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216-021
Victoria T From: Lastufka, Joseph N <Joseph.Lastufka@bp.com> Sent: Thursday, December 21, 2017 1:12 PM To: Loepp, Victoria T (DOA) Cc: Schultz, Kirsten L 5 a Subject: Cancel 01-35 (PTD #216-021) ` w Follow Up Flag: Follow up Flag Status: Flagged Victoria, Please cancel PTD #216-021 (01-35) as it is close to expiration and a new planned 01-35 is currently in development. If you have any questions, please don't hesitate to let me know. Merry Christmas! Thank you, Joe Lastufka Information and Data Controller Cell: (907) 227-84961 Office: (907) 564-4091 IE BP Exploration AlaskaJ900 E. Benson Blvd.lRoom: 788DIAnchorage, AK i Loepp, Victoria T (DOA) From: Lastufka, Joseph N <Joseph.Lastufka@bp.com> Sent: Wednesday, August 16, 2017 4:06 PM To: Loepp, Victoria T (DOA) Subject: New Parker NOV 6012 BOP Stack Attachments: 6012 BOP STACK.PDF Follow Up Flag: Follow up Flag Status: Flagged Victoria, Here is the list of Rotary wells that will have the updated BOP stack. If you need any additional information, please don't hesitate to let me know. 01-35 — PTD #216-021 14-16B — PTD #217-093 L-200A — PTD #216-125 NK-15A — PTD #216-175 Thank you, Joe Lastufka Information and Data Controller Cell: (907) 227-84961 Office: (907) 564-4091 A BP Exploration Alaska1900 E. Benson Blvd.lRoom: 788DIAnchorage, AK 1 THE STATE Ofl 1LASKA GOVERNOR BILL WALKER Mary Endacott Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 01-35 BP Exploration (Alaska), Inc. Permit to Drill Number: 216-021 Surface Location: 930' FNL, 611' FWL, Sec. 08, T10N, R15E, UM Bottomhole Location: 1813' FNL, 2987' FWL, Sec. 08, T10N, R15E, UM Dear Ms. Endacott: Enclosed is the approved application for permit to drill the above referenced development 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, Cathy P. Foerster Chair DATED this %lo day of February, 2016. STATE OF ALASKA .ASKA OIL AND GAS CONSERVATION COMMIS' PERMIT TO DRILL 20 AAC 25.005 3 11111M%famill W JAN 2 8 2016 .And "r°r. la. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ElService - Disp El1 c. Specify if well is proposed for: Drill Lateral ❑ Stratigraphic Test ❑ Development - Oil M ' Service - Winj ❑ Single Zone M 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. 6194193 • PBU 01-35 ' 3 Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 196612 Anchorage, AK 99519-6612 MD: 13193' • TVD: 9147' . PRUDHOE BAY, PRUDHOE OIL 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): ADL 028329 Surface: 930' FNL, 611' FWL, Sec. 08, T10N, R15E, UM 8. Land Use Permit: 13. Approximate spud date: 862' FSL, 421' FWL, Sec. 05, T10N, R15E, UM Top of Productive Horizon: 79-179 June 15. 2016 9. Acres in Property: 2501 14. Distance to Nearest Property: Total Depth: 1813' FNL, 2987' FWL, Sec. 08. T10N, R15E, UM 23300 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: - 86.95 feet 15. Distance to Nearest Well Open Surface: x- 697948 y- 5939973 Zone - ASP 4 GL Elevation above MSL: 40 feet Same Pool 600 6 16. Deviated wells: Kickoff Depth: 300 • feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 99 degrees Downhole: 3205 • Surface: 2349 . 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hale Casinq Weight Grade COUDlina Length MD TVD Mu TVD(including stage data 42" 20" x 34" 129# A-53 80, Surface Surface 80, 80, 250 sx Arctic Set (Aoorox.) 12-1/4" 9-5/8" 40# 3900' Surface Surface 3900' 3446' 1798 sx DeepCrete, 414 sx Class'G' 8-3/4" 7" 26# L-80 VamTo HC 9161' Surface Surface 9161' 8546' 288 sx Class'G' 6-1/8" 4-1/2" 12.6# 13Cr85 VamTo 4182' 9011, 841 V 13193' 9147' 1 465 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 20. Attachments Property Plat ❑ BOP Sketch M Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch R1 Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements Q 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 Staudinqer. Garret from without prior written approval. Email @ P Garret.Staudin er b com 9 Printed Name Mary Endacott Title Engineering Team Leader Signature �Phone +1 907 564 4388 Date Commission Use Only Permit to Drill ` �s,� -z j --_ API Number: 50- J_5 ,- . er i, A proval See cover letter for other Number: (�j (/ a ai 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: f' f QOP o ,Soo}Samples req'd: Yes ❑ No [2/q/ Mud logreq'd: Yes ❑ No p ttS��S� ��r� ��k �iC✓�� }�, f�S tc H2S measures Yes No ❑/ Directional svy req'd: Yes Pr No El Z �bU fly I Spacing exception req'd: Yes ❑ No f3 tnnn���lination-only svy req'd: Yes ❑ No wt �d !a )ve- C! <t p o D r /l r' Z y PrZ2S. ✓ 6A4-C G 3Post)iiztial injection MIT req'd: Yes ❑ No ❑ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 2-14 _ 16 !�T-L Z//! !, ORIGI�AL Form 10-401 Revised 11/2015 This permit is valid for 24 months from the date of approval (20 AAC 25.005(g)) /�—Z.z./ Submit Form and Attachments in Duplicate by To: Alaska Oil & Gas Conservation Commission From: Garret Staudinger, ODE Date: January 27, 2016 RE: 01-35 Permit to Drill The 01-35 well is scheduled to be drilled by Parker 272 in June 2016. This grassroots well is a U- shaped producer targeting the Ivishak Zone 2 Sands. The planned well is a three string, ultra-slimhole design using a 9-5/8" surface casing, 7" intermediate casing, and 4-1/2" production liner. The surface casing will be set in the SV4 shale. The intermediate casing will be set at the top of the Sag River, and the production interval will be completed with a cemented liner and be perforated post rig. The maximum anticipated surface pressure from the Sag River with a full column of gas from TD to surface is 2,325 psi (assumes 7.21 ppg EMW most likely pore pressure and a 0.1 psi/ft gas gradient). The well will be drilled by Parker 272 using their 5,000 psi four preventer BOP stack (3 rams and an annular). The BOP rams and annular will be tested to 3,500 psi. A detailed operations summary is included with the permit application. If there are any questions concerning information on 01-35, please do not hesitate to use the contact information below. Garret Staudinger O: (907) 564-4242 C: (907) 440-6892 Email: garret. staudinger(a)bp.com Attachments: Well Bore Schematic Directional Package BOPE Schematic Diverter Line Layout Diagram Well Head Schematic Tree Schematic 01-35 PTD 1 1/27/2016 Well 01-35 Planned Well Summary Wele Producer Obarget Ivishak Current Status Grass Roots Well Estimated Start Date: 1 6/15/2016 Time to Com lete: 31.0 Da s Surface L Northing Easting I Offsets TRS Location 5,939,972.89 697,948.32 930.2' FNL / 610.5' FWL 1 ON 15E Sec 8 Northing Easting TVDss Offsets TRS Tgt 5 TSAD 5,941,759 697,706 8,578 4417.6' FNL / 421.3' FWL 1ON 15E Sec 5 Tgt 7 BHL 5,939,153 700,350 9,060 1813.5' FNL / 2986.8' FWL 1 ON 15E Sec 8 Planned KOP: 1 300' MD I Planned TD: 13,193' MD / 9,060' TVDss Rig: Parker 272 • GL-RT: 46.95-] RTE (ref MSL): 1 86.95 Directional - Baker wp03 KOP: 300' MD Maximum Hole Angle: `390 in the intermediate section -99' in the production section Close Approach Wells: None. All offset wells pass BP Anti -collision Scan