Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
215-111
Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Monday, September 11, 2017 12:02 PM To: 'Lastufka, Joseph N' Cc: Davies, Stephen F (DOA); Loepp, Victoria T (DOA) Subject: Expired PTDs: PBU S-04A PTD 215-111 and PBU U-06131-1-01 PTD 215-124 Joe, Permit to Drill 215-111, for PBU S-04A, issued 14 July 2015, has expired under the Regulation 20 AAC 25.005 (g). Also, Permit to Drill 215-124, for PBU U-06131-1-01, issued 27 July 2015, has expired. The two PTDs will be marked expired and updated in our database. Please update BP Exploration (Alaska) databases also. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl 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.guhIPalaska.gov. Davies, Stephen F (DOA) From: Gorham, Bradley M <Bradley.Gorham@bp.com> Sent: Wednesday, July 01, 2015 1:54 PM To: Davies, Stephen F (DOA) Cc: Loepp, Victoria T (DOA); Lastufka, Joseph N Subject: RE: PBU S-04A (PTD No. 215-111) - Concatenated Questions and Requests Steve, Please see the comments below in red. If you have any further questions or concerns please feel free to contact me. Thanks, Brad From: Davies, Stephen F (DOA)[mailto:steve.davies@alaska.gov] Sent: Tuesday, June 30, 2015 11:41 AM To: Gorham, Bradley M Cc: Loepp, Victoria T (DOA) Subject: FW: PBU S-04A (PTD No. 215-111) - Concatenated Questions and Requests Bradley, Let me gather all of my comments and questions into a single email so that you only have to respond to this one. 1. BP's planned redrill of existing well PBU S-04 targets the Kuparuk Formation rather than the underlying Sag River or Ivishak Formations. Wouldn't the proper pool for this well be the Aurora Oil Pool rather than the Prudhoe Bay Oil Pool as indicated on the Permit to Drill application? You are correct, the correct pool for this formation should be the Aurora Oil Pool. If so, to date nearly all of the wells drilled to, and completed in, the Aurora Oil Pool have been assigned well numbers that are in the 100 series (for example, PRUDHOE BAY UN AURO S-100, PRUDHOE BAY UN AURO S-110, PRUDHOE BAY UN AURO S-110A, with the well highest number currently being PRUDHOE BAY UN AURO S- 135). Consistent well numbering reduces potential for confusion and/or error. Would BP like to take this opportunity to re -number this proposed redrilled well accordingly so that it conforms to BP's past well numbering convention? Had this been a grassroots well, this well would have been given a well name in the 100 series as you suggested. However, this is a sidetrack and therefore we do not wish to change the numbering convention. Planned injection redrill PBU S-04A targets the Kuparuk Formation. The Area of Review map provided with the Permit to Drill application for PBU S-04A states that there are no Kuparuk well penetrations within the % mile circle of S-04A. In October 2013, the AOGCC approved a Permit to Drill application for well PBU S-130, a planned Aurora Pool (Kuparuk formation) WAG injection well. AOGCC subsequently re -issued this permit in February 2014 due to a change in planned surface and bottom -hole locations. The Permit to Drill for PBU S-130 is valid until October 28, 2015. The revised, proposed bottom -hole location for PBU S-130 lies about 700' west of the planned bottom -hole location for PBU S-04A. Does BP still plan to drill PBU S-130? No — S-04A will be replacing the target area previously planned for S-130. • If not, does BP wish to withdraw the approved Permit to Drill for PBU S-130? Yes, there is no longer a plan to drill S-130. I will get with Joe Lastufka and submit a formal notice to withdraw the S-130 PTD. • If so, will PBU S-130 and PBU S-04A conform to well spacing requirements set forth in Conservation Order No. 457E — Corrected? 3. The planned mud program appears adequate for BP's most likely estimated pore pressures; however, it is not adequate to mitigate BP's maximum expected pressures in the Kuparuk that are estimated at 11.5 ppg (see page 3 of the application). Will BP will have enough barite, CaCO3, or other agents on location to weight up the drilling mud sufficiently to mitigate BP's maximum anticipated pore pressure? BP's drilling rig always have access to enough weight agents to cover the maximum anticipated pore pressure if it is in fact encountered. 4. The present application for PBU S-04A doesn't discuss pre -production or well cleanup operations. Will planned injection well PBU S-04A be pre -produced for an extended period of time (30 days or longer) prior to being placed on regular injection, or will the well simply be flowed back for a short period to clean up perforations? No, the well will not be pre -produced for longer than 30 days. The well will be pre - produced for a short time period to clean up the perforations prior to being placed on injection. Thanks, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7`h Avenue, Suite 100 Anchorage, AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Wednesday, July 01, 2015 11:35 AM To: 'david.c.morales@exxonmobil.com' Cc: Schwartz, Guy L (DOA) Subject: FW: PTU 17 (PTD No. 215-115) - Requests: Directional Survey; Logging Program David, Since Alex is out of the office, I'm forwarding this email to you. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7'h Avenue, Suite 100 Anchorage, AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies, Stephen F (DOA) Sent: Wednesday, July 01, 2015 11:33 AM To: alex.v.podust@exxonmobil.com Cc: Roby, David S (DOA); Schwartz, Guy L (DOA) Subject: PTU 17 (PTD No. 215-115) - Requests: Directional Survey; Logging Program Alex, Directional Survey Could ExxonMobil please submit a legible printed copy of the planned directional survey data for PTU 17? The size of the print on the copy presented in Attachment 4 of the Permit to Drill Application is very small and poorly reproduced, requiring use of a magnifying glass decipher many of the numbers. AOGCC scans all well records into a document management system, and the copy provided will not be legible when scanned. Logging Program AOGCC requires a complete logging suite —minimum: mud log; gamma ray, resistivity, and porosity well log(s)—from the base of conductor pipe to total depth for the first well from each new drill site. Please plan on acquiring this minimum logging suite (Authority: 20 AAC 25.071(a)). Please let me know if you have any questions or if I can help further. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 71h Avenue, Suite 100 Anchorage, AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies(o)alaska.gov. THE STATE o 'AILASKA GOVERNOR BILL. WALKER Ken Allen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Alaska Oil and Gas ConsenTation 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov Re: Prudhoe Bay Field, Aurora Oil Pool, PBU S-04A BP Exploration (Alaska), Inc. Permit No: 215-111 Surface Location: 1633' FNL, 1085' FWL, SEC. 35, T12N, R12E, UM Bottomhole Location: 3773' FSL, 3420' FWL, SEC. 26, T12N, R12E, UM Dear Mr. Allen: Enclosed is the approved application for permit to redrill the above referenced service 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, p4tA44--- Cathy P oerster Chair DATED this 10d-a y of July, 2015. STATE OF ALASKA ALAI OIL AND GAS CONSERVATION COMM ON PERMIT TO DRILL 20 AAC 25.005 REGO D JUN � /_ ) 1 a. Type of work: 1 b.Proposed Well Class: ❑ Development Oil ❑ Service - Wini ❑ Single Zone 1 c. Specify if well is proposed for: ❑ Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development Gas ❑ Service - Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ® Redrill ❑ Reentry ❑ Exploratory ® Service -WAG ❑ Service - Disp ❑ Geothermal ❑ Shale Gas 2. Operator Name: 5. Bond . ® Blanket ❑ Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No 6194193 ' PBU S-04A ` 3. Address 6. Proposed Depth: 12. Field / Pool(s) P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 10290' ' TVD 7088' - Prudhoe Bay / Pry �J Ysz2< i taC� 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: ADL 028257 4 < ;cam iS 1633' FNL, 1085' FWL, Sec. 35, T12N, R12E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 3561' FSL, 3327' FWL, Sec. 26, T12N, R12E, UM January 15, 2016 9. Acres in Property: 14.Distance to Nearest Property: Total Depth 3773' FSL, 3420' FWL, Sec. 26, T12N, R12E, UM 2560 6700' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10.KB Elevation above MSL: 83.65' . feet 15.Distance to Nearest Well Open Surface: x 619247 y- 5979855 Zone- ASP4 GL Elevation above MSL: 36.7' feet to Same Pool: 2600' 16. Deviated Wells: Kickoff Depth: 2750' feet 117. Maximum Anticipated Pressures in psig (see AC 25.035) 20 A Maximum Hole Angle: 61 degrees • Downhole: 3505' Surface: 2825 18. Casing Program S ecifications Top - Setting Depth - Bottom Quantity of Cement, c.f. or sacks Hole Casing Weight I Grade Coupling Length MD TVD I MD TVD (including stage data) 8-1 /2" 7" 26# 13Cr801 L-80 VamTop HC 7690' 2600' 2600' 10290' 7088' 315 sx LiteCrete 242 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): 1 Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) 9575' 9238' 8624' 8624' 8339' 9521' Casing Length Size Cement Volume MD TVD Conductor / Structural 80' 20" x 30" 8 cu yds Concrete 40' - 120' 40'- 120' Surface 2642' 13-3/8" 3729 Arcticset III & Arcticset II 40' - 2682' 40'- 2682' Intermediate 8977' 9-5/8" 1030 cu ft Class'G', 575 cu ft Class'G', 133 cu It Permafrost 38' - 9015' 38' - 8706' Production Liner 814' 7" 360 cu ft Class 'G' 8762' - 9575' 8468' - 9238' Perforation Depth MD (ft): 9028' - 9334' Perforation Depth TVD (ft): 8718' - 9008' 20.Attachments: ❑ Property Plat ® BOP Sketch ® Drilling Program ❑ Time vs Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ® Drilling Fluid Program ® 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: 22. 