BBL Shaker, 70 BBL Degasser, 130 BBL Centrifuge, 80 BBL Volume, 80 BBL Suction) ADDITIONAL RIG TANKS 400 Barrels (4 each 100 BBL Pre-Mix Tanks) TRIP TANK 30 Barrels PILL TANK 30 Barrels GAS DETECTION Sierra Monitor(Digital) Fixed System Gas Detector for H2S and Methane 3 Station sensors, 1 at rig floor, 1 at bell nipple, 1 at shakers INSTRUMENTATION Pason (Pit Bull Model) Pit Volume Totalizer Drilling Waste Disposal: DRILL CUTTINGS Cuttings generated during drilling will be transferred by small cuttings bins to larger Shale Bins before being transported off location by Haul Trucks and disposed of at Prudhoe Bay Drillsite#4, an approved Class II Waste Facility; -or- Upon approval to operate, a Grind & Inject(G&I) unit will be used to process the cuttings from the Shale Bins and dispose of the cuttings down the tubing into the permitted disposal zone in the Umiat DSP-01 well. '" • • COUHI ENTIAL FLUIDS All fluids will be stored in a heated tank farm and upon completion of Umiat DSP-01 as an approved Disposal well, all applicable Class II fluids will be .15 disposed of down the tubing into the permitted disposal zone; -or- If the Umiat DSP-01 well is not permitted or incapable of disposing of fluids, fluids will be transported by Steiger and/or Tundra Bear ATV and brought to Prudhoe Bay Drillsite#4, an approved Class II Waste Facility. Well Control Program: DIVERTER None. BOPE 11" 5M Annular, Double Gate, Mud Cross, Single Gate KILL LINE 3" Line w/2 each 3" 5M Manual Valves CHOKE LINE 3" Line w/1 each 3" 5M Manual Valve, 1 each 3" 5M HCR CHOKE MANIFOLD 5M Choke Manifold, 2" Manual Choke, 2" Hydraulic Choke, 3" Inlet, 3" Panic Line, 3 each 3-1/8" and 13 each 2-1/16"valves(16 total) ACCUMULATOR 170 gallon reservoir, 12 each 15 gallon bottles, nitrogen backup, pneumatic and electric pumps DIVERTER LINE None. BLOOIE LINE Length =50' (Exit point on Drillside of Rig) REMOTE BOP CONTROL Located at Driller's Station Maximum Anticipated BHP 7.0 ppg x 0.052 x 1,288 ft=469 psi Maximum Anticipated Surface 469 psi—(0.10 psi/ft x 1,288 ft) =340 psi Pressure (MASP) Planned BOP Test Pressure Rams 1,500/250 psi;Valves 1,500/250 psi;Annular 1,500/250 psi (10 min each) Casing Test Pressure (7-5/8") 1,500 psi for 30 min Offset Leak-Off/ Formation Integrity Data: Well Name Depth of Shoe Pressure (EMW) LOT or FIT Seabee Test Well#1 1,617' 11.5 ppg FIT Seabee Test Well#1 3,983' 15.3 ppg FIT Seabee Test Well#1 9,980' 17.6 ppg FIT Seabee Test Well#1 12,814' 20.0 ppg FIT CON'cIENnAI. Leak-Off Test Procedure: 1.) Drill shoe track and drill 20' of new hole. Circulate and condition mud. 2.) Pull the drillstring into the shoe. 3.) Close the pipe rams and pump down the drillpipe at slow rates. 4.) Plot drillpipe pressure vs. cumulative volume pumped. The point"B" on the below graph is the leak-off pressure (LOP).The equivalent mud weight of that leak- off pressure is as below: LOT(EMW) = MW+ (LOP/(0.052 x Shoe TVD)) QLEAK OFF TEST PROCEDURE _ B D °. a A-Varies until system is pressured up. — -- B-Leak-off point. C-Injection pressure(rate dependent). A C I D-Fracture closure pressure. Volume Pumped (Bbls) IL 0 .ikxy Umiat #23H — Well Planning Summary Pre-Rig Work: 1) Auger 20" conductor hole to 100'ft MD/TVD. 2) Install 13-3/8" 68#J-55 conductor to 100' ft MD/TVD. 3) Cement 13-3/8" conductor back to surface with 43 bbl of Arctic Set I cement. 4) Install 9.5' internal diameter cellar 9.5' below original ground level. Rig Operations: 1) MIRU Kuukpik#5. 2) Perform rough and final cut of 13-3/8" conductor and prep same. 3) Make cut on 13-3/8" casing. NU 11"Wellhead.Test wellhead to 1,500 psi for 15 min. 4) NU 11" BOPE with blind rams, 1 set of 4-1/2" pipe rams and annular. Nva; ., 15re.141" 5) Test BOPE to 250/1,500 psi for 10 min each (Annular to 250/1,500 . 6) Mix and fill pits with 7.5 ppg Mineral Oil-based Mud (MOBM). w� �Yo ham', 7) MU 9-7/8" bit and 4-1/2" drillpipe drilling BHA#1. 8) Cleanout to base of conductor at 100' MD/TVD. 9) Drill 9-7/8" hole from 100'to KOP at+/-400' MD/TVD. 10) Directionally drill 9-7/8" hole from 400'to TD at+/- 1,800' MD/ 1,272'TVD. 11) POOH. L/D drilling BHA#1. C�O iA • - ? 4 z .��f' 12) MU 7-5/8" float track. RIH w/7-5/8" casing to+/- 1,800' MD/TVD. 13) RU cementers. Mix and pump 100 bbl of 11.0 ppg Permafrost lead cement and 56 bbl of 15.8 ppg Class G tail cement, bringing cement to surface. AL-1-'47f-0 3C-- %f 14) Bump plug. Bleed off and check floats. �`csU4 '"`` s`"ar�` �'- 15) Change pipe rams to 4" pipe rams. 16) Test BOPE to 250/1,500 psi for 10 min each (Annular to 250/1,500). 17) MU 8-1/2" bit and 4" drillpipe drilling BHA#3. 18) Cleanout cement in shoe track of surface casing to 1,775' MD/TVD. 19) RU and pressure test 7-5/8" casing to 1,500 psi for 30 min. 20) Drill remaining shoe track to 1,800' MD/TVD. 21) Drill 20' of new formation to 1,820' MD/TVD. 22) POOH to casing shoe. ,;,• 23) RU and perform LOT/FIT to 12.5 ppg EMW. F` iZ 24) Drill from 1,820'to TD at+/-3,550' MD/ 1,288'ND. 25) Circulate and conditions hole. POOH. LD 4" drillpipe. 26) RIH w/4-1/2" liner to+/-3,550' MD/1,288'ND. °1' L(LJE� 27) Displace MOBM to 7.0 ppg Mineral Oil Completion Fluid. 28) Set liner hanger. POOH. L/D liner running tool and 4" drillpipe. 29) RIH w/4-1/2" tubing,jewelry, torque anchor and tubing hanger. 30) Set torque anchor at+/- 1,675' MD (set to hold tubing in place, not for pressure isolation). • • 0071nriTIA 31) Land hanger. 32) Test hanger to 1,500 psi for 10 min. 33) Run BPV. ND BOPE. NU Tree. Pull BPV. Run TWC.Test tree to 250/1,500 psi for 30 min. 34) Rig down and move out Kuukpik#5. Post-Rig Operations: 1) MIRU Weatherford Mast Unit and Mobile Gripper Unit (CoRod Unit). 2) NU CoRod BOPE including 1" Rod rams and annular preventer. 3) Test BOPE to 750 psi. e 4) PU insertable PCP Pump with X 1" sucker rods, and 1" polish rod. 5) Land insertable PCP pump in tubing profile at+/- 1,600' MD/TVD. 6) ND BOPE. 7) Install electric rotating surface drive head.Test drive head seals to 750 psi. 8) RD Weatherford CoRod Unit. Well Test Operations: 1) MIRU Well Test Unit. 2) RU Well Test Unit to Production Tree wing valve. 3) Flow test well for+/-7 days. 4) Shutdown surface drive. Shut-in well. 5) RD Well Test Unit. 6) RD and secure well. /AI 11- ‘ :A Pad: Umiat#231 ice Pad 1111CLease: AA-084141(BLM) U meat23H 0 Tree Connection: 4.5"OTIS EIIERG i Well Type: Exploration(Oil&Gas) *PROPOSED* Base of Permafrost: 801'MD/793'TVD GL: 575'AMSL HOLE DATA RIG RIM: 598'AMSL 1 Hole Section Size Top(MD) Btm(MD) Top(TVD) Btm(TVD) Mud Wt Max angle A RKB-GL: 23'(2'of ice) { - in ft ft ft ft type ppg deg Conductor 20" 0' 100' 0' 100' N/A N/A 0` B ''' 13-3/8" • xi. - Surface 9-7/8" 0' 1,800' 0' 1,272' OBM 7.5 83° 100'TVD Production 6-3/4" 1,800' 3,550' 1,272' 1,288' OBM 7.5 90° FIT=10.1 ppg LOT=10.6 ppg CASING/TUBING DATA d!' -; Hole Section Size Wt Grade Conn ID Top(MD) Btm(MD) TOC - in lb/ft - - in ft ft ft • tk. Conductor 13-3/8" 68 1-55 PE 12.415" 0' 100' 0' 5 Surface 7-5/8" 29.7 L-80 BTC-MOD 6.875" 0' 1,800' 0' ':f Production 4-1/2" 12.6 L-80 IBT-MOD 3.958" 1,700' 3,550' N/A I Tubing 4-1/2" 12.6 L-80 TC-II 3.958" 0' 1,690' N/A bx: . CEMENT DATA z I r' I ...7., Conductor11:1 Permafrost 23161) 100' 15.7 0.93 43 260 i; Surface ® Permafrost 23(GO 793' 11.0 1.87 100 300 w : Surface El ClassG 793' 1,800' 15.8 1.16 56 271 ''4 �'''" COMPLETION JEWELRY SUMMARY e' Item Description Depth ID OD Install Date ti - ft in - in - •• • 4 1 Tubing Hanger 21' 3.958" 6.184" Proposed 2 Chemical Injection Mandrel 1,000' 3.813" 4.500" Proposed r 4 3r2 3 Pressure/Temperature Gauge 1,550' 3.813" 4.500" Proposed `� ., 4 Pump Seating Nipple 1,600' 3.810" 4.500" Proposed -dJ t.'+ K,, 5 Pressure/Temperature Gauge 1,660' 3.813" 4.500" Proposed 2 ..1 6 PCP Torque Anchor 1,675' 3.958" 6.875" Proposed Z ,t-,•. 7 WLEG 1,690' 3.958" 3.500" Proposed 8 Liner Hanger 1,700' 4.000" 6.875" Proposed RODSTRING SUMMARY ;f�, + Item Description Depth ID OD Install Date R. .;& e - - ft in in I - �'( A 40'Polish Rod 22' - 1.000" Proposed b. B Space Out Rods '� 5 62' - 1.000" Proposed >'+ 14 C COROD ...,` 70' - 1.000" Proposed n 3 0 'fts D Seating Mandrel 1,600' - 3.810" Proposed '-'; O y'- 1,272'TVD E Shear Coupling 1,610' - 1.000" Proposed FIT=12.5 ppg Lower Grandstand-1,197' b `- cc,� ,''S LOT=13.0 ppg F Giraffe String 1,611' - 1.000" Proposed ♦ V G PCP Rotor,XL 189-4100 1,620' - 2.000" Proposed Top LOS A-sand 1,197' `� \` ro H PCP Stator,XL 189-4100 1,650' - 3.810" Proposed r. Base LGS A-sand 1,230' � ;�,\_ y410 AP Slotted Liner 4-1/2" Top LOS B-sand 1,265' �'e : • Base LOS B-sand 1,320' \w 7-5/8" HEEL TOE TO:2,050'MD/1,288'TVD LGS B-sand TD:3,550'MD/1,288'TVD PBTD:2,050'MD/1,288'ND PBTD:3,550'MD/1,288'TVD DATE REVISED BY: WELL HISTORY DESCRIPTION Well Name Umiat f123H 2/6/2013 S.Porhola Proposed Lower Grandstand B-sand Horizontal Slotted Liner PCP Completion Spud Date N/A API No. N/A PTD N/A Max Hole Angle N/A Max Dogleg N/A • CONNT1Al 4-1/296 •-:; - Schlumberger x•10 Field Name Umiat Borehole Name Umiat#23H Hole SlzelinJ 9.875 wee ---- --------. .-_ -.- - ---____ Structure Name ,3,;;Umlat#23 _ BHA Name Umiat 23H BHAO1 9-7/8"Surface Depth In( _ 0.00 Well Name Umiat#23H Depth Out(ft) 1800.00 OD Bot Size Bot H„wvv,g+ Bot Type Cum. Cum. Drill Roe(110 (in) Max OD (in) Gender Length Desc. Manu. Length Weight ID (in) Top Size Top Type Top (ft) (ft) (1000 Ibm) (in) (in) Gender 7. Crossover .__500oseovS ir 1 9 7/8"Insert Bit GFO5V Smith 3.250 9.875 6 625rREG_- Pin 1.00 1.00 _ 0.2 Sk 1 8.250 6.6251 REG Box 1 Mt 2 IA800M7840XP Schlumberger 6.250 8.250 5 500 REG ,Box 28.00 29.00 4.3 III 1 8.250 5.500 REG Pin 612 Jet I 3 18-3/8"Stabilizer 8-3/8"Stabilizer 2.500 8.375 5.500 REG Box I 5.001 34.00 .,_ 5.1 6.750 5.500 REG Pin , A 4 Bottleneck Sub 2.813 6.750 5.500 REG Box 3.00 37.00 5.4 ...___ 6.750 5.500 REO Pln 5 1ARC.6 Schlumberger 2.810 7.500 5.500 FH Box 18.00 55.00 7.2 Crossover Sub2 1 6.750 5.500 FH Pin 6 1 Pe ergeTelescope 675 NF Schlumbr 5.109 6.890 5.500 FH Box 25.00 80.00 -9.3 FI 1FH Pin i vHeavy" m-rg Nc50S4121F) Box 20.00 100.00 10.9 6.750 5.500, 7 ADN-6 Schlumbe er 2.250 6.750 4 500 6.625 4.500,NC50(4121F) Pin 8 7 1/4"Flex NMDC +-_ 2.813 7.250 4.500 Nc50(4 1/2 IF) ;Box 30.00 130.00 14.6 aasawer sob 1 6.625 4.500 NC50(4 12 IF) Pin i 9 7 1/4'Flex NMDC 1 2.813 7.250 4.500 NC50(4 1/2 IF) Box 1 30.00 160.00 18.2 7.250 4500,Nc50.(4 1/2 IF) ,Pin Sever Sub10 Saver Sub (Schlumberger 2.813 7.250 4 500INC50(4 1/2 IF) (Box 3.00 163.00 18.6 Ill Crossover Sub6.750 4 5001NC50(412IFZ Pin Crossover Sub " 2.813 6.750 4.000 NC46(4 IF) Box 3.00 166.00 18.9 7/N"Flex Heavy Weight Drill Pipe 4.500 4.000'Nc46(4 IF) Pin NMDf 12(2)ts)(210) .l 2.750 _6.250 4.000 Nc46(41F) Box 62.00 228.00 21.5 1 6.750 T I 4 .000 NC46(_4 1 ft_ _Pin 1µ,Flex Crossover Sub _ 2.813; 6.750 4.500 NC50(4 1/2 IF) Box 3.001 231.00 21.8 "''OC - 6.500 4.500 NM(4 1/2 IF) Pin 1416 1/2"Jar --1ISmith2.750: 6.500k 4.500 NC6o(41/2IF)l_Box 32.001 263.00 23.7 ' 6.750 I 4.500 Nc5o(4 1/2 IF)jPin 15�Crossover Sub 1 2.813 6.750 4.000'5046(4 IF) 'Box 3.00 266.00 24.0 ADN-6 I 4.500 4.000 50,46(4 IF) Pin -. -. 16 Heavy Weight Drill PIpe11j I 2.750 6.250 4 000,NC46(4 EL Box �. 31.00 297.00 25.3 4.433 4-1/2"16.60 DPS,10% j- 4.000 NC46(4 IF) Pin 1--- 17 Wear 3.826 6.250' 4.000 N046(1IF) Box 31.001 328.00 25.8 1 -- Telescope 675 • I NF I I 1 ARC-6 I Total Length(ft) 328.00 at BHA Comments I Total Weight in Air(1000 Ibm) 25.8 Total Buoyant Weight(1000 Ibm) 25.8 IDealer*.Sub Buoyant Weight Below Jar(1000 21.8 Weight in Air Below Jar(1000 Ibm) 21.8 1 Mud Properties Mud Weight(Ibm/gal) 8-3/8" 411111111) Mud Type WBM StabizerPV(cP) sr 40. YP(Ibf/100ft2) Sensor Offset from Bit(ft) Stabilizer Summary BHA Nozzle Summary APWD 41.58 Blade Mid-Pt to Bit Blade OD(in) Blade Bit Nozzle Reamer Nozzle ARC Resistivity 43.92 (ft) Length Count ID(1/32 in) Count ID(1/32 in) ARC Gamma Ray 44.17 3.010 8.250 1.330 4 14.000 MWD Gamma Ray 64.90 30.500 8.375 2.000 Ae001.47840xp D+I 67.02 TFA(in2) Density 90.52 PD Flow Restrictor Neutron 93.73 (1/32 in) I Rotor By Pass Nozzle TFA(in2) 0.601 (1/32 in) I 0.000 Bend Summary 9 741"Insert - Bend Angle(deg) Bend to Bit(ft) Date 05Feb2013 an orosv 1.830 8.060 Designed By DIR\DCecil-cockwell Approved By S rruirrom Schlumberger e.ISID DPS, Field Name Umiat Borehole Name Umiat#2311 Hole Size(in) 6.750 Structure Name Urnat 423 BHA Name Umiat 23H BHA02 6-3/4"Horizontal X5 MXW Depth In(ft) 1800 00 Well Name Um at 023H IMP Depth Out(ft) 3550.00 OD Bot Size Bot Deec. Manu. Cum. Cum. PlbevY WOO --, (in) Max OD TGender Length 011 Pt.Cile) Length Weight ID (in) op Size Bot Type Top (ft) (ft) (1000 Ibm) (in) (in) ir Type Gender I , 4 500 A Crossover S. - 1 6 3(4"Bit Generic 1 500 6.750 3 500[REG ?in 1.00 1 00 0.1 I ' PD 475 X5 DA 6 1/2" 4.980 3 500IREG Box -1 2 Stabilized CC Schlumberger 3.640 6.375 3 500 NC38 131/2 IF) Box 13.33 14.33 0.8 4.750 i 3.500 NCNI(31/21g1 Pin Ii 3 4.75"Misc.Sub Schlumberger 2.250 4.750 3.500 NC38(31/2 IF) Box 5.00 19.33 1.0 6 - 4.750 3.500 NC38(31/2 IF) Pin Nycke-Jer 4 Periscope 475 Schlumberger 1.430 5.280 3.500 NC%(31/2 IF) Pin 24.00 43.33 2.2 5- IMPulse 25k Medium Flow Schlumberger 4.750 3.500 NC38(31/2 IF) 2.250 5.250 3.500 NC38 131/21F) Box Box 32.00 75.33 3.8 I 4.750 3.500 NC38(31/21F) Pin 6 6"Stabilizer Schlumberger 1.750 6.000 3.500 NC38(31/21F) Box 5.00 80.33 4.1 Crossover Sub i III 3.500 3.500 N038(31/2 IF) Pin * 7 5"Flex NMDC SchlumbeNer 2.250 5.000 3.500 NC38(31/2 IF) Box 30.00 110.33 4.8 li 1" 3.500 3.500 NC38(31/2 IF) Pin Hos,WeStA t I 8 5"Flex NMDC Schlumberger 2.250 5.000 3.500 NC38(31/21F) Box 30.00 140.33 5.6 02**) 113.500 3.500 N038(31/2 IF) Pin 111 111' _9 5"Flex NMDC Schlumberger - 2.2501 5.000 3.500 NC38(31/21F) Box 30.00 170.33 6.3 4.750 3.500 NC38(31/21F) Pin Crossover Sub $ 10 Crossover Sub Rig 1.750 4.750 4.000 X130 Box 5.00 175.33 6.6 * Heavy Weight Drill Pipe 4.000 4.000 xrac Pin 11(12jts) Rig 2.563 5.250 4.000 xrati Box 31.00 206.33 7.5 S.F.(NMDC 4.750 _4.000T39 Pin ' 12 Crossover Sub Rig 2.813 4.750 3.500 N038(31/2 IF) Box 3.00 209.33 7.6 4.750 3.500 NC38(31/219_ Pin r . 13 Hydra-Jar Dei 2.250' 4.830 3.500 NC38(31/2 IF) Box 30.00 239.33 8.7 s F.,NMDC 4.750 3.500 NC38(31/2 IF) Pin 141Crossover Sub Rig 2 813 4.750 4.000 xrn Box 3.00 242.33 8.8 4.000 4.000 XT39 _ Pin 5'Flex WAX 15!Heavy Weight Drill Pipe(7jts)Nil I 2 563 5.250 4 000 XT39 Box 31.00 273.33 9.7 I1 1_3.924 4 000.XT39 Pin 16.4"15.70 DPS,10%Wear Rig 11111 3.2401 4.750 4 000 X139 Box 31.00 304.33 10.3 1,1111 frig 8'StebiMet - I _ I . si',Pulse 2Sh Medon Flow UR it -, . Total Length(ft) 304.33 'BHA Comments I Total Weight in Air(1000 Ibm) 103 Total Buoyant Weight(1000 Ibm) 10.3 Pods..475 Buoyant Weight Below Jar(1000 Ibm) 7 6 Weight in Air Below Jar(1000 Ibm) 7.6 Mud Properties Mud Weight(Ibm/gal) .. _ 4.75.Km 11 Mud Type OBM PV(cP) Sub VP(lbf/100ft2) Sensor Offset from Bit(ft) Stabilizer Summary BHA Nozzle Summary Gamma Ray 6 86 id Blade Mel-Pt to Bit Blade OD(in) Blade Length Bd Nozzle Reamer Nozzle D*I 773 (ft) Count ID(1/32 in) Count 10)1/32 in) _ PenScope Res 27 02 11 010 6 375 0 492 P0175 X5 DA PeriScope GR 36 74 76 830 6 000 2 000 6 V? Impulse Resistivity - 49 43 TFA(in2) Slebizesi CC D+I 54 63 PD Flow Restnctor Impulse Gamma Ray 57 43 (1/32 in) 1 0.000 at . 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Well: Umiat 23H 01. 