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Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 01/12/2023 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 4Q 2022. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through the end of 4Q 2022. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404 Report of Sundry Operations. If you have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Engineer Hilcorp North Slope, LLC By Samantha Carlisle at 3:53 pm, Jan 12, 2023 Digitally signed by Oliver Sternicki (4525) DN: cn=Oliver Sternicki (4525), ou=Users Date: 2023.01.12 14:52:49 -09'00' Oliver Sternicki (4525) By Anne Prysunka at 10:34 am, Sep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y Anne Prysunka at 9:59 am, Aug 08, 2022 'LJLWDOO\VLJQHGE\%R<RUN '1 FQ %R<RUN RX 8VHUV 'DWH '65 6)'0*5$8* -/& GWV Jeremy Price Digitally signed by Jeremy Price Date: 2022.08.19 08:35:35 -08'00' RBDMS JSB 082322 &HPHQW &RQGXFWRU 7RS-RE :HOO / 37' $3, tĞůůEĂŵĞ͗>ϱͲϬϳ WĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϮϭϵϭϬϮ tĞůůdLJƉĞ W>W/EƵŵďĞƌ͗ϱϬͲϬϮϵͲϮϯϲϰϮͲϬϬ :Žď^ĐŽƉĞ͗ŽŶĚƵĐƚŽƌƚŽƉũŽď ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛Ě͍zĞƐ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗KƉĞƌĂďůĞ͕ KŶůŝŶĞ ĂƚĞZĞŐ͘ƉƉƌŽǀĂůZĞĐ͛ǀĚ͍͗ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗ϴͬϮϬͬϮϬϮϮ ƐƚŝŵĂƚĞĚƵƌĂƚŝŽŶ͗ϯĚĂLJ ZĞŐƵůĂƚŽƌLJŽŶƚĂĐƚ͗ĂƌƌŝĞ:ĂŶŽǁƐŬŝ &ŝƌƐƚĂůů ŶŐŝŶĞĞƌ͗KůŝǀĞƌ^ƚĞƌŶŝĐŬŝ ^ĞĐŽŶĚĂůů ŶŐŝŶĞĞƌ͗>ĞƐůŝĞZĞĂǀŝƐ ƌŝĞĨtĞůů ^ƵŵŵĂƌLJ͗ >ϱͲϬϳ ŝƐĂŐĂƐůŝĨƚĞĚƉƌŽĚƵĐĞƌ ŽƌŝŐŝŶĂůůLJĚƌŝůůĞĚĂŶĚĐŽŵƉůĞƚĞĚŝŶϮϬϮϬ͘ ZĞĐĞŶƚŝŶƐƉĞĐƚŝŽŶŽĨƚŚĞ ϭϯͲϯͬϴ͟ ƐƵƌĨĂĐĞĐĂƐŝŶŐ dž ϮϬ͟ ĐŽŶĚƵĐƚŽƌĂŶŶƵůƵƐ ĨŽƵŶĚƚŚĂƚƚŚĞĂŶŶƵůƵƐĐĞŵĞŶƚƚŽƉŝƐůŽĐĂƚĞĚ Εϲ͛ ĨƌŽŵƚŚĞƚŽƉŽĨ ƚŚĞĐŽŶĚƵĐƚŽƌ͘ ƵƌƌĞŶƚ ^ƚĂƚƵƐ͗ >ϱͲϬϳŝƐĐƵƌƌĞŶƚůLJŽƉĞƌĂďůĞĂŶĚŽŶůŝŶĞ͘ ^ĐŽƉĞŽĨtŽƌŬ͗ &ŝůů ƚŚĞ ϭϯͲϯͬϴ͟ ƐƵƌĨĂĐĞĐĂƐŝŶŐ dž ϮϬ͟ ĐŽŶĚƵĐƚŽƌĂŶŶƵůƵƐ ǁŝƚŚĐĞŵĞŶƚ ƚŽ ƌĞĚƵĐĞ ƚŚĞ ĞdžƚĞƌŶĂů ƐƵƌĨĂĐĞ ĐĂƐŝŶŐĐŽƌƌŽƐŝŽŶƌŝƐŬ͘ WƌŽĐĞĚƵƌĞ͗ '+'ƵŵƉĐĞŵĞŶƚ ŝŶƚŽ ƚŚĞ ϭϯͲϯͬϴ͟ ƐƵƌĨĂĐĞĐĂƐŝŶŐ dž ϮϬ͟ ĐŽŶĚƵĐƚŽƌĂŶŶƵůƵƐ ƚŽ Εϲ͟ ĨƌŽŵƚŚĞ ƚŽƉŽĨƚŚĞĐŽŶĚƵĐƚŽƌ͘ '/% &HPHQW &RQGXFWRU 7RS-RE :HOO / 37' $3, Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:219-102 6.50-029-23642-00-00 PRUDHOE BAY, LISBURNE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 14860 14761 8739 9942 none none 8513 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" X 34" 47 - 127 47 - 127 2280 770 Surface 4259 13-3/8" 46 - 4305 46 - 3911 5020 2260 Intermediate 9824 9-5/8" 44 - 9868 44 - 8452 6870 4760 Production Perforation Depth: Measured depth: 10220 - 14761 feet True vertical depth:8739 - 8739 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr85 43 - 10033 43 - 8587 9942 8513Packers and SSSV (type, measured and true vertical depth) 4-1/2" HES TNT Perm Packer Liner 4837 4-1/2" 10222 - 14859 8578 - 8737 9020 8040 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 69124173045227 16144166 2420 5784 1801 719 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Aras Worthington Aras.Worthington@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:907-564-4763 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8737 Sundry Number or N/A if C.O. Exempt: 320-307 No SSSV Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well5 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028320 & 034631 PBU L5-07 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations surface 07/28/20; OA cmt - Pumped total 239 bbls 15.8 ppg cmt and 50 bbls 15.8 cmt/bridgemaker to 1500 psi 08/03/20; OA cmt top job - Pumped total 58.7 bbls of 15.8 ppg neat class G to 2000 psi squeeze pressure 08-04-2020; OA Well Lock'd – Pumped 6 gal of 9.17 ppg Well Lock to 2000 psi 08/07/20; OA Well Lock squeeze - Squeezed OA to 3000 psi 08/31/20; OA re-Well Lock'd - Squeezed 2.5 gal of 9.1 ppg Well Lock to 4000 psi Total pumped: 348 bbls cmt (including 50 bbls with bridgemaker) and 8.5 gal Well Lock, details below: By Samantha Carlisle at 9:49 am, Oct 20, 2020 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2020.10.19 16:43:34 -08'00' Bo York SFD 10/20/2020 RBDMS HEW 11/13/2020 DSR-10/20/2020MGR23OCT2020 ACTIVITYDATE SUMMARY 7/16/2020 T/I/O = 760/1670/780. Temp = 101°. Bleed OAP (eval IAxOA). AL online. OA FL @ 570' (34 bbls). Bled OAP to BT to 10 psi in 2 hrs (all gas). Monitored for 30 min. OAP increased 20 psi. Final WHPs = 760/1670/30. SV = C. WV, SSV, MV = O. IA, OA = OTG. 23:59 7/17/2020 T/I/O = 750/1600/270 TEMP = 100° PPPOT-IC eval IAxOA comm (PASS) PPPOT-IC Sting into test void 0 psi on test void. Monitored for 30 min, no change in pressure. R/U test equipment Pressure test void to 3,500 psi for 30 min. Lost 0 psi in 15 min, lost 0 psi in 2nd 15 minutes (PASSED). Bleed test void to 0 psi. R/D test equipment. 7/21/2020 T/I/O = Temp-SI. Injectivity test of the OA. Pumped 36 bbls Crude into OA till caught pressure. Pressure breakover occured at 41 bbls at 2.5 bpm, OA pressure of 1615 psi. Pumped 11 bbls crude at 3 bpm with OA pressure of 144 psi. Pumped 25 bbls at 4 bpm with OA pressure of 1488 psi. Pumped 7 bbls crude at 5 bpm with OA pressure of 1543. Bled back 10.1 bbls. DSO notified upon departure. SSV/WV/SV (closed), MV (open), IA/OA (OTG). FWHP's = 1546/1297/0 7/22/2020 T/I/O = SI/0/0. . Remove OA working side 2" valve and companion side 2" blind flange. Removed 2" VR plug from companion side. Install 2" integral flanges on both sides and torqued to API specs. Install Block valves and 1502 caps with jewelry. RDMO ***Job Complete*** SEE LOG FOR DETAILS Final T/I/O = SI/0/0. IA/OA = OTG Note: Valve and blind left in well house. 7/22/2020 T/I/O = 1540/1280/40. Temp = SI. Bleed IA & OAP (Pre Cement). AL SI @ casing valve & DLB plug valves (0+ psi). IA FL @ 9840' (#1, S/O). OA FL @ near surface. Bled the IAP from 1280 psi to 30 psi in 6 hours. During the IA bleed the OAP decreased 30 psi. Bled the OAP from 10 psi to 0 psi in 5 seconds (all gas). The IAP and the IA FL remained unchanged and the OAP increased to 10 psi in the 30 minute monitor. Re-bled the OAP before departure (FTS). Job to continue on night shift. FWPs = 1540/30/10. SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:20. 7/22/2020 T/I/O = SSV/30/60. Temp = SI. Bleed OAP to 0 psi (pre OA squeeze). ALP = 0+ psi, SI @ CV. IA FL @ 9840' (sta # 1 SO). OA FL @ surface. Bled IAP to OT to 0+ in 2 hrs. Bled OAP to BT to 0 psi in 2 hrs. Held open bleed on both IA & OA to assist w/ swapping out CV & blind flange to a set of 2" block valves. Monitored for 30 min. IAP unchanged, OAP increased 10 psi. Final WHPs = SSV/0+/10. Rig up in control of valves upon departure. 23:59 7/28/2020 HES OA Cement Job Pumped 5 bbl neat meth spear, pumped 50 bbl hot surfactant wash, pumped 20 bbl 15.8 ppg neat cement, pumped 50 bbl 15.8 ppg cement/Bridgemaker, Pumped 219 bbls of 15.8 ppg cement. Hesitated 20 minutes and c pumped 5 bbl of 15.8 ppg cement. Hesitated 20 minutes and c pumped the final 5 bbls of 15.8 ppg cement into the OA. Well is on a vac after final cement pumped. Blow down. RDMO. Job Complete Daily Report of Well Operations PBU L5-07 Daily Report of Well Operations PBU L5-07 7/29/2020 T/I/O = SSV/0+/Vac. Temp = SI. Strap OA TOC. ALP = 0 psi, AL SI @ casing valve. Removed Vac from OA. Unable to strap TOC in OA due to cement being to green (fresh). SV, WV, SSV = C. MV = O. IA, OA = OTG. 10:15 7/31/2020 T/I/O = 1660/0/vac. Temp = SI. TBG FL and Strap TOC in OA (OA treatment). TBG FL at 10,104' (154 bbls). Stapped OA, fluid at 268' and TOC at 315' (18.3 bbls) SV, SSV, WV = C. MV = O. IA, OA = OTG. 8/3/2020 HES Cement Crew. Job Scope: FIll OA with cement to surface; Batched up 5 bbls of cement at a time and charge pumped each bacth into the OA then bleed of the air in the annulus. Repeated process eleven times until cement to surface. Total volume pumpedf 58.7 bbls of 15.8ppg Neat Class G Cement. Performed squeeze pressure of 2000 psi. Held for 10 mins. Contact DSO status of well. Tags hung on OA. Next Step WellLock. 8/4/2020 T/I/O = SSV/0/110. Temp = SI. WHPs (post WellLock). ALP = 0 psi, SI @ CV. Well Lock sample is still in a liquid form. WH temp = 68°. Heater in well house is working properly. Adjusted heater trunck slightly. 1 door ajar. SV, WV, SSV = C. MV = O. IA, OA = OTG. 23:45 8/4/2020 HES WellLock Job Objective: Verify cement to surface. Sqz WellLock to 3000 psi. DHD rig down iron from cement squeeze. Perform 1 hour no flow. ND integral flanges and clear residual fluids from top of cement in OA. Cement to VR profile on spool at 6 o'clock position. Cement 3/4" below VR profile in spool at 12 oclock position. Call out HES WellLock engineer. Re- install integral flanges, 2" sweeping 45, and 2' pup, Batch up 3 gallons of WellLock with activator added. Batch will reach 70 bc in 11 hours. Dumped 1.5 gallons in OA annular space. Pups on both sides of spool full with Welllock attach Lincoln pump. Pumped a total of 8 gallons into OA. Could not get pressure beyond 2000 psi. Continued pumping holding 1750 psi then ran out of product. Pressure bled down slow then slowed down even more and held at 1000 psi. End job and monitor well every six hours for first 24 then once every 12 hours tell sample hardens. Tags hung and DSO notified. ***Job Complete*** 8/5/2020 T/I/O = SSV/0/0. Temp = SI. WHPs (post WellLock). ALP = 0 psi, AL SI @ casing valve. Well Lock sample is like warm molasses. WH temp = 80°. Heater in well house is working properly. Tree cap @ 0 psi. 1 door ajar. SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:50 8/5/2020 T/I/O = SSV/0/100. Temp = SI. WHPs (post WellLock). ALP = 0 psi, SI @ CV. Well Lock sample is still in a liquid form. WH temp = 70°. Heater in well house is working properly. Adjusted heater trunck slightly. Bled tree cap to 0 psi. 1 door ajar. SV, WV, SSV = C. MV = O. IA, OA = OTG. 04:45 8/6/2020 T/I/O = SSV/0/80. Temp = SI. WHPs (Post Wellock). ALP = 0 psi, SI @ CV. Wellock sample is firm but not hard. WH temp = 82°. Heater working. Back door is open. SV, WV, SSV = C. MV = O. IA, OA = OTG. 18:00 8/6/2020 T/I/O = SSV/0/50. Temp = SI. WHPs (post WellLock). ALP = 0 psi, SI @ CV. Well Lock sample is about the consistency of molasses. WH temp = 80°. Heater in well house is working properly. 1 door ajar. SV, WV, SSV = C. MV = O. IA, OA = OTG. 03:15 f Daily Report of Well Operations PBU L5-07 8/7/2020 Objective: Re-Treat OA with Welllock. Attempted to squeeze Welllock into OA. OA caught pressure immediately. Pressured up to 3,000psi and held for 1hr. No pressure response on the companion side of the OA. Removed flange x 1502 integral on both sides of the OA casing spool and had VR profiles completely covered with hardened Welllock. Installed OA casing valve and blind flange. ***Job Complete, Handed well over to DSO to POP*** 8/8/2020 T/I/O = 810/1720/0+. Temp = 98°. Monitor (post Wellock). ALP = 1720 psi, AL online. OA cemented to surface. WH temp = 74°. Heater in well house working properly, tree cap @ 0 psi. Wellock sample #2 with 6% has of molasses. Wellock sample #1 is moslty set up when firmly squeezed it will still indent. SV = C. WV, SSV, MV = O. IA, OA = OTG. 16:45 8/8/2020 T/I/O = 1650/1660/0+. Temp = SI. Monitor (post well lock). ALP = 2440 psi, SI @ CV. OA cemented to surface. Ops attempted to POP well. WH temp = 62°, adjust heater trunk. Heater in well house working properly, bled tree cap to 0 psi. Well Lock sample has consistency of molasses. SV = C. WV, SSV, MV = O. IA, OA = OTG. 05:30 8/9/2020 T/I/O = 800/1620/620. Temp = 100°. Bleed OAP (eval high OAP). AL online @ 1620 psi. OA cemented to surface. OAP began increasing rapidly around 02:00, Ops bled several times. OAP increasing ~50 psi/minute. Bled OAP every 25 minutes throughtout the job. Ops SI AL, Bled IAP to production from 1460 psi to 800 psi in 5 hours. Continue monitoring WHPs. IAP unchanged, OAP continues to increase >800 psi, continue to bleed OAP as necessary. ***WSR continued on 08/10/2020*** 8/10/2020 ***WSR continued from 08/09/2020*** T/I/O = 730/800/0+. Bleed OAP (eval high IAP). ALP = 2420 psi, SI @ CV & LVs. OA cemented to surface. Continued monitoring OAP and bleeding as necesary, post IA bleed. Released by Ops. OAP bled to 0+ psi before departure. Final WHPs = 730/800/0+. SV = C. WV, SSV, MV = O. IA, OA = OTG. 01:00 8/11/2020 T/I/O = 710/800/730. Temp = 101°. Bleed IAP/OAP to >200 psi (eval IAxOA). ALP = 2440 psi, SI @ CV & LVs. OA cemented to surface. IA FL @ 9840' (Sta #1, SO, 530 bbls). Bled IAP to OT from 800 psi to 300 psi in 3.1 hours. IA FL unchanged, OAP decreased to 690 psi. Bled OAP from 690 psi to 300 psi. Monitored for 30 minutes. OAP increased 280 psi. Final WHPs = 700/300/580. SV = C. WV, SSV, MV = O. IA, OA = OTG. 04:30 8/12/2020 T/I/O = 680/300/60. Temp = 106°. WHPs (Post Wellock). ALP = 2450 psi, SI @ CV & lateral. OA cemented to surface. TP & IAP unchanged, OAP decreased 20 psi since 04:00 this morning. SV = C. WV, SSV, MV = O. IA, OA = OTG. 16:45 8/12/2020 T/I/O = 680/300/80. Temp = 105°. WHPs (post Well Lock). ALP = 2440 psi, SI @ CV & LVs. OA cemented to surface. TP decreased 20 psi, IAP unchanged, OAP decreased 500 psi overnight. SV = C. WV, SSV, MV = O. IA, OA = OTG. 04:00 8/27/2020 T/I/O = 700/380/40. Temp = 110°. Bleed IAP/OAP to 0 psi (Wellock). ALP = 2440 psi, SI @ CV. OA cemented to surface. IA FL @ 9840' (Sta #1, SO, 530 bbls). Bled IAP to OT from 380 psi to 130 psi in 2.5 hrs. **Continued on WSR dated 8/28/20** Daily Report of Well Operations PBU L5-07 8/28/2020 ***Continued from WSR dated 8/27/20*** T/I/O = 690/130/50. Temp = 110°. Bleed IAP/OAP to 0 psi (Wellock). ALP = 2440 psi, SI @ CV. OA cemented to surface. IA FL @ 9840' (Sta #1, SO, 530 bbls). Bled IAP to OT from 130 psi to 0 psi in 5 hrs (total 7.5 hrs). Bled OAP to 0 psi in < 10 sec. Held open bleed on OA for 2 hrs during IA bleed. SI IA and OA bleeds. Monitor for 30 min. IAP unchanged, OAP increased 50 psi. Final WHps = 690/0/50. SV = C. WV, SSV, MV = O. IA, OA = OTG. 06:00 8/29/2020 T/I/O=690/0/100. Pre wellock. RD working side 2"FMC valve. RU 2" 5000 integral. Torqued to API spec. RU Block valve and cap. RD Companion side 2" 5000 blind flange. RU 2"5000 integral. Torqued to API spec. RU block valve and cap. Job Complete. Final WHP's 690/0/0. 