1 hereby certify that the foregoing is true and correct: Date Contact Brad Gorham, 564-4649 Email Bradley. Gorham@bp.com Printed Name Ken Allen Title Engineering Team Leader t Signature i� c / Phone 564-4366 Date b Commission Use Only Permit To Drill l - !-% J % / API Number: Permit Approval D te: See cover letter for Number: 50-029-20959-01-00 other 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 shales: Other: OOP fe'sf fo 40 0OP5 i Samples Req'd El, Yes [9 No Mud Log Req'd: ❑ Yes ❑ No fi /-7 n v l Gtr p i—t (/ n-3 fir tt5 f fo Z 5-001-)sI j H,2S Measures: [;]Yes ❑ No Directional Survey Req'd: ❑ Yes ❑ No `Sr�pacing /YJ lT/�) fYw/ rtG! G ftCr S fCc 1 i�i3TG� exception req'd: [:]Yes ❑ No inclination -only svy Req'd: ❑ Yes E;(No APPROVED BY P R VED BY COMMISSIONER C ISSION Date Form 10-401 Revised 10/2/012 This permit is valid for 24 months fron1%Je b)tJof`fipdrJvai 10 A� 25.005(g)) Submit Form and Attachments In Duplicate To: Alaska Oil & Gas Conservation Commission From: Brad Gorham, ODE Date: June 22, 2015 RE: S-04A Permit to Drill The S-04A well is scheduled to be drilled by Parker 273 in January 2014. This well is a rotary sidetrack injector targeting the Kuparuk C Sands. The planned well is a single string, 7" production liner that targets the Kuparuk C sands. The 7" production liner will be cemented and perforated, with the perforations occurring post rig. The maximum anticipated surface pressure from the Kuparuk with a full column of gas from TD to surface is 2,825 psi (assumes 9.9 ppg EMW most likely pore pressure and a 0.1 psi/ft gas gradient). The well will be drilled by Parker 273 using their 5,000 psi four preventer BOP stack (3 rams and an annular). The BOP rams will be tested to 4,000 psi while the annular preventer will be tested to 3,500 psi. A detailed operations summary is included with the permit application. Below is a brief summary of planned drilling operations: 1. Move in and rig up Parker 273. 2. Nipple up and test BOPE to 4,000 psi. (Annular to 3,500 psi) 3. Pull 4-1/2" tubing from—3,000' MD to surface. (Tubing jet cut pre -rig). 4. RU E-line and run EZSV/GR/CCL 5. Set EZSV at —2,766' MD. 6. PU and set 9-5/8" whipstock at—2,766' MD. (End of Sundry / Beginning of Permit to Drill) 7. Mill window in 9-5/8" casing. 8. Drill 8-1/2" Production hole to top of the Kuparuk B1 at—10,290' MD. 9. Run 7" liner and cement to 500 ft MD above Top of SB_Na (TOC -- 5,700' MD) Pressure test to 4,000 psi. 10. MU cleanout BHA with Sonicscope to log cement for TOC verification 11. Displace wellbore to 8.5 ppg seawater. 12. Run 4-1/2" chrome completion tubing and set production packer. 13. Pressure test the tubing and the inner annulus to 4,000 psi each. 14. Freeze protect to—2,200' TVD and secure the well. 15. Rig down and move off the well. In addition to a planned well summary, a directional plan and proposed completion diagram is attached to the permit application. If there are any questions concerning information on S-04A, please do not hesitate to use the contact information below. Brad Gorham Office: (907) 564-4649 Cell: (907) 223-9529 Email: Bradley.Gorham(aDbp com Attachments: Well Bore Schematic Proposed Pre -Rig Schematic Proposed Completion Directional Plan BOPE Schematic As -Built Survey Rig Shadow Area Review Map Well Head Schematic Tree Schematic S-04A PTD 1 6/22/2015 Planned Well Summary Well S-04A Well Injector Ob activTarete Kuparuk Current Status Rotary Sidetrack Estimated Start Date: 1 1/15/2016 Time to Complete: 1 24.0 Days Surface Northing Easting Offsets TRS Location 5,979,855 619,247 3646.17' FSL 4194.86 12N 12E Sec 35 FEL/ Northing Easting 1 TVDss Offsets TRS Tgt 3 5,985,085 621,400 6,810 1718.3' FNL / 1952.3 12N 12E Sec 26 TLSB FEL Tgt 6 5985298.5 621489.3 7,004 1506.2' FNL / 1859.3 12N 12E Sec 26 BHL FEL Planned KOP: I 2,750' MD Planned TD: I 10,290' MD / 7,004' TVDss Rig: I Parker 273 Directional - SLB WP 5c GL-RT: 46.95 RTE (ref MSL): 83.65 KOP: 2,750' MD Maximum Hole Angle: -60.70 in the production section Close Approach Wells: S-24, S-24A, S-24B, S-25, S-25A, S-25APB1 Survey Program: KOP (2,750' - 3,450' MD) = GYRO 3,450' MD to TD = MWD+IFR+MS Nearest Property Line: -r6,700' Nearest Well within Pool: -2,600' S-04A PTD 2 6/22/2015 Formation Tops and Pore Pressure Estimate (SOR) TU"` r 1 LAJ w (PS) Formation Estimated Formation Top (TVDss) Minimum Pore Pressure (EMW ppg) Most Likely Pore Pressure (EMW ppg) Maximum Pore Pressure (EMW ppg) Depth Uncertainty (+/- TVD ft) Fluid Type (for sands) KOP 2,666 8.4 8.6 9.0 +/-10 ft. Water/ Heavy Oil/ Gas Cut Mud SV3 2,700 8.4 8.6 9.0 +/-10 ft. Water/ Heavy Oil/ Gas Cut Mud SV2 2,857 8.4 8.7 9.0 +/-10 ft. Water SV7 3,195 8.4 9.0 9.0 +/-20 ft. Water/ Free Gas UG4 3,520 8.4 8.9 9.0 +/-20 ft. Water UG4A 3,580 8.4 8.9 10.2 +/-20 ft. Heavy Oil/water UG3 3,875 8.4 8.9 9.0 +/-20 ft. Heavy Oil/water UG1 4,400 8.4 8.7 9.0 +/-20 ft. Heavy Oil/water UG MA 4,710 8.4 8.7 9.0 +/-20 ft. Heavy Oil/water UG MB1 4,760 8.4 8.7 9.0 +/-20 ft. Heavy Oil/water UG_MB2 4,795 8.4 8.7 9.0 +/-20 ft. Heavy Oil/water UG_MC 4,850 8.4 8.7 9.0 +/-20 ft. Heavy Oil/water NA 4,950 8.4 8.7 9.0 +/-30 ft. Viscous Oil NB 4,975 8.4 8.7 9.0 +/-30 ft. Viscous Oil NC 5,000 8.4 8.7 9.0 +/-30 ft. Viscous Oil OA 5,075 8.0 8.6 8.8 +/-30 ft. Viscous Oil OBA 5,110 8.0 8.6 8.8 +/-30 ft. Viscous Oil OBD 5,235 8.0 8.6 8.8 +/-30 ft. Viscous Oil OBF 5,315 8.4 8.6 9.2 +/-30 ft. Viscous Oil Top CM3 (BASE oBF) 5,360 8.4 9.0 9.2 +/-30 ft. Water/Gas Cut Mud CM2 (slumped) 6,380 8.4 9.2 9.5 +/-150ft. Water/Gas Cut Mud CM1 6,435 9.6 10.0 10.1 +/-150 ft. Water/Gas Cut Mud THRZ 6,750 9.6 10.0 10.1 +/-50 ft. Gas Cut Mud TKLB 6,780 9.6 10.0 10.1 +/-30 ft. Gas Cut Mud TKUP (TKC4) 6,785 8.0 9.2 11.5 +/-30 ft. Oil TKC3E 6,795 8.0 9.2 11.5 +/-30 ft. Oil TKC3A 6,800 8.0 9.2 11.5 +/-30 ft. Oil TKC2E 6,815 8.0 9.2 11.5 +/-30 ft. Water TKC2D 6,835 8.0 9.2 11.5 +/-30 ft. Water TKC2C 6,845 8.0 9.2 11.5 +/-30 ft. Water TKC26 6,860 8.0 9.2 11.5 +/-30 ft. Water TKC2A 6,875 8.0 9.2 11.5 +/-30 ft. Water TKC1C 6,885 8.0 9.2 11.5 +/-30 ft. Water TKC16 6,910 8.0 9.2 11.5 +/-30 ft. Water TKC1A 6,930 8.0 9.2 11.5 +/-30 ft. Water LCU (TKB1) 6,940 9.2 9.9 9.9 +/-30 ft. Water TD 7,004 9.2 9.9 9.9 +/-30 ft. Water TKA6* 7,005 9.2 9.9 9.9 +/-30 ft. Water TKAS* 7,010 9.2 9.9 9.9 +/-30 ft. Water S-04A PTD 3 6/22/2015 Casing/Tubing Program Hole Size Liner / Tbg O.D. Wt/Ft Grade Conn Length Top MD / TVDss Bottom MD / TVDss 8-1/2" T' 26# 13Cr / L-80 VamTop HC 7,690' 2,600' / 2,525' 10,290' / 7,004' (150' lap) Tubing 4'Y2" 12.6# 13Cr-85 VamTop 9,786' Surface 9,786' / 6,680' Mud Program Production Mud Properties: LSND 8-1/2" Hole Section Depth Interval Density PV (cp) Ib/00ft2 1 API FL HTHP FL MBT pH 2,750' - 9,300' 9.0 - 9.5 . <17 18-25 <8 N/C <18 9 - 10 9,300' - 10,290' 10.0 - 10.5 . <18 17-22 <4 <10 <20 9 - 10 Logging Program 8-112" Intermediate Sample Catchers - as required by Geology Drilling: Dir/GR/RES/NEU/DENS Open Hole: None Cased Hole: Cement Bond Log Injector Cement Program Casing Size T' 26# L-80 'Top Production Line r Lead Open hole volume + 40% excess Basis Lead TOC Target 500 ft MD above Schrader Bluff DPZ -6,315 MD Tail Open hole volume + 40% excess + 80 ft shoe track Tail TOC 500 - 1,000 ft MD above casing shoe Spacer -50 bbls of Viscosified Spacer weighted to -11.0 pp Mud Push II Total Cement Lead 97.7 bbls, 548.5 cuft, 315 sks of 11.5 ppg LiteCRETE, Yield: 1.74 cuft/sk Volume Tail 50.5 bbls, 283 cult, 242 sks 15.8 lb/gal Class G - 1.16 cuft/sk Temp BHST 158° F Surface and Anti -Collision Issues Surface Close Proximity: No wells will be affected by the Parker 273 rig shadow Sub -Surface Pressure Management: Verify cretaceous pressure 1 month prior to spud. Plan to shut-in S-124 two weeks prior to spud of S- 04A. Ensure no MI injection into S-124 six months prior to spud. Anti -Collision: The following wellbores fail major risk. A deep set tubing tail plug will be set prior to drilling S-04A. S-25 - P&A'd in 1998 due to sidetrack. S-25A - A deep set tubing tail plug will be set prior to drilling S-04A. S-25AP131 - P&A due to sidetrack y S-24 - P&A'd 1999 due to sidetrack. S-24A/S-24B - Effectively the same wellbore as S-24B was a CTD sidetrack that drilled out of the S-24A shoe. A deep set tubing tail plug will be set prior to drilling out S-04A. S-04A PTD 4 6/22/2015 Hydrogen Sulfide S-Pad is considered an H2S site. Recent HAS data from the Dad is as follows - Well Name H2S Level Date of Reading #1 Closest SHL Well H2S Level S-26 12 ppm 1/29/2015 #2 Closest SHL Well H2S Level S-21 59 ppm 1/14/2015 #1 Closest BHL Well H2S Level S-105 26 ppm 1/25/2015 #2 Closest BHL Well 1-12S Level S-121 60 ppm 3/2/2014 #3 Closest BHL Well H2S Level S-108 12 ppm 5/29/2011 #4 Closest BHL Well 1-12S Level S-109 20 ppm 1/19/2015 Max Recorded H2S on Pad/Facility S-201 180 ppm 3/9/2012 Faults There are no prognosed fault crossings for WP 5c. 