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Home My WebLink About221-0827. 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 L-116A Ext Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 221-082 50-029-23025-01-00 9227 Conductor Surface Intermediate Production Liner 6474 79 2626 6651 2709 9162 20" 7-5/8" 5-1/2" x 3-1/2" 2-3/8" 6478 30 - 109 27 - 2653 24 - 6675 6471 - 9180 30 - 109 27 - 2572 24 - 6468 6265 - 6477 9143 470 4790 4990 11780 None 1490 6890 7000 11200 8300 - 9164 3-1/2" 9.2# 13Cr80 22 - 6438 6479 - 6478 Structural No Packer None None Torin Roschinger Operations Manager Tyson Shriver tyson.shriver@hilcorp.com 907-564-4542 PRUDHOE BAY, BOREALIS 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 0028239 22 - 6232 N/A N/A 259 358 25 1404 1260 1788 1276 1250 372 400 323-287 13b. Pools active after work:BOREALIS OIL No SSSV 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 By Grace Christianson at 10:48 am, Sep 26, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.09.26 06:35:19 -08'00' Torin Roschinger (4662) DSR-9/27/23 RBDMS JSB 092623 WCB 4-11-2024 ACTIVITY DATE SUMMARY 9/14/2023 LRS CTU #1, 1.5" Blue Coil. Job Objective: Extended Perforate MIRU and RIH with 1-11/16" YJ MHA with 1.75" DJN. Tag fill at 8856' CTMD. Clean out to hard tag at 9128' CTMD and ensure clean dry drift. POOH. ...Continued on WSR 9-15-23... 9/15/2023 LRS CTU #1, 1.5" Blue Coil. ***Cont. from WSR 9-14-23*** Job Objective: Extended Perforate Make up GR/CCL BHA and RIH. Log from 9000' to 6250', painting tie-in flag at 8200'. POOH and confirm good data (+22' correction). Deploy 500' of 1.56" GeoRazor, 6 SPF, 60 degree phase gas. RIH and perforate 8300' - 8800'. POOH and lay down guns. Freeze protect the tubing to 2500' TVD with diesel. ***Job Complete*** Daily Report of Well Operations PBU L-116A j Make up GR/CCL BHA and RIH. Log from 9000' to 6250', painting tie-in flag at 8200'. g gg POOH and confirm good data (+22' correction). Deploy 500' of 1.56" GeoRazor, 6g SPF, 60 degree phase gas. Tag fill at 8856' CTMD. Cleang out to hard tag at 9128' CTMD and ensure clean dry drift. POOH RIH and perforate 8300' - 8800'. POOH ()y 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU L-116A Extended Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 221-082 50-029-23025-01-00 471 ADL 0028239 9227 Conductor Surface Intermediate Production Liner 6474 79 2626 6651 2709 9162 20" 7-5/8" 5-1/2" x 3-1/2" 2-3/8" 6478 30 - 109 27 - 2853 24 - 6675 6471 - 9180 2350 30 - 109 27 - 2755 24 - 6469 6265 - 6477 9143 470 4790 4990 11780 None 1490 6890 7000 11200 8651 - 9164 3-1/2" 9.2# 13Cr80 22 - 64386472 - 6478 Structural No Packer No SSSV Installed No Packer No SSSV Installed Date: Torin Roschinger Area Operations Manager Brodie Wages David.Wages@hilcorp.com 907.564.5006 PRUDHOE BAY 6/1/2023 Current Pools: Borealis Oil Proposed Pools: Borealis Oil STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov 323-287 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.05.12 15:46:20 -08'00' Torin Roschinger (4662) By Grace Christianson at 4:11 pm, May 12, 2023 10-404 2350 DSR-5/12/23SFD 5/23/2023MGR26MAY23GCW 05/26/23JLC 5/26/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.05.26 14:09:58 -08'00'5/26/23 RBDMS JSB 053023 Well: L-116A PTD:221-082 ExtADP#2 Well Name:L-116A API Number:50-029-23025-01 Current Status:Operable Producer Rig:Slickline / Coil Estimated Start Date:6/1/2022 Estimated Duration:3 days Regulatory Contact:Abbie Barker 564-4915 (O) First Call Engineer:David Wages (713) 380-9836 (c) Second Call Engineer:Josh Stephens (907) 779-1200 (c) Current Bottom Hole Pressure:2141 psi @ 6123’ TVD 6.7 PPGE | 1/18/23 SBHPS Maximum Expected BHP:3,000 psi @ 6500’ TVD 8.9 PPGE | Pattern expected BHP Max. Anticipated Surface Pressure:2350 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:261 psi (9/4/2022 SITP) Min ID:1.781” ID, RR nipple in PTSA @ 6471’ MD Max Angle:111 Deg @ 7041’ Max DLS:48 @ 6830 Tie In: READ Coil Flag 4/23/22 Brief Well Summary: L-116a is a recent CTD slimhole sidetrack with a 2-3/8” liner cemented in place with ~2 fracs in the lateral. Drilling of the lateral went fine with good indication of plenty of oil along the toe 2/3rds of the lateral. After cementing in place, the CTD rig RDMO and slickline installed the LTP. Upon fracturing operations, the LTP became disengaged from the deployment sleeve and compromised the frac operations. Following several squeezes and multiple frac attempts, the well now has 2-3 frac stages in the well with associated lost production due to unstimulated lateral. An initial ExtADP was executed 2/21 in the unstimulated zones between the 1st and 2nd frac stages with minimal benefits seen. This program seeks to add perforates between the 2nd and 3rd frac stage fracs which did not execute quite as cleanly as stage 1, so the benefits seen here should be much better than the initial ADP. Volumes: Feature Depth, MD Volume, bbls Tubing tail 6421 55.9 Liner Top Packer 6471 56.3 PBTD 9164 66.8 Objective: Ext Perf Add unfrac’d sections MITs: 1. 1/4/2022: MIT-T to 4787 psi 2. 1/4/2022: MIT-IA to 4022 psi Procedure: Coiled Tubing Notes: x Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. 8.9 PPGE | Pattern expected BHP Well: L-116A PTD:221-082 ExtADP#2 x The well will be killed and monitored before making up the initial perfs guns. This is generally done during the drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. x Confirm KWF weight based on slickline SBHPS x Last venturi run came back clean, but the last DH operation was a 344’ ExtADP, there may be debris in the well. 1. After MU MHA and pull testing the CTC, tag-up on theCT stripper to ensure BHA cannot pull through the brass upon POOH with guns. 2. Bullhead ~150 bbls 1% KCl down tubing (2x WB vol). Max tubing pressure 4500 psi. a. This step can be performed any time prior to open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSS. b. Use WHP to modify KWF as needed 3. MU and RIH with logging tools and drift BHA/JSN 4. Flag pipe as appropriate per WSS for adperf/CBP runs. 5. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/KWF as needed by pumping down the coil tubing backside. Maintain hole fill taking returns to tank until lubricator connection is re-established. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 6. POOH and freeze protect tubing as needed. 7. Confirm good log data. 8. Confirm well is dead. Bleed any pressure off to return tank. 9. At surface, prepare for deployment of TCP guns. 10. *Perform drill by picking up safety joint with TIW valve and space out before MU guns. Review well control steps with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. a. At the beginning of each job, the crossover/safety joint must be physically MU to the perf guns one time to confirm the threads are compatible. 11.Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. Constantly monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. *Use 1.56” Perfecta, 6 spf, 60° phasing (or equivalent) guns 12.7” penetration, 0.20” EHD a. Calibrate friction factor on logging run. L-116a 2 nd Add Perf Schedule Perf Interval Perf Length Gun Length Air Weight of Gun (lbs) at 12.41 ppf Comments Run 1 8300’–8800’’500’ ~500’~1900# ! NOTE possible BHP 8.9 PPGE may require higher KWF! - mgr Not to exceed .65 psi/ft fracture pressure at sand face. - mgr Well: L-116A PTD:221-082 ExtADP#2 12. RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate interval per Perf Schedule above. a. Note any tubing pressure change in WSR. b. Obtain injection test 13. After perforating, PUH to top of liner or into tubing tail to ensure debris doesn’t fall in on the guns and stick the BHA. Confirm well is dead and re-kill if necessary before pulling to surface. 14. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 15. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 16. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 17. RDMO CTU. Testers (contingent) 1. POP well a. Start well at minimum choke and 1 mmscfd until well IA cleared and well is flowing b. After well is online and stable, Open choke ~10 steps per hour, checking solids every choke adjustment and bottoms up c. Increase GL as needed to keep flow stable d. Obtain 8 hour piggyback well test with pad separator prior to RDMO Attachments: 1. Current Wellbore Schematic 2. Proposed Schematic 3. Coil Tubing BOPE Schematic 4. Standing Orders for Open Hole Well Control during Perf Gun Deployment 5. Equipment Layout Diagram 6. Tie In Log/Perf Sheet ! NOTE! BHP pattern of 8.9 PPGE may require well to be displaced to KWF > 8.9 ppg to undeploy guns. -mgr Well: L-116A PTD:221-082 ExtADP#2 Current Wellbore Schematic Well: L-116A PTD:221-082 ExtADP#2 Proposed Wellbore Schematic Well: L-116A PTD:221-082 ExtADP#2 Coiled Tubing BOPs Well: L-116A PTD:221-082 ExtADP#2 Standing Orders for Open Hole Well Control during Perf Gun Deployment Well: L-116A PTD:221-082 ExtADP#2 Equipment Layout Diagram Well: L-116A PTD:221-082 ExtADP#2 Tie In: READ Coil Flag 4/23/22 Well: L-116A PTD:221-082 ExtADP#2 The Current Tie in log has very little GR signature to go off of, when we pull the tie in log for this perf run, look for the previously shot holes at 8800’ as we are attempting to shoot 500’ of additional perforations just above the previous ADP. Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Work Over Sundry ProcedureDate: May 12, 2023Subject: Changes to Approved Sundry Procedure for Well L-116ASundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the workover (WO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date 7. 