Criteria. Surface to 1200' MD GYRO 1200 - 2500 MWD Standard 1200 - 3901 MWD +IFR + Multi Station W/O crustal Survey Program: 3901 - 5500 MWD Standard 3901 -9161 MWD +IFR + Multi Station W/O crustal 9161 - 10670 MWD Standard 9161 - 13193 MWD +IFR + Multi Station W/O crustal Nearest Property Line: -23,300' - Nearest Well within Pool: -600' 01-35 PTD 2 1/27/2016 Formation Tops and Pore Pressure Estimate (SOR) Formation Estimated Formation Top (TVDss) Most Likely Pore Pressure (EMW p Fluid Type (for sands G 1 400 8.43 BPFR 1950 8.43 SV6 2135 8.43 SV5 2512 8.43 SW 2820 8.43 9 5/8" Casing 3380 8.43 SV3 3420 8.43 SV2 3616 8.43 SV1 4038 9.5 UG4 4641 9.5 UG4A 9.5 UG3 4837 9.5 UG 1 5502 9.5 WS2 6064 9.5 WS1 6324 8.48 CM3 6576 8.83 CM2 7047 9.8 CM1 7731 9.8 THRZ 8120 10.25 BHRZ 8275 10.25 LCU/TKNG 8305 9.95 TJA 8360 9.95 TSGR 8458 7.21 Gas 7" Int. Casing 8460 7.21 TSHU 8490 8.39 TSAD 8563 7.2 Gas TCGL 8752 7.16 Gas BCGL 8818 7.14 Gas/OiINVater PGOC 8880 7.14 Gas/OIINVater 23SB 8906 7.14 Gas/Oil/Water 22TS 8937 7.14 Gas/OiINVater 21TS 8980 7.14 Gas/Oil/Water HOT 8994 7.14 Tar Invert 9000 7.14 21TS 8988 7.14 Gas/OiINVater 22TS 8953 7.14 Gas/Oil/Water 23SB 8924 7.14 Gas/OiINVater PGOC 7.14 Revert 7.14 PGOC 7.14 POWC 7.14 23SB 8943 7.14 Gas/OiINVater 22TS 8996 7.14 Gas/OiINVater HOT 9000 7.14 Tar 21TS Below Plan 7.14 9, TY1 - / , 3 9;7-ram,/ 01-35 PTD 3 1/27/2016 Casing/Tubing Program Hole Size Liner / WVFt Grade Conn Length Top Bottom Tbg O.D. MD / TVDss MD / TVDss 42" 20" x 34" 129# A-53 - 80' Surface 94' / 80' 12-1/4" 9-5/8" 40# L-80 BTC 3,900' Surface 3,900' / 3,380' 8-3/4" 7" 26# L-80 VamTop HC 9,161' Surface 9,161' / 8,459' 6-1/8" 4-'/2" 12.6# 13Cr-85 VamTop 4,182' 9,011' / 8,324' (150' lap) 13,193' / 9,060' Tubing 4-''/z' 12.6# 13Cr-85 VamTop 9,016' Surface 9,016' / 8,328' (-5' into liner TBS) Mud Program Surface Mud Properties: MMO 12-1/4" Hole Section YP LSR-YP Depth Interval (ppg) PV (cp) (lb/1 0ft2) API FL (2x3 - 6) pH m Surface - 3,900' MD 8.6 - 9.3 6-20 35-80 <15 25-60 10.3 - 11 Intermediate Mud Properties: LSND 8-3/4" Hole Section Depth Interval Density PV (cp) YP Ib/1 00ft2 API FL HTHP FL MBT pH 3,900' MD - 8,600' MD 9.7 - 10.1 10-15 18-25 1 <6 NA <20 8.5 - 9.5 8,600' MD - 9,161' MD 10.4 - 10.8 • 12-18 18-25 1 <5 <10 <20 8.5 - 9.5 Production Mud Properties: Water Based Polymer Fluid QUIKDRIL-N 6-1/8" Hole Section Depth Interval Density PV (cp) YP Ib/ OOftz API FL HTHP FL MBT pH 9,161' MD - TD 8.5 - 9.0 <8 1 12-20 <12 NA <4 8.5 - 9.5 Logging Program 12-1/4" Surface I Sample Catchers - not required for surface hole Drilling: Dir/GR Open Hole: None Cased Hole: None 8-3/4" Intermediate ample Catchers - as required by Geology Drilling: Dir/GR/GRAB/RES Open Hole: None Cased Hole: None 6-1/8" Production Sample Catchers - as required by Geology Drilling: Dir/GR/RES/NEU/DEN Open Hole: None Cased Hole: None 0 1 -35 PTD 4 1 /27/2016 Cement Program Casing Size 9-5/8" 40# L-80 BTC Surface Casing Lead Open hole volume + 350% excess in permafrost and 40% excess below permafrost Basis Lead TOC Target surface Tail Open hole volume + 40% excess + 80 ft shoe track Tail TOC 1000 ft MD above casing shoe Spacer -100 bbls of Viscosified Spacer weighted to -10.0 Mud Push II) Total Cement Lead 611.8 bbls, 3435 cuft, 1798 sks of 11.0 ppg Dee CRETE, Yield: 1.91 cuft/sk Volume Tail 85.5 bbls, 480 cult, 414 sks 15.8 lb/gal Class G - 1.16 cuft/sk Temp BHST 68' F Casing Size 7" 26# L-80 amTop Intermediate Casing Lead None Basis Lead TOC N/A Tail Open hole volume + 40% excess + 80 ft shoe track Tail TOC 1500 ft MD above casing shoe Spacer -35 bbls of Viscosified Spacer weighted to -12.0 Mud Push II Total Cement Lead None Volume Tail 59.5 bbls, 334 cult, 287.9 sks 15.8 lb/gal Class G - 1.16 cuft/sk Temp BHST 190' F Casing Size 4-112" 12.6# 13CR-85 VamTop Production Liner Lead None Basis Lead TOC N/A Tail Open hole volume + 30% excess + 80 ft shoe track + 150' liner la + 200' of DP x 7" annulus Tail TOC Top of 4-1/2" liner Spacer -30 bbls of Viscosified Spacer weighted to -12.0 Mud Push II Total Cement Lead None Volume Tail 96.1 bbls, 540 cult, 465.3 sks 15.8 lb/gal Class G - 1.16 cuft/sk Temp BHST 198° F Surface and Anti -Collision Issues Surface Close Proximity: No wells will be affected by the Parker 272 rig shadow. Sub -Surface Pressure Management: Pad 3 OWDWs (oily waste disposal just below the permafrost) are-12,000' away from where 01-35 is planned to intersect the BPRF. No increased risk of overpressure due to distance from these injectors. Jurassic/Cretaceous: Check pressure estimates and verify that injection rates have not changed prior to spud in the closest injection wells. The closest injection well is PWDW1-2A. Ivishak Interval: Collect a new SBHP in the AOI 1 to 2 months prior to spud of 01-35. Check interpreted ML pore pressure against new SBHP in the AOI. Anti -Collision: None. 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. 01-35 PTD 5 1 /27/2016 Hydrogen Sulfide Drill Site 1 is considered an H2S site. Recent HAS data from the Dad is as follows: Well Name 112S Level Date of Reading #1 Closest SHL Well H2S Level 01-25 10 ppm 02/27/02 #2 Closest SHL Well H2S Level 01-26A 0 ppm 06/16/13 #1 Closest BHL Well H2S Level 01-34A 36 ppm 01/28/13 #2 Closest BHL Well H2S Level 01-15B 18 ppm 12/07/14 #3 Closest BHL Well H2S Level 01-29 12 ppm 03/03/13 #4 Closest BHL Well H2S Level 01-32A 10 ppm 02/09/13 Max Recorded H2S on Pad/Facility 01-13 150 ppm 07/19/13 Faults Formation Where MD TVDss Throw Direction and Uncertainty Lost Circ Fault Encountered Intersect Intersect Magnitude Potential No prognosed fault crossings 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. 01-35 PTD 6 1/27/2016 Well Control The 12-1/4" surface hole will be drilled with a diverter (see attached diverter layout). The 8-3/4" 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 01-35 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. 8-3/4" Intermediate Interval Maximum anticipated BHP 3,171 psi at the TSGR at 8,458' TVDss (7.21 ppg EMW) Maximum surface pressure 2,325 psi at the TSGR (0.10 psi/ft gas gradient to surface) 25 bbls with 12.14 ppg frac gradient. Kick tolerance Assumes 7.21 ppg pore pressure in the SGR + 0.5 ppg kick intensity and 10.4 ppg MW. Planned BOP test pressure Rams test to 3,500 psi / 250 psi. Annular test to 3,500 psi / 250 psi Integrity Test — 12-1/4" hole LOT after drilling 20'-50' of new hole 7" Casing Test 3,500 psi surface pressure 6-1/8" Production Interval Maximum anticipated BHP 3,205 psi in the TSAD at 8,563' TVDss (7.2 ppg EMW) Maximum surface pressure 2,349 psi (0.10 psi/ft gas gradient to surface) Kick tolerance Infinite with >9.0 ppg frac gradient. Assumes an 7.21 ppg max pore pressure in the TSGR + 0.5 ppg kick intensity and 8.6 ppg MW. Planned BOP test pressure Rams test to 3,500 psi / 250 psi. Annular test to 3,500 psi / 250 psi Integrity Test — 6-1/8" hole FIT after drilling 20'-50' of new hole 4-1/2" Liner Top Packer 3,500 psi surface pressure Planned completion fluids 8.5 ppg seawater / 2,200 ft diesel to 1,950 ft TVDss 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. i • The well will be monitored for flow when the pumps are off at each connection. • The planned 8.6 - 8.8 ppg fluid will provide over balance to formation fluid. 