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Home My WebLink About220-015From:Guhl, Meredith D (OGC) To:Abbie Barker; Carrie Janowski; Cody Dinger; Darci Horner - (C); Donna Ambruz; Jerimiah Galloway; Joseph Lastufka; Josh Allely; Juanita Lovett; Tom Fouts Subject:Expired Prudhoe Bay PTDs Date:Wednesday, April 27, 2022 1:42:00 PM Hello, The following Permits to Drill, issued to BP Exploration (Alaska) and transferred to Hilcorp North Slope, have expired under Regulation 20 AAC 25.005 (g). The PTDs will be marked expired in the AOGCC database. PBU LIS K-333, PTD 220-004, issued February 3, 2020 PBU 06-15A, PTD 220-012, issued January 30, 2020 PBU LIS L3-26, PTD 220-015, issued February 12, 2020. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl (she/her) Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. THE STATE GOVERNOR MIKE DUNLEAVY Kenneth Allen Engineering Team Lead BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Lisburne Oil Pool, PBU L3-26 BP Exploration (Alaska), Inc. Permit to Drill Number: 220-015 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 wvvw.aogcc.alaska.gov Surface Location: 4350' FSL, 4423' FEL, SEC. 22, T11N, R15E, UM Bottomhole Location: 502' FSL, 2380' FEL, SEC. 23, T11N, R15E, UM Dear Mr. Allen: Enclosed is the approved application for the permit to drill the above referenced development well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce is contingent upon issuance of a conservation order approving a spacing exception. BP Exploration (Alaska), Inc. assumes the liability of any protest to the spacing exception that may occur. 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, ere y . Price air DATED this Na day of February, 2020. STATE OF ALASKA 'ASKA OIL AND GAS CONSERVATION COMMISS PERMIT TO DRILL 20 AAC 25.005 la. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp❑ 1c. Specify if well is proposed for: Drill 0 Lateral ❑ Stratigraphic Test ❑ Development - Oil 0 Service - Winj ❑ Single Zone 0 Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2, Operator Name: 5. Bond Blanket 0 Single Well ❑ 11 Well Name and Number: BP Exploration (Alaska), Inc Bond No. 29S105380 r' PBU 11-3-26 Address: 3. 6. Proposed Depth: 12. Field/Pool(s): MD: 15679' TVD: 8996' PRUDHOE BAY, LISBURNE OIL 1 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): ADL 028322 & 028323 Surface: 4350' FSL, 4423' FEL, Sec. 22, T11 N, R15E, UM 8. DNR Approval Number: 13. Approximate spud date: Top of Productive Horizon: 883' FSL, 2500' FEL, Sec. 22, T11N, R15E, UM 84-62 April 10, 2020 9. Acres in Property: 2560 14. Distance to Nearest Property: Total Depth: 502' FSL, 2380' FEL, Sec. 23, T11 N, R15E, UM , 21770 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 68.25 feet 15. Distance to Nearest Well Open to Same Pool: Surface: x- 708123 , y- 5961374 Zone - ASP 4 GL Elevation above MSL: 21.1 feet 1 1840 16. Deviated wells: Kickoff Depth: 600 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 108 degrees Downhole: 3973 Surface: 3058 18 Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data Driven 20" 129.45# X-56 127' Surface Surface 127' 127' 16" 13-3/8" 68# L-80 BTC 4110' Surface Surface 4110' 3778' 2190 sx LiteCrete, 312 sx Class 'G' 12-1/4" 9-5/8" 47# L-80 Vam 21 9476' Surface Surface 9476' 8378' 704 sx LiteCrete, 163 sx Class'G' 8-1-2" 7" 26# L-80 VamTop HC 869' 9260' 8191, 10129' 8903' 189 sx Class'G' 6-1/8" 1 4-1/2" 12.6# 1 13Cr85 I VamTop 5879' 9800' 1 8633' 1 15679' 1 8996' 219 sx Class'G' 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 0 20. Attachments Property Plat 0 BOP Sketch 0 Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated Contact Name Minge, David from without prior written approval. Authorized Name Allen, Kenneth W Contact Email David.Mingeo_bp.com Authorized Title Engineering Team Lead Contact Phone +1 9075645279 Authorized Signature _ Date 14. e Commission Use Only Permit to Drill �1 Number: vtao— O Is API : 50- Oz.9 — *-- ,—CO Permit Appro I I Date: �/ Z See cover letter for other requirements: e 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: P Other: J&C �$ TE2ST-r o -r560 �5 Z Samples req'd: Yes ❑ No 5Y Mud log req'd: Yes ❑ No t, H2S measures Yes 53" No ❑ Directional svy req'd: Yes B' No ❑ S acing ex eption req'd: Yes IIE' No ❑ Inclination -only svy req'd: Yes ❑ No � i � 10T, 1 Post initial injection MIT req'd: Yes ❑ No El ElZ) �rAr-7A _Z5S, p'3C15) Vlp l�v3eS �.ih l CrP�"'� 7 t�t Y +kAA._ A6 Fes' *r e �, V ALM-I \ A PMR tsmiLL(r-G- 4C01(b r11Y40MROVED BY Approved by: COMMISSIONER THE COMMISSION Date CY "'� 'y Form 10-401 Revised 5/201 This permit is valid for 2� r� R f�&l o p�oval (20 AA 25.005(g)) / ' "r bmit Form and ��,,,jjj '' `` Attachments in Duplicate '��' Lo `=GCB oz/aslao To: Alaska Oil & Gas Conservation Commission From: David Minge, ODE Date: January 21, 2020 RE: L3-26 Permit to Drill The L3-26 well is scheduled to be drilled by Parker 272 in April 2020. This grassroots well is a horizontal producer targeting the Lisburne (Wahoo). The planned well is a four string, big -bore design using 13-3/8" surface casing, 9-5/8" intermediate casing, 7" intermediate liner and 4-1/2" production liner. The surface casing will be set in the SV4. The first and second intermediate strings will be set in the HRZ and top Lisburne, respectively. The production interval will be completed with a cemented and perforated liner. Maximum anticipated surface pressure will be from the Base Lisburne. With a full column of gas, MASP from BLSB to surface is 3058 psi (8.35 ppg EMW at BLSB at 9150' TVDss