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213-150
Davies, Stephen F (DOA) From: Lastufka, Joseph N <Joseph.Lastufka@bp.com> Sent: Wednesday, July 01, 2015 4:08 PM To: Loepp, Victoria T (DOA); Davies, Stephen F (DOA); Hunt, Jennifer L (DOA) Cc: Gorham, Bradley M Subject: Withdraw S-130 (PTD #213-150) Permit to Drill 0, Please withdraw the Permit to Drill for S-130 (PTD #213-150). If you have any questions, please don't hesitate to let me know. Thank you, Joe Lastufka Information and Data Controller Cell: (907) 227-84961 Office: (907) 564-4091 -------------------------------------------------------------------------------------------- �����, ;—,J BP Exploration Alaska1900 E. Benson Blvd. IRoom: 788DJAnchorage, AK -------------------------------------------------------------------------------------------- 1 Loepp, Victoria T (DOA) From: Lastufka, Joseph N <Joseph.Lastufka@bp.com> Sent: Wednesday, July 01, 2015 4:08 PM To: Loepp, Victoria T (DOA); Davies, Stephen F (DOA); Hunt, Jennifer L (DOA) Cc: Gorham, Bradley M Subject: Withdraw S-130 (PTD #213-150) Permit to Drill Follow Up Flag: Follow up Flag Status: Flagged All, Please withdraw the Permit to Drill for S-130 (PTD #213-150). If you have any questions, please don't hesitate to let me know. Thank you, Joe Lastufka Information and Data Controller Cell: (907) 227-84961 Office: (907) 564-4091 -------------------------------------------------------------------------------------------- W BP Exploration Alaska1900 E. Benson B1vd.lRoom: 788DIAnchorage, AK -------------------------------------------------------------------------------------------- 1 THE STATE GO\7ERN0R SFi"' N PARNTF!,1, Ken Allen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 333 west Sevenih Avenue Anchorage, Alaska 99501-3572 Mo;n: 907.279.1433 pox: 907.276.752 Re: Prudhoe Bay Field, Aurora Oil Pool, PBU 5-130 BP Exploration (Alaska), Inc. Permit No: 213-150 (revised) Surface Location: 3629' FSL, 3175' FEL, Sec. 35, T12N, R12E, UM Bottomhole Location: 3768' FSL, 1913', FEL, Sec. 26, T12N, R12E, UM Dear Mr. Allen: Enclosed is the approved application for permit to drill the above referenced service well. This permit supersedes and replaces the permit previously issued for this well dated October 28, 2013. 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, G Cathy P. Foerster Chair, ommissioner DATED this LAday of February, 2013. STATE OF ALASKA ` ALAS OIL AND GAS CONSERVATION C PERMIT TO DRILL 20 AAC 25.005 sL,, Aai le, 6 &t I "--, RECEIVE OMM,/ ION Y(,G -r3-/y FEB 0 6 2014 1 a. Type of work: 1 b.Proposed Well Class: ❑ Development Oil ❑Service - Winj ®Single Zone • 1 c. Specify yif well is r � 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-130 3. Address 6. Proposed Depth: 12. Field / Pool(s) P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 9695' • TVD 7344' Prudhoe Bay / Aurora Pool 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: ADL 028257 - 3629' FSL, 3175' FEL, Sec. 35, T12N, R12E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 3561' FSL, 1952' FEL, Sec. 26, T12N, R12E, UM March 15, 2014 9. Acres in Property: 14.Distance to Nearest Property: Total Depth 3768' FSL, 1913' FEL, Sec. 26, T12N, R12E, UM . 2560 6900' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10.KB Elevation above MSL: 82.95' feet 15.Distance to Nearest Well Open Surface: x 620267 y- 5979855 • Zone- ASP4 GL Elevation above MSL: 36' feet to Same Pool: 2700' 16. Deviated Wells: Kickoff Depth: 300' feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 57 degrees Downhole: 3662 ' Surface: 2950 ' 18. Casing Program S ecifications Top - Setting Depth - Bottom I Quantity of Cement, c.f. or sacks Hole Casing Weight I Grade Coupling Length MD TVD I MD TVD (including stage data) 20" 129# X-56 120' Surface Surface 120' 120' 260 sx Arctic Set (Approx.) 12-1/4" 9-5/8" 40# L-80 BTC 4181' Surface Surface 4181' 3223' 1855 sx Dee Crete 406 sx Class 'G' 8-3/4" 7" 26# L-80 VamTop 9695' Surface Surface 9695' 7344' 350 sx LiteCrete 197 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): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor / Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 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: Date 22. I hereby certify that the foregoing is true and correct: Contact Troy Tempel, 564-5698 Printed Name Email Troy.Tempel@bp.com Ken Allen Title Engineering Team Leader U Signature s - -- --- Phone 564-4366 Date 7 Commission Use Only Permit To Drill-2 `-- �L API Number: �` _— Permit Appro al Date: See cover letter for Number: 50- _", 'V� _, 1� 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 i Other: )-e S f �D 0 0 � 5 Samples Req'd contained shales: f2 Q P L� 1 Sam I q' El [� No Mud Log Req'd: El Yes O1No tJ d � / / a % VCG� �o ✓ H2S Measures: 0 Yes ❑ ❑ No Directional Survey Req'd: [ /Yes No �'l a a. �1 rt, /o � a 6 AAC;2 n 0 3 -3(J•) Spacing exception req'd: El Yes ® No inclination -only svy Req'd: ❑ Yes ❑ No 10 D U n- /D V � APPROVED BY APPROVED BY � OMMISSIONER THE COMMISSION Date Form 10-401 Revised 10/2 12 This OI AL om the date of approval (20 AAC 25.005(g)) sub Form and Attachments in Duplicate y To: Alaska Oil & Gas Conservation Commission From: Troy Tempel, ODE Date: February 3, 2014 Re: S-130 Permit to Drill The S-130 well is scheduled to be drilled by Parker 273 in March 2014. This grassroots well is a water and gas injector targeting the Kuparuk C sands. The planned well is a two string design using a 9-5/8" surface casing and 7" injection casing. The surface casing will be set in the SV2 shale in order to isolate the permafrost and any possible hydrates. Injection casing will be 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 -2950 psi (assuming a 9.9 ppg TKA5 virgin reservoir pressure). This well will be drilled by Parker 273 using a Hydril 5000 psi, four preventer BOP stack (three rams and one annular preventer). The BOP rams will be tested to 4000 psi and the annular preventer tested to 3500 psi. In addition to a planned well summary, a directional plan and proposed completion schematic is attached to the permit application. If there are any questions concerning information on S-130i please do not hesitate to use the contact information below. Troy Tempel Cell: 907-570-1351 Office: 907-564-5698 Email: Troy.Tempel@bp.com Attachments: Well Bore Schematic Directional Plan BOPE Schematic Diverter Line Layout Diagram Rig Shadow Area Review Map Well Head Schematic S-130 PTD Page 1 2/6/2014 Planned Well Summary Well S-130 ` Well WAG injector ' Ob aTarctive et Kuparuk Current Status Grass Roots Well Estimated Start Date: 05/15/2014 Time to Complete: 27 Days Surface Nort ing Eastin Offsets TRS Location 5979855 620267 3629.4 FSL / 3175.3 FEL-1 T12N R12E sec 35 Northing Easting TVDss Offsets TRS Tgt 5985085 621400 -6810' 3561 FSL / 1952 FEL T12N R12E sec TKC4 26 BHL 5985292 621436 -7261' 3768 FSL / 1913 FEL T12N R12E sec 26 Planned KOP: I 300' MD / 217' TVDss Planned TD: I 9695' MD / 7261' TVDss Rig: Parker 273 BF-RT: 1 46.95' RUE (ref MSL): 1 82.95' Directional — Schlumberger S-130 (P11) KOP: 300' MD Maximum Hole Angle: -57' in 9-5/8" and 7" sections Close Approach Wells: No close approach / anti -collision issues Survey Program: Surface to - 750' MD gyro until clean surveys From -750' MD to 9-5/8" shoe = MWD 9-5/8" shoe to TD 9695' MD = MWD Nearest Property Line: 6900 ft Nearest Well within Pool: 2700 ft (S-105) S-130 PTD Page 2 2/6/2014 Formation Tops & Pore Pressure Estimate Formation Estimated Formation Top TVDss Most Likely pore Pressure Depth Uncertainty (+/- TVD ft) Fluid Type (for sands) G1 340 8.4 +/-20 ft. Permafrost SV6 1,530 8.4 +/-20 ft. Permafrost BPRF 1,880 8.6 +/-20 ft. Permafrost EOCU 2,040 8.4 +/-20 ft. water SV5 2,140 8.4 +/-20 ft. water SW 2,325 8.6 +/-20 ft. water SV3 2,710 8.6 +/-20 ft. water/hydrate SV2 2,860 8.7 +/-20 ft. water/hydrate 9 5/8" Surf Csg 3,140 8.7 +/-20 ft. water SV1 3,200 8.7 +/-20 ft. water UG4 3,535 8.9 +/-20 ft. water UG4A 3,580 8.9 +/-20 ft. Heavy Oil/wtr UG3 3,919 8.9 +/-20 ft. water UG1 4,500 8.7 +/-20 ft. water UG_MA 4,780 8.7 +/-20 ft. water UG_MB1 4,825 8.7 +/- 30' Heavy Oil/wtr UG_MB2 4,875 8.7 +/- 30' Heavy Oil/wtr UG_MC 4,945 8.7 +/- 30' Heavy Oil/wtr NA 5,010 8.7 +/- 30' water NB 5,030 8.7 +/- 30' Viscous oil/wtr NC 5,060 8.7 +/- 30' Viscous oil/wtr NE 5,070 8.7 +/- 30' Viscous oil/wtr NF 5,100 8.7 +/- 30' Viscous oil/wtr OA 5,130 8.6 +/- 30' Viscous oil/wtr OBA 5,170 8.6 +/- 30' wtrNiscous oil OBB 5,200 8.6 +/- 30' wtrNiscous oil OBC 5,245 8.6 +/- 30' wtrNiscous oil OBD 5,294 8.6 +/- 30' wtrNiscous oil OBE 5,360 8.6 +/- 30' wtrNiscous oil OBF 5,400 8.6 +/- 30' wtrNiscous oil OBF_BASE 5,430 8.6 +/- 30' wtrNiscous oil CM2 5,750 9.2 ✓ +/- 150' ✓poss GCM Fault #1 6,100 9.2 +/- 150' poss GCM CM1/TSLMP 6,530 10.0 +/- 150' poss GCM TLBK (slumped?) 6,605 10.0 +/- 100' poss GCM Fault #2 6,670 10.0 +/- 100' poss GCM THRZ (slumped?) 