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Home My WebLink About213-112Carlisle, Samantha J (DOA) From: Loepp, Victoria T (DOA) Sent: Tuesday, June 30, 2015 10:29 AM To: Carlisle, Samantha J (DOA) Subject: FW: Z-118 (PTD #213-112) Withdraw Please handle- Thanx, Victoria From: Lastufka, Joseph N[mailto:Joseph.LastufkaCcbbp.com] Sent: Tuesday, June 30, 2015 10:26 AM To: Loepp, Victoria T (DOA) Subject: Z-118 (PTD #213-112) Withdraw Victoria, Please withdraw the Permit to Drill for Z-118 (PTD #213-112). We will not be drilling this well within the 2 year timeframe. Please let me know if you have any questions. Thank you, Joe Lastufka Information and Data Controller Cell: (907) 227-84961 Office: (907) 564-4091 -------------------------------------------------------------------------------------------- w' BP Exploration Alaskal900 E. Benson Blvd. IRoom: 788DJAnchorage, AK -------------------------------------------------------------------------------------------- 1 THE STATE k1as11and Gzs amission OfA i, A 1`3 K A Lonservation Con 1 GOVERNOR SEAM PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276,7542 Ken Allen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Borealis Oil Pool, PBU Z-118 BP Exploration (Alaska), Inc. Permit No: 213-112 Surface Location: 4563' FSL, 3450' FEL, SEC. 19, T11N, R12E, UM Bottomhole Location: 3866' FSL, 3351' FWL, SEC. 17, TI IN, R12E, UM Dear Mr. Allen: Enclosed is the approved application for permit to drill 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 a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy P. oerster Chair DATED this day of September, 2013. STATE OF ALASKA RECEIVE[ ALASh_ . OIL AND GAS CONSERVATION COMMIS ON PERMIT TO DRILL 20 AAC 25.005 JUL 2 3 2013 1 a.Type of work: 1 b.Proposed Well Class: ❑ Development Oil Service - Winj • ®Single Zone 1 c. Specify if well is proposed for: P fY P P ® 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 Z-118 3. Address 6. Proposed Depth: 12. Field / Pool(s) P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 11404' TVD 7065' Prudhoe Bay / Borealis 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: ADL 028262 4563' FSL, 3450' FEL, Sec. 19, T11 N, R12E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 3760' FSL, 3209' FWL, Sec. 17, T11 N, R12E, UM September 20, 2013 9. Acres in Property: 14.Distance to Nearest Property: Total Depth 3866' FSL, 3351' FWL, Sec. 17, T11N, R12E, UM 2,k4V14000' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10.KB Elevation abo MSL: 101.15' feet Distance to Nearest Well Open Surface: x 599223 • y- 5959360 . Zone- ASP4 GL Elevati a MSL: 54. y - feet 115. to Same Pool: 1600' 16. Deviated Wells: Kickoff Depth: 300' feet 17. Maximu . ated Pressure n psig (see 20 AAC 25.035) Maximum Hole Angle: 66 degrees Downh 3432 Surface: 2758 18. Casing Program Specifications I IINP Setting Depth - ottom Quantity of Cement, c.f. or sacks Hole Casing Weight Grade Coupling Length TV TVD (including stage data) 20" 129# X-56 80' a Mae Surfac 34 134' 60 xs Arctic Set A rox. 12-1/4" 9-5/8" 40# L-80 BTC 4482' Surface 4482' 3076' 1864 sx Dee Crete 407 sx Class'G' 8-3/4" 7" 26# L-80 VamTop 11404' Surface Su a 404' 7065' 388 sx LiteCrete 98 sx Class'G' 19. PRESENT WELL CONDITION SU A o be ed for Redrill and Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): E ec pth MD (ft): Effective Depth TVD (ft): Junk (measured) 4. Casing Length Size Lkemkntvoiume MD TVD Conductor / Structural Surface Intermediate Production \ Liner f Perforation Depth MD (ft): Perforation Depth TVD (ft): 20.Attachments: ® Property Plat ®:BOP Sketch ® Drilling Program ❑ Time vs Depth Plot ❑ Shallow Hazard Analysis 0 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 Joshua Mallery, 564-5545 Email Joshua. Mallery@bp.com Printed Name Ken Allen Title Engineering Team Leader Signature '�~ Phone 564-4366 Date_ 3 Commission Use Only Permit To Drill „ / Z API Number: ,{ F •, (✓1Z-/ /5 S _6 % "C Permit Approval D e:/� See cover letter for Number: __L 50- 1 1 other requirements: Conditions of Approv I: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: Other: 7 —C 4-OCL7 S C Samples Req'd: El Yes UNo Mud Log Req'd: []'Yes El No 1Bto) D J/ JJf' I HzS Measures: []] Yes ❑I No Directional Survey Req'd: Q Yes ❑ No F� h/ P 1400 Spacing exception req'd: ❑ Yes 5/No inclination -only svy Req'd: ❑ Yes 0 No ,44 l 7 /tt / f� ►-ram( ct3 � ��— s fir % d 4 APPROVED BY APPROVED BY COMMISSIONER THE COMMISSION Date 13 yyyppp rr Submit Formch t Dcat� � Form 10-401 Revised 10/2012 This per it SHlit b21 i�1Q tl1 Afi�Lm the date of approval (20 AAC 25.005(g)) f/Z-P ,-7 /4 % 13 �i . jj To: Alaska Oil & Gas Conservation Commission From: Joshua Mallery, ODE Date: July 22, 2013 Re: Z-118 