01-35 PTD 7 1 /27/2016 Loepp, Victoria T (DOA) From: Staudinger, Garret <Garret.Staudinger@bp.com> Sent: Thursday, January 28, 2016 1:53 PM To: Loepp, Victoria T (DOA) Cc: Lastufka, Joseph N; Endacott, Mary S Subject: 01-35 Permit to Drill Variance Request Follow Up Flag: Follow up Flag Status: Completed Victoria, The Permit to Drill application for upcoming grassroots well 01-35 should be headed your way in the next day or two. wanted to clarify the Variance Request that I have in the permit application so you are aware of the change. We have typically been submitting grassroots well permits with the Variance Request to remove the flow paddle for the first 1000' MD. One of the safeguards for this variance that we have been putting on the permit applications have been to set gain or loss alarm in the pits to 5 bbls. The Permit to Drill application for 01-35 again asks for the Variance Request to remove the flow paddle for the first 1000 ft, however, the safeguard has been changed to set the gain or loss alarm in the pits to 10 bbls. This is solely for the reason that 5 bbls has proven to be too tight of a tolerance with the large volume of surface holes and mud system used. Every time the pumps are turned on or off, the pit level alarm sounds with the +/- 5 bbls setting. This email is intended to let you know of the change on the permit application before you actually get the permit. Please let me know if you have any questions on this change, or if you would like to discuss further. Regards, Garret Garret Staudinger BP Alaska Wells Rotary Drilling Engineer Office: 907-564-4242 Cell: 907-440-6892 Drill and Complete Operations Summary Pre -Rig Work: 1. Install insulated conductor and weld on landing ring. Install lined Cellar box. Send As -built to Engineer. 2. Spot Gen 5 Wellhead and Slip-Loc wellhead in cellar prior to RU if required 3. Level Pad and prepare location 4. Confirm cretaceous injection pressures 5. Validate injection / production in area per SOR Rig Operations: 1. MIRU Parker 272. Nipple up diverter spool and function test diverter. 2. Prepare pits with MaxDril Mud and P/U 5" DP as required and stand back in derrick. 3. MU 12-1/4" drilling assembly with MWD/GR/Res and directionally drill surface hole to Base Permafrost. Gyro survey until magnetic interference clears up. CBU and short trip to surface. Change bit and dial up/down motor bend as required. 4. RIH and continue drilling 12-1/4" surface hole to section TD at —3900' MD in base of the SV4 shale. CBU until hole is clean. POOH on elevators (if beackreaming is required, RIH until able to POOH on elevators). Lay down BHA. 5. Run and fully cement 9-5/8" 40# L-80 BTC casing to surface, displacing cement with drilling fluid. A TAM port collar may be run at 500' as a contingency. 6. ND diverter and NU casing head and spacer spool. NU BOPE (Configured from top to bottom: annular preventor, 7" fixed, blind/shear, mud cross, 2 '/" x 5'/" VBR). Test rams and annular to 250 psi low / 3500 psi high. Give the AOGCC 24 hrs notice prior to testing. 7. Pressure test 9-5/8" surface casing and wellhead to 250 psi low / 3500 psi high for 5 minutes low / 30 minutes high (This will test casing, wellhead, and OA valves). 8. Make up 8-3/4" drilling BHA with Rotary Steerable and MWD/GR/RES/PWD/GR-at-bit and RIH to float collar, picking up 4" drillpipe as required to TD intermediate interval. 9. Drill out shoe track and displace well to 9.7ppg LSND drilling fluid. Drill 20' of new formation and perform LOT. 10. Drill ahead to +/-200' and above the CM2, ensuring mud weight is 9.9ppg. 11. Continue drilling to +/- 200' MD above the HRZ, weight up to 10.4ppg if not already there. 12. Continue drilling to TD at the Top SAG (estimated at —9161' MD). At TD, CBU, and condition hole as necessary to run 7" casing. POOH. 13. RU and run 7" 26# L-80 Vam Top HC casing to TD. Cement the 7" casing to 1500' MD above the shoe. After bumping the plug on the cement job, pressure test the 7" casing to 3,500 psi for 30 charted minutes. 14. Install 7" packoff and test void to 250 psi low / 5,000 psi high. 15. Freeze -protect the 9-5/" x 7" annulus, once cement has reached 500 psi compressive strength. Confirm that the OA is open before freeze protecting. 16. Change upper rams to 2-7/8" x 5-1/2" VBR and test to 250 psi low, 3500 psi high. 17. PU 6-%" drilling BHA with PDC bit, rotary steerable and DIR/GR/RES/NEU/DEN. RIH and begin drilling out shoe track. 18. Displace the well to 8.6ppg FloPro SF fluid prior to fully drilling out shoe track. 19. Drill out shoe and 20' of new formation and perform FIT. 20. Drill ahead to planned TD at—13,193' MD, per directional proposal and rig site geologist. 21. Circulate hole clean, short trip, circulate and condition hole for liner run. POOH. 01-35 PTD 8 1 /27/2016 22. MU and run 4-%" 12.6# 13CR Vam Top liner to TD. Cement liner leaving TOC at top of 4-1/2" liner. 23. Set liner hanger / liner top packer and displace well to clean seawater above the liner top. 24. POOH, UD drillpipe and the liner running tool. 25. R/U and run a 4-'/", 12.6#, 13Cr, VamTop tubing completion with GLMs. Space out and land the tubing with tubing tail inserted into the liner tieback sleeve. 26. Make up tubing hanger per FMC Rep. Land the tubing hanger, and run in lock down screws. 27. Reverse circulate seawater and corrosion inhibitor into the tubing x casing annulus. 28. Drop ball/rod and set packer and individually test the tubing to 250 psi low / 3500 psi high for 5 minutes low / 30 minutes high. Bleed tubing pressure to 2000 psi and test annulus to 250 psi low / 3500 psi high for 5 minutes low / 30 minutes high. Record each test. 29. Shear the DCK valve. Pump both ways to confirm valve has sheared. 30. With landing joint still rigged up, reverse circulate diesel freeze protect using rig injection pump. 31. Allow diesel to U-tube, drain stack, and rig down landing joint. Monitor well for 1 hour to confirm well is dead. 32. Install TWC and test from above to 250 psi low / 3500 psi high for 5 minutes low / 30 minutes high. 33. Nipple down the BOPE. Nipple up the adaptor flange and tree and test to 5,000 psi with diesel. • Ensure Heet® is left on TWC and only diesel (no water) is left in tree. 34. Install all annuls valves and secure the well. Ensure T/IA/OA all have two barriers in place. 35. Secure the well. Rig down and Move Off. Post -Rig Work: 1. Pull TWC / tree work 2. MIRU slickline. Pull the ball and rod / RHC plug. Drift for perfs. Pull shear valve and set GVLs 3. R/U coil and perform fill clean out 4. R/U e-line. RPM log (if needed). Perforate. 5. ASRC flowback 6. Install well -house and instrumentation and flowline. 