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220-012
From:Guhl, Meredith D (OGC) To:Abbie Barker; Carrie Janowski; Cody Dinger; Darci Horner - (C); Donna Ambruz; Jerimiah Galloway; Joseph Lastufka; Josh Allely; Juanita Lovett; Tom Fouts Subject:Expired Prudhoe Bay PTDs Date:Wednesday, April 27, 2022 1:42:00 PM Hello, The following Permits to Drill, issued to BP Exploration (Alaska) and transferred to Hilcorp North Slope, have expired under Regulation 20 AAC 25.005 (g). The PTDs will be marked expired in the AOGCC database. PBU LIS K-333, PTD 220-004, issued February 3, 2020 PBU 06-15A, PTD 220-012, issued January 30, 2020 PBU LIS L3-26, PTD 220-015, issued February 12, 2020. 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. THE STATE GOVERNOR MIKE DUNLEAVY Sean Mclaughlin Engineering Team Lead BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 06-15A BP Exploration (Alaska), Inc. Permit to Drill Number: 220-012 Surface Location: 355' FSL, 1753' FEL, SEC. 02, T10N, R14E, UM Bottomhole Location: 432' FNL, 1317' FEL, SEC. 11, T10N, R14E, UM Dear Mr. Mclaughlin: Enclosed is the approved application for the permit to redrill the above referenced development well. 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. 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, Jae Price Char 120, DATED this - day of January, 2020. STATE OF ALASKA ASKA OIL AND GAS CONSERVATION COMMISS PERMIT TO DRILL 20 AAC 25.005 AN? �? la. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1c. Specify if well is proposed for: Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development - Oil IZ Service - Winj ❑ Single Zone CQ Coalbed Gas ❑ Gas Hydrates ❑ Redrill R) Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond Blanket 0 Single Well ❑ 11 Well Name and Number: BP Exploration (Alaska), Inc Bond No. 29S105380 I PBU 06-16A Address: 3. 6. Proposed Depth: TVDss: 8733' 12. Field/Pool(s): P.O. Box 196612Anchoraae.AK99519-6612 MD: 10941' TVD: 8801, PRUDHOE BAY, PRUDHOE OIL 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): ADL6B8814 Surface: 355' FSL, 1753' FEL, Sec. 02, T10N, R14E, UM 0 -- B 30 8. DNR Approval Number: 13, Approximate spud date: Top of Productive Horizon: 1421' FSL, 1432' FEL, Sec. 02. T10N, R14E, UM 72-019 March 1, 2020 9. Acres in Property: 2560 14. Distance to Nearest Property: Total Depth: 432' FNL, 1317' FEL, Sec. 11, T10N, R14E, UM 20695 41b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 68.00 feet 15. Distance to Nearest Well Open to Same Pool: Surface: x- 685235 y- 5940935 Zone - ASP 4 GL Elevation above MSL: 38.00 feet 800 16. Deviated wells: Kickoff Depth: 8815 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 106 degrees Downhole: 3300 Surface: 2423 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD(including stage data 4-1/4" 3-1/2"x3-1/4" 9.3#/6.6# 13Cr85 STL/TCII 2901' 8040' 7839' 10941' 8801' ✓ x2-7/8" /6.5# /STL 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): TEffect. Depth TVD (ft): Junk (measured): 9540 9328 None 9439 9227 None Casing Length Size Cement Volume MD TVD Conductor/Structural 80 20" 300 sx PF II 30 - 110 30 - 110 Surface 2648 13-3/8" 2200 sx Fondu 30 - 2678 30 - 2678 Intermediate 8595 9-5/8" 500 sx Class'G', 300 sx CS I, 586 sx Class'G' 28 - 8623 28 - 8414 Liner 6603 7" 275 sx Class'G', 823 sx Class'G', 144 sx Class'G' 2632 - 9535 2932 - 9323 Scab Liner 1241 4-1/2" 288 sx Class'G' 8198 - 9439 7994 - 9227 Perforation Depth MD (ft): 9100 - 9264 Perforation Depth TVD (ft): 8889 - 9053 Hydraulic Fracture planned? Yes ❑ No 0 20. Attachments Property Plat ❑ BOP Sketch 0 Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21 Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated Contact Name Hvatt. Trevor from without prior written approval. Authorized Name Mclaughlin, Sean M Contact Email Trevor.Hyatt@bp.com Authorized Title Engi ring Te 9m Lead - CTD Contact Phone +1 907 564 4627 Authorized Signature Date d Commission Use Only Permit to Drill API 50-029-20459-01-00 it Approval TDate a cover letter for other Number: .