8/31/2020 HES WellLock Job Objective: Verify WellLock to surface. Sqz 2.5 gallons of WellLock w/ 4% activatord to 4000 psi. Rigged up to do one side at a time. Bleed off after WellLock was injected was so slow that we re-rigged to pump down both sides at the same time. Injected 2.5 gallons into OA for 10 1/2 hours. Changed gauges to hydraulic gauges to keep WellLock from setting up inside. Void was so small that each time we opened up to gauge pressure would be gone. Set up 12 hour monitors for first 48 hours then once a day after until sample on THA is hard. Well left flowing at 700 psi / 120 deg F. Tags hung and DSO notified ***Job Complete*** 9/1/2020 T/I/O = 740/0/0. Temp = 120°. WHPs (post Wellock). ALP = 2450 psi, AL SI @ casing valve. WH temp = 88° Wellock sample has began to set up, able to leave imprint when pressed into firmly. Heater in well house working properly back door ajar. SV = C. WV, SSV, MV = O. IA, OA = OTG. 17:30 9/1/2020 T/I/O = 660/0/0. Temp = 120°. WHPs (Post Well Lock). ALP = 2440 psi, SI @ CV. OA cemented to surface. Heater working properly. WH temp = 60°. Adjusted heater trunk. Sample is the consistency of honey. Back door open. SV = C. WV, SSV, MV = O. IA, OA = OTG. 05:30 9/2/2020 T/I/O = 700/0/0. Temp = 120°. WHPs (post Wellock). ALP = 2440 psi, AL SI @ casing valve. WH temp = 82° Wellock sample has began to set up, still able to leave imprint when pressed into firmly. Heater in well house working properly back door open. SV = C. WV, SSV, MV = O. IA, OA = OTG. 04:45 9/3/2020 T/I/O = 700/0/0. Temp = 120*. WHP (post welllock). ALP = 2440, AL SI @ casing valve. WHT = 79*. Welllock sample is still tacky to the touch. Heater in well house working, well house door open. SC = C. WV, SSV, MV = O. IA, OA = OTG. 17:30 9/3/2020 T/I/O = 700/0/0. Temp = 120°. WHPs (post Wellock). ALP = 2440 psi, AL SI @ casing valve. WH temp = 42° Wellock sample is set up and hard. Heater in well house working properly. Front door and back door open. Closed front door. SV = C. WV, SSV, MV = O. IA, OA = OTG. 03:00 9/4/2020 T/I/O = 710/0+/0. Temp = 118°. WHPs (post Wellock). ALP = 2440 psi, SI @ CV. Heater in wellhouse working properly. WH temp = 62°. Wellock sample set up. SV = C. WV, SSV, MV = O. IA, OA = OTG. 06:30 9/5/2020 T/I/O = 730/0+/0. Temp = 118°. WHPs (post Wellock). ALP = 2440 psi, SI @ CV. Heater in wellhouse working properly. WH temp = 70°. Wellock sample set up. TP increased 20 psi, IAP & OAP unchanged overnight. SV = C. WV, SSV, MV = O. IA, OA = OTG. 20:30 Daily Report of Well Operations PBU L5-07 9/6/2020 T/I/O = 700/0+/0. Temp = 120°. WHPs (Post Wellock). ALP = 2440 psi, SI @ CV. Wellock sample is set up. TP decreased 30 psi, IAP & OAP unchanged overnight. SV = C. WV, SSV, MV = O. IA, OA = OTG. 17:50 9/8/2020 T/I/O = 700/0+/0. Temp = 117°. WHPs (post Wellock). ALP = 2440 psi, SI @ CV. WHPs unchanged, temp increased 3° from 9/6/20. SV = C. WV, SSV, MV = O. IA, OA = OTG. 20:00 9/9/2020 T/I/O = 690/0+/0. Temp = 117°. WHPs (post Wellock). ALP = 2440 psi, SI @ CV. TP decreased 10 psi, IAP & OAP unchanged. SV = C. WV, SSV, MV = O. IA, OA = OTG. 20:30 9/12/2020 T/I/O = 680/0/0. Temp = 120*. WHPs (Post Wellock). AL SI @ casing valve (2380 psi). Wellock sample is fully cured. OA casing spool has integral flanges with 1502 caps on both ports. 1502 1/4 turn valve, original FMC valve and blind flange are laying in wellhouse. SV = C. WV, SSV, MV = O. IA, OA = OTG. 08:20. 9/14/2020 RD WOA intergal blind, RU 2' HWO to WOA, Torqued to API specs, RD COA intergal blind flange, RU 2" API Blind flange w/ alemite fitting to COA, Torqued to API specs. RDMO. ***Job Complete***. 9/14/2020 T/I/O = 700/0+/0. Temp = 118*. Monitor IA x OA (Post wellock). AL SI @ casing valve (2380 psi). IA FL @ 9840' (#1, S/O). Removed 1502 integrals and installed blind flange on 6 o'clock postion and 2" FMC casing valve on 12 o'clock position. Increased the IAP incrementally to 1290 psi while monitoring OAP. The OAP increased to 140 psi and stayed stable throughout the remainder of the job. FWPs = 700/1250/140. SV = C. WV, SSV, MV = O. IA, OA = OTG. 17:25 9/16/2020 T/I/O = 720/1170/920. Temp = 100*. Bleed OAP (Eval wellock). AL SI @ casing valve (2380 psi). IA FL @ 9840' (#1, S/O). OA is cemented to surface. Bled the OAP from 920 psi to 0+ psi in 15 seconds (all gas, BT). Maintained an open bleed for 1 hour (OA still had audible flow). SI and monitored for 15 minutes, OAP increased 450 psi. Bled the IAP from 1170 psi to 750 psi in 1 hour (all gas, OT tank). The IAP remained unchanged in the 30 minute monitor. FWP's = 720/750/0+. SV = C. WV, SSV, MV = O. IA, OA = OTG. 16:45 10/9/2020 T/I/O = 1170/720/710. Temp = SI. TIFL (required by sundry). ALP = 1860 psi, SI @ CV. IA FL @ 9840' sta # 1 SO). OA cemented to surface. Stacked well w/ ALP to 1310/1740/770. Attempted to back flow on Tubing but unable to stackout. Bled OAP to 280 psi in < 1 min (all gas). Monitored for 15 min. TP decreased 10 psi, IAP decreased 340 psi, OAP increased 100 psi. Final WHPs = 1300/1400/380. SV, WV = C. SSV, MV = O. IA, OA = OTG. 06:00 10/9/2020 T/I/O = 1260/1100/760. Temp = SI. TIFL - Passed- (Sundry requirement). AL SI @ casing valve (2500 psi). IA FL @ 9840' (#1, S/O). SI AL @ DBL plug valve. Bled the IAP from 1100 psi to 260 psi in 4 hours and 20 minutes. During the IA bleed the TP and IA FL remained unchanged. The IAP and IA FL remained unchanged in the 1 hour monitor. Ops to POP. FWPs = 1260/260/670. SV, WV = C. SSV, MV = O. IA, OA = OTG. 15:30 ) Attempted to back flow on Tubing but unable to stackout. DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23642-00-00Well Name/No. PRUDHOE BAY UN LIS L5-07Completion Status1-OILCompletion Date5/25/2020Permit to Drill2191020Operator BP Exploration (Alaska) Inc.MD14860TVD8737Current Status1-OIL7/22/2020UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:MWD / GR / RES, MWD / GR / RES, MWD / GR / RES / DEN / NEU, MWD / GR / RES / DEN / NEUNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleDF4/9/202068 14861 Electronic Data Set, Filename: L5-07_BH_LTK_Mem_Composite_FE Drilling Data.las32474EDDigital DataDF4/9/2020 Electronic File: L5-07_BHGE_LTK_2MD_Memory Drilling Log.cgm32474EDDigital DataDF4/9/2020 Electronic File: L5-07_BHGE_LTK_2TVDSS_Memory Drilling Log.cgm32474EDDigital DataDF4/9/2020 Electronic File: L5-07_BHGE_LTK_5MD_Memory Drilling Log.cgm32474EDDigital DataDF4/9/2020 Electronic File: L5-07_BHGE_LTK_5TVDSS_Memory Drilling Log.cgm32474EDDigital DataDF4/9/2020 Electronic File: L5-07_BH_OTK-VSS_RLT-MEM_Composite Drilling Dynamics Depth Log.cgm32474EDDigital DataDF4/9/2020 Electronic File: L5-07_BH_LTK_Mem_Composite_FE Drilling Data.dls32474EDDigital DataDF4/9/2020 Electronic File: L5-07_BHGE_LTK_2MD_Memory Drilling Log.pdf32474EDDigital DataDF4/9/2020 Electronic File: L5-07_BHGE_LTK_2TVDSS_Memory Drilling Log.pdf32474EDDigital DataDF4/9/2020 Electronic File: L5-07_BHGE_LTK_5MD_Memory Drilling Log.pdf32474EDDigital DataWednesday, July 22, 2020AOGCCPage 1 of 3L5-,07_BH_LTK_Mem_Composite_FE Drilling __Data.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23642-00-00Well Name/No. PRUDHOE BAY UN LIS L5-07Completion Status1-OILCompletion Date5/25/2020Permit to Drill2191020Operator BP Exploration (Alaska) Inc.MD14860TVD8737Current Status1-OIL7/22/2020UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsSentSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYComments:Mud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NACOMPLIANCE HISTORYDate CommentsDescriptionCompletion Date: 5/25/2020Release Date: 1/22/2020DF4/9/2020 Electronic File: L5-07_BHGE_LTK_5TVDSS_Memory Drilling Log.pdf32474EDDigital DataDF4/9/2020 Electronic File: L5-07_BH_Final Survey Reports.csv32474EDDigital DataDF4/9/2020 Electronic File: L5-07_BH_Final Survey Reports.pdf32474EDDigital DataDF4/9/2020 Electronic File: L5-07_BH_Final Survey Reports.txt32474EDDigital Data0 0 2191020 PRUDHOE BAY UN LIS L5-07 LOG HEADERS32474LogLog Header ScansWednesday, July 22, 2020AOGCCPage 2 of 3 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23642-00-00Well Name/No. PRUDHOE BAY UN LIS L5-07Completion Status1-OILCompletion Date5/25/2020Permit to Drill2191020Operator BP Exploration (Alaska) Inc.MD14860TVD8737Current Status1-OIL7/22/2020UICNoCompliance Reviewed By:Date:Wednesday, July 22, 2020AOGCCPage 3 of 3M. Guhl 7/22/2020 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:219-102 6.API Number:50-029-23642-00-00 PRUDHOE BAY, LISBURNE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028320 & 034631 Property Designation (Lease Number):10. 8. PBU L5-07 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown OA Downsqueeze Op Shutdown GAS GSTOR WAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5Stratigraphic Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 14860 Effective Depth MD: 13Cr85 11. 7/22/2020 Commission Representative: 15. Suspended Contact Name:Aras Worthington Contact Email: aras.worthington@hilcorp.com Authorized Name: Bo York Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8737 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 9942 / 8513 No SSSV Installed Date: Liner 4837 4-1/2" 10022 - 14859 8578 -8737 9020 8040 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 46 - 4305 46 - 3911 14. Estimated Date for Commencing Operations: BOP Sketch 47 - 127 Structural 6870 Proposal Summary 13. Well Class after proposed work: 4-1/2" HES TNT Perm Packer 10220 - 14761 8739 - 8739 4-1/2" 12.6#43 - 10033 Production 14761 8739 none none 47 - 127 770 13-3/8" 9-5/8" Contact Phone:907-564-4763 Date: 4760 80 228020" X 34" Conductor 2260 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 4259 5020 Intermediate 9824 44 - 9868 44 - 8452 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. By Jody Colombie at 11:13 am, Jul 20, 2020 320-307 SFD 7/20/2020 DLB 07/20/20 X DSR-7/20/2020 10-404 MGR20JUL207/20/2020 7/21/2020 RBDMS HEW 7/24/2020 L5-07 OA Cement Squeeze Integrity Engineer: Aras Worthington (907) 564-4763 Ops Engineer: Kirsty Schultz (907) 564-5258 Ops Manager: Bo York (907) 777-8345 Expected Start Date: July 22, 2020 History Gas-lifted Producer drilled and completed in April of 2020 with an open OA shoe. The well has experienced OA re-pressurization upon POP in early July 2020 that is not manageable by bleeds. A MITIA passed on 4/4/2020 and a PPPOT-IC passed to 3500 psi on 7/17/2020. Current Status The well is currently classified as Under Evaluation to monitor and bleed the OA re-pressurization. Objective Execute an OA down-squeeze to fully cement the OA followed by an OA Well Lock resin squeeze to remedy the OA re-pressurization. 2 Procedural steps Fullbore 1. Establish injectivity rate and pressure with diesel or crude oil down the OA and into formation. Max OA pressure 4000 psi. Note that burst strength of 13-3/8” 68# casing is 5020 pis and the collapse strength of the 9-5/8” 47# casing is 5080 psi. 2. Pump ~300 bbls of 15.8 ppg Class G cement down the OA to fully cement the OA from surface to the Surface Casing Shoe. Pump the following schedule at maximum rate below 4000 psi treating pressure: ¾ 10-bbls 60/40 or 5 bbls neat MEOH ¾ 50 bbls hot (180 deg) freshwater + surfactant ¾ 20 bbls neat cement ¾ 50 bbls cement with 15-ppb aggregate ¾ 230 bbls neat cement OA Volume: 13-3/8” x 9-5/8” annulus 13-3/8” 68# x 9-5/8” 47# 12.415” x 9.625” 0.0597 BBLS/FT 4503’ MD Shoe Depth Volume 269 BBLS Special Projects 1. Strap the TOC in the OA. 2. Fill and squeeze the remaining void in the OA with well lock, squeezecrete, or similar product (if needed). Squeeze to 4000 psi. DHD/Operations 1. POP and monitor OA pressure. 2. TIFL to verify casing and tubing barriers. 3. Re-squeeze OA if necessary. 3 L5-07 Current 4 L5-07 Proposed Fully Cemented OA 1a. Well Status: GINJ Oil 55 1b. Well Class: 5 Exploratory Service BP Exploration (Alaska), Inc 14. Permit to Drill Number/Sundry 219-102 2/29/2020 3/24/2020 GL PRUDHOE BAY, LISBURNE OIL 4a. Surface: Top of Productive Interval: Total Depth: 1523' FSL, 164' FEL, Sec. 02, T11N, R15E, UM 1480' FNL, 3998' FEL, Sec. 11, T11N, R15E, UM 5225' FNL, 1251' FEL, Sec. 10, T11N, R15E, UM Surface: x- y- Zone -717271 5974650 ASP 4 11. Gas SPLUG Abandoned 20AAC 25.105 Suspended 20AAC 25.110 WINJ WAG WDSPL No. of Completions: 5/25/2020 15. 50-029-23642-00-00 16. PBU L5-07 Well Name and Number: 14761' / 8739' 20.20 17. TPI:y- Zone -713529 ASP 4x-5971539 Total Depth: x-y-Zone -711108 ASP 45967724 14860' / 8737' None DNR Approval Number:19. 84-62 5. Directional or Inclination Survey: Yes No Submit electronic and printed information per 20 AAC 25.050 (ft MSL) 20.Thickness of Permafrost MD/TVD: MWD / GR / RES, MWD / GR / RES, MWD / GR / RES / DEN / NEU, MWD / GR / RES / DEN / NEU CASING WT. PER FT.GRADE SETTING DEPTH MD TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED Location of Well (Governmental Section): Field/Pool(s): Date Comp., Susp., or Aband.:6. Total Depth (MD/TVD): CASING, LINER AND CEMENTING RECORD TOP BOTTOM 22. SETTING DEPTH TVD 9-5/8" 7" 4-1/2" 215.5# 68# 47# 26# 12.6# L-80 L-80 L-80 13Cr85 47' 44' 9678' 10022' 9868' 10214' 14859' 47' 44' 8297' 8578' 8734' 8452' 8737' 6-1/8" 8-1/2" 12-1/4" 20 yds Concrete 523 sx Class 'G' 1452 sx Class 'G' 590 sx Class 'G' 25. GRADE PACKER SET (MD/TVD) 26. 4-1/2" 12.6# 13Cr85 10033' DEPTH INTERVAL (MD)AMOUNT AND KIND OF MATERIAL USED PRODUCTION TEST27. Date First Production: Not on Production N/A Date of Test: Flow Tubing Press Oil-Bbl: Oil-Bbl: Gas-MCF:Water-Bbl: Oil Gravity - API (corr): Method of Operation (Flowing, gas lift, etc.): Gas-Oil Ratio:Choke Size: Water-Bbl: 10220' - 14761' Open to production or injection?Yes 5 No 24. If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 10220' - 10380' 8739' - 8855' 10440' - 10690' 8891' - 8982' 10780' - 11050' 8989' - 8989' 11230' - 11520' 8967' - 8922' 12104' - 12154' 8832' - 8824' 12434' - 12584' 8785' - 8773' 12620' - 12920' 8771' - 8757' 12959' - 13260' 8756' - 8750' 13363' - 13662' 8747' - 8739' 13802' - 14002' 8740' - 8742' 14040' - 14140' 8743' - 8746' 14400' - 14680' 8745' - 8740' 14720' - 14761' 8739' - 8739' A-53 127'42"20"x34" 13-3/8"46'4305'16"2322 sx LiteCrete, 319 sx Class 'G'46'3911' 9942' / 8512' 1504.5 Bbls Etch Acid, 787.5 Bbls VDA Acid Gas-MCF: Production for Test Period Calculated 24 Hour Rate Hours Tested: Casing Press: 127' ACID, FRACTURE, CEMENT SQUEEZE, ETC. TUBING RECORD DEPTH SET (MD) Yes No 5Was hydraulic fracturing used during completion? Per 20 AAC 25.283 (i)(2) attach electronic and printed information 320-115 Other 12. SSSV Depth (MD/TVD): 2-3/4" Gun Diameter, 6 spf 5/21/2020 - 5/25/2020 Ref Elevations BF 22.28 (attached)5 KB Form 10-407 Revised 3/2020 Sr Pet Eng Sr Pet Geo Sr Res Eng STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Development Stratigraphic Test 2.Operator Name: 3.Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. Date Spudded: 8. Date TD Reached: 9. 10. Plug Back Depth(MD/TVD): 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 66.64 Water Depth, if Offshore:13. N/A One API Number: Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary 23. 18.Property Designation: ADL 028320 & 034631 21.Re-drill/Lateral Top Window MD/TVD: N/A 1932' / 1904' Submit within 30 days of Completion, Suspension, or Abandonment By Samantha Carlisle at 9:45 am, Jun 15, 2020 +(: Completion Date 5/25/2020 HEW RBDMS HEW 6/16/2020 GMGR21JUL2020DSR-6/16/2020 4503' SFD 7/6/2020 4068'SFD 7/6/2020 DLB 06/16/2020 If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base Formation at total depth: Contact Name:Roach, Frank Contact Email: Frank.Roach@bp.com Authorized Name:Lastufka, Joseph N Authorized Title:SIM Specialist Authorized Signature with Date:Contact Phone:+1 907 564 4373 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b. Well Class Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other ( explain). Item 28. Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. 1924' 5750' 9107' 9729' 9966' 10070' 10216' 10324' 10511' 11831' 12475' 5086' 7829' 8339' 8532' 8617' 8736' 8818' 8927' 8989' 8766' Ugnu Colville Mudstone HRZ Sadlerochit Kavik Lisburne - Wahoo 7 Wahoo 6 Wahoo 5 Wahoo 6 (Invert) Wahoo 7 Wahoo 7 (From Base) 1952' 28.CORE DATA Conventional Core(s) Yes No 5 Sidewall Cores Yes No 5 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. Well Tested? Yes 12475'8766' Top of Productive Interval 10216'8736' Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 30. FORMATION TESTS29. GEOLOGIC MARKERS (List all formations and markers encountered): NAME MD TVD Permafrost - Top 20'20'No 5 31.List of Attachments:LOT / FIT Summary, Summary of Daily Drilling Reports, Summary of Post-Rig Work, Survey, Cement Report, As-Built, Wellbore6FKHPDWLF Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Joseph N Lastufka Digitally signed by Joseph N Lastufka Date: 2020.06.14 13:18:19 -08'00' 8,568' MD Test Date Test Type Test Depth (TMD-Ft) Test Depth (TVD-Ft) AMW (ppg) Surface Pressure (psi) Leak Off Pressure (BHP) (psi) EMW (ppg) 03/07/20 LOT 4,503.00 4,068.33 9.00 1,000.00 2,904.35 13.70 03/12/20 LOT 9,868.00 8,452.17 10.30 1,550.00 6,072.38 13.80 Well Name: L5-07 BP AMERICA LOT / FIT Summary Page 1 of 1 ! "#"!$ "% &'&('&& ) 1 234 ! 5 '/!!&& 4) ' &'&('&&(6 ! 5! 2 ! 5 !! !778"/9"79::; ) 4 9&&<::/:=$ 3 6 % 5 +=;; 0 $=% ) 2> 2 =" 2#2 $% 2 &'&.'&& !78 / 8!!78 ""! 7" 7 #!780""! ?"@! # !!7 7" 7 !" 7 6" 9- 8" !!0"!!786"@ /(* ! 6" / 6"@!780!"6 ; "+&/&+;( ! 6" / " !76" "@! 6!!?9 77 ?6" 69 6" " !76" #" !9 6 787 #? 9!! 9!78! "9! 6 78 &/&+; ! &'&('&& !789 / 8!!789"! 7" !7899 77 ?6" 7# 7 ! " !78969 6" 7# 7 ! " &/& ! !789 / 8!!789"! 7" !7 !!7A+"00! 7 !780""! !7896!7 ! 9 "9#9# 7 0"7 " 66 6B96 67 !" 7 7! " " " 9 787 " !-7!- 6 "!78 0""! 7 #78#!9!69 B6 C96!#""!780""! 78# +& 7 ?#" 97" !7 "-#8!7 7- " " " " !7@ 7! !"!6#7" ? 6 !789 "8-"0076"9#"- 7 !""0? DDD !78 DDD ;/& ! 7@! ! / 79 # 7@! !? 6 79&+ +'*E!7!-&+ +'*E 7@! !9! 70@@7 # +:E 7@! !, 7""9 #"0 #!78 #""9969 "!7 !87F969 "! 7 0"!7!-0"7- 9!9 76" #8"9 7!796 ":E 7! #8"9 @!9" " !7@ " * +'&E70 +&/+; ! ) +&;*6'++'&&**All depths reported in Drillers Depths** ! "#"!$ "% &'&('&& ) 1 234 ! 5 '/!!&& 4) ' &'&('&&(6 ! 5! 2 ! 5 !! !778"/9"79::; ) 4 9&&<::/:=$ 3 6 % 5 &=;; 0 $=% ) 2> 2 =" 2#2 $% 2 7@! ! / !0"!6 7@! !09 7" 70@@" 7&+ # 9!" 7;. #@ 0"!6 07! 8!6 7 7@ ?"8! C00C" +/+.;+; ! !7 (*/; 69+:E9!0#"# "(G6 +:E?6!7 +/.H"69 6" "! 69 "0# "# 077 07#" #0"! !9! 69 7 "*7 +/&+.; 9!0 !7 (*/; #" !78@' 7@! !'#& !77 # !9"" G! /&;& 9!0 !7 (*/; !78!@7/&+&; 9!0 !7 ;:./; "9 " 9 "! "+&G6 - !7 +:E9!0#"0!"6 #" "6"0 #" 9 "! +&G6 ";:(G6 $&*&G 7;#"9!A.0 '#!7 #" 7" 9!@?% 7 "9!"A+.0 '#! 86-7"" "6-;7"00 " "6 *!6-;0 "!I9"" "6-+ 0 "!I9"00" "6 9 "+" 9A*-"A*-!" A* 69 78# A./:87'"9 ;/&+ 9!0 ;'+'&& !7 ;:./; 99 "(:G6 69 # !7 "! ""6 ## &/& 9!0 !7 +-;/; !7+:E9!0#"0!"6;:(G6 " +;+G6 $::&G7+#"9!A::0 '#!7 # " 7" 9!@?% 7 "9!"A9 "&;0 '#! 86-++(7"" "6-(&7"00 " "6 *!6-0 "!I9"" "6-& 0 "!I9"00" "6 9 "+." 9A(-"A(-!" A( !77 "*G6 69 7#" 8?!"0!"6*G6 "9!0-8?!" @!?J(*G0 !*G6 9 " 7! 7" 69 78# A./:87'"9 8?!"9!@?@!?(0 -0!"6*G6 - 07! 6 9!@? .((G6 - " 7& 7 ""9 7@ 9!@?-8?!"!788 9 "+G 6 !!"8!6 +/+&& 9!0 ) +&;*6'++'&&**All depths reported in Drillers Depths** ! "#"!$ "% &'&('&& ) 1 234 ! 5 '/!!&& 4) ' &'&('&&(6 ! 5! 2 ! 5 !! !778"/9"79::; ) 4 9&&<::/:=$ 3 6 % 5 ;=;; 0 $=% ) 2> 2 =" 2#2 $% 2 !7 &-:/; !7+:E9!0#"0!"6+;+G6 " &G6 $(:G7(#"9!A+.0 '#!7 # " 7" 9!@?% 7 "9!"A9 "&;0 '#! 86-+*7"" "6-+&:;7 "00" "6 *!6-.0 "!I9"" "6-* 0 "!I9"00" "6 9 "+." 9A++(-"A+*-!" 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"#"!$ "% &'&('&& ) 1 234 ! 5 '/!!&& 4) ' &'&('&&(6 ! 5! 2 ! 5 !! !778"/9"79::; ) 4 9&&<::/:=$ 3 6 % 5 *=;; 0 $=% ) 2> 2 =" 2#2 $% 2 ;';'&& !7 *-++/; !7+:E9!0#"0!"6;*+&G6 " *+&G6 $++G7+#"9!A;0 '#!7 # " 7" 9!@?% 7 "9!"A9 "&0 '#! :86-&&7"" "6-+(7 "00" "6 !6-+;0 "!I9"" "6- ++0 "!I9"00" "6 9 "&*" 9A+(*-"A++-!" A+*+ 6 9!@?@!?J(*G 69 78# A(/+87'"9 "!@"!" #!"98# # #7 #@ +/+ 9!0 !7 *-++/; 7!9 ##"7 #&, " "69 :86-&&7 :!6-+0 "!I9 !+ @!?&67 " ;:(.G6 6"7 "!0"!+67$ 7% ;/+.;+ 9!0 !7 *-++/; 9"9 "0 ##"0!"6;.(:G6 " !@7"9 !7 # &G6 "!@ 78# #" # ! "0 #?0"6 7" ! 78 J;&&G 6 -!60!"6;&&G6 "&.G6 - :86-+(7-!6-++ +0 "!I9 "" #!79978 "&G6 &/&++.; 9!0 !7 *-++/; !97 ##""@ "!0!"6 &G6 "" "6 *+&G6 "79!9787 ##" +/&&;&+ 9!0 !7 *-++/; 7!9 ##" :86-&&7 :!6-+0 "!I9 +/&&; 9!0 ;'*'&& !7 *-++/; 7!9 ##"7 #&, " "69 :86-&&7 :!6-+0 "!I9 !+ @!?&67 " ;.(G6 6"7 "!0"!+67$ 7% &/& 9!0 !7 *-++/; 9"9 "0 ##"0!"6;.(G6 " # ""0 ## (+G6 "79978 #!"98#"#" &/*& 9!0 !7 / ? "9!0#"#0!"6(+G 6 "9!0 7 8! & & 7898 */.* 9!0 78 *-++/; !!780""!/.;. 9!0 78 *-++/; !78978!978 "" @" -7, 7"-@ "! 7 &/+;.; 9!0 ) +&;*6'++'&&**All depths reported in Drillers Depths** ! "#"!$ "% &'&('&& ) 1 234 ! 5 '/!!&& 4) ' &'&('&&(6 ! 5! 2 ! 5 !! !778"/9"79::; ) 4 9&&<::/:=$ 3 6 % 5 =;; 0 $=% ) 2> 2 =" 2#2 $% 2 78 *-++/; !9+; ;'.K-:.L- .- 9!078 "*&&M6 #0" 9 " 70&7 " "!I9" 7" "@!8"0 J+&0 077" #0? ""00@!? +C"7 !7!9 7"@!?+C"7 60"!&-"7!9 7" #!"98# #!60!" " 79'"78# @!?+C"7 9&.-"+& 69 78# (/+87-(/+8"9 +;/+; 9!0 ;''&& 78 *-++/; !9+; ;'.K-:.L- .- 9!078 0!"6*&&M6 "*;G6 9 " 70&7 " "!I9" 7" "@!8"0 J+&0 077" #0? ""00@!? +C"7 !7!9 7"@!?+C"7 60"!& " 79'"78# @!?+C"7 079;:-"+* 69 78# (/+87-(/+8"9 69 "#7!7#+;. ;/; 9!0 78 *-++/; " 7 7"69 "6 78 !"! 7 89 "6 78! "0+6 +6-;7 !7!" +G 076 77 # ! !9! ";70"! 679 */;; 9!0 ) +&;*6'++'&&**All depths reported in Drillers Depths** ! "#"!$ "% &'&('&& ) 1 234 ! 5 '/!!&& 4) ' &'&('&&(6 ! 5! 2 ! 5 !! !778"/9"79::; ) 4 9&&<::/:=$ 3 6 % 5 :=;; 0 $=% ) 2> 2 =" 2#2 $% 2 78 *-++/; 6 +; ;'.K9!078 0"" 96+"0+869 9#77 !<6-;7 !" "698 96("0++87 ! 6 <:6-,@"96 ;N7"@!0 *N"!0 $?7 +/(+9/0 '% 96::/*"0+/.88 7 <6-,@"96*N$?7 +/+: 9/0 '% !" "98 !7!" 7+0 9!0 #79678 6 - " #!78 " #9 7-9 " 6"@787 !0"!6 76 7 #!7896 (/+8I97 !7 69 ! . 7 +67: 7-0+&7 : 7 67(:7- 0+*7 ! 9! ";6!7"! "98 96077!9 78!9!.: 7 9698 7!!9! " +;:7-#0" O8"" 6 7$7%<+;" ;''&& " 76 @"96:*( $69! ? !"<(:N96 0077?% J;"06 "9!0 " "0!"66 ,7 #" "6 7 /+;; 9!0 78 *-++/; 90 !6 C" !7 09# 7@! !? 6 ! " 78C"7 !78 " ? " "?"78 I976 " "9!07 "9 0"", ;/+:;+; 9!0 78 *-++/; 7 " # 7@! !? 6*/&++:; 9!0 78 *-++/; 79+; '.E# 7 " !?8 @@"" 7 ! 978# 0!"678# "!7 (H"078# !7! " "# "886 "6 ;/&+ 9!0 ) +&;*6'++'&&**All depths reported in Drillers Depths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ll depths reported in Drillers Depths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ll depths reported in Drillers Depths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ll depths reported in Drillers Depths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ll depths reported in Drillers Depths** ! "#"!$ "% &'&('&& ) 1 234 ! 5 '/!!&& 4) ' &'&('&&(6 ! 5! 2 ! 5 !! !778"/9"79::; ) 4 9&&<::/:=$ 3 6 % 5 ++=;; 0 $=% ) 2> 2 =" 2#2 $% 2 !7 (-../ 7!9 &/," "69 (86-7;((7-0;+7 +!6-+:0 "!I9 A0!"6++/+.86 "+/:+8 6 69 78# 7'"9 A+/;8 6"7 "!0"!+67$ 7% ;/&&;+( 7 + !7 (-../ 9"9 "0 ##" "!978 0!"6(..G6 ".&G6 +/&&; 7 + ;'+'&& !7 (-../ 9"9 "0 ##"0!"6.&G6 " # ""0 ## ..G6 6"7 "!0"!+67 #78 #" ""0#$ 7% " #8#" !6!7898 / 7 + !7 (-../ ? "+& +'*E#0!"6..G6 " 9!0 7 8! & + 7898 !!780""! +/: 7 + 78 (-../ !78978!978 "" 9!9#78 !789@" 7 # "!I9 9!-7 , 7"-@ "!- 7!7 +/;: 7 + 78 (-../ !9( '.K-*L- .-@6&+7 +78 " #9!078#" *;M6 #0" ! "" 7"" # 0" "! 9C 989! 7 " "!I9 9!" 7" ";+ 0 07" #0? ""00@!+ C"7 7 #" " 79'"78# @!?+C"7 9+(-"+: 69 78# +/;87-+/;8"9 +&/&; 7 + 78 (-../ 7!9 " "69 +6-&7 /&;& 7 + 78 (-../ !9( '.K-*L- .-@6&+7 +78 0!"6*;M6 "+G6 9C 989! 7 " "!I9 9!" 7" ";+ 0 !7!9 7"@!?+ #C"7 60"!+ " 79'"78# @!?+C"7 9&+*-"+. 69 78# +/;87-+/;8"9 69 "#7!7#+. ;/&; 7 + ) +&;*6'++'&&**All depths reported in Drillers Depths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ll depths reported in Drillers Depths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ll depths reported in Drillers Depths** See cementing report included for details. ! "#"!$ "% &'&('&& ) 1 234 ! 5 '/!!&& 4) ' &'&('&&(6 ! 5! 2 ! 5 !! !778"/9"79::; ) 4 9&&<::/:=$ 3 6 % 5 +*=;; 0 $=% ) 2> 2 =" 2#2 $% 2 "9! (-../ #89!!60!"6( '.E "* +'&E PE@! 69 C"7 7 98 07 +/&; 7 + "9! (-../ 9!!67 #* +'&E E C"7 &';70"!#! 67 # 8"" !0"!6?"09 7" +/;;& 7 + "9! (-../ !78 " I976 " "7 9 ? " 98 7 . '.E7 !!78 +/*;;; 7 + 78 (-../ !9! ( '.E78 ";7 0"!;#! 67 " &7707! +67 " +77" +67 96 (- ( 69 78# 7'"9 A+/;8 6 !7 !7!! 7 +&+. 9!"@ +/:*; 7 + !7 (-../ 69#L;-. +'&E !7786? !! '6 69. +'&E#?"8:+:6 C+ 7 - 9 " !-" !-6-"! 9-" 76" 0!F!" +; ;'.EP( '.E99 7 #+& 7&6-(7 ;/(;: 7 + !7 (-../ !97 ##""@ "!7 ## L;-./E !7786?0!"6.+M6 "(M6 #"#" 6 "" +M 6 8"" 077@!?&M6 9&:-"+: 69 78# 7'"9 A+/;8 6"7 "!7 ##"07 !7 8"" 76 # "0!"6(G6 8 " 98 (G6 &6-;.7-:!6-&0 "!I9 8 "98J+;G#78# :/+;(; 7 + !7 (-.(./ !7"9 6 7#" ! &G "00"!6 7"0!"6(G6 " (.(.G6 -.*:G @ / :86-&:7" 6-&7"00 6- +!6-&+0 "!I9" 6+( 0 "!I9"00 6-+;" 9;-"+:.-!" &: 69 78# 7'"9 A+/;8 8" "698" # (.G6 */&+; 7 + ) +&;*6'++'&&**All depths reported in Drillers Depths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ll depths reported in Drillers Depths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ll depths reported in Drillers Depths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ll depths reported in Drillers Depths** ! "#"!$ "% &'&('&& ) 1 234 ! 5 '/!!&& 4) ' &'&('&&(6 ! 5! 2 ! 5 !! !778"/9"79::; ) 4 9&&<::/:=$ 3 6 % 5 +.=;; 0 $=% ) 2> 2 =" 2#2 $% 2 78 +-&+/ 9!7 ?"9 87#; 7 ! #!" 7 7" 0"!! #;9 9 !"! ""'76 6"7 "!0"!097 " 7"! ;# !78 " Q#?+#! 8!#"978!"9 !78 #" "#& !7 !0"!678# 67 7" 7!9 +," "69@!?* #"9! 6-;.7 ?67"! Q+# 69 78# 7'"9 A+/;8 /+.+; 7 & 78 +-&+/ #;7 ! #!" 7" 70 87"!67 ! #!" 7 7" 7 "6 " "9 78 6"7 "!0"!097 " 7 "! Q;# 8!#"978!"9 !78 !0"!678# 67 7" 7!9 +," "69@!?* #"9! 6-;.7 ?67"! Q# 69 78# 7'"9 A+/;8 :/+. 7 & ;'+'&& 78 +-&+/ " 79 "7 "6 " "9 78 6"7 "!0"!097 " 7 "! Q;# 8!#"978!"9 !78 !0"!667 7" " 978 7!77# 7!9 +," "69@!?* #"9! 6-;.7 ?67"! Q# 69 78# 7'"9 A+/;8 &+/&+ 7 & ) +&;*6'++'&&**All depths reported in Drillers Depths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ll depths reported in Drillers Depths** ! "#"!$ "% &'&('&& ) 1 234 ! 5 '/!!&& 4) ' &'&('&&(6 ! 5! 2 ! 5 !! !778"/9"79::; ) 4 9&&<::/:=$ 3 6 % 5 &=;; 0 $=% ) 2> 2 =" 2#2 $% 2 78 +-&+/ 897+67!6 "07 7!9 78! "0:/6 " 7#"! <&6-;+*7-"" <;6-;(:7-"" <*6-*(7-"" <6-:.7-"" <:6-.7-"" <:/6-(:7-"" 69 78# 7'"9 A+/;8 76" #96 /&+; 7 & 78 +-&+/ 7!#8! !0!"6 7! !"+/E 78 ! 8" "6 "9 #" +&+*G6 96 " 6- +;:7 !9!9 "&&7 " > " 7!#8! !9!9 ";:7 "! !978 "" #!"9 79;G @!70?!978 "" ! ";0"!6 C"/ /&;& 7 & ) +&;*6'++'&&**All depths reported in Drillers Depths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ll depths reported in Drillers Depths** ! "#"!$ "% &'&('&& ) 1 234 ! 5 '/!!&& 4) ' &'&('&&(6 ! 5! 2 ! 5 !! !778"/9"79::; ) 4 9&&<::/:=$ 3 6 % 5 &&=;; 0 $=% ) 2> 2 =" 2#2 $% 2 "9! +-&+/ "9 0 !6 C" !7 09#7 # !7 #!"98#7@@ 09# 7 # !7 09 7"""6" +/+*;+;; 7 & "9! +-&+/ !789 " " 69* +'&E700"@G ! # ;.0"@G ! 69 C"7 9!!78 7 9! 98 077 7!"9 !0"!6" ? ";78"" +/+:+*; 7 & "9! +-&+/ " "&7"-;7#78# 0"!679 # 7 #K-&'.K-B*+'&E C"7 !6-@ 0"#" 7 ?"8!7,? :/&&+: 7 & "9! +-&+/ 9 98 7 . '.E7 !!78 /&&;&& 7 & "9! +-&+/ !78 "" I976 /&;&&; 7 & 78 +-&+/ !9! E7! ";70"! ;#! 67 +/&; 7 & ;'+'&& 78 +-&+/ !9! E7! ";70"! ;#! 67 (/& "!9!9- (/& +/;8 " *7707! +67 " +77" +67 6 !7 !7!! 7 +&+. " "7 !78 " I976 /; 7 & !7 +-&+/ 69 !97 ##"7 ## L*-: +'.E!" 9 7" !7786? "(*G6 !! '6 699 " !-" !-6 69: +'.E#?"8:+;6 +7 987 @!70?6 "" " "9! */; 7 & !7 +-&+/ !97 ##""@ "!7 ## L*"*E !770!"6(*G6 "(..G 6 077@!?&M6 #"#" "" (*M6 8"" 69 78# 7'"9 A+/;8 6"7 "!7 ##"07 !7 8"" 76 :/++; 7 & !7 +-&+/ # " !"98#6 !78! 0!"6(..G6 "+*.G6 .*86-:.7 /+&++; 7 & ) +&;*6'++'&&**All depths reported in Drillers Depths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ll depths reported in Drillers Depths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ll depths reported in Drillers Depths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ll depths reported in Drillers Depths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ll depths reported in Drillers Depths** ! "#"!$ "% &'&('&& ) 1 234 ! 5 '/!!&& 4) ' &'&('&&(6 ! 5! 2 ! 5 !! !778"/9"79::; ) 4 9&&<::/:=$ 3 6 % 5 &=;; 0 $=% ) 2> 2 =" 2#2 $% 2 ;'&+'&& !7 +&-;/ " 79 "9 ? "#L*- : +'.E !7786?0!"6+*G6 987 @!70? ""79 ? " -" ! 9 " ! 7 8! ; & , 7 " 0 6"7 "!7 ##"07 !7 #7? "J&#"! 69 78# 7'"9 A./:8 +/+; !" + !7 +&-;/ 69 !97 ##"7 ## L-: +'.E !7786? 699 " !-" ! 987 @!70? "" 697 : +'.E#?"8:+;6 @; 7 " "9! 6"7 "!7 ##"07 !7 #77789J;#" ! 69 78# 7'"9 A./: +/;+; !" + !7 +&-;/ !97 ##""@ "!7 ## L0!"6+*G6 "+;G6 077@!?&M6 #"#" "" &:(M6 8"" 69 78# 7'"9 A./:8 6"7 "!7 ##"07 !7 #7!9787J;#" ! /.;; !" + !7 +&-;/ !60!"6+;G6 "+&G6 "9 78# #"" #7 978"9 "0 ##"7 ##L +;+G6 &86-+&7-+!6-+;0 "!I9 +/(;.; !" + !7 +&-;/ !97 ##""@ "!7 ## L0!"6+&M6 "++M6 077@!?&M6 69 78# 7'"9 A./:8 "79!978 #!"98#+;+G6 "9 ! 78# #" +G6 !6 " #!"98#0!"6++*(G6 " ++G6 &86-+&7-.!6-+*0 "!I9 &/++;(; !" + !7 +&-;/ # !6 #!"98# 78# #" " 7 7" "" "6 !6 " #!"98#0!"6++*(G6 " ++G6 &0 '#! &86-+&7-. +&!6-+* + 0 "!I9 "!@ "00 ++&*G6 S !9!7 "!I9789 # " (0 '#!0!"6++G6 "+&;G6 &86-+;*7- 69 78# 7'"9 A./:8 ;/+++; !" + ) +&;*6'++'&&**All depths reported in Drillers Depths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ll depths reported in Drillers Depths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ll depths reported in Drillers Depths** ! "#"!$ "% &'&('&& ) 1 234 ! 5 '/!!&& 4) ' &'&('&&(6 ! 5! 2 ! 5 !! !778"/9"79::; ) 4 9&&<::/:=$ 3 6 % 5 ;=;; 0 $=% ) 2> 2 =" 2#2 $% 2 !7 +;-+(/ 7! !7!97 ##"" @ "!0!"6++(G6 "+;+(G6 9&-"+ +&G6 6"7 "!7 ##"07 !7 #7!9787+& #" ! 69 ? 60!"6./:8 I97 !7 "./8@7"707 ;N 69 78# 7'"9 A./8 "79" #7!9787 &/++&; !" + !7 +;-::;/ 7! 7"? !7: +'.K!" 9 7" #"0!"6+;+(G6 "+;::;G6 -.;.G @ *;G7:#"9!A./.0 '#!7 # " 7" 9!@? 7 "9!"A9 "+0 '#! ;86-+7"-+:7"00 6 +;!6-+;0 I"" "6+& 0 I"00 6-+&" 9&;;-"+*-!" +(* 9!@?@!?J;0 0"! RH 9!@?@!?J(0 0"! QH 8 #8!"9 !8A+( 97 -6, &*:97 69 78# 7'"9 A./8 ?67"! #7 !778 @!7 0!"6*# "&&# +;:G6 +;::;G6 78707 6"9 "08!"9 99 78 #! :/&++ !" + !7 +;-::;/ 7! !79"9 "0 ##"" @ "!0!"6+;::;G6 "++(G6 - 77 E78 6"7 "!0"!+67!7"! " 978"00" "6 7"! J&# 6"7 "!7 ##"07 !7 #7978& +#" ! 69 78# 7'"9 A./8 7"! E#"J+# "79" #7978 &/&;;&+ !" + !7 +;-::;/ 7! !7!97 ##"" @ "!0!"6++(G6 "++&G6 6"7 "!7 ##"07 !7 #7!9787+#" ! 69 78# 7'"9 A./8 "79" #7!9787 /&;; !" + ;'&;'&& !7 +;-::;/ 7! !7" 79 "!97 # #""@ "!0!"6++&G6 " +;::;G6 6"7 "!7 ##"07 !7 #7!9787+ &#" ! 077@!?& 69 78# 7'"9 A./8 "79" #7!9787 +/+; !" + ) +&;*6'++'&&**All depths reported in Drillers Depths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ll depths reported in Drillers Depths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ll depths reported in Drillers Depths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ll depths reported in Drillers Depths** ! " #$ % & '& ()*)++ 3 456 # 7 )1##++ 6'& ) +)+-)++-! # 7# 4 # 7 ##͹ 1 : 8:**0 ' 6 :++;**1*<$ 5 ! % 7 ,<, 2 & $<% ' 4= & 4 < 4"4 $% & 4 0)+)++ ,(/>*1 !:&#:8 "" 8 "" ?