01-35 PTD 9 1 /27/2016 01-35 Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE I. Well Control / Reservoir Pressures A. Intermediate Hole: The SV1 through WS2 is expected to be a 9.5 ppg EMW. The CM1 and CM2 are expected to be a 9.8 ppg EMW. Formation pressures will be controlled with a 9.7 — 10.1 ppg mud to drill to within 200' MD of the THRZ, ensuring at least a 9.9 ppg while drilling CM1 and CM2. At this point, there will be a weight up to 10.4 ppg to drill the rest of the interval to TD. B. Production Hole: The nearest Ivishak injectors are 01-11i, 01-30i, 01-25i, and 01-24Ai. All injectors are currently shut-in as the seawater injection line to DS-01 went down in May 2015. The liner is expected to be back up in 3Q2016. If timing between injectors coming back on-line and spud of the well changes significantly, check any impacts on the ML pore pressure and update if needed. The Ivishak is expected to be at a 7.21 ppg EMW. Reservoir pressures will be controlled with a 8.6 ppg mud. II. Lost Circulation/Breathing A. Intermediate Hole: There are no expected fault crossings in the intermediate hole. However, breathing has been known to occur in the Colville on other Drill Sites in Prudhoe Bay as a result of high ECD's. B. Production Hole: There no expected fault crossings in the production hole. There is low risk for lost circulation as only minor losses have occurred in offset wells. III. Fault Locations Formation Where MD TVDss Throw Direction and Lost Circ Fault Encountered Intersect Intersect Magnitude Uncertainty Potential No Prognosed Fault Crossings IV. Integrity Testing Test Point Test Depth Test t pe EMW (lb/gal) 9-5/8" Shoe 20'-50' from the 9-5/8" shoe LOT 12.14 ppg T' shoe 20'-50' from the 7" shoe FIT 9.0 ppg V. Hydrogen Sulfide Drill Site 1 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 01-25 10 ppm 02/27/02 #2 Closest SHL Well H2S Level 01-26A 0 ppm 06/16/13 #1 Closest BHL Well H2S Level 01-34A 36 ppm 01/28/13 #2 Closest BHL Well H2S Level 01-15B 18 ppm 12/07/14 #3 Closest BHL Well H2S Level 01-29 12 ppm 03/03/13 #4 Closest BHL Well H2S Level 01-32A 10 ppm 02/09/13 Max Recorded H2S on Pad/Facility 01-13 150 ppm 07/19/13 VI. Anti -Collision Issues None. All offset wells pass BP Anti -collision Scan Criteria. CONSULT THE DS-01 PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. 0 1 -35 PTD 10 1 /27/2016 WE.LHEAD = ACTUATOR= OKB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD Datum TV D = 8800' SS 20" COND, 129.46 #, X-56, ID = 18,770" 9-5/8" CSG, 40#, L-80 BTC, D = 8.835" 39W Minimum ID = 3.725" @ ' 4-1/2" HES XN NIPPLE ESTMATM TOP OF Ca4ENT (_/_/_) - TOP OF 4-1/2" LNR 4-112" TBG, 12-6#, 13CR-85 VAM TOP, 0152 bpf, D = 3.958' 7'CSG,26#,13-CRVAMTOP,ID=6.276' 1—] 9161' PERFORATION SU VIARY REF LOG: ANGLE AT TOP PERF: Note: Refer to Production DB for historical pert data SIZE SPF RJTERVAL Opn/Sqz SHOT SOZ PBTD 4-1/2" LNR, 12.6#, 13-CRVAMTOP, .0152 bpf, U = 3.958" 1 13193' 1 01-35 FSAJ NOTES: CHROME TBG & LNR 4-1/2" HES X NIP. D = 3.813" GAS t_1FT MANDRFI S ST MD TVD DEV TYPE VLV LATCH PORT DATE 8 7 6 5 4 3 2 1 4-1/2" FES X NV ID= 1813" 7- X 4-1/2- HES TNT PKR, ID = 3.875" 4-1/2" HES X NIP, ID = 3.813" 14-1 /2" HES XN NIP. ID =1725" 0, \ j j,-116OWWAVE, WANAPADAMMOV11- Pi JP JT w /RA TAG PUP JT w /RA TAG PRUDHOE BAY LUT WEL '01-35 PE IAT No: API No: 50-029- -00 SEC , T N, R E, ' FSL & FEL. 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N N N N N N M V M Ln N (O M Il m O O M N r� m m co OR 0D OD OR OR Q O0 M (D V m V w N V OO V O0 V OD V O V N N (D O f� 0 n 0 0 O m V m 00 m O OO 4 m CO m OO m m m w m 0D m m m La m a (oo U >. _d mLa MO M Mn L.1 C .... O Cl) N O E a)o m O O m r ❑ o o Lo Lo O ~ ~ O o 2 m d N- L N O L z D_ a s d o O o o O M o m o 00 0 0 0 0 C. o r�: o o o 0 0 0 0 0 0 Ow O 6 O O N m N V 0 O N 6 N m. CO) 0 O 0 0 O O o O 0 C. O m U)0 o R O O O O O O O O d ` O V O Ln In N Ln O J tD N (D N J (O J ❑ O O lD O m O O O M 0 O N (O N O O M O V O N 0 (D 0 (- O m O m N ❑ N m m m m U m m Um m m m O o o O O V O O O O O O O (V C .. d L N F m N N N .-LO a u c d a rn D O W d y d c R o sd+ U a y ❑ a N 0 N o 0 0 o 0 o m N m M 0 0 0 0 0 0 0 0 0 0 0 0 0 0 (o W 0 O 0 O 0 0 Om 0 0 O� 7 m O (o N N o O 0 O 0 O 0 O 0 O 0 O 0 O 0 O 0 O 0 O 0 O 0 O 0 O o O a 'Z3 ,. �� � � m u gILL mo 0 a= N 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 d C..) Z O O O O N M N M N Cl) N c') N M N M N M N 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 O O O O U Q y O) m y 7 p c O 7 7 D_ O m 7 Y N @ N M m m Z l0 N 00 V m m N N M O N 0 O N N N O M m m M m m p V G 7 a U m f* M m M O N O V m N m O N N r", v N m N V v M M O v m v N N N m m m n n IT m m m m m O M � O N � N N M C c c N l0 Y l0 O. O_ E N 7 C M m r- c0 m 00 m V (D O m O m M N N m N M m N m v M N N m m V (D M m O N r- co .- N m (0 00 M N O N r- m d N N E - N N m m c0 m c0 m m 0) 0) 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 O O O O O O 0 O 0 O 'C A .3.. (D m (D (0 (O m m 0 m m m m m m N m m m m m n r- r n n 3 »>j O 0 o H W W N M N m O N m m v N N m V 0 M m N d W o L L f� N O V (O O N M (D O O m m(n O m V V N N O m (O M N O O N m CDO O m O 0) M N m m m N (D m r-, N V m N M V 0) 0) (D N m N m O M N 0) m r- V r- m O m U) M M m M O (0 m N r- m O V N- m m O V m m n m M N (N V m N m N N 0) O V O V M V m V m v m v m V m V m O v m O V 0 0 v O v O v O V m M m M m M m M M m M M m M m M m M m M N N m m m m m m m m m m m m m m m Z N N N N N N N N N N N N N (D N N N N N N N N N N d 0 GI ' U d= 7 C L m m V N O m m M V m m m N m m N U 4 d m V M V m m m MO N m r- m O M N n m m O N M v m m O U N O N (O] r v V 0 r- M 0 ((0 M 0)) (ND N m M N amD (M () T m m m m O N N M M V v N (D (O rl r-m m O 0 N M d p N p N — — — — — — .- — — — - — — — N N N N N > J F 2 N 0 W r O Q N N N O m m r- V m y M O N M v m r- m O N M v T m m o r N OR V m N O N M m N V M N O O m co n f: (D a0 CO N ti N v V O m (D (D M M M m M W M W N r, N (D (D m N N N N N N V m M M O M M N m 00 (D M N m N (D M M v N m N (D m M Ir m a TN m � Z_ M a m M O to N M O OR v m m O f- V m N M Cl- f� to r- M m (O �O N (D m N N � M V r-, m n N � 1-- N m N O m f� M m — m M m N O m O o N 04 N v COM (D m V O N N N V m (D f� M m to m CO m m cc V m CO CO (0 m (D OD t` m m m 0 m m N a V m N m (0 m r- m 00 m O O O N 0 M O V O W U) eo m w ao eo ao m m m m m of w m m m m m m w m ai m m m a p 3 m m M m m m m N m N a) of m O m V W m m m m M m m M t` m M m m M t` m Cl) m m m m w M m m N m v v m m m V N m m O O (f] N m ao m m m m m m N f` m fl- m m N m O m m m m CO N O O m m m v O m V O r'� N O m � Q) M O m m N O m N N (D O m N M rl_ 0 m m M m 0 m m V m 0 m M N m O m (m m m m L E O O M O O M O O M O O M O O M O O M O (O Cl) M N N m M m m M O O m M O O m M O O m M 0 O m M O O m M O O m M O O m M O o m M O O m M O O m M O O m M O O m M O O m M O O m M O O m M O O m M N N QCD Q O Y gN m m O N O O m m v o rl- O � O r- O r- O n O P, O rl O n O r- O n O n n Q L) m m m m r- O m O M m O m O m r- m N m M m M m (a N M O M m M m M m M m M m M m M m M m M m M m O M m O M m O M m O M m O M m U T U O Go f0 Q 0 0 3 O O o LL LL p a m N N M F F L O O Z d d d M o 0 o M o 0 0 0 (•'i o 0 o N o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 4 O 0 y 0 O O M y 0 O O N O O O O O O O O O O O O O O O O V' T O 00 