— 0 : quirements: 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: p� Other: 1V>mQE7'"V` EVT"-' o X 5"CO©'ps Samples req'd: Yes ❑ No N I Mud log req'd: Yes ❑ No lv Z cA*-- ZS if zC-,) H2S measures Yes d No ❑ Directional svy req'd: Yes V No [I Spacing exception req'd: Yes ElNo L7./ inclination -only svy req'd: Yes ❑ No Q, Post initial injection MIT req'd: Yes ❑ No ❑ A � APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: v V O vo -W v UMMINAL Form 10-401 Revised 5/2017 This permit is valid for 24 months from the date of approval (20 AAC 25.005(g)) lv-c�whb ,Oe112 ;�6201-o Submit Form and Attachments in Duplicate To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt t)bp CTD Engineer Date: January 22, 2020 Re: 06-15A Permit to Drill Request Approval is requested for a permit to drill a CTD sidetrack lateral from well 06-15 with the Nabors CDR2 Coiled Tubing Drilling rig on or around March 2020. History of 06-15: Proposal to coil sidetrack 06-15 (an original well location on DS-06 in the GDWFI) to add 2 fresh offtake points in the GDWFI oil pad away from the parent well. 06-15 was drilled in 1980. The well has a long history of squeezes (for gas shut offs), perfs, and reperfs, but the well continued to produce from squeezed perfs. There was a Cretaceous leak that was fixed in 2000, and a rig workover in 2008 where a scab liner was placed across the production section. This well has been popped a handful of times since the RWO, though performance has been mediocre, and the well has had very low on -time over the past decade. The poor performance may be due to the GDWFI oil pad moving up and down within the reservoir, or other factors like Cretaceous damage around the wellbore. Sidetracking the well to the south, to the thicker GDWFI oil column, will return this well to a competitive state, recover more resources, thereby adding value to the business. Proposed plan for 06-15A: A ^2,100' coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The whipstock will be set pre -rig in the 4-1/2" scab liner. The rig will move in, test BOPE and kill the well. A dual string window exit (4-1/2" x 7") + 10' of rathole will be / milled. The well will kick off in the Shublik, build through Zone 4, 3 and 2 to land. Then the well will build back up to Zone 4 ✓ at TD. The proposed sidetrack will be completed with a 3-1/2" x 3-1/4" x 2-7/8" 13Cr solid liner, cemented in place and selectively perforated post rig. This completion will completely isolate and abandon the parent Ivishak perfs. Rig Work (scheduled to begin March 2020) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP: 2423 psi). 2 4i/tr-Ad IC,<. 2. Mill dual string window (4-1/2" x 7") 3. Drill build section: 4.25" OH, "322' (28 deg DLS planned). 4. Drill lateral section: 4.25" OH, —1804' (12 deg DLS planned). 5. Run open hole logs (Sonic/Den/Neu) — if needed. 6. Run 2-7/8" x 3-1/4" x 3-1/2" 13Cr liner to TD. 7. Pump primary cement job: 32.2 bbls, 15.3 ppg Class G, TOC at TOL (-8,040 MD). 8. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) Post-Rig Work: 1. V: Valve & tree work 2. S: SBHPS, set LTP* (if necessary). Set live GLVs. 3. T: Portable test separator flowback. A�cc- Operation Details: �(�c�l �>zz Mud Program: • Drilling/Completion: a min EMW of 8.4 ppg KCL with Geovis for drilling (540 psi over -balance). Disposal: • All Class 1 & II non -hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4 or Pad 3 at DS 6. • Fluids >1% hydrocarbons or flammables must go to Pad 3. Fluids >15% solids by volume must go to GNI. • Fluids with solids that will not pass through 1/4" screen must go to GNI. • Fluids with PH >11 must go to GNI. Hole Size: • 4.25" for entirety of the production hole section. Liner Program: • 2-7/8", 6.5#, 13Cr solid liner: 10,200' MD—10,941' MD • 3-1/4", 6.6#, 13Cr solid liner: 8,060' MD—10,200' MD • 3-1/2", 9.3#, 13Cr solid liner: 8,040' MD — 8,060' MD • A planned 32.2 bbls of 15.3 ppg cement will be used for liner cementing (TOC = TOL at—8,040' MD). • The primary barrier for this operation: a minimum EMW of 8.4 ppg (540 psi over -balance) • A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. • The annular preventer will be tested to 250 psi and 3,500 psi. Directional: • See attached directional plan. Maximum planned hole angle is 106°, inclination at kick off point is 7°. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property line — 20,695' & Distance to nearest well within pool — 800' Logging: • MWD directional, Gamma Ray, and Resistivity will be run through the entire open hole section. Sonic/Den/Neu will be run in open hole if needed. Perforating: • Perforating: —100' of perforations (post rig) — 2", 60 deg random phasing, 6 spf, pert guns. • A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Anti -Collision Failures: • 06-23B P131 fails Major Risk. The wellbore is P&A'd and failure depths are in the reservoir, below production packer and sidetrack point of 06-23C. Hazards: J • Drill Site 6 is considered an H2S pad. Most recent H2S reading on 06-15: 38 ppm (05/02/2019). Max H2S reading on pad on well 06-14: 300 ppm (06/12/2011) J • Overall Lost circulation risk is considered low. Reservoir Pressure: ✓ • The reservoir pressure is expected to be 3300 psi at 8800' TVDSS (7.22 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2423 psi. Trevor Hyatt CC: Well File CTD Engineer Joseph Lastufka 564-4627 TREE = 4-1/16" 5M CAN WELLHEAD = FMC ACTUATOR = BAKER C OKB. ELEV = 68' BF. ELEV = 38.15' KOP = 5200' Max Angle = 28' @ 57W Datun MD = 9079' Datum TVD = 88W SS 9-5/8" CSG, 47#, L-80 HY DRL 563, D = 8.681' 1753' 13-318" CSG, 72#, N-80 BTC, 9) 12.347" 2678' TOP OF 7" SCAB LNR-�2932' 06-15 7" SCA B LNR, 26#, L-80 BTC XO TO I 7793' 13CR-80 VAM TOP Minimum ID = 3.725" ac 8069' 4-112" HES XN NIPPLE 9-5/8" CSG, 47#, L-80 BTC XO TO S 95 BTC 8065' — 12.6#, 13CR-80 VAM TOP, 8081' 0152 bpf, ®= 3.958' TOP OF 4-1/2- SCAB LNR $19$' FSAk _ . Y NOTES: —CHROME TBG & Mr.. -I 1736' I-19-5/8' HES CBNENTER - 2076' 4-1/2" HES X NP, m = 3.813' 2932' 9-5/8' X T BKR ZXP LTP, ®= 629' 2950' 9-5/8" X 7" BKR FLEX LOCK LNR HGR, ID = 6.30- GAS LIFT MANDRELS 3T MD I TVD DEV I TYPE I VLV LATCH I PORT DATE 4 3373 3373 0 KBG2-1 R DONE BK 16 07/04/19 3 5585 5566 23 KBG2-1 R SO BK 20 07/04/19 2 7154 6978 19 KBG2-1 R DMY BK 0 07/04/19 1 7846 7649 12 KBG2-1R DMY BK 0 07/04/19 7943' T X 4-1/2" BKR S-3 PKR, ® = 3.938" - 800T 4-1/2' HES X NP, ED = 3.813" BOW 4-1/2" HES XN NIP. ® = 3 725- 8081'-14-1/2- WLEG, ID = 3.958- 8198' 7" X 5" BKR ZXP LTP w / HMC LNR HGR & XO, ID = 4.276" ITOP OF 7- LNR 8299' 8299' BOT TACK SLV, ®= 7 7" SCAB LNR, 26#,13CR-80 VAM TOP, 8305' 8305' 9-5/8' X 7' BOT HYDRA LNR HGR, ®= 7 .0383 bpf, ID = 6.276" 9-5/8' CSG, 47#, S-95 BTC, O = 8.681- 1-� 8623' 8827' H 7- MARKER JOINT PERFORATION SUMMARY REF LOG: BHCS ON 07/20/80 ANGLEAT TOP PERF: 4" @ 9100' Note: Refer to Production DB for historical perf data SV-E SPF I INTERVAL I Opn/Sgz I DATE SEE PAGE 2 FOR PERFORATION DATA 4-1/2- SCAB LNR, 12.6#, 13CR-80 VAM TOP, 9359' XO TO L-80 HT 4-1/2' SCAB LNR 12.6#, L-80 HT, 9439' 0152 bpf, ID = 3.958' PBTD 9"7" 7- LNR, 29#, L-80 BTC, .0371 bpf, ® = 6.184' 1 m35' DATE I REV BY COMMENTS DATE REV BY COMMENTS 07131/801 ORIGINAL COMPLETION 07/31/15 JMM/JMD PULL PLUG/SETXN LOCK w/IUD 12MBISO LAST WORKOVER 05/07/18 JMG1JMD PULLED UD (05/05/18) 06/21/08 D16 RWO 07/10/18 MS/JMD ADPERFS (07/08/18) 01/14/09 RLM/SV REPERF (01113109) 07/15/19 GJB/JMD GLV C/O (07/04/19) 05/30/09 ???