with 0.1 psi/ft gas gradient). • The well will be drilled by Parker 272 using their 5000 psi four preventer BOP stack (3 rams and an annular). The BOP equipment will be tested to 3500 psi. A detailed operations summary is included with the permit application. If there are any questions concerning information on L3-26, please do not hesitate to use the contact information below. David Minge Office: (907) 564-5279 Cell: (907) 250-2917 Email: david.minge@bp.com Attachments: Well Bore Schematic Directional Package BOPE Schematic Diverter Line Layout Diagram Well Head Schematic Tree Schematic L3-26 PTD 1 1/21/2020 Well L3-26 Planned Well Summary Well Producer Target Lisburne Type Objective Current Status Grass Roots Well Estimated Start Date: 1 04/ F Time to Complete: 1 31.1 Days Surface Northing Easting I Offsets TRS Location 5,961,374.38 708,123.21 1 4350' FSL / 4423' FEL 11 N 15E Sec 22 Northing Easting TVDss Offsets TRS TLSB 5,957,962.34 710,148.27 8835' 883' FSL / 2500' FEL 11 N 15E Sec 22 BHL 5,957,734.39 715,557.59 8928' 502' FSL / 2380' FEL 11 N 15E Sec 23 Planned KOP: I 600' MD Planned TD: I 15,679' MD / 8,928' TVDss Rig: Parker 272 Directional - 1-3-26 WP15 GL-RT: 1 47.15 1 1 RTE (ref MSQ: 1 68.25 KOP: 600' MD -320 in the surface section -350 in the 1st intermediate section Maximum Hole Angle: -350 in the 2nd intermediate section -1080 in the production section Close Approach Wells: All offset wells pass BP anti -collision scan criteria Survey Program: Reference attached directional program Nearest Property Line: 21,770' Nearest Well within Pool: 1,840' Hydraulic Fracture Planned? No 1-3-26 PTD 2 1/21/2020 Formation Tops and Pore Pressure Estimate Formation Depth (TVDss) Most Likely Pore Pressure (ppg EMW BPRF 1856 8.4 SV5 3178 8.4 SW 3343 8.4 SV3 3780 8.4 SV2 3998 8.4 SV1 4368 8.4 UG4 4897 9.5 UG4A 4937 9.5 UG3 5130 9.5 UG1 5769 9.5 WS2 6340 9.3 WS1 6540 9.3 CM3 6740 10 CM2 7227 10 CM1 7751 10 THRZ 8136 10.2 TSAD 8346 7.27 TKVK 8663 9.9 TLSB 8835 8.35 0-26 PTD 3 1 /21 /2020 Casing/Tubing Program Hole Size Casing / Wt/Ft Grade Conn Length Top Bottom Tbg O.D. MD / TVDss MD / TVDss Driven 20" 129.45# X-56 - 127' Surface 127' / 62' 16" 13-3/8" 68# L-80 BTC 4133' Surface 4133' / 3710' 12-1/4" 9-5/8" 47# L-80 Vam 21 9410' Surface 9410' / 8300' 8-1/2" 7" 26# L-80 Vam Top HC 869' 9260' / 8123' 10,129' / 8835' (150' lap) 6-1/8" 4'/2" 12.6# 13Cr-85 Vam Top 5879' 9800' / 8565' 15,679' / 8928' (150' lap) Tubing 4'/2" 12.6# 13Cr-85 Vam Top 9805' Surface 9805' / 8569' (-5' into liner TBR) Mud Program Surface Mud Properties: MMH 16" Hole Section YP LSR-YP Depth Interval (ppg) PV (cp) (lb/1 0ft2) API FL (2x3 - 6) pH rpm Surface - TD (SV4) 8.5 - 9.1 6-20 35-80 <15 25-60 10 - 11 Intermediate 1 Mud Properties: LSND 12-1/4" Hole Section Depth Interval Density PV (cP) Ib/1 OftYP 2 API FL HTHP FL MBT pH 13-3/8" Shoe - UG4 8.8 - 9.8 10-20 20-30 <8 NA <20 8.5 - 9.5 UG4 - WS1 9.8 - 10.1 10-20 20-30 <8 NA <20 8.5 - 9.5 CM3 - CM1 10.1 - 10.5 10-20 20-30 <8 NA <20 8.5 - 9.5 • HRZ - TD HRZ 10.2 - 10.8 10-20 20-30 <5 <10 <20 8.5 - 9.5 Intermediate 2 Mud Properties: LSND 8-1/2" Hole Section Depth Interval Density PV (cp) lb/1 00ft2 API FL HTHP FL MBT pH 9-5/8" Shoe - TD TLSB 10.2 - 10.8 1 10-20 20-30 <5 <10 <20 8.5 - 9.5 Production Mud Properties: Water Based Polymer Fluid 6-1/8" Hole Section Depth Interval Density PV (cP) Ib/1 Oft2 YP API FL HTHP FL MBT pH 7" Shoe - TD 8.6 - 9.0 <12 12-20 <12 NA <4 8.5 - 9.5 3 _ Logging Program nw (0,on)CSgZ51Vbss) 4- 6 q-, 3 $'6EM� %Ob 16" Surface Drilling: Dir/GR Open Hole: None Cased Hole: None 12-1/4" Intermediate 1 Drilling: Dir/GR/RES Open Hole: None Cased Hole: None 8-1/2" Intermediate 2 Drilling: Dir/GR/RES Open Hole: None Cased Hole: None L3-26 PTD 4 1 /21 /2020 6-118" Production Drilling: Dir/GR/RES/NEU/DEN/PEF/CAL/IMAGE Open Hole: None Cased Hole: None Cement Program Casing Size 13-3/8" 68# L-80 BTC Surface Casing Lead Open hole volume + 300% excess in permafrost / 40% excess below permafrost Basis Lead TOC Surface Tail Open hole volume + 40% excess + 80 ft shoe track Tail TOC 500 ft MD above casing shoe -Spacer -100 bbls of 10 ppg Viscosified Spacer (Mud Push II Total Cement Lead 744.8 bbls, 4182 cuft, 2190 sks 11.0 ppg LiteCRETE - 1.91 cuft/sk Volume Tail 64.4 bbls, 362 cult, 312 sks 15.8 ppg Class G - 1.16 cuft/sk Temp BHST 71 ° F Casing Size 9-5/8" 47# L-80 Vam 21 Intermediate Casing Lead Open hole volume + 0% excess Basis Lead TOC 500 ft MD above Top UG4 Tail Open hole volume + 0% excess + 80 ft shoe track Tail TOC 500 ft MD above casing shoe Spacer -60 bbls of 11 ppg Viscosified Spacer (Mud Push II) Total Cement Lead 218.1 bbls, 1225 cuft, 704 sks 11.5 ppg LiteCRETE HP - 1.74 cuft/sk Volume Tail 33.7 bbls, 189 cult, 163 sks 15.8 ppg Class G - 1.16 cuft/sk Temp BHST 167° F Casing Size 7" 26# L-80 Vam Top HC Intermediate Liner Lead N/A Basis Lead TOC N/A Tail Open hole volume + 40% excess + 150 ft liner la + 200 ft 5" DP x CSG + 80 ft shoe track Tail TOC Top of liner Spacer -25 bbls of 12 ppg Viscosified Spacer Mud Push II Total Cement Lead N/A Volume Tail 39.4 bbls, 221 cult, 189 sks 15.8 ppg Class G - 1.17 cuft/sk Temp BHST 179° F Casing Size 4-1/2" 12.6# 13CR-85 Vam Top Production Liner Lead N/A Basis Lead TOC N/A Tail Open hole volume + 30% excess + 150 ft liner la + 200 ft 4" DP x LNR + 80 ft shoe track Tail TOC Top of liner Spacer -30 bbls of 8.6 ppg Viscosified Spacer (Mud Push II) Total Cement Lead N/A Volume Tail 129.6 bbls, 728 cult, 219 sks 8.6 ppg Bimodal - 3.32 cuft/sk (additional volume scaled to severity of loss rate) Temp