*/* ,)>@&:!8# : !A ,-B!& !:* ,)>@8 8 " CC #! D& 8 :/2. #/ 88C#/2. #/ 88C#/2 :&(@ "& ! 8 #8 "" 28"8 !89:"+*" # !:&89" 8) : E>19 10 #:#& ,(/>*1 #:8 "" D #8 "" ?* (@&@Ͳ# !,-B!& ,(>*B!& 288D#A+B!& ! 8 #8 "" 28"8 !89:"+* ++" # !:&89" 8) : E>19 "& & 09!/ 8 28 ! *1*00 #:#& ,(/>*1 !9 8#: 8 8#: & &822# !88 " ,-9!/(8/,( >#!/,* ,, 2 #F: :!,/>##) #2!8 &A!8 # &#&2# ! +>" ,*" :!,/,##) #2!8 &A!8 # ,*"8#89 ,>" :!,/,,##) #2!8 &A!8 # &#&2# ! ,-" ," &A!8 # 8#&2# !, " +*""8!8.892 :# "! 8 :!,/>##) #2!8& : 8& 8 &A!8 # &#&2# ! +*" " ,(1+0*0 #:#& ' ,+*+!),,)++**All depths reported in Drillers Depths** ! " #$ % & '& ()*)++ 3 456 # 7 )1##++ 6'& ) +)+-)++-! # 7# 4 # 7 ##͹ 1 : 8:**0 ' 6 :++;**1*<$ 5 ! % 7 +<, 2 & $<% ' 4= & 4 < 4"4 $% & 4 ,(/>*1 ! : 22 ! D #/#8: :89 : 2 #89 :! : 2" 2# !,(>*B ,0+,,B !& : 02 )!8 :! ,!/,>8 :+/ ,* ,(B!& !:&89" 8) : E>19 +>)"#88 8 # " :!89 22 ! # A8#& ( ""8:!89 22 ! 01+0 #:#& 0)+*)++ ,(/>*1 : : 2" D #2# ! ,0+,,B ,-B!& ! 8 # "@" " # ! 8 #8 "" 28"8 :89 :# 2 "" * (" # !:&89" 8) : E>19 2# !,0+,,B!& -*>B!& : 02 )!8 # "8:89 (" 2# !-*>B!& +B!& : *2 )!8 # "8:89( (" ,1, #:#& ,(/>*1 :&A& "?* " #& 228 "! #8 &A& :! " # ! #! &##892 # (1,(, #:#& 89 ,(/>*1 #89: #:( ,)+@8# #89:& A 89 9& #F: :#F:8! D#82A8 : 88"& ,1,,( #:#& ' ,+*+!),,)++**All depths reported in Drillers Depths** ! " #$ % & '& ()*)++ 3 456 # 7 )1##++ 6'& ) +)+-)++-! # 7# 4 # 7 ##͹ 1 : 8:**0 ' 6 :++;**1*<$ 5 ! % 7 0<, 2 & $<% ' 4= & 4 < 4"4 $% & 4 89 ,(/>*1 #:( ,)+G/,+1**?)2 /,0# >/" # &: 8 8# (>H!& "2 # " #I 8 : 2 82(,8& #F:" 8 >0 2 #F:D 8 (((2 #:+2 89 #8C# I 8 , ,* #: 2++ #8C#& 00, #89 #:8" *2 )!8 (>H2 !& 288# D#AI 8 / 22 D#A+I 1 !:&89" 8) : E>19 # "8#:898 "" E *" (*> "" "8 #:898# :>+/ >+ (>B!& !:8#"9#)8# #&#:89 # "#2 #&# D#82A"## &&!8.&:#I: 8#: ,1.8#D :!J!/J 8 :/ 2 #"9# !&: -1, #:#& 0)+)++ 89 ,(/>*1 8#: ,1.8#D :! 0!/-+8 :/ 2 #"9# !&: !:&89" 8) : E>19 ,1, #:#& 89 ,(/>*1 8: #:8 "" D #8 "( ,)+@# &: 8 8# (@&@Ͳ# !(>H!& ,00>H!& #:8" *2 )!8 :!&XD :0!/,(8 288D#A+ & !:&89" 8) : E>1)>1*9 # "8#:898 "" E >" & + ,0+*B!& -1,, #:#& 89 ,(/>*1 "& (,)+@8#2# !,00>B!& ,(>*B!& 0!/0+8 9 ! & " :+(/ ,( ,(*B!& (1,(, #:#& ' ,+*+!),,)++**All depths reported in Drillers Depths** ! " #$ % & '& ()*)++ 3 456 # 7 )1##++ 6'& ) +)+-)++-! # 7# 4 # 7 ##͹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ll depths reported in Drillers Depths** ! " #$ % & '& ()*)++ 3 456 # 7 )1##++ 6'& ) +)+-)++-! # 7# 4 # 7 ##͹ 1 : 8:**0 ' 6 :++;**1*<$ 5 ! % 7 <, 2 & $<% ' 4= & 4 < 4"4 $% & 4 89 ,(/>*1 #89& 89 &##89 2 # 1(0 #:#& 89 ,(/>*1 : L8B 2X 8# !"8 L# 8 8 ! 8 #8 "" 28," # !:&89" 8) : E>19 ,1* #:#& 28" ,(/>*1 ! 88C28"89 28"( ,)+@ 8# &(@⊸"& ,10* #:#& :# ,(/>*1 "9:#8#!2# !( ,)+@J@ + )>@J@D# 8: :" 28 "# :9"8 ! 8 #8 "" 28> , " # !:&89" 8) : E>19 ,1-0 #:#& ":# ,(/>*1 :#:"891-0- #:#& :# ,(/>*1 #89: #89: F:8 8 :9 288&:#98#2# ! 8: :" 28 "# :9"8 ! 8 #8 "" 28> , " # !:&89" 8) : E>19 ,1,,-0 #:#& :# ,(/>*1 +8 /08"89" 2 #!8: " 8 "+ )>G&G I 8 &#!/D &2 " 8 &8D&A 9# ! "### 8: :" 28 "# :9"8 ! 8 #8 "" 28> , " # !:&89" 8) : E>19 *1,,, #:#& :# ,(/>*1 #89& F:8! & 8 : :9&8 ##89 !:(@2 AI 8 8! ! 88C28"89" #892 # ,1,>, #:#& 28" ,(/>*1 !:"?/28"89!A ++>B !"89# !:" # " D#" &#& " "(1-*@ & :89 :89 :!#:/I#/$*%( 0)(@ #/# # ! 8 #8 "" 28>" # !:&89" 8) : E>19 ,1,-0,> #:#& 28" ,(/>*1 #:8 "" D #8 "" ?2# !++>B!& -0>B!& ! 8 #8 "" 28"8 #:898* >" # !:&89" 8) : E>19 (1,-0 #:#& ' ,+*+!),,)++**All depths reported in Drillers Depths** ! " #$ % & '& ()*)++ 3 456 # 7 )1##++ 6'& ) +)+-)++-! # 7# 4 # 7 ##͹ 1 : 8:**0 ' 6 :++;**1*<$ 5 ! % 7 *<, 2 & $<% ' 4= & 4 < 4"4 $% & 4 0)+-)++ 28" ,(/>*1 #:8 "" D #8 "" ?2# !-0>B!& ,,*B!& ! 8 #8 "" 28"8 #:898*" # !:&89" 8) : E>19 10 #:#& 28" ,(/>*1 8"#! #&99 8#8 " D#" 01!/,>8/0#!/2 #F: :++(/ ++ "& 01!& 928" ,,>*B!& ! 228 "# #A&99 8# 8#8 " D#" & & +/#:#8# (08 8: 0,>& #D28" !2#1 A8: ,,*B!&:+ 1,0 #:#& 28" ,(/>*1 : : 2 "" 8 "( ,)+@8# 2# !,(>*B!& :! : 2 "" 2# !,(>*B!& ,0>>B!& 0!/(>>8 : : 2 "" D # 2# !,0>>B!& (*0B!& ! 8 #8 "" 28"8 :89 : *" # !:&89" 8) : E>19 ! 8 # " "@" 0 ( " # ,1,,, #:#& 28" ,(/>*1 :&A& "?/ D#" !A#28"89"& ! 8 #2 #,!8 2" (" # A& ( 0)(@ #/# #/ I#&:!#:) D#" !A2# ! 228" !:&89" 8) : E>19 1,,0,, #:#& 28" ,(/>*1 #89:& A 89 9&( ,)+@ "&89F:8! !:. &2 D 1,+,,0 #:#& 28" ,(/>*1 A& ( ,)+@8#2# !(*0H!& :>/ > (*H!& ! 8 #8 "" 28"8 :89 : " # !:&89" 8) : E>19 # D#&I 8 /I#A/ #89& #8C###:89 #&# " "#&89 & &8 8 8 " 89828 &!9 &: "&89: # B& " #!8 ,1++,+ #:#& ,(/>*1 &##892 # #89& & A 89 9& ( ,)+@"&89F:8! ,1+0++ #:#& ' ,+*+!),,)++**All depths reported in Drillers Depths** ! " #$ % & '& ()*)++ 3 456 # 7 )1##++ 6'& ) +)+-)++-! # 7# 4 # 7 ##͹ 1 : 8:**0 ' 6 :++;**1*<$ 5 ! % 7 <, 2 & $<% ' 4= & 4 < 4"4 $% & 4 ,(/>*1 !:"?>/* ,)>@ : !A##&& *>B!& $!!A"?*/* ,)>@&:! 8# : !A% ,1+0 #:#& 0)0)++ ,(/>*1 !:&#:8 "" 8 "" ?>/ * ,)>@&:!8# : !A ,-B !& !:* ,)>@8 8 " CC #! D& 8 :/2. #/ 88C#/2. #/ 88C#/2 :&(@ "& ! 8 #8 "" 28"8 !89 :"" # !:&89" 8) : E>19 +1+ #:#& ,(/>*1 #:8 "" D #8 "" ?* (@&@Ͳ# !,-B!& ,(0(B !& 898(@Ͳ# !8"& ,B!& #:(@&@ : 2&##82# !,B !& ,(0(B!& " #F: " 8 "8 #:898 288D#A+B!& ! 8 #8 "" 28"8 !89 :"* ,+" # !:&89" 8) : E>19 9 8989" ,(0,B!& & + ,(0+(B!& ,(1,*0+ #:#& ,(/>*1 "& 2# !,(0(B!& ,(*0B!& ,(09!/(08/,#!/,+2 #F: :+*/ ,/# ++ ,(*0B!& # :# 28 8& "# :9"88& :!& #89 ,! # *" :9" # :#2 #,+ 8 # &#& K,* " 8: "& 2# !,(*0B!& ,(*>B!& ,*-9!/,-8/,#!/,-2 #F: &A!8 # 0 +>" 9 ! ,(>*B!&8 "+2 !:&89" 8) : E>19 01+,*0 #:#& ' ,+*+!),,)++**All depths reported in Drillers Depths** ! " #$ % & '& ()*)++ 3 456 # 7 )1##++ 6'& ) +)+-)++-! # 7# 4 # 7 ##͹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ll depths reported in Drillers Depths** ! " #$ % & '& ()*)++ 3 456 # 7 )1##++ 6'& ) +)+-)++-! # 7# 4 # 7 ##͹ 1 : 8:**0 ' 6 :++;**1*<$ 5 ! % 7 -<, 2 & $<% ' 4= & 4 < 4"4 $% & 4 89 ,(/>*1 #:( ,)+G/,+1**?)2 /,0# >/" # &: 8 8# (>H!& "2 # " #I 8 : 2 82(,8& #F:" 8 > 2 #F:D 8 (((2 #:+2 89 #8C# I 8 , ,* #: 2++ #8C#& 00, #89 #:8" *2 )!8 (>H2 !& 288# D#AI 8 / 22 D#A+I 1 !:&89" 8) : E>19 # "8#:898 "" E ,> ,+" !:8#"9#)8# #& #:89 # "#2 #&# D#82A"## &&!8.&:#I: :> >2 #"9#!&: -1,**0 #:#& 89 ,(/>*1 8: #:8 "" D #8 "( ,)+@# &: 8 8# (@&@Ͳ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ll depths reported in Drillers Depths** ! " #$ % & '& ()*)++ 3 456 # 7 )1##++ 6'& ) +)+-)++-! # 7# 4 # 7 ##͹ 1 : 8:**0 ' 6 :++;**1*<$ 5 ! % 7 ,<, 2 & $<% ' 4= & 4 < 4"4 $% & 4 89 ,(/>*1 8#"9## "#2 #& ## 8D &# "9#&:! & 0!/+8 #:#: ,>88 " "9# 22 ,,& 28#! "9# #:# 0+8 #2# ! #:89 2# !"9# 8:& #D:!#: +* 8:&&8 8 0B&D#82A #:89 #&2# !"9# & 0 2"9# &#:#: 0(8 : ,1(+0 #:#& ! ,(/>*1 ! ( ,)+@# &: 8 8# 2 #8!:&#:# 8 08 ":>1*98! &! $A8&010,:12 )% :!>190M 0!/+8 "8 "89! &A!8 # ,> +" :!0 2>1*9!:&:"88 #;+!/-8 :!,-$0++% 2>1*9 8! &! /.D :!,0+M; 0!/+8 ": 2͸# &# &# ͸#&# #2 #!&8! 8 " ":!#9#! #&>1*9 D8 828&0M +(+&8& 0!8,8 *M# :#2 /2(8-M# :# 2 $8 "" 28 % ": 28#!& ,*>1( &8& :!:9288#: 89 #:#8 &8! D :!+(+ 2# !! .8 " ! 8,*> ! *(! ! 8 ,,! 1,,( #:#& 89 ,(/>*1 8# ## "#2 #& ## 8D 8##:# +8 #2 #:9:! 8:&. & 9: ,#!/,2 #F: 22& & 8# # #:#: +*8&: 22 : 28# 1,,0,, #:#& ' ,+*+!),,)++**All depths reported in Drillers Depths** ! " #$ % & '& ()*)++ 3 456 # 7 )1##++ 6'& ) +)+-)++-! # 7# 4 # 7 ##͹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ll depths reported in Drillers Depths** ! " #$ % & '& ()*)++ 3 456 # 7 )1##++ 6'& ) +)+-)++-! # 7# 4 # 7 ##͹ 1 : 8:**0 ' 6 :++;**1*<$ 5 ! % 7 ,+<, 2 & $<% ' 4= & 4 < 4"4 $% & 4 #: ! ,(/>*1 #:( ,)+@/,+1*?)2 /,0# >:# ! 8 # 8 " # D#82A#" !:98. 8 !A # :I :9:#&8& #F:D! 8 ((( 2 #:8 "" - ,2! ! 8 #8 "" 28& #8 "8#:899 & &8! >19 #8) : 9 ! 2( ,)+@# &: 8 8# 8 ,0>B!&0 8!K(1B& : 8 "9K*1B8 8# 8,00B!&/>>B D& !: :89"9##2! ## 8D/& :89 #89 &#:8 & # :,(-/ ,- 8! A& X: 88C89 22 8 &:8&89F:8! ,*1,>0+0 #:! #: ! ,(/>*1 #D#8" & ! 8 2:8& ,0 2>19#8 (! + 2 ## 8 8"88 & >19#8 (! , 2>19#8 (! :!& " :89 " 22 "#" ! & " ! 8 2:8&8 (1++0,>0 #:! #: ! ,(/>*1 "# &: 8 #& " :89&8 !:&89I 8 "9# &# &# && 2 2 #0!8 :&A& &89I 8 #:#: :89 ,! 08/ #D#98 +8 #:# :89 082 # 0!8/ &A#:#&# # :" 89:#2 F:8! /89A:! #:#: 08 :89& " &2 #0"# &!89 & ,1++0 #:! ' ,+*+!),,)++**All depths reported in Drillers Depths** ! " #$ % & '& ()*)++ 3 456 # 7 )1##++ 6'& ) +)+-)++-! # 7# 4 # 7 ##͹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ll depths reported in Drillers Depths** ! " #$ % & '& ()*)++ 3 456 # 7 )1##++ 6'& ) +)+-)++-! # 7# 4 # 7 ##͹ 1 : 8:**0 ' 6 :++;**1*<$ 5 ! % 7 ,(<, 2 & $<% ' 4= & 4 < 4"4 $% & 4 ":# ,(/>*1 8:& #29&&#A" ##2!## 8D& #:# "9#& 8:& #29&&#A " # &# : "! ## 8D #:# & #29D 8& (82 #,"# &!8$% # D&A $:& % #:# # (82 # !8$D8: 89" % : : &82# ! #&&&$+% 2&8-,, # &:## 8! A& @X && & : &! &"#&8F:8! 2# !#89&& : 8 /#8 & ,1,( #:! ())++ ":# ,(/>*1 #& @X && & : 8! : &"#&8F:8! 2# !#89&& : 8 /#8 & &2:": 89 .8 " " A # :#!2# ! *1* #:! #89& ,(/>*1 ⊼:8&2# ! YD 8D #A &"#&8 F:8! 2# !#89 &:#" :& # 8! # YD &#! D# 2# ! 2!8 " 8#2 #! D ,+1,>* #:! #89& ,(/>*1 :#!889&#F:8! 2# !#892 # ##89 2 8A 2 #&! &&89I 8 & I 8 #D8 8! & !:&! &: : 8 / ##8&8& #8&: &! && : 8 :/ !: # #8#&:#8 9# # *1,> #:! ' ,+*+!),,)++**All depths reported in Drillers Depths** ! " #$ % & '& ()*)++ 3 456 # 7 )1##++ 6'& ) +)+-)++-! # 7# 4 # 7 ##͹ 1 : 8:**0 ' 6 :++;**1*<$ 5 ! % 7 ,<, 2 & $<% ' 4= & 4 < 4"4 $% & 4 ()*)++ #89& ,(/>*1 ⊼:8&2# !: 88 A! & ##89 2 8A  # D8# ! & 8! # 2# !#892 # & #892 #F:8! 8&2 # ! D 8 8 #! "&"#0> ##892 #! D ##A#& ##89 *"# ()*)++ *1* #:! ' ,+*+!),,)++**All depths reported in Drillers Depths** ACTIVITYDATE SUMMARY 4/8/2020 T/I/O = TWC/0/0. RD 2" Piggyback valve OA. Install 4" ASV on dryhole tree. RU lubricator 68-840. PT ASV to 300/5000 psi. (Pass) Charted and Retained. Pull 4" TWC #433 at 105". RD piggyback 2" CIA valve. Install 2" FMC VR plug in CIA. RD 2" CIA valve. Install tapped blind flange w/ alemite fitting on CIA. PT CIA flange and VR plug to 300/3500 psi. (Pass) Charted and Retained. *** JOB Complete *** Final WHP T/I/O = 0/0/0. ASV, upper MV=C. Lower MV = O. IA, OA = OTG. 4/10/2020 ***WELL S/I ON ARRIVAL SWCP 4517***(new well post) PULL B&R FROM RHC AT 9,976' MD PULL RK-DGLV FROM STA#4 AT 6,616' MD PULL RKP-SOV FROM STA#5 AT 4,676' MD SET RK-LGLV (16/64 , 1900) IN STA#5 AT 4,676' MD SET RK-OGLV (20/64) IN STA#4 AT 6,616' MD PULLED RHC BODY FROM 9,976' MD ***CONT ON 4/11/20 WSR*** 4/11/2020 ***CONT FROM 4/10/20 WSR*** (new well post) DRIFT WITH 3.70" CENT & 2.50" S. BAILER TO DEVIATION AT 10,456' SLM ***WELL S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** 4/22/2020 CTU #9 - 1.75" Coil, 0.156" wt Job Objective: Drift, Remedial Cement MIRU CTU. Perform weekly BOP test. MU Drift BHA and RIH. Pump SafeLube down the coil to turn well over while RIH. Light taf at 10470' CTMD. Able to jet through with minimal resistance down to 10490'. Pick up clean and reduce rate to 0.5 bpm and continue drift to 10750' to ensure heel is clean. PUH from 10750 while pumping and become detained at 10,400'. Lose circulation with KCl in coil and KCl returns, no injectivity. Work pipe and then drop 7/8" disconnect ball. Tarp reel and surge ball over gooseneck. ...Continued on WSR 4-23-20... 4/23/2020 CTU #9 - 1.75" Coil, 0.156" wt ***Cont. from WSR 4-22-20*** Job Objective: Drift, Remedial Cement Surge disconnect ball over gooseneck. Bypass MM and begin pressuring up in increments. Disconnect functioned and begin POOH. Left 3.79" OD x 14.26' Drift BHA in hole at 10386' CTMD. FP coil and wellbore down to 3300' with diesel. LD BHA, perfrom injector maint, cut coil, MU Fishing BHA and RIH. RIH past fish depth to a tag at 10830'. Latch fish and attempt to retrieve but can not clear tight spot at 10409' CTMD. ABle to RIH and leave fish at TD, top of fish 14735' CTMD (Bottom of fish at 14750' CTMD). POOH. Make up 2 7/8" motor with 3.76" diamond parabolic mill and 3.79" string reamer, RIH. ...Continued on WSR 4-24-20.... 4/24/2020 CTU #9 - 1.75" Coil, 0.156" wt ***Cont. from WSR 4-23-20*** Job Objective: Drift, Remedial Cement RIH with Milling BHA with 2 7/8" motor, 3.76" diamond parabolic mill and 3.79" string reamer. Mill tight spots at 10360', 10380', 10805' and 10845' and dry drift each. Cleanout to TD and dry tag top of fish at 14722' CTMD down. Pump gel sweep from 14700' and chase out of hole. LD C/O BHA, wear on the mill shows we have debris in the well, MU Venturi and RIH. Venturi from 10250 to 14700'. POOH and recover 7/8" steel disconnect ball, disconnect inner mandel, and 1/4 cup thin steel and brass chunks. Trim pipe and change packoffs. Make up Fishing BHA and RIH to retrieve drift. ...Continued on WSR 4-25-20.... Daily Report of Well Operations PBU L5-07 Daily Report of Well Operations PBU L5-07 4/25/2020 CTU #9 - 1.75" Coil, 0.156" wt ***Cont. from WSR 4-24-20*** Job Objective: Drift and Remedial Cement RIH with Fishing BHA. Tag fish at 14732' CTMD to latch. POOH. No fish, add Slick Catch to GS and RIH. Tag at 14720 3x and POOH. Fish recovered. MU NCS Tools and RIH. Test tools at 600'. Confirm ability to locate upper sleeve. MIRU Cementers. Swap backside to diesel. ...Continued on WSR 4-26-20... 4/26/2020 CTU #9 - 1.75" Coil, 0.156" wt ***Cont. from WSR 4-25-20*** Job Objective: Drift and Remedial Cement Open Sleeve at 10400, and confirm injectivity. Pump 122 bbls of 15.8 ppg Class G cement with GasBlock and put 119 bbls behind pipe. Close sleeve, pressure test to confirm closed, and then reverse out remaining 3 bbls in coil. Jet down coil with powervis from 10700 to 10200 at high rate. Turn well over to SafeLube while jetting OOH from 10760' to surface, jetting jewelry. FP well from 2500' with diesel. LD tools and RDMO to DS16 ....Job Complete... 5/11/2020 T/I/O=Vac/0/0. Pre WWP. Set 4" H TWC #443 @120". PT 4" H TWC #443 from top side to low 300psi and high 3500psi for 5 min ea. Passed. Job Complete. See log. Final WHP,s TWC/0/0. 5/14/2020 CTU #9 2" coil 0.156 WT Objective: initial perf and acid stimulation MIRU. ***Continued on 5/15/2020*** 5/15/2020 CTU #9 2" coil 0.156 WT Objective: initial perf and acid stimulation Complete rig up and pump 1.375" drift ball. Make up test joint BHA. Begin witnessed BOP test. ***Job Continued on 5/16/2020*** 5/16/2020 CTU #9 2" coil 0.156 WT Objective: initial perf and acid stimulation Continue witnessed BOP test. Redress blind/shear ram. Complete bop test. T-Bar malfunction. ***Job Continued on 5/17/20*** 5/17/2020 CTU #9 2" coil 0.156 WT Objective: initial perf and acid stimulation T-Bar malfunction. Lift T-bar to the horizontal. Lay down injector head and lubricator. Secure T-bar and RDMO to SLB shop for repair. ***Job Incomplete*** 5/19/2020 CTU 9 2.0" CT .156wt Objective: Initial perfs and acid stimulation MIRU. ***Job continued on 5/20/20*** Daily Report of Well Operations PBU L5-07 5/20/2020 CTU 9 2.0" CT .156wt Objective: Initial perfs and acid stimulation MIRU. Function test BOPs and all alarms. Perform D1 drills (day/night crews). MU/RIH with HES 2.9" logging carrier w/ 3.70 DJN. Tag repeated at 14730', tried jetting and made no additional hole. Circulate well to slick 2%KCL w/safelube from bottom. Log from tag at TD, 14731.7 to 9700. Flag painted at 14000. POOH. ***Job Continued on 5/21/20*** 5/20/2020 T/I/O=TWC/0/0. Pulled 4" H TWC #443 @100" from WWP for coil to resume job. Job Complete. See log. Final WHP,s Vac/0/0. 