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Home My WebLink About218-049Winston, Hugh E (CED) From: Winston, Hugh E (CED) Sent: Thursday, June 4, 2020 9:10 AM To: tom.g.polasek@conocophillips.com Cc: Loepp, Victoria T (CED) Subject: MT6-081-1 Permit Expired Hi Tom, The permit to drill for well MT6-08L1 which was issued to CPAI on May 3152 2018 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 hug1j;winston glaska.gov_ 907-793-1241 THE STATE VISA W4415 GOVERNOR BILL WALKER Graham Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Re: Greater Moose's Tooth Field, Lookout Oil Pool, MT6-08L1 ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-049 Surface Location: 283' FNL, 3227' FEL, SEC. 6, T10N, R3E, UM Bottomhole Location: 1564' FNL, 712' FEL, SEC. 23, T11N, R2E, UM Dear Mr. Alvord: Alaska Oil and,,'Ta.s 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov Enclosed is the approved application for the permit to drill the above referenced service well. The permit is for a new wellbore segment of existing well Permit No. 218-048, API No. 50-103-20772-00- 00. Production should continue to be reported as a function of the original API number stated above. 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, LUC - 5 � Hollis S. French Chair l DATED this day of May, 2018. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 APR 1 4 91018 1 a. Type of Work: 1 b. Proposed Well Class: Exploratory -Gas ❑ Service - WAG Q - Service - Disp ❑ 1 c. Specify if well is proposed for: Drill ❑ Lateral 0 Stratigraphic Test ❑ Development - Oil ❑ Service - Winj ❑ Single Zone Q ' Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q , Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. • 5952180 MT6-081_1 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 20504 TVD: 7860 Greater Mooses Tooth Unit Oil 4a. Location of Well (Governmental Section): 7. Property Designation: S , n . r Surface: 283' FNL, 3227' FEL, Sec. 6, T1ON, R3E, UM AA081818, AA , M8, AA081819 A�8 L a etc Top of Productive Horizon: 8. DNR Approval Number: 0(4-. 13. Approximate Spud Date: 3980' FNL, 2091' FEL, Sec. 25, T11N, R2E, UM 932553, 340760, 932533, 932554 7/12/2018 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1564' FNL, 712' FEL, Sec. 23, T11 N, R2E, UM 1208, 3837, 607, 1923 1564' to AA094421 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 70 15. Distance to Nearest Well Open Surface: x- 317004 y- 5945523 Zone-4 GL / BF Elevation above MSL (ft): 34 to Same Pool: 3503' to Lookout 1 16. Deviated wells: • Kickoff depth: I Fy%lpg feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: -0,3 0e4 degrees Downhole: 3810 . Surface: 3019 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling I Length MD TVD MD TVD (including stage data) 42" 20" 94 H-40 Welded 80 34 34 115 115 10 yds 16" 13.375" 68 L-80 H563 2022 34 34 2056 2035 942 sx 11.0 ppg DeepCrete, 328 sx 15.8 ppg G 12.25" 9.625" 40 L-80 BTC-M 10201 34 34 10235 7130 95 sx 12.2 ppg Class G, 216 sx 15.8 ppg Class G 8.75" 7.0" 26 L-80 Blue 12046 34 34 12080 7911 380 sx 15.8 ppg G 6" 4.5" 12.6 L-80 TXP 8574 .�9 e 7852 20504 7860 uncemented pert 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? Yes[] No ❑ 1� 20. Attachments: Property Plat (�j BOP Sketch IIJJ Drilling Program In/ Time v. Depth Plot 1/1 Shallow Hazard Analysis Diverter Sketch rl Seabed Report rl Drilling Fluid Program 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.a.polasekPconocophillips.com Authorized Title: Drilling Manager Contact Phone: 907-263-3740 Authorized Signature: Date: +124 1 Zo Commission Use Only Permit to Drill 150- API Number: Permit Approval 2 5 1 g See cover letter for other Number:t2l�- Q - � ] � a ,. �Q Date: J requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other: -77'j ' - n -��- 0 c ` 4 /'" Samples req'd: Yes ❑ No[1f Mud log req'd: Yes❑ No[if D -" ®S �S / HZS measures: Yes 11 No❑ Directional svy req'd: Yes No❑ O - 7 `� Spacing exception req'd: Yes ❑ No[� Inclination -only svy req'd: Yes ❑ No (y Post initial