Permit to Drill The Z-118 well is scheduled to be drilled by Parker 273 in September 2013. The grassroots well is a WAG injector targeting the Kuparuk C sand. The planned well has two hole sections. Surface casing will be set in competent shale in the lower SV1 to isolate the permafrost/running gravels and hydrates. The production hole is planned as a casing string set below the Kuparuk formation in the Miluveach shale. The maximum anticipated surface pressure from the Kuparuk A sands with a full column of gas from TD to surface is -2758 psi (assumes 9.8 ppg KA4 as max pore pressure). This well will be drilled by Parker 273 using their 5000 psi four preventer BOP stack (3 rams and an annular preventer). The BOP rams will be tested to 4000 psi and annular preventer tested to 3500 psi. A detailed operations summary is included with the permit application. Below is a brief summary of planned drilling operations: 1. Move in Parker 273 and function test diverter. 2. Drill 12-1/4" surface hole to TD in the SV1 3. Run 9-5/8" surface casing and cement to surface. 4. Nipple down diverter and Nipple up BOPE and test. 5. Pressure test surface casing to 3500 psi. Drill out shoe and perform LOT. 6. Drill 8-3/4" production hole to TD in the Miluveach. 7. Run 7" casing and cement to above SB_Na Top. Pressure test casing to 4000 psi. 8. Run USIT/CBL to demonstrate cement isolation. 9. Run 4-1/2" L-80 completion tubing and set production packer. 10. Pressure test the tubing and the inner annulus to 4000 psi each. 11. Nipple down BOPE and Nipple up Tree and test 12. Rig down and move off the well. If there are any questions concerning information on Z-118, please do not hesitate to use the contact information below. Joshua Mallery Office: 907-564-5545 Cell: 907-227-2035 Email: Joshua.Mallery@_bp.com Attachments: Well Schematic Directional Plan Z-118 Conductor As-builts '/4 Mile Area of Review BOPE Equipment Schematics Diverter Line Layout Diagram Z-118 PTD Page 1 7/22/2013 Planned Well Summary Well Z-118 Well l WAG injector [Objective et Kuparuk C Current Status Grass Roots Well — Conductor Currently Installed Estimated Start Date: 09/20/2013 Time to Complete: 31 Days Surface Northing Easting Offsets TRS Location 5,959,360 599,233 4563' FSL / 3450' FEL T11 N R12E sec 19 Northing Easting TVDss Offsets TRS SB OA 5,962,470 603,740 -4597' 2332' FSL / 4160' FEL T11 N R12E sec 17 Tgt TKC4 5,963,927 ' 605,804 -6650' 3760' FSL / 2071' FEL T11 N R12E sec 17 BHL 5,964,035 605,945 -6964' 3866 FSL / 1928' FEL T11 N R12E sec 17 Planned KOP: 300' MD/199' TVDss Planned TD: 11,404' MD/6964' TVDss Ri Parker 273 BF-RT: 47' RTE (ref MSt_): 1 10 1. 15 Directional — Schlumberger P13b KOP: 300' MD Maximum Hole Angle: -r660 in the 8-3/4" Hole section Close Approach Wells: All offsets pass major risk analysis Survey Program: Surface to -900 ft MD = GYD-GC-SS (single shot gyro) or MWD+IFR+MS if clean surveys -900 ft MD to TD = MWD+IFR+MS Nearest Property Line: 14,000 ft Nearest Well within Pool: -1600 ft to Z-113 toe Z-118 PTD Page 2 7/22/2013 Formation Tops & Pore Pressure Estimate 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) G1 270 8.35 8.4 8.45 +/- 10 ft. Permafrost SV6 1,020 8.35 8.4 8.45 +/- 10 ft. Permafrost EOCU 1,605 8.35 8.4 8.45 +/- loft. Permafrost SV5 1,690 8.35 8.4 8.45 +/- loft. Permafrost BPRF 1,760 8.35 8.6 8.6 +/- 10 ft. Permafrost SV4 1,830 8.35 8.6 8.6 +/- 10 ft. Hydrates Fault #1 (HSF) 2,000 8.35 8.6 8.6 +J- 50 ft. Hydrates SV3 2,140 8.35 8.6 8.6 +/- 20 ft. Hydrates SV2 2,335 8.35 8.6 8.6 +/- 20 ft. Hydrates SV1 2,665 8.35 8.6 9 +/- 20 ft. Hydrates 9 5/8 surf csg 2,975 8.35 8.6 9 +/- 20 ft. UG4 3,015 8.35 8.7 8.8 +/- 20 ft. Coal UG4A 3,080 8.35 8.8 8.8 +/- 20 ft. Heavy oil UG3 3,420 8.35 8.8 8.8 Heavy oil Fault#2 (Zpad fit) 3,420 8.35 8.8 +/- 100 ft. UG1 3,870 8.35 8.7 8.8 +/- 30 ft. Heavy oil UG MA 4,180 8.35 8.8 8.8 +/- 30 ft. Heavy oil UG MB1 4,230 8.35 8.8 8.8 +/- 30 ft. Heavy oil UG MB2 4,290 8.35 8.8 8.8 +/- 30 ft. Heavy oil UG MC 4,350 8.35 8.8 8.8 +/- 30 ft. Heavy oil NA 4,430 8.4 8.7 8.7 +/- 30 ft. Wet NB 4,460 8.4 8.7 8.7 +/- 30 ft. Wet NC 4,500 8.4 8.7 8.7 +/- 30 ft. Wet NE 4,510 8.4 8.7 8.7 +/- 30 ft. Wet Fault #3 (small) 4,545 Wet NF 4,545 8.4 8.7 8.7 +/- 30 ft. Wet OA 4,595 8.4 8.7 8.7 +/- 30 ft. Oil OBA 4,665 8.4 8.7 8.7 +/- 30 ft. Oil OBB 4,690 8.4 8.7 8.7 +/- 30 ft. Oil OBC 4,735 8.4 8.7 8.7 +/- 30 ft. Oil OBD 4,790 8.4 8.7 8.7 +/- 30 ft. Oil OBE 4,860 8.4 8.7 8.7 +/- 30 ft. Oil OBF 4,900 8.4 8.7 8.7 +/- 30 ft. Oil OBF_BASE 4,955 8.45 8.7 8.7 +/- 30 ft. Oil Fault #4 5,165 +/- 100 ft. No CM2 5,275 8.45 8.7 8.7 +/- 40 ft. No CM1 5,910 9.4 9.4 10.2 +/- 40 ft. No TLBK 6,270 9.4 9.4 10.7 +/- 40 ft. No THRZ 6,440 9.4 9.4 10.3 +/- 30 ft. No TKLB 6,630 9.4 9.4 10.3 +/- 30 ft. No TKC4 6,650 6.4 9 10.4 +/- 30 ft. Oil TKC3E 6,670 6.4 9 10.4 +/- 30 ft. Oil TKC2A 6,670 6.4 9 10.4 +/- 30 ft. Oil TKC1C 6,675 6.4 9 10.4 +/- 30 ft. Oil TKB/LCU 6,680 8.45 9.6 10.4 +/- 30 ft. Oil TKA5 6,715 8.45 9.8 10.4 +/- 30 ft. Wet TKA4 6,735 8.45 9.8 10 Wet /D Z-118 PTD Page 3 7/22/2013 TMLV 6,765 9.6 9.8 10.3 TD 6,860 9.6 9.8 10.5 Casing/Tubing Program Hole Size Casing / Tbg O.D. Wt/Ft Grade Conn Length ft Top (ft) MD / TVDss Bottom (ft) MD / TVDss - 20" 129# X-56 - 80 Surface 134/33 12-1/4" 9-5/8" 40# L-80 BTC 4482 Surface 4482/2975 8-3/4" 7" 26# L-80 VaHCop 11404 Surface 11404/6964 Tubing 4'/2" 12.6# L-80 TCII 10880 Surface 10880/6511 Mud Program Surface Hole Mud Properties: Dril lex Spud Mud 1 12-1/4" Hole Section Depth Interval Density PV YP API FL Chlorides pH Funnel Viscosity ppg (cp) Ib/100 ftz ml130min mg/I sec/ t 0' — 4482' 8.8-9.4 30-50 40-80 15 <1000 10.8 N/A Injection Hole Mud Properties: LSND 1 8-3/4" hole section Depth Interval Density PV YP API FL HTHP FL MBT pH 4482'— 10097' 8.8-9.4 10 - 18 18 - 26 <8 NC <18 9 - 10 10097' — 10798' d 9.8-10.1 10 - 18 18 - 26 <8 NC <18 9 - 10 10798' - TD 10.1-10.4 10 - 18 18 - 26 <4 <10 <20 9 - 10 Logging Program 12-1/4"Surface: Sample Catchers - not required for surface hole Drilling: Dir/GR/Res e Open Hole: None Cased Hole: None 8 %" Production: Sample Catchers — as required by Geology Drilling.Dir/GR/Res/Neutron/Densit Open Hole: None Cased Hole: USIT/CBL Cement Program Casing Size 9-5/8" 40#, L-80 Surface Casing Lead: Open hole volume + 350% excess above BPRF, 40% excess below BPRF. Port collar Basis: used if hole conditions dictate Lead TOC: Surface Tail: Open hole volume + 40% excess + 80 ft shoe track Tail TOC: 1000 ft MD above casing shoe Total Cement Lead 614.2 bbls, 3449 cuft, 1864 sks of 11.0 ppg DeepCRETE, Yield: 1.85 ft3/sk Volume: Tail 84.2 bbls, 473 cult, 407 sks of 15.8 ppg Class G, Yield: 1.16 ft3/sk Z-118 PTD Page 4 7/22/2013 Casing Size 7" 26#, L-80 Production Casing Basis: Lead: Open hole volume + 30% excess Lead TOC: Target above the SB Na Tail: Open hole volume + 30% excess + 80 ft shoe track Tail TOC: 500' MD above casing shoe Total Cement Volume: Lead 121.2 bbls, 680 cult, 388 sks of 11.5 ppg LiteCRETE, Yield: 1.75 ft3/sk Tail 20.5 bbls, 115 cult, 98 sks of 15.8 ppg Class G, Yield: 1.17 ft3/sk Surface and Anti -Collision Issues Surface Shut-in Wells: Z-27, Z-116, Z-104, Z-114, Z-103, Z-118, and P-504A Require Shut-in to move Parker 273 over/off of Z- 118 well slot. To resume on production or injection while Parker 273 is conducting operations an ESD on the rig floor is required. Hydrogen Sulfide Z-Pad is considered an H2S site. Recent H2S data from the pad is as follows: v` Well Name H2S Level Readina Date comments well offline most of the time. H2S #1 Closest SHL Well H2S Level Z-27 16 ppm 6/29/2011 will likely be higher when well back online and retested. #2 Closest SHL Well H2S Level Z-29 5 ppm 3/23/2012 As high as 24 m in 2009 #1 Closest BHL Well H2S Level Z-113 12 ppm 5/10/2012 #2 Closest BHL Well H2S Level Z-100 120 ppm 1/25/2013 #3 Closest BHL Well 112S Level Z-108 20 ppm 12/31/2012 #4 Closest BHL Well H2S Level Z-112 44 ppm 2/7/2013 Max. Recorded H2S on Z-67 200 ppm 3/28/2012 retested at 80 Pad/Facility ppm on 5/5/12 Faults Formation Where Encounter Fault MD Intersect TVDss Intersect Throw Direction and Magnitude Uncertainty Lost Circ Potential Fault #1 (Highland State Fault) - SV4 2,310.0 2,000.0 SW; 170 ft. +/- 150 ft. MD Low Fault #2 (Z Pad Fault) - Ug3 5,425.0 3,420.0 West; 40 ft. +/- 100 ft. MD Low Fault #3 - Schrader OA 7,650.0 4,550.0 SW; 20 ft. +/- 100 ft. MD Low Fault #4 - CM2 8,770.0 5,165.0 SW; 60 ft. +/- 100 ft. MD Low 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. Z-118 PTD Page 5 7/22/2013 Well Control The 12-1/4" surface hole will be drilled with a diverter. (See attached diverter layout) The 8-3/4" section will be drilled with well control equipment consisting of 5,000 psi working pressure pipe 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 4000 psi (3500 psi Annular Test). BOP test frequency for Z-118 will be 14 days with function test every 7 days. Except in the event of a significant operational issue that may effect 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 3432 psi at @ TKA4 at 6,735' TVDss (9.8 ppg EMW) Maximum surface pressure 2758 psi (.10 psi/ft gas gradient to surface) 25 bbls with a 12 ppg frac gradient Kick tolerance Assumes a 0.5 ppg kick intensity over the anticipated 9.8 ppg pore pressure at interval TD with a 10.1 ppg MW. Planned BOP test pressure Rams test to 4000 psi/250 psi Annular test to 3500 si/250 psi Integrity Test — 8-3/4" hole LOT after drilling 20'-50' of new formation below previous shoe 7" Casing The upper VBRs will be changed to 7" rams to accommodate the 7" casing. Variance Request 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). 