6,770 10.0 +/- 100' poss GCM TKLB 6,785 10.0 +/- 50' poss GCM TKC4 6,815 9.4 +/- 30' oil TKC3E 6,830 9.4 +/- 30' water TKC2A 6,875 9.4 +/- 30' water TKC1C 6,890 9.4 +/- 30' water TKB/LCU 6,950 9.9 +/- 30' water TKA6 7,020 9.9 +/- 30' water TKA5 7,030 9.9 +/- 30' water TMLV 7,080 10.0 +/- 30' v`'poss GCM TD 7,261 10.0 +/- 30' poss GCM S-130 PTD Page 3 2/3/2014 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 - 120 Surface 120 / 43 12-1/4" 9-5/8" 40# L-80 BTC 4181 Surface 4181 / 3140 8-3/4" 7" 26# L-80 VaHCop 9695 Surface 9695 / 7261 Tubing 4 Yz" 12.6# L-80 TCII 9121 Surface 9121 / 6741 Mud Proqram Surface Hole Mud Properties: Driiplex Spud Mud 12-1/4" Hole Section Density PV YP API FL Chlorides Funnel Depth Interval ppg (cp) Ib/100 ft2 ml/30min mg/I pH Viscosity sec/qt Surface to 3223' TVD 8.8 — 9.6 30-50 40-80 10 <1000 10.8 60-120 Injection Hole Mud Properties: LSND 8-3/4" Hole Section Depth Interval Density PV YP API FL HTHP FL MBT pH (ppg) 3223' TVD to 5833' g 2 — 9 8 12 - 18 20 - 28 <6 NC <18 9 - 10 TVD 5833' TVD to TD 10.3 — 10.4 12 - 22 20 - 28 <4 <10 <20 9 - 10 Logging Program 12-1/4"Surface: Sample Catchers - not required for surface hole Drillin : DIR/GR/RES Open Hole: None Cased Hole: None 8 3/4" Intermediate: Sample Catchers — as required by Geology Drilling: DIR/GR/RES/NEU/DEN/PWD Open Hole: None Cased Hole: Cement Bond Log Cement Proqram Casing Size 9-5/8" 40#, L-80 Surface Casing Lead: Annular volume plus 350% excess from surface to Base Perm and 40% excess from Base Basis: Perm to 1000' MD above shoe. Port collar can be used as required by hole conditions. Lead TOC: Surface Tail: Annular volume plus 40% excess from 1000' MD above shoe, and 80' MD shoe track Tail TOC: 1000' MD above 9-5/8" casing shoe Total Cement Lead 611 bbls, 3487 ft', 1855 sacks 11.0 ppg DeepCrete, Yield 1.85 ft3/sack Volume: Tail 84 bbls, 471 ft , 406 sacks 15.8 ppg Class G, Yield: 1.16 ft /sack S-130 PTD Page 4 2/3/2014 Casing Size 7" 26#, L-80 Injection Casing Basis: Lead: Annular volume plus 40% excess from TOC to 1000' MD above the shoe Lead TOC: 5777' MD 1596' MD below 9-5/8" casing shoe Tail: Open hole volume + 40% excess + 80 ft shoe track Tail TOC: 1000' MD above casing shoe Total Cement Lead 109 bbls, 612 ft3, 350 sacks 11.5 ppg LiteCrete, Yield: 1.75 ft3/sack Volume: Tail 41 bbls, 230 ft", 197 sacks 15.8 ppg Class G, Yield: 1.17 ft"/sack Surface and Anti -Collision Issues Surface Shut-in Wells: S-124i will be shut in approximately 1-2 weeks prior to spud date to mitigate any potential pressure interactions while drilling through the Kuparuk sands. S-112i and S-110Bi will be evaluated for shut in after bottom hole pressures have been obtained end evaluated. No wells will be affected by the Parker 273 rig shadow. Ant -Collision: No anti -collision issues exist. Hydrogen Sulfide , S-Pad is considered an H2S site. Recent H2S data from the pad is as follows: Well Name H2S Level Reading Date Comments #1 Closest SHL Well H2S Level S-33 24 ppm 2/9/2013 #2 Closest SHL Well H2S Level S-08B 20 ppm 2/10/2013 #1 Closest BHL Well H2S Level S-105 22 ppm 2/15/2013 #2 Closest BHL Well H2S Level S-108 12 ppm 5/29/2011 #3 Closest BHL Well H2S Level S-121 40 ppm 3/17/2013 #4 Closest BHL Well H2S Level S-110 110 PPM 10/8/2007 Max. Recorded H2S on Pad/Facility S-201 500 ppm 6/2/2005 Faults Formation Where MD TVDss Throw Direction and Lost Circ Uncertainty Encounter Fault Intersect Intersect Magnitude potential Fault #1 — CM2 8413.0 6100.0 Northeast. 80 ft. +/- 150 ft. Low Fault #2 — TLBK/HRZ slum 9048.0 6675.0 Northeast. 20-30 ft. +/- 150 ft. 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. S-130 PTD Page 5 2/3/2014 Well Control /" The 12-1/4" surface hole will be drilled with a diverter. (See attached diverter layout) The 8-3/4" hole section will be drilled with well control equipment consisting of 5000 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 4000 psi (3500 psi annular test). BOP test frequency for S-130 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 3662 psi at @ TKA5 at 7030' TVDss (9.9 ppg EMW) Maximum surface pressure 2950 psi (.10 psi/ft gas gradient to surface) 25 bbls with a 12.7 ppg fracture gradient Kick tolerance Assumes a 0.5 ppg kick intensity over the anticipated 10.0 ppg pore pressure at interval TD with a 10.3 ppg MW. Planned BOP test pressure Rams test to 4000 psi / 250 psi Annular test to 3500 psi / 250 psi Integrity Test — 8-3/4" hole 12.7 ppg LOT after drilling —20' MD of new formation below the 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. • The planned 8.8-9.6 ppg fluid will provide over balance to formation fluid. ° • S-128 and S-129 were drilled on S-pad in 2010 with diverter and flow paddle removed to 1000' MD without incident. Operations Summary Pre -Rig Work: 1. Install 20" conductor 2. Weld on an FMC landing ring for the FMC Gen 5 wellhead on the conductor 3. Obtain Static Bottom Hole Pressures (SBHP) from S-105, S-110B, S-112, and / or S-124 4. Obtain Pressure Falloff Test from S-112 and S-124 5. Shut in S-124 prior to spud date 6. 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. S-130 PTD Page 6 2/3/2014 Rig Operations: 1. MIRU Parker 273 2. NU diverter spool & riser. Function test the diverter.) 3. Prepare mud pits with 8.8 ppg Drillplex mud. 4. Pick up enough HT38 4.0" drill pipe to TD surface hole and stage in derrick. 5. Make up BHA #1 to include 12.25" Milltooth Bit, Bent Housing Motor, Universal Bottom Hole Orientation (UBHO) sub and drill ahead using wire -line gyro until BHA #2 can be buried and/or magnetic interference is clear (-750' MD). 6. POOH and pick up BHA #2 to include 12.25" Milltooth Bit, Bent Housing Motor, and DIR/GR/RES. - Utilize the following mud weights while drilling the surface hole section. Surface - 3140' TVDss use 8.8-9.6 ppg 7. Drill surface hole to 4181' MD (60' TVD above the SV1 Top). Perform wiper trip to base of - permafrost. At TD CBU until hole is clean. POOH and prepare for casing run. - If backreaming is required trip back to TD. Final trip out must be on elevators. 8. Run 9.625" 40# L-80 BTC casing down to 4181' MD. If required a TAM Port Collar can be run at 500' MD (Discussion with ODE required). 9. Cement surface casing with -611 BBL of 11.0ppg DeepCRETE lead (350% excess from surface to base of perm and a 40% excess from base of perm to 1000' above shoe) Follow with an -84 BBL 15.8ppg G tail (40% excess from 1000' above shoe). Reciprocate casing during cement job. 10. Nipple down diverter and nipple up casing / tubing head. Nipple up and test BOP. (Configured from top to bottom: annular preventer, 2.875"x5.5" VBR, blind / shear, mud cross, 2.875"x5.5" VBR) Test BOP to 250 psi low / 4000 psi high with appropriate test joint (3500 psi annular test). Give the AOGCC 24 hour notice prior to testing. 11. Pressure test the 9.625" surface casing to 250 psi low / 3500 psi high for 5 minutes low / 30 minutes high once 500 psi compressive strength has been achieved. 12. Make up BHA #3 to include 8.75" PDC Bit, Bent Housing Motor, and DIR/GR/RES/NEU/DEN/PWD. 13. Run in hole and drill out shoe track and swap mud to 9.2 ppg LSND drilling fluid. Drill -20' of new hole, CBU and pull into shoe. Preform LOT to a minimum12.7 ppg for a 25 barrel kick tolerance. 14. Drill ahead to TD at 9695" MD. (181' MD below the TMLV) TD should not be called until LWD/MWD tools have logged the entire Kuparuk formation. - Utilize the following mud weights while drilling the intermediate hole section. 3140' TVDss - 5750' TVDss use 9.2-9.8 ppg 5750' TVDss - 7261' TVDss (TD) use 10.3-10.4 ppg 15. At TD CBU until hole is clean. Short trip to ghost reamer depth (or to achieve MAD pass across Schrader if required). Backream only if necessary. 16. Trip back into hole to TD and CBU until hole is clean. Pull out of hole on elevators. 17. Change upper 2.875"x5.5" VBRs to 7.0" casing rams and test with 7.0" test joint to 250 psi low /4000 psi high. 18. Run 7.0" 26# L-80 VTHC casing down to 9695' MD. 19. Cement casing with -109 BBL 11.5 ppg LiteCrete lead (40% excess from TOC to 1000' above the shoe). Follow with -41 BBL 15.8ppg G tail (40% excess to1000' above the shoe). Planned Top of Cement is 5777' MD. (1000' TVD above the Na) Reciprocate casing during cement job. Bump plug and ensure that floats holds. Pressure test casing to 250 psi low / 4000 psi high for 5 minutes low / 30 minutes high on plug bump. Displace cement with 10.5 ppg NaCl/NaBr brine. 20. Laydown drillpipe while waiting on cement to reach 500 psi compressive strength. 21. Freeze protect the 7.0"x9.625" annulus from surface to the base of permafrost +150' MD (2097' MD) after cement reaches 500 psi compressive strength. 22. Rig up wire -line and run cement bond log (isolation scanner/ modular sonic imaging platform (MSIP)) from Plug Back Total Depth to Surface. (AOGCC requirement on injection well) S-130 PTD Page 7 2/6/2014 23. Run 4.5" 12.6# L-80 TCII completion tubing down to 9121' MD. Land tubing and Run In Lock Down Screws (RILDS). 24. Reverse circulate clean 10.5 ppg NaCl/NaBr brine followed by corrosion inhibited brine. 25. Drop ball and rod down to the RHC-M plug in the XN Nipple at the tubing tail. 26. Set the production packer and pressure test the tubing to 250 psi low / 4000 psi high for 5 minutes low / 30 minutes high. 27. Bleed tubing pressure to 2000 psi. Pressure test the IA to 250 psi low / 4000 psi high for 5 minutes low / 30 minutes high. 28. Hold pressure on the IA and bleed tubing pressures to zero, shearing the DCK shear valve. Pump both ways to confirm circulation ability. 29. With landing joint still rigged up, reverse circulate diesel freeze protect using rig injection pump. 30. Allow diesel to U-tube, drain stack, and rig down landing joint. Monitor well for 1 hour to confirm well is dead. 31. Install a Two Way Check (TWC) with dry rod. Test from below at 250 psi low / 3500 psi high for 5 minutes low / 5 minutes high. Test from above at 250 psi low / 3500 psi high for 5 minutes low / 5 minutes high. 32. Nipple down BOPE. Nipple up adaptor and tree. Fill tree with diesel and test to 250 low / 5000 psi high for 5 minutes low / 5 minutes high. 33. Install all annulus valves and secure the well. Ensure T/IA/OA all have two barriers in place. 