injection MIT req'd: Yes ❑ No ❑ APPROVED BY Approved by. COMMISSIONER THE COMMISSION Date: G Form 10-401 Revised 5/201.7 This permit is valid fo6RIGINAL months from the date of approval per 20 AAC 25.005(g) Submit Form and Attachments in Duplicate �� 6 ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 April 16, 2018 Alaska Oil and Gas Conservation Commission 333 West 7" Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill MT6-08L1 Dear Sir or Madam: ConocoPhillips ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Alpine C-Sand dual lateral injyction well from the MT6 drilling pad. The intended spud date for this well is July 12, 2018. It is intended that Doyon Rig 19 be used to drill the well. MT6-08L1 is planned to be an Alpine C upper lateral injector out of the MT6-08 parent well (covered in a separate PTD). When MT6-08L1 is commenced, the parent well will have run and cemented 13-3/8" surface casing to above the C30 Sand. 9- 5/8" intermediate 1 casing will have been run and cemented to 500' above the uppermost hydrocarbon bearing interval. The second intermediate 7" liner and tie back string will have been run across the shales, landed, and cemented in the Alpine C sand. A 6" lateral will have been drilled in the lower Alpine C Sand with a 4-1/2" liner with perforated pups. A whipstock was set above for the MT6-08L1 kickoff in the Alpine C Sand. The MT6-08L1 lateral will be comprised of a 6" horizontal hole that will be geo-steered in the upper Alpine C sand. The well will be completed as an unstimulated producer with 4.5" liner with pre -perforated pup joints and tied back to surface with a 4.5" tubing upper completion string. The well will be flowed back to clean up the wellbore following drilling operations and then shut in until pad startup. 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. Si e ly,� cc: MT6-08L1 Well File /Ann Haggerty-Sherrod ATO 1530 �(/ ( Johnson Njoku ATO 1720 Tom Polasek Chip Alvord ATO 1570 Drilling Engineer John Cookson ATO 1750 Application for Permit to Drill, Well MTU MT6-08L1 Saved: 18-Apr-18 MT6-08L1 Application for Permit to Drill Document CawcoPhillips Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (9)............................................................ 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 of 20 AAC 25.005 0 (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 It. Seabed Condition Analysis (Requirements of20AAC 25.005(c)(I1)).........................7 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12))...................................7 13. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13)) .........................7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal .......................8 (Requirements of 20 AAC 25.005 (c)(14))............................................................................. 8 15. Attachments................................................................................................................9 Attachment 1 Cement Summary .................................................................................................................. 9 MT6-08 APD Page 1 of 15 Printed: 18-Apr-18 Application for Permit to Drill, Well MTU MT6-08L1 Saved: 18-Apr-18 Attachment 2 Drilling Hazards Summary.................................................................................................... 9 Attachment 3 Completion Schematic........................................................................................................... 9 Attachment 4 Directional Plan...................................................................................................................9 MT6-08 APD Page 2 of 15 Printed: 18-Apr-18 Application for Permit to Drill, Well MTU MT6-08L1 Saved: 18-Apr-18 1. Well Name (Requirements of 20 AAC 25.005 (fl) The well for which this application is submitted will be designated as MTU MT6-08L1. 