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 5 bbls has occurred. • The well will be monitored for flow when the pumps are off at each connection. • Over 50 surface holes have been drilled on Z-pad, providing a high level of confidence in the ability to drill surface hole on the pad without incident. • The planned 8.8 - 9.4 ppg fluid will provide over balance to formation fluid. Z-118 PTD Page 6 7/22/2013 Z-118 Drill and Complete Procedure Summary Pre -Rig Work: 1. Inspect Cellar Box and 20" conductor 2. Weld an FMC landing ring for the FMC Gen 5 wellhead on the conductor. 3. Z-27, Z-116, Z-104, Z-114, Z-103, Z-118, and P-504A required to be shut-in for Rig move. To resume production or injection while Parker 273 is conducting operations an ESD on the rig floor is required. 4. If necessary, level the pad and prepare location for rig move. Shut in nearby wells, bleed off process lines, and remove well houses as necessary. Rig Operations: 1. MIRU. Nipple up diverter spool and function test diverter. 2. Prepare pits with Drilplex Mud and PU 4" 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 TD in the SV1 utilizing gyro as necessary. Perform wiper trip at the base of permafrost. CBU and condition hole as necessary, then POOH for casing. 4. Run and cement 9-5/8" 40# BTC surface casing. A TAM port collar may be run at 500' as a contingency. 5. ND diverter and NU casing / tubing head. NU BOPE (Configured from top to bottom: annular preventer, 2-7/8" x 5-1/2" VBR, blind/shear, mud cross, 2-%" x 5-1/2" VBR). Test BOPE to 250 psi low, 4000psi high with 4" test joint. Give the AOGCC 24 hrs notice prior to testing. 6. Test 9-5/8" 40# BTC surface casing to 3500psi for 30 minutes 7. Make up 8-'/" drilling BHA with MWD/GR/RES/AZI-DEN/NEU/PWD and RIH to float collar. Drill out shoe track and displace to LSND drilling fluid. Drill 20' of new formation and perform LOT. 8. Drill to ± 200' above the CM1, and perform short trip as needed for ECD management. Prior to drilling ahead ensure mud is conditioned and properly weighted (10.1 ppg) for shale stability. 9. Drill ahead to target TD, (230' MD below top TMLV). Ensure LWD/MWD has logged entire Kuparuk formation before calling TD. Circulate and condition fluid. Back-ream/MAD Pass as required over Kuparuk and Schrader Sands, short trip to TD and then POOH on elevators to run casing. 10. Change 2-7/8" x 5-1/2" VBRs to 7" rams and test with 7" test joint to 250 psi low, 4000 psi high prior to running casing. 11. Run 7" production casing and cement. Displace with viscous pert pill followed by 10.2 ppg NaBr . Bring TOC above the Schrader. Bump plug and ensure that float holds. Pressure test casing to 4000 psi for 30 minutes. 12. Change 7" casing rams to 2-7/8" x 5-1/2" VBRs and test with 4-'/z" test joint to 250 psi low, 4000 psi high. 13. Freeze protect 7" x 9 %" annulus after cement reaches 500 psi compressive strength. 14. Perforate the well with —100' MD of 4-1/2" DPC guns. 15. RU SLB E-line. Run GR/Junk basket prior to USIT/CBL log from PBTD to Surface (AOGCC Injector Requirement) 16. Run 4-'/2" L-80 completion w/ 3 GLMs and land tubing hanger. RILDS. 17. Reverse circulate clean brine followed by corrosion inhibited brine for IA. Drop RHC ball and rod on rollers and set packer as per Halliburton recommendation and test tubing to 4000 psi and annulus to 4000 psi. Shear the DCK valve and pump both ways to confirm circulation ability. 18. Install and test TWC. Nipple down the BOPE. Nipple up and test double master valves to 5000 psi. RU DSM and pull TWC. 19. Freeze protect the well to 2000' TVD (base of permafrost is at 1760' TVDss) by pumping diesel down IA, taking clean brine returns to surface. Allow diesel to u-tube into tubing. 20. Install BPV in tubing hanger. Install all annulus valves and secure the well. Ensure that T/IA/OA have two barriers in place. RDMO. Z-118 PTD Page 7 7/22/2013 Post -Rig Work: 1. Install tree with electric valve. Pull BPV 2. Pull B&R. Set GLV design 3. Initial well flowback 4. Set dummy GLVs. 5. MIT -IA. Injectivity Test. 6. Survey of WH elevation. 7. Install wellhouse(s) and flowline(s). 