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Home My WebLink About219-002Winston, Hugh E (CED) From: Winston, Hugh E (CED) Sent: Wednesday, February 3, 2021 1:09 PM To: tom.g.polasek@conocophillips.com Cc: Loepp, Victoria T (CED) Subject: GMTU MT6-01 Permit Expired Hi Tom, The permit to drill for well GMTU MT6-01(#219-002), which was issued to CPAI on January 18th 2019, has expired under regulation 20 AAC 25.005 (g). The permit has been marked expired in the well history file and in the AOGCC database. Please let me know if you have any questions. Thanks Huey Winston Statistical Technician Alaska Oil and Gas Conservation Commission hugh.winston@alaska.gov 907-793-1241 THE STATE GOVERNOR MIKE DUNLEAVY Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Greater Mooses Tooth Field, Lookout Oil Pool, MT6-01 ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-002 Alaska Oil and Gas Conservation Commission Surface Location: 232' FNL, 3096' FEL, SEC. 6, T10N, R3E, UM Bottomhole Location: 3502' FNL, 335' FEL, SEC. 13, T11N, R2E, UM Dear Mr. Alvord: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the 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. 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, Daniel T. Seamount, Jr. Commissioner DATED this /Uday of January, 2019. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ECE, r� J AD' A a Q 2 i2 i'3: 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas 0 Service - WAG Service - Displ] 1c. Specify.if well isproposedfor. Drill ❑ Later Stratigraphic Tep Development - Oi10 ' Service - Winj ❑ Single Zone ❑ I Coalbed 96 Gas Hyd56s Redd Reen r{� Exploratory -Oil ❑ Development - G9 Service - Supply❑ Multiple Zone ❑ Geotherr>91 Shale GP 2. Operator Name: 5. Bond: BlanlOt • Single Wel[ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 5952180 MT6-01 3. Address: 6. Proposed Depth: . 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 23529 TVD: 7777 Greater Mooses Tooth Unit Lookout Pool 4a. Location of Well (Governmental Section): 7. Property Designation: • AA 0 917 4 3 y Surface: 232' FNL, 3096' FEL, Sec. 6, T10N, R3E, UM AA081798, AA081818, AA092345,'AA092340, AAO Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 3497' FNL, 631' FEL, Sec. 30, T11N, R3E, UM 932533, 932553, 340761, 340759, 953086 1/31/2019 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 3502' FNL, 335' FEL, Sec. 13, T11 N, R2E, UM 609, 1209, 600, 640, 640 1777' to AA092346 . 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 89 15. Distance to Nearest Well Open Surface: x- 317135 y- 5945571 Zone-4 GL / BF Elevation above MSL (ft): 44.8 to Same Pool: 3786' to MT6-03 16. Deviated wells: Kickoff depth: 1055 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 94 degrees Downhole: 3567 • Surface: 2779 ' 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 42" 20" 94 H-40 Welded 80 34 34 115 115 10 yds 16" 13.375" 68 L-80 BTC-M 2027 34 34 2061 2033 949 sx 11.0 ppg DeepCrete,331 sx 15.8 ppg G 12.25" 9.625" 40 L-80 TXP 9532 34 34 9566 6917 218 sx 15.8 ppg tail 8.75" 7,0" 26 L-80 Blue 11820 34 34 11854 7885 185 sx 15.8 ppg tail 6" 4.5" 12.6 L-80 Blue 11825 11704 7871 .235291 7777 uncemented perf pup liner 19, PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? lrs t� 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program O 20 AAC 25.050 requirements 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 Name: Tom Polasek Authorized Name: Graham Alvord (265-6120) Contact Email: tom.g. olasek ConocoPhilli s.( Authorized Title: Drilling Manager Contact Phone: 907-263-3740 e- {� f ZA t 1' 2. Authorized Signature: Date: d q Commission Use Only Permit to Drill Z C Xc L 150- API Number: �j Ter 7--(!'6 Permit Approval f See cover letter for other Number %L) 5 -- Date: requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed m,-etthh�ne, gas hydrates, or gas contained in sh Other.,50� rlS� �O j SGri �J 5 Samples req'd: Yet ; ` 'Wo Mud log req'd: YL4/ WNo r� 10 ZSGG �� Vti'7 v/GL % [f�'��r v��tr!- / ip � �iZS measures: Yew ,�,11/q Directional svy req'd: Y!A -❑/No br),I SU t L Zf m (f l f"� 6 r� �IY1 tC/�l 1 ICG`Spacing exception req'd: YeP 4Vo Inclination -only svy req'd: Yf(�1 ffs allo r=J` i/ ( S (/k" W7 a fj P /0 fS Post initial injection MIT req'd: Y25 /0 as flne� C�GCor✓t-C av'a/'ht blc �asivz vbr-) r l v vrf-46 ' Lb 7- to �4D6Cc- a5 .5vo�cr5 avez/iat6le !-tv T L v d Fr -a C 5 fi' vl j Z c- J �C o� " APPROVED BY Approved by' COMMISSIONER THE COMMISSION Date: Form 1D'401 Revised 5/2017 This permit is valid for 24 months fORIG Irom the_date of approval per 20 AAC 25.005(g) Attachments in Duplicate �/� 19 ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 December 26th, 2018 Alaska Oil and Gas Conservation Commission 333 West 71h Avenue, Suite 100 Anchorage, Alaska 99501 Conoco Phil li s p Re: Application for Permit to Drill MT6-01 � Dear Sir or Madam: f"ry � � �} .T let ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore ' ction well from the MT6 drilling pad. The intended spud date for this well is January 315' 2019. It is intended that Doyon Rig 19 be used to drill the well. MT6-01 is planned to be a horizontal Alpine C sand producer. The 16" surface hole will TD above the C-30 sand and then 13- 3/8" casing will be set and cemented to surface. The intermediate hole will be drilled in two sections to mitigate issues with shale instability over the long interval. The 12-1/4" intermediate #1 section will be drilled into the top of the HRZ. A 9-5/8" casing string will be set and cemented from TD to secure the shoe and cover 500' above any hydrocarbon -bearing zones. The second intermediate will be drilled with one of two options, ultimately landing in the Alpine C sand. Option 1, a 7" steerable liner drilling assembly consisting of a 6" pilot BHA ahead of the casing shoe and incorporate a 8-3/4" underreamer for increased annular clearance. The drilling assembly inner string will then be tripped and a cement assembly run into the hole to cement the 7" drilling liner annulus. Option 2, will use an 8-3/4" drilling assembly and under reamed to 10 '/". The section will then be lined with a 7" Liner. Managed Pressure Drilling technology will also be utilized to assist with providing stability through the HRZ, Kalubik, and Miluveach formations. The production interval will be comprised of a 6" horizontal hole that will be geo-steered in the Alpine C sand. The well will be completed with a 4.5" liner with pre -perforated pup joints and tied back to surface with a 4.5" tubing upper completion string. It is requested that a variance of the diverter requirement under 20 AA( '25.035 (h)(2) is granted. At MT6, there has not been a significant indication of shallow, gas or gas hydrates through the surface hole interval. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a) 2. A proposed drilling program 3. A proposed completion diagram 4. A drilling fluids program summary 5. Pressure information as required by 20 ACC 25.035 (d)(2) 6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold layout as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Tom Polasek at 263-3740 (tom.g.polasek@conocophillips.com) or Chip Alvord at 265-6120. Sincerely, cc: MT6-01 Well File / Ann Haggerty- Sherrod ATO 1530 Johnson Njoku ATO 1720 Chip Alvord ATO 1570 Tom Polasek John Cookson ATO 1750 Drilling Engineer Application .or Permit to Drill, Well MTU MT6-01 Saved: 26-Dec-18 MT6-01 Application for Permit to Drill Document ConocoPhillips Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (1))............................................................ 3 2. Location Summary (Requirements of 20 AAC 25.005(c)(2))............................................ 3 Requirements of 20 AAC 25.050(b)............................................................................................................. 3 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) 3 4. Drilling Hazards Information (Requirements of 20 AAC 25.005(c)(4)).........................4 5. Procedure for Conducting Formation Integrity Tests (Requirements of20AAC 25.005 (c) (5)).......................................................................................................................... 5 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6))...........5 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)).......................... 5 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8))....................................6 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) ................................................................................................................................... 7 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10))..........................................7 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)).........................7 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12))...................................7 13. Proposed Drilling Program (Requirements of20AAC 25.005 (c)(13)) .........................7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal .......................9 (Requirements of 20 AAC 25.005 (c)(14))............................................................................. 9 15. Attachments..............................................................................................................10 Attachment 1 Cement Summary ................................................................................................................10 MT6-01 APD Page 1 of 17 Printed: 26-Dec-18 I Applicatioi i for Permit to Drill, Well MTU MT6-01 Saved: 26-Dec-18 Attachment 2 Drilling Hazards Summary..................................................................................................10 Attachment 3 Completion Schematic.........................................................................................................10 Attachment 4 Directional Plan.................................................................................................................10 MT6-01 APD Page 2 of 17 Printed: 26-Dec-18 Application ror Permit to Drill, Well MTU MT6-01 Saved: 26-Dec-18 1. Well Name (Requirements of 20 AAC 25. 005 69) The well for which this application is submitted will be designated as MTU MT6-01. 2. Location Summary (Requirements of20AAC25.005(c)(2)) Location at Surface 232' FNL, 3096' FEL, Sec. 6, T10N, R3E, UM NAD 1927 RKB Elevation . AMSL Northings: 5,945,571 Eastings: 317,135 Pad Elevation 52.1' AMSL Top of Productive Horizon Heel 3497' FNL, 631' FEL, Sec. 30, T11N, RM, UM NAD 1927 Northings. 5,952,804 Eastings: 319,748 Measured Depth, RKB: 11,845' Total Vertical Depth, RKB: 7,884' Total Vertical Depth, SS: 7,814' Total Depth Toe 3502' FNL, 335' FEL, Sec. 13, T11N, ME, UM NAD 1927 Northings: 5,963,469 Eastings: 315,319 Measured 23,529' tDepth,RKB: Total Vertical RKB: 7,777' Total Vertich, SS: 7,688' Requirements of 20 AAC 25.050(b) Please see Attachment 4: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information(Requirements of20 AAC 25.005(c)(3)) Please reference BOP and diverter schematics on file for Doyon 19. MT6-01 APD Page 3 of 17 Printed: 26-Dec-18 Application Tor Permit to Drill, Well MTU MT6-01 Saved: 26-Dec-18 4. Drilling Hazards Information (Requirements of 20 AAC 25.005 (c)(4)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size in Csg Setting Depth MD/TVD ft Fracture Gradient(psi) Pore pressure ASP Drilling (psi) 20 115 / 115 10.9 52 54 13.375 2061 / 2033 14.5 920 1330 9.625 9566 / 6917 13.5 3130 2779 7 11854 / 7885 12.5 3567 2741 4.5 23529 / 7777 12.5 3519 N/A PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb/gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP =FPP - (0.1 x D) Where: FPP = Formation Pore Pressure at the next casing point FPP = 0.4525 x TVD 1. ASP CALCULATIONS Drilling below conductor casing (20") ASP = [(FG x 0.052) - 0.1] D _ [(10.9 x 0.052) - 0.1] x 115 = 54 psi OR ASP = FPP - (0.1 x D) = 920 - (0.1 x 2033) = 717 psi Drilling below surface casing (13-3/8") ASP = [(FG x 0.052) - 0.1] D _ [(14.5 x 0.052) - 0.1] x 2033' = 1330 psi OR ASP = FPP - (0.1 x D) = 3130 - (0.1 x 6917') = 2438 psi 3. Drilling below intermediate casing (9-5/8") ASP = [(FG x 0.052) - 0.1] D = [(13.5 x 0.052) - 0.1] x 6917 = 4164 psi OR ASP = FPP - (0.1 x D) = 3567- (0.1 x 7885') = 2779 psi MT6-01 APD Page 4 of 17 Printed: 26-Dec-18 Application Tor Permit to Drill, Well MTU MT6-01 Saved: 26-Dec-18 4. Drilling below production liner (711) OR ASP = [(FG x 0.052) — 0.1] D = [(12.5 x 0.052) — 0.1] x 7777 = 4277 psi ASP = FPP — (0.1 x D) = 3539 — (0.1 x 7777) = 2741 psi (B) data on potential gas zones, The well bore is not expected to penetrate any gas zones. (C) data concerning potential causes of hole problems such as abnormally geo pressured strata, lost circulation zones, and zones that have a propensityfor differential sticking; Please see Attachment 2 - Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests (Requirements of20AAC25.005 (c)(5)) Drill out surface casing shoe and perform LOT test or FIT in accordance with the Alpine LOT / FIT procedure that ConocoPhillips Alaska has on file with the Commission. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) Casing and Cementin Program Csg/Tbg Hole Size weight Grade Conn. Length Top MD/TVD Btm MD/TVD Cement Program OD (in) pbir) (ft) (ft) (ft) 20 42 79 H-40 Welded 80 Surf 115 / 115 Cemented to surface with 10 yds slurry Cement to Surface with 13-3/8 16 68 L-80 BTC 2,027 Surf 2,061 / 2,033 949 sx DeepCrete Lead at 11.0 ppg, 331 sx Class G Tail Slurry at 15.8 ppq L-80/ 9-5/8 12-1/4 40 TN80 TXP 9,532 Surf 9,566 / 6,917 218 sx Class G Tail at 15.8 ppg HS 7 63/4 26 L-80 TS Blue 11,820 Surf 11,854 / 7,885 185 sx Class G Tail at 15.8 ppg 3-1/2 n/a 12.6 L-80 TS Blue 11,670 Surf 11,704 / 7,871 n/a 4 1/2 6 12.6 L-80 TS Blue 11,825 11,704 / 7,871 23,529 / 7,777 Uncemeneted open hole liner w/ pre - perforated pup joints 7. Diverter System Information (Requirements of20AAC25.005(c)(7)) It is requested that a variance of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. At MT6, there has not been a significant indication of shallow gas or gas hydrates through the surface hole interval. MT6-01 APD Page 5 of 17 Printed: 26-Dec-18 Application for Permit to Drill, Well MTU MT6-01 Saved: 26-Dec-18 8. Drilling Fluid Program (Requirements of20AAC25.005(c)(8)) Surface Intermediate Intermediate production #1 #2 Hole Size in. 16 12.25 6.0 x 8.75 6.0 Casing Size in. 13.375 9.625 7 4.5 Density PPG 9.0 — 10.0 • 9.4 — 10.5 10.0 — 11.2 • 8.8 PV cP 13 10 10 15 Ib./100 YP 35-50 20 - 28 20 - 28 15 - 20 Funnel s/qt. 200 40 - 50 40 - 50 60 - 80 Viscosity Initial Gels Ib./100 50 10 10 10 10 Minute Ib./100 Gels ftz 60 15 20 15 API Fluid cc/30 Loss min. N.C. — 15.0 5.0 5.0 4.0 HPHT Fluid cc/30 Loss min. n/a 8.0 — 12.0 8.0 — 12.0 10.0 pH 11.0 9.5-10.0 9.5-10.0 9.0-9.5 Surface Hole: A mixed -metal oxide fresh water drilling fluid (Drilplex) will be used for the surface interval. Keep flow line viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight <10.0 ppg by use of solids control system and dilutions where necessary. Intermediate #1: Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. Maintain mud weight from 9.4-10.5 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Intermediate #2: Fresh water polymer mud system. Ensure good hole cleaning by maximizing fluid annular velocity. There is a slight potential for lost circulation, particularly after the reservoir is penetrated. Ensure adequate LCM material is available on location and in the field to address any expected losses. Maintain mud weight from 10.0-11.2 ppg. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. The mud will be weighted up to 10.3 ppg or higher before pulling out of the hole. Note: Managed Pressure Drilling (MPD) will be utilized for adding backpressure during connections to mitigate shale instability and cycling. Production Hole: The horizontal production interval will be drilled with a oil -based mud drill -in fluid VersaPro weighted to 8.8-9.5 ppg with calcium carbonate. MPD will be used to hold back pressure, keeping the well dynamically balanced. Diagram of Doyon 19 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. MT6-01 APD Page 6 of 17 Printed: 26-Dec-18 i Application for Permit to Drill, Well MTU MT6-01 Saved: 26-Dec-18 9. Abnormally Pressured Formation Information (Requirements of20AAC 25.005 (c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of20 AAC 25.005 (c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of20AAC25.005 (c)(11)) N/A - Application is not for an offshore well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of20AAC25.005 (c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic. 1. MIRU Doyon 19 onto GMTU MT6-01 over pre -installed 20" insulated conductor. 2. Rig up and test riser, dewater cellar as needed. 3. Drill 16" hole to the surface casing point as per the directional plan. (LWD Program: GR). - 4. Run and cement new 13-3/8" 68 ppf L-80 surface casing to surface. 5. Install BOPE with the following equipment/configuration: 13-5/8" annular preventer, 3-1/2" x 6" VBR, blind ram and 3-1/2" x 6" VBRs. 6. Test BOPE to 250 psi low / 3500 psi high (24-48 hr. AOGCC notice, 72 Hr BLM notice). 7. Pickup and run in hole with 12-1/4" drilling BHA to drill intermediate #1. 8. Chart casing pressure test to 2500 psi for 30 minutes. 9. Drill out shoe track and 20' of new hole. 10. Perform LOT to maximum EMW of 18.0 ppg. Minimum LOT required to drill ahead is 12.5 ppg EMW. Forward data to the AOGCC. 11. Displace well to 9.4 ppg LSND mud. 12. Drill 12-1/4" hole to the casing point as per directional plan. (LWD Program: GR/RES). 13. Circulate wellbore clean and POOH. 14. Change upper VBRs to 9-5/8" solid body rams. Test same to 250 psi low / 3,500 psi high. 15. Run 9-5/8" intermediate casing to TD. 16. Pump single stage cement job to isolate the casing shoe and 500' MD or 250' TVD, whichever is larger, above uppermost hydro -carbon bearing zone (none expected). 17. Change upper 9-5/8" solid body rams to 3-1/2" x 6" VBRs. Test BOPE to 250/3500 psi. 18. Pick up and run in hole with 8-3/4" bit and clean out assembly. Perform a LOT down the 13-3/8" x 9 5/8" casing annulus with Ball Mill and freeze protect. Forward data to AOGCC. 19. Pressure test casing to 3000 psi for 30 minutes and record results. 20. Drill out shoe track and 20' of new hole. MT6-01 APD Page 7 of 17 Printed: 26-Dec-18 f Application for Permit to Drill, Well MTU MT6-01 Saved: 26-Dec-18 21. Perform FIT to 14 ppg EMW. Minimum required to drill ahead is 12.5 ppg EMW. 22. Circulate wellbore clean and POOH. 23. Perform either Option 1 or Option 2 Option 1 a. Pick up and run in hole with the 7" steerable drilling liner. Pick up and stab in 6" pilot BHA assembly. (LWD Program: GR/RES). - b. RIH to bottom with 7" SDL on 5" drill pipe. c. Drill 6" x 8-3/4" SDL hole to production casing point into the Alpine sand using Managed Pressure Drilling to maintain constant bottom hole pressure on connections. (LWD Program: GR/RES). d. Land 7" liner at TD. Disconnect SDL and POOH to surface with inner string and pilot. e. Run in hole with inner string cementing BHA. Stab into liner. Circulate and condition mud in preparations for cementing. Option 2 a. Drill 8-3/4" x 10'/4" Int. 2 to production casing point into the Alpine sand using Managed Pressure Drilling to maintain constant bottom hole pressure on connections. (LWD Program: GR/RES). b. Circulate hole clean and POOH. c. Pick up and run 7" liner to TD. d. Circulate and condition mud in preparations for cementing. 24. Cement 7" liner from shoe to 250' TVD above Alpine Formation. Set liner top packer. Circulate bottoms up from top of liner. POOH laying down 5" drill pipe. 25. Run 7" tie -back and engage seals. Space out to land hanger. 26. Displace 9-5/8" x 7" annulus to corrosion inhibited brine and diesel freeze protect. Land the 7" tie back hanger and pressure test annulus and seals to 2000 psi for 30 min and chart. 27. Pick up 4" DP. Test BOPE to 250 psi low / 3,500 psi high. 28. Pick up and RIH with 6" drilling assembly. (LWD Program: GR/Azimuthal RES). 29. Chart casing pressure test to 3500 psi for 30 minutes and record results. 30. Drill out and perform FIT to 12.5. Minimum acceptable leak -off for drilling ahead is 11.0 ppg EMW. 31. Drill 6" horizontal hole to section TD (LWD Program: GR/ Azimuthal RES). 32. Circulate the hole clean and POOH with drilling BHA. 33. Run in hole with 4.5" liner with pre -perforated pup joints on 4" drill pipe. 34. Set liner top packer and release from liner. 35. Displace well to kill weight brine. 36. Run 3.5" upper completion. 37. Space out and land hanger. 38. Install HP back pressure valve and pressure test hanger seals to 5000 psi. Nipple down BOP. 39. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove back pressure valve. 40. Test tubing to 3500 psi/ 30 min and chart. Test tubing -casing annulus separately to 3300 psi / 30 mins and chart. 41. Shear circulation valve in GLM. 42. Circulate tubing to diesel and install freeze protection in the annulus. 43. Set BPV and secure well. RDMO. MT6-01 APD Page 8 of 17 Printed. 