BHST 181 ° F L3-26 PTD 5 1/21/2020 Surface and Anti -Collision Issues Surface Close Proximity: No wells will be affected by the Parker 272 rig shadow. Sub -Surface Pressure Management: The following wells will be shut-in for reservoir pressure purposes while drilling: • 11-10A • 11-08 • 04-17 Anti -Collision: All offset wells pass BP anti -collision scan criteria. Offset well ownership information All offset wells identified within 200 ft of the proposed wellbore are operated by BP. Hydrogen Sulfide L3-Pad is considered an H2S site. Recent H2S data from the pad is as follows: Well Name H2S Level Date of Reading #1 Closest SHL Well H2S Level 1-3-24 60 05/12/97 #2 Closest SHL Well H2S Level 1-3-30 80 04/19/19 #1 Closest BHL Well H2S Level 1-3-24 60 05/12/97 #2 Closest BHL Well H2S Level 1-4-15 70 04/05/14 #3 Closest BHL Well 112S Level 1-3-28 120 04/16/93 #4 Closest BHL Well H2S Level 1-4-31 45 11/24/13 Max Recorded H2S on Pad/Facility 1-3-24 120 04/16/93 's-' ci ose* We (k Faults Reference "Drilling Critical Issues" section. Drilling Waste Disposal • There is no annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul Class I waste to DS-04 and/or Pad 3 for disposal. Contact the GPB Environmental Advisors (659-5893) for guidance. 1-3-26 PTD 6 1 /21 /2020 Well Control The 16" surface hole will be drilled with a diverter (see attached diverter layout). The 12-1/4", 8-1/2" and 6- 1/8" hole sections will be drilled with well control equipment consisting of 5,000 psi working pressure rams (2), blind/shear rams, and annular preventer capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3,500 psi. BOP test frequency for 11-3-26 will be 14 days with function test every 7 days. Except in the event of a significant operational issue that may affect well integrity or pose safety concerns, an extension to the 14 day BOP test period should not be requested 12-1/4" Intermediate 1 Interval Maximum anticipated BHP 3259 psi at Base WS1 at 6740' TVDss 9.3 ppg EMW Maximum surface pressure 2585 psi at Base WS1 0.10 si/ft gas gradient to surface Kick tolerance 25 bbls with 11.6 ppg frac gradient. Planned BOP test pressure Rams test to 3500 psi / 250 psi. Annular test to 3500 psi / 250 psi Integrity Test - 12-1/4" hole LOT after drilling 20'-50' of new hole 9-5/8" Casing Test 3500 psi surface pressure 8-1/2" Intermediate 2 Interval Maximum anticipated BHP 3292 psi at BSAD at 8662' TVDss 7.31 ppg EMW Maximum surface pressure 2426 psi at BSAD 0.10 si/ft gas gradient to surface Kick tolerance 25 bbls with 11.6 ppg frac gradient. Planned BOP test pressure Rams test to 3500 psi / 250 psi. Annular test to 3500 psi / 250 psi Integrity Test - 8-1/2" hole LOT after drilling 20'-50' of new hole 7" Casing Test 3500 psi surface pressure 6-1/8" Production Interval Maximum anticipated BHP 3973 psi in the LSB at 9150' TVDss 8.35 ppg EMW Maximum surface pressure 3058 psi in the LSB 0.10 si/ft gas gradient to surface Kick tolerance N/A - see Variance Request 2. Planned BOP test pressure Rams test to 3500 psi / 250 psi. Annular test to 3500 psi / 250 psi Integrity Test - 6-1/8" hole N/A - see Variance Request 2. Planned completion fluids 8.5 ppg seawater / -2,000' TVDss diesel 1-3-26 PTD 7 1/21/2020 Variance Requests 1. To avoid the risk of plugging the flow line with large rocks and wood encountered while drilling surface hole, it is requested to drill without a flow paddle for the first portion of the surface hole. After drilling past the larger rocks and wood sections, the flow paddle will be put back in the flow line (<1000 ft). This is a variance from 20 AAC 25.033. Procedures/Safeguards with paddle removed: • Fluid levels will be monitored in the pits for both gains and losses while drilling. Alarms will be set to indicate if gain or loss of more than 10 bbls has occurred. • The well will be monitored for flow when the pumps are off at each connection. • The planned 8.5 — 9.1 ppg fluid will provide over balance to formation fluid 2. A variance to 20 AAC 25.030(f) is requested to forgo the FIT after drilling out the 7" liner shoe. The planned depth of the Intermediate 2 liner shoe is in the target reservoir (Lisburne), and the production section does not depart the Lisburne formation. This request is contingent upon a successful Intermediate 2 cement job. 1-3-26 PTD 8 1/21/2020 L3-26 Drill and Complete Operations Summary Pre -Rig Operations 1. Pad prep and conductor inspection (conductor already installed) Rig Operations 1. MIRU Parker 272. 2. Nipple up diverter system and function test. 3. MU 16" surface motor drilling assembly with 5" DP and drill to TD of surface section. POOH and LD drilling assembly. 4. Run 13-3/8" casing to TD and cement. Test casing to 3500 psi. 5. Nipple down diverter system. Nipple up 13-5/8" wellhead system. Nipple up BOPE and test to 3500/5000 psi. BOP configuration (top -bottom): ann ar, 9- /8" FBR, blind/shear, mud cross, 2-7/8" x 5" VBR 'Z 7 %our /2 a A c.e �' /7O(rCL_ 6. MU 12-1/4" intermediate #1 drilling assembly with 5" DP. Drill shoe track and 20'-50' formation. 7. Perform LOT. 8. Drill 12-1/4" section to TD in the HRZ formation. POOH and LD drilling assembly. 9. Run 9-5/8" casing to TD and cement. Test casing to 3500 psi. 10. Install 9-5/8" casing packoff and test to 3500 psi. Inject freeze protect into 9-5/8" x 13-3/8" annulus. 11. Change upper ram to 4-1/2" x 7" VBR and test. 12. MU 8-1/2" intermediate #2 drilling assembly with 5" DP. �Drrill shoe track and 20'-50' formation. 13. Perform LOT. b, C. .TiEi�- � Aq r 4 �: r CST 5r C A 51 g X 1_i_5Z`'io -1-1 OGC C 14. Drill 8-1/2" section to TD in the top Lisburne. POOH and LD drilling assembly. 