5/21/2020 CTU 9 2.0" CT .156wt Objective: Initial perfs and acid stimulation OOH with log and shows a +30 correction making PBTD = 14761.78 and EOP at flag 14019.69. Deploy perf gun #1. RIH. Perforate 14720-14761'. POOH with guns. Pump acid stage #1: 26.5 bbl Etch and 18.5 bbl VDA Acids. Displace acid to perfs. Pre acid injection was 5 bpm at 2000psi. Post acid injection was 5 bpm at 500psi. ***Job Continued on 5/22/20*** 5/22/2020 CTU 9 2.0" CT .156wt Objective: Initial perfs and acid stimulation Make up and deploy perf gun #2. 279.77' of 2.75" millenium charges. Perforate 14400-14680. POOH. Kill well. OOH with gun #2, all shots fired. Lay down guns. ***Job Continued on 5/23/2020*** 5/23/2020 CTU 9 2.0" CT .156wt Objective: Initial perfs and acid stimulation Deploy gun #3. RIH. Experienced lockup through uphill section of the well ~11890- 12200 (bottom of gun depth). Able to continue in hole at 20fpm. Tag PBTD and correct depth. PUH and perforate: 12959 - 13260, 13363 - 13662, 13802 - 14002, 14040 - 14140 POOH and kill well. ***Job Continued on 5/24/20*** 5/24/2020 CTU 9 2.0" CT .156wt Objective: Initial perfs and acid stimulation Flow check well. Undeploy gun #3. Deploy gun #4. RIH. Tag PBTD and correct depth. PUH to shot depth and perforate: 12104 - 12154, 12434 - 12584, 12620 - 12920. Flag pipe on the way out of hole at 11000 (corrected to bottom shot). Corrected EOP at white flag = 10140.67'. POOH and kill well. ***Job Continued on 5/25/20*** Daily Report of Well Operations PBU L5-07 5/25/2020 CTU 9 2.0" CT .156wt Objective: Initial perfs and acid stimulation Flow check well. Retrieve gun #4. Deploy gun #5. Tagged PBTD and correct depth. PUH and perforate: 10220 - 10380, 10440 - 10690, 10780 - 11050, 11230 - 11520. POOH and kill well. ***Job Continued on 5/26/20*** 5/26/2020 CTU 9 2.0" CT .156wt Objective: Initial perfs and acid stimulation Finish well kill. Lay down gun #5. MU/RIH with BOT venturi w/3.69" mule shoe. Run venturi up and down the liner. 2 overpulls observed. Venturi came back with perf debris and sand. The screen was completely packed off. Re-run. ***Job Continued on 5/27/20*** 5/27/2020 Heat Uprights for CT (NEW WELL POST) Heat Upright to 110* for Coil 5/27/2020 CTU 9 2.0" CT .156wt Objective: Initial perfs and acid stimulation Continue in hole with second venturi. Venturi from 10000' to TD and back up to 10000', POOH. Screens packed off with formation solids and metal shavings. Rerun Venturi. Venturi from 9900' to TD tag at 14748' and then back up to 10,000'. RIH Dry and able to drift to TD. While dry drifting back up we encountered a tight spot at ~14110' (same depth as previous runs). Able to venturi through and then dry drifted back down and up clean. Continued to pump down the backside while POOH to keep formation from dumping more solids into the liner. Recover 2-3 cups of formation solids and ~ 1/8 cup of thin metal chips which appear to be from previous milling. Screens were not packed off so venturi was still effective. Lay down tools and set TWC. Begin preparations for weekly BOP Test. ...Continued on WSR 5-28-20... 5/28/2020 CTU 9 2.0" CT .156wt ***Cont. from WSR 5-27-20*** Objective: Initial perfs and acid stimulation Complete weekly BOP test. Pull TWC. Trim coil and change pack offs. Prepare for Openhole operations. ...Continued on WSR 5-29-20... 5/28/2020 T/I/O=0/0/0. Set 4" H TWC #438 through stack with T bar @18.6'. Job Complete. Final WHP,s 0/0/0. 5/29/2020 T/I/O=TWC/0/0 R/U lubricator, PT'd, pass. Pulled 4" CIW "H" TWC #438 through stack for Klondike WWP. Tagged @ 100". Shut barriers, R/D lubricator. FWP's 0/0/0 see log for details. 5/29/2020 CTU 9 2.0" CT .156wt ***Cont. from WSR 5-28-20*** Objective: Initial perfs and acid stimulation Kill Well and maintain well control using MCHF. Deploy Lee Energy Speed Squeeze BHA with 311' of spacer pipe. RIH, tag PBTD and correct depth. Pump stages 2, 3, & 4. 323 Bbls Etch and 166 Bbls VDA Acids. Standby while acid transports reloaded. ...Continued on WSR 5-30-20... Daily Report of Well Operations PBU L5-07 5/30/2020 CTU 9 2.0" CT .156wt ***Cont. from WSR 5-29-20*** Objective: Initial perfs and acid stimulation Standby for Acid transports to be reloaded. Pump Acid stages 5, 6, & 7. 492 Bbls Etch and 258 Bbls VDA Acids. Return to standby while Acid transports reloaded. ...Continued on WSR 5-31-20... 5/31/2020 CTU 9 2.0" CT .156wt ***Cont. from WSR 5-30-20*** Objective: Initial perfs and acid stimulation Standby for Acid transports to be reloaded. Spot Acid Transports, PT Frac Pump line, pump Stages 8-11 as per plan. 441 Bbls Etch and 222 Bbls VDA Acids. Standby while Acid Transports reloaded. ...continued on WSR 6-1-20... 6/1/2020 CTU 9 2.0" CT .156wt ***Cont. from WSR 5-31-20*** Objective: Initial perfs and acid stimulation Standby for Acid transports to be reloaded.. Pump final stages #12 and 13. 222 Bbls Etch and 123 Bbls VDA Acids. POOH. Overpull at SSV nipple as packer attempted to set. Blow lower burst disc and circulate ball to open lower circ sub. Kill Well and retrieve Lee Energy Speed Squeeze BHA. ...Continued on WSR 6-2-20.... 6/2/2020 CTU 9 2.0" CT .156wt ***Cont. from WSR 6-1-20*** Objective: Initial perfs and acid stimulation FP well and install TWC. Pump corrosion inhibitor and blow down coil with N2. RDMO to Maint and spool pipe. ...Job complete.... !" ! !#! $% & % ' (" ( ) * +, * $% - - & ( ) ! !"#$ $%&&'&() & *+ , -+ !. * !"#$ $%&&'&() * / " ". "% ' / "" , +$ 0 +$ 1-2 # 3($& 1.4&(5 62 67# *+$ 1-2 # 8 , 9 (3$& :(1.4&( # ;/ ) # ;; < ) % " ) ) %0 1. )( 6" .. .) ))=.'&$ ) ' 6>&>6>>' .$6:>'.: ' =.>?.' ..(4=.&?(.'( $/- - % ) ) 1 )213 -2 3 %0 ))). ) )) ' ' 6> (6& '(. . 6$ .':( $ '$ - )1 ' ) ' =$ ? 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"7 "7 "7 %7 % & %: WELL NAME Date : Shoe @ : FC @ :Top Liner @ : Type: Type : Type : Type : Type : XYes No Yes X No X Yes No X Yes No X Yes No Date : Volume lost during displacement (bbls) : Density (ppg) : Mixing / Pumping Rate (bpm) : Volume : Reciprocated? % Returns during job : 95 Cement returns to surface? Spacer returns? Vol to Sur : Density (ppg) : Rate (bpm) : Volume (bbls) : Method Used To Determine TOC : Returns to surface FIRST STAGE4490' MD 4400' MD Preflush (Spacer) Density (ppg) : Casing Rotated? surface 66G Lite Crete Volume (bbls): 790 Yield : 1.91 Cement In Place At :Estimated TOC : surface Volume (actual / calculated) : 209.4 FCP (psi) : 3100 Pump used for disp : Rig Plug Bumped? Bump press : 6 Sacks : 319.4456897 5 Post Flush (Spacer) N/A Yield : 1.16 Displacement : Quickdril-N Density (ppg) : 8.7 Rate (bpm) : 15.8 100 11 Lead Slurry MUDPUSH II Density (ppg) : 10 Volume pumped (bbls) : Sacks : 2322.227749 Mixing / Pumping Rate (bpm) : 5 Tail Slurry Remarks: L5-07 CEMENT REPORT Surface Hole Size :16"Casing Size :13 3/8" WELL NAME Date : Shoe @ : FC @ :Top Liner @ : Type: Type : Type : Type : Type : Yes X No Yes X No X Yes No Yes X No Yes X No Date : Volume lost during displacement (bbls) : Density (ppg) : Mixing / Pumping Rate (bpm) : Volume : none Reciprocated? % Returns during job : 100 Cement returns to surface? Spacer returns? Vol to Sur : Density (ppg) : Rate (bpm) : Volume (bbls) : Method Used To Determine TOC : Lift pressrueFIRST STAGE9868' MD 9778' MD Preflush (Spacer) Density (ppg) : Casing Rotated? surface 108G Volume (bbls): Yield : Cement In Place At : 18:40 hrs 3/11/2020 Estimated TOC : surface Volume (actual / calculated) : 710.5 FCP (psi) : 808 Pump used for disp : Rig Plug Bumped? Bump press : 10 Sacks : 522.7293103 5 Post Flush (Spacer) water 8.3 5 10 Yield : 1.16 Displacement : LSND Density (ppg) : 10.3 Rate (bpm) : 15.8 65 Lead Slurry MUDPUSH II Density (ppg) : 13 Volume pumped (bbls) : Sacks : #DIV/0! Mixing / Pumping Rate (bpm) : Tail Slurry Remarks: L5-07 CEMENT REPORT Intermediate 1 3/11/2020 Hole Size :12 1/4 Casing Size :9 5/8" 8,568 MD mgr per Frank Roach Drilling Engr. WELL NAME Date : Shoe @ : FC @ :Top Liner @ : Type: Type : Type : Type : Type : XYes No Yes X No Yes X No Yes X No Yes X No Date : Volume lost during displacement (bbls) : Density (ppg) : Mixing / Pumping Rate (bpm) : Volume : 21.00 Reciprocated? % Returns during job : 98% Cement returns to surface? Spacer returns? Vol to Sur : Density (ppg) : Rate (bpm) : Volume (bbls) : Method Used To Determine TOC : cir out 260 bbls from top of linerFIRST STAGE10214' MD 10169' MD Preflush (Spacer) Density (ppg) : Casing Rotated? 9678 300G Unislurry Volume (bbls): Yield : Cement In Place At : 05:45 hrs 3/16/2020 Estimated TOC : 9,678 Volume (actual / calculated) : 165 FCP (psi) : 2200 Pump used for disp : Rig Plug Bumped? Bump press : 2700 3 Sacks : 1452.025862 5 Post Flush (Spacer) water 8.3 5 10 Yield : 1.16 Displacement : LSND Density (ppg) : 10.3 Rate (bpm) : 15.8 30 Lead Slurry MUDPUSH II Density (ppg) : 13 Volume pumped (bbls) : Sacks : #DIV/0! Mixing / Pumping Rate (bpm) : Tail Slurry Remarks: L5-07 CEMENT REPORT Intermediate 1 3/16/2020 Hole Size :8 1/2 Casing Size :7" WELL NAME Date : Shoe @ : FC @ :Top Liner @ : Type: Type : Type : Type : Type : Yes X No Yes X No Yes X No Yes X No Yes X No Date : Volume lost during displacement (bbls) : L5-07 CEMENT REPORT Production Liner 1 4/26/2020 Hole Size :6 1/8 Casing Size :4.5 Remarks: 6 15.8 Lead Slurry Fresh Water Density (ppg) : 8.34 Volume pumped (bbls) : Sacks : 590.4905172 Mixing / Pumping Rate (bpm) : 1.3 Tail Slurry Displacement : water Density (ppg) : 8.3 Rate (bpm) : Sacks : #DIV/0! Post Flush (Spacer) Yield : Volume (actual / calculated) : 28 FCP (psi) : 1171 Pump used for disp : Coil Pump Plug Bumped? Bump press : 1.3 Cement In Place At : 02:37 hrs 4/26/2020 Estimated TOC : 10,400 Method Used To Determine TOC : Injection point, loss zones below injeciton point, we expect the cement went towards the toe of the well.FIRST STAGE14859' MD 10400' MD Preflush (Spacer) Density (ppg) : Casing Rotated? 10022' MD Class G Volume (bbls): 122 Yield : 1.16 Density (ppg) : Mixing / Pumping Rate (bpm) : Volume : none Reciprocated? % Returns during job : 0 Cement returns to surface? Spacer returns? Vol to Sur : Density (ppg) : Rate (bpm) : Volume (bbls) : STATE OF ALASKA By: Reviewed OIL AND GAS CONSERVATION COMMISSION ReReP.Iiewed Supry BOPE Test Report for: PRUDHOE BAY UN LIS L5-07 �� Comm Contractor/Rig No.: Schlumberger 9 PTD#: 2191020 ' DATE: 5/16/2020 ' Inspector Bob Noble - Insp Source Operator: BP Exploration (Alaska) Inc. Operator Rep: John Conrad Rig Rep: Charly Horwath Inspector Type Operation: WRKOV Sundry No: Test Pressures: yP p Inspection No: bopRCN200519093550 Rams: Annular: Valves: MASP: 320-115 — - -- Type Test INIT 250-4000 ' 250-3500- 250-4000 - 2318 f Related Insp No: TEST DATA MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: P/F Upper Kelly P/F NA Visual Alarm Time/Pressure P/F Location Gen.: P Trip Tank NA NA, System Pressure 2950 P Housekeeping: P Pit Level Indicators NA NA - Pressure After Closure 2.0.75 P PTD On Location P Flow Indicator NA NA' 200 PSI Attained 5 - P Standing Order Posted P Meth Gas Detector P P " Full Pressure Attained 25 P Well Sign P H2S Gas Detector P P Blind Switch Covers: All Stations P " Drl. Rig P _ MS Misc NA NA Nitgn. Bottles (avg): 0 NA Hazard Sec. P Inside Reel Valves l P - Kill Line Valves ACC Misc 0 NA Misc NA Check Valve 1 2" P FLOOR SAFTY VALVES: Quantity P/F Upper Kelly _ 0 NA Lower Kelly 0 NA Ball Type 2 P Inside BOP 0 NA FSV Misc 0 NA BOP STACK: CHOKE MANIFOLD: Quantity Size P/F Quantity P/F Stripper 1 2" P No. Valves 12 P ' Annular Preventer 1 7" P Manual Chokes 2 P - #1 Rams 1 Blind/Shear F ✓ Hydraulic Chokes 0 NA - A -#2 #2Rams 1 2" Pipe/Slip P CH Misc 0 NA #3 Rams 1 " 2.375" Pipe/SIP ' #4 Rams 1 2" Pipe/Slip P, #5 Rams 0 NA INSIDE REEL VALVES: #6 Rams 0 NA (Valid for Coil Rigs Only) Choke Ln. Valves 1 2 1/16" P Quantity P/F HCR Valves 1 2 1/16' p Inside Reel Valves l P - Kill Line Valves 2 2 1_/1.6" F Check Valve 1 2" P BOP Misc 0 NA Number of Failures: 2 ✓ Test Results Test Time 34 Remarks: Blind/Shears failed, Did not witness a R/T. Inside kill valve leaked and it was serviced. Did not witness a R/T on the valve. Date: 4/9/2020 Transmittal Number: 93741-L5-07 BPXA WELL DATA TRANSMITTAL Subsurface Information Management 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 Digital zip files for the well log packages listed below are being provided to you via SharePoint. If you have any questions please contact Merion Kendall: 907-564-5216; merion.kendall@bp.com. SW Name Log Date Company Description Format L5-07 3/24/2020 Baker Hughes Compensated Bulk Density, Neutron Porosity, Multiple Propagation Resistivity, Gamma Ray 2” & 5” MD & TVDSS, Memory Logs; Final Deviation Survey Data Zip File Please Sign and Return one copy of this transmittal to GANCPDC@bp365.onmicrosoft.com Thank you, Mer Merion Kendall SIM Specialist ----------------------------------------------------------------------------------------------- BP Exploration Alaska|900 E. Benson Blvd.|Room: 716B|Anchorage, AK ----------------------------------------------------------------------------------------------- AOGCC https://bp365.sharepoint.com/sites/BPtoAOGCCElectronicPermittingandReporting/ DNR https://drop.state.ak.us/drop/ Received by the AOGCC on 04/09/2020 PTD: 2191020 E-set: 32474 THE STATE 'ALASKA GOVERNOR MIKE DUNLEAVY David Wages Well Interventions Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Lisburne Oil Pool, PBU L5-07 Permit to Drill Number: 219-102 Sundry Number: 320-115 Dear Mr. Wages: 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 Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, C�2 C)� sie L. Chmielowski Commissioner DATED this j2day of March, 2020. STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS �A {��Q 20 AAC 25.280 f 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate Q Repair Well ❑ ✓+ a0 rdii�m ❑ Suspend [I Perforate ❑ Other Stimulate 0 Pull Tubing 13Cl> W� ram ❑ Piug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing Q Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: 5. Permit to Drill Number. 219-102 3. Address: P.O. Box 196612 Anchorage, AK Exploratory ❑ Development 99519-6612 Stratigraphic ❑ Service 116. API Number: 50-029-23642-00-00 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 * PBU L5-07 - 9. Properly Designation (Lease Number): 10. Field/Pools: ADL 0028320. 