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216-055
THE STATE 4A,-,.LASKA Crystal Smith GOVLRNOR NIIKL MTNI.HAV)' December 1, 2020 John L. Hendrix L l (p -d55 Alaska Oil and Gas Conservation Commission 333 west Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a ogc c.o la ska.gov Preparedness & Response Region Manager CEO & President Dept. of Environmental Conservation Furie Operating Alaska, LLC Division of Spill Prevention and Response 188 W Northern Lights Blvd, Suite 620 555 Cordova Street Anchorage, AK 99503 Anchorage, AK 99501 Re: Request for determination that Furie Operating Alaska, LLC's wells are incapable of flowing oil to the ground surface Dear Ms. Smith and Mr. Hendrix: By letter dated November 5, 2020, Furie Operating Alaska, LLC (Furie) requested that the Alaska Oil and Gas Conservation Commission (AOGCC) make a determination that none of their operated wells is capable of flowing liquid hydrocarbons to the ground surface. AS 31.05.0300 Under AS 31.05.030(1), the Commission is authorized to determine whether an operator of a natural gas exploration facility has demonstrated with reasonable certainty that its well or wells will not penetrate a formation capable of flowing oil to the ground surface. Such a determination results in the exemption of wells at the natural gas exploration facility from the requirements of AS 46.04.030 and AS 46.04.040. Furie has requested such a determination. Furie's current activities in the Kitchen Lights Unit (KLU) fit the definition of a "natural gas production facility" as defined in AS 46.04.050(b) and not the definition of "natural gas exploration facility found in AS 46.04.050(c) because Furie is engaged in regular production of natural gas from the Julius R. Platform in the Cook Inlet. Since Furie's operations do not involve a "natural gas exploration facility" the AOGCC cannot make a determination under AS 31.05.030(1). However, AOGCC provides this review of Furie's drilling and production operations to the Alaska Department of Environmental Conservation for its consideration. Crystal Smith and John L. Hendrix December 1, 2020 Page 2 of 2 KLU Exploration and Development Well Drillin¢ History Furie's' initial exploration activities in the KLU were to search for oil and gas. During the exploration program, a total of six exploratory wells were drilled. The wells and their current status are listed below: Well Status2 KLU 1 Suspended KLU 2 Plugged and abandoned KLU 2A Suspended KLU 3 Converted to a development well and currently producing KLU 4 Suspended KLU 5 Plugged and abandoned In addition to the six exploratory wells listed above, Furie has drilled an additional four development wells. These wells and their current status are listed below: Well Status KLU AA Producing KLU A-2 Plugged and abandoned KLU A -2A Producing KLU A-4 Producing Potential for Flowing Liauid Hydrocarbons to the Ground Surface After review of well records and production data, the AOGCC concludes that it is reasonably certain that none of the Furie-operated wells in the KLU are capable of flowing liquid hydrocarbons to the ground surface. Generally speaking, in the Cook Inlet Basin oil production is not possible from the Upper Tyonek and shallower formations. The only KLU well drilled deep enough to encounter the Lower Tyonek and deeper potentially oil-bearing formations was the KLU 1 exploration well, but data from that well do not indicate the presence of producible liquid hydrocarbons. KLU 1 was subsequently plugged with multiple downhole plugs making it incapable of flowing at all even if producible liquid hydrocarbons had been discovered. Likewise, even though they didn't penetrate potential oil-bearing formations, the KLU 2, 2A, 4, 5, and A-2 wells have also been rendered incapable of any production due to the setting of downhole and surface plugs in the wells. None of the four remaining wells, all of which are currently in production, has ever shown any production of liquid hydrocarbon, nor is there any data in the well records for these wells showing that they encountered any producible liquid hydrocarbons. ' The initial exploration well in the KLU (KLU #1) was drilled by Escopeta Oil Company, LLC, but Furie is now operator of this and all wells in the KLU. 1 The three wells listed as suspended have all the necessary downhole plugs and surface plugs that would be required to plug and abandon the well, but the casing has not been cut off below the mudline as required by AOGCC regulations so they cannot be classified as plugged and abandoned. Crystal Smith and John L. Hendrix December 1, 2020 Page 2 of 2 Conclusion After careful review of the production and well data for the KLU wells, the AOGCC concludes that it is reasonably certain that none of the wells that Furie operates is capable of flowing liquid hydrocarbons to the ground surface. Please contact Mr. Dave Roby (at dave.roby(i alaska.eov or 793-1232) if you have questions concerning this determination. Digitnnysigned Jeremy by Jeremy M. Digitally signed by Nice Jessie L. M. PricewtE 2920.1241 DigltMy Agned by Daniel T. Jessie L Chmielowski 11:0345 -09'W' D,MAT.Seamcuetl,. Date: zo2o.12.01 Chmielowski Date'"I" 9, Seamount, Jr. 11.26:92-09'99' 19:19,." v or Jeremy M. Price Commissioner, Chair cc: Laurie Silfven, DEC Daniel T. Seamount, Jr. Jessie L. Chmielowski Commissioner Commissioner As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in pan within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days ifthe Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.090(b), "[tlhe questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. FRATIf� RIE i0r0;o OPEALASKA LLC RECEIVED November 5, 2020 I;OV 0 6 2020 Alaska Oil and Gas Conservation Commission A0GCC 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 RE: Determination to Request that all FURIE's KLU wells are compliant with AS 31.05.030(1) Dear Chairman Price, Furie Operating Alaska LLC (FURZE) is requesting AOGCC's determination to eliminate the Alaska Department of Environmental Conservation (ADEC)'s requirement for an oil discharge prevention and contingency plan and corresponding proof of financial responsibility placed on Furie under previous ownership. Furie Operating Alaska, LLC submits this letter requesting a determination from AOGCC that all of the producing wells (Table 1) in FURIE's Cook Inlet Kitchen Lights Unit (KLU) produce only natural gas from the Beluga and Sterling formations, with no co -production of liquid hydrocarbons or oil. FURIE also requests determination that there are no wells currently capable of oil or liquid hydrocarbon production from the Tyonek or deeper formations based on the following: • Oil commodity economics are not favorable for the foreseeable future and FURIE has suspended plans to explore and develop deeper, potentially oil-bearing horizons. There are no oil-bearing strata nor oil shows identified within the Beluga and Sterling formations within the 4 producing wellbores (KLU #A-1, KLU #A -2A, KLU #3, and KLU #A-4). There are no other FURIE wells capable of hydrocarbon production. • All producing wells are plugged back to the base of the gas producing Beluga formation. There are currently no producible penetrations of the potentially oil bearing upper or lower Tyonek, nor the Hemlock -Sunfish formations in any of the above noted producing gas wells. There were no tests of liquid hydrocarbons below the top of the Tyonek in any FURIE wells. Three unsuccessful exploratory wells (KLU #4, KLU #2, KLU #1) were drilled, but not tested on company leases and are cemented back to sea floor (Table 2). Two wells (KLU #4, KLU #2) reached total depth within the base of the Beluga formation and did not penetrate deeper potentially oil bearing Tyonek or Hemlock formations. A third well (KLU #1) was a deep exploratory test that terminated in the Tyonek. KLU #1 did not encounter producible hydrocarbons and has been cemented. The open hole portion of the well was plugged back with cement from 15,298' to 13,108' MD, inside 9-7/8" casing shoe located at 13,383' MD. All perforations and productive intervals were cemented with top of uppermost cement plug at 325' MD, 122' below seafloor with 13-3/8" cap installed. All cement plugs were set in place per AOGCC P&A requirements. FURIE requests the AOGCC determination that we are natural gas producer only and, as such, are compliant with AS 31.05.030 and do not have any wells capable of flowing oil or liquid hydrocarbons to the ground surface. (a) AS 31 05 030 (1) that evidence obtained through evaluation demonstrates with reasonable certainty that all of the wells at a natural gas exploration facility will not penetrate a formation capable of flowing oil to the ground surface. If the drilling of a well at an exploration facility exempted under this subsection does penetrate a formation capable of flowing oil to the surface, the owner or operator shall submit an oil discharge prevention and contingency plan and proof of financial responsibility to the department to meet the requirements of AS 46.04.030 and 46.04.040. Finally, FURIE also requests a determination/confirmation that the FURIE KLU production platform and onshore facility produce and process natural gas only, with no capacity to produce or transport liquid hydrocarbons or oil. AS 46.04.050. Exemptions. (a) The provisions of AS 46.04.030 , 46.04.040, and 46.04.060 do not apply to an oil terminal facility that has an effective storage capacity of less than 5,000 barrels of crude oil or less than 10,000 barrels of non -crude oil. (b) The provisions of AS 46.04.030 and 46.04.040 do not apply to a natural gas production facility and a natural gas terminal facility; for purposes of this subsection, "natural gas production facility" and 'natural gas terminal facility" mean a platform, facility, or structure that, except for storage of refined petroleum products in a quantity that does not exceed 10,000 barrels, is used solely for the production, compression, storage, or transport of natural gas. (c) The provisions of AS 46.04.030 and 46.04.040 do not apply to a natural gas exploration facility if the Alaska Oil and Gas Conservation Commission has determined under AS 31.05.030 (1) that evidence obtained through evaluation demonstrates with reasonable certainty that all of the wells at a natural gas exploration facility will not penetrate a formation capable of flowing oil to the ground surface. If the drilling of a well at an exploration facility exempted under this subsection does penetrate a formation capable of flowing oil to the surface, the owner or operator shall submit an oil discharge prevention and contingency plan and proof of financial responsibility to the department to meet the requirements of AS 46.04.030 and 46.04.040. For purposes of this subsection, "natural gas exploration facility" means a platform, facility, or structure that, except for storage of refined petroleum products in a quantity that does not exceed 10,000 barrels, is used solely for the exploration for natural gas. Additionally, we would like to reference the attached letter to Crystal Smith P&R Manager dated August 11,2020, Attachment A: Request for suspension of FURIE Operating Alaska's Oil Discharge Prevention and Contingency Plan, Cook Inlet Exploration Kitchen Lights Unit ADEC C -Plan (C - Plan No. 16 -CP -5184) and Relief from Financial Responsibility Requirements. If you have any questions or require further information, please contact Rick Dusenbery at (907) 331-9282, email at r.dusenberv(@furiealaska.com or call me at (907) 365-9945. Regards, John. Hendrix CEO resident Fune O rating Alaska, LLC Jessie Chmielowski, Commissioner Dan Seamount, Commissioner Jody Colombie, AOGCC Special Assistant David Roby, Senior Petroleum Engineer Guy Schwartz, Senior Petroleum Engineer Table 1 FURIE Operating Alaska Well Location List and Status WW Name CWNnt Stalof "IN vma wmn lou C MY w L 11. Se4U9n T~ShIP ftw meNd on L4ord1.0 NAD 27 K Y Dow. KW Ad Yro4uur 50233206524)000 216-069 33915L,891'M 24 ION 11W Seward 29432585 2536121.20 AK Zm e4 KLU A -L PM 50233-20655-01-00 216066 8%'EWL, 343'ESL 24 ION 21W Seward 294331.49 2536125.62 AK Ione 04 KWA-1 erodv4Yr 502332065600-00 216-063 854'EWL, 342'ESL 24 ION IIW Seward 294319.20 2536123.69 AK 2me 44 KLU3 ftw. 50233-206/00000 213-015 34' ESL, 909' EWL 24 ION IIW Seward 294345.W 2536130.00 AK Z." KLU4 50233-20616004I0 213-088 122' EEL, 2,422' ENL 8 I" 11W Seward 309226.00 2545942.00 AK Zane e4 UUU 50233-20603-0100 212-142 1,543'EN42A20'EEL 35 ION IIW Seward 290842.22 2529019.06 AN Zorn 04 KW3 50233.20593-0000 211-039 241'ENL, 2,095'6WL 25 ION 1100 Seward 295300.00 2535400.00 AK Zme pd IUU A-2 YM 5023330655-0000 216055 5WFE 343'ESL 24 ION I1W Seward 2%331.49 2536125.62 AK ZorN P4 ILIUS Y4 502333%32-0000 214-022 952' EEL, 2,105 ESL 22 9N 1100 Seward 286441.00 350W 11.00 AK Zone MO YLU2 Yid 50733306030000 212429 1,521' ENL, 2,802'EWL 35 ION 1100 Seward 290M0.19 2529041.93 AK Zone e4 EatlPLy merewmlue./1nw1 WYufPYbUorm 60'S6'li'N/I51'W'23RV Onfhore 9redueN4n 60'44'09'N/151'19"90'00 f Table 2 -Summary of Wells Awaiting P&A Status Well Status Comments KLU #4 (PTD 213-088) 1 Dry hole -no economic hydrocarbons I Drilled to a total depth of 9,163' MD/ W.O cut of 15' of 30" casing remaining above mudline. KLU #1 (PTD: 211-039) Dry hole -no economic hydrocarbons Drilled to a total depth of 15,298' I encountered MD/ 15,298' TVD. Formation at depth of TD: Lower TYONEK. Wellbore cemented, incapable of flow Open hole plugged back with cement from 15,298' to 13,108' MD, inside 9 7/8" casing shoe located at 13,383' MD. Wellbore cemented. Top of uppermost cement plug at 325' MD, 122' below seafloor with 13-3/8" cap installed. All cement plugs set in place per AOGCC P&A requirements. W.O. 30" casing cut below mudline encountered 18,639' TVD. Formation at depth of TD: BELUGA. Wellbore cemented. Wellbore cemented, incapable of i Top of uppermost cement plug at flow 1 196' MD, 4' below seafloor. All cement plugs set in place per AOGCC P&A requirements. W.O. 30" casing cut below mudline. Dryhole no economic hydrocarbons Drilled to a total depth of 10,750' KLU #2A (PTD: 212- 147) encountered MD/ 7,109' TVD. Formation at depth of TD: BELUGA; Wellbore Wellbore cemented, incapable of cemented. Top of uppermost flow cement plug at 227' MD, 15' below seafloor with 13-3/8" cap installed. All cement plugs set in place per AOGCC P&A requirements. W.O cut of 15' of 30" casing remaining above mudline. KLU #1 (PTD: 211-039) Dry hole -no economic hydrocarbons Drilled to a total depth of 15,298' I encountered MD/ 15,298' TVD. Formation at depth of TD: Lower TYONEK. Wellbore cemented, incapable of flow Open hole plugged back with cement from 15,298' to 13,108' MD, inside 9 7/8" casing shoe located at 13,383' MD. Wellbore cemented. Top of uppermost cement plug at 325' MD, 122' below seafloor with 13-3/8" cap installed. All cement plugs set in place per AOGCC P&A requirements. W.O. 30" casing cut below mudline ATTACHMENT A er F,1 RI E VIA HAND DELIVERY/EMAIL August 11, 2020 Alaska Department of Environmental Conservation Prevention, Preparedness & Response Program Division of Spill Prevention and Response 555 Cordova Street Anchorage, Alaska 99501-2617 Attn: Crystal Smith, P&R Region Manager Re: Request for suspension of FURZE Operating Alaska's Oil Discharge Prevention and Contingency Plan, Cook Inlet Exploration Kitchen Lights Unit ADEC C -Plan (C -Plan No. 16 -CP -5184) and Relief from Financial Responsibility Requirements Dear Ms. Smith: Thank you very much for the conference call with you and Graham Wood on August 3, 2020. We were pleased to Introduce some of the new FURIE Operating Alaska LLC management team and provide a brief overview of our company's status, current operations and priorities. FURZE Operating Alaska LLC is exclusively a producer of dry biogenic natural gas with no co -production of any oil or liquid hydrocarbons. The above referenced ADEC C -Plan No. 16 -CP -5184 was developed to address the C -Plan requirements for FURIE's multiyear Cook Inlet Exploration Drilling Program. This C -Plan was originally approved In February 2012, with 5 subsequent revisions, and last updated In July 2018. As a natural gas producer with no current plans to drill or develop oil prospects on our leases, FURZE requests exemption from the requirements of Oil Discharge Prevention and Contingency Plan (ADEC C -Plan No. 16 -CP -5184) as specified under Alaska Statute 46.04.050. Notwithstanding the foregoing, FURZE Operating Alaska will continue to adhere to all C -Plan, HSE and regulatory requirements pertaining to the safe operation of our existing Cook Inlet KLU natural gas production platform, pipelines and on -shore facilities. In support of our request, the company offers herein a brief summary of our corporate re -structuring and operations. Corporate ProRle and Status - FURIE Operating Alaska LLC Chapter 11 debtor FURIE Operating Alaska LLC and related debtor companies, Cornucopia Oil & Gas Company LLL and Corsair Oil & Gas LLC, Bled an amended plan of reorganization on June 7, 2020 in the U.S. Bankruptcy Court for the District of Delaware. The plan was accepted by the court on lune 11, 2020 and set forth the proposed acquisition of the assets and existing equity interests of the debtors' assets by Anchorage based HEX Cook Inlet LLC (HEX -CI). The transaction closed on June 30, 2020 and HEX -CI Page I 1 Furie Operating Alaska, LLC 1 188 W Northent Lights Blvd, Suite 620, Anchorage, AK 995031907.277.3726 Coo� nitlWtX,N AY(A Uf took control of the assets on July 1, 2020. Post -closing, FURIE Operating Alaska LLC remains as the designated corporate operating entity. FURZE Operating Alaska LLC has engaged a highly experienced team of professionals to manage company operations in a safe, expedient and socially responsible manner. In all circumstances, the company and management are mandated to protect the public's interest and safety. The new management team is establishing itself as a prudent, diligent and environmentally responsible operator. In all aspects of our business, management is following best practices designed to optimize ultimate hydrocarbon recovery and create in-state employment, economic development and royalty revenue for Alaskans. Oil Discharge Prevention and Contingency Plan -ADEC C -Plan (C -Plan No. 16 -CP -5184) FURIE Operating Alaska LLC produces only non -associated biogenic dry natural gas from our operated Kitchen Ughts Unit (KLU) platform. The dry gas is co-produced with varying amounts of relatively fresh formation water from the Beluga and Sterling formations through four existing gas production wells. The produced gas comprises 99.4% methane and is transported from the Cook Inlet offshore gas production platform via pipeline to our onshore gas processing and sales facility. There are no associated oil, condensate, or natural gas liquids produced with the natural gas (Attachment A). Oil commodity economics are not favorable for the foreseeable future and FURIE has suspended plans to explore and develop deeper, potentially oil-bearing horizons. There are no oil-bearing strata nor oil shows Identified within the Beluga and Sterling formations within the 4 producing wellbores (KLU #A-1, KLU #A -2A, KLU 113, and KLU #A-4). All producing wells are plugged back to the base of the gas producing Beluga formation. There are currently no producible penetrations of the potentially oil bearing lower Tyonek or Hemlock formations in any of the above noted producing gas wells. Three unsuccessful exploratory wells (KLU #4, KLU #2, KLU #1) were drilled on company leases and are cemented back to sea floor (Attachment C). Two wells (KLU #4, KLU #2) reached total depth within the Beluga formation and did not penetrate deeper potentially oil bearing Tyonek or Hemlock formations. A third well (KLU #1) was a deeper test that terminated in the Tyonek. KLU #1 did not encounter producible hydrocarbons and has been cemented. The open hole portion of the well was plugged back with cement from 15,298'to 13,108' MD, inside 9-7/8" casing shoe located at 13,383' MD. All perforations and productive intervals were cemented with top of uppermost cement plug at 325' MD, 122' below seafloor with 13-3/8" cap installed. All cement plugs were set In place per AOGCC P&A requirements. FURIE Operating Alaska LLC is currently updating the 2020 Plan of Development as well as the 2020 Plan of Operations. In the past month post -closing, the company has identified several critical operational and commercial priorities that will be included in the updated plans: • Restoring gas production from the suspended KLU-A4 wellbore • Increasing gas production from the KLU #3, #A -2A, #A-1 wells • Completing the permitting and installation of produced water handing facilities on the KLU gas production platform Page 12 Furie Operating Alaska, LLC 1 188 W Northern Lights Blvd, Suite 620, Anchorage, AK 99503 1 907.277.3726 JEA • Completing thorough technical engineering, geoscience and HSE due diligence on all company owned assets, including pipelines, facilities producing, suspended and P&A wells • Completing several critical commercial and financial tasks relating to insurance, property taxes, gas marketing and operating efficiencies FURIE Operating Alaska LLC is requesting waiver of the existing DEC financial responsibility Insurance requirements as the company is exclusively a producer of dry non -associated natural gas with no co -production of oil or liquid hydrocarbons. FURIE Operating Alaska LLC is not currently exploring for, developing or producing oil or gas liquids, and therefore does not operate any of the following operating structures that require proof of Financial Responsibility. The company requests a suspension of FURIE Operating Alaska's Oil Discharge Prevention and Contingency Plan (ODPCP, C -Plan) and Release from Financial Responsibility Requirements detailed below: • Oil Terminal Facility - facilities with storage capacity more than 5,000 barrels of crude or 10,000 of non -crude. 46.04.900 115) (ASP). • Pipeline - structures used to transport oil or petroleum products between production facilities or to vessels. 46.04.900 119) 1ASPI. • Exploration Facility - platform, vessel, or other facility used to explore for oil resources. 46.04.900 (8) (ASP). • Offshore or Onshore Production Facility - drilling rig, drill site, flow station, gathering center, pump station, storage tank, well and related appurtenances. 46.04.900 (201 (ASP) The company currently has $1.63M in existing Bond/CD deposits on file with various Alaska State Agencies (Attachment B). These demonstrate that the company has financial capability and is committed to corporate responsibility as defined by State Law. Should you have any questions or require a technical presentation beyond the information presented here, please do not hesitate to contact the undersigned directly. Thank you for your consideration. Respectfully, Rick Dusenbery (�- Chief Operating Officer FURIE Operating Alaska LLC Page 13 Furie Operating Alaska, LLC 1 188 W Northern Lights Blvd, Suite 620, Anchorage, AK 99503 1 907.277.3726 F U RJhE AttachmentA Kitchen Lights Unit Total Production by Well & Pool Initial Production to lune 30, 7020 Page 14 Furie Operating Alaska, LLC 1 188 W Northern Lights Blvd, Suite 620, Anchorage, AK 99503 1907.277.3726 l � I t SHV,Nn Attachment B - Summary of Bond/CD Amounts FURIE Alaska Operating LLC Type of Bond Agency Bank Bond/CD Reference Amount If AOGCC AOGCC Northrim 3128440746 $650,000 Blanket Well Band AOGCC Northrim 7101559313 $200,000 Statewide Oil and Gas SOA,DNR Northrim 7101550668 $500,000 Bond Pipeline DR&R SOA, Div of Mining, Land and Northrim 7102128969 $228,375 Water Pipeline Survey SOA, Div of Mining, Land and Northrim 7102128977 $ 50,000 Water TOTAL $1,628,375 Attachment C- Summary of Suspended Wells Awaiting Final P&A Status well Status Comments KW g4 )PTD: 213-088) Dry hole -no economic hydrocarbons _ Drilled to a total depth of 9,163' MD/ encountered 8,639' TVD. Formation at depth of TO: Wellbore cemented, incapable of flow BELUGA. Wellbore cemented. Top of uppermost cement plug at 196' MD, 4' below seafloor. All cement plugs set in place per AOGCC P&A requirements. W.O an of 15' of 30" casing remaining above mudline. KILL! 42A (PTD: 212.147) Dry hole -no economic hydrocarbons Drilled to a total depth of 10,750' MD/ encountered 7,109' TVD. Formation at depth of To: Wellbore cemented, incapable of flow - BELUGA; Wellbore cemented. Top of uppermost cement plug at 227' MD, 15' below seafloor with 13-3/8" cap Installed. All cement plugs set in place per AOGCC P&A requirements. W.O cut of 15' of 30" casing remaining above mudline. KLU 41 )PTD: 211-039) Dry hole -no economic hydrocarbons Drilled to a total depth of 15,298' MD/ encountered 15,298' TVD. Formation at depth of TD: Wellbore cemented, incapable of flow TYONEK. Open hole plugged back with cement from 15,298! to 13,108' MD, Inside 9 7/8" casing shoe located at 13,383' MD. Wellbore cemented. Top of uppermost cement plug at 325' MD, 122' below seafloor with 13-3/8" cap Installed. All cement plugs set in place per AOGCC P&A requirements W.O cut of 15' of 30" casing remaining above mudline. Page 15 Furie Operating Alaska, LLC 1 188 W Northern Lights Blvd, Suite 620, Anchorage, AK 99503 1907.277.3726 DATA SUBMITTAL COMPLIANCE REPORT ,z/z/zo,s Permit to Drill 2160550 Well Name/No. KLU A-2 Operator FURIE OPERATING ALASKA, LLC API No. 50-733-20655-00-00 MD 7038 TVD 5103 Completion Date 7/8/2016 Completion Status P&A Current Status P&A UIC No REQUIRED INFORMATION Mud Log fid'' Samples No ✓ p Directional Survey Yes VZ y DATA INFORMATION Types Electric or Other Logs Run: LWD/GR, Mud Logs, LWD Triple Combo -Multiple Propogation Res Co (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start StopReceived CH Comments Log C 27661 Log Header Scans 0 0 2160550 KLU A-2 LOG HEADERS ED C 27661 Digital Data 400 7038 11/1/2016 Electronic Data Set, Filename: LAS_Furie > Operating Alaska—Randolph Yost_KLU#A-2 Condor 7912806.las ED C 27661 Digital Data 11/1/2016 Electronic File: Furie_Randolph Yost_KLU#A- • 2_2MD TC_7912806.cgm ED C 27661 Digital Data 11/1/2016 Electronic File: Furie_Randolph Yost _KLU#A- 2_2MD TC_7912806.cgm.meta ED C 27661 Digital Data 11/1/2016 Electronic File: Furie_Randolph Yost • _KLU#A- 2_2MD_TC_7912806.pdf ED C 27661 Digital Data 11/1/2016 Electronic File: Furie_Randolph Yost_KLU#A- - 2 2MD TC 7912806.tif ED C 27661 Digital Data 11/1/2016 Electronic File: Furie_Randolph Yost_KLU#A- • 2_2TV D_TC_7912806 . cg m ED C 27661 Digital Data 11/1/2016 Electronic. File: Furie_Randolph Yost_KLU#A-• 2_2TVD_TC_7912806.pdf ED C 27661 Digital Data 11/1/2016 + Electronic File: Furie_Randolph Yost _KLU#A- 2 2TVD TC 7912806.tif ED C 27661 Digital Data 11/1/2016 Electronic File: Furie_Randolph Yost_KLU#A- 2_5MD TC_7912806.cgm ED C 27661 Digital Data 11/1/2016 Electronic File: Furie_Randolph Yost_KLU#A- • 2_5MD TC_ 7912806.cgm.meta ED C 27661 Digital Data 11/1/2016 Electronic File: Furie_Randolph Yost Q _KLU#A- 2_5MD_TC_7912806.pdf ED C 27661 Digital Data 11/1/2016 Electronic File: Furie_Randolph Yost_KLU#A- • 2 5MD TC 7912806.tif AOGCC Page 1 of 5 Friday, December 02, 2016 DATA SUBMITTAL COMPLIANCE REPORT 12/2/2016 Permit to Drill 2160550 Well Name/No. KLU A-2 MD 7038 ED C -- j ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C TVD 5103 27661 Digital Data 27661 Digital Data 27661 Digital Data 27661 Digital Data 27661 Digital Data 27661 Digital Data 27777 Digital Data 27777 Digital Data 27777 Digital Data 27777 Digital Data 27777 Digital Data 27777 Digital Data 27777 Digital Data 27777 Digital Data 27777 Digital Data 27777 Digital Data 27777 Digital Data 27777 Digital Data Operator FURZE OPERATING ALASKA, LLC API No. 50-733-20655-00-00 Completion Date 7/8/2016 Completion Status P&A Current Status P&A UIC No - 11/1/2016 - --------- ------------------- Electronic File: Furie_Randolph Yost _KLU#A- 2_5TV D_TC_7912806 . cg m 11/1/2016 Electronic File: Furie_Randolph Yost_KLU#A- 2_5TVD_TC_7912806. pdf 11/1/2016 Electronic File: Furie_Randolph Yost_KLU#A- ' 2_5TVD_TC_7912806.tif 11/1/2016 Electronic File: Furie_Randolph Yost_KLU#A- 2_FinalSurveyListing. pdf 11/1/2016 Electronic File: Furie_Randolph Yost_KLU#A- 2_FinalSurveyListing.txt 11/1/2016 Electronic File: Survey_KLU#A- . 2_Condor_awp.xls 150 7090 11/1/2016 Electronic Data Set, Filename: KLU A-2.las 11/1/2016 Electronic File: Canrig Morning Reports 6-19- 16. pdf 11/1/2016 Electronic File: Canrig Morning Reports 6-20- 16.pdf 11/1/2016 Electronic File: Canrig Morning Reports 6-21- 16. pdf 11/1/2016 Electronic File: Canrig Morning Reports 6-22- 16.pdf 11/1/2016 Electronic File: Canrig Morning Reports 6-23-' 16. pdf 11/1/2016 Electronic File: Canrig Morning Reports 6-24- • 16. pdf 11/1/2016 Electronic File: Canrig Morning Reports 6-25- , 16. pdf 11/1/2016 Electronic File: Canrig Morning Reports 6-26- s 16. pdf 11/1/2016 Electronic File: Canrig Morning Reports 6-27- 16. pdf 11/1/2016 Electronic File: Canrig Morning Reports 6-28-, 16. pdf 11/1/2016 Electronic File: Canrig Morning Reports 6-29- 16.pdf ---------- - ------ AOGCC Page 2 of 5 Friday, December 02, 2016 DATA SUBMITTAL COMPLIANCE REPORT 12/2/2016 Permit to Drill 2160550 Well Name/No. KLU A-2 Operator FURZE OPERATING ALASKA, LLC API No. 50-733-20655-00-00 MD 7038 TVD 5103 Completion Date 7/8/2016 Completion Status P&A Current Status P&A UI p C No I ED C 27777 Digital Data _ 11/1/2016 Electronic File: M Canrig Morning Reports 6-30- , 16. pdf ED C 27777 Digital Data 11/1/2016 Electronic File: Canrig Morning Reports 7 -1 -' 16.pdf ED ED C 27777 Digital Data 11/1/2016 Electronic File: CanrigMorning g Reports 7-2- 16.pdf ED C 27777 Digital Data 11/1/2016 Electronic File: Canrig Morning Reports 7-3- - -ED 16.pdf ED C 27777 Digital Data 11/1/2016 Electronic File: Canrig Morning M r Reports7-4- • 16. pdf ED C 27777 Digital Data 11/1/2016 Electronic File: Capri Morning R - - g g eports 7 5 • 16. pdf ED C 27777 Digital Data 11/1/2016 Electronic File: Canrig Morning Reports 7-6-' - -ED 16.pdf ED C 27777 Digital Data 11/1/2016 Electronic File: Canrig Morning Reports 7-7- ' 16. pdf ED C 27777 Digital Data 11/1/2016 Electronic File: Canrig Morning Reports 7-8- 16.pdf ED C 27777 Digital Data 11/1/2016 Electronic File: KLU_A-2.dbf . ED C 27777 Digital Data 11/112016 Electronic File: klu_a-2.hdr' ED C 27777 Digital Data 11/1/2016 Electronic File: KLU_A-2.mdx • ED C 27777 Digital Data 11/1/2016 Electronic File. klu a-2r.dbf • ED C 27777 Digital Data _ 11/1/2016 Electronic File: klu_a-2r.mdx• ED C 27777 Digital Data 11/1/2016 Electronic File: KLU_A-2 DBF SCL. ' ED C 27777 Digital Data 11/1/2016 Electronic File: KLU SCL. • MDX ED C 27777 Digital Data _A-2 1111/2016 Electronic File: KLU_A-2 tvd. dbf ED C 27777 Digital Data 11/1/2016 Electronic File: KLU A-2 tv d mdx ED C 27777 Digital Data 11/1/2016 Electronic File: Furie KLU A-2 - Final nal Well Report.doc ED C 27777 Digital Data 11/1/2016 Electronic File: Furie KLU A-2 -Fin I Final Well _ Report.pdf ED C 27777 Digital Data 11/1/2016 Electronic File: KLU A-2 - DrillingDynamics y amics Log MD.pdf AOGCC Page 3 of 5 Friday, December 02, 2016 DATA SUBMITTAL COMPLIANCE REPORT 12/2/2016 Permit to Drill 2160550 Well Name/No. KLU A-2 Operator FURIE OPERATING ALASKA, LLC API No. 50-733-20655-00-00 MD 7038 TVD 5103 Completion Date 7/8/2016 Completion Status P&A Current Status P&A UIC No ED C 27777 Digital Data 11/1/2016 Electronic File: KLU A-2 - Drilling Dynamics Log P TVD.pdf ED C 27777 Digital Data 11/1/2016 Electronic File: KLU A-2 - Formation Log MD.pdf j ED C 27777 Digital Data 911/1/2016 Electronic File: KLU A-2 - Formation Log TVD.pdf df • ED C 27777 Digital Data 11/1/2016 Electronic File: KLU A-2 - Gas Ratio Log MD.pdf df ED C 27777 Digital Data Q 11/1/2016 Electronic File: KLU A-2 -Gas Ratio Log TVD.pdf ED C 27777 Digital Data 11/1/2016 d Electronic File: KLU A-2 - LWD Combo Lo + 9 p MD.pdf ED C 27777 Digital Data 11/1/2016 Electronic File: KLU A-2 - LWD Combo Log TVD.pdf ED C 27777 Digital Data 11/1/2016 Electronic File: KLU A-2 - DRILLING DYNAMICS LOG MD.tif ED C 27777 Digital Data 11/1/2016 Electronic File: KLU A-2 - DRILLING DYNAMICS LOG TVD.tif ED C 27777 Digital Data 11/1/2016 Electronic File: KLU A-2 - FORMATION LOG - MD.tif ED C 27777 Digital Data 11/1/2016 Electronic File: KLU A-2 - FORMATION LOG . TVD.tif ED C 27777 Digital Data 11/1/2016 Electronic File: KLU A-2 - GAS RATIO LOG . MD.tif ED C 27777 Digital Data 11/1/2016 Electronic File: KLU A-2 - GAS RATIO• LOG TVD.tif ED C 27777 Digital Data 11/1/2016 Electronic File: KLU A-2 - LWD COMB • O LOG MD.tif ED C 27777 Digital Data 11/1/2016 Electronic File: KLU A-2 - LWD COMBO LOG • ----- -------- ----TVD.tif Well ores amples Information: - -- SampleSet Interval Name Start Stop Sent Received Number Comments INFORMATION RECEIVED - ---- - -- -- AOGCC Page 4 of 5 Friday, December 02, 2016 DATA SUBMITTAL COMPLIANCE REPORT 12/2/2016 Permit to Drill 2160550 Well Name/No. KLU A-2 Operator FURIE OPERATING ALASKA, LLC API No. 50-733-20655-00-00 MD 7038 TVD 5103 Completion Date 7/8/2016 Completion Status P&A Current Status P&A UIC No Completion Report Y Directional / Inclination Data v Mud Logs, Image Files, Digital Data / NA Core Chips p Y/ts) Production Test Information Y / Mechanical Integrity Test Information Y /a Composite Logs, Image, Data Files 0 Core Photographs Y / QGeologic Markers/Tops Daily Operations Summary Gy Samples Cuttin s g p es Y/O Laboratory Analyses Y/ A COMPLIANCE HISTORY Completion Date: 7/8/2016 Release Date: 6/10/2016 Description Date Comments Comments: Compliance Re Date: AOGCC Page 5 of 5 Friday, December 02, 2016 -� FURIE Operating Alaska LLC October 31, 2016 Alaska Oil and Gas Conservation Commission 333 W. 7t" Avenue, Suite 100 Anchorage, AK 99501 RE: 10-407 for KLU# A2 Kitchen Lights Unit —follow-up data PTD 216- -055 / Sundry 316-356 Dear AOGCC: 01(o-055 o2 7 7 "14- h k. *.A"# * "Lk NOV o 1 2016 AOGCC Enclosed is the LAS files for the Canrig and the Baker Hughes logs. Also included is the EOW report from Canrig in both paper and pdf format. Included is the Canrig Drilling Dynamics log Md and TVD. Enclosed are the digital copies supplied from Canrig and BakerHughes. These have all the logs and reports supplied by the respective companies. If you have questions, please feel free to contact me at 337-981-0270. Sincerely, David McCraine Furie Operating Alaska, LLC Drilling Engineer Furie Operating Alaska LLC 14906 Ambassador Caffery Pkwy Suite #800 1 Lafayette, LA 1 70508 1 Office 337-806-9021 FURZE Operating Alaska LLC October 19, 2016 Alaska Oil and Gas Conservation Commission 333 W. 7t" Avenue, Suite 100 Anchorage, AK 99501 RE: 10-407 for KLU# A2 Kitchen Lights Unit PTD 216- -055 / Sundry 316-356 Dear AOGCC: 2 16055 27 66 1 DATA LOGGE-ED %0 15/201Q OCT 21 2016, M.K.RENDER A^^CC Enclosed is the 10-407 for KLU #A2 with attached wellbore diagram, daily well operations summary, directional survey, and casing/cement report. Included is the LWD Triple Combo Logs, MD and TVD in 1:600 and 1:240 scale and the mud logs. Enclosed is a flash drive with each log electronically, directional survey and a sepia of the triple combo. Please signify that you have received and accepted this data by stamping and returning a copy of this letter to me at the Lafayette address or by emailing me a copy to D.mccraine@furiealaska.com. If you have questions, please feel free to contact me at 337-981-0270. Sincerely, 7 )V David McCraine Furie Operating Alaska, LLC Drilling Engineer �.e�r,��rcd . �D�2a/� � M. 6xkc Furie Operating Alaska LLC 14906 Ambassador Caffery Pkwy Suite #800 1 Lafayette, LA 1 70508 1 Office 337-806-9021 STATE OF ALASKA ALASKA OILAND GAS CONSFRVATION r:nMMISgInN DECEIVED OCT 2 1 2016 WELL COMPLETION OR RECOMPLETION REPORT AND LOG ',O-%-* la. Well Status: Oil Gas SPLUG Other Abandoned SuspendedH 20AAC 25.105 20AAC 25.110 GINJ WINJ[:]_ WAGF-1 WDSPL EJ No. of Completions: 1b. Well Class: Development 01Exploratory Service0 Stratigraphic Test 14. Permit to Drill Number / Sundry: 216-055/ 316-356 2. Operator Name: Furie Operating Alaska, LLC 6. Date Comp., Susp., or Aband.: 7/8/16 3. Address 4906 Ambassador Caffery Pkwy, Ste 800 Lafayette, LA 70508 7. Date Spudded: .�61 G4 - c.v I` q 1 1%4 15. API Number: 50-733-20(05 S -d d -00 - o 16. Well Name and Number: Kitchen Lights Unit # A-2 4a. Location of Well Governmental Section)- ( ) Surface: 895.93 FWL& 343.48FSL; T10N; R11 W; Sec 24 Top of Productive Interval: NA Total Depth: 1405.17 FEL & 1776.5 FNL; T1 ON : R11 W: Sec 24 8. Date TD Reached: 7/4/16 9. Ref Elevations: KB: 107' GL: BF: 17. Field / Pool(s): Kitchen Lights Unit/ undefined natural gas pool 10. Plug Back Depth MD/TVD: 2290' MD/ 2011.3 TVD 18. Property Designation: ADL 389197 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 294,331.49 y- 2,536,125.62 Zone- 4 TPI: x- NA y- Zone- Total Depth: x- 297364.21 y- 2539232.79 Zone- 4 11. Total Depth MD/TVD: 7038'Md/ 5210' TVD 19. Land Use Permit: 12. SSSV Depth MD/TVD: 7038'Md/ 5103' TVD 20. Thickness of Permafrost MD/TVD: 5. Directional or Inclination Survey: Yes (a ed) No H Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: 117' (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, 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 LWD -GR 0-2284'- 1:1,240 scale TVD and MD; 1:600 scale TVD and MD LWD- (Triple Combo) Multiple Propogation Res Compensated Neutron Porosity Compensated Bulk Density, GR f/ 2284'- 7038'; 1;240 scale TVD & MD; and 1:600 scale TVD & MD with LWD -GR 0-2284'- 1:;240 scale TVD and MD; 1:600 scale TVD and MD Mud Logs --Formation Log, Gas Ratio Log, Driling Dynamics Log, and LWD Combo Lithology Log. Md & TVD 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT TOP BOTTOM TOP BOTTOM PULLED 1376' 20" 94# X-56 0' 0 376' Driven NA 0 13/37511 72# N-80 0 2265' 0 1985' 17.5" Lead -900 sks-12.3 ppg & 2.33 Cu 0 Tail -900 sks-15.6 ppg & 1.19 Cu fi No M 24. Open to production or injection? YesLi Lecsi If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number): AT VERIFIED L �- 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes No Per 20 AAC 25.283 (1)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: I 124 Calculated -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): -?q /WzW/y Form 10-407 Revised 11/2015 s 4 7-16 JONTINUED ON PAGE 2 �BDnns c, L- nrr Submit ORIGINIAL only 28. CORE DATA Conventional Core(s): Yes No ® Sidewall Cores: Yes Do 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. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes �lo IVI If yes, list intervals and formations tested, briefly summarizing test results. Attach Permafrost -TopInj Permafrost - Base separate pages to this form, if needed, and submit detailed test information, including Top of Productive Interval reports, per 20 AAC 25.071. Sterling 3639' 2879' Beluga 6790' 5054' Formation at total de the '4'1 1 ic+ r%f Summary of Daily reports; Wellbore Schematic; Directional Survey; Cement Report 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. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: David McCraine Email: d.mccraine ,furiealaska.COm Printed Name -Title: Drilling Engineer. Ph - - Signature: one: 337 981 0270 Date: / INSTRUCTIONS General: 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. Item 1a: 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 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: 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. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records 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. 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. 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. Item 31: 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. Form 10-407 Revised 11/2015 Submit ORIGINAL Only FURZE OPERATI 4 ALASKA, LLC F&RIE KITCHEN LIGHTS Ui.. , NO A-2 Final plugs COOK INLET, ALASKA Operating Alaska LLC 8/05/16 DEM WELL BORE SCHEMATIC SL: X - 294,331.4E; Y - 2,536,125.62P BHL: X - 298,571.41.E; Y - 2,540,6; API: TBD Permit TBD I I I I r ■ I 1 r . r ■ ! I I 1 I I ■ I ! Base of Cement 3260'MD ■ f 1 ■ I 1 I 1 1 I 1 I f 1 1 I■ Cement from 4940'-4370 ■ ! 1 1 1 Cement 6330' - 4952' 1 ■ I I I 1 ■ I 1 ■ , I ! ■ a ■ I I I ! ■ ■ f 1 I I Cement 7038'- 6336' I I I I ■ r I I ■ I ! r Is. _.r �.sai s■®swsr.s®ssd TUBULARS & SETTING DEPTHS PP (PPG) MW (PPG) Frac (PPG) DIRECTIONAL FORMATION EVALUATION DEPTH (KB) MD TVD DRILL FLOOR RKB TO: 108 HIGH TIDE 121 MEAN LOW LOW WATER 225 SEA FLOOR 376 156'P 20" x 7/8" W/T DRIVE PIPE Mudlog LWD: GR 12 1/4" x 17 1/2" KOP @ 300'; BUR - 3°/100'; 'Az - 45.4° EOB @ 1906'MD 1724 -TVD Hold 48.182°inc 8 45.4° Az 46.68° Az 2,265 1,985 13 3/8" 72# N-80 BTC 8.8 9.4 13.5 12 1/4" HOLE Mudlog Cement 3260' - 2290' G� MWD/LWD: Triple Combo Hold 48.182°inc 8 45.4 Az 46.68° Az u o 5475' M D / 4103' TVD ' Drop to 42.8°and tum to 36.8° Az by - 2°/100' DLS by 5882' MD / 4388.5'TVD Hold to 7475'MD/ 5554' TVD Build to 43.578° by 7553'MD/ 5611'TVD Hold to 9789'MD/ 7231' tvd 3000 3200 2585 3639 2879 Sterling 4,000 3,118 } Cement from 4940'-4370, 4590 �. Cement 6330' - 4952' 5000 �$9 8 5102 3854 MDT 3800' Sand 5475 4103' MDT 4018' Sand 5714 4271 MDT 4172' sand 6000 4474�'`�"'*'"F FA I Cement 7038' - 6336' 6570 MDT 4669 Sand 6790 5054 Beluga 7038 1 5210 112 1/4" Open Hole 9.6 10.1 schematic_PXxlsx 10/19/16 FS FAI BAKER ADVANTk..j'E Final Survey Listing HUGHES INTEQ Operator Furie Operating Alaska Fields Kitchen Lights Unit API No 50-733-20655 Well KLU#A-2 Wellbore KLU#A-2 Condor Orig Hole Rig Randolph Yost Job 7912806 Well Origin Latitude 60.9367 deg Longitude -151.1564 deg North Reference True Drill Depth Zero Rotary Table Vertical Datum is Mean Sea Level Vertical Datum to DDZ 107.000 ft Vertical Section North 0.000 ft Vertical Section East 0.000 ft Vertical Section Azimuth 45.6900 deg Vertical Section Depth 0.000 ft Grid Convergence 0.0000 deg Magnetic Declination 16.4800 deg Total Correction 16.4800 deg TVD Calculation Method Minimum Curvature D -Raw Calculation None Local Magnetic Field 55543 nT Local Magnetic Dip Angle 73.8800 deg Local Gravity Field 9.823 m/s^2 Tie MD Incl Azim North East TVD VS Temperature CRS LEN DLSBuild Turn In ft deg deg ft ft ft ft degF ft I deg/ 100ft deg/ 100ft deg/ 100ft U 107.000 0.00 0.00 0.000 0.000 107.000 0.000 200.000 0.50 357.67 0.405 -0.016 199.999 0.271 93.000 0.54 0.54 -2.51 300.000 3.94 3.50 4.272 0.176 299.909 3.110- 100.000 3.44 3.44 5.83 366.170 9.49 28.15 11.357 2.890 365.611 10.002 66.170 9.27 8.39 37.25 418.000 6.67 29.73 17.740 6.400 416.921 16.971 77.0 51.830 5.46 -5.44 3.05 476.000 5.87 32.30 23.172 9.655 474.574 23.095 58.000 1.46 -1.38 4.43 506.000 5.62 32.65 25.705 11.267 504.423 26.019 30.000 0.84 -0.83 1.17 600.000 5.41 39.68 32.991 16.580 597.989 34.910 94.000 0.75 -0.22 7.48 664.000 6.07 40.93 37.870 20.723 661..668 41.282 82.4 64.000 1.05 1.03 1.95 696.000 6.37 43.07 40.445 23.044 693.479 44.742 82.4 32.000 1.18 0.94 6.69 727.000 6.59 45.40 42.950 25.485 724.281 48.239 85.1 31.000 1.11 0.71 7.52 758.000 7.57 47.49 45.579 28.257 755.044 52.058 85.1 31.000 3.27 3.16 6.74 790.000 8.75 47.54 48.646 31.606 786.720 56.598 85.1 32.000 3.69 3.69 0.16 822.540 9.86 47.49 52.200 35.486 818.831 61.857 85.1 32.540 3.41 3.41 -0.15 857.300 11.28 46.80 56.539 40.158 85`3.001 68.231 87.8 34.760 4.10 4.09 -1.99 889.560 12.58 46.56 61.114 45.009 884.563 74.898 87.8 32.260 4.03 4.03 -0.74 916.380 13.67 46.80 65.292 49.441 910.682 80.987 87.8 26.820 4.07 4.06 0.89 953.330 14.73 47.95 71.427 56.112 946.503 90.047 87.8 36.950 2.97 2.87 3.11 984.990 15.70 48.33 76.971 62.301 977.053 98.348 87.8 31.660 3.08 3.06 1.20 1010.110 15.96 48.81 81.505 67.438 1001.220 105.192 87.8 25.120 1.16 1.04 1.91 1048.420 16.53 49.12 88.541 75.523 1038.000 115.891 93.2 38.310 1.50 1.49 0.81 1079.970 18.02 49.27 94.663 82.614 1068.126 125.242 93.2 31.550 4.72 4.72 0.48 1104.450 19.07 49.11 99.751 88.507 1091.335 133.013 93.2 24.480 4.29 4.29 -0.65 1142.760 19.40 47.94 108.111 97.962 1127.506 145.618 93.2 38.310 1.32 0.86 -3.05 1173.870 20.04 46.83 115.219 105.686 1156.792 156.111 87.8 31.110 2.38 2.06 -3.57 1198.780 20.81 45.72 121.228 111.967 1180.135 164.803 385.2 24.910 3.46 3.09 -4.46 1294.690 24.93 46.66 147.007 138.877 1268.487 202.067 93.2 95.910 4.31 4.30 0.98 1389.140 27.26 47.50 175.286 169.306 1353.304 243.595 96.0 94.450 2.50 2.47 0.89 1483.890 29.83 47.07 206.002 202.565 1436.529 288.850 98.7 94.750 2.72 2.71 -0..45 1578.300 35.10 46.30 240.772 239.407 1516.157 339.502 98.7 94.410 5.60 5.58 -0.82 1672.810 39.53 46.63 280.219 280.936 1591.304 396.774 98.7 94.510 4.69 4.69 0.35 1766.170 42.40 46.93 322.125 325.537 1661.794 457.962 98.7 93.360 3.08 3.07 0.32 1861.240 48.11 45.93 368.666 374.419 1728,691 525.451 104.1 95.070 6.05 6.01 -1.05 1956.420 49.29 46.15 418.300 425.890 1791.509 596.953 104.1 95.180 1.25 1.24 0.23 2051.950 48.43 46.21 468.113 477.798 1854.358 66.8.894 104.1 95.530 0.90 -0.90 0.06 2147.980 49.36 46.68 517.970 530.238 1917.492 741.246 106.8 96.030 1.04 0.97 0.49 2228.270 48.51 46.93 559.406 574.370 1970.235 801.770 109.5 80.290 1.08 -1.06 0.31 2327.490 47.98 47.28 609.787 628.594 2036.310 875.765 87.8 99.220 0.60 -0.53 0.35 2426.020 50.95 46.87 660.784 683.417 2100.339 950.618 90.5 98.530 3.03 3.01. -0.42 2521.910 51.36 47.15 711.708 738.046 2160.483 1025.281 90.5 95.890 0.48 0.43 0.29 2616.390 51.20 47.35 761.746 792.176 2219.581 1098.968 93.2 94.480 .0.24 -0.17 0.21 2710.480 50.62 46.56 811.590 845.547 2278.909 1171.978 98.7 94.090 0.90 -0.62 -0.84 2805.480 49.43 46.53 861.661 898.394 2339.941 1244.769 101.4 95.000 1.25 -1.25 -0.03 2900.050 49.61 45.88 911.444 950.316 2401.335 1316.698 104.1 94.570 0.56 0.19 -0.69 2995.120 49.65 45.91 961.855 1002.326 2462.913 1389.130 104.1 95.070 0.05 0.04 0.03 3089.830 50.06 46.29 1012.055 1054.493 2523.975 1461.525 106.8 94.710 0.53 0.43 0.40 3185.560 49.83 45.46 1063.069 1.107.091 2585.580 1534.798 109.5 95.730 0.71 -0.24 -0.87 3280.420 49.54 44.62 1114.177 1158.272 2646.954 1607.123 112.2 94.860 0.74 -0.31 -0.89 3375.440 49.77 45.13 1165.497 1209.369 2708.469 1679.535 112.2 95.020 0.48 0.24 0.54 3470.550 48.98 44.27 1216.804 1260.146 2770.396 1751.710 109.5 95.110 1.08 -0.83 -0.90 Page 1 I a I BKER ADVANT)%.,J'E Survey HUGHES INTEQ Operator Furie Operating Alaska Fields Kitchen Lights Unit API No 50-733-20655 Well KLU#A-2 Wellbore KLU#A-2 Condor Orig Hole Rig Randolph Yost Job 7912806 Tie MD Incl Azirn North East TVD VSTemperature CRS LEN DLS Build Turn In ft deg deg ft ft ft ft degF fit ideg/100ftideg/100ftideg/100ft 3565.920 49.24 44.12 1268.495 1310.405 2832.826 1823.782 112.2 95.370 0.30 0.27 -0.16 3661.060 49.44 44.61 1320.090 1360.869 2894.817 1895.935 112.2 95.140 0.44 0.21 0.52 3754.900 49.72 45.06 1370.752 1411.241 2955.661 1967.368 112.2 93.840 0.47 0.30 0.48 3849.110 48.46 43.07 1421.897 1460.760 3017.359 2038.530 114.9 94.210 2.08 -1.34 -2.11 3944.450 48.20 43.11 1473.906 1509.412 3080.745 2109.674 114.9 95.340 0.27 -0.27 0.04 4039.090 48.33 43.37 1525.354 1557.793 3143.745 2180.232 114.9 94.640 0.25 0.14 0.27 4133.880 48.55 43.15 1577.008 1606.400 3206.629 2251.096 1149 94.790 0.29 0.23 -0.23 4229.450 48.67 43.78 1629.046 1655.723 3269.819 2322.741 114.9 95.570 0.51 0.13 0.66 4323.660 48.80 43.93 1680.110 1704.785 3331.954 2393.519 114.9 94.210 0.18 0.14 0.16 4417.480 48.96 44.08 1730.947 1753.887 3393.654 2464.166 114.9 93.820 0.21 0.17 0.16 4512.140 49.15 44.39 1782.175 1803.766 3455.688 2535.643 114.9 94.660 0.32 0.20 0.33 4606.680 49.49 44.99 1833.144 1854.187 3517.313 2607.327 117.6 94.540 0.60 0.36 0.63 4700.910 49.94 44.89 1884.026 1904.962 3578..241 2679.203 117.6 94.230 0.48 0.48 -0.1.1 4795.820 50.34 45.54 1935.346 1956.671 3639.070 2752.054 117.6 94.910 0.67 0.42 0.68 4889.640 50.25 44.59 1.986.326 2007.767 3699.406 2824,228 117.6 93.820 0.78 -0.10 -1.01 4984.830 49.72 43.81 2038.589 2058.593 3760.213 2897.106 117.6 95.190 0.84 -0.56 -0.82 5078.940 48.25 43.00 2090.1.72 2107.390 38.21.972 2968.056 109.5 94.110 1.69 -1.56 -0.86 5173.870 48.33 42.88 2142.052 2155.667 3885.135 3038.842 112.2 94.930 0.13 0.08 -0.13 5267.380 47.32 42.84 2192.849 2202.805 3947.916 3108.056 114.9 93.510 1.08 -1,08 -0.04 5361.910 47.04 42.22 2243.944 2249.675 4012.168 3177.287 114.9 94.530 0.56 -0.30 -0.66 5456.600 47.47 42.49 2295.332 2296.525 4076.438 3246.708 117.6 94.690 0.50 0.45 0.29 5551.050 46.84 41.24 2346.899 2342.742 4140.666 3315.801 117.6 94.450 1.18 -0.67 -1.32 5645.590 46.04 39.75 2398.990 2387.232 4205.817 3384.025 120.3 94.540 1.42 -0.85 -1.58 5740.020 45.68 39.58 2451.156 2430.487 4271.579 3451.417 120.3 94.430 0.40 -0.38 -0.18 5833.480 45.76 40.07 2502.544 2473.340 4336.830 3517.978 120.3 93.460 0.38 0.09 0.52 5929.900 44.81 38.25 2555.661 2516.611 4404.671 3586.045 123.0 96.420 1.66 -0.99 -1.89 6025.230 42.36 36.10 2608.002 2556.339 4473.722 3651.036 123.0 95.330 3.00 -2.57 -2.26 6118.300 41.69 36.16 2658.325 2593.076 4542.859 3712.476 123.0 93.070 0.72 -0.72 0.06 6213.110 42.14 36.39 2709.385 2630.549 4613.411 3774.958 123.0 94.810 0.50 0.47 0.24 6307.690 42.29 36.59 2760.476 2668.341 4683.459 3837.691 123.0 94.580 0.21 0.16 0.21 6402.120 42.57 36.94 2811.514 2706.474 4753.158 3900.630 123.0 94.430 0.39 0.30 0.37 6496.510 42.93 36.95 2862.721 2744.985 4822.471 3963.957 125.7 94.390 0.38 0.38 0.01 6591.520 43.32 37.39 2914.474 2784.226 4891.815 4028.188 125.7 95.010 0.52 0.41 0.46 6687.840 43.72 37.86 2967.005 2824.718 4961.660 4093.858 125.7 96.320 0.53 0.42 0.49 6781.420 44.26 38.22 3018.193 2864.769 5028.987 4158.274 125.7 93.580 0.64 0.58 0.38 6875.660 44.84 38.22 3070.133 2905.671 5096.146 4223.825 125.7 94.240 0.62 0.62 0.00 6971.030 45.49 38.70 3123.089 2947.736 5163.388 4290.917 128.4 95.370 0.77 0.68 0.50 Projection to TD 7038.000 Tie Column 45.49 Legend: 38.70 1 I - interpolated 3160.361 tie -point, 2977.597 S - 5210.336 4340.972 U 66.970 T Surface 0.00 0.00 0.00 survey station,, - user -defined,, - Page 2 !Well: KLU#A-2 !Path: !Reference North is: TRUE !Magnetic Declination is: 16.48 !True to Grid Convergence: 0.00 !Tie In Point data: !MD 107.00 INC 0.00 Azicorr 0.00 TO 107.00 N/S 0.00 E/W 0.00 !Measured Depth Inclination Azimuth Closure Dist Planar VS Course Length Inc r VS Dogleg Position North !--------------------------------------------------------------------- Vertical Depth ------------------------------------------------- Position East 107.00 ------------------------------------------------ 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 107.00 0.00 200.00 0.50 357.67 0.41 0.27 93.00 0.27 0.54 0.41 200.00 -0.02 300.00 3.94 3.50 4.28 3.11 100.00 3.11 3.44 4.27 299.91 0.18 366.17 9.49 28.15 11.72 10.00 66.17 10.00 9.27 11.36 365.61 2.89 418.00 6.67 29.73 18.86 16.97 51.83 16.97 5.46 17.74 416.92 6.40 476.00 5.87 32.30 25.10 23.10 58.00 23.10 1.46 23.17 474.57 9.65 506.00 5.62 32.65 28.07 26.02 30.00 26.02 0.84 25.71 504.42 11.27 600.00 5.41 39.68 36.92 34.91 94.00 34.91 0.75 32.99 597.99 16.58 664.00 6.07 40.93 43.17 41.28 64.00 41.28 1.05 37.87 661.67 20.72 696.00 6.37 43.07 46.55 44.74 32.00 44.74 1.18 40.44 693.48 23.04 727.00 6.59 45.40 49.94 48.24 31.00 48.24 1.11 42.95 724.28 25.48 758.00 7.57 47.49 53.63 52.06 31.00 52.06 3.27 45.58 755.04 28.26 790.00 8.75 47.54 58.01 56.60 32.00 56.60 3.69 48.65 786.72 31.61 822.54 9.86 47.49 63.12 61.86 32.54 61.86 3.41 52.20 818.83 35.49 857.30 11.28 46.80 69.35 68.23 34.76 68.23 4.10 56.54 853.00 40.16 889.56 12.58 46.56 75.90 74.90 32.26 74.90 4.03 61.11 884.56 45.01 916.38 13.67 46.80 81.90 80.99 26.82 80.99 4.07 65.29 910.68 49.44 953.33 14.73 47.95 90.83 90.05 36.95 90.05 2.97 71.43 946.50 56.11 984.99 15.70 48.33 99.02 98.35 31.66 98.35 3.08 76.97 977.05 62.30 1010.11 15.96 48.81 105.79 105.19 25.12 105.19 1.16 81.51 1001.22 67.44 1048.42 16.53 49.12 116.37 115.89 38.31 115.89 1.50 88.54 1038.00 75.52 1079.97 18.02 49.27 125.64 125.24 31.55 125.24 4.72 94.66 1068.13 82.61 1104.45 19.07 49.11 133.36 133.01 24.48 133.01 4.29 99.75 1091.33 88.51 1142.76 19.40 47.94 145.89 145.62 38.31 145.62 1.32 108.11 1127.51 97.96 1173.87 20.04 46.83 156.35 156.11 31.11 156.11 2.38 115.22 1156.79 105.69 1198.78 20.81 45.72 165.02 164.80 24.91 164.80 3.46 121.23 1180.14 111.97 1294.69 24.93 46.66 202.23 202.07 95.91 202.07 4.31 147.01 1268.49 138.88 1389.14 27.26 47.50 243.70 243.60 94.45 243.60 2.50 175.29 1353.30 169.31 1483.89 29.83 47.07 288.91 288.85 94.75 288.85 2.72 206.00 1436.53 202.56 1578.30 35.10 46.30 339.54 339.50 94.41 339.50 5.60 240.77 1516.16 239.41 1672.81 39.53 46.63 396.80 396.77 94.51 396.77 4.69 280.22 1591.30 280.94 1766.17 42.40 46.93 457.97 457.96 93.36 457.96 3.08 322.13 1661.79 325.54 1861.24 48.11 45.93 525.46 525.45 95.07 525.45 6.05 368.67 1728.69 374.42 1956.42 49.29 46.15 596.96 596.95 95.18 596.95 1.25 418.30 1791.51 425.89 2051.95 48.43 46.21 668.90 668.89 95.53 668.89 0.90 468.11 1854.36 477.80 2147.98 49.36 46.68 741.25 741.25 96.03 741.25 1.04 517.97 1917.49 530.24 2228.27 48.51 46.93 801.77 801.77 80.29 801.77 1.08 559.41 1970.23 574.37 2327.49 47.98 47.28 875.77 873.75 99.22 878.60 0.60 609.79 2036.31 628.59 2426.02 50.95 46.87 950.63 948.33 98.53 953.47 3.03 660.78 2100.34 683.42 2521.91 51.36 47.15 1025.30 1022.73 95.89 1028.15 0.48 711.71 2160.48 738.05 2616.39 51.20 47.35 1099.00 1096.13 94.48 1101.87 0.24 761.75 2219.58 792.18 2710.48 50.62 46.56 1172.02 1168.88 94.09 1174.90 0.90 811.59 2278.91 845.55 2805.48 49.43 46.53 1244.82 1241.45 95.00 1247.70 1.25 861.66 2339.94 898.39 2900.05 49.61 45.88 1316.75 1313.19 94.57 1319.63 0.56 911.44 2401.33 950.32 2995.12 49.65 45.91 1389.18 1385.45 95.07 1392.06 0.05 961.85 2462.91 1002.33 3089.83 50.06 46.29 1461.58 1457.66 94.71 1464.46 0.53 1012.05 2523.98 1054.49 3185.56 49.83 45.46 1534.85 1530.76 95.73 1537.73 0.71 1063.07 2585.58 1107.09 3280.42 49.54 44.62 1607.17 1602.99 94.86 1610.06 0.74 1114.18 2646.95 1158.27 3375.44 49.77 45.13 1679.57 1675.32 95.02 1682.48 0.48 1165.50 2708.47 1209.37 3470.55 48.98 44.27 1751.74 1747.42 95.11 1754.67 1.08 1216.80 2770.40 1260.15 3565.92 49.24 44.12 1823.80 1819.46 95.37 1826.76 0.30 1268.50 2832.83 1310.40 3661.06 49.44 44.61 1895.94 1891.57 95.14 1898.93 0.44 1320.09 2894.82 1360.87 3754.90 49.72 45.06 1967.37 1962.93 93.84 1970.37 0.47 1370.75 2955.66 1411.24 3849.11 48.46 43.07 2038.53 2034.07 94.21 2041.56 2.08 1421.90 3017.36 1460.76 3944.45 48.20 43.11 2109.67 2105.27 95.34 2112.78 0.27 1473.91 3080.74 1509.41 4039.09 48.33 43.37 2180.24 2175.88 94.64 2183.41 0.25 1525.35 3143.75 1557.79 4133.88 48.55 43.15 2251.11 2246.79 94.79 2254.33 0.29 1577.01 3206.63 1606.40 4229.45 48.67 43.78 2322.76 2318.46 95.57 2326.03 0.51 1629.05 3269.82 1655.72 4323.66 48.80 43.93 2393.55 2389.24 94.21 2396.85 0.18 1680.11 3331.95 1704.79 4417.48 48.96 44.08 2464.20 2459.87 93.82 2467.52 0.21 1730.95 3393.65 1753.89 4512.14 49.15 44.39 2535.69 2531.32 94.66 2539.02 0.32 1782.18 3455.69 1803.77 4606.68 49.49 44.99 2607.38 2602.93 94.54 2610.72 0.60 1833.14 3517.31 1854.19 4700.91 49.94 44.89 2679.26 2674.72 94.23 2682.60 0.48 1884.03 3578.24 1904.96 4795.82 50.34 45.54 2752.11 2747.46 94.91 2755.45 0.67 1935.35 3639.07 1956.67 4889.64 50.25 44.59 2824.29 2819.53 93.82 2827.63 0.78 1986.33 3699.01 2007.77 4984.83 49.72 43.81 2897.18 2892.38 95.19 2900.53 0.84 2038.59 3760.21 2058.59 5078.94 48.25 43.00 2968.15 2963.36 94.11 2971.54 1.69 2090.17 3821.97 2107.39 5173.87 48.33 42.88 3038.96 3034.22 94.93 3042.41 0.13 2142.05 3885.13 2155.67 5267.38 47.32 42.84 3108.20 3103.51 93.51 3111.71 1.08 2192.85 3947.92 2202.80 5361.91 47.04 42.22 3177.47 3172.84 94.53 3181.04 0.56 2243.94 4012.17 2249.68 5456.60 47.47 42.49 3246.93 3242.38 94.69 3250.58 0.50 2295.33 4076.44 2296.52 5551.05 46.84 41.24 3316.08 3311.63 94.45 3319.83 1.18 2346.90 4140.67 2342.74 5645.59 46.04 39.75 3384.38 3380.11 94.54 3388.33 1.42 2398.99 4205.82 2387.23 5740.02 45.68 39.58 3451.87 3447.82 94.43 3456.10 0.40 2451.16 4271.58 2430.49 5833.48 45.76 40.07 3518.54 3514.68 93.46 3523.01 0.38 2502.54 4336.83 2473.34 5929.90 44.81 38.25 3586.74 3583.11 96.42 3591.52 1.66 2555.66 4404.67 2516.61 6025.23 42.36 36.10 3651.92 3648.59 95.33 3657.23 3.00 2608.00 4473.72 2556.34 6118.30 41.69 36.16 3713.59 3710.57 93.07 3719.54 0.72 2658.32 4542.86 2593.08 6213.11 42.14 36.39 3776.31 3773.60 94.81 3782.87 0.50 2709.38 4613.41 2630.55 6307.69 42.29 36.59 3839.31 3836.85 94.58 3846.42 0.21 2760.48 4683.46 2668.34 6402.12 42.57 36.94 3902.51 3900.30 94.43 3909.87 0.39 2811.51 4753.16 2706.47 6496.51 42.93 36.95 3966.12 3964.13 94.39 3973.70 0.38 2862.72 4822.47 2744.98 6591.52 43.32 37.39 4030.64 4028.85 95.01 4038.41 0.52 2914.47 4891.82 2784.23 6687.84 43.72 37.86 4096.60 4094.98 96.32 4104.55 0.53 2967.01 4961.66 2824.72 6781.42 44.26 38.22 4161.30 4159.82 93.58 4169.39 0.64 3018.19 5028.99 2864.77 6875.66 44.84 38.22 4227.13 4225.79 94.24 4235.36 0.62 3070.13 5096.15 2905.67 6971.03 45.49 38.70 4294.51 4293.29 95.37 4302.86 0.77 3123.09 5163.39 2947.74 7038.00 45.49 38.70 4342.12 4340.97 66.97 4351.97 0.00 3160.36 5210.34 2977.60 Day Date KLU A2 Drilling OPERATIONAL SUMMARY 1 5/6/16 Hook up tugs Anna T, Bob Franco, and Arctic Titan and tow rig to location. Guardsman anroute with rig to assist. 2 5/7/16 Tow rig to 639; from platform, soft pin and wait on tide. Tow to 69' from platform and soft pin with 50% preload. Unhook tugs. 3 5/8/16 Finish 50% preload and install starboard anchor lines and mid -line bony as tide allows. 4 5/9/16 Hook up starboard aft anchor line & install mid -line buoy on Port Bow anchor line. 5 5/10/16 Hook port forward anchor line and tugs. Jack down to floating draft. Winch rig on location. Preload bow leg and remove starboard aft anchor line. 6 5/11/16 Continue preloading bow and starboard legs. Penetration Bow leg -10'; Starboard leg - 10'; Remove anchor lines and spool cable. Install service lines to floor. Begin preloading port leg. 7 5/12/16 Finish 100% preload - Penetration Port leg - 10'. Jack up to 61' air gap. Prepare and skid out 37'. Install platform ESD. Set slick line unit on platform. 8 5/13/16 General repairs and maintenance, finish installings ESD stations, repair hand rails, Back load work boat, 9 5/14/16 Prepare for USCG and AOGCC Inspection Load &,Backload W. boat, install ventilation cover, work on oil/water sep, Assist Expro W.L. 10 5/15/16 Prepare for USCG and AOGCC Inspection unload &,Backload W. boat, Install stairs to platform, service dechlorinator,work on o/w separator 11 5/16/16 Prepare for USCG and AOGCC inspection, change out cmt & barite hoses, Trouble shoot ESD' S, clean book cell on omni pure unit. 12 5/17/16 Prepare for USCG and AOGCC inspect.,Tested ESD's for total engine shut down,ok, repair vent alarm onpit room doors, Inspect safety equip. 13 5/18/16 Prepare for USCG and AOGCC inspection, general cleaning, change out water hoses from main deck to rig floor. Repair kick plates on rig floor. Test lub and air shutdown on emg. generator. 14 5/19/16 Prepare for USCG and AOGCC inspection, Ran all equipment. Backload 3 1/2" DP and 20 4 3/4" dc's . Install gaskets on shakers, and repair water lines 15 5/20/16 Prepare for USCG and AOGCC inspection, change out hot water heaters. Install emerg. Gen. uv breaker, tested generator and test ok. 16 5/21/16 Prepare for USCG and AOGCC inspection, Installing Co2 system for paint lockers,check Koomey pumps kick on and off,repair hot water heater. 17 5/22/16 Prepare for USCG and AOGCC inspection, Install BOP hoses, fire and abandon drill, installing Co2 system in paint locker, maintnaence & repair 18 5/23/16 Performed USCG inspection. Offload WL unit to platform. Offload 20" Drive Pipe .Work on USCG deficiency. 19 5/24/16 Work on USCG deficiency list and rig maintenance. Repair brace on # 1 life boat and air leak on #2 life boat. Repair e -lights by lifeboats. Repair self closing quarter doors. 20 5/25/16 Work on USCG deficiency list and rig maintenance. Replacing pins in fire extinguishers. Repairing doors in quarters. Repairing rig fire detection system. 21 5/26/16 Work on USCG deficiency list and rig maintenance. Repair doors as needed. Repair lights and install fire ext, brackets as needed. Repairing rig fire detection system. 22 5/27/16 Work on USCG deficiency list and rig maintenance. Finish replace fire ext brackets, continue repair on water tight doors, Install blind flanges on Iwter cooler lines not used. Install light in shaker house. 23 5/28/16 in pit room. Replaced heliport netting. Replaced 5" isolatin valves on fire main. Worked valves at rig floor, trip tank, pump room, &pit room. 24 5/29/16 repaired water tight doors. Repiar plumbing on 4th level quarters. Remove oil water seperator. Remove water pump room tight door for repair. 25 5/30/16 Work on USCG deficiency list and rig maintenance. Continue repiar of pump room water tight doors. Remove life boat # 2 & # 3. Install # 3 in port davit. Unable to lift lifeboat # 3from boat deck due to crane proble. Troubleshooting crane &Cleaning sack room and various storage areas. 26 5/31/16 Work on USCG and ABS deficiency list and rig maintenance. Troubleshoot starboard crane. Replace water tight door in engine room. Replace fire main piping on helideck. Replace angle iron in pit room. 27 6/1/16 Work on USCG and ABS deficiency list and rig maintenance. Install # 3 capsule on on starboard side. Repair strobe alarm lights in SCR and engine room. Repiring fire main valves. 28 6/2/16 Work on USCG and ABS deficiency list and rig maintenance. Repair emergency gen. Finish repair fire main. Finish door repairs. Install 1-12S detection equipment. ADS finished noncompliance repairs. Wait on COC. 29 6/3/16 ABS inspect repairs. Perform rig maintenance and housekeeping. Organizing deck. Offload hammer equipment. Receive COC. 30 6/4/16 Preparing for AOGCC inspection. Rig maintenance and housekeeping. Install new hoses on brake water line. Trouble shoot port crane line speed. 31 6/5/16 Preparing for AOGCC inspection. Rig maintenance and housekeeping. Replace bad lights in derrick. Replace derrick camera. 32 6/6/16 Preparing for AOGCC inspection. Rig maintenance and housekeeping. RU 5-90 hammer and pcik up 20" x.812" X-56 with XLS-C connections. Drive 20" on slot B.' 33 6/7/16 Preparing forAOGCC inspection. Finish driving 20" Slot B to 381'. Skid rig and driving & cut 20" on slot D to 386'. R/D OES. Skid in for rig work. 34 6/8/16 Install BOP hoist under rig. Remove choke and kill wing. 35 6/9/16 Disassemble BOP's, AOGCC inspection, Rigging up Halliburton zero discharge equipment. Rig maintenance 36 6/10/16 Pump out fluid from Koomey unit. Prepare for zero discharge. Changed equalizer line in mud pit. 37 6/11/16 Preparing for AOGCC inspection. Assemble BOP's, dressed rams, pressure wash Koomey tank. Prepare choke and kill line for fitting. 38 6/12/16 Preparing for AOGCC inspection, adjust brakes, replace swivel packing, continue to rig up zero discharge equipment. Finish cleaning accumulater tank. 39 6/13/16 Preparing for AOGCC inspection, Install rams, function test HCR valves completed welding choke & kill line flanges. Install VBR in top and bottom ramsand BSR in middle rams of BOP stack. Function test choke and kill lines. Repiar choke # 2. Check pre -charge on pilsation dampener. 40 6/14/16 Preparing for AOGCC inspection, skid rig package, R/U service lines, spot nitrogen bottles, weld diverter vent lines. 41 6/15/16 Preparing for AOGCC final inspection, installed and function diverter system, calibrate rig monitoring system. Finish install divereter line. Install load ring and test. 42 6/16/16 AOGCC inspection, remove and trouble shoot diverter valve, re -install and test same, good test. Clean filter screens on accumulater. 43 6/17/16 Welded diverter stands, troubleshoot and repair Koomey unit, pick up drill pipe, repair top drive and port crane. Calibrate PVT 44 6/18/16 Pick up drill pipe, passed AOGCC inspection. Offload and backload MV Sovereign and M/V Perserverance. 45 6/19/16 Build spud mud, TIH and tag at 254', Spud Well @1830 hour on 6/19/16., wash and ream to 381'. 46 6/20/16 P/U 12 1/4" BHA, TIH to 381', rotate and slide to 789' taking wireline survey using Gyrodata to 784'MD/ 780' tvd. 47 6/21/16 Slide from 784' to 1,794' building angle. 48 6/22/16 Drill 12 1/4" hole to section TD at 2284', CBU TOH and L/D BHA P/U Hole opener BHA, TIH to 381' Open hole to 17 1/2" to 568'. 49 6/23/16 Open hole to 17 1/2" from 568' to 596', trouble shoot and repair top drive blower motor, Open hole from 596' to 11515I. 50 6/24/16 Opened hole to 17-1/2" to 2,884', circulate hole clean, wiper trip to shoe at 381', TIH, circulate hole clean, POOH. 51 6/25/16 L/D 17-1/2" BHA, Run 13 3/8" casing to 2,265'. Cement casing, bum plug, g 120 bbls cement returns. Wash out diverter. 52 6/26/16 Wash out cement, clean flow line, N/D diverter, clean cement, install and test wellhead, modify grating around wellhead on platform. 53 6/27/16 Nipple up DSA, riser BOP's, M/U Koomey lines and fuction BOP's, N/U bell nipple, install flowline, Test Bop's. 54 6/28/16 Complete Bap test, M/U BHA, TIH & tag cement @ 2158' M D Circulate prepare for casing test. Test casing to 2700 psi, drill cement, float equipment and formation f/ 2158' 55 6/29/16 to 2,304', FIT test. Displace mud, drill f/ 2304' to 2336'. Rotary drill and orient 12 1/4" hole from 2,336 feet to 3,455 feet. Rotary drill and orient 12 1/4" hole from 3,455 feet to 5,030 feet. Drill to 5,053', wiper trip to casing shoe, drill and slide to 5,700 feet. Drill and Slide from 5700' to 7000' Drilled to 7,038', Circulate clean, POOH to 5,950', backream tight hole to 56 6/30/16 57 7/1/16 58 7/2/16 59 7/3/16 60 7/4/16 37821'. POOH, download MWD, L/D BHA, R/U and test BOP's. Finish Testing BOPs & related equipment 200 - 3500p si; Annular 200 - 61 7/5/16 2500 psi w/ H2O, 5 minutes each test, Clean rig floor & platform, P/U GIH w/1497' of 3 1/2" DP x 7038' of 5" DP, CHC, Spot cmt plug from 7038' to 6470% POOH t/6269' CHC, POOH to shoe. to 225917 CCM while WOC, GIH Ta TOC 6336' w/ 20K CCM Tag @ @ 62 7/6/16PD-6'H- J6 6226"" hilo, build 50 bbls cement spacer, Mix & pump P&A plug #2 from 3401- 4940` POOH to 4900 ' ,CCH, POOH into shoe to 2259, CCM . �. OC ,, 2259' - 4900', CCH, GIH Tag TOC @ 4952'w/1 Ok dwn R/U 63 7/7/16 `- pump Plug #3 f/ 4940'- 4440', POOH 4940'- 4054', POOH f/ 4054', L/D MWDM ois f/�d r c c is t11 691' install Ball catcher sub CIH t/ 4054') WOC/CCH, TIH f/4054 - 43701, TAG TOC @ 4370'w/ 12K down. 64 7/8/16 TOOH t/ 3260, R/U Cmt head pump K/O plug f/3260-2350', POOH, LD cmt head assy, RU test BOPs to AOGCC permit requirements, perform accumulator draw down test. L/D 3 1/2" DP f/derrick FURIE OPERATING ALASKA, LLC CASING AND CEMENTING DETAIL CASING/LINER SIZE: 13-5/8 IN. CASING TYPE: 72#1 N-80, BTC SET @ 2265 MD 1994.57 TVD DATE: 6/25/16 (CSG ON BTM) WELL INFORMATION AREA: Kitchens Lights Unit BLK: KLU MLLW _ HOLE SIZE: 17.5 TOTAL DEPTH: 2284 MD 2205 LAST CASING STRING: 20 IN. SET @ 381 MD 381 LOG OF CASING/LINER STRING IRPIIZIN tM RnTTnU 1 ICT ITCIIAC IAI nonCo 011AI. 121 TVD TVD WELL # KLU A-2 WATER DEPTH: 108 RKB - Water: 121 RKB - ML: 225 # OF PIECES O.D. ITEM - MAKE - DESCRIPTION #/FT THRD GRADE MAKE-UP LENGTH DEPTH RKB TO TOP 1 13.375 Casing Shoe 2836.74 BTC 411 1.88 2263.12 2 13.325 Casing Joints 72 BTC N-80 78.96 2184.16- 1 13.375 Float Collar BTC 1.83 2182.33 49 13.325 Casing Joints 72 BTC N-80 2122.68 59.65 1 13.375 Pup Joint 72 BTC N-80 3.45 56.20 1 18.76 Hanger BTC 1.26 54.94 1 13.375 Landing Joint 72 BTC N-80 39.81 15.13 1 13.375 Pup Joint 72 BTC N-80 25.10 -9.97 CASING INVENTORY JTS LENGTH TOTAL LENGTH OF STRING 2274.97 SUBTRACT NON -CASING ITEMS 4.92 ADD FULL JTS LEFT OUT 15 556.69 TOTAL 0 2826.74 TOTAL CSG DELIVERED W/O THRDS) 1 2836.74 CEMENTING DETAILS 1 V Ir1L LLIVV 1 I I yr 0 1 MM-') 44114.wf SUBTRACT CUT-OFF & LANDING JTS 64.91 ADD KB TO CUT-OFF LENGTH 54.94 , CASING/LINER SETTING DEPTH 2265.00 1 ---------------------------------------1 CFMFNTIN[; r.nRAPAAIV- Qf%hlllmhornor STAGE # OF SX WEIGHT YIELD FT6 CEMENT TYPE & ADDITIVES 1 900 12.3 2.33 2273 Class G, w/ 0.05 gps D-47 (defoamer), 0.65 gps D-75 (extender) 2 411 15.6 1.19 589 Class G, w/ 0.2 gps D-47 (defoamer), 0.25 gps D-168 (fluid loss), 0.05 gps D-230 dis erant CFNTALIZFR PI Ar'_FMFNT MAKE TYPE NO. PLACEMENT Davis Lynch Bow Spring 1 10' above casing shoe with 2 stop collars @ 2255' Antelope Solid Body 27 1 on everyjoint from 2184' to 18521, every other joint from 1770" to 278" JOB DETAILS TIME CIRC PRIOR TO CEMENTING: HRS. FULL RETURNS THROUGHOUT JOB? (Y/N) Y EST. MUD LOSSES: 0 BBL DISPLACED CEMENT WITH 325 BBL OF 9.4 ppg Mud BUMPED PLUG? (Y/N) Y BUMPED W/ 1500 PSI FLOATS HELD? (Y/N) Y ESTIMATED BBL CEMENT TO SURFACE 120 EST. TOP OF CEMENT 54.94'- wllhead CIP @ 23:00 hrs Cemented String Wt: NA Weight set on slips: NA COMMENTS 35 % excess cement was pumped. I IWI%l vvuv yuuyG. SUPERVISOR(S): James Pritchard / Dale Munger MRI (VER. 1.0 - 5/30/09) P� �i� css�-� Regg, James B (DOA) From: Brooks, Phoebe L (DOA) Sent: Tuesday, July 12, 2016 12:48 PM � � To: Furie Drilling "A�el Cc: Regg, James B (DOA) Subject: RE: Revised BOPE Test Report 7-5-16 Attachments: ADS Randolph Yost 07-05-16 Revised.xlsx Attached is a revised report with the following edits: • Well name now reflects KLU A-2, PTD #2160550 • Hazard Sec. was changed to "P" (If not posted, this is a violation) 0 Ball Type fields include 2 "P" (TIW valves are Full Opening Ball Valves so the FSV Misc fields now include 0 "NA") • Annular Preventer Test Result "FP" • BOP Misc Test Result "NA" Number of Failures now reflect 4 Please update your copy or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Statistical Technician 11 Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 CONFIDENTIA LITYNOTICE : This e-mail. rnessa.Q-(---, im.-luding any attac1iments, contains information iron the Alaska Ofland Gas Conservati.on Commission. (.AOGCC), State of Alaska and is for the sole u -se of the intended recipient(s). It may conla.incon fidential and/ or privileged inforrn.ation.. The Unauthorized review, use or disclosure of such. information ni.a�,Tviolate state or federal law. If you I I are a uniritended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the A.OGCC :is aware of the :nvistake in sending it to you, contact Phoebe Brooks at 907-79342242 or phoebe.brooks@aIa.ska.goQv. From: Furie Drilling [mailto:furie-drilling furiealaska.com] Sent: Thursday, July 07, 2016 2:05 PM To: DOA AOGCC Prudhoe Bay; Regg, James B (DOA); Brooks, Phoebe L (DOA) Subject: Revised BOPE Test Report 7-5-16 Revised to show lower pipe rams fail/pass and explained 2 FSV Misc in remarks section. James Pritchard Randolph Yost Rig 907-250-1119 furie-drillinRC@furiealaska.com �a Test Results Number of Failures: 4 Test Time: 7.0 _ Hours Repair or replacement of equipment will be made within N/A days. Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Remarks: Tested BOPE w/ joint of 5-1/2" drill pipe 200 psi low / 3500 psi high. Annular tested to 200 psi low / 2500 psi high. Functioned tested both super chokes and manual choke. Lower pipe rams failed initial test. Re -test after circulating water to remove air. Passed. Choke manifold valves failed initial test, funcitioned all valves and circulated water, Re- test, passed. AOGCC Inspection 24 hr Notice Yes Date/Time 7/3/16 08:53 Waived By Jim Regg Test Start Date/Time: 7/4/2016 17:30 (date) (time) Witness Test Finish Date/Time: 7/5/2016 0:30 Form 10-424 (Revised 11/2015) ADS Randolph Yost 07-05-16 Revised.xlsx STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION J BOPE Test Report Submit to: jim.reggR)aIaska.gov AOGCC. I nspectorsP_aIaska. qov Phoebe. brooksP-alaska.gov Contractor: Advanced Drilling Solutions Rig No.: Randolph Yost DATE: 7/5/2016 Rig Rep.: Rickey Skipper/ Mike McCull( Rig Phone: 907-342-7205 Operator: Furie Operating Alaska Op. Phone: 907-250-1119 Rep.: James Pritchard / Dale MungE E -Mail furie-drilling@furiealaska.com Well Name: KLU A-2 PTD # 2160550 - Sundry # N/A Operation: Drilling: X Workover: Explor.: Test- Initial: Weekly: X Bi -Weekly: Test Pressure (psi): Rams: 200/3500 Annular: 200/2500 Valves: 200/3500 MASP: 2886 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen. P Well Sign P Upper Kelly 1 P Housekeeping P Rig P Lower Kelly I P PTD On Location P Hazard Sec. P Ball Type 2 P Standing Order Posted P MISC. NA Inside BOP 1 P FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 N/A NA Trip Tank P P Annular Preventer 1 . 13-5/8115M FP,r, Pit Level Indicators P P #1 Rams 1 2-7/8 X 5 VBR P Flow Indicator P P #2 Rams 1 Blind Shear P Meth Gas Detector P P #3 Rams 1 2-7/8 X 5 VBR FP $`" H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 4-1/16th 10M P Inside Reel valves 0 NA HCR Valves 2 - 4-1/16th 10M P Kill Line Valves 1 4-1/16th 10M P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure (psi) 2980 P CHOKE MANIFOLD: Pressure After Closure (psi) 1800 P Quantity Test Result 200 psi Attained (sec) 43 P No. Valves 18 FP Full Pressure Attained (sec) 220 P Manual Chokes 1 P Blind Switch Covers: All stations Yes Hydraulic Chokes 2 P Nitgn. Bottles # & psi (Avg.). 12 @ 2200 P CH Misc 0 NA ACC Misc 0 NA �a Test Results Number of Failures: 4 Test Time: 7.0 _ Hours Repair or replacement of equipment will be made within N/A days. Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Remarks: Tested BOPE w/ joint of 5-1/2" drill pipe 200 psi low / 3500 psi high. Annular tested to 200 psi low / 2500 psi high. Functioned tested both super chokes and manual choke. Lower pipe rams failed initial test. Re -test after circulating water to remove air. Passed. Choke manifold valves failed initial test, funcitioned all valves and circulated water, Re- test, passed. AOGCC Inspection 24 hr Notice Yes Date/Time 7/3/16 08:53 Waived By Jim Regg Test Start Date/Time: 7/4/2016 17:30 (date) (time) Witness Test Finish Date/Time: 7/5/2016 0:30 Form 10-424 (Revised 11/2015) ADS Randolph Yost 07-05-16 Revised.xlsx Kul, ¢-z ov -Regg, James B (DOA) From: Regg, James B (DOA) '0 Sent: Tuesday, July 05, 2016 4:48 PM C � To: Furie Drilling; DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Cc: Yost; John Stuart; Dave McCraine Subject: RE: BOPE Test Charts & Report 7-05-16 Charts and report are not matching. Also have several questions. - Which specific Choke Manifold Valves failed? Charts indicate failures of initial test attempts for CMV's 3,4,6,7,9 a n d C M V's 518,,10113118 What are the "FSV Misc" components listed as quantity "2" and result 11P11*.? Report indicates Upper Pipe Rams as "FP".- test chart indicates the Lower Pipe Rams as "FP"; clarify which is correct Report indicates Annular is "P" (pass); test chart has the same signature as the Lower Pipe Rams which was called "FP"; what's the difference? Annular pressure test signature is a bit odd. Why the pause (with pressure loss and repressure) in the test and slow (3-4min) buildup to the required test pressure? What were the closing times for the Annular and Rams performance tests? (closing time defined as time from function until BOP closed, effecting a seal — regulated operating pressure recovered to its normal setting)? Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (A0GCQ, 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 Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. From: Furie Drilling [mailto:furie-drilling furiealaska.com] Sent: Tuesday, July 05, 2016 4:25 AM To: DOA AOGCC Prudhoe Bay; Regg, James B (DOA); Brooks, Phoebe L (DOA) Cc: Yost; John Stuart; Dave McCraine Subject: BOPE Test Charts & Report 7-05-16 Brian Vines Rig Clerk Randolph Yost Rig 337-804-2513 furie-drilliniz(@furiealaska.com Fumm� STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: jim.regg(d_)alaska.gov AOGCC. I nspectors(a)alaska. gov Phoebe. brooks(a)alaska. gov Contractor: Advanced Drilling Solutions Rig No.: Randolph Yost DATE: 7/5/2016 Rig Rep.: Rickey Skipper / Mike McCullc Rig Phone: 907-342-7205 Operator: Furie Operating Alaska Op. Phone: 907-250-1119 Rep.: James Pritchard / Dale Munge E -Mail furie-drilling@furiealaska.com Well Name: KLU A-2 CONDOR PTD # 216-055 Sundry # N/A Operation: Drilling: X Workovers Explor.: Test: Initial: Weekly: X Bi -Weekly: Test Pressure (psi): Rams: 200/3500 Annular: 200/2500 Valves: 200/3500 MASP: 2886 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen. P Well Sign P Upper Kelly 1 P Housekeeping P Rig P Lower Kelly 1 P PTD On Location P Hazard Sec. NA Ball Type 0 NA Standing Order Posted P Misc. NA Inside BOP 1 P FSV Misc 2 P BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 N/A NA Trip Tank P P Annular Preventer 1 13-5/8115M P Pit Level Indicators P P #1 Rams 1 2-7/8 X 5 VBR FP Flow Indicator P P #2 Rams 1 Blind Shear P Meth Gas Detector P P #3 Rams 1 2-7/8 X 5 VBR P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 4-1/16th 10M P Inside Reel valves 0 NA HCR Valves 2 4-1/16th 10M P Kill Line Valves 1 4-1/16th 10M P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 I' Time/Pressure Test Result System Pressure (psi) 2980 P CHOKE MANIFOLD: Pressure After Closure (psi) 1800 P Quantity Test Result 200 psi Attained (sec) 43 P No. Valves 18 FP Full Pressure Attained (sec) 220 P Manual Chokes 1 P Blind Switch Covers: All stations Yes Hydraulic Chokes 2 P Nitgn. Bottles # & psi (Avg.): 12 @ 2200 P CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 2 Test Time: 7.0 Hours Repair or replacement of equipment will be made within N/A days. Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Remarks: Tested BOPE w/ joint of 5-1/2" drill pipe 200 psi low / 3500 psi high. Annulas tested to 200 psi low / 2500 psi high. Functioned tested both super chokes and manual choke. Lower pipe rams failed initial test. Re -test after circulating water to remove air. Passed. Choke manifold valves failed initial test, funcitioned all valves and circulated water, Re- test, passed. AOGCC Inspection 24 hr Notice Yes Date/Time 7/3/16 08:53 Waived By Jim Regg Test Start Date/Time: 7/4/2016 17:30 (date) (time) Witness Test Finish Date/Time: 7/5/2016 0:30 Form 10-424 (Revised 11/2015) BOPE Test Report 7-05-16.xlsx Total Safety U.S., Inc. 209 E. 51st Avenue Anchorage, AK 99503 Phone: (907) 743-9871 Fax: (907) 743-9872 GAS DETECTION SYSTEM TEST SHEET : _* TOTAL SAFETY Customer: Onshore: Offshore: Report Date: Time: AFE/Job#: Rig/Location: Drilling Company: Company Representitive: Telephone Number: Total Safety Technician: Current Site Activity: Type of System: Type of Test: Calibration Bump Test Sensor# 1 Sensor # 2 Sensor # 3 Type of Sensor: Type of Sensor: Type of Sensor. Location: Location: 'Location: Calibrated from: Calibrated from: Calibrated from: Bumped at: Bumped at: 11 Bumped at: Low alarm < 30 seconds: -ow alarm < 30 seconds, Low alarm < 30 seconds. Battery Voltage: Battery Voltage: Battery Voltage: Comments: Comments: Comments: Sensor # 4 Sensor # 5 Sensor # 6 ,Type of Sensor: Type of Sensor: Type of Sensor: Location: Location: Location: Calibrated from: Calibrated from: Calibrated from: Bumped at, Bumped at: Bumped at: Low alarm < 30 seconds- Low alarm < 30 seconds: Low alarm < 30 seconds: Battery Voltage: Battery Voltage: Battery Voltage: Comments: Comments: Comments: Sensor # 7 Sensor # 8 Sensor # 9 Type of Sensor: Type of Sensor: Type of Sensor: Location: Location, Location: Calibrated from: Calibrated from: Calibrated from: Bumped at: Bumped at: Bumped at: Low alarm < 30 seconds: Low alarm < 30 seconds: Low alarm < 30 seconds: Battery Voltage: Battery Voltage: Battery Voltage: Comments: Comments: Comments: Sensor # 10 iType Sensor. H Sensor # 12 of Sensor: Type of Sensor: Type of Sensor: Location: Location: Location: Calibrated from: Calibrated from: Calibrated from: Bumped at: Bumped at: Bumped at: Logia alarm < 30 seconds: Low alarm < 30 seconds- Low alarm < 30 seconds: Battery Voltage: Battery Voltage: Battery Voltage: Comments: Comments- Comments: Total Safety Technician White - Office Canary Customer Nil< - File Company Represenitive Date: f M1 -e, "000- \, --2000 CP I 100 ON 00 0(, ca T if N�) � 0009 OOOL 0006 OQ THE STATE OJ A J�1L,,A-'SKA,,,__, GOVERNOR BILL WALKER Bruce Webb Sr. Vice President Furie Operating Alaska, LLC. 4906 Ambassador Caffery Pkwy, Suite 800 Lafayette, LA 70508 Alaska Clot airid Gas Conservation CciumiS"911"'GlIn- 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Re: Kitchen Lights Unit, KLU Undefined Natural Gas Pool, Kitchen Lights Unit #A-2 Permit to Drill Number: 216-055 Sundry Number: 316-356 Dear Mr. Webb: 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 . Foerster Chair f& DATED this (0 day of July, 2016. RBDMS w JUIL 0 6 2016 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 JUL ') 5 2 0 16 6is IIS//L 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: Furie Operating Alaska LLC Exploratory Development Stratigraphic Service 216-055 3. Address: 6. API Number: 4906 Ambassador Caffery Suite 800 Lafayette, LA 70508 50-733-20655-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? AA Will planned perforations require a spacing exception? Yes17 NoLJ Kitchen Lights Unit #A-2 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 389197 1 Kitchen Lights Unit Undefined Natural Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 7038 5210 7038 5210 2886 Casing Length Size MD TVD Burst Collapse Structural 381' 20" x.812 wt 381' 380' 3980 2510 Conductor Surface 2265' 13 3/8" 72 #N80 2265' 1995' 2670 5380 Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type: Packers and WSV MD (ft) and TVD (ft): Im 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program IQ BOP Sketch Exploratory Stratigraphic Development 1X1 Service I 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 5 -Jul -16 OIL ❑ WINJ ❑ GAS ❑ WAG ❑ WDSPL ❑ Suspended FAO GSTOR F1 SPLUG 16. Verbal Approval: For first plug Date: 7/4/16 Commission Representative: Guy Schwartz GINJ ❑ Op Shutdown Abandoned 17. 1 hereby certify that the foregoing is true and the procedure approved herein , will not be deviated from without prior written approval. 4 Contact � eo c4tFE mail ��� Printed Name Titles iC. t Y-6 -7ts-i 1 ('0 Signature Phone Date 5 -Jul -16 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 45 (4e Plug Integrity F-1 BOP Test ❑ Mechanical Integrity Test F-1 Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? YesF-1 No Subsequent Form Required: U l APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: or �Pp Form 10-403evised 1112015A proved a plication is valid for 12 months from he date of approval. 0 Submit Form and Attachments in Duplicate RBDMS L,- L/- JUL 0 6 2 016 Q FURZE Operating Alaska LLC July 5, 2016 RE: 10-403 for KLU#A-2 Alaska Oil and Gas Conservation Commission 333 W. 7t" Avenue, Suite 100 Anchorage, AK 99501 Gentlemen, JUL U 5 2016 AOGCC Enclosed is the 10-403 Sundry Notice, for the P & A, KO plug and sidetrack of Furie Operating Alaska, LLC (FOA) Well KLU#A-2 (Permit to Drill # 216-055). • FOA has attached the Well Bore Diagram and the Procedure. If you have questions, please feel free to contact me at 907-277-3726. Sincerely Bruce Webb AOGCC Received Stamp Here: Furie Operating Alaska, LLC 1029 W. 3rd Avenue, Suite 500 1 Anchorage, Alaska 1 99501 1 Office: 907-277-3726 d FURZE OPERATING of ALASKA, LLC FURIEKITCHEN LIGHTS UNIT NO A-2 Proposed plugs COOK INLET, ALASKA OOK Operating Alaska LLC 4MSM6 DEM WELL BORE SCHEMATIC SL: X - 294,331.4E; Y - 2,536,125.62t BHL: X - 298,571.41.E; Y-2,540,6*. TUBULARS a SETTING DEPTHS PP Mw Frac DIRECTIONAL API: TBD DEPTH (KE) (PPG) (PPG) (PPG FORMATION EVALUATION Permit TBD MD TVD DRILL FLOOR RKB TO: 90 HIGH TIDE . _ 111 .. 116 N EAN LOW LOW YWATER 219 EA FLOOR •- . } • . r114" Mud, •~ - x 17112" KOP 940'; BU 9'1100'; 'Az - 43 d' EOB 0 19067A 1724TM old48.182'lnc & 45.4' Az 46.88' Az �' r .� ♦ N-, �, _ */yy� •yr ..r--��. .r.r /M+t Iii. �udlog ' 12114' HOLE Cement 3260'- 2350' Top dressed to 240Wt MWDILWD• I riple Combo 1 I • Nold 48.182'Inc 4 46.4' Az 46.88' Az e� 0 3473' MD 14103' TVD +�� 1 Drop to 42.8'and turn to 36.8' Az by 21100' DLS by 3882' MD 14388.5'TVD i old to 747SMCV 3554' TVD - ' uld to 43.57& by 7553MD/ 5611'TVD old to 9789'MOI7131' tvd 3000 3200 2585 Base of Cement 32WMD � 1 1 3639 2879 Sterling 1 i l , 1 I 1 4,000 3,119 � 1 I I I Cown! frau: 4800'44901 Ce -vent from 4800'4450 1 , 41i9Q Cement 6340' - 4980' Comont 6340' - 4980' 6000 5102 3854 MDT 3800' Sand , I 5475 4103' MDT 41118' Sand ,r 5714 4271 MDT 4172' sand I 6000 4474 ' t Cement 7038' - 6470. 1 Cement 7038'- 6470' 6570 MDT 4669 Sand 6790 5054 Beluga �2 4R. ',•,�.� ,j dl#.'t , av .►• - •.., •.-.r �, t r '1 :•+�• rV .. 7016 KLU # A2 PTD 216 - 055 Open hole P &A, KO plug and sidetrack. x 00-nF-I )Nv6 cct'-�-Pez-'VDe-C!10 zk"� or,( PZkoe Tl% Z'ik&6%QbC 1. TIH with 3 1/2" stinger on 5" drill pipe. �... , �,•� 2. Set open hole plug from: -.r..----- 7038'- 6470' MD, (5210' - 4803' TVD) 568' plug to have 534.6 cubic feet of class G cement with additives, 460 Sacks. 460 sacks class g +.1 gps D047 9 antifoam), +.2 gps D145A ( Dispersant), + .3 gps D168 ( fluid Loss), NOTE: preliminary design running pilot test. Weight -15.8 ppg Yield -1.16 cu. Ft./sk Water - 4.479 gps Seawater Pump Time - 7:25 Note 15 % excess calculated. 3. PU to 63 5 0'MD and circulate. 4. WO C 5. TIH and tag cement plug at 6470'. V0010, 6. PU to 6340'MD and set an open hole balanced plug from 6340' - 4990'MD, (4707' - 3765' TVD) u. . me X350' plug to have 1270 cubic feet of class G cement with additives, 1095 sacks. 1095 sacks class g +.1 gps D047 9 antifoam), +.2 gps D145A C Dispersant), +3 gps D168 (fluid Loss), NOTE: preliminary design running pilot test. Weight -15.8 ppg Yield - 1.16 cu. Ft./sk Yield - 1.16 cu. Ft./sk Water - 4.479 gps Seawater Pump Time - 7:25 Note 15 % excess calculated. 7. POOH to 4900' and CBU. 8. WOC Agewl "-su 9. TIH and to cement plug at,634T. 10. PU to 4800'MD and set an open hole balanced plug from 4800'- 4490'MD, (4.1 - 3' TVD) 310' plug to have 292 cubic feet of class G cement with additives, 252 sacks. 252 sacks class g + .1 gps D047 9 antifoam), +.2 gps D145A (Dispersant), + .3 gps D168 (fluid Loss), NOTE: preliminary design running pilot test. Weight -15.8 ppg Yield --1.16 cu. Ft./sk Yield -1.16 cu. Ft./sk Water - 4.479 gps Seawater Pump Time 7:25 Note 15 % excess calculated. 11. WOC. 12. TIH and tai cement at 4490'. 13. POOH to 3260'. 14. Spot a KOP from 3 60' - 2350', (2634' 2051' TVD) Plug to be 808 sacks of class G + .2 gps antifoam + .08 gps D230 ( dispersant), + .2 gps D 168 ( fluid loss) ID LZ C--.-:1. C �943= 5 1 Weight -16.5 ppg. Yield -1.06 cubic ft/ sack Water - 3.931 gps - Fresh. Pump Time - 4:23. Note 15 % excess calculated. 15. POOH to 2300 and CBU. 16. POOH. 17. Lay down 3 1/2" drill pipe. 18. MU KO assembly consisting of PDC bit, mud motor, MWD and triple comb LWD. 19. TIH and tag cement plug. 20. Time drill off of plug at 2400'. 21. Drill to 5993' MD/5326 TVD dropping angle to 14° at X- 296,024.01 and Y- 2,537,762.1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAr. 9.; 9AO FRECEIVEQ JUL 0 5 2016 AOGCG 1. Type of Request- Abandon Plug Perforations F] Fracture Stimulate Li Repair Well Li Operations shutdownLJ Suspend Perforate H Other Stimulate Pull Tubing (Zhange Approved Program H Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing O/e r., 2. Operator Name: 4. Current Well Class: W 5. Permit to Dr 4u-mber. Furie Operating Alaska LLC Exploratory Development 3. Address: Stratigraphic H Service 216-055 '-'o 6. APIN u ber: 4906 Ambassador Caffery Suite 800 Lafayette, LA 70508 1 50-73 /-20655-00-00 7. If perforating: Well B. Well Name nd Number. What Regulation or Conservation Order governs well spacing in this pool? N� ,�� Will planned perforations require a spacing exception? Yes Ll No K Lights Unit #A-2 9. Property Designation (Lease Number): 10, Field/Pool(s): ADL 389197 1 Kitchen Lights Unit Undefined Natural Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MID (ft): Total Depth TVD MY Effective Depth MD: Effective Depth TVD* MPSP (psi): Plugs (MD): Junk (MD): 7038 5210 7038 5210 288 Casing Length Size MD 91D Burst Collapse Structural 381' x.812 wt 381' 380, 3980 2510 Conductor Surface 2265 13 3/8" 72 #N80 22651 1995' 2670 5380' Intermediate Production Liner Perforation Depth M 44r: Perforation Depth TVD (11): Tubing Size: Tubing Grade: Tubing MID (ft): � At Packers and SSSV Type: Pa ers and SSSV MD (ft) and TVD (ft): J Nk 12. Attachments: Proposal Summary Lnj Wsllbore schematic 13. Well Class after proposed work: Detailed Operations Program SOP Sketch Exploratory Stratignaphic DevelopmentD(I service I 14. Estimated Date for Commencing Operations- 5 -Jul -16 15. Well Status after proposed work: OIL E] WIND WDSPL Suspended WAG H GSTOR SPLUG 16. Verbal Approval., For first plug Date:GAS Commission Representative: Guy Schwartz L--�A GINJ Op Shutdown Abandoned 17. 1 hereby certify that the foregoing is true and the procedure a herein will not be deviated from without prior written approval. Contact David McCraine Drilling Engineer Email D.mccraine@furiealaska.com Printed Name rifle David E. McCraiT Drilling Engineer Signature Phone Date f 337-981-0270 5 -Jul -16 COMMISSION USE ONLY Conditions of approval: Notify Commission so at a representative may witness Sundry Number: 3�t�-3�1..Q Plug Integrity SOP est F] Mechanical Integrity Test Location Clearance Other. Post Initial Injection MIT Req'd Yes No Spacing Exception Required Yes H No B/ Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Submit Form and Fom(,/10403 Revised 1112015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate ORIGINAL to FURIE FURIE OPERATING of ALASKA, LLC KITCHEN UG14TS UNIT NO A-2 Proposed plugs COOK INLET, ALASKA Operating Alaska LLC 411SM6 OEM WELL BORE SCHEMA71C SL: X - 294,331.4E; Y - 2,536,125.621 3HL: X - 298,571.4l .E; Y - 2,540,6-, TUBULARS &SETTING DEPTHS PP Mw Frac ... M;iCTIbNAL NPI: TBD DEPTH (KSI (PPG) PP FORMAnON EVALUAMN PermDRILL FLit TBD M2- TVD OOR - RK8 TO: EOB @ 1906'MD 1724 -TVD so 116 HIGH TIDE MEAN LOW LOW WATER 269 SEA FLOOR to Mudl*g 12114" x 17112" LWD: GR KOP a 300; OUR - 3"MW', -AZ - 45 C EOB @ 1906'MD 1724 -TVD Hold 48.18rinc & 45.,4' Az 46.86• Az 41 A A - 12114" HOLE u d udlog 'o g Cen1wA 32W'- 236W 7*p dressed to 24Wt W D, f rip ca Iple Combo rDg*and old 48.1&2*inc & 45A* Az 48.86' Az Hold 4 a V '5 5475MD 14103' TVD Drop t to 42. tum to 36.8* Az by 2'11W OLS by Ws2, mo 143s& rM Hold to 747VMCV 5554' TVD Budd io43.578 hy7553UD/58i1,TvD • 3000 Hdd to 9789WDI 7231'tvd 5. Base of Cerneni 32WMD 3200 2686 =9 2879 Sterling 1 4,000 3,119 Cenumt from 4800'4494 Cwrwd from 4800'-4490 4590 Cement 6340' - 4090' i C*nwnt 934W - 4M' 15000 5102 38" DT 3800' Sand 6476 4103' MDT4018'Sand 5714 42TI MOT 4172'sand 6000 4474 Cwmrlt 7038' - 6470' 1 Cement 7038' - 64701 6570 MDT 4669 Sand $790 5064 Beluga 40.1 KLU # A2 PTD 216-055 Open hole P & A, KO plug and sidetrack. 1. TIH with 3 Y2" stinger on 5" drill pipe. 2. Set open hole plug from: 7038-F - 6470' MD, (5210'- 4803' TVD) 568' plug to have 534.6 cubic feet of class G cement with additives, 460 Sacks. 460 sacks class g +.1 gps D047 9 antifoam)., +.2 gps D145A ( Dispersant), +.3 gps D168 (fluid Loss), NOTE: preliminary design running pilot test. Weight -15.8 ppg Yield -1.16 cu. Ft./sk Water - 4.479 gps Seawater Pump Time - 7:25 Note 15 % excess calculated. 3. PU to 6350'MD and circulate. 4. WOC 5. TIH and tag cement plug at 6470' 6. PU to 6340'MD and. set an open hole balanced plug from 6340'- 4990'MD, (4707) - 3765-P TVD) 1350' plug to have 1270 cubic feet of class G cement with additives, 1095 sacks. 1095 sacks class g +.1 gps D047 9 aDtifoam), + .2 gps D 145A ( Dispersant), + .3 gps D168 (fluid Loss), NOTE: preliminary design running pilot test. Weight -15.8 ppg Yield -1.16 cu. Ft./sk Yield - 1.16 cu. Ft./sk Water - 4.479 gps Seawater Pump Time - 7:25 Note 15 % excess calculated. 7. POOH to 4900' and CBU. 8. WOE 9. TIH and tag cement plug at 6340'. 10. PU to 4800'MD and set an open hole balanced plug from 4800" - 4490"MDt (4' - 31 TVD) 310' plug to have 292 cubic feet of class G cement with additives, 252 sacks. 252 sacks class g +.1 gps D047 9 antifoam), +.2 gps D145A (Dispersant), +.3 gps D168 ( fluid Loss), NOTE: preliminary design running pilot test. Weight - 15.8 ppg Yield -1.16 cu. Ft./sk Yield - 1.16 cu. Ft./sk Water - 4.479 gps Seawater Pump Time - 7:25 Note 15 % excess calculated. 11. WOC. 12. T1 and tag cement at 4490'. 13. POOH to 3260'. 14. Spot a KOP from 3260'- 2350% (2634-1 2051' TVD) Plug tobe808 sacks of class G + .2 gps antifoam + .08 gps D23 0 ( dispersant), + .2 gps D 168 ( fluid loss) Weight -16.5 ppg. Yield -1.86 cubic ft/ sack Water - 3.931 gps, - Fresh. Pump Time - 4:23. Note 15 % excess calculated. 15. POOH to 2300 and CBU. 16. POOR 17. Lay down 3 1/2" drill pipe. 18. MU NO assembly consisting of PDC bit, mud motor, MWD and triple combo LWD. 19. TIH and tag cement plug. 20. Time drill off of plug at 2400". 21. Drill to 5993MD/5326 TVD dropping angle to 14° at X- 296,024.01 and Y- 2.,537)762.1 Bettis, Patricia K (1130A) From: Quick, Michael J (DOA) Sent: Tuesday, July 05, 2016 1:46 PM To: David McCraine Cc: Schwartz, Guy L (DOA); Bettis, Patricia K (DOA) Subject: RE: KLU A2 sundry to plg for redril Dave — Yes we will need paper copies with an original signature on one of the copies. We will start to process what you have submitted as to not hold up the operation. Michael Quick Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Anchorage, AK 99501 (907) 793-1231 (phone) (907) 276-7542 (fax) mike.quick@alaska.gov 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 AO GCC is aware of the mistake in sending it to you, contact Mike Quick at 907-793-1231 or mike.guick@alaska.gov. From: David McCraine [mailto:d.mccraine@furiealaska.com] Sent: Tuesday, July 05, 2016 1:38 PM To: Quick, Michael J (DOA) Cc: Schwartz, Guy L (DOA) Subject: KLU A2 sundry to pig for redril Attached are two copies of the Sundry for redrill with procedure and schematic. If anything else is needed please let me know. Do I need to send I paperr copies also? Thanks. Dave McCraine Furie Operating Alaska -Lafayette Drilling Engineer 337-981-0270 Office 337-501-6854 Cell Bettis, Patricia K (DOA) From: Quick, Michael J (DOA) Sent: Tuesday, July 05, 2016 1:43 PM To: Bettis, Patricia K (DOA) Subject: FW: KLU A2 sundry to pig for redril Attachments: SC284-Furie16070515400.pdf; SC284-Furie16070515410.pdf FYI Michael Quick Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Anchorage, AK 99501 (907) 793-1231 (phone) (907) 276-7542 (fax) mike.guick@alaska.gov 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 recipients) . 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 Mike Quick at 907-793-1231 or mike.guick@alaska.gov. From: David McCraine[mailto:d.mccraine@furiealaska.com] Sent: Tuesday, July 05, 2016 1:38 PM To: Quick, Michael J (DOA) Cc: Schwartz, Guy L ( DOA) Subject: KLU A2 sundry to pig for redril Attached are two copies of the Sundry for redrill with procedure and schematic. If anything else is needed please let me know. Do I need to send I paperr copies also? Thanks. Dave McCraine Furie Operating Alaska -Lafayette Drilling Engineer 337-981-0270 Office 337-501-6854 Cell Sundry Application Plug for Re -drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re - drilled. Those wells that are not re -drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist work) the initial reviewer will cross out that erroneous entry and initial then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended" box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) �-�'Q 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re -drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been Geologist handled properly. At this same time, they will also review the list of suspended wells for accuracy. MEMORANDUM TO: Jim Regg 1�ej`I P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: 6/22/2016 FROM: Lou Grimaldi SUBJECT: BOP Stack Inspection Petroleum Inspector KLU A-2 Kitchen Lights Unit Furie Operating Alaska LLC PTD 2160550 June 18, 2016: While out on the Randolph Yost jack-up drilling rig the other day I made a cursory inspection of the 13 5/8" stack that was up on the mezzanine. This stack is a rental unit. I took a bunch of pictures but the lighting was such that I had to use the flash and that whited out most of them. Attached are the best and representative of all ram bores. - There were new Blind/Shears in the #2 station. - Ram preventers all appeared to be in freshly spruced up condition. Hone patterns were evident in all the bores and all rubber goods were new. The door seal areas were flat and I saw no evidence of pitting. I have to say that they looked very good. - Annular Preventer pack -off element appeared to be new/very good condition. One thing I like to look at is the ring groove on the annular cap. This is critical if they have to rig up snubbing on top of the stack. The groove was like new. - I could not see the side entry ports on any of the ram bodies Summary: I performed the initial visual inspection of the rental BOP stack. Components inspected were in good condition. There were no function or performance tests of the stack components today. Attachments: Photos (4) 2016-0618_BOP_V isual_Randolph-Yost_lg.docx Page 1 of 3 BOP Stack Visual Inspection — Randolph Yost Jack-up Drilling Rig Photos by AOGCC Inspector L. Grimaldi 6/18/2016 Ow 13 5/8" 1 OM psi Upper Pipe Ram/Door Seal M_M.MM mom = 13 5/8" 10M psi Blind Shear Ram/Door Seal 2016-0618 BOP Visual Randolph -Yost Iv,.docx Page 2 of 3 13 5/8" 1 O psi Lower Pipe Ram/Door Seal 13 5/8" 5M psi Annular Sealing Element and Ring Groove 2016-0618_BOP_Visual_Randolph-Yost_lg.docx Page 3 of 3 Schwartz, Guy L (DOA) ��('� �� -- d a From: Schwartz, Guy L (DOA) Sent: Saturday, June 18, 2016 2:44 PM To: David McCraine Cc: Regg, James B (DOA); Grimaldi, Louis R (DOA) Subject: Re: 121' diverter lines / Rancloph Jost David. Furie has approval to spud well per your response using a 12.25" pilot hole as proposed in item 3 below. The other two items will be addressed in a separate email before approval to drill out of surface casing shoe. Regards, Guy Schwartz AOGCC 907-301-4533 Sent from my Whone On Jun 17,, 2016, at 1:26 PM, David McCraine <d.mccrainekfuriealaska.com> wrote: 1 The Furie rental stack is consisting of 3 Cameron Type U and a Schaffer annular. The Randolph Yost rented a stack to replace the stack supplied with the rig. Both stacks are similar with the choke and kill line connected to the outlets of the ram instead of using a cross. This system is used on Jackups to be able to get the BOP's under the floor in one lift. The BOP hoist are designed for this height and this reduces handling risks to the personnel. 2. The choke and kill line configuration is the original design of this manifold. Fuire will label the the choke, kill and the standpipe lines. We ani also plan to label the the *individual choke valves. 3. Furie will drilla 12 1 /4" pilot hole and open the hole to 17 1 /2" in a separate trip. Regards. Dave McCraine Furie Operating Alaska -Lafayette Drilling Engineer 337-981-0270 Office 337-501-6854 Cell From: Guy Schwartz <guy. schwa rtz@_a laska.gov> Date: Friday., June 17, 2016 at 3:14 PM To: Dave McCraine <d.mccraine@furiealaska.com> Cc: "Begg, James B (DOA)" <iim.regg a► alaska.gov> Subject: RE: 12" diverter lines / Randoph Jost David, Per our phone call I was going to restate the three items I saw on the rig yesterday: 1) State why a flow cross is not being used ... not required by regulation but is recommended under API RP53 Currently choke and kill lines are plumbed into the Shear ram body. 2) Why is the kill line tied into the choke manifold? This is very unusual and seems to be unnecessary. This would add confusion in a well control situation adding to the possibility for human error. Find out why this was routed as it is now.. there may be some reason that I am missing. No one on the rig had a good explanation. 3) The 12" diverter lines/valves are working as designed. The logic is hardwired to open only one line to the downwind side of the rig. Instead of opening both lines and defeating the logic AOGCC requests that you drill a 12 124" pilot hole and use the system as designed. This will meet all regulations under 20 AAC 25.035(c) for diverter systems. Approval to change the PTD plan from 17.5" to 12 1Z4" pilot hole can be made on a separate email. 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 IGuy. schwartz(2talaska.gov). From: David McCraine[mailto:d.mccraineC@furiealaska.com] Sent: Friday, June 17, 2016 9:33 AM To: Schwartz, Guy L (DOA) Subject: 12" diverter lines Guy, we have the diverter system working, but we would like to have permission to close the upwind line, if needed, in a diverter situation. This would mean diverting though one 12" line. We do not think it is safe diverting into the wind, but are confident one 12" line is capable. If we are not allowed to close one 12" line as needed, Furie would like to drill a 12 1/4" pilot hole and open it to 17 1/2 left you a message. How do I need to handle this issue? Thanks. Dave McCraine Furie Operating Alaska -Lafayette Drilling Engineer 337-981-0270 Office 337-501-6854 Cell THE STATE 01ALASKA GOVERNOR BILL WALKER David E. McCraine Drilling Engineer Furie Operating Alaska, LLC. 1029 West 3rd Avenue, Suite 500 Anchorage, Alaska 99501 Alaska 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: Kitchen Lights Unit, Kitchen Lights Undefined Gas Pool, KLU #A-2 Furie Operating Alaska, LLC. Permit to Drill Number: 216-055 Surface Location: 895.93' FWL, 343.48' FSL, Sec. 24, T10N, R11 W, S.W. Bottomhole Location: 223.03' FEL, 314.64' FNL, Sec. 24, T1 ON, R11 W, S.W. Dear Mr. McCraine: Enclosed is the approved application for permit to drill the above referenced development well. 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. Variance requests: Furie Operating Alaska, LLC.'s (Furie) request to eliminate conductor pipe as required for offshore installations is APPROVED. A 20 inch structural pipe will be driven to 345 ft MD and a diverter installed for drilling the 17 '/2 inch surface hole section to a depth of 2300 ft. MD. In drilling KLU #3 (on same platform) no indications of shallow gas were seen in the surface hole section to same depth. Diverter will be utilized for surface hole drilling. Furie's request to use 2 x 12 inch diverter lines for drilling 17 1/2 inch OH is APPROVED. The equivalent surface area of the two 12 inch diverter lines is essentially the same as a 17 1/2 inch hole. (236 sq. in vs 240 sq. in). Furie's request to eliminate 142S monitoring equipment is DENIED. Standard procedure and best operating practices in the Cook Inlet require installation of H2S equipment for offshore drilling installations. Conditions of Approval: 1. Rig inspection and resolution of all deficiencies required before drilling operations start. 2. 10,000 psi 13-5/8 inch BOPE to be tested to 3500 psi minimum. Initial witnessed test may will at 5000 psi for commissioning BOPE. (SM annular to 2500 psi -min) 3. 13 5/8 inch surface casing shoe must tested to min FIT/LOT of 13.5 ppg EMW. FIT data to be submitted to AOGCC. 4. Casing tests as follows: • 13 3/8 inch casing test pressure = 2500 psi ( 46% of burst) • 9 5/8 inch casing test pressure = 3500 psi (44% of burst) 5. BOP Casing Rams to be tested as per following: • 9 5/8 inch rams to 2500 psi 6. Daily Drilling report to be submitted to Commission by email. 7. BOPS equipment will be on 7 day testing cycle (i.e. not to exceed 7 days). 8. Furie is required to install H2S monitoring equipment on board. 9. CBL required over 9 5/8 inch casing to determine TOC and cement quality. 10. Sundry approval required for completion operations including running tubing, perforations or hydraulic fracture stimulations. This permit to drill does not exempt you from obtaining additional permits or an approval 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. 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 an 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 fd-day of June, 2016. STATE OF ALASKA 1/ZSt� )KAOILAND GAS CONSERVATION COMMI PERMIT TO DRILL 20 AAC 25.005 E DW -E C E I V E MAY 11 2 016 1 a. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. pecify if I s- pro` osed for: Drill Lateral Stratigraphic Test Development - Oil N Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name: 5. Bond: Blanket M,, , Single Well 11. Well Name and Number: Furie Operating Alaska LLC Bond No. 402-081A tJ Kitchen Lights Unit # A-2 3. Address: 6. Proposed Depth: 12. Field/Pool(s): 4906 Ambassador Caffery Pkwy Suite #800 MD: 9789 TVD: - 7231 KLU Undefined Natural Gas Pool 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 895.93 FWL & 343.48 FS of T1ON: R11W, Sec24 ADL 389197 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2244.4 FEL & 2825.13 FNL of T10N:R11W. Sec 24 N/A 6/3/16 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 223.03 FEL & 314.64 FNL of T10N : R11 W : Sec 24 2560 3+ miles (non Furie) 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): ,� 1 15. Distance to Nearest Well Open Surface: x- 294331.49 y- 2,536,125.62 Zone- 4 GL Elevation above MSLft () ?&; to Same Pool: 33005 16. Deviated wells: Kickoff depth: 37S feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 4,A degrees Downhole: lv�) le j� Surface: 011/ 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) Driven 20" 94 ppf X-56 XLC-S 345 0 0 345 345 DRIVEN 17.5" 13-3/8" 72 ppf N-80 BTC 2300 0 0 2300 1985 Lead 2218 cu.ft. 12.3 ppg tail 623 cuff 15.6 ppg 12.25" 9 5/8" 53.5 ppf 170 BTC 9789 0 0 9789 7231 Lead 1683 cu.ft. 13.5 ppg Tail 928 cu.ft. 15.6ppg _T 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 Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Property Plat BOP Sketcli/MDrilling Program Time v. Depth Plot Shallow Hazard Analysi, Diverter Sketcilvi 14N Seabed Report 19 Drilling Fluid Program 20 AAC 25.050 requirement 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact David McCraine Email D.mccraine furiealaska.com Printed Name David McCraine Title Drilling Engineer Signature r�� Phone 337-981-027 0 Date 5/9/16 Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other d Date: �.. .r Number: CS 50- 3 ' G (.� -- � ` requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbedme hane, gas hydrates, or gas contained in shales: Other:�., Z-16/' Samples req'd: Yes No Mud log req'd: Y N 6) Lo 4 fe ., '�' H2S measures: Yes No Directional svy req'd: Y N Spacing exception req'd: Yes ' No Inclination -only svy req'd: Y N Post initial injection MIT req'd: Y NcLj 60 C L L ewk C�;. CAL �COL p P - APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: (� ORIGINAL Submit Form and Form 10-401 (Revised 11/2015) This permit is valid for 24 months from the date of approval (20 AAC 25.005(g)) Attachments in Duplicate FURIE RECEIVED Operating am:aa tic MAY 11 2016 AOGCC May 10, 2016 Alaska Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Re: PTD 216-055 Well: Kitchen Lights Unit #A-2 TO WHOM IT MAY CONCERN: Furie Operating Alaska, LLC (FOA) hereby requests a modification in the Permit to Drill 216-055, the KLU # A-2, an offshore development well within its Kitchen Lights Unit located in the Cook Inlet of Alaska. FOA would like to drill the well to 9879' MD/ 7231' TVD, and is submitting a new form 10-401 Application for Permit to Drill with the required documents. Attached please find the following information required by 20 AAC 25. 00, in duplicate, for your review. 1) Form 10-401 Application for Permit to Drill 2) Well Prognosis: a. Anticipated Formation Tops b. MASP while drilling to TD with 13-5/8" IOM BOP C. Drilling Hazards d. Drilling Fluid Plan e. Survey Plan f. Logging Plan g. Mudlogging Plan —waiver request h. Casing Plan i. Cementing Plan j. Well Control Equipment 3) Plat showing the surface location 4) Well bore Diagram 4906 AMBASSADOR CAFFERY PKWY SUITE # 800. LAFAYETTE, LA 70508 1 OFFICE: 337.981.0270 1 5) Directional Plan 6) Drilling Program 7) Depth Days Plot 8) Geo Mechanical Plot 9) Seismic Cross Section 10) Geological Formation Top Prognosis 11) Projected Mud Program 12) Casing Design Information 13) Kick Tolerance 14) FIT Procedure If you have any questions or require further information please contact Furie Drilling Engineer, David McCraine, at (337) 981-0270 or d.mccraine(&,furiealaska.com . Sincerely, David McCraine Drilling Engineer 4906 AMBASSADOR CAFFERY PKWY SUITE # 800. LAFAYETTE, LA 70508 1 OFFICE: 337.981.0270 2 l FURIE 7 , Operating Alaska LLC Permit to Drill Kitchen Lights Unit Well # A-2 Table of Contents Description pie Permit To Drill 1 Well Prognosis 2 Surface Plat 6 Wellbore Diagram 7 Directional Plan 8 Proximity Plat and Statement 11 Drilling Procedure 13 Depth vs Days Plot 19 Geo- Mechanical Plot 20 Sesmic X -Section 21 Formation Top 22 Mud Program 23 Casing Design Factors 24 Kick Tolerance Worksheet 25 Formation Integrity Test Procedure 26 Well Control Equipment 27 211/4" Diverter Diagram 28 13 5/8" 10M BOP Diagram 29 13 5/8" 10M choke Manifold 30 Mud Pit Capacity Chart 31 Wellhead Diagram 32 FURIE Operating Alaska LLC Well Prognosis For KLU # A-2 Kitchen Lights unit # A-2 is a developmental well off of the Julius R monopod in the Cook Inlet. The objectives are the upper and lower Sterling encountered in the KLU #3. KLU # A-2 is a directional well drilled with the jackup, Randolph Yost. Upon reaching TD of 978'M/723 I' TVD, Furie plans to run 9 5/8" 53.5 ppf L-80 BTC casing and cement it in place, prior to nippling down and setting a dry hole tree. A sundry will then be submitted for the completion. Surface Location: X-294,331.49 & Y- 2,536,125.62 Bottom Hole Location: X-298,292 & Y- 2,5399099 Total Depth 9789'MD / 7231' TVD a) Formation Depths: Sterling - 3603' MD/ 2863' TVD — potential gas zones Beluga — 6833' MD/ 5082' TVD — potential gas zones Property Lease: ADL3 89197 b) Maximum Anticipated Surface Pressure. - MASP =Frac Gradient at shoe —Gas gradient 1195 psi = (13.5*.052*1985tvd)- (.Ipsi/ft* 1985') x,oTZ x 7431) 22- c) Potential Drilling Hazards: ------ Review Review of KLU # 1 & sidetrack revealed coal sloughing in the 12 1/4' hole causing stuck pipe incidents at 10.248', 10570', 1025' . Back reaming, washing and reaming helped to successfully clean the hole. Additional mud weight was used to stabilize the wellbore and run 9 7/8" casing. KLU # 3 - The drive pipe was washed out with a 26" bit and KLU # 3 was spudded on 4/26/13 drilled to 1950' with a 9. 1ppg mud. No mud losses were observed. No gas was encountered. The casing crew was rigged up and 13 3/8" 72 ppf N-80 BTC casing was run to 1903'. The casing was cemented with 37 bbls of cement return and theg p lu s bumped. The annulus was washed out to 289' using grout strings. A FIT was taken to 12.5 ppg EMW. The mud was displaced with a new LSND 9.3 ppg mud. The KLU # 3 was drilled to 10,293' with no drilling issues Review of the most recent experience drilling of the 12-1/4" hole for the KLU2 & 2a found that lost circulation was experienced at 3179' with a loss rate of 120 bph but was F U R I E Operating Alaska LLC cured with two 30ppb LCM pills. While on KLU#1, coal sloughing caused stuck pipe incidents at 10,248', 10,570' & 10,625'. Back reaming, washing and reaming, successfully cleaned the hole. Additional mud weight was used to stabilize hole prior to running 9-7/8" casing. KLU # 4 - KLU4 while driving the 30" X 1.5" X 56 to 318' pipe hit refusal at 257' with 197 blows / ft. A pilot hole was drilled to . 317' and which allowed driving to continue to 318'. While drilling the 12-1/4n pilot hole, losses as high as 40 bph between 1080' and 1650' were encountered but 30 bbl pills with 15#/bbl fiber were effective in controlling the loss. The pilot hole was opened to 26" with losses from 491'-728',1260-1340' and 1605"-1845" 30 bbl pills 20#/bbl med fiber 15 #/bbl caco3 were effective in controlling the losses. At 2396' the 20" casing shoe was set. After drillout a -LD of- 14.3 ppg EMW was achieved. With a KOP at 2700' an Inclination to 24 degrees was achieved and the well was directionally drilled to 9200' TO. At 6282' a loss of 105 bbls. occurred which required a 20 bbl pull 16 #/bbl to cure. The well had to be backreamed 6165-3616' prior to drilling to 7818. Drilling ahead required backreaming each stand. The bit trip from 7818' required backreaming out and wash back into the hole. The second bit trip from 7818 was made on the elevators as well as the rip from 9200 TD. E line logging was attempted but became stuck and had to strip over to recover. Pipe convey logs were run without incident. A 13-5/8" casing string was ran and cemented. The mechanical DV didn't open during the second phase of cement job as the dart didn't reach tool due to 24 -degree angle. A down squeeze of the 20" X 13-5/8" annulus was required. None of the offsets encountered 1-12S. The KLU# A-2 is drilling the same fault block as the KLU #3 and the gas analysis shows that no H2S is present d) Drilling Fluid Summary Surface Hole: a directional 17 1/2" hole to 2300'MD/ 1985' TVD Gels spud mud — ±9.4 Z p ppg Production Hole — 12 1/4" hole from 23 00' MD/ 1985' TVD —9789' MD/ 7231 ' TVD 10.0 - 10.1 glycol[[ KCL/ amine inhibited mud e) Survey Program: The well will be surveyed at interval not exceeding 100' apart as required by 20 ACC 25.050. FURIE Operating Alaska LLC A directional plat showing the well within 200' of the KLU A-2, the KLU # 3 is included in the directional section. The KLU # 3 is owned by Furie Operating Alaska, LLC making Furie Operating Alaska, LLC the only affected applicant to wells in proximity. f) Logging Program: GR LWD: 400' - 2300': Triple combo LWD : 2300'— 9789'MD Furie asks for a waiver from the Triple Combo above 23 00'. g) Mud logging: Furie will mud log from 400' — 9789' MD in accordance with 20 AAC 25.071 . h) Planned Casing program for KLU # A-2: Casing 20" x.812" 13 3/8" 9 5/8" Depth 345' MD/ 126' Penetration 2300' MD/1985' TVD 9789'MD/ 7231' TVD Hole Size Driven 17 %2" 121/4 Weight (ppf) 166.56 * 72 53.5 Grade X-56 N-80 L-80 Connection XLC- SE BTC BTC - RS * Plain end weight. i) Cementing Summary: 20" x .812" wall (18.3 76" ID) Drive Pipe Drive to 345' with 126' penetration — no cement 13 3/8" 72 ppf set at 2300'MD/1985' TVD RKB Lead volume 126' x 0.4677cf/ft with 0% excess — 58.93 cu ft 1555 x 0.6946 x 100% excess — 2160 cu. Ft. Total lead volume = 2218 cu ft. Tail volume 400' x 0.6946 x 100% excess = 555.68 cu. Ft. 80' x.8314 cu ft/ ft with 0% excess = 66.5 cu ft Total tail volume = 622 Cu. Ft. e00 .