8. Pump RG2401 (Blue -Goo) on top of surface casing cement Z-118 PTD Page 8 7/22/2013 Z-118 Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE I. Well Control / Reservoir Pressures: A. Surface Hole Over Burden: Normal pore pressures are expected throughout the surface hole drilling operations B. Production Hole Over Burden: Normal pore pressures are expected to range from 8.45 — 8.7 ppg ✓ through the Ugnu and Schrader down to the CM2. The Schrader sands are expected to be mostly wet with OA, and OB being oil bearing. Ugnu Sands may contain Heavy oil. The CM1 is over pressured at a most likely pore pressure of 9.4 ppg. C. Kuparuk Reservoir: The pore pressure in the Kuparuk C sands and A sands are anticipated to be over pressured at 9.0 ppg and 9.4 ppg respectively. However, the Kuparuk C sands are expected to be oil f bearing while the A sands are wet. II. Lost Circulation/Breathing A. Surface Hole: Lost circulation is considered a minimal risk if mud properties remain in specification. The highland state fault has been crossed in offset well at similar depths without issues. B. Production Hole: Breathing and/or lost circulation is a possibility due to 3 fault crossings. The Z pad fault has been penetrated in nearby well Z-116 without issues. Fault #3 has not been crossed before, but is expected to have a small offset. Fault #4 in the CM2 has not been crossed before and has a low potential for lost circulation. If lost circulation becomes a problem, follow the LCM decision tree provided in the drilling program. Utilize good hole cleaning practices to avoid high ECD and prevent pack -off potential which could induce breathing. III. Kick Tolerance/Integrity Testing A. With the planned mud weight, the kick tolerance is 25 bbls with a 12.0 ppg LOT in the production section. If planned LOT values are not achieved, do not drill ahead without risk assessment and proper authorization. All kick tolerances are calculated based on 0.5 ppg kick intensity over likely pore pressure. Test Point Test Depth Test type EMW Ib/ al) 9-%" Shoe 20'-50' from the 9-5/8" Shoe LOT 12.0 ppg minimum (25 bbls) 13.0 ppg target (50 bbls) IV. Hydrogen Sulfide A. As Z-Pad is considered an H2S site, refer to the ADW "Hydrogen Sulfide" SOP for the appropriate operational guidelines. The max recorded H2S readings on the pad were 200 ppm in Z-67 March 2012. V. Faults Formation Where Encounter Fault MD Intersect TVDss Intersect Throw Direction and Magnitude Uncertainty Lost Circ Potential Fault #1 (Highland State Fault) - SV4 2,310.0 2,000.0 SW; 170 ft. +/- 150 ft. MD Low Fault #2 (Z Pad Fault) - Ug3 5,425.0 3,420.0 West; 40 ft. +/- 100 ft. MD Low Fault #3 - Schrader OA 7,650.0 4,550.0 SW; 20 ft. +/- 100 ft. MD Low Fault #4 - CM2 8,770.0 5,165.0 SW; 60 ft. +/- 100 ft. MD Low VI. Anti -Collision Issues A. The closest wells to Z-118 are: Z-103 (13ft), Z-114 (31ft) at their closest points. All wells pass major risk criteria CONSULT THE Z-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. Z-118 PTD Page 9 7/22/2013 TREE= 4-1/16" WELLHEAD = FMC ACTUATOR = Bectric KB. ELEV = Z-118 Proposed DATE REV BY COM EWS DATE REV BY COMMBVTS 04/22/13 J6N Proposed (Dir P13) BOREALIS UW WELL: Z-118 PERMf No: API No: SEC19 T11 N R12E FSL 4563 FEL 3450' BP Exploration (Alaska) DATE Redacted by M. 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Schiumber,gerl PBU WOA Z-118 (P13b) 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 Tool Program Date 511012013 From To (usft) (usft) Survey (Wellbore) Tool Name Description 46.95 900.00 Plan #13b Z-118 (Plan Z-118 v6) GYD-GC-SS Gyrodata gyro single shots 900.00 2,400.00 Plan 913b Z-118 (Plan Z-118 v6) MWD MWD - Standard 900.00 4,480.00 Plan #13b Z-118 (Plan Z-118 v6) MWD+IFR+MS MWD + IFR + Multi Station 4,480.00 6,080.00 Plan #13b Z-118 (Plan Z-118 v6) MWD MWD - Standard 4,48000 11,403.70 Plan #13b Z-118 (Plan Z-118 v6) MVVD+IFR+MS MWD + IFR + Multi Station Survey Interval Surface hole: 1 per stand - 93 ft' Intermediate hole 1 per stand - 93 ft " Production hole: 1 per stand - 93 ft' " (except where planned or as -drilled doglegs are 5°/100' DLS or more; then survey every -30 ft across the interval, or when the client requests) Close Approach Analysis results: Under method (2), note: All wells pass Major risk 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 05/10/2013 0= ,19 38 ■ 37 ■ 35 ■ 67i ■ 10 ■ 9 ■ 8 ■ 7 ■ 6 ■ 112 ■ 104 ■ 3 ■ 2 ■ 1 ■ 39 ■ 11 ■ 12 ■ 13 ■ 14 ■ 15 ■ 16 ■ 17 ■ 18 ■ 46 ■ 19 ■ 20 ■ g •, V-PAD s, N — GRID �. .,SPINE RD ■ 33 +�JL' -PAD / 32 4� fly S� ,e VI ■ 31 Z-PAD ■ 30 29 X for THIS PROJECT 1 ). SPARE C SPARE B 103i P-504A ■ P-5048 ■ 21 ■ 22 ■ 23 ■ 24 ■ 25 ■ 26 ■ SLOT 1 ■ SLOT 2 ■ Z-100 ■ SLOT 4 ■ 101 'YYv YY \r\r Tr v V r 7 v v v T T v 7 7 7 y Y 7 r 7 TV Y RENAMED CONDUCTOR REVISION NOTE WELL: SPARE —A THIS AS -BUILT DRAWING IS A REISSUE OF A PREVIOUS AS -BUILT DRAWING FOR CONDUCTOR SPARE-D. RENAMED CONDUCTOR ARE AS FOLLOWS: OLD COND. NAME NEW COND. NAME SPARE —A Z-118i VICINITY MAP NTS 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 AUGUST 16, 2005. •EGEND AS -BUILT WELL CONDUCTOR RENAMED ■ EXISTING WELL CONDUCTOR NOTES: 1. REFERENCE FIELD BOOKS: W004-13, W004-16, W004-19. 