2. Location Summary (Requirements of20AAC25.005(c)(2)) Location at Surface 283' FNL, 3227' FEL, Sec. 6, T10N, RM, UM ' NAD 1927 RKB Elevation 70.0' AMSL Northings: 5,945,523 Eastings: 317,003 Pad Elevation 34.0' AMSL Top of Productive Horizon Heel 3980' FNL, 2091' FEL, Sec. 25, T11N, R2E, UM NAD 1927 Northings: 5,952,479 Eastings: 313,292 Measured Depth, RKB: 11,873' Total Vertical Depth, RKB: 7,884' Total Vertical De th, SS: 7,814' Total Depth Toe 1564' FNL, 712' FEL, Sec. 23, T11N, R2E, UM NAD 1927 Northings: 5,960,270 Eastings: 309,581 Measured Depth, RKB: 20,504' Total VerticalDe th, RKB: 7,860' Total Vertical Depth, SS: 7,790' Requirements of 20 AA 25.050(b) Please see Attachment 4: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information (Requirements of20AAC25.005(c)(3)) Please reference BOP and diverter schematics on file for Doyon 19. MT6-08 APD Page 3 of 15 Printed: 18-Apr-18 Application for Permit to Drill, Well MTU MT6-08L1 Saved: 18-Apr-18 4. Drilling Hazards Information (Requirements of20AAC25.005 (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 2056 / 2035 14.5 910 1331 9.625 10235 / 7130 16.5 3176 3019 7 12080 / 7911 12.5 3810 2987 4.5 20504 / 7860 12.5 3773 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 20" conductor 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) = 910 - (0.1 x 2035') = 706.5 psi Drilling below surface casing (13-3/8") ASP = [(FG x 0.052) - 0.1] D _ [(14.5 x 0.052) - 0.1] x 2035' = 1331 psi OR ASP = FPP - (0.1 x D) = 3176 - (0.1 x 7130') = 2463 psi Drilling below first intermediate casing (9-5/8") ASP = [(FG x 0.052) - 0.1] D _ [(16.5 x 0.052) - 0.1] x 7130 = 5405 psi OR ASP = FPP - (0.1 x D) = 3810- (0.1 x 7911') = 3019 psi , MT6-08 APD Page 4 of 15 Printed: 18-Apr-18 4. Drilling below production liner (7) OR Application for Permit to Drill, Well MTU MT6-081-1 Saved: 18-Apr-18 ASP = [(FG x 0.052) — 0.1] D = [(12.5 x 0.052) — 0.1] x 7911 = 4351 psi ASP = FPP — (0.1 x D) = 3773 — (0.1 x 7860) = 2987 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 propensity for 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 4 Program Csg/Tbg Hole size Weight Grade Conn. Length Top MD7TVD Btm MDiTVD Cement Program CD (in) (Ib7ft) (ft) (ft) (ft) (in20 42 79 H-40 Welded 80 Surf 115 / 115 Cemented to surface with 10 yds slurry H563/ Cement to Surface with 13-3/8 16 68 L-80 TXP 2,021 Surf 2,056 / 2,035 942 sx DeepCrete Lead at 11.0 ppg, 328 sx Class G Tail Slurry at 15.8 ppg 9-5/8 12-1/4 40 L-80 TXP/ TN-80 10,200 Surf 10,235 / 7,130 95 sx Class G Lead at 12.2 ppg HC 216 sx Class G Tail at 15.8 ppg n/a Plug 1: 335 sx Class G at 12.2 ppg (Pilot) 8-3/4 n/a n/a n/a 1665 10,400 / 7,225 12,065 / 8,046 Plug 2: 335 sx Class G at 12.2 ppg Plug 3: 377 sx Class G at 17.0 ppg 7 6 x 8- 26 L-80 BTC/ 12,045 Surf 12,080 / 7,911 380 sx Class G 15.8 ppg cemented to liner 3/4 Blue top at 9,985' MD 4-1/2 n/a 12.6 L-80 563 11,895 Surf 11,930 / 7,892 n/a 4 1/2 6 12.6 L-80 TXP 8,558 1 7,892 20,504 / 7,860 Uncemeneted open hole liner w/ pre - perforated pup joints tl 7. Dlverter System Information (Requirements of20AAC25.005(c)(7)) A diverter will be rigged up while drilling the surface hole as per 20 AAC 25.035 (h)(2). MT6-08 APD Page 5 of 15 Printed: 18-Apr-18 Application for Permit to Drill, Well MTU MT6-081_1 Saved: 18-Apr-18 8. Drilling Fluid Program (Requirements of20AAC25.005(c)(8)) Production Hole Size in. 6.0 Casing Size in. 4.5 Density PPG 8.8 PV CP 15 YP Ib./100 15 - 20 ftz Funnel s/qt. 60 - 80 Viscosity Initial Gels Ib./100 10 10 Minute Ib./100 Gels ft2 15 API Fluid cc/30 Loss min. 4.0 HPHT Fluid CC/30 10.0 Loss min. pH 9.0 — 9.5 Production Hole: The horizontal production interval will be drilled with a water -based mud drill -in fluid FloPro weighted to 8.8-9.5 ppg with calcium carbonate. MPD will be used to hold back pressure, keeping the well dynamically balanced. .r- Diagram of Doyon 19 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. MT6-08 APD Page 6 of 15 Printed: 18-Apr-18 Application for Permit to Drill, Well MTU MT6-08L1 Saved: 18-Apr-18 9. Abnormally Pressured Formation Information (Requirements of20AAC25.005 (c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) N/A - Application is not for an offshore well. 12. Evidence of Bonding (Requirements of20 AAC 25.005 (c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic. 1. End PTD for MT6-08 and begin PTD for MT6-08L1. 