1n , EFIERGy Prepared by: Customer Approval: Name: Andy Lee Name: Stan Porhola Position: Project Engineer Position: Drilling Engineer Company: M-I SWACO Alaska Company: LINC Energy,Ina Date: AFE#: Version: 1.0 Approver ID: Logit#: Version 1.0 Confidential Page 1 of 12 S 11011Afigoop, • Maintaining proper document control is critical with regard to the development of appropriate well design.No changes will be made without being supported by the appropriate documentation and described below in table, ,n 1.0 1/30/2013 Draft version of purposed fluids plan for LINC's Umiat 23H Project Summary: Umiat is located 140 miles southwest of Deadhorse resulting in additional logistical challenges. All product and equipment will be transported out of Deadhorse and brought to the staging area off the haul road at mile 359(near pump station 2) 55 road miles south of Deadhorse; from there it will be transported by rolligon or flown out to location. Umiat 23H will be drilled with Kuukpik Rig#5 to a total depth of 3,550' MD— 1,288' TVD with a max angle of 90°. Umiat 23H will be completed as a slotted liner producer in the lower Grandstand B-sand and drilled in two intervals. The first interval will be drilled with a 9-7/8"bit and M-I Swaco's VersaClean drilling fluids system,the drilling fluid let over from Umiat 18 will be re-used for Umiat 23H's surface interval. After drilling the surface interval to 1,800' MD it will be cased with 7-5/8"casing. The second interval will be drilled with a 6-3/4"bit and M-I Swaco's VersaPro oil base drilling fluid systema Umiat 23H will be completed with 4.5"slotted liner hung from 1,700' to 3,550' MD along with 4.5" .F production tubing to 1,690' MD. Version 1.0 Confidential Page 2 of 12 • • CNRENA1. § v, .., 4_, ,U ° ƒ k 0 \ \ CU < < \ \ > < J H / \ / • C z z 5 £ z » » R 4... 0...L- >" co / / o \ \ 7 ( / IP ¥ & & u % w + 5 a E _ 'g — 2 w o 2 R 2 0 0 0 o o < 0 o ' 2 2 ƒ R 40 I K & & K » z c % CO I k E 3 & co \ / 0 • / C 2 e § F— s- CU Q N < Q G % $ Cr, a 3 11 a § k ~ ® - - Z Cr - # 5 C CL 03 \ a) O k / g 4.1 2 / ® _ CD 5 ® § _ C ® r o o m # m e < / / COk » 5 \ m 2 E « z E ° C LL i- » E -C # = 13 y \ 0 o_ CU 4-U ° ,v 2 m CD m CD Q Cr) / \ % \ \ _ m « » » 2 2 E 2 cz • k k g 2 X / / @ \ W r o 2 0 / g k k 2 i CO CD c CD 0 \ / / / eri o / / I 5 _ _ N o = _ ¥ ca # L a) RI / m § C / E / / / \ / \ e 5 ▪ , / i C / 2 ƒ \ ° » 3 / — ° / _ A / z z C R a / 0- I- 9- O co 2 - = E % E \ / / / S / \ \ 2 ° 0 / ' F = 0 i \ \ \ \ f / cis / _ = m > / / / \ \ \ D a) / $ \ _ ) \ \ + a) 2 0 / \ E \ ro ( � c \ / / \ 6 % 2 \ 0- ƒ 0- J \ ro\ k 2 = § * (DUD ° D 0 G R C ° » / / / / ( \ / \ / / 0 / ± 00 \ I— 1.-- 1— Z "- 00 e = e -0 3 e k = A Schlordwpat Company SIA.0„ COIA CONFINTIAI. l h Mud �. Depth Weight Total Interval Casing Size Hole Size Casin• Intervals Depth MD TVD Mud System (ppg) Days Cost V Conductor Depth 100' 7.625"OD 9.875" 0 1800' 1,272' 7.5 ppg 6 6.875"ID .094 bbls/11 VerSaClean 4.5"OD 6.75" 3,550' 1,288' 7 5 6 3.958"ID .044 bbls/ft VerSaPID PP9 1 Completion 4.5"OD 3.958" ID 0152 bbls/ft 3,5501,288' LVT-200 2 Total Total Cost Days 14 Version 1.0 Confidential Page 3 of 12 _ MI i i isperrampow Surface Interval: 9.875" Hole, 0— 1,800' MD, 1,272' TVD Lithology through this zone is a composite of small gravel in the upper sections with a grading downward to sand,clay,and siltstone in the lower zones with the base of the permafrost located at 801' MD. The surface section for Umiat 23H will be drilled with the drilling fluid utilized for Umiat well 18. When bringing the flue. ; into the rig complete a full mud check and adjust the properties accordingly. If the fluid was previously weighed up it may require to be run through the centrifuge in order to remove any low gravity solids from the previous well. Surface Interval: 0' — 1,800' MD Drilling Fluid System VersaClean Key Products LVT-200,IMG-400,Lime,VersaCoat HF,VersaWet,Ecotrol RD,Calcium Chloride,M-I Wate, Truvis. Solids Control TBD Potential Problems Running gravel,unconsolidated sand,and clay.Unforeseen formation pressures,Hole Cleaning, Lost Circulation,Water intrusion from the formation. MUD PROPERTIES at 20 HTHP Fluid Depth MD Mud Wt. Loss Oil/Water (ft) (ppg) Funnel Viscosity PV LSYP (ml/30min) Ratio 1,800' 7.5 + 45-70 20-30 10- 12 <5 70/30 NOTE: This program is provided as a guide only.Well conditions will always dictate fluid properties and product additions required for well-bore integrity. VersaPro Formulation 7.7 ppg(O/W Ratio 70/30): LVT 200 .695 bbls Truvis 5.0—7.0 ppb Lime 2 ppb VersaCoat HF 5 ppb VersaWet 2 ppb Ecotrol RD (Dependent on fluid loss) Water 0.18 bbls/bbl Calcium Chloride(95%) 21.7 ppb M-I Wate As needed for Density Version 1.0 Confidential Page 4 of 12 EIMIi ais v•p • A Std Canpagl Surface Interval Drilling Concerns: ➢ Unforeseen Surface Gas—Gas hydrates may be encountered,take the proper precautions for such an occurrence. ➢ Hole Cleaning—Gravel sizes that are larger than normal can contribute to poor hole cleaning. Ifs encountered increase viscosity to assist with good hole cleaning. ➢ Washing out conductor shoe—Maintain low flow rates for the initial 200' of drilling to reduce the risk of washing out the conductor shoe. Surface Interval Fluid Operations: 1. Read all MSDS's on products that will be used throughout the surface interval. Have Drilling Fluids Specialist that's onsite give an interdiction to drilling with an oil base mud with all the crews. 2. Ensure that all the rigs valves and seals are compatible with oil base drilling fluid. 3. Confirm that all rig pits and surface lines have been cleaned and blown down to prevent any contamination to the new oil base mud system. 4. Transferring base fluid from the storage tanks to the Rig—Before transferring any fluid from the storage tank uprights to the rig's pits ensure that a fluid transfer permit is filled out and all the proper precautions are in place before any transfers are made.After the fluid transfer is made confirm that the proper amount of fluid was transferred by strapping the storage tanks. The volume used will need to be tracked on a daily basis and recorded. 5. Build the initial surface volume in accordance with the VersaClean formula. Adjust rheology as necessary to target a LSYP of 10 for good hole cleaning. 6. If Ecotrol RD is added to the active do not over treat. Over treating a system with Ecotrol RD can increase drilling fluid viscosity. 7. While running in to drill out the conductor shoe you can expect ice and cement,normally these are contaminants of drilling fluid but while drilling with an OBM there won't be any issues. 8. Keep drill solids as low as possible by running available surface equipment equipped with the recommended screen sizes,screen up when the hole allows. 9. Always monitor volumes closely, if losses are seen consult the Company Representative, Driller and Drilling Engineer and reference the fluid loss decision tree. 10. Capture the drilling fluid temperature,amount of drilling fluid loss, and the results of any sweeps pumped in M-I SWACOS ONE-TRAX Reporting system. 11. Monitor the Modified HTHP using 5 micron alloxite disks at 185°F while drilling. Maintain below 6.0 cc/30 min and<1.0 cc spurt loss. Adjust the fluid loss as needed with additions of ECOTROL RD if needed. 12. Upon reaching TD watch the bottoms-up cuttings closely. If the well does not readily clean up or if there are any excess of torque, drag, pick-up or slack-off weights pump a high viscosity /weighted sweep and observe bottoms up again to confirm the wellbore is clean Continue pumping while rotating and reciprocating until the wellbore is clean. Version 1.0 Confidential Page 5 of 12 MI SV1/AC ASO,lumbaoaCompany '" CONHDENTJAL 13. Do not lower YP before running 7-5/8 casing. After casing is landed lower YP per Schlumbergerr. Cementers and conduct cement job. 14. Note the volumes of cement pumped along with the amount of fluid pumped to bump the plug in MI SWACO's reporting system. 15. After cementing clean pits, flush lines and start building the new VersaPro system in preparation for drilling the next interval. Version 1.0 Confidential Page 6 of 12 SiArAlla A Schlumberpr Company • Production Interval: 6.75" Hole, 1,800'-3,550' MD, 1,288' TVD The Production interval will be drilled with a 6.75"bit with a VersaPro drilling fluids system at a 90 degree angle. Pipe rotation and pump rate will be important to achieve good hole cleaning. The VersaPro system will start out unweighted, if the density needs to be increased while drilling ahead S-200 will be the weighting agent. 23H will be completed with a 4.5" slotted liner, if any LCM needs to be added consult the company representative for approval. Its recommended that no reservoir damaging products are used. rte'. Production Interval: 6.75" Hole, 1,800' —3,550' MD Drilling Fluid System VersaPro Key Products LVT-200,Truvis,Lime,VersaCoat HF,VersaWet,Ecotrol RD,Calcium Chloride,SafeCarb. Solids Control TBD Potential Problems Running gravel,unconsolidated sand,and clay.Unforeseen formation pressures,Hole Cleaning, Lost Circulation,Water intrusion from the formation. MUD PROPERTIES HTHP Fluid Depth MD Mud Wt. Loss Oil/Water (ft) (ppg) Funnel Viscosity PV LSYP (ml/30min) Ratio 1,800'to 3,550' 7.5 + 45-70 20-30 7- 10 <5.0 70/30 4 VersaPro Formulation 8.8 ppg(0/W Ratio 70/30): LVT 200 .695 bbls Truvis 4.0—6.0 ppb Lime 2 ppb VersaCoat HF 5 ppb VersaWet 2 ppb Ecotrol RD (Dependent on fluid loss) Water 0.18 bbls/bbl Calcium Chloride(95%) 21.7 ppb S-200 As needed Version 1.0 Confidential Page 7 of 12 ivu svurac�►_ � � COh A Schlumberger Company Production Interval Drilling Concerns: ➢ Hole Instability—While drilling through shales take notice of the cuttings size and shape to ensure that there are no hole instability issues or indications of break out i.e. large angled calvings. ➢ Lost Circulation—Monitor fluid volumes to detect any early signs of lost circulation,if lost circulation is encountered treat appropriately. ➢ Surge and Swab—Surge and Swab can increase the potential for wellbore instability, use proper drilling and tripping practices to try and mitigate this risk. Production Interval Fluid Operations: 1. Once again confirm that all MSDS's on products that will be used throughout the surface interval have been reviewed. Have Drilling Fluids Specialist that's onsite give an interdiction to drilling with an oil base mud with all the crews. 2. Confirm that all rig pits and surface lines have been cleaned and blown down to prevent any contamination to the new oil base mud system. 3. Transferring base fluid from the storage tanks to the Rig—Before transferring any fluid from the storage tank uprights to the rig's pits ensure that a fluid transfer permit is filled out and all the proper precautions are in place before any transfers are made.After the fluid transfer is made confirm that the proper amount of fluid was transferred by strapping the storage tanks. The volume used will need to be tracked on a daily basis and recorded. 4. If Ecotrol RD is added to the active do not over treat. Over treating a system with Ecotrol RD can increase drilling fluid viscosity. 5. After bringing fluid from the uprights into the pits, adjust rheology as necessary to target the LSYP at 7 - 10 for good hole cleaning and suspension properties. 6. Monitor the HTHP(@165°F)&keep below 8.0 cc/30 min(using paper).Also run a Modified HTHP using a 5 micron alloxite disc, keeping fluid loss below 10.0 cc and spurt loss below 2.0 cc. 7. If weighing up the drilling fluid is required use S-200 to increase density. 8. If the mud weight needs to be increased past 11.5 ppg due to unforeseen hydrocarbons or pressures, barite sag could become an issue. (Barite sag is a reduction in the MW out due to the dynamic and static settling of barite) If the mud density is weighed up past 11.5 ppg avoid low pump rates and low drill string rotation. Make sure and run the VSST barite sag test. 9. Keep drill solids as low as possible by running available surface equipment equipped with the recommended screen sizes, start with 230's or 270's and screen up when possible. 10. If losses are seen,stopping losses needs to be the first priority. Monitor the severity and act appropriately, consult the LINC company rep before pumping any LCM. It's recommended that no LCM is pumped down hole that could potentially damage the formation. A Well Commander circulating sub will be ran on the BHA to accommodate any lost circulation material that needs to be pumped down hole to stop losses. 11. Capture the results of any sweeps pumped in M-I SWACOS ONE-TRAX Reporting system. Version 1.0 Confidential Page 8 of 12 MI AfeMraMrer Conway 12. Upon reaching TD watch the bottoms-up cuttings closely. Circulate 3 bottoms up, pump a high '' viscosity /weighted sweep with max rpm and pump rate. At this time the BHA will be laid out at 90 '. degrees so rotation and pump rate will be essential to cleaning the hole. Ensure that the hole is clean and stable before pulling out of hole 13. No pre-treatment of drilling fluid will be necessary to bump the plug after pumping cement. Keep track of all losses and the amount of fluid required to bump the plug. 14. After cementing has commenced displace the well with a 20 bbl high viscosity spacer followed by LVT 200. Be prepared to over circulate to ensure that the completion fluid is clean. Version 1.0 Confidential Page 9 of 12 nlli SINACJ'a- - • A Schlurdte'get Con+D•�V CONFIDENTI , a:-<..,.. ::;; Lost Circulation Decision Tree — Production Interval Losing fluid while drilling Measure rate of loss - • 1 1 1 Seepage losses<20 bbl/hr Partial losses 20-60 Severe losses 60— bbl/hr 200 bbl/hr or total V V If fault related drill across If fault related drill across If fault related drill across fault 1-1.5 roee t length of theethhroww before 1-1.5length times the len th fault 1-1.5 times the treating losses of the throw before treating length of the throw before 1 high-fluid-loss pill: Spot 40 ppb pill*: Spot 80 ppb pill: Note—Pill should be a Adding to active minimum oft 5 itmes the SAFECARB 20 12 SAFECARB 40 5ppb 3-5 ppb SAFECARB � length of thief zone SAFECARB 40 12 40 can be added to SAFECARB 250 5 ppb ppb No sAFECARB soo 3o ppb NO FORM-A-BLOK NUT PLUG F 8 the active while success success drilling to help ppb reduce seepage losses. No 1 Spot plug: FORM-A-SET AK or Reverse Gunk Squeeze Version 1.0 Confidential Page 10 of 12 Mi SWAiCC • 1 1. A SchIurlberper Co11Venr Health, Safety&Environmental Drilling crews should be instructed in the proper procedures for handling fluid products. P. Personal Protective Equipment (PPE) charts should be posted in the pit room, the mud lab, & the office of the Drilling Forman. P PPE must be in good working order & be utilized as recommended by the PPE charts. Ensure a good stock of PPE is available prior to starting the well. Product additions should be made with the intent to use the complete unit amounts of products (sacks, drums, cans), as much as possible in order to minimize inventory of partial units. Ensure all MSDS sheets are up to date and readily available for workers to access for information. Review MSDS's regularly before completing tasks. P. Ensure that all product stored outside is protected from the weather. P Do not store partial units (sacks) outside if possible. • Ensure that all liquid products are stored with the correct secondary containment.,: • When transferring fluids &/or cuttings from the rig to tanks, insure all hoses are properly secured and clear of any Ice that could be plugging them. Ensure that all fluid transfer forms have been completed in order to avoid spills. Do not use aluminum cam lock fittings when transferring brine or brine base mud. Confirm that all drilling wastes are properly documented & manifested as per the Alaska Waste Disposal & Reuse Guide (Red Book). Any questions about drilling wastes should be directed to LINC Energy's company representative. Version 1.0 Confidential Page 11 of 12 Mi SV1�A • • 1 A sCnm,lberrif -- - � • /QNciEN7/AL •', 4 Oil Base Mud - Product Health and Safety Reference HMIS HAZARD RATINGS • Product Function Health Flammability Reactivity PPE, ALPINE DRILL BEADS Torque Reducer 1* 1 0 E CALCIUM CHLORIDE Weighting Agent 1* 1 0 E CITRIC ACID pH Modifier 1 0 0 E ECOTROL RD Fluid Loss Reducer 1* 1 0 E EMI-1760 Weighting Agent 1* 0 0 E FORM-A-SQUEEZE Lost Circulation Material 1 1 0 E G-SEAL Lost Circulation Material 1 1 0 E _", HRP Viscosifier 2 1 0 J LIME Alkalinity 2 0 0 E LUBE 776 Lubricant 1 1 0 J LVT-200 Base Fluid 1 1 0 E M-I WATE Weighting Agent 1* 0 0 E M-I SEAL Lost Circulation Material 1* 1 0 E MIX II F, M, C Lost Circulation Material 1* 1 0 E PECAN NUT PLUG Lost Circulation Material 1* 1 0 E SACK BLACK Filtration Control 2 1 0 E SAFECARB ALL Bridging Agent 1* 1 0 E SAFE-SURF 0 II Displacement Surfactant 2 2 0 J SOLTEX Shale Inhibitor 3 1 0 J TRUVIS Viscosifier 1* 1 0 E ,. VERSACOAT HF Wetting Agent/Emulsifier 1 2 0 E VERSATHIN HF Rheological Modifer 1 2 0 J VERSATROL Wellbore Stabilizer/Fluid 2 1 0 E VERSAWET Emulsifier/Wetting Agent 1 1 0 E HMIS PERSONAL PROTECTIVE EQUIPMENT INDEX A-Safety Glasses B-Safety Glasses, Gloves C-Safety Glasses,Gloves, Synthetic Apron D- Face Shield, Gloves, Synthetic Apron E-Safety Glasses,Gloves, Dust Respirator F-Safety Glasses,Gloves, Synthetic Apron, Dust Respirator G -Safety Glasses, Gloves, Vapor Respirator H -Splash Goggles, Gloves, Synthetic Apron, Vapor Respirator I-Safety Glasses,Gloves, Dust and Vapor Respirator 3 -Splash Goggles, Gloves, Synthetic Apron, Dust and Vapor Respirator K-Air Line Hood or Mask, Gloves, Full Suit, Boots X-Consult your supervisor for special handling directions Version 1.0 Confidential Page 12 of 12 • • +rit cmnrL1 w , 0 I I I I Tr o; ; W J z < Z J U CI. < LnI M i I . 