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 L-116A Extended Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 221-082 50-029-23025-01-00 9227 Conductor Surface Intermediate Production Liner 6474 79 2626 6651 2709 9162 20" 7-5/8" 5-1/2" x 3-1/2" 2-3/8" 6478 30 - 109 27 - 2853 24 - 6675 6471 - 9180 30 - 109 27 - 2755 24 - 6469 6265 - 6477 9143 470 4790 4990 11780 None 1490 6890 7000 11200 8651 - 9164 3-1/2" 9.2# 13Cr80 22 - 6438 6472 - 6478 Structural No Packer No SSSV Installed N/A N/A Stan Golis Sr. Area Operations Manager Brodie Wages David.Wages@hilcorp.com 907.564.5006 PRUDHOE BAY, Borealis 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 0028239 22 - 6232 N/A N/A 134 328 238 100 852 1162 1226 1035 340 400 322-648 13b. Pools active after work:Borealis Oil No SSSV Installed No Packer 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 By Samantha Carlisle at 8:30 am, Feb 28, 2023 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2023.02.27 16:53:31 -09'00' Stan Golis (880) PBU L-116A Extended Perf w CTU PRUDHOE BAY, Borealis Oil WCB 11-24-2023 Perforate DSR-2/28/23 322-648 Sundry Number 221-082 RBDMS JSB 030223 ACTIVITY DATE SUMMARY 1/15/2023 ***WELL S/I ON ARRIVAL*** PULLED DREAM CATCHER FROM 6,389' SLM (6,399' MD) ***-10' CORRECTION*** DRIFT TO 6,650' SLM W/ KJ, 3' x 1-1/2", 1-3/4" CENT, 1-1/2 BULL NOSE RAN DUAL SBHP GAUGES IN CARRIER (1.66"o.d) (PER PROCEDURE) ***JOB COMPLETE, WELL LEFT S/I*** 2/4/2023 LRS CTU 2, 1.5" Blue COil, Job Objective: Extended Adperf MIRU. Well flowing upon arrival. Shut in GL and bleed IA to 325 psi. Freeze protect flowline. Make up and RIH with HES GR/CCL and 1.75" drift. Tagged at 8716. Able to pull up. Become detained at 8671'. Work pipe and pop free. Pull heavy at GLM #3. Work through. Breakdown tools. Trim pipe. ***Continued on 2/5/23*** 2/5/2023 LRS CTU 2, 1.5" Blue COil, Job Objective: Extended Adperf Make up BOT Milling BHA. Redirected to go to complete PRE CTD work on 09-43. Will return at late date ***Job Delayed*** 2/10/2023 LRS Well Test unit 1, Begin WSR 2-10-23, STANDBY, Cont WSR on 2-11-23 2/11/2023 LRS Well Test Unit #1, Cont. WSR from 2-10-23, STANDBY, Cont WSR on 2-12-23 2/12/2023 LRS Well Test unit 6, Continue WSR from 2-11-23, STANDBY, Cont WSR on 2-13- 23 2/12/2023 LRS Well Test Unit #1, Continued from 2/11/23 WSR, STANDBY, Continue to 2/13/23 WSR 2/13/2023 LRS Well Test Unit #1, Continued from 2/12/23 WSR, STANDBY, Continue to 2/14/23 WSR 2/14/2023 LRS Well Test Unit #1, Continued from 2/13/23 WSR, STANDBY, Continue to 2/15/23 WSR 2/15/2023 LRS Well Test Unit #1, Continued from 2/14/23 WSR, STANDBY, Continue to 2/16/23 WSR 2/16/2023 LRS Well Test Unit #1, Continued from 2/15/23 WSR, SB, Continue to 2/17/23 WSR. 2/17/2023 LRS Well Test Unit #1. Continued from 2/16/23 WSR. SB, Continue to 2/18/23 WSR. 2/20/2023 LRS CTU #2, 1.5" Blue Coil; Job Objective Perforating MIRU. Well S/I on arrival. Shut in GL and bleed IA to 320 psi. MU & RIH with 1-11/16" Yellowjack milling venturi BHA with 1.74" burnshoe. Cleanout to TD at ~ 9148' CTM. Paint pink safety flag at 9128' CTM. MU 1-11/16" HES GR/CCL logging tools and RIH. Log from 9121' - 6200' at 50 FPM. Paint ***yellow*** flag at 8700.03' / 8695' M / 8698.96' HES. POOH & confirm good data (+4' correction). Replace the reel swivel. ***Job in Progress*** 2/21/2023 LRS CTU #2 1.5" Blue Coil. Job Scope: Perforating Load well w/ 81 bbls of 1% KCL & 12 bbls 60/40. Perform no-flow test - Good. Unstab and maintain continuous hole fill with 60/40. MU 17 HES 1.56" Geo Razor perf guns. RIH to flag. Correct to top shot. PU to 8800'. Perf 8800 - 9144' MD. POOH. Load & Kill well with 101 bbls of 1% KCL. Perform no-flow test - Good. Unstab and maintain continuous hole fill with 60/40. BD 17 HES 1.56" Geo Razor perf guns. RDMO ***Job Complete*** Daily Report of Well Operations PBU L-116A Make up BOT Milling BHA LRS CTU 2, 1.5" Blue COil, Job Objective: Extended Adperf MIRU. g Make up and RIH with HES GR/CCL and 1.75" drift. Tagged at 8716. Able gg to pull up. Become detained at 8671'. Work pipe and pop free. Pull heavy at GLM #3. Work through. LRS CTU #2, 1.5" Blue Coil RDMO The adperfs are shown correctly on the new WBS, below. -WCB jg MIRU. Well S/I on arrival. Shut in GL and bleed IA to 320 psi. MU & RIH with 1-11/16" Yellowjack milling venturi BHA with 1.74" burnshoe. Cleanout to TD at ~ 9148' CTM. MU 17 HES 1.56" Geo Razor perf guns. RIH to flag. Correct to top shot. PU to 8800'. Perf 8800 - 9144' MD. g POOH MU 1-11/16" HES GR/CCL logging tools andyggg g RIH. Log from 9121' - 6200' at 50 FPM. Paint ***yellow*** flag at 8700.03' / 8695' M Daily Report of Well Operations PBU L-116A 2/21/2023 LRS Well Test Unit 6, Flowback/ Post CTU ADPERF. Begin WSR on 2/21/23. IL Well L-116, OL Well ?. Unit move, Stand By For Coil. Job in Progress. Continue WSR on 2/22/23 2/22/2023 LRS Well Test Unit 6, Flowback/ Post CTU ADPERF. Continue WSR from 2/21/23. IL Well L-116, OL Well L-116 K. Flange.Stand By For Coil, Unit Move, RU, PT, POP. Job in Progress. Continue WSR on 2/23/23 2/23/2023 LRS Well Test Unit 6, Flowback/ Post CTU ADPERF. Continue WSR from 2/22/23. IL Well L-116, OL Well L-116 K. Flange. POP, flow stablize, Divert into WPS. Job in Progress. Continue WSR on 2/24/23 2/24/2023 LRS Well Test Unit 6, Flowback/ Post CTU ADPERF. Continue WSR from 2/23/23. IL Well L-116, OL Well L-116 K. Flange. Perform 8 Hr PB WT, Divert out of WPS, BD, RD. Job Completed. 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ƌĂƚĞƐƉƵŵƉĞĚŝŶĂŶĚĨůƵŝĚƌĞƚƵƌŶƐŽƵƚŽĨƚŚĞǁĞůů͘&ůƵŝĚƐŵĂŶͲǁĂƚĐŚŵƵƐƚďĞƉĞƌĨŽƌŵĞĚ ǁŚŝůĞĚĞƉůŽǇŝŶŐƉĞƌĨŐƵŶƐƚŽĞŶƐƵƌĞƚŚĞǁĞůůƌĞŵĂŝŶƐŬŝůůĞĚĂŶĚƚŚĞƌĞŝƐŶŽĞǆĐĞƐƐĨůŽǁ͘ ΎhƐĞ ϭ͘ϱϲ͟WĞƌĨĞĐƚĂ͕ϲƐƉĨ͕ϲϬΣƉŚĂƐŝŶŐ;ŽƌĞƋƵŝǀĂůĞŶƚͿŐƵŶƐ ϭϮ͘ϳ͟ƉĞŶĞƚƌĂƚŝŽŶ͕Ϭ͘ϮϬ͟ , Ă͘ ĂůŝďƌĂƚĞĨƌŝĐƚŝŽŶĨĂĐƚŽƌŽŶůŽŐŐŝŶŐƌƵŶ͘ 1RWWRH[FHHGIUDFWXUHJUDGLHQWDWSHUIV PJU tĞůů͗ >Ͳϭϭϲ Wd͗ϮϮϭͲϬϴϮ W/͗ϱϬͲϬϮϵͲϮϯϬϮϱͲϬϭ >Ͳϭϭϲ ĚĚWĞƌĨ^ĐŚĞĚƵůĞ WĞƌĨ/ŶƚĞƌǀĂů WĞƌĨ >ĞŶŐƚŚ 'ƵŶ >ĞŶŐƚŚ ŝƌtĞŝŐŚƚŽĨ 'ƵŶ;ůďƐͿ ĂƚϭϮ͘ϰϭƉƉĨ ŽŵŵĞŶƚƐ ZƵŶϭ ϴϴϬϬ͛ ʹ ϵϭϰϰ͛ϯϰϰ͛Εϯϰϰ͛Εϭϯϳϲη ϭϲ͘ Z/,ǁŝƚŚƉĞƌĨŐƵŶĂŶĚƚŝĞͲŝŶƚŽĐŽŝůĨůĂŐĐŽƌƌĞůĂƚŝŽŶ͘WŝĐŬƵƉĂŶĚƉĞƌĨŽƌĂƚĞŝŶƚĞƌǀĂůƉĞƌWĞƌĨ^ĐŚĞĚƵůĞ ĂďŽǀĞ͘ Ă͘ EŽƚĞĂŶǇƚƵďŝŶŐƉƌĞƐƐƵƌĞĐŚĂŶŐĞŝŶt^Z͘ ď͘ KďƚĂŝŶŝŶũĞĐƚŝŽŶƚĞƐƚ ϭϳ͘ ĨƚĞƌƉĞƌĨŽƌĂƚŝŶŐ͕Wh,ƚŽƚŽƉŽĨůŝŶĞƌŽƌŝŶƚŽƚƵďŝŶŐƚĂŝůƚŽĞŶƐƵƌĞĚĞďƌŝƐĚŽĞƐŶ͛ƚĨĂůůŝŶŽŶƚŚĞŐƵŶƐ ĂŶĚ ƐƚŝĐŬƚŚĞ,͘ ŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚĂŶĚƌĞͲŬŝůů͕ ŝĨŶĞĐĞƐƐĂƌǇ͕ ďĞĨŽƌĞƉƵůůŝŶŐƚŽƐƵƌĨĂĐĞ͘ ϭϴ͘ WƵŵƉƉŝƉĞĚŝƐƉůĂĐĞŵĞŶƚǁŚŝůĞ WKK,͘^ƚŽƉĂƚƐƵƌĨĂĐĞƚŽƌĞĐŽŶĨŝƌŵǁĞůů ŝƐ ĚĞĂĚ͘ <ŝůůǁĞůůŝĨŶĞĐĞƐƐĂƌǇ͘ ϭϵ͘ ZĞǀŝĞǁǁĞůůĐŽŶƚƌŽůƐƚĞƉƐ ĂŶĚ^ƚĂŶĚŝŶŐKƌĚĞƌƐ ǁŝƚŚĐƌĞǁƉƌŝŽƌƚŽďƌĞĂŬŝŶŐůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶĂŶĚ 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3XPSEEOVRISSJFODVVJFHPHQWOHWEEOFRPHDURXQG&7WKHQJJ 38+DERYHOLQHU6ORZO\VTXHH]HFHPHQWWRILQDOSUHVVXUHRISVLDSSUR[ VHW&,%3DW JJ # 3XPSHGEEOVRISSJ&ODVV*FHPHQWOHWEEODERYHJ QR]]OHDQGSXOOXSWRDERYHWRSSHUILQWHUYDO 'RZQVTXHH]HFHPHQW LQWRSHUIVIRULQLWLDOSVLEXPSWRSVLEEOVEHKLQGSLSH WELL COMPLETION OR RECOMPLETION REPORT AND LOG 5-1/2"x3-1/2" E By Meredith Guhl at 2:17 pm, May 13, 2022 Completed 4/24/2022 MDG RBDMS 5/13/2022 MDG G SFD 8/12/2022MGR24AUG2022 DSR-5/13/22 Activity Date Ops Summary 2/5/2022 Started moving the rig down the L-Pad access road and the lead NES weighted sow truck broke down. Notified L-Pad Operator that we are blocking the road. Decision made to backup both subs back to V-Pad and swap Sow out for Dozer to assist moving the Main Sub Continue moving rig to L-pad Main & Pits subs on L- Pad, remove Jeeps. Verify all Tree & CSG Valves are closed and spot Main & Pit Subs. Rig spotted and accepted at 14:00. Safe out rig and start MIRU Ops Checklist. Cycle tree valves, 925 psi on well, call out grease crew swab will not hold pressure. Leak test on swab is good. Remove tree cap. Install BOPs. Make up MP line. Grease choke valves and BOP test valves. Load KCl and PowerVis drilling fluid into pits. Swap out risers to get correct working height. Get RKB measurements. Install spill catcher around riser. Rig up test chart. Configure test joint. M/U nozzle, M/U injector to well. Line up valves, fluid pack lines. Fill reel forward. Get good shell test. Test BOPs. 2/6/2022 Continue testing BOPE (05:00 start). Test #1 - IRV, Stripper, C7, C9, C10, C11 - Pass. PU injector and install night cap Test #2 - Blind Shear, R2, BL2, C-15 - Pass. Remove night cap and install Test Cap with 2" Test Joint. Test #3 - Annular, TIW#1, B1, B4 - Pass. Test #4 - Upper 2" P/S, TIW #2, B2, B3 - Pass. Test #5 - Lower 2" P/S, C5, C6, C8, TV2 - Pass. Test #6 - Choke A, Choke C - Pass. Drawdown Test - Pass Test Gas & PVT Alarms. Test #7 - Upper 2" Pipe/Slips, C1, C4, TV1 - Pass. Test #8 - 2-3/8" Pipe/Slips, C2, C3 - Pass RD test equipment and PU PDL's and test to 3500psi, MASP = 2828psi PDL's tested to 3500psi, install BHI Floats and PT floats and body test to 3500psi. Good PT to 3500psi on floats & body. PJSM to MU the Milling BHA. Pressure deploy BHA. Mill is 2.79" No-Go reamer is 2.80" No-Go. RIH pump 1.5 bpm through open EDC. Keep WHP above initial value then adjust to keep returns around 1.0 bpm. Tie-in depth from 6600' correct -10.5'. Up wt is 32k. Tag whipstock 6675'. Pick up and circulate remaining KCl around. Circ 1.8 / 1.36 bpm at 9.94# EDC with 396 psi WHP. With clean KCl to surface shut down, shut in ECD = 9.88 ppg. Resume circulating KCl out to tiger tank. Purge riser to bleed trailer. Swap to mud, once mud at bit losses increasing, gradually open choke. Mud at surface bring returns inside. Close EDC. Pump 1.7 bpm mud getting 0.6 bpm back. Discuss plan forward with ODE. Open EDC and circulate. Line up trucking and fluids for milling with reduced mud system. Enough fluids on location. Close EDC, RIH and tag window at 6675'. Pick up and start milling. 