034631 8 028322 PRUDHOE BAY. LISBURNE OIL 11, PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): -15200' —8783' —15100' 8783' 2318 None None Casing Length Size MD TVD Burst Collapse Structural Conductor -80 20" x 34" Surface - -125' Surface - -125 Surface 4490 13-318" Surface - -4536 Surface - -4067 5020 2P70 Intermediate -9603 9-518" Surface - -9650 Surface - -8267 6870 4760 Liner -761 7" -9500 - -10261 -8143 - -8767 7240 5410 Liner -5090 4-112" -10110 - -15200 -8645 - -8783 Perforation Depth MD {ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4-112" 12.8# 1 13Cr85 I Surface --10118 Packers and SSSV Type: 4-1/2" HES TNT Packer Packers and SSSV MD (ft) and TVD (ft): -9963 / -8500 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class atter proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: April 15, 2020 15. Well Status after proposed work: Oil 0 W1NJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Wages, David be deviated from without prior written approval. Authorized Name: Wages, David Contact Email: David.WagesQbp.com Contact Phone: 907.564.5869 Authorized Title: Well Inten2nitions Engirper Authorized Signature: Date: 3 20 Zo COMMISSION USE ONLY IF Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0y BOP Test 1y�-- Mechanical Integrity Test ❑ Location Clearance [1 Other: ©f'� / G S� / [;t . ���U��S I. 1�Sean sJ Post Initial Injection MIT Req'd? Yes ❑ No Q Spacing Exception Required? Yes 0 No LV' Subsequent Form Required: A0 V(3 R Aftree�� ha APPROVED BYTHE Approved by COMMISSIONER COMMISSION Date_ ORIGINAL .f- � Submit Farm and Form 10-403 Revised 0412017 Approved application is valid for 12 months from the date of approval. Y�-� Attachments in Duplicate Y/4AP I 031(ZIAO Sundry Request to Deploy Extended Length Acid Stimulation BHA Utilizing The Well Work Platform Well: 1-5-07 Date: 3/10/2020 Engineers: David Wages: 907-564-5669 Kirsten Schultz: 907-564-5105 MASP: 2318 Well Type: Producer Estimated Start date: April 15, 2019 History: 1-5-07 is to be drilled March 2020 with 2000' of perforations shot in the Lisburne formation. The perforations will be shot in 400' clusters. All perforations will individually receive an acid stimulation. Scope of Work: The scope of this work is to utilize Service Coil and the Well Work Platform to deploy an extended length straddle BHA to individually perform an acid stimulation of each perforation cluster in this newly drilled Lisburne well. After the stimulation is complete, perform the initial well POP and flowback any unspent acid prior to turning the well over to Operations. Proposed WWP Procedure: • MIRU WWP, BOPE and support equipment • MIRU CTU • Test BOPE as configured top down (annular, blind shears, 2" pipe/slips, mud cross, 2-318" pipe/slips, 2" pipe/slips). Test a blind shears and pipe slips to 3500 psi and the annular to 2500 psi. — Z- 41 A.- /) e Test 4.0 WGCG --540-:4 ZJ'W'Oemm' • Perform motor and mill drift • Perform tie-in logging run • Kill well with 1% KCL • Deploy -500' straddle packer BHA and stimulate all perforation clusters. Safety joint with FOSV will be on floor during BHA deployment and laydown. • RDMO WWP and Coil Unit �,� � t`v,45 � �e#1u �y�e -V .TWA-- e �Nt.,.-�Zazo r1 w t/&C Proposed Wellbore Confieuration Proposed Completion Diagram Im• VA3jAaw. PROPOSED OZTMIM- RPR e" , s - - r . 'Arco& rm- ma" , .0:. M4W xis M&m M+ 110 t 911 ff 1111 10 0 f f a •* - 4"R ' F .br f. ♦ - . as €€ + + f l� J � +1r�4�F • 4Y +. pVmpa- Ymr � 4 ti, 2W _ 4M *4* FW �C- -&W*;* in-M,*V A"Wrm -C" Leal WLW AMOL"y %GOP" MIR NW99 ,Tari SM Iff WWWAL NOW marts-swr LS -07 zwmrf; -e -,m CWMWVMSLM —..7w%Ari+ $l . aolt;1 UFTWrlWN MD NO MV FVM VLV LA" POW VAW 4 t Ir 41rmpa3Fiqp w� 4 a "r, Hi 94* " V - : i fMTi�+iM' O �44T Pik ff. JEW BOP rig uR Platform Floor Riser to platform floor 1 I ' 1 I I 1 I 1 � I I I I � I Annular I • I I W Blind/Shear Hydraulically Actuated V Ive -K- *EU7 Coil Pipe/Slip Choke Line ®p ✓ Kill Line 2-318" Pipe/Slip Coil Pipe/Slip v 7 x 7 Spool O SSV ° Master Valve THA Tubing Head Ground Level %D a E 41 a 0 Ln A J E D 0 0° u a d u; � a r � N Q M Ln m m N N C p U p w t� M v C1 C � f1 m O x w 2 a C L IA a c m (V a) o � L 3 N F al a - 3 a� L H � 0 N a, L E cl 2� o v u r 3 Q. a, DoC ,q C enm N Q _ 4L) CA 0a 3 0 x o a E v� ai oo t °' 4 - CA w 0 0 c 3 'Q tkb 7 L 41Q a, c E 3 L ot Y a) � C 3 c _ro L Q 6-1 �a a m L- 41 }' a w N � 3 c x ._ m a E E m o' ,A a% a 3 L � L YLn O L Q CL N V1 -� E m 0 m 3 of (Wds) ales 8 9 ti z 0 O C2 9 of { � v L - T #. `t o 0 0 N c 0 3 f 'fir a E bo Go u U • � 1 to i N H � .o � til -- c m no Cal .F u L 0 - -- L 3 0cw a) a 4-C M L N +� E a m a 0009 o0ov 000z 0 000z• Nov - rn v 9 - (Isd) ssaid-uue - do(Isd) ssaid-6ql - (Isd) ssaid uue iml - (Isd a 0OZ9 008V 0ovv 000 (isd)ssaid H8 Ci ICO) IN IT - 6 V cT ta E a E L a C E E LA C `J E N m O N U N Ir•+ LA 0 � � L O C — U � 3 � L M' m E a O � � C CL en c°C3 0 3 N GJ U a ,Co e 3 O a 4' W CU c n L L Q ++ L , kA W CL 60 41 o o tO L f0 C a a cc m E N J a v o C -a o aC 2, A L L C. R � E C u a ++ ro � rc m L r u O ro 4- `o C o N O N +�O 0 V X N m E a a o N E O a '� -0 Y a R a Ln H L4�/f u Q A o � oA o L4 C J H E m E a o u ^ a E ui , x 's O rf C Q -W- N -0 en a 2' w cr rN E NN m N 3 W N C L m m C " V I N ;0N cp n Go � a D d (A to r- CA a� -0 M U3 X C� OC fO Q N M LQ U U a ❑ C �i 6 U-.VAl CA H THE STATE V 0 1 1 1 45 W W4 110 C GOVERNOR MIKE DUNLEAVY Kenneth Allen Engineering Team Lead BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Lisburne Oil Pool, PBU L5-07 BP Exploration (Alaska), Inc. Permit to Drill Number: 219-102 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.cogcc.alaska.gov Surface Location: 1528' FSL, 171' FEL, SEC. 02, TI IN, RI 5E, UM Bottomhole Location: 223' FNL, 1397' FEL, SEC. 15, TI IN, RI 5E, UM Dear Mr. Allen: Enclosed is the approved application for the permit to drill 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, re Price ha DATED this (/day of January, 2020. STATE OF ALASKA 'ASKA OIL AND GAS CONSERVATION COMMIS.` PERMIT TO DRILL b 20 AAC 25.005 la. Type of Work: 1 b Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1 c. Specify if well is proposed for: Drill R1 ' Lateral ❑ Stratigraphic Test ❑ Development - Oil 0 , Service - Winj ❑ Single Zone 0. Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ 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. 295105380 PBU L5-07 ` 3 Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 196612 Anchorage, AK 99519-6612 MD: 15200'` TVD: 8783'< PRUDHOE BAY, LISBURNE OIL 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): ADL 028320, 034631 & 028322 Surface: 1528' FSL, 171' FEL, Sec. 02, T11N, R15E, UM 8. DNR Approval Number: 13. Approximate spud date: Top of Productive Horizon: 1490' FNL, 4014' FEL, Sec. 11, T11N, R15E, UM 84-62 May 1, 2020 9. Acres in Property: 2560 14. Distance to Nearest Property: Total Depth: 223' FNL, 1397' FEL, Sec. 15, T11N, R15E, UM 22700 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 66.75 • feet 15. Distance to Nearest Well Open Surface: x- 717265 y- 5974656' Zone - ASP 4 GL Elevation above MSL: 19.6 feet to Same Pool: 1430 16. Deviated wells: Kickoff Depth: 800 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 99 degrees Downhole: 3645 Surface: 2791 18. Casing Program: Specifications I Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weiqht Grade Coupling Length MD TVD MD TVD (includinq staqe data) 42" 20" x 34" 215.5# A-53 80' Surface 125' Sufrace 125' 260 sx Arctic Set (Aoorox.) 16" 13-3/8" 68# -80 BTC 4490' Surface 4536' Surface 4067' 2546 sx LiteCrete, 315 sx Class'G' 12-1/4" 9-5/8" 47# L-80 Vam 21 9603' Surface 9650' Surface 8267' 597 sx Class'G' 8-1/2" T' 26# L-80 VamTop HC 761' 9500' 8143 10261' 8767' 1 206 sx Class'G' 6-1/8" 1 4-1/2" 1 12.6# 1 13Cr85 1 VamTop 1 5090' 1 10110' 1 8645' 15200' 8783' 1 197 sx BiModal or 558 sx Class'G' 19 PRESENT WELL CONDITION SUMMARY (To be completed or Redri�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 Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Hydraulic Fracture planned? Yes ❑ No ❑ 20. Attachments Property Plat ❑ BOP Sketch Z Drilling Program Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date hereby certify a e toregoing is true and the procedure approved herein will not be deviated Contact Name Nocas. Noel from without prior written approval. Authorized Name Allen, Kenneth W Contact Email Noel.Nocas(cb_bp.com Authorized Title Engineering Team Lead Contact Phone Authorized Signature Date % Commission Ose Onl Permit to Drill`` �C) 2- C «' Permit Approv �/ See cover letter for other Number: L� ` l Z API : 50- ('�i1 L �� %Z! Date: (N requirements: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methan , gas hydrates, or gas contained in shales: Other: ©}%� �–� �S�jO ) Samples req'd: Yes ❑/ No 2tMud log req'd: Yes No I / H2S measures Yes [3 No ❑ Directional svy req'd: Yes n3' No ❑ 93/ No PSpacing d Yes Nor exception re Inclination -only svy req'd: Yes No L El �j Zo4AC. .033 ' No aim, Do /e Iry S t -s t Idea u �.-�e9 e� *-b �1 ►fib .I.A5 •� Post initial injection MIT req'd: Yes El No ❑ J.'5+C.l*'c✓lam-}�ev1j APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: i 1of � a 1. l!/�0 We IN7`Z`4Fo m 10-401 Revise /2017 �+ — Thl$pellmrt Is valid for 24 nt11s �rdate dF t�;PL(20 AAC 25.005(g)) Submit4onr dnu VVV Attachments in Duplicate To: Alaska Oil & Gas Conservation Commission From: Noel Nocas Date: July 11, 2019 RE: L5-07 Permit to Drill The L5-07 well is scheduled to be drilled by Parker 272 in May 2020. This grass roots well is a horizontal producer primarily targeting Zone 7. The planned well is a four string, big -bore design using 13-3/8" surface casing, 9-5/8" intermediate casing, 7" intermediate liner and 4-1/2" production liner. The surface casing will be set in the SV4. The first and second intermediate strings will be set in the HRZ and top Lisburne, respectively. The production interval will be completed with a cemented and perforated liner. Maximum anticipated surface pressure will be from the Base Sadlerochit. With a full column of gas, MASP from BSAD to surface is 2,791 psi (8.21 ppg EMW at BSAD at 8538' TVDss with 0.1 psi/ft gas gradient). The well will be drilled by Parker 272 using their 5,000 psi four preventer BOP stack (3 rams and an annular). The BOP rams and annular will be tested to 3,500 psi. A detailed operations summary is included with the permit application. If there are any questions, please do not hesitate to use the contact information below. Noel Nocas Office: (907) 564-5027 Cell: (907) 229-9532 Email: noel.nocas@bp.com Attachments: Well Bore Schematic Directional Package BOPE Schematic Diverter Line Layout Diagram L5-07 PTD 1 7/11/2019 Planned Well Summary Well 1-5-07 Well e Producer Ob eget Lisburne tive Current Status Grass Roots Well Estimated Start Date: I May 2020 Time to Complete: 1 38.7 Appx Northing Easting Offsets TRS Surface 5,974,656 717,265 • 1528.47' FSL / 170.60' 11N 15E Sec 2 LocationL Lisburne FEL . Planned KOP: 800.0' MD I Planned T -D T 15200.0' MD / 8715.0' TVDss Rig: Parker 272 1 GL -RT: 1 47.15 1 1 RTE ref MSL): 1 66.75 Directional - WP03 Maximum Hole Angle: Northing Easting TVDss Offsets TRS Top 22700.0' Nearest Well within Pool: 1430.0' Lisburne 5,971,529.0 713,513.0 -8697.0 1490.0' FNL / 4013.9' 11N 15E Sec 11 FEL TD point 5,967,442.0 710,970.0 -8716.0 223.6' FN L/ 1397.3' 11 N 15E Sec 15 Planned KOP: 800.0' MD I Planned T -D T 15200.0' MD / 8715.0' TVDss Rig: Parker 272 1 GL -RT: 1 47.15 1 1 RTE ref MSL): 1 66.75 Directional - WP03 Maximum Hole Angle: -350 in the surface section -35° in the intermediate section -99° in the production section Close Approach Wells: All offset wells pass BP anti -collision scan criteria Survey Program: Reference attached directional program Nearest Property Line: 22700.0' Nearest Well within Pool: 1430.0' Hydraulic Fracture Planned? No L5-07 PTD 2 7/11/2019 Formation Tops and Pore Pressure Estimate Formation Estimated Formation Top TVDss Most Likely Pore Pressure EMW Fluid Type (for sands) BPRF 1850.0 8.35 None SVS 3490.0 8.35 Water SV4 3697.0 8.35 Water SV3 4056.0 8.35 Water SV2 4247.0 8.35 Water SVI 4631.0 8.35 Water UG4 5025.0 9.0 Water UG3 5411.0 9.0 Water UGI 5767.0 9.0 Water WS2 6571.0 9.0 Water CM3 6887.0 10.0 Water/ gas cut mud CM2 7827.0 10.0 Water/ gas cutmud CMI 8080.0 10.2 Water/ gas cut mud THRZ 8270.0 10.3 gas cut mud LCU/ Ivishak 8479.0 8.21 Gas/Oil/Water Kavik 8538.0 9.9 TLSB 8662.0 6.9 Gas/Oil/Water Landing Point 8959.0 6.9 Gas/OilNVater L5-07 PTD 3 7/11/2019 Casing/Tubing Program Hole Size Casing / Wt/Ft Grade Conn Appx Top Bottom 10-20 Tbg O.D. None Ib/100ft2 13-3/8" Shoe -TD Length MD / TVDss MD / TVDss 42" 20" x 34" 215.5# A-53 - 80' Surface 125'/ 60' 16" 13-3/8" 68# L-80 BTC 4490' Surface 4536'/ 4000' 12-1/4" 9-5/8" 47# L-80 Vam 21 9603' Surface 9650'/ 8200' 8-1/2" 7" 26# L-80 Vam Top HC 761' 9500'/ 8076' 10261'/ 8700' (150' lap) 6-1/8" 4-1/2" 12.6# 13Cr-85 Vam Top 5090' 10110'/ 8578' 15200'/ 8716' (150' lap) Tubing 4-1/2" 12.6# 13Cr-85 Vam Top 10115' Surface 10115'/ 8582' (-5' into liner TBR) Mud Program Surface Mud Properties: MMH 16" Hole Section Depth Interval Density PV (cp) YP Ib/100ft2 Surface - TD (SV4) 8.5-9.1 ' 6-20 35-80 Intermediate 1 Mud Properties: 12-1/4" Hole Section LSND Density Depth Interval Density PV (cp) YP 10-20 20-30 None Ib/100ft2 13-3/8" Shoe -TD 9.1 - 11.0 ' 10-20 20-30 (HRZ) GR-RES-NEU- DENS-Ima None Intermediate 2 Mud Properties: LSND 8-1/2" Hole Section Depth Interval Density PV (cp) (Ib/1 9-5/8" Shoe - TD TLSB) 1 10.3 - 11.0 10-20 20-30 Production Mud Properties: Water 6-118" Hole Section Based Polymer Fluid CH Logs Depth Interval Density PV (cp) YP Ib/100ft2 7" Shoe - TD 1 8.5-9.1- • <12 12-20 Logging Program Interval MWD/LWD OH Los CH Logs Surface GR None - Intermediate GR -RES None Intermediate GR-RES-NEU- DENS None Production GR-RES-NEU- DENS-Ima None 1-5-07 PTD 4 7/15/2019 Cement Program Casing Size 13-3/8" 68# L-80 BTC Surface Casing Lead Oen hole volume + 350% excess in permafrost / 40% excess below permafrost Basis Lead TOC Surface Basis Tail Open hole volume + 40% excess + 85 ft shoe track Tail TOC 500 ft MD above casing shoe Spacer -100 bbls of 10 ppg Viscosified Spacer Mud Push II Total Cement Lead 866.1 bbls, 4863 cuft, 2546 sks 11.0 ppg LiteCRETE - 1.91 cuft/sk Volume Tail 65.2 bbls, 366 cuft, 315 sks 15.8 ppg Class G - 1.16 cuft/sk .