0 M C opo p i v a, •-00.o = — � I3 CC \ O V _. ", - \ \ N N t 0. .-I it E Tr Tr N i4 o c cU 3 32 CCO IA I I -_ N v An w m E 'N I: N •—.. v' � I F— U CO W -o I I in •— c0 E = o . \ m al 0 aD. N \ i i . 0 __________, in Icn immiJ 0 0 0 0 0 0 0 0 O� in N N Nein n M in Cl (laaj) yidaa • COVIntAI iaLly TIAL li nC Umiat #23H EIIERGY PTD No. TBD Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) Well Information Max Bottom Hole Pressure 469 psi 0.364 psi/ft x 1,288' TVD Max Surface Pressure 340 psi 469 psi—0.1 psi/ft Shallow Gas Zones 1,197' TVD Gas in Grandstand Reservoir Drilling Hazards 9-7/8" Hole/ 7-5/8" Casing(Surface) Event Risk Level Mitigation Strategy Gas hydrates Low Control drill, reduce pump rates, reduce drilling fluid temperatures, add Lecithin Clay balling Medium Maintain planned mud parameters and flow rates, increase mud weight, weighted sweeps, reduce fluid viscosity, control ROP Abnormal pressure in Low BOPE drills, increased mud surface formations weight Broach of Conductor Low Monitor cellar continuously during interval. Directional Control High BHA Design, Mud Motor for high build, LWD Hole swabbing/tight hole on Low Circulate hole clean prior to trips trip. Proper hole fill (use of trip sheets), pumping out of hole as needed. Lost Circulation High Prevent by keeping hole clean. If loses occur— reduce pump rates and mud rheology, use LCM Gravel/Sand Sloughing Medium Increase mud weight/viscosity, pump high viscosity sweeps. Monitor fill on connections. Possible Thaw Bulb/Water Low Watch return viscosity for Flow signs of thinning. Increased mud weight/viscosity as needed. • • CONFIDE7Jj, 6-3/4" Hole/4-1/2" Liner(Production) Event Risk Level Mitigation Strategy Gas hydrates Low Control drill, reduce pump rates, reduce drilling fluid temperatures, add Lecithin Clay balling Medium Maintain planned mud parameters and flow rates, increase mud weight, weighted sweeps, reduce fluid viscosity, control ROP, Kla-Shield Mud Abnormal Reservoir High Well control drills, check Pressure for flow during connections, increased mud weight, contingent weight material Sticking BHA in Coals Low Control drill through coals. Frequent reaming and trips through coals until sticking tendency abates. Hole swabbing on trips Medium Reduced trip speeds, mud properties, proper hole filling,pumping out of hole, real time ECD monitoring, use weighted sweeps Lost circulation High Reduced pump rates, reduced trip speeds, real time ECD monitoring,mud rheology, lost circulation material Sloughing shale, Tight hole High Increased mud weight, controlled connection and trip speeds, sweeps, and real time equivalent circulating density(ECD)monitoring Directional Control High BHA Design, Rotary Steerable, Periscope Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers • • COAFTEpr , i f'': 4 ij, L CO d NO in -I 01 c N O O) 0 L t4.1 8 N C 0 ao C _� N a, C L N ` y. 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I .1459.741 !,.. irl ,--: QTEST PORT - ----- 10 LOCKDOWN SCREWS II-5000 18-541 Nil le �� 'i, 'N' —2 I/16-5000 MOO 120 GV • 22.75 ii i ... (577.55) III; i �• `-, i 4, O i i 9.15 .� ii I (232.41) Z bIlli Eli t� 0 IIi II7EI4 PART NUMBER If DESCRIPTION 1 13 3/8 CO CASING I P164819 CASING HEAD ASSEMBLY 2 13-300-718 GEN 5 TUBING HEAD ASSEMBLY 3 P166043 7 5/8 CASING HANGER 7 5/8 0D CASING 4 12-150-017 7 5/8 RACKOFF ASSEMBLY 5 P156963 TUBING HANGER ASSEMBLY I 6 02-047-619 TUBING HEAD ADAPTER ASSEMBLY 7 P118334-0005 BELL NIPPLE 1 4 1/2 00 CASING 8 12-093-113 7 5/8 C-21 CASING HANGER 1 LL O ALASKA QUOTE FXXXXX -- REF:DM100042348 0012DMI080698 O PRIVATE AND CONFIDENTIAL I REVISIONS DESCRIPTIONCD THIS 00c0140 AND NC TRE IxfswAKIN COeTARO KRIM ARE NI d 02-26-13 004,0ENTIA:AM EXCIUSiH PROVER',N RUC IEpWOEBGES AND NAY NOT 01 11,4 RCREPRODUCED,USED.OIsPA.M.,' nauR.MxARE PUBIC B4 ANY LIMWR PRIOR TO B02-27-13 SURFACE WELLHEAD LAYOUT, 0226-13alIFINIC Technologies OMEN AOMORI/ATI.BY fur IECNbl04',ES 111,OONRA ,NT Is — RECIPICxT P;NKUAx11O ACEENEN11O Tit MELDING,AND GENERATION 5 WELLHEAD, '""°`•�� MT RE AEI..WOK UN.. Z.MARQUEZ 02-26-13 VAMSACILINRA ES MAT MIMES M.IN ACCORDANCE BM EMS 5000 COMPLETION. „N ram. n Au RE CONSIDERED fur TEC.P.00ZES OES1DN AND 1101 S _ EASTERWD00 02-26-13 806*xc 01108010 IDENTICAL ARTICLES M PARIS 1NREOT SW.NOT BE NANI.CTM(0 R. AI BXNNDR.CTO.MANYMR PERSON DMI00156406 xITrouT THC PRIM EXPRESS BRITTEN ANTNDNI2ATIM BY FRC IECNwEarcs R-HAMILTON 02-26-13 l cowcIENrIAI. Choke Manifold Valves 2 " To Shaker 3" Panic To Gasbuster 3 1/8" Tt-2 1/16" - - O 2 1/16" • ip < � 21/1 2 1/16" 31/8" 8 Leoloi a 4D 21/16" diA 2 1/16" Manual Choke 1 Automatic Choke 2 1/16" Inlet Pressure Sensor 3" 5,000 PSI Choke Manifold Kuukpik Drilling Rig 5 RED = 3 1/18" 5,000 PSI VALVES AND LINES BLUE = 2 1/16" 5,000 PSI VALVES Kuukpik Drilling Rig 5 Choke Manifold Drawn By: L Ross Date: 8/1/04 C-2 #11 #10 • #16 #5 #4 -., #15 M- _ ,, 9rw �� � Kuukpik Drilling Rig 5 Choke Manifold • UMIAT#23H CONFIDENTIA!CoRod BOPE Diagram I I 2-9/16" Upper Annular 2-9/16" Lower Annular 1 I 3-1/8"Rod Ram I I X-Over 4-1/16"x 3-1/16" -------10. 3" To Choke and Manual Kill Lines Flanged = Pump-In-MS � [06Sub � 4-1/16" Gate Valves prIppror, 4-1/16"Radigan Spool C 11" Wellhead 0.0'=Ice Pad Level 5M 417 0.0'=Top of Cellar 111. -6.0'=Bottom Ice Pad 13-3/8"Conductor Casing irl -10.0'=Base of Cellar • • CONrLENTIAl >1% Q s_ an O 4- .— '0_ s. a) CO N a) V c C = M o cl c N I O ea }a U fa 0— V1 'cu — E to o 0 s a) 13 VI o CO o. ca *, c u W •_ el-+ E O a5 • • CONFIDENTIAL . ,,, 4_, c (1.) 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U c 0 cn a ca I— +-, Ca 0- N I— hA co F- co 0- Q E • • Page 1 of 2 • • Schwartz, Guy L (DOA) From: Stan Porhola [stan.porhola@lincenergy.com] Sent: Tuesday, February 19, 2013 4:44 PM To: Schwartz, Guy L (DOA) Subject: RE: BOPE rams for Umiat#23H (PTD 213-020) Guy, Answers to your comments and questions: 1.) Step 4 should be 4" rams. We had a previous version where we looked at using 4.5" drillpipe, but we will only be using 4" drillpipe in Umiat. 2.) 7-5/8" casing rams will be used when running surface casing. 3.) X-overs with an FOSV will be on the rig floor when running casing. 4.) If required by BLM, we will install a similar bermed area opposite the blooie line on the edge of the Umiat#23H ice pad. Stan Stan Porhola 10 Drilling and Completions Engineer P +1 907 375 2615 M +1 907.280.8492 E stan.porhola@lincenergy.com IDC 3000 "C" Street, Suite #103 Anchorage AK 99503 EfERGY United States P +1 907 868 8660 sVWW Ilncenergy.com F +1 907 868 8881 Disclaimer Notice: The message and attachment(s) contained in this e-mail are intended for the named recipient(s) only. It may contain privileged or confidential information or information which is exempt from disclosure under the applicable laws. If you are not the intended recipient, you must not read, print, retain, copy, distribute, forward or take any action in reliance on it or its attachment(s). If you have received or have been forwarded this e-mail in error, please notify us immediately by return e-mail or e-mail linc@lincenergy.com and delete this message from the computer in its entirety. Internet communications cannot be guaranteed to be secure and error-free as the information could be intercepted, corrupted, lost, arrive late or contain viruses. The sender and this Company therefore do not accept any liability or responsibility of whatsoever nature in the context of this message and its attachment(s) which arises as a result of Internet transmission. Opinions, conclusions, representations, views and such other information in this message that do not relate to the official business of this Company shall be understood as neither given nor endorsed by it. From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, February 19, 2013 4:17 PM To: Stan Porhola Subject: BOPE rams for Umiat #23H (PTD 213-020) Stan, I have a few comments and questions regarding PTD for Umiat 23H : 1. In step 4 you mention installing 4.5" rams. Do you mean 4" rams instead for your drillpipe? 2. You do not mention installing rams in the remaining BOP ram ( 3 rams stack+ annular) ... planning on 7 5/8" ram for running the surface casing?. 3. Need X-overs with FOSV on rig floor when running 4 '/2" liner or 7 5/8" casing. 2/20/2013 Page 2 of 2 • • 4. As we discussed what will you do with the Panic line as far as berming if required by BLM.? Is there any change to the panic line set up and location due to berming? I see it on the rig map layout you provided. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 2/20/2013 • • 6-16 2. 3g 5/ 5 z13- oZo Guy, The Umiat#18 well will drill the surface hole using a Diverter. Based on the offset Navy wells drilled in Umiat, primary well control should be attained with our planned mud weight of 7.5 ppg across the sub-normally pressured shallow oil sands down to the Lower Grandstand. As an extra precaution,the mud weights will be increased as we enter the Torok formations and raised to a maximum 9.0 ppg. The use of the diverter should provide adequate secondary well control since the offset Umiat wells drilled by the Navy showed the Lower Grandstand (Hydrocarbon bearing zone)to be a sub- normally pressured reservoir.The Navy was even able to use Cable Tool Rigs that did not use a full column of fluid to surface while drilling these wells. No shallow sands below the Lower Grandstand encountered any shallow abnormally-pressured gas or oil in the Torok.The shallowest gas zone noted was in the Torok in the Seabee#1 (PTD 100-223) at 2,652' MD/TVD. In the event of a well control incident while the diverter is installed, the plan will be to close the diverter and evacuate the rigsite.The BLM has requested a bermed area at the end of the pad where the diverter outlet is facing. However, due to the sub-normally pressured Lower Grandstand reservoir,this scenario is extremely unlikely. The Umiat#23H well will drill the surface hole using a BOPE.This is being done in place of running a diverter due to the wellhead configuration not being able to accommodate the diverter and the fact that both the surface and production hole will be drilled in the target reservoir. In the event of a well control incident while the BOPE is installed on the surface hole,the plan will be to close the annular preventer and direct flow through the choke manifold and out the rig blooie line. A hard shut-in if there is pressure would likely cause a failure at the conductor casing shoe (estimated LOT EMW is 10.6 ppg). Due to the sub-normally pressured Lower Grandstand reservoir, this scenario is extremely unlikely.At the request of the BLM,we will be testing the BOPE on Umiat#23H to 1,500 psi (minimum pressure required for Exploratory wells per Onshore Order#2)with a test plug at the base of the wellhead to isolate the conductor casing shoe. Stan Stan Porhola ip ' • • an. ompleti•ns Engineer STATE OF ALASKA VCD ALA OIL AND GAS CONSERVATION COMMON Py PERMIT TO DRILL 20 AAC 25.005 1a.Type of Work: 1b.Proposed Well Class: Development-Oil ❑ Service- Winj ❑ Single Zone ❑✓ lc.Specify if well is proposed for: Drill 0 Lateral ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry ❑ Exploratory Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 0 Single Well ❑ 11.Well Name and Number: Linc Energy Operations,Inc. Bond No. 9244998424 Umiat#23H 3.Address: 6. Proposed Depth: 12. Field/Pool(s): 3000 C Street,Suite 103,Anchorage,AK 99503 MD: TVD: 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): Exploratory(Umiat) Surface: 1,032'FSL,1,254'FWL,Sec 32-T1N-R1W,U.M. FEDAA84141 Top of Productive Horizon: 8. Land Use Permit: 13.Approximate Spud Date: N/A 3/15/2013 Total Depth: 9.Acres in Property: 14. Distance to Nearest Property: 11,500.00 acres 1,025' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10. KB Elevation above MSL: 598 feet 15. Distance to Nearest Well Open Surface: x-732,474 y-5,631,271 Zone-5 GL Elevation above MSL: 575 feet to Same Pool: N/A 16.Deviated wells: Kickoff depth: feet 17. Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: degrees Downhole: Surface: 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect. Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat 0 BOP Sketch 0 Drilling Program 0 Time v.Depth Plot ❑✓ Shallow Hazard Analysis❑✓ Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Stan Porhola Contact stan.porhola(c�lincenerclv.com Email Printed Name Corri Feige Title General Manager-Alaska 42/ Signature (� Phone (907)868-8660 Date jk/R Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: 50- Date: requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: ❑ Other: Samples req'd: Yes ❑ No❑ Mud log req'd:Yes❑ No0 H2S measures: Yes ❑ No❑ Directional svy req'd:Yes❑ No❑ Spacing exception req'd: Yes ❑ No❑ Inclination-only svy req'd:Yes❑ No❑ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Submit Form and Form 10-401(Revised 10/2012) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate e , III • _ ,i _ ne « .f (flERGY Linc Energy Operations, Inc. 3000 "C" Street, Suite#103 Anchorage, Alaska 99503 February 21, 2013 Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Application for Permit to Drill (Variance Request) Well: Umiat#23H (Exploratory Oil Well) TRS: SWSW, T1 N, R1 W, Section 32, Umiat Meridian Dear Chairman Foerster, Linc Energy Operations, Inc. applied for a Permit to Drill (PTD) for an onshore Exploratory Oil well on an ice pad in Umiat. The well will be drilled on BLM land under the authority of a current Oil & Gas (O&G) Exploration Lease (BLM Lease AA-084141) held by Renaissance Umiat, LLC. Linc requests the following variance request for this well: 1.) Variance to the requirements of 20 AAC 25.265(cx1) addressing Well Safety Valve System requirements to have the surface safety valve located within the vertical run of a well's tree. The PCP artificial lift pump installed will include a rod string inside the tubing that would preclude the surface safety valve from closing. Instead, the surface safety valve will be located off of the wing valve along the flowline, installed during the well testing and removed when the well is shut-in. The following are Linc Energy designated contacts for reporting responsibilities to the AOGCC: 1) Drilling and Completions Stan Porhola, Drilling and Completions Engineer (907) 868-8660 2) Geologic Data and Logs Dave Whitacre, Project Manager (907) 868-8660 • • The AOGCC is requested to treat as confidential all information in the Permit to Drill (except the Public Information Copy) as information in these documents is drawn from research and data proprietary to Linc. If you have any questions or require further information, please contact either Com Feige, General Manager — Alaska at (907.868.8660) or Nick Scales, Drilling Operations Manager at(907.868.8660). Sincerely, I r Corr' A. Feige General Manager-Alaska 5 • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. O 411) TRANSMITTAL LETTER CHECKLIST WELL NAME (J1 i.i ,Z11 PTD# .21-3c4,0 Development Service /Exploratory Stratigraphic Test Non-Conventional Well FIELD: POOL: Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue.to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name)must contact the Commission to obtain advance approval of such water well testing program. 