15. Run 7" liner to TD and cement. POOH and LD liner running assembly. Test liner to 3500 psi. 16. Change upper ram to 2-7/8" x 5" VBR and test. C � '� � A)/ ?_ £ t>oR."V �� 0 VZ * . & P? R wn4L_ 17. MU 6-1/8" production drilling assembly with tapered 4" x 5" DP. Drill shoe track. 18. Drill 6-1/8" section to TD in the Lisburne formation. POOH and LD drilling assembly. 19. Run 4-1/2" liner to TD and cement. Set hanger and liner top packer. POOH and LD liner running assembly. 20. Run-V2500' of 2-7/8" guns and perforate production liner. 21. Run and land 4-1/2" completion. 22. Drop B&R and set production packer. Individually test tubing and IA to 3500 psi. 23. Shear GLV and circulate freeze protect to —2000' TVD. Set TWC and test to 3500 psi. 24. Nipple down BOPE. Nipple up adapter and dry hole tree and test to 4500 psi. 25. RDMO Parker 272. L3-26 PTD 9 1/21/2020 Post -Rig Operations 1 V Install tree. Pull TWC. 2 S Pull MR. Set DGLV. 3 C Set retainer/CBP. Acid job. Mill retainer/CBP. Estimate 3-6 stages. 4 S Set LGLVs. SBHP. 5 T Flowback test. L3-26 PTD 10 1/21/2020 L.3-26 Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE I. Well Control / Reservoir Pressures A. Surface Hole: The permafrost and SV formation are expected to be normally pressured at 8.4 ppg EMW. Pore pressures will be controlled with 8.5 — 9.1 ppg water based mud. B. Intermediate 1 Hole: The Sagavanirktok sands are expected to be at 8.4 ppg. The Ugnu formation is expected to be at 9.5 ppg EMW. The West Sak formation is expected to be at 9.3 ppg. The Colville formation is expected to be at 10.0 ppg EMW. Pore pressures will be controlled with a 8.8 — 10.8 ppg water based mud. C. Intermediate 2 Hole: The Sadlerochit formation is expected to be at 7.3 ppg EMW. The Lisburne formation is expected to be at 8.35 ppg EMW at casing point. Pore pressures will be controlled with a 10.2 — 10.8 ppg water based mud. D. Production Hole: The Lisburne is expected to be at 8.35 ppg EMW. Reservoir pressures will be controlled by using 8.5 — 9.0 ppg water based mud. II. Lost Circulation/Breathing A. Surface Hole: There are no expected fault crossings. Be alert for surface broaching in offset wells. B. Intermediate 1 Hole: There are no expected fault crossings. Be aware of wellbore breathing risk in the Colville formation. Keep drilling ECDs below hard line. C. Intermediate 2 Hole: There are no expected fault crossings. Be aware of lost circulation risk at casing point. D. Production Hole: There are two expected fault crossings. Offset L3-Pad wells have experienced moderate to high lost circulation in this region. III. Fault Locations Formation Where Fault Encountered MD Intersect TVDss Intersect Throw Direction and Magnitude Uncertainty Lost Circ Potential Fault 1 —Lisburne 11,122' -9,068' W/ 15' 150' Medium Fault 2 — Lisburne 15,193' -8,898' E / 20' 150' Medium IV. Integrity Testing Test Point Test Depth Testtype EMW (lb/gal) 13-3/8" Shoe 20'-50' from the 13-3/8" shoe LOT 11.6 ppg 9-5/8" Shoe 20'-50' from the 9-5/8" shoe LOT 11.6 ppq V. Hydrogen Sulfide L3-Pad is considered an H2S site. Recent H2S data from the pad is as follows. - Well Name H2S Level Date of Reading #1 Closest SHL Well H2S Level L3-24 60 05/12/97 #2 Closest SHL Well H2S Level L3-30 80 04/19/19 #1 Closest BHL Well H2S Level L3-24 60 05/12/97 #2 Closest BHL Well H2S Level L4-15 70 04/05/14 #3 Closest BHL Well H2S Level L3-28 120 04/16/93 #4 Closest BHL Well H2S Level L4-31 45 11/24/13 Max Recorded H2S on Pad/Facility L3-24 120 04/16/93 VI. Anti -Collision Issues All offset wells pass BP anti -collision scan criteria. CONSULT THE L3-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. L3-26 PTD 11 1/21/2020 Iff = H-LH,TUATO = P RO P iuS E D :TUATOR = 8-EV - REV 2 ELLv = _ >P ix Angle = _° Q � 20' COND, turn MD = 129AU, X-56, tumTVD= 8900' SS D = 18.75" 13-31W CSG, 68#, L-80 BTC, D = 12.415" 4133' .11 TOc —5000' TOP OF 7" LNR 1— 9260- SK GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 5 4 3 2 1 9260' 9-5/8" X 7" WFD LTP w/11EBACK SLV & WFD HGR, ID = 9-5/8' CSG, 47#, L-80 VAM 21, D = 8-681" 9410' YZI 4-1/2" HES X NP, D= 3-813" Minimum ID = 9650' 7- X 4-1/2' HES TNT PKR, ID = 4-1/2" HES X NP, D = 3-813" 4-1/2" HES XN NP, D = 3.725" ITOP OF 4-1/2" LNR — 9800' j 4-1/2- TBG, 12.6#, 13CR-85 VAM TOP, 9805, -0152 bpf, D = 3-958" LNR, 26#, L-80 VAM TOP HC, 10129' ;83 bpf, D = 6276" PBf;ORATION SUMMARY REF LOG A NGLE AT TOP PERT Note: Refer to Production DB for historical pert data SIZE SPF NTERVAL Opn/Sqz SHOT SQZ PBTD 1b694' 4-1/2" LNR, 12.6#, 13CR-85 VAM TOP, 15679' .0152 bpf, ID = 3.958" 9800' IHGR,7"X 5"WFD LTP wmEBACK SLV & WFD ID = 9805' 4-1/2" WLEG, D = 3-958' ELMD TT NOT LOGGED F----]5" X 4-1/2" XO, ID = _" DATE REV BY COMMENTS DATE REV BY COMMENTS ORIGINAL COMPLETION 07/29/19 JMD BULT PROPOSAL 07/31/19 NWJMD BULTPROPOSALREVI 0925/19 NWJMD BULT PROPOSAL REV 2 LISBURNE UNfi WELL: L3-26 PERMIT No: API No: 5"29- -W SEC T N R E ' FSL & BP Exploration (Alaska) �2 CL a m 'i cn LO NCD a M Z Z = N Q J J A— W J a IL d U Z d- N N Q Q 3 Q N N a m a COD c0 d N N Q (0a a U N m m N Y Y E J Z Z dd a H W ci U L C O d L w N d � � C d O C 3 U d w U 0 a m J 'f z d) O LL m U) a Q � N � E d M J Q ` Z C N N Cl) Z J J J IL Q a� p 0 m d y .d+ c)av�33 0 C O O t'j d m d U � � N > N U m o cn 3 0m c m m m c c (D m N "v M N W � Z a d o c o ccu U N f- m J d co m co Q c Q a a Y Y U d Q Q ca W N 3 N a- d N p 0 C7 J Q U 0 Z « M Q Q � Q Q Q Z Z d E co Z v y O N O. 