a0 VO J O p 0 O N O O J o p 0 C] O O O M O N O O O O O O o O 6 O O O O O C] O O O 0 O m O O O O O O O O O N Q � m Cl) v N m m n m m O N M V N m r-I m m � O � N a N N U N 2 + o, � o c d a rn d c o _ (coiczzl 0o c)a m33p a o N o 0 2 o a Z 3 m `W e d Ao 0 w a= m a o g U o O Z Q y 0 0 C 'C ❑ y Q O O O 3 d r Y M y //w,�� //O�D� 6 a a 3jy E o a u ,n 2 c �o 00 F LU w U r� O 0 vi u 0 rn c d t c c � m - w a� t co m Q r 2 n N y p y N y W y O ID O E C 7 'O u w n = m N Ci C Q 01 w A � T ❑ t7 ❑ Z N N O O ❑ ❑ 2 J fA W 7 N Y (o O In C N of r- V O y E C Q � U A Of C T r N N co CO d cn y N Ca a m o a 0 o m N a❑ N E N Z rn co ) o >O F � L O 0 E2 N N a = m rn rn coN O O Q u a o v I m ao rn 3 0 Q U T N O (D COO u] ui CC L� O (D 0] E o n 3 0 c m Lt (n 0 0 y t+1 T <h O M Q co o 2 m l0 2 7 z a d a d o O ri 4 T M U) � c � N p �'' � ❑ O N ,400 IL s V p c N p ®+ o d _ a rn 'Q w y c C 5 y N \ $M o a m 3 3 o a u C W m Sun 0 o uo a a U � z C) X X Q _m m 0N N of 3 3 [L m m 7 Y M m Z A lm��� c m m m E vYi a a , d E c ❑ W ai u .o c O W L w d N � C d O O O O C U O. it o ❑ N "" L � d 0 w U a G u ❑ Z .3 J>O 0 F z U) ❑ cL O °- 0 O O_ N N a `/ m (p O o L � J N a m 4 a E m z J J Lo > U m rn = > > cn C7 > w U > 0 > C7 C) m H m H Hu) m (n U: m m CL m 1n ll'l l0 ui 'A to In N N N m Ill N ll'l m (!l N N N N o m o m rn m m m m m m m m m m m al m m m m m m m m m Q jp L M 00 (D V (O V (O (D (O N oD N m V m I� f— O O co M Y u M N QO c I'o N N In V 'f (OD N I"I ( Ql IO m I� V M m � J > Oz f` N OO N a0 N V M aD co m to M 00 00 N h V co co m N v Q l0 U T (D N O I� m Ill O m (D (D N u7 (D O O N M N (D m u? . co Q O 3 L L (7 0 L 6 00 N R O V (O 1n V M a0 O (O M (D u7 (D m N N � "O ❑ C (? c N Ul (O V (O N � � O .- N (D m M •- m m (Do M M O 2 m N a o 7 h N m N m w V M m D) I-: O V m m N w Lo 6 m m M m z a a a 6- a v Q C (V a y m a E ad+ N U a iA O LL o l 1 PS d U > m M M O E _ a d o Q L n 0 o 3 a ❑ c c M o 2 m m g z n. a na a o c O Q C o m a C U a y O O. ❑ ❑ 0 0 0 ❑ o (n O N O O O c�+l O � O O N N O N a0 p (D MO O (n O) W to V O (h O V OO M tY M to co m N m N O o m M O O 1° O m O LL LL -DLL -O LL m LL LL LL LL LL LL a F- F O F O F- .6 F F- F F F F o O o O (fin O (on L t O V = N O L N N OD V N M O M O M N p R OD cl m n N M M O W d n J J O J J N J IJ J J O J O M m ❑ ❑ ❑ (C) ❑ (n N ❑ ❑ ❑ O O ❑ C r r r C O l0 YO N N y0 lU A W N (D YO �6 N y0 O7 �6 N N U (n (n (n (n (n (n (n (n (n u) fn u) fn Ul (n Cn (n (n O '7 In O) 0 O h (D M N In I� OO a0 I: co r V O M r N N N 6 6 6 � N N N w O O M m N (- 7 N W M N N W (O O In V M V h N (D I M N N N M M M M N N N W d } R C_ L O O V O o (n M M O M 0 0 M (n 0 (n .-- W V N 0 O O 00 N V rl� It OR n M M N (n 1- rM W N 0 m N J !A V V Ou M V M ) (D n O D N O O M O) N � O O ao � (DM N ((D (n M ao Z N N N— — — — — .- 4 +. M .- W m M 0 (n O OI I- rl� M N (D Cl! (l rl� rl (O m O U� N � O O) U O O) m W (n M mOD V (O (D M O O - m M (n v ,r C. N M V r, n M IT CD un (n (D M MO O M M Ma,0 N M n OD M O OD OO M m m OD O W m o 0 0 0 o O 0 0 C. o O 0 0 0 0 0 0 0 o 'O O O O O O O O O N N N N N o O O M N V t O O ( O O 0 C] N V 'it N m M OO w co m co O O O O O I, N 0 (O O O) N M (D T O O Ol N G NM N CO O] O M (O (O N (n (D N O M (D d p 3, Co co w m m m m m o o M North America - ALASKA - BP Prudhoe Bay PB DS 01 Plan 01-35 Plan 01-35 01-35 wp03 Anticollision Summary Report 27 October, 2015 WE 0 &P,"-- 2 BAKER HUGNES BP F//G by Anticollision Report BAKER HUGHES Company: North America - ALASKA - BP Project: Prudhoe Bay Reference Site: PB IDS 01 Site Error: 0.00usft Reference Well: Plan 01-35 Well Error: 0.00usft Reference Wellbore Plan 01-35 Reference Design: 01-35 wp03 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well Plan 01-35 01-35 plan @ 86.95usft (rigx) 01-35 plan @ 86.95usft (rigx) True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Reference 01-35 wp03 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,514.65usft Error Surface: Elliptical Conic Survey Tool Program Date 10/27/2015 From To (usft) (usft) Survey (Wellbore) Tool Name Description 46.95 1,200.00 01-35 wp03 (Plan 01-35) GYD-GC-SS Gyrodata gyro single shots 1,200.00 2,500.00 01-35 wp03 (Plan 01-35) MWD MWD - Standard 1,200.00 3,901.00 01-35 wp03 (Plan 01-35) MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/0 Crustal 3,901.00 5,500.00 01-35 wp03 (Plan 01-35) MWD MWD - Standard 3,901.00 9,161.00 01-35 wp03 (Plan 01-35) MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal 9,161.00 10,670.00 01-35 wp03 (Plan 01-35) MWD MWD - Standard 9,161.00 13,193.35 01-35 wp03 (Plan 01-35) MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal 1012712015 2:29:38PM Page 2 of 5 COMPASS 5000.1 Build 61 �.1111411. BP WE by Anticollision Report BAKER HUGHES Company: North America - ALASKA - BP Local Co-ordinate Reference: Well Plan 01-35 Project: Prudhoe Bay ND Reference: 01-35 plan @ 86.95usft (rigx) Reference Site: PB DS 01 MD Reference: 01-35 plan @ 86.95usft (rigx) Site Error: 0.00usft North Reference: True Reference Well: Plan 01-35 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore Plan 01-35 Database: EDM R5K - Alaska PROD - ANCP1 Reference Design: 01-35 wp03 Offset ND Reference: Offset Datum Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) PB DS 01 01-01 - 01-01 - 01-01 13,183.07 9,475.00 1,041.08 321.64 727.18 Pass - Major Risk 01-01A- 01-01A- 01-01A 2,003.87 1,900.00 1,125.81 56.45 1,070.49 Pass - Major Risk 01-01A- 01-01 B - 01-01 B 2,003.87 1,900.00 1,125.81 56.45 1,070.49 Pass - Major Risk 01-01A-01-01C-01-01C 1,990.78 1,900.00 1,125.28 55.84 1,070.52 Pass - Major Risk 01-02 - 01-02 - 01-02 400.00 400.00 1,047.02 9.74 1,037.28 Pass - Major Risk 01-03 - 01-03 - 01-03 5,459.50 5,700.00 640.19 261.89 379.96 Pass - Major Risk 01-03 - 01-03A - 01-03A 5,459.50 5,700.00 640.19 261.89 379.96 Pass - Major Risk 01-04 - 01-04 - 01-04 9,770.78 9,000.00 872.88 162.27 712.09 Pass - Major Risk 01-04 - 01-04A- 01-04A 9,770.78 9,000.00 872.88 162.40 711.96 Pass - Major Risk 01-04 - 01-04B - 01-04B 11,073.68 8,900.00 665.29 120.70 551.42 Pass - Major Risk 01-05 - 01-05 - 01-05 400.00 400.00 900.09 10.29 889.79 Pass - Major Risk 01-05 - 01-05B - 01-05B 382.45 375.00 899.75 9.91 889.84 Pass - Major Risk 01-05 - 01-05B - Plan 01-05B Wp16 382.45 375.00 899.75 10.34 889.41 Pass - Major Risk 01-05 - 01-05PB1 - 01-05PB1 400.00 400.00 900.09 10.29 889.79 Pass - Major Risk 01-06 - 01-06 - 01-06 378.43 375.00 866.57 7.44 859.13 Pass - Major Risk 01-06 - 01-06A - 01-06A 384.62 375.00 866.68 7.55 859.12 Pass - Major Risk 01-07 - 01-07 - 01-07 443.09 450.00 876.38 12.19 864.19 Pass - Major Risk 01-07 - 01-07A - 01-07A 443.09 450.00 876.38 12.19 864.19 Pass - Major Risk 01-07 - 01-07APB1 - 01-07APB1 443.09 450.00 876.38 12A 9 864.19 Pass - Major Risk 01-08 - 01-08 - 01-08 377.59 375.00 924.11 6.38 917.73 Pass - Major Risk 01-08 - 01-08A- 01-08A 4,802.74 5,550.00 791.65 100.79 695.50 Pass - Major Risk 01-08 - 01-08APB1 - 01-08APB1 381.99 375.00 924.19 6.46 917.73 Pass - Major Risk 01-09 - 01-09 - 01-09 400.00 400.00 995.56 10.90 984.66 Pass - Major Risk 01-09 - 01-09A - 01-09A 400.00 400.00 995.56 10.90 984.66 