� Temp BHST 77° F Casing Size 9-5/8" 47# L-80 Vam 21 Intermediate Casing Lead N/A Basis Lead TOC N/A Basis Tail Open hole volume + 40% excess + 85 ft shoe track Tail TOC 1300 ft MD above casing shoe Spacer -50 bbls of 13 ppg Viscosified Spacer Mud Push II Total Cement Lead N/A Volume Tail 123.4 bbls, 693 cuft, 597 sks 15.8 ppg Class G - 1.16 cuft/sk Temp BHST 170° F Casing Size 7" 26# L-80 Vam Top HC Intermediate Liner Lead N/A Basis Lead TOC N/A Tail Open hole volume + 40% excess + 150 ft liner lap + 460 ft 5" DP x CSG + 85 ft shoe track Tail TOC Top of liner Spacer -25 bbls of 13 ppg Viscosified Spacer Mud Push II Total Cement Lead N/A Volume Tail 43.0 bbls, 242 cuft, 206 sks 15.8 ppg Class G - 1.17 cuft/sk Temp BHST 176° F Casing Size 4-1/2" 12.6# 13CR-85 Vam Top Production Liner Lead N/A Basis Lead TOC N/A Tail Open hole volume + 30% excess + 150 ft liner lap + 200 ft 4" DP x LNR + 85 ft shoe track Tail TOC Top of liner Spacer -30 bbls of 8.6 ppg Viscosified Spacer Mud Push II Lead N/A Total Cement Volume Tail 116.3 bbls, 653 cuft, 197 sks 8.6 ppg Bimodal - 3.32 cuft/sk (additional volume scaled to r severity of loss rate) If there are not major losses 15.8ppg Class G will be pumped @ 1.17cuft/sk Temp BHST 176° F Surface and Anti -Collision Issues Surface Close Proximity: No wells will be affected by the rig shadow. Sub -Surface Pressure Management: No wells will be shut-in for reservoir pressure purposes while drilling. Anti -Collision: All offset wells pass BP anti -collision scan criteria. Offset Well Ownership Information All offset wells identified within 200 ft of the proposed wellbore are operated by BP. L5-07 PTD 5 7/11/2019 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. 1-5-07 PTD 6 7/11/2019 Well Control The 16" surface hole will be drilled with a diverter system. The 12-1/4", 8-1/2" and 6-1/8" hole sections will be drilled with well control equipment consisting of 5,000 psi working pressure rams (2), blind/shear ram, and annular preventer capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3,500 psi. BOP test frequency will be 14 days with function test every 7 days. Except in the event of a significant operational issue that may affect well integrity or pose safety concerns, an extension to the 14 day BOP test period should not be requested 12-1/4" Intermediate 1 Interval Maximum anticipated BHP 3,223 psi at Base WS2 at 6887' TVDss 9.0 ppg EMW Maximum surface pressure 2,534 psi at Base WS2 0.10psi/ft gas gradient to surface Kick tolerance >25 bbls with 11.55 ppg frac gradient. Kick tolerance Assumes most likely pore pressure + 0.5 ppg kick intensity at Integrity Test — 6-1/8" hole Base WS2 9 and 10.5 ppg MW. Planned BOP test pressure Rams test to 3,500 psi / 250 psi. Planned completion fluids Annular test to 3,500 psi / 250 psi Integrity Test — 12-1/4" hole LOT after drilling 20'-50' of new hole 9-5/8" Casing Test 3,500 psi surface pressure 8-1/2" Intermediate 2 Interval Maximum anticipated BHP 3,645 psi at BSAD at 8538' TVDss 8.21 ppg EMW Maximum surface pressure 2,791 psi at BSAD 0.10psi/ft gas gradient to surface Kick tolerance >25 bbls with 11.6 ppg frac gradient. Kick tolerance Assumes most likely pore pressure + 0.5 ppg kick intensity at Integrity Test — 6-1/8" hole BSAD 8.21 TLSB 6.9 and 10.5 ppg MW. Planned BOP test pressure Rams test to 3,500 psi / 250 psi. Planned completion fluids Annular test to 3,500 psi / 250 psi Integrity Test — 8-1/2" hole LOT after drilling 20'-50' of new hole 7" Liner Test 3,500 psi surface pressure 6-1/8" Production Interval Maximum anticipated BHP 3,214 psi in the LSB at 8959' TVDss 6.9 ppg EMW Maximum surface pressure 2,319 psi in the LSB 0.10psi/ft gas gradient to surface Kick tolerance Infinite with >9.5 ppg frac gradient. Assumes most likely pore pressure + 0.5 ppg kick intensity in the LSB 6.9 and 8.6 ppg MW. Planned BOP test pressure Rams test to 3,500 psi / 250 psi. Annular test to 3,500 psi / 250 psi Integrity Test — 6-1/8" hole FIT after drilling 20'-50' of new hole 4-1/2" Liner / LTP Test 3,500 psi surface pressure Planned completion fluids 1 8.5 ppg seawater / —2,000' TVD diesel 1-5-07 PTD 7 7/11/2019 Variance Requests 1. 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). This is a variance from 20 AAC 25.033. 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 10 bbls has occurred. • The well will be monitored for flow when the pumps are off at each connection. • The planned 8.5 — 9.1 ppg fluid will provide over balance to formation fluid. 2. The Lisburne formation can be highly fractured with high lost circulation potential. Assuming zonal isolation requirements are met on the 7" liner cement job, and if lost circulation occurs prior to drilling 20 ft. of new formation, it is requested to drill to the 6-1/8" production section to TD without obtaining a FIT. A similar event occurred in 2015 on L1-23 (PTD 215-060) and a — variance request was granted. This is a variance from 20 AAC 25.030 (1). 1-5-07 PTD 8 7/11/2019 Drill and Complete Operations Summary Pre -Rig Operations Install 20" conductor and cellar box. Weld landing ring. Survey. Rig Operations 1. MIRU Parker 272. Nipple up diverter system and test. 2. MU 16" surface drilling assembly with 5" DP and drill to TD. POOH and LD drilling assembly. 3. Run 13-3/8" casing to TD and cement. Test casing to 3500 psi. 4. Rig down diverter system. Nipple up 13-5/8" wellhead system. Nipple up BOPE and test to 3500 psi. BOP configuration (top -bottom): annular, L9--5//8" FBR, blind/shear, d cr ss, 2-7/8" x 5" VBR �7 !L ✓ .�� ff'i C P mu_crCC_ 5. MU 12-1/4" intermediate #1 drilling assembly with 5" DP. Drill shoe track and 20'-50' formation. 6. Perform LOT. 7. Drill 12-1/4" section to TD in the HRZ formation. Wiper trip as needed. POOH an D drilling assembly. 8. Run 9-5/8" casing to TD and cement. Test casing to 3500 psi. 9. Install 9-5/8" casing packoff and test to 3500 psi. Inject freeze protect into 9-5/8" x 13-3/8" annulus. 10. Change upper ram to 4-1/2" x 7" VBR and test. 11. MU 8-1/2" intermediate #2 drilling assembly with 5" 1DP. Drill Lshoe track and 20'-50' formation. 12. Perform LOT. 13. Drill 8-1/2" section to TD in the top Lisburne. Wiper trip as needed. POOH and LD drilling assembly. 14. Run 7" liner to TD and cement. Set hanger and liner top packer. POOH and LD liner running assembly. Test liner to 3500 psi. 15. MU 6-1/8" production drilling assembly with tapered 4" x 5" DP. Drill shoe track and 20'-50' formation. 16. Perform FIT. �,' G %-TA L _t y9-Y'�Ar C"' 17. Drill 6-1/8" section to TD in the Lisburne formation. Perform wiper trip as needed. POOH and LD drilling assembly. 18. Run 4-1/2" liner to TD and cement. Set hanger and liner top packer. POOH and LD liner running assembly. Test liner / liner top packer to 3500 psi. 19. Perforate Production Liner 20. Run and land 4-1/2" completion. Set packer 21. Circulate freeze protect to 2000' TVD. 22. Set TWC and test to 3500 psi. 23. Nipple down BOPE. Nipple up adapter and dry hole tree and test to 4500 psi. 24. RDMO Parker 272. L5-07 PTD 9 7/11/2019 Post -Rig Operations 1. Install Tree, Pull TWC 2. Pull B&R/RHC, Set LGLV 3. Set plugs and perform acid job (estimate 5 stages) 4. Flowback well L5-07 PTD 10 7/11/2019 L5-07 Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE I. Well Control / Reservoir Pressures A. Intermediate Hole 1: The UG4 is expected to be a 9 ppg EMW. The CM1, CM2 and CM3 are expected to be a 10-10.2 ppg EMW. Formation pressures will be controlled with a 9.5 ppg mud to drill to within 200' MD of the CM3. At this point, there will be a weight up to 10.3 — 11.0 ppg to drill the rest of the interval to TD. B. Intermediate Hole 2: The Ivishak is expected to be at a 7.2 ppg EMW. Reservoir pressures will be controlled with a 10.3 — 11.0 ppg mud needed to drill the HRZ/Kavik. C. Production Hole: The Lisburne is expected to be at a 6.9 ppg EMW. Reservoir pressures will be controlled by using 8.5 — 9.1 ppg water based mud. 11. Lost Circulation/Breathing A. Intermediate Hole 1: There are no expected fault crossings in the first intermediate hole. However, breathing has been known to occur in the Colville on other Drill Sites in Prudhoe Bay as a result of high ECD's. B. Intermediate Hole 2: There are no expected fault crossings in the second intermediate hole. However, the Ivishak will be drilled with a high mud weight/pore pressure differential which increases the likelihood of lost circulation. C. Production Hole: There is one expected fault crossings in the production hole. Past wells have experienced severe lost circulation and well bore breathing in the Lisburne. Ill. Fault Locations Formation Where Fault Encountered MD Intersect TVDss Intersect Throw Direction and Magnitude Uncertainty Lost Circ Potential L3 N 015 11440.0 -8875.0 N / 85' +/- 100' 1 Medium IV. Integrity Testing Test Point Test Depth Testtype EMW Ib/ al 13-3/8" Shoe 20'-50' from the 13-3/8" shoe LOT 11.55 ppg 9-5/8" Shoe 20'-50' from the 9-5/8" shoe LOT 11.6 ppg 7" Shoe 20'-50' from the 7" shoe FIT 9.5 ppg 1-5-07 PTD 11 7/11/2019 V. Hydrogen Sulfide % L1 -Pad is considered an H2S site. Recent H2S data from the pad is as follows: VI. Anti -Collision Issues All offset wells pass BP anti -collision scan criteria. CONSULT THE L5 -PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. 1-5-07 PTD 12 7/11/2019 Well Name H2S Level Date of Reading Parent well (if sidetrack) None nan NaT #1 Closest SHL well H2S level L5-09 30.0 2006-05-01 #2 Closest SHL well H2S levdel 1-5-05 22.0 2018-07-05 #1 Closest BHL well H2S level L5-08 30.0 2019-01-04 #2 Closest BHL well H2S level 1-5-04 40.0 2018-01-11 #3 Closest BHL well H2S level 1-3-12 0.0 2018-12-30 #4 Closest BHL well H2S level 1-3-10 50.0 2019-01-04 Max. recorded H2S on pad/facility L5 -12A 500.0 2019-01-26 VI. Anti -Collision Issues All offset wells pass BP anti -collision scan criteria. 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't Cl ll� CD V O1 N N N R L O CA (0 CA n M 0 Cn O V O M M M U) U QQ y O 0 0 O O M CD CO CO 0 N O (O N CO C` a0 N O CO n O O c0` CID O r` j 0 S .- N CO CO W 0 m (D co CD OD CD C. M (O O Ea y CO O O O O O O O N CO O CID r W 0 N u7 N N N N N N N N CO u'1 CO CO co co Q J L 7 r Z n L �~-' O O O O O O O CO M O O O CO W CO CA a)01 V CA n N n (0 (� cD N CA C L O O y Q. y W V t` M V 0 N N oc m L' cl '- O N N_j Z J J J d J C6 ❑ 7 .- N m m O O O O C O p G $ zm M O 0. North America - ALASKA - BP Lisburne L5 L5-07 PLAN L5-07 L5-07 WP03 Anticollision Summary Report 11 July, 2019 Company: North America - ALASKA - BP Project: Lisburne Reference Site: L5 Site Error: 0.00usft Reference Well: 1-5-07 Well Error: 0.00usft Reference Wellbore PLAN L5-07 Reference Design: L5-07 WP03 BP Anticollision Report Local Co-ordinate Reference: Well L5-07 TVD Reference: PLAN KB P272 @ 66.75usft (Original Well Elev) MD Reference: PLAN KB P272 @ 66.75usft (Original Well Elev) 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 L5-07 WP03 Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,715.27usft Error Surface: Elliptical Conic Survey Tool Program Date 7/11/2019 From To MWD MWD - Standard (usft) (usft) Survey (Wellbore) MWD - Standard 47.15 1,600.00 L5-07 WP03 (PLAN L5-07) 1,600.00 4,537.00 L5-07 WP03 (PLAN L5-07) 1,600.00 4,537.00 L5-07 WP03 (PLAN L5-07) 4,537.00 9,651.00 L5-07 WP03 (PLAN L5-07) 4,537.00 9,651.00 L5-07 WP03 (PLAN L5-07) 9,651.00 10,261.00 L5-07 WP03 (PLAN L5-07) 9,651.00 10,261.00 L5-07 WP03 (PLAN L5-07) 10,261.00 15,199.85 L5-07 WP03 (PLAN L5-07) 10,261.00 15,199.85 L5-07 WP03 (PLAN L5-07) Summary Site Name Offset Well - Wellbore - Design L5 L5-01 - 1-5-01 - L5-01 L5-03 - 1-5-03 - L5-03 L5-03 - 1-5-03 - L5-03 WP12A L5-04 - 15-04 - L5-04 L5-05 - 1-5-05 - L5-05 L5-08 - 1-5-08 - L5-08 L5-09 - 15-09 - L5-09 L5-12 - 1-5-12 - L5-12 L5-12 - L5 -12A - L5 -12A L5-13 - 1-5-13 - L5-13 L5-15 - 1-5-15 - L5-15 L5-15 - L5-15PB1 - L5-15PB1 L5-17 - 1-5-17 - L5-17 L5-17 - L5 -17A - L5 -17A Tool Name Description GYD-GC-SS Gyrodata gyro single shots MWD MWD - Standard MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal MWD MWD - Standard MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal MWD MWD - Standard MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal MWD MWD - Standard MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal Reference Offset Centre to Measured Measured Centre Depth Depth Distance (usft) (usft) (usft) 1,539.86 1,525.00 186.43 723.94 725.00 128.00 874.89 875.00 125.99 928.54 925.00 204.15 5,891.86 6,250.00 502.80 706.72 700.00 188.30 911.24 900.00 51.54 927.01 925.00 230.17 919.93 925.00 230.05 1,088.14 1,075.00 174.95 933.06 925.00 231.25 933.06 925.00 231.25 1,081.93 1,075.00 293.52 1,081.93 1,075.00 293.52 No -Go Allowable Distance Deviation Warning (usft) from Plan (usft) 24.42 162.02 Pass - Major Risk 12.76 115.24 Pass - Major Risk 15.17 110.81 Pass - Major Risk 16.70 187.45 Pass - Major Risk 464.15 41.39 Pass - Major Risk 14.66 173.64 Pass - Major Risk 18.06 33.48 Pass - Major Risk 19.59 210.58 Pass - Major Risk 19.45 210.60 Pass - Major Risk 17.79 157.16 Pass - Major Risk 19.95 211.30 Pass - Major Risk 19.95 211.30 Pass - Major Risk 18.17 275.35 Pass - Major Risk 18.17 275.35 Pass - Major Risk 7/11/2019 8:47 58AM Page 2 of 3 COMPASS 5000.1 Build 61D by Company: North America - ALASKA - BP Project: Lisburne Reference Site: L5 Site Error: O OOusft Reference Well: 1-5-07 Well Error: O OOusft Reference Wellbore PLAN 1-5-07 Reference Design: 15-07 WP03 BP Anticollision Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: Well 1-5-07 PLAN KB P272 @ 66.75usft (Original Well Elev) PLAN KB P272 @ 66.75usft (Original Well Elev) True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Reference Depths are relative to PLAN KB P272 @ 66,75usft Coordinates are relative to: 15-07 Dffset 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: 1.66° C) LO v c 0 co Q a) U) a) c a) U 0 a) C a) U Ladder Piot 0 2000 4000 6000 8000 10000 12000 Measured Depth (2000 usftfin) LEGEND -� 1-5-15, 1-5-15PI31, L5-15PB1 V1 $ 1-5-05,1-5-05,15-05 V1 1-5-01,1-5-01,1-5-01 V1 -#- L5 -15,L5 -15,L5 -15V1 -$- 1-3-12,1-3-12,1-3-12 V1 L5 -12,L5 -12,L5 -12V1 -�}- L5 -17,L5 -17,L.5 -17V1 $ 1-5-08, L5-08, L5-08 V1 L5-12, L5 -12A, L5 -12A VO $ L5-17, L5 -17A, L5 -17A V 13 15-03,1-5-03,1-5-03 VO $ 1-5-07 WP03 $ 1-5-04,1-5-04,1-5-04 V1 1-5-03,1-5-03,1-5-03 VWP12A VO �¢- 1-5-13,1-5-13,1-5-13 V1 -$- L5-09, L5-09, L5-09 V1 7/11/2019 8:47.58AM Page 3 of 3 COMPASS 5000 1 Build 61D EN J P . 6.m � 30 lAl (U!/8sn ooS) (+)glio /(-)glnos 0 $o�6; osooz z o�t�sso`-r�-�t Iq o000 �Lo $S S g J � JocSUI o J�N�+ �mm m p�O�pNmO �OpN� �rrr�rrrrr�c�rr� 99'914 D'514��5AA5AO p oo o 0 o I o o N o clj oo M o 0 0s 0 0 0 o 0O O O O O O C O S S O O O O o 0 poo�j M<.io m000coovr'io ToonC?o ^? VYM2 SSG71 �2 922ZE92 z p�'e om ov�v��m"v mc�vNN �2L' ommmm SSo88Si SiO88 i a; iNN —ooM .6 L6mmm�gma6 '2vggog . . ...�����mgi S ... 0�giF 'ae C m w y F W O U �mlmp0 I I� _ o + 1 IzY mm wm I 3 g�33333333. o f H9H 5Z aL y ' fa SiiS�aagSg�. ' x,333333;331: �8888888"�'� �I��S$888888� 190200 a N 9600 O 3 u (u!/ysn 009) g1daQ [uo19uan arul u u C 6000 5400 4800 n 4200 ry N 3600 C O 3000 uv 2.400 U .2 19800 1200 LU 600 3 0 ca T O -600 •1200 m a \� :O { /CD 8 C) 8 8° \ j N \ 3 'IT \ \ . 0 \ \ \ \ \ \ L r = � � 5 ,_, ,_, ,_o 13600 ,se 12800 ,_o ,_o 11600 em, ,_, ,_o 10000 } g _ _ -�- - g rrw! (uAnOZ) o k\Sa ua m ema ° { �!{22Mlmq!! § § �q IT ,8Q33383333 �35P-5 P_5q, '_�8SS88SS X333333333 i iE�8888$8$8' LL `f 8 m <�3 Z � uCN U cV m Q E305m t =oda= Z�,SWmwc OHO U ' I `�OOb��"��ONmNnbN�Oei � jo d�unm ��n �ri6uiemmnviv �memmme�omm O O O N O b O O O O O O o 0 �000000'a 0000' 00000 000��mme�aoa�o<mo pp +, Oovmi00nm NQS Nbt"`p��Ntp J i mriOjm mY 4'?`?