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Home My WebLink About222-0307. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU M-201 Commence MI Injection Per AIO 25A.024 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 222-030 50-029-23711-00-00 18744 Conductor Surface Tieback Production Liner 5200 80 7754 7070 11393 18478 20" 9-5/8" 7" 7" x 4-1/2" 5249 27 - 107 27 - 7781 25 - 7095 7087 - 18480 27 - 107 27 - 5178 25 - 4991 4987 - 5249 None 4760 / 3090 5410 7500 None 6870 / 5750 7240 8430 8015 - 18216 4-1/2" 12.6# L-80 22 - 7253 5178 - 5268 Structural 4-1/2" HES TNT Perm Packer 2225, 1914 7148 5015 Torin Roschinger Operations Manager Tyson Shriver tyson.shriver@hilcorp.com 907-564-4542 PRUDHOE BAY, POLARIS OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028257, 0028260, 0047448 22 - 5060 N/A N/A 2004 907 50 0 1938 2773 N/A 13b. Pools active after work:POLARIS OIL HES RS 25 Non-SC SSSV 7148, 5015 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.08.20 06:37:59 - 08'00' Torin Roschinger (4662) By Grace Christianson at 1:51 pm, Aug 20, 2024 RBDMS JSB 082824 DSR-8/21/24WCB 10-2-2024 ACTIVITY DATE SUMMARY 7/29/2024 Hot DSL WAG Swap (WAG SWAP) Pumped 3 bbls 50/50 meth and 138 bbls 180* DSL down Tbg. Pad Op notified of well status per LRS departure. SV,WV,SSV=C MV=-O IA.,OA=OTG 8/3/2024 ***WELL S/I ON ARRIVAL*** R/U POL 61 ***WSR CONT ON 8-4-24*** 8/4/2024 ***WSR CONT FROM 8-3-24*** DRIFTED TO & EQUALIZED 4-1/2'' RED SPYDER @ 2225' MD PULLED 4-1/2'' RED SPYDER FROM 2225' MD BRUSHED w/ 4-1/2'' BLB, 3.80'' CENT, BRUSHED X-NIP @ 2225' MD SET 3.81'' X-LOCK (eq sub 4 x 3/16" & 4 x 1/8'' ports), 4-1/2" REDSPIDER(oal=48", w/ secondary lockdown, sn=RS-25) @ 2225' MD (tag hung on master) RAN 4-1/2'' CHECK SET TO RED SPYDER @ 2225' MD (sheared) PERFORM PASSING DRAW DOWN TEST ***JOB COMPLETE, WELL LEFT S/I*** Daily Report of Well Operations PBU M-201 1 Regg, James B (OGC) From:Regg, James B (OGC) Sent:Thursday, November 30, 2023 3:54 PM To:Oliver Sternicki Subject:RE: 20 AAC 25.265(j) temporary SSSV removal clarification Thanks for taking my call. Yes, temporarily removing the SSSV from M‐201 for evaluaƟng the effect the MCX valve has on the injecƟon rate falls under 20 AAC 25.265(j). Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907‐793‐1236 From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Thursday, November 30, 2023 10:22 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Subject: 20 AAC 25.265(j) temporary SSSV removal clarification Mr. Regg, PBU well M‐201 (PTD# 222030) is a produced water injector that is required to have a SSSV due to being within 660’ of a navigable waterway. We have found that there is a large difference between the injecƟon rate of the well when it is on normal injecƟon (SSSV installed) vs when we have conducted downhole work such as iprofs with the SSSV removed. Even with the largest bean size installed in the MCX valve the injecƟon rates into the well are dramaƟcally lower and at a higher pressure than we have seen in iprofs. We would like to temporarily remove the SSSV from M‐201 and place the well on injecƟon to see if the injecƟon rate remains high, indicaƟng that the MCX is acƟng as a signiﬁcant choke or if the injecƟon rate reduces over the course of a few days, indicaƟng that the higher rates observed during logging are a funcƟon of replacing near wellbore volume aŌer a shut‐in. I wanted to verify that removal of the SSSV as we propose falls under 25.265(j) as “rouƟne well pad or plaƞorm operaƟons”. Regards, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. PBU M-201PTD 2220300 Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 06/13/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230417 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU B-21 50029215350000 186023 5/8/2023 HALLIBURTON Jewelry Log MPU B-21 50029215350000 186023 5/12/2023 HALLIBURTON Leak Detection Log MPU B-21 50029215350000 186023 5/13/2023 HALLIBURTON Multi Finger Caliper Report MPU I-04A 50029220680100 201092 4/17/2023 HALLIBURTON Cement Bond Log NS-16A 50029230960100 206141 4/3/2023 HALLIBURTON RBT NS-23 50029231460000 203050 4/25/2023 HALLIBURTON RBT PBU 09-24A 50029214280100 223003 4/9/2023 HALLIBURTON RBT-Coilflag PBU C-26A 50029208340100 198145 3/17/2023 HALLIBURTON Production Profile PBU M-201 50029237110000 222030 5/29/2023 HALLIBURTON Inj. Profile PBU S-32A 50029220990100 212082 5/23/2023 HALLIBURTON CAST CBL PBU S-37A 50029222910100 212092 5/19/2023 HALLIBURTON RBT PBU V-221 50029232460000 205013 5/14/2023 HALLIBURTON Inj. Profile PBU W-04 50029219070000 189008 3/8/2023 HALLIBURTON CAST CBL PBU W-209 50029231700000 203128 5/13/2023 HALLIBURTON Inj. Profile PBU W-219 50029234290000 210105 4/16/2023 HALLIBURTON Inj. Profile PBU Z-223 50029237200000 222080 2/28/2023 HALLIBURTON Inj. Profile SRU 213B-15 50133206540000 215130 4/28/2023 HALLIBURTON Perf Please include current contact information if different from above. T37729 T37729 T37729 T37730 T37731 T37732 T37733 T37734 T37735 T37736 T37737 T37738 T37739 T37740 T37741 T37742T37743 PBU M-201 50029237110000 222030 5/29/2023 HALLIBURTON Inj. Profile Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.13 13:09:15 -08'00' 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) Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/18/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221118 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# PBU F-29B 50029216270200 211147 8/20/2022 Halliburton SpinnerPressTemp PBU L-202 50029232290000 204196 10/24/2022 Halliburton PPROF PBU L-222 50029234200000 209119 10/21/2022 Halliburton IPROF PBU M-201 50029237110000 222030 10/17/2022 Halliburton IPROF Please include current contact information if different from above. By Meredith Guhl at 2:37 pm, Nov 18, 2022 T37276 T37277 T37278 T37279PBU M-201 50029237110000 222030 10/17/2022 Halliburton IPROF Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.18 14:44:07 -09'00' DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-029-23711-00-00Well Name/No.PRUDHOE BAY UN POL M-201Completion Status1WINJCompletion Date4/29/2022Permit to Drill2220300OperatorHilcorp North Slope, LLCMD18744TVD5200Current Status1WINJ9/9/2022UICYesWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:ROP, AGR, DGR, ABG, EWR, ADR MD & TVDNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleDF5/24/20227770 18706 Electronic Data Set, Filename: PBU M-201 ADR Quadrants All Curves.las36552EDDigital DataDF5/24/20227770 18706 Electronic Data Set, Filename: PBU M-201 ADR Quadrants All Curves.las36552EDDigital DataDF5/24/2022100 18744 Electronic Data Set, Filename: PBU M-201 LWD Final.las36552EDDigital DataDF5/24/2022 Electronic File: PBU M-201 ADR Image.dlis36552EDDigital DataDF5/24/2022 Electronic File: PBU M-201 ADR Image.ver36552EDDigital DataDF5/24/2022 Electronic File: PBU M-201 Geosteering End of Well Plot.emf36552EDDigital DataDF5/24/2022 Electronic File: PBU M-201 Geosteering End of Well Plot.pdf36552EDDigital DataDF5/24/2022 Electronic File: PBU M-201 Geosteering End of Well Report.pdf36552EDDigital DataDF5/24/2022 Electronic File: PBU M-201 Post-Well Geosteering X-Section Summary.pdf36552EDDigital DataDF5/24/2022 Electronic File: PBU M-201 Post-Well Geosteering X-Section Summary.pptx36552EDDigital DataDF5/24/2022 Electronic File: PBU M-201 Geosteering End of Well Plot Hi-Res.tif36552EDDigital DataDF5/24/2022 Electronic File: PBU M-201 Geosteering End of Well Plot.tif36552EDDigital DataDF5/24/2022 Electronic File: MPU I-29 LWD Final TVD.cgm36552EDDigital DataDF5/24/2022 Electronic File: PBU M-201 LWD Final MD.cgm36552EDDigital DataFriday, September 9, 2022AOGCC Page 1 of 3PBU M-201 LWDFinal.las DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-029-23711-00-00Well Name/No.PRUDHOE BAY UN POL M-201Completion Status1WINJCompletion Date4/29/2022Permit to Drill2220300OperatorHilcorp North Slope, LLCMD18744TVD5200Current Status1WINJ9/9/2022UICYesWell Cores/Samples Information:ReceivedStart Stop CommentsTotalBoxesSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYMud 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 HISTORYCompletion Date: 4/29/2022Release Date: 3/24/2022DF5/24/2022 Electronic File: M-201_Definitive Survey Report.pdf36552EDDigital DataDF5/24/2022 Electronic File: M-201_Definitive Survey Report.txt36552EDDigital DataDF5/24/2022 Electronic File: M-201_Definitive Surveys.xlsx36552EDDigital DataDF5/24/2022 Electronic File: M-201_GIS.txt36552EDDigital DataDF5/24/2022 Electronic File: M-201_Plan.pdf36552EDDigital DataDF5/24/2022 Electronic File: M-201_VSec.pdf36552EDDigital DataDF5/24/2022 Electronic File: PBU M-201 LWD Final MD.emf36552EDDigital DataDF5/24/2022 Electronic File: PBU M-201 LWD Final TVD.emf36552EDDigital DataDF5/24/2022 Electronic File: PBU M-201 ADR Image.dlis36552EDDigital DataDF5/24/2022 Electronic File: PBU M-201 ADR Image.ver36552EDDigital DataDF5/24/2022 Electronic File: PBU M-201 LWD Final MD.pdf36552EDDigital DataDF5/24/2022 Electronic File: PBU M-201 LWD Final TVD.pdf36552EDDigital DataDF5/24/2022 Electronic File: PBU M-201 LWD Final MD.tif36552EDDigital DataDF5/24/2022 Electronic File: PBU M-201 LWD Final TVD.tif36552EDDigital DataFriday, September 9, 2022AOGCC Page 2 of 3 DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-029-23711-00-00Well Name/No.PRUDHOE BAY UN POL M-201Completion Status1WINJCompletion Date4/29/2022Permit to Drill2220300OperatorHilcorp North Slope, LLCMD18744TVD5200Current Status1WINJ9/9/2022UICYesComments:Compliance Reviewed By:Date:Date CommentsDescriptionFriday, September 9, 2022AOGCC Page 3 of 3M. Guhl9/9/2022 By Anne Prysunka at 11:42 am, Aug 04, 2022 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 21, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Matt Herrera P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC M-201 PRUDHOE BAY UN POL M-201 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/21/2022 M-201 50-029-23711-00-00 222-030-0 W SPT 5015 2220300 1500 978 980 982 984 134 326 323 327 INITAL P Matt Herrera 6/25/2022 MIT-IA performed to 2000 PSI per Operations post DHD from failed previous Initial MIT-IA performed on 6/7/22. Inconsistent rising injection pressures and temp prohibited accurate determination as to whether well had defined pressure stabilization. It was determined to be a pass after review by J. Regg. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN POL M-201 Inspection Date: Tubing OA Packer Depth 536 2037 1979 1983IA 986 331 45 Min 1989 988 336 60 Min 1996 Rel Insp Num: Insp Num:mitMFH220629125933 BBL Pumped:1 BBL Returned:1 Thursday, July 21, 2022 Page 1 of 1        56 psi total pressure loss = 2.7% of initial test pressure; jbr  By Meredith Guhl at 1:30 pm, Jun 21, 2022 Completed 4/29/2022 MDG RBDMS 6/21/2022 MDG G DSR-6/21/22MGR07SEP2022DLB 08/24/2022 6.21.2022 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2022.06.21 12:37:25 -08'00' Monty M Myers CASING AND LEAK-OFF FRACTURE TESTS Well Name:PBU M-201 Date:4/17/2022 Csg Size/Wt/Grade: Supervisor:Lot/Amend Csg Setting Depth:7781 TMD 5178 TVD Mud Weight:9.5 ppg LOT / FIT Press =674 psi LOT / FIT =12.00 ppg Hole Depth =7810 md Fluid Pumped=1.7 Bbls Volume Back =1.4 bbls Estimated Pump Output:0.062 Barrels/Stroke LOT / FIT DATA CASING TEST DATA Enter Strokes Enter Pressure Enter Strokes Enter Pressure Here Here Here Here ->00 ->00 ->476 ->6273 ->8 195 ->12 472 ->12 328 ->18 631 ->16 413 ->24 783 ->20 518 ->30 955 ->24 601 ->36 1126 ->28 678 ->42 1303 -> ->48 1483 -> ->54 1665 -> ->60 1850 -> ->66 2036 -> ->74 2292 -> ->86 2673 Enter Holding Enter Holding Enter Holding Enter Holding Time Here Pressure Here Time Here Pressure Here ->0 678 ->0 2673 ->1 585 ->1 2652 ->2 563 ->2 2650 ->3 550 ->3 2650 ->4 539 ->4 2648 ->5 529 ->5 2647 ->6 519 ->10 2643 ->7 511 ->15 2638 ->8 504 ->20 2634 ->9 496 ->25 2630 ->10 489 ->30 2627 -> -> -> -> -> -> 9 5/8" 47#/40# L-80 0 4 8 12 16 20 24 28 0 6 12 18 24 30 36 42 48 54 60 66 74 86 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 0 102030405060708090100Pressure (psi)Strokes (# of) LOT / FIT DATA CASING TEST DATA 678 585563550539529519511504496489 267326522650265026482647 2643 2638 2634 2630 2627 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 0 5 10 15 20 25 30Pressure (psi)Time (Minutes) LOT / FIT DATA CASING TEST DATA Activity Date Ops Summary 4/4/2022 Blow down steam, air, water. R/D interconnects. clean pits. Scope derrick down. Raise modules. Split modules apart and stage on pad for mob. Walk sub base off V-227Aand rotate. Install back tires. R/U yoke on sub and hook up to truck. Stage on pad. Move all modules from 'V' pad to 'M' pad and stage on pad. Set rig mats. Spot sub base over M-201. Shim and level sub base. Set and level catwalk. 