/TLH PERF 04/11/09 08/27/19 BTN/JMD ADPERFS (08/24/19 12/17/09 MBM/SV SET PXN PLUG (12/09/09) 01/22120 JNUJMD ADDED BF ELEV PRUDHOE BAY UNIT WELL: 06-15 PERMIT No: 1800320 API No: 50-029-20459-00 SEC 2, T10N, R14E, 355' FSL & 1753' FEE BP Exploration (Alaska) 06-15 PERFORATION SUMMARY REF LOG: BHCS ON 0720/80 ANGLE AT TOP PERF: 4° @ 9100' Note: Refer b Pmduction DB for Iisb6cal perfdala SV-E SPF INTERVAL OprVSqz DATE 3-318" 4 9100 - 9104 S 07/17/87 3-1 /8" 4 9124 - 9144 S 10/05/85 3-1 /8" 4 9154 - 9174 S 10/05/85 3-1 /8" 4 9184 - 9200 S 0722/9C 2-7/8" 6 9195 - 9200 O 0824/19 3-3/8" 4 9200 - 9204 S 0820/94 3-3/8" 6 9200 - 9205 O 07/08/18 3-3/8" 6 9213 - 9233 O 04/11 /09 3-3/8" 6 9216 - 9226 S 08/15/91 2-7/8" 6 9225 - 9250 O 0628AM 3-12" 6 9225 - 9250 O 01 /13AN 3-3/8" 4 9226 - 9245 S 0620/08 3-3/8" 4 9248 - 9263 S 06/20/08 3-3/8" 4 9263 - 9264 S 08/04/91 DATE REV BY COMMENTS DATE REV BY COMMENTS 07/31/80 ORIGINAL COMPLETION 07/31/15 JMM/JMD PULL PLUG✓SETXN LOCK w/UD 12N8180 LAST WORKOVER 05/07/18 JMG/JMD PULLED IUD (05/05118) 06t21/08 D76 RWO 07/10/18 MS/JMD ADPERFS (07/08118) 01/14/09 RLM/SV REPERF (01/13/09) 07/15/19 GJB/JMD GLV C/O (07/04/19) 05/30/09 ???/TLH PERF 04/11/09 08/27/19 BTWJMD ADPERFS 08/24/19 12/17/09 MBM/SV ISETPXN PLUG (12/09/09) 101122r2O IJNUJMDIADDED BF ELEV PRUDHOE BAY UNIT WELL: 06-15 PERMff No: 1800320 API No: 50-029-20459-00 SEC 2, T10N, R14E, 355' FSL $1753' FEL BP Exploration (Alaska) TRFF = WELLHEAD = FMC ACTUATOR = OKB. ELEV = 68' BF. ELEV = ? KOP = 5200' Max Argyle_ Datum MD = _2 a—, Datum TVD = 8800' SS 0 6 15A SAFL NOTES: WELL ANGLE > 70° @ '. PROPOS-D MAX DLS _' @ _'. —CHROME TBG & LNR'- 9-5/8" CSG, 47#, L-80 HYDML 563, D = 8.681" I 1753' 13-3/8" CSG, 72#, N-80 BTC, ID = 12.347" 2 778' TOP OF 7" SCAB LNR 2932' 7" SCAB LNR, 26#, L-80 BTC XO TO 7793' 13CR-80 VAM TOP Minimum ID = " @ ' TOC/TOL - 8040' 9-5/8" CSG, 47#, L-80 BTC XO TO S-95 BTC H 8065' bpf, ID 4-1/2" TBG, 12.6#, 13CR-80 VAM TOP, 8081' .0152 bpf, D = 3.958" TOP OF 4-1/2" SCAB LNR 8198' TOP OF 7" LNR 1--1 8299' 7" SCAB LNR, 26#,13CR-80 VAM TOP, 8305' 0383 bpf, D = 6.276" 9-5/8" CSG, 47#, S-95 BTC, D = 8-681" I-1 8623' 4-1/2" KB PACKER WHIPSTOCK 8815' 4-1/2" SCAB LNR, 12.6#, 13CR-80 VAM TOP, -8815' .0152 bpf, ID = 3.958' 7" LNR, 29#, L-80 BTC, .0371 bpf, D = 6.184" PERFORATION SUMMARY REF LOG: ON ANGLE AT TOP PERF: —" @ Note: Referto Production DB for historical perfdata SIZE SPF I INTERVAL O NS z DATE 3-1/4' LNR, 6.6#, 13CR-85 TC11, .0079 2-7/8" LNR, 6.5#,13CR-85 STL, .0058 D = 2.85" 10200' PBTD — D = 2.441" 1094V 1736' —j 9-5/8" HES CEMENTER 2076' 4-1/2" HES X NP, D = 3.813" �I 2932' I-19-518" X 7" BKR ZXP LTP, D = 6.29" 2950' 9-5/8" X 7" BKR FLEX LOCK LNR HGR, D = 6.30" GAS LIFT MANDRELS iT MD TVD DEV TYPE VLV LATCH PORT DATE 4 3373 3373 0 KBG2-1 R DOME BK 16 07/04/19 3 5585 5566 23 KBG2-1 R SO BK 20 07/04/19 2 7154 6978 19 KBG2-1 R DMY BK 0 07/04/19 1 7846 7649 12 KBG2-1 R DMY BK 0 07/04/19 - 7912' 4-1/2" HES X NP, D = 3.813" 7943' 7" X 4-1 /2" BKR S-3 PKR, ID = 3.938" - 8007' 4-1/2" HES X NIP, D = 3.813" - 8040' 3.70" DEPLOYMENT SLEEVE, ID = 3.00" 8069' 4-1/2" HES XN NP, D = 3.725" -E== 3-1/2"XNIP,ID=2.31" 3-1/2" X 3-1/4" XO, ID = 2.786" 808V 4-1/2" WLEG, D = 3.958' 8198' 17" X 5" BKR ZXP LTP w / HMC LNR HGR & XO, D = 4.276" 8299' -jBOT TIEBACK SLV, D = ? 8305' 9-5/8" X 7" BOT HYDRA LNR HGR, ID = ? MILLOUT WINDOW (06-15A) 8815' -' 10200' 3-3/16" X 2-7/8' XO, D = 2.377" DATE REV BY COMMENTS DATE REV BY COMMENTS 07/31/80 ORIGINAL COMPLETION 12/18180 LAST WORKOVER 06/21/08 D76 RWO CTD (06-15A) 07/26/19 JMD BULT PROPOSED PRUDHOE BAY UNIT WELL: 06-15A PERMIT No: API No: 50-029-20459-01 SEC 2. T10N. R14E. 355' FSL & 1753' FEL BP Exploration (Alaska) RAO 01 Q Q O CL ea � L o Q Q La Q N �: O O LO � O V A O �a cc a o Z d o O d a m ..L J, z O m W 0 0 m a U z � Q H O s ir m m a CO 0 m rn l6 3 Q J C m CD E m' T 3 _ m m m 7 c p O Q N m d c m � H 0 U d m a m a 6 ¢ N U Lr) o CL Q o¢ r Q ° a a zo o o a" Ell p e o tr a w =1 am . 1 E 0 E (n V C c c W N W c p =O N O M c v ¢ a 0 a d Y Y m ¢ ¢ W N N CO U � O a :) N a a m U O C7 a z O O m r No 0 Q z z E v co 0 N D N m a O a a f o i z 3: Z N N N O OO (O Oj 7 M c6 V' N O M m m m. J m r m > 7 O O •� U r N C 9 J J C7 N CO I' G III aND co � 9 r N U. 