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Home My WebLink About220-0331 Guhl, Meredith D (OGC) From:Guhl, Meredith D (OGC) Sent:Wednesday, June 29, 2022 10:02 AM To:Abbie Barker; Carrie Janowski; Cody Dinger; Darci Horner - (C); Donna Ambruz; Jerimiah Galloway; Joseph Lastufka; Josh Allely; Juanita Lovett; Tom Fouts Subject:PBU Expired Permits: 220-029, 220-031, and 220-033 Hello, The following Permits to Drill, issued to Hilcorp North Slope, have expired under Regulation 20 AAC 25.005 (g). The PTDs will be marked expired in the AOGCC database.  PBU K‐322, PTD 220‐029, issued 2 April 2020  PBU 11‐41, PTD 220‐031, issued 27 March 2020  PBU 04‐31A, PTD 220‐033, issued 31 March 202 If you have any questions, please contact me. Thank you, Meredith Meredith Guhl (she/her) Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793‐1235 CONFIDENTIALITY NOTICE: This e‐mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e‐mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907‐793‐1235 or meredith.guhl@alaska.gov. Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Kenneth Allen Engineering Team Lead BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 04-31A BP Exploration (Alaska), Inc. Permit to Drill Number: 220-033 Surface Location: 379’FNL, 528’FWL, SEC. 35, T11N, R15E, UM Bottomhole Location: 2224’FNL, 955’FWL, SEC. 35, T11N, R15E, UM Dear Mr. Allen: Enclosed is the approved application for the permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jeremy M. Price Chair DATED this ___ day of March, 2020. Sincerely, Jeremy M Price 31 1a. Contact Name:Mclaughlin, Sean M Contact Email:Sean.McLaughlin@bp.comAuthorized Name:Allen, Kenneth W Authorized Title:Engineering Team Lead Authorized Signature: Contact Phone: Approved by: COMMISSIONER APPROVED BY THE COMMISSION Date: 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Drill Type of Work: Redrill 5 Lateral 1b.Proposed Well Class:Exploratory - Gas 5 Service - WAG 5 1c. Specify if well is proposed for: Development - Oil Service - Winj Multiple Zone Exploratory - Oil Gas Hydrates Geothermal BP Exploration (Alaska), Inc Bond No. 29S105380 11.Well Name and Number: PBU 04-31A TVD:11551'8592' 12. Field/Pool(s): PRUDHOE BAY, PRUDHOE OIL MD: ADL 028324 70-039 July 1, 2020 4a. Surface: Top of Productive Horizon: Total Depth: 379' FNL, 528' FWL, Sec. 35, T11N, R15E, UM 2383' FNL, 2814' FWL, Sec. 35, T11N, R15E, UM 2224' FNL, 955' FWL, Sec. 35, T11N, R15E, UM Kickoff Depth:9430 feet Maximum Hole Angle: 115 degrees Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole:Surface:3340 2640 17.Deviated wells:16. Surface: x- y- Zone -713369 5951509 ASP 4 10. KB Elevation above MSL: GL Elevation above MSL: feet feet 62.00 31.20 15.Distance to Nearest Well Open to Same Pool: Cement Quantity, c.f. or sacks MD Casing Program: 8590'7902' 19.PRESENT WELL CONDITION SUMMARY Production 80 1925# Poleset 9870 9102 9446, 9553 9446 8695 9478, 9497, 9553 32 - 112 Surface 2300 sx PF 'E', 400 sx PF 'C', 100 sx PF 'E' 8632 -8957 Seabed Report Drilling Fluid Program 5 20 AAC 25.050 requirements Shallow Hazard Analysis 5 Commission Use Only See cover letter for other requirements: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes No H2S measures Yes No Spacing exception req'd: Yes No Mud log req'd: Yes No Directional svy req'd: Yes No Inclination-only svy req'd: Yes No Other: Date: Address: Location of Well (State Base Plane Coordinates - NAD 27): 6.6#/6.5#13Cr85 2443 3-1/4"x2-7/2960' 9380 - 9720 29-21334-01-00 29 - 9364 300 sx Class 'G' Intermediate Conductor/Structural Single Zone Service - Disp NoYesPost initial injection MIT req'd: NoYes 5 Diverter Sketch Sr Pet Eng Sr Res Eng TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Stratigraphic Test Development - Gas Service - Supply Coalbed Gas Shale Gas 2.Operator Name: 5.Bond Blanket 5 Single Well 3. P.O. Box 196612 Anchorage, AK 99519-6612 6. Proposed Depth: 7. Property Designation (Lease Number): 8. DNR Approval Number:13.Approximate spud date: 9.Acres in Property: 14. 