4/5/2022 Lay rig mats. Attempt to spot mud mod and pipe shed. Difficulties on pipe shed side due to limited space on pad. Finish spotting pipe shed. Spot mud mod, and gen mod. Verify interconnects will work. Release NES trucks at 17:30. Rig up interconnects. Assist electrician with electrical inter connect. Swap to generators. Apply steam to rig. Lower all stairs. Scope derrick up. Install derrick pins, rig up weight buckets and Geronimo line. Plug in derrick lines. Bridle down. Remove MPD head and set in cellar. Install bell nipple. Set BOP Stack on diverter 'T'. Install bolts and torque orient 'T' for vent line. Install knife valve and accumulator lines. Install diverter vent sections. Wire wheel shaker motor mounts. Take links out of drag chain. Install 4" conductor valves. C/O UPR's to 4.5" x7" VBR's. Tighten chain binders. Install trip nipple and air up boots. Work on rig acceptance checklist. 4/6/2022 Cont. working on rig acceptance checklist. C/O saver sub, bell guide and block dies to 5". Pump through and inspect both mud pumps. Mount and torque shaker motors. Install mousehole. Obtain RKB's. Continue loading and strapping drill pipe in shed. Cont working on rig acceptance checklist. Assist welder with bolt on suction pod pump 1, crack in shaker 2 bed an adjustment holes on shaker 2. Pressurize accumulator and adjust bag pressure for mousehole. Rig accepted at 15:30. Drift, pick up and rack back 260 joints HWDP, 14 joints of HWDP. Sim Ops: test gas alarms, take on spud mud. Assist welder with beyond flowline deflection extension, cellar door latch Pick up 3 stands of HWDP and jars. L/D mouse hole from rotary. Total 130 stands DP and 9 stands HWDP with jars. String on new drilling line. Set slips and dog collar on drill pipe. Remove secondary crown save from dead line, remove wraps from deadman. M/U snake as per procedure. Start re-stringing the blocks and draw works. Slipping on 1,305' of drillling line. 4/7/2022 Finish torqueing deadman brass and main support bolts. Unhang blocks and calibrate first layer on drum. Check crown and floor saver. Service rig: grease TD, blocks, crown, spinners, check gear oil on TD and rotary. P/U bit, XO, lift subs. Prep to pick up BHA. R/U tongs and cat head. M/U cleanout BHA: 12-1/4 Kymera bit, motor. RIH on HWDP to 106'. Pick up off bottom Perform Diverter test: knife valve open in 6 seconds, annular close in 10 seconds. Accumulator draw down test: starting pressure 3000 psi, pressure after closure 1900 psi, first 200 psi recharge 19 seconds, full recharge 52 seconds. (6) N2 bottles at 2367 psi. RIH to 106'. Drill rathole from 106' to 220' at 300 gpm, 1150 psi, 30 rpms, 1250ft-lbs, WOB 2K. P/U 42K, S/O 42K, ROTW 40K. Jet flow line and pump down bleeder as needed. POOH racking back 3 stands HWDP. Inspect bit - good. P/U 40K, S/O 40K. Cont. M/U BHA: GWD, DM, WER-M5, TM collar. Measure RFO=136.39°. Plug in and upload MWD. P/U and M/U (2) flex collars to 159'. Wash and ream with HWDP to 220' at 300 gpm, 30 rpms. Cont. drilling 12-1/4" hole from 220' to 351' at 425 gpm, 600 psi, 30 rpms 1.5-3Kft-lbs, WOB 5-10K. P/U 55K, S/O 55K, ROT 55K. Continuously jetting flow line, pump through bleeder as needed. 50-120 bph loss rate Observe erratic pump pressure, then no pump pressure as troubleshooting. KOP 283'. Observe small pea gravel to large gravel over shakers. Observe losses up to 125 bph. POOH from 351' to 90' (inside conductor) while going through pumps. Observe fine pea gravel and sand in both pumps all valve and seats, suctions and discharges. Clean out mud pumps. RIH to 339' with no issues. Wash down to 351' and continue slide drilling from 351' to 403 ' at 425 gpm, 670 psi, WOB 5- 10K. P/U 55K, S/O 55K, ROT 55K. Rack stand back and pick up jar stand. RIH and set down at 490'. Screw in and establish circulation. Observe 450-500 psi high pump pressure. Troubleshoot, appears jet nozzle plugged. DD ran hydraulics and shows potential of two plugged nozzles. Attempt to unplug bringing pumps up to 550 gpm/1800 psi and surging pumps. Loss rate while circulating ~60 bph, drilling ~125 bph. POOH from 403', racking back HWDP, DC, and MWD. Break out bit. Observe two nozzles plugged, all three cones jammed with gravel, two cutters with 1/3-1/2 broken, one cone dragged. 1-2-BT-N-E-I-PN-PP. M/U new bit to motor. RIH with MWD tools from derrick. Measure RFO 135.46°. RIH with flex collars, HWDP and Jars to 370'. Wash down from 370' to 403' at 400 gpm, 625 psi, 30 rpms 1300 ft-lbs. Cont. drilling 12-1/4" hole from 403' to 413' at 400 gpm, 625 psi. Drag chain packed off and chain fell off the gear. Rack back one stand. Use supersucker to clear out drag chain. reconnect chain to gear. Cont. drilling 12-1/4" hole from 413' to 525' (total=112', AROP 75 fph) at 425 gpm, 705 psi, WOB 5- 10K. 100% sliding. ECD 9.75 ppg w/ 8.95 ppg mud. P/U 62K, S/O 62K, ROT 58K. Continuously jetting flow line, pump down bleeder as needed. Observe loss rate decrease down to 10-15 bph, observe clay sand and some gravel over the shakers. Daily disposal to G&I: 228 bbls, total=228 bbls. Daily H2O from Lake 2: 450 bbls, total 1130 bbls. Daily losses 505 bbls, total 505 bbls. Distance to WP09: 0.22', 0.13' high, 0.18' left. 4/8/2022 Cont. drilling 12-1/4" hole from 525' to 1034' (total=509', AROP 85 fph) at 450 gpm, 1050 psi, 40 rpms, 3-4Kft-lbs, WOB 5-10K. ECD 9.5 ppg w/ 8.9ppg mud. P/U 62K, S/O 62K, ROT 58K. Jetting and pumping down flow line as needed. Last GWD survey 918'. Cont. drilling 12-1/4" hole from 1034' to 1480' (total=446', AROP 75 fph) at 450 gpm, 1070 psi, 60 rpms, 5-6Kft-lbs, WOB 5-10K. ECD 9.82 ppg w/ 9.1ppg mud. Max Gas 21u. P/U 79K, S/O 77K, ROT 76K. Jetting and pumping down flow line as needed. Cont. drilling 12-1/4" hole from 1480' to 1859' (total=379', AROP 63 fph) at 450 gpm, 1421 psi, 60 rpms, 6-7Kft-lbs, WOB 5-20K. ECD 9.97 ppg w/ 9.35ppg mud. Max gas 20u. P/U 92K, S/O 74K, ROT 76K. Jetting and pumping down flow line as needed. Start backreaming full stands. Cont. drilling 12-1/4" hole from 1859' to 2560' (total=701', AROP 117 fph) at 500 gpm, 1455 psi, 80 rpms, 6Kft-lbs, WOB 5-8K. ECD 10.1 ppg w/ 9.5ppg mud. Max gas 21u. P/U 98K, S/O 74K, ROT 86K. Jetting and pumping down flow line as needed. Backream full stands. Base of permafrost logged at 2164'. Daily disposal to G&I: 798 bbls, total= 1026 bbls. Daily H2O from Lake 2: 580 bbls, total 1610 bbls. Daily losses 230 bbls, total 735 bbls. Distance to WP09: 47.34', 46.93' Low, 6.21' Right. 4/9/2022 Cont. drilling 12-1/4" hole from 2560' to 3196' (total=636', AROP 106 fph) 500 gpm, 1430 psi, 80 rpms, 7Kft-lbs, WOB 3-8K. ECD 10.3 ppg w/ 9.5ppg mud. Max gas 45u. P/U 114K, S/O 78K, ROT 89K. Backream full stands. At 2805' shakers unloaded with thick mud/cuttings. Reduce flow to 400 gpm and CBUx2 Cont. drilling 12-1/4" hole from 3196' to 3770' (total=574', AROP 96 fph) at 500 gpm, 1451 psi, 80 rpms, 7-11Kft-lbs, WOB 6-12K. ECD 10.3 ppg w/ 9.5ppg mud. P/U 120K, S/O 77K, ROT 94K. Jetting and pumping down flow line as needed. Backream full stands. Cont. drilling 12-1/4" hole from 3770' to 4276' (total=506', AROP 84 fph) at 500 gpm, 1550 psi, 80 rpms, 7-11Kft-lbs, WOB 6-12K. ECD 10.3 ppg w/ 9.55ppg mud. Max gas 141u. P/U 132K, S/O 78K, ROT 103. Jetting and pumping down flow line as needed. Backream full stands. Cont. drilling 12-1/4" hole from 4276' to 4861' (total=585', AROP 98 fph) at 500 gpm, 1660 psi, 80 rpms, 10-11Kft-lbs, WOB 3-8K. ECD 10.24 ppg w/ 9.55ppg mud. Max gas 230u. P/U 139K, S/O 86K, ROT 105. Jetting and pumping down flow line as needed. Backream full stands. Daily disposal to G&I: 1083 bbls, total= 2109 bbls. Daily H2O from Lake 2: 1160 bbls, total 2770 bbls. Daily losses 0 bbls, total 735 bbls. Distance to WP09: 16.09', 15.58' high, 3.99' right. 50-029-23711-00-00API #: Well Name: Field: County/State: PBW M-201 Prudhoe Bay West Hilcorp Energy Company Composite Report , Alaska 4/7/2022Spud Date: 4/10/2022 Cont. drilling 12-1/4" hole from 4861' to 5293' (total=432', AROP 72 fph) at 500 gpm, 1530 psi, 80 rpms, 12-13Kft-lbs, WOB 3-8K. ECD 10.24 ppg w/ 9.55ppg mud. Max gas 942u. P/U 174K, S/O 98K, ROT 115. Jetting and pumping down flow line as needed. Backream full stands. At 5105' observe oil at shakers, blinding them off. Reduce flow to 400 gpm and screen down to 120's. Cont. drilling 12-1/4" hole from 5293' to 5740' (total=447', AROP 75 fph) at 400 gpm, 1350 psi, 80 rpms, 14-16Kft-lbs, WOB 4-13K. ECD 10.32 ppg w/ 9.55ppg mud. Max gas 523u. P/U 169K, S/O 86K, ROT 110. Jetting and pumping down flow line as needed. Backream full stands. Cont. drilling 12-1/4" hole from 5740' to 6120' (total=380', AROP 64 fph) at 400-500 gpm, 1457 psi, 80 rpms, 16-20Kft-lbs, WOB 5-12K. ECD 10.38 ppg w/ 9.55ppg mud. Max gas 531u. P/U 176K, S/O 89K, ROT 119K. Jetting and pumping down flow line as needed. Backream full stands. Cont. drilling 12-1/4" hole from 6120' to 6498' (total=378', AROP 63 fph) at 550 gpm, 2250 psi, 80 rpms, 16-20Kft-lbs, WOB 12-20K. ECD 10.84 ppg w/ 9.55ppg mud. Max gas 382u. P/U 188K, S/O 90K, ROT 122K. Jetting and pumping down flow line as needed. Backream full stands. Daily disposal to G&I: 1140 bbls, total= 3249 bbls. Daily H2O from Lake 2: 830 bbls, total 3600 bbls. Daily losses 0 bbls, total 735 bbls. Distance to WP09: 12.95', 11.3' high, 6.33' right. 4/11/2022 Cont. drilling 12-1/4" hole from 6498' to 6946' (total=448', AROP 75 fph) at 550 gpm, 2105 psi, 80 rpms, 19-20Kft-lbs, WOB 12-20K. ECD 10.24 ppg w/ 9.6ppg mud. Max gas 412u. P/U 202K, S/O 91K, ROT 130K. Jetting and pumping down flow line as needed. Backream full stands. Cont. drilling 12-1/4" hole from 6946' to 7073' (total=127', AROP 64 fph) at 550 gpm, 2250 psi, 60-80 rpms, 19-22Kft-lbs, WOB 12-20K. ECD 10.32 ppg w/ 9.55ppg mud. Max gas 577u. P/U 208K, S/O 92K, ROT 132K. Slide as needed for 4°/100' build. Backream full stands. Service rig: troubleshoot loss of draw works power. Change out DSU inverter in sub drive house. Circulate at 250-350 gpm, 908 psi. Cont. drilling 12-1/4" hole from 7073' to 7391' (total=318', AROP 40 fph) at 550 gpm, 2150 psi, 80 rpms, 19-20Kft- lbs, WOB 12-17K. ECD 10.12 ppg w/ 9.5ppg mud. Max gas 419u. P/U 209K, S/O 92K, ROT 134K. Slide as needed for 4°/100' build. Backream full stands. Cont. drilling 12-1/4" hole from 7391' to 7691' (total=300', AROP 50 fph) at 525 gpm, 2055 psi, 80 rpms, 19-20Kft-lbs, WOB 5-20K. ECD 10.1 ppg w/ 9.5ppg mud. Max gas 130u. P/U 216K, S/O 88K, ROT 128K. Slide as needed for 4°/100' build. Backream full stands. Daily disposal to G&I: 1321 bbls, total= 4570 bbls. Daily H2O from Lake 2: 1160 bbls, total 4760 bbls. Daily losses 49 bbls, total 784 bbls. Distance to WP09: 13', 12.76' high, 2.86' right. 4/12/2022 Cont. drilling 12-1/4" hole from 7691' to casing point at 7790' (total=99', AROP 50 fph) at 550 gpm, 2135 psi, 80 rpms, 19-21Kft-lbs, WOB 8-12K. ECD 10.2 ppg w/ 9.5ppg mud. Max gas 576u. P/U 216K, S/O 88K, ROT 128K. Slide as needed for 4°/100' build. Backream full stands. Obtain final survey. BROOH from 7790' to 7647'. Pump high vis sweep (on time, 10% increase) around plus two bottoms up at 550 gpm, 2010psi, 60 rpms, 19-21Kft-lbs, reciprocating pipe. Rack stand back ever bottoms up. Max gas 593u, ECD 10.2 ppg. P/U 201K, S/O 88K, ROTW 127K RIH on elevators to 7790', no issues. L/D single. Downlink to put GWD in out-run mode. BROOH from 7790' to 7620' at 550 gpm, 1970 psi, 80 rpms, 20Kft-lbs, ECD 9.96 ppg with 9.5 ppg mud. P/U 198K, S/O 85K, ROT 125K. Cont. to BROOH from 7620' to 5100' at 520 gpm, 1600 psi, 60 rpms, 14-16Kft-lbs, ECD 10.2 ppg with 9.5 ppg mud. Max gas 256u. P/U 175K, S/O 92K, ROT 111K. Pulling 15-30 fpm as hole dictates. Cont. to BROOH from 5100' to 2850' at 545 gpm, 1470 psi, 80 rpms, 8-13Kft-lbs, ECD 10.08 ppg with 9.5 ppg mud. Max Gas 117u. P/U 115K, S/O 75K, ROT 85K. Pulling 15-30 fpm as hole dictates. Slight packoffs and erratic tq from 4430'-4410', 3511'-3590' Cont BROOH from 2850' to 1010' at 545 gpm, 1190 psi, 80 rpms, 3-4Kft-lbs, ECD 9.8 ppg, max gas 48u. P/U 91K, S/O 64K, ROT 72K. Pull 2-25fpm as hole dictates. Slow pulling speed 2 stands prior to permafrost and obtain 2 x BU. Slow pulling speed from 2050' - 1770' due to erratic TQ. At 1290' observe ECD's climb to 10.77 ppg and shakers begin to unload with sand and clay. Reduce pulling speed to 2 fpm. Observe shakers clean up after 2.5x bottoms up and ECD's drop to 9.8 ppg. Daily disposal to G&I: 979 bbls, total= 5549 bbls. Daily H2O from Lake 2: 1160 bbls, total 5920 bbls. Daily losses 120 bbls, total 904 bbls. Distance to WP09: 0.87', 0.15' low, 0.86' right. 