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O N M n O) n N n O - n (D N O n n n CO j co C CO m m m m m m m m m m m m m m m m m m m + (p y (O (D CD U) (D co O co O co c0 O (O (O O c0 (O O co t W w mm �oO (D V Mn 00 VM N (D m r NO Oi i V co ON v 0) v 7 (O rU) (D r-,: V c0 00 M n O`®W Cl (� 0 V (� N V U) N V N M OD (A OD Cl) O n CO U) V N N (D U) U) N LO V N U) O) 00 cD U) 0) co (o M n �+ a IX :@ Z p C U] v V v v v c'7 c M v N v N N 0) v '- 0 0) O v O v O) o v CD 0 v m o v n 0 V n 0 v U) 0 0) yp, (- g z 0) O Z 7 a m cl G 0 rn rn rn rn rn rn rn rn rn rn C cl a) rn 0 Ui 10 In 10 0 LO LO W) o Ui U) ' Ui 10 0 LO O OL a) ' OD N n N U) Cl) CD M M O O OD U) O n CO V O OD 00 co N LO 00 (D OD O) a0 OD O U) (D V .. n U) V (O V U) V V V O U) V n (D V V O n CO V V N O) V Cl) O) V M O N Cl) O U) N O U) U) O) V W V N n V Cl) O V (o V V '0 U (D N O 00 D W M (O (O (C) 00 0) O) N (D Cl) O m (D OD M 0) (D (o O (D O) N (3) N c- V V O N O) co N O) W M O (O V (D O U) n n O (O O n r` .- N n U) O U) W V co V U) V (1) M N M O n Cl) N N O N CD U) OD U) n n N 7 O O V V O O (D n O O (D 0CD V co V 0O O (O (D V CD n m M V O M co o CO O LO O co N cc co V O Co u1 W (D U) O O) (D CO O (3) (O O) U) Cl) N Cl) O) O) Cl) U) V U) (D (O c0 (D O to U) V n CO n O o N . co c0 fa OD O OD c0 OD 00 OD a0 OD (M(0 06 06 MO) m O0 cl a0 O O CO O CA N O c0 cc 00 >> F 3 O) O) O O) n N (D m n U) V l9 n Cl) OD O V7 OD n O V O n Cl) n O (D V N CD Cl) n U) (O V N n n (D n V n n 0) N CO n 0) M M O N co n O N U) O) O M O O 0) U) (D W zi V M Q N I a m O 0 O 0 O 0 O 0 O o O O O O o O N O 00 n V M O O U) n O O O o o o O O o o JJJ Q r• n o n O n 0 n 0 n 0 n 0 n 0 0 n n n n r n 00 OD o rn m 0) (D o (0 0 (D 0 (D 0 (D 0 N (Up 11a CD E o � L U., z (n d O a Odz .-- (o CD (D N O O O O CD o O m 0 O 00 O (D V m O O O O U] co O O M O O f�I O O O O CL 0) >+ N U) O O U) O U) O V) N O O (D L' O o O O O O Q y (m o ai N m m M U cD 3 m (D 0 J U ai r m m OND m 0 m Di m a Di O o O f C O 0 n 0 Cl! 0 N 0 coO 0 0 (D C') ¢ a v • CD to • O m en 00 N c cz m m 0 a . 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U) O o On V O (VO .n- v O (h (co U P� Cl rn n v o m On W) O QN Cl)) v V U) (o (o r � m d !, 2 16 J C 3 a' 0) 0 cli 0 C� 0 cli o C,� m 0 N 0) 0 U 7 3 E LO N 0 mm ' m $)o y T 7 E Z O N O n V O N CO O N co D) cl (o (n N n CO a (D _ CID O (O m 0D c pp+ O (D O n N n N n O n O n co O) (o q 3 0 co co co OD CD CD w0 m,yS _ (00 CO (o coo ( m m coo Cl? n (D m U? rni V m V V n C N O LO V V N V co Cl) Cl) N N N 0) W 0) N g c V _ O p O O O O O O O O ,pi Z 0) G v W 2 Obi LO OV1 Obi Obi O Ln G W D) OVi N a) n n N n n N a) (A O 01 m m n ('7 O CO v LO m r- n v�i vOi co Cl) Cl) C CL � I O U n v O 00 aD (o n Cl) m rn CO c? vi N (D rn o N M r N m N C0 ro of 10 (D (o V v ro (0 N (o v v U� v) (o (o rl� r` o R �1 Z 0) V LO N (o ao � N (O V ao w N M N ODao co O O O m (O m O) n m 0) n n n m V n n co Cl) N v rl� co N C0 (1) n co Q 'I z� V) LO LO N Cl) 0) 00 N co n C7 i0 m Lo N O n O V ao CO rn O (D rn C? v IT N O n d Qm Y rn 0 0 0 0 0 0 0 0 0 g 0 0 0 0 0 0 0 0 0 r _ = > Q c O ZQ n a a S` Z o o LL 0 ' 0 0 0 0 0 0 0 0 � O Cn o IT o 0 v o v v 0 LO 0 (o 0 0 0 o v (d N (n (D t0 n ao O m 0) o 0 0 0 0 0 0 0 0 &i o .8� 0 rn N � a a m Y O � oo m 0LO o 0 0 co 0 a m a p z m n � p m m a r w w > 2 @ 4) _� Q LO m O Y N 3 j 17 (O O m d — m m _C Y F W m C O L t m a � C m 0 c � .Qq L m a°m'o 0 o. a> t 0) a m D 0 0 0 C) o 0 o v o) 0) m v m o °' N m d a O c c w`Fo- m (,� H Y W W in m 1- m m N m m m m O O U) m m � f� N Uf M ID� r CO m CO m m m m M m m f- O m�o N m M N m O j O m m m V O m M m m m N m M O m 0 m M m m V j M O m V m m m O M m N O V N m V N m N O L N ifI O M N m m m O O O m m LO CO N N (O r Z r a m V V' M m m Q V' V N m O N O N O m O In O V m m m M m (D O V m U) 'M-m O y�r M m L m m m O m N V m '- M m M m M n a O V O f� N M