23414 Distance to Nearest Property: Location of Well (Governmental Section): 4b. 2560 1050 18.Specifications Top - Setting Depth - Bottom Casing Weight Grade TVDHole Coupling MDLengthTVD (including stage data) 4-1/4"TCII/STL 11550' 8592'223 sx Class 'G' (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft):Plugs (measured):Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk(measured): Casing Length Size MD 20"32 - 112 13-3/8"31 - 2474 31 - 2473 9335 9-5/8" Liner 815 7"9040 - 9855 8311 - 9087 Perforation Depth MD (ft):Perforation Depth TVD (ft): 20. Attachments Property Plat BOP Sketch 55 Drilling Program 55 Time v. Depth Plot Permit to Drill Number:API Number : 50 Permit Approval Date: Reentry 500 sx Class 'G', 300 sx PF 'C', 660 sx Class 'G' Hydraulic Fracture planned? 29 - 8617 Cement Volume Sr Pet Geo Form 10-401 Revised 3/2020 This permit is valid for 24 months from the date of approval (20 AAC 25.005(g)) 79'VV Kenneth Allen Digitally signed by Kenneth Allen Date: 2020.03.26 13:20:43 -08'00' By Samantha Carlisle at 1:44 pm, Mar 26, 2020 MGR27MAR20 SFD 3/26/2020 220-033 DSR-3/26/2020 * 24 hour notice for BOPE test to 3500 psi *Variance to 20 AAC 25.112(i) approved for alternate plug placement. GR27MAR20 03/31/2020 JLC 03/31/2020 To: Alaska Oil & Gas Conservation Commission From: Sean McLaughlin CTD Engineer Date: March 25, 2020 Re: 04-31A Permit to Drill Request Approval is requested to drill and complete the proposed 04-31A coiled tubing sidetrack. Proposed plan for 04-31A: The sidetrack will be a ~2120’ horizontal CST that will kick-out from the parent in Zone 3. The CST will establish competitive offtake in Zone 2. During pre-rig work it is proposed to set a 4-1/2” x 7” Delta whipstock at a kickoff depth of ~9430’ MD. CT will mill the 3.8” window pre-rig + 10’ of rat hole. The rig will move in, test BOPE and kill the well prior to drilling the build and lateral sections. The proposed sidetrack will be completed with a 3-1/4” x 2-7/8” 13-Cr solid liner and cemented in place. The rig will perforate ~1000 ft. The following describes the work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current well and proposed sidetrack is attached for reference. Pre-Rig Work (scheduled to begin May 1st, 2020) 1. SL Dummy GLMs. MIT-IA. Drift for Whipstock 2. EL Set Delta Whipstock. 3. C Mill Window at 9430’ 4. V Pre-CTD Tree work. Rig Work (scheduled to begin July 2020) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2460 psi). 2. Drill production section: ~4.25" OH to 11550’ 3. Run 3-1/4” x 2-7/8” 13Cr liner to TD. 4. Pump primary cement job: 46 bbls, 15.3 ppg Class G, TOC at TOL (~8590’ MD)*. 6. Perforate Wellbore. 2” Maxforce guns planned (~1000’, 6spf, planned). 7. Freeze protect well to a min 2,200' TVDss. 8. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) Post-Rig Work: 1. V: Valve & tree work 2. SL/FB: Set LTP if needed. PT LTP. Set LGLM. 3. T: Portable test separator flowback Sundry 320-136 24 hour notice for AOGCC to witness BOPE test to 3500 psi, 24 hour notice for AOGCC to witness. PTD 220-033 Mud Program: x Drilling/Completion: a min EMW of 8.4 ppg KCL with Geovis for drilling (503 psi over-balance). Disposal: x All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4 or Pad 3 at DS 6. x Fluids >1% hydrocarbons or flammables must go to Pad 3. x Fluids >15% solids by volume must go to GNI. x Fluids with solids that will not pass through 1/4” screen must go to GNI. x Fluids with PH >11 must go to GNI. Hole Size: x ~4.25” for entirety of the production hole section. Liner Program: x 2-7/8”, 6.5#, STL, 13Cr solid liner: 9911’ MD – 11550’ MD x 3-1/4”, 6.6#, TCII, 13Cr solid liner: 8590’ MD – 9911’ MD x A planned 46 bbls of 15.3 ppg cement will be used for liner cementing (TOC = TOL at ~8590’ MD). x The primary barrier for this operation: a minimum EMW of 8.4 ppg. x A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Well Control: x BOP diagram is attached. x Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. x The annular preventer will be tested to 250 psi and 3,500 psi. Directional: x See attached directional plan. Maximum planned hole angle is 115°, inclination at kick off point is 17°. x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. x Distance to nearest property – 23414’ x Distance to nearest well within pool – 1050’ Logging: x MWD directional, Gamma Ray, and Resistivity will be run through the entire open hole section. Perforating: x Perforating: ~1000’ of perforations, 2”, 60 deg random phasing, 6 spf, perf guns. x The primary barrier for this operation: a minimum EMW of 8.4 ppg. x A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Anti-Collision Failures: x None. All offset wells pass BP anti-collision scan criteria. Hazards: x DS 04 is an H2S pad. Max recorded H2S reading on 04-31: 50 ppm on 5/10/2019. Max H2S recorded on the pad: 1400 ppm on 04-41A on 1/12/2016. x One potential fault crossing at 11333’ MD. x Lost circulation risk is considered Low. Reservoir Pressure: x The reservoir pressure on 04-31A is expected to be 3340 psi at 8800’ TVDSS (7.3 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2460 psi. x A min EMW of 8.4 ppg for this well will provide 503 psi over-balance to the reservoir. Sean McLaughlin CC: Well File CTD Engineer Joseph Lastufka 223-6784 DS 04 is an H2S pad. MWD directional, Gamma Ray, and Resistivity w EMW of 8.4 ppg f S (7.3 ppg equivalent). !"#$%&#! '"(#) *+, *$ $ -( )! " ! " ,. #, .$%!& '()% , * *' +* ,-./'01).$! *# $(."/, "'0$(.", "'(%.3 4 '%.35)6 '7.-35 &8-9::%;)$%.35)6 '+'(< 7.-35 &8-! 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" = = = @>#., ?>. #,.#@ # # # >#. >-#. =?.=, -= -= -= >=?,.,, ->. .-, -= -= -= >==-., ->. .@ -= -= -= >==-., ->. .@ -= -= A >==-., ->. .@ -= -= -= >==-., ->. .@ @-.= @-#. ,?.= @-.= @-#. ,?.= 2 =>@-#. =>@-#. .? - - - ->,-#.=- ->,-#. -.- - - - ->,-#.=- ->,-#. -.- - - A ->,-#.=- ->,-#. -.- @ @ @ @-.#? @-#. @.@@ ->. ->#. =?.?? ->,.# ->@#. ?.@- 6 17 $ 17&#$$$$8 2,+$ Well Bighole Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 6.0 ft Top of Annular Element 6.7 ft Bottom Annular 8.0 ft CL Blind/Shears 9.3 ft CL 2-3/8" Pipe/Slips 10.1 ft B1 B2 B3 B4 Choke Line Kill Line CL 2-3/8" x 3-1/2" VBRs 12.6 ft CL 2-3/8" Pipe/Slips 13.4 ft CL of Top Swab 16.0 ft Swab Test Pump Hose T1 T2 Swab 1 CL of Flow Cross 17.4 ft Master CL of Master 18.8 ft LDS IA OA LDS Ground Level CDR2-AC 4 Ram BOP Schematic 21-Nov-17 CDR2 Rig's Drip Pan 7-1/16" 5k Flange X 7" Otis Box Hydril 7 1/16" Annular 2-3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8"Pipe/Slips Blind/Shear 7-1/16" 5 Mud Cross 2-3/8" x 3-1/2" VBRs WELL PERMIT CHECKLISTCompanyBP Exploration (Alaska) Inc.Well Name:PRUDHOE BAY UNIT 04-31AInitial Class/TypeDEV / 