4/13/2022 BROOH from 1010' to 719' MD, GPM 475, PSI 930, RPM 80, TQ 3K, ECD 9.5, Max Gas 45u, P/U 80K, SO65K, Rot 68K. Pull 2-25 fpm as hole dictates. See hole unload @ 955 to 800' pulling 2 fpm until clean. Lost 21 bbls during Back reaming. TOOH on elevators from 719' to 161' racking back 9 stds HWDP and Jars. P/U 74K, SO 64K PJSM, L/D BHA, Break and L/D Bit and Mtr. Bit graded 3-4-BT-A-X-2-CT-TD. Clean and Clear Rig Floor. PJSM, Stage and rig up 9 5/8" Casing running equipment. Verify pipe count to Tally. Blow down CMT Line and finish casing running check list. Static loss rate @ 1 bph. PJSM P/U M/U 9.625" Shoe Track 125.91', BakerLoc and check floats, good. Drop ByPass plug as per HES rep onsite. Cont. RIH W/ 9.625" L-80 40# TXP BTC to 1,752' MD. Encountered tight spot at 1,732' MD work through W/ 5 bpm 150 psi 8-9 rpm Trq stall set 14k using string weight. P/U 82k SLK 65k ROT80k. Lost 14 bbls. Max Gas 64u. Trq TXP BTC 21k. Fill every 5 jnts, break Circ every 15 jnts. Cont working tight spots F/ 1,752’ to 1,806’ MD parameters 5 bpm 150 psi 8 rpm Trq stall set at 15k. Encountering dynamic losses 20-30 bph Observed sand & clay with slight gravel and wood at shakers. Cont RIH working intermittent tight spots F/ 1,806’ to 2,143’ MD same parameters. Run speed 10-30 fpm. P/U 106k SLK 75k ROT 84k. Max Gas 22u. Lost 86 bbls. Fill every 5 jnts, break Circ every 15 jnts. CBU Rot Rec F/ 2,143’ to 2,223’ MD. Stage pumps up to 6 bpm 125 psi 8 rpm Trq 11-15k Max Gas 21u. P/U 122k SLK 74k ROT 81k. Dynamic loss rate 9 bph. Cont RIH working intermittent tight spots F/ 2,223’ to 2,998’ MD. 5 bpm 150 psi 8 rpm Trq stall 15k. Trq TXP BTC 21k. Run speed 10-40 fpm. P/U 150k SLK 72k ROT 72k. Max Gas 21u. Lost 12 bbls. Cont RIH working intermittent tight spots F/ 2,998’ to 3,812’ MD. 5 bpm 150 psi 8 rpm Trq stall 15k. Trq TXP BTC 21k. Run speed as hole dictates. RIH on elevators F/ 3,812’ to 4,551’ MD. Run speed 35-40 fpm. P/U 210k SLK 96k ROT 86k. Max Gas 18u. Lost 16.5 bbls. Fill every 5 jnts, break Circ 15 jnts CBU over 3 jnts F 4,551’ to 4,670’ MD. Stage up to 6 bpm 200 PSI F/O 34% P/U 218k SLK 100k Max Gas 18u. Dynamic loss rate 7-8 bph. Cont. RIH W/ 9.625" L-80 40# TXP BTC on elevators F/ 4,670’ to 5,200’ MD. Run speed 35-40 fpm. P/U 265k SLK 95k. Max Gas 16u. Lost 4 bbls. Trq TXP BTC 21k. Fill every 5 jnts, break Circ every 15 jnts. Daily disposal to G&I: 661 bbls, total= 6210 bbls. Daily H2O from Lake 2: 410 bbls, total 6330 bbls. Daily losses 160 bbls, total 1064 bbls. Distance to WP09: 0.87', 0.15' low, 0.86' right. Cont. drilling 12-1/4" hole from 7691' to casing point at 7790' ( 4/14/2022 Continue RIH on elevators w/ 9 5/8", L-80, 40# TXP BTC from 5200' to 5402' TQ BTC t 21K, Run Speed 35-40 fpm, P/U 300K, SO 99K, Max Gas 16u, lost 11 bbls, fill every 5 jts and break circulation back to pits every 15 jts. MU ESCMTR after Jt 133. RIH with 47# Vam Top Csg f/5404 to 6505'. Tq to 31K. RIH while CBU over 3 jts from 6505' to 6700'(End of Tangent Section) staging pumps to 6 BPM/290 PSI, 7 BPH dynamic loss rate. Continue RIH on elevators w/ 9 5/8", L-80, 47# Vam Top Csg from 6700' to 7026' TQ BTC t 31K, Run Speed 35-40 fpm, P/U N/A, SO 118K, lost 3.5 bbls, fill every 5 jts and break circulation back to pits every 15 jts. Continue RIH on elevators w/ 9 5/8", L-80, 47# Vam Top Csg from 6700' to 7780' TQ BTC t 31K, Run Speed 10-25 fpm, P/U N/A, SO 112K, lost 24.2 bbls, fill every 5 jts and break circulation back to pits every 15 jts. Wash last 2 jts to bottom. @ 7780' MD Stage pump to 6BPM/320 PSI, attempt to Rot pipe w/ TQ Limiter set @ 18K, no Rotation. Attempt to Recip pipe with 380K P/U and no break over. Circulate and condition mud for cement job. No losses while circulating. Blow Down Top Drive and R/U Cement line to Volant. Contiune to circulate through the cement line while prepping pits and R/U Cementers. PJSM, Wet lines w/ 5 bbls H2O (HES) and P/T low kick out 1,130/ 4,601 psi high. Pump 1st stage cement job as follows: 60 bbls 10 ppg Tuned spacer w/ 4# red dye & 5 ppb poly flake (1st 10 bbls). Release F/ Volant & drop bypass plug. HES pump Lead Type I/II cmt 321 bbls (769 sx) 12 ppg, 2.347 yld, 4.5 bpm, ICP 380 psi FCP 277 PSI. Tail Type I/II cmt (Wet at 20:28) 87 bbls (400 sx)15.8 ppg, 1.156 yld, 3.45 bpm, ICP 367 psi FCP 502 PSI. Release F/ Volant & drop shutoff plug. Displace w/ 20 bbls H2O (HES) 5.7 bpm 380 PSI then turn over to rig. Rig disp w/ 371.7 bbls 9.5 ppg spud mud, 6 bpm ICP 259psi FCP 545 psi. HES disp 72 bbls 9.4 ppg tuned spacer, 4.5 bpm ICP 590 psi FCP 639 psi. Rig disp 114.3 bbls (111.4 bbls Calc) 9.5# spud mud 4 bpm, ICP 754 psi FCP 1,093 psi. Reduced rate last 10 bbls to 3 bpm, FCP 1,080 PSI. Bump plug Press up to 1,630 psi. Held pressure for 5 minutes, check floats - good. CIP 00:25 hrs. Full returns throughout job. Pump at 3 bpm Press up to 2,730 psi ES cementer opened slowly and Press bled down to 1,000 PSI. Increase pumps to 4 bpm ICP 1,395 FCP 410 psi after 2 BU. Increased pump rate to 5 bpm 540 psi.. At ~500 STKS (31 bbls) away saw clabbered up mud, started dumping at 3,700 stks (229 bbls) of contaminated cement. Dumped a total of 403 bbls W/ 102 bbls contaminated cement at surface. After 5 BU shut down and flush stack W/ Black Water. Disconnect knife valve and function Annular multiple times. Re Connect knife valve. SIMOPS Clean suction screen MP #1. Haul off dumped mud and prep for 2nd stage. Stage pumps up 5 bpm 495 psi CBU total 4X. SIMOPS Prep pits and truck for 2nd stage cement job. Daily disposal to G&I: 114 bbls, total= 6324 bbls. Daily H2O from Lake 2: 960 bbls, total 7290 bbls. Daily losses 69 bbls, total 1133 bbls. 4/15/2022 Continue to circulate through stage tool @ 2355', while WOC and prepping for 2nd stage cement. 6 BPM/530 PSI. PJSM, Pump 2nd stage cmt job. Lineup to cmtrs, wet lines w/ 5 bbls FW. Mix/Pump 60 bbls 10# Tuned Spacer III w/ 4# red dye first 10 bbls, 3.5 BPM, 230 psi. Mix and pump 461 sxs (280 bbls)( 2.883 yld) ArcticCem Lead Cement at 10.7 ppg. Pump Lead until seen @ Surface. See Spacer @ 210 bbls into Lead. See Green Cmt 235 bbls into Lead. (Calculated STS volume =328 bbls). Go into Tail CMT. Mix and pump 267 sxs (56.5 bbls)(1.169 yld) Type I/II Tail Cement at 15.8 ppg. Drop closing plug. Displace cmt w/ 20 bbls FW f/ Cmt Unit. Rig 150 bbls (152.8 calculated)(2 bbls under) 9.5ppg mud, 6bpm/ 975psi, FCP 563 psi @ 3 bpm last 15 bbls. Bumped and psi up to 1880 psi (ES shift @ 1570 psi) Held 5 min. CIP @ 12:15. Full Returns through out job. Circulated 212 bbls of Green CMT to surface. Drain Stack, Flush stack with black water cycle bag x3, R/D CMT line and Volant, N/D Diverter sections, Loosen speed head and suspend stack. Set 9.625" emergency slips W/ 40k as per Vault rep onsite. Cut 9.625" Csg (29.39') Cut 9.625" Csg (29.39'). Reland Stack and Johnny whack stack and jet flowline with black water. Blow Down all Surface Equipment. Continue to N/D Diverter components. Set Stack Back, remove Diverter Tee, and adapt and set aside in Cellar. Welder Dress Csg Stub. Simops: Clean pits, suction manifold, and screen on both pumps. PJSM Install RCD studs on top of Annular. P/U RCD and suspend W/ tugger. P/U BOP and move off pedestal. Install RCD to Annular. Unhook tugger and set BOP beck on pedestal. PJSM P/U wellhead and install on 9.625" csg. Set test plug. Vault rep energize seals and test 500 psi 5 min, 3,800 psi 10 min, good. PJSM Install DSA and BOP on wellhead. Secure chains and buckle's. Install drip pan, choke & kill lines. Install 4" MPD hard lines. M/U test sub to TD, flood MPD lines. Test MPD 250/ 1,250 psi good. SIMOPS Cont cleaning pits, Derrick inspection. Obtain RKB. PJSM Break in UPR's VBR's (4.5" X 7") W/ 4.5" & 7" test jnts as per procedure. P/U M/U 5" test jnt M/U pump in sub, 5" TIW #1 and 5" Dart Valve Flood and purge air F/ manifold and lines. Shell test to 3,000 psi, good. PJSM Test UPR’s (4.5” X 7”) W/ 7” test jnt 250/ 3000 psi 5 min. Cont BOPE test W/ 5" to 250 PSI low and 3,000 PSI high for 5 Min. Tested Choke Manifold 1-15, 5" Dart, 1 ea 5" TIW, Upper and lower IBOP, Mez Kill, HCR (F/P) and manual Kill, Super Choke (F/P) and manual to 1,600 PSI, Upper and lower VRB Rams (2.875" X 5.5"). Witnessed waived by AOGCC Rep Guy Cook. Daily disposal to G&I: 2101 bbls, total= 8425 bbls. Daily H2O from Lake 2: 550 bbls, total 7840 bbls. Daily losses 0 bbls. Surface loss total 1133 bbls. 4/16/2022 Continue Testing BOPE. Witness waived by Guy Cook. Test to 250/3000 psi 5 min ea. Test on 4 1/2", 5", and 7" pipe size. Test Gas Alarms. Perform Draw Down: Start 3050 psi, After close: 1500 Psi, 200 psi build: 25 sec, Full recovery: 93 sec. N2: 6 @ 2366 psi Ave. PJSM, Pull test plug. L/D test jt. Blow down choke and kill line. Clean and clear rig floor. Install 9" ID Wear Bushing. PJSM, Stage all BHA components on rig floor for Clean out run. Service Rig. Inspect welds on Top Drive Cradle and found a 1.5" crack starting on upper DS of Cradle. P/U 8.5" Bit, XR-CPS (TFA 0.9419) 1.5° StrataForce Lobe 6.7- 6 stg Motor and HWDP w/ SLB Jars (Hydra) to 589' PU and single in hole with 5" DP from 589' to 1720' MD. Drift w/3.125" PUW 69K, SOW 60K Continue to PU and single in hole with 5" DP from 1720' to 2300'' MD. Drift w/3.125" PUW 88K, SOW 64K M/U Top Drive, fill pipe, Wash down from 2300' and Tag Top of ESCMTR @ 2356'. Drill ESCMTR, 450 GPM/730 PSi, 30 RPM, 6K TQ, 5-7 WOB. PUW 88, SOW 64K, Rot 76K. Pas through with and without pumps. Cont single in hole W/ 5" 19.5# S-135 NC-50 F/ 2,370' to 5,039' MD. Total 140 jnts. Drift 3.125" OD. P/U 165k SLK 68k. PJSM Fill string. Cont RIH F/ Derrick 5" D.P. F/ 5,039' to 7,391l MD. Wash down to 7,645' MD. P/U 225k SLK 82k. Encountered cement stringers at 7,395'. Cont wash and ream F/ 7,391' to 7,642' MD 450 gpm 780 psi 5-30 rpm Trq stall set at 18k. Circ surf to surf. Rot Rec F/ 7,642' to 7,581' MD. Dumped clabber mud and cured cement at BU. Adjusting flow rates due to drag chain. 450 gpm 780 psi 10-30 rpm Trq stall set at 21.5k due to high trq stalls. P/U 213k SLK 82k ROT 130k. Adding lube due to Trq. PJSM M/U TIW, headpin and 1502's. R/U test Equip. Circ through mud cross and purge out air. Shut UPR. Press up and found sacrificial Mezz kill valve leaking at ~300 psi. Inspect & grease valve body. Test 9.625" Csg to 2,500 psi for 30 min, good. Pump 4.6 bbl, bled 4.5 bbl. R/D test Equip. PJSM Drill F/ 7,642' to 7,680' MD. Tag BFA on depth at 7,657' MD. Encountering high Trq stall and bit stall W/ Trq limiter set at 22.4k. Adjusted parameters and added a total of 4 drum of lube. Trq smoothing out while drill shoe track. 400 gpm 890 psi 30 rpm Trq 19-22k. Saw shut off rubber at surface. Good cement. Cont drill shoe track and 20' of new hole F/ 7,680" to 7,810' MD. FC (7,696') & shoe (7,781') on depth. 400 gpm 1,220 psi 30 rpm Trq 15k WOB 3-9k P/U 177k SLK 84k ROT 128k. Begin displacing 9.5 ppg Spud Mud W/ 9.5 ppg BaraDril N during during rat hole. Work through shoe multiple times, no issue. Cont Displacing to 9.5 ppg BaraDil N 4% Lubes 450 gpm 850 psi 30 rpm Trq 14k P/U 198k SLK 94k ROT 125k. SPR. PJSM Shut UPR and purge air through manifold and lines. Perform FIT 12 EMW W/ 9.5 ppg MW 7,781' MD 5,178' TVD 674 psi. Pump 1.7 bbl bled 1.4 bbl. Blow down lines. Monitor well 10 min static. Send 9.625" Csg & FIT digital copy to AOGCC for approval to drill ahead. PJSM POOH rack 5" D.P. F/ 7,781' to 7,509' MD ensure not swabbing. Pump dry job. Blow down. Cont POOH rack 5" D.P. F/ 7,509' to 4,495' MD. P/U 142k SLK 87k. No losses. Daily disposal to G&I: 513 bbls, total= 8938 bbls. Daily H2O from Lake 2: 200 bbls, total 8040 bbls. Daily losses 0 bbls. Surface loss total 1133 bbls. . Wash last 2 jts to bottom. @ 7780' MD Test 9.625" Csg to 2,500 psi for 30 min, good. Perform FIT 12 EMW W/ 9.5 ppg 4/17/2022 Cont POOH F/ 4,495' to 589' MD. P/U 60k SLK 60k. No losses. PJSM Rack back 5" HWDP & jar. L/D 14 jnts 5" HWDP. L/D 1.5° Motor and 8.5" Bit. Bit Grade 1-1- WT-A-E-I-N-BHA. Clean and clear rig floor. PJSM P/U X/O's, subs and components for BHA. Prep rig floor for making up BHA. PJSM P/U M/U 8.5" Hycalog TK 66 PDC (TFA 0.7777), 8.5" Hycalog NRP, 7600 GeoPilot 25KSI, 6.75" ADR, 8.375" ILS, 6.75" DGR, 6.75" PWD, 6.75" DM, 6.75" ALD, 6.75" CTN, 6.75" TM HOC & 8.375" ILS. . Plug in and download MWD. Cont M/U 6.75" NM FS (Non Ported/ Plunger) 6.75" NM FC, 6.75" NM FS (Non Ported/ Plunger), 6.75" NM FC, 2ea 5" HWDP, 6.5" SLB Hydra Jar & 1 ea 5" HWDP. Total length 310.84'. PJSM Grease crown sheave, blocks, top drive & iron roughneck. PJSM Single in hole BHA 4 W/ 5" 19.5# S-135 NC50 (234 jnts) F310' to 7,743' MD. Drift 3.125" OD. Follow break in procedure for new D.P. At 2,654' MD break in GeoPilot and pulse test MWD at 450 gpm 995 psi. Blow down TD. P/U 154k SLK 94k. PJSM Install RCD bearing as per Beyond rep onsite. Loosen grey clamp. Pull trip nipple. Drain stack. Install penetrating cone and install RCD bearing on stand. Adjust BOP to ODS and tighten turnbuckles. Set RCD bearing and tighten grey clamp. Check for leaks, good. 400 gpm 1,150 psi. PJSM Cut and slip drilling line. ACCUM TM 899. Cut 11 wraps (69') 3,629' left on