2. DATES OF SURVEY: SEPT.. NOV. & DEC., 2004. 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. 4. PAD AVERAGE SCALE FACTOR IS 0.999911213. 5. HORIZONTAL CONTROL IS BASED ON Z PAD CONTROL MONUMENTS MON 2 AND MON 3. 6. ELEVATIONS ARE BPX MEAN SEA LEVEL (M.S.L.) DATUM. 7. VERTICAL CONTROL IS BASED ON Z PAD MONUMENTATION. 8. REFERENCE DRAWING FRB05 WOZ 02 FOR ORIGINAL CONDUCTOR RENAME. LOCATED WITHIN PROTRACTED SEC. 19, T. 11 N., R. 12 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. I OFFSETS Y=5,959,360.08 N= 2,081.91 70'17'54.271" 70.2984086' 4,563' FSL 118i X= 599,223.10 E= 2,130.09 149'11'47.212" 149.1964478' S4.2 3,450' FEL F. i$p bG= �-' -- bHE-KEo ALLISON 4 28/13 .......... ORAwNG gp p FR813 WOZ 03 WOA Z— PAD SHEET i assure � N0 -- RENAMED AS —BUILT CONDUCTORS 00 4 28 ISSUED FOR INFORMATON .0 RFA SCALE =zoo' WELL: Z-1181 1 of 1 NO. DATE REVISION BY CHK MgOIYR nnlu -T Q CD T 66 7 l CDO N O� r C) N O r_ LO r CD m r C) C) LO 'U) VJ ^Q cLL C O U ,Lo _ s s 19 m� 8 2b 9 bS 9 2 _m lBdL �b6 'LI N o r 8 88 9b (Pb bb 9b 9 p� 9S 89 OL O o /1� / C. �y rn S 09 b -- 9Vjlij N o I A 9k, S 09_ J,-,& a b 99 (9 08 O 8L 0 %o o /g 6 m S b 9 _ 9 0_S Z8 Llv6l 0 06 8 Z$ v6l 6 fit{LIV i ! c� 8 o m co N G b! 89 S� 0� - 09co m p� co 08 `�! ` 93 9! c? 9e "6' 06 8S _ a m O& all09 1 �'9 co 0 0 555 8 9 m 9 1 a 9 xoz. 99 cIj v��A �tE s 2� 34AA PBI JJYA34M 0 M g#, / h0 a� _'3AG n coo -3AP bra\� S t a44, CZ� o0 A�-rl 8Q Ste` F 9 Z o r 9 t`L c� �9s� sr �d� /Elt$ �o EL 8 2 2 � p6 U v + ` S� Y v9Z-P� , 201 8 = �' N oAl2 6 9L co W_ 0 l# upld/ (v 61�2 `� p 6 �b 4L �36J o A 9 `�b �� J61p�a� # A �oZL 1 cD o c � � m 2 2 A g 2 N ti Tc N Z 4 # d # i IZ-113PB v 6 p 2 m ro . "KNA 2 ° 0��6 All-vry A� o o 0 �1go Ify\ V, oW u o "c Yam'' c') N 0 (h c3Q d cat o $ o aoc N ,' ." r a co cv d n *e O c R (p co cn 1" 0 N ^ mo °' 6a , ^ `YO i� DeF a d' °° a v N d a cm" " M m 00 ;. .` �y a a,.. Z-60 T CO c0 N c,.o m Ny. rC,n m ao� o v m N cD O- (O o c�tn �N r �B ,' o m N i In In In N Qr M (O (O 47 r� ^ o m m _r_ y 2 co cd c0 cS7 � V� a.a,aaa Z-10/P n #8 oved 0 0 0 .. 4) 9 o 0 0 0 0 o 0 0 0 0 o o o 0 0 0 N o o 0 0 0 coo r (a (O L -It c'7 (7 N co om N (a (D r o 0 (n (u!/llsn 0030 (+)ulaoN/(-)4lnoS a a� o J6iQ� i�;[-9, �os� 11P\ .. Zz,- tiff . if - - ILE 1►. ♦ • Nib 61, 116 ♦. -4 G' a ON MIIMI fill ®��/ Wyk .' f � t`�• Aw mill • 00 00 cz N co •� ON ' U; #" - ds, N O � V9Z- cD v N 0 p o N N UO 117 (0a cc C ID 0 6 _1 -662-66 b O o oiaLO<Z. 2�OP�, ti v 0 o 3012�50 a 6 N N � � O 97 � N�t O! S C\, A 0 ti T 1'L1 6 co i R t 0 0 1� 1 Cl) Pia ^ .. v N C N O.. !O OQ O C N N t, Q o 0C O o r O 04 -- - co o j9 !� N m N z2�o- o o �� •- �o �. CIA + CD Y ON ti � 2 T-"�o o ry n- N O 0 s2j m� 0 s o ?a L m.' s 0 0 > o ° b °D 7 0 Q 0 OJ N ! CIO o — Z _00 TcN N N N ,. o a 'j Ccn d 0 C / 0 m aNaom o CL � 0 9 [ � ciCo a' 9 9 G 0� y n a �P �, N �P a IN� 'S"y �% j,✓ t 2 m N c2 A o aaaa- a- .. U o C. 0 o O o 0 0 0 o O O o 0 cn O u9 O N Clt!l L9 O In O LO O M C1 cm N N c? o �'N (ui/ldsn ooL) (+)43ao no N/(-)41 S � a a� p N V O N M n N O O N LO N O U) O N n 01 O O W C LO 00 U) O �17 CDLC)L O_ 0 LO n co N (z CD 0 m O v LO n M CD M N cp cc, Z CD LOO O to O Ln O to CD CD In O u'1 O In O n to w In In V M M CM (uiMsn 0G) uoileaedeS ailuao of ailuao � I O 1 'I N IIIVVV f0 a 0 M n N � � a IV a IV CD t Company: NorthAmerica-ALASKA - BP Project: Prudhoe Bay Reference Site: PB Z Pad Site Error: 0.00usft Reference Well: Plan Kup Z-118 (103+15) v6 Well Error: 0.00usft Reference Wellbore Plan Z-118 v6 Reference Design: Plan #13b Z-118 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 Plan Kup Z-118 (103+15) v6 Z-118 plan P273 @ 101.15usft (P273) Z-118 plan P273 @ 101.15usft (P273) True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCPt Offset Datum Reference Plan #13b Z-118 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval S.00usft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,335.68usft Error Surface: Elliptical Conic Survey Tool Program From (usft) 46.95 900.00 900.00 4,480.00 4,480.00 Date 5/10/2013 To (usft) Survey (Wellbore) 900.00 Plan #13b Z-118 (Plan Z-118 v6) 2,400.00 Plan #13b Z-118 (Plan Z-118 v6) 4,480.00 Plan #13b Z-118 (Plan Z-118 v6) 6,080.00 Plan #13b Z-118 (Plan Z-118 v6) 11,403.70 Plan #13b Z-118 (Plan Z-118 v6) Tool Name GYD-GC-SS MWD MWD+IFR+MS MWD MWD+IFR+MS Description Gyrodata gyro single shots MWD - Standard MWD + IFR + Multi Station MWD - Standard MWD + IFR + Multi Station 511012013 8:57:30AM Page 2 of 5 COMPASS 5000.1 Build 61 BP Anticollision Report Company: North America -ALASKA- BP Project: Prudhoe Bay Reference Site: PB Z Pad Site Error: 0.00usft Reference Well: Plan Kup Z-118 (103+15) v6 Well Error: 0.00usft Reference Wellbore Plan Z-118 v6 Reference Design: Plan #13b Z-118 