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. Well Control The 8-1/2" hole section 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 4,000 psi except for the annular preventer which will be tested to 3,500 psi. BOP test frequency for S-04A 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. 8-1/2" Intermediate Interval Maximum anticipated BHP 3,505 psi at the TKB1 at 6,940' TVDss (9.9 ppg EMW) Maximum surface pressure 2,825 psi at the TKB1 (0.10 psi/ft gas gradient to surface) 25 bbls with 12.9 ppg frac gradient. Kick tolerance Assumes 9.9 ppg pore pressure in the KUP + 0.5 ppg kick intensity and 10.5 ppg MW. Planned BOP test pressure Rams test to 4,000 psi / 250 psi. Annular test to 3,500 psi / 250 psi Integrity Test — 8-1/2" hole No LOT will be performed after milling the 9-5/8" window. The original 13-3/8" LOT was 14.0 ppg equivalent. 7" Casing Test 4,000 psi surface pressure S-04A PTD 5 6/22/2015 Drill and Complete Operations Summary Current Condition and Well History 1. Pull Plug at 8624' MD. D&T TD. 2. Injectivity Test. 3. Fullbore P&A. -22 bbls of 15.8 ppg class G cement. Planned TOC at 8606' MD. 4. D&T TOC. Drift for Tubing Punch. 5. A/SL: CMIT-TxIA 2500 psi. 6. Tubing Punch at 9500' MD. 7. Circulate Cement Plug into TBG & IA -190 bbls of 15.8 Class G. TOC --6000' (length -2400' MD) 8. D&T Cement. Drift for Jet Cut 9. A/SL: CMIT-TxIA 2500 psi. 10. Jet Cut TBG-3000'. Planned KOP is-2750'. 11. Bleed T/I/O to 0 psi 12. Install Dry Hole Tree. Install Annulus Valves. Set TWC and test from above and below. 13. Remove the well house. 14. Level the pad and prepare location for the rig. Rig Operations 1. MIRU Parker 273. ' 2. Test TWC from below to 3,500 psi for 30 minutes. 3. Nipple down tree. Nipple up and test BOPE to 3,500 psi. ✓ 4. Pull TWC with lubricator. 5. RU hard lines to BOP. Circulate out diesel freeze protection through choke to tiger tank with clean 8.5 ppg seawater. 6. RU and pull the 4-1/2" tubing from the pre -rig jet cut at-3,000' MD. 7. RIH with 9-5/8" clean out assembly. 8. RU E-line w/ GR/CCL log and set EZSV at -2,766' MD and pressure test to 3,500 psi for 30 min (chart test). 9. PU 9-5/8" whipstock, bottom trip anchor and 8.5" window milling assembly (to include full gauge string mills) and RIH to the top of the EZSV and orient and set the whipstock. 10. Swap the well over to 9.4 ppg LSND based milling fluid. 11. Mill window in the 9-5/8' casing. 12. POOH for drilling BHA. 13. MU 8-1/2" motor assembly drilling BHA, with GR/RES/PWD, UBHO (Gyro) and RIH. 14. Kick off and drill ahead to end of the build section of the 8-1/2" hole (-4,368' MD) 15. Circulate the well clean and POOH. 16. MU 8-1/2" PDC bit and RSS drilling BHA, GR/RES/NEU/DEN/PWD and RIH. 17. Drill 8-1/2" intermediate interval to section TD at --10,290' MD weighting -up the drilling fluid using spike fluid maintaining the following density ranges: a. KOP - TCM2: 9.0 - 9.5 ppg b. TCM2 - TD: 10.0 - 10.5 ppg 18. Circulate and condition the hole at TD, wiper trip as needed and TOH to run the 7" casing. 19. Change upper VBR pipe rams to 7" casing rams and test to 250 psi low / 4,000 psi high. 20. Run and cement 7", 26#, combination 13CR & L-80, VAM TOP HC casing to TD. S-04A PTD 6 6/22/2015 21. Change upper 7" casing rams to VBR pipe rams and test to 250 psi low / 4,000 psi high. 22. MU cleanout BHA with SonicScope and RIH 23. Clean out as needed. Once on bottom displace well to 8.5 ppg seawater. 24. POOH while logging to verify TOC as per AOGCC requirements. 25. R/U and run a 4-'h", 13.5#, 13CR, VAMTOP tubing completion with GLM's. 26. Make up tubing hanger per Cameron Rep. Land the tubing hanger, and run in lock down screws. 27. Reverse circulate filtered 8.5 ppg brine and corrosion inhibitor into the tubing x casing annulus. 28. Drop ball/rod and set packer and individually test the tubing to 4,000 psi for 30 minutes. 29. Bleed tubing pressure to 2,000 psi and pressure test the IA to 250 psi low / 4,000 psi high for 5 minutes low / 30 minutes high. 30. Hold pressure on the IA and bleed tubing pressure to zero, shearing the DCK shear valve. Pump both ways to confirm circulation ability. 31. With landing joint still rigged up, reverse circulate diesel freeze protect using rig injection pump 32. Allow diesel to U-tube, drain stack, and rig down landing joint. Monitor well for 1 hour to confirm well is dead. 33. Install TWC and test from above and below to 250 psi low / 4,000 psi high for 5 minutes each. . 34. Nipple down the BOPE. Nipple up the adaptor flange and double master valves and test to 5,000 psi with diesel. 35. Ensure "Heet" is left on top of the TWC and only diesel (no water) is left in the tree. 36. Install all annulus valves and secure the well. Ensure T/IA/OA all have two barriers in place. 37. RDMO. S-04A PTD 7 6/22/2015 S-04A Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE I. Well Control / Reservoir Pressures A. Production Hole: 8.6 — 9.2 ppg PP from KOP to Top CM2 — Mud weight specification 9.5 ppg 9.2 — 10 ppg PP from Top CM2 through Kuparuk Sands — Mud weight specification 10.5 ppg 11. Lost Circulation/Breathing A. Production Hole: There are no expected fault crossings in the production hole. However, breathing and/or lost circulation associated with excessive circulating pressures should be considered a possibility on this well. III. Fault Locations There are no prognosed fault crossings for WP 5c. IV. Integrity Testing Test Point Test Depth Test t e EMW (lb/gal) 9-5/8" Window No LOT will be performed LOT Original LOT achieved a 14 ppg MW equivalent V. Hydrogen Sulfide S-Pad is considered an H2S site. Recent H,S data from the Dad is as follows: Well Name H2S Level Date of Reading #1 Closest SHL Well H2S Level S-26 12 ppm 1/29/2015 #2 Closest SHL Well H2S Level S-21 59 ppm 1/14/2015 #1 Closest BHL Well H2S Level S-105 26 ppm 1/25/2015 #2 Closest BHL Well H2S Level S-121 60 ppm 3/2/2014 #3 Closest BHL Well H2S Level S-108 12 ppm 5/29/2011 #4 Closest BHL Well H2S Level S-109 20 ppm 1/19/2015 Max Recorded H2S on Pad/Facility S-201 180 ppm 3/9/2012 VI. Anti -Collision Issues The following wellbores fail major risk. A deep set tubing tail plug will be set prior to drilling S-04A. ➢ S-25 — P&A'd in 1998 due to sidetrack. S-25A — A deep set tubing tail plug will be set prior to drilling S-04A. w S-25APB1 — P&A due to sidetrack w S-24 — P&A'd 1999 due to sidetrack. v S-24A/S-24B — Effectively the same wellbore as S-24B was a CTD sidetrack that drilled out of the S-24A shoe. A deep set tubing tail plug will be set prior to drilling out S-04A. CONSULT THE S-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. S-04A PTD 8 6/22/2015 TREE = 6" Can/ WELLHEAD= &tEVOY ACTUATOR = BAKER C KB. ELEV = 74-W BF,E.EV = 3820" KOP = 4850' Max Angle = 25' @ 70W Datum MD = 9193' Datum TVD = 8800' SS 13-3/8" CSG, 72#, L-80, D=12.347 I-1 2680' S —O SAFE • r NOTES: H2S READINGS AVERAGE 125 ppm WHEN ON MI. WELL REQUIRES A SSSV WHEN ON Mi. © 218V 4-1/2" OT S X NP, D = 3.813" I-E:��' 9-s/8 DV PK R GAS LIFT MANDRELS STI MD I TVD DEV TYPE VLV I LATCHI PORT DATE 11 1 13007 13006 1 1 MMG DMY I RK 1 0 11 /02/09 Minimum ID = 2.31'• @ 8624' 4-1/2" X 2-7/8" NIP REDUCER 8590• 41/2" HESXNP, D=3.813" 8606' 9 5/8" X 41/2' BAKERS 3 RCR 8624' 41/2" HES X tNP, D = 3.813" 8624' 2-7/8" X NP R®UCB?, D = 2.31" (02/18/10) 8624' 2-7/8" XX t3lJG (02/13/12) 5-1 /2" TBG, 17#, L-80 PC, .0232 bpf, D = 4.892" 8654' 8649' 865T 9 5/8" X 4-1/2' UNIQUE MACE# E OVER SHOT 8684• TBG SEAL ASSY 8707' 9-5/8" X 4-1/2' BROWN PKR D 8760' 41/2" HES X NP, D = 3.813- TOP OF 7" LNR 1-1 8762' 4-112' TBG, 12.6#, L-80, .0152 bpf, D = 3.958" 883T 9-5/8" CSG, 47#, L-80, ID= 8.681" 9013' PERFORATION SL*A WRY RE LOG: BHCS 08/05/83 ANGLE AT TOP PE3RF: 19` @ 9028' Note: Refer to Production DB for historical pert data SIZE SPFJ INTERVAL Opn/Sqz SHOT SOZ 3-3/8" 6 9028 - 9070 O 02/02/89 2-7/8" 4 9180 - 9190 O 03/12t84 3-3/8" 6 9190 - 9210 O 03/12/84 2-7/8" 4 9210 - 9220 O 03/12/84 3-3/8' 6 9220 - 9240 O 03/12/84 2-7/8' 4 9240 - 9250 O 03/12/84 3-3/8" 6 9250 - 9270 O 03112/84 2-7/8" 4 9270 - 9304 O 03112/84 2-7/8" 4 9318 - 9334 O 03/12/84 PBTD 952V 7" TBG, 26#, L-80, .0383 bpf, ID = 6.276" 9575• 8i 799'—14-1/2" I$ XN NP, D = 3.725" 8844' �MD TT LOGGED 02/17/95 9166• H MA RKET2 JOr,T 9521 " H FISH PERF GUN 