2. Pick up and RIH with 6" drilling BHA. 3. Drill 6" hole to section TD (LWD Program: GR/Azimuthal RES) 4. Circulate hole clean and pull out of hole with drilling BHA 5. RIH with Whipstock retrieval tool and MWD. Retrieve Whipstock and POOH. 6. RIH with 4.5" liner with perf pups and hook hanger and POOH �� 7. RIH with lateral entry module (LEM) and packer assembly. Orient LE set packer and POOH 8. Run new 4.5" tubing with landing nipple, gas lift mandrel(s), and seal assembly. Displace mud in production casing to kill weight brine, space out and sting into upper liner top packer, and land tubing hanger 9. Install BPV and pressure test seals to 5000 psi. Nipple down BOP 10. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove BPV. 11. Test tubing to 3500 psi / 30 minutes and chart test. Test casing annulus separately to 2500 psi / 30 minutes and �! A chart test. �� NLt 12. Shear circulation valve in GLM.�� ]tGr� `y ZC� S ' y 1 zt--) 13. Circulate tubing to diesel and install freeze protection in the annulus. 14. Set BPV and secure well. Rig down and move out. M MT6-08 APD Page 7 of 15 Printed: 18-Apr-18 Application for Permit to Drill, Well MTU MT6-081-1 Saved: 18-Apr-18 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AA 25.005 (e)(14)) Incidental fluids developed from drilling operations on well MT6-08 will be injected into dedicated Class 1 disposal well CD1-01A. The MT6-08 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 1100' TVD. Significant hydrocarbon zones include the Alpine. There will be 500' of cement placed above the top of the Alpine reservoir. Once MT6-08 and MT6-08L1 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) * (2,035') + 1,500 psi = 2770 psi Pore Pressure = 910 psi Therefore Differential = 2770 — 910 = 1860 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 MT6-08 APD Page 8 of 15 Printed: 18-Apr-18 15. Attachments Attachment I Cement Summary Attachment 2 Drilling Hazards Summary Attachment 3 Completion Schematic Attachment 4 Directional Plan Application for Permit to Drill, Well MTU MT6-08L1 Saved: 18-Apr-18 MT6-08 APD Page 9 of 15 Printed. 18-Apr-18 Application for Permit to Drill, Well MTU MT6-08L1 Saved: 18-Apr-18 Attachment 1 — Cement Summary MT6-08L1wp04 Cementing Program: This is an open hole uncemented liner. MT6-08 APD Page 10 of 15 Printed: 18-Apr-18 Application for Permit to Drill, Well MTU MT6-08L1 Saved: 18-Apr-18 Attachment 2 — Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 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 Well Proximity Risks: MT6-08 and MT6-08L1 will be the third well drilled on the pad. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in the following attachments. Drilling Area Risks: Reservoir Pressure: Offset production has the potential to reduce the reservoir pressure. LCM material will be on location to deal with losses. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. MT6-08 APD Page 11 of 15 Printed: 18-Apr-18 Application for Permit to Drill, Well MTU MT6-08L1 Saved: 18-Apr-18 Attachment 3 — Completion Schematic MT6-08 Mufti -Lateral Injector wp04 DRAFT Completion Schematic as of 4-13-18 rop Alpine C 7Bw TvLi z-i Pilot Hole (PB1) 12;,065' CAB I 8,3i - Ta'D ..... 