spool. Install guard and Trq deadman. Set TD limits. Grease drawworks spline EAM and check brake gap, good. PJSM Service rig. Grease crown, blocks, TD, spinners, iron roughneck & stand pipe manifold. Perform EAM crown and block wobble, good. Open coffin on TD clean up residual oil and found 2 loose Hydraulic hoses, tighten. Unhang blocks. Wash down F/ 7,743' to 7,804' MD 400 gpm/ mpd 392, 1,090 psi, 40 rpm, TRQ 11-12k,ECD 10.18. P/U 158l SLK 97k ROT 128k. Send down links prior to exiting shoe to calibrate MWD depth. No issue going through shoe. SPR's. Drill 8.5" Hole F/7,820 to 7,997' MD (5,173' TVD) Total 177' (AROP 70.8’) 500 gpm/ mpd 489, 1,660 psi, 100 rpm, TRQ on 15-17k, TRQ off 15-16k, wob 5-7k. ECD 10.47 Max Gas 41u. P/U 180k, SLK 90k, ROT 120k. MPD 100%. Back ream 60'. Distance to WP09: 1.51’, 1.45’ Low 0.4’ Left. Daily disposal to G&I: 882 bbls, total= 9820 bbls. Daily H2O from Lake 2: 270 bbls, total 8310 bbls. Daily losses 0 bbls. Surface loss total 1133 bbls. 4/18/2022 Drill 8.5" Hole F/7,997 to 8,567' MD (5,158' TVD) Total 570' (AROP 95’) 500 gpm/ mpd 488, 1,745 psi, 100 rpm, TRQ on 16-17k, TRQ off 15-16k, wob 6-10k. ECD 10.6 Max Gas 115u. P/U 178k, SLK 78k, ROT 120k. MPD 100%. Back ream 60'. Drill 8.5" Hole F/8,567 to 9139' MD (5160' TVD) Total 572' (AROP 95.3’) 500 gpm/ mpd 492, 1,890 psi, 120 rpm, TRQ on 17.5k, TRQ off 16-18k, wob 3-10k. ECD 10.95, MW in/out 9.4+/9.5, Max Gas 843u. P/U 177k, SLK 74k, ROT 118k. MPD Hold 140 psi Drilling/100 connections. Back ream 60'. Drill 8.5" Hole F/9,139' to 9,809' MD (5,181' TVD) Total 670' (AROP 111.6') 500 gpm/ mpd 490, 1,930 psi, 120 rpm, TRQ on 19.5k, TRQ off 16-18k, wob 7-9k. ECD 11.05, MW in/out 9.5/9.55, Max Gas 921u. P/U 178k, SLK 72k, ROT 118k. MPD Hold 140 psi dynamic/80 psi static. Back ream 60'. Using MPD to control gas at shakers. Drill 8.5" Hole F/9,809' to 10,410' MD (5,190' TVD) Total 601' (AROP 100.2') 500 gpm/ mpd 490, 2,050 psi, 120 rpm, TRQ on 20-21k, TRQ off 18-19k, wob 5-9k. ECD 11.14, MW in/out 9.5, Max Gas 758u. P/U 176k, SLK 72k, ROT 115k. MPD Hold 140 psi dynamic/80-100 psi static. Back ream 60'. Distance to WP09: 17.16’, 16.60’ Low 4.36’ Left 20 concretions for a total thickness of 72' ( 2.8% of the lateral). Footage Oba Sand 2,467'. Daily disposal to G&I: 510 bbls, total= 10330 bbls. Daily H2O from Lake 2: 680 bbls, total 8990 bbls. Daily Metal: 2 Total 2. Daily losses 0 bbls. Surface loss total 1133 bbls. 4/19/2022 Drill 8.5" Hole F/10,410' to 10,983' MD (5,188' TVD) Total 573' (AROP 95.5') 500 gpm/ mpd 490, 2,120 psi, 120 rpm, TRQ on 17-18k, TRQ off 17-18k, wob 5-10k. ECD 11.12, MW in/out 9.5, Max Gas 581u. P/U 167k, SLK 77k, ROT 115k. MPD Hold 140 psi dynamic/80-100 psi static. Back ream 60'. Drill 8.5" Hole F/10,983' to 11,745' MD (5,179' TVD) Total 762' (AROP 127') 500 gpm/ mpd 495, 2,170 psi, 120 rpm, TRQ on 19k, TRQ off 16k, wob 5-8k. ECD 11.21, MW in/out 9.4+, Max Gas 869u. P/U 166k, SLK 72k, ROT 116k. MPD Hold 140 psi dynamic/80-100 psi static. Back ream 60'. Drill 8.5" Hole F/11,745' to 12,443' MD (5,184' TVD) Total 698' (AROP 116.4') 500 gpm/ mpd 499, 2,230 psi, 120 rpm, TRQ on 16-18k, TRQ off 16k, wob 8-10k. ECD 11.22, MW in/out 9.4+/9.5, Max Gas 661u. P/U 167k, SLK 72k, ROT 116k. MPD Hold 130-140 psi dynamic/80-100 psi static. Back ream 60'. Encountered Fault #1 at 12,113' MD (11' DTS) causing exit above target OBa-Sand into OA-Clay with minimal losses. Reentered OBa sand at 12,140' MD. Drill 8.5" Hole F/12,443' to 12,980' MD (5,165' TVD) Total 537' (AROP 89.5') 500 gpm/ mpd 487, 2,360 psi, 120 rpm, TRQ on 22-23k, TRQ off 19-20k, wob 8-10k. ECD 11.41, MW in/out 9.5, Max Gas 564u. P/U 175k, SLK 57k, ROT 111k. MPD Hold 130-140 psi dynamic/80-100 psi static. Back ream 60'. Distance to WP09: 14.16’, 7.53’ High 11.99’ Left Fault #1 12,113' MD Throw 11' DTS. 30 concretions for a total thickness of 107' ( 3.6% of the lateral hole section). Footage Oba Sand 4,946'. Footage out: 87'. Daily disposal to G&I: 741 bbls, total= 11071 bbls. Daily H2O from Lake 2: 1200 bbls, total 10190 bbls. Daily Metal: 0.5 Total 2.5. Daily losses 0 bbls. Surface loss total 1133 bbls. 4/20/2022 Drill 8.5" Hole F/12,980' to 13,588' MD (5,181' TVD) Total 608' (AROP 101') 500 gpm/ mpd 487, 2,460 psi, 120 rpm, TRQ on 22-23k, TRQ off 19-20k, wob 8-10k. ECD 11.4, MW in/out 9.5, Max Gas 649u. P/U 167k, SLK 59k, ROT 111k. MPD Hold 80-100 psi dynamic/80-100 psi static. Back ream 60'. Re-interpreted fault at 12,140' as 20' DTN, putting the wellbore in OA sands. Drill 8.5" Hole F/13,588' to 14,244' MD (5,199' TVD) Total 656' (AROP 109') 500 gpm/ mpd 486, 2,460 psi, 120 rpm, TRQ on 21k, TRQ off 18k, wob 6-9k. ECD 11.39, MW in/out 9.5, Max Gas 827u. P/U 174k, SLK 56k, ROT 114k. MPD Hold 80 psi dynamic/80 psi static. Back ream 60'. Re-acquired Oba sands at 13,700' MD. Close approach S-41 at 13,150' MD CF .68 CC 52.14', no magnetic interference. Drill 8.5" Hole F/14,244' to 14,798' MD (5,202' TVD) Total 544' (AROP 90.7') 500 gpm/ mpd 486, 2,540 psi, 120 rpm, TRQ on 22-25k, TRQ off 22k, wob 8-10k. ECD 11.39, MW in/out 9.5, Max Gas 786u. P/U 182k, SLK 48k, ROT 114k. MPD Hold 60 psi dynamic/85 psi static. Back ream 60'. Drill 8.5" Hole F/14,798' to 15,177' MD (5,206' TVD) Total 379' (AROP 126.4') 500 gpm/ mpd 484, 2,625 psi, 120 rpm, TRQ on 22-25k, TRQ off 22-23k, wob 6-10k. ECD 11.55, MW in/out 9.5, Max Gas 758u. P/U 167k, SLK 35k, ROT 111k. MPD 100% dynamic/80-90 psi static. Back ream 60'. Lost slack Wt at 14,862' MD. PJSM C/O Swab, Liner & wear plat on MP# 1 Pod 2. ROT Rec F/ 15,177' to 15,115' MD 290 gpm/ mpd 277, 1,190 psi, 45 rpm, TRQ 22-23k. ECD 10.88, Max Gas 638u. Drill 8.5" Hole F/15,177' to 15,363' MD (5,211' TVD) Total 186' (AROP 93') 480 gpm/ mpd 463, 2,450 psi, 110 rpm, TRQ on 24-26k, TRQ off 22-24k, wob 6-10k. ECD 11.42, MW in/out 9.5, Max Gas 728u. P/U 167k, SLK 35k, ROT 111k. MPD 100% open dynamic/60-80 psi static. Back ream 60'. Distance to WP09: 8.9’, 8.8’ Low 1.32’ Right Fault #1 12,140' MD Throw 20' DTN. 47 concretions for a total thickness of 350' (4.7% of the lateral hole section). Footage Oba Sand 5,815' Footage out: 1647' Total 7,462'. Daily disposal to G&I: 570 bbls, total= 11641 bbls. Daily H2O from Lake 2: 960 bbls, total 11150 bbls. Daily Metal: 0 Total 2.5. Daily losses 0 bbls. Surface loss total 1133 bbls. 4/21/2022 Drill 8.5" Hole F/15,363' to 16,004' MD (5,223' TVD) Total 641' (AROP 107') 500 gpm/ mpd 484, 2,460 psi, 120 rpm, TRQ on 26-28k, TRQ off 24-25k, wob 6-11k. ECD 11.5, MW in/out 9.5, Max Gas 767u. P/U 189k, SLK 35k, ROT 110k. MPD 100% open Back ream 60'. Perform 460 bbls dilution at 15,745' to lower MBT. Observe 300 psi pressure drop, but no decrease in TQ. Drill 8.5" Hole F/16,004' to 16,770' MD (5,239' TVD) Total 766' (AROP 128') 450 gpm/ mpd 440, 2,250 psi, 120 rpm, TRQ on 19-21k, TRQ off 17-18k, wob 5-11k. ECD 11.5, MW in/out 9.5, Max Gas 840u. P/U 190k, SLK 35k, ROT 113k. MPD hold 100 psi to mitigate losses over shakers due to gas. Back ream 60'. Begin additions of Lube 776 at 16,200 up to 0.25% reducing TQ from 26-28Kft-lbs to 19-21Kft-lbs. Drill 8.5" Hole F/16,770' to 17,468' MD (5,250' TVD) Total 698' (AROP 116') 450 gpm/ mpd 430, 2,330 psi, 120 rpm, TRQ on 21-23k, TRQ off 19-20k, wob 5-11k. ECD 11.57, MW in/out 9.5, Max Gas 680u. P/U 195k, SLK 35k, ROT 113k. MPD hold 100 psi to mitigate shakers. Back ream 60'. Drill 8.5" Hole F/17,468' to 18,030' MD (5,263' TVD) Total 562' (AROP 93.7') 450 gpm/ mpd 431, 2,385 psi, 100 rpm, TRQ on 23-24k, TRQ off 22k, wob 4-10k. ECD 11.62, MW in/out 9.55/9.6, Max Gas 665u. P/U 209k, SLK 35k, ROT 111k. MPD 100% open, hold 100 psi dynamic. Back ream 60'. Distance to WP09: 55.07’, 54.56’ Low 7.44’ Right. Fault #1 12,140' MD Throw 20' DTN. 61 concretions for a total thickness of 424' ( 4.7% of the lateral hole section). Footage Oba Sand 8,492' Footage out: 1645' Total 10,137'. Daily disposal to G&I: 1015 bbls, total= 12656 bbls. Daily H2O from Lake 2: 840 bbls, total 11990 bbls. Daily Metal: 0 Total 2.5. Daily losses 0 bbls. Surface loss total 1133 bbls. 4/22/2022 Drill 8.5" Hole F/18,030' to 18,436' MD (5,252' TVD) Total 406' (AROP 68 fph) 450 gpm/ mpd 431, 2,430 psi, 120 rpm, TRQ on 26-27k, TRQ off 24-25k, wob 5- 12k. ECD 11.62, MW in/out 9.55/9.6, Max Gas 504u. P/U 198k, SLK 35k, ROT 110k. MPD 100% open, Back ream 60'. Start building angle, targeting 99° while evaluating interpretation and low resistivity within the formation to confirm wellbore is within Oba sands. Drill 8.5" Hole F/18,436' to 18,744' MD (5199' TVD) Total 308' (AROP 51fph) 500 gpm/ mpd 476, 2930 psi, rpm, 100-120 TRQ on 26-28k, TRQ off 20-222k, wob 7-12k. ECD 11.9 MW in/out 9.55/9.6, Max Gas 575u. P/U 189k, SLK 35k, ROT 106k. MPD 100% open, Back ream 60'. at 18,450 target 103° inclination while continuing to evaluate interpretation. Confirm top of OA- sand at 18,644', continue to drill to 18744' to log top of OA with MWD. Obtain final survey 18,744' MD 5,199' TVD, 102.5° Inc 318.6° Azi Pump 40 bbl 8.9 ppg 37 Vis & 9.5 ppg 240 Vis tandem sweeps. Sweeps on time W/ 0% increase. Perform 4X BU clean up cycle. Rot Rec F/ 18,744' to 18,698' MD 500 gpm/ mpd 479, 2930 psi, rpm,120 TRQ 23-24k, ECD 11.54 MW in/out 9.55/9.6, Max Gas 45u. P/U 168k, SLK 35k ROT 108k Build SAPP train & prep for displacement. PJSM Displace F/ 9.5 ppg Spud Mud to 9.5 ppg QuickDril 3% Lubes. Pump 3X 40 bbl SAPP Pill W/ 20 bbl QuickDril in-between. Chase W/ QuickDril. Rot Rec F/ 18,744’ to 18,698’ MD 330 gpm/ mpd 317, 1,010 psi 120 rpm Trq 24-25k. ECD 10.36. Max Gas 20u. P/U 181k SLK 35k ROT 114k. Monitor well 10 min, static. Shut in MPD, no pressure build. PJSM Drop 2.39” OD rabbit. BROOH F/ 18,744’ to 18,485’ MD 500 gpm/ mpd 458, 1930 psi, 120 rpm, Trq 21-22k, ECD 10.7, Max Gas 36u. P/U 180k SLK 35k ROT 118k Distance to WP09: 50.24’, 1.55’ High 50.22’ Right Fault #1 12,140' MD Throw 20' DTN. 61 concretions for a total thickness of 424' ( 4.7% of the lateral hole section). Footage Oba Sand 8,492' Footage out: 1645' Total 10,137'. Daily disposal to G&I: 974 bbls, total= 13630 bbls. Daily H2O from Lake 2: 360 bbls, total 12350 bbls. Daily Metal: 0 Total 2.5. Daily losses 0 bbls. Surface loss total 1133 bbls. 4/23/2022 BROOH F/ 18,485’ to 15,752’ MD 500 gpm/ mpd 450, 1875 psi, 120 rpm, Trq 18k, ECD 10.6, Max Gas 390u. MPD 100% open. Pull speed 25-35 ft/min as hole dictates. P/U 194k SLK 35k ROT 112k. Dynamic losses 30 bbls. BROOH F/ 15,752’ to 13,400’ MD 500 gpm/ mpd 465, 1840 psi, 120 rpm, Trq 14-18k, ECD 10.6, Max Gas 443u. MPD 100% open. Pull speed 20-30 ft/min as hole dictates. P/U 180k SLK 71k ROT 115k F/ 15,592' to 15,355' MD observed intermittent pack offs slow pull speed 1-10 ft/min. Dynamic losses 30 bbls. BROOH F/ 13,400’ to 10,345’ MD 500 gpm/ mpd 460, 1660 psi, 120 rpm, Trq 10-12k, ECD 10.55, Max Gas 684u. MPD 100% open. Pull speed 20-40 ft/min as hole dictates. P/U 158k SLK 90k ROT 121k Dynamic losses 39 bbls. BROOH F/ 10,345’ to 7,676’ MD 500 gpm/ mpd 472, 1610 psi, 120 rpm, Trq 7-9k, ECD 10.33, Max Gas 225u. MPD 100% open. Pull speed 20-40 ft/min as hole dictates. P/U 155k SLK 97k ROT 125k Dynamic losses 15 bbls. No Rot/Pump out BHA at 84 gpm/ mpd 58. 180 psi due to swabbing. Saw 2-5k intermittent drag. Pump 30 bbl 9.5 ppg 325 vis sweep. Rot & Rec F/ 7,676' to 7,610' MD. 500 gpm/ mpd 486, 1580 psi, 30 rpm, Trq 5-6k, ECD 10.17, Max Gas 856u. MPD 100% open. P/U 155k SLK 97k ROT 125k. Daily disposal to G&I: 2237 bbls, total= 15867 bbls. Daily H2O from Lake 2: 240 bbls, total 12590 bbls. Daily Metal: 0 Total 2.5. Daily losses 98.5 bbls, Total 98.5 bbls. Surface loss total 1133 bbls. 4/24/2022 Continue circulating sweep around, 40% increase in cuttings. 