1.71 / 1.33 bpm at 3500 psi FS. MW 8.6 / 8.59 ppg In / Out. 2/7/2022 Continue milling window f/6674.9' to 6677.4'. In rate = 1.70 bpm Out rate = 1.54 bpm loss rate avg 12-18 bph. Circ PSI = 3530 psi WOB = 2.18k ECD = 10.28 ppg. WHP = 123 psi IAP = 825 psi OAP = 294 psi. 6679.1' WOB dropped off indicating BOW. Continue milling at 1 fph to dress the BOW with the string mill and mill 10' of Rat Hole Rat hole milled to 6689.4', PUH at as milled TF for first back ream pass. A little motor work at the top on the as milled TF. Back ream at 160° a little MW at the top. Back ream at 190° a little MW at the top Lost pumps, close choke, WHP at 190psi and climbing, ECD dropped to 9.6 ppg eqv. Pumps back online, not sure why we lost pumps, electrician looking at control panel for pumps. Zero out MM for a bottoms up and verify TT line is clear if we have to divert returns outside. Seeing a little motor work at the top of the window, continue back ream at as mill TF until clean. Circ PSI = 3527 psi WOB = 0 k ECD = 10.27 ppg. WHP = 122 psi IAP = 852 psi OAP = 301 psi. Bottoms up was clean, no change in rate or density Last back ream was clean, shut down pump trapping 10.4 ECD for losses and then dry drift window. Dry drift down was clean. PU dry and window is clean, open the EDC and POOH for build BHA OOH, BHI & SDI still troubleshooting Gyro in the mouse hole on the rig floor. Circulate and maintain 10.2 ECD at the window while they troubleshoot not getting toolfaces on the fly The Gyro is working but we are not be able to get TF's on the fly and will have to stop drilling to generate a pumps off survey to get a current TF. We will need to control drill for about 40-50' to keep the reactive torque at a minimum while drilling blind/WO TF. LD BHA and undeploy milling BHA MPD Line is not reading pressure from the WB side and suspect an Ice Plug, line up to circulate down the coil to maintain 10.2 ECD at the window while thawing the MPD line. MPD line is thawed, circ a few bbls through it to make sure it's clear and warmed up. Line is good, continue with Undeploy. BHA OOH, Window Mill gauge 2.79 Go 2.78 No Go, String Mill Gauge 2.81 Go 2.80 No Go. PJSM with night crew then finish L/D BHA #1. Maintain 10.3# ECD at window with MPD pump while changeout BHA. Inspect 12' of CT above connector, nothing seen. Deploy BHA #2, build BHA with Gyro. M/U UQC and test Gyro / BHI comms in the stack. Move forward with deployment after good test. RIH BHA #2. Pump through open EDC. At 240' go to 1.8 bpm. Try 10.3# ECD at window: 1.8 / 1.8 bpm In / Out. 10.6# : 1.8 / 1.4 bpm. 10.74# : 1.8 / 1.0 bpm. Go back to 1 bpm keep 10.4# wile RIH. Tie-in depth from 6580'. Correct -10'. RIH to 6669' close EDC and get gyro survey. Pass through window and tag end of rathole 6688'. Get up wt + 3 ft, bring pumps to 1.7 bpm. CoilTrak bore pressure up to 5900 psi. Pull back through window and troubleshoot. Get another survey just above window. Pass through window to 6684' bring pumps up again. Ease down to 6688' and start drilling. Pressures are high but motor appears to be drilling. Drill from 6690'. 1.66 / 1.35 bpm @ 5200 psi FS. MW 8.61 / 8.59 ppg. ECD 10.48# with 190 psi WHP. Control drill with 1k DWOB to minimize TF swings. Drill to 6721'. Need survey here, PU and pump B/U. RIH back to 6720' shut down, shut in trap 10.5# wait for survey. Survey no good, try again 2x and get it. Continue drilling from 6720' to 6745'. Get another gyro survey at 6740'. Pump B/U then shut down, shut in trap 10.6# ECD. Good survey, continue drilling from 6745' to next survey point 6775'. 1.69 / 1..58 bpm @ 5130 psi FS. MW 8.61 / 8.60 ppg. ECD 10.49# with 165 psi WHP. Try 5 times at 6775' to get survey, not able to. Continue drilling from 6775'. 2/8/2022 Continue drilling build at 6832', holding 10.5 ECD at the window. Avg loss rate at ~10 bph, pits have plenty of mud in them and we have fluid ready at the mud plant. DLS f/6770' t/ 6830' 44-47° so we have backed off on the WOB and the trend line is showing ~42's now Build landed at 6936', dynamic flow check well to POOH. Geo Mad Pass log while POOH f/6828' to window for Resistivity. In Rate = 1.69 bpm Out Rate = 1.57 bpm Loss Rate = 7.2 bph. IAP = 1008 psi OAP = 309 psi. Mad Pass Log completed. Shut down pump to open EDC, open MPD Line and circ through it to verify it clear. Line is clear, line up down the coil and POOH pumping through the EDC. OOH, lost 6 bbls on TOOH. Flow check well, good no flown pressure undeploy the build BHA BHA OOH, bit grade is 1-2-CT. MU Lateral BHA with Agitator, 0.9° Bend Motor and 3.25" Bi-Center Bit. RIH with lateral BHA. Tie-in depth, correct -10.5'. Pick up and CCL log across liner top area. Close EDC. Pass through window no issues. Go to 0.5 bpm. RIH to bottom. Drill from 6936' to 7100'. 1.69 / 1.64 bpm @ 4000 psi FS. MW 8.65 / 8.62 ppg In / Out. ECD 10.50# at window with 150 psi WHP. ROP ~40 ft/hr with 2.5k DWOB. At 6973' pick up and purge Out MM with air. Pump 5 bbls lo / hi vis sweeps at 7090'. Pull 150' wiper from 7100', clean pass up and down. Drill from 7100' to 7250'. 1.69 / 1.54 bpm @ 4400 psi FS. MW 8.69 / 8.75 ppg In / Out. ECD 10.57# at window with 150 psi WHP. Pump 5 bbls lo / hi vis sweeps at 7220'. Pull 150' wiper trip from 7250'. Clean pass up and down. Drill from 7250' to 7400', 1.75 / 1.73 bpm @ 4350 psi FS. MW 8.69 / 8.78 ppg In / Out. ECD 10.66# at window with 150 psi WHP. Pump 5 bbls lo / hi vis sweeps at 7380'. Pull wiper trip from 7400'. Clean pass to window. Jog below window. Pull through window and open EDC. Pump 5 bbls lo / hi vis sweeps to surface 2.5 / 2.3 bpm. Tie-in depth correct +2'. Pump until returns clean, then close EDC, RIH. Log RA marker. Drill from 7400'. 1.82 / 1.78 bpm @ 4400 psi FS. MW 8.70 / 8.70 ppg In / Out. ECD 10.58# at window with 90 psi WHP. 50-029-23025-01-00API #: Well Name: Field: County/State: PBW L-116A Prudhoe Bay West Hilcorp Energy Company Composite Report , Alaska 2/9/2022 Continue drilling ahead at 7600' 7620' PU off bottom, ECD climbed from 10.6 to 11.2 ECD suspect well is loading up. Slow pulling speed for low and high vis pills coming out. About half way through a bottoms up the well unloaded a good amount of cuttings, RIH. Bottoms up from pills the brought another slug of cuttings All parameters look good and back to normal, continue drilling lateral at 7620'. FS psi = 4330 psi On BTM psi = 4580 psi ROP = 125 fph. In Rate = 1.71 bpm Out Rate = 1.68 bpm. WHP = 62 psi ECD = 10.58 ppg IAP = 1324 psi OAP = 312 psi Drilled 450' to 7850', wiper trip to window. Clean trip to the window. Open the EDC, wash down across the WS then pull back into the CSG and pump a bottoms up. Correct depth +1', close EDC and RIH Back on bottom drilling at 7850'. Free Spin psi = 4241 On BTM psi = 4382psi ROP = 55fph. In Rate = 1.86 bpm Out Rate = 1.69 bpm. WHP = 89psi ECD = 10.63 ppg IAP = 1265psi OAP = 312psi. 13:30 Drilled to 8000', short 150' wiper. 15:00 Drilled to 8150' short 150' wiper Drilled 450' to 8300' long wiper to the window. Jog below window then pull into CSG, open EDC and circ at max rate for bottoms up. 2.5 BPM at 11.09 ECD. PLC is having problems keeping constant data supplied for PVT and WITS feed and need to swap cables. Bottoms up is clean, close choke trapping 760 psi to maintain 11.0 ECD while allowing rig electrician to swap PLC Cables. New cable did not work, continue manual straps. Allow rig mechanic to tighten a coupler on one of the Right-Angle Drives on the injector. Log Tie-In. Correct +1'. Jet across window @ 2bpm. Close EDC and continue wiper trip to resume drilling Back on bottom drilling at 8300'. Free Spin psi = 4700 On BTM psi = 4911psi ROP = 100-150fph. In Rate = 1.84 bpm Out Rate = 1.65 bpm. WHP = 242 psi ECD = 11.2 ppg IAP = 910 psi OAP = 313psi. 21:00. Drilled to 8450', short 150' wiper. 23:00 Drilled to 8600' short 150' wiper. 00:30 Drilled to 8750' Drilled 450' to 8750' long wiper to window. Log Tie-In and correct +1'. Jet window and tray at max rate with open EDC. Close EDC and RIH to resume drilling Back on bottom drilling at 8750'. Free Spin psi = 4683 On BTM psi = 4911psi ROP = 100-150fph. In Rate = 1.88 bpm Out Rate = 1.83 bpm. WHP = 237 psi ECD = 11.2 ppg IAP = 1064 psi OAP = 309 psi. 05:30 Drilled to 8900', short 150' wiper. 2/10/2022 Continue drilling as per plan at 9040'. In Rate = 1.8 bpm Out Rate = 1.8 bpm ROP = 90 120 fph. MWT in = 8.64 ppg Out MWT = 8.66 ppg. ECD = 11.24 ppg IAP = 1169 psi OAP = 310 psi. Drilled 450' to 9200', perform long wiper to the window. Jog below the window, PU above window at min rate, shut down pump and open the EDC. EDC open, pump at max rate to 11.2 ECD. Bottoms up is clean, start walking ECD up to 11.5 ppg in stages to see if we will incur any losses with the 11.5 KWF.11.3 ECD = 0.1 bpm loss rate = 6 bph. 11.4 ECD = 0.2 bpm loss rate = 12 bph. 11.5 ECD = 0.4 bpm loss rate = 24 bph Log tie in, correct depth +3'. Allow Nabors electrician to swap out the PLC Computer to see if it fixes our PLC issues New PC did not work, close EDC and RIH to continue drilling Back on bottom drilling at 9200'. In Rate = 1.75 bpm Out Rate = 1.6 bpm ROP = 30 fph. MWT in = 8.58 ppg Out MWT = 8.65 ppg. ECD = 11.26 ppg IAP = 946 psi OAP = 299 psi Drilled to 9226' in shale, Geo's called TD. PU and RIH for DD to get on bottom survey then wiper to window. Pull above window, open EDC, circ a bottoms up then POOH chasing pills. At surface, RIH pumping max rate. Log Tie-In pass. Correct +8'. Wiper trip to bottom to confirm/correct TD. Tag and confirm bottom at 9227'. PUH and begin pumping liner running pill. Lay in liner running pill to 6900'. Pump KWF until good returns noted at surface. Flow check well. No flow. 5 bbls to fill well after 30 minutes for ~ 10 bph loss rate. POOH. Paint yellow flag @ 6378.2'. EOP = 6300'. Paint white flag @ 3878.2' EOP = 3800'. OOH - Flow check well. ~ 5 bph loss rate. LD Lateral drilling BHA. Bit graded 1-1. Function Test BOP's. Final verification of liner tally and running order. Clean and clear rig floor. 