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well Plan Kup Z-118 (103+15) v6 Z-118 plan P273 @ 101.15usft (P273) Z-118 plan P273 @ 101.15usft (P273) True Minimum Curvature 1.00 sigma EDM R5K-Alaska PROD -ANCPt 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 Z Pad Plan Kup Z-106 (27+30) v6 - Plan Z-106 - Plan #4 414.80 415.00 46.06 7.56 38.51 Pass - Major Risk Plan Kup Z-111 (29.5) v6 - Plan Z-111 - Plan #10 Z 440.57 425.00 163.68 8.01 155.66 Pass - Major Risk Plan Kup Z-114 (27+45) v6 - Plan Z-114 - Plan #21 434.15 435.00 31.12 7.93 23.19 Pass - Major Risk Plan Sch Z-201 (SO) v6.1 - Plan Z-201 - Plan #7 Z 9,088.47 8,700.00 742.39 228.30 611.63 Pass - Major Risk Plan Sch Z-202 (NO) v6.1 - Plan Z-202 - Plan #3 Z 7,573.28 7,915.00 506.14 175.27 364.02 Pass - Major Risk Plan Sch Z-203 (NB) v6.1 - Plan Z-203 - Plan #3 Z 2,449.87 2,305.00 233.06 61.03 189.39 Pass - Major Risk Plan Sch Z-212 (NL) v6.1 - Plan Z-212 - Plan #4 Z 2,929.46 2,470.00 512.12 66.76 465.64 Pass - Major Risk Plan Sch Z-213 (SJ) v6.1 - Plan Z-213 - Plan #4 Z 3,351.05 3,075.00 117.57 83.76 48.49 Pass - Major Risk Plan Sch Z-215 (NM) v6.1 - Plan Z-215 - Plan #3 Z 2,943.33 2,330.00 627.25 66.46 582.25 Pass - Major Risk Plan Sch Z-216 (NI) v6.1 - Plan Z-216 - Plan #3 Z- 2,591.39 2,190.00 546.90 55.22 506.24 Pass - Major Risk Plan Sch Z-217 (NN) v6 - Plan Z-217 - Plan #4 Z-2 3,538.80 2,835.00 613.13 89.72 556.34 Pass - Major Risk Z-100 - Z-100 - Z-100 1,607.89 1,540.00 333.20 29.11 304.33 Pass - Major Risk Z-101 - Z-101 - Z-101 1,687.52 1,655.00 52.88 41.92 16.33 Pass - Major Risk Z-102 - Z-102 - Z-102 389.10 370.00 91.82 7.76 84.06 Pass - Major Risk Z-102 - Z-102PB1 - Z-102PB1 389.10 370.00 91.82 7.76 84.06 Pass - Major Risk Z-103 - Z-103 - Z-103 457.87 440.00 12.76 7.46 5.32 Pass - Major Risk Z-103 - Z-103PB1 - Z-103PB1 457.87 440.00 12.76 7.46 5.32 Pass - Major Risk Z-103 - Z-103PB2 - Z-103PB2 457.87 440.00 12.76 7.46 5.32 Pass - Major Risk Z-113 - Z-113 - Z-113 3,132.42 2,780.00 138.92 71.57 88.29 Pass - Major Risk Z-1 13 - Z-1 1 3PB1 - Z-1 1 3PB1 3,132.42 2,780.00 138.92 71.57 88.29 Pass - Major Risk Z-115 - Z-115 - Z-115 2,769.97 2,505.00 173.39 57.51 129.67 Pass - Major Risk Z-116 - Z-116 - Z-116 471.65 460.00 53.74 8.69 45.07 Pass - Major Risk Z-116 - Z-116PB1 - Z-116PB1 471.65 460.00 53.74 8.69 45.07 Pass - Major Risk Z-116 - Z-116P82 - Z-116PB2 471.65 460.00 53.74 8.69 45.07 Pass - Major Risk Z-15 - Z-15 - Z-15 751.93 750.00 472.00 12.79 459.21 Pass - Major Risk Z-19 - Z-19 - Z-19 2,308.83 2,330.00 134.37 80.74 68.11 Pass - Major Risk Z-19 - Z-19A- Z-19A 2,308.38 2,325.00 134.44 80.71 68.11 Pass - Major Risk Z-21 - Z-21 - Z-21 1,001.79 985.00 140.96 17.96 123.00 Pass - Major Risk Z-21 - Z-21 A- Z-21 A 1,003.42 980.00 140.97 17.97 123.00 Pass - Major Risk Z-210 - Z-210 - Z-210 1,633.82 1,670.00 62.56 36.89 31.70 Pass - Major Risk Z-210 - Z-210PB1 - Z-210PB1 1,633.82 1,670.00 62.56 36.89 31.70 Pass - Major Risk Z-22 - Z-22 - Z-22 1,430.98 1,430.00 123.03 32.25 92.62 Pass - Major Risk Z-22 - Z-22A- Z-22A 1,432.69 1,430.00 123.06 32.47 92.46 Pass - Major Risk Z-22 - Z-22B - Z-22B 1,433.11 1,425.00 123.07 32.49 92.46 Pass - Major Risk Z-23 - Z-23 - Z-23 1,125.77 1,105.00 203.53 18.79 184.74 Pass - Major Risk Z-23 - Z-23A- Z-23A 1,126.44 1,095.00 203.55 18.96 184.58 Pass - Major Risk Z-23 - Z-23ALl - Z-23ALl 47.11 47.11 235.99 0.91 235.08 Pass - Major Risk Z-23 - Z-23B - Z-23B 1,126.42 1,095.00 203.55 18.96 184.58 Pass - Major Risk Z-24 - Z-24 - Z-24 1,262.75 1,235.00 234.91 22.45 212.48 Pass - Major Risk Z-25 - Z-25 - Z-25 1,316.78 1,285.00 265.47 26.79 238.69 Pass - Major Risk Z-26 - Z-26 - Z-26 1,431.72 1,390.00 294.75 26.98 267.81 Pass - Major Risk Z-26 - Z-26A - Z-26A 1,431.72 1,390.00 294.75 26.98 267.81 Pass - Major Risk Z-27 - Z-27 - Z-27 408.57 400.00 76.51 7.48 69.03 Pass - Major Risk Z-28 - Z-28 - Z-28 422.88 415.00 110.91 8.56 102.35 Pass - Major Risk Z-29 - Z-29 - Z-29 402.92 395.00 145.05 6.94 138.11 Pass - Major Risk Z-30 - Z-30 - Z-30 439.20 430.00 180.89 7.22 173.68 Pass - Major Risk Z-30 - Z-30A - Z-30A 443.12 425.00 180.96 7.44 173.52 Pass - Major Risk Z-31 - Z-31 - Z-31 469.27 465.00 216.33 8.25 208.08 Pass - Major Risk Z-32 - Plan Z-32C - Plan #7 Z-32C 454.91 460.00 251.03 8.28 242.75 Pass - Major Risk Z-32 - Z-32 - Z-32 458.64 455.00 251.12 8.37 242.75 Pass - Major Risk Z-32 - Z-32A - Z-32A 454.63 450.00 251.02 8.27 242.75 Pass - Major Risk Z-32 - Z-32B - Z-32B 455.00 445.00 251.03 8.28 242.75 Pass - Major Risk 511012013 8:57.30AM Page 3 of COMPASS 5000.1 Build 61 Company: North America-ALASKA-BP Project: Prudhoe Bay Reference Site: PB Z Pad Site Error: 0.00usft Reference Well: Plan Kup Z-118 (103+15) v6 Well Error: 0.0ousft Reference Wellbore Plan Z-118 v6 Reference Design: Plan #13b Z-118 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 Plan Kup Z-118 (103+15) v6 Z-118 plan P273 @ 101.15usft (P273) Z-118 plan P273 @ 101.15usft (P273) 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) PB Z Pad Z-32 - Z-32BPB1 - Z-32BPB1 455.00 445.00 251.03 8.28 242.75 Pass - Major Risk Z-32 - Z-32BPB2 - Z-328PB2 455.00 445.00 251.03 8.28 242.75 Pass - Major Risk Z-61 - Z-61 - Z-61 2,719.34 2,550.00 124.26 90.69 61.49 Pass - Major Risk Z-61 - Z-61 PB1 - Z-61 PB1 2,717.73 2,540.00 107.98 109.91 28.60 Pass - Major Risk 511012013 5 5730AM Page 4 of 5 COMPASS 5000.1 Build 61 :, .