Q. e LO In m m m m m m m m W f- r- Qp o�06CO06mCOMmCOmODCOWMmm C7 N N a m > O O O m m m m m m O O O Q O O N N M m r N m m m u) O O O V + a M N n N V n NZ co 'COD m m m N n m O N if mm mOC m ooa- Cq . D 0 O O az c O c @ c m o � a c�aaAs�c North America - ALASKA - BP PBU 06 06-15 PLAN 06-15A 06-15A WP02 Anticollision Summary Report 18 December, 2019 Baker Hughes- Company: North America - ALASKA - BP Project: PBU Reference Site: 06 Site Error: 0.00usft Reference Well: 06-15 Well Error: 0.00usft Reference Wellbore PLAN 06-15A Reference Design: 06-15A WP02 BP Anticollision Report Baker Hughess Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 06-15 Mean Sea Level Kelly Bushing / Rotary Table @ 68.00usft (DOYON 16) True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Reference 06-15A WP02 Fiker type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 8.815.00 to 10,941.40usft Scan Method: Tray. Cylinder North Results Limited by: Maximum centre distance of 1291 Error Surface: Pedal Curve Survey Tool Program Date 12/18/2019 ' From To (usft) Weft) Survey (Wellbore) Tool Name Description 100.00 8,815.00 1 : Camera based gyro multisho (06-15) CB -GYRO -MS Camera based gyro multishot 8,815.00 10,941.40 06-15A WP02 (PLAN 06-15A) MWD MWD - Standard Summary Reference Offset Centre 10 Measured Measured Centre Site Name Depth Depth Distance Offset Well - Wellbore - Design Will) (usft) (usft) 06 06-15 - 06-15 - 06-15 9,120.00 9,540.00 518.69 06-16 - 06-16A - 06-16A 06-16 - Plan 06-16A - Plan 06-16A 06-16 - Plan 06-16A Contingency - Plan 06-16A Co 06-19 - 06-19 - 06-19 10,600.00 8,800.00 953.84 06-19 - 06-19A- 06-19A 9,375.00 9,200.00 1,106.57 06-21 - 06-21 - 06-21 10,458.99 8,975.00 1,097.72 06-21- 06-21 A - 06-21 A 10,458.99 8,975.00 1,097.72 06-21 - 06-21A- Plan #2 10,458.99 8,975.00 1,097.72 06-21 - 06-21 B - 06-21 B 9,650.00 9,200.00 1,256.73 06-21 - 06-21C - 06-21C WP02 Prelim 10,875.00 10,200.00 1,153.90 06-23 - 06-23 - 06-23 06-23 - 06-23A - 06-23A 06-23 - 06-23B - 06-23B 06-23 - 06-23BPB1 - 06-23BPB1 8,940.00 10,603.00 1,273.78 06-23 - 06-23C - 06-23C 06-24 - 06-24B - 06-24B 8,971.67 12,578.00 688.16 HURLST HURLST-01 R ( See Audit Notes) - HURLST-01 R SAG RIV ST 1 SAGR-01 - SAGR-01 - SAG RIV ST 1 No -Go Allowable Distance Deviation Warning Waft) from Plan (usft) 10.06 518.69 Pass - NOERRORS Out of range Out of range Out of range 221.33 737.26 Pass - Major Risk 194.28 913.47 Pass - Major Risk 244.05 857.25 Pass - Major Risk 244.10 857.20 Pass - Major Risk 240.62 858.42 Pass - Major Risk 239.88 1,040.68 Pass - Major Risk 291.41 879.38 Pass - Major Risk Out of range Out of range Out of range 13.53 1,273.04 Pass - Minor 1/200 Out of range 407.58 355.11 Pass - Major Risk Out of range Out of range 12/18/2019 2:24:57PM Page 2 of 3 COMPASS 5000.15 Build 90 Company: North America - ALASKA - BP Project: PBU Reference Site: 06 Site Error: 0.00usft Reference Well: 06-15 Well Error: O.00usft Reference Wegbore PLAN 06-15A Reference Design: 06-15A WP02 BP Anticollision Report Baker Hughes Local Co-ordinate Reference: Well 06-15 TVD Reference: Mean Sea Level MD Reference: Kelly Bushing / Rotary Table @ 68.00usft (DOYON 16) 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 Reference Depths are relative to Kelly Bushing / Rotary Table @ Coordinates are relative to: 06-15 Offset Depths are relative to Offset Datum Coordinate System is Alaska NAD27 State Plane Zones, NAD27 ' OGP-Usa AK Central Meridian is 150' 0' 0.000 W ° Grid Convergence at Surface is: 1.41 ° 1400- C 1050- 0 LO C (O Q- (a) 700- LD C a) U O N m 350- U 0 0 Ladder Plot I I I I _ _ _ _ _ I I I I I I _ - _ - J - _ _ _ _ I I I I I I _ _ _ _ _I _ _ _ _ _ I I I I I I _ _ _ _ _I _ _ _ _ _ I I I I I I _ _ _ _ _ _ _ I I I I I I _ _ _I ------- I I I I i I J- _ _ _ - I I I I I I I I - - - - J _ _ _ _ _ I I I I I I I I _ _ _ _ J _ _ _ _ I I I I I I I I _ _ _I_ _ _ _ I I I I _ _ _ I I I I I_ _ _ _ { I I I