2/11/2022 MU liner as per plan, well taking 5 bph fill the well and pipe every 10 jts or 30 min. 85 of 96 jts of 2-3/8" liner will be ran 85 jts MU, 11 jts in PS, MU Liner Running Tools. MU Injector to the liner. RIH with liner pumping at min rate down the coil. 100' in the hole and we are not seeing any returns. Line up across the top to fill the well, it looks like we might be pushing fluid away with the liner Stop at 3800' EOP Flag (6565.37 elec) and add 2752.45'. Correct to 6552.45' -12.92' correction. RIH to 6665', line up down the coil and displace well to drilling mud. In Rate = 1.05 bpm Out Rate = 0.45 bpm, restriction from liner causing losses. Increased rate to 1.5 bpm in and only gained 0.1 bpm Back rate down to 1.0 bpm, ECD = 11.22 ppg. Mud to surface, In Rate = 1.0 bpm WHP = 270 psi ECD = 11.21 ppg. Shut down the pump and trap 450 psi WHP, ECD = 11.41 ppg. WT CK with pumps off = 29k, RIH WT = 19k. RIH with liner pumping at 0.2 bpm maintaining 11.2 ECD at the window. Set down at 8471', PU WAT = 38k, RIH, set down at 8466' several times at varying depth. Made it past to 8501' and set down again, online at 1.0 bpm to clean up OH a little then try RIH again Continue working liner down at 8620'. Work liner down to final setting depth of 9180'. Pick up weight 45k. Release from liner per NS rep @ 1.5 bpm. Line up to swap well back over to 11.2ppg KWF. KWF to surface. Flow check well. ~ 8bph loss rate POOH keeping hole full. Flow check well at surface LD LRT and BHA. Prep to pump eline slack. MU 1 jt 2 1/16" CSH and pump slack forward. Cut and recover 205' of eline. Prep to pump 5/8" ball. Pump and recover 5/8" ball. Clean and clear rig floor. Prep for running 1" CSH cement stinger BHA. 2/12/2022 MU 1" CSH Work String. Rattle each joint for scale & rust. Well taking ~6 bph, fill hole every 30 min. RU Head Pin every 30 joints to flush excess scale & rust All CSH ran and pumped through. MU upper BHA with 2-1/16" CSH & MHA RIH with CMT BHA. Displace coil to 1% KCL @ 9150'. Returns 1:1. Displace liner to KCL. Establish PUW of 30k. RIH to engage ORCA valve. See initial seal engage @ 9172'. Set 10k down at 9176'. Pressure up to 3700 psi and see shear disc rupture. Continue displacing until KCL returns noted at surface. Establish 1:1 returns @ 1bpm with 500 psi WHP. 3612 psi circ. 1:1 returns @ 1.4 bpm with 500 psi WHP and 4500 psi circ. Confirm density and rate equivalent through cement micro motion. PJSM with cement supervisor, Nabors, Worley truck pusher Pump 15 bbl fresh water to pressure test cement lines. PT to 4700 psi. Pump 19.3 bbls 15.3ppg Class G cement followed by 5 bbl fresh water. Chase with 100 bbl PowerPro contam pill. Shut down pumps @ 57.5 bbls and unsting from ORCA. 33k PUW. Displace 3.3 bbls of remaining cement. Cement in place @ 1 Displace/contaminate @ .7 bpm and 2660 psi. Unable to get any higher rates without returns falling off. POOH @ 20 fpm contaminating cement. Slowly increase rate to 1.25 bpm and 3461 psi with 1:1 returns. Continue reciprocating in liner. Final pass with PowerVis from 9162' (10' from ORCA) Continue reciprocating in liner displacing well to 1% KCL @ 1.4 bpm with 1:1 returns. Wait on cement to reach 500 psi compressive strength. 2/13/2022 Continue circulating to allow CMT compressive to reach 500psi before swapping to 11.2 KWF CMT should be at 500 psi compressive strength based on the lab report. Swap coil to KWF and displace to surface KWF at surface, shut down pump and flow check well for 30-min Good no flow, fill well, no losses, POOH to LD the 1" CSH OOH, flow check well for 10-min. Good No Flow, PU injector, fill the hole, LD the upper BHA and 1" CSH Lost power both Gen #1 & #2 down, secure well with floor valve, monitor shaker for returns 48.5 bbls in active pit. Power restored by bringing Gen #3 while troubleshooting Gens #1 & #2. Error code showed loss of fuel pressure. Elevators won't latch, swap elevators, continue pulling 1" Continue pulling and LD 1" CSH LD last joint and cement stinger. Clear and clean rig floor. MU and RIH with swizzle stick to jet stack. Pump reverse slack in coil. Confirm eline moving. Cut 243' of coil and did not find eline. MU Nabors internal coil connector. Pull test to 50k. Pressure test to 5200 psi. Line up to pump slack forward with KWF. Did not move eline. Pump 5' of eline out coil. Rehead BHI. Work liner down to final setting depth of 9180'. Pump 19.3 bbls 15.3ppg Class G cement followed by 5 bbl fresh water. Chase with 100 bbl PowerPro contam pill. Shut down pumps @ 57.5 bbls and unsting from ORCA. 33k PUW. Displace 3.3 bbls of remaining cement. Cement in place @ 1 Displace/contaminate @ .7 bpm and 2660 psi. 2/14/2022 Continue to head up BHI UQC (Upper Quick Connect). Change out Packoff's, UQC MU. MU Nozzle BHA with floats, stab on well, closed S&M Valves. PT Floats and Packoff's Good PT, bleed of pressure, displace fresh water in coil over to KWF. Coil swapped to KWF, open S&M Valves and RIH pumping slack forward. Tag TOL at 6473', swap to 1% Slick KCl, PU and retag. Tag same depth. PU 10' and displace well to KCl 1:1 returns. Well swapped to KCl KCl at surface, 1:1 returns POOH. 4500' swap to diesel down the coil. Having trouble getting prime. Out rate started increasing, close choke WHP at 305p (but pump was shutting down when choke was closed) WHP = 305 psi, bleed off 0.5 bbls. WHP built up to 273psi, bleed off 0.75 bbls pressure came back up to 274psi. Using 8.6ppg fluid 6600 Datum and 274psi WHP, BHP = 9.39ppg equivalent. Discuss plan forward with Drilling Manager to run in hole, circ a bottoms up holding 350psi (9.6ppg equiv) and POOH RIH, tag at 6470'. Increase rate and circ bottoms up holding 350psi WHP. Out density is increasing a little to 9.2ppg, might be a little breathing the OE discussed at the beginning of the well as a potential. Bottoms up is clean, no gas just the increase in density then came back down Pump 50% excess with clean returns, POOH to FP well holding 350psi. Online with diesel, diesel at nozzle POOH laying in holding 575psi WH. OOH. Secure well. Jet stack. Service all tree valves with grease crew. Clear and clean rig floor. ND Managed Pressure line. ND BOP stack. Troubleshoot BHI continuity issues. Continue working on RDMO checklist. 2/15/2022 ND BOP Stack. Fluid pack tree cap above swab with MeOH. PT tree cap to 3500 psi. Good. Continue RDMO checklist. Clean pits. General rig repair and painting. Rig Release 06:00. ACTIVITYDATE SUMMARY 2/18/2022 Remove CDR Kill line and tapped blind flange. Install tree cap assembly and companion flange. Torque to API specs. 3/28/2022 T/I/O=431/04/268 Pressure test TBG to 4000 psi. Pumped 21 bbls DSL down tbg. could not achieve test pressure, LLR of 1450 psi @ 1 bpm and 1850 psi @ 2bpm. shut down and monitor for 20 min pressure fell off to 837 psi. Final WHP's 817/1/261 Pad op notified on departure 4/3/2022 ***WELL S/I ON ARRIVAL***( set liner top packer) B&F TUBING/DEPLOYMENT SLEEVE W/ 3 1/2" BRUSH, 2.50" CENT, 2 3/8" BRUSH @ 6,459' SLM (lrs pumped 100bbls of crude) RAN 10' x 2.74" DUMMY WHIP STOCK & DUMMY PTSA TO 6,458' SLM(good) SET 3 1/2" MONO-PAK LINER TOP PACKER IN DEPLOYMENT SLEEVE @ 6,471' MD LRS UNABLE TO GET PASSING 2500psi MIT-T ***CONT WSR ON 4/4/22*** 4/3/2022 T/I/O= 936/VAC/260 TEMP= SI ( LRS UNIT 72) ** S/L ASSIST ** SET LINER TOP PACKER ** PUMPED 100 BBLS CRUDE DOWN TBG TO LOAD WELL AND ASSIST IN BRUSH IN FLUSH. Pumped 4 bbls crude to pressure TBG to 2750 ***job continued to 04-04-22*** 4/4/2022 T/I/O= 1139/VAC/260 TEMP = S/I ( LRS UNIT 72) S/L ASSIST ** LINER TOP PACKER** MIT- T to 2500 PSI ( 2750 PSI MAX APPLIED) ** PASS** PUMPED 1 BBLS CRUDE DOWN TBG TO REACH TEST PRESSURE. SEE LOG FOR DETAILS. BLED TBG TO 1000 PSI (~1 BBLS) S/L IN CONTROL OF WELL UPON DEPARTURE. TAG HUNG ON WV . 4/4/2022 ***job continued from 04-03-22*** No fluids pumped, called off for Rig work 4/4/2022 ***CONT WSR FROM 4/3/22*** (fracturing) RAN 3 1/2" LTTP TO NS MONO-PAK LTP @ 6,454' SLM (MIT-T 2636# pass) PULL GUTTED 1.781" RSG FROM INSIDE LTP @ 6463' SLM(closed liner-no perfs) SET 1.781" RR PLUG @ 6463' SLM (MIT-T pass) PULL 1.781" RR PLUG @ 6463' SLM ***JOB COMPLETE, WELL SECURE, PAD OP NOTIFIED*** 4/24/2022 ***Well S/I On Arrival*** Coil Unit #6 1.5" Coil Tubing - Job Scope - Log/Perf/Frac Support MIRU CTU6. C/O packoffs. Make up Read logging BHA & RIH. Tag TD 9155 ctmd. Log up to 6350 ctmd. POOH w/BHA. Good data at surface, 12.5' correction. Corrected EOP = 9,097.11'. MU HES & RIH w/ 1.56" Millennium perf gun (60 degree phasing, 6 spf, 1.76" swell). At flag, correct counter to bottom shot = 9,121.92' MD. Tag bottom lightly and pu to neutral. Load & launch 1/2" ball. Perforate interval 9,144' MD - 9,164' MD. Pooh w/BHA. Establish injectivity down tubing w/diesel 1 bpm, broke over 2380 psi. On surface w/spent guns. Install night cap. ***Continued on 4/25/22*** 4/25/2022 ***SLB Frac Crew*** Job Scope = Stage 1 Frac - Perform passing low/high pressure test to 8900 psi. Daily Report of Well Operations PBU L-116A Daily Report of Well Operations PBU L-116A 4/25/2022 ***Job continued from 4/24/22*** Coil Unit #6 1.5" Coil Tubing - Job Scope - Log/Perf/Frac Support - 4 stages Injectivity test w/SL KCI 1.2 bpm @ 2800 psi. 3.4 bpm @ 2952 psi. Freeze protect tubing w/26 bbls of diesel (3000' TVD). Final WHP = 520 psi. Stack down risers, injector head. N/D BOP stack, lay down mast. Move CTU6 forward from well to allow Frac access for tree saver / stand pipe. Standby for Frac Stage 1. MIRU CTU6. Make up FCO BHA = 1.75" JSN. RIH w/BHA. ***Job continued on 4/26/22*** 4/25/2022 LRS 70 Frac Support: Heat and tranfer 90 bbls dsl to 90*, Hold backside pressure. 4/26/2022 ***Job continued from 4/25/22*** Coil Unit #6 1.5" Coil Tubing - Job Scope - Log/Perf/Frac Support - 4 stages RIH w/BHA. Dry tag fill 6,835' ctm. PUH and establish circulation 1:1 returns. Begin cleanout 6,835' ctm, maintain 450 psi on choke to minimize solids influx. Cleanout proppant 6,835' ctm - 9,165' ctm. Paint green flag. Corrected EOP = 9,040.38' MD. Pooh w/BHA pumping. Weights clean through 2-3/8" Liner. FP coil & tubing while Pooh. M/U NS CBP BHA & RIH. At the flag, correlate to COE of 9050.7', no depth change required. Set the plug 9090' COE. Attempt to test plug, establish injection rate of 1385 psi @ 1 bpm. Pooh w/BHA. Discuss plan forward w/OE. M/U FCO BHA & RIH, cleanout 2-3/8" Liner from 6,783' - 9,090'. Pooh w/BHA pumping. FP coil & tubing. ***Continued on 4/27/22 WSR*** 4/27/2022 ***Job continued from 4/26/22*** Job Scope: Frac Support Continue Pooh w/FCO BHA pumping to surface w/JSN. M/U Northern Solutions 2- 3/8" CBP BHA & RIH. Tagged CBP @ 9,090'. Set 2nd CBP @ 9,084'. Attempt to MIT- T, establish injectivity down tubing .3 bpm @ 700 psi. Possible LTP leaking. Pooh w/ BHA pumping pipe displacement. Perform injectivity test at surface. 0.5 bpm at 950 psi and 1 bpm at 1350 psi. Decision made to run STP log. Call out Read Logging Tools. RIH w/ Read STP Tools. Log Baseline Pass down to 9050' ctm. Log 60fpm up/down pass from 9050' up to 6100'. Stop Counts at 9050', 6900', 6550' & 6100'. Pooh. ***Continue Job on 4/28/22 WSR*** 4/27/2022 ***STANDBY FOR COIL ASSIST*** (fracturing) 4/27/2022 ***Job continued from 4/26/22*** Job Scope: Frac Support Continue Pooh w/FCO BHA pumping to surface w/JSN. M/U Northern Solutions 2- 3/8" CBP BHA & RIH. Tagged CBP @ 9,090'. Set 2nd CBP @ 9,084'. Attempt to MIT- T, establish injectivity down tubing .3 bpm @ 700 psi. Possible LTP leaking. Pooh w/ BHA pumping pipe displacement. Perform injectivity test at surface. 