20" 79 ppf H-40 Insulated Conductor 79 feet, oernente-d to surface 13-31 " 68 ppf L-80 TXP Surface Casing @ 2056' 1AD 1211:35 TVD cemented to surface 4-1.t2' 12.6 ppf L-80 Blue to -11'93V' 06+1D 7" 26 ppf L-80 Tenaris BTC Tieback to 9,985' 1.016,986" TVO @ cc= TOL @ 9.,98.lVD16,986'-P D @ 55` 9 5(8"' 40 ppf L40 TXP (to 584T MD) 9 &V 40 ppf 711" b HC (to TD) 111,235' tu1D 1713Gi' -PVD Ti C of 9 541- 9„235 it MD TuNng 1 Liner Cornplebon: 1) 4-1 _'" Landing Hippie (3.813' ID) 2) 42/-' x 1' GLM 3) 4-142 x'1' GLM 4) 4-34- x 1' GLM 5) Liner Top Packer 1 Hanger w.1 Tie Back slwve 6) LEM and Hook danger 7) Liner Top Packer,' hanger wTTie Back Siec%,e 81 44 q Lauding Clippie (3.725" NoGo) 9) 4 e< Blue Blank Pipe 10) 4'A' Blue toner wth Perf Jbints Upper Lateral 6" Hanle, TD at at 20.5DV MD / 796V T49D r, 4',z' 92.6'# L-N Blue L-urer Vfdh Perf Pups O O S? O 4 ' " 2-6#With L-80 Blue Liner i:4ettePerf Pups 0 0 0 0 0 0 0 T' 26 ppf L-80 Tenaris Blue Liner 6' Hole. TD at to 12,DW PAD 17911' TiM @ a3 deny at 20.5W NID i 789W TVD 04/231201B -TOP MT6-08 APD Page 12 of 15 Printed: 18-Apr-18 Application for Permit to Drill, Well IVITU IVIT6-081_1 Saved: 18-Apr-18 Attachment 4 —Area of RevIew MT608 and MT608L1 Area of Review: This Area of Review is required as MT6-08 and MT6-08L] are being permitted as and Alpine C sand injector. There are no wells the fall with 1/4 mile of the well's entry point into the Alpine C sand. Existing wells are colored red. Future wells scheduled to be drilled prior to MT6-08 in blue. eskAF"Ism" I MT6-08wp04 Lower Lat Quarter Mile View 15000 ,2112000 C) 10 e4o C) C) CI) 9000- 0 z 6000- 0 3000 0 -15000 -12000 -9000 -6000 -3000 0 3000 6000 9000 West(-YEast(+) (3000 usftfin) MT6-08 APD Page 13 of 15 Printed: 18-Apr-18 ms+s+zora MT6-08 wp04 Lower Lat 1 He UTS.M. L 645 Attachment 5 - Directlonal Plan MT6-O8L1 Application for Permit to Drill, Well MTU MT6-081-1 Saved: 18-Apr-18 31) Quarter Mile View ti 8OOt� i 6Qao 12000 0000 VTS�M.UT 8000 MT6-08 APD Page 14 of 15 Printed: 18-Apr-18 0 •CL s �(L O V O c U) Z L O = — Q a � .Q — a U cn � O J Q O t iJ00 O O *k L acoO a 3 o ._ d 4-0 G� co OI O V La 0 a 00 0 N 3 C M N N a) w w N > > L% 6 cu c c c 0 o U U � OJI N N 3 O O N U 0 0 Z d > N U O O m Ud dUE _m a1) a (D d J J E Q> O - J J p F m W W E ❑ f w C CD aoi 'w CD 'm > ui O •0 C O m N y N S` � C d O C O ° m d w a O o w d mU y �' O >❑> ❑ O 7 ego J F Z Co ❑ tf O a Q i .0 E a F- o Z) U) o O O U L) Z Z cL O L t _rn C N t: ,_. al m a U O Z Y m m ❑ F Q U) o J s O N UI QC Jao N a7 U_ ) ° o Qo -_� o N LZ 3 �u¢ cu N/� o c a) OI m N -Ccu O N C c� (O c Z Q S r r U a a �(L i a 0 N O d J ,OO rn N to u p 6 .m+ G1 0� d Q m w m 0 0 0 0 o O 0 co 0 (O M N O N I- V (O O V N U U O O O O O O cod 0 0 0 m IL y Z w C c N y c W c o a N Nl 3 3 a° 4? 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LO ui (n LO (n N N h (n (O LO N (O (O (O Z N (D (O r N t` V N 0) v N 0) r- v v M (N rl O O O m O) O) m w w w v 00 m (o r- m m w r- � rs r- 1� n 10 m (D 0) co 0) O O w O O O N O M O v O l0 O (O O r O w O m O O n a r` rl c w 00 OD w w OD 00 w w w of 9 O O O O O O O O O W M M w M 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 O 0 O O O O m o 0 0 o 0 0 (2 0 0 o 0 0 (O 0 0 (D 0 O o 0 o O 0 0 O 0 0 0 0 0 0 O 0 o o 0 o 0 o o 0 O O 0 O o p) N a, J � Q O o m w rn O w (O M N w (O w (D (D V N (0 N r N m N N Cl) N m m M O m O m m N m N w N w N r- N O w rn 0 N w w w w w w m m 00 w w 00 w w o m w O w (0 M N G) 0) m 0) O w w w w m m m r- m r� w IT w V N N N M L O M M m Cl) M Cl) Cl) m Cl) N ° fa N Q r` w w w w w w � w w w w w w N O O m m w m N O O O O O m m m m m m m m m m ccw ccw w r- I-- co m m m m of m e m o m m m m m 0 m m m O N �O CO. N V w w Q N M v w N r0 (0 w m N O 0) er le m m N O 0) 0) N O 0) m Cl! O 0) 0) Cl! O m 0) N O m 0) N O m 0) N O m m N O O 0) m N N O O m m V C � 0 m m M M r- 0 � a a O LLO H G o r 0 0 L 0 o O to O y 0 v w m ? v o o o 0 o 0 o 0 0 0 o 0 o 0 0 0 o o 0 0 T (O O V (D O N w J o D O m f� a O O o O 0 O 0 O o O O O o O 0 O o O O O 2 O) m O m y O aYR- N O N N �- N N - Cl) - V - r0 - w --- t- - w - m O - — ,a C Y co y U) C �a h N O 00 O N co a_ 3 m V O O O h CID > > co N M O N M o O OD m O N M lO w 1-- w m o M N W W N M M M M M M M M M V' V V V V 7 V V V M In to to N m N to M N N m N m (D (D N M 00 O V 1- m V m r w m (n N N m m M o m M T o 1- (D a' N oo W M o m N Lo m O m (D M N O OD > N > m r r r m (I LQ to V 14 d' M M N N r r O c m m o (D oc t` n (D ci U C N N N 0 t0 In N IO N Ln N to N In N If) N N N In N If) N In N Lo N lO N 1n N 1n N to N to N Lo C C N In l('1 to to Ln II') to lO