- FU RI E Operating Alaska LLC 9 5/8" 53.5 ppf set at 9789' MD/ 7231' TVD w/ TOC A 3200' Lead Volume 4300'x.3132 cu ft/ ft x.25% excess — 1683 cu ft Tail Volume 2289' x .3132 cu ft/ ft x .25% excess = 896.14 cu ft 80' x.3973 Cu ft/ ft x 0% excess — 31.78 cu ft Total Tail volume — 9.. ...28 cubic ft. j) Well Control Equipment: 21 1/4" 2M Diverter with two (2) 12" diverter lines. 13 5/8" 5M annular and 13 5/8" 1 O three ram BOP k) Gas Detection: Furie plans to rig up Flo -show and gas detection on the initial rig up, prior to spud for methane gas detection. -4' Hz- S' 15 V Kitchen Lights Unit #A-2 _ Proposed Bottom Hole cIt NAD27 Alaska Zone 4 Feet X : 298,571.41 a -.. M Y : 2,540,673.75 Lat : 60°56'57.6554"N Lon : 151 °07'58.8018"W NAD83 Lat : 60°56'55.6457"N Lon : 151008'06.8685"W + ' f / ' 223.03' I N 1/4 Jco r �KE 114 LO CIDN N 22 23 —_ --- 2- 4 19 41M Top of Production' A�� NAD27 Alaska Zone 4 Feet °T X : 296,507.00 �'��`L Y : 2,538,199.00 .ki Lat : 60056'32.9352"N Lon : 151 °08'39.7202"W ,fv ! Q' 1 E 1/4 flh°' NAD83 �0/`L' SURFACE TO Lat : 60°56'30.9259"N � Lon : 151008'47.7871 "W 895.93' TOP OF LU -3 I PRODUCTION ii1...;_€-,A2 1 ,* KLU-1 Co Kitchen Lights Unit #A-2 't Proposed Well Surface `o NAD27 Alaska Zone 4 Feet X : 294.331.49 Y : 2,536,125.62 Lat : 60056'12.1442"N 27Lon : 151009'23.0125"W 26 NAD83 25 Lat : 60056'10.1353"N 30 Lon : 15100931.0796"W I 0 Z 34 35 36 31 I HEREBY CERTIFY THAT THE ABOVE PROPOSED NOTES WELL SURFACE LOCATION IS CORRECT. 1. COORDINATES TRANSFORMED FROM ���� ,, ,ftp �►'� ` NADCON (ALASKA). OF A , 2. THIS DRAWING IS NOT FOR NAVIGATION, I s;+•'"'•'*,�_� ONLY WELLS IN THE IMMEDIATE VICINITY OF ow 11:�s' '.' THE SURVEYED WELL ARE SHOWN. 3. AKCS27 DENOTES ALASKA COORDINATE 4Q,TH `K. * '' SYSTEM OF 1927. • • t a 4. SECTION 24, TOWNSHIP 1 ON RANGE 11W, SEWARD MERIDIAN IS WITHIN THE ALASKA C� S/ 3 //� " * STATE WATERS OF COOK INLET. 5. SECTION LINE OFFSETS COMPUTED FROM "� •"' • • • • • • • + • • • • • .. • . • ..... • . , • PROTRACTED SECTION CORNER VALUES. Mark �C:iih,;ke ;•Q' 6. SURFACE AND BOTTOM HOLE INFORMATION OW Az �e%••.s �p, 12656••' •F ��0�s��• �► PROVIDED BY CLIENT AND DOES NOT REPRESENT A FUGRO CHANCE FIELD SURVEY. MARK KEITH BUHRKE RPLS #12656 STATE OF ALASKA J F U R I E Operating Alaska LLC PROPOSED LOCATION KITCHEN LIGHTS UNIT #A-2 ADL #389197 NE 1/4 OF SECTION 24, TOWNSHIP 1 ON, RANGE 11 W SEWARD MERIDIAN, ALASKA FUGRO CHANCE INC. 200 Dulles Drive Lafayette, Louisiana 70506 (337) 237-1300 Geodetic Datum: NAD27 SCALE 0 2000 Projection: AKCS27 Zone 4 1:24000mmli Gr!d Units: US SURVEY FEET FEET Job No.: 1600301 Date: 5/2/2016 Drwn: BCN Chart: Of: 1 1 DWG File: H:\2016\1600301\GIS\...\Cook in let_Sec24-T10N-R11... 5/03/2016 FURIE OPERATING of ALASKA, LLC 0:0 KITCHEN LIGHTS UNIT NO A-2 FURIE -0 COOK INLET, ALASKA Operating Alaska LLC 4/15/16 DEM WELL BORE SCHEMATIC X SL: X - 294,331.4E; Y - 2,536,125.621 HL- X BHL: X - 298,571.41.E; Y - 2,540,6-, DIRECTIONAL TUBULARS & SETTING DEPTHS PP Mw Frac API: TBD (PPG) (PPG) (PPG) FORMATION EVALUATION DEPTH (KB) Permit TBD MD TVD DRILL FLOOR RKB TO: 90 HIGH TIDE . ............ . . MEAN LOW LOW WATER 219 SEA FLOOR 376 126`1.2@" i 719" WIT pit Mudlog LWD: GR I 17 1/2" KOP @ 300'; B U R - 3*1100'; 'Az 46.4* EOB @ 1906'MD 1724 -TVD Hold 48.182*inc & 45.4* Az 46.68' Az ELECTRIC LOGS (OPTIONAL): I 2,30.0 1,985 13 318" 72'# N-$0 STC 8. 9.4 13.5 I Mudlog 12 1/4" HOLE r MWDILWD: Triple Combo Hold 48.182'inc & 45.4* Az 46.68' Az o 5475' MD / 4103' TVD Drop to 42.8*and turn to 36.8' Az by 27100' DLS by 5882' MD / 4388.5'TVD Hold to 7475'MD/ 5554' TVD Build to 43.578* by 7553'11+1D/ 5611'TVD 3000 Hold to 9789'MD/ 7231'tvd 3200 2585 TOC 3639 2879 Sterling ELECTRIC LOGS (OPTIONAL: MDT -have available 4,000 3,118 5000 5102 3854 MDT 3800' Sand 5475 4103' MDT 4018'Sand 5714 4271 MDT 4172' sand 6000 4474 6504 4814 MDT 4669 Sand 6790 5054 Beluga 9789 7231 $1$- 53.5 # �-$Q OTC X0 schematic—POD.x1sx 5/5/16 17 FURIEFurie Operating Alaska, LLC BAKER Location: Cook Inlet, Alaska (Offshore) Slot: KLU#A-2 Condor (Slot B) Field: Kitchen Lights Unit Well: KLU#A-2 Condor HUGHES Facility: Furie Monopod Platform Wellbore: KLU#A-2 Condor Sloth Plot reference wellpath is KLU#A-2 Condor (SlotB)_Ver#13 Grid System: NAD27 / TM Alaska SP, Zone 4 (5004), US feet True vertical depths are referenced to Randolph Yost (Planned Elev) (RT) * = Wellpath was transformed from a different geodetic datum Measured depths are referenced to Randolph Yost (Planned Elev) (RT) North Reference: True north Randolph Yost (Planned Elev) (RT) to Mean Sea Level: 132 feet Scale: True distance Mean Sea Level to Mud line (At Slot: KLU#A-2 Condor (Slot B)): 118 feet Depths are in feet Coordinates are in feet referenced to Slot Created by: ulricard on 2016-04-28 Database: WA ANC Defn Well Profile Data Design Comment MD (ft) Inc (0) Az (0) TVD (ft) Local N (ft) Local E (ft) DLS (0/100ft) VS (ft) Tie On 132.00 0.000 45.404 132.00 0.00 0.00 0.00 0.00 End of Tangent 375.00 0.000 45.404 375.00 0.00 0.00 0.00 0.00 End of Build (J) 2000.02 48.751 45.404 1810.92 456.80 463.29 3.00 649.46 End of Tangent (J) 5518.83 48.751 45.404 4131.00 2314.27 2347.18 0.00 3290.34 End of 3D Arc (J) 5955.89 42.625 36.670 4436.48 2548.78 2552.95 2.00 3602.31 End of Tangent (J) 6833.19 42.625 36.670 5082.00 3025.31 2907.75 0.00 4193.86 End of Tangent 7475.00 42.625 36.670 5554.24 3373.92 3167.31 0.00 4626.62 End of 3D Arc (J) 7553.53 43.578 38.497 5611.59 3416.43 3200.04 2.00 4680.12 End of Tangent (J) 9528.06 43.578 38.497 7042.00 4481.71 4047.30 0.00 6038.73 End of Tangent 9788.95 43.578 38.497 7231.00 4622.47 4159.25 0.00 1 6218.24 Scale, inch 1500 Easting (ft) -750 0 750 1500 2250 3000 3750 450250 9 6,257 cas% 9 Condor (MDT 6960 Sand -Apr 28_2016) 4500 3750 -1250 N Condor (Original TD Jan 252016Condor (Beluga)Condor AIT (4669'Sand 3000 0 Condor (4172' Sand) OZ On Condor (Primary Tgt _Jan 25_2016 20in Drive Pipe Condor (3800' Sand) 2250 1250- �Gasin9 Surface rd °{ 3.37 1 500 2500 C cam 750 3750 oo a �N� Condor (3800' Sand) �` � �O S, �C O3 ok ti`�1 Condor (Primary Tgt _Jan 25_2016) �, �a e� 20in Drive Pipe ds 0 �1 N Condor (4172' Sand) a�e,�` 1,9 Z S � Condor (4669' Sand) Sao IL 5000 C'onaor �o aoko Condor (Beluga) Condor (Original TD Jan 25_2016) a `970t --750 6250 p toe aok���oe o Condor (MDT 6960 Sand_Apr 28_2016) 7500 Ga ti �o °J 875250 0 1250 2500 3750 5000 6250 7500 Vertical Section (ft) Scale 1 inch 2500 Azimuth 41.980 with reference 0.00 N, 0.00 E Report Generated Operator Area Field Facility Slot Well Wellbore Wellpath y Wellbore Last Revised Sidetrack from User Calculation method Declination Ellipse Confidence Limit Slot Location Facility Reference Pt Field Reference Pt • • Projection System North Reference Scale Horizontal Reference Point Vertical Reference Point MD Reference Point Field Vertical Reference �F Randolph Yost (Planned Elev) (RT) to Mean Sea Level - Randolph Yost (Planned Elev) (RT) to Mean Sea Level Randolph Yost (Planned Elev) (RT) to Mud Line at Slot (KLU#A-2 Conc Section Origin X Section Origin Y Section Azimuth Surface Position Uncertainty Ellipse Start MD Local North Local East Grid East Grid North Latitude [ft] [ft] [US ft] [US ft] !.294331.49 60'56'12.144"N 294330.50 2536132.70 .I' 295510.04 Start MD End MD Positional Uncertainty Model Log Name / Comment [ft] [ft] ! 1 11 11 • • • String / Diameter Start MD End MD Interval Start TVD End TVD Start N/S Start ENV End N/S End ENV [ft] [ft] [ft] [ft] [ft] [ft] [ft] [ft] [ft] Wellbore Wellbore Longitude Horiz. Uncert 1sd Vert. Uncert 1sd [ft] [ft] '!• 1 1 11 11 Target Name MD TVD North East Grid East Grid North Latitude Longitude Shape Comment [ft] Condor (3800'Sand) [ft] [ft] [ft] [US ft] [US ft] [ft] 1 11 11 1 1 11 1 • r SZ -W, MD Inclination [ft] [°] Azimuth [°] TVD TVDSS North East Grid East Grid North Latitude Longitude DLS Toolface Build Rate Turn Rate Vert Sect Major Semi Minor Semi Vert Semi Minor Azim Comments �i.8.i� ��� ir8ia ® �® �WTi [ft] 1 11 11 1 1 11 1 • r SZ -W, [ft] 11 1 11 1 1 1 1 11 .• .. •• ' • • ®® ':1 iLFTM [ft] 1 11 ! 11 1 1 1 1 i1 / ./ ®� �� ! •• ii -7, WTi [ft] 1 11 ! 11 1 1 1 1 It � �• .: � �zr� [US ft] •• •• •• ' W-, •, , •• •• .. •. .. II • ' 1 • 1 •• , •. .. [US ft] W W-5'® all &TV FWA E, F, . . ./' W• 1' . • FW 0 L-11 A-1-2 I OA E, 15, M • . •1' • . • .1' • ,1 • BYJ&*M K--1$Wa PM1.1, Pil E . • . 1 ' . • 1 • 1 • .t" • • • 1 .1" • .: - - - • - - - - Oft] 161111• $1 RITATAMCI '!• c 1 � 1 11 1• 1 1 1 1 0 167 2 IN I1• 1 RWATJ1 11 '1• 1 III®,/ '1• 111 11 0 &11• .• 11 1 • 1 1 '1• •11 11 '1• 1 • 11 - - - ° ] [ ] [°/100ft ! !1 1 11 1 1 1 1 1 1 1 11 1 11 1 11 1 11 11 111 11 I 1 1 1 I 1 11 11 1 11 11 [°/100ft] ! !1 1 1 1 1 11 111 • •. 1 t1 1 11 1 11 [ft] [ft] [ft] [ft] [°] 1 11 1 11 ! 11 1 11 1 1! - • 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 11 1 1 1 1 �� 111 1 1 •1 I ®® • • •- �� '1 1 '®� ®�� ����� �� � 1 • �® Furie Operating Alaska, LLC as FURIELocation: Cook Inlet, Alaska (Offshore) Slot: KLU#A-2 Condor (Slot B) FrA Field: Kitchen Lights Unit Well: KLU#A-2 Condor i"tip hof s'iftij �.i i f IMKMFacility: Furie Monopod Platform Wellbore: KLU#A-2 Condor SIotB HUGM reference wellpath is KLU#A-2 Condor (SlotB)_Ver#13 Grid System: NAD27 / TM Alaska SP, Zone 4 (5004), US feet -Plot - -- Well Profile Data True vertical depths are referenced to Randolph Yost (Planned Elev) (RT) ° = Wellpath was transformed from a different geodetic datum Design Comment MD ft Inc (°) Az (°) TVD (ft) Local N (ft) Local E (ft) DLS (°/100ft) VS (ft) Measured depths are referenced to Randolph Yost (Planned Elev) (RT) North Reference: True north - ---_- -- Tie On 132.00 0.000 45.404 132.00 0.00 0.00 0.00 0.00 Randolph Yost (Planned Efev) (RT) to Mean Sea Level: 132 feet Scale: True distance --- - - -- -- - - - -- End of Tangent 375.00 0.000 45.404 375.00 0.00 0.00 0.00 0.00 Mean Sea Level to Mud line (At Slot: KLL#/A-2 Condor (Slot B)): 118 feet Depths are in feet - - --�- -- - - - - Coordinates are in feet referenced to SlotEnd of Build (J) 2000.02 48.751 45.404 1810.92 456.80 463.29 3.00 649.46t Created bY: ulricard on 2016-05-09 - - - -- -- -- End of Tangent (J) 5518.83 48.751 45.404 4131.00 2314.27 2347.18 0.00 3290.34 Database' WA ANC Defn End of 30 Arc (J) 5955.89 42.625 36.670 4436.48 2548.78 2552.95 2.00 3602.31 End of Tangent (J) 6833.19 42.625 36.670 5082.00 3025.31 2907.75 0.00 4193.86 End of Tangent 7475.00 42.625 36.670 5554.24 3373.92 3167.31 0.00 4626.62 End of 3D Arc (J) 7553.53 43.578 38.497 5611.59 3416.43 3200.04 u 2.00 _ 4680.12 End of Tangent (J) 9528.06 43.578 38.497 7042.00 4481.71 4047.30 0.00 6038.73 End of Tangent 9788.95 43.578 38.497 7231.00 4622.47 4159.25 0.00 6218.24 Scale 1 inch = 50 Easting (ft) -50 -25 0 25 50 75 100 125 150 175 200 225 250 275 300300 Z 275 001 250 225 �Q00 200 175 ,7 00 150 v125Z O ,`p00 �,0 100 O 75 70 00 50 000 120 25 a � Q tr 00 a � 0- r'L3 tsYiot n 6, 00 y,w.: ear s KLUtFA-2 C9ndor (Slot BI - 0 O cO -25 -50 FURI E Operating Alaska LLC DIRECTIONAL PROXIMITY A directional plat showing the well within 200' of the KLU A-2, the KLU # 3 is included in the directional proximity section. The KLU # 3 is owned by Furie Operating Alaska, LLC, making Furie Operating Alaska, LLC the only affected applicant to wells in proximity. FURIE Operating Alaska LLC FURZE OPERATING ALASKA KITCHEN LIGHTS UNIT NO. A-2 COOK INLET PROCEDURE A. LOCATION 1. Jack down to water and test Randolph Yost hull for seaworthiness. 2. Record tug's name, dock departure time and time at location. 3. Hook up lines and free legs. 4. Tow rig to location. a. X = 294,331.49E & Y=2,583,125.62N (NAD 27, ASP Zone 4). Lat: 600 56' 12.144" Long; -1510 09'23.013" 5. Take side scan sonar to verify location clearance. 6. Winch rig into position against platform. 7. Orient Randolph Yost with 234 -degree bow heading. 8. Pre -load Randolph Yost. 9. Jack up to skid cantilever over platform. B. Drive Pipe 20" x.812" wall to 350'±126' Penetration — RKB to sea floor - ±219' 1. Rig up 20" casing running tool and S-90 drive hammer. Note: Have NOV hand on location: 2. PU 20" x.812" with XLC-S connectors joint with deviated double wall drive shoe. 3. Orient shoe in 45 ° and run scribe line. 4. PU 20" x .812" with XLC-S connectors. 5. Drive 20" to 345', ±126' of penetration. Anticipate maximum blow count to be 55 BPF. Make up Torque; Min.- 27,000 ft -lbs.; Ideal — 30,000 ft -lbs; Max — 70,000 ft -lbs. 6. Cut 20" spaced out for drilling spools to be below mezzanine deck and tree to be above mezzanine deck. 7. Install 20" load ring. 8. Install the riser connector with the WQ seal on the 20". 9. Test the riser adapter by testing between the WQ seals to 2000 psi. 10. Install the 21 1/4" 2 M riser. 11. NU 21 1/4" 2M diverter with two 12" outboard lines. ` 6- c- f o 12. NU 12" outboard lines to divert and function test. ��-'' W4,4"AA�- 13. MU 17 /2 GTX -CGI 9.5 Ultra XL Motor, 8 NM CS DP with 8 straight blade stab, Navi Track, Pulser, NM downhole filter sub, NM UBHO, 2 joints 8" NMCSDP, XO, 8 joints 5" HWDP, 7' j ars, 12 joints 5" HWDP, 5" drill pipe to surface. 13 FURIE Operating Alaska LLC C. Drilling 17 1/2" Hole to 2300' MD/ 1985' TVD 1. Pick up 8000' of 5" drive pipe. 2. GIH with 17 1/2" GTX — CGI bit, 9.5" Ultra XL Motor, 8" NM CS DP with 8" straight blade stab, Navi Track, Pulser, GR sub, NM downhole filter sub, NM UBHO, 2 joints 8" NMCSDP, XO, 14 joints 5" HWDP, 6.25' j ars, 6 joints 5" HWDP, 5" drill pipe to surface. 3. Wash out DP to 375', viscoscified mud. 4. Run Single shot gyro and get inclination survey at the base of drive pipe. 5. Orient mm and build 3'/l 00' in 45.404 azimuth to 2300'MD /1985'tvd. 6. CBU and POOH to DP shoe. 7. PU 17 1/2" hole opener and make wiper trip, if needed. 8. GIH to TD and CBU. 9. POOH. 10. RU 13 3 8" casing running tools. Run 13 3/8" 72 # N-80 BTC casing as follows: a. 13 3/8" 72# N-80 BTC float shoe b. ±80' of 13 3/8" 72 ppf N-80 BTC casing c. 13 3/8 72# N-80 BTC float collar d. ± 1826 of 13 3/8 80 ppfN-80 BTC casing. e. Cameron T-137 casing hanger running tool with T-137 Metal seal neck x 13 3/8" BTC box bottom. f. 13 3/8" 72 ppf N-80 BTC Landing joint Note: 13 3/8" float shoe is baker -locked to pin end of joint # 1 and coupling is Baker -locked on joint # 1. Baker lock joint # 1 coupling and joint # 2 pin. Joint # 2 coupling is baker -locked to joint and float collar is Baker locked in coupling. Do not Baker lock joint # 3 to float collar. Make up torque values should be carefully noted on the first 6 -8 joints while making up casing to the base of the triangle. Use this established torque value on the remainder of the casing. If coupling face is between minus 1 thread turn (.2") and the base of the triangle, the make-up is satisfactory. Centralize first joint at 10' from shoe with stop ring. Centralize next 8 couplings and then every other coupling to mudline. Total 29 centralizers. 11. Lower the casing until it lands on the load ring. 12. Rig up circulating swedge and circulate bottoms up with 50% wash-out factor or 428 bbls minimum. Circulate until background gas is at or below below drilling levels. Stage pumps up to 8-10 bbls /minute. Watch for losses and reduce rate if losing volume. Bottoms up is 285 bbls. 100% wash-out is 570 bbls. / �% FURIE Operating Alaska LLC 13. Rig up Cement per cement program below: Spacer- 80 bbls Mud push II @ 10.0 ppg Lead 640 sacks Class G +.05 gal/sack Antifoam + 0.5agl/sack Extender WEIGHT: 12.3 ppg YIELD: 2.36 Cu. Ft / sk Water: 13.561 gps: - Seawater Mix Fluid: 14.11 gps Tail 940 sacks Class G + .2 gal/sack Antifoam + 0.08 gal/sack Dispersant L. T. + 0.45 ..n gal/sack Fluid Loss + .06 gal/sack Accelerator WEIGHT: 15.6 ppg YIELD: 1.22 Cu. Ft / sk Water: 4.838 fps: Mix Fluid: 5.628 gps Spacer 5 BBLs fresh water 14. Displace cement with 328 BBLS mud to top of float collar. Bump plug with 1000 psi over pump pressure., Do not over displace cement by more than 6 bbls. Capacity of 13 3/8" shoe track is 12 bbls. +ZA 15. Rotate 9 right hand turns and release the running,toV and POOH. 17. ND diverter and riser. 16. Strip the drilling riser adapter over the T-13 7 casing hanger. 17. NU Cameron 13 3/8" MBS x 13 5/8" 5M psi WP wellhead. " 18. Tighten the lockdown screws in an alternating cross fashion to 400 -ft -lbs is on each lockdown screw. 19. Test wellhead to 2500 psi for ±5 minutes. Burst of 72 ppf N-80 BTC casing is 5380 psi. NOTE: Casing test will test wellhead also. 20.. NU 11" 5m x 13 5/8" 1 O DSA. 21. NU 13 5/8" 10M" BOP, and 13 5/8" 5M Annular, bell nipple and all choke and kill lines. 22. Install test plug. Shell test BOP to 5000 psi. 23. Test BOP and all equipment on a chart to;5015000 si. Test annular to 250/ psi. AOGCC _ p � to witness.,it `' NOTE: Drilling MASP is 1210 psi to break down a 13.5ppg EMW shoe at 1985' TVD Production MASP is 2887 psi using MDT pressures of 9.6 ppg EMW and a. I psi/ft gas gradient at 7231' TVD. All future test to be 250 psi low and 3500 psi high. FURIE Operating Alaska LLC D. Drilling 12 1/4" hole to 9,789' MD/ 7,231' TVD L� BOP test every 7 days on a chart to 250/ 3500 on rams and surface equipment and 25Q/; -<o on annular. AOGCC to witness test and give AOGCC 48-hour notice. l 1. Make up 12 1/4" PDC bit with .902 TFA, Bit sub with float, 8" Xtreme motor AKO 1.1 with float, 8" NMCSDP with 12 1/8" straight bald string stab, stop sub, 8" Ontrack (GR, Res, Survey, Pressure) sub, Modular stab 1/8" UG., BCPM (pulser), LithoTrack (Density/ Neutron), Stop sub, NM downhole filter sub, 2 joints 8" NMCSDP, XO, 8 joints 5" HWDP, 7" hydraulic jars, (12) 5" HWDP, 5" s-13 5, 19.5# drill pipe to surface. 2. TIH to ±2215', top of cement. v 3. Circulate and get uniform weight using spud mud. 4. T " cgising to 2700 psi for 30 minutes on agbarl. Casing Burst value is 5380 psi. 5. Drill cement, float equipment and 20 gf new formation. 6. Perform 13 3/8 shoe test to,l�'�'IT. Anticipate a 13.5 EMW frac at1985 . Using 9.4 plug p ppg g ppg mud, a 13.0 ppg at 1985' TVD is 372 test pressure. Using a 9.4 ppg mud weight a 13.5 ppg EMW Frac pressure is 423 psi. JA 1r-�`" 7. Shoe test procedure. /1 a. Drill a minimum of 20' but no more than 50' below casing shoe. b. CBU and until uniform mud Y weight throughout the system. rd g g loe c. Pick up into shoe 10'. d. Close blowout preventer, annular. e. Pump down the drill string at 1/4 -1 /2 BPM, keeping rate constant. sP Ft 7_1i�l,o f. Plot the fluid pumped every 1/4bbl vs the drill pipe pressure. g. Draw a straight line best fitting the first 4-5 points.404e h. Plot the additional points until the points fall off the line or the maximum required pressure for FIT is obtained. Keep rate constant the entire time. t Lt., i. Shut down and record instantaneous shut-in pressure (ISIP). And total volume pumped. -----. j. Record the shut-in drill pipe pressure using 1 minute intervals for a total of 10 minutes. k. Plot the shut-in pressures. 1. Bleed pressures off and open the drill string back to the tanks. Record the volume recovered. 8. Upon completion of the test, forward the data to the Drilling Engineer in Lafayette for dispersing to the appropriate agency's and for confirmation. Sterling g 3639' MD/ 2879'TVD 9. Continue drilling to 5518' MD/ 4131' TVDTVD maintaining angle and direction, after successful LOT. 10. Continue drilling to 5 95 5' MD/ 4426' TVDTVD dropping angle to 42.8' and 3 6.6' azimuth. Beluga g 6790' MD/ 5054'TVD 11. Continue drilling to 7475' MD/ 5554'TVD maintaining angle and direction. 12. Continue drilling to 7554' MD/ 5612' TVDTVD building angle to 43.578° and 38.5° azimuth. 13. Continue drilling to 9789' MD/ 7231'TVD maintaining angle and direction. 16 FURIE Operating Alaska LLC 14. Take surveys every 100'. 15. Circulate high viscosity sweeps as needed for hole cleaning. Maintain YP 13-18 &viscosity 40- 42 with PV of 10-15. 16. CBU at TD. Anticipated mud weight is 10. ppm. Mud weight is anticipated for mud and hole stability. 17. 18. Condition to run 9 5/8" casing or for logging run. 19. POOH and L/D BHA, LWD. 20. If additional MDT is wanted, rig up electric line unit. NOTE: Be prepared make a wiper with 12 1/4" hole opener, after logging. 21. Change rams to 9 5/8" casing rams. 22. Test bonnet seals to 1000 psi. 23. Test Basing, rams to 2500 psi;,c� 24. RU casing running tools. 25. Run 9 5/8" 53.5 # L-80 BTC -RS casing as follows: a. 9 5/8" 53.5# L-80 BTC - RS float shoe b. 80' of 9 5/8" 53.5 ppf L-80 BTC - RS casing c. 9 5/8" 53.5# L-80 BTC float collar d. 6700' of 9 5/8" 53.5# L-80 BTC - RS casing. e. Cameron 9 5/8" mandrel casing hanger with running tool. f. 13 3/8" 68 ppf K-55HC BTC Landing joint Note: 9 5/8" float shoe is baker -locked to pin end of joint # Land coupling is Baker -locked on joint # 1. Baker lock joint # 1 coupling and joint # 2 pin. Joint # 2 coupling is baker -locked to joint and float collar is Baker locked in coupling. Do not Baker lock joint # 3 to float collar. Make up torque values should be carefully noted on the first 6 -8 joints while making up casing to the base of the triangle. Use this established torque value on the remainder of the casing. If coupling face is between minus 1 thread turn (.2") and the base of the triangle, the make-up is satisfactory. Centralize first joint at 10' from shoe with stop ring. Centralize next 8 joints and then every other j oint to 3 000'- 42 centralizers. Total 51 centralizers. 26. Land casing in MBS system. 27. Rig up and circulate bottoms up with 25% wash-out factor or 496 bbls minimum. Circulate until background gas is the same or below drilling levels. Stage pumps up to 6.5 - 7 bbls /minute. Watch for losses and reduce rate if losing volume. Bottoms up is 546.2 bbls. 25% wash-out is 683 bbls. i FURIE Operating Alaska LLC 28. Rig up and cement per cement program below: Spacer- 80 bbls Mud push II @ 11.5 ppg Lead 985 sacks Class G + .05 gal/sack Antifoam + 0.5agl/sack Extender WEIGHT: 13.5 ppg YIELD: 1.71 Cu. Ft / sk Water: 8.146 gps: - Seawater Mix Fluid: 9.256 gps Tail 761 sacks Class G + .2 gal/sack Antifoam + 0.12 gal/sack Dispersant + 0.3 gal/sack Fluid Eo_s`s`_T .06 gal/sack Accelerator WEIGHT: 15.6 ppg YIELD: 1:2-2,Cu. Ft / sk Water: 4.951 gps: Mix Fluid: 5.631 gps 29. Displace cement with ±_686 BBILSS ea Water to top of float collar. Bump plug with 1000 psi over pump pressure. 6 Use top and bottom plugs. Do not over displace cement by more than 3 bbls. Capacity of 13 3/8" shoe track is 5.6 bbls. 30. Bleed off pump pressure and make sure floats are holding. 31. ND cement head. 32. Back off running tool with 16 right hand rotations and lay running tool and landing joint down. 33. Install pack-off.Lo �j �, 34. ND BOP. NU dry hole tree. �" I"' /Cit 35. Completion to be performed before rig leaves platform. AOGCC sundr is re uired�before completin KLU # A-2. 8 r z � u-1('z�x R FURIE Operating Alaska LLC KLU # A-2 DVD 1000 2000 -1-- - - - _A.__.._ _.,_ 3000 J.._..... ....... ��Mucl Weight �Safe Drilling Frac Gradient K-L—u A4W FURRI, Mr) jft2LAkJciCC2 (� I co, t C) j6%2 :s: I t � 4CIP 4=> - ft <> 737- 0 1 73G- 0 1 737- 0 1 733.0 1 001 - 0 -n AD 43S_ 0 345S_ 0 :3 -Et 7 S 0 3435.0 3!51 �. 0 JCID I *1"T sterling REDACTED M. Guhl 1/12/2017 FURZE Operating Alaska LLC FORMATION DEPTHS: Geological Data from KLU # 3 Formatiiom Formation Tops (TVD RTS. MD RT Potential Sterling 2868' 3603' Gas Beluga 5082' 6833` Gas Property Lease: ADL 389197: Furie Operating Alaska has 100% ownership. :�l FURIE Operating Alaska LLC KLU # A 2 Mud MD Mud Viscocity Plastic Yield pH Fluid loss As needed Weight As required for < 10 cc fluid loss Viscosity Point SteelSealS 25/50 5ppb 345'- 8.8-9.3 80-120 40-20 55-35 8.5-9.5 <10.0- 2300' Soltex As needed Baroid 41 As needed for 10.0 ppg Aldacide -G API 2300- 9.0-10.1 40-53 6-15 13-24 8.5-9.5 <12.0- 9789 HTHP System Formulation for 345'-2300'; AQUAGEL/ freshwater spud mud. PRODUCT CONCENTRATION Water 0.905 bbl AQUAGEL 15 - 25 ppb Barazan D plus As needed Pac-L DEXTRID LT As required for < 10 cc fluid loss Baracarb 5/25/50 5ppb SteelSealS 25/50 5ppb BARAFIBRE 4.9 ppb Baroid 41 As required for 8.8-9.3 ppg mud weight Caustic 0.1 ppb 8.5 - 9 H) ALDACIDE G 0.1 ppb System Formulation for 2300'-9789': 2% KCL/BDF-499/ GEM GP. PRODUCT CONCENTRATION Water 0.905 bbl KCL 7 ppb Caustic 0.2 ppb (9pH) Barazan D plus 1.0 ppb Dextrid 1-2 ppb Pac L 1 pb BDF 499 4 ppb GEM GP 1.0 % by volume Baracarb 5/25/50 10 ppb 3.3 ppb of each) Baritol Plus As needed Soltex As needed Baroid 41 As needed for 10.0 ppg Aldacide -G 0.1 ppb a-3 FURIE Operating Alaska LLC CASING DESIGN FACTORS Csg Collap Burst Burst Tensile Tensile SF SF SF se Connection Connection Collapse Burst Tension 13 2670. 5380 5380 1661M 1693000 2.75 �. 4.50 10.0 , 3/8„ 95/8 6620 ' 7930 7930 1244M 1329000 1.74 r 2.75 2.38 13 3/8" 72ppf N-80 BTC set at 2300'MD/ 1985' TVD Collapse based on mud weight at casing point. 9.4 ppg x.052 x 1985 = 970.3 psi; DF = collapse rating/ collapse pressure = 2670/970.3 = 2.75 Calculated Burst is based on Frac Gradient at 13 3/8" shoe - gas gradient (13.5 ppg x.052 x 1985') - (.1psi/ft x 1985') _ 1195 psi -199 psi = 1210 psi; Drilling MASP DF = Burst/MASP = 5380/1195 = 4.50 Tension Strength Calculation 72 ppfx 2300'= 165,600# DF = pipe body yield/ calculated tensile DF = 1661000/ 165600 = 10.0 Casing Test Pressure - 2700 psi. 50% of 5380 = 2690 ((MW - PP backup)x .052 x TVD depth)) +test pressure = (9.4 -9.0) x.052 x1900 + 2700 = 2740 psi 9 5/8" 53.5 ppf L-80 BTC - RS at 9789' MD/ 7231' TVD Collapse based on mud weight at casing point. 10.1 ppg x.052 x 7231' = 3798 psi; DF = collapse rating/ collapse pressure = 6620/3798 = 1.74 Calculated Burst is based on pore pressure - gas gradient`~ (9.6 ppg x.052 x 7231') - (.1psi/ft x 7231') _ - 3609.7 psi - 723.1 psi = 2886.6 psi; Production MASP DF = Burst/MASP = 7930/2886.6 = 2.75 DF Calculated Tension in air 53.5ppf x 9789'= 523712# 1244000/523712 = 2.38 DF = pipe body yield/ calculated tensile = P zy 001!w. tFURIE Operating Alaska LLC KICK TOLERANCE CALCULATION Possible Formation Pressure - 10.1 ppg (.5 ppg over anticipated) Planned TD mud weight -10.1 ppg Surface Casing Shoe - 2300' MD/ 1985' TVD LOT @ Surface Casing shoe -13.5 ppg EMW Hole Depth - 9789' MD/ 7231' TVD Bit Size - 12 1/4" Bha Length - 151' Average OD of BHA - 8" Drill Pipe OD - 5" Influx Gradient =.1 psi/ft Kick Intensity =.5 ppg - MASCIP - Maximum Allowable shut-in casing Pressure (Shoe LOT/ Frac - MW) x.052 x TVD of shoe (13.5 ppg-10.1ppg) x.052 x 1985' = 351 psi Height influx: (MASICP-((Kick Intensityx.052x tvd of well) ))/ (Current MW x.052) -Gas Gradient ((351-(.5 x .052x 5054))/ ((10.1 x.052) - .1 psi/ft)= 388' Influx volume Annular capacity between the hole and pipe BHA annular capacity -((12.25"x12.25") - (8x8)) /1029.4 =.0836 bbl/ ft - Drill Pipe annular capacity: ((12.25"x12.25") - (5x5)) /1029.4 =.0836 bbl/ ft - Influx volume: Influx Volume at shoe = Height / Pipe Cap. - 388'x.1215 bbl/ft = 47 bbl LOT @ shoe = 13.5 ppg x.052 x 1985' = 1393 psi Formation pressure @ TD = 10.1 ppg x.052 x 7231' TVD = 3798 psi Using Boyle's Law - P1V1= P2V2: to get bottom hole conditions. 47 bbls x 1393 psi= 3798psiV2 V2 = 17.2 bbls The smaller is the max kick before breaking down the shoe - 11.2 bbls. zs FURIE Operating Alaska LLC FORMATION INTEGRITY AND LEAK OFF TEST PROCEDURE I DRILL 20' TO 50' OF NEW HOLE BELOW THE CASING SHOE. 2 CIRCULATE THE HOLE TO ESTABLISH A UNIFORM MUD DENSITY THROUGHOUT THE SYSTEM (REQUIRED FOR A GOOD DOWNHOLE PRESSURE TEST. PICK UP INTO THE SHOE. a CLOSE THE BLOWOUT PREVENTER (RAM OR ANNULAR). 4 PUMP DOWN THE DRILL STRING MAINTAINING CONSTANT RATE. THE SLOWEST POSSIBLE PUMP RATE IS PREFERRED TO ALLOW DETECTION OF LEAKS. PUMP RATES OF % TO 1 BPM ARE TYPICAL; HOWEVER, ADJUST THE PUMP RATE TO MATCH THE TEST PUMP CAPABILITY TO MAINTAIN A CONSTANT PUMP RATE. PLOT THE FLUID PUMPED IN % BBL INCREMENTS VS. DRILL PIPE PRESSURE. THE DATA POINTS SHOULD INITIALLY FORM A STRAIGHT LINE WITH A SIMILAR SLOPE TO THE CASING INTEGRITY TEST, AS THE SYSTEM COMPRESSIBILITY IS ARE SIMILAR. EVENTUALLY, THE FORMATION BEGINS TO TAKE FLUID; AT THIS POINT THE PRESSURE WILL CONTINUE TO RISE, BUT AT A SLOWER RATE AND THE DATA POINTS WILL DEVIATE FROM THE STRAIGHT LINE. THE FIRST SUSTAINED OCCURRENCE OF THIS DEPARTURE IS THE LEAK -OFF POINT. PUMP NO MORE THAN AN ADDITIONAL 3 DATA POINTS AFTER THE SUSPECTED LEAK -OFF POINT IS REACHED TO ASSURE CONTINUES DECREASING SLOPE ON THE PRESSURE VERSUS VOLUME PLOT. IF A STRAIGHT LINE CANNOT BE ESTABLISHED DURING THE INITIAL PUMPING (SUGGESTING A SURFACE LEAK ORIGIN THE SYSTEM} OR A NEAR LEAK -OFF POINT IS NOT INDICATED, CONSIDER RE -RUNNING THE TEST. BE SURE TO BLEED ALL PRESSURE OFF THE SYSTEM PRIOR TO RE -RUNNING THE TEST A SLIGHTLY HIGHER PUMP RATE MAY BE CONSIDERED IF A CLEAR DEPARTURE IS NOT INDICATED ON THE PRESSURE VERSUS VOLUME PLOT SMALL FILTRATION FLUID LOSSES CAN CAUSE A SLOPE CHANGE, ESPECIALLY AT SLOW PUMP RATES, AND CONFUSE THE IDENTIFICATION OF A MORE DEFINITIVE LEAK OFF POINT. NOTE: IF THE MAXIMUM EMW SPECIFIED IN THE WELLPLON IS REACHED WITHOUT INDICATION OF LEAK -OFF, SHUT DOWN AND HOLD THE PRESSURE THERE. THIS BECOMES THE DATA FOR A FORMATION INTEGRITY TEST (FIT) INSTEAD OF A LEAK OFF TEST {LOT). F SHUT DOWN WHEN THE LEAK -OFF POINT IS OBSERVED AND 3 ADDITIONAL DATA POINTS HAVE BEEN PUMPED INTO THE FORMATION. RECORD THE INSTANTANEOUS SHUT-IN PRESSURE (ISIP). WITH THE PUMP SHUT DOWN, MONITOR AND RECORD SHUT-IN PRESSURE EVERY MINUTE FOR 10 MINUTES PLOT THE INFORMATION AND RECORD THE LOT POINT OR FIT POINT. BLEED THE PRESSURE OFF AND RECORD THE FLUID VOLUME RECOVERED IF POSSIBLE. IF IN DOUBT OF THE LEAK OFF POINT, CONTACT THE DRILLING ENGINEER OR DRILLING TEAM LEAD TO DISCUSS AND EVALUATE THE TEST. UPON COMPLETION OF THE TEST, FORWARD THE DATA TO THE DRILLING ENGINEER IN ANCHORAGE. THE DRILLING ENGINEER WILL FORWARD THE INFORMATION TO THE PROPER AGENCIES. 16 FURIE Operating Alaska LLC WELL CONTROL EQUIPMENT 211/4" 2M Diverter with two (2) 12" diverter lines. Function test. 13 5/8" 5M annular and 13 5/8" 10M three ram BOP MASP - 1210 psi From Casing Design Calculations to break down the shoe at 1985' tvd . 72-3 v '11� .� it, BOP Test Pressure.- 250 psi low and 3500 psi high on annular, rams and all related BOPS. Initial commissioning BOP test pressure will be 250 psi low and 5000 psi on the rams. 17 � FURIE Operating Alaska LLC Proposed length of inner barrel to Flowline RKB Bottom Bellnipple RKB to TOP OF DIVETER - - - - - - - - - - - - - - - - - Pw Annular 21 1/4 2K 21 1/4 2M flange with RX7.3r r r - RKB TO ANN U.LAR- r z Diverter valve RKB RKB To Unihead RKB to Deck . 67.00 ® ft Stick in --------------- --. , , PPLE LENGTH 17.00 , , , , , , , , , , , ......................................................... ................................................................................................. 2.61 10.00 ............................................................... �............. Fastlock Adapter ; 1.5 ................................................................V ..........., I I 1. SEE LVAVC 0002 FOR GaeM NoTE& R!" 2. FOR LOCATIM SEE Oft 1021, 1022 IM3 02U 1m. I FOR PLUP CASLNG UWATION SM DO. JOK a SECTON wo SCAtl- NONE Typ. LAXW18 LfiX4 4i 3/18 �---Typ- cz:=2=C= N SECTION SCALE- NOW SLUT V nM W OF UW0 TO ACWr t- Me PL (0) M RATE AND WD AS smom 5/8 DETAIL 9WF.• 1%2'-11-01 A 6() pp SEC110N RXG p" 1 sy (a) Ik $CALL- l'-1 '-ON (Typ TDP umlo - \-.PL 1 3/47 (0) SECTION SU PC 2004 FOR UVATIM Z-7* tr Sum r-i'-Fr— Pei (0). P"QRW NORTH UBRI V-0 i/f 12 1 3/4' PL (tri DETAIL W 100 (SEE SCAM. loull-tr —W- 2050) (M.) %alp - mm *XoEa to BE *I&" %j T k 0 nANM �, 1 A 1 LWLM NOM DIH:RMSE - /' CA lit I ATL DETAIL AU FRAME; MOMRS IHIS tim amm -04"w =At SUAIL. I* - i' -a' WTH (L4)_TC BE L4*4xi/2 (0) AWaM ClW5j M op I am Pa4am KALF-fm mcm WTAL 3 73 ft OLK rrscw FURZE OPERATNG ALASKA, LL.C. WVWD DETAIL 3. AMU ft -WL 4 M RC Ax cow vw D" a -UP 1vs RC QA P"WA AS W= Wmm STKXM Wamm KAYM UOVW ANOM FW HE AM KW CLOSEr PL an &I "war fmodvibM2 WWM UQHTV MT 3 COOK UU. MASKA AM W7Lv=AL uTm Ft:R irmos its. WT *A MAIN DECK AVVW MR 101M am C" FRAMNO PLAN RKWMett aeCcApm I —1— =- kue„�art day — --- -- -- I ------------ ------ --- Proposed length of inner barrel to Flowline 25.00 RKB Bottom section Belinipple B/NIPPLE LENGTH TOP of ANNULAR Flange NNU A ------------------,► Shaffer 13.6/8x5K top studded BXI 60 Bottom flange 13.6/8x5K BX 160 13 6/8" BX159 10m by 13 5/8" BX160 5m DSA rim ffn _rM @a IN ft Cameron Type U 13.518 x I OK OwIMI&C U11 U -H LLIV 1 2 718" x 6'v 1 0 C VBR ------------ -------- EBind Shear 0 Rams ------ 0 Kill Cameron Type U 13.5/8xI0K GAI ISR Shear Rams cw booster 0 Cameron Type U 13.518 x 10K ............. C1 0 2 E718" x 5" VBR II Flanges 13.3/8x10K BX159 RKB To Unihead I 63.6A .................................................... I ............ 8.00 yJ RKB to Deck 67.00 ft ft Stick in -------------------------- 12-00 ft ................................................................ * ................... 4 4.51 ft 5.55 ft Choke LIA v 3.47 ft ................................................................. ........... 6.54 ft 13 5/8 Riser v .......................................... ....................... ........... Fastlock Adapter 3.10 ft .............................. I ................................. . ....... RKB�a FURIEi Operating Alaska LLC _ i 8:00 i ------------- -------- o RKB to Deck 67.00 0 Proposed length of inner barrel to Howline- 25.00 ; i ft Stick in 0 RKB Bottom section Reltnipple �- i --: --,: ----------------------'�--- B/NIPPL °LENGTH 0 12.00 e e ...............................................................v..................... TOP of ANNULAR Flange LANNU����� -------- a Annular 13.5/8 x 5K ' 4.51 f=langes 13.5/8XIDK BX159 Cameron Type U 13.5/810K double: - - 5" x 2 7/8" _ (, y VRR ram_ C7 •5.5.5 -------------------® ,Q z e ISR ShearjjjMMjj Q A.. Rams - . rJu� s' Choke Line ' t B ' 3.47 Kill Line D Q ' Cameron Type U 13.5/81 in le 5" x 27/8" _ o ,p ® y VAR ram ........................................................ t .�...,. uiv t Elan es 13.3/ x10K BX159 ' 6.54 -r . ,• 13 5/8 Riser 0 e e ................................................................... X............. RKB To Unihead 63250 R • ... - Fastlock Adapters , - x.10 .............♦..•...•.....•............................ ; ••••••p••u• ..............w.._.......... _...Y............ ................. *........ ., r7=77c.0. -7- fi,77774777e `f }1,a. tt1: 2_ q1 overboard choke line ##14 VOLUME TANK RIG RANDOLPH YOST SANDTRAP 1 : 50 BBLS DEGASSER PIT: 70 BBLS DSR: 35 BBLS DST: 35 BBLS CLEAN PIT: 38 BBLS 0.9 BBLS/INCH 0.45 BBLS/INCH 0.45 BBLS/INCH 0.48 BBLS/INCH 0.35 BBLS/CM 0.175 BBLS/CM 0.175 BBLS/CM 0.18 BBLS/CM TANK 1 :366 BBLS 3 BBLS/INCH 1.2 BBLS/CM GEL TANK: 225 BBLS 1.2 BBLS/INCH 0.5 BBLS/CM SLUG PIT: 45 BBLS 0.375 BBLS/INCH 0.15 BBLS/CM TANK 2:335 BBLS TANK 3:335 BBLS 2.8 BBLS/INCH 2.8 BBLS/INCH 1.1 BBLS/CM 1 1.1 BBLS/CM FURIE Operating Alaska LLC TANK 4: 366 BBLS 3 BBLS/INCH 1.2 BBLS/CM M Note: Dimensional information reflected this UIdVVI Y are tf.I)LIITICjU::u ieasurements only. 2 Stage MBS System w/ 4-1/16" 5K Completion I Nam, L) av- Pf,':551-Wt, )00# )00# 4tCAMERON # 1167594 32� Schwartz, Guy L (DOA) From: David McCraine <d.mccraine@furiealaska.com> Sent: Friday, June 10, 2016 12:54 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: John Stuart; Gordon Raines _; j Subject: diverter lines :.AO -'r ft A ,Z-,, (� Attachments: SC284-Furie16061014150.pdf Attached are the deck plans for the top and the production decks showing the diverter lines. We can lock out all the sources on the top deck. They are not Classl Div 1. The back-up generater should be the only source in service. The 43'divererter lines are calculated to extend ±12' on the edge of the platform on the platform west side and 2 1/2to 311 past the platform on the platform east side. We are not able to support the 12" lineany further to get them 75 ' away. These are calculated from the edge of the well slot. The basic size of the monopod is only a 75'x 76I. The production deck is 20' below the top deck and the platform generaters exhaust is a source. We are not able to get 75' away, unless we can support the line with it being 85'± above MLLW. Rotating the lines 30 -40 degrees clockwise, may get further away from the sources, but puts the end of the diverter line ponied towrd the rig, which we do not recommend. We looked at suspending the diverter line from the cantelever beams of the rig, but the rig floor has very similar dimensions of the rig floor. We will not be able to get the diverter line further out doing this. The example described to me is understood, but it was referenced to a land location. With a small platform and a jackup rig, we do not have the surface area to get 75' away. Please review and let's discuss. Regards. Dave McCraine Furie Operating Alaska -Lafayette Drilling Engineer 337-981-0270 Office 337-501-6854 Cell ~� tTFORM. NORTH t c r t M , f j T -- rt i 3 r ti f , 0 i LIST Of EQUIPMENT DESCRMO4 I �n c 'Qn LEGEND: CLASS f. 20K 0 4AZAR0011S AREA CLAM r. ZVNE : 14VAAODUS MEA, CLASS r. ZOW 2 RA?AQD U5 AREA MW-HAZAR(as AF*A P 1. THK RArORM INS BEIM CLASSIFU nu ACC ROAKE Mmt An RP 503 (S m-ak 0). T. PC L4UN HERfM WER IS IEYPOWAY AT THE LOCATfM. . 1 � 00 e el; I :r t J..4:A•t 'J' .� •:'i 1 r ` MM + t� mmr , W --j LIST OF EQUIPMENT DESCAtpTION WO E5; WWW11D ik. A=RU#M um API AF Sm t=Tom E*. FUME OPERVING ALASKA, LLC WWMJACW VVEWiFAD TEST PLATFORM MANAGMaW Bmshwmft&dwwl- so ELEC. HAL AREA CLASSWCATION xmwm uwm mdlbp" PRODUCrON DECK PLAN Lwow - 410104 -FOA -EE -PS -8110-501 5m r or 1 5 Schwartz,, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, May 06, 2016 4:38 PM To: 'David McCraine' Subject: RE: KLU #A-2 (PTD 216-055) I think I am good with the all you have submitted . Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALRY 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: David McCraine [rnailto:d.mccraine@a furiealaska.com] Sent: Thursday, May 05, 2016 2:02 PM To: Schwartz., Guy L (DOA) Subject: Re: KLU #A-2 (PTD 216-055) Guy, I have all the data to submit for the modification of the APD for KLU # A-2. Attached is contents thati plan to submit. I am not re -submitting the schematics or the proximity plat with statement. They are the same. Do I need anything else? Thanks. Dave McCraine Furie Operating Alaska -Lafayette Drilling Engineer 337-981-0270 Office 337-501-6854 Cell From: Guy Schwartz <guy. schwa rtz @a laska.gov> Date: Wednesday,, April 27,.2016 at 7:23 PM To: Dave McCraine <d.mccraine@furiealaska.com> Cc: Patricia Bettis <patricia.bettis@alaska.gov>, John Stuart <j.stuart@furiealaska.com> Subject: RE: KLU #A-2 (PTD 216-055) Initial test to 5000 psi is fine for the 10K BOPE. My oversite as the wellhead is 5000 psi anyway for this well. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTWITYNOTICE: 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. schwartzAalaska.gov). From: David McCraine rmailto:d.mccraineC@furiealaska.com] Sent: Wednesday, April 27, 2016 8:35 AM To: Schwartz, Guy L (DOA) Cc: Bettis, Patricia K (DOA); John Stuart Subject: Re: KLU #A-2 (PTD 216-055) Thanks Guy. We will go to 13.Oppg EMW FIT for our shoe test. I do get 329 bbls displacement at the estimated top of the floats. We always recalculate this with actual pipe measurements. The shear rams are certified and a copy is in the rig book sent to AOGCC. We will rig up the H2S monitors for both wells. It is not a good practice to take the test pressures to the max rating, if not needed. The people operating the equipment are at risk to the higher pressures, as is the pumping equipment, lines, etc. We propose to make the initial test to 5000 psi for this season, as this is well over any Production MASP we will encounter this season. Regards. Dave McCraine Furie Operating Alaska -Lafayette Drilling Engineer 337-981-0270 Office 337-501-6854 Cell From: Guy Schwartz <guy.schwartz@alaska.gov> Date: Tuesday, April 26, 2016 at 4:29 PM To: Dave McCraine <d.mccraine@furiealaska.com> Cc: Patricia Bettis <Patricia.bettis@alaska.gov> Subject: KLU #A-2 (PTD 216-055) David, Here is a draft of the approval letter details that will pertain to the approval of the PTD for A-2 . A couple issues I saw with PTD: 1) I calculate a min of 13 ppg for LOT to get acceptable inflow on the surface casing shoe. (15 bbls influx) 2) On page 15 for the surface casing displacement volume on step 14 I get a higher number than 284 bbls. Can you check this? (13 3/8" casing has capacity of .148 bbl/ft) 3) The shear rams must be certified for the size of drill pipe you are using (have documentation ready) 4) Note that H2S monitors should be ready to for the first well ... they will be needed later on anyway. 5) I assume the initial BOP test will go up to 10,000 psi to commission the equipment. There after 3500 psi is fine for the duration of this well. NOTE: we have not seen a spacing exemption application yet. These take time to process.. FYI. 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 (Guy. schwartznalaska.gov). r Clearance Report ���� FURIE KLU#A-2 Condor (SIotB)_Ver#13 nDeratingASoskaLLC Closest Approach EAKER Page 3 of 53 HUGHES EFERENCE •AIDENTIFICATION ©perator Furle Operatin Alaska, LLC Slot KLU#A-2 Condor (Slot B) rea ook Inlet, Alaska (Offshore) Well KLU#A-2 Condor Field Kitchen Lights Unit Wellbore IKLU#A-2 Condor (SlotB) Facility IFurie Monopod Platform CALCULATION RANGE & CUTOFF From: 132.00ft MD To: 9788.95ft MD C -C Cutoff: (none) FFSET WELL CLEARANCE SUMMARY (90 Offset Wellpaths selected) Ellipse separations calculated in Closest Approach plane Offset Facili Offset Slot Offset Well Offset Wellbore Offset Wellpath C -C Clearance Distance AOR Ellipse Separation Distance Ref Min C -C Diverging Ref MD of Min Min Ell Sep ACR MD Clear Dist from MD Min Ell Sep Ell Sep Dvrg from Status ft ft ft Furie Monopod Platform KLU#3 (Slot A) KLU#3 KLU #3 NaviTrak MWD<388-1893'>OnTrak MWD<1925-10393> 518.41 6.76 518.41 520.45 -6.68 520.45 FAIL Furie Monopod Platform KLU Osprey (Scot D) D) KLU Osprey (Slat D) D) KLU#A-1 Osprey (Slot D) KLU#A-1 Osprey (Slot D)_Ver#6 132.00 12.41 375.00 375.00 -1.18 375.00 FAIL Shell -Standard Richfield State State #1 SRS State #1 SRS State #1 SRS State #1 SRS State #1 Drift Indicator <0-16375'> 4263.56 1084.47 4263.56 4327.79 887.25 4327.79 PASS Kitchen Lights Unit #1 jKLU#1 Kitchen lights Unit #1 ! KLU#1 Kitchen Lights Unit #2 !KLU#2 Kitchen Lights Unit #2 KLU#2 S Cook Inlet St 3 ASCI St 3 Kitchen Lights Unit #4KLU#4 KLU#1 JKLU KLU#1 KLU#2A KLU#2 SCI St 3 KLU#4 #1 Rd #1 10nTrak KLU#1 KLU #2A KLU #2 SCI St 3 AWB KLU#4 MWD<5082-15298'> Schlumberger MVVD <U - 88055 OnTrak MWD<2070-107505 OnTrak MWD<494 - 91065 SCI St 3 AWP OnTrak MWD<450-9200'> 1682.00 1262.14 1682.00 1682.00 1262.14 1682.00 1693.54 1138.33 1693.54 1138.33 1693.54 PASS 1693.54 PASS 4482.00 5250.13 4482.00 4536.49 5083.18 4536.49 PASS 423.77 7912.12 423.77 423.77 7790.26 423.77 PASS 132.00 10046.67 375.00 474.32 9926.63 474.32 PASS 9788.95 14154.79 9788.95 9788.95 14014.90 9788.95 PASS Kitchen Li hts Unit #5 U#5 E KLU#5 KLU#5 KLU#5 132.0 30732.2fi 375.00 332.00 30810.05 332.00 PASS Kick Tolerance Calculations KICK TOLERANCE: 13.2 bbl Compare CASE 1 and CASE 2 volumes for the gas influx above. The smallest volume is selected to represent the maximum kick volume allowed without breaking down the shoe (or weakest formation) It is difficult to shut in a well with less than a 10 bbl kick volume guy Schwartz 6/3/2016 input in yellow areas only KLU 2A MW (ppg) 10 ppg LOT/FIT (ppg) 13.5 ppg TVD Casing Shoe (ft) 1955 ft TVD If a formation deeper than the casing shoe is known to be weaker than the casing shoe (have a lower fracture gradient/LOT) then that weaker formations TVD and LOT can be used in place of the casing shoe information for more accurate calculations Kick Intensity (ppg) 0.5 ppg Formation Pore Pressure cannot be less than the MW to have a kick! 4.5 ppg kick tolerance over current MW is a standard assumption Assume that the kick is hydrocarbon gas (not oil or water) TVD of Kick Influx (ft) 7200 ft TVD Gas Gradient (psi/ft) 0.1 psi/ft Change only if gas gradient is known to be different Hole Size (in) 12.25 inches Drill Pipe OD (in) 5 inches BHA OD (in) 8.5 inches Lenth of BHA (ft) 304 ft If the BHA is longer than the open hole, the kick will come to surface very quickly due to the smaller annular capacity 0.1215 bbl/ft Annular Capacity between OH and DP 0.0756 bbl/ft Annular Capacity between OH and BHA 361.27 psi Maximum Allowable Surface Pressure 187.2 psi Underbalance due to Kick Intensity 174.07 psi margin before casing shoe is broken down/fractured (or weakest formation below casing shoe) Height of Gas Kick 414.5 feet Volume of Gas Kick 31.3 bbi CASE 1 Assume Kick is only around the BHA (not the DP) at the influx depth Volume of Gas Kick 50.4 bbl Assume Kick is only around the DP (not the BHA) at shoe depth Volume at influx 13.2 bbl CASE 2 depth Conversion KICK TOLERANCE: 13.2 bbl Compare CASE 1 and CASE 2 volumes for the gas influx above. The smallest volume is selected to represent the maximum kick volume allowed without breaking down the shoe (or weakest formation) It is difficult to shut in a well with less than a 10 bbl kick volume t "ECEIVED STATE OF ALASKA 3KA OIL AND GAS CONSERVATION COW, .310N APIA 12 2016 PERMIT TO DRILL r���• ?n Qac 9-j; nn -r% �A i /I 1 a. Type of Work: 1 b. Proposed Well Class: I Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1 c. Specify if well is proposed for: Drill El - Lateral ❑ Stratigraphic Test ❑ Development - Oil ❑ Service - Winj ❑ Single Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ ❑ Reentry Exploratory - Oil ❑ _ Development Gas ❑ Service - Supply ❑ Multiple Zone '0% Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket 0 ti Single Well ❑ 11. Well Name and Number: Furie Operating Alaska LLC Bond No. 402-081 A Kitchen Lights Unit # A-2 3. Address: 6. Proposed Depth: 12. Field/Pool 4906 Ambassador Caffery Pkwy Suite #800 MD: 6790' ' TVD: 5054'- KLU Undefi d Natural Gas Pool 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 895.93 FWL & 343.48 FSL of T10N:R11 W; Sec24 S ^ ADL 389197 % Top of Productive Horizon: 8. Land Use Permit: proximate Spud Date: 1Z5/10/2016 2217.89 FWL 1697.21 FSL of T10N:R11W: Sec 24 S-0&- N/A Total Depth: 9. Acres in Propertv: 44. Distance to Nearest Property: 1475.06 FEL & 1911.53 FNL ofT10N : R11W : Sec 24 S'SVAI t 256 3+ miles (non Furie) 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 104 15. Distance to Nearest Well Open Surface: x- 294331.49 y- 2,536,125.62 Zone- 4 GL Elevation above MSL (ft): to Same Pool: 21350 16. Deviated wells: Kickoff depth: _100 3 feet 17. Maximum Potential Pressures in psigPee 20 AAC 25.035) Maximum Hole Angle: y ` 42/8 degrees Downhole: 2,444 S ace: 11210 18. Casing Program: Specifications Top - Setting Depth - Bo om Cement Quantity, c.f. or sacks Hole Casing Weight Grade 12011 IX Coupling Length MD TVD MD TVD (including stage data) Driven 94 ppf -56 XLC-S 345 0 0 45 345 DRIVEN 17.5" 13-3/8" 72 ppf N-80 BTC 2300 0 0 2300 1985 Lead 2218 cuff 12.3 ppg tail 623 cuff 15.6 p 12.25" 95/811 53.5 ppf L-80 BTC 6790 0 0 6790 5054 Lead 587 cuff 13.5 ppg Tail 1805 cuff 15.6p 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill a Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): t. pth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size ment Volume MD TVD Conductor/Structural \/Y 00 Surface (0$�y Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Property Plat 0 BOP Sketc Drilling Program Q Time v. Depth Plot Q Shallow Hazard Analysis❑ Diverter Sket Seabed Report ❑ Drilling Fluid Program 20 AAC 25.050 requirements0 21. Verbal Approval: Commission Representative: 4/11/2016 Date 22. 1 hereby certify that the foregoing is true and the r roved herein will not be deviated from without prior written approval. Contact David McCraine Email D.mccraine@-Vuriealaska.com Printed Name David McCraine Title Drilling Engineer Signature Ac Phone 337-981-0270 Date 4/11/2016 Commission Use Only Permit to Drill API mber: Permit Approval See cover letter for other _ Number: 1 50- _ ,3 ..2 L -- -' (� �7 � OQ Date: requirements. Conditions of approval : if box is checked, well may not be used to explore for, test, or produce coalbed met ha e, gas hydrates, or gas contained in shales: Other: Samples req'd: Yes ❑ No Mud log req'd: Yes❑ NoV H2S measures: Yes ❑ No Directional svy req'd: Yes5ir No❑ Spacing exception req'd: Yes V No ❑ Inclination -only svy req`d: Yep] Noi Post initial injection MIT req'd: Yes❑ No❑ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ORIGINAL Submit Form and Form 10-401 (Revised 11/2015) This permit is valid for 24 months from the date of approval (20 AAC 25.005(g)) Attachments in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM. ION PERMIT TO DRILL 20 AAC 25.005 RECEIVED MAR 2 5 2016 rV1,11 f 1a. Type of Work: .Well Class: Development - Oil Service - Winj Single Zone 1c. Specify if well is proposed for: Drill Lateral�,.b'=c Test Development-Gas� Service - Supply Multiple Zone Coalbed Gas Gas ydrates Redrill ReentryExploratory Service - WAG Service - Disp Geothermal S e Gas 2. Operator Name: 5. Bond: Blanket Single Well 11. Well Name and N ber: Furie Operating Alaska LLC Bond No. 402-081A Kitchen Lights Uni A-2 ° 3. Address: 6. Proposed Depth: 12. Field/Pool(s 4906 Ambassador Caffery Pkwy Suite #800 MD: 6790' TvD: 5054 KLU UndefinNatural Gas Pool 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 895.93 FWL & 343.48 FSL of T10N:R11 W, Sec24 ADL 389197 Top of Productive Horizon: 8. Land Use Permit: 13. A roximate Spud Date: 2217.89 FWL 1697.21 FSL of T1ON: R11 W: Sec 24 NA Total Depth: 4/18/16 9. Acres in Property: Distance to Nearest Property: 1475.06 FEL & 1911.53 FNL of T10N : R11 W : Sec 24 256 3+ miles (non Furie) 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 104 15. Distance to Nearest Well Open Surface: x- 294331.49 y- 2,536,125.62 Zone 4 GL Elevation above MSL: feet to Same Pool: 2350 16. Deviated wells: Kickoff depth: 345 feet 17. Maximum Anticipated Pressures in psig (see 2 C 25.035) Straight hole Maximum Hole Angle: 42.8 degrees Downhole: 2,444 S rface: 1,210 18. Casing Program: ISpecifications Top - Setting Depth - BottoqFf Cement Quantity, c.f. orsacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 20" 94 ppf X-56 XLC-S 345 0 0 345 345 DRIVEN 17.5" 13-3/8" 72 ppf N-80 BTC 2300 0 0 2300 1985 Lead 2218 cu.ft. 12.3 ppg tail 623 tuft. 15.6 ppg 12.25" 9 5/8" 53.5 ppf L-80 BTC 6790 0 0 6790 5054 Lead 587 cuff 13.5 ppg Tail 1805 cu.ft. 15.6ppg 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re- t perations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured):ffe�t. MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size CehyKent Volume MD TVD Conductor/Structural DRIVEN Surface Intermediate Production IV Liner Perforation Depth MD (ft): oration Depth TVD (ft): 20. Attachments: Property Plat BOP Sketchrilling Program Time v. Depth Plot Shallow Hazard Analysi Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirement 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct. Date Contact Printed Name J, / AL Title / Email vR of t / 1 f Lr iA 6 n �7f c rr eel - Signature 1-11,71C4.fL Phone 33 I ' '78i"®d 70 Date Commission Use Only Permit to Dr' Number: API Num r: 50- SS-oo -D� erm Pit Approval See cover letter for other 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 shale Other: Samples req'd: Yes NON Mud log req'd: H2S measures: Yes No Directional svy req'd: Spacing exception req'd: Yes No Inclination -only svy req'd: Approved by: APPROVED BY COMMISSIONER THF r:()MMISCIrNJ n e. ORIGINAL Submit Form and Form 10-x01 (Revised 10/2012) This permit is valid for 24 months from the date of approval ( 20 AAC 25.005(g)) Attachments in Duplicate FURIE Operating Alaska LLC Mar 23, 2016 Alaska Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill Well: Kitchen Lights Unit #A-2 TO WHOM IT MAY CONCERN: RECEIVED MAR 2 5 2016 Furie Operating Alaska, LLC (FOA) hereby applies for a Permit to Drill an offshore development well within its Kitchen Lights Unit located in the Cook Inlet of Alaska. FOA would like to request a waiver from 20 AAC 25.030 (c), (B) to eliminate the conductor casing and request permission to set the Surface casing at 2300' MD, 1985' TVD RKB. The proposed justifications include: 1) Wells KLU# 1 thru 5, SRS state # 1 &2, SCI: # 2 & 3 none of which exhibited any shallow gas issues were all drilled without a conductor. In both cases with the structural casing or conductor casing a diverter system is utilized hence, from a well control perspective the installation of the conductor provides no additional well control over the structural casing with a diverter and with no potable water sources to protect there is no benefit provided by an additional string of casing. 2) KLU #A-2 is drilling the same surface interval as the KLU #3, a well on the same platform. The KLU # 3 did not encounter any gas through the depth of the KLU # A-2 proposed surface casing setting depth. 3) Historical evidence from wells KLU# 1 thru 5, SRS State #1&2, SCI: #2 & 3 none of which exhibited any shallow gas issue. The approved setting depth for the surface casing has ranged from 1503' on SRS#2 to 2718' on SRS #1( 2nd closest offset to KLU# 3) and to 2838' on the KLU # 5. The setting depth for KLU#1-3 was based on reprocessed historical shallow hazard survey data and was restricted to 1900' for the sake of conservatism. FOA would like to request a waiver from 20 AAC 25.035(c)(1)(A) requirement for a 16" diverter line. FOA requests permission to use a diverter with two 12" lines, which will open simultaneously while drilling a 17.5" surface hole to a depth of 2300' MD, 1985' TVD RKB. 4906 AMBASSADOR CAFFERY PKWY SUITE # 800. LAFAYETTE, LA 70508 1 OFFICE: 337.981.0270 The proposed justifications include: 1) Numerous past practices in the Inlet of using a dual 12" diverter lines on a 17.5" pilot hole i.e. Buccaneer at Cosmo. 2) No shallow gas issues associated with offset wells KLU #I , KLU #2-2a, KLU #3, KLU #4, KLU # 5, Shell SRS 1&2 or Arco South Cook Inlet #3. 3) KLU #A-2 is drilling the same surface interval as the KLU #3. The KLU # 3 did not encounter any gas through the depth KLU # A-2 plans to set surface casing. The KLU # 3 is on the same platform and is f6' from the KLU # A-2. The Kitchen Lights Unit Well KLU #A-2 will be drilled from the jack-up rig, "Randolph Yost". Well KLU# A-2is anticipated to spud 4/18/2016. After reaching TD, 9 5/8" 53.5 ppg L-80 BTC casing will be run and cemented. A dry hole tree will be installed. A Sundry will be submitted for the completion. Attached please find the following information required by 20 AA 25.005for your review. 1) Form 10-401 Application for Permit to Drill 2) Well Prognosis: a. Anticipated Formation Tops b. MASP while drilling to TD with 13-5/8" 10M BOP C. Drilling Hazards d. Drilling Fluid Plan e. Survey Plan f. Logging Plan g. Mudlogging Plan —waiver request h. Casing Plan i. Cementing Plan j. Well Control Equipment 3) Plat showing the surface location 4) Plat showing offset well proximity 5) Well bore Diagram 6) Drilling Program 4906 AMBASSADOR CAFFERY PKWY SUITE # 800. LAFAYETTE, LA 70508 1 OFFICE: 337.981.0270 2 7) Depth Days Plot 8) Geo Mechanical Plot 9) Geological Formation Top Prognosis 10) Projected Disposal Volumes and Mud Program 11) Casing Design Information 12) Kick Tolerance 13) FIT Procedure 14) Diagrams: a. 21-1/4" 2000 psi diverter with 2 12" diverter line b. 13-5/8" 10M BOP diagram C. IOM Choke/Kill/Manifold d. Pit and Shaker tank diagram e. Well head system diagram If you have any questions or require further information please contact Furie Drilling Engineer, David McCraine, at (337) 981-0270 or d.mccraine@furiealaska.com . Sincerely, G.� David McCraine Drilling Engineer r FURIE i ®perating Alaska LLC Permit to Drill Kitchen Lights Unit Well # A-2 Table of Contents Description Page Permit To Drill 1 Well Prognosis 2 Surface Plat 6 Wellbore Diagram 7 Directional Plan 8 Proximity Plat and Statement 11 Drilling Procedure 13 Depth vs Days Plot 19 Geo- Mechanical Plot 20 Formation Top 21 Mud Volume & Program 23 Casing Design Factors 25 Kick Tolerance Worksheet 26 Formation Integrity Test Procedure 27 Well Control Equipment 28 211/4" Diverter Diagram 29 13 5/8" 10M BOP Diagram 30 13 5/8" 10M choke Manifold 31 Mud Pit Capacity Chart 32 Wellhead Diagram 33 F U R I E Operating Alaska LLC Well Prognosis For KLU # A-2 Kitchen Lights unit # A-2 is a developmental well off of the Julius R monopod in the Cook Inlet. The objectives are the upper and lower Sterling encountered in the KLU #3. KLU # A-2 is a directional well drilled with the j ackup Randolph Yost. Upon reaching TD of 6790'M/5054' TVD, Furie plans to run 9 5/8" 53.5 ppf L-80 BTC casing and cement it in place, prior to nippling down and setting a dry hole tree. A sundry will then be submitted for the completion. Surface Location: X-294,331.49 & Y- 2,536,125.62 Bottom Hole Location: X-297,292 & Y- 2,5395099 Total Depth 6790'MD / 5054' TVD a) Formation Depths: Sterling - 3639' MD/ 3118' TVD — potential gas zones Property Lease: ADL3 89197 b) Maximum Anticipated Surface Pressure: MASP =Frac Gradient at shoe —Gas gradient 1195 psi = (13.5*.052*1985tvd)- (.Ipsi/ft* 1985') c) Potential Drilling Hazards: Review of KLU # 1 & sidetrack revealed coal sloughing in the 12 1/4' hole causing stuck pipe incidents at 10.248', 10570', 10,625'. Back reaming, washing and reaming helped to successfully clean the hole. Additional mud weight was used to stabilize the wellbore and run 9 7/8" casing. KLU # 3 - The drive pipe was washed out with a 26" bit and KLU # 3 was spudded on 4/26/13 drilled to 1950' with a 9.1 ppg mud. No mud losses were observed. No gas was encountered. The casing crew was rigged up and 13 3/8" 72 ppf N-80 BTC casing was run to 1903'. The casing was cemented with 37 bbls of cement return and the plugs bumped. The annulus was washed out to 289' using grout strings. A FIT was taken to 12.5 ppg EMW. The mud was displaced with a new LSND 9.3 ppg mud. The KLU # 3 was drilled to 10,293' with no drilling issues Review of the most recent experience drilling of the 12-1/4" hole for the KLU2 & 2a found that lost circulation was experienced at 3179' with a loss rate of 120 bph but was cured with two 30ppb LCM pills. While on KLU#1, coal sloughing caused stuck pipe FURI E Operating Alaska LLC incidents at 10,248', 10,570' & 10,625'. Back reaming, washing and reaming, successfully cleaned the hole. Additional mud weight was used to stabilize hole prior to running 9-7/8" casing. KLU # 4 - KLU4 while driving the 30" X 1.5" X 56 to 318' pipe hit refusal at 257' with 197 blows / ft. A pilot hole was drilled to 317' and which allowed driving to continue to 318'. While drilling the 12-1/4n pilot hole, losses as high as 40 bph between 1080' and 1650' were encountered but 30 bbl pills with 15#/bbl fiber were effective in controlling the loss. The pilot hole was opened to 26" with losses from 4911-728',1260-1340' and 1605"-1845" 30 bbl pills 20#/bbl med fiber 15 #/bbl caco3 were effective in controlling the losses. At 2396' the 20" casing shoe was set. After drillout a LOT of- 14.3 ppg EMW was achieved. With a KOP at 2700' an Inclination to 24 degrees was achieved and the well was directionally drilled to 9200' TO. At 6282' a loss of 105 bbls. occurred which required a 20 bbl pull 16 #/bbl to cure. The well had to be backreamed 6165-3616' prior to drilling to 7818. Drilling ahead required backreaming each stand. The bit trip from 7818' required backreaming out and wash back into the hole. The second bit trip from 7818 was made on the elevators as well as the rip from 9200 TD. E line logging was attempted but became stuck and had to strip over to recover. Pipe convey logs were run without incident. A 13-5/8" casing string was ran and cemented. The mechanical DV didn't open during the second phase of cement job as the dart didn't reach tool due to 24 -degree angle. A down squeeze of the 20" X 13-5/8" annulus was required. None of the offsets encountered H2S. The KLU# A-2 is drilling the same fault block as the KLU #3 and the gas analysis shows that no H2S is present d) Drilling Fluid Summary Surface Hole: a directional 17 1/2" hole to 2300'MD/ 1985' TVD Gel spud mud — 9.0 ppg v Production Hole — 12 1/4" hole from 23 00' MD/ 1985' TVD — 6790' MD/ 5054' TVD J 10.0ppg glycol/ 1 col/ KCL/ amine inhibited mud e) Survey Program: The well will be surveyed at interval not exceeding 100' apart as required by 20 ACC 25.050. 3 FURIE Operating Alaska LLC A directional plat showing the well within 200' of the KLU A-2, the KLU # 3 is included in the directional section. The KLU # 3 is owned by Furie Operating Alaska, LLC making Furie Operating Alaska, LLC the only affected applicant to wells in proximity. f) Logging Program: Triple combo: 23 00' — 6790' MD Furie asks for a waiver from the Triple Combo above 2300'. g) Mud logging: The KLU # A-2 is drilling the same interval that the KLU # 3 drilled. Furie requests a waiver from 20 AAC 25.071 Geologic Data and Logs as it will be the same data sample already supplied to AOGCC. h) Planned Casing program for KLU # A-2: Casing 20" x .812" 13 3/8" 9 5/8" Depth 345' MD/ 126' Penetration 2300' MD/1985' TVD 6790'MD/ 5054' TVD Hole Size Driven 17 1/2" 121/4 Weight 166.56 * 72 53.5 Grade X-56 N-80 L-80 Connection XLC- SE BTC BTC - RS * Plain end weight. i) Cementing Summary: 20" x .812" wall (18.3 76" ID) Drive Pipe Drive to 345' with 126' penetration — no cement 13 3 /8" 72 ppf set at 23 00' MD/ 198 5' TVD RKB Lead volume 126' x 0.4677cf/ft with 0% excess = 58.93 cu ft 1555 x 0.6946 x 100% excess = 2160 cu. Ft. Total lead volume = 2218 cu ft. Tail volume 400' x 0.6946 x 100% excess = 555.68 cu. Ft. 80' x.8314 cu ft/ ft with 0% excess = 66.5 cu ft Total tail volume = 622 Cu. Ft. y FURIE Operating Alaska LLC 9 5/8" 53.5 ppf set at 6790' MD/ 5054' TVD w/ TOC A 3200' v Lead Volume 1500'x .3132 cu ft/ ft x .25% excess — 587 cu ft Tail Volume 2090' x.3132 cu ft/ ft x.25% excess = 818 cu ft 80' x .3 973 Cu ft/ ft x 0% excess = 31.78 cu ft Total Tail volume — 850 cubic ft. j) Well Control Equipment: 21 1/4" 2M Diverter with two (2) 12" diverter lines. 13 5/8" 5M annular and 13 5/8" 10M three ram BOP k) Gas Detection: Furie plans to rig up Flo -show and gas detection on the initial rig up, prior to spud for methane gas detection. Furie requests a waiver to 20 ACC 25.065 H2S and the H2S detection system as the KLU # 3 gas analysis was 99.9% methane and the KLU # A-2 is drilling the same interval. S 15 14 �- • Mark Keith Buhrke / • • :i No. 12 •••` li 9 ,�• , L'_� (s�• quo PROTRACTED SECTION CORNER VALUES. 6. BOTTOM HOLE INFORMATION PROVIDED BY CLIENT AND DOES NOT REPRESENT A FUGRO CHANCE FIELD SURVEY. . �3 18 Ktchen Lights Unit #A2 Proposed Bottom Hole NAD27 Alaska Zone 4 Feet X : 297,292.00 Y : 2,539,099.00 Lat : 60°5641.9315"N Lon : 151.08'24.1485"W NAD83 Lat : 60"56'39.9221"N Lon: 151 °08'32.2153"W cl u1 NW !4\\ NE - /41475.06' KTUI-A2 RF4,"- 22 23 --__ 19 Aw SW 1 SE 114 •� � 895.9-3 TFORM OU [7 KLU-1 a ccs Kitchen Lights Unit #A2 Proposed Well Surface CIO NAD27 Alaska Zone 4 Feet X : 294,331.49 Y : 2,536,125.62 Lat : 60.56'12.1442"N 27Lon : 151.09'23.0125"W 26 NAD83 25 30 Lat : 60°56'10.1353'N Lon : 151.0931.0796"W I l- 0 Z of _ - 0 KLU-2 a r 34 35 36 31 I HEREBY CERTIFY THAT THE ABOVE PROPOSED WELL SURFACE LOCATION IS CORRECT. *,��►°1r���� , *%;%o ow %; O% IF A ��� e go • • • • •' • • • • • � 41 0•••�" ,, ow �.•• •.'si rr 49TN • : t ••i"••"'•««•••*«•�«..•.••.••• I NOTES 1. COORDINATES TRANSFORMED FROM NADCON (ALASKA). 2. THIS DRAWING IS NOT FOR NAVIGATION, ONLY WELLS IN THE IMMEDIATE VICINITY OF THE SURVEYED WELL ARE SHOWN. 3. AKCS27 DENOTES ALASKA COORDINATE SYSTEM OF 1927. 4. SECTION 24, TOWNSHIP 1 O RANGE 11W, STATEWATERSEWARD S IOFC OAN IS IKHNNTITHE ALASKA ET. 5. SECTION LINE OFFSETS COMPUTED FROM �- • Mark Keith Buhrke / • • :i No. 12 •••` li 9 ,�• , L'_� (s�• quo PROTRACTED SECTION CORNER VALUES. 6. BOTTOM HOLE INFORMATION PROVIDED BY CLIENT AND DOES NOT REPRESENT A FUGRO CHANCE FIELD SURVEY. MARK KEITH BUHRKE RPLS # 12656 STATE OF ALASKA FURIE Operating Alaska LLC PROPOSED LOCATION KITCHEN LIGHTS UNIT #A-2 ADL #389197 NE 1/4 OF SECTION 24, TOWNSHIP 1 ON, RANGE 11 W SEWARD MERIDIAN, ALASKA FUGRO INC. ORD 200 Dulles Drive Lafayette, Louisiana 70506 (337) 237-1300 Geodetic Datum: NAD27 SCALE 0 2000 Projection: AKCS27 Zone 4 1:24000 MMENI Grid Units: US SURVEY FEET FEET Job No.: 1600195 Date: 3/18/2016 Drwn. BCN Chart: Of: 1 1 DWG File: Q:\2016\1600195\CAD\...\160019501 3/21/2016 S FURZE OPERATIN ALASKA, LLC F&RIEKITCHEN LIGHTS UNIT NOCondor COOK INLET, ALASKA Operating Alaska LLC 2/1/16 DEM WELL BORE SCHEMATIC SL: X - 296,507E; Y - 2,538,199N BHL: X - 2971292E; Y - 2,539,099N API: TBD Permit TBD • :- • .- .. .. .•. .. .;. ••c ••■■■■■ ■;.;■;• :-:•off .;.;.;: .-..•. f;f;■;■ .... f•f •f•■ ■f■,■rr .•.•.■. .;.;.;. .•.•.-. .•.•.•. .•.•.•. ■,■,■-. .•.•.•. ■, KLU Condor Rev (A#2) schematic.xlsx TUBULARS &SETTING DEPTHS PP (PPG) MW (PPG) Frac (PPG) DIRECTIONAL FORMATION EVALUATION DEPTH (KB) 62' Air Gap MD TVD DRILL FLOOR RKB TO: 90 HIGH TIDE 115 MEAN LOW LOW WATER 219 SEA FLOOR 3�$ 1 Z�6 �4" x �' Ill')` �RIVE Po`� - Mudlog 12 1/4" x 17 1/2" KOP @ 300'; BUR - 3'/100'; 'Az -45.4° EOB @ 1906'MD 1724'TVD Hold 48.182°inc &45.4° Az 46.68' Az ELECTRIC LOGS OPTIONAL ...1,800.... 13 3/8" G8# K-55 H'C BTCM 8,-, 9.4 13..2 Mudlog 12 1/4" HOLE MWD/LWD: Hold 48.182°inc 8< 45.4° Az 46.68' Az 0 5475' MD / 4103' TVD Drop to 42.8'and tum to 36.8' Az by 2'/100' DLS by 5882' MD / 4388.5'TVD Hold to 6789'MD/ 5054' TVD 3000 3200 2585 TOC 3624 2868 Sterling ELECTRIC LOGS OPTIONAL Neutron Density -Dipole Sonic -GR -SP - Caliper - (Triple Combo) MDT -have available 4,000 3,118 5000 5102 3854 MDT 3800' Sand 5475 4103' MDT 4018' Sand 5714 4271 MDT 4172' sand 6000 4474 6504 4814 MDT 4669 Sand Beluga 679Q 5054 9 5/8'° 53,.5 # L-80 BTC Mod 9. 10 3/22/16 7 FUME Furie Operating Alaska, LLC Location: Cook Inlet, Alaska (Offshore) Slot: KLU#A-2 Condor (Slot B) Field: Kitchen Lights Unit Well: KLU#A-2 Condor Facility: Furie Monopod Platform Wellbore: KLU#A-2 Condor Sloth F Ckg ?AA BAKER HUGHE5 Scale 1 inch = 850 Easting (ft) -425 0 425 850 1275 1700 2125 2550 2975 3400 75C 150C 225C Q. U : 3000 N L 3750 4500 5250 6000 750 0 750 1500 2250 3000 3750 4500 5250 Vertical Section (ft) Scale 1 inch= 1500 ft Azimuth 43.860 with reference 0.00 N, 0.00 E 3400 2975 2550 2125 Z O 1700 cfl 1275 850 425 0 -425 Plot reference wetlpath is KLU#A-2 Condor (SlotB)_Ver#10 _ True vertical depths are referenced to Furie Platform (RT) Grid System: NAD27 / TM Alaska SP, Zone 4 (5004), US feet ---------------------- Measured depths are referenced to Furie Ptatform (RT) -------- - Reference: True north Scale: True distance _-North Furie Platform (RT) to Mean Sea Leel. 104 feet Mean Sea Lejel to Mud fine (At Slot KLU#A-2 Condor (Std B)): 98 feet Depths are in feet Coordinates are in feet referenced to Slot I Created by, ulricard on 27/Jan/2016 F Ckg ?AA BAKER HUGHE5 Scale 1 inch = 850 Easting (ft) -425 0 425 850 1275 1700 2125 2550 2975 3400 75C 150C 225C Q. U : 3000 N L 3750 4500 5250 6000 750 0 750 1500 2250 3000 3750 4500 5250 Vertical Section (ft) Scale 1 inch= 1500 ft Azimuth 43.860 with reference 0.00 N, 0.00 E 3400 2975 2550 2125 Z O 1700 cfl 1275 850 425 0 -425 Well Profile Data Design Comment MD (ft) Inc (0) Az (0) TVD (ft) Local N (ft) Local E (ft) DLS (°1100ft) VS (ft) Tie On 104.00 0.000 45.404 104.00 0.00 0.00 0.00 0.00 End of Tangent 300.00 0.000 45.404 300.00 0.00 0.00 0.00 0.00 End of Build (J) 1906.06 48.182 45.404 1723.35 446.83 453.19 3.00 636.20 End of Tangent (J) 5474.99 48.182 45.404 4103.00 2314.27 2347.18 0.00 3295.03 End of 3D Arc (J) 5882.04 42.806 36.816 4388.50 2531.84 2538.38 2.00 3584.40 End of Tangent (J) 6789.14 1 42.806 1 36.816 5054.00 1 3025.31 1 2907.75 1 0.00 1 4196.13 F Ckg ?AA BAKER HUGHE5 Scale 1 inch = 850 Easting (ft) -425 0 425 850 1275 1700 2125 2550 2975 3400 75C 150C 225C Q. U : 3000 N L 3750 4500 5250 6000 750 0 750 1500 2250 3000 3750 4500 5250 Vertical Section (ft) Scale 1 inch= 1500 ft Azimuth 43.860 with reference 0.00 N, 0.00 E 3400 2975 2550 2125 Z O 1700 cfl 1275 850 425 0 -425 Page 2 of 2 R1 Operating Alaska LLC DIRECTIONAL PROXIMITY A directional plat showing the well within 200' of the KLU A-2, the KLU # 3 is included in the directional proximity section. The KLU # 3 is owned by Furie Operating Alaska, LLC, making Furie Operating Alaska, LLC the only affected applicant to wells in proximity. If FURIE Furie Operating Alaska, LLCFeA as Location: Cook Inlet, Alaska (Offshore) Slot: KLU#A-2 Condor (Slot B) MKwww Field: Kitchen Lights Unit Well: KLU#A-2 Condor HUGH Facility: Furie Monopod Platform Wellbore: KLU#A-2 Condor SlotB Plot reference wellpath is KLU#A-2 Condor (SlotB)_Ver#10 Easting (ft) True vertical depths are referenced to Furie Platform (RT) Grid System: NAD27 / TM Alaska SP, Zone 4 (5004), US feet Measured depths are referenced to Furie Platform (RT) North Reference: True north Furie Platform (RT) to Mean Sea Level: 104 feet Scale: True distance Mean Sea Level to Mud line (At Slot: KLU#A-2 Condor (Slot B)): 98 feet Depths are in feet Coordinates are in feet referenced to Slot Created by: ulricard on 21/Mar/2016 Scale 1 inch = 50 ft Easting (ft) Well Profile Data -25 Design Comment MD (ft) Inc (0) Az (') TVD (ft) Local N (ft) Local E (ft) DLS (°/100ft) VS (ft) Tie On 104.00 0.000 45.404 104.00 0.00 0.00 0.00 0.00 End of Tangent 300.00 0.000 45.404 300.00 0.00 0.00 0.00 0.00 End of Build (J) 1906.06 48.182 45.404 1723.35 446.83 453.19 3.00 636.20 End of Tangent (J) 5474.99 48.182 45.404 4103.00 2314.27 2347.18 0.00 3295.03 End of 3D Arc (J) 5882.04 42.806 36.816 4388.50 2531.84 2538.38 2.00 3584.40 End of Tangent J 6789.14 42.806 36.816 5054.00 3025.31 2907.75 0.00 4196.13 Scale 1 inch = 50 ft Easting (ft) -25 0 25 50 75 100 125 150 175 200 225 250 275 300300 o``7.0 GO 275 250 PP Sr 225 200 - u 150 0 125 oo .ate- 100 75 _ 50 0 25 ��O 500 � P� sp �tJ#A-2 ndor (Slot ) o.._ --w� I .ra..�..: R.::_-.i-�[.:�.�-.�Bc,�PYYJIL '.4tT.�:�it'�L...T_'C ... .. -. .:_SS.:. .,.a.. i... � ., u•-LiG.'__•� C _.__:;. _�Ju...��-'.i2 L^ -.:y _.c-'. :' -.T.a:.�+fLLEu�.�.�..e3s. ,zL.:::G.'�i .•. - _ _ -25 y FURIE L- Operating Alaska LLC FURZE OPERATING ALASKA KITCHEN LIGHTS UNIT NO. A-1 COOK INLET PROCEDURE A. LOCATION 1. Jack down to water and test Randolph Yost hull for seaworthiness. 2. Record tug's name, dock departure time and time at location. 3. Hook up lines and free legs. 4. Tow rig to location. a. X = 294,331.49E & Y=2,583,125.62N (NAD 27, ASP zone 4). Lat: 600 56' 12.144" Long; -1510 09'23.013" 5. Take side scan sonar to verify location clearance. 6. Winch rig into position against platform. 7. Orient Randolph Yost with 234 -degree bow heading. 8. Pre -load Randolph Yost. Have screw pumps on location for pre -loading. 9. Jack up to skid cantilever over platform. B. Drive Pipe 20" x.812" wall to 350'±126' Penetration— RKB to sea floor - 183' 1. Rig up 20" casing running tool and D-62 drive hammer. Note: Have Dril-Quip hand on location: 2. PU 20" x.812" with XLC-S connectors joint with deviated double wall drive shoe. 3. Orient shoe in 45' and run scribe line. 4. PU 20" x.812" with XLC-S connectors. 5. Drive 20" to 345', ±126' of penetration. Anticipate maximum blow count to be 55 BPF. Make up Torque; Min.- 27,000 ft -lbs.; Ideal — 30,000 ft -lbs; Max — 70,000 ft -lbs. 6. Cut 20" spaced out for drilling spools to be below mezzanine deck and tree to be above mezzanine deck. 7. Install 20" load ring. 8. Install the riser connector with the WQ seal on the 20". 9. Test the riser adapter by testing between the WQ seals to 2000 psi. 10. Install the 21 1/4" 2 M riser. 11. NU 21 1/4" 2M diverter with two 12" outboard lines. 12. NU 12" outboard lines to divert and function test. 13. MU 17 %2" GTX -CGI, 9.5" Ultra XL Motor, 8" NM CS DP with 8" straight blade stab, Navi Track, Pulser, NM downhole filter sub, NM UBHO, 2 joints 8" NMC SDP, XO, 8 joints 5" HWDP, 7' j ars, 12 j pints 5" HWDP, 5" drill pipe to surface. /3 FURIE Operating Alaska LLC C. Drilling 17 1/2" Hole to 2300' MD/ 1980' TVD SS 1. Pick up 2000' of 5" drive pipe. 2. GIH with 17 1/2" GTX — CGI bit, 9.5" Ultra XL Motor, 8" NM CS DP with 8" straight blade stab, Navl Track, Pulser, NM downhole filter sub, NM UBHO, 2 joints 8" NMC SDP, XO, 8 joints 5" HWDP, 7' j ars, 12 joints 5" HWDP, 5" drill pipe to surface. 3. Wash out DP to 375', viscoscified mud. 4. Run Single shot gyro and get inclination survey at the base of drive pipe. 5. Orient mm and build 3'/100' in 45.404 azimuth to 23 00' MD /I 985'tvd. 6. CBU and POOH to DP shoe. 7. PU 17 1/2" hole opener and make wiper trip. 8. GIH to TD and CBU. 9. POOH. 10. RU 13 3 8" casing running tools. Run 13 3/8" 72 # N-80 BTC casing as follows: a. 13 3/8" 72# N-80 BTC float shoe b. ±80' of 13 3/8" 72 ppf N-80 BTC casing c. 13 3/8" 72# N-80 BTC float collar d. 1826' of 13 3/8" 80 ppfN-80 BTC casing. e. Cameron T-137 casing hanger running tool with T-137 Metal seal neck x 13 3/8" BTC box bottom. f. 13 3/8" 72 ppf N-80 BTC Landing joint Note: 13 3/8" float shoe is baker -locked to pin end of joint # 1 and coupling is Baker -locked on joint # 1. Baker lock joint # 1 coupling and joint # 2 pin. Joint # 2 coupling is baker -locked to joint and float collar is Baker locked in coupling. Ido not Baker lock joint # 3 to float collar. Make up torque values should be carefully noted on the first 6 -8 joints while making up casing to the base of the triangle. Use this established torque value on the remainder of the casing. If coupling face is between minus 1 thread turn (.2") and the base of the triangle, the make-up is satisfactory. Centralize first joint at 10' from shoe with stop ring. Centralize next 8 couplings and then every other coupling to mudline. Total 29 centralizers. 11. Lower the casing until it lands on the load ring. 12. Rig up circulating wedge and circulate bottoms up with 50% wash-out factor or 428 bbls minimum. Circulate until background gas is at or below below drilling levels. Stage pumps up to 8-10 bbls /minute. watch for losses and reduce rate if losing volume. Bottoms up is 285 bbls. 100% wash-out is 570 bbls. / L/ FURIE l_ Operating Alaska LLC 13. Rig up Cement per cement program below: Spacer- 80 bbls Mud push II @ 10.0 ppg Lead 640 sacks Class G + .05 gal/sack Antifoam + 0.5agl/sack Extender WEIGHT: 12.3 ppg YIELD: 2.36 Cu. Ft / sk Water: 13.561 gps: - Seawater Mix Fluid: 14.11 gps Tail 940 sacks Class G + .2 gal/sack Antifoam + 0.08 gal/sack Dispersant L. T. + 0.45 gal/sack Fluid Loss + .06 gal/sack Accelerator WEIGHT: 15.6 ppg YIELD: 1.22 Cu. Ft / sk Water: 4.838 gps: Mix Fluid: 5.628 gps Spacer 5 BBLs fresh water 14. Displace cement with 284 BBLS mud to top of float collar. Bump plug with 1000 psi over pump pressure. Do not over displace cement by more than 6 bbls. Capacity of 13 3/8" shoe track is 12 bbls. 15. Rotate 9 right hand turns and release the running toll and POOH. 17. ND diverter and riser. 16. Strip the drilling riser adapter over the T-137 casing hanger. 17. NU Cameron 13 3/8" MBS x 13 5/8" 5M psi WP wellhead. 18. Tighten the lockdown screws in an alternating cross fashion to 400 -ft -lbs is on each lockdown screw. 19. Test wellhead to 2500 psi for ±5 minutes. Burst of 72 ppf N-80 BTC casing is 5380 psi. NOTE: Casing test will test wellhead also. 20.. NU 11" 5m x 13 5/8" 1 O DSA. 21. NU 13 5/8" 1OM" BOP, and 13 5/8" 5M Annular, bell nipple and all choke and kill lines. 22. Install test plug. Shell test BOP to 2500 psi. 23. Test BOP and all equipment on a chart to 250/2500 psi. Test annular to 250/ 2500 psi. AOGCC to witness. NOTE: Drilling HASP is 1210 psi to break down a 13.5ppg EMW shoe at 1980' TVD Production HASP is 1939 psi using a. I psi/ft gas gradient. 15, \7 y FURIE 1. Operating Alaska LLC Anticipated mud weight is 10.0 ppg. Mud weight is anticipated for mud and hole stability. 14. Condition to run 9 5/8" casing or for logging run. 15. POOH and L/D BHA, I". 