34. RDMO Post Rig Operations: 1. Install tree with electric safety valve. Pull Back Pressure Valve (BPV) 2. Rip up slickline and pull ball and rod / RHC 3. Replace the DCK shear valve with a dummy GLV 4. Perforate underbalanced post -rig with wire -line 5. Rig up slickline and drift / tag to obtain SBHP 6. Flow back to portable separator 7. Water injectivity step rate test below fracture gradient 8. Install wellhouse and flowline 9. Pump RG2401 (Blue -Goo) on top of surface casing cement S-130 PTD Page 8 2/6/2014 S-130 Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE I. Well Control / Reservoir Press-urw. A. Surface Hole: Hydrate gas i 'expected in the S-130 surface hole and has been reported on S-Pad in the past. This has previously been seen in the lower SV; roughly 2700' TVDss to 3000' TVDss. Hydrate occurrence is much`lower when drilling into the East side of S-Pad. B. OverBurden: Formation pressures are expected to range from 8.4 — 8.9 ppg down to the CM2. `J Schrader sands are expected to be mostly wet. Gas cut mud (GCM) is possible from the top of the CM2 down through the Kalubik with a 9.2 — 10.0 ppg expected pore pressure. ✓ C. Kuparuk Reservoir: The Kuparuk sands are predicted to be normally pressurized with 9.4 - 9.9 ppg pore pressure. However, Kuparuk A sand overpressure was seen in the recent S-110A sidetrack. The r` nearby S-112i and S-124i wells will be shut in prior to spud to help minimize this possibility. II. Lost Circulation/Breathing A. Surface Hole: Lost circulation is considered a minimal risk if mud properties remain in specification. B. Fault Crossings: Two faults will be crossed by S-130. Fault #1 occurs at the CM2 (8413' MD, 6100' TVDss) with an 80' Northeast throw. Fault #2 occurs at a slumped TLBK/HRZ zone (9048' MD, 6675' TVDss) with a 20-30' Northeast throw. The potential for lost circulation at each fault is low as each of these intervals are shale, but hole stability should be considered a risk through these sections. C. Injection Hole: Hole stability and breathing in the Colville, HRZ, and Kalubik sections is considered a key drilling risk. Proper mud weights, mud weight up times (multiple circulations), and managing temperatures during circulations can reduce these risks. III. Integrity Testing Test Point ITest Depth I TestType I EMW (lb/gal) 9-5/8" Shoe I 20'-50' from the 9-5/8" Shoe I LOT 1 12.7 ppg minimum 25bbls IV. Hydrogen Sulfide A. As S-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 500 ppm in S-201 June 2005. V. Faults Formation Where Encounter Fault MD Intersect ft TVDss Intersect ft Throw Direction and Ma nitude Uncertainty Fault #1 — CM2 8413.0 6100.0 Northeast. 80 ft. +/- 150 ft. Fault #2 — TLBK/HRZ slum 9048.0 6675.0 Northeast. 20-30 ft. +/- 150 ft. VI. Anti -Collision Issues A. No anti -collision issues. CONSULT THE S-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. S-130 PTD Page 9 2/6/2014 TREE= 4-1/16" CIW WELLHEAD= FMC ACTUATOR = INITIAL KB ELE\ 82.95' BF. ELEV = 46.95 KOP = -300' Max Angle = 57 Datum MID = _ Datum TVD = PROPOSAL 20" CONDUCTOR, 129#, X-56, D = 19.124 1-1 120- 9-5/8" CSG, 40#, L-80 BTC, D = 8.835" I� �4181 r Minimum ID = " @ ' ESTIMATED TOP OF CEMENT -5777 TOC is 1 000'TVD above the DPZ (Top NA) 1/2" TBG, 12.6#, L-80 TCII, .0152 bpf, ID = 3.958" 1--1 -9121 PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: _° @ ' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz SHOT SOZ Pf3TD —9615 CSG, 26#, L-80 VAM TOP .0383 bpf, D = 6.276"-9695 S - 13 0 SAF NOTES: H2S HEADINGS AVERAGE 125 ppm WHEN ON M I. WELL REQUIRES A SSSV WHEN ON MI. -500 9-5/8" TAM PORT COLLAR, ID = " --2097 4-1/2" HES X NIP, ID = 3.813" GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 3500 2 5250 1 -6500 -8971 j-�4-1/2" HES X NP, D = 3.813" -9002 -j7" X 4-1/2" HES TNT PKR D = 3.870" -------------- �9039 4-1 /2" HES X NP, D = 3.813" ~9109 1-14-1/2" HES XN NIP, D = 3.725" -9122 -14-1/2" WLEG, D =4.00" ELMD TT NOT LOGGED —9152 2 - 10' MARKER JOINTS w /RA TAG DATE REV BY COMMENTS DATE REV BY COMMTNTS 09/09/13 TTT BUILD PROPOSAL 02/03/14 TTT DIRECTIONAL UPDATE AURORA UNIT WELL: S-130 PERMIT No: AR No: 50-029- -00 SEC 35, T12N, R12E� 3629' FSL & 3175 FEL BP Exploration (Alaska) L O� C C- M y rt+ O Q a) w Td V O ,d V = � a H O a O a` EL 0 '7 V! _ d N f0 _C • m � • N J m J m t J J O D o w w m a m f0 z C J DO °fnn E E c QM F� o N�� m b° E_ _H xz° o w N o° Q fu CE- O S M 0,-0 fma. 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O 11G3 (a0D1 9Si1/lS) ""_. _. _. _. _. _. _. _. _. _. _. _. _. _. _. _. _. _. _. _. _. _. _. _. 4250 4250 ucija5e2.s57viii"'_.._„_.._.,_,._„_„_.._„_„_,._„_„_„_„_„_.._„_„_„_„_.._,._„_,._.._„_,._„_.......... ._.._,._,._.._.._,._.._.._„_,._ _,._„_.--- ......... ............................................ 7197 MD p<9�_.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.:_.._.._.:_.._.._.._.._.._........................................ ._..-.._..-.......................................................... 5100- -- - 5100 _::_::_::_::_::_::_::_::_::_::_::_::_::_::_.. .................... ._.,_,._„_„_.,_„_„_.,_„_.,_„_„_„_.,_„_„_„_„_.,_„_,._„_.,_„_,._,......................... .............. 1 cM2('zss Tv ) 5950 9413 MD 5950 Fu.2 Boas MD Tgt Kuv 919] MD _.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._,._,._.._.._,._.,_.._.._.._.._.. .. _.. .._.._.. _.._.._.._.._.. _.._.. CM1.l TSLMP (fi612 95_ND� ._.. _.. 6800 TIiR2(6]52.95P/DI ...................._.._.. 6800 ?5 .................................... ....�.,,...............................� .:._.:_,..::. _.,::.:.::.....,.::......................::.,.:, ---:-_„_-----,:., TK6'LCU ]032x�95myND2 MLV a7Y ._.._ _ _.._.. _.._.._.._ TD 9695 MD / 7650 S-130(P11) 7650 0 850 1700 2550 3400 4250 5100 5950 Vertical Section (ft) Azim = 13.122' Scale = 1:450(ft) Origin = ON/-S. OE/-W ��-l Well: Field:30 (P11) Plan S-130 Prudhoe Bay Unit - ;�7�w S-PAD Gravity 8 Magnetic Parameters Surface LocaOon NAD27 Alaska State Plane, Zone 04, US Feet Miscellaneous Model: BGGM 2013 Dip: 81.003° Date: 6/20/2011 La[: N 7021 f2.8f Northing: 6979866RUS Grid Conv: 0.92° Slot: Sbt a-09 v3 ND Ref: Rotary Table182.98R above MSL) MagDec: 19.66° FS: 67628.86nT Gravity FS: f002.003mgn Lon: W749 f Easting: 620267RUS Stale Fact: 1 Plan: 5-1301P1f) by 0 Schlumberger -1500 -1000 -500 0 500 1000 1500 2000 2500 3000 5500 V S-130(P11) 5500 X m 5695 MD FII s2 SOJB MD T91 Kup 9197 MD 5000 5000 S-1 Flt 2 6675ss ttpt a413 MD S-130 Flt 1 6100ss 4500 4500 ECry ]t97 9] MD 4000 4000 Cry 1100 6131 MD 3500 3500 0 3000 3000 m m cn z 2500 2500 s-sa J181 MD 2000 2000 1500 1500 E,i Cry 2993 MD 1000 1000 Cry 3100 2334 MD Cry aim 500 �pMD 500 End Cry Cry 2]5100 20a] MD t?00 MD Cry 2/100 500 MD End Cry 632 MD KOP Cry 1IC0 0 300 MD Cry 2 S 100 0 600 MD -1500 -1000 -500 0 cME 500 1000 1500 2000 2500 3000 EW (ft) Scale = 1:300(ft) Borehole: Well: Field: Structure: S-130 (PI 1) Plan S-130 Prudhoe Bay Unit - WOA S-PAD Gravity 8 Magnetic Parameters Surface Locatlon NAD27 Alaska Stale Plane, Zone 04, US Feet Model: BGGM 2073 Dip: 81.003' Date: 5/20/2074 Lat: N 7021 12.87 Northing: 5979855RU5 Grid Conv: 0.92' �Mlscellaneous Slot Slot a-09 v3 ND Ref: Rotary Table182.95R above MSL) MagDec: 19.66° FS: 57625.86nT Gravity FS: 7002.003mgn Lon: W149 1 Eastlng: 620267RU5 Scale Fact: t Plan: 5-130(P11) _ - o LO w Q r� ------------- ----- ---------,.- ----- 0Lo � 0 I m d o co r � o m o 0 � � o r o , C Lo cn O O o L Q N i, o v 3 cn I 0 cl N —.—__--- ------ --�-- I I I I i i - - o o II i � O o N 07 r � V1 O N m-007 Cl) c N cdrrr O (n (n ;k m L -0 C/) NNcda IL CL 0- CL CL II I o u7 o uo f� CO (D N o Ln o uo o m N -ItV m M N (ui/l}sn 0 uoilejedag ailuao of ailuao o 0 �n o in o N .2 '- Company: NorthAmerica- ALASKA - BP Project: Prudhoe Bay Reference Site: PB S Pad Site Error: 0.00usft Reference Well: Plan S-130 (slot 13+30) Well Error: 0.0ousft Reference Wellbore Plan S 130 Reference Design: Plan #11 5-130 BP Anticollision Report Local Co-ordinate Reference: Well Plan 5-130 (slot 13+30) TVD Reference: 5-130 plan P273 @ 82.95usft (P273 plan) MD Reference: 5-130 plan P273 @ 82.95usft (P273 plan) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 1.00 sigma Database: EDM R5K - Alaska PROD - ANCP1 Offset TVD Reference: Offset Datum 2eference Plan #11 S-130 :filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference nterpolation Method: MD Interval5.00usft Error Model: ISCWSA )epth Range: Unlimited Scan Method: Tray. Cylinder North tesults Limited by: Maximum center -center distance of 1,164.78usft Error Surface: Elliptical Conic Survey Tool Program Date 1/28/2014 From To (usft) (usft) Survey (Wellbore) Tool Name Description 46.95 750.00 Plan #11 5-130 (Plan S 130) GYD-GC-SS Gyrodata gyro single shots I 750.00 2,250.00 Plan #11 S-130 (Plan S 130) MWD MWD - Standard 750.00 4,180.00 Plan #11 S-130 (Plan S 130) MWD+IFR+MS MWD + IFR + Multi Station 4,180.00 5,680.00 Plan #11 S-130 (Plan S 130) MWD MWD - Standard 4,180.00 9,694.72 Plan #11 S-130 (Plan S 130) MWD+IFR+MS MWD + IFR + Multi Station 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-11 - S-11 - 5-11 530.09 520.00 256.66 11.00 245.66 Pass - Major Risk S-11 - S-11A- S-11A 530.96 520.00 256.68 11.02 245.66 Pass - Major Risk 5-11 - 5-11 B - S-11 B 531.44 520.00 256.69 11.03 245.66 Pass - Major Risk S-110 - 5-110 - S-110 4,038.12 4,100.00 241.59 92.50 176.05 Pass- Major Risk S-110 - S-110A - 5-110A 3,657.23 3,710.00 328.93 226.46 187.39 Pass - Major Risk 5-110 - 5-110B - Plan #5b 5-110B approved 3,423.96 3,565.00 250.10 278.39 73.17 Pass - Major Risk S-12 - 5-12 - S-12 591.37 580.00 134.10 12.25 121.85 Pass - Major Risk S-124 - S-124 - 5-124 6,319.92 6,420.00 699.52 139.61 562.40 Pass - Major Risk S-12A - S-12A - S-12A 590.42 585.00 152.27 12.82 139.46 Pass - Major Risk S-12A - S-12B - S-12B 590.42 585.00 152.27 12.82 139.46 Pass - Major Risk 5-13 - Plan S-13A- Plan #10 S-13A 509.21 505.00 30.25 8.86 21.39 Pass - Major Risk 5-13 - 5-13 - S-13 509.76 495.00 30.26 8.72 21.54 Pass - Major Risk S-14 - S-14 - S-14 851.24 835.00 75.65 13.26 62.39 Pass - Major Risk S-14 - S-14A- S-14A 851.24 835.00 75.65 13.26 62.39 Pass - Major Risk 5-15 - 5-15 - S-15 Out of range S-36 - S-36 - 5-36 515.01 505.00 215.66 8.36 207.31 Pass - Major Risk S-37 - 5-37 - S-37 1,000.00 1,005.00 186.19 16.38 170.30 Pass - Major Risk S-37 - S-37A- S-37A 1,000.00 1,005.00 186.19 16.12 170.58 Pass - Major Risk S-37 - S-37APB1 - S-37API31 1,000.00 1,005.00 186.19 16.41 170.29 Pass - Major Risk 5-41 - S 41 - S-41 4,198.77 4,535.00 863.12 135.90 792.60 Pass - Major Risk S-41 - 5-41 A - S-41 A 4,191.34 4,520.00 863.25 137.61 792.58 Pass - Major Risk S-41 - S-41 AL 1 - S-41 AL 1 4,191.34 4,520.00 863.25 137.61 792.58 Pass - Major Risk S41 - S 41 L1 - S 41 L1 4,198.77 4,535.00 863.12 135.91 792.60 Pass - Major Risk S41 - S-41 PB1 - S41 PB1 4,190.77 4,535.00 863.12 135.89 792.60 Pass - Major Risk 112812014 9:49:28AM Page 2 of COMPASS 5000.1 Build 61 Project: Prudhoe Bay Site: PB S Pad Well: Plan S-130 (slot 13+30) Wellbore: Plan S 130 Design: Plan #11 S-130 From Colour To MD From Surface to 2800'md Scan interal 25 ft 47 500 Scale 1 inch : 100ft All wells pass the major risk 500 1000 1000 1500 See AC summary report for detailes 1500 2000 2000 2500 0 2500 3000 - _- 3000 3500 3500 4000 330. .. 330 30 4000 4500 - 4500 9695 27 220 16 11 5 90 ;+ 7t, 5 _rt� `1u- 1 q; 240 11} II • 120 275 210 a _ 330 - --. 150 180 Azimuth from North [I vs Centre to Centre Separation [100 usft/in] 300 240 Project: Prudhoe Bay Site: PB S Pad Well: Plan S-130 (slot 13+30) Wellbore: Plan S 130 Design: Plan #11 S-130 From Colour To MD From 2700'md to TD Scan interal 25 ft 47 500 Scale 1 inch : 100ft All wells pads the major risk 500 1000 ... 1000 1500 See AC summary report for cletailes 1500 2000 2000 2500 0 2500 3000 ----- ----- 3000 3500 --- - .... ... . .. . ... .. - -- ---- ----- 3500 4000 210 180 150 Azimuth from North [] vs Centre to Centre Separation [100 usft/in] PARKER 272 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 o o 0 0 0 0 00 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 W QI L J w N l v U^+ _ l 1 0 CD _ _ J , :l ass i - '-I 0 N l N 0_ E �a i O LL Kol H 0 L Z_L 6 e,e, 4r `finn C7 IIDL£-S Y' co. N I —IW9E-8— 71,1 s, i E 0 CL (U 3 CL L 7 fu Y N .n N c w Ln a m 0 0 a rN o. E a) a It N Redacted by M. Guhl 9/2/2021 WELL NAIATE �h;�cluhn��nt r. �;�nic: '�pl���,i�n� _ - Strrtigr�il;l�ictc�t "n:�•,i��cn�i<n.<il POOL. Check Box for Appropriia.e Letter / Paragraphs to tie Included in Trarasutittal Letter C11-1ECX 011 TION� TEXX OR APPROVAL L;uTTER ] MULTI The permit is for a new wellbore segment of existing well Permit II LATERAL No. API No. SU- (If last two diuits Production should continue to be reported as a function of the Orin "I in API number are API number stated above. between 60-69) data lo,.!s In accordance with 20 AAC 25.005(1'), all records. and acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on pennit). 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 pen -nit: 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 a proval 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 da s after com letion, suspension or abandonment of this well. Revised 5/2013 WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, AURORA OIL - 640120 PTD#:2131500 Administration Appr Date SFD 2/10/2014 Engineering Appr Date VLF 2/13/2014 Geology Appr Date SFD 2/10/2014 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 ny BP EXPLORATION (ALASKA) INC Initial Class/Type Permit fee attached NA Lease number appropriate Yes Unique well name and number Yes Well located in a defined pool Well located proper distance from drilling unit boundary Well located proper distance from other wells Sufficient acreage available in drilling unit If deviated, is wellbore plat included Operator only affected party Operator has appropriate bond in force Permit can be issued without conservation order Permit can be issued without administrative approval Can permit be approved before 15-day wait Well located within area and strata authorized by Injection Order # (put 10# in comments) (For All wells within 1/4 mile area of review identified (For service well only) Pre -produced injector: duration of pre -production less than 3 months (For service well only) Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D) Conductor string provided Surface casing protects all known USDWs CMT vol adequate to circulate on conductor & surf csg CMT vol adequate to tie-in long string to surf csg CMT will cover all known productive horizons Casing designs adequate for C, T, B & permafrost Adequate tankage or reserve pit If a re -drill, has a 10-403 for abandonment been approved Adequate wellbore separation proposed Ifdiverterrequired, does it meet regulations Drilling fluid program schematic& equip list adequate BOPEs, do they meet regulation BOPE_press rating appropriate; test to _(put psig in comments) Choke manifold complies w/API RP-53 (May 84) Work will occur without operation shutdown Is presence of H2S gas probable Mechanical condition of wells within AOR verified (For service well only) Permit can be issued w/o hydrogen sulfide measures Data presented on potential overpressure zones Seismic -analysis of shallow gas zones Seabed condition survey (if off -shore) Contact name/phone for weekly_ progress reports [exploratory only] Well Name: PRUDHOE BAY UN AURO S-130 SER / PEND GeoArea 890 Unit 11650 Entire well lies within ADL 028257. Program SER Well bore seg On/Off Shore On Annular Disposal Yes PRUDHOE BAY, AURORA OIL - 640120, governed by CO 457B Yes CO 457B, Rule 1: Spacing units within the pool shall be a minimum of 40 acres. 20 AAC 25.055(a)(1) and (2) Yes shall not apply to property lines within the external boundaries of the Aurora Participating Area Yes Yes Yes Yes Yes Yes Yes Yes AIO 22E Yes None No Yes Yes Conductor set to 120' Yes Surface casing set to 3223' TVD Yes 198% excess planned No TOC 5777' MD Yes Injection interval will be completed with injection casing, cemented and perforated Yes Yes Rig has steel tanks; all waste to approved disposal wells NA Yes Anti -collision analysis complete; no major risk failures; Yes Yes Max formation pressure is 3662 psi(7030' TVD)9.9 ppg EMW; will drill w/ 9.2-10.4 ppg EMW Yes Yes MPSP is 2950 psi; BOPs test pressure is 4000 psi Yes Yes Yes H2S measures required Yes No wells within quarter mile radius No S-Pad wells are H2S-bearing. Per 20 AAC 25.065(b), H2S measures are required in conformance_ Yes with API RP 49 (1987). Mud program -is adequate for operator's estimated most likely pore pressures. NA Will -be drilled using coiled tubing. _Gsa hydrates expected as discussed in the Drilling Critical Issues NA section; hydrates will -be -drilled while on diverter. NA Geologic Engineering Public Revised Permit Application: change in surface and bottom -hole locations. Gas hydrates are expected as in the "S-130 Drilling Commissioner: Date: Commissioner: Date Commissioner Date Critical Issues" section of the application. Hydrates will be drilled while on diverter. SFD 10/10/13 SFD Rev. 2/10/14 DTS Z I I 1 I l s co" L �� THE STATE Alaska GH and Gas 01ALA",\LLSE, Q'14� Cci:j-eer\,TztL'(an C=,.-,,nL'-ssE'an GOVERNOR SEAN 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, Aurora Oil Pool, PBU S-130 BP Exploration (Alaska), Inc. Permit No: 213-150 Surface Location: 3640' FSL, 3811' FEL, Sec. 35, T12N, R12E, UM Bottomhole Location: 3760' FSL, 1884', FEL, Sec. 26, T12N, 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, Commissioner DATED this 2Fday of October. 2013. STATE OF ALASKA jI E C E' D ALAS, OIL AND GAS CONSERVATION COMMI, ON PERMIT TO DRILL OCT 0 9 2013 20 AAC 25.005 1 a.Type of work: 1 b.Proposed Well Class: ❑ Development Oil ❑ Service - Winj ® 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-130 3. Address 6. Proposed Depth: 12. Field / Pool(s) P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 9803' TVD 7338' Prudhoe Bay / Aurora Pool 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: ADL 028257 3640' FSL, 3811' FEL, Sec. 35, T12N, R12E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 3561' FSL, 1952' FEL, Sec. 26, T12N, R12E, UM February 15, 2014 9. Acres in Property: 14.Distance to Nearest Property: Total Depth 3760' FSL, 1884' FEL, Sec. 26, T12N, R12E, UM 2560 6900' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10.KB Elevation above MSL: 76.8' ' feet 15.Distance to Nearest Well Open Surface: x 619631 y- 5979855 - Zone- ASP4 GL Elevation above MSL: 36' feet to Same Pool: 2700' 16. Deviated Wells: Kickoff Depth: 300' feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 57 degrees Downhole: 3659 ' Surface: 2948 - 18. Casing Program S ecifications Top - Setting Depth - Bottom Quantity of Cement, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 20" 129# X-56 120' Surface Surface 120' 120' 260 sx Arctic Set (Approx.) 