Pass - Major Risk 01-10 - 01-10 - 01-10 483.52 500.00 1,101.67 13.76 1,087.91 Pass- Major Risk 01-10 - 01-10A- 01-10A Plan 5 10,807.01 11,565.00 677.64 209.46 502.22 Pass - Major Risk 01-10-01-10A-01-10AXX 47.45 47.45 1,098.60 0.92 1,097.68 Pass - Major Risk 01-11 - 01-11 - 01-11 435.01 425.00 170.81 10.02 160.79 Pass - Major Risk 01-12 - 01-12 - 01-12 484.24 475.00 209.97 11.19 198.78 Pass - Major Risk 01-12 - 01-12A- 01-12A 484.24 475.00 209.97 11.34 198.63 Pass - Major Risk 01-13 - 01-13 - 01-13 1,352.89 1,325.00 297.08 31.04 266.23 Pass - Major Risk 01-14 - 01-14 - 01-14 1,626.23 1,575.00 343.72 43.98 300.26 Pass - Major Risk 01-14 - 01-14A - 01-14A 1,626.23 1,575.00 343.72 43.98 300.26 Pass - Major Risk 01-15 - 01-15 - 01-15 1,844.47 1,750.00 388.56 57.36 331.98 Pass - Major Risk 01-15 - 01-15A- 01-15A 1,850.77 1,750.00 388.87 57.74 331.94 Pass - Major Risk 01-15 - 01-15B - 01-15B 11,053.87 9,943.00 422.49 193.40 256.16 Pass - Major Risk 01-16 - 01-16 - 01-16 2,035.85 1,900.00 421.90 45.93 377.06 Pass - Major Risk 01-16 - 01-16A - 01-16A 48.45 48.45 623.85 0.93 622.92 Pass - Major Risk 01-17 - 01-17 - 01-17 2,215.76 2,050.00 467.05 76.25 392.29 Pass - Major Risk 01-17 - 01-17A- 01-17A 2,215.76 2,050.00 467.05 76.25 392.29 Pass - Major Risk 01-17 - 01-17B - 01-17B 2,215.76 2,050.00 467.05 75.98 392.56 Pass - Major Risk 01-17 - 01-17C - 01-17C 2,215.76 2,050.00 467.05 75.95 392.59 Pass - Major Risk 01-18 - 01-18 - 01-18 386.11 375.00 208.32 6.56 201.76 Pass - Major Risk 01-18 - 01-18A - 01-18A 390.12 375.00 208.39 6.63 201.76 Pass - Major Risk 01-19 - 01-19 - 01-19 5,303.55 5,100.00 270.82 168.56 103.23 Pass - Major Risk 01-19 - 01-19A- 01-19A 5,303.55 5,100.00 270.82 168.56 103.23 Pass - Major Risk 01-19 - 01-19B - 01-19B 5,303.55 5,100.00 270.82 168.56 103.23 Pass - Major Risk 01-19 - 01-19C - 01-19C 5,303.55 5,100.00 270.82 168.72 103.07 Pass - Major Risk 01-20 - 01-20 - 01-20 2,227.83 2,050.00 274.63 89.26 186.92 Pass - Major Risk 01-21 - 01-21 - 01-21 6,995.16 6,750.00 335.01 241.44 97.17 Pass - Major Risk 01-21 - 01-21 A- 01-21A 6,995.16 6,750.00 335.01 241.44 97.17 Pass - Major Risk 01-22 - 01-22 - 01-22 1,844.17 1,750.00 196.21 41.95 155A2 Pass - Major Risk 01-22 - 01-22A - 01-22A 1,844.17 1,750.00 196.21 41.95 155.12 Pass - Major Risk 1012712015 2.29:38PM Page 3 of 5 COMPASS 5000.1 Build 61 ° BP 41 by Anticollision Report BAKER we+ HUGHES Company: North America - ALASKA- BP Project: Prudhoe Bay Reference Site: PB DS 01 Site Error: 0.00usft Reference Well: Plan 01-35 Well Error: 0.00usft Reference Wellbore Plan 01-35 Reference Design: 01-35 wp03 Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: Well Plan 01-35 01-35 plan @ 86.95usft (rigx) 01-35 plan @ 86.95usft (rigx) True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) PBDS01 01-22 - 01-22B - 01-22B 1,844.17 1,750.00 196.21 41.95 155.12 Pass - Major Risk 01-23 - 01-23 - 01-23 1,633.93 1,575.00 146.88 34.57 112.85 Pass - Major Risk 01-24 - 01-24 - 01-24 1,383.43 1,350.00 109.80 34.34 75.68 Pass - Major Risk 01-24 - 01-24A- 01-24A 1,383.43 1,350.00 109.80 34.34 75.68 Pass - Major Risk 01-25 - 01-25 - 01-25 966.05 950.00 50.05 16.79 33.37 Pass - Major Risk 01-26 - 01-26 - 01-26 537.17 525.00 61.82 11.49 50.33 Pass - Major Risk 01-26 - 01-26A- 01-26A 543.13 525.00 61.91 11.58 50.33 Pass - Major Risk 01-28 - 01-28 - 01-28 336.30 325.00 891.06 6.36 884.70 Pass - Major Risk 01-28 - 01-28A- 01-28A 336.30 325.00 891.06 6.36 884.70 Pass- Major Risk 01-29 - 01-29 - 01-29 11,519.02 8,850.00 801.02 104.97 699.27 Pass - Major Risk 01-30 - 01-30 - 01-30 400.00 400.00 946.77 7.99 938.78 Pass - Major Risk 01-30 - Plan 01-30a - 01-30a wp02 409.32 400.00 946.94 8.32 938.61 Pass - Major Risk 01-31 - 01-31 - 01-31 13,191.43 9,425.00 1,074.95 303.46 784.62 Pass - Major Risk 01-32 - 01-32 - 01-32 1,943.83 1,825.00 401.68 43.04 359.58 Pass - Major Risk 01-32 - 01-32A - 01-32A 9,507.82 9,650.00 390.27 130.76 303.95 Pass - Major Risk 01-32 - 01-32A - 01-32A wp05 9,485.37 9,725.00 406.85 130.80 323.58 Pass - Major Risk 01-33 - 01-33 - 01-33 1,722.94 1,650.00 364.03 36.87 327.76 Pass - Major Risk 01-34 - 01-34 - 01-34 13,192.75 8,600.00 1,207.62 289.79 983.18 Pass - Major Risk 01-34 - 01-34A- 01-34A 13,104.19 9,225.00 1,008.32 251.12 762.03 Pass - Major Risk 1012712015 2.29:38PM Page 4 of 5 COMPASS 5000.1 Build 61 .*4, P BP ME Fag st Anticollision Report BAKER HUGHES Company: North America - ALASKA - BP Project: Prudhoe Bay Reference Site: PB DS 01 Site Error: 0.00usft Reference Well: Plan 01-35 Well Error: 0.00usft Reference Wellbore Plan 01-35 Reference Design: 01-35 wp03 Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: Well Plan 01-35 01-35 plan @ 86.95usft (rigx) 01-35 plan @ 86.95usft (rigx) True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum reference Depths are relative to 01-35 plan @ 86.95usft (rigx) Coordinates are relative to: Plan 01-35 )ffset Depths are relative to Offset Datum Coordinate System is US State Plane 1927 (Exact solution), Alaska Zone 04 ;entral Meridian is 150° 0' 0.000 W ° Grid Convergence at Surface is: 1.50' Ladder Plot 1600 -- -� ,I I I I I I I I i c 1 I = 1200 [ii r I I d i °' 800 IV = , .J c J N - _• 400 r i, -- - - U -- (LEGEND - I 01-01' 1,01-01V2 01-10,01-1oA,01 -1OAPlan5VO $ 01-21',01-21A,01-21AV2 01iS1A,01-01A,01-01AV7 01-10,01-10A,01-10A)(XVO 01-22,01-22,01-22V4 �9 01-0 ,0 ,00 1 B V6 0-1�61-11,01-1-22, 1-22&01-23 01-01A,01-01C,?P99CV6 6nnn 01-12,01-12,01Z�M 10L1la 01-22,01-2214,4199bVO 15000 01-02,01-02,01-02V2 oWha?xA0,@ep!hQ500usft/in) 01-23,01-23,01-23V2 01-03,01-03A,01-03AV1 $ 01-14,01-14,01-14V2 $ 0 1 -24,01-24A, 0 1 -24A V1 -X- 01-04,01-04,01-04V2 $ 01-14,01-14A,01-14AVO 01-25,01-25,01-25V1 $ 0 1 -04,01-04A, 0 1 -04A V7 01-15,01-15,01-15V2 01-26,01-26,01-26V1 01-04, 01-04B, 01-04B VO 01-15, 01-15A, 01-15A V 1 01-26, 01-26A, 01-26A V2 $ 01-05,01-05,01-05V3 01-15,01-15B4O1-15BVO 01-28,01-28,01-28V1 0 1 -05,01 -05B, 0 1 -05B V1 1 $ 01-16,01-16,01-16V13 01-28,01-28A,01-28AVO 0 1 -05,01 -05B, Plan 0 1 -05B Wp 16 V31 ->R- 01-16,01-16A,01-16AVO 01-29,01-29,01-29V7 -fit- 01-05,01-05PB1,01-05PB1V2 01-17,01-17,01-17V2 01-30,01-30,01-30V1 01-06,01-06,01-06V1 $ 01-17,01-17A,01-17AV2 01-30, Plan 01-30a,01 -30a wpO2 V1 $ 0 1 -06,01-06A, 0 1 -06A V1 $ 0 1 -17,01 -1 7B, 0 1 -1 7B V2 01-31,01-31,01-31 V1 1012712015 2.29:38PM Page 5 of 5 COMPASS 5000.1 Build 61 W ,We sunn 5 � � A &9- 0 `noa� M 0 a � °doMMa O N � 133 m m m o a`aaa� 3 � o -- o z m 0 N - 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N IL h Jo J a �a r o rno m r� � 1d om 2 m Z 04*1?1 jil o �o �o s sa$s3sea��e� sa��a$s�s s s a� s � �ffisa q3p sgare�s�ma� �d�3��� oo"vos3da8dB§8o-68ff 9d$ = o peso sqs ,#�woasAs xx3333 0 6 .� ID O O't O o 04 O O N V 'ITM M N N g M ch � 00 O N 0 00 o b o o o cs �o o o 0 0 a r N 0 ¢ ¢ ¢ 3 � 3 y o�a�a�a 0>�333�3 i � d ¢ a M M n� n U MnMmfn w o aaaaaaa w o0 ¢ o A0000000 � Tnnnnnn o. 3 3 3 3 3 z�M��M�M �0000000 c0 00000v> 000000M � oo�o�o�rn m nNoo�n�m� p Q�NtO�JN OHO' 0 0 0 0 0 0 p0�000000 0 o co so .