16. If additional MDT is wanted, rig up electric line unit. NOTE: Be prepared make a wiper with 12 1/4" hole opener, after logging. 17. Change rams to 9 5/8" casing rams. 18. Test bonnet seals to 1000 psi. 19. RU casing running tools. 20. Run 9 5/8" 53.5 # L-80 BTC -RS casing as follows: a. 9 5/8" 53.5# L-80 BTC - RS float shoe b. 80' of 9 5/8" 53.5 ppf L-80 BTC - RS casing c. 9 5/8" 53.5# L-80 BTC float collar d. 6700' of 9 5/8" 53.5# L-80 BTC - RS casing. e. Cameron 9 5/8" mandrel casing hanger with running tool. f. 13 3/8" 68 ppf K-55HC BTC Landing joint Note: 9 5/8" float shoe is baker -locked to pin end of joint # Land coupling is Baker -locked on joint # 1. Baker lock joint # 1 coupling and joint # 2 pin. Joint # 2 coupling is baker -locked to joint and float collar is Baker locked in coupling. Do not Baker lock joint # 3 to float collar. Make up torque values should be carefully noted on the first 6 -8 joints while making up casing to the base of the triangle. Use this established torque value on the remainder of the casing. If coupling face is between minus 1 thread turn (.2") and the base of the triangle, the make-up is satisfactory. Centralize first joint at 10' from shoe with stop ring. Centralize next 8 joints and then every other j oint to 3 000'- 42 centralizers. Total 51 centralizers. 21. Land casing in MBS system. 22. Rig up and circulate bottoms up with 25% wash-out factor or 496 bbls minimum. Circulate until background gas is the same or below drilling levels. Stage pumps up to 6.5 - 7 bbls /minute. watch for losses and reduce rate if losing volume. Bottoms up is 379 bbls. 25% wash-out is 496 bbls. r7 FURIE Operating Alaska LLC 23. Rig up and cement per cement program below: Spacer- 80 bbls Mud push II @ 11.5 ppg Lead 343 sacks Class G + .05 gal/sack Antifoam + 0.5ag1/sack Extender WEIGHT: 13.5 ppg YIELD: 1.71 Cu. Ft / sk Water: 8.146 gps: - Seawater Mix Fluid: 9.256 gps Tail 736 sacks Class G + .2 gal/sack Antifoam + 0.12 gal/sack Dispersant + 0.3 gal/sack Fluid Loss + .06 gal/sack Accelerator WEIGHT: 15.6 ppg YIELD: 1.22 Cu. Ft / sk Water: 4.951 gps: Mix Fluid: 5.631 gps 24. Displace cement with ± 474 BBLS S'eaWater to top of float collar. Bump plug with 1000 psi over pump pressure. Use top and bottom plugs. Do not over displace cement by more than 3 bbls. Capacity of 13 3/8" shoe track is 5.6 bbls. 25 Bleed off pump pressure and make sure floats are holding. 26. ND cement head. 27. Back off running tool with 16 right hand rotations and lay running tool and landing joint down. 28. ND BOP. NU dry hole tree. 29.Completion to be performed before rig leaves platform. AOGCC sundry is required before completing KLU # A-2. 00-0.8sow FURIE Operating Alaska LLC N 1000 2000 3000 5000 6000 8000 1 *T--T---�-'-T---'-T---T 0V -4N Ln M Ln qT Ln Ln �D Ln I,*- w m 0 r-4 Ln N m qzT Ln (Yi 4 l6 r -i V-4 r4 r -i V-1 V-4 rq r -q CONDOR DVD /9 U. �0 X w a RIE FU i - Operating Alaska LLC 0 111 4000 5000 FURIE OPERATING P 'KA, LLC KITCHEN LIGHTS UNIT # A-2 DEPTH vs PRESSURES MAIN MAIN! 6110 81101 MAIN! am MAIN NMI MAIN 110110 =01 a 001101 MAIN MAIN MAIN am M MAIN mm MAIN 001101 MAIN 001101 001110 MAIN 10001 �M`0101101 MAIN 10001 MiNkIRMIN in in 00101 0011000110 001101 MAIN! 001101001101 1=2001101 MAIN &=I 00110 10001 001101� am, 0000 001101 1 MAIN i MAIN law 10001 00110 00101 two MAIN MAIN NONE 8 9 10 11 12 13 14 15 16 17 18 19 20 Mud Weight Equivalent ® ppg FURIE Operating Alaska LLC FORMATION DEPTHS: Geological Data from KLU # 3 Formatiiom Formation Tops (TVD Sterling 2868' TVD MD RT 3624' Potential Property Lease: ADL 389197: Furie Operating Alaska has 100% ownership. Gas ar Jots Operating Alaska LLC 1796.0 3433.0 0% KLU A2 CONDOR .0 n CO NP MDT 401E 5535 MD 4145 TVD -i FURIE Operating Alaska LLC KLU # A-2 Mud Volume 12 1/4" hole Interval: 345 - 2300' 17 1/2" hole 9.0 ppg Aqua Gel ID Depth ID Depth BBLs Pit Volume 500 Cased Holy 18.138" 345' 110 Open Hole 17o51e 2300' 582 Washout % 100% 582 Dilution (total x 1.6) 2838 total volume x 1.4) 3856 Interval: 2300 - 6790' 12 1/4" hole 9.0 -10 ppg Aqua Gel ID Depth BBLs Pit Volume 500 Cased Hole 12.415" 2300' 345 Open Hole 12.25 6790 655 Washout % 15% 225 Dilution (total x 1.4) 2415 total volume 4140 ir7 FURZE Operating Alaska LLC KLU # A 2 Mud MD Mud Viscocity Plastic Yield pH Fluid loss As needed Weight As required for < 10 cc fluid loss Viscosity Point SteelSealS 25 50 5 ppb 345'- 8.8-9.3 80-120 40-20 55-35 8.5-9.5 <10.0- 2300' Soltex As needed Baroid 41 As needed for 10.0 pp Aldacide -G API 2300- 9.0-10.0 40-53 6-15 13-24 8.5-9.5 <12.0- 6790 HTHP System Formulation for 345' -2300'; AQUAGEL/ freshwater spud mud. PRODUCT CONCENTRATION Water 0.905 bbl AQUAGEL 15 - 25 ppb Barazan D plus As needed Pac-L DEXTRID LT As required for < 10 cc fluid loss Baracarb 5/25/50 5 ppb SteelSealS 25 50 5 ppb BARAFIBRE 4.9 pDb Baroid 41 As required for 8.8-9.3 ppg mud weight Caustic 0.1 ppb 8.5 - 9 H) ALDACIDE G 0.1 ppb System Formulation for 2300'-6790': 2% KCL/BDF-499/ GEM GP. PRODUCT CONCENTRATION Water 0.905 bbl KCL 7 ppb Caustic 0.2 ppb (9pH) Barazan D plus 1.0 ppb Dextrid 1-2 ppb Pact 1ppb BDF 499 4 ppb GEM GP 1.0 % by volume Baracarb 5/25/50 10 ppb 3.3 ppb of each) Baritol Plus As needed Soltex As needed Baroid 41 As needed for 10.0 pp Aldacide -G 0.1 ppb av FURI Operating Alaska LLC CASING DESIGN FACTORS Csg Collap Burst Burst Tensile Tensile SF SF SF se Connection Connection Collapse Burst Tension 13 2670 5380 5380 1661M 1693000 2.75 4.50 10.0 3/8„ 95/8 6620 7930 7930 1244M 1329000 2.52 4.09 3.42 13 3/8" 68ppf HCK-55 BTC -RS set at 2300'MD/ 1985' TVD Collapse based on mud weight at casing point. 9.4 ppg x.052 x 1985 = 970.3 psi; DF = collapse rating/ collapse pressure = 2670/970.3 = 2.75 Calculated Burst is based on Frac Gradient - gas gradient (13.5 ppg x.052 x 1985') - (.1psi/ft x 1985') _ 1195 psi -199 psi - 1210 psi; Drilling HASP DF = Burst/HASP = 5300/1195 = 4.50 Tension Strength Calculation 72 ppfx 2300'= 165,600# DF = pipe body yield/ calculated tensile DF = 1661000/ 165600 = 10.0 Casing Test Pressure - 2500 psi. 50% of 5380 = 2690 ((MW - PP backup)x .052 x TVD depth)) +test pressure = (10.0 -9.0) x.052 x1985 + 2500 = 2603psi 9 5 8" 53.5 ppf L-80 BTC - RS swet at 6790' MD/ 5054' TVD Collapse based on mud weight at casing point. 10.0 ppg x.052 x5054 = 2628.08 psi; DF = collapse rating/ collapse pressure = 6620/2628.08 = 2.52 Calculated Burst is based on pore pressure - gas gradient (9.3 ppg x .052 x 5054') - (.1psi/ft x 5054') _ 2444.11 psi - 505.4 psi = 1938.7psi; Production HASP DF - Burst/HASP = 7930/1938.71 = 4.09 DF Calculated Tension in air 53.5ppf x 6790'= 363,265#DF = pipe body yield/ calculated tensile 1244000/363265 = 3.42 ♦L 00,19 FURIE L - Operating Alaska LLC KICK TOLERANCE CALCULATION Possible Formation Pressure - 10.8 ppg .5 ppg over anticipated Planned TD mud weight -10.0 ppg Surface Casing Shoe - 2300' MD/ 11980' TVD LOT Cad Surface Casing shoe -13.5 ppg EMW Hole Depth - 6790' MD/ 5054' TVD Bit Size - 12 1/4" Bha Length - 151' Average OD of BHA - 8" Drill Pipe OD - 5" Influx Gradient =.1 psi/ft Kick Intensity =.5 ppg - MASCIP - Maximum Allowable shut -incasing Pressure (13.5 ppg-10.Oppg) x .052 x 1980' = 360 psi Height influx: (MASICP-((Kick Intensityx.052x tvd of well) ))/ (Current MW x.052) -Gas Gradient ((360 -(.5 x .052x 5054))/ ((10 x .052) - .1 psi/ft)= 545' Influx volume Annular capacity between the hole and pipe BHA annular capacity -((12.25"x12.25") - (8x8)) /1029.4 = .0836 bbl/ ft - Drill Pipe annular capacity: ((12.25"x12.25") - (5x5)) /1029.4 =.0836 bbl/ ft - Influx volume: Influx Volume at shoe = Height / Pipe Cap. - 545'/.1215 bbl/ft = 66 bbl LOT @ shoe = 13.5 ppg x .052 x 1980'= 1390 psi Formation pressure @ TD = 9.8 ppg x.052 x 5054'= 2575 psi Using Boyle's Law- P1V1= P2V2: to get bottom hole conditions. 66 bbls x 1390 psi= 2575psiV2 V2=35.6bbls The smaller is the max kick before breaking down the shoe - 35.66 bbls. FURIE nd OFF TEST PROCEDURE FORMATION I TER('!� 'a NOM0 If a 16.0 ppR EMWor the maximum EMWWcified in the wellplan is reached without indication ofleak-off, shutdown and hold the pressure there. This becomes the data for aformation integrity test M77 instead of a leak off test (LO4 6. Shut down when the leak -off point is observed and 3 bbls of mud have been pumped into the formation. Record the instantaneous shut-in pressure (]SIP). With the pump shut down, monitor and record a IS second and 3o second shut-in pressure and the shut-in pressures for a minimum of 10 minutes (at 30 second intervals) or until the shut-in pressure stabilizes. Plot the Information and record the LOT point or FIT point Bleed the pressure off and record the fluid volume recovered If Possible. If In doubt of the leak off point, contact the Drilling Engineer or Drilling Team Lead to discuss and evaluate the test® Upon completion of the test, forward the data to the Milling Engineer in Anchorage. The Drilling Engineer will forward the information to the proper agencies. 00jo 0 -- FUR I E upmerating Alaska LLC WELL CONTROL EQUIPMENT 211/4" 2M Diverter with two (2) 12" diverter lines. Function test. 13 5/8" SM annular and 13 5/8" 10M three ram BOP MASP -1210 psi From Casing Design Calculations. To break down the shoe at 1980'tvd. BOP Test Pressure.- 250 psi low and 2500 psi high on annular, rams and all related POPE. d. 8 ` RKB 00. FURIE1 _ 1 Operating Alaska LLC i 8.00 1 -------- -- -------- - RKB to Deck ' 67.00 Proposed length of inner barrel to i Flowline 26.00 ; 1 ft Stick in 1 1- RKB Bottom Bellnipple � � ----------------------------- 1 -' 1 1 1 1 1 1 B/NIPPLE LENGTH 17.00 1 1 1 1 1 1 • 1 1 I 1 1 1 1 1 1 1 1 1 1 1 RKB to TOP OF DIVETER Ulm -----------------►............................................................................................., 0 0 0 0 Annular 21 1/4 2K a 4.33 21 1/4 2M flange with RX7.3- •' 1 RKB TO ANNL LAR' ' 1 1 1 .�.__................................................................................................. ♦ 2.61 1 Diverter valve RKB RKB To Unihead ........................................... .............................................................................., 10.00 21 1/4 Riser .......................................................................`............. Fastlock Adapter ; 1.5 .......................................................................If ............ ,2 9 RKB FURIEi Operating Alaska LLC ; 8.00 t ----------- -- -------- RKB to Deck 67.00 Proposed length of inner barrel to EJowline o 25.00 i ft Stick in B ' -----------RKB Bottom section Rel}nipple ------------ B/NIPPL .°L-ENGTH- ---- - - - - 12.00 i t i i i i t ......................................................................t:..................... TOP of ANNULAR Flange 1 Rh ILMOLA --- -- -- _ Annular 13.5/8 x 5K ' 4.51 Flanges. 13.5/8X1OK BX159 �N Cameron Type U 13.5/810K double: so_ a 7/8 _ p VBR ram s ----------------� � r &5-5 t o (i, E hear -,- RamsRam s. --- t Choke Line t Kill Line ® ( t 3.47 e Cameron Type U 13.5/810 ingle 0 5"3127/8"—��- VBR ram . .. V.Mw I _ Flanges 13.3/8x1OK BX159 - ; 6.54 13 5/8 Riser t t t B ................................................................... + ............ RKB To Unihead 5,50. �'• - Fastlock Adapter- t -- . --- � - x.10 ..........v ......... ............. ...a .................................. .......... un..�....uw ..,.1.' :.... .........r.... ............. ..r.................... .......... ' - • .. - .: .'o. .O - - .r ,� �•`u �^ f��=,r � �,s� n'��" �, �x ° e� °�'` �-X F` .�rfF'.Rd .tf''rt4 '*fi r+.`N:.a'f„?�.+P �+" +.:.pt N�- `:.i lr.-�" ♦ x.v'�.ft`, .. �z. fi� � � �. 30 overboard choke line #14 Lw1williAl W MmAlk SANDTRAP 1: 50 BBLS DEGASSER PIT: 70 BBLS DSR: 35 BBLS DST: 35 BBLS CLEAN PIT: 38 BBLS 0.9 BBLS/INCH 0.45 BBLS/INCH 0.45 BBLS/INCH 0.48 BBLS/INCH 0.35 BBLS/CM 0.175 BBLS/CM 0.175 BBLS/CM 0.18 BBLS/CM TANK 1 : 366 BBLS 3 BBLS/INCH 1.2 BBLS/CM GEL TANK: 225 BBLS 1.2 BBLS/INCH 0.5 BBLS/CM w SLUG PIT: 45 BBLS 0.375 BBLS/INCH 0.15 BBLS/CM TANK 2:335 BBLS TANK 3:335 BBLS 2.8 BELS/INCH 2.8 BBLS/INCH 1.1 BBLS/CM 1 1.1 BBLS/CM -- FURIE Operating Alaska LLC TANK 4: 366 BBLS 3 BBLS/INCH 1.2 BBLS/CM 86-22 $1 51.1601 4-1/1611 5,000# 4-1/1611 5j.000# Baker 11 C 11 4-1/16" 51 000# A 4-1/16" 5,000# 13-5/8 51000# 2-1/16" 50000# 22.38 9-3 F (,4-. fill 13-5/8 5,000# 23.50 6.1911 2 Stage MBS System w/ 4-1/16" 5K Completion Note: Dimensional information reflected on this drawing are estimated measurements only. 4-1/16" 5,000# (LUJ r-2-1/16" 5,000# —now Arm -1/16" 5,000# (ET 2010 13-3/811 9— 5/8 " 1 4-1/211 AMERON Dal # 1167594 33 Kick Tolerance Calculations KICK TOLERANCE: 20.6 bbl Compare CASE 1 and CASE 2 volumes for the gas influx above. The smallest volume is selected to represent the maximum kick volume allowed without breaking down the shoe (or weakest formation) It is difficult to shut in a well with less than a 10 bbl kick volume guy schwartz 4/14/2016 input in yellow areas only Furie KLU A-2 MW (ppg) 10.3 ppg LOT/FIT (ppg) 13.5 ppg TVD Casing Shoe (ft) 1980 ft TVD If a formation deeper than the casing shoe is known to be weaker than the casing shoe (have a lower fracture gradient/LOT) then that weaker formations TVD and LOT can be used in place of the casing shoe information for more accurate calculations Kick Intensity (ppg) 0.5 ppg Formation Pore Pressure cannot be less than the MW to have a kick! 0.5 ppg kick tolerance over current MW is a standard assumption Assume that the kick is hydrocarbon gas (not oil or water) TVD of Kick Influx (ft) 5054 ft TVD Gas Gradient (psi/ft) 0.1 psi/ft Change only if gas gradient is known to be different Hole Size (in) 12.25 inches Drill Pipe OD (in) 5 inches BHA OD (in) 8 inches Lenth of BHA (ft) 351 ft If the BHA is longer than the open hole, the kick will come to surface very quickly due to the smaller annular capacity 0.1215 bbl/ft Annular Capacity between OH and DP 0.0836 bbl/ft Annular Capacity between OH and BHA 329.472 psi Maximum Allowable Surface Pressure 131.404 psi Underbalance due to Kick Intensity 198.068 psi margin before casing shoe is broken down/fractured for weakest formation below casing shoe) Height of Gas Kick 454.7 feet Volume of Gas Kick 38.0 bbl CASE 1 Assume Kick is only around the BHA (not the DP) at the influx depth Volume of Gas Kick 55.2 bbl Assume Kick is only around the DP (not the BHA) at shoe depth Volume at influx 20, 6, bbl CASE 2 depth Conversion KICK TOLERANCE: 20.6 bbl Compare CASE 1 and CASE 2 volumes for the gas influx above. The smallest volume is selected to represent the maximum kick volume allowed without breaking down the shoe (or weakest formation) It is difficult to shut in a well with less than a 10 bbl kick volume Kitchen Lights Unit #A-2 (PTD 216-055) Variance requests: Furie"s request to eliminate conductor pipe as required for offshore installations is APPROVED. 20" structural pipe will be driven to 345 ft MD and a diverter installed for drilling the 17 1/2"surface hole section to a depth of 2300 ft. MD. In drilling KLU #3 (on same platform) no indications of shallow gas were seen in the surface hole section to same depth. Furie's request to use 2 x 12" diverter lines for drilling 17 Y2" OH is APPROVED. The equivalent surface area of the two 12" is essentially the same as a 17 %2" hole. (236 sq in vs 240 sq in). Furies request to eliminate H2S monitoring equipment is DENIED. Standard procedure and best operating practices in Cook Inlet require installation of H2S equipment for offshore drilling installations regardless. Conditions of Approval: 1. Rig inspection required before drilling operations start. 2. 10,000 psi 13-5/8" BOPS to be tested to 3500 psi minimum. Initial witnessed test may be higher at the discretion of Furie for commissioning ROPE. ( 5M annular to 2500 psi - min) 3. 20" surface casing shoe must tested to leak off (LOT) or to min FIT of 13.0 ppg EMW. 4. Casing tests as follows: • 13 3/8 casing test pressure — 2500 psi ( 46% of burst) 9 5/8" casing test pressure = 3500 psi (44% of burst) 5. BOP Casing Rams to be tested as per following: • 9 5/8" rams to 2500 psi 6. Daily Drilling report to be submitted to Commission by email. 7. BOPE equipment will be on 7 day testing cycle (i.e. not to exceed 7 days). 8. Mud -logging equipment to be rigged up and operational from the base of the 30" x. 1.5" (X52) conductor drive -pipe (400' md) to TD. 9. Furie is required to H2S monitoring equipment on board and operational. 10. CBL required over 9 5/8" casing to determine TOC and cement quality. 11. Sundry approval required for completion operations including running tubing, perforations or hydraulic fracture stimulations. Bettis, Patricia K (DOA) From: David McCraine <d.mccraine@furiealaska.com> Sent: Friday, May 20, 2016 4:12 AM To: Bettis, Patricia K (DOA) Subject: Re: KLU A-2 (PTD No. 216-055): Permit to Drill Application Attachments: KLU#A-2_Condor_SlotB_ Ver#13 Well Path Geo Report.xlsx Here it is. I meant to send this earlier. The KB will be ±132' above MSL. We have to get higher to get over the monopod. Regards. Dave McCraine Furie Operating Alaska -Lafayette Drilling Engineer 337-981-0270 Office 337-501-6854 Cell From: Patricia Bettis <patricia.bettis@alaska.gov> Date: Thursday, May 19, 2016 at 6:14 PM To: Dave McCraine <d.mccraine@furiealaska.com> Subject: KLU A-2 (PTD No. 216-055): Permit to Drill Application Good afternoon David, For the revised permit to drill application for KLU A-2 with a proposed depth of 9,789' MD, please send the Baker Hughes Planned Wellpath Geographic Report to me in an excel spreadsheet. The printed version submitted with the application has such a small font that it is unreadable. Also, the Baker Hughes Planned Wellpath Geographic Report shows the KB as 132'; whereas on the Form 10-401, Box 10, the KB is reported as 104'. Please verify which KB elevation is correct. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7t" 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. Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Thursday, May 19, 2016 3:14 PM To: 'David McCraine' Subject: KLU A-2 (PTD No. 216-055): Permit to Drill Application Good afternoon David, For the revised permit to drill application for KLU A-2 with a proposed depth of 9,789' MD, please send the Baker Hughes Planned Wellpath Geographic Report to me in an excel spreadsheet. The printed version submitted with the application has such a small font that it is unreadable. Also, the Baker Hughes Planned Wellpath Geographic Report shows the KB as 132'; whereas on the Form 10-401, Box 10, the KB is reported as 104'. Please verify which KB elevation is correct. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7t" 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. Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, April 27, 2016 4:23 PM To: 'David McCraine' Cc: Bettis, Patricia K (DOA); John Stuart Subject: RE: KLU #A-2 (PTD 216-055) Initial test to 5000 psi is fine for the 10K BOPS. My oversite as the wellhead is 5000 psi anyway for this well. 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 if to you, contact Guy Schwartz at (907-793-1226) or (Guy.schwartz@alaska.gov). From: David McCraine rma i Ito: d. mccra ineffu riea laska. com Sent: Wednesday,, April 27, 2016 8:35 AM To: Schwartz, Guy L (DOA) Cc: Bettis, Patricia K (DOA); John Stuart Subject: Re: KLU #A-2 (PTD 216-055) Thanks Guy. We will go to 13.Oppg EMW FIT for our shoe test. I do get 329 bbls displacement at the estimated top of the floats. We always recalculate this with actual pipe measurements. The shear rams are certified and a copy is in the rig book sent to AOGCC. We will rig up the H2S monitors for both wells. It is not a good practice to take the test pressures to the max rating, if not needed. The people operating the equipment are at risk to the higher pressures, as is the pumping equipment, lines, etc. We propose to make the initial test to 5000 psi for this season, as this is well over any Production MASP we will encounter this season. Regards. Dave McCraine Furie Operating Alaska -Lafayette Drilling Engineer 337-981-0270 Office 337-501-6854 Cell From: Guy Schwartz <guy. schwa rtz @alas ka.gov> Date: Tuesday., April 26, 2016 at 4:29 PM To: Dave McCraine <d.mccraine furiealaska.com> Cc: Patricia Bettis <Patricia.bettis@aa�ka.gov> Subject: KLU #A-2 (PTD 216-055) David, Here is a draft of the approval letter details that will pertain to the approval of the PTD for A-2. A couple issues I saw with PTD: 1) I calculate a min of 13 ppg for LOT to get acceptable inflow on the surface casing shoe. (15 bbls influx) 2) On page 15 for the surface casing displacement volume on step 14 I get a higher number than 284 bbls. Can you check this? (13 3J8" casing has capacity of .148 bbl/ft) 3) The shear rams must be certified for the size of drill pipe you are using (have documentation ready) 4) Note that H2S monitors should be ready to for the first well ... they will be needed later on anyway. 5) I assume the initial BOP test will go up to 10,000 psi to commission the equipment. There after 3500 psi is fine for the duration of this well. NOTE: we have not seen a spacing exemption application yet. These take time to process.. FYI. 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 (Guy.schwartz a,alaska.gov). P) Bettis. Patricia K (DOA) From: AnchorageMEGCluster@alaska.gov Sent: Tuesday, April 19, 2016 3:54 PM To: Bettis, Patricia K (DOA) Subject: Delivery Status -McAfee Email Gateway Anchorage Attachments: deliverystatus.txt; Example of Request for Spacing Exception --- The following addresses had delivery problems --- <d.mccraine@furiealaska.com> (Unable to deliver message within specified time.) Bettis, Patricia K (DOA) From: Sent: To: Subject: Attachments: Good afternoon Dave, Bettis, Patricia K (DOA) Tuesday, April 19, 2016 2:27 PM 'David McCraine' Example for Spacing Exception Moraine 1 Request for Spacing Exception Moraine l.pdf I've combined the two emails for you that I've been trying to send to both you and Bruce. 20 AAC 25.055(a)(4) states, "if gas has been discovered, the drilling unit for the pool is a governmental section; not more than one well may be drilled to and completed in the pool on any governmental section; a well may not be drilled or completed closer than 3,000 feet to any well drilling to or capable of producing from the same Pool." A spacing exception to the spacing requirements is needed for the KLU A-2 well, as that well is proposed to be drilled within the same government section as KLU #3 (Section 24, Township 10 North, Range 11 West, S.M.). A permit to drill application will not be approved prior to the spacing exception beim- granted. 20 AAC 25.05 5 (d), the commission will review an application for an exception to the provisions of this section in accordance with 20 AAC 25.540. In taking a precursory glance at KLU A-1 Permit to Drill Application, if KLU A-1 is closer than 3,000 feet to KLU #3, a spacing exception will be needed to drill that well. Attached is an example for a spacing exception request for an oil well. For KLU A-1 and A-2, the applicable regulations are 20 AAC 25.055(a)(2) and (a)(4), and 20 AAC 25.055(d). (The operator must submit everything listed under 20 AAC 25.055(d).) Please note that the operator also will need to provide justification as to why the wells need to drilled at the proposed locations, contrary to statewide well spacing provisions of 20 AAC 25.055. Please note that the commission will review an application for an exception to the provisions of this section in accordance with 20 AAC 25.540, which requires public notice and a tentative hearing date. For an exception to statewide spacing exception for gas wells, the application must include the names of all owners, landowners, and operators of all properties within 3,000 feet of a well drilling for gas for which an exception is sought. A notice of the request for a spacing exception must be sent to all owners, landowners, and operators of all properties within 3,000 feet of a well drilling for gas. AOGCC requires copies of the Certified Mail Return Receipt sent to said owners, landowners, and operators. If Furie is the only owner and operator within 3,000 feet of a well drilling for gas for which a spacing exception is request, please state so. However, a copy of the notice must be sent to the landowners, which is DNR. If you have any questions, please do not hesitate to contact me. Regards, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7t" 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 Vatricia.b tai alpska. � y. From: David McCraine[mailto:d.mccraine@furiealaska.com] Sent: Tuesday, April 19, 2016 2:14 PM To: Bettis, Patricia K (DOA) <patricia.bettis@alaska.gov> Subject: Test Dave McCraine Furie Operating Alaska -Lafayette Drilling Engineer 337-981-0270 Office 337-501-6854 Cell Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Monday, April 18, 2016 3:50 PM To: 'd.mccraine@furiealaska.com' Subject: Example of Request for Spacing Exception Attachments: Request for Spacing Exception Moraine l.pdf Good afternoon Dave, This is an example for a spacing exception request for an oil well. For KLU A-1 and A-2, the applicable regulations are 20 AAC 25.055(a)(2) and (a)(4), and 20 AAC 25.055(d). Please note that the operator will need to provide justification as to why the wells need to drilled at the proposed locations, contrary to statewide well spacing provisions of 20 AAC 25.055. Please note that the commission will review an application for an exception to the provisions of this section in accordance with 20 AAC 25.540, which requires public notice and a tentative hearing date. If you have any questions, please do not hesitate to contact me. Regards, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7t" 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_riia.ettis�_ll a�.g. ConocoPhillips December 9, 2014 Commissioner Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 W. 7t" Ave, Suite 100 Anchorage, Alaska 99501 Re: Notice and Request for Exception to 20 AAC 25.055 Moraine 1, Kuparuk River Unit, Alaska Dear Commissioner: P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4297 D,l"C" 10 2 0. 14 ConocoPhillips Alaska, Inc. ("CPAI") hereby notifies you and applies for an exception to the provisions of 20 AAC 25.055 for the drilling of the Moraine I (the "Well"). The Well will be drilled within the same governmental quarter section as well 3S-620. The Well will be drilled as a vertical well having the following locations.. Surface Location: 4620.3' FNL, 43 67.6' FEL, Sec 1. 2, T 12N, R7E, UM; Target Location: 4296.4' FNL, 4186.3' FEL, Sec 12, T12N, R7E, UM; Bottomhole Location: 4296.4'FNL, 4186.3' FEL, Sec 12, T12N, ME, UM. The Well is located in ADL 025528 which is owned by CPAI (55.402367%), BP Exploration (Alaska) Inc. (39.282233%) Chevron USA Inc (4.950600%) Exxon -Mobil Alaska Production Inc. (0.36480%). Exhibit I shows the location of the Well and all other adjoining governmental quarter sections. Well 3S-620 will be a grass roots rotary horizontal producer to test the performance of the Moraine formation. Well Moraine I will be drilled from an ice pad location to acquire core, logs and fluid samples and will be plugged & abandoned after completion of its data acquisition. objectives. The primary objective of well Moraine I is to acquire data to delineate the Moraine reservoir. Well 35- 620 and core acquisition well Moraine I are expected to be spud in Jan -15. See Exhibit I , which shows well 3S-620 in the same governmental quarter section as the Well. Exhibit 2 lists the names and addresses of all owners, landowners and operators of all properties within 1,000 feet of the Well. These owners are the same owners of the governmental quarter sections directly and diagonally offsetting the Well. Exhibit 3 is the Verification of Facts and Affidavit of Brian Seitz. If you have any questions or require any additional information, please call me at 265-6961. Sincerely,, Brian Seitz Development Supervisor CPF 1&3 ConocoPhillips Alaska Inc 700 G Street, Anchorage, AK 99510 Phone.- (907) 265 6961 Attachments: Exhibits 1, 2 & 3 Lid: [go * W V & EXHIBIT 1 Conocokillips Kuparuk River Unit 3S.620, MORRAINE *oww. Paul Wharton Iftmwby- J. A. Uuruhn Foo Nm 14020301801 3S420, MORRAINE Tc—�: 10.20-1 EXHIBIT 2 List of all owners, landowners and operators of all properties within 1,000 feet of the Moraine I well. These are the owners and operators of the governmental quarter sections directly and diagonally offsetting the Moraine I well. Operator & Owner: ConocoPhillips Alaska, Inc. 700 G Street (Zip 99501) P. O. Box 100360 Anchorage, AK 99510 Attention: Patrick J. Wolfe Owners (Non -Operators): BP Exploration Alaska Inc. 900 E. Benson Boulevard (Zip 99508) P. O. Box 196612 Anchorage, AK 99519 Attention: John Dittrich Chevron USA Inc. 1029 West 3rd Ave. Suite 150 Anchorage, AK 99501 Attention: Glenn C. Fredrick ExxonMobil Alaska Production Inc. 3301 C Street, Suite 400 (Zip 99503) P. O. Box 196601 Anchorage, AK 99519 Attention: Gilbert Wong Landowner: State of Alaska Department of Natural Resources Division of Oil and Gas 3601 C Street, Suite 1380 Anchorage, AK 99503-5948 Attention: William Barron EXHIBIT 3 TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the Alaska Oil and Gas Conservation Commission in the Matter of the Request of Conoco Alaska, Inc. for an Exception to the Provisions of 20 AAC 25.055 for CPAI Moraine 1 STATE OF ALASKA THIRD JUDICIAL DISTRICT VERIFICATION OF FACTS AND AFFIDAVIT OF BRIAN SEITZ. W% Brian Seitz, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Brian Seitz. I am over 19 years old and have personal knowledge of the matters set forth herein. 2. 1 am a Development Supervisor for the well operator, ConocoPhillips Alaska, Inc. ("CPAI"). 3. 1 am acquainted with the facts associated with the drilling of well Moraine 1. 4. 1 have reviewed the application submitted for the exception to 20 AAC 25.055. To the best of my knowledge and belief all facts therein are true and accurate. 5. 1 have reviewed the plats attached as Exhibit "1" and it correctly portrays pertinent and required data. S. Pursuant to 20 AAC 25.055 (b), CPAI, the well operator, prepared a Notice of Request for Exception to the Provision of 20 AAC 25.055. A copy of this notice is attached hereto. 7. On December 9, 2014, pursuant to 20 AAC 25.055 (b), CPAI sent a copy of said notice by certified mail to the last known address of all owners, landowners and operators of all properties within 1,000 feet of CPAI's Moraine 1 well, and of the governmental quarter sections directly and diagonally offsetting the governmental quarter section of the proposed location of CPAI's Moraine 1 well. These names and addresses are set forth on Exhibit 2 attached to CPAI's Request for Exception to Provisions of 20 AAC 25.055 dated December 9, 2014. Subscribed and sworn to this 9th day of December, 2014. Bri"an§Kitz STATE OF ALASKA H THIRD JUDICIAL DISTRICT This instrument was acknowledged before me this 9th day of December, 2014, by Brian Seitz. '� -0 - STATE OF' Notary Public, State of Alaska T A C B 0 NOTARYPUBLIC My Commission Expires: A U 0 (0 REBECCA SWENSEN .My C� My Commission Expiros Aub.27,2015 'w1W - - - W WW'W'Ww'wwW W WWWWVWIWW Bettis, Patricia K (DOA) From: Colombie, Jody J (DOA) Sent: Monday, April 18, 2016 10:57 AM To: Bruce Webb Cc: Bettis, Patricia K (DOA) Subject: RE: checking in Bruce- Your email has not been working. We need an application for a spacing exception for Kitchen Lights Al and A2, From: Bruce Webb [mailto:b.web�furiealaska.com] Sent: Monday, April 18, 2016 10:42 AM To: Colombie, Jody I (DOA) Cc: Bruce Webb Subject: checking in Hi Jody, I got your message — but I'm leaving for a meeting. I'll be back in the afternoon. Regards, Bruce Webb Sr. Vice President 1029 West 3rd Avenue, Suite 500 Anchorage, Alaska 99501 Office: 907.277.3726 Fax: 907.277.3796 Cell: 907.331-7399 Email: bwebbpfuriealaskanom Bettis, Patricia K (DOA) From: AnchorageM EGCIuster@alaska.gov Sent: Saturday, April 16, 2016 10:17 AM To: Bettis, Patricia K (DOA) Subject: Delivery Status -McAfee Email Gateway Anchorage Attachments: deliverystatus.txt; FW: KLU A-2 (PTD 216-055): Permit to Drill Application The following addresses had delivery problems <b.webb@furiealaska.com> (Unable to deliver message within specified time.) Bettis, Patricia K (DOA) From: AnchorageMEGCIuster@aIaska.gov Sent: Friday, April 15, 2016 4:37 PM To: Bettis, Patricia K (DOA) Subject: Delivery Status -McAfee Email Gateway Anchorage Attachments: deliverystatus.txt; FW: KLU A-2 (PTD 216-055): Permit to Drill Application --- The following addresses had delivery problems --- <d.mccraine@furiealaska.com> (Unable to deliver message within specified time.) Bettis, Patricia K (DOA) From: AnchorageMEGCluster@alaska.gov Sent: Friday, April 15, 2016 1:07 PM To: Bettis, Patricia K (DOA) Subject: Delivery Status -McAfee Email Gateway Anchorage Attachments: deliverystatus.txt; FW: KLU A-2 (PTD 216-055): Permit to Drill Application The following addresses had delivery problems --- <d.mccraine@furiealaska.com> (Unable to deliver message within specified time.) Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Friday, April 15, 2016 10:14 AM To: Ib.webb@furiealaska.com' Subject: FW: KLU A-2 (PTD 216-055): Permit to Drill Application Good morning Bruce, I've been receiving odd bounce -back server notifications when I've tried to .send the below email to David McCraine. 5o, I thought it world be best to forward this email to you to ensure that Furie received it. Have a great weekend, From: Bettis, Patricia K ( DOA) Sent: Thursday, April 14, 2016 4:35 PM To: 'David McCraine' <d.mccraine@furiealaska.com> Subject: FW: KLU A-2 (PTD 216-055): Permit to Drill Application David, If YOU have received this email, please confirm. I am getting confusing notifications on my end. Thanks, Patricia From: Bettis, Patricia K (DOA) Sent: Wednesday, April 13, 2016 11:06 AM To: 'David McCraine' <d n cra ne fu ,alaska.co > Subject: KLU A-2 (PTD 216-055): Permit to Drill Application Good morning David, 20 AAC 25.055(x)(4) states, "if gas has been discovered, the drilling unit for the pool is a governmental section; not more than one well may be drilled to and completed in the pool on any governmental section; a well may not be drilled or completed closer than 3,000 feet to any well drilling to or capable of producing from the same pool." A spacing exception to the spacing requirements is needed for the KLU A-2 well, as that well is proposed to be drilled within the same government section as KLU #3 (Section 24, Township 10 North, Range 11 West, S.M.). A permit to drill application will not be approved prior to the spacing exception being granted. 20 AAC 25.055(d), the commission will review an application for an exception to the provisions of this section in accordance with 20 AAC 25.540. Please give me a call if you have any questions. In taking a precursory glance at KLU A -i Permit to Drill Application, if KLU A-1 is clo.-,er than 3,000 feet to KLU #3, a spacing exception will be needed to drill that well. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7t" 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 oratriciarhettis�a��y. Bettis, Patricia K (DOA) From: AnchorageM EGCluster@alaska.gov Sent: Thursday, April 14, 2016 4:26 PM To: Bettis, Patricia K (DOA) Subject: Delivery Status -McAfee Email Gateway Anchorage Attachments: deliverystatus.txt; KLU A-1 (PTD 216-063): Permit to Drill Application The following addresses had delivery problems <d.mccraine@furiealaska.com> (Unable to deliver message within specified time.) Bettis, Patricia K (DOA) From: AnchorageMEGCluster@alaska.gov Sent: Thursday, April 14, 2016 11:09 AM To: Bettis, Patricia K (DOA) Subject: Delivery Status -McAfee Email Gateway Anchorage Attachments: deliverystatus.txt; KLU A-2 (PTD 216-055): Permit to Drill Application --- The following addresses had delivery problems --- <d.mccraine@furiealaska.com> (Unable to deliver message within specified time.) Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Thursday, April 14, 2016 4:35 PM To: 'David McCraine' Subject: FW: KLU A-2 (PTD 216-055): Permit to Drill Application If you have received this email, please confirm. I am getting confusing notifications on my end. Thanks, Patricia From: Bettis, Patricia K ( DOA) Sent: Wednesday, April 13, 2016 11:06 AM To: 'David McCraine' <d.mccraine@furiealaska.com> Subject: KLU A-2 (PTD 216-055): Permit to Drill Application Good morning David, 20 AAC 25.055(x)(4) states, "if gas has been discovered, the drilling unit for the pool is a governmental section; not more than one well may be drilled to and completed in the pool on any governmental section; a well may not be drilled or completed closer than 3,000 feet to any well drilling to or capable of producing from the same pool." A spacing exception to the spacing requirements is needed for the KLU A-2 well, as that well is proposed to be drilled within the same government section as KLU #3 (Section 24, Township 10 North, Range 11 West, S.M.). A permit to drill application will not be approved prior to the spacing exception being granted. 20 AAC 25.055(d), the commission will review an application for an exception to the provisions of this section in accordance with 20 AAC 25.540. Please give me a call if you have any questions. In taking a precursory glance at KLU A-1 Permit to Drill Application, if KLU A-1 is closer than 3,000 feet to KLU #3, a spacing exception will be needed to drill that well. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE: This e-mail rY7_-j-sage, 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 atricia.hettis sleeks. ov. Bettis, Patricia K (130A) From: Microsoft Outlook To: David McCraine Sent: Thursday, April 14, 2016 1:04 PM Subject: Relayed: FW: KLU A-2 (PTD 216-055): Permit to Drill Application Delivery to these recipients or groups is complete, but no delivery notification was sent by the destination server: David McCraine (d.mccraine furiealaska.c Subject: FW: KLU A-2 (PTD, 216-055): Permit to Drill Application Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Thursday, April 14, 2016 1:04 PM To: 'David McCraine' Subject: FW: KLU A-2 (PTD 216-055): Permit to Drill Application From: Bettis, Patricia K (DOA) Sent: Wednesday, April 13, 2016 11:06 AM To: 'David McCraine' <d.mccraine@furiealaska.com> Subject: KLU A-2 (PTD 216-055): Permit to Drill Application Good morning David, 20 AAC 25.055(a)(4) states, "if gas has been discovered, the drilling unit for the pool is a governmental section; not more than one well may be drilled to and completed in the pool on any governmental section; a well may not be drilled or completed closer than 3,000 feet to any well drilling to or capable of producing from the same pool." A spacing exception to the spacing requirements is needed for the KLU A-2 well, as that well is proposed to be drilled within the same government section as KLU #3 (Section 24, Township 10 North, Range 11 West, S.M.). A permit to drill application will not be approved prior to the spacing exception being granted. 20 AAC 25.055(d), the commission will review an application for an exception to the provisions of this section in accordance with 20 AAC 25.540. Please give me a call if you have any questions. In taking a precursory glance at KLU A-1 Permit to Drill Application, if KLU A-1 is closer than 3,000 feet to KLU #3, a spacing exception will be needed to drill that well. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7t" 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 p ici ,. t i � s y. Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Wednesday, April 13, 2016 11:06 AM To: 'David McCraine' Subject: KLU A-2 (PTD 216-055): Permit to Drill Application Good morning David, 20 AAC 25.055(x)(4) states, "if gas has been discovered, the drilling unit for the pool is a governmental section; not more than one well may be drilled to and completed in the pool on any governmental section; a well may not be drilled or completed closer than 3,000 feet to any well drilling to or capable of producing from the same pool." A spacing exception to the spacing requirements is needed for the KLU A-2 well, as that well is proposed to be drilled within the same government section as KLU #3 (Section 24, Township 10 North, Range 11 West, S.M.). A permit to drill application will not be approved prior to the spacing exception being granted. 20 AAC 25.055(d), the commission will review an application for an exception to the provisions of this section in accordance with 20 AAC 25.540. Please give me a call if you have any questions. In taking a precursory glance at KLU A-1 Permit to Drill Application, if KLU A-1 is closer than 3,000 feet to KLU #3, a spacing exception will be needed to drill that well. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7t" 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 orri ia. ettis@a ���g_p y. Bettis, Patricia K (DOA) From: David McCraine <d.mccraine@furiealaska.com> Sent: Wednesday, April 13, 2016 4:32 AM To: Bettis, Patricia K (DOA) Subject: Re: KLU A-2 (PTD 216-055): Permit to Drill Application Attachments: KLU#A-2_Condor_SlotB_Ver#10 Wellpath Geo Report.xlsx; KLU#A-1 -Osprey—SlotD Ver#5 Well Path Geo Report.xlsx Attached are the directional. Sorry about the schematic, attached are the survey sheets for the directional for the A-1 and the A-2. They are small in the print. You are correct in the KLU # A-1 approaching the KLU # 1. 1 have not contacted Mr Ganer to get the throw on the fault, but plan to do so. Regards. Dave McCraine Furie Operating Alaska -Lafayette Drilling Engineer 337-981-0270 Office 337-501-6854 Cell From: "Bettis, Patricia K (DOA)" <pAtfjgi .be tis .@alaska.gov> Date: Tuesday, April 12, 2016 at 12:04 PIVI To: Dave McCraine <d.rnccraine@Lufiealaska.�_qrn> Subject: RE: KLU A-2 (PTD 216-055): Permit to Drill Application Good morning David, Thank you for the wellbore schematic; but what is needed is an excel spreadsheet of the proposed wellbore survey that provides from surface to total depth the wellbore's, measured depth, true vertical depth, inclination, azimuth, dog leg rate (degree/100ft), etc. Thank you, Patricia From: David McCraine [mailto:d.mccraine@furiealasl<a.com] Sent: Monday, April 11, 2016 8:12 AM To: Bettis, Patricia K (DOA) <patricia.bettisSalaska.2ov> Subject: Re: KLU A-2 (PTD 216-055): Permit to Drill Application Attached is the Excel file of the schematic. Thanks. Dave McCraine Furie Operating Alaska -Lafayette Drilling Engineer 337-981-0270 Office 337-501-6854 Cell From: "Bettis, Patricia K (DOA)" < atricia.bettis ala ka�> Date: Thursday, April 7, 2016 at 7:53 PM To: Dave McCraine < .mcgrq r Puri( aacc n> Subject: KLU A-2 (PTD 216-055): Permit to Drill Application Good afternoon Dave, It was very nice to meet you this morning. I began the review of the application, today, and there are two items that immediately stand out. The Form 10-401 needs to be resubmitted on the updated Form 10-401 (Revised 11/2015). This form may be found at the following web address: htt : doa alas a.gov forr isforms.htrnl. We will need both a signed original and a co py. The font for the proposed wellbore survey is so small that the OCR software cannot read it. Please forward the proposed wellbore survey in an excel spreadsheet. The excel spreadsheet may be emailed to me. Thank you Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7t" 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 oriioiav�. Bettis, Patricia K (1130A) From: David McCraine<d.mccraine@fuhea|askazom> Sent Monday, April l],2OI5O:I2AM To: Bettis, Patricia K(ODA) Subject Re: KLUA-2(PTD 2I6 -O55): Permit toDrill Application Attachments: KLUA-2 Schematic Slot B.x|sx Attached is the Excel file of the schematic. Dave W1cCr ine FuheOperating Alaska -Lafayette Drilling Engineer 337-981-0270 Office 337-501-6854 Cell From: "Bettis, Patricia K(DOA)" Date: Thursday, April 7, 2016 at 7:53 PM To: Dave Mc[raine Subject: KLU A-2 (PTD 216-055): Permit to Drill Application Good afternoon Dave, It was very nice tomeet you this morning. | began the review ofthe application, today, and there are two items that immediately stand out. The Form 10-402needs toberesubmitted onthe updated Form 10-401(Revised ll/2015).This form may be found at the following web address: VVewill need both asigned original and a copy. The font for the proposed wellbore survey is sosmall that the OCR software cannot read it. Please forward the Patriciaproposed wellbore survey in an excel spreadsheet. The excel spreadsheet may be emailed to me. Thank you Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333West 7=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 and/orprivi|egedinfomnction.Theunautouhzedrevew'useordisdosureofsuch\nfonnauonmayvio|atestat orfederal law. If youereanunintendednedpientofth)semai|'p|easede|eteit,vv)thoutfirstsavingorforwardingb,and'sothsttheADGCCisaware of the mistake in sending it to you, contact Patricia Bettis at (907) 793-1238 or FURIE OPERATINk ALASKA, LLC FUr?IE KITCHEN LIGHTS UNIT NOCondor COOK INLET, ALASKA Operating Alaska LLC 2/1/16 DEM WELL BORE SCHEMATIC SL: X - 294,331.4E; Y - 2,536,125. TUBULARS &SETTING DEPTHS PP MW Frac DIRECTIONAL BHL: X - 2971292.E; Y - 21539,0 API: TBD (PPG) (PPG) (PPG) FORMATION EVALUATION DEPTH (KB) Permit TBD MD TVD DRILL FLOOR RKB TO: 90 HIGH TIDE 115 MEAN LOW LOW WATER 219 SEA FLOOR 15•• # 376 126'P 20" x 7/8" WIT DRIVE PIPE 45.4° Az 46.68° Az to 5475' MD / 4103' TVD 17 1/2" Drop to 42.8°and turn to 36.8° Az by KOP @ 300'; BUR - 3°/100'; 'Az - 45.4 2°/100' DLS by 5882' MD / 4388.5'TVD EOB @ 1906'MD 1724-TVD Hold to 6789'MD/ 5054' TVD 3000 Hold 48.182°inc 8 45.4° Az 46.68° Az 2585 TOC 3639 2879 Sterling ELECTRIC LOGS (OPTIONAL): 2,300 1.,985 13 3/8°' 72# N-80 BTC 8.8 9.4 13.5 ELECTRIC LOGS (OPTIONAL): MDT -have available 4,000 3,118 12 1/4" HOLE 5000 MWD/LWD: 5102 3854 MDT 3800' Sand Triple combo 5475 4103° MDT 4018' Sand 5714 4271 Hold 48.182°inc & 6000 4474 6504 4814 MDT 4669 Sand Beluga 6790 5054 9 5i8" 53.5 # L-80 BTC Mo 9.3 10 q1 KLU A-2 Schematic Slot B (002).x1 45.4° Az 46.68° Az to 5475' MD / 4103' TVD Drop to 42.8°and turn to 36.8° Az by 2°/100' DLS by 5882' MD / 4388.5'TVD Hold to 6789'MD/ 5054' TVD 3000 3200 2585 TOC 3639 2879 Sterling ELECTRIC LOGS (OPTIONAL): MDT -have available 4,000 3,118 5000 5102 3854 MDT 3800' Sand 5475 4103° MDT 4018' Sand 5714 4271 MDT 4172' sand 6000 4474 6504 4814 MDT 4669 Sand Beluga 6790 5054 9 5i8" 53.5 # L-80 BTC Mo 9.3 10 sx 4/12/2016 Bettis, Patricia K (DOA) From: Dave McCraine <d.mccraine@furiealaska.com> Sent: Thursday, April 07, 2016 5:34 PM To: Bettis, Patricia K (DOA) Subject: Re: KLU A-2 (PTD 216-055): Permit to Drill Application I am not sure how I have a copy of the old 401 form. I only downloaded the form from the site that you provided! I will get this to you Monday as I am traveling back on Friday. Sent from my iPhone 337 501- 6854. On Apr 7, 2016, at 5:02 PM, Bettis, Patricia K (DOA) <pa ricia.bettis@a � ,,gc�> wrote: Good afternoon Dave, It was very nice to meet you this morning. I began the review of the application, today, and there are two items that immediately stand out. The Form 10-401 needs to be resubmitted on the updated Form 10-401 (Revised 11/2015). This form may be found at the following web address: http:/Idoa.alaska.gov/oc/formsfforrns.htrri(. We will need both a signed original and a copy. The font for the proposed wellbore survey is so small that the OCR software cannot read it. Please forward the proposed wellbore survey in an excel spreadsheet. The excel spreadsheet may be emailed to me. Thank you Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7t" 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 ,aricia.bttis alaska. ggy. 1 Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Thursday, April 07, 2016 4:53 PM To: 'd.mccraine@furiealaska.com' Subject: KLU A-2 (PTD 216-055): Permit to Drill Application Good afternoon Dave, It was very nice to meet you this morning. I began the review of the application, today, and there are two items that immediately stand out. The Form 10-401 needs to be resubmitted on the updated Form 10-401 (Revised 11/2015). This form may be found at the following web address: http:/jdoa.alasi<a.Eov/oc1forms forms.html. We will need both a signed original and a copy. The font for the proposed wellbore survey is so small that the OCR software cannot read it. Please forward the proposed wellbore survey in an excel spreadsheet. The excel spreadsheet may be emailed to me. Thank you Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7t" 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. Kitchen Lights Unit #A-2 (PTD 216-055) Variance requests; Furie's request to eliminate conductor pipe as required for offshore installations is APPROVED. 20" structural pipe will be driven to 345 ft MD and a diverter installed for drilling the 17 Y2"surface hole section to a depth of 2300 ft. MD. In drilling IGLU #3 (on same platform) no indications of shallow gas were seen in the surface hole section to same depth. Diverter will be utilized for surface hole drilling. Furie's request to use 2 x 12" diverter lines for drilling 17 Y2" OH is APPROVED. The equivalent surface area of the two 12" is essentially the same as a 171/2" hole. (236 sq in vs 240 sq in). Furie's request to eliminate H2S monitoring # oring equipment is DENIED. Standard procedure and best operating practices in Cook Inlet require installation of H2S equipment for offshore drilling installations regardless. Conditions of Approval: 1. Rig inspection required before drilling operations start. ' 2. 10,000 psi 135/8" BOPE to be tested to 3500 psi minimum. Initial witnessed test may will at 5000 psi for commissioning BOPS. ( 5M annular to 2500 psi - min) 3. 13 5/8" surface casing shoe must tested to min FIT/LOT of 13.5 ppg EMW. FIT data to be submitted to AOGCC . 4. Casing tests as follows: 0 13 3/8 casing test pressure = 2500 psi ( 46% of burst) * 9 5/8" casing test pressure = 3500 psi (44% of burst) 5. BOP Casing Rams to be tested as per following: e 9 5/8" rams to 2500 psi 6. Daily Drilling report to be submitted to Commission by email. 7. BOPS equipment will be on 7 day testing cycle (i.e. not to exceed 7 days). 8. Fun*e is required to install H2 S monitoring equipment on board. 9. CBL required over 9 5/8" casing to determine TOC and cement quality. 10. Sundry approval required for completion operations including running tubing, perforations or hydraulic fracture stimulations. • • 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. TRANSMITTAL LETTER CHECKLIST WELL NAME: _ 9 U ki N — 24 PTD: 0 I(0 —OSS 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 LATERAI, 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(fl, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PIS and API number (50-_- fromrecords, 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 we 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 also required for this well: Well Logging 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 2/2015 WELL PERMIT CHECKLIST Field & Pool KITCHEN LIGHTS, UNDEFINED GAS - 470500_ Well Name: KLU A-2 _ _ Program DEV Well bore seg ❑ PTD#: 2160550 Company FURZE OPERATING ALASKA LLC _ _ _ Initial Class/Type DEV / PEND GeoArea _820 Unit 11120 On/Off Shore Off _ Annular Disposal ❑ Administration 1 _Perm it fee attached _ _ _ _ _ _--------------- _ _ - _NA_ - - _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ - _ _ _ - _ _ _ _ _ - - 2 Lease -number appropriate------ __ - Yes- ADL0389197,entire wellbore ._-___-_--__--_______-___-__--_____________________ 3 -Unique well name and number - - _ - - - _ _ - - - _ - _ _ Yes - - _ - _ _ _ KLU A-2 - - - - _ - - _ _ _ _ _ _ _ - - - - - - - - - - - - - - - - _ 4 Well -located in_a_defined -pool - - - - - - - - - - - - - _ _ - - _ _ _No_ _ - _ - _ KITCHEN LIGHTS UNDEFINED GAS - 470500, governed by 20 AAC 25.055._ _ _ _ - - _ _ _ _ _ 15 Well -located proper -distance fromdri_Ilingunit_boundary------------- Yes _--_____-_____ ----------------------------- 16 Well -located proper distance from other wells- - - - - _ _ _ _ - _ - _ _ _ _ _ _ _ _ _ _ _ -No- _ _ _ Proposed KLU A -2 -would be within 3000'-KLU_#3 gas development well. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ i 7 Sufficient acreage_available in-d_rilling unit - - _ - - - - - _ _ -No_ _ _ _ KLU A-2 would be second gas well drilled within_ a government section. _ - _ _ _ - _ _ _ _ _ _ - - - - - - _ 8 -if-deviated, -is_wellbore plat_included _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 9 -Operator only affected party _ _ _ _ _ _ _ _ Yes _ _ _ - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ - 110 Operator has- appropriate bond inforce_____ Yes- -___-_-______________________________ 11 _Permit can be issued without conservation order_ _ - _ _ _ - _ _ - _ - _ _ - - _ _ Yes _ _ - - - - _ - _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Appr Date 12 _Permit_ can be issued without administrative_approval - _ _ - _ _ _ - _ _ _ _ - _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 13 -Canpermitbeapproved before 15-day_wait _- ____-_____Yes_____________-____--_ ------------------ --------------__-- - PKB 6/10/2016 14 Well -located within area and -strata _authorized by Injection Order # (-put_ 10# in_comments)_ (For- _N -A - - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - 15 All wells_within_1/4_mile_area-of review identified (For service only_)_ - _ - _ _ _ _ _NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ - - - - - - - _ _ _ _ _ ---------------------------- --- i------- 16 -Pre-produ-ced injector: duration -of pre --production less than 3 months_ (For_service well only) _ _ -NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ -------------------------------------------------------- 1,17 Nonconven, gas -conforms toAS31.05.030(�.1_.A),{�2.A-D) - - - - --- - _NA_ _ - _ __-_ _ _ _--__----________________ __-__----____________ - 18 Conductor string -provided - _ _ _ _ - _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _Yes - - _ _ _ - _ 20" stu ctu ral pipe- drive n_to 345ft(-conductor pipe waived ) _ _ - _ _ _ Engineering 19 Surface_casing- protects all -known USDWs_____________ __ Yes _-_____Noauifers.. Well is offshore. __-_---_-_____ ____---- -- 20 CMT_v_ol adequate to circulate_ on conductor & surf_csg _ _ _ _ _ _ _ _ _ _ _ _ _ _ ---------- Yes _ - - _ - _ _ 13 5/8" surface casing be -fully cemented. _ _ _ _ _ _------------------------------------ 21 CMT_v_oladequate_totie-in_longstringto-surfcsg---_-__-_--____No__-_---_ TOC is_planned_at3200_ft-MDinthe-95/8"_casing____________________________________ 22 _CMT_willcoverall known -productive horizons -__-__-_ _____________Yes______ ________---___-______ 23 Casing designs adequate for C,-T� B _&_ permafrost_ _ _ - _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ _ BTC calc are provided and meet industry -standards. _ _ _ _ _ _ 24 Adequate_ tankage_ or reserve pit - _ _ _ _ _ _Yes _ _ _ _ mud and_cuttings_to be disposed -per ADEC permit.- _ - - _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - 25 -If-a- re -drill, has_ a 10-403 for abandonment been approved _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _NA_ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ _ _ _ _ - --------------------------------------------- 26 Adequate -wellbore separation _proposed _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ - KLU 3 on same_platform_. -Directional plan provided/ Close crossing -with KLU #3 for 600 ft _ _ - - _ _ - _ _ _ _ _ X27 _If-Ifdoes it_meet regulations_ _ _ _ _ _ _ _ _ _ _ -_ _ _ _ _ _ _ _ -- - _Yes _ _ _ _ _ will use 2 x 12_ inch_diverters for 17.5 " surface hole _ _ _ _ _ _ ------------------------- Appr Date j28 _Drilling fluid_ program schematic_& equip_list_adequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes - - _ _ _ - - Max formation pressure =_3609 psi (9.6_ppg EMW) _ Will drill with_10._1 _ppg mud _ _ _ _ _ _ - - - - - - - _ _ _ _ _ _ _ _ GLS 6/10/2016 129 _BOPEs,_do they meet regulation _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ _ _ _ Randoph_Yost has 13 5/8" 10,000psi_B0PE_ Annular is _5000 -psi_ _ _ _ - - - - - - - - - - - - - - - - - - - - - - - - �30 _B - - -press rating ap�ropriate;_t - - to_(put prig in comments) _ - _ _ _ _Yes - _ _ _ _ _ - - - - - — — - psi Will_test BOPE to 5000 psi in_itially_... 3500 psi_thereafter. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 31 -Choke- manifoId complies w/API_RP-53 (May 84)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ _ _ _ _ _ _ _ _ Yes - - _ _ _ _ _ 10,000 psi -Choke man_ifold._ - _ _ _ _ - _ _ - _ _ _ _ _ _ _ _ - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - 32 Work will occur without_ operation _shutdown_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ - -Yes - _ _ _ - - Sundry -is required for well completion_, perforating. -Batch drilling -surface hole on A-2_and A-1. - _ - _ - _ _ _ - _ _ _ �33 _Is presence of H2S gas probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _No_ - - - _ _ - _ H2S not expected .. Rig will_ have sensors and_a_larms. _ _ _ _ _ _ _ _ _ _ _ _ 34 _Mechanical condition of wells within AOR verified (For service well only_) _ _NA_ - _ _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 35 _Permitcan beissued w/o hydrogen -sulfide measures _-____-______--___No____-_-_ H2S measures re _____________ ___________________________-______________- Geology 36 -Data-presented on potential overpressure zones _ _ _ _ _ _ - _ _ _ _ - _ _ _ -Yes _ _ _ Expected reservoir�ressure is 9.62 ppg EMW* will be drilled using -9.4 to _10.-1 -ppg mud. _ _ _ _ _ _ _ Appr Date 37 _Seismic-analysis_ofshallowgas-zones _________________________ ______NA______ _-______--___-------___________-____---_____ PKB 6/10/2016 38 _Seabed condition survey -(if off -shore) - - - - _ _ _ - _ _ _NA_ _ _ _ _ - - _ Will -be drilled from _Julius R_mono -od. 39 _Contact _name/phone for weekly_progress reports [exploratory only-] _ _ - _ _ _ _ _ _ _ _ _ _NA_ _ _ _ _ _ _ _ Development gas well to be drilled. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ _ Geologic Engineering Public Revised permit due to extending TD to 9789 ft md. GIs Commissioner: Date: Commissioner- Date Commissioner Date • Well History File APPENDIX Inforunation 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. r� FURIE GperatingA[askaLLC KITCHEN LIGHTS UNIT A-2 Exploration Well Cook Inlet, Alaska ADL # 389917 Tract 9 1521.6' FNL & 2807.6' FWL of Section 10, T10N/R11 W, Seward Meridian X= 290840.19', Y= 2529041.92' FINAL WELL REPORT MUDLOGGING DATA Provided by: CAI'�RI� Dmu�c Tmixoux:r Lna. Approved by: Tony Cosenza Compiled by: Josh Dubowski Britten Adams Dave Deatherage Distribution: T.D. Date: 7/4/2016 6d FUR{E Kitchen Lights Unit A-2 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW .................... 1.1 Equipment Summary .......................................... 1.2 Crew.................................................................... 2 WELL DETAILS......................................................... 2.1 Well Summary .................................................... 2.2 Hole Data............................................................ 2.3 Daily Activity Summary ....................................... 3 KLU A-2 GEOLOGICAL DATA .................................. 3.1 KLU A-2 Lithostratigraphy................................... 3.2 KLU A-2 Mudlog Summary ................................ 3.2.1 Surface to the top of the Sterling Formation 3.2.2 Top of the Sterling to the Top of the Beluga 3.2.3 Top of the Beluga to TD .............................. 4 DRILLING DATA ........................................................ 4.1 KLU A-2 Connection Gases ................................ 4.2 KLU A-2 Trip (Wiper) Gases ............................... 4.3 KLU A-2 Sampling Program / Sample Dispatch. 4.4 Survey Data ........................................................ 4.5 Bit Record........................................................... 4.6 Drilling Fluid Record ............................................ 4.7 Dilling Progress Chart ......................................... 5 DAILY REPORTS ...................................................... 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 Data CD CANRIG ............................................................................ 2 ............................................................................ 2 ............................................................................ 2 ............................................................................ 3 ............................................................................ 3 ............................................................................ 4 ............................................................................ 4 ............................................................................ 6 ............................................................................ 6 ............................................................................ 6 ............................................................................ 6 ............................................................................ 7 ............................................................................ 8 ............................................................................ 9 ............................................................................ 9 ............................................................................ 9 ..........................................................................10 ..........................................................................11 ..........................................................................13 ..........................................................................14 ..........................................................................15 ..........................................................................16 1 6d FUR{E Kitchen Lights Unit A-2 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type / Position Total Comments Years Days Technician Days Downtime 8 28 QGM Agitator gas trap 6 16 Howard Lamp 3 Ditch gas Flame ionization 0 Doug Merkert 6 total gas & chromatography. David Deatherage 34 Hook Load / Weight on bit RW Transducer 0 6 Mud Flow In RW Calculation 0 Mud Flow Out RW Flow Paddle 0 Mudlogging unit computer HP Compaq Pentium 4 0 system x2, DML & Ri watch Data collection system RW K -Box data collection & 0 distribution center Pit Volumes, Pit Gain/Loss RW Vega sonic pit sensors 0 Pump Pressure RW Pressure transducer 0 Pump stroke counters RW Proximity switch 0 Rate of penetration RW Calculation/Draw works 0 encoder Topdrive RPM RW RPM sensor 3 hrs Spud before rigged u Top DriveTorque RW Torque sensor 3 hrs Spud before rigged u 1.2 Crew Unit Type Arctic Steel Unit Number ML067 Mudloggers Years ', Days *2 Mudloggers Years Days Technician Days Josh Dubowski 8 28 Jessie Becerra 6 16 Howard Lamp 3 Britten Adams 5 9 Doug Merkert 6 12 Jeff Terrell 9 David Deatherage 34 9 James Foradas 8 6 ;' Years experience as Mudlogger �2 Days at wellsite between spud and total depth of well 2 CANRIG FURIE Kitchen Lights Unit A-2 WELL DETAILS 2.1 Well Summary Operator FURIE Operating Alaska, LLC Well Name KLU A-2 Field Kitchen Light Unit County Kenai Peninsula Borough State Alaska Company Representative Dale Munger, James Pritchard, Clay Carly, Isaiah Del Toro Location: Surface Coordinates NAD 27 X = 298,000 Y = 2,540,009 AK Zone #4 60° 56' 12.144" Latitude, 151° 09'23.013" Longitude Water Depth 107' MLLW Rig Floor Elevation 118' RKB To MLLW Sea Level Classification Gas API # 50-733-20655-00-00 Permit # 216-055 Rig Name/Type Randolph Yost Jackup / Triple Topdrive Spud Date 6/20/2016 Total Depth Date July 4t" 2016 Total Depth 7038' MD / 5210' TVD Days Drilling 8 TD Formation Beluga Primary Target Depth 4018 Sand (Sterling) 5535' MD / 4103' TVD Secondary Target Depth Beluga MDT 4973A 6960' MD / 5156' TVD Completion Status / Date Sidetrack / 1St Cement Plug Set 7/5/16, Kick -Off Plug 7/8/16 LWD-MWD Services Baker Hughes Inteq Directional Drilling Baker Hughes Inteq Drilling Fluids Service Halliburton I Baroid Wireline Logging Service NONE Rig Instrumentation CANRIG Drilling Technology Ltd Rigwatch CANRIG FURIE Kitchen Lights Unit A-2 2.2 Hole Data Additional Comments Drilled to 7038' MD. Decision made to sidetrack well 7-4-2016. 2.3 Daily Activity Summary 6/19/16 150'-380'(230') Drill 150-380 MD. Pull out of hole for new BHA. 6/20/16 380'-722' (342') Rig up Expo wireline and Gyro tools. Slide and drill from 413'— 503'MD. Run in hole with Gyro toll and no survey. Retry Gyro tool and get correct survey. Drill and slide from 503'- 563'MD. Take Gyro survey at 476'MD and good survey. Drill and slide to 593'MD. Take survey with Gyro tool at 506'MD. Continue drilling and sliding to 687'MD. Take another Gyro survey at 600'MD. Drill and slide to 722'MD. 6/21/16 722'-1700' (978') Drilled and slide ahead from 722'-1700' MD. 6/22/16 1700'-2284' (584') Drilled ahead from 1700'-2284' MD. Pull out of hole and lay down tool per Baker Hughes. Pick up 17.50" bit and heavy weight. Run in hole and re -drill to 521' MD. 6/23/16 Continue to re -drill borehole with 17.50" bit from 183'-1515'MD. 6/24/16 Re -drill hole with 17.50" bit from 1457'-2284' MD. Pull out of hole and run down to bottom for a wiper clean. Finish wiper clean and circulate bottoms for clean hole. 6/25/16 Continue to circulate bottom up and prepare to rig -up casing equipment. Pre -job safety meeting for casing operations on rig floor. Run casing from surface to 2262' MD. Rig down casing equipment. Pre -job safety meeting for cement job and test cement lines. Complete cement job and wait for cement to dry. 6/26/16 Rig floor and platform maintenance. Prepare to change over BOP stacks. 6/27/16 4 CANRIG Maximum Depth Mud Shoe Depth Hole TD Dev. Casing/ LOT MD TVD MD TVD Section Formation Weight a (inc) Liner ft ft (ppg) ft(ft)(ppg) 12.25" / 2284' 2007' Surface 9.1 48.5 13 3/8" 2265' 1994' 13.5 17.5" 12.25" 7038' 5210' Beluga 10.0 45.49 Cement PNA PNA - Additional Comments Drilled to 7038' MD. Decision made to sidetrack well 7-4-2016. 2.3 Daily Activity Summary 6/19/16 150'-380'(230') Drill 150-380 MD. Pull out of hole for new BHA. 6/20/16 380'-722' (342') Rig up Expo wireline and Gyro tools. Slide and drill from 413'— 503'MD. Run in hole with Gyro toll and no survey. Retry Gyro tool and get correct survey. Drill and slide from 503'- 563'MD. Take Gyro survey at 476'MD and good survey. Drill and slide to 593'MD. Take survey with Gyro tool at 506'MD. Continue drilling and sliding to 687'MD. Take another Gyro survey at 600'MD. Drill and slide to 722'MD. 6/21/16 722'-1700' (978') Drilled and slide ahead from 722'-1700' MD. 6/22/16 1700'-2284' (584') Drilled ahead from 1700'-2284' MD. Pull out of hole and lay down tool per Baker Hughes. Pick up 17.50" bit and heavy weight. Run in hole and re -drill to 521' MD. 6/23/16 Continue to re -drill borehole with 17.50" bit from 183'-1515'MD. 6/24/16 Re -drill hole with 17.50" bit from 1457'-2284' MD. Pull out of hole and run down to bottom for a wiper clean. Finish wiper clean and circulate bottoms for clean hole. 6/25/16 Continue to circulate bottom up and prepare to rig -up casing equipment. Pre -job safety meeting for casing operations on rig floor. Run casing from surface to 2262' MD. Rig down casing equipment. Pre -job safety meeting for cement job and test cement lines. Complete cement job and wait for cement to dry. 6/26/16 Rig floor and platform maintenance. Prepare to change over BOP stacks. 6/27/16 4 CANRIG FURIE Kitchen Lights Unit A-2 Continue rig maintenance while testing BOP stack 6/28/16 Completed BOP testing with state rep. Prepare BHA to run in hole and maintenance rig. Build and run BHA in the hole to 2143'. Circulate mud through cased hole to get correct mud -weight. Clean out pits for new mud products. 6/29/16 2284'-2304' (20') Perform casing pressure test on 13 3/8" casing; Drill out cement / shoe track (observed thick mud and cement at shakers); Drill new formation from 2284' to 2304'; Perform F.I.T. to 13.5ppg E.M.W.; Build spacer, prepare to displace well, Displace well with 10.Oppg WBM; Build volume and treat new mud for upcoming hole section while offloading old spud mud to boat. 6/30/16 2304'-3357' (1153') Circulate and condition mud; Drill 2304'-3457'. 7/1/16 3457'-5031' (1574') Drill 3457'-5031'. 7/2/16 5031'-5702' (671') Drill 5031'-5052'; Circulate clean; SPR's; Dry job; Pull to shoe; Clean Ditch and shakers; RIH; Safety ream 1 stand to 5052'; Drill 5052'-5702'. 7/3/16 5702'-7004' (2002') Drill 5702'-7004' 7/4/16 7004'-7038' (34') Dri117002'-7938'; Circulate; Laydown single; Circulate; Dry job; POOH to 5997', Tight; Break circulation; Wash to 6091'; Back ream 5997'-4485; Dry job; POOH; Download LWD; Stand back BHA; Make up test plug; Run test plug; test BOPE. 7/5/16 Finish testing BOPE; Pull test plug; Pick up 1497' of 3'/2" tubing; RIH drill pipe to 7038'; Circulate; Cementing safety meeting; Circulate; Pump cement; Pull 8 stands; Circulate. 7/6/16 Circulate; Pull to shoe; W.O.C.; Circulate; RIH to 6150'; Circulate; RIH to 6325' tag cement; Circulate; Pump/set cement plug; Pull to 4890'; Circulate; Dry job; Pull to shoe; W.O.C. 7/7/16 W.O.C.; Circulate; RIH to 4892'; Circulate; Pump/set cement plug; Pull to 4000'; Circulate; POOH; Laydown directional BHA that was stood back in derrick; RIH to 1196'; W.O.C.; RIH to 4057'; Circulate; Rih slow to 4341'. 7/8/16 RIH to 4892'; Tag cement plug; Pull to 3255'; Circulate; Pump/set cement Kick -Off plug; POOH; Make up, RIH test plug; Test BOPE; Pull. Laydown test plug. 5 CANRIG FURIE Kitchen Lights Unit A-2 3 KLU A-2 GEOLOGICAL DATA 3.1 KLU A-2 Lithostratigraphy KLU #2A FORMATION Prognosed Geologist Picks MD ft TVD ft SSTVD ft MD ft TVD ft SSTVD ft Sterling 3639' 2879' -2761 3858' 3023' -2905' Beluga 6959' 5054' -4936 6960' 5156' -5038' TD 9805' 7203' -7085' 7038' 5210' -5092' 3.2 KLU A-2 Mudlog Summary 3.2.1 Surface to the top of the Sterling Formation 391' to 3,858' MD (391' to 3,023' TVD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 957 0.7 144 39 0 3.4 This Section was comprised mainly of massive unconsolidated sand, conglomeratic sand and occasionally interbedded with tuffaceous claystone. No notable hydrocarbon shows were observed through this interval. The sands were typically medium gray to dark medium gray with occasional blue, brown or olive hues. Dominated by clear, translucent and opaque quartz with dark gray to black lithics abundant as well. Unconsolidated, upper coarse to lower medium to lower fine grained. Grains ranging up to 14mm were not uncommon in the top section of the interval, decreasing in size near the base. Sorting ranged from poorly sorted in the upper hole section to moderate down through to the top of the Sterling. Sub angular to angular to sub rounded and occasionally well rounded. Overall, moderate to poor sphericity with scattered good sphericity. Micas, pyrite, greenstone, carbonaceous material, volcanic ash and siltstone were all present but not abundant. The tuffaceous claystones are typically light to dark medium gray with brown, olive and occasionally reddish hues. Lumpy to mushy consistency with a pulverulent to malleable to earthy fracture. Typically pulverized to nodular to rounded cuttings habit. Waxy to earthy to dull luster and silty to smooth to sometimes gritty texture. Trace interbedded with thin sands. No notable gas peaks. 6 CANRIG FURIE Kitchen Lights Unit A-2 3.2.2 Top of the Sterling to the Top of the Beluga 3,858' to 6,960' MD (3,023' to 5,156' TVD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 333 3 92 1537 1 0 64 This section was comprised of tuffaceous sandstone, sand, tuffaceous siltstone and tuffaceous claystone with occasional coal beds. The sands and tuffaceous sands were typically medium gray to yellowish gray to off white and ranged from unconsolidated to soft and crumbly to trace firm. Predominantly fine to medium grained but ranged from granule to very fine. Typically sub rounded to angular with occasional well rounded grains and moderate to poor sorting. Typically grain supported with pale white ashy matrix. Dominantly quartz with feldspars and dark lithics common. Other accessory minerals include: Rhyolite, micas, pyrite, carbonaceous sediment/shale and dark mafics. The tuffaceous siltstones and claystone in this section are typically light medium gray to medium gray with pale yellow, brown or blue hues. Occasional dark brown siltstone clasts lacking tuffaceous material. Typically soft to crumbly to firm crumbly and occasionally pulverulent. Smooth to very fine abrasive texture and very to moderately expansive. occasional carbonaceous banding throughout, occasionally deformed to trace sediment in matrix. Non calcareous. The coals in this section are typically black to very dark brown. Firm, crumbly to dominantly crunchy. Typically have a smooth texture with a sub hackley fracture. Commonly matte to slightly shiny luster to occasionally micro sparkly. Occasional trace out gassing. Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 5857 526 107811 6385 457 91418 6602 1477 356294 952 6618 1537 347422 406 6651 1 731 164795 6685 448 86272 6812 666 135245 6835 993 198860 78 6877 1089 219413 160 7 CANRIG FURIE Kitchen Lights Unit A-2 3.2.3 Top of the Beluga to TD 6,960' to 7,038' MD 5,156' to 5,210' TVD Drill Rate ft/hr Total Gas units TG C1 C2 Maximum Minimum Average Maximum Minimum Average 136 3.7 66 148 9 60 This small section is comprised of tuffaceous claystone The tuffaceous claystone is dominantly light to medium gray with a bluish hue and scattered brownish hues. Overall has a soft, pliant to crumbly tenacity. Has a smooth to abrasive texture that grades to a tuffaceous siltstone and noncalcareous. Occasional coal to lignitic organic material included and rare disseminated pyrite. The bluish hued clasts are moderately expansive while other hues are only slightly. Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 6962 136 26311 8 CANRIG FURIE Kitchen Lights Unit A-2 4 DRILLING DATA 4.1 KLU A-2 Connection Gases 1unit = 0.05% Methane Equivalent = 200ppm Methane Depth (feet) Gas over BGG (units) 6657' 422 4.2 KLU A-2 Trip (Wiper) Gases 50 units = 1% Methane Eauivalent Depth (feet) Trip Type Trip to (feet) Gas (units) 5053 Wiper 2284 5 7038 TD Trip Surface 108 100 {O 80 70 60 rZ 50 O i=+ i} t 40 O 30 20 10 Connection FloWback 500 400 300 r� O 200 100 0 0 ,`,I. -„f.-,, 46 r+C r 4544 r.0 -w47 a, 4r a4 t^. as �5F hi 1�r ��`SW�7 ISr �r Lm -m 4s 7,, 44 m.”, f•�I�-S'•i SD G O>C}O6 w I-. I-- C6 IG 4547 llli r s 4', r r O 0 OOr 07 h-I�sD 064547^f �7 �*'7C+I Farr QG'c, mw 1— 1— 4 tP 4: LCs *.'h *'hA e sN+:f 47 N ISN �C r m t3 mmI-. W mpprF•i f+�P5 Lys +,61�6�ds O r NM O47 k0 fO CA?. dtO rC+�{h•.T%0 E6 Imo. CD ds IG 0+.1041 C�.I hI NI C*If*.1 RIMC"'dM ['S "`IMS"9MC^A r3 "�i "'f ^trtrt .. �S �'i*'F'T!f 4747474745454'A47454745ROL6�4iSbi6{6tG{6tC1-- DEPTH (ft) 9 CANRIG FURIE Kitchen Lights Unit A-2 4.3 KLU A-2 Sampling Program / Sample Dispatch Set Type / Purpose Frequency Interval Dispatched to Washed, screened & 30'210'-7038' A dried Reference Samples Ricky Bell Set owner: Furie Furie Spartan 151 rig 52300 Nikiski Beach Rd. Nikiski, Alaska 99635 Washed, screened & 30 B dried Reference Samples 210`-7038' Set owner: Furie Sample frequency was locally altered according to drill rate constraints and zones of interest. 