F- m m (NC r r r r r r r r r r r r r r r r r r r r r r r r r r r W N OI U) N Y 6 6 l0 E V' N O m m 7 N o w co V N O OD (D V N o co (o 7 N O OD (D V N N O cD a N r 7 (D m N IO co O M (O m N V 1- O co (o co r � O N IO co r 0 0 3 m o O O O N N N N M (+) M 7 V V 4 In IO to (6 moo (p o fay` �I�` V 0 7 to m cc r Octm O - N M V 10O Imo (OD n 00 (1 c N c 'I 'I tLO (cf (6 �/ V j (9 C M M M to to N co N M Lo co Lo M to M In V IO '7 If) V I() 't IO V to 7 IO V IO 7 N 7 to 7 IO '7 m t0 In In IO to to Lo to t0 Lo N Lo to to m Lo d J J Q ,c N WW C ❑ O u') N to tO to to to N Lo Lo Lo Lo Lo Lo Lo Lo tO to N Io t0 Lo If) N N Lo to >W > > H W Z N m 1� V N m (D V m m V m (O V m (o V m (O co W O W n r 1` 1` (D o (O o u( N to In V V V V M M M M N N N N Ci 0 0 o o_ o 0 a o o O c) O 0 o(3 o 0 o 0_ 0 o 0 o 0 0 0 D o c) o o o o 0 o a o 0 M V v I N CO f� M m O C N M V v m ( o 0 � C((3 W m O c 0 c\ N 0 M 0 "t 0 In O CO O f- yO L m m m m m m m m m O r O r O r O r O r O r O r O r O r O r r r r .-- r r r N N N ^Z d O U R a U U y 3 o o o 0 Or i d w R o o o O O O O 0 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 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 ID 0 o o o o O w d U y w U ❑ "" >❑> O 7 (�6 Otf LL J O Q Q O O O O O O o o O O o 0 o O O o 0 o O o O o T o 0 0 O O O 0 O 0 O 0 O o o O o o o 0 0 0 o o 0 o 0 o o 0 o o 0 o o 0 o 0 O o O O o o o O o o o 0 O 0 o 0 o 0 o o 0 o (6 a. � m O m O c 0 0 V (n O C c O p O (p r m r o r (O r o r (D r (D r O r m r (D r (fl 1l_ o O N N N N N to N V N -It N M N M N N N N N N N o N O N r r Q M m W I� n OD n N r O r M n m r N r CD n M t, w n CD n m 1` M n CD 1` W n DD r- au r N r DO 1` M r DO N n DD n OD r W n (3 O) a ❑ v to m t0 N O o (D m (D o O r O o m m [D CO m I- co (o to N 7 7 CO M N N O O m o 00 o r r to (D In to V' V m m m m cc oc m oc m oc m oc m oc m oc m oc m Octoc m m oo rn m m to m oc m o m m ww ro oo m oo W co m oD co oD CO oc W m t%1 cc a0 aD 1- 1�1� I� f� i� F` o M M M L M M Co M M M M M co M M M M M M P') Cl) M Cl) M Cl) M Cl) M M M Cl) M Cl) M M M Cl) M Cl) M Cl) M co M M M Co M M M Cl) M M 07 M M M M co co M ') co M M (M co M M M co M co co M M M co co M co M U) E U C N N Q (p YO a U N a j m m m N N N m N m N m N m N m N m N m N m N m N m N m N m N m N m N m N m N m N m N m N m N m N m N m N m N cL N Q 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 0 J m m m m m m m m m m m m m m m m m m m m m m m m m m m .d O J a �� C „„ (^ d C U N U oD oo Q. O 9 c?c N c c 00 (O O N R t0 H F U d (L S o o o o o o o o o c) cD o o o o o 0 0 cD o O O O O o o o o 0 0 o o a a o o o o o o O O o o o o 0 cD o o 0 O o o (q a o 0 0 o o o(D o c) c) 0 0 o o 0 o o o o 0 0 o o 0 o (D o !o ]a C m o cl 0 N M j 0 V 0 In c m 0 n oc oo C m O C 0 r cl N 0 M 0 7 0 N O CO O I� O CO O m O c O r O N O M o V' 0 N ( (O 0 h O N V �^. M co co y ❑ r r r co .- M r M r M r Cl) r M r V r V' r V r V r 7 r � r 7 r 7 .- 7 r cr r (o r tO r to r Lo r (O r to r tO r to r � ^O Y. O V Rn U O c y J 9 a) o o— m m a) '.. d C R O 0 a ir) �: O m Cal O Q fA N Q � T i E E- u U) O O O U .0 Q) N Q co co a M 0 0 0 N N w w O m m N (D M m 'It co Lo m m (D m (D m cD O n n N r� M � (o n m n n n m n m n o m m M m V m (o oo (O co n m m m m co n M m (O m O (o co N N Oi n m M M m o (O n O V m N M n (O M N m m V (O O M (O O N n n ITm CO m V (O O N (O m ?N ?N N» m (D (o (o (o V V Cl Cl N Ni N O O m m m m m n n (O m m (o u) u U C C = N N N N (n ((1 (n m (U (U (U (17 (17 l0 (O oto loft CD (O 0 (o Oo ( (oo u)(o (oo (oo IOo (O Z V V V V V V V V V V V V V V V V V V V V V V V V V F- m .m W r r r r r r r r r r r r r r r r r r r r r r r r r r r N oo 3 r 9 — 0 0 2 N O O Z d o It m en m V N N m O m m O m M V m N m o N m V m n V O N M O m m m m r V V N n O O m N m (o V m N r m m 0 0 � (p n n n m m m m m m m O O O r N N N M M M. V V V n n U y C �\ N m (O n Lo () m It m Cl) O r N O M m c CO N n (O n m m n (O m It m CO O N r N CD M CO OD V n (O m m (O n V oc M m N O r E lII J J Q — J J E H G ,C ` �-' v (7j (o m (O Lo m u) (o m (D N m m N m (O (O m (D (O m m w) m m (o m m (o m (D (o m m (o m m