-�nMmm O North America - ALASKA - BP Prudhoe Bay PBDS01 Plan 01-35 Plan 01-35 01-35 wp03 plus 500' MD Anticollision Summary Report 28 October, 2015 BAKER NUGHES r" BP FGFag by Anticollision Report BAKER HUGHES Company: North America - ALASKA - BP Project: Prudhoe Bay Reference Site: PB DS 01 Site Error: 0.00usft Reference Well: Plan 01-35 Well Error: 0.00usft Reference Wellbore Plan 01-35 Reference Design: 01-35 wp03 plus 500' MD Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well Plan 01-35 01-35 plan @ 86.95usft (rigx) 01-35 plan @ 86.95usft (rigx) True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Reference 01-35 wp03 plus 500' MD Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 200.00usft Error Surface: Elliptical Conic Survey Tool Program Date 10/28/2015 From To (usft) (usft) Survey (Wellbore) 46.95 1,200.00 01-35 wp03 plus 500' MD (Plan 01-35) 1,200.00 2,500.00 01-35 wp03 plus 500' MD (Plan 01-35) 1,200.00 3,901.00 01-35 wp03 plus 500' MD (Plan 01-35) 3,901.00 5,500.00 01-35 wp03 plus 500' MD (Plan 01-35) 3,901.00 9,161.00 01-35 wp03 plus 500' MD (Plan 01-35) 9,161.00 10,670.00 01-35 wp03 plus 500' MD (Plan 01-35) 9,161.00 13,693.40 01-35 wp03 plus 500' MD (Plan 01-35) Tool Name Description GYD-GC-SS Gyrodata gyro single shots MWD MWD - Standard MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal MWD MWD - Standard MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal MWD MWD - Standard MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal 1012812015 5:38:06PM Page 2 of 4 COMPASS 5000.1 Build 61 0*0,z BP by Anticollision Report Company: North America - ALASKA - BP Local Co-ordinate Reference: Well Plan 01-35 Project: Prudhoe Bay TVD Reference: 01-35 plan @ 86.95usft (rigx) Reference Site: PB IDS 01 MD Reference: 01-35 plan @ 86.95usft (rigx) Site Error: 0.00usft North Reference: True Reference Well: Plan 01-35 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore Plan 01-35 Database: EDM R5K - Alaska PROD - ANCP1 Reference Design: 01-35 wp03 plus 500' MD Offset TVD Reference: Offset Datum ri.® BAKER HUGHES Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) PB DS 01 01-01 - 01-01 - 01-01 Out of range 01 -01A - 01 -01 A - 01 -01 A Out of range 01-01A - 01-01 B - 01-01 B Out of range 01-01 A - 01-01 C - 01-01 C Out of range 01-02 - 01-02 - 01-02 Out of range 01-03 - 01-03 - 01-03 Out of range 01-03 - 01-03A- 01-03A Out of range 01-04 - 01-04 - 01-04 Out of range 01-04 - 01-04A- 01-04A Out of range 01-04 - 01-04B - 01-04B Out of range 01-05 - 01-05 - 01-05 Out of range 01-05 - 01-05B - 01-05B Out of range 01-05 - 01-05B - Plan 01-05B Wp16 Out of range 01-05 - 01-05PB1 - 01-05PB1 Out of range 01-06 - 01-06 - 01-06 Out of range 01-06 - 01-06A- 01-06A Out of range 01-08 - 01-08 - 01-08 Out of range 01-09 - 01-09 - 01-09 Out of range 01-09 - 01-09A - 01-09A Out of range 01-11 - 01-11 - 01-11 435.01 425.00 170.81 10.02 160.79 Pass - Major Risk 01-12 - 01-12 - 01-12 Out of range 01-12 - 01-12A- 01-12A Out of range 01-16 - 01-16 - 01-16 Out of range 01-21 - 01-21 - 01-21 Out of range 01-21 - 01-21 A - 01-21 A Out of range 01-22 - 01-22 - 01-22 1,844.17 1,750.00 196.21 39.64 157.28 Pass - Major Risk 01-22 - 01-22A- 01-22A 1,844.17 1,750.00 196.21 39.64 157.28 Pass - Major Risk 01-22 - 01-22B - 01-22B 1,844.17 1,750.00 196.21 39.64 157.28 Pass - Major Risk 01-23 - 01-23 - 01-23 1,633.93 1,575.00 146.88 32.59 114.68 Pass - Major Risk 01-24 - 01-24 - 01-24 1,360.11 1,325.00 109.38 33.09 76.37 Pass - Major Risk 01-24 - 01-24A- 01-24A 1,360.11 1,325.00 109.38 33.09 76.37 Pass- Major Risk 01-25 - 01-25 - 01-25 966.05 950.00 50.05 16.79 33.37 Pass - Major Risk 01-26 - 01-26 - 01-26 537.17 525.00 61.82 11.49 50.33 Pass - Major Risk 01-26 - 01-26A- 01-26A 543.13 525.00 61.91 11.58 50.33 Pass - Major Risk 01-28 - 01-28 - 01-28 Out of range 01-28 - 01-28A- 01-28A Out of range 01-29 - 01-29 - 01-29 Out of range 01-31 - 01-31 - 01-31 Out of range Plan 01-35 - Plan 01-35 - 01-35 wp03 11,625.00 11,625.00 0.00 122.85 -105.57 FAIL - Major Risk 1012812015 5:38:06PM Page 3 of 4 COMPASS 5000.1 Build 61 f by BP Few as Anticollision Report BAKER HUGHES Company: North America - ALASKA- BP Project: Prudhoe Bay Reference Site: PB DS 01 Site Error: 0.00usft Reference Well: Plan 01-35 Well Error: 0.00usft Reference Wellbore Plan 01-35 Reference Design: 01-35 wp03 plus 500' MD Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well Plan 01-35 01-35 plan @ 86.95usft (rigx) 01-35 plan @ 86.95usft (rigx) True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Reference Depths are relative to 01-35 plan @ 86.95usft (rigx) Coordinates are relative to: Plan 01-35 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927 (Exact solution), Alaska Zone 04 Central Meridian is 150' 0' 0.000 W ° Grid Convergence at Surface is: 1.50° 200- 150- 0 0 co cn 100- c a� U 0 U 50- 0 0 Ladder Plot -->'- -- I I I I - - ------------------ -------------- I I ---- -I--------I---- --- - , I I II , - -- -- , I - --- I I - ----'-- -- I -- =-J - - -- , ---------- I - - - - -'- -JI-- -- -- ----------------- J - - - -- I -- I , - - _ --I-- -- I I - - - - -I- -- - - - - -- -I- _- - -- - - - - -1- - -. --- ---I--- - I I I I I 1 1 1 r I 2500 5000 7500 10000 12500 15000 Mea"cr &Xg2500 usftrin) ul-ul,ul-V-I,ul-u-I VZ 01-01A,01-01A,01-01A V7 01-01A,01-01 B4O1-01 BV6 01-01A,01-01C,01-01CV6 01-02, 01-02, 01-02 V2 01-03, 01-03, 01-03 V2 0 1 -03,01-03A, 0 1 -03A V1 01-04,01-04,01-04 V2 — 01-04, 01-04A, 01-04A V7 -8- 01-04,01-04B4O1-04BV0 01-06,01-06A,01-06A V1 $ 01-08,01-08,01-08V5 01-09, 01-09, 01-09 V2 $ 01-09,01-09A,01-09AV1 01-11,01-11,01-11 V2 01-12,01-12,01-12 V3 01-12, 01-12A, 01-12A V3 - 01-16,01-16,01-16V13 — 01-21,01-21,01-21 V1 01-21.01-21A.01-21A V2 -X% 01-24,01-24,01-24V2 $ 01-24,01-24A,01-24AV1 01-25, 01-25, 01-25 V1 $ 01-26,01-26,01-26 V1 $ 01-26,01-26A,01-26AV2 �— 01-28,01-28,01-28V1 01-28, 01-28A, 01-28A V0 — 01-29,01-29,01-29V7 01-31,01-31,01-31 V1 1012812015 5:38:06PM Page 4 of 4 COMPASS 5000.1 Build 61 m W �mm we `U9 _ � N m m a66 o m `0 � n w 3m 0 W M Z v ro 0 o� m n c w do 3 3H C m a 0 Ico a y Q 7 M C a c c 2mAAo ac.aa� °JN3a°w a 3a 0 I o N a Northing (450 usft/in) 8 8 8p 8 8 s 8 8 8 s p8 8 8 8 8 8 8 bpi 8 8 8 b � ppi Z2 8 O T W m 1 m m rn m m m m m m m m 711750 711750 711100 711100 710450 710450 709800 709800 00 0 709150 709150 � o o 708500 o o _ 708500 O 707850 0 <i 707850 O 2D N m 707200 Dv n > 707200 O \O Q CD � CD 706550 CO o c5 - <0 706550 CD.— op N I.nf�.• _ J 705900 o -- o ' o m 705900 O 0 Cp ) (V N 705250 o p0 0 705250 CD CD un 9 0 704600 ° o o za -. 704600 0 l L _ 703950 o 0 703950 0 703300 N O Q rn 00 cNv o � CD 703300 clip0 0 - 702650 N o c� N. q 702650 .