500 gpm, 1580 psi, 30-80 rpms, 6Kft-lbs, ECD 10.1 ppg, max gas 24u. Monitor well, static. Close MPD chokes no pressure build. Pull MPD bearing, set trip nipple. Clean and clear rig floor. Service rig: grease crown, blocks, top drive, iron roughneck, drawworks. Perform derrick inspection. Open coffin lid on TD and C/O leaking test port O-ring. Change out shaker motor bolt. Monitor well on trip tank 3 bph loss rate. POOH laying down drill pipe from 7676' to 7488', no indication of swabbing. Pump dry job, blow down TD and geo-span. Cont. POOH laying down drill pipe to 4338'. P/U 109K, S/O 92K. Calc disp 16.8 bbls, actual 21.4 bbls. Cont. POOH laying down drill pipe from 4338' to 310'. L/D HWDP and Jars to 186'. Calculated displacement for trip 45, actual 46. L/D BHA: flex collar, float sub. Remove sources. L/D flex, float sub and stabilizer. Plug in and download MWD. L/D TM & DM, remove pulsar. L/D CTN, ALD and ADR. Close blinds. Break and L/D NRP, Bit and GeoPilot. Bit Grad 2-3-CT-A-X-I-WT-TD. Static loss ~3 bph. Clear and clean rig floor. L/D BHA components. Set Iron roughneck in storage place. Remove Hydraulic elevators. PJSM Bring up 270 ea 7 1/4" OD solid body centrali zers. R/U fill up line. P/U Weatherford 4.5" handling Equip. R/U 75T YC elevators. R/U JAM and tongs. Stage running jewelry in pipe shed. PJSM P/U M/U 4.5" 12.6# JFE-80S JBear Shoe Track and check floats, good. Cont Float in hole 4.5" 12.6# JFE-80 liner W/ 4.5" 11.6# Welltec Mech Open Hole PKR & 4.5" Innovus HD Multicycle Frac Sleeve as per tally F/ 68.82' to 657' MD. Use Best-O-Life 4010N. Install 7 1/4" OD solid body centralizers every Jnt. Remove every other brass shear pin form frac sleeves as per plan. Torq turn average shoulder low 2450 lb, high 3100 lb, Max 5400 lb. P/U 38k SLK 38k. Lost 9 bbls. Cont Float in hole 4.5" 12.6# JFE-80 liner W/ 4.5" 11.6# Welltec Mech Open Hole PKR & 4.5" Innovus HD Multicycle Frac Sleeve as per tally F/ 657' to 4,036' MD. Use Best-O-Life 4010N. Install 7 1/4" OD solid body centralizers every Jnt. Remove every other brass shear pin form frac sleeves as per plan. Torq turn average shoulder low 2450 lb, high 3100 lb, Max 5400 lb. P/U 72k SLK 54k. Calc 72 bbls, Act 64 bbls Lost 18 bbls. Daily disposal to G&I: 171 bbls, total= 16038 bbls. Daily H2O from Lake 2: 240 bbls, total 12830 bbls. Daily Metal: 0 Total 2.5. Daily losses 47 bbls, Total 98.5 bbls. Surface loss total 1133 bbls. 4/25/2022 Cont Float in hole 4.5" 12.6# JFE-80 liner from 4036' to 8073' W/ 4.5" 11.6# Welltec Mech Open Hole PKR & 4.5" Innovus HD Multicycle Frac Sleeve as per tally. Use Best-O-Life 4010N. Install 7 1/4" OD solid body centralizers every Jnt. Remove every other brass shear pin form frac sleeves as per plan. Torque turn to 5400ft- lbs. P/U 65k SLK 50k. Calc 144 bbls, Act 116 bbls Lost 27 bbls. Set down at 7934' work pipe down to 7995' with up to 15K down and 5K overpull. Cont Float in hole 4.5" 12.6# JFE-80 liner from 8073' to 11,196' W/ 4.5" 11.6# Welltec Mech Open Hole PKR & 4.5" Innovus HD Multicycle Frac Sleeve as per tally . Use Best-O- Life 4010N. Install 7 1/4" OD solid body centralizers every Jnt. Remove every other brass shear pin form frac sleeves as per plan. Verify total of 69 shear pins removed (3 pins x 23 frac sleeves). P/U 72K, S/O 48K. Observe 5-15K drag through open hole, pick up and work pipe as needed due to lack of down wt. C/O elevators and tongs to 7". PJSM M/U X/O 4.5" JBer P X 7" W563. P/U RIH 4 jnts 7" 26# L-80 W563 filling each jnt to 11,359' MD. C/O elevators to Hydraulic 5" D.P. P/U M/U SLZXP & 2 3/8" 5,000 psi rupture disk & 1.75" ball seat. M/U to Liner to 11,405' MD. R/D Weatherford handling Equip. Static loss rate ~3 bph. PJSM Convey 4.5" Liner W/ 5"19.5# S-135 NC50 D.P. F/ Derrick F/ 11,405' to 14,838' MD. Filling every stand and top off every 5. Observe interment drag down to ~40k string wt while running, picked up without issue and continue running without issue. Run speed 10-40 ft/min as hole dictates. P/U 113k SLK 75k. Calc 28 bbl, Act - 21 bbl, lost 49 bbls. PJSM Convey 4.5" Liner W/ 5"19.5# S-135 NC50 D.P. F/ Derrick F/ 14,838' to 18,480' MD. Work tight hole F/ 18,275' to 18,291' MD using string weight. Filling every stand and top off every 5. Observe interment drag down to ~40k string wt while running, picked up without issue and continue running without issue. Run speed 10-40 ft/min as hole dictates. P/U 163k SLK 98k. Calc 28 bbl, Act 2 bbl, lost 26 bbls. Daily disposal to G&I: 57 bbls, total= 16095 bbls. Daily H2O from Lake 2: 0 bbls, total 12830 bbls. Daily Metal: 0 Total 2.5. Daily losses 88 bbls, Total 233 bbls. Surface loss total 1133 bbls. o 18744' to log top of OA with MWD. Cont Float in hole 4.5" 12.6# JFE-80 liner from 4036' to 8073' W/ 4.5" 11.6# Welltec Mech 4/26/2022 Rig up to shear Airlock and fill pipe. Set string in tension at 18,480'. Rig up pump in sub, TIW, head pin and high pressure hoses. Pressure up on sting and observe Airlock burst at 896 psi. Pump 8 bbls at 5 bpm as per Airlock procedure. Wait 30 min to allow fluid to swap. Line adn fill pipe using charge pump at 1-1.5 bpm through pump in sub, allowing air to burp through head pin down bleeder line. Monitoring tubing with 1" line off bleeder hose. Pump 85 bbls and shut down, wait for 20 minutes to allow fluid to swap. Pump 50 bbls down drill string, observe fluid at bleeder at 40 bbls and slow down rate. Shut down and allow fluid to swap for 30 minutes. Pump last 35 bbls adjusting rate as needed to allow fluid to swap. Total pumped down drill sting 170 bbls. Monitor well on trip tank with 3 bph loss rate. Rig up 5' pup joint, side entry sub and TIW. Screw in top drive and rig up hose to circulating manifold. Circulate a liner volume at 4 bpm, 570 psi. Drop 1.25" phenolic ball and pump on seat at 4 bpm 495 psi, slow rate to 2 bpm with 72 bbls to go. Observe ball on seat at 4395 stokes (calc 4677/290 bbls strokes) Pressure up to 3000 psi to set SLZXP. Pressure not holding taking ~1/2 bpm to maintain 3000 psi. Check surface equipment, shut in pumps and observe pressure continue to drop. Bleed off. Shut manual IBOP. Pressure back up to 3000 psi, pressure still not holding, taking 3/4 bpm to maintain 3000 psi. Bleed off pressure. Discuss options with town. Pressure up to 3500 psi with mud pumps, attempt to increase pressure to 4000 psi with test pump, unable to gain any pressure. Observed SLZXP neutralize at 3512 psi. Bleed off pressure and shut in, observe 341 psi build on drill pipe. Bleed off and shut in, 300 psi pressure build. Discuss with town. Line up on trip tank and bleed pressure off drill pipe, 0.5bbls bled in 5 min. Shut in 5 mins with 58psi pressure built. Bleed 0.25 bbls in 5 min. Rig down pump in sub, TIW. Pick up and observe SLZXP free with 20K less PUW. Pumped total 283 bbls PJSM Shut UPR and purge air from system. PT packer to 1,500 psi for 10 min on chart, good. Pumped 2.4 bbls, bled 2.4 bbls. Open UPR. Line up in drill string. Attempt to close WIV and floats at 2 bpm cycling pumps 2X to 1,000 psi, press bled down. Pumped 4.6 bbls for a total of 283 bbls to set WIV. Wash up at 2 bpm 143 psi cleaning packer tie back. Circ Surf to surf at 10 bpm 470 psi Max Gas 649u. Monitor well & went static at 10 min, monitor another 5 min, static. PJSM POOH rack back one stand and 20' pup to 7,030' MD. Pump dry job & blow down TD, choke, kill and manifold. Cont POOH L/D 5" D.P. F/ 7,030' to 2,837' MD. Calc 36 bbls, Act 45 bbls, lost 9 bbls. Cull D.P. for CAT 5 in pipe shed. PJSM Cont POOH L/D 5" D.P. F/ 2,837' to 295' MD. Calc 22 bbls, Act 29 bbls, lost 7 bbls. Cull D.P. for CAT 5 in pipe shed. RIH W/ remaining 5" D.P. F/ derrick F/ 295' to 6,122' MD. P/U 131k SLK 92k. Calc 50.4 Act 43.4, lost 7 bbls. POOH L/D 5" D.P. F/ 6,122' to 4,100' MD. P/U 105k SLK 85k. Calc 14 bbls, Act 16.5 bbls, lost 2.5 bbls. Cull D.P. for CAT 5 in pipe shed. Daily disposal to G&I: 57 bbls, total= 16152 bbls. Daily H2O from Lake 2: 120 bbls, total 12950 bbls. Daily Metal: 0 Total 2.5. Daily losses 53 bbls, Total 286 bbls. Surface loss total 1133 bbls. Pressure up to 3000 psi to set SLZXP. Pump 8 bbls at 5 bpm as per Airlock procedure. Wait 30 min to allow fluid to swap. Pressure up on sting and observe Airlock burst at 896 psi. Line adn fill pipe using charge pump at 1-1.5 bpm through pump in sub, allowing air to burp through head pin down bleeder line. Rig up to shear Airlock and fill pipe. Activity Date Ops Summary 4/27/2022 Cont. to POOH laying down drill pipe from 6122' to 200'. Calc disp 36 bbls, Actual 46 bbls.,Cut and slip 94' of drillin gline. Check brake air gaps. Service rig: grease crown, blocks, top drive, wash pipie, spinners, iron roughneck and drawworks. Check oil in top drive. Check top drive cradle weld crack Service pipe skate.,POOH from 200', L/D drill pipe and liner running tool.,Rig up to RIH with tie-back string. Pull wear bushing. Remove 5" hydraulic elevators. Clean and clear rig floor. Bring Weatherford job box, slips, dog collar to rig floor. R/U elevators and power tongs. Verify pipe count in shed. Pick up bullet seals and RIH with 7", L-80, BTC casing as per detail to 3912'. M/U to diamond with an average TQ of 9,000 ft-lbs and checking TQ. PUW 107K, SOW 84K. Continue RIH with 7", L-80, BTC casing as per detail F/ 3912' - T/ tag depth @ 7091' MD. M/U to diamond with an average TQ of 9,000 ft-lbs and checking TQ. PUW 168K, SOW 110K. Tag 2x w/ 20k dn. Calculate spaceout w/ BOT rep. 3-4k seal drag. Pressure up annulus @ tag depth to 300 psi to ensure seals are engaged (good). Bleed off same.,L/D tag jts. M/U 3.82' spaceout pup below first full jt (#170). M/U hanger w/ landing jt. Landout (1.69' off no go). Shut annular and rig up to reverse circulate. Pressure up annulus to 250 psi, strip up and locate circ ports on seal assy.,Reverse circulate down 9-5/8" x 7" annulus w/ 115 bbls 9.5 ppg CI brine followed by 85 bbls diesel. LRS ICP 50 psi @ 1 bpm, FCP 400 psi @ 1.5 bpm.,Strip down and landout tieback @ final set depth 7089.37' MD (75k string wt on hanger). Remove landing joint. M/U packoff running tool. Set packoff and test same 500/5000 psi w/ 5/15 min hold. Line up and purge lines. PT 9-5/8" x 7" annulus to 1500/30 minuts - good. 2.1 bbls pumped, 2.0 bbls bled back. R/D and B/D test lines.,R/D casing equipment, R/U to RIH with 4-1/2" upper completion. C/O power tongs and pipe handling equipment. Install 4-1/2" elevators. Prep shed and verify pipe count.,Daily disposal to G&I: 0 bbls, total= 16152 bbls. Daily H2O from Lake 2: 120 bbls, total 13070 bbls. Daily Metal: 0 Total 2.5. Daily losses 63 bbls, Total 349 bbls. Surface loss total 1133 bbls. 4/28/2022 PJSM, M/U 4.5" mule shoe, "X" nipple 3.813" profile (RHCM), TNT pkr assy. Baker loc all connections from Pkr down. Run 4.5" VamTop, L-80, 12.6# upper completion as per detail F/ surface to 5992' MD. Weatherford JAM used to QC connections 4400 ft/lbs tq. 90 fpm as per HES rep. P/U 85k, S/O 64k. 9 bbl loss.,Continue run 4.5" VamTop, L-80, 12.6# upper completion as per detail F/ 5992' - T/ 7227' MD. M/U hanger and landout final depth 7252' MD with 34k string wt on hanger. Weatherford JAM used to QC connections 4400 ft/lbs tq. 90 fpm as per HES rep. P/U 101k, S/O 69k. RILDS. L/D landing joint.,M/U TCII xo w/ landing joint. R/U circulating equipment to reverse circulate IA to tbg. Reverse circulate Clean brine 1x tbg capacity (110 bbls) followed by 1x IA capacity (277 bbls) of CI 9.5 brine @ 4 bpm, ICP 390, FCP 320. Shut down, drop ball and rod. 30 min fall time for ball and rod. Purge air from pumping and testing equipment. Pump ball on seat and observe packer set @ 2150 psi. Monitor OA (0 psi). Pressure test tubing 3500 psi w/ 30 min hold (questionable test w/ 2x 20 psi bobbles on chart). Bleed down, shut down rig hydraulics and retest with slight but steady psi drop (failed test). L/D landing joint, Troubleshoot surface equipment. Retest using blind rams. Double block and isolate surface equipment. Pressure up to 3700 psi with same results. IA maintained a 50 psi increase every time, OA @ 0 psi. Discussed with town engineer. Concluded tubing had good integrity and leak was at ball and rod seat. Chart and record test. Bleed down tbg to 2000 psi and test IA to 3500 psi w/ 30 min hold (good test). Bleed down tbg and shear GLM SOV (good shear).,Install BPV. Flush surface equipment with soap pill. Johnny whack stack and jet flowline. B/D cmt line, choke and kill lines. B/D TDS, mud pumps and drain stack. B/D circulating equipment. PJSM, Remove trip nipple, Install MPD cap. N/D choke and kill lines. N/D 4 point chain, drip pan, koomey lines. Unflange from tubing spool. Rack back BOP's on stump and secure same. Sym Ops - Clean pits. Inspect mud pumps. N/U tree and tq flange 3330 ft/lbs as per Wellhead rep. Remove BPV and install TWC. Test void 500/5000 psi with good test. Test tree 250/5000 psi w/ 10 min hold on ea (good test). Test fluid diesel. Witness by Co Rep. Daily disposal to G&I: 746 bbls, total= 16898 bbls. Daily H2O from Lake 2: 120 bbls, total 13190 bbls. Daily Metal: 0 Total 2.5. Daily losses 17 bbls, Total 366 bbls. Surface loss total 1133 bbls. 4/29/2022 Freeze protect 4.5" x 7" IA and 4.5" tubing with 96 bbls diesel. Sym Ops - Clean pits and prep for rig move. Secure well and release rig @ 12:00. 