26-Dec-18 Application for Permit to Drill, Well MTU MT6-01 Saved: 26-Dec-18 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005 (c)(14)) Incidental fluids developed from drilling operations on well MT6-01 will be injected into a permitted surface casing x production casing annulus on the MT6 pad or dedicated Class 1 disposal well CD1-01A. The MT6-01 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 1200' TVD. Significant hydrocarbon zones include only the Alpine sand based on pre -drill interpretations. There will be 500' MD, or 250' TVD, whichever is greater, of cement placed above the top of the Alpine reservoir. Once MT6-01 has been drilled and completed, consideration may be given to permit this well for annular injection. An application for Sundry Operations form 10-403 will then be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080 could then begin once properly permitted. As stated above, any - zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,033') + 1,500 psi = 2767 psi Pore Pressure = 920 psi Therefore Differential = 2767 — 920 = 1847 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt Grade Range Connection Collapse 85% of Burst 85% of (ppf) Type Collapse Burst 13-3/8" 68 L-80 3 BTC-M 2260 psi 1921 psi 5020 psi 4267 psi 9-5/8 40 L-80 3 BTC-M 3090 psi 2626 psi 5750 psi 4887 psi MT6-01 APD Page 9 of 17 Printed: 26-Dec-18 Application Tor Permit to Drill, Well MTU MT6-01 Saved: 26-Dec-18 15. Attachments Attachment 1 Cement Summary Attachment 2 Drilling Hazards Summary Attachment 3 Completion Schematic Attachment 4 Directional Plan MT6-01 APD Page 10 of 17 Printed. 26-Dec-18 Application for Permit to Drill, Well MTU MT6-01 Saved: 26-Dec-18 Attachment I — Cement Summary GMTU MT6-01 wp02 Proposed Casing & Cementing Schematic (Updated December 18. 20 18) 167 Open Hole Planned TOC -9.066• 161D I 15.8 ppq Tail Class 0 slurry Planned Top of 7" Liner Q.411 TIVID ? U25-TVID .. ... .. ... .. ... 1-.11 12-*,47 Open Hole Planned TOC -10,106'MD; 7.GU'TVD 15.13 ppg class 0 slurry 6" x V,+ Open Hole r Open Hole 23,527 MD! 7,77T TVD 20-H-40Welded Conikctor 1.151 ................... 13-318- 68N L-80 TXPA3TCM 2,0el'MW2,033'TVD ... .. ... .. .. ... . Z .!nc'.2 .-.i . .. ... 7- 26# L-80 TS Blue Tie ................. 9-5W 40# L4d nW-80 UP Liner 9.SWMDI5.91TTVD .............. . 7- 26# L-00 TS Blue Liner 11,854'MD I 7j3B5'TVD ... .. .. ... .. ... 12fW 1-40 TS Blue Liner with PeTf Pups MT6-01 APD Page 11 of 17 Printed: 26-Dec-18 Application for Permit to Drill, Well MTU MT6-01 Saved: 26-Dec-18 13-3/8" Surface Casing run to 2,061' MD / 2,033' TVD. Cement from 2,061' MD to 1,561' (500' of tail) with Class G + Adds. @ 15.8 PPG, and from 1,561' to surface with 11.0 ppg DeepCrete. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost, zero excess in 20" conductor. Lead slurry from 1,561' MD to surface with DeepCrete @ 11.0 ppg Conductor (115' — 36') X 1.0190 ft3/ft X 1.0 (0% excess) = 81 ft3 Permafrost to Conductor (1,100' — 115') X 0.4206 ft3/ft X 3.5 (250% excess) = 1,450 ft3 Top of Tail to Permafrost (1,561'— 1,100') X 0.4206 ft3/ft X 1.5 (50% excess) = 291 ft3 Total Volume = 81 + 1,450 + 291 = 1,822 ft3 => 949 sx of 11.0 ppg DeepCrete @ 1.92 ft3 /sk Tail slurry from 2,061' MD to 1,561' MD with 15.8 ppg Class G + additives Shoe to Top of Tail (2,061'-1,561') X 0.4206 ft3/ft X 1.50 (50% excess) = 316 ft3 Shoe Joint (80') X 0.8407 ft3/ft X 1.0 (0% excess) = 68 ft3 Total Volume = 316 + 68 = 384 ft3 => 331 sx of 15.8 ppg Class G + additives @ 1.16 ft3/sk 9-5/8" Intermediate casing to 9,566' MD / 6,917' TVD Cement 500' up from 9-5/8" casing shoe from 9,566' MD to 9,066' MD. Assume 30% excess annular volume. Tail slurry from 9,566' MD to 9,066' MD with 15.8 ppg Class G + additives Shoe to Top of Tail (9,566'— 9,066') X 0.3132 ft3/ft X 1.40 (30% excess) = 219 ft3 Shoe Joint (80') X 0.4257 ft3/ft X 1.0 (0% excess) = 34 ft3 Total Volume = 219 + 34 = 253 ft3 => 218 sx of 15.8 ppg Class G + additives @ 1.16 ft3/sk MT6-01 APD Page 12 of 17 Printed: 26-Dec-18 Application for Permit to Drill, Well MTU MT6-01 Saved: 26-Dec-18 7" Intermediate liner run to 11,854' MD / 7,885' TVD Top of slurry is designed to be 250' TVD above top of Alpine C Sand. Assume 30% excess annular volume. 6" x 8-3/4" underreamer to be 100ft behind the drill bit. Main slurry from 11,854' MD to 10840' MD with 15.8 ppg Class G + additives 8-3/4" Hole to Top of Slurry (11,854' — 10,840') X 0.1503 ft3/ft X 1.30 (30% excess) = 198 ft3 Shoe Joint (80') X 0.2148 ft3/ft X 1.0 (0% excess) = 17 ft3 Total Volume = 198 + 17 = 215 ft3 => 185 sx of 15.8 ppg Class G + additives @ 1.16 ft3/sk MT6-01 APD Page 13 of 17 Printed: 26-Dec-18 Application for Permit to Drill, Well MTU MT6-01 Saved: 26-Dec-18 Attachment 2 — Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 16"' Hole / 13-3/8" Casino Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low First well on Pad, traveling cylinder diagrams Gas Hydrates Low If observed — control drill, reduce pump rates and circulating time, reduce mud temperatures Clay Balling Medium Maintain planned mud parameters and flow rates, Increase mud weight, use weighted sweeps, reduce fluid viscosity,control ROP Abnormal Pressure in Low Diverter drills, increased mud weight. Shallow Surface Formations hazard study noted minimal risk Lost Circulation Medium Reduce pump rates, mud rheology, add lost circulation material, use of low density cement slurries port collar, control pipe running seeds 12-1/4" Hole / 9-5/8" Casino Interval Event Risk Level Mitigation Strategy Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring,MPD stripping ractices Abnormal Pressure in Low Well control drills, check for flow during Overburden Formations connections, increase mud weight. Shallow hazard study noted minimal risk Hole Cleaning Low Monitor ECD and torque/drag trends, control drill and use best hole cleaning practices 6" x 8-3/4" Hole / 7" Liner - Casino Interval Event Risk Level Mitigation Strategy Sloughing shale, Tight High i MPD for shale stability, Steerable Drilling Liner, hole Increase mud weight, control ROP, connection and trip speeds, sweeps, and real time equivalent circulating density (ECD) monitoring, run casing as liner Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring,Liner will be in place at TD Abnormal Reservoir Low Well control drills, check for flow during Pressure connections increase mud weight Hydrogen Sulfide gas Low HzS drills, detection systems, alarms, standard well control practices, mud scavengers MT6-01 APD Page 14 of 17 Printed. 26-Dec-18 Application for Permit to Drill, Well MTU MT6-01 Saved: 26-Dec-18 6" Hole / 4-1/2" Pre -Perforated Liner - Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring Abnormal Reservoir Low Well control drills, check for flow during Pressure connections increased mud weight Differential Sticking Low Uniform reservoir pressure along lateral, keep pipe moving,control mud weight Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers MT6-01 APD Page 15 of 17 Printed: 26-Dec-18 Application for Permit to Drill, Well MTU MT6-01 Saved: 26-Dec-18 Well Proximity Risks: MT6-01 will be the eighth well drilled on the pad. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in the following attachments. Drillina Area Risks: Reservoir Pressure: Offset production has the potential to reduce the reservoir pressure. LCM material will be on location to deal with losses. Weak sand stringers could be present in the overburden. LCM material will be available to seal in losses in the intermediate section. Lower Shale Stability: HRZ/Kalubik/Miluveach in the intermediate #2 hole sections will require higher mud weights than historically used to enhance wellbore stability. Steerable Drilling Liner may be used and Managed �— Pressure Drilling will be used in conjunction with a 4-string casing design to mitigate shale instability. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. MT6-01 APD Page 16 of 17 Printed. 26-Dec-18 Application for Permit to Drill, Well MTU MT6-01 Saved: 26-Dec-1 8 Attachment 3 -Completion Schematic MT6-01, Contigency Completion Schematic WP02 20"79 ppfH-40 Insulated Conductor 80 fee., cemented to surfaoe 13-318" 1138 ppf L-80 TXPj'BTCM Surface Casing @2O6I'hlDI_M33TVD 0 cernenied to surface 3-I12119-3 ppf L-80 EUE to 7" 26 ppf L-80 TS Blue Tie Back 9 518" 40 ppf L-SO TXP (to 7,652'MD) 9 W 40 ppf T"O HS UP (to TD) @ C4,56 T1,101 6.9 ITTVD 0- .0 ak G) TOC at Least 300100 above Packer & 500' MD above Alpine C. Planned to Uner Top. 0 Top Allpirke C 11, 854'&ID 17,8841 TVD T'26 ppf L-80 TS Blue Liner to 11,854'MD I 7,884'rVD @ 86 deg Attachment 4 - Directional Plan MT6-01 Tubing f Liner Completion 1) 3-$4.- Land fing Nipple (2.813- ED) 2) 3-'A-"x 1"GLM 3) 3-!A.'x l'GLM 4) SLE OH3 5) 3-IT x 7" Premier Packer 0) 3-16Landing Nipple (2-213' ID) set at -J4 deg 7) Liner Top PackerlHanger wl Tie Back sleeve El) 4 IW TXP Blank Pipe Q) 4' -' BTC Frac Sleeves 10) 4 WTXP Perforaled JDnI 4-W' 12-6# L40 TXP With Frac Sleeves (D GD 6" Hole, TD at - at 23,529'MD/7,777TVD MT6-01 APD Page 17 of 17 Printed: 26-Dec-18 V am L O CL N4) I.L E E cn ■i co 0 N d v d 0 00 T- 0 In�C� " w(O C O W[V•]W D t5 z � W a a s =E O m N O O ^ M Wow m rn o T O> 0 0 > > - O O U ° U O- f0 0 o a O N U N 00 N_ 0 ,�Qq] �` ,�Qp��\ V V O N Y N U > N _ O O O U _ J d' v a — :E 2i v � rn E E� c c' c a c ,O3 > > y CD W > a c ° '= U N L J J (7 o- m W � C ° a0 C d U A C O O ❑ d O w d m U H U y L d a 0 0 « N o ❑ > F g z in 0 C) N r O rn M C , u n a 0 0 L) o o� •� a c rn A L � � z N O Z W U) N m U) c (6 N (0 Q CL O U) L o 0 o z o -- C N w In O O_ U a Ocu E U) x 0 a N O t w U 3 ° z Y C ° a) Z N 0CL O O O W o m O O J m a r 7 N a _= t O Y Cl. n O :� m N C� a z °0 3 �� m Q O 0 0 0 c F U)Q (0 N co c0 co Z Q s �a r v O w C C .O O C m m fN ❑ N a y V _ O C1 N d N C a 0 6 r O wd..u.a° N 0a`N33o a` �c7� in in N N N N O N O O r- M Ln Lo r` v c- O M Lo Q) a Lo a ai O a U a, ol m a If O cCL dw 0 Q �a V O c a_ a- m m > T no .4 c N ni O 3 3 O O 3 of o o a OD 00 Y O O O 3 (6 w (0 U g 2 M v N E (0 7 C ~ 2 ow T C.. a O C m a a p 0: m m a vain33o N L U U U U U U U U O U U U U CD N N N N .N a V a V a V a U Om Y -o Y a Y a Y O m ix LL K m x o �inLL nLLU)LLw o o >o> o >$ o 0 0$ d >. y > o (D 2 2 2 2 CO N N N N U U U U (n Q Q Q Q C) (n E LL LL LL LL z U + + + + F C7 N O O O O O O O o 0 m O O O O O O O O o 0 of o o 6 6 ri vi y M 00 o m o r r 4. o 0 o c O O oc m E N N m m p O H m co Oca m o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o 0 m � o M o -a 'j O O O O O o O O o o o o o o o 07 N 00 00 bo 07 co co a0 V co V co V co V W V ro V W V W N. r_ O N N N N N N N N N N N (N N N N p O Lo z) Lo Lo Lo u� In Ln In N V7 z1 zl Lo z z z z z z z z z z z z z z z N N N N N N N N N N N N Lo m c0 m N N N O N m N m N m N m N m N z) N m N z7 N z7 N N N O N O M .0 - CM N M N to M N M N V0 M N zi M N z7 M N z1 M N 4� M (N 4) M N z) M N o M N o M N u1 m N �o M N m O V J O o o o 0 o o 0 o o o o o o o r r r r r r r r r r r r r r r 5 y N u7 �M - r c)c—)M L6 r L6 m M N M L6 M m M N M ui m M N co M _ 6 M M u) co r M N m m N o co m m co l0 � " M M M w N N N N N N N N N N N N o r co N N N N N N N N N N N N u� m m r r r r r r r r r r r r r rV m � C lf Ln N Lo 47 m V) N Lo LO 6 u) Lo lo Ln V7 Ln LO m t � t+ N V m V m V m V m V m V m V m V m V m V O V m V m V O C' O V m O z u) u) Ln 'n u) m m v) m O O O O O O o o o O 0 o O o O o O o o O O o o O O O O O O O O O O O O O M O o M r O u m N N O O O O O O O O O O o O 0 O 0 O o O o O o O O O �n N N N O O O O O O O O O O O o N N N a, J cD 0 O N O O O O O O O O O O O O O O O O O O O O O O O O N m N o Cl) _ _ (o _ O O N co V' o o r o m m O N c O m o O O O O O O O O O O O O O O O O O O O O O O O N m N o o O O O O O O O O O O m O m m M O � O N O M O V O m o o O r O o O m O O In O O m m N t 3 O O o O O O O O O O O O O O o O O o O O O O O O O O O O O O O O O O O O O M N O M N o M N N a 0 O 0 O 0 O 0 O o O o O o O o O o O 0 O 0 O 0 O O o N M Lo � C O N m N N O m cj O o O 0 o 0 O 0 o O O o O 0 O 0 O 0 o 0 O O 'a O O a J 0 o 0 0 T C) o M d o V O O O O o O O o O o O O O O o O O o O z] j o m o 0 O o O C �- N M V In o r o m c O N M N o If — m c O c a a ! i 3 3 m N N n O m m 1- N V m �- m o (O n V n n m M m m a ,a M O m m n n m M O p�. 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(n O) to D) �n O D) (n LO d) to W (D O (n W W (n (n O (n O m O (n Q) Ln Q) (n O (n W m W (o Q) (n O (D Q1 m Q) )n Q) Ln z m m (n m (n N V' m _ N M V N N M N m V' r M V' (n N r O OR m O Cl) N O N m (D V m M r (n V r O V m N (O O V' V' V m N m In a) M M V V' M r m )n r (D m r to m () O W D) O O In O m O m O V M NM M N 'IT((] N (O O 7 r r V r V r V r O m D) m U ^,� V m V V V V' V r 'V Vn V) (D (D m (D (n m (n (n (n (n (n �n (n (n 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O O o O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O O O O O O (V N N O O O O O O O O O N N O O N V m m m r m O m W O r O W N r r m N m (D m m O CV (D N m M m m m m m m r m m V 0)Dl r N m V O m In m M N N N � O O M m m r r r r r c0 0 N m O r m m r r m r: m r m r m r m r m r m r m r m r m r r rl-i r r r r r r r r: r r r r r r r r � w N V (0 m O D) r d) (V CO CO O O N M m m m r m D) D) m r m m O O r r N (n m N (n m OR m OR m V' r r M M (n V V N O W W m r r m m m m m (n O m m m m r m m r m r m r m r m r m r m r m r m m m m m m m m m m m m m m m (D m m m m m m m � r r r r r r r r r r r r r r r r r r r r r r r m m r r m r m r m r m r m r N O m m m m m m m m m m m m m m m N N N N N N N M C) C') M M M M M M M 6 CM M M M M = M 0 M M M Cl) co M M M Cl) M M co m co M Cl) M M M M Cl) Cl) M M co M co Cl) M M M M C) Cl) M M M Cl) M M co M Cl) M E N R N Q O v v M M v Cl? v M v M v M v M o o 0 0 0 0 0 0 0 0 0 rn m m m N N N N N N N O O O O O O O o O O O O m O O O m m m m m m a m rn o M 0)m m m m m m a)m a) m m m m 0 Go C N N O w O a m LL ~ a ILL- ILL- O. a G O L C O L O O 0 0 O 0 O 0 O 0 o N V' y v O o M C' 0 a v O o O 0 O 0 O 0 O 0 O O O o— C') NM v N W F CO N — O 0 O 0 Tj O O OQ) OO O O o O N O O M I- M M rM O V (O (O M O n O CO O r O m O (D O O O O - (O Cl) 'M41 r Cl) o O N 0 0 M NL= D) 0 N O N O N O N OV N N N O O