0.5 bpm at 950 psi and 1 bpm at 1350 psi. Decision made to run STP log. Call out Read Logging Tools. RIH w/ Read STP Tools. Log Baseline Pass down to 9050' ctm. Log 60fpm up/down pass from 9050' up to 6100'. Stop Counts at 9050', 6900', 6550' & 6100'. Pooh. ***Continue Job on 4/28/22 WSR*** 4/28/2022 ***Job continued form 4/27/22*** Job Scope: Frac Support STP log shows LTP leaking and anomoly around whipstock/window depth. Decision form OE to turn over to SL . Decision from SLB to rig down and bring to shop to swap out injector head. ***Job Not Complete / Coil will Return*** 4/28/2022 T/I/O= 500/0/250 (Assist Slickline) TFS U-3, Assist SL with Trouble shooting LTP. Pumped 16 bbls cude to Achieve LLR of 0.5 BPM @ 1150 psi. Load TBG with 3 bbls 50/50 followed by 17 bbls 1% KCL. ***Job continued on 04/29/2022*** Daily Report of Well Operations PBU L-116A 4/28/2022 ***WELL S/I UPON ARRIVAL*** (fracturing) SET 3-1/2" LTTP IN 3-1/2" NS LTP @ 6471' MD. THUNDERBIRD TESTED LTTP IN LTP.(see log) SET 1.78" RR PLUG IN RR-NIPPLE IN LTP @ 6471' MD. THUNDERBIRD PERFORMED INJECTIVITY TEST @ 1 BPM/1300psi & .5 BPM/1150psi. PULLED 1.78" RR PLUG FROM LTP @ 6471' MD. MADE 1 ATTEMPT TO PULL NS 3 1/2" MONO-PAK LTP FROM 6,455' SLM (jar 1hr) ***CONT WSR ON 4/29/22*** 4/29/2022 ***CONT WSR FROM 4/28/22*** (fracturing) JARRED ON LTP @ 6,471' MD FOR 7hrs (8hrs total jar time) THUNDERBIRD ASSISTED W/ PUMPING (see t-bird log for details) ***CONT WSR ON 4/30/22*** 4/29/2022 ***Job Continued from 04/28/2022*** Assist SL (Pulling Liner Top) Pumped a total of 546 bbls 1% KCL and 69 bbls 50/50 meth to assist SL. Tag hung on WV. SL in Control of well @ departure. FWHP=550/0/250 4/30/2022 ***Job Continued from 4/28/22*** Job Scope: Frac Support MIRU CTU. Perform weekly BOP test. MU 2 1/8" BOT fishing assembly with 3'' GS. Drop 6 SBG sticks on the swab and chase them down. Latch LTP at 6454'. Hit 24 jar licks, no movement. Pump off fish. Pump 45 bbls 1%KCL w/SL down backside. Resume jarring ***Continue job on 5-1-22*** 4/30/2022 ***CONT WSR FROM 4/29/22*** (fracturing) RD HES 759 SLICKLINE UNIT ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** 5/1/2022 *** Continue Job from 4/30/22*** Job Scope - Support Frac Continued to Jar on LTP with no success. Performed pipe management. Swap tools to BOT Hip-Tripper. Latched LTP 6450' ctmd. Hip-Tripped for 30 miutes with no movement. Hit 50 jar licks with no success in moving the LTP. FP coil and tubing. Tools look good at surface. Load fluids for Cement Squeeze. ***Job in Progress*** 5/2/2022 ***Continue Job from 5/1/22 WSR*** RIH w/ 1.50" BDJSN. Take pipe displacement returns to formation while RIH. Lay in PowerVis from 7800' up to TOL at 6471'. Rig up HES Cementers. Pump 10.5 bbls of 15.8 ppg cement with choke closed. Parked at 6440' ctmd. Pumped 5 bbls out and started hesitation squeezing. At 8 bbls out the nozzle acheived 2000 psi squeeze. Bled pressure back and laid in the the last 2.5 bbls of cement. Contaminated and chased from 7300' ctmd. Chased out of hole washing the jewelry. Washed BOP's and freeze protected the coil. RIH and laid in diesel from 2000' to surface. Wait on compressive strength. RIH w/1.75 JSN. Tag CBP at 9084.8'. Correct depth to 9084' (CBP depth). Pooh. Flagged Pipe at 8600'. Corrected EOP at Flag= 8590.03'. Pooh pumping pipe displacement. ***Job Continued on 5/3/22*** 5/3/2022 ** FRAC** Unit 46 LRS Heat frac tanks to 110* and Diesel transport to 90*. 5/3/2022 ***Job Continued from 5-2-22*** Continue Pooh pumping pipe displacement. At surface, Pressure Test cement squeeze to 3000 psi. Passed. Lost 154 psi in 1st 15 min & 30psi in 2nd 15 mins. MU & RIH w/ HES 1.56" x 20' Perf Gun. Tie into top shot at the flag. Shoot perf interval 8651-8671. Rig unit down and pull forward for the next Frac stage. ***Job Continued on 5-4-22*** 5/4/2022 Assist frac. LRS Unit 46 Holding IA pressure on back side. Pumped 5 bbls out andg started hesitation squeezing. A Daily Report of Well Operations PBU L-116A 5/4/2022 SLB FRAC L-116A Kuparuk C Sand - Stage 2 of 4 LRS connect upstream of PRV skid. Confirm PRVs are set to 3800psi. Bring IA pressure up to 3,500 psi and hold. OA - maintained an open bleed. Pump fresh water at 4 BPM at 3359 psi for injectivity test. Pump fresh water at 11.4 BPM at 5962 psi. Perform hard shut down: ISIP 2895psi. Pump crosslinked gel (pad) at 19.2 BPM at 5991 psi. 100bbl Pump .5 ppa scour at 20 BPM 5865 psi with xlink throughout Tubing. 100bbl Pump crosslinked gel (pad) at 20 BPM at 6102 psi. 100bbl Pump 1 ppa stage of 16/20 carbolite at 19.7 BPM 5701 psi with xlink gel. 50bbl Pump 2 ppa stage of 16/20 carbolite at 19.7 BPM 5649 psi with xlink gel. 50bbl Pump 3 ppa stage of 16/20 carbolite at 19.6 BPM 5535 psi with xlink gel. 100bbl Pump 4 ppa stage of 16/20 carbolite at 17.9 BPM 5299 psi with xlink gel. 100bbl Pump 5 ppa stage of 16/20 carbolite at 17.9 BPM 5238 psi with xlink gel. 100bbl Pump 6 ppa stage of 16/20 carbolite at 17.6 BPM 5332 psi with xlink gel. 100bbl Pump 7 ppa stage of 16/20 carbobond at 17.6 BPM 5480 psi with xlink gel. 50bbl Pump 8 ppa stage of 16/20 carbobond at 17.7 BPM 5845 psi with xlink gel. 50bbl Pump crosslinked gel flush at 18.2 BPM at 6251 psi. 26bbl Pump diesel flush at 10 & 5 BPM at 4550 psi. 34bbl Frac pumped with 5bbl underdisplaced. Top of sand (CarboBond) 7369MD. Net pressure observed: 35 psi. Proppant in formation: 94,242 lbs Proppant left in LNR: 1,564 lbs Hand over to coil to prep for stage #3. ***Stage #2 complete*** 5/4/2022 ***Job Continued from 5-3-22*** Job Scope - Frac Support Standby for the next Frac stage. Completed stage 2 stage of frac. MIRU CT unit. MU NS FCO BHA. RIH with 1.75"JSN. Tag sand at 6881' and cleanout to 8350'. Paint White flag @8287'. POOH pumping. ***Job Continued on 5-5-22*** 5/5/2022 CTU #6 1.5" CT ***Job Continued from 5-4-22*** Job Scope - Frac Support Cleanout to 8350'. Paint White flag @8287'. MU NS 2 3/8" CBP BHA and RIH. Correct depth at flag to ME of plug at 8308.3' , PU and set CBP at 8,300' ME (top of plug 8299.34'). PUH and attempt to test plug to 3,000psi, but pressure would not hold above 2550psi. POOH and lay down setting tool. Pressure test CBP and found inital LLR of .32BPM at 2,815psi. Troubleshoot surface lines and did not find a leak. Re-attempt MIT of CBP and LLR was too small to establish at 3,000psi. Consult with OE and decided to increase injection pressure to 4,000psi. Well started taking fluid at .3bpm @3,500psi. OE wanted to pump LCM pill down hole to try and seal leak. Pumped 3/4 of a bag of nut plug to the leak, saw a 4,200psi pressure spike at ~43bbls away, continued to displace LCM to the final 56bbl volume. Inital injection was 1.1BPM at 3900psi and final injectivity was .25BPM at 4,250psi. OE decided to skip stage 3 frac and proceed with stage 4. Pop off well and lay down nozzle BHA. PU HES 1.56"x20' gun, RIH and perforate 7390-7410'. POOH and lay down perf gun. ***Job Continued on 5-6-22*** Daily Report of Well Operations PBU L-116A 5/6/2022 T/I/O=CTU/SI Assist CTU with Acid Job (FRACTURING) Pumped 15.5 bbls 15% HCL followed by 5 bbls FW and 3 bbls meth down CT. CTU on well upon departure. CVs OTG FWHP=CTU 5/6/2022 CTU #6 1.5" CT ***Job Continued from 5-5-22*** Job Scope - Frac Support Perforated 7390-7410'. POOH and lay down perf gun. Gun fired and 1/2" ball recovered, Attempt injectivity test, but could only get 0.2bpm at 4500 psi. Contact OE to discuss. OE decides to re-perf in different location. Cut pipe, MU NS connector and MHA. MU HES 1.56" x 20' gun and RIH. Contact OE for new perf location. RIH and perforate 7490-7510'. PUH and perform injectivity test .5BPM at 4,250psi. POOH with perf guns. Consult with OE and decided to make a cleanout run then acidize the perfs. MU nozzle BHA, RIH and FCO from 8284' to surface, jet perfs while POOH. Pumped 10bbbl gel pill on bottom and chased OOH. Wash BOPs. Perform Injectivity test 2.6 bpm at 4100 psi. RIH pumping min rate down CT maintaining 800 psi WHP. Rig up LRS w/SLB 15% HCL and pump into CT. Lay 5 bbl across perfs 7490-7510, let soak 15 min and inject down CTBS 2.2 bpm at 3300 psi. ***Job Continued on 5-7-22*** 5/6/2022 LRS Heat DSL on SLB transport to 90* for Frac. 5/7/2022 SLB FRAC L-116A Kuparuk Sand - Stage 4 of 4 (stage 3 not done) LRS connect to PRV skid, test PRVs to 3,800psi - good. Pump fresh water at 18BPM at 6,248psi Shut down and monitor - ISIP 2,900psi Pump crosslinked gel (pad) at 20 BPM at 6200 psi. 126bbl Pump .5 ppa scour at 20 BPM 5865 psi with xlink throughout Tubing. 100bbl Pump crosslinked gel (pad) at 20 BPM at 6102 psi. 100bbl Pump 1 ppa stage of 16/20 carbolite at 18 BPM 5537 psi with xlink gel. 50bbl Pump 2 ppa stage of 16/20 carbolite at 18 BPM 4926 psi with xlink gel. 50bbl Pump 3 ppa stage of 16/20 carbolite at 18 BPM 4568 psi with xlink gel. 100bbl Pump 4 ppa stage of 16/20 carbolite at 18 BPM 4412 psi with xlink gel. 69bbl OE was concerned that we were fracing the heel and cut sand early Pump cosslinked gel flush 18 BPM 4300psi 20bbl Pump diesel flush at 18 BPM at 4200 psi. 32bbl Frac pumped with 5bbl underdisplaced. Top of sand (CarboBond) 6308MD. Proppant in formation: 26303 lbs Proppant left in LNR: 714 lbs Daily Report of Well Operations PBU L-116A 5/7/2022 CTU #6 1.5" CT ***Job Continued from 5-6-22*** Job Scope - Frac Support Continue with acid treatment of perforations. Lay 5 bbl 15% HCL across perfs 7490- 7510, Let soak 15 min and inject down CTBS 3.0 bpm at 3600 psi. Lay final 5 bbls accross perforations and POOH above liner top. Perform injectivity test down CTBS, 3.4 bpm at 3200 psi. RIH to 7600' clean out sump and POOH pumping pipe displacement and FP coil. FP well, RDMO coil foward for frac job. Oilstates leaves 2 elements from Tree Saver in well after frac. SL rig up and try to recover elements. Move CT and stand up mast and perform weekly BOP test. SL recover 1 complete element from on top of master valve. ***Job Continued on 5-8-22*** 5/7/2022 ***WELL S/I ON ARRIVAL*** FISH ONE ELEMENT IN TWO PIECES OFF MASTER VALVE IN TREE ***CONT WSR ON 05/08/2022*** 5/7/2022 ** ASSIST FRAC ** Hold pressure on IA between 3500 psi. and 3800 psi. Frac still on well at time of departure. 