50-029-23711-00-00API #: Well Name: Field: County/State: PBW M-201 Prudhoe Bay West Hilcorp Energy Company Composite Report , Alaska Concluded tubing had good integrity and leak was at ball and rod seat. Pressure test tubing 3500 psi w/ 30 min hold ACTIVITYDATE SUMMARY 4/29/2022 MU FMC Gen 5 tubing hanger, 4-1/2" TC-II, 4" H BPV profile with 4-1/2" TC-II pin x 4- 1/2" Vam Top pin x/o pup to completion string. Land hanger at 22.03¿ RKB, verify landed thru IA, RILDS, torque gland nuts to 450 ft/lbs, torque LDS to 450 ft/lbs. Standby for rig to circulate. Set 4" BPV with dry rod, rig crew ND BOP. Clean hanger top, lift threads, BPV retrieval threads, inspect seal areas, fill void with test oil, install new RX-54, NU 11" x 4" THA with dry hole tree. RU test equipment, pump hyd oil across test void, good returns. Sting into SBMS monitor port for duration of test. Test THA void to 500 psi low for 10 mins, PASS. Test THA void to 5000 psi for 10 mins, PASS. Bleed all test pressure and drain hyd oil. RD test equipment. Pulled BPV and set TWCV. Rig tested tree with diesel 250/5000 for 10 mins each, PASS. Bleed all test psi, pull 4" H TWCV with dry rod. Secure tree. 4/30/2022 T/I/O=0/0/0. Post I-Rig. Removed 4" dryhole temp valve and inatalled 4" CIW production tree with SH-3000 acutator, Pressure tested against MV to 350/5000 PSI (Pass). Installed production piping, Torqued all flanges to specs. Set well house and floor kit. Final WHP's 0/0/0. ***Job Cmplete*** 5/1/2022 ***WELL S/I ON ARRIVAL*** (leak detection log) PULLED BALL & ROD f/ RHC PLUG BODY @ 7724' MD PULLED BEK-SHEAR VALVE FROM GLM @ 2,831' MD. SET BK-DGLV IN GLM @ 2,831' MD. PULLED 3.813" RHC PLUG BODY @ 7,224' MD. ***JOB CONTINUED ON 5/2/22 WSR*** 5/2/2022 ***JOB CONTINUED FROM 5/1/22 WSR***(leak detection). RIGGED DOWN POLLARD SL #60. ***JOB COMPLETE, WELL LEFT S/I ON DEPARTURE*** 5/4/2022 Travel to location, SB to rig up 5/4/2022 T/I/O = 480/0/0. Temp = SI. TBG & IA FL (E-line Req). TBG FL @ 324' (5 bbls). IA FL @ surface. SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:30 5/4/2022 ***WELL S/I ON ARRIVAL*** RIG UP HES 759 ***CONT WSR ON 05/05/2022*** 5/5/2022 ***CONT WSR FROM 05/04/2022*** BRUSH X-NIPPLE @ 7,224' MD W/ 4-1/2" BLB, 3.78" G.RING SET 4-1/2" XX-PLUG IN X-NIPPLE @ 7,224' MD AOGCC STATE WITNESS MIT-T & MIT-IA 3500# (see log for details) EQUALIZE & PULL 4-1/2" XX-PLUG FROM X-NIPPLE @ 7,224' MD ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED ON WELL STATUS*** 5/5/2022 Assist Sl with AOGCC MIT-T MIT IA (Witnessed by Adam Earl ) T/I/O = 181/6/0 MIT-T to 3588 psi. ( PASSED) MIT IA to 3628 psi. ( PASSED ) SL on well at time of departure. 5/7/2022 ***WELL SHUT IN ON ARRIVAL, DSO NOTIFIED*** (TRACTOR BASELINE) RIH W/ 3-1/8" WELLTEC TRACTOR W/STP LOGGING TOOLS. UNABLE TO GET THROUGH FRAC SLEEVE AT 14797', MADE MULTIPLE ATTEMPTS W/O PROGRESS. DECSION MADE TO TRY SMALLER TRACTOR IN AM. TOOLS CAKED W/ WHAT LOOKS LIKE FORMATION SAND, ...CONT ON 8-MAY-2022... 5/8/2022 T/IA/OA=150/540/0 Assist Eline with LDL, Pumped 83 BBLS DSL down TBG Eline in control of well upon departure Daily Report of Well Operations PBU M-201 ( MIT-T to 3588 psi. ( PASSED) MIT IA to 3628 psi. ( Daily Report of Well Operations PBU M-201 5/8/2022 ...CONT FROM 7-MAY-2022... UNABLE TO PASS THROUGH RESTRICTION/OBSTRUCTION AT 14400' WHILE TRACTORING AND PUMPING LOG LDL WHILE PUMPING 0.75 BPM TO 7000' ***WELL LEFT S/I UPON DEPARTURE, TURNED OVER TO DSO*** 5/25/2022 CTU 9 Pipe swap from 1.75" to 2.0" ***Continued on 5/26/2022*** 5/26/2022 CTU 9 Pipe swap from 1.75" to 2.0" ***Continued on 5/27/2022*** 5/27/2022 CTU 9 Pipe swap from 1.75" to 2.0" ***In Progress*** 5/28/2022 CTU 9 2.0" CT Job Objective: FCO, Drift for NCS BHA, Set packers, and shift sleeves Road unit from the yard to M-201. MIRU. Make up BOT 2-7/8" Tempress BHA w/ 3" JSN and RIH. Ran into lock up at 11330, circed gel pill and safelube. Clean gel pill returned, shut down pumps and continue dry drift down to 14557. Run into lock up/fill. Begin jetting. ***Job Continued 5/29/2022*** 5/29/2022 CTU 9 2.0" CT Job Objective: FCO, Drift for NCS BHA, Set packers, and shift sleeves Continue jetting at sleeve #10 with gel, chase out. Continue in hole until lock up at 17093. Circ in more safelube.Tag TD at 18429' ctm. Pump 15 bbls gel sweep off bottom and chase ooh jetting across jewelry. Pump gel sweep at heel and chase out of hole. ***Job Continued on 5/30/2022*** 5/30/2022 CTU 9 2.0" CT Job Objective: FCO, Drift for NCS BHA, Set packers, and shift sleeves Continue pulling and chasing gel out of hole. Swap out tempress. Make up and RIH with BOT whipstock drift BHA with 3.800" gage rings. Tag at 18434' ctm. Lay in Lube 776/LoTorq pill. Pooh pumping pipe voidage. RIH with NCS sleeve shifting BHA. RIH to TD and set packer below lowest welltec packer. Could not pressure up to set packers. Tried to set again - same results. Set NCS packer above welltec packer and had the same leak off rate. Proceed with shifting sleeves. Shift sleeve #1 at 1080psi, 2bpm @ 500 psi Shift sleeve #2 at 1105psi, 2bpm @ 587 psi Shift sleeve #3 at 1389psi, 2bpm @ 734psi Set at 17450 - Below Welltec packer, pressured up to 2000psi, same bleed off rate. Unset tool with 400psi differential to confirm element set. WHP fell rapidly - confirmed element was set. Shift sleeve #4 at 1215psi, 3bpm @ 1070psi. *Stopped pressuring up at 1000psi during the set to see if pressure would hole above welltec packer, prior to shifting - did not hold. ***Job Continued on 5/31/2022*** Daily Report of Well Operations PBU M-201 5/31/2022 CTU 9 2.0" CT Job Objective: FCO, Drift for NCS BHA, Set packers, and shift sleeves Continue shifting sleeves and hunting for leaks. Shift sleeve #5 at 1391psi, 2bpm @ 801psi Shift sleeve #6 at 1369psi, 2bpm @ 753psi Shift sleeve #7 at 1269psi, 2bpm @ 740psi Set below packer at 15811 and had the same leak rate. Set directly above this packer as well, same leak rate. Shift sleeve #8 at 1392psi, 3bpm @ 1070psi Shift sleeve #9 at 1526psi, 2bpm @ 799psi Set below packer at 14685 and had the same leak rate, .6bpm at 2400psi. Set above packer at 14685 and have the same leak rate. P-subs closed to confirm Shift sleve #10 at 1426psi, 3bpm @ 1067psi Shift sleeve #11 at 1636psi, 2bpm @ 887psi Shift sleeve #12 at 1647psi, 2bpm @ 869psi Set below packer 13599 leak rate is .4bpm at 2110psi Sleeves 13, 14, & 15 left closed. Set below packer at 12131 and pressure held at 2281. Go through Welltec packer setting procedure and inflate packers to 4800psi.Still had to pump at ~.2bpm to maintain pressure. Diagnostic set at 12840, 12550, 12340, 12275 - all had similar leak rates of 100psi/minute. Shift sleeve #16 at 1055psi, 2.8bpm @ 974psi Shift sleeve #17 @ 1677psi, 2bpm @ 785psi Shift sleeve #18 @ 1100 psi, 2 bpm @ 770 psi Shift sleeve #19 @1350 psi, Estblish an injection rate of 1.8 bpm at 1060 psi for 5 mins Shift sleeve #20 @ 1306 psi, 2 bpm @ 840 psi Shift sleeve #21 @ 1386 psi, 2 bpm @ 850 psi Shift sleeve #22 @ 1192 psi, Establish an injection rate of 3.4 bpm 1150 psi for 5 mins and 1200 psi at 5 bpm for 2 mins TD Shoe Depth: PBTD: No. Jts. Returned RKB RKB to BHF RKB to THF Jts. 130 56 Yes X No Yes X No 5.4 Fluid Description: Liner hanger Info (Make/Model): Liner top Packer?: Yes No Liner hanger test pressure:X Yes No Centralizer Placement: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp:X Yes No Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job Cement returns to surface?x Yes No Spacer returns?x Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp:X Yes No Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Post Job Calculations: Calculated Cmt Vol @ 0% excess: Total Volume cmt Pumped: Cmt returned to surface: Calculated cement left in wellbore: OH volume Calculated: OH volume actual: Actual % Washout: Casing (Or Liner) Detail Float Shoe 9.625 CSG RKB 10 3/4 440.5 1.50%434SECOND STAGE1 12:15 Returns to Surface Rotate Csg Recip Csg Ft. Min. PPG9.5 Shoe @ 7781 FC @ Top of Liner7,695.00 Floats Held 434 bbl 744.5 bbl 304 440.5 H2O CASING RECORD County State Alaska Supv.J. Lott / C. Montague Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.PBW M-201 Date Run 13-Apr-22 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top TCP BTC Innovex 1.76 7,781.00 7,779.24 2,297.28 2,297.28 26.70 9 5/8 47.0 L-81 VAM Tenaris Csg Wt. On Hook:35,000 Type Float Collar:Standard No. Hrs to Run:24 8.34 5.7 1880 10 10.7 280 3.5 100 281 Bump Plug?FIRST STAGE10Tuned Spacer 60 15.8 563 3.4 9.5 6 150/152.8 20/20 1630 102bbl cement HES 15.8 87 Bump press Cement Circulated to surface from stage tool depth Bump Plug? Y 0:25 4/14/2022 2,356 2356 7,781.007,790.00 CEMENTING REPORT Csg Wt. On Slips: Spud Mud Tuned Spacer 461 2.88 Stage Collar @ 60 Bump press 100 212 ES Closure OK 56.5 ArcticCem Type Type I/II 267 12 321 26.70 RKB to CHF Type of Shoe:Standard Casing Crew:Weatherford No. Jts. Delivered No. Jts. Run 209 19 Length Measurements W/O Threads Ftg. Delivered 8,360.00 Ftg. Run 7,781.00 Ftg. Returned 579.00 Ftg. Cut Jt.29.39 Ftg. Balance www.wellez.net WellEz Information Management LLC ver_04818br 3.4 Jnt 1 2 ea 10' from end, 1 ea jnt 3 & 4. Every jnt F/ 5-26, every other F/ jnt 28-50, 1 ea 130-134, 1 ea ES pups, 1 ea jnt 144-148, every third jnt F/ 151-193. 65 total solid bow spring. 9.625 CSG 9 5/8 40.0 L-80 TCP BTC Tenaris 82.14 7,779.24 7,697.10 Float Collar 10 3/4 TCP BTC Innovex 1.46 7,697.10 7,695.64 9.625 CSG 9 5/8 40.0 L-80 TCP BTC Tenaris 39.14 7,695.64 7,656.50 Baffle Adapter 10 3/4 TCP BTC Halliburton 1.41 7,656.50 7,655.09 9.625 CSG 9 5/8 40.0 L-80 TCP BTC Tenaris 5,278.26 7,655.09 2,376.83 Pup 9 5/8 40.0 L-80 TCP BTC Tenaris 18.07 2,376.83 2,358.76 ES Cementer 11 3/4 TCP BTC Halliburton 2.81 2,358.76 2,355.95 Pup 9 5/8 40.0 L-80 TCP BTC Tenaris 17.59 2,355.95 2,338.36 9.625 X/O 9 5/8 47.0 L-80 VAM Tenaris 41.08 2,338.36 2,297.28 Type I/II 769 2.35 Type I/II 400 1.16 4.5 1.17 4/15/2022 Surface Spud Mud Cement Circulated to surface from stage tool depth 100 Returns to Surface Surface 100 X Y 'HILQLWLYH6XUYH\5HSRUW $SULO +LOFRUS1RUWK6ORSH//& 3UXGKRH%D\ 0 0 3URMHFW &RPSDQ\ /RFDO&RRUGLQDWH5HIHUHQFH 79'5HIHUHQFH 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helsea Wright Digitally signed by Chelsea Wright Date: 2022.04.25 08:24:28 -08'00' Benjamin Hand Digitally signed by Benjamin Hand Date: 2022.04.25 09:55:38 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 20, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Matt Herrera P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC M-201 PRUDHOE BAY UN POL M-201 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/20/2022 M-201 50-029-23711-00-00 222-030-0 W SPT 5015 2220300 1500 1171 1159 1129 1109 24 262 209 165 INITAL F Matt Herrera 6/7/2022 MIT-IA Performed to 1900 PSI Per Operations. Operations will reschedule upon review of test and operating parameters that could have contributed to failure and proceed with a retest at a later date. Operations will shut well in if not able to retest within required timeframe. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN POL M-201 Inspection Date: Tubing OA Packer Depth 23 1923 1775 1701IA 45 Min 60 Min Rel Insp Num: Insp Num:mitMFH220607103912 BBL Pumped:1.1 BBL Returned:1 Monday, June 20, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 7RWDO3UHVVXUHORVVH[FHHGHGDOORZHGGXULQJPLQWHVWMEU MIT-IA Performed to 1900 PSI F James B. Regg Digitally signed by James B. Regg Date: 2022.06.20 16:56:59 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 13, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC M-201 PRUDHOE BAY UN POL M-201 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/13/2022 M-201 50-029-23711-00-00 222-030-0 N SPT 5015 2220300 1500 2026 2485 2492 2490 0 80 78 75 OTHER P Adam Earl 5/5/2022 MIT-IA Tested as per PTD 2220300 post drill.pre injection 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN POL M-201 Inspection Date: Tubing OA Packer Depth 1080 3667 3640 3628IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220509121847 BBL Pumped:1.6 BBL Returned:1.6 Monday, June 13, 2022 Page 1 of 1 9 9 9 9 9 9 99 9 9 SVLWHVWUHT G MIT-IA T .pre injection James B. Regg Digitally signed by James B. Regg Date: 2022.06.13 14:44:26 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 13, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC M-201 PRUDHOE BAY UN POL M-201 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/13/2022 M-201 50-029-23711-00-00 222-030-0 N SPT 5015 2220300 1500 2026 3687 3612 3588 0 0 0 0 OTHER P Adam Earl 5/5/2022 MIT-T Tested as per PTD 2220300 post drill.pre injection 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN POL M-201 Inspection Date: Tubing OA Packer Depth 1076 1243 1244 1241IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220509120720 BBL Pumped:0.7 BBL Returned:0.7 Monday, June 13, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 SVLWHVWUHT G 9 9 .pre injectionMIT-T T James B. Regg Digitally signed by James B. Regg Date: 2022.06.13 14:41:26 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Grassroots Injector M-201 (PTD #222030) AOGCC required initial MIT-IA failed Date:Wednesday, June 8, 2022 2:02:02 PM Attachments:image001.png MIT PBU M-201 06-07-22.xlsx From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, June 8, 2022 9:25 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Brodie Wages <David.Wages@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com> Subject: OPERABLE: Grassroots Injector M-201 (PTD #222030) AOGCC