33.7" DATE REV BY COMMENTS DATE REV BY COMMENTS 08/09/83 ORIGINAL COMPLETION 04/23/15 DJS/ PJC PULL BKR PATCH 08/08/99 JRR LAST WORKOVER 05/11/15 OS/ PJC TBG CORRECTON 03/20/10 KJB/SV SET PATCH (03118/10) 01/18/12 TMWJMD ADDED H2S SAFETY NOTE 02/15/12 TP/JMD TREEC/O(02/11/12) 02/15/12 1 MSS/JMDI SEr 2-7/8" XX PLUG (02/13/12) FRUDF10E BAY L T WELL: S-04 PE RhTf No:'1830790 AR No: 50-029-20959-00 Sec_ 35, T12R T12E, 1633 FTL 8 1085' FWL BP Exploration (Alaska) TREE= 6"aW WELLHEAD= M:EVOY ACTUATOR = BAKER C KB. ELEV = 74.00' BF. ELEV = 38.20 KOP = 4859 Max Angie = 25° @ 7009 Datum MD = 9193' Datu m TV D = 8800' SS 1 13-3/8" CSG, 72#, L-80, D=12.347 I 26W 4-1/2" Tubing Jet Cut-3,000' Top of Plug #2 H-6,000' Top Of Plug #1 Minimum ID = 2.31" @ 8624' 4-1/2" X 2-7/8" NIP REDUCER 5-1 /2' TBG, 17#, L-80 FC, .0232 bpf, D = 4.892" 1—I 8654' OF 7" LNR I —I 8762' 4-1/2" TBG, 12.6#, L-80, _0152 bpf, D= 3.958" I 8837" 9-5/8" CSG, 47#, L-80, D = 8.681' 9013' PERFORATION SUMMARY Rff LOG: BHCS 08/05/83 ANGLE AT TOP PEFF: 19" @ 9028' Note: Refer to Production DB for historical pert data SIZE SPFj INTERVAL Opn/Sqz SHOT SQZ 3-3/8" 6 9028 - 9070 O 02/02/89 2-7/8" 4 9180 - 9190 O 03112/84 3-3/8" 6 9190 - 9210 O 03112/84 2-7/8" 4 9210 - 9220 O 03/12/84 3 3/8" 6 9220 9240 O 03/12/84 2-7/8" 4 9240 - 9250 O 03/12/84 3-3/8" 6 9250 - 9270 O 03/12/84 2-7/8" 4 9270 - 9304 O 03/12184 2-7/8" 4 9318 - 9334 O 03/12/84 PBTD 952V 7" TBG, 26#, L-80, _0383 bpf, ID = 6.276" 9575' S —O SAFE.. f NOTES: H2S READINGS AVERAGE 125 ppm WHEN ON MI. WELL REQUIRES A SSSV WHEN ON MI_ © 2181' 4-1/2" OTIS X NIP, D= 3.813" 2590' 9-518 DV PKR GAS LIFT MANDRELS STI MD I TVO I DEV I TYPE VLV LATCHI PORT I DATE 1 13007130061 1 1 M IG JDMIYJ RK I 0 11/02/09 • ` � 8590' 4-1t2" HES X NP, D = 3.813" . 8606' 9-5/8" X 4-1I2" BAKER S-3 PKR ®k 8624' 41 /2" HES X NP D = 3.813" 8624• 2-7/8" X NIP RM)CER D = 2.31" (02/1 all0) ° • ' °. 8624' 2-7l8" XX PLUG (02l13/12) 865T 9 5/8" X 4-112" UNIQUE MACHINE OVER SHOT ° 8684' TBG SEAL ASSY g. 870T 9-5/8" X 4-1/2" BROWN PKR, D = 3.958" 8760' 4-1/2" HES X NP, D = 3.813" 8799' 41l2" HE5 XN NP, D = 3.725" 0. 8844' ELMD TT LOGGED 02l17l95 r •.a " r r • " • ' • `r. 9166' MARKER JOI tT r' 9521" --� H PERF GUN 33.7" DATE REV BY COMMENTS DATE REV BY COM EWS 08/09183 ORIGINAL COMPLETION 04/23✓15 DJS/ PJC PILL BKR PATCH 08/08/99 JRR LAST WORKOVER 05/11/15 OS/ PJC TBG CORRECTON 03/20/10 KJB/SV SET PATCH (03118/10) 01/18112 TM 1JMD ADDED WS SAFETY NOTE 02/15/12 TRJMD I TREL CIO (02/11/12) 02/15/12 MISSMMIJ SET 2-718" XX PLUG (02/13/12) PRUDHOE BAY UNIT WELL: S-04 PERMIT No: '1830790 API No: 50-029-20959-00 Sec_ 35, T12K T12E, 1633' FNL 8 1085' FWL BP Exploration (Alaska) = 6" CIW WELLHEAD= McEVOY ACTUATOR = BAKER KB. ELEV = 74.00' BF. ELEV = 38.29 KOP = 4850' Max Angle = 25" @ 70W Datum MD = 91937 DatumTVD= 8800'SS V -04A Proposal SAFE. NOTES: H2S READINGS AVERAGE 125 ppm WHEN ON Mi. WELL REQUIRES A SSSV WHEN ON MI_ j 13-3/8" CSG, 72#, L-80, ID=12.347 —j 2680 9-5/8" WHIPSTOCK 9-5/8" CSG, 47#, L-80, ID = 8.681" � 9-5/8" EZSV, (_/_/ ) -276& Planned TOC �-1-5,700' 17" LNR, 26#, L-80 VAM TOP HC, .0383 BPF, ID = 6.276" F- -9 600' 7" X 5"BKR ZXPN LTP, ID = — -9,730' P-1/2" TBG, 12.6#, 13CR-85 VAM TOP, .0152 bpf, ID = 3.958" 1 PHFORATION SUMMARY REF LOG: ON ANGLE AT TOPPERF: _' @ Note: Refer to Production DB for historical pert data SIZE SFF NTERVAL Opn/Sgz SHOT SOZ 17" LNR, 26#, 13 Cr VAM TOP HC, .0383 BPF ID = 6.276" �—J_1 2590' H 9-5/8 DV PKR 4-1/2" HES X NIP, ID = 3.813" 9-5/8" X 7" HES TNT PKR, ID = " GAS LIFT MANDRELS ST KU TVID DEV TYPE V LV LATCH PORT DATE 4 3 2 1 4-1/2" HES X NIP, ID = 3.813" 4-1/2" HES X NIP, ID = 3.813" 4-1/2" HES XN NIP, ID = 3.725" F 4-1/2" WLEG, ID = 3.958" 1 PBTD DATE REV BY COMMENTS DATE REV BY COMMENTS 08/09/83 ORIGINAL COMPLETION 04/23/15 WS/ PJC PILL BKR PATCH 08108/99 JRR LAST WORKOVER 05/11/15 OS/ PJC TBG CORRECTON 03/20/10 KJB/SV SET PATCH (03/18/10) 01/18/12 TMWJMD ADDED H2S SAFETY NOTE 1021151121 TPVJMD I TREE CIO (02/11/12) 02/15/12 1 MSS/J SET 2-718" XX PLUG (02113112) PRUDHOE BAY UNIT WELL: S-04 PERMIT No: "1830790 AR No: 50-029-20959-00 Sec. 35, T12K T12E, 1633 FNL & 1085' FWL BP Exploration (Alaska) r- O CL NNW f.6 c.i d O _ c � a O a) CL O L a U) a CD a _ h m . m � N • m J J J O m r U) (A m N 7 ° rG O p C Z m m C N > > H L) No 7a s E c m Q o m m m M• d r a m E �Fws• O r �N °orn °' r o u g z x r o a rn r _E fio �fLODm °r)NX1°o Norm r°OC3 00mror°� L Y O L 2 .. C L m m m 0 C a ` f O t G Cal m O A C 0 C m y 0 A 0 j E 'pf E R O Co 32 C m L C pttQQyyyJJ m m A« a m m o C O W m C ro LL C m C m Z .fm. m c m m r& m m m n m CO O Km j Q m m m fq m m m O m U- U o C O m U V U m mC) fo m o m o m m m o > �c� co>> co��c�Eo �z�� a O m m _ tL (V m M m O 7 m = M O Q O O C h O m r N Q m m V n C CL >O (-TL w C N U3 N Q O O m O mN O ¢ N U N fr) N N f!) N fD m 0 0 D_ M Q N • m 0 N Q Q C CV C ti N O T moo_ 2a'7 m o m i°mmm m a fn m a froi tQ n Z z z o o N E o O O C A w ) Q N O C p1 i Y W O C W m .. . J 2 m o O U) E 0 G 9 O LL r R e rm 13 -j Oa O m Z C x O c c 9 0 r .. o >, >• Q 5 0 o m Q L O O 9 N O. Y m o- C O Op u m 2 O O O. 0 7-. 0 j 0 O K UIL N3COQ N(n FCI JJUU' � OF C n � W pa L Y i r W � I' Z C i o w_ > > og i N Z If (n O F C O ^ f F � E f ° If C C C E E 0 C C c Y M r O N N h m m O} N m Q Q N m o (n M m f n m N r N O) M r N m m O a) r ry p •l NNN N � � c7 !� N R LLJ n N O O m fp m N 0 V O N ffl ' D u)fn fo m fn fn in fn fn mr nm o NCti Mp. fn m Qh r o Np V N N ry N N N CV N N N CV N N M M Cti M M M M Q Q �} Q ffl f° m nmmm)m mrnm)mm mrn rnfnm rnarnm)rn fn fnrn�m rnmm) o mfo com f�0mmfo fn fo fo fo �� mfC m�fo i0 fo fn fo m mfo fo V NQO m NQh OQ OCV mn O cl c? ` O NNMQ cmn m N Cn Cn m N n M� m M � m Q ., p ffJ N m M M A fT 0 0 0 m M N m m a o M fn N Q N f0 1� O^ f0 N f7 D m r n r r n D m m Cm m m m Cpp Om0 W W mmj m o o O .N. N N m M p v fiQ'J COO fD n O)CnO O) mmT mm mOmoo Op Op0 c, p0 wwm rnrn rrrrn rrrmm mmmmm com mm n uQ1i umi °)f°D) f°n)fon)m)fmn fon) umi °f umi uo'iN fm°)Ofmm)rn fnmrnm)t0 mmmm) u) h f0 fn � M m r r T p m M M O m O r M f p Q f 0 f 0 Q f b M m N N M fn r m M fn N m 0 0 N M Q 4n f[) f0 n r p V N N N N N NNN M M, M M M Q � Q �} Q Q Q Q of V Q Q f �fn fn p o r r r r r r r r n n r r n n n r r r n n r n p 5 2 2 � 2 2m(tmm z0,m=a w Z W Z W Cm=a:M =WW 0 f n f n Q M f VImm m m M r m Q 2 n MMMQ Cn Cn q)Nm o q oW M cq 19 nN fV V mmpp� vm^gym mfCj t(lOQ Mfrj M Ch NNNN V M fN+I f•Nj M m o � r m O m Off) r f p m n N O N C V N M O �q ,cl 910 mm CDm00fq eDMpM Lq cc! NQ Qm D tp fn ftj m h Q O m .-- m 0p voi Q fmn fc" o o6N w m K r° �N m (no N ��O M mmn N N N N N h V M f n p m Q r n m r O t o O N � O C ry m e t M N r N ^ z m m cc! � m {p � C> fp fn M M mr O lD fV pm m p N O (n p m Q m M iQln^N mClfpnm (Ip�mm m�}ra}Q fnO(nNN OINO N ry M O m O m M fp m p Q O r to n m Q p N N NM M Q Q f O f C) m m n i N N r N n m O ) ONfmr m�{mm m(DQfO Nt•mj NO� •'�O�Q �Nfnj J_ N fD fp m C N N fm+I f0 mN r' NN MC>M Qh��m rn^ r m m fo n N m f N N V f N m m O- h m m M � fm Q f Q f) > m m C° m m N O m m •. fm n O m N b N CD N m M N f0 O fn N rp rioifri6. m m6mm mi lo. wf me . Mvoq�.- w�f.� Q m m m m m �} C n f n f n r m m m N p M f p m m M h m Q m -nnnn rm�mo NNMQ u)mmmr nw.m , oo� J NNN N N NNN M M f M M M M f.) M M M M M M f M Q Q Q > Q M p N O p r n m p O � M m p Q p � M m m O m O m o ) N N p N N C n p mn Q C p V O N p f p O . O m h o M m h p > m N O N m f 0^ Q N ( n i f jvmw N ONO Q J m m p 0 O O m) O m m n ry N m M m Q n 0 m m p ] m m r n "" N m 0 N N M Q f[) N f() m n r m fn m m J NNN N N NNN M M f`> M M M M MMM M M M M Cmj M M M M m ff) fm N Q M N O m Cp m n m b. N f") m m fD m 0 0 m 1 fnMM M Q(np(D OryMNMCn Q,r (np N Nm0 M vmfp m m N N N ry N N N N N N M N N N J N M M M M N N m m I n m M m N m M f () m N m •-- m r 0 ) vI Q Q. Q r (n , O N 0) to n 'T m N O p Cn p m m Q °) fO M Q r r O N N N N V n m m m O O Q m •- fn O m m m O N Q m 0 6 N N N N M Cy M M M Q Q ff) f° f f° m b ) O O n 0 O O f r) O O O ry 0 0 0 O p O ry O O O O r 0 O ry f p ) O m f• j m O O .; O O 0 0 0 0 0 O f p 0 0 0 O O O f C j 0 O m 0 f n m m m O O e t 0 0 O m) O O O O h O C ry O O O O e} O O m m) n nnn m(np 0 NryMQfn mmrrm mO��N MMM U U O O O d j dL t r Z ' numiMM N v v fti v H m C/) U U) U) > j WZ� to ay I C 7 Y � ( O 2 LL n W I' 07 � 2 U C I( W 7 f N r i o ( Fr 0 u E c Q mrb I I ch rOrrnO OOOmO Omaf rna) mmmc7 n c`] c")N OC J-t9 ofOOIT of MN�bm q V Ncn 10 V N cn OOf my of rM YOi c7�Ar;^ In Q NAQ h�Oirn •p n�-r oc mor rm bO Ncnm �Nr mm O)OCOOO ^ NNO ?Inbm J O O^ N N N M I a ^ N N N M N'^^ ^' Q^^ '^ P^^ ^ P Q Q ] O 0 0 0 0 0 O O O O O � cN0 (Np cN0 cND � b cN0 cNp b cND N � cN0 cN0 cN0 cNp � b fN0 b 0 N tN0 N b rN0 N tND b rND N b IND fN0 YR aJ NN c] (")mmN O mO mrnrn QQpNN Oc)0 mmnbb QN Nm )m 1` N1` V r`N r\<y (") Nr u].