to m m (O m n (o m 1- (o m n to m n (O m n m m n to m n (o m n (o m n (o m [I-n (O m l0 m co 10 m m (O m N w w ` C H w O Z LO (n (O (n m (n o m (D (o o (o (n o m (o (n Lo m (o (O (o (o (n m (n () M m m M m m M m (O M O m - M O m (O C- O m If1 M O m _ O O O O m m m m m m m m n n n n (O (O m. m (0 U0 (o V 1� r r r ri o CO o 0 0 0 0 0 0 0 0 0 m (D o (O m o o o o 6 U -Q o m o m 0 000 O 0 0 N 0 M 0 V 0 (O m n o m 0 m 0 O 0_ o N o M o V o (O o m o n o m o m o O o_ o N o M o V y O r r N N N N N N N N N N M M M M M M M M M M V V V V Vt w d 7 N O U N (p uy 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 N d .L A 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 O O o o o o O O O o o o o o o O O O w d U y 9 cf0i ❑ V y❑ J I- Z M ❑ I- o 0 0 o 0 0 0 o o o o o o o o o o 0 o o 0 o o O o o O o o 0 o 0 0 0 0 0 0 0 0 0 o o o o 0 0 o 0 o 0 0 0 0 0 o O o o O o 0 o o o o 0 o o o o o 0 o O O O o 0 0 o O i m N v � J O ❑ O 0 0 0 0 o m m m m m m m m m m m m n n n n n m m m o m (D r m r m O (O O (o O (O O (o O (o O (O O (o O (O O (O O to O u0 Lo M Cl) N N r r o O m O m O m O m O n O n O m O m O (o O (n O V O V o M o M O N O N O O O o O n n n n n n m n m n oc n m n m n oc n m n oc n m n m n cc n cc n oc n cc r m n m n oc n oc n m n m n m n � ❑ N O O o O o m m m m m m m m m m m m n n n n n m m m (D o (D (D (D O (o O (o O u7 O (o O (O O (O O (O O (O O (o O (O O (O CO M N N O O m m m m n n (O (O (O (O V V M M N N O m cc - m m - m m - m m - co m - � m - m m - m m n m - n OIL n m n m n m n m n m n m n m n m n m n m n m n m n m n m m 'o n m n cc � n n n n n n n - n n n - n - n - N. n - n - n - n - - n n - n - n - - n - n n - n - - n - n v v v v v v v v v v v v V v V v v v v v v v v v v v v L M M M Cl) M Cl) M M M Cl) M M M Cl) M CO M M M M M M M co M Cl) M Cl) M Cl) M M M m M M M M M Cl) M M M co M co M Cl) co Cl) M co M M M M co co co M co co co co M co co co co M co M co M M M M M M co M u) N ° U N QC (p (/1 O- H m N m N m N m N m N m N m N m N m N m N m N m N m N m N m N m N m N m N m N m N m N m N m N m N m N m N m N O Y cL 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 O O O Q O un J m m m m m m m m m m m m m m m m m m m m m m m m m m m o ao Z� c� m'❑i3 E m m Cl)U O o o coF- o N N N U a o- o 0 o 0 o o o o 0 0 0 0 0 0 o o 0 0 o o 0 0 0 00 o o 0 o o 0 0 0 o 0 0 o o n 0 o 0 o o o o o 0 o o o o o o Q T o O O O O O O O O O O O o 0 0 o O O O O O O O O O O O tO d o m O m O O O r o N O M O V O (O O m O n O m O m o O O r O N o M O V O (O O (D O n O m o m O O O r O N O PM O V ((j ri ui m (o m co m ro m co m co n n n n ao ao m N d 4 O C d OD fl d a m E a 0 .r0+ N Cl y U0 F 1 a N n Ln Q U ^m aN y COL o �= ¢(° � U a aZ� i3 co 00 o O O p N N N H H CS (a�� T `o c E U a` in 3 �: o N (M 7 to O CO A O N M 7 CO n C? 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IZ Di m Q a $ `� 0 W ��-- m m o v Q Ld O Ln cm 0 0 I� m m 0 O p m C? o 0 0 4 o 0 0 0 0 0 0 0 0 0cs 0 0 0 0 o I I I I I I I i I I I I I I I O 1 I I I i I I I I r , I I I I - - - - - - - - - - I I I I - - - - - I i I I - - - - - - - I I I I - - - O O I I I I I I I I I }I - - - - - - - - I O O L L I I 0 I I I I I I I I I Q -- - - -- -- I ---- I---- cu J I I U) I I I cB C I I I I I I I I I I I I I I I o G I I I 1 I I I I I O O I I - - - I 1 - - - - - - - - - I - - - - - Ln M I I I I I i I I I I I I I I I I O U') _O O co U-) CO O (ui/lisn 099) uoijaaadag ailuao o} ai}uao 0 0 U n N Q Q AR L O >> >o J CS o > J 't 0 O 0 CDO > (> - 'IT1 O p _ / J m > O O CD i P- ri ❑ I i O i ❑ > mm O O O C? N N Q i N {N1 $ O m 5 Q W ¢ O (1 w Cl) 3 m m $ co Q m $ LO CO 00p lo- LU cc co 0 0 0 0 0 0 o (O f— (O (O H (O O N O V O Lo O Lo co- O O r CO CC O O O O - O I-F H H H H H F H O O O O O (p (p (p (p C co C m C m C m C C (o (a C C C m m m C (p m 1- 2i 2i 2 2i a d a. a. a a a d a E (ui/ pg'Z) Jo}oej uoijejedaS 0 co O U _R, O h N cn IT r TRANSMITTAL LETTER CHECKLIST WELL NAME: 6^ i l-. /►'� i �, —O g PTD: .21$ —O`!I Development ✓ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: 6 di" A., / Od POOL: Zcc C'i ' Z 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. 