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M M C7 C') Cl) m M Cl) Z; N_ m m m V m m O O m M N m N O O N N n m m O m r m N E;m n m r- r O r N r M M m m m N � O_ V co co CO (o M m r N r.- m m m r-m m m (o m N r O N N O O o N m V N m n O - O O C m (n V O O V m m M N m 0) Co in N • moo Oo m m m m m m m m m m m m m m m m m m r Cl) V m N V m n 0 m m O r N m m m N N N N M N O N OR m N m O co (o N O O O M V )o m r m M M (o O o m V N m O m O (o M O v Cl) N M m r O O V m M m V n m m m m m V N _ m Cn N n NO 00 m m m m C O O o O O oo m m m m m m m m of ai m m W CA CA m m of m m m 0 0 0 0 0 0 0 0 v v v v m m m m 0 0 0 0 0 0 0 0 O O o 0 0 O O o 0 0 0 o O o 0 0 0 0 O o 0 0 0 O o 0 0 0 v v v v v v v v v v v v v IT v v v v m m m m m m m m m m m m m m m m m m O O O o O O O O 0 O p 0 O m m m m m m m m m m m m O o V n V V n r V n O o 00 g o 0 o 0 0 0 o U7 Cl) N Cl) Cn Cl) CA M LO Cl) )n C'M m M m V m (o m m m r m m O m N m m O m o V O m O (") m ? 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T N m m N m co m V m u) Cl) m m (c m r` m m m m m O m -I m N m M m It N u) m m u) rl- m m to m o O rn -I Lo N N M N v LY d L y co v) M M M co M co M ? v vC V u) u) u) to N o >> Q W V F z to Q r O O- r0 ci u) l+I O N M M N O �-- N O Ln O M O O O m m N m M m. o m m to m M m m m n', m M r` m (q T u) u7 O m N m 7 P m m m m m M m N O m O m M N m N m M M v O Lo N u) m (Z m r- u) m N m m m m o M m� u) Lo lr Lo m m m co m m m m m cc co co cq m m (0 rn aN M f7 M M M Mc? co m M Cl) Cl) Cl) Cl)m Cl) Cl) Cl) qi M M M Cl) M M ... z i� C I (13 I a V N u) m N m m N V m m m m m m m m m m m m m m m m m m m m m V N cO m m m m m m m m m m m m m m m m m m m m m p V N o m n r- N N N N N N N N rn N � N n N r� N N r-- N N 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 pr N OD m m m m m m m m m m m m m m m m m m m CO m m m m I >❑ F m m n r*. Cl) � . M L rn 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 m m m m m m m m m m m m m m V N O u) m Iq V V V V v V a a a V v V C V V a't - m - n - cn - v - 0 - c - a- v - v - G - v v v v v G v v G v a v cc v G G >Q �y F V 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 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 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 v v v v v v v v v v v v v v v v v v v v m m m v m m v m m m m m m m m m m m m m m m m v m v m m v m 4 — EL m Q g O m m m m o o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Q O m m C m o m m m N O O {y O a 0 O o O O O O O O O o O 0 O 0 O 0 O 0 O o O O O O O O O o O 0 O 0 O o O O 0 0 0 o m m m m m m m m m m m m m m m m m m m m m m o m ro E N C m d M C J Q C No Z N O ~ o O N MM5� o 0 z J J J a J M 7 0 o O o M q O o 0 0 0 0 0 0 0 0 0 0 0 0 o O o 0 0 N N y 0 o o O O O o O O O O O o O v r O O n 0 O o O O o O O O o o O 0 O O 0 O O 0 O O 0 O O 0 O O 0 O O 0 O O 0 O O 0 O o 0 O O 0 O O 0 O O 0 O O 0 O O o O Q pQj Q to Q m m m m N O .-- N M v M m r m m O - N M v Lo m N m N N N N � N � N � N c2 N � N � N � ('� � ['� (•7 lh Ce . ('� . M .. 07 C . C _ N oNi M U o c M a d c o N Q C W N \ o :E m U d N 3 Q 6, rn WN a U Z x r Q w � 7 oLO lQ N N w co (o a va aU ' TuTu m o d a C) M Y Y z z E a) � CL CL 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 O O 0 O O O O 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 Co d � J O p o m v o n cn rn o N o 0 v) v o 0 o n m m rn Cl? N O Cl) CO n (D o a1 O O O O O a) ao co co ao m o 0 0 0 0 r m a) O N clV o 0 n n r n r r r r w M N O O m cDD � Lo N N O m m CD r o 0 m o O o N m m m o v C1 O O O O M m m r n r c m m o r r r r r r r c z Lo rr Lo Lo r r r r r r 0 m G G rn G m e C rn a Zo 0 o 0 0 0 o o o o o N O n Ln N O c00 0 m vri 0 0 In LO 0 0 LO m n o co n m CD o - N c� V LO o m m (n 0 co m m m W NO.. mc0 ((O (O Lo (mn M rn V 7 m a) N N M C N (w rr NO 0 r a) $ M C? C? C? C? C? M M M M Z� ocm ccm ccm m arD arD OD N m m m m m m m m m m p N M m CO m o m o o m m v v v v v v v v v v rn rn rn rn rn rn rn rn rn rn p m m m m m m m m m o 0 0 0 0 0 0 0 0 0 0 v v v v v v v v v v rn rn rn rn rn rn rn rn rn rn Q �- O O O o 0 0 0 0 0 0 O O O O N O O O O O O O O O O O O O O O O O m m m N O O O O O O O O O O O 0 0 o O O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 a) o o aD r n r r r r o Ci am) O n . N m (D cm+) N O o v o a) m m w o m n o m c) m n n p- rn r r o o n m m 0 O N cl V v) v v v v v o vi LO o vi vi O N O m r v N O m m a) LO � v cl) v) c) c) M N N o ci co rn r o co rn r� c) n v N CD It O o n v r co to o 0 0 o v v cn co W) r r n 0 0 0 0 c rn rn 0 c o rn 0 0 0 rn rn rn rn rn rn rn rn 0 0 0 0 0 0 o co o o 0 O U (00 N c+1 amD v O O cn N O N N N � u N N cl) v o 0 o n m a) O -- N V o (o 0 o (D o co N r- N r- v c) m y o o m rn m C ? N 6) c`7 C) N N (P coDN M O m N cl) N V r r n n o ao ao cco 0 cc ri I? ri ri ri ri ri c? c? of ai IT w [ruco � o D N Oco o) O O n O c7 o N o V O_ n m m cco m m m m a O W 01 m m m m m m m o m m m m 0 to rn m o o) rn o 0 0 m O O r m M O ci V N o a) N v O o M m 0 0 v v o 0 o o r r o rn o) C m e G am m e c G m G 0 o o o ow m m m co o 0 o O o o o o 0 0 o o o o O O O O O O O O v v v v v v v v v v v rn m m a) a) o rn rn rn a) a) CL m O 0 O O O O O O O O N N O p 0 O O O O O O O O O O O O O O O O O m co o o o (n In o o v) o O o o O O O O O O O m r o to 0 o 0 0 o m (D o cQp m a) Cl) a) a) a) a) a) a) rn m m o r: o 0 0 o m m aD o U o o V N E �. E ar cl) m Q E J 9 Z _1 J J d J O O O O O O O O O c7 e' O O m Lo O O O O O O O 0 0 0 0 0 0 0 . 