-'- mNOOb cc]O Dcb V) IIm? V O rn rnb fp IA (V Oi Oi m O r O m Oi N r\ m R •uJ H2 r�c�]c`]b v Orroo mo In uJ ml.mmrn N^^co �—N 'N m _o NN nJv mr` m crJb corm mrn000 00000 N NN N N N N N N N N N I V Q Q Q Q Q C O c c J I o u' o o I n l n h b) O c c J I n c 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 m m m m m m m m m m u"i u"i u°'i I°'n v"i h uc'i u°'i vrni v°'i vc'i umi h h h urni Irrni m u�'] u h h u h h uc'i v°'i m i h mh h(ri (r) 1f1 h If)� h ([ih bbm u'i m ctj ccjh hhu]crj� hYihh I[i h � NIn J O 0 0 0 0 0 QQQOQ O O O O O O O O O O O O O O O 0 0 0 0 0 O O O O O OOOOO 0000 O OO b b000 00 �00 OOOOO OO O, q i o o 0 0 0 Q 0 o Q 0 0 0 0 o m c] m N o 0 0 0 0 0 0 0 0 0 0 (=io O O o 0 7U) co ca U)rn cn co c/IU)co co V)c) J JJ JIn U)a)c) V)U)U)U)V] U) Cl) U)U)UN 7 u)r7 _ _ _ _ _ _ _ M •- Q m m N e} c`J O Or m OJ cn A m try O m OJ of rn n b e OJ OJ N c'I ? ct) m m N c!) u] Q ct) m N O c`I b cn O m 0 of m R N m i V Oi Oi r; In W cj rj O cV o Oi m N ui r Oi r; O Oi c0 r` C6 nch cc]mmm0 Ic]mhc7 b mNbm� QmONN Nch c"J n]q V ICJbbr mof O)N ^ N N N N N N N N N N N N N N N N N N N N N N N Q Y a f ^ r m 0 c o ^� O c c] e Y m O Q m m N Q O b N ^ O N c `] m N R^ O N N b m r ] of O N�-m RUr m I I eq Ow cO OOrN bIPOa mr Inv r\Om i A �] R cE 01 C I N Q1 f�j ? r\ c'j of M rn N O O N f m V b Oi o N m o [p K ? cD r r m P^ OJ (7 r\ O h m OJ b (`l N m Q rn N C7 b b r\ m rn O) O N t7 b b f\ O N ch 0 naf O Nc�]c`] In crJ I m mrrmrn rn0^ N N N N N N c7�NQ NNNNN NNNN N vvQQQ QclJtcJO hhOOO bICJ hInb hb bud ] m u b b ON b m Inrn 0 z o rJb rn m m^ m O b r o c b m u N O n b m r •m NN V h rNc"r c0 thq O Ornmrm bcn@OJN OmrO h h 0 O r V N NNNNN N N c`J c`N') c�ln LLN] LLN']c �hc[m] h h h bh([mJ umf hhhh I[Njh cn h h h h O b U] b b b b h e7 M m N u] cn cn ct) O b Itl b uJ b cn cn cn cn m h b m b b b b b b b b b b b b b c7 N h m rn 'c7 m c7 m cn m r) m m m c`] m rn C] m m N c7 try m m t7 C) b m m m c�J m m ^ M r •t � c`J c'J b m Y] of rn a m � rn Q O ch M b b f` m rn rn rn N •t cn b Of N m w b m r r m m m m m m m m Of Of OJ OJ Of 0 0 0 bbmmm mmbbb bbmbb bbmbb bl�rr Jo 00000 0000 0 00- r0000 000.-O o0000 doom O 00000 OOOO O OO IQ mm O? 0000 OO N O 00000 OOO N io uio ouio ui oui (ri o oLo vmoo Lo uioo^^ ui ci o ui ui 000� •b aln lnro r` M b mc) NQUJmm ao� (n]v nQo Y eY sY e{ e} e{ t() b to to b, m m m m m b b b b b m tmp b b cmp (mp (mp (mp b m r0 ) b b b b b b m b m m b b b c 0 m m m m b m b b b m b b b b b b b b m m m c N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N > O 0 0 0 0 0 0 0 0 0 O O O o Q Q Q 0 0 0 0 O O o 0 0 O O O O O 0 0 0 0 r c n m c? 0 0 0 0 0 0 9 0 0 0 0 0 0 0 0 0 0 0 i N 0 0 0 0 0 0 0 o o 0 o o 0 0 bhp �b hb bbbLoh Lo� ] O V Om mOJ ct) V n]rJ r00 OOm c`J �- my 00 m a� c[)af N m of QQ • c `] m N m I� I� O c� O c r J h O< b O O O V O r� c n O m d; < N m�• c [) O o J O�� � cp f;O�hcO O�r`O ri riA NOCi Omtcj �-Oi �Nmcry cp f`cV tC Oih NI[jOO of aJ c`]c"IR ct)bm O NnJ Qu]m rrm OJ OJ of aJ rn OJ OJ 0000 .- N J CIJ In lobmb bbbr. r` amrnrnrn rnrnrngrn mmrnrna o0000 0000 \ UJ Q ~ LU a ) MC U m ^ F >` E �i�i iZiZ�Zi U�ODUU� ^m aNmCL NN0 N NNNN 2 c)c) : o c�C� C7 C�mmm mmmmmc=YY YYv_ Y YYYYY YYUo U � U �7n 000 Noc/)oo U UUU W 1-F-V- V-4-cnn V- 4-4-V-titi tiF_ JH U) m 0 by 0 Schiumbuger —1 0 500 1000 1500 2000 2500 3000 S-04A (P5c) ro 5500 5500 6 91 MD 766e rvD r 9993 MD 669] ND 5-130 T91 Kup .Ti 996a MD 6694 ND 5Q00 9738 MD 6— ND SQQQ Entl Cry Cry 3 5/160 9433 MD 6559 ND 4500 4500 4000 4000 3500 3500 0 3000 3000 A,2500 2500 u A, z 2000 2000 1500 1500 1000 1000 End Cry 4366 MD ND 500 500 Tne- 2716 MD 2] ND 13 1 C" Cry 3.111. 2— MD 2766 2690 MD 2 NO ND 0 Base Wvp—k 0 2766 MD 3766 rvD Top Wmp—k 2750 MD 2— ND S-04 0 500 1000 1500 2000 2500 3000 EW (ft) Scale = 1:800(ft) r7;-04A Well:Field: Structure: (P5b) S-04 Prudhoe Bay Unit - WOA S-PAD Gravity 8 Magnetic Parameters Surface Location NAD27 Alaska State Plane, Zone Od, US Fee[ Model: BGGM 2014 Dip: 81.007' Dale: 31-Dec-2015 Lat: N 70 21 12.97 Northing: 5979855RU5 Grid Conv: 0.912' jM,isellaneous Slot S-00 ND Rai: Rotary Table(83.65R strove MSL) Mag Dec: 18.799° FS: 57556.763nT Gravity FS: 1002.003mgn (9.80685 Based) Lon: W 149 1 56.02 Easting: 619267hUS Scale Fact: 0.99991615 Plan: $-04A (P5b) (Everton) Project: Prudhoe Bay Site: PB S Pad Well: S-04 -124/S r2q Wellbore: Plan S-04A � I I � I ' Design: Plan #5c S-04A 5950 a 66 M 5600 I I 3 64 4 1 /2" Spjp 5250 - - #S I i 9 6 s' I 48 li js 4900 58 8� j 56 y6/S_16 li 6 °' SE32/S 2A 943/S-4 L 4550 Cp - -- 40 4 4 m ^ ^ ^ 54 90 ^ p, SSA A 4200 38 S-1',OS/S-10 8 - $ 0 8 442 6 2 66 7 mom 50 m 4 a- $ 0 3850 48 C? GO 62 4 $ CI) \ c Q 6 40 a 46 49 9 0 d2 6 60 ? 3500 - � S/S 3 86 60 S"34,, 0 78 u 38 N 90 8 4 3150 + 7g g�i 6 e2 �j s 6 p�p�� 74 708 4 o s l 'o z 2800 708 - m Z 2 S 68 78 ) 6 Sa 4 -- 0 to 26i 7 Z;v "1i3O as �4 �p S `P4 �q SO p 2450 - -- �A - 1 8 6� S 64 T 2 3 6 6 8 6 ,8 Q� iJA m h w 6 q 62 66 l 2100 4 4-� 64 4 7 \3� 60 s 30 62 4 s p s, SO o 76 g6 60 8 L5/ S 7 Q 2 v Q5� SO rn N A 7 1750 i` S _S �i *1 0 o w o v 2 28 19 46 S 86 26 2 86 2 8 1400-i 4 4 8 2 0 y 26 4�'� S2 o 2 rn, rn� Q ,} 2 8 N N 1050 6 �a q Oo� �plv 70000 p� 00.0 - n TO ;350 r I � 7 e CV IV, r CI `r 0 Q m n® NII M o $ O5/ � -350 !�00��s �S 700 0 1050 v 1 0� Ile 1750 2100 2450 2800 W&TISMA 31150 3500 3850 4200 29 N/est(-)/East(+) (700 usft/in) p ��9Aa a� U, Project: Prudhoe Bay Site: PB S Pad _ ? 124/S_ pq/ 78 —( Well: S-04 Wellbore: Plan S 04A 1 $ 06 j 24 Design: Plan #5c S-04A 'ps s -°3 #,$ 34 76 S� I ! I I � 3 i i --- � >2�' 68 - 72 .10 2400 i 64 �� so 34 3 115-4 411S,4i R 2250 —_ 66 A15.9A 1 _ Sp0 � v Sp, 5 . 62 6 ' 2 48 �i I 66 Q 2100 j 64 d 1950 - \- �s 3 62 6 011 4r q8 v 30 60 S�Si S- v o 1800 14 SI 9 O 1650 - 60 w rn ! 8 D 28 q 88 1 q 8 54 o N $8 6 88 Q S 1500 $6 N 5e 26 \\ O ch 84 o'7 °6, 0 �... m $6 69 84 csO 1350 ; --- �6 $4 82 erg 6 48 li s? 8`° cPCc0 .± Z 24 8p -4 - 1200 — — - 1050--- 0 78 ' \ r'� ! 42 4 � 24 SO 861p/8-10q 900 42 v Sp V 2 �p/S o0 3 0 1 - 750 921 0 --- 6� 36 34ra 66 �� -"CS�- � 6 1 rn ° A 4 6' C, o 4 6 c� Y 82 600 p �— ai v v aD LO —CD - n c 450 20 6 4 — —��' 6 m c S 2 62 38 Q �p cni cocj q1 4 S 18 3 3 8 8 300ti o �J 76 O d 36 q 216 v 150 CO 8 v � d ry�5 5 8 ~ ly°2 0 w o, 01 0 mx r —cv u?g, w 1 2 ^ 9 co P A � -150 m tP 2 8 00 20 1 300 0 600 750 1 u� 900 �� > 1200 1350 1500 1650 1800 2y' i B 6 29Ae ps Ast(-)/East(+) (300 usft/in) N :-32/S-32A 2 �31S-�L1 ��i5-37AF Project: Prudhoe Bay �,P�� 3 Site: PB S Pad a1 Well: 5-04 _ Wellbore: Plan S-O4A _ _ 4�pi Design: Plan #5b S-O4A (S-130) N s_oaa cr q 3 m S• 1 4 800 — - + rymc C6 i I 70_ 750 700 — — — s ss °' 650 - — — i it 600 — v rn Q6 Ica 66 I COCOco _- ro 550 L1 A, 500 • a 4Q I S-3jq, 64 c C', ? 450 0 _D 400 Z 35062 � -- 3 0 U) 300 — - 70 - m oQ 60 I CO n 250 - 36 - c 4 I cij 31 , CO 200 Q - v' I I ' 150 - -- S 24/S 246 46 I ii I 100 _—. - � 2 5rr4 -, S211S2� i 50 2 4 3 R30 5 0 5 Y' �� 9� p 30 0A 1irto III SO .- UJ CrI -50 P U' Cn 4 _ s 129 OIS"20 6 2�S0E s �9' y 3 -100 -100 Tv✓�L -50 29�5 0 50 0 2jS21)50 200 250 00 350 O $ 6 7 450 `�9-5500 sO9 550 600 IR West( -)/East(+) (1OO1i�;, ft/in) po� 9 08 2 0 9 a _43S-43 P'--: Plan #5c S-04A (S-04/Plan S-04A) III I000 2000 300( �,o� 5c 6 COMPASS 5000.1 Build 61 6/16/2015 2:52 PM SOHIO ALASKA PETROLEUM COI-IPANY WELLHEAD LOCATION DATA 1) WELL S-4 2) Pad S . 3) ,dellhead Location 1633SNL 10851%TEL x = 619,247 y = 5,979,8S5 LAT. 70° 211 12.97" LONG. 1490 011 S4.01" N36° 071W GYRO West 4) Bearing of Gyro Marker N70° 241E GYRO East (True) 5) Local Benchmark Elevation 32.97 Ft. A ,SL 6) Top Edge of Cellar * 36.70 Ft. AI•,SL 7) Base Flange Elevation �L Z'n Ft. AMSL 8) Kelly Bushing Elevation 0 4z) Ft. A:-SL * Base Flange and Kelly Bushing NOT Installed This Date. NOTES, 1) Items 1 and 2 should be filled in by the Drilling Supervisor on the rig when a new well spuds in. 2) The surveyor should fill in Items 3, 4, 5 and 6. 3) The completed form should be returned to Drilling Dept. for distribution. 4) The bearing of the Gyro Marker is required as a True, not a Magnetic bearing. 5) Base Flange and Kelly Bushing Elevations measured by the Drilling Supervisor. CIRCULATION: District Field Engineer - 2 District Drilling Engineer/Drilling Engineer - 1 Slope - to Rig for Posting - 2 !.:ell Record Clerk, Geology - 1 ;:ell Files Engineering Associate, Drilling - Original Petroleum Engineering, SFO -1 Ellen �i. ,-,iller ^. o a ~�roF \\�Z1 •. v g'�H� i�~ • •I�e !�.•.• .. •.. N..•P. con Ltraen . --April- 20,-1982___-- C3te YEAR ELEVATION COMMENTS 2011 36.02' MARKED WITH YELLOW PAINT 2013 35.99' MARKED WITH YELLOW PAINT NOTES 1. VERTICAL DATUM IS BP MSL. 2. BASIS OF VERTICAL ELEVATION: MON S-4; ELEV. = 38.64' 3. BASE FLANGE ELEVATIONS ARE OBTAINED DURING A COMPREHENSIVE WELL -BORE SUBSIDENCE PROGRAM BASED ON LOCAL CONTROL CONFIRMED THROUGH STATIC SATELLITE OBSERVATIONS. onallims MANSER savm DATE: 6/17/15 no N FRB15 8FE S-F M8JOB NO : SCALE: NOT TO SCALE 04.