5/8/2022 ***CONT WSR FROM 05/07/2022*** FISH OUT THIN PIECE OF ELEMENT FROM 20' SLM W/ 3-1/2" BLB, 2-7/8" BLB RAN 3-1/2" BLB, 2-7/8" BLB TO SSSV NIP @ 2,202' MD RECOVERED NOTHING RAN 3-1/2" BLB, 2.67" WIRE GRAB TO DEP SLEEVE @ 6,471' MD RECOVERED SMALL PIECES ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED ON WELL STATUS*** 5/8/2022 CTU #6 1.5" CT ***Job Continued from 5-7-22*** Job Scope - Frac Support Oilstates left 2 elements from he Tree Saver in the well after the frac. SL rigged up and tried to recover elements. Move CT and stand up mast and perform weekly BOP test. SL recover what appears to be 1 complete element and a portion of the 2nd, from on top of the master valve. Complete weekly BOP test and lay down mast. SL made 2 more runs and retrieved a strip of element and some pieces. RD SL and MIRU CT. MU BOT milling BHA and RIH, Tag up near LTP. Rolled pumps to get into liner but had a stall 2' in. Time milled through liner top packer to get in liner. Cleaned out from 6,471'- 9086' thru 1st CBP at 8284. Unable to mill thru 2nd CBP at 9084. Stacking weight but no motor stall. Tried several wiper trips with gel sweeps to clean out the welbore to be able to get weight transfer. ***Job Continued on 5-9-22*** Daily Report of Well Operations PBU L-116A 5/9/2022 CTU #6 1.5" CT ***Job Continued from 5-8-22*** Job Scope - Frac Support Continue cleanout and mill CBP at 8300', 9084, and 9090', Stacking weight/hydraulicing off last plug. Make wiper trip out of liner and pump another gel sweep to remove debris that may be preventing weight transfer. RIH to CBP, and able to get weight to just above plugs. Stack weight and try to mill/stall motor, but unable to stall. POOH to check tools. Motor and mill in good condition, some marks on OD of mill and bit box, but matrix and carbide in good condiion. MU 1.75" venturi burn shoe and RIH. Tagged CBP at 9095' CTMD mill CBPs and push to bottom at 9,160'. POOH ***Job Completed*** WELL Date : Shoe @ FC @ :Top Lin Type: Type : Type : Type : Type : Yes X No Yes No Yes No X Yes No Yes No Date : 15 PBW L-116A CEMENT REPORT 44604 Hole Size :3.25"Casing Size :2 3/8" 15.3 Yield : 1.23 Sacks : 88 Mixing / Pumping Rate (bpm) : 1/0.7 Density (ppg) :Class G Volume (bbls): 19.3 Tail Slurry Volume (bbls) : Density (ppg) : Yield :Sacks : Mixing / Pumping Rate (bpm) : Bump press : Volume : Displacement : PowerPro Density (ppg) : 8.5 Rate (bpm) : 1.25 Volume (actual / calculated) : 100/100 Density (ppg) : Rate (bpm) : 6471 Method Used To Determine TOC :Calculated / Cement returned from liner top. N/A Casing Rotated? Reciprocated? % Returns during job : 100 Cement returns to surface? Spacer returns? Vol to Sur : FCP (psi) : 2660 Pump used for disp : Rig Pump(GD) Fresh Water Cement In Place At : 13:00 2/12/22 Estimated TOC : Plug Bumped? Post Flush (Spacer) Lead Slurry Density (ppg) : 8.4 Volume pumped (bbls) : Volume lost during displacement ( 0.5 Remarks:FIRST STAGE9180 9165 6471 Preflush (Spacer) Calculated / Cement returned from liner top. Vert Uncert 1sd[ft]0.003.00Start MDEnd MDSurvey Date[ft][ft]28.506649.6102/18/226649.616708.5602/18/226708.569227.0002/18/22MDInclinationAzimuthTVDTVDSSNorthEastGrid EastGrid NorthLatitudeLongitudeDLSToolfaceBuild RateTurn RateVert SectComments[ft][°][°][ft][ft][ft][ft][US ft][US ft][°/100ft][°][°/100ft][°/100ft][ft]0.00 0.00 163.68 0.00 -76.70 0.00 0.00 583173.75 5978093.86 70°21'0.4380"N149°19'29.0152"W0.00 0 0.00 0.00 0.0028.50 0.00 163.68 28.50 -48.20 0.00 0.00 583173.75 5978093.86 70°21'0.4380"N149°19'29.0152"W0.00 0 0.00 0.00 0.00107.23 0.19 163.68 107.23 30.53 -0.13 0.04 583173.79 5978093.74 70°21'0.4367"N149°19'29.0141"W0.24 0 0.24 0.00 -0.06194.21 0.23 163.68 194.21 117.51 -0.43 0.13 583173.88 5978093.43 70°21'0.4337"N149°19'29.0115"W0.05 -172.281 0.05 0.00 -0.20304.37 0.46 355.25 304.37 227.67 -0.20 0.15 583173.90 5978093.66 70°21'0.4360"N149°19'29.0107"W0.62 -48.494 0.21 -152.90 -0.03407.70 0.65 338.76 407.69 330.99 0.76 -0.09 583173.65 5978094.62 70°21'0.4454"N149°19'29.0179"W0.24 -6.659 0.18 -15.96 0.44502.87 1.56 334.87 502.84 426.14 2.43 -0.84 583172.88 5978096.28 70°21'0.4619"N149°19'29.0397"W0.96 30.79 0.96 -4.09 1.03594.37 2.22 344.58 594.29 517.59 5.27 -1.84 583171.85 5978099.11 70°21'0.4898"N149°19'29.0689"W0.80 28.184 0.72 10.61 2.22689.49 2.73 350.18 689.33 612.63 9.28 -2.72 583170.93 5978103.11 70°21'0.5292"N149°19'29.0946"W0.59 6.321 0.54 5.89 4.29780.72 3.73 351.88 780.41 703.71 14.36 -3.51 583170.08 5978108.17 70°21'0.5792"N149°19'29.1176"W1.10 7.038 1.10 1.86 7.16845.59 5.60 354.24 845.06 768.36 19.59 -4.12 583169.41 5978113.41 70°21'0.6307"N149°19'29.1356"W2.90 2.91 2.88 3.64 10.26937.42 6.73 354.73 936.36 859.66 29.41 -5.07 583168.36 5978123.21 70°21'0.7272"N149°19'29.1632"W1.23 -67.029 1.23 0.53 16.221029.80 7.23 346.66 1028.06 951.36 40.46 -6.90 583166.40 5978134.23 70°21'0.8359"N149°19'29.2169"W1.19 -67.913 0.54 -8.74 22.361125.06 8.31 332.41 1122.45 1045.75 52.39 -11.48 583161.69 5978146.12 70°21'0.9532"N149°19'29.3506"W2.31 -14.195 1.13 -14.96 27.091218.30 9.91 330.07 1214.51 1137.81 65.32 -18.60 583154.43 5978158.96 70°21'1.0804"N149°19'29.5588"W1.76 -51.811 1.72 -2.51 30.621310.85 10.19 328.10 1305.64 1228.94 79.17 -26.90 583145.97 5978172.72 70°21'1.2166"N149°19'29.8013"W0.48 -24.182 0.30 -2.13 33.911404.69 11.92 324.39 1397.74 1321.04 94.10 -36.93 583135.78 5978187.53 70°21'1.3634"N149°19'30.0944"W1.99 -22.385 1.84 -3.95 36.661497.91 13.30 321.94 1488.71 1412.01 110.37 -49.15 583123.39 5978203.67 70°21'1.5234"N149°19'30.4515"W1.59 39.095 1.48 -2.63 38.711590.52 15.35 327.99 1578.44 1501.74 129.15 -62.21 583110.11 5978222.30 70°21'1.7082"N149°19'30.8333"W2.74 161.946 2.21 6.53 41.841684.12 14.50 329.10 1668.88 1592.18 149.71 -74.80 583097.30 5978242.72 70°21'1.9104"N149°19'31.2011"W0.96 -50.906 -0.91 1.19 46.531775.77 15.24 325.75 1757.46 1680.76 169.52 -87.47 583084.41 5978262.38 70°21'2.1051"N149°19'31.5715"W1.24 -7.679 0.81 -3.66 50.651870.10 17.86 324.60 1847.88 1771.18 191.56 -102.83 583068.81 5978284.25 70°21'2.3219"N149°19'32.0204"W2.80 16.115 2.78 -1.22 54.301963.06 19.66 326.14 1935.89 1859.19 216.17 -119.80 583051.57 5978308.66 70°21'2.5639"N149°19'32.5164"W2.01 -9.844 1.94 1.66 58.522056.58 20.96 325.51 2023.60 1946.90 243.02 -138.04 583033.03 5978335.31 70°21'2.8280"N149°19'33.0494"W1.41 37.592 1.39 -0.67 63.322151.52 21.11 325.83 2112.21 2035.51 271.16 -157.26 583013.51 5978363.23 70°21'3.1048"N149°19'33.6111"W0.20 -48.192 0.16 0.34 68.272245.18 21.80 323.79 2199.38 2122.68 299.15 -177.01 582993.45 5978391.00 70°21'3.3800"N149°19'34.1882"W1.08 14.206 0.74 -2.18 72.742337.89 23.22 324.70 2285.03 2208.33 327.95 -197.74 582972.40 5978419.57 70°21'3.6633"N149°19'34.7941"W1.58 30.138 1.53 0.98 77.032431.49 24.71 326.75 2370.56 2293.86 359.38 -219.13 582950.67 5978450.75 70°21'3.9723"N149°19'35.4193"W1.82 97.175 1.59 2.19 82.612525.39 24.64 328.22 2455.88 2379.18 392.43 -240.20 582929.23 5978483.56 70°21'4.2974"N149°19'36.0351"W0.66 -90.209 -0.07 1.57 89.542603.23 24.64 327.76 2526.64 2449.94 419.95 -257.40 582911.73 5978510.88 70°21'4.5680"N149°19'36.5379"W0.25 123.845 0.00 -0.59 95.552731.83 24.38 328.71 2643.65 2566.95 465.30 -285.49 582883.14 5978555.92 70°21'5.0141"N149°19'37.3588"W0.37 -160.867 -0.20 0.74 105.662824.46 22.80 327.29 2728.54 2651.84 496.74 -305.12 582863.17 5978587.14 70°21'5.3233"N149°19'37.9325"W1.81 -168.542 -1.71 -1.53 112.552918.31 21.28 326.44 2815.52 2738.82 526.24 -324.36 582843.60 5978616.42 70°21'5.6134"N149°19'38.4949"W1.65 162.878 -1.62 -0.91 118.413012.47 20.41 327.21 2903.52 2826.82 554.28 -342.70 582824.96 5978644.25 70°21'5.8892"N149°19'39.0309"W0.97 177.12 -0.92 0.82 123.943104.39 18.69 327.48 2990.14 2913.44 580.17 -359.29 582808.07 5978669.96 70°21'6.1438"N149°19'39.5161"W1.87 170.603 -1.87 0.29 129.303198.07 17.91 327.90 3079.08 3002.38 605.03 -375.02 582792.08 5978694.64 70°21'6.3883"N149°19'39.9757"W0.84 144.399 -0.83 0.45 134.603292.40 16.88 330.48 3169.10 3092.40 629.24 -389.47 582777.35 5978718.68 70°21'6.6263"N149°19'40.3982"W1.36 149.861 -1.09 2.74 140.393385.30 15.83 332.74 3258.24 3181.54 652.24 -401.92 582764.65 5978741.54 70°21'6.8525"N149°19'40.7621"W1.32 -42.795 -1.13 2.43 146.833478.67 16.98 329.19 3347.81 3271.11 675.27 -414.74 582751.58 5978764.42 70°21'7.0791"N149°19'41.1368"W1.63 -77.734 1.23 -3.80 153.033572.71 17.34 324.48 3437.66 3360.96 698.47 -429.92 582736.15 5978787.45 70°21'7.3072"N149°19'41.5803"W1.53 -149.955 0.38 -5.01 157.613666.38 16.76 323.31 3527.22 3450.52 720.66 -446.10 582719.73 5978809.46 70°21'7.5255"N149°19'42.0532"W0.72 168.38 -0.62 -1.25 160.763759.41 15.87 323.98 3616.50 3539.80 741.71 -461.59 582704.00 5978830.33 70°21'7.7324"N149°19'42.5062"W0.98 7.367 -0.96 0.72 163.643852.23 17.05 324.50 3705.51 3628.81 763.05 -476.96 582688.40 5978851.50 70°21'7.9423"N149°19'42.9553"W1.28 164.517 1.27 0.56 166.823946.42 16.81 324.73 3795.62 3718.92 785.41 -492.84 582672.27 5978873.68 70°21'8.1622"N149°19'43.4196"W0.26 125.597 -0.25 0.24 170.314037.90 16.37 326.97 3883.30 3806.60 807.02 -507.51 582657.37 5978895.12 70°21'8.3747"N149°19'43.8482"W0.85 179.68 -0.48 2.45 174.184130.17 15.88 326.98 3971.93 3895.23 828.51 -521.47 582643.16 5978916.45 70°21'8.5860"N149°19'44.2565"W0.53 -15.299 -0.53 0.01 178.484222.98 16.58 326.31 4061.05 3984.35 850.17 -535.74 582628.66 5978937.95 70°21'8.7991"N149°19'44.6734"W0.78 89.4 0.75 -0.72 182.694315.40 16.64 330.73 4149.61 4072.91 872.69 -549.52 582614.63 5978960.31 70°21'9.0205"N149°19'45.0764"W1.37 125.907 0.06 4.78 187.824407.96 16.25 332.70 4238.39 4161.69 895.76 -561.94 582601.96 5978983.24 70°21'9.2474"N149°19'45.4394"W0.74 -138.282 -0.42 2.13 194.334501.6515.07328.524328.604251.90917.79-574.31582589.345979005.1470°21'9.4641"N149°19'45.8011"W1.74-139.869-1.26-4.46200.18BH CoilTrak (2019) (Standard) L-116A CoilTrak MWD <6743.11-9227> L-116AOWSG MWD rev2 + IFR2 + Axial Corr + Sag Correction L-116 MWD+IFR+MS <0-7190> L-116BH GTK (Standard) L-106A CoilTrak SDI Gyro <6675-6708.56> L-116APositional Uncertainty ModelLog Name / CommentWellbore149°19'29.0152"W149°19'34.1407"W148°46'1.0006"WHoriz Uncert 1sd[ft]0.0020.00[US ft]5978093.865978232.735974812.00Latitude70°21'0.4380"N70°21'1.8231"N70°20'17.5522"N[ft]175.39Grid