I I I I _ _ _ _ _I_ _ _ _ I I I I I I I I - - - - J - _ - - _ I I I I I I I I - _ - _ J _ _ _ _ I I I I I I I I _ _ _ _ _I_ _ _ _ _ I I I I I I I I _ _ _ _ _I_ _ _ _ I I I I I I I I _ _ _ _ _I_ _ _ _ I I I I I I I I _ _ _ _ _I_ _ _ _ I I I I - I I I I - - - -�-- -- � I I I I --- -'- - -- I I I I --- -I- - -- I I I I --- -I- - -- I I I I --- -I- - -- I I I I --- -I- - -- I I I I 2000 4000 6000 8000 MeagsleatCepM000 usftfin) $ 06-16, Plan 06-16A, Plan 06-16A VO $ 06-16, Plan 06-16A Contingency, Plan 06-16A Contingen grVO $ 06-16, 06-16A, 06-16A VO •� 06-16,06-16,06-16V1 $ 06-11,06-11,06-11 V10 $ 06-25 Plan, 06-25 Plan, 06-25 Wp 2.0 V6 $ 06-12,06-12BL1,06-12BL1 VO $ 06-12,06-12APB1,06-12APB1 VO $ 06-12, 06-12APB2, 06-12APB2 VO $ 06-12, 06-12, 06-12 V9 10000 12000 $ 06-04, 0604A,06434A V10 $ 06-04, 06-04, 06-04 V1 $ 06-04, 06-04B, %-04B VO -96- 06-21, 06-21 C, 06-21 CVbP02 Prelii $ 06-23, 06-23, 06-23 V1 -A- 06-23, 06-23A, 06-23A V1 �f 06-23, 06-23B, 06-23B V2 $ 06-23,06-23BPB1,06-23BPB1 V1 - 06-23, 06-23C, 06-23C V2 �f HURLST-01 R (See Audit Notes), 1211812019 2:24:57PM Page 3 of 3 COMPASS 5000.15 Build 90 00- ` z 0 0 0 Z o W m z ��z�� W�$91 _ CE ®s== LU LL Y W.. .. .. .. .. 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Cylinder North Results Limited by: Maximum centre distance of 200 Error Surface: Pedal Curve Survey Tool Program Date 12/18/2019 From To (usft) (usft) Survey (Welibore) Tool Name Description i 100.00 8,815.00 1 : Camera based gyro multisho (06-15) CB -GYRO -MS Camera based gyro multishot 8,815.00 11,441.40 06-15A WP02 Plus 500ft MD (PLAN 06-15 MWD MWD - Standard Summary Site Name Offset Well - Welibore - Design 06 06-14 - 06-14 - 06-14 06-14 - 06-14A- 06-14A 06-14 - 06-14B - 06-14B 06-16 - 06-16 - 06-16 06-16 - 06-16A - 06-16A 06-16 - Plan 06-16A- Plan 06-16A 06-16 - Plan 06-16A Contingency - Plan 06-16A Contingency 06-25 Plan - 06-25 Plan - 06-25 Wp 2.0 HURLST SAG RIV ST 1 Reference Offset Centre to Measured Measured Centre Depth Depth Distance (usft) (usft) (usft) 3,900.01 3,900.00 121.24 3,897.01 3,900.00 121.22 3,903.48 3,900.00 121.25 4,674.62 4,675.00 98.18 4,674.62 4,675.00 98.18 4,674.62 4,675.00 98.18 31.00 31.00 120.23 352.48 350.00 150.24 1211812019 3:26:39PM Page 2 of 2 COMPASS 5000.15 Build 90 Quick Test Sub to Otis Top of 7" Otis Distances from top of riser Excluding quick -test sub Top of Annular CDR2-AC 4 Ram BOP Schematic Date 21-Jan-20 1.1 ft L—.—._.—.—._._._._.—it._._._._.—. Top of Annular Element 6.7 ft Bottom Annular 8.0 ft CL Blind/Shears 9.3 ft CL Pipe/Slips 10.1 ft 61 Kill Line CL VBRs CL Pipe/Slips CL of Top Swab CL of Flow Cross CL of Master LDS LDS Ground Level 1 12.6 ftNo 13.4 ft10 4 7-1116" 6k Flange X 7" Otis Box Swab T1 T2 41-12 Choke Line Test Pump Hose TRANSMITTAL LETTER CHECKLIST WELL NAME: PJ' (k., 0.6" l5A PTD: a o t ' / Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: Prwd Loer BAYPOOL: Pru-d 6-t' a { Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - -� from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Spacing Approval to produce/inject is contingent upon issuance of a Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the 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: Non- production or production testing of coal bed methane is not allowed for 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) 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 �V/ by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool PR E OIL - 640150 PTD#:2200120 Administration Appr Date DLB 1/27/2020 Engineering Appr Date MGR 1/29/2020 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 I25 26 27 28 29 30 Well Name: PRUDHOE BAY UNIT 06-15A - Program DEV Initial Class/Type DEV / PEND GeoArea 890 Unit 11650 On/Off Shore On Permit. fee attached NA - Lease number appropriate_ - - - - _ _ - _ Yes Unique well name and number - - - - - - - - - - - - -- - - - Yes - - - - - - - - - - - Well