- ---- ------ ---------- 11 -1- S PAD 0 VICINITY MAP N TS 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 OCTOBER 13, 2013. VAR WOA - S PAD SHEET: WELL 04 BASE FLANGE ELEVATIONS 1OF1 TREE= 6" MCEVOY WELLHEAD= IVbEVOY ACTUATOR = OTIS KB. ELEV = 74.00' BF. ELEV = 38.20' KOP = 4850' Max Angle = 25 a 7000' Datum MID 9193' Datum TVD = 8800' SS 13-3/8" CSG, 72#, L-80, ID=12.347 H 2680' Minimum ID = 3.725" @ 8799' 4-1/2" HES XN NIPPLE 1 5-1 /2" TBG, 17#, L-80 IPC, 0.0232 bpf, ID = 4.892" H 8654' S 04 I SAFETY NOTES Q 2181 —I412" OTIS X NIP, ID = 3.813" 57< 2590' 9-5/8 DV PKR GAS LIFT MANDRELS STI MD I TV I DEV I TYPE I VLV LATCH 8590' H 4-1 /2" HESX NIP, D = 3.813" 8600' H 0-5/8" X 4-1/2" BAKER S-3 PKR 8624'H 4-1 /2" HES X NIP, D = 3.813" 8649' 4-1/2" X 5-1/2" XO, ID = 3.958" 8657' HUNIQUEMACHINE O/S, ID=4.562" 8684' "TBGSEALASSY 8707' 9-5/8" BROWN PKR, ID= 3.958" 8760' 41 /2" HESX NIP, D = 3.813" TOP OF T' LNR $762' 8799' 4EXP, D25 14-12" TBG, 12.6#, L-80, 0.0152 bpf, ID= 3.958" I $$37' 9-5/8" CSG, 47#, L-80, ID = 8.681" 9013' PERFORATION SUMMARY REF LOG: BHCS 08/05/83 A NG LE AT TOP PERF: 19 @ 9028' Note: Refer to Production DB for historical oerf data SIZE SPF INTERVAL Opn/Sgz DATE 3-3/8" 6 9028-9070 O 02/02/89 2-7/8" 4 9180-9190 O 03/12/84 3-3/8" 6 9190-9210 O 03/12/84 2-7/8" 4 9210-9220 O 03/12/84 3-3/8" 6 9220-9240 O 03/12/84 2-7/8" 4 9240-9250 O 03/12/84 3-3/8" 6 9250-9270 O 03/12/84 2-7/8" 4 9270-9304 O 03/12/84 12-7/8"1 4 1 9318-9334 1 O 1 03/12/84 FSTD 5521' T' TBG, 26#, L-80, 0,0383 bpf, ID = 6.276" 9575' 8837' H BROWN IPC TBG TAIL, ID = 3.958" 8844' H ELMD TT LOGGED 02/17/95 9166' H MA RKER JOINT 9521" H33.7" P92FGUN DATE REV BY COMMENTS DATE REV BY COMMENTS 08/09/83 ORIGINAL COMPLETION 08/08/99 JRR LAST WORKOVER 03/07/01 SIS-MH CONVERTED TO CANVAS 03/12/01 SIS-MD FINAL 0921/01 RN/KAK CORRECTIONS PRUDHOEBAY UNIT WELL: S-04 PERMIT No: 83-0790 API No: 50-029-20959-00 Sec. 35, T12N, T12E BP Exploration (Alaska) Oilfield Services, Alaska Schlumberger Drilling & Measurements 6411 A Street Anchorage, AK 99518 Tel (907) 273-1700 Thursday June 18, 2015 Brad Gorham BP Exploration (Alaska) Inc. Schlumberger PBU WOA S-04A (P5c) Parker 273 Close Approach Analysis We have examined the potential intersections of the subject well with all other potentially conflicting wells, according to the BPA Directional Survey handbook (BPA-D-004) dated 09/99. Method of analysis: 1. A list of wells to be analyzed is created in Compass by performing a global scan with an initial search radius of two hundred feet with an increment of one hundred feet for every one thousand feet of measured depth in the subject well. 2. Wells are analyzed using the Compass Anti -collision module (BP Company setup) with major risk safety factors applied. 3. All depths are relative to the planned well profile. Survey Program: Please see BP anti -collision report Survey Interval Intermediate hole: 1 per stand — 93 ft - (except where doglegs exceed 5/100, then survey every 30 ft) Production hole: 1 per stand — 93 ft - (except where doglegs exceed 5/100, then survey every 30 ft) Close Approach Analysis results. - Under method (2), note: S-24/A/B and S-25/APB1/A fails the major risk. There are BP TCRW's in place to cover the exemption. Risk rule of 1:10 is being used, per the client. They pass these rules. There is potential to see magnetic interference from KOP of 2750'md to ±3450'md. A gyro single -shot will be run while drilling the KOP interval, due to near -by anti -collision reasons. All data documenting these procedures is available for inspection at the Drilling & Measurements Drilling Engineering Center (DEC). Close Approach Drilling Aids to be provided: A drilling map and traveling cylinder plot will be provided. Checked by: Scott DeLapp 06/18/2015 Company: North America - ALASKA- BP Project: Prudhoe Bay Reference Site: PB S Pad Site Error: 0.00usft Reference Well: 5-04 Well Error: 0.00usft Reference Wellbore Plan S-04A Reference Design: Plan #5c S-04A 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 5-04 S-04A plant @ 83.65usft (rigx) S-04A plant @ 83.65usft (rigx) True Minimum Curvature 1.00 sigma EDM R5K -Alaska PROD - ANCP1 Offset Datum Reference Plan #5b S-04A Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 5.00usft Error Model: ISCWSA Depth Range: 2,709.65 to 10,290.64usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,224.37usft Error Surface: Elliptical Conic Survey Tool Program Date 6/1612015 From To (usft) (usft) Survey (Wellbore) Tool Name Description 109.65 2,709.65 Survey 1 BOSS -GYRO (S-04) BOSS -GYRO Sperry -Sun BOSS gyro multishot 2,709.65 2,750.00 Plan #5b S-04A (Plan S-04A) BOSS -GYRO Sperry -Sun BOSS gyro multishot 2,750.00 3,450.00 Plan #5b S-04A (Plan S-04A) GYD-GC-SS Gyrodata gyro single shots 3,450.00 4,950.00 Plan #5b S-04A (Plan S-04A) MWD MWD - Standard 3,450.00 4,950.00 Plan #5b S-04A (Plan S-04A) MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal 4,950.00 5,450.00 Plan #5b S-04A (Plan S-04A) MWD MWD - Standard 3,450.00 5,450.00 Plan #5b S-04A (Plan S-04A) MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal 5,450.00 5,950.00 Plan #5b S-04A (Plan S-04A) MWD MWD - Standard 3,450.00 5,950.00 Plan #5b S-04A (Plan S-04A) MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal 5,950.00 6,450.00 Plan #5b S-04A (Plan S-04A) MWD MWD - Standard 3,450.00 6,450.00 Plan #5b S-04A (Plan S-04A) MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal 6,450.00 6,950.00 Plan #5b S-04A (Plan S-04A) MWD MWD - Standard 3,450.00 6,950.00 Plan #5b S-04A (Plan S-04A) MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal 6,950.00 7,450.00 Plan #5b S-04A (Plan S-04A) MWD MWD - Standard 3,450.00 7,450.00 Plan #5b S-04A (Plan S-04A) MIND+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal 7,450.00 7,950.00 Plan #5b S-04A (Plan S-04A) MWD MWD - Standard 3,450.00 7,950.00 Plan #5b S-04A (Plan S-04A) MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal 7,950.00 8,450.00 Plan #5b S-04A (Plan S-04A) MWD MWD - Standard 3,450.00 8,450.00 Plan #5b S-04A (Plan S-04A) MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal 8,450.00 8,950.00 Plan #5b S-04A (Plan S-04A) MWD MWD - Standard 3,450.00 8,950.00 Plan #5b S-04A (Plan S-04A) MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal 8,950.00 9,450.00 Plan #5b S-04A (Plan S-04A) MWD MWD - Standard 3,450.00 9,450.00 Plan #5b S-04A (Plan S-04A) MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal 9,450.00 9,990.00 Plan #5b S-04A(Plan S-04A) MWD MWD - Standard 3,450.00 9,990.00 Plan #5b S-04A (Plan S-04A) MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal 9,990.00 10,290.64 Plan #5b S-04A (Plan S-04A) MWD MWD - Standard 9,990.00 10,290.64 Plan #5b S-04A (Plan S-04A) MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal 611612015 3:12:16PM Page 2 of 6 COMPASS 5000.1 Build 61 Company: North America - ALASKA- BP Project: Prudhoe Bay Reference Site: PB S Pad Site Error: O.00usft Reference Well: 5-04 Well Error: O.00usft Reference Wellbore Plan S-04A Reference Design: Plan #5c S-04A Summary Site Name Offset Well - Wellbore - Design PB S Pad Plan S-136 (Arsenal) - Plan 5-136 - Plan #6b S-13 5-01 - S-01 - S-01 S-01 - 5-01 A- 5-01 A 5-01 - 5-01 B- 5-01 B S-01 - 5-01 C - S-01 C 5-02 - IGNORE ME - Plan 3 S-02 - IGNORE ME - S-02AL2 S-02 - S-02 - S-02 S-02 - S-02A- S-02A S-02 - S-02AL1 - S-02AL1 5-02 - S-02ALl PB1 - S-02ALl PB1 5-02 - S-02AP81 - S-02APB1 5-03 - 5-03 - 5-03 S-04 - 5-04 - S-04 5-05 - 5-05 - S-05 S-05 - S-05A - S-05A S-05 - S-05APB1 - S-05APB1 S-06 - S-06 - 5-06 5-07 - Plan S-07B RST - Plan #2 S-07B RST S-07 - S-07 - S-07 S-07 - S-07A- S-07A S-08 - 5-08 - S-08 S-08 - S-08A - S-08A 5-08 - S-08B - S-08B S-09 - 5-09 - 5-09 5-09 - S-09A - S-09A 5-09 - S-09APB1 - Plan #7 S-09A S-09 - S-09APB1 - S-09APB1 5-09 - S-09APB2 - S-09APB2 5-09 - S-09APB3 - S-09APB3 S-100 - 5-100 - 5-100 S-101 - 5-101 - 5-101 S-101-5-101PB1-5-101PB1 5-102 - 5-102 - 5-102 5-102 - 5-1021-1 - S-1021-1 S-102 - 5-10211 PB1 - 5-10211 PB 1 S-102 - 5-102PB1 - S-102PB1 S-103 - S-103 - 5-103 SA 05 - 5-105 - 5-105 S-106 - 5-106 - S-106 S-106 - 5-106PB1 - S-106PB1 S-107 - 5-107 - 5-107 S-108 - S-108 - 5-108 S-108 - S-108A` - 5-108A 5-109 - 5-109 - 5-109 S-109 - S-109PB1 - S-109PB1 S-110 - S-110 - S-110 5-110 - 5-110A - S-110A 5-110 - S-110B - S-110B 5-111 - S-111 - S-111 S-111 - 5-111 P B 1- 5-111 PB 1 S-111 - 5-111 P82 - S-111 PB2 C-119 - 5-11 9 - C-119 6/16/2015 3:12:16PM BP Anticollision Report Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Reference Offset Centre to Measured Measured Centre Depth Depth Distance (usft) (usft) (usft) Well S-04 S-04A plant @ 83.65usft (rigx) S-04A plan2 @ 83.65usft (rigx) True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum No -Go Allowable Distance Deviation (usft) from Plan (usft) 2,713.70 2,695.00 326.97 44.14 282.84 2,713.70 2,695.00 326.97 44.14 282.84 2,709.73 2,695.00 326.90 44.09 282.81 2,709.73 2,695.00 326.90 44.09 282.81 2,960.99 2,955.00 204.64 40.27 164.39 2,960.99 2,955.00 204.64 40.27 164.39 2,961.38 2,955.00 204.65 40.54 164.12 2,961.38 2,955.00 204.65 40.10 164.56 2,961.38 2,955.00 204.65 40.54 164.12 2,960.99 2,955.00 204.64 40.53 164.12 2,710.46 2,720.00 315.61 39.19 278.03 2,714.65 2,705.00 0.00 0.91 -0.91 2,757.13 2,750.00 111.03 42.45 68.58 2,753.94 2,740.00 110.96 42.39 68.58 2,753.94 2,740.00 110.96 42.39 68.58 3,020.95 3,005.00 211.36 43.03 