O O O ( N N— _ F N R N N N a C �.m C a 0 LO a m O LO a Y a (n N CC) m a s � a o E V E O Co O C U 0 V) a ko U O c V C C C C R R a d W rn C C O O 00 N N O O O = a co m w a Y o m4 �j m 2 g v a a w C a E O U n 0) O n v R 0) R n m O O M m Ci n (mo N 7 (O = R (A O N (V N M N V N N N n N 1� N n N m O N N Im C W m Q) m 01 Q7 d) a) b) m O) O) O N N N N N N N N N N N N J �- o 0 0 0 0 0 0 o e z z z z z z z z z z z z 0) (O M R m M N 7 n N R m O 7 O N R m (O n N m 7 M M V V O O N R N ,a O r r N M V Ln m m m n n = R R R R R R R R R R R R R J O O O O O O O O O O O O n n n n n n n n n n n r V R O N N N M (i M N R M o'r V m N N R co M m O V N O N r r n O N O m m � O M Q1 m 0) O m ccR N N R = W M (M M CM M C) M N] M Cl) co M � o O ci (O N Cn n N N N M V V V V m N Cn 7 V ((1 n O m O O W N M C r S m (A m W m W m O m (A cN0 m (ND 61 (No m (No m CND O coN(NO m W pN u) (n N (n N Lo in N Cn N Cn to z N G) O N V (00 � m m �2 O) (D co O R n N m M m `7 R m Lo (q Lo e m m V' O n oc CA N 0 O 0 O 0 O 0 O o O o O o O O O o O o O o o O O O O O O O o O O O O N N M_ m m m m O m n O 0) N V n7 d• R V 7 V M O W Lo V V M N (V Om mi m p m ,2 m O � m O M n O O) N V' n V R 7 V V C) O In C M M N O O O R N m m m m m m m m m m U) (n R R R ococR R ocR o R oc ZF n n n n n n n n n n n n m m m m m m m m m m rnR (nm L M CI M m M M M M M M M M M M M co M M M M N N (o C) 7 M Co M Co Co M M M M M (7 M E N ° v R N Q O N O) N O n m M Ln N ll7 m M M N m O O Om) (`07 N N M M M M co M M M O m a) O D) O) a) T O O N N N N N N N N N N z z z z z z z z z z 0oo 00 O M 04 Ci N cq O O (00 lmn n co co co co m O O O eo bo ao ao ao ao _ ao r co co m r O O O O O O r r M (00 N 001 N V Ci (Uo oq ro ro m Oc ro m n � � m Cn (o R M m (n N u) h M co Cl) Cl) M Cl) Cl) M Cl) Cl) V r O co N Iq N (In r O M1 n N Lo Lo Lo IT co (o M cl m (p C) M (O <f V IQ n Lo n Lo C0 (O N n Cn Cn N N m Lo m )o (n In co 0) M (On (mo M 000 O co � CA R 6 (n N m (n V 6 M 0R oo Om0 Om0 OM) O O Lo O N N m m m m m n O O O O O O O N O O O O O O O O O u) O O N O O O O O O O O O O m V N Cl) 0) O co m N O O M o•) 0) n O 0) m N CCD ((oo coN(ND Vo if) V) Q' V M n n n n n n n n O (o V N Cl) O) O R m N O O CM (M m n O O m N V) CO (D O C) R V R Lo R N (n V 7 co M M N R R 00 ooR R ocR R R n n n n n n n r- n n Lo ((q m m m IQ (mo (mo m (mo (mD N N N N N N N N N N Cl) M OM•) M co Cl) M co M co Q. 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HYDRAULIC KNIFE VALVE 16" OD DIVERTER LINE 20" 94 ppf CONDUCTOR PIPE GMTU MT6-05 Sundry Attachements Page 1 of 28 Printed: 17-Jan-19 BOP Schematic EMMMf_=IMMM RKB How Box Flow tine Center uvadi ^cK^ Annular Preventer Bottom Annular Preventer Center HYDRIL Upper Rams Center HYDRIL Blind Rams KW C Center HYDRIL Lower Rams ULDS LLDS LR GL *All ram measurements are to the middle of the ram body and from RKB BOP Equipment • 1 ea. - Hydril annular SOP, model MSP, 21 1/4" x 2000 psi, flanged, NACE trim • 1 ea. - Hydril annular BOP, model GK, 13 5/8" x 5000 psi, flanged, NACE trim • 2 ea. - Hydril single gate, model MPL, 13 5/8" x 5000 psi, flange x flange, NACE trim with ten inch operators • 1 ea. - Hydril single gate, model MPL, 13 5/8" x 5000 psi, flange x flange, NACE trim with fourteen inch operators • Stack is moved by 2 ea., 20 ton hydraulic BOP cranes controlled by a remote console • Rams are handled with a hydraulic winch in the cellar BOP Closing Unit • 1 ea. — Hydril, 8 station, 3000 psi, 165 gallon accumulator unit • Primary closing hydraulic power is provided by an electrically driven triplex pump with adequate high pressure hydraulic bottle storage. • Secondary system back-up is a 30:1 air pump, and emergency tertiary back-up closing pressure is provided by a four -bottle, high pressure nitrogen rack. The PLC controlled remote closing BOP operator panels are located in the doghouse, accumulator unit and the utilities module. GMTU MT6-05 Sundry Attachements Page 2 of 28 Printed: 17-Jan-19 Rig Choke Manifold MATERIAL LIST —item esengton A 1-1116'tOhl Remote operated dro t Choke_ B 3418' SM Adjustable Choke 1,2.5 2.1116- 5M Manual Cafe Valr! $,d,8-18 � 3.1(8" 5M Malwal Gate valve RIG - 19 LEDGEND White Handle Valves Normally Open Red Handle Valves Normally Closed y1 Date: 11;!! Rev. 1 Divert 1 Line MWIL4/8MI6 /ncs erne GMTU MT6-05 Sundry Attachements Page 3 of 28 Printed: 17,1an-19 Loepp, Victoria T (DOA) From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Thursday, January 17, 2019 2:52 PM To: Loepp, Victoria T (DOA); Dai, Weifeng Subject: RE: [EXTERNAL]CD5-24(PTD 219-006), MT6-01(PTD 219-002) Hi Victoria, Very valid question and we should have done a better job at explaining this situation. We may drop (not drill) MT6-01 depending on what the reservoir quality looks like in MT6-02, the neighboring well to MT6-01. If the reservoir quality is low on MT6-02 we will not drill MT6-01 and will move the rig over to CD5 and drill CD5-24. The decision to drill either MT6-01 or CD5-24 will likely be made sometime between Jan 19 and -Jan 25. Feel free to call or email if you would like to talk about this more or have more questions. Thanks Victoria, Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Thursday, January 17, 2019 1:54 PM To: Polasek, Tom G <Tom.G.Polasek@conocophillips.com>; Dai, Weifeng<Weifeng.Dai@conocophiIli ps.com> Subject: [EXTERNAL]CD5-24(PTD 219-006), MT6-01(PTD 219-002) Both of these PTDs have a Spud date of 2/1/2019 using Doyon 19. What's happening here? Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoeppCa'balaska. 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 AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.aov l ll:GMT III, ,-01 <== Data Input e: V Loepp <== Data Input Mud Weight (ppg) 8.80 <_= Data Input Weak point or LOT - Measured depth (ft) 2,061 Weak point or LOT True vertical depth (ft) 2,033' <_= Data Input Weak point or LOT - Hole angle (deg) 22.70 — Data Input Weak point or LOT - Hole size (in) 13.375" <_= Data Input Weak point pressure or LOT - EMW (ppg) 12.50 — Data Input — Data Input Zone of interest - Measured depth (ft) 11,704' <== Data Input - Zone of interest - True vertical depth ft p ( ) 7,871' Zone of interest - Hole angle (deg) 82.7° <_= Data Input Zone of interest - Hole size (in) 9.625" — Data Input Zone of interest - Pore pressure EMW (ppg) 9.50 — Data Input — Data Input Gas gradient (psi/ft) 0.10 1 <_= Data Input Bottom hole assembly OD (in) 8.0" <_= Data Input Bottom hole assembly length (ft) 200' — Data Input Drill pipe OD (in) 5.500" <== Data Input BHA annular vol. @ zone of interest (bbl/ft) 0.0278 DP annular vol. @ zone of interest (bbl/ft) 0.0606 DP annular vol. weak point bbl/ft 0.1444 Weak point pressure PIO 1,321 psi Weak point pressure - Safety margin: Max anticipated formation pressure (psi): Weak Pt to Zone of Interest distance (TVD ft): Pmax Pmax EMW Pf OH {TVD) 1,321 psi 12.50 ppc 3,888 psi 5,838' Weak Pt to Zone of Interest distance (MD ft): OH {MD} 9,643' Maximum influx height at the bit (TVD ft): H (TVD) 293' Maximum influx height at the bit (MD ft): H {MD) 2,297' Calc. volume of (H) around BHA: Calc. volume of (H) around drill pipe: Calc. volume that H equals @ initial shut in: V1bha V1 dp V1 5.6 bb/ 127.1 bbl 132.6 bbl Calc. vol. that H equals @ weak point (MD ft): VWp 45.8 bbl Calc. volume of Vwp @ initial shut in: V2 15.6 bbl Kick Tolerance: V2 15.6 bbl Davies, Stephen F (DOA) From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Monday, January 7, 2019 7:19 AM To: Davies, Stephen F (DOA) Subject: RE: [EXTERNAL]RE: GMTU MT6-01 (PTD 219-002) - Request Attachments: GMT1 Conductor As -Built CE-MT60-1007_Rev1 .pdf Hi Steve, My apologies. 