12-1/4" 9-5/8" 40# L-80 BTC 4188' Surface Surface 4188' • 3217' 1775 sx Dee Crete 408 sx Class 'G' 8-3/4" 7" 26# L-80 VamTop 9803' Surface Surface 9803' 7338' 337 sx LiteCrete 182 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): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor / Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 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: Date 22. 1 hereby certify that the foregoing is true and correct: Contact Troy Tempel, 564-5698 Email Troy.Tempel@bp.com Printed Name Ken Allen Title Engineering Team Leader Signature Phone 564-4366 Date L9 8 .� Commission Use Only Permit To Drill API Number: f'Le' �7 '� `� '�E- Permit Ap roval D te: See cover letter for Number: �,/ .'j � L% 50- �C other requirements: Conditions of Approval: If box is checked, well may not be used to explore for, test, or prod ce coalbed methane, gas hydrates, or gas 0 contained shales: Other. �—O (�U U (� 5, Samples Req'd [:]Yes ❑ No Mud Log Req'd: ❑ Yes 0 No / � v r HzS Measures: E�Yes ❑ No Directional Survey Req'd: 0 Yes El No / Spacing exception req'd: ❑ Yes © No inclination -only svy Req'd: ❑ Yes Q No 633tj APPROVED BY APPROVED BY d OMMISSIONER THE COMMISSION Date •^ Form 10-401 Revised 10/20 2 This p r i flf I f 1 o h from the date of approval (20 AAC 25.005(g)) Submit Form and Attachments In Duplicate vP�� ro -Z// 3 � ���� �J To: Alaska Oil & Gas Conservation Commission From: Troy Tempel, ODE Date: October 7, 2013 Re: S-130i Permit to Drill The S-130i well is scheduled to be drilled by Parker 273 in February 2014. This grassroots well is a water and gas injector targeting the Kuparuk C sands. The planned well is a two string design using a 9-5/8" surface casing and 7" injection casing. The surface casing will be set in the SV2 shale in order to isolate the permafrost and any possible hydrates. Injection casing will be 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 M P 5 to surface is —2948 psi (assuming a 9.9 ppg TKA5 virgin reservoir pressure). This well will be drilled by Parker 273 using a Hydril 5000 psi, four preventer BOP stack (three rams and one annular preventer). The BOP rams will be tested to 4000 psi and the annular preventer tested to 3500 psi. In addition to a planned well summary, a directional plan and proposed completion schematic is attached to the permit application. If there are any questions concerning information on S-130i please do not hesitate to use the contact information below. Troy Tempel Cell: 406-207-0766 Office: 907-564-5698 Email: Troy.Tempel@bp.com Attachments: Well Bore Schematic Directional Plan S-130 As -staked BOPE Schematic Well Head Schematic Diverter Line Layout Diagram Rig Shadow Area Review Map S-130 PTD Page 1 10/7/2013 Planned Well Summary Well S-130i Well WAG injector Ob active et Kuparuk Current Status Grass Roots Well Estimated Start Date: 02/15/2014 1 Time to Complete: 27 Days Surface Northing Easting I Offsets ITRS Location 5979855 619631 3640 FSL / 3811 FEL T12N R12E sec 35 Northing Easting TVDss Offsets TRS Tgt 5985085 621400 -6810' 3561 FSL / 1952 FEL T12N R12E sec TKC4 26 BHL 5985285 621465 -7261' 3760 FSL / 1884 FEL T12 R12E sec 26 Planned KOP: 300' MD / 223' TVDss Planned TD: 9803' MD / 7261' TVDss Ri Parker 273 BF-RT: 1 40.8' RTE (ref MSS): 76.8' Directional — Schlumberger S-130i (P8) KOP: 300' MD Maximum Hole Angle: -57' in 9-5/8" and 7" sections Close Approach Wells: Close approach with S-110 & S-110A at - 3400' MD to 3600' MD Survey Program: Surface to - 1000' MD gyro until clean surveys From -1000' MD to 9-5/8" shoe = MWD 9-5/8" shoe to TD 9803' MD = MWD Nearest Property Line: 6900 ft Nearest Well within Pool: 2700 ft (S-105) S-130 PTD Page 2 10/8/2013 Formation Tops & Pore Pressure Estimate Formation Estimated FormationTop (TV Most Likely Pore Pressure (EMW ppg) Depth Uncertainty (+/- TVD ft) Fluid Type (for sands) G1 340 8.4 +/-20 ft. Permafrost SV6 1,530 8.4 +/-20 ft. Permafrost BPRF 1,880 8.6 +/-20 ft. Permafrost EOCU 2,040 8.4 +/-20 ft. water SV5 2,140 8.4 +/-20 ft. water SW 2,325 8.6 +/-20 ft. water SV3 2,710 8.6 +/-20 ft. water/hydrate SV2 2,860 8.7 +/-20 ft. water/hydrate 9 5/8" Surf Csg 3,140 8.7 +/-20 ft. water SV1 3,200 8.7 +/-20 ft. water UG4 3,535 8.9 +/-20 ft. water UG4A 3,580 8.9 +/-20 ft. Heavy Oil/wtr UG3 3,919 8.9 +/-20 ft. water UG1 4,500 8.7 +/-20 ft. water UG_MA 4,780 8.7 +/-20 ft. water UG_MB1 4,825 8.7 +/- 30' Heavy Oil/wtr UG_MB2 4,875 8.7 +/- 30' Heavy Oil/wtr UG_MC 4,945 8.7 +/- 30' Heavy Oil/wtr NA 5,010 8.7 +1- 30' water NB 5,030 8.7 +/- 30' Viscous oil/wtr NC 5,060 8.7 +/- 30' Viscous oil/wtr NE 5,070 8.7 +/- 30' Viscous oil/wtr NF 5,100 8.7 +/- 30' Viscous oil/wtr OA 5,130 8.6 +/- 30' Viscous oil/wtr OBA 5,170 8.6 +/- 30' wtrNiscous oil OBB 5,200 8.6 +/- 30' wtrNiscous oil OBC 5,245 8.6 +/- 30' wtrNiscous oil OBD 5,294 8.6 +/- 30' wtr/Viscous oil OBE 5,360 8.6 +/- 30' wtr/Viscous oil OBF 5,400 8.6 +/- 30' wtrNiscous oil OBF BASE 5,430 8.6 +/- 30' wtr/Viscous oil CM2 5,750 9.2 +/- 150' poss GCM Fault #1 6,100 9.2 +/- 150' poss GCM CM1/TSLMP 6,530 10.0 +/- 150' poss GCM TLBK (slumped?)poss 6,605 10.0 +/- 100' GCM Fault #2 6,670 10.0 +/- 100' poss GCM THRZ (slumped?) 61770 10.0 +/- 100' poss GCM TKLB 6,785 10.0 +/- 50' poss GCM TKC4 6,815 9.4 +/- 30' oil (%I,A-e� 6 mot' -Ae, 7 7- - V, g /d • 3 /C) Y S-130 PTD Page 3 10/7/2013 TKC3E 6,830 9.4 +/- 30' water TKC2A 6,875 9.4 +1- 30' water TKC1C 6,890 9.4 +/- 30' water TKB/LCU 6,950 9.9 +J- 30' water TKA6 7,020 9.9 +/- 30' water TKA5 7,030 9.9 +/- 30' water TMLV 7,080 10.0 +/- 30' poss GCM TD 7,261 10.0 +/- 30' poss GCM Casinq/Tubing Proqram -P91-14 �,a A``, 4,k- , (en) i0' - i©.Y Hole Size Casing / Tbg O.D. Wt/Ft Grade Conn Length (ft) Top (ft) MD / TVDss Bottom (ft) MD / TVDss - 20" 129# X-56 - 120 Surface 120 / 43 12-1/4" 9-5/8" 40# L-80 BTC 4188 Surface 4188 / 3140 8-3/4" 7" 26# L-80 VaHCop 9803 Surface 9803 / 7261 Tubing 4'/2" 12.6# L-80 TCII 9230 Surface 9230 / 6742 Mud Proqram Surface Hole Mud Properties: Drilplex Spud Mud 1 12-1/4" Hole Section Depth Interval Density PV YP API FL Chlorides pH Funnel Viscosity ppg (cp) Ib/100 ft, ml/30min mg/I sec/ t Surface to 3217' TVD 8.8 — 9.6 30-50 40-80 10 <1000 10.8 60-120 Injection Hole Mud Pro erties: LSND 1 8-3/4" Hole Section Depth Interval Density PV YP API FL HTHP FL MBT pH (pp ) 3217' TVD to 5827' g 2 — 9 8 12 - 18 20 - 28 <6 NC <18 9 - 10 TVD 5827' TVD to TD 10.3 — 10.4 12 - 22 20 - 28 <4 <10 <20 9 - 10 Logging Program 12-1/4"Surface: Sample Catchers - not required for surface hole Drilling: DIR/GR/RES Open Hole: None Cased Hole: None 8-%" Intermediate: Sample Catchers — as required by Geology Drilling: DIR/GR/RES/NEU/DEN/PWD Open Hole: None Cased Hole: Cement Bond Log S-130 PTD Page 4 10/7/2013 Cement Pro ram Casing Size 9-5/8" 40#, L-80 Surface Casing Lead: Annular volume plus 350% excess from surface to Base Perm and 40% excess from Base Basis: Perm to 1000' MD above shoe. Port collar can be used as required by hole conditions. Lead TOC: Surface Tail: Annular volume plus 40% excess from 1 000'MD above shoe, and 80' MD shoe track Tail TOC: 1000' MD above 9-5/8" casing shoe Total Cement Lead 610 bbls, 3425 ft3, 1775 sacks 11.0 ppg DeepCrete, Yield 1.93 ft3/sack Volume: Tail 184 bbls, 473 ft , 408 sacks 15.8 ppg Class G, Yield: 1.16 ft /sack Casing Size 7" 26#, L-80 Injection Casing Basis: Lead: Annular volume plus 30% excess from TOC to 1000' MD above the shoe Lead TOC: 5786' MD 1598' MD below 9-5/8" casing shoe Tail: Open hole volume + 30% excess + 80 ft shoe track Tail TOC: 1000' MD above casing shoe Total Cement Lead 105 bbls, 590 ft3, 337 sacks 11.5 ppg LiteCrete, Yield: 1.75 ft3/sack Volume: Tail 38 bbls, 213 ft , 182 sacks 15.8 ppg Class G, Yield: 1.17 ft"/sack Surface and Anti -Collision Issues Surface Shut-in Wells: S-112i and S-124i will be shut in approximately 1-2 weeks prior to spud date to mitigate any potential pressure interactions while drilling through the Kuparuk sands. Wells affected by the Parker 273 rig shadow include S-31 i, S-33, and S-08. S-31 i and S-08 will be shut in during rig move and drilling. S-33 will be shut in during rig move, but may be put back online if an emergency shut-in device (ESD) is installed. This will be determined by the future S-33 production rates. Ant -Collision: In order to reduce the required shallow directional build rates on S-130i, minor risking parent wellbore S- 110 and sidetrack S-110A is required. Referenced from S-130i, this area of possible collision covers approximately 3400' MD to 3800' MD. Referenced from S-110 this area covers 3325' MD to 3650' MD. S-110 is currently abandoned with cement. S-110A is currently shut in, but a downhole plug will be installed before drilling. Hydrogen Sulfide S-Pad is considered an H2S site. Recent H2S data from the pad is as follows: Well Name H2S Level Reading Date Comments #1 Closest SHL Well H2S Level S-33 24 ppm 2/9/2013 #2 Closest SHL Well H2S Level S-08B 20 ppm 2/10/2013 #1 Closest BHL Well H2S Level S-105 22 ppm 2/15/2013 #2 Closest BHL Well H2S Level S-108 12 ppm 5/29/2011 #3 Closest BHL Well H2S Level S-121 40 ppm 3/17/2013 #4 Closest BHL Well H2S Level S-110 110 ppm 10/8/2007 Max. Recorded H2S on Pad/Facility S-201 500 ppm 6/2/2005 Faults Formation Where Encounter Fault MD TVDss Throw Direction Uncertainty Lost Circ Intersect Intersect and Magnitude Potential Fault #1 - CM2 8510.0' 6090.0' Northeast. 