� � .. - �I -. Project: Prudhoe Bay Site: PB Z Pad Well: Plan Kup Z-118 (103+15) v6 Wellbore: Plan Z-118 v6 Design: Plan #13b Z-118 From 4400'md (9-5/8") to TD Scan enteral 25 ft Scale 1 inch : 50 ft All wells pass major risk 0 180 Azimuth from North [I vs Centre to Centre Separation [50 usft/in] From Colour To MD 47 500 900 1300 1700 2100 2500 2900 500 900 1300 1700 2100 2500 2900 3300 3700 4000 11405 90 PARKER 273 BOP STACK RAM TYPE BOP: SHAFFER LXT DOUBLE BOP 13 5/8"-5M 13 5/8"-5M STUDDED TOP 13 5/8"-5M FLANGED BOTTOM W/(2) 14" UL2 OPERATOR, UPPER CAVITY ° AND (2) 14" PSLK W/BSTR OPERATOR, LOWER CAVITY DUTCH LOCK DOWN FLANGE ANNULAR BOP: SHAFFER LXT 13 5/8"-5M 13-5/8" 5M STUDDED TOP 13-5/8" 5M FLANGED BOTTOM 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 0 o 11r o o ari 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 13 5/8"— 5M FLANGED BOTTOM 3-1/8" 5M FLEX HOSE W/(2) 14" UL2 OPERATOR 0 >1 co TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: L f / 1 Z Development /Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: POOL: , e'�2_ 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. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no Dry Ditch Sample greater 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 Commission 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 Well Logging logs are also required for this well: Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 5/2013 WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, BOREALIS OIL - 640130 Well Name: PRUDHOE BAY UN BORE Z-118 Program SER Well bore seg PTD#:2131120 Company BP EXPLORATION (ALASKA) INC Initial Class/Type SER / PEND GeoArea 890 Unit 11650 On/Off Shore On Annular Disposal Administration 1 Permit fee attached Yes 2 Lease number appropriate Yes Entire well in ADL 0282620. 3 Unique well name and number Yes 4 Well located in a defined pool Yes PRUDHOE BAY, PRUDHOE OIL POOL - 64015, governed by CO 341D 5 Well located proper distance from drilling unit boundary Yes CO 341 D, 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. 7 Sufficient acreage available in drilling unit Yes 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes 13 Can permit be approved before 15-day wait Yes SFD 8/6/2013 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For Yes Borealis Oil Pool is governed by AID 24A. 15 All wells within 1/4 mile area of review identified (For service well only) Yes None 16 Pre -produced injector: duration of pre -production less than 3 months (For service well only) Yes 17 Nonconven. gas conforms to AS31.05.0300.1.A),0.2.A-D) Yes 18 Conductor string provided Yes Conductor set to 134' Engineering 19 Surface casing protects all known USDWs Yes Surface casing set to 3076' TVD '20 CMT vol adequate to circulate on conductor & surf csg Yes 180% excess planned 21 CMT vol adequate to tie-in long string to surf csg No TOC 7500' MD 22 CMT will cover all known productive horizons Yes Production casing will be cemented 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; all wells pass major risk 27 If diverter required, does it meet regulations Yes Flow paddle waived <1000' per 20 AAC 25.0330) Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure is 3432 psi at 6735' TVD(9.8 ppg EMW); will drill w/ 8.8-10.4 ppg EMW VLF 9/4/2013 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MPSP is 2758 psi; BOPS will be tested to 4000 psi 31 Choke_ manifold complies w/API RP-53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S measures required 34 Mechanical condition of wells within AOR verified (For service well only) Yes AOR complete 35 Permit can be issued w/o hydrogen sulfide measures No Z-Pad wells are H2S-bearing. H2S measures are required. Geology 36 Data presented on potential overpressure zones Yes Expected reservoir pressure is 8.4 - 9.8 ppg EMW. Wellbore will be drilled using 8.8 - 10.4 mud. Appr Date 37 Seismic analysis of shallow gas zones NA SFD 8/6/2013 38 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly progress reports [exploratory only] NA Geologic Engineering Publi Commissioner: Date: Commissioner: Date C o r __ � s , -�-ramAcglvg