0 v, a o o r o o o O O O O O v n T O O O O O O O O O o O v N O O O O O O O O) N O O Cc?O O O O O O N p O O o r 0 O O O O O O r a) O N c7 V o o r n m a1 D7 CD N c') v (n o (o p ri a a v v v v v v v v v v vi 6 vi vi (ri N vi vi p v y m a c p O d d y m 0a`in3$p a O NE 0 a m 0 0 Cl)Lo m a U 0 Z U � � Q N N N N N 0 OD 00 d m to d N 0 a a' N m m E M Y Y U) J Z Z E d 'c g a r w m U .a C O d L w N d m O (n O O p M C O d in � O O N O In y d � (D (O a0 � 2 m c U v w S U N d T K = w >> J F Z G7 ❑ Im (NO N M O +� C d rn V n E C O o R Q ❑ Q ❑ Q Q � Cl) m V N M m n V N O I� V O O N N O M0. co m O O O Co O ca O C U l0 U V O O O O O mO L O C] O L o � L V N M M O t O O O 7 In m C U U U cn n o V '° O w O O_ v 0 m m m O O OMD " m m M ❑ N 0 r ° c� m m in m m in in in in in in in cn m r-- m E o v OD (D Ln o (O (n O m CO M (n rn Z o (4 n (o 0) n V o n M N o (D rn N o O O O N n �j v V n to N n N v IT n W (l- M In N M O) V M N M (D M � m D) M n O M (D,(O M (O M N W N 73 — — — N NM M CD m n N C_ O O U O (O (O 10O (3) M M 00 Ln M 00 N W O M N O O m O in M (O M M n N 7 M N (O O O m 0 O OD N N n W o N M (D n V OD Ln J N m OM 00 M V m m V v_ N M in m n rn v N (n Lq n n OO [O fV () Z N N M MI? 07 07 MC? ('7 O? (+I In M = + ... Ln d N N N N m l0 L OD (D m Cl) (D 0)n O Q V C m= D? n - O (O to O M n M O O (n .- LC)(n N V n N OD m 0)M M In O 0) 00 m O N Y m m Cl) m W L O OI M OD N 07 (D M (n O O V V V N (D Q O V V N (D (n N 00 O) V V O N O V D) W 0) N V V m m � O O) MO) O) J y 0 - — .- N CO OD 00 OD 0) O) O OD 00 00 OD ap Ol7 V O) N a E O) N O O O O n m M CO Cl) Cl) Cl)Cl) CO MV E ,� V (D — WO O O O (O O M n(DO C L (D Z (D (0 Q .,. CD O O O O (O (n O In Ln M O n n O) N OD M V Cl) m N n N (O n r d N N O N A N °. N m N 00 to Cl) N �-- — n O O O _ (n D) n D) CO (v) Cl) Z J J J d J W d N n O V m Q C M C N O d C C N N V d a o) o E N go N U 0. ip 0 a N North America - ALASKA - BP Lisburne L3 L3-26 PLAN L3-26 L3-26 WP15 Anticollision Summary Report 23 September, 2019 Company: North America - ALASKA - BP Project: Lisburne Reference Site: L3 Site Error: 0.00usft Reference Well: 1-3-26 Well Error: 0.00usft Reference Wellbore PLAN 1-3-26 Reference Design: 1-3-26 WP15 BP Anticollision Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well L3-26 PLAN KB P272 @ 68.25usft PLAN KB P272 @ 68.25usft True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Reference 1-3-26 WP15 Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria nterpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,763.23usft Error Surface: Elliptical Conic Survey Tool Program Date 9/23/2019 From To (usft) (usft) Survey (Wellbore) 47.15 400.00 1-3-26 WP15 (PLAN 1-3-26) 47.15 400.00 1-3-26 WP15 (PLAN 1-3-26) 400.00 800.00 1-3-26 WP15 (PLAN 1-3-26) 400.00 800.00 1-3-26 WP15 (PLAN 1-3-26) 800.00 1,100.00 1-3-26 WP15 (PLAN 1-3-26) 800.00 1,100.00 1-3-26 WP15 (PLAN 1-3-26) 1,100.00 1,300.00 1-3-26 WP15 (PLAN 1-3-26) 1,100.00 1,300.00 1-3-26 WP15 (PLAN 1-3-26) 1,300.00 1,600.00 1-3-26 WP15 (PLAN 1-3-26) 1,300.00 1,600.00 1-3-26 WP15 (PLAN 1-3-26) 1,600.00 4,111.00 1-3-26 WP15 (PLAN 1-3-26) 1,600.00 4.111.00 1-3-26 WP15 (PLAN 1-3-26) 4,111.00 9,479.00 1-3-26 WP15 (PLAN 1-3-26) 4,111.00 9,479.00 1-3-26 WP15 (PLAN 1-3-26) 9,479.00 10,129.00 1-3-26 WP15 (PLAN 1-3-26) 9,479.00 10,129.00 1-3-26 WP15 (PLAN 1-3-26) 10,129.00 15,679.41 1-3-26 WP15 (PLAN 1-3-26) 10,129.00 15,679.41 1-3-26 WP15 (PLAN 1-3-26) Tool Name BLIND GYD-GC-SS BLIND GYD-GC-SS BLIND GYD-GC-SS BLIND GYD-GC-SS BLIND GYD-GC-SS MWD MWD+IFR+MS-WOCA MWD MWD+I FR+MS-WOCA MWD MWD+IFR+MS-WOCA MWD MWD+IFR+MS-WOCA Description Blind drilling Gyrodata gyro single shots Blind drilling Gyrodata gyro single shots Blind drilling Gyrodata gyro single shots Blind drilling Gyrodata gyro single shots Blind drilling Gyrodata gyro single shots MWD - Standard MWD + IFR + Multi Station W/O Crustal MWD - Standard MWD + IFR + Multi Station W/O Crustal MWD - Standard MWD + IFR + Multi Station W/O Crustal MWD - Standard MWD + IFR + Multi Station W/O Crustal 9/23/2019 2:29:04AM Page 2 of 4 COMPASS 5000.1 Build 81D by Company: North America - ALASKA - BP Project: Lisburne Reference Site: L3 Site Error: 0.00usft Reference Well: L3-26 Well Error: 0.00usft Reference Wellbore PLAN 1-3-26 Reference Design: 1-3-26 WP15 Summary Site Name Offset Well - Wellbore - Design 04 04-18 - 04-18 - 04-18 04-18 - 04-18A - 04-18A 04-20 - 04-20 - 04-20 04-22 - 04-22A - 04-22A 04-22 - 04-22ALl - 04-22AL1 04-22 - 04-22AP61 - 04-22APB1 04-24 - 04-24 - 04-24 04-25 - 04-25 - 04-25 04-25 - 04-25PB1 - 04-25PB1 04-35 - 04-35 - 04-35 04-35 - 04-35A - 04-35A 04-35 - 04-35AP131 - 04-35APB1 L3 L3-18 - 1-3-18 - L3-18 L3-19 - L3-19 - L3-19 L3-22 - L3-22 - L3-22 1-3-22 - L3-22A - L3-22A 1-3-23 - 1-3-23 - 13-23 L3-24 - 1-3-24 - 13-24 L3-25 - 1-3-25 - 13-25 L3-28 - 1-3-28 - L3-28 L3-30 - L3-30 - L3-30 1-3-31 - L3-31 - L3-31 1-3-31 - L3-31 P61 - 1-3-31 PB1 BP Anticollision Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: Reference Offset Measured Measured Depth Depth (usft) (usft) 8,729.24 10, 875.00 8,729.24 10, 875.00 11, 368.46 11, 075.00 12,698.71 10,775.00 12, 821.67 13,150.00 12, 702.76 10, 850.00 13, 923.11 11, 000.00 15, 674.46 15, 674.46 15, 674.46 801.73 392.24 408.25 399.94 392.24 806.66 400.11 1,086.28 1,588.54 1,590.36 1,590,36 9,475.00 9,475.00 9,475.00 800.00 375.00 400.00 400.00 375.00 800.00 400.00 1,075.00 1,575.00 1, 575.00 1, 575.00 Well L3-26 PLAN KB P272 @ 68.25usft PLAN KB P272 @ 68.25usft True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Centre to No -Go Allowable Centre Distance Deviation Warning Distance (usft) from Plan (usft) (usft) 749.42 267.50 481.90 Pass - Major Risk 749.42 267.50 481.90 Pass - Major Risk 1,169.50 172.37 1,052.59 Pass- Major Risk 943.45 241.58 737.95 Pass - Major Risk 262.47 249.39 94.83 Pass - Major Risk 935.39 242.05 725.05 Pass - Major Risk 673.09 383.59 351.20 Pass - Major Risk Out of range Out of range 1,185.62 248.81 1,002.59 Pass - Major Risk 1,185.62 248.59 1,002.81 Pass - Major Risk 1,185.62 248.72 1,002.68 Pass- Major Risk 236.40 24.74 211.68 Pass - Major Risk 231.44 25.18 206.26 Pass - Major Risk 120.02 23.87 96.15 Pass - Major Risk 120.06 24.86 95.20 Pass - Major Risk 178.06 26.67 151.40 Pass - Major Risk 54.42 25.48 28.95 Pass - Major Risk 180.69 25.74 154.95 Pass - Major Risk 57.66 30.35 27.31 Pass - Major Risk 82.50 34.68 47.82 Pass - Major Risk 273.19 35.46 237.73 Pass - Major Risk 273.19 35.46 237.73 Pass - Major Risk 9/23/2019 2:29:04AM Page 3 of 4 COMPASS 5000. 