80 ft. +/- 150 ft. Low Fault #2 — TLBK/HRZ (slump) 9156.0' 6675.0' Northeast. 20-30 ft. +/- 150 ft. Low S-130 PTD Page 5 10/7/2013 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 IDS-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 12-1/4" surface hole will be drilled with a diverter. (See attached diverter layout) The 8-3/4" hole section will be drilled with well control equipment consisting of 5000 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 4000 psi (3500 psi annular test). BOP test frequency for S-130 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 3659 psi at @ TKA5 at 7030' TVDss (9.9 ppg EMW) Maximum surface pressure 2948 psi .10 si/ft gas gradient to surface ✓ 25 bbls with a 12.8 ppg fracture gradient Kick tolerance Assumes a 0.5 ppg kick intensity over the anticipated 10.0 ppg pore pressure at interval TD with a 10.3 ppg MW. Planned BOP test pressure Rams test to 4000 psi / 250 psi Annular test to 3500 psi / 250 psi Integrity Test — 8-3/4" hole 12.8 ppg LOT after drilling 20' MD of new formation below the 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 F - 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 bbis has occurred. • The well will be monitored for flow when the pumps are off at each connection. • The planned 8.8-9.6 ppg fluid will provide over balance to formation fluid. • S-128 and S-129 were drilled on S-pad in 2010 with diverter and flow paddle removed to 1000' MD without incident. Operations Summary Pre -Rig Work: 1. Install 20" conductor 2. Weld on an FMC landing ring for the FMC Gen 5 wellhead on the conductor 3. Obtain Static Bottom Hole Pressures (SBHP) from S-105, S-110/S-110A, S-112, and / or S-124 4. Obtain Pressure Falloff Test from S-112 and S-124 5. Shut in S-124 prior to spud date S-130 PTD Page 6 10/7/2013 6. Set a downhole plug in the S-110A tubing tail and fluid pack tubing x IA with kill weight fluid. 7. 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 Parker 273 2. NU diverter spool & riser. Function test the diverter. 3. Prepare mud pits with 8.8 ppg Drillplex mud. 4. Pick up enough HT38 4.0" drill pipe to TD surface hole and stage in derrick. 5. Make up BHA #1 to include 12.25" Milltooth Bit, Bent Housing Motor, Universal Bottom Hole Orientation (UBHO) sub and drill ahead using wire -line gyro until BHA #2 can be buried and/or magnetic interference is clear (-1000' MD). 6. POOH and pick up BHA #2 to include 12.25" Milltooth Bit, Bent Housing Motor, and DIR/GR/RES. 7. Drill surface hole to 4188' MD (60' TVD above the SV1 Top). Perform wiper trip at base of permafrost. At TD CBU until hole is clean. POOH and prepare for casing run. - If backreaming is required trip back to TD. Final trip out must be on elevators. 8. Run 9.625" 40# L-80 BTC casing down to 4188' MD. If required a TAM Port Collar can be run at 500' MD (Discussion with ODE required). 9. Cement surface casing with -610 BBL of 11.0ppg DeepCRETE lead (350% excess from surface to base of perm and a 40% excess from base of perm to 1000' above shoe) Follow with an -84 BBL 15.8ppg G tail (40% excess from 1000' above shoe). Reciprocate casing during cement job. 10. Nipple down diverter and nipple up casing / tubing head. Nipple up and test BOP. (Configured from top to bottom: annular preventer, 2.875"x5.5" VBR, blind / shear, mud cross, 2.875"x5.5" VBR) Test BOP to 250 psi low / 4000 psi high with appropriate test joint (3500 psi annular test). Give the AOGCC 24 hour notice prior to testing. 11. Pressure test the 9.625" surface casing to 250 psi low / 3500 psi high for 5 minutes low / 30 minutes high once 500 psi compressive strength has been achieved. 12. Make up BHA #3 to include 8.75" PDC Bit, Bent Housing Motor, and DIR/GR/RES/NEU/DEN/PWD. v 13. Run in hole and drill out shoe track and swap mud to 9.2 ppg LSND drilling fluid. Drill 20' of new hole, CBU and pull into shoe. Preform LOT to a minimum12.8 ppg for a 25 barrel kick tolerance. 14. Drill ahead to TD at 9803' MD. (200' MD below the TMLV) TD should not be called until LWD/MWD tools have logged the entire Kuparuk formation. - Utilize the following mud weights while drilling the intermediate hole section. 3140' TVDss - 5750' TVDss use 9.2-9.8 ppg 5750' TVDss - 7261' TVDss (TD) use 10.3-10.4 ppg 15. At TD CBU until hole is clean. Short trip to ghost reamer depth (or to achieve MAD pass across Schrader if required). Backream only if necessary. 16. Trip back into hole to TD and CBU until hole is clean. Pull out of hole on elevators. 17. Change upper 2.875"x5.5" VBRs to 7.0" casing rams and test with 7.0" test joint to 250 psi low /4000 psi high. 18. Run 7.0" 26# L-80 VTHC casing down to 9798' MD. 19. Cement casing with 105 BBL 11.5 ppg LiteCrete lead (30% excess from TOC to 1000' above the shoe). Follow with a 38 BBL 15.8ppg G tail (30% excess to1000' above the shoe). Planned Top of Cement is 6430' MD. (650' TVD above the NA) Reciprocate casing during cement job. Bump plug and ensure that floats holds. Pressure test casing to 250 psi low / 4000 psi high for 5 minutes low / 30 minutes high on plug bump. - Displace cement with 10.5 ppg NaCl/NaBr brine. 20. Laydown drillpipe while waiting on cement to reach 500 psi compressive strength. 21. Freeze protect the 7.0"x9.625" annulus from surface to the base of permafrost +150' MD (2238' MD) after cement reaches 500 psi compressive strength. S-130 PTD Page 7 10/7/2013 22. Rig up wire -line and run cement bond log (isolation scanner/ modular sonic imaging platform (MSIP)) from Plug Back Total Depth to Surface. (AOGCC requirement on injection well) 23. Run 4.5" 12.6# L-80 TCII completion tubing down to 9230' MD. Land tubing and Run In Lock Down Screws (RILDS). 24. Reverse circulate clean 10.5 ppg NaCl/Naar brine followed by corrosion inhibited brine. 25. Drop ball and rod down to the RHC-M plug in the XN Nipple at the tubing tail. 26. Set the production packer and pressure test the tubing to 250 psi low / 4000 psi high for 5 minutes low / 30 minutes high. 27. Bleed tubing pressure to 2000 psi. Pressure test the IA to 250 psi low / 4000 psi high for 5 minutes low / 30 minutes high. 28. Hold pressure on the IA and bleed tubing pressures to zero, shearing the DCK shear valve. Pump both ways to confirm circulation ability. 29. Install Two Way Check (TWC) with T-bar. Test from below at 250 psi low / 3500 psi high for 5 minutes low / 30 minutes high. Test from above at 250 psi low / 3500 psi high for 5 minutes low / 30 minutes high. 30. Nipple down the BOPE. Nipple up and test double master valves to 5000 psi / 5 min. 31. RU Drill Site Maintenance (DSM) lubricator and pull Two Way Check (TWC). 32. Freeze protect TxIA to 500 ft TVD by reverse circulating diesel down the IA. Allow the diesel to U- tub between tubing and IA. 33. RU Drill Site Maintenance (DSM) lubricator and install Back Pressure Valve (BPV) into tubing hanger and test to 250psi low / 3500 psi high for 5 minutes low / 30 minutes high from bellow. 34. Install all annulus valves and secure the well. Ensure T/IA/OA all have two barriers in place. 35. RDMO Post Rig Operations: 1. Install tree with electric safety valve. Pull Back Pressure Valve (BPV) 2. Rip up slickline and pull ball and rod / RHC 3. Replace the DCK shear valve with a dummy GLV 4. Perforate underbalanced post -rig with wire -line 5. Rig up slickline and drift/tag to obtain SBHP 6. Flow back to portable separator 7. Water injectivity step rate test below fracture gradient 8. Install wellhouse and flowline 9. Pump RG2401 (Blue -Goo) on top of surface casing cement S-130 PTD Page 8 10/7/2013 S-130 Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE I. Well Control / Reservoir Pressures: A. Surface Hole: Hydrate gas is expected in the S-130 surface hole and has been reported on S-Pad in the past. This has previously been seen in the lower SV and upper UG; roughly 2775' TVDss to 3600, TVDss. S vcx>` wt G B. OverBurden: Formation pressures are expected to range from 8.4 — 8.9 ppg down to the CM2 — Schrader sands are expected to be mostly wet. Gas cut mud (GCM) is possible from the top of the CM2 down through the Kalubik with a 9.2 — 10.0 ppg expected pore pressure. ✓ C. Kuparuk Reservoir: The Kuparuk sands are predicted to be normally pressurized with 9.4 - 9.9 ppg ✓ pore pressure. However, Kuparuk A sand overpressure was seen in the recent S-110A I e rac--The nearby S-112i and S-124i wells will be shut in prior to spud to help minimize this possibility. II. Lost Circulation/Breathing J A. Surface Hole: Lost circulation is considered a minimal risk if mud properties remain in specification. B. Fault Crossings: Two faults will be crossed by S-130. Fault #1 occurs at the CM2 (8510, MD, 6090' TVDss) with an 80' Northeast throw. Fault #2 occurs at a slumped TLBK/HRZ zone (9156' MD, 6675' TVDss) with a 20-30' Northeast throw. The potential for lost circulation at each fault is low as each of these intervals are shale, but hole stability should be considered a risk through these sections. C. Injection Hole: Hole stability and breathing in the Colville, HRZ, and Kalubik sections is considered a key drilling risk. Proper mud weights, mud weight up times (multiple circulations), and managing temperatures during circulations can reduce these risks. III. Intearitv Testina Test Point I Test Depth I Test type I EMW (lb/gal) 9-%" Shoe 120'-50' from the 9-5/8" Shoe LOT 12.8 ppg minimum (25 bbls) IV. Hydrogen Sulfide A. As S-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 500 ppm in S-201 June 2005. V. Faults Formation Where Encounter Fault MD Intersect TVDss Throw Direction Uncertainty Lost Circ Intersect and Magnitude Potential Fault #1 — CM2 8510.0' 6090.0' Northeast. 