1. MT6-01 is a Producer. There is no planned injection aside from a possible Frac. 2. Ground Level = 44.8 ft MSL, Existing Pad Level = 52.1 ft MSL, RKB = 89 ft MSL (That gives and air gap from rig floor down to pad of 36.9 ft) (As Built attached) Thanks tom From: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Sent: Friday, January 04, 2019 2:22 PM To: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Subject: [EXTERNAL]RE: GMTU MT6-01 (PTD 219-002) - Request Tom, While reviewing CPAI's Permit to Drill application I noticed that the Permit to Drill form has the box labeled "Development - Oil" checked, but CPAI's cover letter for the application states that MT6-01 is "...an onshore injection well...". Which is correct? If this will be an injection well, the application is missing Area of Review, confinement, and well integrity information (please contact Victoria Loepp for further more specific requirements). On a minor note, the KB and ground level values shown on the application form do not match those shown in the "Location Summary" table on page 3 of the supporting documentation. Which values are correct? Thanks for your help, Steve Davies Senior Petroleum Geologist AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies, Stephen F (DOA) Sent: Friday, January 4, 2019 12:49 PM To:'Polasek, Tom G' <Tom.G.Polasek@conocophi llips.com> Subject: RE: GMTU MT6-01 (PTD 219-002) - Request Tom, To keep this permit moving along the AOGCC's review process, I scanned and converted the directional data. So, disregard my previous request. Steve Davies Senior Petroleum Geologist AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies, Stephen F (DOA) Sent: Friday, January 4, 2019 10:14 AM To:'Polasek, Tom G' <Tom.G.Polasek@conocophillips.com> Subject: GMTU MT6-01 (PTD 219-002) - Request Tom, If you're in today and it's convenient, could CPAI please provide the planned directional data for this well in Excel spreadsheet or ASCII table form? That would help speed my review. Otherwise, I must scan the printed data, convert it to digital data, and quality control the converted data before loading it into my mapping software. Thank you for your help, Steve Davies Senior Petroleum Geologist AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. Remark: AOGCC Permit to Drill 219-002: Coordinate Check 7 January 2019 INPUT Geographic, NAD83 OUTPUT State Plane, NAD27 5004 -Alaska 4, U.S. Feet Accuracies of conversions from NAD 83 to NAD 27 are typically 12 to 18 cm. MT6-01 1/1 Latitude: 70 15 22.00700 Northing/Y: 5945571.228 Longitude: 151 28 52.03200 Easting/X: 317135.098 Convergence: -1 23 28.10601 Scale Factor: 0.999937987 Datum Shift (m.): Delta Lat. = 38.571, Delta Lon =-118.045 Corpscon v6.0.1, U.S. Army Corps of Engineers REV I DATE I BY I CK I APP I DESCRIPTION REV DATE I BY Ch APP DESCRIPTION 1 02/24/18 RR I CZ I GH I UPDATED PER K180003ACS ALPINE SATELLITE DEVELOPMENT C 5 N GMT1 TO ALPINE , g, ACCESS ROAD LOCATION OF J CT THIS SURVEY D ILL IT ° IA 11N GMT1 \\ Cr T TI0 , ww VICINITY MAP NOT TO SCALE LEGEND: O PROPOSED CONDUCTOR • EXISTING CONDUCTOR SECTION 31, T.11 N.,R. 3 SECTION 6, T.10 N.,R. 3 P p,0 SND OES�GN �� o N GMT 1 PAD -� PLANT N N M�1�p5 20.0 '00" LCMF KUUKPIK U M I A Q ALPINE SURVEY OFFICE PHONE : 907-670-4739 ALPINE MODULE:MT60 UNIT: MT ConocoPhillips ALPINE PROJECT GMT1 WELL CONDUCTORS Alaska, Inc. AS —BUILT LOCATIONS CADD FILE NO. 18-02-01-1 02 23 2018 DRAWING NO: CE-MT60-1007 PART: 1 of 3 REV: 1 REVI DATE IBY ICK IAPPI DESCRIPTION REV I DATE BY CI. APP DESCRIPTION 1 02/24/18 RR I CZ I GH I UPDATED PER K180003ACS ALL CONDUCTORS ARE LOCATED IN PROTRACTED SEC. 06, T 10 N, R 3 E, U.M. EXIST. SFNLINEFWLS WELL 'Y' 'X' LAT.(N) LONG.(W) GND MT6-01 5,945,316.08 1,457,169.59 70*15'22.007" 151*28'52.032" 232' 1920' 44.8 52.1 MT6-02 5,945,309.25 1,457,150.88 70*15'21.935" 151'28'52.571" 239 1902' 44.4 52.1 MT6-03 5,945,302.35 1,457,132.05 70*15'21.863" 151*28'53.114" 247' 1883' 44.3 52.2 MT6-04 5,945,295.47 1,457,113.24 70'15'21,791" 151°28'53.656" 254' 1864' 44.7 52.2 MT6-05 5,945,288.65 1,457,094.47 70`15'21.719" 151*28'54.197" 261' 1846' 44.8 52.2 MT6-06 5,945,281.78 1,457,075.68 70`15'21.647" 151 *28'54.739" 269' 1827' 44.9 52.2 MT6-07 5,945,275.02 1,457,056.87 70*15'21.576" 151°28'55.281" 276' 1809' 44.8 52.4 MT6-08 5,945,268.15 1,457,038.09 70°15'21.504" 151 °28'55.822" 283' 1790' 44.3 52.3 MT6-09 5 945 261.33 1,457,019.34 70*15'21.433" 151°28'56.363" 1 290' 1772' 45.0 52.3 U� I� NOTES 1. COORDINATES SHOWN HEREON ARE ALASKA STATE PLANE, ZONE 4, NAD 83. TKTUUKPIK M I A 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL V Q (B.P.M.S.L.) ALPINE SURVEY OFFICE P HONE * 907-670-4739 ALPINE MODULE: MT60 UNIT: MT ConocoPhillips ALPINE PROJECT GMT1 WELL CONDUCTORS Alaska, Inc. AS -BUILT LOCATIONS CADD FILE NO. 18-02-01-1 02 23 2018 DRAWING NO: CE-MT60-1007 PART: 2 OF 3 REV: 1 REV I DATE I BY I CK I APP I DESCRIPTION I REV I DATE I BY (n I APP I DESCRIPTION 1 102/24/181 RR I CZ I GH I UPDATED PER K180003ACS NOTES: 1. ALL COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. ORIGINAL GROUND ELEVATIONS WERE DERIVED FROM THE TOPOGRAPHICAL DESIGN SURVEY DATED 09/09/2015. 3. BASIS OF COORDINATES: GMT1 PERMANENT CONTROL MONUMENTS PER SURVEY BY KUUKPIK/UMIAQ, OCTOBER 2017. 4. DATES OF AS —BUILT SURVEYS: WELL CONDUCTORS MT6-01 THRU MT6-09, 02/23/18, FB.2018-05 ,PG.1. p�E, OF..... 1� SURVEYOR'S CERTIFICATE 411 `':''�••'•9 �1� 1 HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED °• *�� TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA, THAT THIS AS -BUILT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT i........49th............................. SUPERVISION, THAT THE MONUMENTS SHOWN HEREON ACTUALLY EXIST i % AS DESCRIBED, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE ................................................0 CORRECT. ca: Donald G. Bruce �o = DATE: REGISTRATION NO. No. LS-5077 J ♦••I1 AROFESS I ON\ A .... \,P�W4 KUUKPIK UMIAQ ALPINE SURVEY OFFICE PHONE:907-670-4739 10.1, ALPINE MODULE: MT60 UNIT: MT ConocoPhillips ALPINE PROJECT GMT1 WELL CONDUCTORS Alaska, Inc. AS —BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 18-02-01-1 02/23/2018 1 CE—MT60-1007 1 3 OF 3 1 1 AOGCC PTD No. 219-002 Coordinate Check 4 January 2019 INPUT Geographic, NAD27 Latitude: 70 15 23.25200 Longitude: 151 28 40.76500 OUTPUT State Plane, NAD27 5004 - Alaska 4, U.S. Feet MT6-01 1/1 Northing/Y: 5945571.269 Easting/X: 317135.095 Convergence: -1 23 28.10610 Scale Factor: 0.999937987 Remark: Corpscon v6.0.1, U.S. Army Corps of Engineers TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: Z1 C/ -G�e-) 2.