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(n v 0 c.) c) Q Q o m m v � N 2 a 0 U) cn 0 M LLI n W O)E � NMV � Mr � CnO r N� O O N N MN N (No (N N- W NC,) MO M U N M V Lo (M M coM I- OU co coco ' i� O O a a) O csj CCO O N 0 U 0: O O o Vp) 0 (N 0 _ O VN) LLI Mo Es N C N N 55 E *4 N C N a) co) O 0`i' Q C ' 0 .? IIv O. a C Q O a) a 0 as a W a Q c9 a +w► • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically • organize this category of information. FINAL WELL REPORT MUDLOGGING DATA Umiat #23H Provided by: Approved by: Compiled by: Eric Andrews Michael Strawn Distribution: 4/21/2014 T.D. Date: 3/10/2014 Umiat #23H 1 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ................................................................................................ 2 1.1 Equipment Summary ...................................................................................................................... 2 1.2 Crew................................................................................................................................................ 2 2 WELL DETAILS ..................................................................................................................................... 3 2.1 Well Summary................................................................................................................................. 3 2.2 Hole Data ........................................................................................................................................ 3 2.3 Daily Activity Summary ................................................................................................................... 4 3 GEOLOGICAL DATA ............................................................................................................................. 6 3.1 Lithostratigraphy ............................................................................................................................. 6 3.2 Mudlog Summary ............................................................................................................................ 7 3.3 Connection Gases ........................................................................................................................ 11 3.4 Sampling Program / Sample Dispatch .......................................................................................... 13 3.5 Trip Gases .................................................................................................................................... 15 4 PRESSURE / FORMATION STRENGTH DATA ................................................................................. 16 4.1 Pore pressure evaluation ................................................................................................................... 16 5 DRILLING DATA .................................................................................................................................. 17 5.1 Survey Data .................................................................................................................................. 17 5.2 Bit Record ..................................................................................................................................... 19 6 SHOW REPORTS ............................................................................................................................... 23 7 DAILY REPORTS ................................................................................................................................ 24 Enclosures: 2”/100’ Formation Log (MD/TVD) 2”/100’ LWD Combo Log (MD/TVD) 2”/100’ Gas Ratio Log (MD/TVD) 2”/100’ Drilling Dynamics Log (MD/TVD) Final Digital Well Data on CD/ROM Umiat #23H 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 Effective Circulating Density (ECD) From MI SWACO 70’ to TD 0 Hook Load / Weight on bit Pason WITS Feed 0 Mud Flow In Derived from Strokes/Minute and Pump Output 0 Mud Flow Out Pason WITS Feed 0 Mudlogging unit computer system Intel(R)Core(TM)2 Duo CPU 0 Mudlogging unit DAC box In-unit data collection/distribution center 0 Pit Volumes, Pit Gain/Loss Pason WITS Feed 0 Pump Pressure Pason WITS Feed 0 Pump stroke counters Pason WITS Feed 0 Pason Well Monitoring Components Pason computer networked in Mudlogging Unit 0 Rate of penetration Pason WITS Feed 0 RPM Pason WITS Feed 0 Torque Pason WITS Feed 0 1.2 Crew Unit Type : Steel Arctic Unit Number : ML067 Mudloggers Years *1 Days *2 Sample Catchers Years Days Technician Days Eric Andrews 2 30 Dickey Hudgins 3 27 Travis Smith 4 Michael Strawn 7 30 Dylan Muller 2 27 *1 Years experience as Mudlogger *2 Days at wellsite between spud and total depth of well Umiat #23H 3 2 WELL DETAILS 2.1 Well Summary Well: 23H API Index #: 50-287-20029-00-00 Field: Umiat Exploration Surface Co-Ordinates: 1031’ FSL, 4026’ FEL, Sec. 32, T1N, R1W, (UM) Borough: North Slope Primary Target Depth: Lower Grandstand 4100’ MD /986’TVD/ TVD SS -388’ State: Alaska TD Depth: 4100’ MD/986’ TVD Rig Name / Type: Kuukpik 5, Arctic Double Suspension Date: Primary Target: Lower Grandstand License: AA-084141 Spud Date: 2/15/2014 Ground Elevation: 562’ MSL Completion Date: 3-10-2014 RT Elevation: 598’ MSL Completion Status: Ran 4.5” Liner to TD. Secondary Target: Depth: Classification: Exploration TD Date: 3-10-2014 TD Formation: Lower Grandstand Days Testing: None Days Drilling: 24 2.2 Hole Data Hole Section Maximum Depth TD Formation Mud Weight (ppg) Dev. (oinc) Coring Casing/ Liner Shoe Depth LOT (ppg) MD (ft) TVDS S (ft) MD (ft) TVDSS (ft) 9.875” 1980’ 1260’ Base Lower Grandstand 8 93.66 None 7.625” 1968’ 1260’ 11.0 6.75” 4100’ 986’ Top Lower Grandstand 7.8 90.00 None 4.5” Additional Comments The Linc Energy drill project of well Umiat#23H in the Umiat Field was spud by tagging an ice plug at 43’ and drilling ahead with a 9.875” bit to 300’ where the mud system was circulated to clean the hole. At this point pulling out of the hole to lay down BHA #1 and picking up BHA #2 re-ran back in hole with the original bit, RR Bit #1. The drilling resumed through the surface section and the base of the Perma-Frost, TD at the intermediate casing point at 1980’ within the Lower Grandstand. Samples were taken at 30 ft intervals to 310’ and 10 ft samples were taken from 310’ to 1710’ MD/1266’ TVD. Samples from Canrig consisted of two wet and three dry taken in 30 ft intervals to the bottom of the pilot hole at 4100 ft MD/986 ft TVD in the Middle Grandstand. Umiat #23H 4 2.3 Daily Activity Summary 2/15/2014: Held Spud meeting. Drilled out cement to the bottom of the well conductor at 70’. 2/16/2014: Fill damper with nitrogen, test surface lines, drilling ahead from 97’ to 330’MD, circulate and condition mud and monitor well, pull out of hole reaming tight spots, trip in hole, clean and circulate, pull out of hole to make up new BHA. 2/17/2014: Pick up BHA, make up MWD tools, trip in hole, drill ahead from 330’ to 381’MD, change fuel filters on generators, start to pull 1 stand observed 10K over pull, circulate and rotate, packed off unable to get returns or rotate, make up fishing jars and jarred 10 times with no gain, try to work pipe free. 2/18/2014: Working stuck pipe without success, cut and slip drill line, rig up tongs, break down jars, service rig, Shut down HPU to fix leak. 2/19/2014: Adjust draw works cam, install shaker screen gaskets, build fork pockets for jacking rams, repair shaker jack pump, repair filter hose on #2 HPU, rig up lines to water pump for cement jobs, move radioactive source box to floor, monitor well. 2/20/2014: Monitor well waiting and warming on wireline unit, rig up wireline fishing tools, fishing nuclear source from hole, rig down Halliburton wireline, rig up for fishing BHA, fishing for BHA. 2/21/2014: Fishing pipe free and establish circulation, circulate and wash, back ream tight spot 310’ to 300’, lay down BHA and fishing tools, service and inspect rig, cut and slip drill line, make up BHA. 2/22/2014: Pick up BHA and trip in hole, drill ahead from 382’ to 398’, change elevators, drill ahead from 398’ to 583’ sliding to build angle, replace coupler on #2 HPU, slide drill ahead from 583’ to 706’MD. 2/23/2014: Drilling ahead sliding as needed to build angle from 706’ to 997’MD, back ream from 997’ to 957’MD, slide drilling from 997’ to 1025’MD, condition mud and circulate bottoms up. 2/24/2014: Pull out of hole and lay down BHA#3, pick up BHA#4 and trip in hole, drilling ahead sliding as needed from 1025’ to 1287’ at report time. 2/25/2014: Drilling ahead sliding to build angle from 1287’ to 1390’MD, pull out of hole from 1350’ to 1050’ stand back drill pipe and run in hole with heavy weight drill pipe, drill ahead sliding as needed from 1350’ to 1480’MD. 2/26/2014: Drilling ahead sliding to build angle from 1480’ to 1498’MD, change out liner and swab on mud pump 2, drill ahead sliding as needed to build angle from 1498’ to 1712’MD. 2/27/2014: Drilling ahead sliding as needed to build angle from 1712’ to 1787’MD, repair mud pump 2, drill ahead sliding as needed to build angle from 1787’ to 1926’MD. 2/28/2014: Drilling ahead sliding as needed to build angle from 1926’ to 1980’MD, circulate bottoms up, back ream 1980’ to 850’MD, pull out of hole and lay down BHA, service rig and replace rotation sensor damaged while jarring on 2/17/2014, start rig up tongs. 3/1/2014: Pick up BHA#5, trip in hole to 373’ and test MWD tools, trip in hole to 1980’MD, pull out of hole logging and lay down BHA. Umiat #23H 5 3/2/2014: Lay down BHA, clean and service rig, rig up to run 7.625” casing, pick up and test float equipment, run in hole with 7.625” casing to 1480’MD, establish circulation and continue to run in hole to set casing @ 1968’MD, circulate and condition mud. 3/3/2014: Circulate and condition mud, pressure test lines, cement, displace cement, pressure up to 1500 psi for 15 min. and bleed off pressure (floats holding), blow down lines and rig down circulation equipment, rig down cement equipment, set pack off, nipple down stack, start nippling up BOP’s 3/4/2014: Nippling up BOP’s, setting stack on casing, installing stand pipe and kill line manifold, cleaning pits, loading drill pipe in pipe shed, installing rotary table and mouse hole, cleaning cellar, hook up koomie lines, change out saver sub and grab dies and testing gas alarms. 3/5/2014: Cleaning and servicing rig, laying down 4.5” drill pipe, cleaning drill pipe, changing out elevator inserts, rigging up BOP test equipment. 3/6/2014: Testing BOP’s, installing flow and fill up lines, installing wear bushing, laying down test joint, thawing Kelly hose, installing Kelly hose, picking up drill pipe, servicing rig, made up/picked up BHA, started tripping in hole to 1786’MD. 3/7/2014: Wash down to tag cement @ 1876’, drill shoe and 20’ of formation to 2000’MD, condition mud and circulate bottoms up until shakers clean, conduct FIT, clean and fill pits, service rig, displace mud, clean flow trough and pits 5&6, transfer new mud and change shaker screens, drilling ahead with steerable bit from 2000’ to 2193’MD. 3/8/2014: Drilling ahead from 2193’ to 2964’MD. 3/9/2014: Drilling ahead from 2964’ to 3998’MD. 3/10/2014: Drilling ahead from 3998 to 4100’MD, circulated bottoms up, pulled out of hole pumping from 4100’ to 775’, circulated bottoms up four times, serviced rig, tripped in hole for wiper trip to bottom, circulating and conditioning mud. 3/11/2014: Reaming out of hole from bottom to 700’MD, trouble shooting generators #1&2, cutting and slipping drill line, pulling out of hole from 700’ to surface laying down BHA and MWD tools, rigging up to run 4.5” liner, monitoring well. 3/12/2014: Running in hole with 4.5” slotted liner from surface to 2161’MD, rig down from running liner, picking up and rigging up equipment for 2.375” tubing, running in hole with 2.725” tubing to 2100’, stab in seal sub and tag at 2131’, rig down from running tubing, pick up 1 stand drill pipe and circulate at 2196’, run in hole with drill pipe and liner to 3617’MD. Umiat #23H 6 3 GEOLOGICAL DATA 3.1 Lithostratigraphy LWD tops refer to provisional picks by the mudlogger. FORMATION PROGNOSED LWD PICK MD (ft) TVD (ft) MD (ft) TVD (ft) 9 7/8” 23H Surface Section Upper Grandstand 630’ 614’ 530’ 529’ Top Lower Grandstand 988’ 950’ 971’ 928’ Middle Lower Grandstand 1190’ 1096’ 1150’ 1058’ Base Lower Grandstand 1575’ 1253’ 1370’ 1179’ 9 7/8” Surface TD 2200’ 1210’ 1980’ 1260’ 6 3/4” 23H Production Section Base Lower Grandstand 2390’ 1145’ 2270’ 1181’ Middle Lower Grandstand 3040’ 1004’ 2460’ 1111’ TD 3699’’ 890’ 4100’ 986’ Umiat #23H 7 3.2 Mudlog Summary Conductor to Casing Point: Top Lower Grandstand, Middle Lower Grandstand, and Base Lower Grandstand 70’ to 1974' MD (70' to 1258' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 6482 .3 34.7 138 0 4.9 The Grandstand includes sand, sandstone, and siltstone. The sandstone is predominant in this well with siltstone interbedded and traces of secondary pyrite minerals. Oil shows in this well were very slight. Siltstone (1590' - 1670') = dark gray to grayish black; hard to very hard, occasionally firm friable; very well indurated; tough and dense to crunchy tenacity; irregular earthy fracture; tabular to wedgelike cuttings habit, cuttings are much smaller than they have been in previous samples; dull, earthy luster; slightly granular and abrasive and occasionally silty and smooth; massive structure; no visual fluorescence; traces of pale green and dull orange cut fluorescence from 1640' to 1650'; no residual ring fluorescence; no odor; no degassing; background gas remains low. Sandstone (1850' - 1915') = dark gray to grayish black; lower very fine to upper very fine sand grains; moderate to high sphericity; subangular to subrounded; moderate to well sorted; well to very well consolidated; close packed contact cemented grains; dominantly clear and frosted quartz in a silty matrix; no visual fluorescence; pale orange cut fluorescence; faint orange residual cut ring; no odor; slight degassing observed from wet sandstone. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 1197.000 0.634 55.627 13.628 0.000 0.000 0.000 0.681 0.000 1198.000 2.164 189.407 46.795 0.000 0.000 0.000 2.340 0.000 1199.000 1.216 106.172 26.453 0.000 0.000 0.000 1.323 0.000 1200.000 1.216 105.912 26.610 0.000 0.000 0.000 1.331 0.000 1201.000 1.163 101.048 25.601 0.000 0.000 0.000 1.280 0.000 1202.000 1.163 100.799 25.751 0.000 0.000 0.000 1.288 0.000 1203.000 1.127 97.438 25.100 0.000 0.000 0.000 1.255 0.000 1204.000 1.127 77.760 20.001 0.000 0.000 0.000 1.920 0.000 1205.000 0.634 43.722 10.863 0.000 0.000 0.000 0.543 0.000 1206.000 0.634 44.075 10.460 0.000 0.000 0.000 0.523 0.000 Depth TG C1 C2 C3 C4I C4N C5I C5N 1651.000 1.057 77.527 1.555 1.037 0.000 0.000 1.516 1.516 1652.000 1.427 104.293 2.231 1.487 0.000 0.000 1.337 1.337 1653.000 1.586 115.501 2.625 1.750 0.000 0.000 3.609 3.606 1654.000 6.026 623.000 15.000 10.000 0.000 0.000 3.215 3.215 1655.000 3.330 313.632 6.222 4.148 0.000 0.000 3.478 3.478 1656.000 3.013 286.966 4.504 3.003 0.000 0.000 3.091 3.091 1657.000 3.172 305.420 3.556 2.370 0.000 0.000 2.397 2.397 1658.000 3.383 329.370 2.528 1.686 0.000 0.000 0.088 0.088 1659.000 4.599 452.629 1.719 1.146 0.000 0.000 0.000 0.000 Umiat #23H 8 1675.000 6.079 260.100 5.685 2.843 0.948 0.000 0.000 0.000 1676.000 11.471 484.527 12.873 6.437 2.146 0.000 0.000 0.000 1677.000 10.413 434.197 13.635 6.817 2.272 0.000 0.000 0.000 1678.000 7.242 298.009 10.837 5.418 1.806 0.000 0.000 0.000 1679.000 4.229 171.717 7.119 3.560 1.187 0.000 0.000 0.000 1680.000 3.489 257.891 12.723 6.489 2.032 0.000 0.000 0.000 1681.000 3.436 239.674 11.248 5.624 2.094 0.000 0.000 0.000 1682.000 4.916 342.011 16.132 8.066 3.315 0.000 0.000 0.000 1683.000 6.132 425.489 20.172 10.086 4.534 0.000 0.000 0.000 1684.000 6.502 449.975 21.441 10.720 5.231 0.000 0.000 0.000 1836.000 17.232 804.776 30.070 10.502 2.831 0.000 0.000 0.000 1837.000 1.533 71.640 2.643 0.923 0.262 0.000 0.000 0.000 1838.000 3.753 175.500 6.392 2.230 0.664 0.000 0.000 0.000 1839.000 4.282 200.346 7.202 2.511 0.785 0.000 0.000 0.000 1840.000 6.079 284.645 10.099 3.519 1.152 0.000 0.000 0.000 1841.000 7.083 331.874 11.619 4.046 1.387 0.000 0.000 0.000 1842.000 9.779 458.497 15.837 5.512 1.977 0.000 0.000 0.000 1843.000 10.836 675.000 23.000 8.000 3.000 0.000 0.000 0.000 1844.000 11.048 2246.132 77.297 25.616 9.606 0.000 0.000 0.000 1845.000 10.149 2064.983 71.763 22.627 8.485 0.000 0.000 0.000 1846.000 9.621 1958.901 68.739 20.591 7.722 0.000 0.000 0.000 1847.000 8.669 1766.466 62.583 17.782 6.668 0.000 0.000 0.000 1848.000 7.770 1584.552 56.672 15.246 5.717 0.000 0.000 0.000 1849.000 4.282 873.725 31.544 8.018 3.007 0.000 0.000 0.000 Umiat #23H 9 Casing Point: Base Lower Grandstand to Middle Lower Grandstand 1974’’ to 4100' MD (1258'to 986' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 21441 .4 111.2 28 0 6.8 Sandstone/siltstone (2280'-2370') = gray light yellowish gray sandstone with dark gray siltstone; hard crunchy to very hard tough tenacity; very well indurated; nodular to platy cuttings habit; irregular fracture; thick bedded well sorted rounded to sub--rounded close packed contact cemented grains in a silty matrix; interbedded with siltstone; gritty to abrasive texture; vitreous luster in sandstone with dull earthy luster in siltstone; dull orange fluorescence in siltstone; no odor or cut ring; low apparent visual porosity; sandstone increasing throughout sample interval. Sand (2670' - 2790') = dark gray to grayish black; lower fine to upper very fine sand grains; high to very high sphericity; subrounded to rounded; well to very well sorted; unconsolidated sand grains; no cement; no matrix; dominantly clear quartz sand grains; trace amounts of sandstone and siltstone found in sample; sandstone: moderately hard to firm friable; lower fine sand grains; cemented sand grains in a silty matrix; siltstone: firm friable to easily friable; poor to moderate induration; crumbly tenacity; irregular and earthy fracture; tabular to wedgelike cuttings habit; dull, earthy luster; smooth and silty, occasionally slightly gritty texture; thin structure; no visual fluorescence; extremely weak dull yellow fluorescence; no residual ring; no odor or any other hydrocarbon indicators. Siltstone (3540' - 3620') = grayish black to brownish black; moderately hare to hard; very well indurated; tough, dense and crunchy tenacity; irregular, blocky fracture; wedgelike to tabular cuttings habit; sparkling luster; matte texture; thin structure; no visual fluorescence; slow, weak Yellow fluorescence; no streamers or residual ring; no odor or any other hydrocarbon indicators. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 2329.000 28.055 430.121 0.000 0.000 0.000 18.349 7.522 6.795 2330.000 28.108 433.256 0.000 0.000 0.000 17.214 7.979 6.565 2331.000 28.372 439.662 0.000 0.000 0.000 16.195 8.501 6.381 2332.000 28.266 440.363 0.000 0.000 0.000 14.958 8.916 6.113 2333.000 28.372 444.351 0.000 0.000 0.000 13.833 9.396 5.891 2334.000 28.424 447.523 0.000 0.000 0.000 12.676 9.862 5.657 2335.000 28.530 451.541 0.000 0.000 0.000 11.536 10.348 5.431 2336.000 28.372 451.385 0.000 0.000 0.000 10.291 10.739 5.156 2337.000 28.266 452.043 0.000 0.000 0.000 9.076 11.144 4.893 2338.000 28.213 453.534 0.000 0.000 0.000 7.885 11.569 4.640 2339.000 28.161 455.010 0.000 0.000 0.000 6.699 11.991 4.388 2637.000 18.616 1972.162 39.386 13.481 2.809 2.247 0.000 0.000 2638.000 17.192 1821.891 34.354 13.280 2.767 2.213 0.000 0.000 2639.000 18.932 3100.000 55.000 24.000 5.000 4.000 0.000 0.000 2640.000 23.678 3758.821 71.732 27.967 5.826 4.661 0.000 0.000 2641.000 23.573 3738.057 76.363 26.682 5.559 4.447 0.000 0.000 2642.000 18.141 2873.654 62.577 19.641 4.092 3.274 0.000 0.000 2643.000 9.703 1535.445 35.509 10.028 2.089 1.671 0.000 0.000 2847.000 6.065 491.772 16.569 13.217 0.000 6.821 2.254 0.000 2848.000 12.287 994.892 33.409 27.157 0.000 14.331 4.473 0.000 Umiat #23H 10 2849.000 15.768 1274.769 42.663 35.332 0.000 19.048 5.618 0.000 2850.000 14.977 1208.986 40.325 34.019 0.000 18.716 5.221 0.000 2851.000 11.074 892.609 29.671 25.494 0.000 14.301 3.776 0.000 2852.000 9.651 483.848 16.467 14.745 0.000 8.374 2.808 0.000 2853.000 9.651 503.495 16.623 14.292 0.076 8.283 2.123 0.000 3563.000 15.451 1263.305 29.597 6.152 3.809 0.000 2.056 0.000 3564.000 15.610 1275.993 29.762 6.088 3.813 0.000 2.337 0.000 3565.000 15.873 1297.340 30.126 6.061 3.841 0.000 2.640 0.000 3566.000 16.401 1340.170 30.982 6.129 3.931 0.000 3.000 0.000 3567.000 16.084 1314.070 30.243 5.880 3.818 0.000 3.210 0.000 3568.000 16.084 1313.833 30.102 5.749 3.782 0.000 3.478 0.000 3569.000 16.084 1403.000 32.000 6.000 4.000 0.000 4.000 0.000 3570.000 15.821 1372.522 31.925 6.157 3.764 0.000 3.764 0.000 3571.000 15.135 1312.430 31.121 6.163 3.457 0.000 3.457 0.000 3572.000 15.293 1325.503 32.031 6.502 3.348 0.000 3.348 0.000 Umiat #23H 11 3.3 Connection Gases 1unit = 0.02% Methane Equivalent Date Time Depth Gas over BGG Feb/March 2014 (feet) (units) 2/23/2014 3:29 771 11 7:13 829 0 10:03 890 0 14:00 952 0 20:54 1,013 0 2/24/2014 14:52 1,075 0 17:36 1,136 0 20:00 1,198 2 22:50 1,259 0 2/25/2014 2:41 1,321 0 10:49 1,383 3 20:00 1,434 0 2/26/2014 2:25 1,499 0 8:20 1,559 0 12:57 1,616 0 20:43 1,679 0 2/27/2014 2:45 1,742 0 6:58 1,803 6 14:43 1,865 1 2/28/2014 0:10 1,926 1 3/7/2014 19:45 2,034 1 21:59 2,097 1 23:05 2,160 1 3/8/2014 1:01 2,223 1 2:00 2,287 1 4:35 2,350 2 6:09 2,414 0 7:53 2,477 0 10:23 2,540 1 13:12 2,594 1 16:07 2,666 1 17:48 2,728 2 19:29 2,793 1 20:57 2,852 11 22:26 2,915 9 3/9/2014 0:29 2,981 4 1:55 3,044 4 4:19 3,108 0 5:29 3,171 2 6:55 3,235 0 8:24 3,294 1 9:53 3,361 4 12:05 3,425 6 13:23 3,494 4 14:42 3,554 5 16:00 3,617 2 Umiat #23H 12 17:12 3,681 10 18:28 3,743 3 19:50 3,807 3 21:10 3,871 3 22:40 3,934 3 3/10/2014 0:05 3,998 1 1:01 4,028 2 1:46 4,059 2 2:32 4,090 1 Umiat #23H 13 3.4 Sampling Program / Sample Dispatch Set Type / Purpose Frequency Interval Dispatched to A Washed in base oil; Centrifuged (“Dry”); in vials 30’ 10’ 30’ 130’ – 310’ 310’ – 1710’ 1710’’ – 4100’ Linc Energy 3000 “C” Street, Suite # 103 Anchorage, AK 99503 Via Hotshot arranged by Linc Energy Drilling Engineer B Washed in base oil; Centrifuged (“Dry”); in vials 30’ 10’ 30’ 130’ – 310’ 310’ – 1710’ 1710’ – 4100’ BLM Alaska State Office 222 West 7th Avenue #13 Anchorage, AK 99513 Via Hotshot arranged by Linc Energy Drilling Engineer C Washed in base oil; Centrifuged (“Dry”); in vials 30’ 10’ 30’ 130’ – 310’ 310’ – 1710’ 1710’ – 4100’ Attn: Howard Okland State of Alaska C/O Linc Energy Operations Alaska Via Hotshot arranged by Linc Energy Drilling Engineer D Unwashed Wet 30’ 10’ 30’ 130’ – 310’ 310’ – 1710’ 1710’ – 4100’ Linc Energy 3000 “C” Street, Suite # 103 Anchorage, AK 99503 Via Hotshot arranged by Linc Energy Drilling Engineer E Unwashed Wet 30’ 10’ 30’ 130’ – 310’ 310’ – 1710’ 1710’ – 4100’ Attn: Howard Okland State of Alaska C/O Linc Energy Operations Alaska Via Hotshot arranged by Linc Energy Drilling Engineer * Sample frequency was locally altered according to drill rate constraints and zones of interest. Set’s A, B, C: Box 1: 130’ – 750’ Box 2: 750’ – 1250’ Box 3: 1250’ – 1830’ Box 4: 1830 – 3330’ Box 5: 3330’ – 4100 Sets D, E Box 1) 130’ – 920’ Box 2) 920’ – 1520’ Box 3: 1520’ – 2700’ Umiat #23H 14 Box 4: 2700’ – 4100’ Um i a t # 2 3 H 15 3. 5 T r i p G a s e s 1u n i t = 0 . 0 2 % M e t h a n e E q u i v a l e n t De p t h G a s o v e r B G G D e p t h G a s o v e r B G G (f e e t ) ( u n i t s ) ( f e e t ) ( u n i t s ) 10 2 5 ’ 9 12 8 7 ’ 1 14 8 0 ’ 2 19 2 6 ’ 4 29 6 4 ’ 8 39 9 8 ’ 7 Um i a t # 2 3 H 16 4 P R E S S U R E / F O R M A T I O N S T R E N G T H D A T A Co n n e c t i o n g a s o c c u r r e d t h r o u g h m o s t o f t h e d r i l l i n g , b u t p e a k s w e r e c o n s i s t e n t l y d i f f i c u l t t o d i s t i n g u i s h f r o m b a c k g r o u n d g a s e s, indicating pore pr e s s u r e r e m a i n e d c l o s e t o b a l a n c e d w i t h m u d w e i g h t . Co n n e c t i o n g a s e n c o u n t e r e d w a s c o n s i s t e n t l y l o w a n d n o t e a s i l y f ou n d a b o v e b a c k g r o u n d g a s . T h i s w a s d u e t o t h e m u d w e i g h t b e i n g close to fo r m a t i o n p r e s s u r e w i t h p u m p p r e s s u r e f r o m s t a r t o f t h e w e l l w h i l e d r i l l i n g w i t h a 9 . 5 p p g m u d ; t o t h e e n d o f t h e P i l o t h o l e . . The mud weight was not in c r e a s e d t h u s t h e b a c k g r o u n d g a s e s a n d c o n n e c t i o n g a s e s w e r e c l o s e t o g e t h e r a l l t h e w a y t o t h e H R Z t o p a n d t o t h e c o r i n g p o i n t . The pore pr e s s u r e i s e s t i m a t e d t o h a v e v a r i e d f r o m 9 . 4 t o 9 . 6 f r o m c a s i ng p o i n t t o t h e H R Z , r e m a i n i n g c l o s e t o t h e m u d w e i g h t w i t h i n t h e equivalent ci r c u l a t i n g d e n s i t y o f t h e m u d p l u s p u m p p r e s s u r e . 4. 1 Po r e p r e s s u r e e v a l u a t i o n Fo r m a t i o n In t e r v a l Pr i m a r y Li t h o l o g y (% ) Se c o n d a r y Li t h o l o g y (% ) In t e r v a l T o p s P o r e P r e s s u r e ( E M W ) Tr e n d I n d i c a t o r s MD (f t ) TV D (f t ) Mi n (p p g ) Ma x (p p g ) Tr e n d Up p e r G r a n d s t a n d S s / S d 6 0 % S l t s t 4 0 % 5 3 0 ’ 5 2 9 ’ To p L o w e r Gr a n d s t a n d Ss / S d 8 0 % S l t s t 2 0 % 9 7 1 ’ 9 2 8 ’ Mi d d l e L o w e r Gr a n d s t a n d Ss / S d 6 0 % S l t s t 4 0 % 1 1 5 0 ’ 1 0 5 8 ’ Ba s e L o w e r Gr a n d s t a n d Sl t s t 8 0 % S s / S d 2 0 % 1 3 7 0 ’ 1 1 7 9 ’ Su r f a c e T D S s / S d 8 0 % S l t s t 2 0 % 1 9 8 0 ’ 1 2 6 0 ’ Ba s e L o w e r Gr a n d s t a n d Sl t s t 7 0 % S s 3 0 % 2 2 7 0 ’ 1 1 8 1 ’ Mi d d l e L o w e r Gr a n d s t a n d Sl t s t 8 0 % S s / S d 2 0 % 2 4 6 0 ’ 1 1 1 1 ’ To t a l D e p t h S d 9 0 % S s 1 0 % 4 1 0 0 ’ 9 8 6 ’ NO T E : C l y s t = C l a y s t o n e / C l a y , S d = S a n d , S l t s t = S i l t s t o n e , S s = S a n d S t o n e , S h = S h a l e , S s t = S a n d s t o n e , A s h = A s h F a l l T u f f Umiat #23H 17 5 DRILLING DATA 5.1 Survey Data Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (ft) Dogleg Rate (o/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 N/A 21.00 0.00 0.00 21.00 0.00 0.00 0.00 0.00 253.80 0.72 19.84 253.79 1.38 0.50 0.25 0.31 313.58 2.95 74.80 313.54 2.13 2.11 1.71 4.36 385.99 5.87 88.28 385.73 2.73 7.61 7.02 4.25 448.24 8.17 89.98 447.51 2.83 15.22 14.49 3.71 506.10 10.54 93.56 504.60 2.50 24.61 23.80 4.22 571.00 12.99 96.61 568.13 1.29 37.78 36.98 3.89 632.29 16.23 99.16 627.43 -0.86 53.08 52.43 5.39 695.00 20.35 100.33 686.96 -4.21 72.47 72.10 6.60 756.65 24.05 102.56 744.03 -8.87 95.29 95.38 6.15 816.85 27.80 102.22 798.16 -14.51 120.99 121.67 6.23 877.50 31.97 101.41 850.74 -20.68 150.56 151.87 6.91 940.63 35.78 102.69 903.14 -28.05 184.97 187.03 6.14 1001.33 39.29 101.72 951.27 -35.85 221.11 223.97 5.86 1063.19 42.90 101.84 997.88 -44.15 260.90 264.61 5.84 1124.52 47.04 102.39 1041.26 -53.26 303.27 307.91 6.78 1186.19 51.62 102.75 1081.44 -63.44 348.91 354.63 7.44 1247.11 55.66 102.27 1117.55 -74.06 396.80 403.63 6.66 1309.26 59.89 101.22 1150.68 -84.75 448.26 456.17 6.95 1366.30 63.31 100.97 1177.81 -94.40 497.49 506.33 6.01 1424.84 66.88 100.80 1202.46 -104.42 549.63 559.41 6.10 1484.27 70.85 100.67 1223.88 -114.74 604.08 614.83 6.68 1545.39 75.24 101.21 1241.70 -125.84 661.46 673.27 7.23 1622.12 81.23 100.05 1257.34 -139.68 735.26 748.34 7.95 1703.53 87.69 99.29 1265.20 -153.28 815.10 829.33 7.99 1729.47 89.09 98.60 1265.92 -157.31 840.71 855.25 6.02 1790.82 89.66 99.81 1266.59 -167.13 901.26 916.59 2.18 1852.86 90.20 100.00 1266.67 -177.80 962.38 978.63 0.92 1904.56 93.66 99.01 1264.93 -186.33 1013.33 1030.29 6.96 1997.52 96.91 97.99 1256.31 -200.01 1104.87 1122.81 3.66 2060.57 101.72 98.39 1246.11 -208.87 1166.43 1184.98 7.65 2123.61 106.20 97.94 1230.90 -217.56 1226.97 1246.11 7.14 2188.51 110.59 97.74 1210.43 -225.96 1287.97 1307.64 6.77 2253.08 110.64 96.84 1187.69 -233.63 1347.91 1368.00 1.31 2315.09 111.44 98.14 1165.43 -241.17 1405.29 1425.82 2.34 2378.21 112.22 100.36 1141.95 -250.59 1463.12 1484.41 3.49 Umiat #23H 18 2441.70 111.82 100.31 1118.15 -261.15 1521.02 1543.26 0.63 2503.81 108.00 100.97 1097.00 -271.93 1578.41 1601.65 6.23 2567.55 106.37 99.51 1078.17 -282.75 1638.33 1662.54 3.37 2629.40 106.29 100.09 1060.78 -292.85 1696.81 1721.89 0.91 2689.28 103.91 99.20 1045.18 -302.54 1753.81 1779.70 4.23 2756.28 101.10 98.96 1030.68 -312.86 1818.39 1845.09 4.21 2816.14 101.07 99.75 1019.17 -322.41 1876.35 1903.83 1.30 2881.28 100.68 100.82 1006.88 -333.83 1939.29 1967.80 1.72 2940.55 100.60 101.13 995.93 -344.92 1996.48 2026.04 0.53 3005.38 97.70 99.63 985.62 -356.44 2059.43 2090.04 5.02 3073.83 95.43 99.71 977.80 -367.87 2126.46 2158.03 3.32 3135.17 92.88 101.13 973.35 -378.93 2186.62 2219.20 4.76 3197.88 90.34 102.12 971.59 -391.56 2248.02 2281.86 4.35 3262.63 87.91 102.21 972.58 -405.20 2311.30 2346.55 3.76 3324.27 86.09 102.75 975.81 -418.51 2371.40 2408.04 3.08 3390.54 88.56 102.36 978.90 -432.89 2436.01 2474.17 3.77 3455.69 89.59 102.21 979.95 -446.75 2499.66 2539.26 1.60 3513.17 89.00 101.65 980.66 -458.64 2555.89 2596.70 1.42 3578.35 88.77 101.40 981.93 -471.66 2619.74 2661.85 0.52 3639.80 88.59 101.61 983.34 -483.91 2679.94 2723.26 0.45 3706.00 88.56 101.16 984.99 -496.97 2744.82 2789.42 0.68 3769.36 90.00 101.06 985.78 -509.18 2806.99 2852.76 2.28 3832.73 90.14 101.13 985.71 -521.37 2869.17 2916.12 0.25 3895.68 89.48 100.30 985.92 -533.08 2931.02 2979.06 1.68 3952.31 90.03 99.83 986.16 -542.98 2986.78 3035.69 1.28 4017.89 90.07 98.83 986.10 -553.61 3051.49 3101.27 1.53 4062.62 90.00 99.48 986.07 -560.72 3095.65 3145.99 1.46 Um i a t # 2 3 H 19 5. 2 B i t R e c o r d Bi t S i z e M a k e T y p e / S # J e t s / T F A De p t h I n MD / To t a l Fo o t a g e Bi t Hr s Av g . RO P (f t / h r ) WO B (K l b s ) RP M PP (p s i ) Wear BHA 1 9 . 8 7 5 ” S m i t h XR + C M i l l e d To o t h / P Y 6 3 5 6 4X 1 4 / 0 . 6 0 1 3 9 ’ 2 6 1 ’ 9 . 3 3 2 8 . 0 1 1( R R # 2 ) 9 . 8 7 5 ” S m i t h XR + C M i l l e d To o t h / P Y 6 3 5 6 4X 1 4 / 0 . 6 0 1 3 0 0 ’ 7 8 ’ 2 . 7 4 2 8 . 5 2 1( R R # 3 ) 9 . 8 7 5 ” S m i t h XR + C M i l l e d To o t h / P Y 6 3 5 6 4X 1 4 / 0 . 6 0 1 3 7 8 ’ 6 4 7 ’ 3 5 . 1 7 1 8 . 4 3 2 9 . 8 7 5 ” S m i t h XR + C M i l l e d To o t h / P Y 6 3 5 7 4X 1 4 / 0 . 6 0 1 1 0 2 5 ’ 9 5 5 ’ 8 2 . 8 3 1 1 . 5 4 1R R (4 ) 9. 8 7 5 ” S m i t h XR + C M i l l e d To o t h / P Y 6 3 5 6 4X 1 4 / 0 . 6 0 1 1 9 8 0 ’ 0 ’ 0 0 5 3 6 . 7 5 ” S m i t h Sm i t h P D C / JH 6 5 9 0 5X 1 1 / . 4 6 4 1 9 8 0 ’ 2 1 2 0 ’ 3 2 . 4 6 6 5 . 3 6 Um i a t # 2 3 H 20 5. 2 . 1 . 1 . 1 . 1 . 1 . 1 . 1 M u d R e c o r d Co n t r a c t o r : M I S W A C O Mu d T y p e : V e r s a C l e a n , L V T - 2 0 0 , M O B M Da t e D e p t h MW (p p g ) EC D (p p g ) VI S (s / q t ) PV Y P G e l s FL (c c ) FC So l s (% ) O/ W Ra t i o Sd (% ) pH Cl (ml/l) Ca (ml/l) 2/ 1 5 / 1 4 9 7 ’ 7 . 6 5 - 4 8 1 8 4 2 / 4 / 5 - - / - - 7 0 / 3 0 - - 1 2 5 0 0 0 - 2/ 1 6 / 1 4 3 2 0 ’ 7 . 8 - 5 7 2 1 1 2 1 0 / 1 0 / 1 1 - - / 1 1 7 1 / 2 9 - - 1 1 9 0 0 0 - 2/ 1 7 / 1 4 3 8 2 ’ 7 . 7 5 - 6 5 2 2 1 2 1 0 / 1 1 / 1 2 6 . 2 - / 1 - . 3 . 3 7 1 / 2 9 - - 1 1 8 0 0 0 - 2/ 1 8 / 1 4 3 8 2 ’ 7 . 7 5 - 6 4 2 2 1 1 1 0 / 1 1 / 1 2 5 . 9 - / 1 1 . 1 4 7 1 / 2 9 - - 2 5 0 0 0 - 2/ 1 9 / 1 4 3 8 2 ’ 7 . 8 5 - 6 1 2 2 1 1 1 0 / 1 1 / 1 2 5 . 8 - / 1 1 . 1 4 7 1 / 2 9 - - 2 5 0 0 0 - 2/ 2 0 / 1 4 3 8 2 ’ 7 . 8 - 8 9 2 9 1 0 1 2 / 1 3 / 1 4 5 . 8 - / 1 1 . 1 1 6 7 / 3 3 - - 3 5 0 0 0 - 2/ 2 1 / 1 4 3 8 2 ’ 7 . 8 - 8 2 2 6 1 4 1 2 / 1 3 / 1 4 5 . 8 - / 1 2 1 / 6 6 3 2 3 3 4 2 0 - 2/ 2 2 / 1 4 7 0 6 ’ 7 . 9 - 9 6 2 6 2 0 1 1 / 1 2 / 1 3 5 . 6 - / 1 . 0 8 6 7 / 3 3 - - 3 4 0 0 0 - 2/ 2 3 / 1 4 1 0 2 5 ’ 7 . 9 - 9 7 2 7 2 4 1 1 / 1 2 / 1 4 5 - / 1 . 8 4 6 7 / 3 3 - - 3 4 0 0 0 - 2/ 2 4 / 1 4 1 2 8 5 ’ 7 . 9 - 1 0 5 3 3 2 8 1 3 / 1 5 / 1 9 5 - / 1 1 . 5 6 8 / 3 2 - - 3 3 0 0 0 - 2/ 2 5 / 1 4 1 4 8 5 ’ 8 - 1 0 0 3 5 2 1 1 8 / 2 0 / 2 3 5 - / 1 2 6 7 / 3 3 - - 3 3 0 0 0 - 2/ 2 6 / 1 4 1 7 1 3 ’ 8 - 8 8 3 2 2 2 9 / 1 1 / 1 2 5 - / 1 2 7 0 / 3 0 - - 2 9 0 0 0 - 2/ 2 7 / 1 4 1 9 2 7 ’ 8 . 1 - 1 0 5 2 9 2 1 1 1 / 1 2 / 1 4 5 - / 1 2 . 2 5 7 0 / 3 0 - - 2 7 0 0 0 - 2/ 2 8 / 1 4 1 9 8 0 ’ 8 - 8 5 2 7 1 7 1 0 / 1 1 / 1 2 - - / - 1 . 