1 Build 81D i by Company: North America - ALASKA - BP Project: Lisburne Reference Site: L3 Site Error: O.00usft Reference Well: 1-3-26 Well Error: O.00usft Reference Wellbore PLAN 13-26 Reference Design: L3-26 WP15 BP Anticollision Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: Well L3-26 PLAN KB P272 @ 68.25usft PLAN KB P272 @ 68.25usft True Minimum Curvature 1.00 sigma EDM R5K-Alaska PROD -ANCP1 Offset Datum Reference Depths are relative to PLAN KB P272 @ 68.25usft Coordinates are relative to: 1-3-26 Offset Depths are relative to Offset Datum Coordinate System is Alaska NAD27 State Plane Zones, NAD27' OGP-Usa AK Central Meridian is 150' 0' 0.000 W ° Grid Convergence at Surface is: 1.59' Ladder Plot J 0 0 3000 6000 9000 12000 15000 18000 Measured Depth (3000 usftfin) LEGEND �- L3-28,L3-28,L3-28V1 - - 04-35,04-35APB1,04-35APB1VO L3-25,L3-25,L3-25VO �F 04-18,04-18A, 04-18A VO - - 04-35,04-35A, 04-35A VO - — 13-30,1-3-30,1-3-30V1 -�- 04-18,04-18,04-18V3 $- L3-24,L3-24,L3-24V1 $ 04-25,04-25,04-25V1 $ 04-22,04-22AL1,04-22AL1 VO $ 1-3-31,1-3-31,13-31 V1 $ 04-25,04-25PB1,04-25PB1 V1 $ 04-22,04-22APB1,04-22APB1VO $ L3-31,1-3-31PB1,1-3-31P61VO $ 13-22,1-3-22,1-3-22V1 $ 04-22, 04-22A, 04-22A VO $ L3-23, L3-23, L3-23 V1 $ 1-3-22, 1-3-22A, 13-22A VO $ 04-24,04-24, 04-24 V1 L3-18, L3-18, L3-18 V1 -$- L3-19, L3-19, L3-19 V1 912312019 2:29:04AM Page 4 of 4 COMPASS 5000.1 Build 81D M* v (ut/Ijsn 008) (+)ulloN/(-)glnoS p mo m�tQl z SEE000ssooso�Ns z 5m' m'm'o�om�m'm'�oN6ti� ¢vwvu�u�wwv�w<n rn vow ��F r2rZ: m �� . 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I-0000000000000000va t000a 00000 o.-�oi of oimmm aavmm00000��rv��rr E "'"'o000000000000000 Y .-� o0000000000 n000 0000 oo c��^ai of ai LL «dpO000000 M00.-.-CQ�� 0 9200 c > - - - - - - -. 8800 -- 8400 O O a ci ry - — 8000 .c 0 0J - J 3 o N ry ry m A -7600 7200 2 > 3 N m R �- n > --- --- - 6800 a@i S ry a o � m o 6400 N ry _ soon5600 MN. -NNE, 5200 a a o m > 4800 m N > e m - � N N 4400 .o Z n . .. ..---..._ . -_- -_- v in v� in v e < e < J m E N J a l . 4000 wJJ 2momN _— o Y 3600 a a3 c a Q .� a po 0 �0p 0 0 0 0 0 0 0 0 0 0 0 (uy3jsn OZ) uoi}eaedag ai;uao of ajluaZ) 3200 >m>Nog z800 Jmm d 2400 0 0 0 0 0 p J 4 4 44 o - M - 2000 e l o+ e (`7 J co 1600 N M J' - 1200 O O O r O O m O O Ln (f) CD (O O (O n U[ (r N N M (O r l2 _ 800 V� r r r r r r 400 0 O U � o o 0 0 0 cc:)) W v N o0 E V q o0 (f7 (n O r CCD) V' O f (O (O m L r V CIJ 04 U U U '+o o1n�,N��nmvnvmi m.N-. v�otap,o i5� �aoNpcvin �m�ue�mri ri �nm Ji US N .- � °agc�oc�j �dls❑'.'LL❑o❑S❑o -zd»>zdzzdzdo oommmOmo .omomo � odo�Hm�oN00000vo�o zz waaaaaaaaaaaaaaanw N � ,., � N N—mNNmNNN Nan N-m.m- D.R 6R4 + �`�NNmt�mm ;,3 ¢533333333�i 33�333 3 Ho �F— w zcorooS;: p'.o'm.nvmT9rod 2 n�i `k,HnnNrvrv`api `Rin`n ❑ Ui n N ti o 0 0 0 0 0 0 0 o O O O o O o o V< N QPvm2.2,ff f «m '^' qq �--Nmmmmmmmm m E��000000000000000o GOQ 0000000000000000 � CL m�8immmmmmrn (jf m m m }d ❑ � o o a o N o M v v c y p yp n C m U cU N Qe E rail m m Z iNHFf Jj a Ev uv Y AWfA W c 3 QU U 0 o m t0!) Y09 h M tOD � N N N qE Q E A#99 s 4 ma97 43aa9 if15 I DS—L3 1 �T� 22 VICINITY MAP N. T. S. ■ ■ ■ ■ ■ L3-26 ■ ■ ■ DRILL SITE L-3 SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS AS —BUILT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF MARCH 18, 2015. LEGEND: NOTES: + AS —BUILT 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4 NAD27. ■ EXISTING CONDUCTOR GEODETIC COORDINATES ARE NAD27. f] WELL SLOT WITH CONDUCTOR 2. HORIZONTAL AND VERTICAL CONTROL ARE BASED ON DS-1_3 PAD OPERATOR MONUMENTS L-3 NORTH AND L-3 SOUTH, 3. ELEVATIONS ARE BP EXPLORATION MLLW DATUM. GRAPHIC SCALE 4. MEAN PAD SCALE FACTOR IS: 0,9999491. 0 100 200 400 5, DATE OF SURVEY: MARCH 18, 2015. 6. REFERENCE FIELD BOOK: NS15-15, PGS. 11-12, MI ( IN FEET ) 1 inch = 200 ft. I n(nT�r� unTuiNi ODrITDA(`TC-n c[7r' ')) T 11 NI R 1', F I IMIAT KAFRIP.IAN. Al AWA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITICN(D.DD) BOX ELEV. OFFSETS Y=51961,374.38 N 4984.75 70*17'52.176" 70.2978267 21 1' 4,350' FSL 3-26 X= 708,123.21 E 5087.72 148`18'51.946" 148.3144295' 4,423' FEL 11 CRAWN: J. WOLF 3 f goo by EOA DRILL SITE L3 SHEET AS —BUILT CONDUCTOR WELL L3— 26 1 of 1 CHECKED: A. ROLLAWAY GATE: 3 19 15 CRAN{NG: MB15 DSL3 01 JOB NO, D, s 20 IS REMSED DATE Jzw m 00 NO 3L19 1 DATE ISSUED FOR INFORMATION _ _ __ REVISION JZw I By AAH CHI( SC�E1'_200. 