required initial MIT-IA failed Mr. Wallace, Fullbore and DHD performed a failing AOGCC witnessed MIT-IA on 6/7/22. It was determined that during the test, the injection rate was changed as the result of a choke change made inadvertently by an instrumentation tech. The well was shut-in due to upcoming facility maintenance work scheduled to begin tomorrow. The witnessed MIT-IA will be rescheduled after the facility work, when the well is back online under stable conditions. Sorry for any inconvenience. Please feel free to contact me if you have any questions. John Condio (covering for) Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2220300 Type Inj W Tubing 1171 1159 1129 1109 Type Test P Packer TVD 5015 BBL Pump 1.1 IA 23 1923 1775 1701 Interval I Test psi 1500 BBL Return 1.0 OA 24 262 209 165 Result F Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Hilcorp Alaska LLC Prudhoe Bay / PBU / M Pad Ryan Holt 06/07/22 Notes:AOGCC MIT-IA post initial injection. PWI injection rate & pressure was unstable due to instrument tech apperantly drove the choke to a pinched back setting during the MIT-IA. Well was shut-in 6/7/22. MIT-IA will be rescheduled when well is BOI and stable after upcoming facility maintenance work. Notes: Notes: Notes: M-201 Form 10-426 (Revised 01/2017)MIT PBU M-201 06-07-22 David Douglas Hilcorp North Slope, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 05/24/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL : *** REVISION #2 *** Note: This re-distribution supersedes previously delivered Final LWD data for PBU M-201 PBU M-201 (PTD: 222-030 API: 50-029-23711-00-00) FINAL LWD FORMATION EVALUATION LOGS (04/07/2022 to 04/22/2022) x ROP, AGR, DGR, ABG, EWR-M5, ADR, Horizontal Presentation (2” & 5” MD/TVD Color Logs) x Final Definitive Directional Survey x Final Geosteering and EOW Report/Plots SFTP Transfer – Main Folders: PBU M-201 LWD Subfolders: PBU M-201 Geosteering Subfolders: Please include current contact information if different from above. PTD:222-030 T36552 Revision 2 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.24 13:33:52 -08'00' David Douglas Hilcorp North Slope, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 05/12/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL : *** REVISED DATA *** Note: This re-distribution supersedes previously delivered Final LWD data for PBU M-201 PBU M-201 (PTD: 222-030 API: 50-029-23711-00-00) FINAL LWD FORMATION EVALUATION LOGS (04/07/2022 to 04/22/2022) x ROP, AGR, DGR, ABG, EWR-M5, ADR, Horizontal Presentation (2” & 5” MD/TVD Color Logs) x Final Definitive Directional Survey x Final Geosteering and EOW Report/Plots SFTP Transfer – Main Folders: PBU M-201 LWD Subfolders: PBU M-201 Geosteering Subfolders:g Please include current contact information if different from above. PTD:222-030 T36552 Revised Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.12 13:51:54 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20220505 1600 NOTIFICATION PTD 222-030 PBU M-201 - MITs Date:Thursday, May 5, 2022 4:57:31 PM Subject: PBU M-201 - MITs Eric, I wont advise differently. Let’s hope the ball and rod were leaking. AOGCC will want notification for opportunity to witness. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Oliver, Chris Wallace, AOGCC Inspectors From: Eric Dickerman <Eric.Dickerman@hilcorp.com> Sent: Tuesday, May 3, 2022 5:17 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: PBU M-201 - MITs Mel, In reference to PTD 222-030, PBU M-201. The MIT-T performed on the rig did not pass the stabilization criteria. The TBG pressured was up to 3,818 psi and after 30 min ended at 3,737 psi with the IA pressure remaining at 50 psi throughout the test. The overall tubing pressure loss was acceptable but did not meet the stabilization criteria. The MIT-T was attempted again with similar results. Because the IA pressure did not show any response during the test, we believe the tubing has integrity and that the ball and rod were leaking. After the MIT-T attempt, the MIT-IA passed pressure loss and stabilization criteria beginning at 3,700 psi and ending 30 min at 3,615 psi with 1,000 psi differential greater than the tubing. The tubing did not show signs of re-pressurization during the MIT-IA. We are planning to send slickline out to the well to set a plug in the tubing and perform the MIT-T and MIT-IA again, unless you advise otherwise. Thank you, Eric Dickerman Hilcorp – FS2 OE Cell: 307-250-4013 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. David Douglas Hilcorp North Slope, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 05/03/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL : PBU M-201 (PTD: 222-030 API: 50-029-23711-00-00) FINAL LWD FORMATION EVALUATION LOGS (04/07/2022 to 04/22/2022) x ROP, AGR, DGR, ABG, EWR-M5, ADR, Horizontal Presentation (2” & 5” MD/TVD Color Logs) x Final Definitive Directional Survey x Final Geosteering and EOW Report/Plots SFTP Transfer – Main Folders: PBU M-201 LWD Subfolders: PBU M-201 Geosteering Subfolders:g Please include current contact information if different from above. PTD:222-030 T36552 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.03 16:19:07 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:James Lott - (C) To:Regg, James B (OGC);DOA AOGCC Prudhoe Bay;Brooks, Phoebe L (OGC) Cc:Joseph Engel;Monty Myers;Oliver Amend - (C) Subject:Hilcorp Innovation 04-16-22 BOP Test Report Date:Sunday, April 17, 2022 10:00:39 AM Attachments:Hilcorp Innovation 04-16-22.xlsx James Lott HILCORP Drilling Foreman HILCORP INNOVATION Rig PBU, North Slope Alaska 907-670-3094 (Office) 907-398-9069 (Cell) Harmony 1006 jlott@hilcorp.com jameslott352@yahoo.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 3%80 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu b m i tt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:Innovation DATE: 4/16/22 Rig Rep.: Rig Phone: 907-3095 Operator: Op. Phone:9073094 Rep.: E-Mail Well Name: PTD #22220300 Sundry # Operation: Drilling: x Workover: Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/3000 Annular:250/3000 Valves:250/3000 MASP:1760 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 1P Housekeeping P Rig P Lower Kelly 1P PTD On Location P Hazard Sec.P Ball Type 2P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13-5/8", 5K P Pit Level Indicators PP #1 Rams 1 4-1/2""x 7"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 1 2-7/8"x5-1/2"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 3-1/8, 5K P Inside Reel valves 0NA HCR Valves 2 3-1/8, 5K P Kill Line Valves 2 3-1/8, 5K P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure (psi)3050 P CHOKE MANIFOLD:Pressure After Closure (psi)1500 P Quantity Test Result 200 psi Attained (sec)25 P No. Valves 15 P Full Pressure Attained (sec)93 P Manual Chokes 1P Blind Switch Covers: All stations Yes Hydraulic Chokes 1FP Nitgn. Bottles # & psi (Avg.): 6 @ 2366 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:1 Test Time:6.5 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 4/15, 12:47 Waived By Test Start Date/Time:4/16/2022 1:30 (date) (time)Witness Test Finish Date/Time:4/16/2022 8:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Guy Cook Hilcorp FP on Super Choke.Pump and flush through Super Choke, Re-test with Pass. Matt Vanhoose Hilcorp James Lott PBU M-201 Test Pressure (psi): jlott@hilcorp.com Form 10-424 (Revised 02/2022) 2022-0416_BOP_Hilcorp_Innovation_PBU_M-201 99 9 9 9 9 9 9 9 9 9 -5HJJ FP on Super Choke.Pump and flush through Super Choke, Re-test with Pass. FP 4/16/22 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20220412 1711 APPROVAL to Variance (PTD#222030) Injection Packer Set Depth Variance Date:Tuesday, April 12, 2022 5:12:56 PM From: Rixse, Melvin G (OGC) Sent: Tuesday, April 12, 2022 5:11 PM To: Wyatt Rivard <wrivard@hilcorp.com> Cc: Joseph Engel <jengel@hilcorp.com> Subject: RE: M-201 (PTD#222030) Injection Packer Set Depth Variance Wyatt, As stated in your request below: The production tubing packer will be set below the top of the Schrader N sands. Therefore, variance to 20 AAC 25.412. (b) is approved. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Tuesday, April 12, 2022 2:08 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Joseph Engel <jengel@hilcorp.com> Subject: M-201 (PTD#222030) Injection Packer Set Depth Variance Hello Mel, The Innovation Rig TD’d the 9-5/8” surface hole section today at 7790’ MD on well M-201 (PTD # 222030). This places the target surface casing shoe depth at the top of the Schrader OBA sand at ~87 degrees inclination. Similar to our last grassroots injector, Z-221 (PTD # 221095), we are planning to set the injection tubing packer and X-Nipple for ball and rod deployment at a slickline accessible depth. The injection packer is planned to be set at ~7170’ MD with the ball and rod landing at ~7210’ MD (~65deg inclination). This will place the injection packer ~620’ MD from the surface casing shoe. From a TVD standpoint the injection packer is 155’ TVD from the surface casing shoe and is below the top of the Schrader N sands ( ~7082’ MD). With the surface casing shoe and the injection packer set below the top of Schrader Bluff, injection fluids will be confined to the Schrader bluff sands. Hilcorp requests a variance to 20 AAC 25.412.(b) for injection packer set greater than 200 feet measured depth (~620’MD) from upper most injection on well M-201 (PTD # 222030). Thank You, Wyatt Rivard | Operations Engineer (PBU: J, Q, R, S, U, W pads)O: (907) 777-8547 | C: (509)670-8001 | wrivard@hilcorp.comHilcorp Alaska, LLC | Anchorage, AK 99503 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:James Lott - (C) To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:Joseph Engel; Monty Myers Subject:Diverter Hilcorp Innovation 4-7-22 Date:Friday, April 8, 2022 12:59:26 PM Attachments:Diverter Hilcorp 04-07-22.xlsx James Lott HILCORP Drilling Foreman HILCORP INNOVATION Rig PBU, North Slope Alaska 907-670-3094 (Office) 907-398-9069 (Cell) Harmony 1006 jlott@hilcorp.com jameslott352@yahoo.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. PBU M-201 PTD 2220300 Date: 4/7/2022 Development:X Exploratory: Drlg Contractor:Rig No.Innovation AOGCC Rep: Operator:Oper. Rep: Field/Unit/Well No.:Rig Rep: PTD No.:2220300 Rig Phone: Rig Email: MISCELLANEOUS:DIVERTER SYSTEM: Location Gen.:P Well Sign:P Designed to Avoid Freeze-up?P Housekeeping:P Drlg. Rig.P Remote Operated Diverter?P Warning Sign P Misc:NA No Threaded Connections?P 24 hr Notice:P Vent line Below Diverter?P ACCUMULATOR SYSTEM:Diverter Size:13 5/8 in. Systems Pressure:3000 psig P Hole Size:12 1/4 in. Pressure After Closure:1900 psig P Vent Line(s) Size:16 in.P 200 psi Recharge Time:19 Seconds P Vent Line(s) Length:215 ft.P Full Recharge Time:52 Seconds P Closest Ignition Source:80 ft.P Nitrogen Bottles (Number of):6 Outlet from Rig Substructure:199 ft.P Avg. Pressure: 2367 psig P Accumulator Misc:NA Vent Line(s) Anchored:P MUD SYSTEM:Visual Alarm Turns Targeted / Long Radius:P Trip Tank:P P Divert Valve(s) Full Opening:P Mud Pits:P P Valve(s) Auto & Simultaneous: Flow Monitor:P P Annular Closed Time: 10 sec P Mud System Misc:0 NA Knife Valve Open Time: 6 sec P Diverter Misc:NA GAS DETECTORS:Visual Alarm Methane:P P Hydrogen Sulfide:P P Gas Detectors Misc:0 NA Total Test Time:0.5 hrs Non-Compliance Items:0 Remarks: Submit to: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report GENERAL INFORMATION WaivedHilcorp *All Diverter reports are due to the agency within 5 days of testing* jlott@hilcorp.com TEST DATA Joel Sture phoebe.brooks@alaska.gov Hilcorp Test on 5" Pipe Size 0 James Lott 0 670-3094 TEST DETAILS jim.regg@alaska.gov AOGCC.Inspectors@alaska.gov PBU M-201 Form 10-425 (Revised 05/2021)2022-0407_Diverter_Hilcorp_Innovation_PBU_M-201       J. Regg; 4/8/2022       333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Monty M Myers Drilling Manager Hilcorp North Slope, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Prudhoe Bay Field, Polaris Oil Pool, PBU M-201 Hilcorp North Slope, LLC Permit to Drill Number: 222-030 Surface Location: 3415' FSL, 606' FEL, Sec. 01, T11N, R12E, UM, AK Bottomhole Location: 1344' FSL, 56' FWL, Sec. 23, T12N, R12E, UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jeremy M. Price Chair DATED this ___ day of March, 2022. 