1-OILGeoArea890Unit11650On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2200330PRUDHOE BAY, PRUDHOE OIL - 640150NA1 Permit fee attachedYes Entire well in ADL 028324.2 Lease number appropriateYes3 Unique well name and numberYes PRUDHOE BAY, PRUDHOE OIL POOL - 64015, governed by CO 341H4 Well located in a defined poolYes CO 341H, Rule 2: There shall be no restrictions as to well spacing except that no pay shall be5 Well located proper distance from drilling unit boundaryYes opened in a well closer than 500 feet to the boundary of the affected area.6 Well located proper distance from other wellsYes As planned, well conforms to spacing requirements.7 Sufficient acreage available in drilling unitYes8 If deviated, is wellbore plat includedYes9 Operator only affected partyYes10 Operator has appropriate bond in forceYes11 Permit can be issued without conservation orderYes12 Permit can be issued without administrative approvalYes13 Can permit be approved before 15-day waitNA14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (ForNA15 All wells within 1/4 mile area of review identified (For service well only)NA16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)NA 04-31A is a CTD sidetrack. All drilling will be in the reservoir from existing parent well.18 Conductor string providedNA 04-31A is a CTD sidetrack. All drilling will be in the reservoir from existing parent well.19 Surface casing protects all known USDWsNA 04-31A is a CTD sidetrack. All drilling will be in the reservoir from existing parent well.20 CMT vol adequate to circulate on conductor & surf csgNA 04-31A is a CTD sidetrack. All drilling will be in the reservoir from existing parent well.21 CMT vol adequate to tie-in long string to surf csgYes Fully cemented solid liner into parent well production tubing.22 CMT will cover all known productive horizonsYes23 Casing designs adequate for C, T, B & permafrostYes CDR2 has adequate tankage and good truck support.24 Adequate tankage or reserve pitYes Sundry 320-136 approved by staff.25 If a re-drill, has a 10-403 for abandonment been approvedYes Planned wellpath has no close approaches to existing wells.26 Adequate wellbore separation proposedNA Not applicable. 04-31A is a CTD sidetrack. All drilling will be in the reservoir from existing parent well.27 If diverter required, does it meet regulationsYes All fluids overbalanced to reservoir.28 Drilling fluid program schematic & equip list adequateYes 1 CTD packoff, 1 annular, 4 ram stack, 1 flow cross29 BOPEs, do they meet regulationYes 5000 psi stack tested to 3500 psi30 BOPE press rating appropriate; test to (put psig in comments)Yes31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownYes DS04 is an H2S pad. Standard BP monitoring will be in place.33 Is presence of H2S gas probableNA This well is a producer.34 Mechanical condition of wells within AOR verified (For service well only)No DS 04 wells are H2S-bearing. H2S measures are required.35 Permit can be issued w/o hydrogen sulfide measuresYes Expected reservoir pressure is 7.3 ppg EMW; will be drilled using 8.4 ppg mud and coiled tubing. Should36 Data presented on potential overpressure zonesNA higher pore pressures be encountered, BP has immediate access to nearby fluid37 Seismic analysis of shallow gas zonesNA mixing facilities. One fault crossing planned at 11,333' MD. Risk of lost circulation is low.38 Seabed condition survey (if off-shore)NA39 Contact name/phone for weekly progress reports [exploratory only]ApprSFDDate3/26/2020ApprMGRDate3/27/2020ApprSFDDate3/26/2020AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateGWVJMP 03/31/2020JLC 03/31/2020