03 o S�� m sol oo �oW ew`oo'S gem i9. W ec �d IJi �$��6HiV 2 N ONNN\ O NNH N NAN pN NN n. n Mi .n s �nnn nMHk 23 �INII nnn O y ,B/L � iae �e �BK m vsg�aK ;� f- � t�J CNN mNN NN ZN i I � i 1 t 1 I m a i V TW Vol lBR t- L .,Z C ,Y/C 9-,9 .Z/l M-,lZ .11-,ll L� O p O � .Z/l S-,ZY O O �3d11 �w � r�f W ZCZ < 5w K ya o kf \\ .9 n H N O LO PARKER 272 DIVERTER RISER SPOOL, SPACER 21-1/4" 2M PSI R-73 FLANGED STD RING GROOVE 11'-3 15/16" OVERALL LENGTH DIVERTER VENT SPOOL 21-1/4" 2M PSI R-73 FLANGED STD RING GROOVES W/ 16" CLASS 300# ANSI 816.5 OUTLET 3'-10" OVERALL LENGTH 1YDRIL DIVERTER ANNULAR ASP 21-1/4" X 2000 PSI ;TUD x FLANGE i-73 RING GROOVE ISER SPOOL, SPACER 11-1/4" 2M PSI -73 FLANGED ;TD RING GROOVE I'-10° OVERALL LENGTH 6" 300 PSI CWP 00% FULL PORT OPENING IYDRAULICALLY ACTUATED ;NIFE GATE VALVE VITH CLASS 300# ANSI 816.5 FLANGE 6" DIVERTER VENT LINE — ` co -p J N cc Cn > o E 0 cu 1= 0 j 4 ~ CO 0- - — — — — — — — — — — — — — — — — — 1 I I • N• I co N o I M O Ln--- 0) N .09 CV) • • zo It N c0 75 \ > 0 E L E o O H I'L ti Q N W Q C) a Q 0 0 N II W U U) co O N LO w IN O U W Z_ J J W 0 U Q .a N n co N c O Q. Y Q Q co O c O N O N a� a� CL c 0 c� ;_ 0 c c� L a� c co N c O i O L 0 U- h v°y a 2 � ; \gr �� zz 3 $%! \ . ;}| § §k soSf ��z; B/9�'�� ■ � 2 o \ •r§ h; � m. ■|�� J $J & m� £ |! ) §! c Ap- 1E 0 fO en L.11f- -V "", ,Iww 140AC, 0.1-111-4 1.5., 'T -2sooas -- --Vl*w ---- 11 r- - r, +mc RUDHOE BAY DRILLING BIG BORE WELLHEAD SYSTEM PRUDHOE BAY .ALASKA 28.31 120 GV HHIVAIt AN.0 CUNF IUtNIIAL REV1610N5 pE6C9iPi,pN MRROUE2 OB-01-06 I/16-5000 TREE MAROUE2 Y'E• OB-01-06 W/ 4 I/16-5000 WING e u1Li0ry 06-01-06 p. euarCN 06-01-06 DM100023007 Transform Points i Source coordinate system Target coordinate system State Plane 1S27 - Alaska Zone 4 1 J3 (,C L 3�AJbers Equal Area (-154) Datum: Datum: NA;D 1 a,27 - North America Datum of 1927 (glean) NA.D 1927 - North America Datum of 1927 (Mean) 599390,5.62 476227.35 Easting Northing 1 5961374 — Y 1708123 1 64629.7 2258339.1 2 i 2 ype values into the spreadsheet or copy and paste columns of data from a spreadsheet using the keyboard shortcuts Ctd+C to espy, and Ctd+Vto paste. Then click on the appropriate armor button to transform the points to the desired coordinate system. Back Finish Cancel Help , TRANSMITTAL LETTER CHECKLIST WELL NAME: P B U, L 3 —',�, 6 VDevelopment _ Service Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: -Prad hoe B a POOL: Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - -� from records, data and logs acquired for well name on permitj. The permit is approved subject to full compliance with 20 AAC 25.055. Spacing Approval to produce/inject is contingent upon issuance of a Exception conservation 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: Non- production or production testing of coal bed methane is not allowed for 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 2/2015 WELL PERMIT CHECKLIST Field &Pool PRUDHOE BAY, LISBURNE OIL - 640144 — Well Name: PRUDHOE BAY UN LI_S-L3-26 —_ Program DEV _-__--_ Well bore seg ❑ PTD#:2200150 Company BP Exploration (Alaska) Inc. _ --___ Initial Class/Type --DEV / PEND GeoArea 890 Unit _11650_— On/Off Shore On Annular Disposal ❑ Administration A Permit fee attached NA ------------ 2 Lease number appropriate Yes 3 Unique well -name and number Yes 4 Well located in a defined -pool - Yes 5 Well located proper distance from drilling unit boundary- - - Yes 6 Well located proper distance from other wells Yes I i7 Sufficient acreageavailableindrillingunit_ - - - - - No - - - - Two wells in same quarter section: L3-26 & L3-24.- 8 if deviated, iswellboreplat included - - - Yes - - - - - - - Directional plan view_&_ wellbore profile included. 9 Operator only affected party - Yes - 10 Operator hasappropriatebond in force Yes 11 Permit can be issued without conservation order- - - - - Yes Appr Date 12 Permit can be issued without administrativeapprovalNo Spacing exception needed. 13 Can permit be approved before 15-day wait- - Yes DLB 1/30/2020 �14 Well located within area andstrataauthorized 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 AS31.05.0300.1.A),0 2.A-D) - NA - 18 Conductor stringprovided- - Yes 20" 129# driven conductor to 127' Engineering 19 Surface casingprotectsall known_ USDWs - Yes Fully cemented-13-3/8" set at 3778' TVD 20 CMT vol adequate -to circulate -on conductor & surf csg Yes - - Fully cemented surface casing. 300% excess -on lead - - 21 CMT vol adequate to tie-in long string to -surf csg Yes - 22 CMT will cover -all known productive horizons Yes Ivishak -and Lisburne fully covered - - - - - - - - 23 Casing designs adequate for C, -T, B & permafrost- - - - - Yes 24 Adequate tankage or reserve pit - Yes Parker 272 has adequate pits and good truck support 25 If_a re -drill, has a 10-403 for abandonment been approved NA This is a new grassroots- well. 26 Adequate wellbore separation proposed Yes - All offset wells pass BP major risk separation criteria - 27 if diverter required, does it meet_ regulations Yes Appr Date 28 Drilling fluidprogramschematic_& equip list adequate Yes All fluids overbalance to pore pressure MGR 2/7/2020 129 BOPEs, do they meet regulation Yes 1 annular, 3 ram stack. 30 BOPE press rating appropriate; test to -(put psig in comments) Yes 13-5/8"-stack rated to 5000 psi 31 Choke manifold complies _w/API_RP-53 (May 84)_ - Yes 32 Work will occur without operation shutdown - - Yes Parker 272 is inongoingoperations 33 Is presence of H2S gas probable Yes BP H2S monitoring systems will be in place 34 -Mechanical-condition of wells within AOR verified (For service well only) NA i35 Permit -can be issued w/o hydrogen- sulfide measures - No L3-Pad-wells are H2S-bearing. H2S measures are required. Geology l36 Data presented on potential overpressure zones - Yes Appr Date 37 Seismic analysis of shallow gas zones _ NA DLB 2/4/2020 38 Seabed condition survey -(if off -shore) - N_A 39 Contact name/phone for weekly progress reports_ [exploratory only) NA- - Geologic Engineering Public Commissioner: Date: Commissioner: Date mmis Loner Date D-rs Ella 2� c zlloh�o WZ n