East[US ft]583173.75582996.83651958.00Slot LocationFacility Reference PtField Reference PtLocal North[ft]-140.8347.31°included50-029-23025-01Local EastGrid NorthLongitudeSection AzimuthSurface Position UncertaintyAPI#NAD27 / TM Alaska SP, Zone 4 (5004), US feetTrue0.9999080.64 EastSlotRig on L-116 (RT)Rig on L-116 (RT)Mean Sea Level76.70 ftE 0.00 ftN 0.00 ft2.00Std DevWA_ANC_DefnProjection SystemNorth ReferenceScaleConvergence at SlotHorizontal Reference PointVertical Reference PointMD Reference PointField Vertical ReferenceRig on L-116 (RT) To Mean Sea LevelSection Origin XSection Origin YDeclinationEllipse Confidence LimitDatabase02/18/22 at 11:07 using WellArchitect 6.0HilcorpNorth Slope, AlaskaPrudhoe BayL-PadL-116L-116AL-116AL-116A02/18/2022L-116 at 6649.61 MDUlricardMinimum curvatureWellpathWellbore last revised Sidetrack fromUserCalculation methodFieldFacilitySlotWellWellboreActual Wellpath Geographic Report - including Position UncertaintyReport by Baker HughesOperatorAreaPage 1 of 3 4593.77 14.60 326.93 4417.65 4340.95 937.74 -586.90 582576.53 5979024.94 70°21'9.6602"N149°19'46.1691"W0.67 -79.56 -0.51 -1.73 204.454686.63 14.81 323.13 4507.47 4430.77 957.04 -600.41 582562.81 5979044.09 70°21'9.8501"N149°19'46.5640"W1.06 -166.371 0.23 -4.09 207.614782.17 14.43 322.76 4599.92 4523.22 976.28 -614.94 582548.07 5979063.17 70°21'10.0393"N149°19'46.9887"W0.41 -150.333 -0.40 -0.39 209.984875.04 13.93 321.57 4689.96 4613.26 994.25 -628.89 582533.92 5979080.98 70°21'10.2161"N149°19'47.3965"W0.62 145.486 -0.54 -1.28 211.914969.72 13.46 322.97 4781.95 4705.25 1011.98 -642.61 582520.01 5979098.55 70°21'10.3904"N149°19'47.7975"W0.61 170.155 -0.50 1.48 213.855063.16 12.87 323.43 4872.93 4796.23 1029.02 -655.36 582507.07 5979115.44 70°21'10.5579"N149°19'48.1702"W0.64 -129.349 -0.63 0.49 216.035156.47 12.69 322.42 4963.93 4887.23 1045.49 -667.80 582494.45 5979131.77 70°21'10.7199"N149°19'48.5339"W0.31 121.87 -0.19 -1.08 218.055249.64 12.41 324.58 5054.87 4978.17 1061.75 -679.85 582482.23 5979147.90 70°21'10.8799"N149°19'48.8860"W0.59 -176.958 -0.30 2.32 220.235340.93 11.65 324.38 5144.16 5067.46 1077.24 -690.90 582471.00 5979163.27 70°21'11.0322"N149°19'49.2091"W0.83 -177.646 -0.83 -0.22 222.605433.47 10.66 324.16 5234.95 5158.25 1091.78 -701.35 582460.39 5979177.68 70°21'11.1751"N149°19'49.5147"W1.07 -157.234 -1.07 -0.24 224.785527.59 9.81 322.05 5327.57 5250.87 1105.16 -711.38 582450.21 5979190.95 70°21'11.3067"N149°19'49.8078"W0.99 -177.273 -0.90 -2.24 226.485618.93 8.96 321.79 5417.69 5340.99 1116.88 -720.57 582440.90 5979202.57 70°21'11.4220"N149°19'50.0763"W0.93 -149.423 -0.93 -0.28 227.685712.76 8.32 319.14 5510.45 5433.75 1127.76 -729.53 582431.82 5979213.34 70°21'11.5290"N149°19'50.3383"W0.80 -148.871 -0.68 -2.82 228.465806.21 7.59 315.74 5603.00 5526.30 1137.29 -738.26 582422.98 5979222.78 70°21'11.6227"N149°19'50.5935"W0.93 -151.879 -0.78 -3.64 228.515900.52 6.57 310.86 5696.59 5619.89 1145.28 -746.69 582414.47 5979230.68 70°21'11.7013"N149°19'50.8399"W1.25 -145.253 -1.08 -5.17 227.735993.22 5.81 305.47 5788.75 5712.05 1151.47 -754.52 582406.57 5979236.78 70°21'11.7622"N149°19'51.0688"W1.03 -133.052 -0.82 -5.81 226.186084.78 5.30 299.18 5879.88 5803.18 1156.22 -761.98 582399.05 5979241.45 70°21'11.8089"N149°19'51.2870"W0.87 -134.284 -0.56 -6.87 223.916179.51 4.66 290.38 5974.26 5897.56 1159.70 -769.41 582391.59 5979244.84 70°21'11.8430"N149°19'51.5041"W1.05 -86.074 -0.68 -9.29 220.816273.89 4.71 285.07 6068.32 5991.62 1162.04 -776.75 582384.23 5979247.10 70°21'11.8661"N149°19'51.7186"W0.46 97.594 0.05 -5.63 217.006368.62 4.68 288.68 6162.73 6086.03 1164.29 -784.16 582376.79 5979249.26 70°21'11.8882"N149°19'51.9353"W0.31 -164.83 -0.03 3.81 213.086461.83 4.24 287.06 6255.66 6178.96 1166.52 -791.06 582369.87 5979251.42 70°21'11.9101"N149°19'52.1369"W0.49 -141.392 -0.47 -1.74 209.526556.77 3.93 283.35 6350.36 6273.66 1168.30 -797.58 582363.33 5979253.12 70°21'11.9276"N149°19'52.3275"W0.43 -122.038 -0.33 -3.91 205.936649.61 3.87 281.90 6442.98 6366.28 1169.68 -803.74 582357.15 5979254.44 70°21'11.9412"N149°19'52.5076"W0.12 -178.085 -0.06 -1.56 202.34 Tie On Point to L-1166675.00 3.66 281.79 6468.32 6391.62 1170.02 -805.37 582355.52 5979254.76 70°21'11.9445"N149°19'52.5553"W0.83 172.93 -0.83 -0.43 201.37 Top of WS6708.56 8.61 91.76 6501.78 6425.08 1170.16 -803.91 582356.98 5979254.92 70°21'11.9459"N149°19'52.5124"W36.44 -0.413 14.75 506.47 202.556743.11 22.63 91.50 6534.97 6458.27 1169.91 -794.63 582366.26 5979254.77 70°21'11.9435"N149°19'52.2413"W40.58 0.163 40.58 -0.75 209.19 Int Az6770.68 34.79 91.56 6559.11 6482.41 1169.55 -781.42 582379.48 5979254.56 70°21'11.9400"N149°19'51.8550"W44.11 14.233 44.11 0.22 218.676801.15 48.32 96.08 6581.86 6505.16 1168.11 -761.31 582399.59 5979253.33 70°21'11.9258"N149°19'51.2675"W45.46 15.322 44.40 14.83 232.466830.61 61.92 100.24 6598.68 6521.98 1164.61 -737.47 582423.47 5979250.11 70°21'11.8914"N149°19'50.5704"W47.58 8.136 46.16 14.12 247.626860.60 74.06 102.03 6609.89 6533.19 1159.23 -710.24 582450.75 5979245.03 70°21'11.8386"N149°19'49.7747"W40.85 -0.807 40.48 5.97 263.986890.98 86.93 101.85 6614.90 6538.20 1153.05 -680.99 582480.07 5979239.17 70°21'11.7778"N149°19'48.9196"W42.37 2.75 42.36 -0.59 281.296920.96 100.97 102.53 6612.84 6536.14 1146.75 -651.83 582509.30 5979233.20 70°21'11.7158"N149°19'48.0672"W46.89 14.767 46.83 2.27 298.466951.98 108.12 104.51 6605.05 6528.35 1139.75 -622.65 582538.55 5979226.52 70°21'11.6470"N149°19'47.2145"W23.86 93.184 23.05 6.38 315.156980.24 107.87 108.47 6596.32 6519.62 1132.12 -596.89 582564.39 5979219.18 70°21'11.5720"N149°19'46.4613"W13.36 89.941 -0.88 14.01 328.917010.77 107.83 112.63 6586.96 6510.26 1121.92 -569.68 582591.71 5979209.28 70°21'11.4717"N149°19'45.6662"W12.97 -131.881 -0.13 13.63 342.007040.78 106.50 111.09 6578.10 6501.40 1111.24 -543.07 582618.43 5979198.90 70°21'11.3667"N149°19'44.8884"W6.61 -101.591 -4.43 -5.13 354.327070.67 105.57 106.62 6569.84 6493.14 1101.97 -515.89 582645.71 5979189.93 70°21'11.2755"N149°19'44.0940"W14.71 -69.725 -3.11 -14.95 368.007100.28 106.94 102.64 6561.55 6484.85 1094.78 -488.40 582673.28 5979183.05 70°21'11.2049"N149°19'43.2903"W13.71 -60.682 4.63 -13.44 383.347130.27 109.20 98.29 6552.24 6475.54 1089.60 -460.37 582701.36 5979178.18 70°21'11.1539"N149°19'42.4711"W15.71 -85.137 7.54 -14.50 400.437160.16 109.52 93.53 6542.33 6465.63 1086.70 -432.33 582729.43 5979175.59 70°21'11.1254"N149°19'41.6515"W15.06 -95.666 1.07 -15.93 419.077191.53 109.02 88.84 6531.97 6455.27 1086.09 -402.73 582759.02 5979175.31 70°21'11.1194"N149°19'40.7865"W14.20 -89.383 -1.59 -14.95 440.417225.47 109.00 83.63 6520.91 6444.21 1088.19 -370.73 582791.00 5979177.77 70°21'11.1401"N149°19'39.8510"W14.51 75.191 -0.06 -15.35 465.367255.39 110.00 87.85 6510.92 6434.22 1090.29 -342.61 582819.09 5979180.18 70°21'11.1608"N149°19'39.0292"W13.71 89.624 3.34 14.10 487.457285.49 109.97 92.40 6500.63 6423.93 1090.23 -314.33 582847.37 5979180.43 70°21'11.1602"N149°19'38.2026"W14.21 156.808 -0.10 15.12 508.197320.05 105.71 94.29 6490.04 6413.34 1088.30 -281.50 582880.22 5979178.87 70°21'11.1412"N149°19'37.2430"W13.38 171.239 -12.33 5.47 531.027350.33 101.12 95.01 6483.02 6406.32 1085.91 -252.15 582909.59 5979176.81 70°21'11.1178"N149°19'36.3852"W15.33 174.766 -15.16 2.38 550.977382.51 96.45 95.44 6478.10 6401.40 1083.02 -220.49 582941.27 5979174.26 70°21'11.0893"N149°19'35.4597"W14.57 -157.241 -14.51 1.34 572.287410.36 92.06 93.60 6476.04 6399.34 1080.83 -192.81 582968.97 5979172.38 70°21'11.0678"N149°19'34.6507"W17.08 -116.518 -15.76 -6.61 591.147440.40 89.78 89.04 6475.56 6398.86 1080.14 -162.79 582999.00 5979172.03 70°21'11.0610"N149°19'33.7733"W16.97 -98.209 -7.59 -15.18 612.747470.47 89.26 85.43 6475.81 6399.11 1081.59 -132.76 583029.00 5979173.81 70°21'11.0753"N149°19'32.8956"W12.13 -110.995 -1.73 -12.01 635.797500.51 87.39 80.54 6476.69 6399.99 1085.26 -102.97 583058.75 5979177.80 70°21'11.1113"N149°19'32.0249"W17.42 -117.237 -6.23 -16.28 660.177530.48 85.32 76.49 6478.59 6401.89 1091.21 -73.67 583087.98 5979184.08 70°21'11.1699"N149°19'31.1684"W15.15 -104.366 -6.91 -13.51 685.757560.22 84.34 72.60 6481.27 6404.57 1099.10 -45.13 583116.43 5979192.29 70°21'11.2475"N149°19'30.3341"W13.44 82.673 -3.30 -13.08 712.087590.44 84.43 73.30 6484.23 6407.53 1107.92 -16.37 583145.08 5979201.42 70°21'11.3342"N149°19'29.4937"W2.32 106.648 0.30 2.32 739.197620.67 83.50 76.46 6487.41 6410.71 1115.76 12.64 583174.01 5979209.58 70°21'11.4113"N149°19'28.6456"W10.84 78.718 -3.08 10.45 765.847649.85 84.27 80.27 6490.52 6413.82 1121.61 41.06 583202.35 5979215.75 70°21'11.4688"N149°19'27.8151"W13.25 68.802 2.64 13.06 790.697680.45 86.47 85.89 6492.99 6416.29 1125.28 71.32 583232.57 5979219.75 70°21'11.5049"N149°19'26.9305"W19.67 96.312 7.19 18.37 815.427710.61 86.19 88.46 6494.92 6418.22 1126.76 101.38 583262.61 5979221.57 70°21'11.5195"N149°19'26.0520"W8.55 85.226 -0.93 8.52 838.527740.63 86.50 92.09 6496.84 6420.14 1126.62 131.33 583292.56 5979221.76 70°21'11.5181"N149°19'25.1765"W12.11 86.675 1.03 12.09 860.447770.80 86.71 95.60 6498.62 6421.92 1124.60 161.38 583322.62 5979220.07 70°21'11.4982"N149°19'24.2983"W11.63 87.438 0.70 11.63 881.157800.55 86.87 99.05 6500.29 6423.59 1120.81 190.83 583352.12 5979216.62 70°21'11.4610"N149°19'23.4373"W11.59 -130.628 0.54 11.60 900.237831.22 85.75 97.74 6502.26 6425.56 1116.34 221.11 583382.44 5979212.48 70°21'11.4170"N149°19'22.5524"W5.61 -104.542 -3.65 -4.27 919.467860.70 84.92 94.50 6504.66 6427.96 1113.21 250.32 583411.68 5979209.68 70°21'11.3862"N149°19'21.6986"W11.31 -96.507 -2.82 -10.99 938.807890.64 84.50 90.70 6507.42 6430.72 1111.86 280.10 583441.46 5979208.65 70°21'11.3729"N149°19'20.8283"W12.72 -84.959 -1.40 -12.69 959.777919.70 84.81 87.28 6510.13 6433.43 1112.37 309.02 583470.38 5979209.49 70°21'11.3779"N149°19'19.9828"W11.77 -49.634 1.07 -11.77 981.387950.27 87.33 84.32 6512.23 6435.53 1114.60 339.43 583500.76 5979212.06 70°21'11.3999"N149°19'19.0940"W12.70 -102.833 8.24 -9.68 1005.257980.48 86.43 80.33 6513.87 6437.17 1118.63 369.32 583530.60 5979216.42 70°21'11.4395"N149°19'18.2204"W13.52 -89.638 -2.98 -13.21 1029.958010.15 86.47 75.77 6515.71 6439.01 1124.76 398.29 583559.49 