- / Development Service Exploratory _ Stratigraphic Test Non -Conventional FIELD: Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - -� from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging V- 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 GRTR MOOSES TOOTH, LOOKOUT OIL - 2821 PTD#: 2190020 Company CONOCOPHILLIPS ALASKA, INC. Initial Class/Type Well Name: GMTU MT 6-01 Program SER- Well bore seg ❑ SER / PEND GeoArea 890_ Unit 10750 On/Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached_ - - - - - - - - - - NA_ - 2 Lease number appropriate- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ _ - Yes - - - - - - Surface Location lies within AA0081798; Top Productive_ Interval lies in AA0081818; 3 Unique well name and number _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - _ _ - Yes .. Portions of Productive Interval lie in AA0092345, AA0092340-,TD lies in_AA0081.743. 4 Well locatedina-defined pool_____________________________ Yes GreaterMoosesTooth, Lookout Oil Pool -282100--- ____----------- ____ 5 Well located proper distance from drilling unit -boundary -- - - - - - - - - - - - - - - - - Yes - - - - - - - Conservation Order No. 747, issued_May 29, 2018, govems_Lookout Oil_ Pool. - - - - - - - - 6 Well located proper distance from other wells- _ - - - - _ - - _ - - - - - - - - - - - - - - - - Yes - - - . - - - No restrictions as- to well spacing except that no -pay shall be opened to a well within 500-feet of an_ - - - - - - _ _ _ 7 vailable in -drilling unit_ - - - - - - _ - Sufficient acreage -available ------- --------------- Yes . - .. - - - external property line wh_ere_the owners -and landowners are not the same on -both -sides of the line, - - - - _ _ _ 8 If deviated, is-isplat-included .. _ Yes - _ - - - - Wellbore_will_ be_more than 500' from an external property line _wh_ere _owner_ship or landownership_ - - - - _ - _ _ - - 9 Operator only affected party- - - - - - - - - - - - - - - - - - - - - - - .Yes - - changes._As_planned_, this conforms with spacing requirements._ - - - - - - - _ - - - - - - - - _ _ - _ _ - - - 10 Operator has_appropriate bond in force - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 11 Permit_can be issued without conservation order_ _ _ _ _ _ _ _ _ _ _ _ _ - - Yes - - - . - .. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 12 Permit_ can be issued without administrativ_e.approval_ _ _ _ _ _ _ _ _ _ _ _ - _ Yes- - - - _ _ __ _ _ 13 Can permit be approved before 15-day- Yes SFD 1/7/2019 - - - - - - - - - - - - - - - - - - - - - - - - _ - - - - 14 Well located within area and strata authorized by -Injection Order # (put_10# in_comments)-(For- NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 15 All wells -within 1/4_mile area of review identified (For service well only)- - - - - - - - - - - NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - - - - - - - - - - - - - - - - 16 Pre -produced injector_ duration of pre production less than 3 months_ (For service well only) NA_ _ _ - - - _ _ _ - - - - - - - 17 Nonconven, gas conforms to AS3.1.05.0300,1_.A),(j.2.A-D) - - - - - - - - - - - - - - - - - - - - NA_ - _ - _ _ - _ - _ - _ - _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 18 Conductor string -provided - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ _ - - - _ - 80' conductor set_ - - - - - - - - Engineering 19 Surface casing -protects all -known USDWs - - - - - - - Yes - - - - - - - Surface casing set to 2061' MD . . 20 equate_to circulate -on conductor & surf_csg - - - - - - CMT_vol_ad------------ ---- - - Yes - - - - - - - Surface casing cementing uses 155%,excess - - - - - - - - - - - - .. - 21 CMT_vol_adequate _to tie-in long string to surf csg- - - - - - - - _ - - - -------- - - - - - - No_ - ------------------ - - - - _ _ _ - - - - - - - - - - - - - - - - - - - - 22 CMT-will cover all knownproductive horizons- - - - - - - - - - - - - - - - - - - - - - - - - - No - - - - - Productive -intervals will be completed with uncemented frac sleeves_ - - - - - 23 Casing designs adequate for C,_T, B &_ permafrost _ - - - - - _ _ - - - Yes - - - - - - - - - - - - - - - - 24 Adequate tankage_or reserve pit - - - - - - - - - - - - - - - - - - - - - - -------------- Yes - Rig has steel tanks; all_waste_to approved disposal wells_ - - - - - - - - - - - - - _ - - - - - - - 25 If a_re-drill, has_a_ 1.0-403 for abandonment been approved - _ _ _ _ _ _ _ - _ _ NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - -- - - 26 Adequate wellbore separation proposed - - - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - - - - - Anti -collision analysis complete; no major risk failures . - - - - - - - - - - - - - .. - - 27 If_diverter required, does it meet regulations_ - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - Diverter waiver granted per 20 AAC 25.035(h)(2) - - . _ _ - _ - - - - - - - - - - Appr Date 28 Drilling fluid_ program schematic-&- equip list adequate_ _ _ - - - - - _ Yes Max formation_ pressure is_3567 psig(8.8 ppg EMW ); will drill w/8 8-11,2- _ - . - - - - VTL 1/16/2019 29 BOPEs,_do they meet regulation - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 30 BOPE_press rating appropriate; test to_(put psig in comments)- - - - - - - - - - - - - - - - - - - - Yes - ... MPSP is 2779 psig; will test BOPs_to 3500_psig - - 31 Choke manifold complies w/API_RP-53 (May 84)- - - - - - - - - - - - - - - - - _ Yes - - - - - - - - - - - - - - - 32 Work will occur without operation shutdown- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ _ _ _ --------------------------------------------------------------- 33 Is presence_of H2S gas _probable - - - - - - - - - - - - - - - - - - - - - - - _ _ - _ Yes - _ _ _ - - H2S measures required- - - - - - - - - - - - - - 34 MechanlealconditionofwellswithinAORverified(Forservicewellonly)- - - - - - - - - - - - - NA_ - - -- ------- - - - - - - - - - - - - -------- - - - .. - . _ - _ - _ - - --- - _ _ _ _ _ _ _ -- - - - - - 35 Permitcan be issued w/o hydrogen_ sulfide measures - - - - - _ _ _ - - - - - - No - - - - - - Limited -production history; H2S measures required. Mitigation strategy in Drilling Hazards Summary. - - - - - Geology 36 Data_presented on potential overpressure zones - - - - - - - - - - Yes - - - - Drilling fluid program -appears-adequate-to control- operators forecast pressures._ Managed_ Pressure - - - - - - Appr Date 37 Seismic analysis_ of shallow gas -zones_ - - - - - - - - - - - Yes - - - - - Drilling Technique will be used in. portions of well to stabilize- shale and dynamically balance -the-well. SFD 1/4/2019 38 Seabed condition survey _(if off_ -shore)_ - - - - - - - - - - _ - _ _ _ NA_ - _ _ - - - - - - - - - - - - - - - - - -- - - - -- 39 Contactname/phone for weekly- progress reports _[exploratory only] ---- _------------ NA -------------------------------------------------------------- Geologic Engineering Public Date: Date Date Commissioner: Co issioner: Commissioner