80 ft. +/- 150 ft. MD Low Fault #2 — TLBK/HRZ (slump) 9156.0' 6675.0' Northeast. 20-30 ft. +/- 150 ft. MD Low VI. Anti -Collision Issues A. Minor risking of S-110/S-110A is required to achieve the necessary surface build rates of S-130. Anti - collision issues with S-110/S-110A occur at approximately 3400' MD to 3600' MD. Prior to drilling S- 110/S-110A will be shut in and a downhole plug installed. Special care will be taken to monitor drilling parameters during this interval. All other well trajectories pass major risk criteria. CONSULT THE S-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. S-130 PTD Page 9 10/7/2013 IHLE 41/Ib-CaVV WELLHEAD = FMC' ACTUATOR = NT1AL KB ELEV= BF. ELEV - KOP = -2800 Max Angle = Datum MD = �8833' Datum- WD = 6700' SS 0 : • 0 , a 20" CONDUCTOR 129#, X-56, D = 19.124 1—� 120- 9-5/8' CSG, 40#, L-80 BTC, D = 8.835" 88 Minimum ID = " ESTMATED TOP OF CEMET 78786 1/2" TBG, 12.6#, L-80 TCI, .0152 bpf, D = 3.958" 1—� —9230 PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: _° @ Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz SHOT SQZ PBTD —9723 17" CSG, 26#, L-80 VAM TOP .0383 bpf, D = 6.276" 1—{ —9803 S 13 0 SAFL TOTES,' H2S READINGS AVERAGE 125 ppm ✓ WHEN ON MI. WELL REQUIRES A SSSV WHEN ON Ml. ^500 9-5/8" TAM PORT COLLAR, ID = " ^2088 Al--�-44--1/2* HES X NIP, D = 3.813' GAS LIFT MANDRELS momo�� • mm —9080 1--14-1/2" HES X NIP, D = 3.813" -9111 -i 7" x 4- t /r HES TNT PKR D = 3.870" 9148 4-1/2" HES D = X NP, 3.813" ^-9218 I—i4-1/2" HES XN NP, D = 3.725" { —9231 (-14-1/2" WLEG, ID=4.00" ��l3MD TT NOT LOGG® �9261 2 - 10" MARKER JOINTS w /RA TAG DATE RE1/ BY COMMENTS DATE REV BY COMMENTS XXIXX/13 INITIAL COMPLETION 09/09/13 PJC BUILD PROPOSAL 09/12/13 TT/PJC MARKER JT CORRECTION ALJRORA LIMIT WELL: S-130 PERMIT No: API No: 50-029- -00 SEC 8, T11N, R12E, 4563' FSL 8 3480' FE7 BP Exploration (Alaska) O C. N� I.L. Q CU 0 C M a V) y O o C v O a G a_ C) M YJ V _ m C ♦ `� m � m J m N I-- N V1 m M o a o p Z L m m C N UHoA n°a° E 0 0 N O L Em �l-ww Mm0° CN O m u`0i E m 0 0 0 N M d Z O N= C m 00 m O m p m 0 O m O N O 2• r M m O m H O t L Z C L m ® O C V F O Z O m O A m « m (n c m A A ] C O Y C O C C O W Q C d LL c .m. 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O O tp 0 u) m o 0 o O O O O O 0 0 0 0 0 o m O O c 0 0 0 0 0 O O O O O O O O O O O O O O O O O 1 0 0 0 0 O G tl Nm t 0000tn O tli gulp mmmmp muj l+l uj Nn000 00000 tri V 000 OojO uj V Ocn O^ O h b V O m O ulp .-mmmm Nu) O V a a000 00 cry rN V Nc `Q m ^O h bN nn mmO�D Nt7 cal Q f� m�NtO m a Q Qb mtmm�r mmmma m a NNNNN NNMc`l c`l chM V V V QQQQ V Q V V Q V V Qu)to mmmmm nm ul ulm mbbbb bb mbb b m,^ oatn tna maaaa aammm mamma maaaa mmaaa aammm mmmma mmmmm aammm a �— to tnbrmm a mamma maa aarn a?a 0?m m a?m o?o?amm m m m m m mmaaa mmaaa aammm m ~ N N N M m m m m m« j m m m m �6 m m m m m m m m m pj m m tU mm to m m m m m m m[ . tc m e tlj tb m t m m tC ry� — — Q p p p p p C N N 2MV b 00ooo 00000 00000 0000 o00o0 0c' O p m OOOOO OOOOOOOOOO O O g O O O l0 Q r 1�rit` t` K uj 0Nto uj uj ujh ujm u to h uj to uj uj uj h to to Ui mh to ui Q t O t[ l m t 0 u] u] t n u l t n m m m m m Q V V M n l t c l a l o l N N N N N N N N N N N N N NNN N N N N N N N N N N N N Q O O m 0 b m n N m r r c`l O O O O O C, o r V O r O V b t V N c O m m O O t O V r r t O O a^ O o u] Q u l O t O OOV Om mm V rN mmlgq OOOOM OOmOa OCI N CI V V mbma ulb V mb roM O NrNm V 0 O O V a r Nn� M htU v O--- - 0 0 0 cj OO tU Ot0 - - tam V tri m uj m m-N'u] m-tV hOtD of tG K m6K K mmmm caul crp �? Omf barb om�O mp O��NN cog col V r m u m rnlO V m nl�-anm br 0 �-N r NNNNN cl V V V V m m mb m mm rr rrr rr n n^^^ ^^^nn ^^^^ ^ m0 Oof m aNi aNi MO m m a O Z O mp d �n m W ¢ C�C7 Z C� m as cl c ma cl mr¢mo cm mmm m`mm#�� 2Y a+YY Y U CO) W cn co ul> »0 O �� W Z2Z Z2000 00000 Uti Ut-LL t-rHri- F- m '0 b m C u]Nm ON A ^ N M 7 M m W Q Q Q Q Q Q C�NNm Nm m"" b b bN mM 7 o N Q21 N N h h b LL} b b 2 m m b m m m a a rn a a m x C e 0 0 0 0 0 m O C uj ui uih h m e O � C J 0 0 0 0 0 O _ = O O O N C O 0 e pmj � C n W f0 tN0 fND W m v Div vi Rio m m m m m m N b M Q m y^ o o 0 Z �d Fi I ai o o a �vmrn No Dui ui ui N NNN N m m h� h b o = umi N umi W m mv.�- v m M > hh�o tNo br h b h b Y] N 93 0 0 0 N- .-. 0 0 09 O N �OOihN� 0m . m o f 0 0 O N D 7 W N_ e rnaaa oim 5 m m m Q Z N N F Ql tU W � fU m N .— E F it z y N Z Z a m F m F- L H N N J J _ N W W 0000 00 LL LL h hhh CN aQD N N N N N J m m U) J J LL u) co n LL LL m � O o b to h m C U b m 0 0 N N m h (n v 0 0 a Y m ow a'a a obi a m : � H O e a e J e C � e U E b h o Y Y Y Y a n by 0 Schlumherger WELL FIELD STRUCTURE S-130 (P8) Prudhoe Bay Unit - WOA S-PAD Magrete Pa2mder5 SuRace Location N D27 Al-ka State Pl Z.. N. U5 Feat MLscelbreous Modal- eGGM 2012 Dip: 81.036' Dale: December 31, 2013 la[ N 702112.906 I'll 59T9B55.00-1 Grb .o 0915' Sbt: Sbt l8—(5-130 plan) T Rat'. Ro[ q Tade(76.8R above MSL) Mag Dec: 19921' F5: 57611 CnT Lon: W1. 1J2.292 Ea ,, 61%3100flU6 Scale Fad: O.%99162fi Pbn. 5-130(P8) I -Date: August O6. 0 1000 2000 3000 4000 5000 0 1000 2000 3000 S O O O m 4000 m U U) 0 t- 5000 6000 7000 RTE KOP Cry 1100 Cry 21100 Cry 2.5/100 Cry 2.751100 End Cry Cry 31100 .. _.._�._.._.. 6---•-------.--:._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.. y._.._.._.._.._.._.._.._.....� End Crv: ..........p.................. se eFm E'w"3/100.. �........... p.................................. _.._ _.._.._.._.._.._ ._.......................... cU_........................ ........ I................ ....... .................... —g— — ....................... _.._.._.._.._.._.._.._. ...................... End Cm ................................ _.._.._.._.._. _ _.._.._.._.._.._.._.._. ......................... .._.._s._.._.._.._.._.._.._.._.._i._.._.. _.._.. ._.._.._j._.._.._.._.._.._.._.._..ti._.._.._.._.._.._.._.._..�.., ............................................ .......................-1..... .......... ................... ..:...................................... Cm 41100 .. _.._;._.._.._.._.._.._.._.._.._;._.._.._.._.._.._.._.._.._;._.._.._.._.._.._.._.._.-._.._.._-.—_--_.-_.._..:.._.._- _ _.._.._.._ ........................ :.:.::..:.:t.::.tt.Il.tt.k:.aa.lk.at..:.t...t.::.ak.ak.:t.t..:.......................o..:t.:t.::..:.a:.........r......t:.tt.tt .t:f51�CNa... ....... .: __._.......................... ------------- _.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._...._.._.._...._.._.._.._.._.._.._.._.._. _.._.._.._.._.._.._.. _.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._._.._.._.._.._.._..__.._.._.._.._.._.._.._.._.._.._.._.._.: ............... Base ........ ......................... .......................... .......................... .......................... _.._.._.._.._.._.._.._ _ ................... ..........j...................................}..................................5...................................j...................................}.................................. n.. .......................... Fit #1: 0 1000 2000 3000 4000 5000 Vertical Section (ft) Azim = 19.59° Scale = 1:1000(ft) Origin = 0 N/—S, 0 E/—V S-130 0 1000 2000 3000 4000 5000 6000 7000 by 0 Schlumherger S-130 (P8) FlELD Prudhoe Bay Unit - WOA 51�E S-PAD Mapretc Panmgen 6urlare I —I" ND27Rb SMa Pore. Zore N.l Feat Nlbpgbreous Mo6el: BGGM Ail Dip: 61.036' Dab: Darembar 31, 2013 u N 192112.906 NONtlnp: 5919655.00M16 GMCam: 0.915' 6bt. Sbt 16 avp(S-130 pbn) —Rq'. RoWgT—(/66Rabova MSL) Map Dac: 19.921' FS: —1—T Lon: w'. 102 . Easti, 61963100— Srab Fla. 0.999916 Ran: 5-130(Ps) Sn D 0, Rapist O6, 2013 -800 0 800 1600 2400 5600 4800 4000 0 3200 0 00 m m U in v 2400 v v 1600 800 0 cry i End Cry 31101 End Cry Cry 2.75/100 Cry 2.51100 Cry 2/100\ .............j............................