10 CANRIG �- FURIE Kitchen Lights Unit A-2 4.4 Survey Data 11 cANRIG KLU A-2 Measured Depth (ft) Inclination (0) Azimuth (0) TVD (ft) Vertical Section (ft) North(+) South(-) East(+) West(-) Dogleg ('/100ft) 107 0 0 107 0 0 0 0 200 0.5 357.67 200 0.29 0.41 -0.02 0.54 300 3.94 3.5 299.91 3.29 4.27 0.18 3.44 366.17 9.49 28.15 365.61 10.38 11.36 2.89 9.27 418 6.67 29.73 416.92 17.47 17.74 6.4 5.46 476 5.87 32.3 474.57 23.68 23.17 9.65 1.46 506 5.62 32.65 504.42 26.65 25.71 11.27 0.84 600 5.41 39.68 597.99 35.61 32.99 16.58 0.75 664 6.07 40.93 661.67 42.01 37.87 20.72 1.05 696 6.37 43.07 693.48 45.48 40.44 23.04 1.18 727 6.59 45.4 724.28 48.97 42.95 25.48 1.11 758 7.57 47.49 755.04 52.78 45.58 28.26 3.27 790 8.75 47.54 786.72 57.3 48.65 31.61 3.69 822.54 9.86 47.49 818.83 62.54 52.2 35.49 3.41 857.3 11.28 46.8 853 68.89 56.54 40.16 4.1 889.56 12.58 46.56 884.56 75.54 61.11 45.01 4.03 916.38 13.67 46.8 910.68 81.61 65.29 49.44 4.07 953.33 14.73 47.95 946.5 90.63 71.43 56.11 2.97 984.99 15.7 48.33 977.05 98.89 76.97 62.3 3.08 1010.11 15.96 48.81 1001.22 105.7 81.51 67.44 1.16 1048.42 16.53 49.12 1038 116.33 88.54 75.52 1.5 1079.97 18.02 49.27 1068.13 125.63 94.66 82.61 4.72 1104.45 19.07 49.11 1091.33 133.35 99.75 88.51 4.29 1142.76 19.4 47.94 1127.51 145.89 108.11 97.96 1.32 1173.87 20.04 46.83 1156.79 156.34 115.22 105.69 2.38 1198.78 20.81 45.72 1180.14 165.01 121.23 111.97 3.46 1294.69 24.93 46.66 1268.49 202.17 147.01 138.88 4.31 1389.14 27.26 47.5 1353.3 243.55 175.29 169.31 2.5 1483.89 29.83 47.07 1436.53 288.63 206 202.56 2.72 1578.3 35.1 46.3 1516.16 339.12 240.77 239.41 5.6 1672.81 39.53 46.63 1591.3 396.22 280.22 280.94 4.69 1766.17 42.4 46.93 1661.79 457.2 322.13 325.54 3.08 1861.24 48.11 45.93 1728.69 524.5 368.67 374.42 6.05 1956.42 49.29 46.15 1791.51 595.82 418.3 425.89 1.25 2051.95 48.43 46.21 1854.36 667.57 468.11 477.8 0.9 2147.98 49.36 46.68 1917.49 739.71 517.97 530.24 1.04 2228.27 48.51 46.93 1970.23 800.03 559.41 574.37 1.08 2327.49 47.98 47.28 2036.31 873.75 609.79 628.59 0.6 2426.02 50.95 46.87 2100.34 948.33 660.78 683.42 3.03 2521.91 51.36 47.15 2160.48 1022.73 711.71 738.05 0.48 2616.39 51.2 47.35 2219.58 1096.13 761.75 792.18 0.24 11 cANRIG �- FURIE Kitchen Lights Unit A-2 KLU A-2 Measured Inclination Depth (ft) (0) Azimuth (0) TVD (ft) Vertical North(+) Section (ft) South(-) East(+) West(-) Dogleg ('/100ft) 2616.39 51.2 47.35 2219.58 1096.13 761.75 792.18 0.24 3280.42 49.54 44.62 2646.95 1602.99 1114.18 1158.27 0.74 3375.44 49.77 45.13 2708.47 1675.32 1165.5 1209.37 0.48 3470.55 48.98 44.27 2770.4 1747.42 1216.81 1260.15 1.08 3565.92 49.24 44.12 2832.83 1819.46 1268.5 1310.41 0.3 3661.06 49.44 44.61 2894.82 1891.57 1320.09 1360.87 0.44 3754.9 49.72 45.06 2955.66 1962.93 1370.75 1411.24 0.47 3849.11 48.46 43.07 3017.36 2034.07 1421.9 1460.76 2.08 3944.45 48.2 43.11 3080.74 2105.27 1473.91 1509.41 0.27 4039.09 48.33 43.37 3143.74 2175.88 1525.35 1557.79 0.25 4133.88 48.55 43.15 3206.63 2246.79 1577.01 1606.4 0.29 4229.45 48.67 43.78 3269.82 2318.46 1629.05 1655.72 0.51 4323.66 48.8 43.93 3331.95 2389.24 1680.11 1704.79 0.18 4417.48 48.96 44.08 3393.65 2459.87 1730.94 1753.88 0.21 4512.14 49.15 44.39 3455.69 2531.32 1782.18 1803.77 0.32 4606.88 49.49 44.99 3517.44 2603.08 1833.25 1854.29 0.6 4700.91 49.94 44.89 3578.24 2674.72 1884.03 1904.96 0.49 4795.82 50.34 45.54 3639.07 2747.45 1935.35 1956.67 0.67 4889.64 50.25 44.59 3699.01 2819.53 1986.33 2007.77 0.78 4984.83 49.72 43.81 3760.21 2892.37 2038.59 2058.59 0.84 5078.94 48.25 43 3821.97 2963.36 2090.17 2107.39 1.69 5173.87 48.33 42.88 3885.14 3034.22 2142.05 2155.67 0.13 5267.38 47.32 42.84 3947.92 3103.51 2192.85 2202.8 1.08 5361.91 47.04 42.22 4012.17 3172.84 2243.95 2249.67 0.56 5456.6 47.47 42.49 4076.44 3242.38 2295.33 2296.52 0.5 5551.05 46.84 41.24 4140.67 3311.63 2346.9 2342.74 1.18 5645.59 46.04 39.75 4205.82 3380.11 2398.99 2387.23 1.42 5740.02 45.68 39.58 4271.58 3447.82 2451.16 2430.49 0.4 5833.48 45.76 40.07 4336.83 3514.68 2502.54 2473.34 0.38 5929.9 44.81 38.25 4404.67 3583.11 2555.66 2516.61 1.66 6025.23 42.36 36.1 4473.72 3648.59 2608 2556.34 3 6118.3 41.69 36.16 4542.86 3710.57 2658.32 2593.08 0.72 6213.11 42.14 36.39 4613.41 3773.6 2709.38 2630.55 0.5 6307.69 42.29 36.59 4683.46 3836.85 2760.48 2668.34 0.21 6402.12 42.57 36.94 4753.16 3900.3 2811.51 2706.47 0.39 6496.51 42.93 36.95 4822.47 3964.13 2862.72 2744.98 0.38 6591.52 43.32 37.39 4891.82 4028.85 2914.47 2784.23 0.52 6687.84 43.72 37.86 4961.66 4094.98 2967.01 2824.72 0.53 6781.42 44.26 38.22 5028.99 4159.82 3018.19 2864.77 0.64 6875.66 44.84 38.22 5096.15 4225.79 3070.13 2905.67 0.62 6971.03 45.49 38.7 5163.39 4302.86 3123.09 2947.74 0.77 PROJECTED TD 7038 45.49 38.7 5210.34 4351.97 3160.36 2977.6 0 12 cANRIG 6e-, FURIE Kitchen Lights Unit A-2 4.5 Bit Record 13 CA►NRIG Avg Avg Type / Jets / Total Bit PP Bit Size Make In Out ROP WOB RPM Bit Grading Serial# TFA Footage Hrs (psi) ft/hr kibs Mill Tooth 1x14, NB 1 12.25" HTC GT -C-1 3x16 291 90' 90 1.0 147.5 322 Not Rated 5207676 0.7394 Mill Tooth 1x14, 1RR1 12.25" HTC GT -C-1 3x16 381 2284 1903 25.8 156.2 7.9 8.2 1540 2 -1 -WT -A -E -In -NO -TD 5207676 0.7394 PDC NB 2 12.25" HTC TD605SX 7x16 2284 7038' 4754 89.0 103.5 7.3 73.1 1964 1 -1 -CT -T -X -In -BT -TD 1.3744 7040648 13 CA►NRIG 6e-, FURIE Kitchen Lights Unit A-2 4.6 Drilling Fluid Record Contractor: Halliburton Date Depth (ft) MW (ppg) VIS PV YP Gels FL FC I Sols N O/W Ratio Sd (%) pH Cl (mg/1) Ca (mg/1) MBT FLT (F) SPUD MUD 6/19/16 381 8.8 103 34 37 14/19/44 5.8 2 20.4 0/96.3 - 9.4 1750 80 20 6/20/16 751 8.9 95 27 34 21/46/62 5.8 1 4.1 0/95.6 0.75 9.1 2500 200 15 6/21/16 1725 9.0 94 29 35 24/55/70 6.1 2 4.8 0/94.9 0.50 9.3 2600 320 15 84 6/22/16 2284 9.0 90 29 32 15/45/58 6.4 2 6.0 0/93.7 0.75 9.0 2000 80 15 102 6/23/16 1478 9.25 84 30 30 14/40/55 6.2 2 6.5 0/93.2 0.50 9.2 1900 80 15 90 6/24/16 2282 1 9.45 106 35 37 18/55/73 1 6.2 2 7.7 0/92.0 0.50 10 1700 80 17.5 90 6/25/16 2282 9.40 80 30 26 12/36/50 6.4 2 7.7 0/92.0 0.50 9.0 1600 40 15 6/26/16 2282 9.4 80 30 26 12/36/50 6.4 2 7.7 0/92.0 0.50 9.0 1600 40 KCI Polmer/GEM 6/29/16 2304 10.15 55 15 18 7/9/11 5.0 1 7.7 0/91.5 0.10 10.9 11700 200 72 6/30/16 3445 10.0 42 12 21 9/10/13 6.4 1 7.0 0/92.0 0.50 10.0 11400 200 7/1/16 4966 10.05 46 13 24 7/9/13 5.9 1 7.6 0/91.5 0.30 0.8 11000 400 4.0 102 7/2/16 5605 10.0 46 14 20 6/8/11 5.6 1 8.0 0/91.0 0.20 10.1 11200 280 4.8 105 7/3/16 6930 10.08 50 20 23 6/9/12 5.8 1 9.1 0/89.9 0.05 9.7 11500 300 7.5 115 7/4/16 7038 10.15 46 16 18 5/7/10 5.8 1 9.2 0/89.8 0.05 10.2 11500 220 7.5 7/5/16 7038 10.4 52 1 19 25 8/18/0 7.0 1 10.1 0/88.9 0.05 12.0 12000 580 8.0 7/6/16 4890 10.15 45 14 17 5/10/13 6.2 1 8.8 0/90.3 0.05 11.4 11700 680 8.0 7/7/16 4062 10.05 47 1 13 16 5/6/7 6.2 1 8.6 0/90.5 0.01 10.9 10500 1280 7.5 Abbreviations MW = Mud Weight Gels = Gel Strength Sd = Sand content ECD = Effective Circulating Density FL = Filtrate/Fluid Loss (ml/30min) Cl = Chlorides VIS = Funnel Viscosity (sec/qt) FC = Filter Cake (1/32inch) Ca = Hardness Calcium PV = Plastic Viscosity Sols = Solids O/W = Oil to Water ratio YP = Yield Point FLT = Flowline Temperature MBT = Methylene Blue Test (ppb equiv) 14 CA►NRIG 4.7 Dilling Progress Chart LVVV 1 x}44 1744 1G44 1544 1404 1300 1200 1100 r 0 1000 a 000 a 800 700 600 600 400 300 200 100 FURZE ,.4•�.r:iC Kitchen Lights Unit A-2 Drilling Progress Curve V 1000 2000 3000 4000 QY 5000 4s G444 7000 0000 9000 10000 M m Nl t 3 IT' CASING POINT 2284' d M to to M � to to d ea co 1MPER 2a- 505T TO SH4:fE to to 1� 10 to to co to to to to to fl _ 'o % M1 r r w 4r.1 N C_ 511 TD -row rop CN 511 ! * 4 *1 m M R ham- hti fx fx ham- fw to to to N to to to to to to M to d Gate N d d d d d d 1p M d d d V 1000 2000 3000 4000 QY 5000 4s G444 7000 0000 9000 10000 15 CANRIG to to ca to to to ea co to to to 1� 10 to to co to to to to to fl _ 'o % r r 4r.1 N C_ 511 9N � CN 511 ! * 4 *1 m M R ham- hti fx fx ham- fw to to to to to to to to to to to to to Gate 15 CANRIG FURIE Kitchen Lights Unit A-2 DAILY REPORTS Fude DAILY WELLSITE REPORT C46NRIG KLM -2 REPORT FOR GATE 61 W2D DEPTH SM PRESENT OPERATION POOH TIME 11:311 pm YESTERDAY iBo 24 HOUR FOOTAGE 2DO CASING INFORMATION 20 DEPTH INCLINATION ,AZIMUTH VERTICAL DEPTH SURVEY DATA 3 T IN FORMATION INTERVAL CONDITION REASON NO. SIZE TYPE &'N JETS IN OUT FOOTAGE HOURS TfDC PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG PATE OF PENETRATION C FT'HR SURFACETOROUE C G AMPS WEIGHT ON OFT i KLBS ROTARY RPM i RPM PUMP PRESSURE PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Geis CL - FO SOL SD OIL MOL PH Ca+ GCI MIND SUMMARY INTERVAL To TOOLS G S SUMMARY (unhzl HIGH LOW AVERAGE DITCH GAS & TRI P GAS GUTTING GAS Civ WIPER GAS CHROMATOGRAPHY (ppml SURVEY METHANE (C-1) & I CONNECTION GAS HIGH ETHANE (C,2:) a AVG PROPANE (D-3) ( CURRENT BUTANE (C -d) f CURRENT HAGKGROUNI VAVG PENTANE {O-5 i HYDROCARBON SHOVES INTERVAL LITHOLOGY"REMARKS GAS DESCRIPTION LITHCLOGY Sard, Bk & Lithics PRESENT LITHOLOGY OAILYACTIIFFFY SUMMARY Ddled (+mm 150-sw MD. Now POOH Www BHA_ CANRIG PEFRSONNEL ON BOARD 4 DAILY COST EIML427'65, RVI! -$720 FIE PORT BY BHtten Adams 16 CANRIG FURZE Kitchen Lights Unit A-2 Fu62 Alaska LLC [ AILY WELL�SITE ]REPORT CANRIG KLu A-2 REPORT FOR Dale Munger DATE Jun 2a. 2716 DEPTH 722 PRESENT OPERATION Sliding Ahead 'TIME 22:41:14 YESTERDAY 3a2 24 HOUR FOOTAGE 34a CASING INFORMATION 20' DEPTH INCLINATION AZIMUTH VEPTIOAL DEPTH SURVEY DATA BIT INFOPMATION INTERVAL GONDITICN PEASO% NO. SIZE TYPE S(N JETS IN OUT FOOTAGE HOURS TIEVC PULLED DRILLING PARAMETEPS HIGH LOW AVERAGE CURPENTAVG PATE OF PENETRATION 22a9.6 9 6% &1 0 454 16&3 97.0424D =T. -HR SUPFACETOROUE 6+559 P 521 0 0 5313 a AMDE WEIGHT ON ®IT a 9 722 0 @ 722 1i.D KI -63 ROTARY PPM 36 Ind 521 0 0 722 5.2 P}I19 PUMP PPESSUPE 16M 39a 35 a sm 1356.3 138D.2302a P_I DRILLING MUD REPOPT DEPTH MW VIS PV YP FL Cels CL - FC SOL SD OIL MEIL pH Ga3 COI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (unitsl HIGH LCW AVERAGE DITCH GAS a 0 .555 D 595 D.5 TRI P Gly CUTTING GS a & 722 D 722 0.0 WIPED GAS CHPOMATOGPAPHY On) SURVEY METHANE (O-1) D 0 722 D 722 D.D CONNECTION GAS HIGH ETHANE (G-2) D 722 D 722 11.0 AVG PROPANE (G-3) D 722 D 722 0.0 CURRENT BUTANE (G-4) a 722 D 19 722. 0.0 OUPRENT EIACKGROUNDfAVG PENTANE(C-5) D 722 D 9 722 0.0 HYD} ICCA.RBON SHCWS INTEPrVAL LITHOLOGYMEMARKS GAS DESCPIPTION UTHOLOGY Sand, 5% Bieck Uthics PPESENT UTHOLOGY 95% Sand, 5% Bleck l ithics DAILY Pig up Expo wireline and Gyro sada, Side said drill FrM 413'— 503 -MD. Run in We with Gyro tall and nv survey. ACTIVITY Petr.. GifficiDal and get caned survey. Drill and side ham 5W'- Wa'MD_Teke rlrrasurvey at 476MID and good SUMMARY sieve... llsnd siaiet® 593°MD_Teke sureeywilh G..ratacdat 5a6�'MD. C-xFknue Take amid Gym survey Ed 6D[ 1AD. Ddll Eard side 1n 722'MD. driling and sI&V 1D E�7'MD. CANR1IS PERSONNEL ON BOARD 4 DAILY COST DNI L-$2765, Rigwatch - $720 Kmllpk . 10 11 1.. � r 17 cANRIG FURIE Kitchen Lights Unit A-2 Furie Oper-.ding Alaska, LL DAILY WELLSITE REPORT CANRIG KLU A-2 REPORT FOR Dale Munger DATE Jun 21. 2016 DEPTH 17aa PRESENT OPERATION Slid'mg sbnc TIME 2T0D YESTERDAY 722 24 HOUR FOOTAGE 973 CASING INFORMATION 20' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT IN FORMATION INTERVAL CONDITION RrASO`a NO. SIZE TYPE S'1J METS IN CUT FOOTAGE HOURS Tf3'C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVC PATE OF PENETRATION 4194.4 19 762 a_7 1631 15a-6 ®7.79763 FTMP SURFACETOROUE 7597 9 1632 -D 1 D8 0 E2.a3a22 AMPS WEIGHT ON Br 36 Q 1512 ,p ! 1155 811 15.18519 KLBS ROTARY RPM 49 P@ 1632 19 1132 a -19.113678 RPM PUMP PRESSURE 1962 1@ 15241 37 752 14d%5 1575.79954 PSI DRiILLNGMiUD REPORT DEPTH MW VIS PY YP RL GPIs CL -- FC SOL SD OIL MHL pH Ca3 CCI MIND SUMMARY INTERVAL TO TOOLS GAS SUMMARY (uT&I HIGH LOW AVERAGE DITCH CAS 1 0 1109 D 753 19.5 TEMP GikS CUTTING GAS D 0 1700 D 170G 19.19 WIPER GAS CHROMATOGRAPHY (p ") SURVEY METHANE (C-1) 0 0 17DD D 9 17DO 19.0 CONNECTIGJ4 CTAS HIGH ETHANE (C-2) 0 0 17019 0 >3 170D 0.0 AVG PROPANE (C-3) 0 9 170D D 9 1703 0.0 CURRENT BUTANE (C,4) 0 13 1700 D Gni- 1700 -D.19 CURRENT BACKGROUNDrAVG a -a PENTA'ME (C-5) D La 1700 D & 170D U.'U HY01I.O RI3ON SHCWS INTERVAL LITHOLOGYMEWMKSS GAS DESCRIPTION LITHOLOGY 9S% Samd, .5% Tuffaceous Clayson PRESENT LITHOLDGY w% Sand, 40`Yo- Tuffacecus Clay€1Dne DAILY ACTIVITY SUMMARY Ddled and side ahead fram722'-17W h4_ CAN RIG PERSONNEL ON BOARD 4 DAILY DOST DML- 65, Rigwatch-3720 REPORT BY Britten Adams 18 cANRIG FURZE Kitchen Lights Unit A-2 Furie Cpm abng Asks, LLC D,AILYWELLSITE REPORT CANRIG '' ILLU A-2 REPORT FOR Dale Munger DATE Jun 22, 2Dl6 DEPTH 2284 PRESENT OPERATION Pe -drilling with17.50'. TIME 14:17:17 YESTERDAY 17U0 24 HOUR FOOTAGE 564 CASING INFORMATION 2o, DEPTH INCLINATION AZINUTH VERTICAL DEPTH SURVEY DATA BIT INIFORMATION INTERVAL CONDITION REASO% NO. SIZE TYPE &N JETS IN CUT FOOTAGE HOURS T13'C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE GURRENTAVG PATE OF PENETRATION 956.7 9 1741 2.4 217.5 154 6 8 IEW1 F7.1 PP. SURFAGETOROUE 6917 19 21114 11 I 17D7 40058 7693.543215 AMPS WEIGHT ON ®fI s5 Q W29 0 1 9f 11.2 7.46552 KLES ROTARY RPM 51 19 2414 a 17D7 22.9 49.64966 RPO% PUMP PRESSURE 2W 19 2274 1263 2165 1829.1 84RM PSI DRILLING MUD REPORT DEPTH MW VIS PY YP FL Gels CIL FC SOL SLI OIL NEL PH Cao GCI MWID SUMMARY INTERVAL TO TOOLS GAS SUMMARY (uni sl HUGH LOW AVERAGE DITCH GAS 1 0 2252 [1 ( 2243 a15 TRIP GAS CUTTING GAS a 0 2284 a 2284 ax] WIPER GAS CHROMATOGRAPHY Opm; SURVEY METHANE (C-1) 119 iso 2252 62 2282 53 CONNEGTION GAS HIGH ETHANE (G2) ❑ 0 2?,M (1 2284 rL4 AVG PROPANE (C-3) 0 (D 2284 [1 2284 d-4 CURRENT BUTANE (C,4) 4 0 2284 4 2284 S1-0 CURRENTBAGKGROUNDfAVG PENTANE(C-5) d (D 2284 (1 2284 4-0 HYI]EI.00AREON SHOWS INTERNAL UTHOLOGYIPEMAPKS GAS DESCRIPTION LITHOLOGY 140-% Sand PRESENT LITHOLOGY DAILY AGTNCfY Dded shoed irm 17OT-2294' MD. Pull W d h2le and lay down fool per Elder Hughn. up 17 iQ' hit SUMMARY and heavy w*17L Ron in hois and regi Il iD 521' MIJ_ ANF11G PERSONNEL ON BOARD 4 DAILY DOST DML- $2765, Rigwatch- $,720 TIMI: ft,, � r h - . n 19 CANRIG FURZE Kitchen Lights Unit A-2 Furie Cperabng Atka, LLC DAILY ELL ITE REPORT ILLU fr2 CAN�IG REPORT FOR Dale Munger [SATE Jun 22.2015 DEPTH 22LA PRESENT OPERATION Pe -Drilling el�eetl. TIME 23 C10 oo YESTERDAY 2284 2A HOUR FOOTAGE a CASING INFORMATION 20' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA SIT IN FORMATION INTERVAL CONDITION REASO% NO. SIZE TYPE &N JETS IN OUT FOOTAGE HOURS T13C PULLED DRILLING PARAMETERS HIGH ILOW AVERAGE CURRENT AVG PATE OF PENETRATION ( FT°HR SURFACETOROUE i AMPS WEIGHT ON ®fT ( KLEE• ROTAGY RPM ( RPM PUMP PRESSURE PSI DRILLING MUD REPORT DEPTH vW VIS PV YP FL Gels CL - SOL SD OIL MEIL pH Ca+ CGI MND SUMMARY INTERVAL TO TOOLS OAS SUMMARY (unilsl HIGH LCW AVERAGE DITCH GAS TRIP GAS CUTTING GS Q WIPERGAS CHROMATOGRAPHY +pprril SURVEY METHANE (C-1) CONNECTION GAS HIGH ETHANE (G2) AVG PROPANE () (y CURRENT 3UTANE (G-4) ( CURRENT RAGKGPIDUNDfAVC PENTANE (G-) i HYOPGCAR13ON SHCWS INTERVAL LITHOLOGY;FIEMAPKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILYACTIVITY SUMMARY Pe- & ling with 17507' U1 f om 55T- 1478 MI}_ CANRIG PERSONNEL ON BOARD 4 DAILY COST DNL- 2765, Rigw -720 REPORT BY BHttGn Adams 20 cANRIG FURZE Kitchen Lights Unit A-2 Furie C�nraabng Alaska, LLC L LILY WELL ITE REPORT CANRIG 14LU fr2 REPORT FOR Dale Munger SATE Jun 22° 2[715 DEPTH 2284 PRESENT OPEPATION Cir€ublinp Boman -up a] 229°4' MD. TIME 23:0]:67 YESTERDAY 2254 24 HOUR FOOTAGE a {CASING INcOAMATICA 24' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 31T IN FORMATION INTERVAL CONDITION REASO`, NO. SIZE TYPE &N JETS IN OUT FOOTAGE HOURS T13C PULLED DRILLING PARAMETERS HIGH ILOW AVERAGE CURRENT AVG PATE OF PENETRATION ( I FT°°HR SURFACETOROUE AMPS WEIGHT ON Sff ( KLEE• ROTARY RPM ( RPM PUMP PRESSURE PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL - FC SOL SO OIL MBL pH Ca+ CGI www SUMMARY INTERVAL TO TOOLS OAS SUMMARY (uT&I HIGH LOW AVERAGE DITCH GS TRIP GAS CUTTING GAS Q WIPES GIS CHROMATOGRAPHY pprnl SURVEY METHANE (G-1) CONNECCTIOH QkS HIGH ETHANE (G-2) AVG PROPANE( ) (yam CUREENT BUTANE (G-4) 4 0 GURRENf UAGKGPIDUNIVAVC PENTANE(C-5) l$ HYI]EOCARIBON SHGWS INTERVAL LITHOLOOYfAEklhPIKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Redd hde wit I T'50' b-' from 14-17'-2264° MD. Pul caul of We aW Fun down la bcllvrn lar awiper cbaan SUMMARY Finish wipwr clean and arcJk;,e LO a!ns for dean hde. DANRIG PERSONNEL ON BOARD 4 DAILY COST DML- $2765, $720 REPORT BY Brun Adams 21 cANRIG FURZE Kitchen Lights Unit A-2 Furie Cperabng Atka, LLC L]AILY'WrELLITE REPORT CANRIG '' KLU fr2 REPORT FGA Dale Manger DATE Jun 22, Lroi5 DEPTH 2284 PRESENT OPERATION Gamieling cement Job. TIME 2oilo.oU YESTEPDAY 24 HOUR FOOTAGE ❑ CASING INFORMATION 2Q- 19.87s' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 31TINIFORMATION INTERVAL CONDITION REA50h NO. SIZE TYPE &N JETS IN CUT FOOTAGE HOURS T13C PULLED DRILLING PARAMETERS HUGH ILOW AVERAGE CURRENT AVG PATE OF PENETRATION ( t F UHR SURFACE TORQU E r AMPS: WEIGHT ON ®rr ( KLEE• ROTARY RPM ( RPM PUMP PRESSURE PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL - FC SOL SD CIL MBL pH Ca+ CGI MIND SUMMARY INTERVAL TO TOOLS GAS SUMMARY (uT&I HIGH LCW AVERAGE DITCH GAS TRIP GAS GUTTING GAS Q WIPERGAS CHROMATOGRAPHY +pprnl SURVEY METHANE (C-1) CONNECTION GAS HIGH ETHANE (C,2) AVG P140PANE (C-3) CURRENT BUTANE (G-4) 4 0 CURRENT RAGKGPIDLINIVAVC PENTANE(C-5) t$ HYDROCARBON SHOWS INTERVAL LITHOLOGYfAEkAARKS GAS DESOPIPTION LITHOLflGY PRESENT LITHOLOGY DAILY ACTNrITY Conikue to cimiale bodrrrn sp and prepare b ilp-up Qumg equipment Pre-joh safety meeting far as ng SUMMARY operatxc nr' rig Rom Pun casing frcrn surface to 2262' MD. Rig down casing�ipment. Pre•jobsaiely rneeiing for oemert jof and test cement Ines. Complele rorrrentA and weft for cementlo dry. CANRIG PERSONNEL ON BOARD 4 DAIL'Y COST DhAL- $2765, RigWatch- 720 REPORT BY Bdtten Adams 22 cANRIG FURZE Kitchen Lights Unit A-2 Furie Cperaling Atka, LLC DAILY WELLSITE REF IRT CANRIG IGLU fr2 REPORT FOR Dale Munger DATE Jun 2E, 2o16 DEPTH 22o4 PRESENT OPERATION Paplazdng BOP stark TIME 23.01):DD YESTERDAY 22034 m HQUR FOOTAGE D CASING INFORMATION or 18.575` DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT IN FORMATION INTERVAL CONDITION REASO`, NO. SIZE TYPE &N JETS IN OUT FOOTAGE HOURS T13C PULLED DRILLING PARAMETERS HIGH ILOW AVERAGE CURRENT AVG PATE OF PENETRATION ( FT,°HR SURFACETOROUE i AMPS WEIGHT ON ®IT ( KLBE• ROTARY RPM ( RPM PUMP PRESSURE PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL - FC SOL Sa OIL MBL pH Ca+ CCI MIND SUMMARY INTERVAL TO TOOLS GAS SUMMARY (unilsl HIGH LCw AVERAGE DITCH GAS TRIP GAS CUTTING GAS Q WIPER GAS CHROMATOGRAPHY +pprril SURVEY METHANE (C-1) CONNECflON QkS HIGH ETHANE (G-2) AVG PROPANE (C-3) (yam CURRENT 34lTANE (C-4) 4 0 CURRENT BACKGPIDUNDfAVC PENTANE(C-5) t$ HYDRCCAPEON SHOWS INTERVAL LITHOLOGYfAE6AARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY IIAIL'YAGTIVfFY SLOA AARY Gwe the rig fox and phdarm msintenemce. Preperela charge oretSOP stacks. DANRIG PERSONNEL ON BOARD 4 DAILY COST DML- $2765, RigWatch- $720 REPORT BY B611ton Adams 23 cANRIG FURZE Kitchen Lights Unit A-2 Furie Germing Atka, LLC DAILY WELLS ITE REPORT OIG I{LU �2 REPORT FOR Dale Mungea DATE Jun 27, 2x15 DEPTH 2234 PRESENT OPERATION Piepare w -d 1eslirg 90P TIME 23:03:[X] YESTERDAY 2284 24 HOUR FOOTAGE U CASING INFOPMA71ON DEPTH INCLINATION AZIMUTH VERTICAL DEP-H SURVEY DATA SIT IN FORMATION INTERVAL CONDITION REASON NO. SIZE TYPE &N JETS IN OUT FOOTAGE HOURS T13C PULLED DRILLING PARAMET EPS HIGH ILOW AVERAGE CURRENT AVG PATE OF PENETRATION ( FT,°HR SURFACE TOROU E i AMPS WEIGHT ON 9rr ( KLEE• ROTARY RPM ( RPM PUMP PRESSURE PSI DRILLING MUD REPORT DEPTH vW VIS PV YP FL Gels CL - SOL Sa OIL M8L pH Ca+ CGI MIND SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GS TRIP GAS CUTTING GAS Q WIPEFI GAS CHROMATOGRAPHY 0 pprril SURVEY METHANE (Cl) CONNECTION QkS HIGH ETHANE (G,2) AVG P140PANE (C-3) (y CURRENT 3UTANE (C-4) (CURRENT RAGKGRDUNIVAVC PENTANE (G-5 HYOPGCAR13ON SHOWS INTERVAL LITHOLOGY;FIEMAPKS GAS DESCRIPTION LIT HOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Qntinue 1a maintenance the rig ward teslirg 3013 s!EL*. CANRIG PERSONNEL ON BOARD 4 DAILY COST DIAL - $2765, RigWatch- 724 REPORT BY BHttGn Adams 24 cANRIG FURIE Kitchen Lights Unit A-2 Furie Loeralinsg Alaska, LL DAILY WELLSITE REPORT CANRIG KLU OrE REPORT FOR Dale Munger DATE Jun 28. 2016 DEPTH 2794 PRESENT OPERATION Girrulaung and omidlimir•] T id -IV_ 2S:COM YESTERDAY 2794 24 HOUR FOOTAGE C CASING IN FOAMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT IN FORMATION INTERVAL CONDITION PEAS0% NO. SIZE TYPE aN JETS IN OUT FOOTAGE HOURS T13C PULLED DRILLING PARAMETERS HIGH LOQ'! AVERAGE CURRENT AVG PATE OF PENETRATION ( FT,°HR SURFACETOROUE C ¢ ASI?£: WEIGHT ON ®FF KLBE• ROTARY RPM PPM PUMP PRESSURE PSI DRILLING MUD PEPORT DEPTH MW VIS PV YP FL Gels CL_ FC SOL SD OIL MEIL pH Ga.4 GCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (unitsl HIGH LOW AVERAGE DITCH GAS TRIP GADS CUTTING GAS Q WIPER GAS a; HROMATOGPIAPHY +ppird SURVEY METHANE (C-1) CONNECTION GAS HIGH ETHANE (C-2) ( AVG PPOPANE(G3) CURRENT BUTANE (C-4) ( GU11RI3IT RAGKGRDUNdrAVG PENTANE(C-5) r HYINI.CCA.RBON SHOWS INTERVAL LITHOLGGY(PEMARKS GAS DESCRIPTION LITHCLOGY PRESENT LITHCLOGY UAILYACTTVFFY Completed BOP testing Mh stWB rap. Pnepere EIHAto nun in bole amd maintefiamce fig. Huikiand nun ETA in the SLAY hale 11) 214LBA'MD. Circulate Trod tbmugh csse hale ID get Wn)a t marl-weighL Clean wi p E iaf neer rnud praduas. CA N RI G PERSONNE L ON BOA AD 4 DAIL'YCOST DML -$2765, RigWatch - $720 REPORT BY BdttGn Adams 25 cANRIG FURZE Kitchen Lights Unit A-2 Furie Cperaling Atka, LLC i►tioafienLigftUni DAILY'WrELLITE F3ERCiRT CANRIG '' KLU A2 REPORT FOR Dale Munger DATE Jun .29, 2016 DEPTH 2344' PRESENT OPERATION Giculate and Condnicn Mud Systen TIME 23A4:00 YESTERDAY 2284' 24 HOUR FOOTAGE hex CASING INFORMATION 2]' Gcnductn 9 381' 13 .1a' Q 2265 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT IN FORMATION INTERVAL GONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TUG PULLED 2 121 4' BHI, TDfISSX 7MD608 7x15 22m MDd'2DD-P TVD W 0.5 SIH NIA DRILLING PARAMETERS HIGH LCw AVERAGE GURRENTAVG PATE OF PENETRATION 338.7 2NO' 6.7 0 2297 128.4 B3.2 FTMP SURFAGETOROUE 4237 2289' 3153 0 2335' 3597.5 3405.3 AMPS WEIGHT ON Orr 9 9 2298' 0.9 0 231x3' 4.3 4.2 KLBS ROTARY RPM 62 0 2288' 46 ea 2335' 5314 50.5 RPM PUMP PRESSURE 1203 9 2322' ",9 is 22P5' 963.7 1D35.9 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP PL Geis GL - FG SOL EE OIL MBL pH Ca+ GGI VWD SUMMAPY INTERVAL 2284' TO 2344' TOOLS Mucinnalorwf MWD, Gamma. Resistivity. Neutron Density and Pvrrsity txIs preserrlty in hale GA,S SIIMMAPiY (unftsk HIGH LOW AVERAGE Dn'GH GAS 0.9u 2337 0.2u 2301' 0.6u TRIP GAS WA GUTTING GAS WIPER GAS WA CHROMATOGRArPHY Wnnp SURVEY Ger METHANE (G-1) 142 2317 17 2301' 86:8 COMEGTI€TN GAS HIGH Ger ETHANE (G,2) 0 2344' 0 23" 4A AVG Gu PROPANE (C-3) 0 0 2344' 0 23x4' 4A0 CURRENT Gu BUTANE (G-4) D @ 2344' 0 M" 9-G CIJRRENTBAGIMPOUNOFAVG G.su f 0.5u PENTANE (C-5) D (D 2344' 0 2344° GA HYEFU R1 ON S"S No Significant Hydnxmb n Sbvws in I=24 hours INTERNAL LITHOLOGYXREMARI{S GAS DESCRIPTION LffHOLOGY Rlr0Dre9vlidE1tedSend PRESENT LIT14OLOGY Unto%svlidsted Sund DAILY Perioeencasing pressure teal on 10 3rS' casing; Dn1I cutcernenio shun 9rark Obsereed :hickrnud and cerner' al A"Tf4''ITI� shakers} IX1 new Ivnraticn from 2284' 10 2K4'; Pee4ft4m F.I_T. ID tris E M.W.: Build sparer, prmare to dispa,ce SUMMARY Well. Displar�eWell with 1O.Cppg W&M; Brildvolume and veal new mud {or upcoming hale seaian while offloading cid spud mud to Ioosd: Direr ticn* drill ahead hvrrr 23�'to 2344': Gimrlaee and ccndihcn rnud system. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: $2765, RigWatch=$720 REPORT BY Doug I'-orkert 26 cANRIG FURIE Kitchen Lights Unit A-2 Furie Opera*g Alaska, LL Wihen LyMs Uri1 DAILY WELLSITE REPORT CANRIG KLU A2 REPORT FOR Dale Munger DATE Jun 30. 2015 DEPTH 3445 PRESENT OPERATION Drilinp TIME 23:10 YESTERDAY 2344 25ti IDUR FOOTAGE 1101 CAS NG INFOA MATIOhI m, Card & 3331' 13 a8'@ 2265' DEPTH NDLINATION AZIMUTH VERTICAL DEPTH 3'}®9.63 50.C6 4629 2523.98 SURVEY DATA 5195.56 49.63 4SA6 2585.5B 525x.42 49.54 "-62 2646.95 5375.44 49.77 4.6-13 2708.47 BIT IN FORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SAN JETS IN OUT FOOTAGE HOUR'S T1310 PLILLED NB 2 12 1.'4- BHI TD6DsSX 704:1606 7x16 22sm SIH DRILLING PARAMETERS HIGH LOW AVERAGE OURRENTAVG PATE OF PENETRATION 381.18 2:584 1.7 P ! 2775 125.D 13.71&% FT.'HR SURFACETOROUE 651x5 3324 D Side 4366.4 Side AVPS WEIGHT ON BIT 3 2381 0.1 Q 5]19 5.7 2.31781 KLBS ROTARY RISA 96 0 5324 D 0 Side 54.8 Side RPM PUMP PPESSURE 1954 @ 31118 1095 0 2344.UOW 1634.9 1655.46867 PSI DRILLNG,MUD REPORT DEPTH MW VIS PV YP FL •:refs CG FC SOL SD OIL MBL pH Ca3 ;CI MWD SUMMARY INTEIRVAL 2284' TO 344.5' TOOLS Sumay, GR, Reaistio, Densisty, P4rwiiy GAS SUMMARY (uniisl HIGH LOW AVERAGE DITCH GAS 39 Q %12.D0000 D 13 2758.D0)DJ 9.D TRIP GAS OUT: INC CCAS a 0 WIPEq GAS CHROMATOGRAPHY (PPrrU SURVEY METHANE (C-1) 8582 12 314D.D00W 21 (D 2756:D00W I 6.4 CONNECTION GAS HIGH u ETHANE (C-2) 0 12 3USD3000 a (D 5446:f800d0 a.0 AVG 0 PROPANE (C-3) 0 19 36"5.D00Lr0 a (qD BA45.DOOM a.0 CURRENT 0 BUTANE (G4) 0 19 5445:[800U0 a 5445:00000 0:f? CURRENT BACKGROUN6rAVG 1.12 PENTANE (C-5) 0 @ 5445.00000 a ( 5445:00000 0:d HYDROCARBON SHONS NONE INTERVAL LITHO LOGC'REMARKS GAS DESCRIPTION LITHOLOGY Sand with interbedded Tuffaceaus days siWane PRESENT LITHOLOGY 31Y% Sand. 60% Tutfac&-Djs Ckslam, 10:�. Silivorre, Trace Coxal DAILY ACTIVITY SUMMAAY CANRIG PERSONNEL ON BOARD 4 DAILY COST DML $2765, RW $720 REPORT BY DavGdoatherap 27 cANRIG FURIE Kitchen Lights Unit A-2 Furie Oper-Ming Alaska, LL Kib:&n Ligft Uril DAILY WELLSITE REPORT CANRIG IGLU fr2 REPORT FGA Dale Munger DATE Jul o1 , 2D15 DEPTH 4991 PRESENT OPERATION Grilling -n ME 23:03 YESTERDAY 3445 24 HOUR FOOTAGE 1545 CASING INFGA MIIATION 23' Cued & 381' 13 aw @ 2265, DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4605.68 49.49 44°99 2E03.08 SURVEY DATA 4700.91 49.94 44A9 2674.72 4795.E2 50.34 45,54 2747.45 4889.64 50.25 "-59 2619.53 37 INFUAMATION INTERVAL CONDITION REASON NO. SIZE TYPE &N JETS IN OUT FOOTAGE HOURS T.SIC PULLED �3 2 12 174` PDG 6HI TDEasn 71 owa 7x16 2285' SIH DRILLING PARAMETERS HIGH LOW AVEPIAGE CURRENTAVG PATE OF PENETRATION 281.0 12 4.302 4.1 3460 114.1 a,279511 FTIHR SURFAGETOROUE 9457 a 5554 0 Slide 539D.9 Sime AMPS WEIGHT ON Err 29 Q 5979 0.2 p 39471 E 0 5� iL2S ROTARY RPM 134 (a 3554 0 Slide WA Side RPM PUMP PRESSURE 2210 Q 4}23 1W2 3019 1934.4 2159 PSI DRILLINGAIUD REPORT DEPTH IAIYI' VIS PV YP FL ,Gels CL - FC SOL SD OIL MBL pH Ca+ CGI MWD SUMMARY INTEPVi}4L 2284' TO 4991' TOOLS Surrey, GR, ResisGiiiy. Pomo ly. Density GAS _SUMMARY Gini sl HIGH LOW AVERAGE DITCH CAS s 0 4845 0 0 4257.0300W 1.4 TRIP GAS CUTTI INC CCAS a 0 4991 0 0 4991 .D 30M 0.0 WI PEA CAIS CHROMATOGRAPHY 1FRN SURVEY METHANE (G-1) 1316 0 4546 70 0 3452 322.E CONNECTION CAS HIGH a ETHANE (G2) 0 0 0 Qr 0.0 AVG D PROPANE (C-3) o (a) o 0 0.0 GUAAENT BUTANE (G-4) 0 0 0 a 4.4 CURRENT BACKGROUNDYAVG :2 PENTANE (C-5) 0 0 0 0 0.0 HYDROrAPd3ON SHCWS NONE INTERVAL LITHOLDGY1REMARKS GAS DESCGIPTION LITHOLOGY IntertaddedSands. Tutfareoia04 Siltslmev mincf33W PRESENT LITHOLOGY 80% S.-m&Samds1cr9Tuf ceras Sand, 10%Tuffa ems Glaysione, 1 a%Tufferadas Siftslane DAILY ACT rFYBLIIt MAJRY Drill 344s -4w, CANRIG PERSONNEL ON BOARD # DAILY COST DML 276!5. RW $720 REPORT BY Dave Doatherage 28 cANRIG FURIE Kitchen Lights Unit A-2 Furie Oper-Ming Alaska, LL Kitchen Lights Uril DAILY W ELL ITE REPORT CANRIG KLU fr2 REPORT FOR Dale Munger DATE .Jul 1)2, 2016 DEPTH 5635 PRESENT OPERATION Dri ling TIME 23:14 YESTERDAY 4991, 24 HOUR FOOTAGE 544 CASI NG INFOG MATION 2]' Ound & 531' 13 &8' @ 22655' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5257.88 47.32 42.84 3947.92 SURVEY DATA 53+51 .91 47.14 4222 4D12.17 5456-6 47.47 42A9 4076.44 5551 M 45,&4 4124 4140.67 BIT INFORMATION INTERVAL € 3NDITION GEASOt NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T'&'O PULLED NB 2 121fC PDO HTC TDim5SX 704LWB 7315 2284' SIH DRILLING PARAMETERS HIGH LOW AVERAGE OURRENTAVG RATE OF PENETRATION 291.5 12 533D 5.4 •5616 74.1 553 F7.1 FP. SURFAGETOROUE 7E03 a 5444 0 Slide 4514 6.4 AMPS WEIGHT ON Err 27 Q 5496 0.1 5334. 9.5 72 QBS ROTARY RPM 116 a r 4 Slide 64.1 D RPv' PUMP PPESSLIGE 2841 G = 1892 5446 M88.9 2149 PSI DRILLHGLIUD REPORT DEPTH sms WIN 10.0 Vis 46 PV 14 YP 219 FL 5.6 GEIS SIM G -L- 11200 F3 1 SOL 8,o SID 020 OIL o MEIL 4.B pH 14.1 Qu 280 CGI MWD SUMMARY INTEIRVAL 2284' TO 5535' TOOLS Suvey. Garnme. Resisli , Pomso, Density GAS _SUMMARY Gxnilsl HIGH LOW AVERAGE DITCH GAS 56 54.65 0 5064 14.6 TRIP GAS GUTTING GAS WIPED GAS 9j a 5452' CHGOM ATOGR,3PHYIgm) 5UPVEY METHANE (G-1) 1134-5 5365 1 D i t .50bU 21369.6 GC)NNECTION GAS HIGH a ETHANE (C-2) 0 [ter 4 A AVG o PROPANE (C-3) 4 4A CUGGENT o BUTANE (G4) 4 it 4A CURRENT RACKGGOUND%VG sf 12 PENTANE (C-5) 4 [ SI 10 HYDROCARBON SHOWS NONE INTERVAL LITHO GGYfPEM0LPKS GAS DESCRIPTION LITHGLOGY Irrlm bedded 5amds, Srlts with occammall Goal beds PRESENT LITHOLOGY 9 S SandslonetTullaceous Sand. 1451} Tuthapo.Is Sihst ne DAJLYA,,GTrVITY SUMMARY Ni 4991y'=5452; Gini deem; Pull to shoe; men ritrh end shakers; PIH Dril 15' 552 -Y-35 GANRIO PERSONNEL ON BOARD 4 :DAILY COST DFL 675, RW $724 REPORT BY Dave Doatherage 29 cANRIG FURIE Kitchen Lights Unit A-2 Furie Oper-Ming Alaska,, LL Kitchen LightsUril DAILY WELL ITE REPORT UNRIG KLU A2 REPORT FOR Dale Munger DATE .Jul in. 2D16 DEPTH 6941' PRESENT OPERATION Dri'ling TIME 2a.00 YESTERDAY %35 24 HOU R FOOTAGE 1308° CASING INFORMA+kTION 2]'sand @ 3a1' 13 ale, ig 2265' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8531.52 43.32 37.39 4811.e2 SURVEY DATA E697.B4 43.72 37.86 4951.56 57B1.42 4425 Sam 5we.99 E075.% 44.34 3822 51+96.15 BIT IN FORMATION INTERVAL CONDITION REASON; NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TEv0 PULLED NB 2 12 1lC PDG HTC TDFA5S{ 7a4EF,+1B 7X15 2284' SIH DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG PATE OF PENETRATION 224.2 12 5736 0.9 6021 88.7 74A 17.1 FR SURFAGETOROUE 7530 a 52BD 0 Slide 509B.9 5391 AMPS WEIGHT ON Err 33 Q 5936 0.1 G 6.595 B.7 9. KLBS ROTARY RPM 112 a B28U a Slim=_ 75.8 B7.6 RP!i PUMP PPESSURE 2547 19 5844 19M 5746 M5.3 2369.9 PSI DRILLING LIUD REPORT DEPTH Lfw VIS PV YP FL {mels CL- FC SOL SD OIL MBL pH Ca+ CGI MWD SUMMARY INTERVAL 2244' TO 6941' TC(DLS Suwey. G3rnme, Resist". Density, Porosity GSAS SUMMARY Ginilsl HIGH LOW' AVERAGE DITCH GAS 1.537 ftp 661 B.00jOD 19.9 0 6W9 143.3 TRIP GAS OUSTT INC CSS [ 0 WIPER GAS CHROMATOGRAPHY (Qpm) SURVEY t9 METHANE (G1) 366821 0 6517 200 6939 289M.5 CONNECTION GAS HIGH 1 @ 422u ETHANE (G2) 9% (a 6831 a Merry 235 AVG D PPOPANE (C-3) D a a_a CURRENT t9 BUTANE (G4) 0 0 Girt GURRENT BAGKCROUNIXrAVG 43,1 1 a PENTANE (C-5) D a a ak HYOROCARBON SHOW'S NONE INTERVAL Lf T1DL+CYn4EiIlMI3 LASS DESCRIPTION UTHOLDGY IraNbedded SeadlaSardshme.Taffinemsa4(Srihwith Gaal reawis PRESENT LITHOLOOY 237 Gael, 40% SmidGanr#ome, 40%C13ylSiltstnme DAILY ADTIVr Y SLIAMARY Dri 5635'-6941' CANRIG PERSONNEL ON BOARD 4 DAILY COST DML :$ 2675, rwr $720 REPORT BY Dawe D-oathorago 30 cANRIG FURIE Kitchen Lights Unit A-2 Furie Operatng Alaska, LL Kitt hen Light Urit DA ILY WELL ITE REPORT CANRIG IGLU fr2 REPORT FOP Dale Munger DATE Jing 04, 2016 DEPTH low TD PRESENT OPERATION &OPE Tesi TIME 23)3o YESTEPDAY 6941° 24 HOUR FOOTAGE 37 CASING INFORMATION 20-CON11.9mi, t3 alar@ 2265' DEPTH INDLINATION AZMUTH VERTICAL DEPTH SURVEY DATA PmjWed TD 7096' 45.49 53.7 51 20.94' BIT INFOPMATION INTERVAL CONDITION REASON NO. SIZE TYPE &N JETS IN CUT FOOTAGE HOURS T.SC PULLED NB 2 '12 VC PDC HTC TD-5a5SX 70405D8 7x16 2264' 71038' 4754 89 TD DRILLING PARAMETERS HIGH LOVE AVERAGE OURRENTAVG PATE OF PENETPATION 146.7 9 6 3.7 0 702T 72-0 MIA FT.HP SURFACETORDUE 62IT7 19 7x21' &593 13 7087 6t20.2 RIA AMPS WEIGHT ON Orr 24 6944' 3.9 13 6976 1315 4A KLBS ROTARY PPkA 92 7021' 83 0 7037 91-0 RIA RPM PUMP PPESSURE 2717 5944' 225D 0 7132T 2404A RIA PSI DRILLING MUD REPOPT DEPTH IJrP'f VIS PV YP FL Gels CL- F -3 SOL SD OIL MOL pH Ca+ CCI MWD SUMMARY INTERVAL 2294, TO 7D38' TOOLS Suwey, Garnme, RedrA r ly, Density, Pom6ty :AS SUMMARY iz&l HIGH LOIN AVERAGE DITCH GAS 153 Q 695.9' 9 0 702T 63.5 TRIP GAS TUTTING GAS 19) a WIPER GAS CHROMATOGRAPHY [Ppm) SURVEY METHANE (C-1) 28925 12 69.57' 1575 9 702T 11232.3 CONNECTION GAS HIGH a ETHANE (C-2) D a D.D AVG a PROPANE (C-3) D a D.D CURRENT a BUTANE (G-4) D -5 D.D CURRENT BAGKGROUN❑�AVG 3 5 PENTANE ("- D K& i D.D HYMCCAP1 ON SHUNS NONE INTEpRfAL UTHOLOGY'REMAPKS GAS DESOPIPTION LITHOLOGY Intertadded Tuffawaus OW'Sill and Send %flh S=ored Coal PRESENT LITHOLOGY 50% Sand?Sandsunarruboeous Sand, 4a% Turtacems CLW Dlmime DAILY ACTIVITY OdII 6941'-7x96'; Circ: Letdown -�m81e; Gn2wod; ❑ry Ob: Pull lin 077% CirGD Wash 1a 6791; Badcream 5gg7'- SUMMA RY 44135: POOH; Drnvnhaj LWD; So* hii; Sland back EIH : Make uP lest plug; Test ROPE OANRIOPERSONNEL ON BOARD DAILYCOST DML$2675, R $720 REPORT BY Dave Dsathlorage 31 cANRIG FURZE Kitchen Lights Unit A-2 Furie Cpereding Alaska, LLC KitehenLightUnd IDALILY'WrELLSITE REPORT CANRIG KLU -2 REPORT FOR Dade Munger [DATE July a5, 2o% DEPTH 7 za TU PRESENT OPERATION Circulating TIME 23.w YESTERDAY 7m 24 HOUR FOOTAGE a CASING INFOPMATNON 2a` owd 9 381' 13 afe, & 2m5, DEPTH MKI.114ATKDN AZIMUTH VERTICAL DEPTH SURVEY DATA Pmoded TD 70SU 45.49 33.7 5210.34' BIT INFORMATION INTERVAL CONDITION REASON NO_ SIZE TYPE S?N JETS IN OUT FOOTAGE HOURS TKG PULLED NONE DRILLING PARAMETERS HIGH LO'W' AVERAGE GURRENTi AVG RATE OF PENETRATION WA F F."HP SURFACETOROUE WA AMPS WEIGHT ON Orr ¢ WA KLES ROTARY RPM WA RPM PUMP PRESSURE WA PSI DRILLING MUD REPORT DEPTH law MW VIS PV YP FL Gels CL - FC SOL SD OIL MOL PH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS NONE :AS SUMMARY iz&l HIGH LOW AVERAGE DITCH GAS 6) TRIP GAS 1 ae @ 703LB UTTINC GAS 0 WIPER GAS CHROMATOGRAPHY (pprn) SURVEY METHANE (C-1) a a CONNECTION GAS HIGH ETHANE (C-4 r9 a AVG PROPANE (G3) Qi a CURRENT BUTANE (C-4) 0 CUR RENT OACKGROLPHDIAVG o.s t 1.5 PENTANE (" HYMCCAR60N SHOWS NONE INTERVAL LITHO LOG Y(RENAkvIKS GAS DESCRIPTION LITHOLOGY PRESEN4TLITHOLOGY SsndrSsnds1orogTuIfBxmsSand 40%Tint sC4.13ilmzle 01AILYACTIVrrY Finish tes&g BOPE; Pull kFa plus: Pk* up 1W of 3 .V tuhvng: RIH dril pipe to 703e: 3Tulsle; Cenrenzng SUk4MARY safety weeding: aruime; Pump cemem; Pull B smrds: CmilrdB. CANRIG PEPLSONNEL ON BOARD 2 DAILY COST DML $2675, RW $720 REPORT BY Rave Dloarthorage 32 cANRIG FURIE Kitchen Lights Unit A-2 Furie CWmfing Alaska, LLC I(itohen Ligf»s Unit DAILY WELLITE REPORT � l CANRIG KLUA-2 REPORT FOR Isaiah Del Taro DATE JUI X75, 2016 DEPTH law TD PRESENT OPERATION W_O.C. 0 Shoe TIME 23:00 YESTERDAY 7aav 24 HOUR FOOTAGE c° CASING INFORMATION DEPTH INMNATION AZIMUTH VERTICAL DEPTH SURVEY DATA Projected TD 7033 45.49 W.7 521 o.m SIT IN FORMATION INTERVAL GONDITTON REASON NO. SIZE TYPE SrN ~JETS IN OUT FOOTAGE HOURS T'i?C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG PATE OF PENETRATION f �jr p MIA FT HR SURFAGETOROUE @ WA AMPS WEIGHT ON 9ff 'kVA K E ; ROTARY RPM f3• WA RPM PUMP PRESSURE i WA PSI DRILLING MUD REPORT DEPTH jwm VIS PV YP Fv Gels GL- LFC FGSOL SD OIL M9L pH Ga+ CGI MwfD:S IMMARY INTERVAL TO TOOLS GAS SUMMARY funds) HIGH LOW AVERAGE DITCH GAS ( TRIP GAS CUTTING GAS i WIPER GAS 2 CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 0 1:576 CONN ECTION GAS HIGH G ETHANE (C-2) a D AVG PROPANE (C-3) 0 D CURRENT 9UTANE (C,4) a D CURRENT ]B4CKGRQUNIMAVG o-3 f 0.5 PENTANE (C-5) a D HYDPOGAR90N SHOWS INTERVAL LITH0LQGYfPEIIA& IK5 GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAI_YA TNIF'Y Pull to shoe; W -O.0-; Girculsde; PIHto 51.50: amalaie: RIH to 623s: Gmulaie; Cement Pull to 4890'; SL MMAPY 0TCk lrsie; PL la shoe; W.O.C_ OANRIO PERSONNEL ON BOARD 2 DAILY COST DML S 2545, RVQ 720 REPORT BY DamG D�eathorage 33 cANRIG FURZE Kitchen Lights Unit A-2 Fuhe Operatimg Aia&a, LLG KilbbenLighNs Emit DAILY WELL ITE REPORT CANRIG YLUA-2 REPORT FOR Isaiah Del Taro DATE JdG7. 2015 DEPTH 7[133 TD PRESENTOPERATION Girculaling TIME 23:DD YESTERDAY ma, 24 HOUR FOOTAGE a CASINO INFORMATION m, Coed @ s31' 13 ala, @ 22&3' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA Projected TD 7{]35' 45.49 X3.7 521 d.34' IT INFO€IMATION INTERVAL GONDITION REASON NO. SIZE TYPE SrN JETS IN OUT FOOTAGE HOURS T13C PULLED DRILLWG RARAMETERS HIGH LOW AVERAGE CURRENT AVG PATE OF PENETRATION NA FT[HR SURFAGETORME KI 'A AMPS WEIGHT ON DET RIA IQBS ROTARY RPIM ( RIA RPM PUMP PRESSURE t C RIA Psi DRILLHGMUD REPORT DEPTH MW VIS PV YP FL Gels CL - FC SOL SO OIL M9L pH Ca+ CGI MWD S1 IMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH OAS @ TRIP GAS CUTTING GAS @ WIPER GAS 1 CHROMIATOGRAPH4I pw) SURVEY METHANE (G-1) @ CONN EOTIONGAS HIGH ETHANE (G,2) @ AVG PROPANE (G-3) @ CURRENT BUTANE (G -d) @ CURRENT 13A.GXGROUNU'AVG o-1 f 4.3 PENTANE {C-5) HYDROCARHON SHOWS INTERVAL LITHJLOGYMEMARKS GAS DESCRIPTION LITHCLJ GY PRESENT LITHCLOGY DAILY ACTIVITY W.O.C.; Circulme; PIH to 4892; Circukda.. Set emnem pkq, Pull '; Cirru[me: POOH: Lspdom directima] SUMMARY 9HA thai was sbodback in denick: RIH b i511tb'; W.O.G.; PIH w4A5T; Circulate_ GINRIG PERSONNEL ON BOARD 2 DAILY COST DML S 245, RW 720 REPORT BY Dave Deatherage 34 cANRIG FURIE Kitchen Lights Unit A-2 Fude Operating Alaska, LLC KhohenLighis Unit DAILY WELLSITE REPORT CANRIG KLU A-2 REPORT FOR Isaiah Del Taro DATE Jul, oB. 2D15 DEPTH 7osa'TD PRESENT OPERATION L,D Test Plug TIME 23 no YESTERDAY lose 24 HOUR FGOTAGE a, CASING INFORMATIGN err Cond @ sa7, 13 a'®. @ 22MY DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA PrD.Wed TD 703' 45.49 W.7 S21 d.M SIT IN FORMATION INTERVAL GONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FCCfTAGE HOURS T'B?C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG PATE OF PENETRATION MIA FT'HR SURFACETOROUE IIIA AMPS WEIGHT ON 9rr NIA KLBS ROTARY RPM ( WA RPM PUMP PRESSURE C RIA PEI DRILLING MUD REPORT DEPTH IwH VIS PV YP FL Geis GL,- LFC FCSOL SD OIL M3L pH Ga+ CGI MWD SUMMARY INTERNAL TO TOOLS GAS SUMMARY (unds) HIGH LOW AVERAGE DITCH GAS TRIP GAS CUTTING GAS WIPER GABS CHROMATOGRAPHY Wm) SURVEY METHANE (C-1) CONN ECTIGN GAS HIGH ETHANE (G2) AVG PROPANE (C-3) CURRENT BUTANE (C,4) CURRENT ]BACKGROUND'AVG o_1 f o.3 PENTANE (C-5) HYDPOCARHON SHOWS INTERVAL LITHOLOGY'REMAPK5 CAS DESCRIPTION LITHOLOGY PRESENT LITHOiLC}GY DAILY ACTIVITY €iTculwe; Tap Cement; Pull to E25s; Circulate: Pump set cernern Kic$t-Off plug; POOH: Make uP'hm test SUMMARY plug: Test &OPE; PuILIlaydcwn test plug_ OANRIO PERSONNEL ON BOARD 4 OAILY COST DML S 2675, RW 724 REPORT BY Dare D�eathorage 35 cANRIG