918 , 0 L/ R , API No. 50- ! 0 3 - 0 0 -06 - 0Q. (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 Requirements / Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 5/2013 WELL PERMIT CHECKLIST Field & Pool GRTR MOOSES TOOTH, ALPINE UN O - 28210 Well Name: GMTU MT_6_-081_1_ —__ Program SER _ Well bore seg ❑�/ PTD#:2180490 Company CONOCOPHILLIPS ALASKA, INC. __--_ _ Initial Class/Type - _SER / PEND_ GeoArea 890 Unit 10750 _ On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D) NA_ 11 Permit fee attached NA 2 Lease number appropriate No Partially: AA 092346 closed in 2010. AA 081798 contains surface location; portion of well passes 3 Unique well name and number Yes through AA 081818; top prod interval and TD in AA 081819. SFD 4 Well located in a defined _pool Yes Greater Mooses Tooth, Lookout Oil Pool - 282100 5 Well located proper distance from drilling unit boundary - - Yes Conservation Order No. 747, issued _May 29, 2018, governs 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 Sufficient acreage available in -drilling unit Yes external property line where the owners and landowners are not the same on both sides of the line. 8 If deviated, is wellbore plat included Yes As planned, this well conforms with statewide spacing requirements. 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes Appr Date 11 Permit can be issued without conservation order Yes Conservation Order No. 747, issued May29, 2018, governs Lookout Oil Pool. Permit can be issued without administrative approval Yes SFD 5/30/2018 �12 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For- Yes Area Injection -Order No. 40, issued May 29, 2018, governs Lookout Oil Pool. 15 All wells within 1/4 mile area of review identified (For service well only) Yes None present._ 16 Pre -produced injector: duration of pre -production less than 3 months (For service well only) No Operator: MT6-08L1 will only be flowed back enough to clean up. It will not be pre -produced. 18 Conductor string provided _NA Conductor and surface casing set in motherbore. Engineering 19 Surface casing protects all known USDWs NA 20 CMT vol adequate to circulate on conductor & surf csg NA 21 CMT vol adequate to tie-in long string to surf csg NA 22 CMT will cover all known productive horizons Yes Drilling lateral out of 7" liner.... Will target upper Alpine C sand. 23 Casing designs adequate for C, T, B & permafrost Yes BTC supplied on similar GMT well. 24 Adequate tankage or reserve pit Yes Rig has steel pits. 25 If a re -drill, has a 10-403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes well path is 50 ft TVD above MT6-08 lateral. 27 If diverter required, does it meet regulations_ NA_ Lateral..._ Appr Date '28 Drilling fluid program schematic & equip list adequate Yes Max formation press= 3810_psi ( 9.3_ ppg EMW) will drill with 8.9 - 9.5 mud using MPD for well control GLS 5/10/2018 i29 BOPEs, do they meet regulation Yes Doyon 19 has 5000 psi BOPE 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP= 3019 psi Will test BOPE to 3500 psi 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 not expected .. Rig has sensors and alarms 34 Mechanical condition of wells within AOR verified (For service well only) Yes 1/4 mile AOR done. There are no wells in the area oether than parallel mainbore. 35 Permit can be issued w/o hydrogen sulfide measures No H2S measures required. Geology 36 Data presented on potential overpressure zones Yes Production interval will be drilled with 8.8-9.5 ppg mud using Managed Pressure Drilling Technique Appr Date 37 Seismic analysis of shallow gas zones NA to keep the well balanced dynamically. SFD 5/8/2018 38 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly progress reports_ [exploratory only] NA_ Onshore injection well branch. Geologic Engineering Public 7" liner requires a CBL log. May permit well for Annular disposal if CA LOT's are favorable. GIs Corn i ioner: ors Date: Commissioner: 5 / 3 lily Date C missioner 4 Date � '� 13, I I ,J