located in_a_defined-pool _ - - - - _ Yes Well located proper distance from drilling unit -boundary Yes - ----- -------- ----------- Well located proper distance from other wells- - - - - - - - - - - - - - - - - - Yes - Sufficient acreage available in drilling unit_ - - - - - - - - Yes -If deviated, is-wellbore platinc_lu_ded - - - - _ - Yes - - - - - - Directional_p_la_n_view_&_ wellbore profile included. Operator only affected party Yes Operator has appropriate_ bond in force Yes Permit_can be issued without conservation order_ - - - - - - Yes _ . Permit -can be issued -without administrativ_e_approval _ _ - - - - - - - - _ _ - - - - - - Yes _ Can permit be approved before 15-day wait_ - _ Yes Well located within area and -strata authorized by Injection Order # (put_ 10# in -comments)_ (For_ _N_A_ _ _ _ _ _ - - ------- - - - - -- All wells- within _1/4_mile-area _of review identified (For service well only)- - - - - - - NA_ - - - - - - - - - - - - Pre -produced injector: duration of pre -production Less_ than. 3 months_ (For service well only) - - NA_ _ _ - - _ _ - . - - - Nonconven. gas conforms to AS31.05._0300.1_.A),(j.2.A-D) - - - - NA_ _ _ - - - - - - - - Well bore seg Annular Disoosal Conductor string -provided - - - _ NA_ _ _ _ _ _ _ _ CTD Sidetrack, all drilling within the reservoir from existing wellbore Surface casing_protects- all -known- USDWs - - - - - - - - - _ - - - - - NA - CTD Sidetrack, all drilling within the reservoir from existing wellbore CMT-v_ol_ adequate to circulate on conductor_& surf _csg _ - ----- NA. CTD Sidetrack, all drilling within the reservoir from existing wellbore - - - - - -- CMT_vol_ adequate -to tie -in -long string to surf csg_ - _ - - - - - - - - - _ NA_ - - - - - - CTD Sidetrack, all drilling within the reservoir from existing wellbore 9 CMT_will coverall known_productive horizons_ - - - - - _ _ _ Yes - - - Fully cemented 2.875_p_roduction liner - - - - - - - - Casing designs adequate for C,-T, B &_permafrost - - - ------ - - _ _ _ _ _Yes _ - - - _ - ----------------------------- Adequate -tankage -or reserve pit - - - - Yes _ - - CDR2 has adequate tankage and good truck support_ If_a-re-drill_, has_a 1.0-403 for abandonment been approved Yes - - - - - - PBU 06-16 PTD180-032,_Sundry320-042_ - - - - - - - - - - Adequate wellbore separation _proposed - - - - _ _ _ Yes - - - - - All offset wells_ pass BP separation criteria If_diverter required, does it meet regulations- -- - - - - - - - - - - - _ _ _ _N_A_ - _ _ _ All drilling in -production hole from existing wellbore Drilling fluid -program schematic_& equip list.adequate _ - - - _ - _ - - - Yes - - - - BO_PEs,_do they meet_ regulation - - - - - - - Yes 1 packoff_, 1 annular, 4_ram stack B_OPE_press rating appropriate; test to -(put psig in comments)_ ---Yes 5000 psi stack tested to 3500 psi _ - - - Choke _manifold complies w/API_RP-53 (May 84)_ _ _ _ _ _ - - - - - - Yes _ _ _ _ _ _ _ _ _ _ _ _ _ Work will occur without operation shutdown_ - Yes Is presence- of H2S gas_ probable - - - - - - - - - - - - - - - - _ _ Yes - DS6 is considered an H2S pad. BP -monitoring systems will be in place. Mechanical, condition of wells within AOR verified (For service well only) - - - - _ - - - NA- - - - - - - - - - - - - - - - --- - - - 35 Permit_can be issued w/o hydrogen_ sulfide measures _ _ - _ - - - - - - - - --- No DS 06 wells are_H2_S-bearing. H2S measures are required_. ------ Geology 36 Data presented on potential overpressure zones _ - - - - - -- - - - Yes Appr Date 37 Seismic -analysis_ of shallow gas_zones_ _ _ - - - - - - - _ _ _ - - - - - _ NA_ - - - - - - - - 38 Seabed condition survey -(if off_ -shore) - - _ _ _ _ _ NA_ - - - _ - 39 Contact name/phone for weekly -progress reports [exploratory only] - _ _ _ NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - - - - - - - - - Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date P T 5 ILY