168.38 2,709.65 2,805.00 663.31 72.70 607.26 2,709.65 2,790.00 664.34 72.80 608.27 2,709.65 2,790.00 664.34 72.80 608.27 3,396.81 3,380.00 420.64 54.06 367.71 3,396.81 3,380.00 420.64 54.06 367.71 3,396.81 3,380.00 420.64 54.06 367.71 3,397.09 3,395.00 533.17 52.78 481.58 4,049.50 3,910.00 512.20 57.93 454.62 4,049.50 3,910.00 512.20 57.99 454.56 4,049.50 3,910.00 512.20 57.93 454.62 4,049.50 3,910.00 512.20 57.93 454.62 4,049.50 3,910.00 512.20 57.93 454.62 4,899.99 4,375.00 667.97 93.78 577.32 4,623.47 4,145.00 853.67 82.11 779.68 4,623.47 4,145.00 853.67 82.11 779.68 6,230.83 5,580.00 1,184.85 257.03 957.58 Page 3 of 6 133.84 Warning Out of range Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Out of range Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk FAIL-NOERRORS Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Pass - Major Risk Out of range Pass - Major Risk Pass - Major Risk Out of range Pass - Major Risk Out of range Out of range Out of range Out of range Pass - Major Risk COMPASS 5000.1 Build 61 Company: NorthAmerica- ALASKA - BP Project: Prudhoe Bay Reference Site: PB S Pad Site Error: 0.00usft Reference Well: 5-04 Well Error: 0.0ousft Reference Wellbore Plan S-04A Reference Design: Plan #5c S-04A Summary Site Name Offset Well - Wellbore - Design PB S Pad S-113 - S-113 - 5-113 S-113 - 5-113A - S-113A 5-113 - 5-1138 - S-113B S-113 - 5-113C - 5-113C WP1 5-115 - S-115 - S-115 5-116 - 5-116 - S-116 5-116 - 5-116A - 5-116A S-116 - S-116APB1 - S-116APB1 S-116 - 5-116APB2 - 5-116APB2 S-117 - S-117 - S-117 S-118 - S-118 - S-118 5-119 - 5-119 - 5-119 S-120 - 5-120 - 5-120 S-121 - S-121 - S-121 5-121 - SA 21 PB1 - 5-121 PB1 5-122 - S-122 - 5-122 5-122 - S-122PB1 - S-122PB1 5-122 - 5-122PB2 - 5-122PB2 5-122 - 5-122PB3 - S-122PB3 S-123 - S-123 - S-123 5-124 - 5-124 - 5-124 S-125 - S-125 - 5-125 S-125 - S-125PB1 - S-125PB1 5-129 - Plan 5-129A future CST- Plan 5-129A fut 5-129 - S-129 - 5-129 S-129 - S-129PB1 - S-129PB1 5-129 - S-129PB2 - 5-129PB2 5-13 - S-13A - S-13A S-13 - S-13APB1 - S-13APB1 5-15 - 5-15 - 5-15 5-19 - 5-19 - S-19 5-20 - 5-20 - 5-20 5-20 - S-20A - S-20A 5-200 - S-200 - 5-200 5-200 - S-200PB1 - S-200PB1 5-201 - 5-201 - 5-201 S-201 - 5-201 PB1 - S-201 PB1 5-21 - 5-21 - 5-21 S-213 - 5-213 - 5-213 S-213 - 5-213A - S-213A 5-213 - S-213ALl - 5-213ALl S-213- 5-213ALl-01 - 5-213ALl-01 5-213 - 5-213AL2 - S-213AL2 5-213 - S-213AL3 - 5-213AL3 S-216 - 5-216 - 5-216 S-22 - S-22 - S-22 5-22 - S-22A- S-22A S-22 - S-22B - 5-228 S-23 - 5-23 - S-23 5-24 - 5-24 - 5-24 S-24 - S-24A - S-24A S-24 - S-24B - 5-248 S-25 - 5-25 - 5-25 BP Anticollision Report Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Reference Offset Centre to Measured Measured Centre Depth Depth Distance (usft) (usft) (usft) Well S-04 S-04A plant @ 83.65usft (rigx) S-04A plant @ 83.65usft (rigx) True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum No -Go Allowable Distance Deviation (usft) from Plan (usft) 2,711.87 3,055.00 1,030.43 51.60 984.60 2,711.87 3,055.00 1,030.43 52.35 983.89 2,711.87 3,055.00 1,030.43 51.92 984.32 2,711.87 3,055.00 1,030.43 51.92 984.32 2,711.53 2,845.00 1,130.06 46.61 1,086.15 2.709.65 2,930.00 824.72 44.57 782.40 2,712.96 2,730.00 501.48 40.06 462.72 2,711.86 2,710.00 167.37 37.41 130.80 2,711.86 2,710.00 167.37 37.41 130.80 2,711.86 2,710.00 167.37 37.41 130.80 2,736.44 2,745.00 997.01 39.07 957.96 2,736.44 2,745.00 997.01 39.07 957.96 2,936.47 2,975.00 517.49 40.20 477.32 2,909.48 2,900.00 260.10 43.08 217.02 2,828.29 2,820.00 154.43 47.75 106.73 2,828.29 2,820.00 154.43 47.75 106.73 2,710.24 2,710.00 928.89 42.80 891.35 2,710.24 2,710.00 928.89 42.80 891.35 2,872.34 2,855.00 78.83 40.83 38.00 2,982.25 2,935.00 754.49 42.06 712.58 3,095.25 3,060.00 754.94 44.40 710.66 3,095.25 3,060.00 754.94 44.40 710.66 3,095.25 3,060.00 754.94 44.40 710.66 3,095.25 3,060.00 754.94 44.40 710.66 3,095.25 3,060.00 754.94 44.40 710.66 2,710.53 3,065.00 650.03 61.99 594.53 2,889.43 2,875.00 297.90 37.94 259.96 2,889.43 2,875.00 297.90 37.94 259.96 2,889.43 2,875.00 297.90 37.94 259.96 2,815.45 2,795.00 150.21 36.27 113.97 2,861.97 2,845.00 29.34 5.55 23.81 2,770.19 2,750.00 30.98 4.97 26.01 2,770.19 2,750.00 30.98 4.97 26.01 2.712.69 2,695.00 33.61 5.65 27.96 Warning Out of range Out of range Out of range Out of range Out of range Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Pass - Major Risk Out of range Out of range Out of range Out of range Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Out of range Out of range Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Minor 1 /20 Pass - Minor 1 /20 Pass - Minor 1 /20 611612015 3,12:16PM Page 4 of 6 COMPASS 5000. 1 Build 61 BP Anticollision Report Company: North America - ALASKA- BP Local Co-ordinate Reference Project: Prudhoe Bay TVD Reference: Reference Site: PB S Pad MD Reference: Site Error: O.00usft North Reference: Reference Well: S-04 Survey Calculation Method: Well Error: O.00usft Output errors are at Reference Wellbore Plan S-04A Database: Reference Design: Plan #5c S-04A Offset TVD Reference: Well S-04 S-04A plan2 @ 83.65usft (rigx) S-04A plan2 @ 83.65usft (rigx) True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP I 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 S Pad S-25 - S-25A- S-25A 2,712.69 2,695.00 33.61 5.65 27.96 Pass - Minor 1/20 S-25 - S-25APB1 - S-25APB1 2,712.69 2,695.00 33.61 5.65 27.96 Pass - Minor 1/20 S-26 - S-26 - S-26 2,712.92 2,695.00 81.64 35.61 46,04 Pass - Major Risk S-27- S-27- S-27 3,032.62 3,015.00 134.91 39.27 95.72 Pass- Major Risk S-27 - S-27A- S-27A 3,032.62 3,015.00 134.91 39.27 95.72 Pass - Major Risk S-27- S-278 - S-27B 3,031.74 3,014.93 134.90 39.26 95.72 Pass- Major Risk S-28 - S-28 - S-28 3,077.36 3,070.00 171.91 43.06 128.86 Pass - Major Risk S-28 - S-28A - S-28A 3,073.15 3,065.00 171.81 42.96 128.86 Pass - Major Risk S-28 - S-28B - S-28B 3,073.92 3,065.00 171.82 42.98 128.86 Pass - Major Risk S-28 - S-28BPB1 - S-28BPB1 3,073.92 3,065.00 171.82 42.98 128.86 Pass - Major Risk S-29 - S-29 - S-29 2,709.65 2,770.00 566.38 52.89 514.09 Pass - Major Risk S-29 - S-29A- S-29A 2,709.65 2,775.00 566.37 52.78 514.19 Pass - Major Risk S-29 - S-29ALl - S-29AL1 2,709.65 2,775.00 566.37 53.04 513.92 Pass - Major Risk S-30- S-30 - S-30 2,717.95 2,700.00 287.12 39.76 247.38 Pass- Major Risk S-31 - S-31 - S-31 3,506.88 3,490.00 142.56 62.72 80.94 Pass - Major Risk S-31 - S-31 A - S-31 A 3,506.88 3,490.00 142.56 62.56 81.09 Pass - Major Risk S-32 - S-32- S-32 4,108.92 4,010.00 596.23 74.35 521.83 Pass- Major Risk S-32 - S-32A- S-32A 4,108.92 4,010.00 596.23 74.35 521.83 Pass- Major Risk S-33 - S-33 - S-33 3,405.40 3,405.00 432.15 44.79 387.65 Pass - Major Risk S-34 - S-34 - S-34 4,143.66 4,300.00 625.40 62.23 571.05 Pass - Major Risk S-35 - S-35 - S-35 5,148.26 4,765.00 423.74 104.73 320.63 Pass - Major Risk S-400 - S-400 - S-400 Out of range S-400 - S-400A - S-400A Out of range S-401 - S-401 - S-401 Out of range S-401 - S-401 PB1 - S-401 PB1 Out of range S-41 - S-41 - S-41 6,133.48 5,350.00 907.84 164.74 790.69 Pass - Major Risk S-41 - S-41 A - S-41 A 6,143.74 5,355.00 908.63 168.49 789.47 Pass - Major Risk S-41 - S-41 AL 1 - S-41 AL 1 6,143.74 5,355.00 908.63 168.48 789.47 Pass - Major Risk S-41 - S-41 L1 - S-41 Lt 6,133.48 5,350.00 907.84 164.76 790.68 Pass - Major Risk S-41 - S-41 PB 1 - S-41 PB1 6,133.48 5,350.00 907.84 164.74 790.69 Pass - Major Risk S-42 - S42 - S-42 4,000.00 3,980.00 428.38 51.96 377.80 Pass - Major Risk S-42 - S-42A- Plan #4b S-42A 4,450.26 4,430.00 96.63 74.50 42.83 Pass - Major Risk S-42 - S-42A- S-42A Out of range S42 - S42PB1 - S-42PB1 4,000.00 3,980.00 428.38 51.96 377.80 Pass - Major Risk S-43 - S-43 - S-43 4,172.88 4,025.00 160.77 70.74 96.30 Pass - Major Risk S-43 - S-431_1 - S-43L1 4,172.88 4,025.00 160.77 70.74 96.30 Pass - Major Risk S44 - Plan S44A - Plan #9 S44A 3,280.07 3,150.00 650.74 41.98 609.07 Pass - Major Risk S-44 - S-44 - S-44 3,911.58 3,800.00 496.30 49.61 446.69 Pass - Major Risk S-44 - S-44L1 - S-44L1 3,911.58 3,800.00 496.30 49.61 446.69 Pass - Major Risk S-44 - S-44L1 PB1 - S-441_1 PB1 3,911.58 3,800.00 496.30 49.61 446.69 Pass - Major Risk 6/16/2015 3:12:16PM Page 5 of 6 COMPASS 5000.1 Build 61 Redacted 9/1/2021 M. Guhl I ltr 10 IL C" EP -FMC PRUDHOE BAY DRILLING BIG BORE WELLHEAD SYSTEM -UT PRUDHOE BAY. ALASKA O O rl6-�OOC MD] 23' CV I` O O f 1 I 0-�000 -REE Wi 4 I;'!6-5000 WING O C7 r' r, O J fMCTmmo"iw „ate,.,,_ DM10002300� PARKER 273 BOP STACK RAM TYPE BOP: DUTCH LOCK DOWN FLANGE SHAFFER LXT DOUBLE BOP 13 5/8"-5M 13 5/8"-5M STUDDED TOP rrhl 13 5/8"-5M FLANGED BOTTOM 0 ANNULAR BOP: W/(2) 14" UL2 OPERATOR, UPPER CAVITY 0 SHAFFER LXT 5/8"-5M AND (2) 14" PSLK W/BSTR OPERATOR, LOWER CAVITY 13-5/8" 5M STUDDED TOP 0 13-5/8" 5M FLANGED BOTTOM 0 DRILLING CROSS: 13 5/8"-5M FLANGED TOP 13 5/8"-5M FLANGED BOTTOM W (2) 3 1/8"-5M SIDE OUTLETS 0 0 00 e e e 0 o es 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 o nwr o 0o si o o oo 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 