- C _ o _ c: 702000 N N o - -IL OQ08 ®®®� `' 702000 N 7 0 QF 701350 N vo c O� -_ - 701350 N 0 0 9 U700700 0 - - OD - --- -_ 700700 U C OO \ C += o O 'm 700050 a o 700050 m 699400 0 o - 699400 LO N 0 r o 698750 0 PO P - o 698750 N 696100 0' �O o 0 J a o 698100 OC 697450 � 697450 O 9 c 696800 co 696800 O a 696150 696150 695500 0 695500 N 0 0gip$- 694850 0 o Op 694850 _ 08 694200 694200 693550 0000 Q 693550 � a 692900 M CDN 692900 o 692250 U co o N 692250 CV 691600 o O 691600 M N 690950 690950 690300 690300 O O (ui/33sn OSt) 2ui43aoN PARKER 272 BOP STACK RAM TYPE BOP: DUTCH LOCK DOWN FLANGE SHAFFER LXT DOUBLE BOP 13 5/8"-5M 13 5/8"-5M STUDDED TOP 13 5/8"-5M FLANGED BOTTOM g 4o ANNULAR BOP: W/(2) 14" UL2 OPERATOR, UPPER CAVITY SHAFFER LXT 13 5/8"-5M AND (2) 14" PSLK W/BSTR OPERATOR, it n LOWER CAVITY 13-5/ 8 5M STUDDED TOP 13-5/8" 5M FLANGED BOTTOM e � e DRILLING CROSS: 13 5/8"-5M FLANGED TOP 13 5/8"-5M FLANGED BOTTOM W (2) 3 1/8"-5M SIDE OUTLETS KILL LINE: 2-1/16" 5M FLEX HOSE 2-1/16" 5M X 3-1/8" 5M D.S.A. 3-1/8" 5M FLANGED MANUAL GATE VALVE 3-1/8" 5M FLANGED HYDRAULIC GATE VALVE r ° ° o ° o° CHOKE LINE: RAM TYPE BOP: 3-1 /8" 5M FLANGED MANUAL GATE VALVE SHAFFER LXT SINGLE 13 5/8" 5M 3-1/8" 5M FLANGED HYDRAULIC GATE VALVE 13 5/8"-5M STUDDED TOP13 5/8"- 5M FLANGED BOTTOM 3-1/8" 5M FLEX HOSE W/(2) 14" UL2 OPERATOR Enter/Exit 1rA Jed Enter/Exit � I ED II — I1 1 1, II I I I I I 1119 I ` • 1A I I 17 1 - I 1 1120 1 I I II I I I I 16 • I I •2 I I 8121 1 II 32 • I 11 I 15 AVCS (1 I it3 I I •22 33 • I 1 1 I 1 1 14 I i 1 f O~ •4 � � I •23 C%4 I I •13i 1 •5 I \n DS 1-35 64 Diverter E,,dusion Zone p5 Radius from End I I �' I I � I of Diverter) I I l •112 I I II I 11 11 �I 1 O � I � I.6 co �Iowfo Diverter , •11 1 I ' I In Use 1 I I - I i t I 1 1I �•1� 11 /I 1 I• I I i i 1 I• 7 � I I I I \ 1.J 1220' I Odr— Loader Parking Pr itited During Su face Ha — — — — — _ 1 1 •28 ' I Drilling Traffic Access) 1 ly I 1 I •29 �� to Pad Entrance' � 1 I �\ I I I I t 8 / 1 J� li I 1 430 AN 31 ` I 9 I I 1'4 300 �' � 1 I I I I I i •34 1, 11 III 1751 / I III, 1 I }p � I 1335 11�-- 230 �-r — — — — ► -- ■ WELL A WELL INJECTOR I DATE : 03/18/2015 SCALE: 1" = 250 MAP DATE: 2014 I PBU - DS 1 For current Well and Service information please see Atlas: http://alaska-gis.bpweb.bp.com bsl4495.mxd �LZ I � r 1 � � :. Tto .� cc r ""' "" OWN ■tom Roo' mom 00E _4: 0)v X CO CU � t � CD L v tM 4-_> Qo o D _ LO N C) Q Parker F g 272/273 New Diverter Layout Showing Distance to Ignition Sources in Red. JGS 1-2-2016 Air Heaters Rig Boilers Air Heater 20' Exclusion Zone Loader Parking Prohibited i.W Utility Modul F s� Drill Mo ule { Rig Cellar 75' f (DumrTV Well Hous r Rig Flo(%r Cantilever o New Diverter Vent Line Cellar, BOP Deck &,\ 4 50' Rig Floor Are All Classified Areas (No Ignition Sources) 041 ud Module Vac Trucks Note 1 -All ignition sources are outside the 75' radius from the end of the diverter vent line. Boilers are located on a deck 2 levels below the air heaters on the rig. Note 2 -An exclusion zone will be used to keep the loader from parking in the 75' radius around the diverter vent. A, 5 .47 3� SCSSV =aIT� Q I 0 57.74 1467.6 i33.[5 I h L I75 577.85 9.I15 .dl ITLM'� PART NUMBER E= DESCR PTIOIV I j13-300-030 D V-R—ER L4DID NC RING z_{ 38322-0005 9 8 CASING NANO -ER 3 P�72070 SLi P-IN LANDING R11IG -- �4 11 P164819 'I, ; ASING HEAD ASS2MBL'/ 13-3G0 7'8. ,;EN 5 IUBING HEAD ASSEMBL+ 'P.23277-.0002 7 CAS'N6 RANGER �- -12-'50-CIG 7 ?ACKOFF ASSEVOLr e IPIE6963 TUBING PIANGFR ASSEMBLT 9 02-0.a7 9 TUB. EG HEAD ASSEMBL, 10 2-093 7e 9 9/8 C "LASING HANGER . rE5 N CRT 0 _01gDOWN SCREWS -11-5000 ;R-5A� 16 5000 MOD 1-0 GV `S 'ORT .. , SINE WS 501110 IR 1, 5000 MOD I.'D CV -- 20I'D CAS NG 9 5/9 OD CAS,NG 7OD CASING I/, OD CASING �u X ., 8 X 7 X REF: DMIOIC 104'E-g 2DM1080698 III PRIVATE AND CONFIDENTIAL UNLESS I—ER11SI s 1 IN 1-1—IONs ISE SCRI—GN TC)LERANSE a c3 cs II _ s CE`,EMA_ WE _'. -IE AL CD "„ , • .,.tt..p °A° 2'_ E d L,�H x x I- -- fM�AWabgl�s O aA ANGLE x - -5000 COMPLTI II os-��.. ,�„ �M IC`DI Ce 92.25 50. -11 O O : i0 500o MOD 1,-'0 cM O O `- -4 1,16-5000 V00 I2C rlV 5c0o V2; eM ACID 0 o --a/iF-5000 MOD ® O 1 W/I, i6-E000 WV NG pDM 0002007 TRANSMITTAL LETTER CHECKLIST WELL NAME: zxat::� 0/r-35 PTD: Z Development Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: POOL: 2r�% �r 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 onpermit). 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 sample 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) 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, PRUDHOE OIL - 640150 PTD#:2160210 Company BP EXPLORATION (ALASKA) INC. Initial Class/Type Well Name: PRUDHOE BAY UNIT 01-35 Program DEV Well bore seg DEV / PEND GeoArea 890 Unit 11650 On/Off Shore On Annular Disposal Administration 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D) NA 1 Permit fee attached NA 2 Lease number appropriate Yes Entire Well lies within ADL0028329. 3 Unique well name and number Yes 4 Well located in a defined pool Yes PRUDHOE BAY, PRUDHOE OIL POOL - 64015, governed by CO 341F 5 Well located proper distance from drilling unit boundary Yes CO 341 F, Rule 2: There shall be no restrictions as to well spacing except that no pay shall be 6 Well located proper distance from other wells Yes opened in a well closer than 500 feet to the boundary of the affected area. Planned well conforms to CO 7 Sufficient acreage available in drilling unit Yes 341 F, Rule 2. 8 If deviated, is wellbore plat included Yes 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 12 Permit can be issued without administrative approval Yes SFD 2/2/2016 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 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 18 Conductor string provided Yes 80' conductor provided Engineering 19 Surface casing protects all known USDWs Yes 3900' MD 20 CMT vol adequate to circulate on conductor & surf csg Yes 221 % excess 21 CMT vol adequate to tie-in long string to surf csg No 22 CMT will cover all known productive horizons Yes Productive interval will be completed with cemented production liner and perforated 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig has steel tanks; all waste to approved disposal wells 25 If a re -drill, has a 10-403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Anti -collision analysis complete; no major risk failures 27 If diverter required, does it meet regulations Yes Diverter meets regs; flow paddle waived <1000' drilling per 20AAC25.0330) Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pres is 3205 psig(7.2 ppg EMW ); will drill w/ 8.5-10.8 ppg EMW VTL 2/10/2016 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MPSP is 2349 psig; will test BOPs to 3500 psig 31 Choke manifold complies w/API RP-53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S measures required 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No IDS 01 wells are H2S-bearing. H2S measures are required. Geology 36 Data presented on potential overpressure zones Yes Planned mud weights appear adequate to control the operator's forecast of most likely pore pressures. Appr Date 37 Seismic analysis of shallow gas zones NA Should higher pore pressures be encountered, BP has immediate access to nearby fluid mixing facilities. SFD 2/2/2016 38 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly progress reports [exploratory only] NA Geologic Engineering Public Commissioner: Date: Date Commissioner Date QL� //k/ '1ICoommmissioner: (_�c/,, Z��`"�r