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rudhoe Bay West M-201 SB Injector Drilling Procedure ,QQRYDWLRQ5LJ&KRNH0DQLIROG6FKHPDWLF 3DJH Prudhoe Bay West M-201 SB Injector Drilling Procedure &DVLQJ'HVLJQ 3DJH Prudhoe Bay West M-201 SB Injector Drilling Procedure ´+ROH6HFWLRQ0$63 3DJH Prudhoe Bay West M-201 SB Injector Drilling Procedure 6SLGHU3ORW1$'*RYHUQPHQWDO6HFWLRQV 3DJH Prudhoe Bay West M-201 SB Injector Drilling Procedure 6XUIDFH3ODW$V6WDNHG1$' 6WDQGDUG3URSRVDO5HSRUW 0DUFK 3ODQ0ZS +LOFRUS1RUWK6ORSH//& 3UXGKRH%D\ 0 3ODQ0 0 0100020003000400050006000True Vertical Depth (2000 usft/in)-1000 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 17000 18000Vertical Section at 320.00° (2000 usft/in)M-201 wp06 HeelM-201 wp06 CP1M-201 wp06 CP1.5M-201 wp06 CP3M-201 wp06 Toe9 5/8" x 12 1/4"4 1/2" x 8 1/2"500100015002000250030003500400045005000550060006500700075008000850090009500100001050011000115001200012500130001350014000145001500015500160001650017000175001800018500190001950019887M-201 wp06Start Dir 3º/100' : 300' MD, 300'TVDStart Dir 4º/100' : 600' MD, 598.77'TVDEnd Dir : 1677.56' MD, 1527.4' TVDFault #1 (40' Throw down to north)Start Dir 4º/100' : 6723.35' MD, 4826.48'TVDEnd Dir : 7719.67' MD, 5175.05' TVDStart Dir 2º/100' : 7819.67' MD, 5176.8'TVDEnd Dir : 8858.57' MD, 5181.2' TVDStart Dir 2º/100' : 10951.92' MD, 5162.21'TVDEnd Dir : 12233.07' MD, 5170.53' TVDStart Dir 2º/100' : 12297.7' MD, 5171.46'TVDEnd Dir : 13917.9' MD, 5188.87' TVDStart Dir 2º/100' : 15749.21' MD, 5200.73'TVDEnd Dir : 16127.17' MD, 5201.8' TVDStart Dir 2º/100' : 17115.41' MD, 5201.8'TVDEnd Dir : 18993.01' MD, 5201.8' TVDTotal Depth : 19887.34' MD, 5201.8' TVDBPRFSV3Ugnu 4AUG3Ugnu MBNAOAOBaHilcorp North Slope, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Ellipsoid SeparationWarning Method: Error RatioWELL DETAILS: Plan: M-20125.30+N/-S+E/-WNorthingEasting LatitudeLongitude0.000.005974491.02628209.33 70° 20' 18.759 N 148° 57' 34.750 WSURVEY PROGRAMDate: 2022-02-21T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool26.50 700.00 M-201 wp06 (M-201) GYD_Quest GWD700.00 7820.00 M-201 wp06 (M-201) 3_MWD+IFR2+MS+Sag7820.00 19887.34 M-201 wp06 (M-201) 3_MWD+IFR2+MS+SagFORMATION TOP DETAILSTVDPath TVDssPath MDPath Formation1834.80 1783.00 2147.72 BPRF2791.80 2740.00 3611.40 SV33633.80 3582.00 4899.20 Ugnu 4A3967.80 3916.00 5410.04 UG34892.80 4841.00 6829.42 Ugnu MB5024.80 4973.00 7082.08 NA5142.80 5091.00 7439.02 OA5174.80 5123.00 7707.86 OBaREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: M-201, True NorthVertical (TVD) Reference:M-201 as-staked @ 51.80usftMeasured Depth Reference:M-201 as-staked @ 51.80usftCalculation Method: Minimum CurvatureProject:Prudhoe BaySite:MWell:Plan: M-201Wellbore:M-201Design:M-201 wp06CASING DETAILSTVD TVDSS MD SizeName5176.81 5125.01 7820.00 9-5/8 9 5/8" x 12 1/4"5201.80 5150.00 19887.34 4-1/2 4 1/2" x 8 1/2"SECTION DETAILSSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation1 26.50 0.00 0.00 26.50 0.00 0.00 0.00 0.00 0.002 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 Start Dir 3º/100' : 300' MD, 300'TVD3 600.00 9.00 270.00 598.77 0.00 -23.51 3.00 270.00 15.11 Start Dir 4º/100' : 600' MD, 598.77'TVD4 1677.56 49.17 314.55 1527.40 300.28 -417.06 4.00 50.97 498.11 End Dir : 1677.56' MD, 1527.4' TVD5 6723.35 49.17 314.55 4826.48 2978.59 -3137.84 0.00 0.00 4298.70 Start Dir 4º/100' : 6723.35' MD, 4826.48'TVD6 7719.67 89.00 316.00 5175.05 3627.69 -3778.50 4.00 2.26 5207.74 End Dir : 7719.67' MD, 5175.05' TVD7 7819.67 89.00 316.00 5176.80 3699.61 -3847.95 0.00 0.00 5307.48 M-201 wp06 Heel Start Dir 2º/100' : 7819.67' MD, 5176.8'TVD8 8858.57 90.52 336.72 5181.20 4559.82 -4420.29 2.00 85.90 6334.33 End Dir : 8858.57' MD, 5181.2' TVD9 10951.92 90.52 336.72 5162.21 6482.70 -5247.49 0.00 0.00 8339.06 Start Dir 2º/100' : 10951.92' MD, 5162.21'TVD10 11041.91 90.00 335.00 5161.80 6564.82 -5284.29 2.00 -106.78 8425.62 M-201 wp06 CP111 12233.07 89.17 311.19 5170.53 7510.45 -5994.40 2.00 -92.05 9606.46 End Dir : 12233.07' MD, 5170.53' TVD12 12297.70 89.17 311.19 5171.46 7553.01 -6043.03 0.00 0.00 9670.32 M-201 wp06 CP1.5 Start Dir 2º/100' : 12297.7' MD, 5171.46'TVD13 13917.90 89.63 343.59 5188.87 8899.63 -6904.48 2.00 89.39 11255.63 End Dir : 13917.9' MD, 5188.87' TVD14 15749.21 89.63 343.59 5200.73 10656.34 -7421.74 0.00 0.00 12933.83 Start Dir 2º/100' : 15749.21' MD, 5200.73'TVD15 16079.38 90.00 337.00 5201.80 10967.00 -7533.00 2.00 -86.79 13243.3316 16127.17 90.00 337.96 5201.80 11011.15 -7551.31 2.00 90.00 13288.92 End Dir : 16127.17' MD, 5201.8' TVD17 17115.41 90.00 337.96 5201.80 11927.14 -7922.21 0.00 0.00 14229.02 M-201 wp06 CP3 Start Dir 2º/100' : 17115.41' MD, 5201.8'TVD18 18993.01 90.00 300.40 5201.80 13322.75 -9127.73 2.00 -90.00 16073.01 End Dir : 18993.01' MD, 5201.8' TVD19 19887.34 90.00 300.40 5201.80 13775.36 -9899.06 0.00 0.00 16915.53 M-201 wp06 Toe Total Depth : 19887.34' MD, 5201.8' TVD 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250 12000 12750 13500 South(-)/North(+) (1500 usft/in)-9750 -9000 -8250 -7500 -6750 -6000 -5250 -4500 -3750 -3000 -2250 -1500 -750 0 West(-)/East(+) (1500 usft/in) M-201 wp06 Toe M-201 wp06 CP3 M-201 wp06 CP1.5 M-201 wp06 CP1 M-201 wp06 Heel 9 5/8" x 12 1/4" 4 1/2" x 8 1/2"10001500175020002250250027503000325035003750400042504500475050005202M-201 wp06 Start Dir 3º/100' : 300' MD, 300'TVD Start Dir 4º/100' : 600' MD, 598.77'TVD End Dir : 1677.56' MD, 1527.4' TVD Fault #1 (40' Throw down to north) Start Dir 4º/100' : 6723.35' MD, 4826.48'TVD End Dir : 7719.67' MD, 5175.05' TVD Start Dir 2º/100' : 7819.67' MD, 5176.8'TVD End Dir : 8858.57' MD, 5181.2' TVD Start Dir 2º/100' : 10951.92' MD, 5162.21'TVD End Dir : 12233.07' MD, 5170.53' TVD Start Dir 2º/100' : 12297.7' MD, 5171.46'TVD End Dir : 13917.9' MD, 5188.87' TVD Start Dir 2º/100' : 15749.21' MD, 5200.73'TVD End Dir : 16127.17' MD, 5201.8' TVD Start Dir 2º/100' : 17115.41' MD, 5201.8'TVD End Dir : 18993.01' MD, 5201.8' TVD Total Depth : 19887.34' MD, 5201.8' TVD CASING DETAILS TVD TVDSS MD Size Name 5176.81 5125.01 7820.00 9-5/8 9 5/8" x 12 1/4" 5201.80 5150.00 19887.34 4-1/2 4 1/2" x 8 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'LVWDQFH%HWZHHQ3URILOHV'LVWDQFH%HWZHHQ3URILOHV(OOLSVH6HSDUDWLRQ'LVWDQFH%HWZHHQFHQWUHVLVWKHVWUDLJKWOLQHGLVWDQFHEHWZHHQZHOOERUHFHQWUHV$OOVWDWLRQFRRUGLQDWHVZHUHFDOFXODWHGXVLQJWKH0LQLPXP&XUYDWXUHPHWKRG0DUFK &203$663DJHRI 0.001.002.003.004.00Separation Factor0 425 850 1275 1700 2125 2550 2975 3400 3825 4250 4675 5100 5525 5950 6375 6800 7225 7650 8075Measured Depth (850 usft/in)M-14No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.WELL DETAILS:Plan: M-201 NAD 1927 (NADCON CONUS)Alaska Zone 0425.30+N/-S +E/-W Northing EastingLatitudeLongitude0.000.005974491.02628209.3370° 20' 18.759 N148° 57' 34.750 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: M-201, True NorthVertical (TVD) Reference:M-201 as-staked @ 51.80usftMeasured Depth Reference:M-201 as-staked @ 51.80usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2022-02-21T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool26.50 700.00 M-201 wp06 (M-201) GYD_Quest GWD700.00 7820.00 M-201 wp06 (M-201) 3_MWD+IFR2+MS+Sag7820.00 19887.34 M-201 wp06 (M-201) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)0 425 850 1275 1700 2125 2550 2975 3400 3825 4250 4675 5100 5525 5950 6375 6800 7225 7650 8075Measured Depth (850 usft/in)M-13M-14M-15M-32GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference26.50 To 19887.34Project: Prudhoe BaySite: MWell: Plan: M-201Wellbore: M-201Plan: M-201 wp06Ladder / S.F. Plots1 of 2CASING DETAILSTVD TVDSS MD Size Name5176.81 5125.01 7820.00 9-5/8 9 5/8" x 12 1/4"5201.80 5150.00 19887.34 4-1/2 4 1/2" x 8 1/2" &OHDUDQFH6XPPDU\$QWLFROOLVLRQ5HSRUW0DUFK+LOFRUS1RUWK6ORSH//&3UXGKRH%D\03ODQ000ZS5HIHUHQFH'HVLJQ03ODQ000ZS&ORVHVW$SSURDFK'3UR[LPLW\6FDQRQ&XUUHQW6XUYH\'DWD+LJKVLGH5HIHUHQFH:HOO&RRUGLQDWHV1( 1 :'DWXP+HLJKW0DVVWDNHG#XVIW6FDQ5DQJHWRXVIW0HDVXUHG'HSWK*HRGHWLF6FDOH)DFWRU$SSOLHG9HUVLRQ%XLOG(6FDQ5DGLXVLV8QOLPLWHG&OHDUDQFH)DFWRUFXWRIILV8QOLPLWHG0D[(OOLSVH6HSDUDWLRQLVXVIW*/2%$/),/7(5$33/,('$OOZHOOSDWKVZLWKLQ RIUHIHUHQFH6FDQ7\SH6FDQ7\SH 3UXGKRH%D\+LOFRUS1RUWK6ORSH//&$QWLFROOLVLRQ5HSRUWIRU3ODQ00ZS&RPSDULVRQ:HOO1DPH:HOOERUH1DPH'HVLJQ#0HDVXUHG'HSWKXVIW0LQLPXP'LVWDQFHXVIW(OOLSVH6HSDUDWLRQXVIW#0HDVXUHG'HSWKXVIW&OHDUDQFH)DFWRU6FDQ5DGLXVLV8QOLPLWHG&OHDUDQFH)DFWRUFXWRIILV8QOLPLWHG0D[(OOLSVH6HSDUDWLRQLVXVIW6LWH1DPH6FDQ5DQJHWRXVIW0HDVXUHG'HSWK&ORVHVW$SSURDFK'3UR[LPLW\6FDQRQ&XUUHQW6XUYH\'DWD+LJKVLGH5HIHUHQFH5HIHUHQFH'HVLJQ03ODQ000ZS0HDVXUHG'HSWKXVIW6XPPDU\%DVHGRQ0LQLPXP6HSDUDWLRQ:DUQLQJ03ODQ000ZS &HQWUH'LVWDQFH 3DVV3ODQ000ZS &OHDUDQFH)DFWRU 3DVV3ODQ000ZS (OOLSVH6HSDUDWLRQ 3DVV666$6$ &HQWUH'LVWDQFH 3DVV66$6$ (OOLSVH6HSDUDWLRQ 3DVV66$6$ &OHDUDQFH)DFWRU 3DVV66$3%6$3% &HQWUH'LVWDQFH 3DVV66$3%6$3% (OOLSVH6HSDUDWLRQ 3DVV66$3%6$3% &OHDUDQFH)DFWRU 3DVV66$3%6$3% &HQWUH'LVWDQFH 3DVV66$3%6$3% (OOLSVH6HSDUDWLRQ 3DVV66$3%6$3% &OHDUDQFH)DFWRU 3DVV66$3%6$3% &HQWUH'LVWDQFH 3DVV66$3%6$3% (OOLSVH6HSDUDWLRQ 3DVV66$3%6$3% &OHDUDQFH)DFWRU 3DVV66$6$ &OHDUDQFH)DFWRU 3DVV66$6$ &HQWUH'LVWDQFH 3DVV66$6$ (OOLSVH6HSDUDWLRQ 3DVV666 &OHDUDQFH)DFWRU 3DVV666 (OOLSVH6HSDUDWLRQ 3DVV666 &HQWUH'LVWDQFH 3DVV66$6$ &HQWUH'LVWDQFH 3DVV66$6$ (OOLSVH6HSDUDWLRQ 3DVV66$6$ &OHDUDQFH)DFWRU 3DVV66%6% &OHDUDQFH)DFWRU 3DVV66%6% (OOLSVH6HSDUDWLRQ 3DVV0DUFK &203$663DJHRI 3UXGKRH%D\+LOFRUS1RUWK6ORSH//&$QWLFROOLVLRQ5HSRUWIRU3ODQ00ZS&RPSDULVRQ:HOO1DPH:HOOERUH1DPH'HVLJQ#0HDVXUHG'HSWKXVIW0LQLPXP'LVWDQFHXVIW(OOLSVH6HSDUDWLRQXVIW#0HDVXUHG'HSWKXVIW&OHDUDQFH)DFWRU6FDQ5DGLXVLV8QOLPLWHG&OHDUDQFH)DFWRUFXWRIILV8QOLPLWHG0D[(OOLSVH6HSDUDWLRQLVXVIW6LWH1DPH6FDQ5DQJHWRXVIW0HDVXUHG'HSWK&ORVHVW$SSURDFK'3UR[LPLW\6FDQRQ&XUUHQW6XUYH\'DWD+LJKVLGH5HIHUHQFH5HIHUHQFH'HVLJQ03ODQ000ZS0HDVXUHG'HSWKXVIW6XPPDU\%DVHGRQ0LQLPXP6HSDUDWLRQ:DUQLQJ66%6% &HQWUH'LVWDQFH 3DVV666 &OHDUDQFH)DFWRU 3DVV666 (OOLSVH6HSDUDWLRQ 3DVV666 &HQWUH'LVWDQFH 3DVV663%63% &OHDUDQFH)DFWRU 3DVV663%63% (OOLSVH6HSDUDWLRQ 3DVV663%63% &HQWUH'LVWDQFH 3DVV663%63% &OHDUDQFH)DFWRU 3DVV663%63% (OOLSVH6HSDUDWLRQ 3DVV663%63% &HQWUH'LVWDQFH 3DVV666 &HQWUH'LVWDQFH 3DVV666 (OOLSVH6HSDUDWLRQ 3DVV666 &OHDUDQFH)DFWRU 3DVV666 (OOLSVH6HSDUDWLRQ 3DVV666 &OHDUDQFH)DFWRU 3DVV666 &HQWUH'LVWDQFH 3DVV663%63% &HQWUH'LVWDQFH 3DVV663%63% (OOLSVH6HSDUDWLRQ 3DVV663%63% &OHDUDQFH)DFWRU 3DVV666 &HQWUH'LVWDQFH 3DVV666(OOLSVH6HSDUDWLRQ3DVV666&OHDUDQFH)DFWRU3DVV66$6$ &HQWUH'LVWDQFH 3DVV66$6$ (OOLSVH6HSDUDWLRQ 3DVV66$6$ &OHDUDQFH)DFWRU 3DVV66$3%6$3% &HQWUH'LVWDQFH 3DVV66$3%6$3% (OOLSVH6HSDUDWLRQ 3DVV66$3%6$3% &OHDUDQFH)DFWRU 3DVV666&HQWUH'LVWDQFH)$,/666&OHDUDQFH)DFWRU)$,/0DUFK &203$663DJHRI 3UXGKRH%D\+LOFRUS1RUWK6ORSH//&$QWLFROOLVLRQ5HSRUWIRU3ODQ00ZS&RPSDULVRQ:HOO1DPH:HOOERUH1DPH'HVLJQ#0HDVXUHG'HSWKXVIW0LQLPXP'LVWDQFHXVIW(OOLSVH6HSDUDWLRQXVIW#0HDVXUHG'HSWKXVIW&OHDUDQFH)DFWRU6FDQ5DGLXVLV8QOLPLWHG&OHDUDQFH)DFWRUFXWRIILV8QOLPLWHG0D[(OOLSVH6HSDUDWLRQLVXVIW6LWH1DPH6FDQ5DQJHWRXVIW0HDVXUHG'HSWK&ORVHVW$SSURDFK'3UR[LPLW\6FDQRQ&XUUHQW6XUYH\'DWD+LJKVLGH5HIHUHQFH5HIHUHQFH'HVLJQ03ODQ000ZS0HDVXUHG'HSWKXVIW6XPPDU\%DVHGRQ0LQLPXP6HSDUDWLRQ:DUQLQJ66$6$&HQWUH'LVWDQFH)$,/66$6$&OHDUDQFH)DFWRU)$,/66$6$(OOLSVH6HSDUDWLRQ)$,/66$/6$/&HQWUH'LVWDQFH)$,/66$/6$/&OHDUDQFH)DFWRU)$,/66$/6$/(OOLSVH6HSDUDWLRQ)$,/66/6/&HQWUH'LVWDQFH)$,/66/6/&OHDUDQFH)DFWRU)$,/663%63%&HQWUH'LVWDQFH)$,/663%63%&OHDUDQFH)DFWRU)$,/66$6$ &HQWUH'LVWDQFH 3DVV66$6$ (OOLSVH6HSDUDWLRQ 3DVV66$6$ &OHDUDQFH)DFWRU 3DVV6XUYH\WRROSURJUDP)URPXVIW7RXVIW6XUYH\3ODQ 6XUYH\7RRO 0ZS *<'B4XHVW*:' 0ZS B0:',)5066DJ 0ZS B0:',)5066DJ(OOLSVHHUURUWHUPVDUHFRUUHODWHGDFURVVVXUYH\WRROWLHRQSRLQWV6HSDUDWLRQLVWKHDFWXDOGLVWDQFHEHWZHHQHOOLSVRLGV&DOFXODWHGHOOLSVHVLQFRUSRUDWHVXUIDFHHUURUV&OHDUDQFH)DFWRU 'LVWDQFH%HWZHHQ3URILOHV'LVWDQFH%HWZHHQ3URILOHV(OOLSVH6HSDUDWLRQ'LVWDQFH%HWZHHQFHQWUHVLVWKHVWUDLJKWOLQHGLVWDQFHEHWZHHQZHOOERUHFHQWUHV$OOVWDWLRQFRRUGLQDWHVZHUHFDOFXODWHGXVLQJWKH0LQLPXP&XUYDWXUHPHWKRG0DUFK &203$663DJHRI 0.001.002.003.004.00Separation Factor7500 8250 9000 9750 10500 11250 12000 12750 13500 14250 15000 15750 16500 17250 18000 18750 19500 20250 21000 21750Measured Depth (1500 usft/in)M-200 wp02S-110AS-111S-124S-41S-41ANo-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.NOERRORSWELL DETAILS:Plan: M-201 NAD 1927 (NADCON CONUS)Alaska Zone 0425.30+N/-S +E/-W Northing EastingLatitudeLongitude0.000.005974491.02628209.3370° 20' 18.759 N148° 57' 34.750 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: M-201, True NorthVertical (TVD) Reference:M-201 as-staked @ 51.80usftMeasured Depth Reference:M-201 as-staked @ 51.80usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2022-02-21T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool26.50 700.00 M-201 wp06 (M-201) GYD_Quest GWD700.00 7820.00 M-201 wp06 (M-201) 3_MWD+IFR2+MS+Sag7820.00 19887.34 M-201 wp06 (M-201) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)7500 8250 9000 9750 10500 11250 12000 12750 13500 14250 15000 15750 16500 17250 18000 18750 19500 20250 21000 21750Measured Depth (1500 usft/in)S-13AS-13APB1GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference26.50 To 19887.34Project: Prudhoe BaySite: MWell: Plan: M-201Wellbore: M-201Plan: M-201 wp06Ladder / S.F. Plots2 of 2CASING DETAILSTVD TVDSS MD Size Name5176.81 5125.01 7820.00 9-5/8 9 5/8" x 12 1/4"5201.80 5150.00 19887.34 4-1/2 4 1/2" x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