� KOP Cm 1100 ,,o, RTE 0 800 1600 2400 <<< W Scale = 1:800(ft) E >>> 5600 4800 4000 3200 2400 1600 800 0 0 0 0 O O 0 O O O 0 N C O r rn 7 O O o N o L a N o � o � co m � N (d cn 0 o O n CD 0 o 0 v Cl) O CD 0 O CD L CDV) CD L O L CD L CDL O L O n O (O L to -ItV' c' 7 N N r (ui/usn 0G) uopajedas ailuao of aa}uao I i I m o � i I Cl) to m rn M � � r r Company: North America - ALASKA- BP Project: Prudhoe Bay Reference Site: PB S Pad Site Error: 0.00usft Reference Well: Plan 5-130 (slot 31+15) Well Error: 0.00usft Reference Wellbore Plan S-Kup 130 Reference Design: Plan #8 5-130 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 S-130 (slot 31+15) 5-130 plan @ 76.80usft (D25) S-130 plan @ 76.80usft (D25) True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Reference Plan #8 S-130 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 5.00usft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,176.25usft Error Surface: Elliptical Conic Survey Tool Program From (usft) 40.80 1,100.00 1,100.00 4,190.00 4,190.00 Date 8/6/2013 To (usft) Survey (Wellbore) 1,100.00 Plan #8 S-130 (Plan S-Kup 130) 2,600.00 Plan #8 S-130 (Plan S-Kup 130) 4,190.00 Plan #8 5-130 (Plan S-Kup 130) 5,690.00 Plan #8 5-130 (Plan S-Kup 130) 9,803.26 Plan #8 5-130(Plan S-Kup 130) Tool Name Description GYD-GC-SS Gyrodata gyro single shots MWD MWD - Standard MWD+IFR+MS MWD + IFR + Multi Station MWD MWD - Standard MWD+IFR+MS MWD + IFR + Multi Station 81612013 8.07.01AM Page 2 of 4 COMPASS 5000.1 Build 61 BP Anticollision Report Company: North America - ALASKA- BP Local Co-ordinate Reference: Well Plan S-130 (slot 31+15) Project: Prudhoe Bay TVD Reference: S-130 plan @ 76.80usft (D25) Reference Site: PB S Pad MD Reference: S-130 plan @ 76.80usft (D25) Site Error: O.00usft North Reference: True Reference Well: Plan S-130 (slot 31+15) Survey Calculation Method: Minimum Curvature Well Error: O.00usft Output errors are at 1.00 sigma Reference Wellbore Plan S-Kup 130 Database: EDM R5K-Alaska PROD -ANCP1 Reference Design: Plan #8 S-130 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) PB S Pad S-06 - S-06 - S-06 530.91 525.00 168.35 10.08 158.27 Pass - Major Risk S-07 - S-07 - S-07 548.53 540.00 55.23 9.97 45.26 Pass - Major Risk S-07 - S-07A- S-07A 548.53 540.00 55.23 9.97 45.26 Pass - Major Risk S-08 - S-08 - S-08 689.32 680.00 56.06 15.55 40.50 Pass - Major Risk S-08 - S-08A- S-08A 689.32 680.00 56.06 15.55 40.50 Pass - Major Risk S-08 - S-08B - S-08B 689.32 680.00 56.06 15.55 40.50 Pass - Major Risk S-09 - S-09 - S-09 912.55 900.00 164.32 19.34 144.98 Pass - Major Risk S-10 - Plan S-1 OB - Plan #9 S-1 OB 1,119.97 1,115.00 260.76 21.49 239.27 Pass - Major Risk S-10 - S-10 - S-10 1,120.93 1,105.00 260.77 21.35 239.43 Pass - Major Risk S-10 - S-1 OA - S-1 OA 1.120.93 1,105.00 260.77 21.35 239.43 Pass - Major Risk S-10-S-10APB1-S-1OAPB1 1.120.93 1,105.00 260.77 21.50 239.27 Pass - Major Risk S-109 - S-109 - S-109 2,600.00 2,605.00 395.80 68.60 333.66 Pass - Major Risk S-109 - S-109PB1 - S-109PB1 2,600.00 2,605.00 395.80 68.60 333.66 Pass - Major Risk S-110 - S-110 - S-110 3,522.14 3,355.00 67.14 26.57 47.83 Pass - Minor 1 /200 S-110 - S-110A- S-11 OA 3,547.93 3,395.00 82.01 77.71 19.00 Pass - Minor 1/200 S-121 - S-121 - S-121 2,597.36 2,440.00 414.95 73.55 344.17 Pass - Major Risk S-121 - S-121 PB1 - S-121 PB1 2,597.36 2,440.00 414.95 73.55 344.17 Pass - Major Risk S-123 - S-123 - S-123 583.08 570.00 123.78 11.92 111.95 Pass - Major Risk S-124 - S-124 - S-124 2,562.54 2,575.00 109.17 76.55 32.94 Pass - Major Risk S-13 - Plan S-13A- Plan #10 S-13A 1,487.91 1,465.00 582.99 27.29 555.71 Pass - Major Risk S-15 - S-15 - S-15 416.23 420.00 828.28 10.10 818.17 Pass - Major Risk S-27 - S-27 - S-27 479.80 470.00 238.68 8.72 229.96 Pass - Major Risk S-27 - S-27A - S-27A 479.80 470.00 238.68 8.72 229.96 Pass - Major Risk S-27 - S-27B - 6-27B 483.91 475.00 238.72 8.77 229.96 Pass - Major Risk S-28 - S-28 - S-28 577.56 570.00 200.91 10.03 190.89 Pass - Major Risk S-28 - S-28A- S-28A 577.89 570.00 200.92 10.03 190.89 Pass - Major Risk S-28 - S-28B - S-28B 578.73 570.00 200.93 10.05 190.89 Pass - Major Risk S-28 - S-28BPB1 - S-28BPB1 578.73 570.00 200.93 10.05 190.89 Pass - Major Risk S-29 - Plan S-29B - S-29B wp06 828.37 815.00 88.27 14.44 73.83 Pass - Major Risk S-29 - S-29 - S-29 829.45 815.00 88.28 14.30 73.99 Pass - Major Risk S-29 - S-29A- S-29A 829.40 820.00 88.28 14.45 73.83 Pass - Major Risk S-29 - S-29ALl - S-29AL1 829.40 820.00 88.28 14.45 73.83 Pass - Major Risk S-30 - S-30 - S-30 561.02 550.00 90.40 10.09 80.30 Pass - Major Risk S-31 - S-31 - S-31 514.92 505.00 20.15 8.96 11.20 Pass - Major Risk S-31 - S-31 A - S-31 A 514.92 505.00 20.15 8.96 11.20 Pass - Major Risk S-32 - S-32 - S-32 1,088.72 1,070.00 233.26 21.53 211.73 Pass - Major Risk S-32 - S-32A - S-32A 1,088.72 1,070.00 233.26 21.38 211.88 Pass - Major Risk S-33 - S-33 - S-33 582.75 575.00 19.55 10.04 9.51 Pass - Major Risk S-34 - S-34 - S-34 1,093.85 1,075.00 312.39 18.10 294.35 Pass - Major Risk S-35 - S-35 - S-35 1,213.10 1,195.00 331.72 18.48 313.75 Pass - Major Risk S-38 - S-38 - S-38 1,055.92 1,045.00 189.65 16.76 172.96 Pass - Major Risk S41 - S41 - S-41 3,203.65 3,310.00 542.17 96.54 474.98 Pass - Major Risk S-41 - S-41A- S41A 3,204.74 3,305.00 542.16 97.78 474.66 Pass - Major Risk S-41 - S-41AL1 - S-41 AU 3,204.74 3,305.00 542.16 97.78 474.66 Pass - Major Risk S-41 - S-41 L1 - S-41 L1 3,203.65 3,310.00 542.17 96.55 474.98 Pass - Major Risk S-41 - S-41 PB1 - S-41 PB1 3,203.65 3,310.00 542.17 96.54 474.98 Pass - Major Risk 81612013 8:14:49AM Page 3 of COMPASS 5000.1 Build 61 fit k il 351 ■34i / S010 r-- r 28 N ■32 I � N 0381 ■9 I — I ca 0029 ( I S PAD S PAD I 3� S-130� 36 — — 34 t ppp .7 , •30 ( ■124i I 35 I ■123 I FLARE PIT ■28 %J ■27 ■ 5 M26 025 I VICINITY MAP 04 I N.T.S. ■24 ■21 03 i GRAPHIC SCALE 923 ( 0 100 200 400 020 F ( IN FEET ) 02 t 1 inch = 200 r1. i I 11 M 22,!� i LI i m 8 Jl AIN a LFG ND: + PROPOSED CONDUCTOR I ■ EXISTING CONDUCTOR I ® THERMISTORS -# LIGHT POST — — — UNDERGROUND ELECTRIC NOTES" 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4 NAD27. GEODETIC COORDINATES ARE NAD27. 2- HORIZONTAL AND VERTICAL CONTROL ARE BASED ON S PAD OPERATOR MONUMENTS S-1 AND S-2. J. ELEVATIONS ARE BP EXPLORATION MEAN SEA LEVEL DATUM. 4. MEAN PAD SCALE FACTOR IS., 0.9999165 5. REFERENCE DRAVANG CE--VIPS-00G00, CONSTRUCTION HAZARD DRAIMNG LOCATION. I nrATFn WITHIN PPOTPACTFn CFC 15 T 19 N R 1? F IIA,IIAT ► PPIFIIAN Al ASICA WELL NO. A.S.P. COORDINATES PLANT COORDINATES GEODETIC POSITION(DMS) GEODETIC POSITION(D.DD) CELLAR 80X ELEV, SECTION OFFSETS S-130 Y=5,979,855.00 * N 1710.84 70'21'12.906" 70.3535849' NSA 3,640' FSL X= 619,631.00 E 1000.28 149'01'42.792" 149.0285533' 3,811' FEL S-13S Y=5,979,294.00 N 964.56 70'21'07.505" 70.3520848' NSA 3,091' FSL X= 618,885.00 E 1561.04 149'02'04.856" 149.0346822- 4,567' FEL DECAMP .._ CNIINED: ww p 11 --- DATE: PRO1373 DUOS 02_ _ WOA S PAD SHEET y_ (_ +oe No, PROPOSED CONDUCTOR LOCATION omens xKl. 1 of 1 1--200' WELLS S-130 d1: 135 "0 OATE REWS014 FW [,-,t Ln a, 0 O 0 0 Ln M O 0 0 r, 0 0 0 a) Lnx _0 a) -0 —0 J N a) aj d - .3 .✓ � p 30 0 rp j 3 .n'p L? (D _ Mi o a) ° E -c 5) _ w N N c 0) 7 a) a) a) o 2 Y a l` W6 sue - Z 00 i e°'s r 1 N r f 1 9 1 1 1 1 1 I f ors 1 1 1 i r 1 t 1 1 1 1 �0 1 JOB" 0 i i I IHI 5L a m Redacted by M. Guhl 9/2/2021 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 PARKER 272 BOP STACK 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 •O W (2) 3 1/8"-5M SIDE OUTLETS ..,. o 0 o•d 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 o S� r o 0 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 3UCL P,_L'G F_G 1OR- ND Fi-G TION PORT Mc CORPORATION :AD EQUIPMENT DIVISION {OUMN.'IE%AS i VVIO%4013 TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: 5 Development V Service Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: POOL: �� t ''«�- C)6 Check Boa for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are Well Logging m 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, AURORA OIL - 640120 PTD#:2131500 Company BP EXPLORATION (ALASKA) INC Initial Class/Type Well Name: PRUDHOE BAY UN AURO S-130 Program SER Well bore seg SER / PEND GeoArea 890 Unit 11650 On/Off Shore On Annular Disposal Administration 1 Permit fee attached NA 2 Lease number appropriate Yes Entire well lies within ADL 028257. 3 Unique well name and number Yes 4 Well located in a defined pool Yes PRUDHOE BAY, AURORA OIL - 640120, governed by CO 457B 5 Well located proper distance from drilling unit boundary Yes CO 457B, Rule 1: Spacing units within the pool shall be a minimum of 40 acres. 20 AAC 25.055(a)(1) and (2) 6 Well located proper distance from other wells Yes shall not apply to property lines within the external boundaries of the Aurora Participating 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 10/10/2013 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For Yes AIO 22E 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) No 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D) Yes 18 Conductor string provided Yes Conductor set to 120' Engineering 19 Surface casing protects all known USDWs Yes Surface casing set to 3217' TVD 20 CMT vol adequate to circulate on conductor & surf csg Yes 198% excess planned 21 CMT vol adequate to tie-in long string to surf csg No TOC 5786' MD 22 CMT will cover all known productive horizons Yes Injection interval will be completed with injection casing, 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; no major risk failures; 27 If diverter required, does it meet regulations Yes Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure is 3659 psi(7030' TVD)9.9 ppg EMW; will drill w/ 9.2-10.4 ppg EMW VLF 10/22/2013 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MPSP is 2948 psi; BOPS test pressure is 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 No wells within quarter mile radius 35 Permit can be issued _w/o hydrogen sulfide measures No S-Pad wells are H2S-bearing. Per 20 AAC 25.065(b), H2S measures are required in conformance Geology 36 Data presented on potential overpressure zones Yes with API RP 49 _(1987). 0' - 8135' MD; expect_ gradient equivalent to 8.4 - 8.9 ppg, will be Appr Date 37 Seismic analysis of shallow gas zones NA drilled using 8.8 - 9.8 ppg mud. 8135' to TD: expect gradient equivalent to 9.2 - 10.0 ppg; will be SFD 10/10/2013 38 Seabed condition survey (if off -shore) - NA_ drilled using_10.3 - 10.4 ppg mud. 39 Contact name/phone for weekly progress reports [exploratory only] NA_ Geologic Engineering Pjiblic Gas hydrates are expected from about 3450' to 5000' MD. Warning and mitigation measures are contained in the "S-130 Drilling Commissioner: Date: Commissio P,r: Date er Date Critical Issues" section of the application. SFD 10/10/13