`?W yoo z mm m�rvmn nm �n mnv�im^m 0 3ooyo�'rv°rv$nnnggoo 0 'U �''m tinmueimnoomm� m ��o�oe�o��omm�o .......... d'o oorvn x C O cl (0 in d c U m C N U r v z° 0 s E ■ __(450 usft/in) w North America - ALASKA - BP Lisburne L5 L5-07 PLAN L5-07 1-5-07 WP03 Plus 500ft MD AOGCC Offset Well Report 10 July, 2019 by Company: North America - ALASKA - BP Project: Lisburne Reference Site: L5 Site Error: 0.00usft Reference Well: 1-5-07 Well Error: 0.00usft Reference Wellbore PLAN 15-07 Reference Design: 1-5-07 WP03 Plus 500ft MD BP Anticollision Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: Well L5-07 PLAN KB P272 @ 66.75usft (Original Well Elev) PLAN KB P272 @ 66.75usft (Original Well Elev) True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Reference 1-5-07 WP03 Plus 500ft MD Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 200.00usft Error Surface: Elliptical Conic Summary Site Name Offset Well - Wellbore - Design L5 L5-01 - 1-5-01 - 1-5-01 1-5-03 - L5-03 - 1-5-03 15-03 - L5-03 - L5-03 WP12A 1-5-05 - 1-5-05 - 15-05 1-5-07 - PLAN 1-5-07 - L5-07 WP03 1-5-08 - 1-5-08 - 15-08 1-5-09 - 15-09 - L5-09 1-5-13 - 1-5-13 - 1-5-13 Reference Offset Centre to Measured Measured Centre Depth Depth Distance (usft) (usft) (usft) 386.74 375.00 186.67 398.95 400.00 126.53 399.50 400.00 125.88 406.75 400.00 66.02 4,525.00 4,525.00 0.00 406.75 400.00 184.15 711.72 700.00 50.91 391.12 375.00 174.99 7/10/2019 10:37.38PM Page 2 of 2 COMPASS 5000.1 Build 81D Q I' I - 4 (a h IN 1 ,I 134" 1 d 32 a _ _ 031 1 20 025 f i I 1 L 2 1 �+ . 021 R` 4 5� 1 F 01� 75 yy 6 1 I 016 J 75' Radius 12" nition Sources. 4ffw 1 of 11 1 11 � II a t I QD Parker 272 on Well L5-07 Traffic Pattern while Rig on Diverter WELLHEAD = ACTUATOR = OKB_ ELEV = BF. ELEV = KOP= Max Angle Datum MD = Datum TVD= 8900' SS PROP%.SED REV 3 20" COND, —125 129.45#, X56, U =18.75" 13318" CSG, 68#, L 80 BTC, ID = 12.415" 4536' j Minimum ID = of @Q 9-5/8" TOC 83§0• TOP Of 7" LNR 9500- F--5-/8" 500 9-5/8" CSG, 47#, L-80 VAM21, ID = 8.681" 9650 TOP OF 4-1/2" LNR 10110 4-1/2" TBG, 12.6#, 13CR-85 VAM TOP, 10115' 0152 bpf, ID = 3.958- 7- LNR, 26#, L-80 VAM TOP HC, 10261' .0383 bpf, D = 6.276" PERFORATION SUNT/IARY REF LOG: ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ I PBTD t 4-1/2" LNR, 12.6#, 13CR•86 VAM TOP —{ 15200' .0152 bpf, ID = 3.958" L5-07 SAFEI' TES: WELL ANGLE> 70' @ ' `"' MAX DOGLEG. @ CHROME TBG & LNR �4-1/2"HES XNIP, 1)=3.813" I GAS LIFT MANDRILS ST MD TVD DEV TYPE V LV LATCH ! PORT DATE 4 3 9500' �9-5/8- X 7" _ LTP w/HGR & TIEBACK SLEEVE, ID = —14-1/2" HES X NP, ID = 3.813" 996W 7" X 4-1/2" HES TNT PKR, 1) = 3.856" "HES XN NP, ID 3.72 = 3.725" 10110 7" X 5" WFT UP w/HGR & TIEBACK SLEEVE, ID = " 10115' 4-1/2' WLEG, ID = 3.958" ELMD TT NOT LOGGED DATE REV BY CONVENTS DATE REV BY COMMENTS ORIGINAL COMPLETION 03/27/19 JMD BUILT GR PROPOSED 03/27/19 NWJMD BUILT GR PROPOSED REV 3 LISBURNE Lffr WELL- L5-07 PERMIT No: AP1 No: 50-029- -00 SEC _, T_N, R E, ' FSL & ' FWL BP Exploration (Alaska) 1/r ,6.45• /-1 -- 2S _ x g p m �M� / G4G 4� F i GGE mu N �/v \\\ i i��1n N\\n i\\\ \\\^' rT •\�j •yA SOK mmm�p `-'oomA mmmmm moomm � ��m_svo F N U N O CCNU G U U O N U N O N G 1�• I U 9 C F F `/ ^I CCCv ;; �3:c� •CCs CCC'• tee: Fm nooN ooC OO+KO Kt RIO$ 19 R C o ! S E; m O v \_ � m O z m N o z F O F � e � ■ 12 C(n Cl, m p NI -' 9 ■ ■ 8 L5-07 5 ■ N Ss,m 4 3 \ IIIIIIIIIIE GRAPHIC SCALE 0 50 100 200 ( IN FEET ) 1 inch = 100 ft. —N— I I DRILL SITE L-5 MON. L5—SOUTH LEGEND AS—BUILT CONDUCTOR EXISTING WELL ® CONTROL MONUMENT NOTES: 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NA027. (EPSG:26734) 2. GEODETIC POSITIONS ARE NA027. (EPSG:4267) 3. BEARINGS AND DISTANCES SHOWN ARE ALASKA STATE PLANE GRID. 4. DRILL SITE L-5 AVERAGE SCALE FACTOR IS: 0.9999537. 5. BASIS OF VERTICAL CONTROL IS DRILL SITE L-5, 2018 WELL BORE SUBSIDENCE STUDY FOR TBM NS124249 (EL 18.93'). 6. DATE OF SURVEY: FEBRUARY 2, 2020. 7. REFERENCE FIELD BOOK: NS20-01 PGs 43-45. 8. COMPUTED RELATIVE ACCURACY (THIRD ORDER): BASELINE DISTANCE: 1:52,484 BASELINE AZIMUTH: N/A ALLOWABLE VERTICAL CLOSURE: ±0.01' 9. NAD27 COORDINATES DERIVED USING TRIMBLE BUSINESS CENTER—HCE, VER. 3.92. 10, GEODETIC COORDINATES DERIVED USING CORPSCON VER B.O.I. __w 4_5 -oma VICINITY MAP 11=1000' SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS AS—BUILT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF FEBRUARY 1, 2020. BASIS OF COORDINATES: HELD COORDINATES OF RECORD DRILL SITE L-5, MONUMENT L-5 SOUTH Y= 5,974,312.47 N= 4,317.00 X= 717,780.37 E= 5,421.50 NAD27, ASP, ZONE 4 DS—L5 PLANT DESCRIPTION: 10' SQUARE STEEL PLATE ON 4'0 STEEL PIPE. WITH PUNCH MARK AND ELEVATION ON PEENED UP NORTHWEST CORNER, 2.5' ABOVE TUNDRA. LOCATED WITHIN PROTRACTED SEC. 02, T. 11 N., R. 15 E., UMIAT MERIDIAN, ALASKA WELL NO. I A.S.P. COORDINATES I PLANT ICOORDINATES GEODETIC POSITION(DMS) GEODETIC POSITION(D.DD) SECTION OFFSETS I PAD ELEVATION1 I CELLAR BOX EL. BASE FLANGE EL. L5-07 Y= 5,974,650.41 X= 717,271.34 N= 4,654.96 E= 4,912.45 70'20'00.150" 148'14'14.168" 70.3333749' 148.2372689' 1,523 FSL 164' FEL 20.1' 0 20.2' N/A sort vim DRAWN: DRAPER ` N r CHECKED: JACOBS D 3/20 DRAWNG: NG: FRB79 DSLS 01 PRUDHOE BAY, ALASKA EOA DRILL SITE L5, WELL L5-07 CONDUCTOR AS—BUILT sxEE'r: 1 OF 1 coAk AECC582 8DI W. nRE%*n LANE (ANaa)��szs�A Ilsoz SCALE: 1• 100. oD z s zo LS 1 FOR INFORVAMON KMO � NO. DATE REMSION BY CMK Re,v ,eA OZ -/03J ;D K, = .6�3- Davies, Stephen F (CED) From: Davies, Stephen F (CED) Sent: Monday, July 29, 2019 3:44 PM To: Nocas, Noel Subject: RE: PBU L5-07 (PTD 219-102) - Well Spacing Question Noel, It is best that the Permit to Drill and the Spacing Exception Application arrive together. If an exception to the spacing requirements is indeed needed for a well, the Permit to Drill for that well will not be approved until the Spacing Exception Conservation Order is approved and signed by AOGCC's Commissioners. By example, although the Permit to Drill Application for PBU 1-5-07 has passed through review process by AOGCC's staff geologists and engineers, it will not be approved by the Commissioners until the Spacing Exception Order is completed and submitted for their simultaneous review. Please let me know if you have additional questions. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Nocas, Noel <Noel.Nocas@bp.com> Sent: Thursday, July 18, 2019 8:25 AM To: Davies, Stephen F (CED) <steve.davies@alaska.gov> Subject: RE: PBU L5-07 (PTD 219-102) - Well Spacing Question Steve, I figured it was something like that, no confusion on this side. I want to make sure that in the future I am not wasting any of your time, so I wanted to check with you on future process. Do you prefer the PTD request comes prior to the spacing exception, or is it helpful to have the proposed well information in the form of a PTD request so you have context for the spacing exception? I can communicate this to the drilling team here and possibly optimize the process to ensure we are all on the same page. Thank you for your time and attention, Noel -------------- Noel Nocas Drilling Engineer — BP Alaska noehnocas by com o. 907-564-5027 c. 907-229-9532 From: Davies, Stephen F (CED) <steve.davies@alaska.gov> Sent: Wednesday, July 17, 2019 1:36 PM To: Nocas, Noel <Noel.Nocas@bp.com> Subject: RE: PBU L5-07 (PTD 219-102) - Well Spacing Question Noel, Thank you for your help. It looks like the arrow on my map somehow moved to the left during transmission of the email. Apologies for any confusion. Regards, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Nocas, Noel <Noel.Nocas@bp.com> Sent: Wednesday, July 17, 2019 1:21 PM To: Davies, Stephen F (CED) <steve.davies@alaska.Rov> Cc: Swanson, Mark <Mark.Swanson@bp.com> Subject: RE: PBU L5-07 (PTD 219-102) - Well Spacing Question Hi Steve, Currently Bill is on vacation but we will work on the spacing exception rapidly upon his return. Thank you for your time. Best, Noel --------------- Noel Nocas Drilling Engineer — BP Alaska noel.nocas@bp.com o. 907-564-5027 c. 907-229-9532 From: Davies, Stephen F (CED) <steve.daviesCcDalaska.Zov> Sent: Wednesday, July 17, 2019 11:07 AM To: Nocas, Noel <Noel.Nocas@bp.com> Subject: PBU L5-07 (PTD 219-102) - Well Spacing Question Noel, The Lisburne Oil Pool at Prudhoe Bay is governed by Conservation Order No. 207C (CO 207C). Rule 3 of that order states: "The well spacing unit shall be one producing well per governmental quarter section. No pay may be opened in a well closer than 1,000 feet to the pay opened in another well or opened in a well which is closer than 500 feet to the boundary of the affected area." According to my map, below, BP's planned PBU L5-07 producer will apparently be open to the Lisburne Oil Pool within the same governmental quarter section as active producer PBU L3-12 (PTD 186-161). If this is correct, PBU L5-07 will require a spacing exception to be drilled, completed and produced, and BP's Permit to Drill application for this well cannot be approved until such an exception is approved by the AOGCC. Rule 17 of CO 207C allows the AOGCC to administratively waiver the requirements based upon an application from BP. In March 2019, the AOGCC issued a similar spacing exception decision (see CO 207B.001) for nearby well PBU L5-03 (PTD 219-033). Bill Bredar at BP is familiar with the spacing exception application process. fu - 00 *04 Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.daviescot alaska.tov. 3 Davies, Stephen F (CED) Subject: FW: PBU 1-5-07 (PTD 219-102) - Well Spacing Question From: Davies, Stephen F (CED) Sent: Wednesday, July 17, 2019 11:07 AM To: Noel.nocas@bp.com Subject: PBU 1-5-07 (PTD 219-102) - Well Spacing Question Noel, The Lisburne Oil Pool at Prudhoe Bay is governed by Conservation Order No. 207C (CO 207C). Rule 3 of that order states: "The well spacing unit shall be one producing well per governmental quarter section. No pay may be opened in a well closer than 1,000 feet to the pay opened in another well or opened in a well which is closer than 500 feet to the boundary of the affected area." According to my map, below, BP's planned PBU 1-5-07 producer will apparently be open to the Lisburne Oil Pool within the same governmental quarter section as active producer PBU 1-3-12 (PTD 186-161). If this is correct, PBU 1-5-07 will require a spacing exception to be drilled, completed and produced, and BP's Permit to Drill application for this well cannot be approved until such an exception is approved by the AOGCC. Rule 17 of CO 207C allows the AOGCC to administratively waiver the requirements based upon an application from BP. In March 2019, the AOGCC issued a similar spacing exception decision (see CO 2076.001) for nearby well PBU 1-5-03 (PTD 219-033). Bill Bredar at BP is familiar with the spacing exception application process. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.¢ov. 2 • • • • Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.¢ov. 2 TRANSMITTAL LETTER CHECKLIST WELL NAME: 41-2tC PTD: _Z_ /7 — /y 7 Development _ Service _ Exploratory Stratigraphic Test Non -Conventional FIELD: ,�yc� POOL: �./ ✓=�-C 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. 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 j (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, LISBURNE OIL - 640144 Well Name: PRUDHOE BAY UN LIS L5-07 _ —Program DEV _ — Well bore seg PTD#:2191020 Company BP Exploration (Alaska Inc. _ Initial Class/Type _ _DEV / PEND GeoArea 890 —_ Unit _11650 On/Off Shore On Annular Dispc Administration 1 Permit fee attached NA 2 Lease number appropriate_ Yes Surface Location lies within ADL0028320; Top Productive Interval lies in ADLO.034631, - 3 Unique well name and number Yes TD lies -in ADL0028322. 4 Well located in a defined pool - - Yes PRUDHOE BAY, LISB_U_RNE OIL - 640144, governed by CO 207B 5 Well located proper distance from- drilling unit boundary InCmpt CO 2076_, Rule 3: The well spacing unit shall be one producing well per -governmental quarter section. No 6 Well located proper distance from other wells Yes pay may be opened in awell closer than 1,000 feet to the pay opened in another well or opened in a 7 Sufficient acreage available in drilling unit_ Yes well which is closer than 500 feet to the boundary of the affected area, 8 If deviated, is wellbore plat -included Yes 19 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 14 Well located within area andstrata authorized by Injection Order # (put 10# in comments) (For NA - 15 All wells within 1/4_mile _area _of review identified (For service well only) NA_ 16 Pre -produced injector: duration -of pre -production less than 3 months_ (For service well only) NA 17 Nonconven. gas conforms to AS31.05,0300.1.A),0.2.A-D) NA 18 Conductor string provided - Yes 20" x 34" Conductor 215_#_ - - Engineering 19 Surface casing_ protects all -known- USDWs - - - Yes Fully cemented._ Shoe -set in SV3 - 20 CMT_ vol_ adequate_ to circulate on conductor _& surf csg Yes Fully cemented_ - - - - - - . 21 CMTvoI_ adequate to tie-in long string to surf csg_ NA - - - - 22 CMT will coverall known_ productive horizons_ Yes Lisburne and I_vishak will be -covered. . 23 Casing designs adequate for C,_T, B &_permafr_ost Yes 24 Adequate tankage or reserve pit - - - - - - Yes Parker 272 has ongoing operations and good truck support 25 If -a- re -drill, has. a- 10-403 for abandonment been approved NA_ New well ----------------- 26 Adequate.wellbore separation -proposed Yes All offset wells pass BP separation criteria 27 If diverter required, does it meet_ regulations_ - - - - - - Yes Appr Date 28 Drilling fluid_ program schematic & equip list adequate_ Yes All fluids should be overbalanced MGR 7/29/2019 29 BOPEs, do they meet regulation - - - - - - - - Yes . 13_-5/8" Stack 1 annu_lar,_3_ ram_ _ _ 30 BOPE_press rating appropriate; test to (put prig in comments)_ - Yes 5M stack_ tested_ to 3500 -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 L1_ pad is considered_ a_n_H2S_pad, all monitoring equipment will. be -in place. - - - i34 of Mechanical condition of wells within AOR verified (For service well only) NA - This well -is a producer_ - - - - - - - - - �35 Permit_can be issued hydrogen-sulfide measures No L5-Pad.wells are H2S-bearing.112S measures are required._ Geology 36 Data_presented on potential overpressure zones .. - Yes Planned mud weights appear -adequate to control the operator's forecast of -most likely pore pressures. Appr Date 37 Seismic analysis_ of shallow gas_zones_ - - - - - _NA High Iikelih_ood for encountering lost circulation within_ Lisburne as discussed in the Drilling Critical SFD 7/17/2019 38 Seabed condition survey -(if off -shore) - - - NA. Issues section of this application. - - - 39 Contact name/phone for weekly -progress reports. [exploratory only] NA- Geologic Engineering Public Co issioner: Date: Zo Commissioner: Date C mi i Dat ■❑