TOP 8" 5M FLEX HOSE 13 5/8"— 5M FLANGED BOTTOM 3-1 / W/(2) 14" UL2 OPERATOR Davies, Stephen F (DOA) From: Gorham, Bradley M <Bradley.Gorham@bp.com> Sent: Wednesday, July 01, 2015 1:54 PM To: Davies, Stephen F (DOA) Cc: Loepp, Victoria T (DOA); Lastufka, Joseph N Subject: RE: PBU S-04A (PTD No. 215-111) - Concatenated Questions and Requests Steve, Please see the comments below in red. If you have any further questions or concerns please feel free to contact me. Thanks, Brad From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Tuesday, June 30, 2015 11:41 AM To: Gorham, Bradley M Cc: Loepp, Victoria T (DOA) Subject: FW: PBU S-04A (PTD No. 215-111) - Concatenated Questions and Requests Bradley, Let me gather all of my comments and questions into a single email so that you only have to respond to this one. 1. BP's planned redrill of existing well PBU S-04 targets the Kuparuk Formation rather than the underlying Sag River or Ivishak Formations. Wouldn't the proper pool for this well be the Aurora Oil Pool rather than the Prudhoe Bay Oil Pool as indicated on the Permit to Drill application? You are correct, the correct pool for this formation should be the Aurora Oil Pool. If so, to date nearly all of the wells drilled to, and completed in, the Aurora Oil Pool have been assigned well numbers that are in the 100 series (for example, PRUDHOE BAY UN AURO S-100, PRUDHOE BAY UN AURO S-110, PRUDHOE BAY UN AURO S-110A, with the well highest number currently being PRUDHOE BAY UN AURO S- 135). Consistent well numbering reduces potential for confusion and/or error. Would BP like to take this opportunity to re -number this proposed redrilled well accordingly so that it conforms to BP's past well numbering convention? Had this been a grassroots well, this well would have been given a well name in the 100 series as you suggested. However, this is a sidetrack and therefore we do not wish to change the numbering convention. Planned injection redrill PBU S-04A targets the Kuparuk Formation. The Area of Review map provided with the Permit to Drill application for PBU S-04A states that there are no Kuparuk well penetrations within the % mile circle of S-04A. In October 2013, the AOGCC approved a Permit to Drill application for well PBU S-130, a planned Aurora Pool (Kuparuk formation) WAG injection well. AOGCC subsequently re -issued this permit in February 2014 due to a change in planned surface and bottom -hole locations. The Permit to Drill for PBU S-130 is valid until October 28, 2015. The revised, proposed bottom -hole location for PBU S-130 lies about 700' west of the planned bottom -hole location for PBU S-04A. Does BP still plan to drill PBU S-130? No — S-04A will be replacing the target area previously planned for S-130. • If not, does BP wish to withdraw the approved Permit to Drill for PBU S-130? Yes, there is no longer a plan to drill S-130. I will get with Joe Lastufka and submit a formal notice to withdraw the S-130 PTD. • If so, will PBU S-130 and PBU S-04A conform to well spacing requirements set forth in Conservation Order No. 457E — Corrected? 3. The planned mud program appears adequate for BP's most likely estimated pore pressures; however, it is not adequate to mitigate BP's maximum expected pressures in the Kuparuk that are estimated at 11.5 ppg (see page 3 of the application). Will BP will have enough barite, CoCO3, or other agents on location to weight up the drilling mud sufficiently to mitigate BP's maximum anticipated pore pressure? BP's drilling rig always have access to enough weight agents to cover the maximum anticipated pore pressure if it is in fact encountered. 4. The present application for PBU S-04A doesn't discuss pre -production or well cleanup operations. Will planned injection well PBU S-04A be pre -produced for an extended period of time (30 days or longer) prior to being placed on regular injection, or will the well simply be flowed back for a short period to clean up perforations? No, the well will not be pre -produced for longer than 30 days. The well will be pre - produced for a short time period to clean up the perforations prior to being placed on injection. Thanks, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 CONFIDENTIALITY NOTICE. This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. TRANSMITTAL LETTER CHECKLIST WELL NAME: 4F 1, PTD: Development I/ Service _ Exploratory _ Stratigraphic Test Non -Conventional FIELD: POOL: Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit 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 samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, AURORA OIL - 640120 Well Name: PRUDHOE BAY UNIT S-04A Program SER Well bore seg ❑ PTD#: 2151110 Company BP EXPLORATION (ALASKA) INC Initial Class/Type SER / 1-OIL GeoArea 890 Unit 11650 On/Off Shore On Annular Disposal ❑ Administration 17 _Nonconven. gas conforms to AS31.05.0300.1 A),0.2.A-D) NA_ Appr Date SFD 7/10/201 Engineering Appr Date VTL 7/6/2015 5 35 Geology 36 Appr Date 37 SFD 6/30/2015 38 39 Permit fee attached NA- Lease.number appropriate - - - - - - - - - - Yes . Entire well lies within ADL 028257._ _Unique well name and number Yes - - - - - - - Well located in a defined pool Yes PRUDHOE BAY, AURORA OIL - 640120, governed by CO 457B_-_Corrected. Well located proper distance_ from drilling unit boundary_ - - - Yes Rule 1:-"Spacing units within the pool shall -be a minimum of 40 acres._ 20 AAC 25.055(a)(1). Well located proper distance from other wells_ Yes - - - - - - and_(2)-shall_ not apply to property lines within the external_ boundaries of the Aurora_ - - Sufficient acreage available in drilling unit_ Yes Participating Area." Well will conform to spacing requirements.. SFD 7/10/2015_ If_deviated, is_wellbore plat -included _ _ _ _ _ _ _ Yes ---------------------------------- Operator only affected party_ - - Yes Operator has appropriate_ bond in force Yes .Permit. can be issued without conservation order_ Yes . Permit can be issued -without administrative approval Yes - - - - - - - Can permit be approved before 15-day wait Yes _ - - - - - - - - - - .. . Welllocated within area and -strata authorized by Injection Order # (put_ 10# in comments) (For! Yes ....... AIO-22E--- - - - --------------------------------- All wells _within .1/4_mile_area-of review identified (For service well only) - - - - Yes Permit for PBU Aurora_S-130, 700' to west, withdrawn by BP._ SFD 7/10/2015 Pre -produced injector: dur_ation.of pre production less than 3 months_ (For -service well only) No - - - - - - Condu_ctor string_ provided NA_ Conductor set in PBU 5-04_ - Surface casing protects all -known- USDWs NA - - - - - Surface casing set in PBU S-04 - - - - - - - CM.T Vol adequate to circulate_on conductor_& su_rf_csg - - - - - M. . - - Surface casing set and fully cemented - - - - - - - - - - . - - CMT-vol adequate -to tie-in long string to -surf csg_ - - - - - - NA.. - CMTwill cover -all known -productive horizons_ - - - - - - - - Yes - . - - - Productive- interval will -be completed with cemented production_ liner -and perforated_ Casing designs adequate for C,_T, B &_ permafr_ost_ - - - - - - - - - Yes . - - - . Adequate _tankage _or reserve pit - - - - Yes - - - - Rig has steel tanks; all_waste-to approved disposal wells_ If_a_re-drill_, has_a 107403 for abandonment been approved - Yes _ _ _ _ _ _ _ PTD 183-079,_Sundry 315-404_ - Adequate wellbore separation -pro -posed- Yes - - - analysis complete; ajor risk failures S-25A, S-24A: will deep_ set TT plug prior to drilling_ - - - Anti-collisionm If_diverter required, does it meet_ regulations_ . .. NA_ Drilling fluid_ program schematic_& equip -list -adequate- Yes Max formation_ pressure is_3505 psi(9.9 ppg EMW); will drill w/ 9-10.5 ppg_ EMW_ _B_OPEs,_do they meet regulation - - - - - - - Yes _ BOPE_press rating appropriate; test to_(put psig in comments)_ - Yes MPSP is 2825 ps g,, will test BOPS to 4000_psi_ Choke manifold complies w/API_ RP-53 (May 84)_ - - - - - Yes Work will occur without operation shutdown_ - Yes - - Is presence of H2S gas_ probable_ Yes H2S measures required_ - - - Mechanical_condition of wells within AOR verified (For service well only) - - - - - - Yes AOR 1/4 mile conducted; no Kuparuk_penetrations within 1/4 _m_i radius - - - - - - - . . Permit_ can be issued w/o hydrogen. sulfide measures - - - - - - - No PBU S-Pad wells -are H2S-bearing. Per 20 AAC 25.065(b), H2S measures -are required.- -Data -presented on potential overpressure zones - - - - Yes Strata from CM1 through Kalubik are abnormally geo-pressured (>9.6_ppg), Planned mud program Seismic analysis of shallow gas -zones- - .. - - - - - - - - - . NA appears adequate for BP's most likely estimated pore pressures. - - - Seabed condition survey -(if off_ -shore) - - - - - NA_ Contact name/phone for weekly -progress reports- [exploratory only] - - - - - - - - - - - - - - - - NA_ Geologic Engineering Public Date: Date Date Commissioner: Commissioner: Commissioner om _71/� i� ����-�s