1 7 7 2 / 2 8 - - 2 4 0 0 0 - 3/ 1 / 1 4 1 9 8 0 ’ 8 - 8 6 2 8 1 7 1 0 / 1 1 / 1 1 - - / - 1 . 2 7 6 / 2 4 - - 2 3 0 0 0 - 3/ 2 / 1 4 1 9 8 0 ’ 8 - 8 2 3 0 1 5 1 0 / 1 1 / 1 1 - - / - 1 . 2 5 7 7 / 2 4 - - 2 2 0 0 0 - 3/ 3 / 1 4 1 9 8 0 ’ 8 - 8 0 2 7 2 3 1 0 / 1 1 / 1 1 5 - / 1 1 . 2 4 7 6 / 2 4 - - 2 2 0 0 0 - 3/ 4 / 1 4 1 9 8 0 ’ 8 - 8 8 2 6 2 3 9 / 1 0 / 1 0 - - / - 1 . 2 8 7 6 / 2 4 - - 2 2 0 0 0 - 3/ 5 / 1 4 1 9 8 0 ’ 8 - 8 8 3 1 1 1 9 / 1 0 / 1 1 - - / - 1 . 2 8 7 6 / 2 4 - - 2 2 0 0 0 - 3/ 6 / 1 4 1 9 8 0 ’ 8 - 8 6 3 1 1 1 9 / 1 0 / 1 1 - - / - 1 . 2 8 7 6 / 2 4 - - 2 2 0 0 0 - 3/ 7 / 1 4 2 1 9 3 ’ 7 . 3 - 5 0 1 5 1 0 6 / 6 / 7 - - / - - - / - - - 4 6 0 0 - 3/ 8 / 1 4 2 9 7 3 ’ 7 . 6 - 5 8 1 8 1 7 9 / 1 1 / 1 2 - - / - 3 9 7 / 3 - - 2 3 0 0 - 3/ 9 / 1 4 3 9 9 5 ’ 7 . 8 - 6 2 2 0 1 4 1 1 / 1 2 / 1 3 - - / - 4 1 0 0 / 0 - - 1 7 0 0 - 3/ 1 0 / 1 4 4 1 0 0 ’ 7 . 7 - 5 0 1 6 1 8 1 3 / 1 7 / 1 9 - - / - 4 1 0 0 / 0 - - 1 8 0 0 - Ab b r e v i a t i o n s MW = M u d W e i g h t G e l s = G e l S t r e n g t h S d = S a n d c o n t e n t E C D = E f f e c t i v e C i r c u l a t i n g D e n s i t y WL = W a t e r o r F i l t r a t e L o s s C l = C h l o r i d e s V I S = F u n n e l V i s c o s i t y F C = F i l t e r C a k e Ca = H a r d n e s s C a l c i u m P V = P l a s t i c V i s c o s i t y S o l s = S o l i d s O / W = O i l t o W a t e r r a t i o YP = Y i e l d P o i n t Um i a t # 2 3 H 21 Um i a t # 2 3 H 22 D A Y S V E R S U S D E P T H ( M D ) 0 50 0 10 0 0 15 0 0 20 0 0 25 0 0 30 0 0 35 0 0 40 0 0 45 0 0 2 / 1 0 / 1 4 2 / 1 1 / 1 4 2 / 1 2 / 1 4 2 / 1 3 / 1 4 2 / 1 4 / 1 4 2 / 1 5 / 1 4 2 / 1 6 / 1 4 2 / 1 7 / 1 4 2 / 1 8 / 1 4 2 / 1 9 / 1 4 2 / 2 0 / 1 4 2 / 2 1 / 1 4 2 / 2 2 / 1 4 2 / 2 3 / 1 4 2 / 2 4 / 1 4 2 / 2 5 / 1 4 2 / 2 6 / 1 4 2 / 2 7 / 1 4 2 / 2 8 / 1 4 3 / 1 / 1 4 3 / 2 / 1 4 3 / 3 / 1 4 3 / 4 / 1 4 3 / 5 / 1 4 3 / 6 / 1 4 3/7/14 3/8/14 3/9/14 3/10/14 3/11/14 3/12/14 DA T E D E P T H ( F T ) 13-1/2" Hole 9-7/8" Hole 6-3/4" Hole Wireline Logs Completion Um i a t # 2 3 H 23 6 SHOW REPORTS 24 7 DAILY REPORTS Hydrocarbon Show Report #1 Operator: Well:API Number: Field: Date: Rig: Time: County: Depth Start End State:2760 MD 2788 MD Country:1029 TVD 1035 TVD Averages Before During After Maximum ROP (fph)63 85 72 85 WOB 4 5 5 5 RPM 155 156 155 156 Mud Weight Chloride Total Gas 5 12 8 12 C1 (ppm) C2 (ppm) C3 (ppm) C4 (ppm) C5 (ppm) Lithology Cuttings Analysis Odor None Fluorescence Cut Fluorescence Residual Cut Stain Amount Trace Type None Amount Amount Distribution very spotty Intensity Color Color Intensity dull Color Residual Fluorescence Cut Color orange Intesity Color Color Oil Show Rating Free Oil in Mud Comments North Slope Alaska USA Linc Energy 50-287-20029-00-0023H Umiat Kuukpik #5 3/8/14 19:05 None Sand (2670' - 2790') = dark gray to grayish black; lower fine to upper very fine sand grains; high to very high sphericity; subrounded to rounded; well to very well sorted; unconsolidated sand grains; no cement; no matrix; dominantly clear quartz sand grains; trace amounts of sandstone and siltstone found in sample; sandstone: moderately hard to firm friable; lower fine sand grains; cemented sand grains in a silty matrix; siltstone: firm friable to easily friable; poor to moderate induration; crumbly tenacity; irregular and earthy fracture; tabular to wedgelike cuttings habit; dull, earthy luster; smooth and silty, occasionally slightly gritty texture; thin structure; no visual fluorescence; extremely weak dull yellow fluorescence; no residual ring; no odor or any other hydrocarbon indicators. 1 10 100 1000 10000 1234 pp m Pixler Plot DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Report by: 1 10 100 1000 10000 1234 Linc Energy Umiat 23H Ratio Plot #1 March 8,2014 Depths 2,760 -2,777 MD' DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report # 2 Operator: Well:API Number: Field: Date: Rig: Time: County: Depth Start End State:3692 MD 3700 MD Country:984 TVD 984 TVD Averages Before During After Maximum ROP (fph)8 16 13 16 WOB 5 5 5 5 RPM Mud Weight Chloride Total Gas 5 16 13 16 C1 (ppm)1,230 3,544 1,724 C2 (ppm)35 76 51 C3 (ppm)15 31 15 C4 (ppm)14 33 13 C5 (ppm)4 15 5 Lithology Cuttings Analysis Odor None Fluorescence Cut Fluorescence Residual Cut Stain Amount Trace Type Streaming Amount Amount Distribution Trace Intensity Weak Color Color Intensity Color Yellow Residual Fluorescence Cut Color Intesity Color Color Oil Show Rating Free Oil in Mud Comments No0.3 North Slope Alaska USA Linc Energy 50-287-20029-00-0023H Umiat Kuukpik #5 3/9/14 17;40 None Sand (3690- 3720 = dark gray to grayish black; lower fine to upper very fine sand grains; high to very high sphericity; subrounded to rounded; well to very well sorted; unconsolidated sand grains; no cement; no matrix; dominantly clear quartz sand grains; trace amounts of sandstone and siltstone found in sample; sandstone: moderately hard to firm friable; lower fine sand grains; cemented sand grains in a silty matrix; siltstone: firm friable to easily friable; poor to moderate induration; crumbly tenacity; irregular and earthy fracture; tabular to wedgelike cuttings habit; dull, earthy luster; smooth and silty, occasionally slightly gritty texture; thin structure; extremely weak dull yellow fluorescence; weak yellow streaming cut; no odor 1 10 100 1000 10000 1234 pp m Pixler Plot DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Report by:Eric Andrews 1 10 100 1000 10000 1234 Linc Energy Umiat 23H Ratio Plot #2 March 9, 2014 Depths 3,690' - 3,710' MD DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report # 3 Operator: Well:API Number: Field: Date: Rig: Time: County: Depth Start End State:3870 MD 3900 MD Country:984 TVD 984 TVD Averages Before During After Maximum ROP (fph)8 16 13 16 WOB 5 5 5 5 RPM 155 155 155 155 Mud Weight Chloride Total Gas 5 16 13 4 C1 (ppm)1,230 3,544 1,724 327 C2 (ppm)35 76 51 13 C3 (ppm)15 31 15 5 C4 (ppm)14 33 13 2 C5 (ppm)4 15 5 2 Lithology Cuttings Analysis Odor None Fluorescence Cut Fluorescence Residual Cut Stain Amount Trace Type Dull Amount Amount Distribution Trace Intensity Weak Color Color Intensity Color Orange Residual Fluorescence Cut Color Intesity Color Color Oil Show Rating Free Oil in Mud Comments No0.2 North Slope Alaska USA Linc Energy 50-287-20029-00-0023H Umiat Kuukpik #5 3/9/14 21:53 None Sandstone (3870' - 3960') = gray to dark gray and traces of brownish black; brittle crumbly to hard tough tenacity; pulverulent nodular cuttings; irregular fracture; fine well sorted rounded to sub-rounded close packed contact cemented grains in a massive bedded structure; beds seperated and differentiated by cementation; silty matrix beds have hard tough tenacity and contact cemented beds are brittle to crumbly; vitreous to dull luster; gritty texture; traces of scattered dull orange fluorescense; no odor or cut 1 10 100 1000 10000 1234 pp m Pixler Plot DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Report by:Mike Strawn 1 10 100 1000 10000 1234 Linc Energy Umiat 23H Ratio Plot #3 March 9, 2014 Depths 3,870' - 3,890 MD DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report # 4 Operator: Well:API Number: Field: Date: Rig: Time: County: Depth Start End State:4000 MD 4046 MD Country:986 TVD 986 TVD Averages Before During After Maximum ROP (fph) WOB RPM Mud Weight Chloride Total Gas C1 (ppm) C2 (ppm) C3 (ppm) C4 (ppm) C5 (ppm) Lithology Cuttings Analysis Odor None Fluorescence Cut Fluorescence Residual Cut Stain Amount Trace Type Dull Amount Amount Distribution Trace Intensity Weak Color Color Intensity Color Orange Residual Fluorescence Cut Color Intesity Color Color Oil Show Rating Free Oil in Mud Comments No0.2 North Slope Alaska USA Linc Energy 50-287-20029-00-0023H Umiat Kuukpik #5 3/10/14 1:00 None Sand/Sandstone (3960' - 4100) = gray to dark gray and traces of brownish black; brittle crumbly to hard tough tenacity; pulverulent nodular cuttings; irregular fracture; fine well sorted rounded to sub-rounded close packed contact cemented grains in a massive bedded structure; beds seperated and differentiated by cementation; silty matrix beds have hard tough tenacity and contact cemented beds are brittle to crumbly; vitreous to dull luster; gritty texture; traces of scattered dull orange fluorescense; no odor or cut 1 10 100 1000 10000 1234 pp m Pixler Plot DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Report by:Mike Strawn 1 10 100 1000 10000 1234 Linc Energy Umiat 23H Ratio Plot #4 March 10, 2014 Depths 4,000' - 4,042' MD DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Linc Energy Operations, Inc. Umiat DAILY WELLSITE REPORT Umiat #23H REPORT FOR Dave Boyer DATE Feb 16, 2014 DEPTH 317' PRESENT OPERATION Making Up BHA TIME 23:59 YESTERDAY 97' 24 HOUR FOOTAGE 220' CASING INFORMATION 13.375" @ 70' 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 1 9.875 Smith Cone PY6356 4x14 97' 330' 233' 4.25 BHA Change DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 2838.4 @ 239.0 5.3 @ 271.0 56.5 963.9 FT/HR SURFACE TORQUE 0 @ 317.0 0 @ 317.0 -522.3 0.0 AMPS WEIGHT ON BIT 37 @ 297.0 0 @ 159.0 -3.9 27.2 KLBS ROTARY RPM 0 @ 317.0 0 @ 317.0 -522.3 0.0 RPM PUMP PRESSURE 825 @ 293.0 0 @ 206.0 28.5 73.3 PSI DRILLING MUD REPORT DEPTH 330' MW 7.8 VIS 58 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 138 @ 229' -1 @ 152' 30.7 TRIP GAS N/A CUTTING GAS @ @ WIPER GAS 39u CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 0 @ 317' 0 @ 317' 0.0 CONNECTION GAS HIGH 0u ETHANE (C-2) 0 @ 317' 0 @ 317' 0.0 AVG 0u PROPANE (C-3) 0 @ 317' 0 @ 317' 0.0 CURRENT 0u BUTANE (C-4) 0 @ 317' 0 @ 317' 0.0 CURRENT BACKGROUND/AVG 15u/31u PENTANE (C-5) 0 @ 317' 0 @ 317' 0.0 HYDROCARBON SHOWS No shows this section. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Nanushuk PRESENT LITHOLOGY Siltstone 40%, Sand 30%, Sandstone 20%, Shale 10%. DAILY ACTIVITY SUMMARY Fill damper with nitrogen, test surface lines, drilling ahead from 97’ to 330’MD, circulate and condition mud and monitor well, pull out of hole reaming tight spots, trip in hole, clean and circulate, pull out of hole to make up new BHA. CANRIG PERSONNEL ON BOARD E. Andrews, M. Strawn, D. Hudgins, D. Muller DAILY COST $3290.00 REPORT BY Mike Strawn Linc Energy Operations, Inc. Umiat DAILY WELLSITE REPORT Umiat #23H REPORT FOR Dave Boyer DATE Feb 17, 2014 DEPTH 382' PRESENT OPERATION Working Pipe TIME 23:59 YESTERDAY 300' 24 HOUR FOOTAGE 81' CASING INFORMATION 13.375" @ 70' 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 1 9.875" Smith Cone PY6356 4x14 97' In Hole 284' 6.37 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 326.8 @ 368' 4.9 @ 366' 42.0 6.2 FT/HR SURFACE TORQUE 0 @ 382' 0 @ 382' 0.0 0.0 AMPS WEIGHT ON BIT 53 @ 382' 19 @ 369' 33.7 53.8 KLBS ROTARY RPM 0 @ 382' 0 @ 382' 0.0 0.0 RPM PUMP PRESSURE 1505 @ 320' 183 @ 382' 1336.4 183.1 PSI DRILLING MUD REPORT DEPTH 382' MW 7.7 VIS 73 PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 300' TO 381' TOOLS Directional, Mud Motor and Gamma. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 24 @ 301' 1 @ 356' 1.2 TRIP GAS 0u CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 0 @ 382' 0 @ 382' 0.0 CONNECTION GAS HIGH N/A ETHANE (C-2) 0 @ 382' 0 @ 382' 0.0 AVG N/A PROPANE (C-3) 0 @ 382' 0 @ 382' 0.0 CURRENT N/A BUTANE (C-4) 0 @ 382' 0 @ 382' 0.0 CURRENT BACKGROUND/AVG 0u/1u PENTANE (C-5) 0 @ 382' 0 @ 382' 0.0 HYDROCARBON SHOWS No shows this section. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Nanushuk PRESENT LITHOLOGY Siltstone 60%, Sandstone 20%, Sand 10%, Shale 10%. DAILY ACTIVITY SUMMARY Pick up BHA, make up MWD tools, trip in hole, drill ahead from 330’ to 381’MD, change fuel filters on generators, start to pull 1 stand observed 10K over pull, circulate and rotate, packed off unable to get returns or rotate, make up fishing jars and jarred 10 times with no gain, try to work pipe free. CANRIG PERSONNEL ON BOARD E. Andrews, M. Strawn, D. Hudgins, D. Muller DAILY COST $3350.00 REPORT BY Mike Strawn Linc Energy Operations, Inc. Umiat DAILY WELLSITE REPORT Umiat #23H REPORT FOR Dave Boyer DATE Feb 18, 2014 DEPTH 382' PRESENT OPERATION Repairing HPU Oil Leak TIME 23:59 YESTERDAY 382' 24 HOUR FOOTAGE 0' CASING INFORMATION 13.375" @ 70' 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 1 9.875" Smith Cone PY6356 4x14 97' In Hole 284' 6.37 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 382 MW 7.8 VIS 58 PV 21 YP 12 FL Gels 10/10/11 CL- 119,000 FC -/1 SOL -3.36 SD OIL 71/29 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 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS No new hole drilled last 24 hours. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Nanushuk PRESENT LITHOLOGY Siltstone 60%, Sandstone 20%, Sand 10%, Shale 10%. DAILY ACTIVITY SUMMARY Working stuck pipe without success, cut and slip drill line, rig up tongs, break down jars, service rig, Shut down HPU to fix leak. CANRIG PERSONNEL ON BOARD E. Andrews, M. Strawn, D. Hudgins, D. Muller DAILY COST $3290.00 REPORT BY Mike Strawn Linc Energy Operations, Inc. Umiat DAILY WELLSITE REPORT Umiat #23H REPORT FOR Dave Boyer DATE Feb 19, 2014 DEPTH 382' PRESENT OPERATION Monitoring Well TIME 23:59 YESTERDAY 382' 24 HOUR FOOTAGE 0' CASING INFORMATION 13.375" @ 70' 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 1 9.875" Smith Cone PY6356 4x14 97' In Hole 284' 6.37 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 382 MW 7.8 VIS 58 PV 21 YP 12 FL Gels 10/10/11 CL- 119,000 FC -/1 SOL -3.36 SD OIL 71/29 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 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS No new hole drilled last 24 hours. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Nanushuk PRESENT LITHOLOGY Siltstone 60%, Sandstone 20%, Sand 10%, Shale 10%. DAILY ACTIVITY SUMMARY Adjust draw works cam, install shaker screen gaskets, build fork pockets for jacking rams, repair shaker jack pump, repair filter hose on #2 HPU, rig up lines to water pump for cement jobs, move radioactive source box to floor, monitor well. CANRIG PERSONNEL ON BOARD E. Andrews, M. Strawn, D. Hudgins, D. Muller DAILY COST $3290.00 REPORT BY Mike Strawn Linc Energy Operations, Inc. Umiat DAILY WELLSITE REPORT Umiat #23H REPORT FOR Dave Boyer DATE Feb 20, 2014 DEPTH 382' PRESENT OPERATION Fishing BHA TIME 23:59 YESTERDAY 382' 24 HOUR FOOTAGE 0' CASING INFORMATION 13.375" @ 70' 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 1 9.875" Smith Cone PY6356 4x14 97' In Hole 284' 6.37 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 382 MW 7.8 VIS 58 PV 21 YP 12 FL Gels 10/10/11 CL- 119,000 FC -/1 SOL -3.36 SD OIL 71/29 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 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS No new hole drilled last 24 hours. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Nanushuk PRESENT LITHOLOGY Siltstone 60%, Sandstone 20%, Sand 10%, Shale 10%. DAILY ACTIVITY SUMMARY Monitor well waiting and warming on wireline unit, rig up wireline fishing tools, fishing nuclear source from hole, rig down Halliburton wireline, rig up for fishing BHA, fishing for BHA. CANRIG PERSONNEL ON BOARD E. Andrews, M. Strawn, D. Hudgins, D. Muller DAILY COST $3290.00 REPORT BY Mike Strawn Linc Energy Operations, Inc. Umiat DAILY WELLSITE REPORT Umiat #23H REPORT FOR Dave Boyer DATE Feb 21, 2014 DEPTH 382' PRESENT OPERATION Making Up BHA TIME 23:59 YESTERDAY 382' 24 HOUR FOOTAGE 0' CASING INFORMATION 13.375" @ 70' 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 1 9.875" Smith Cone PY6356 4x14 97' In Hole 284' 6.37 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 382 MW 7.8 VIS 90 PV 29 YP 10 FL Gels 11/12/13 CL- 35,000 FC -/1 SOL 1.14 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 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS No new hole drilled last 24 hours. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Nanushuk PRESENT LITHOLOGY Siltstone 60%, Sandstone 20%, Sand 10%, Shale 10%. DAILY ACTIVITY SUMMARY Fishing pipe free and establish circulation, circulate and wash, back ream tight spot 310’ to 300’, lay down BHA and fishing tools, service and inspect rig, cut and slip drill line, make up BHA. CANRIG PERSONNEL ON BOARD E. Andrews, M. Strawn, D. Hudgins, D. Muller DAILY COST $3290.00 REPORT BY Mike Strawn Linc Energy Operations, Inc. Umiat DAILY WELLSITE REPORT Umiat #23H REPORT FOR David Boyer DATE Feb 22, 2014 DEPTH 706' PRESENT OPERATION Drilling Ahead TIME 23:59 YESTERDAY 382' 24 HOUR FOOTAGE 324' 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 2151.0 @ 431' 0.4 @ 435' 48.2 63.9 FT/HR SURFACE TORQUE 305 @ 680' 0 @ 385' 84.0 192.6 AMPS WEIGHT ON BIT 19979 @ 629' 0 @ 477' 66.0 15.1 KLBS ROTARY RPM 0 @ 386' 0 @ 385' -12.3 0.0 RPM PUMP PRESSURE 1420 @ 695' 183 @ 382' 836.1 1408.8 PSI DRILLING MUD REPORT DEPTH 583' MW 7.8 VIS 87 PV 25 YP 27 FL Gels 10/11/13 CL- 35,000 FC -/1 SOL 0.76 SD OIL 97/3 MBL pH Ca+ CCI MWD SUMMARY INTERVAL 382' TO 706' TOOLS Directional, Gamma, Resistivity and Mud Motor. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 10 @ 402' 0 @ 530' 0.8 TRIP GAS 0u CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 65 @ 550' 0 @ 530' 3.7 CONNECTION GAS HIGH 0u ETHANE (C-2) 0 @ 706' 0 @ 706' 0.0 AVG 0u PROPANE (C-3) 0 @ 706' 0 @ 706' 0.0 CURRENT 0u BUTANE (C-4) 14 @ 402' 0 @ 530' 0.2 CURRENT BACKGROUND/AVG 0u/1u PENTANE (C-5) 0 @ 706' 0 @ 706' 0.0 HYDROCARBON SHOWS No shows this section. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Nanushuk Formation PRESENT LITHOLOGY Siltstone 70%, Siltstone 30%. DAILY ACTIVITY SUMMARY Pick up BHA and trip in hole, drill ahead from 382’ to 398’, change elevators, drill ahead from 398’ to 583’ sliding to build angle, replace coupler on #2 HPU, slide drill ahead from 583’ to 706’MD. CANRIG PERSONNEL ON BOARD E. Andrews, M. Strawn, D. Hudgins, D. Muller DAILY COST $3290.00 REPORT BY Mike Strawn Linc Energy Operations, Inc. Umiat DAILY WELLSITE REPORT Umiat #23H REPORT FOR David Boyer DATE Feb 23, 2014 DEPTH 1025' PRESENT OPERATION Circulating TIME 22:54:19 YESTERDAY 706' 24 HOUR FOOTAGE 319' CASING INFORMATION 13.375" @ 70' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 695' 20.35 100.33 696.96' 756.65' 24.05 102.56 744.03' 816.85' 27.8 102.22 798.17' 877.5' 31.97 101.41 850.74' 940.63' 35.78 102.69 903.15' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED R1 9.875" Smith Milled Tooth XR+C PY6356 4x14 97' 1025' 928' 33.19 ROP DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 6482.3 @ 1017' 0.8 @ 1000' 46.7 3.8 FT/HR SURFACE TORQUE 396 @ 976' 88 @ 894' 200.8 180.8 AMPS WEIGHT ON BIT 19 @ 718' 10 @ 747' 15.5 16.8 KLBS ROTARY RPM 1 @ 1004' 0 @ 915' 0.0 0.0 RPM PUMP PRESSURE 1531 @ 1006' 1148 @ 961' 1362.4 1398.29004 PSI DRILLING MUD REPORT DEPTH 1024' MW 7.9 VIS 97 PV 27 YP 24 FL Gels 11/12/24 CL- 34,000 FC -/1 SOL 0.84 SD OIL 67/33 MBL pH Ca+ CCI MWD SUMMARY INTERVAL 382' TO 1025' TOOLS Directional, Gamma, Resistivity and Mud Motor. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 54 @ 876' 0 @ 990' 2.8 TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 5380 @ 876' 0 @ 741' 60.0 CONNECTION GAS HIGH 11u ETHANE (C-2) 0 @ 1025' 0 @ 1025' 0.0 AVG 2u PROPANE (C-3) 4 @ 762' 0 @ 801' 0.2 CURRENT 0u BUTANE (C-4) 33 @ 775' 0 @ 801' 3.0 CURRENT BACKGROUND/AVG 8u/3u PENTANE (C-5) 20 @ 774' 0 @ 995' 1.5 HYDROCARBON SHOWS No major shows this section, for minor shows see mud log. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Nanushuk Formation PRESENT LITHOLOGY Saqnd 60%, Sandstone 30%, Siltstone 10%. DAILY ACTIVITY SUMMARY Drilling ahead sliding as needed to build angle from 706’ to 997’MD, back ream from 997’ to 957’MD, slide drilling from 997’ to 1025’MD, condition mud and circulate bottoms up. CANRIG PERSONNEL ON BOARD E. Andrews, M. Strawn, D. Hudgins, D. Muller DAILY COST $3290.00 REPORT BY Mike Strawn Linc Energy Operations, Inc. Umiat DAILY WELLSITE REPORT Umiat #23H REPORT FOR David Boyer DATE Feb 24, 2014 DEPTH 1287' PRESENT OPERATION Drilling Ahead TIME 23:59 YESTERDAY 1025' 24 HOUR FOOTAGE 262' CASING INFORMATION 13.375" @ 70' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 940.63' 35.78 102.69 903.14' 1001.33' 39.29 101.72 951.27' 1063.19' 42.90 101.84 997.88' 1124.00' 47.04 102.39 1040.89' 1186.00' 51.62 102.75 1081.29' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED R1 9.875" Smith Milled Tooth XR+C PY6356 4x14 97' 1025' 928' 33.19 ROP 2 9.875" Smith Milled Tooth XR+C PY6357 4x14 1025' In Hole 262' 10.31 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 143.0 @ 1202' 3.8 @ 1025' 31.7 19.8 FT/HR SURFACE TORQUE 581 @ 1169' 106 @ 1212' 208.8 153.9 AMPS WEIGHT ON BIT 21 @ 1244' 13 @ 1264' 17.2 16.3 KLBS ROTARY RPM 0 @ 1275' 0 @ 1230' 0.1 0.5 RPM PUMP PRESSURE 1582 @ 1279' 1340 @ 1071' 1443.5 1474.0 PSI DRILLING MUD REPORT DEPTH 1285' MW 7.9 VIS 105 PV 33 YP 28 FL Gels 13/15/19 CL- 33,000 FC -/1 SOL 1.5 SD OIL 68/32 MBL pH Ca+ CCI MWD SUMMARY INTERVAL 1025' TO 1287' TOOLS Directional, Gamma, Resistivity and Mud Motor. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 52 @ 1049' 0 @ 1215' 0.4 TRIP GAS 2u CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 6315 @ 1049' 7 @ 1215' 33.2 CONNECTION GAS HIGH 2u ETHANE (C-2) 123 @ 1049' 0 @ 1032' 1.4 AVG 1u PROPANE (C-3) 0 @ 1287' 0 @ 1287' 0.0 CURRENT 0u BUTANE (C-4) 0 @ 1287' 0 @ 1287' 0.0 CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) 7 @ 1025' 0 @ 1032' 0.2 HYDROCARBON SHOWS No major shows this section, for minor shows see mud log. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Torok Formation PRESENT LITHOLOGY Siltstone 100% DAILY ACTIVITY SUMMARY Pull out of hole and lay down BHA#3, pick up BHA#4 and trip in hole, drilling ahead sliding as needed from 1025’ to 1287’ at report time. CANRIG PERSONNEL ON BOARD E. Andrews, M. Strawn, D. Hudgins, D. Muller DAILY COST $3290.00 REPORT BY Mike Strawn Linc Energy Operations, Inc. Umiat DAILY WELLSITE REPORT Umiat #23H REPORT FOR David Boyer DATE Feb 25, 2014 DEPTH 1480' PRESENT OPERATION Drilling Ahead TIME 23:59 YESTERDAY 1287' 24 HOUR FOOTAGE 193' CASING INFORMATION 13.375" @ 70' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1186.00' 51.62 102.75 1081.29' 1247.11' 55.66 102.27 1117.51' 1309.26' 59.89 101.22 1050.64' 1366.30' 63.31 100.97 1177.77' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9.875" Smith Milled Tooth XR+C PY6357 4x14 1025' In Hole 455' 26.8 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 95.5 @ 1384' 0.7 @ 1397' 18.3 23.8 FT/HR SURFACE TORQUE 569 @ 1347' 88 @ 1334' 245.8 181.0 AMPS WEIGHT ON BIT 28 @ 1377' 8 @ 1441' 16.0 15.7 KLBS ROTARY RPM 1 @ 1377' 0 @ 1357' 0.1 0.0 RPM PUMP PRESSURE 1849 @ 1453' 1379 @ 1348' 1546.6 1814.7 PSI DRILLING MUD REPORT DEPTH 1465' MW 8.0 VIS 100 PV 35 YP 21 FL Gels 18/20/23 CL- 33,000 FC -/1 SOL 2.0 SD OIL 67/33 MBL pH Ca+ CCI MWD SUMMARY INTERVAL 1025' TO 1480' TOOLS Directional, Gamma, Resistivity and Mud Motor. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 18 @ 1377' 0 @ 1464' 1.9 TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 307 @ 1356' 0 @ 1456' 28.6 CONNECTION GAS HIGH 3u ETHANE (C-2) 0 @ 1480' 0 @ 1480' 0.0 AVG 1u PROPANE (C-3) 0 @ 1480' 0 @ 1480' 0.0 CURRENT 0u BUTANE (C-4) 0 @ 1480' 0 @ 1480' 0.0 CURRENT BACKGROUND/AVG 1u/2u PENTANE (C-5) 1 @ 1335' 0 @ 1354' 0.1 HYDROCARBON SHOWS No major shows this section, for minor shows see mud log. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Nanushuk PRESENT LITHOLOGY Siltstone 80%, Sandstone 20%. DAILY ACTIVITY SUMMARY Drilling ahead sliding to build angle from 1287’ to 1390’MD, pull out of hole from 1350’ to 1050’ stand back drill pipe and run in hole with heavy weight drill pipe, drill ahead sliding as needed from 1350’ to 1480’MD. CANRIG PERSONNEL ON BOARD E. Andrews, M. Strawn, D. Hudgins, D. Muller DAILY COST $3290.00 REPORT BY Mike Strawn Linc Energy Operations, Inc. Umiat DAILY WELLSITE REPORT Umiat #23H REPORT FOR David Boyer DATE Feb 26, 2014 DEPTH 1712' PRESENT OPERATION Drilling Ahead TIME 23:59 YESTERDAY 1480' 24 HOUR FOOTAGE 232' CASING INFORMATION 13.375" @ 70' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1366.30' 63.31 100.97 1177.80' 1484.27' 66.88 100.80 1202.45' 1484.27' 70.85 100.67 1223.87' 1545.39' 75.24 101.21 1241.69' 1614.33' 80.68 100.19 1256.06' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9.875" Smith Milled Tooth XR+C PY6357 4x14 1025' In Hole 687' 42.54 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 132.3 @ 1622' 0.3 @ 1530' 23.5 6.3 FT/HR SURFACE TORQUE 577 @ 1513' 94 @ 1495' 238.6 199.9 AMPS WEIGHT ON BIT 22 @ 1522' 1 @ 1622' 16.7 19.5 KLBS ROTARY RPM 1 @ 1616' 0 @ 1525' 0.1 0.0 RPM PUMP PRESSURE 1984 @ 1710' 1718 @ 1486' 1794.5 1976.7 PSI DRILLING MUD REPORT DEPTH 1465' MW 8.0 VIS 100 PV 35 YP 21 FL Gels 18/20/23 CL- 33,000 FC -/1 SOL 2.0 SD OIL 67/33 MBL pH Ca+ CCI MWD SUMMARY INTERVAL 1025' TO 1712' TOOLS Directional, Gamma, Resistivity and Mud Motor. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 11 @ 1676' 0 @ 1620' 1.6 TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 623 @ 1654' 3 @ 1620' 84.7 CONNECTION GAS HIGH 0u ETHANE (C-2) 26 @ 1688' 0 @ 1636' 2.4 AVG 0u PROPANE (C-3) 13 @ 1688' 0 @ 1636' 1.3 CURRENT 0u BUTANE (C-4) 8 @ 1689' 0 @ 1671' 0.4 CURRENT BACKGROUND/AVG 4u/2u PENTANE (C-5) 0 @ 1712' 0 @ 1712' 0.0 HYDROCARBON SHOWS No major shows this section, for minor shows see mud log. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Torok Top PRESENT LITHOLOGY Sandstone 70%, Sand 20%, Siltstone 10%. DAILY ACTIVITY SUMMARY Drilling ahead sliding to build angle from 1480’ to 1498’MD, change out liner and swab on mud pump 2, drill ahead sliding as needed to build angle from 1498’ to 1712’MD. CANRIG PERSONNEL ON BOARD E. Andrews, M. Strawn, D Hudgins, D. Muller DAILY COST $3290.00 REPORT BY Mike Strawn Linc Energy Operations, Inc. Umiat DAILY WELLSITE REPORT Umiat #23H REPORT FOR David Boyer DATE Feb 27, 2014 DEPTH 1926' PRESENT OPERATION Drilling Ahead TIME 23:59 YESTERDAY 1712' 24 HOUR FOOTAGE 214' CASING INFORMATION 13.375" @ 70' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1614.33' 80.68 100.19 1256.06' 1703.53' 87.69 99.29 1265.20' 1729.47' 89.09 98.60 1265.92' 1790.82' 89.66 99.81 1266.59' 1852' 90.20 100.00 1266.67' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9.875" Smith Milled Tooth XR+C PY6357 4x14 1025' In Hole 901' 57.2 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 64.2 @ 1758' 1.6 @ 1913' 17.9 24.2 FT/HR SURFACE TORQUE 634 @ 1862' 136 @ 1904' 373.2 472.2 AMPS WEIGHT ON BIT 24 @ 1879' 12 @ 1925' 17.8 12.4 KLBS ROTARY RPM 0 @ 1926' 0 @ 1926' 0.0 0.0 RPM PUMP PRESSURE 2058 @ 1857' 703 @ 1787' 1914.6 1909.4 PSI DRILLING MUD REPORT DEPTH 1713' MW 8.0 VIS 88 PV 32 YP 22 FL Gels 9/11/12 CL- 29,000 FC -/1 SOL 2.0 SD OIL 70/30 MBL pH Ca+ CCI MWD SUMMARY INTERVAL 1025' TO 1926' TOOLS Directional, Gamma, Resistivity and Mud Motor. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 17 @ 1836' 0 @ 1754' 2.8 TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 2246 @ 1844' 4 @ 1823' 284.2 CONNECTION GAS HIGH 6u ETHANE (C-2) 77 @ 1844' 0 @ 1772' 5.0 AVG 2u PROPANE (C-3) 33 @ 1891' 0 @ 1772' 3.7 CURRENT 1u BUTANE (C-4) 9 @ 1844' 0 @ 1823' 0.3 CURRENT BACKGROUND/AVG 10u/3u PENTANE (C-5) 47 @ 1891' 0 @ 1881' 4.4 HYDROCARBON SHOWS No major shows this section, for minor shows see mud log. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Torok Top PRESENT LITHOLOGY Sandstone 70%, Sand 20%, Siltstone 10%. DAILY ACTIVITY SUMMARY Drilling ahead sliding as needed to build angle from 1712’ to 1787’MD, repair mud pump 2, drill ahead sliding as needed to build angle from 1787’ to 1926’MD. CANRIG PERSONNEL ON BOARD E. Andrews, M. Strawn, D. Hudgins, D. Muller DAILY COST $3290.00 REPORT BY Mike Strawn Linc Energy Operations, Inc. Umiat DAILY WELLSITE REPORT Umiat #23H REPORT FOR David Boyer DATE Feb 28, 2014 DEPTH 1980' PRESENT OPERATION Rigging Up Tongs TIME 23:59 YESTERDAY 1926' 24 HOUR FOOTAGE 54' CASING INFORMATION 13.375" @ 70' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1852.00' 90.20 100.00 1266.67' 1926.00' 95.50 99.00 1263.03' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9.875" Smith Milled Tooth XR+C PY6357 4x14 1025' 1980' 955' 61.33 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 61.2 @ 1977' 1.0 @ 1947' 20.1 46.9 FT/HR SURFACE TORQUE 643 @ 1938' 129 @ 1942' 450.3 565.3 AMPS WEIGHT ON BIT 23 @ 1927' 12 @ 1926' 18.0 19.1 KLBS ROTARY RPM 1 @ 1935' 0 @ 1963' 0.1 0.0 RPM PUMP PRESSURE 1950 @ 1931' 1856 @ 1971' 1926.9 1891.1 PSI DRILLING MUD REPORT DEPTH 1927' MW 8.1 VIS 105 PV 29 YP 21 FL Gels 11/12/14 CL- 27,000 FC -/1 SOL 2.25 SD OIL 70/30 MBL pH Ca+ CCI MWD SUMMARY INTERVAL 1025' TO 1980' TOOLS Directional, Gamma, Resistivity and Mud Motor. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 12 @ 1947' 0 @ 1971' 5.9 TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 408 @ 1958' 24 @ 1971' 166.1 CONNECTION GAS HIGH 1u ETHANE (C-2) 11 @ 1958' 0 @ 1970' 3.6 AVG 1u PROPANE (C-3) 7 @ 1952' 0 @ 1970' 2.3 CURRENT 1u BUTANE (C-4) 0 @ 1980' 0 @ 1980' 0.0 CURRENT BACKGROUND/AVG 0u/6u PENTANE (C-5) 3 @ 1926' 0 @ 1970' 1.8 HYDROCARBON SHOWS No major shows this section, for minor shows see mud log. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Torok Top PRESENT LITHOLOGY Sandstone 70%, Siltstone 20%, Sand 10%. DAILY ACTIVITY SUMMARY Drilling ahead sliding as needed to build angle from 1926’ to 1980’MD, circulate bottoms up, back ream 1980’ to 850’MD, pull out of hole and lay down BHA, service rig and replace rotation sensor damaged while jarring on 2/17/2014, start rigging up tongs. CANRIG PERSONNEL ON BOARD E. Andrews, M. Strawn, D. Hudgins, D. Muller DAILY COST $3290.00 REPORT BY Mike Strawn Linc Energy Operations, Inc. Umiat DAILY WELLSITE REPORT Umiat #23H REPORT FOR David Boyer DATE Mar 01, 2014 DEPTH 1980' PRESENT OPERATION Laying Down BHA TIME 23:59 YESTERDAY 1980' 24 HOUR FOOTAGE 0' CASING INFORMATION 13.375" @ 70' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1904.56' 93.66 99.01 1264.93' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9.875" Smith Milled ToothXR+C PY63574x14 1025' 1980' 955' 61.33 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 1980' MW 8.0 VIS 85 PV 27 YP 17 FL Gels 10/11/12 CL- 24,000 FC -/- SOL 1.17 SD OIL 72/28 MBL pH Ca+ CCI MWD SUMMARY INTERVAL 1025' TO 1980' TOOLS Directional, Gamma, Resistivity and Mud Motor. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 13u 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 0u/3u (when Circulating) PENTANE (C-5) @ @ HYDROCARBON SHOWS No new hole drilled last 24 hours. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Torok Top PRESENT LITHOLOGY Sandstone 70%, Siltstone 20%, Sand 10%. DAILY ACTIVITY SUMMARY Pick up BHA#5, trip in hole to 373’ and test MWD tools, trip in hole to 1980’MD, pull out of hole logging and lay down BHA. CANRIG PERSONNEL ON BOARD E. Andrews, M. Strawn, D. Hudgins, D. Muller DAILY COST $32290.00 REPORT BY Mike Strawn Linc Energy Operations, Inc. Umiat DAILY WELLSITE REPORT Umiat #23H REPORT FOR David Boyer DATE Mar 02, 2014 DEPTH 1980' PRESENT OPERATION Circulating TIME 23:59 YESTERDAY 1980' 24 HOUR FOOTAGE 0' CASING INFORMATION 13.375" @ 70' 7.625" @ 1968' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1904.56' 93.66 99.01 1264.93' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9.875" Smith Milled ToothXR+C PY63574x14 1025' 1980' 955' 61.33 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 1980' MW 8.0 VIS 86 PV 28 YP 17 FL Gels 10/11/11 CL- 23,000 FC -/- SOL 1.2 SD OIL 76/24 MBL pH Ca+ CCI MWD SUMMARY INTERVAL 1025' TO 1980' TOOLS Directional, Gamma, Resistivity and Mud Motor. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 17u 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 0u/3u (when Circulating) PENTANE (C-5) @ @ HYDROCARBON SHOWS No new hole drilled last 24 hours. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Torok Top PRESENT LITHOLOGY Sandstone 70%, Siltstone 20%, Sand 10%. DAILY ACTIVITY SUMMARY Lay down BHA, clean and service rig, rig up to run 7.625” casing, pick up and test float equipment, run in hole with 7.625” casing to 1480’MD, establish circulation and continue to run in hole to set casing @ 1968’MD, circulate and condition mud. CANRIG PERSONNEL ON BOARD E. Andrews, M. Strawn, D. Hudgins, D. Muller DAILY COST $32290.00 REPORT BY Mike Strawn Linc Energy Operations, Inc. Umiat DAILY WELLSITE REPORT Umiat #23H REPORT FOR David Boyer DATE Mar 03, 2014 DEPTH 1980' PRESENT OPERATION Nippling Up BOP's TIME 23:59 YESTERDAY 1980' 24 HOUR FOOTAGE 0' CASING INFORMATION 13.375" @ 70' 7.625" @ 1974' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1904.56' 93.66 99.01 1264.93' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9.875" Smith Milled ToothXR+C PY63574x14 1025' 1980' 955' 61.33 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 1980' MW 8.0 VIS 82 PV 30 YP 15 FL Gels 10/11/11 CL- 22,000 FC -/- SOL 1.25 SD OIL 76/24 MBL pH Ca+ CCI MWD SUMMARY INTERVAL 1025' TO 1980' TOOLS Directional, Gamma, Resistivity and Mud Motor. 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 0u/0u (when Circulating) PENTANE (C-5) @ @ HYDROCARBON SHOWS No new hole drilled last 24 hours. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Torok Top PRESENT LITHOLOGY Sandstone 70%, Siltstone 20%, Sand 10%. DAILY ACTIVITY SUMMARY Circulate and condition mud, pressure test lines, cement, displace cement, pressure up to 1500 psi for 15 min. and bleed off pressure (floats holding), blow down lines and rig down circulation equipment, rig down cement equipment, set pack off, nipple down stack, start nippling up BOP’s. CANRIG PERSONNEL ON BOARD E. Andrews, M. Strawn, D. Hudgins, D. Muller DAILY COST $3290.00 REPORT BY Mike Strawn Linc Energy Operations, Inc. Umiat DAILY WELLSITE REPORT Umiat #23H REPORT FOR David Boyer DATE Mar 04, 2014 DEPTH 1980' PRESENT OPERATION Testing Gas Alarms TIME 23:59 YESTERDAY 1980' 24 HOUR FOOTAGE 0' CASING INFORMATION 13.375" @ 70' 7.625" @ 1974' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1904.56' 93.66 99.01 1264.93' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9.875" Smith Milled ToothXR+C PY63574x14 1025' 1980' 955' 61.33 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 1980' MW 8.0 VIS 80 PV 27 YP 23 FL Gels 10/11/11 CL- 22,000 FC -/1 SOL 1.24 SD OIL 76/24 MBL pH Ca+ CCI MWD SUMMARY INTERVAL 1025' TO 1980' TOOLS Directional, Gamma, Resistivity and Mud Motor. 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 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS No new hole drilled last 24 hours. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Torok Top PRESENT LITHOLOGY Sandstone 70%, Siltstone 20%, Sand 10%. DAILY ACTIVITY SUMMARY Nippling up BOP’s, setting stack on casing, installing stand pipe and kill line manifold, cleaning pits, loading drill pipe in pipe shed, installing rotary table and mouse hole, cleaning cellar, hook up koomie lines, change out saver sub and grab dies and testing gas alarms. CANRIG PERSONNEL ON BOARD E. Andrews, M. Strawn, D. Hudgins, D. Muller DAILY COST $3290.00 REPORT BY Mike Strawn Linc Energy Operations, Inc. Umiat DAILY WELLSITE REPORT Umiat #23H REPORT FOR David Boyer DATE Mar 05, 2014 DEPTH 1980' PRESENT OPERATION Rigging Up for BOP Test TIME 23:59 YESTERDAY 1980' 24 HOUR FOOTAGE 0' CASING INFORMATION 13.375" @ 70' 7.625" @ 1974' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1904.56' 93.66 99.01 1264.93' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9.875" Smith Milled ToothXR+C PY63574x14 1025' 1980' 955' 61.33 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 1980' MW 8.0 VIS 88 PV 26 YP 23 FL Gels 9/10/10 CL- 22,000 FC -/- SOL 1.28 SD OIL 76/24 MBL pH Ca+ CCI MWD SUMMARY INTERVAL 1025' TO 1980' TOOLS Directional, Gamma, Resistivity and Mud Motor. 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 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS No new hole drilled last 24 hours. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Torok Top PRESENT LITHOLOGY Sandstone 70%, Siltstone 20%, Sand 10%. DAILY ACTIVITY SUMMARY Cleaning and servicing rig, laying down 4.5” drill pipe, cleaning drill pipe, changing out elevator inserts, rigging up BOP test equipment. CANRIG PERSONNEL ON BOARD E. Andrews, M. Strawn, D. Hudgins, D. Muller DAILY COST $3290.00 REPORT BY Mike Strawn Linc Energy Operations, Inc. Umiat DAILY WELLSITE REPORT Umiat #23H REPORT FOR David Boyer DATE Mar 06, 2014 DEPTH 1980' PRESENT OPERATION Tripping In Hole TIME 23:59 YESTERDAY 1980' 24 HOUR FOOTAGE 0' CASING INFORMATION 13.375" @ 70' 7.625" @ 1974' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1904.56' 93.66 99.01 1264.93' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9.875" Smith Milled ToothXR+C PY63574x14 4x14 1025' 1980' 955' 61.33 TD 3 6.75" Smith PDC JH6590 1980' In Hole 0' 0.0 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 1980' MW 8.0 VIS 88 PV 31 YP 11 FL Gels 9/10/11 CL- 22,000 FC -/- SOL 1.28 SD OIL 76/24 MBL pH Ca+ CCI MWD SUMMARY INTERVAL 1025' TO 1980' TOOLS Directional, Gamma, Resistivity and Mud Motor. 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 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS No new hole drilled last 24 hours. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Torok Top PRESENT LITHOLOGY Sandstone 70%, Siltstone 20%, Sand 10%. DAILY ACTIVITY SUMMARY Testing BOP’s, installing flow and fill up lines, installing wear bushing, laying down test joint, thawing Kelly hose, installing Kelly hose, picking up drill pipe, servicing rig, made up/picked up BHA, started tripping in hole to 1786’MD. CANRIG PERSONNEL ON BOARD E. Andrews, M. Strawn, D. Hudgins, D. Muller DAILY COST $3290.00 REPORT BY Mike Strawn Linc Energy Operations, Inc. Umiat DAILY WELLSITE REPORT Umiat #23H REPORT FOR David Boyer DATE Mar 07, 2014 DEPTH 2193' PRESENT OPERATION Drilling Ahead TIME 23:59 YESTERDAY 1980' 24 HOUR FOOTAGE 213' CASING INFORMATION 7.625" @ 1974 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1904.56' 93.66 99.01 1264.87' 1997.52' 96.91 97.99 1256.31' 2060.57' 101.72 98.39 1246.11' 2123.61' 106.20 97.94 1230.90' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.75" Smith PDC JH6590 5x11 1980' In Hole 213' 5.2 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 132.9 @ 2113' 16.5 @ 2035' 76.6 50.8 FT/HR SURFACE TORQUE 565 @ 1980' 152 @ 1998' 260.2 343.6 AMPS WEIGHT ON BIT 19 @ 1980' 3 @ 2102' 5.7 8.6 KLBS ROTARY RPM 102 @ 2075' 47 @ 2030' 70.2 51.8 RPM PUMP PRESSURE 1891 @ 1980' 978 @ 2077' 1660.2 1748.0 PSI DRILLING MUD REPORT DEPTH 1980' MW 8.0 VIS 86 PV 31 YP 11 FL Gels 9/10/11 CL- 22,000 FC -/- SOL 1.28 SD OIL 76/24 MBL pH Ca+ CCI MWD SUMMARY INTERVAL 1980' TO 2193' TOOLS Directional, Power Drive, Gamma and Resistivity. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 11 @ 2000' 0 @ 2082' 4.6 TRIP GAS 11u @ Shoe CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 597 @ 2101' 5 @ 2041' 157.7 CONNECTION GAS HIGH 1u ETHANE (C-2) 0 @ 2193' 0 @ 2193' 0.0 AVG 1u PROPANE (C-3) 9 @ 2034' 0 @ 2082' 0.5 CURRENT 1u BUTANE (C-4) 0 @ 2193' 0 @ 2193' 0.0 CURRENT BACKGROUND/AVG 6u/5u PENTANE (C-5) 21 @ 2097' 0 @ 2082' 5.5 HYDROCARBON SHOWS No major shows this section, for minor shows see mud log. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Nanushuk PRESENT LITHOLOGY Siltstone 70%, Sandstone 30%. DAILY ACTIVITY SUMMARY Wash down to tag cement @ 1876’, drill shoe and 20’ of formation to 2000’MD, condition mud and circulate bottoms up until shakers clean, conduct FIT, clean and fill pits, service rig, displace mud, clean flow trough and pits 5&6, transfer new mud and change shaker screens, drilling ahead with steerable bit from 2000’ to 2193’MD. CANRIG PERSONNEL ON BOARD E. Andrews, M. Strawn, D. Hudgins, D. Muller DAILY COST $3290.00 REPORT BY Mike Strawn Linc Energy Operations, Inc. Umiat DAILY WELLSITE REPORT Umiat #23H REPORT FOR David Boyer DATE Mar 08, 2014 DEPTH 2964' PRESENT OPERATION Drilling Ahead TIME 23:59 YESTERDAY 2193' 24 HOUR FOOTAGE 771' CASING INFORMATION 7.625" @ 1974' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2629.40' 106.29 100.09 1060.78' 2689.28' 103.91 99.20 1045.18' 2756.28' 101.10 98.96 1030.68' 2816.14' 101.07 99.75 1019.17' 2881.28' 100.68 100.68 1006.88' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.75" Smith PDC JH6590 5x11 1980' In Hole 984' 16.25 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 4831.7 @ 2598' 0.4 @ 2576' 97.2 58.0 FT/HR SURFACE TORQUE 564 @ 2932' 171 @ 2853' 411.9 533.8 AMPS WEIGHT ON BIT 16 @ 2853' 0 @ 2294' 5.0 4.47 KLBS ROTARY RPM 198 @ 2946' 51 @ 2193' 144.8 197.4 RPM PUMP PRESSURE 1927 @ 2829' 925 @ 2603' 1699.0 1863.3 PSI DRILLING MUD REPORT DEPTH 2000' MW 7.3 VIS 50 PV 15 YP 10 FL Gels 6/6/7 CL- FC -/1 SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 1980' TO 2964' TOOLS Directional, Power Drive, Gamma and Resistivity. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 28 @ 2335.00000 0 @ 2593.00000 8.5 TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 3758 @ 2640.00000 0 @ 2593.00000 327.3 CONNECTION GAS HIGH 11u ETHANE (C-2) 76 @ 2641.00000 0 @ 2501.00000 7.9 AVG 3u PROPANE (C-3) 35 @ 2849.00000 0 @ 2727.00000 2.2 CURRENT 9u BUTANE (C-4) 36 @ 2311.00000 0 @ 2819.00000 3.0 CURRENT BACKGROUND/AVG 7u/9u PENTANE (C-5) 21 @ 2195.00000 0 @ 2761.00000 2.7 HYDROCARBON SHOWS No major shows this section, for minor shows see mud log. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Nanushuk PRESENT LITHOLOGY Sand 80%, Sandstone 20%. DAILY ACTIVITY SUMMARY Drilling ahead from 2193’ to 2964’MD. CANRIG PERSONNEL ON BOARD E. Andrews, M. Strawn, D. Hudgins, D. Muller DAILY COST $3290.00 REPORT BY Mike Strawn Linc Energy Operations, Inc. Umiat DAILY WELLSITE REPORT Umiat #23H REPORT FOR David Boyer DATE Mar 09, 2014 DEPTH 3998' PRESENT OPERATION Drilling Ahead TIME 23:59 YESTERDAY 2964' 24 HOUR FOOTAGE 1034' CASING INFORMATION 7.625" @ 1974' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 3639.35' 88.59 101.61 983.34' 3706.00' 88.56 101.16 984.99' 3769.36' 90.00 101.06 985.78' 3832.73' 90.14 101.13 985.71' 3895.68' 89.48 100.30 985.92' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.75" Smith PDC JH6590 5x11 1980' In Hole 2018' 30.52 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 21441.2 @ 3346' 2.3 @ 3241' 129.4 0.0' FT/HR SURFACE TORQUE 615 @ 3940' 83 @ 3358' 506.5 578.7 AMPS WEIGHT ON BIT 16 @ 3110' 0 @ 3558' 5.0 5.7 KLBS ROTARY RPM 197 @ 2964' 0 @ 3358' 163.9 171.4 RPM PUMP PRESSURE 2106 @ 3210' 246 @ 3426' 1869.7 2089.7 PSI DRILLING MUD REPORT DEPTH 3995'MD MW 7.8 VIS 62 PV 20 YP 14 FL Gels 11/12/13 CL- 1,700 FC SOL 4 SD OIL 100/0 MBL pH Ca+ CCI MWD SUMMARY INTERVAL 1980' TO 3998' TOOLS Directional, Power Drive, Gamma and Resistivity. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 16 @ 3726' 0 @ 3162' 6.0 TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 3455 @ 3688' 3 @ 3321' 624.5 CONNECTION GAS HIGH 10u ETHANE (C-2) 115 @ 3056' 0 @ 3264' 23.9 AVG 3u PROPANE (C-3) 41 @ 3688' 0 @ 3097' 6.8 CURRENT 1u BUTANE (C-4) 67 @ 3056' 0 @ 3142' 8.7 CURRENT BACKGROUND/AVG 2u/6u PENTANE (C-5) 41 @ 3056' 0 @ 3264' 5.3 HYDROCARBON SHOWS No major shows this section, for minor shows see mud log. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Nanushuk Lower Grandstand PRESENT LITHOLOGY Sand 90%, Sandstone 10%. DAILY ACTIVITY SUMMARY Drilling ahead from 2964’ to 3998’MD. CANRIG PERSONNEL ON BOARD E. Andrews, M. Strawn, D. Hudgins, D. Muller DAILY COST $3290.00 REPORT BY Mike Strawn Linc Energy Operations, Inc. Umiat DAILY WELLSITE REPORT Umiat #23H REPORT FOR David Boyer DATE Mar 10, 2014 DEPTH 4100' PRESENT OPERATION Circulating TIME 23:59 YESTERDAY 3998' 24 HOUR FOOTAGE 102' CASING INFORMATION 7.625" @ 1974' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 3895.68' 89.48 100.30 985.92' 3952.31' 90.03 99.83 986.18' 4017.89' 90.07 98.83 986.12' 4062.62' 90.00 99.48 986.09' 4100 90.00 99.48 986.09' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.75" Smith PDC JH6590 5x11 1980' 4100' 2120' 32.75 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 2098.0 @ 4061' 5.3 @ 4091' 84.1 25.2 FT/HR SURFACE TORQUE 612 @ 4063' 139 @ 3999' 561.2 468.6 AMPS WEIGHT ON BIT 7 @ 4093' 0 @ 4100' 4.4 0.1 KLBS ROTARY RPM 182 @ 4094' 17 @ 4093' 165.6 164.8 RPM PUMP PRESSURE 2187 @ 4100' 1556 @ 4035' 1961.1 2187.3 PSI DRILLING MUD REPORT DEPTH 39956' MW 7.87 VIS 62 PV 20 YP 14 FL Gels 11/12/13 CL- 1,700 FC SOL 4 SD OIL 100/0 MBL pH Ca+ CCI MWD SUMMARY INTERVAL 1980' TO 4100' TOOLS Directional, Power Drive, Gamma and Resistivity. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 11 @ 4029' 1 @ 4099' 6.9 TRIP GAS N/A CUTTING GAS @ @ WIPER GAS 5u CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 2503 @ 4029' 110 @ 4099' 1307.8 CONNECTION GAS HIGH 2u ETHANE (C-2) 89 @ 4034' 5 @ 4099' 47.2 AVG 2u PROPANE (C-3) 33 @ 4029' 2 @ 4099' 18.1 CURRENT 1u BUTANE (C-4) 33 @ 4034' 0 @ 4099' 17.4 CURRENT BACKGROUND/AVG 0u/7u PENTANE (C-5) 27 @ 4029' 1 @ 4099' 14.3 HYDROCARBON SHOWS No major shows this section, for minor shows see mud log. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Lower Grandstand PRESENT LITHOLOGY Sand 90%, Sandstone 10%. DAILY ACTIVITY SUMMARY Drilling ahead from 3998 to 4100’MD, circulated bottoms up, pulled out of hole pumping from 4100’ to 775’, circulated bottoms up four times, serviced rig, tripped in hole for wiper trip to bottom, circulating and conditioning mud. CANRIG PERSONNEL ON BOARD E. Andrews, M. Strawn, D. Hudgins, D. Muller DAILY COST $3290.00 REPORT BY Mike Strawn Linc Energy Operations, Inc. Umiat DAILY WELLSITE REPORT Umiat #23H REPORT FOR David Boyer DATE Mar 11, 2014 DEPTH 4100' PRESENT OPERATION Monitoring Well TIME 23:59 YESTERDAY 4100' 24 HOUR FOOTAGE 0' CASING INFORMATION 7.625" @ 1974' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4062.62' 90.00 99.48 986.09' 4100.00' 90.00 99.48 986.09' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.75" Smith PDC JH6590 5x11 1980' 4100' 2120' 32.75 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 4100' MW 7.7 VIS 64 PV 19 YP 21 FL Gels 13/15/17 CL- 1,500 FC SOL 4 SD OIL 99/1 MBL pH Ca+ CCI MWD SUMMARY INTERVAL 1980' TO 4100' TOOLS Directional, Power Drive, Gamma and Resistivity. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 12u 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 0u/1u (when Circulating) PENTANE (C-5) @ @ HYDROCARBON SHOWS No new hole drilled last 24 hours. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Lower Grandstand PRESENT LITHOLOGY Sand 90%, Sandstone 10%. DAILY ACTIVITY SUMMARY Reaming out of hole from bottom to 700’MD, trouble shooting generators #1&2, cutting and slipping drill line, pulling out of hole from 700’ to surface laying down BHA and MWD tools, rigging up to run 4.5” liner, monitoring well. CANRIG PERSONNEL ON BOARD E. Andrews, M. Strawn, D. Hudgins, D. Muller DAILY COST $3290.00 REPORT BY Mike Strawn Linc Energy Operations, Inc. Umiat DAILY WELLSITE REPORT Umiat #23H REPORT FOR David Boyer DATE Mar 12, 2014 DEPTH 4100' PRESENT OPERATION Running In Hole With Liner TIME 23:59 YESTERDAY 4100' 24 HOUR FOOTAGE 0' CASING INFORMATION 7.625" @ 1974' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4062.62' 90.00 99.48 986.09' 4100.00' 90.00 99.48 986.09' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.75" Smith PDC JH6590 5x11 1980' 4100' 2120' 32.75 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 4100' MW 7.8 VIS 72 PV 20 YP 19 FL Gels 13/14/16 CL- 1,600 FC SOL 3.94 SD OIL 99/1 MBL pH Ca+ CCI MWD SUMMARY INTERVAL 1980' TO 4100' TOOLS Directional, Power Drive, Gamma and Resistivity. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 12u 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 0u/1u (when Circulating) PENTANE (C-5) @ @ HYDROCARBON SHOWS No new hole drilled last 24 hours. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Lower Grandstand PRESENT LITHOLOGY Sand 90%, Sandstone 10%. DAILY ACTIVITY SUMMARY Running in hole with 4.5” slotted liner from surface to 2161’MD, rig down from running liner, picking up and rigging up equipment for 2.375” tubing, running in hole with 2.725” tubing to 2100’, stab in seal sub and tag at 2131’, rig down from running tubing, pick up 1 stand drill pipe and circulate at 2196’, run in hole with drill pipe and liner to 3617’MD. CANRIG PERSONNEL ON BOARD E. Andrews, M. Strawn, D. Hudgins, D. Muller DAILY COST $3290.00 REPORT BY Mike Strawn