5979222.87 70°21'11.4997"N149°19'17.3738"W15.34 -23.355 0.13 -15.37 1055.398040.48 89.32 74.54 6516.82 6440.12 1132.53 427.58 583588.69 5979230.95 70°21'11.5761"N149°19'16.5176"W10.23 1.693 9.40 -4.06 1082.198073.39 94.05 74.68 6515.86 6439.16 1141.25 459.29 583620.30 5979240.03 70°21'11.6619"N149°19'15.5908"W14.38 2.815 14.37 0.43 1111.418100.51 97.48 74.85 6513.13 6436.43 1148.34 485.32 583646.25 5979247.41 70°21'11.7316"N149°19'14.8299"W12.66 -43.299 12.65 0.63 1135.358125.48 99.33 73.08 6509.48 6432.78 1155.16 509.06 583669.91 5979254.49 70°21'11.7987"N149°19'14.1361"W10.20 -88.425 7.41 -7.09 1157.428160.60 99.41 69.45 6503.76 6427.06 1166.29 541.87 583702.59 5979265.98 70°21'11.9081"N149°19'13.1770"W10.20 -67.655 0.23 -10.34 1189.098190.43 100.86 65.81 6498.51 6421.81 1177.46 569.02 583729.61 5979277.46 70°21'12.0180"N149°19'12.3835"W12.96 -85.156 4.86 -12.20 1216.628220.56 101.17 61.76 6492.75 6416.05 1190.52 595.54 583755.99 5979290.81 70°21'12.1464"N149°19'11.6081"W13.23 -98.245 1.03 -13.44 1244.978250.70 100.51 57.35 6487.08 6410.38 1205.52 621.06 583781.33 5979306.09 70°21'12.2939"N149°19'10.8623"W14.54 -113.119 -2.19 -14.63 1273.898281.88 99.15 54.16 6481.76 6405.06 1222.81 646.45 583806.53 5979323.65 70°21'12.4639"N149°19'10.1201"W10.98 159.95 -4.36 -10.23 1304.288310.19 95.16 55.62 6478.23 6401.53 1238.96 669.42 583829.32 5979340.06 70°21'12.6227"N149°19'9.4486"W14.99 134.859 -14.09 5.16 1332.118341.06 92.36 58.43 6476.21 6399.51 1255.72 695.26 583854.96 5979357.10 70°21'12.7875"N149°19'8.6933"W12.84 95.014 -9.07 9.10 1362.478370.77 91.81 64.56 6475.13 6398.43 1269.88 721.34 583880.88 5979371.55 70°21'12.9268"N149°19'7.9310"W20.70 121.507 -1.85 20.63 1391.248401.86 89.57 68.21 6474.75 6398.05 1282.33 749.81 583909.22 5979384.31 70°21'13.0492"N149°19'7.0986"W13.77 95.605 -7.20 11.74 1420.618430.40 89.29 71.07 6475.03 6398.33 1292.26 776.57 583935.85 5979394.54 70°21'13.1468"N149°19'6.3166"W10.07 44.868 -0.98 10.02 1447.018460.90 91.51 73.28 6474.82 6398.12 1301.60 805.60 583964.78 5979404.19 70°21'13.2386"N149°19'5.4680"W10.27 105.349 7.28 7.25 1474.688490.35 90.74 76.08 6474.24 6397.54 1309.37 833.99 583993.08 5979412.29 70°21'13.3150"N149°19'4.6380"W9.86 70.552 -2.61 9.51 1500.828520.60 92.52 81.14 6473.38 6396.68 1315.34 863.63 584022.64 5979418.58 70°21'13.3737"N149°19'3.7719"W17.73 97.638 5.88 16.73 1526.658550.63 91.97 85.20 6472.21 6395.51 1318.91 893.41 584052.39 5979422.48 70°21'13.4088"N149°19'2.9012"W13.63 101.554 -1.83 13.52 1550.968582.65 90.95 90.16 6471.39 6394.69 1320.21 925.39 584084.34 5979424.13 70°21'13.4215"N149°19'1.9666"W15.81 119.33 -3.19 15.49 1575.348610.69 89.32 93.06 6471.32 6394.62 1319.42 953.41 584112.37 5979423.66 70°21'13.4137"N149°19'1.1475"W11.86 86.423 -5.81 10.34 1595.418640.68 89.48 95.61 6471.64 6394.94 1317.15 983.31 584142.29 5979421.72 70°21'13.3914"N149°19'0.2735"W8.52 -102.693 0.53 8.50 1615.858670.4288.5591.476472.156395.451315.321012.98584171.985979420.2170°21'13.3733"N149°18'59.4062"W14.27-96.219-3.13-13.921636.41Page 2 of 3 8700.39 88.13 87.58 6473.02 6396.32 1315.57 1042.93 584201.92 5979420.80 70°21'13.3757"N149°18'58.5308"W13.05 -99.822 -1.40 -12.98 1658.598730.63 87.26 82.50 6474.23 6397.53 1318.18 1073.03 584231.98 5979423.74 70°21'13.4013"N149°18'57.6512"W17.03 -50.932 -2.88 -16.80 1682.488762.26 89.78 79.40 6475.05 6398.35 1323.15 1104.25 584263.14 5979429.06 70°21'13.4502"N149°18'56.7387"W12.63 -76.417 7.97 -9.80 1708.808792.05 90.64 75.84 6474.94 6398.24 1329.54 1133.34 584292.16 5979435.77 70°21'13.5129"N149°18'55.8883"W12.29 -89.442 2.89 -11.95 1734.518820.87 90.68 71.54 6474.61 6397.91 1337.63 1160.99 584319.71 5979444.16 70°21'13.5925"N149°18'55.0800"W14.92 -120.145 0.14 -14.92 1760.328850.70 88.12 67.13 6474.92 6398.22 1348.15 1188.89 584347.49 5979454.99 70°21'13.6959"N149°18'54.2645"W17.09 31.227 -8.58 -14.78 1787.978880.23 91.75 69.33 6474.96 6398.26 1359.10 1216.31 584374.78 5979466.25 70°21'13.8035"N149°18'53.4630"W14.37 129.257 12.29 7.45 1815.548910.68 90.09 71.36 6474.47 6397.77 1369.34 1244.98 584403.34 5979476.80 70°21'13.9042"N149°18'52.6250"W8.61 -117.029 -5.45 6.67 1843.568940.64 87.64 66.55 6475.06 6398.36 1380.09 1272.92 584431.16 5979487.86 70°21'14.0099"N149°18'51.8080"W18.01 8.311 -8.18 -16.05 1871.398970.44 89.42 66.81 6475.83 6399.13 1391.88 1300.28 584458.38 5979499.96 70°21'14.1258"N149°18'51.0084"W6.04 97.366 5.97 0.87 1899.499002.95 88.86 71.16 6476.31 6399.61 1403.54 1330.61 584488.58 5979511.95 70°21'14.2404"N149°18'50.1216"W13.49 101.602 -1.72 13.38 1929.699030.58 88.00 75.37 6477.07 6400.37 1411.49 1357.06 584514.93 5979520.19 70°21'14.3186"N149°18'49.3486"W15.55 44.511 -3.11 15.24 1954.529059.10 90.83 78.15 6477.36 6400.66 1418.02 1384.81 584542.61 5979527.03 70°21'14.3827"N149°18'48.5373"W13.91 129.148 9.92 9.75 1979.359095.33 88.99 80.41 6477.42 6400.72 1424.76 1420.41 584578.12 5979534.16 70°21'14.4489"N149°18'47.4969"W8.04 89.481 -5.08 6.24 2010.089135.12 89.05 86.43 6478.10 6401.40 1429.31 1459.91 584617.57 5979539.15 70°21'14.4937"N149°18'46.3422"W15.13 8.597 0.15 15.13 2042.209164.02 91.96 86.87 6477.85 6401.15 1431.00 1488.76 584646.39 5979541.16 70°21'14.5102"N149°18'45.4990"W10.18 63.461 10.07 1.52 2064.559188.72 93.69 90.35 6476.63 6399.93 1431.60 1513.42 584671.04 5979542.03 70°21'14.5161"N149°18'44.7782"W15.72 0 7.00 14.09 2083.089227.0093.6990.356474.166397.461431.371551.62584709.245979542.2370°21'14.5137"N149°18'43.6616"W0.00N/A0.000.002111.00Projection to TDPage 3 of 3 From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20220314 PTD221-082 PBU L-106A Sundry 322-061 Tubing movement during fracturing Date:Monday, March 14, 2022 2:54:49 PM Attachments:image004.png L-116A TubeMove Calculations.docx From: Brodie Wages <David.Wages@hilcorp.com> Sent: Thursday, March 10, 2022 7:36 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] PTD221-101 PBU L-106A Sundry 322-061 Tubing movement during fracturing Hi Mel, I had intended to put all three wells in one document but I ran out of time before I needed to head out of the office today. Please see attached documentation for L-116A tubing movement calculations. The tubing configuration in L- 116A has been frac’d in the past. David “Brodie” Wages Ops Engineer C: 713.380.9836 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Friday, March 4, 2022 3:25 PM To: Brodie Wages <David.Wages@hilcorp.com> Subject: RE: [EXTERNAL] PTD221-101 PBU L-106A Sundry 322-061 Tubing movement during fracturing Brodie L-116 shows the PBR ID of 4”. It may be the same as S-118 below, but I cannot tell from the information I have. 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). 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: Brodie Wages <David.Wages@hilcorp.com> Sent: Friday, March 4, 2022 1:52 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] PTD221-101 PBU L-106A Sundry 322-061 Tubing movement during fracturing Hi Mel, I’ve never seen vendor frac modelling that shows tubing movement, but I will send the tubing movement calculations we do. Best I can tell it’s a 10’ long PBR with the seals on the seal assembly deployed via the tubing and ~1/2’ off bottom, S-118 we think was landed about the same and performed well during the frac, in 2004, this was the well I based L-118 on when we designed that CTD multistage frac similar to this L-116a. I’ve got the original wellfiles on order (they are currently in the Benson building), I’ll have L-116a tube moves to you shortly. Previous modeling showed that, when the completion was landed in 5000# compression in cold fluids, a frac would heat it up to 90 degF with 9500 psi final treating pressure to cause 4.3’ of movement on a 4” sealbore diameter PBR. Once I get the well files I’ll send you a L-116a (and L-106a, L-122L1) tube moves. David “Brodie” Wages Ops Engineer C: 713.380.9836 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Friday, March 4, 2022 9:59 AM To: Brodie Wages <David.Wages@hilcorp.com> Subject: [EXTERNAL] PTD221-101 PBU L-106A Sundry 322-061 Tubing movement during fracturing Brodie, Same questions for PBU L-106A. Or if you want to send your vendors fracturing modeling, that may suffice. 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: Rixse, Melvin G (OGC) Sent: Wednesday, March 2, 2022 4:14 PM To: Brodie Wages <David.Wages@hilcorp.com> Subject: PTD221-082 L-116A Sundry 322-051 Tubing movement during fracturing Brodie, A few questions for your fracturing treatment: 1. What is your calculated 3-1/2” production tubing movement at (7800 psi – 3500 psi) = 4300 psi pressure difference? 2. Is the PBR ID = 4.0” so consequently the piston forces on the 3-1/2” tubing (ID 2.992”) ~34,000? 3. What will be the mean tubing temperature difference prior to fracturing treatment and at the end(coldest) of the fracturing treatment? 4. What is the total length of the polish bore on the receptacle? 5. Will you have enough length at the current tubing tail position to remain within the receptacle at maximum fracture differential pressure of 4300 psi, and minimum tubing temperature? 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). 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L-116ATubing Movement Calculations PTD: 221082 Tubing movement calcuations were performed to verify enough sealbore length has been installed during initial well completion. Below are the background informaiton and supporting documentation. L-116A Casing Tally: … Working through drilling files, I can confirm that the PBR is at least 10’ long. While the tally notes 11.37’, I expect some of that distance to be connections or wasted space. Tubing Tally: A drawing of the sealbore assembly shows the lowermost seal stack to be very close to the ½ mule show on the bottom: To find the spaceout, we look at the most recent caliper run Sept-19-2007 where we find that the bottom of the PBR at 6433.8’ and the bottom the the seal assembly at 6433.6’, we have a 0.2’ spaceout. At the time of running the caliper, the well had been shut in over 15 days so the tubing should be as close to initial conditions as reasonably expected see screenshot of caliper below: L-116ATubing Movement Calculations PTD: 221082 Knowing our PBR length, where our seals are and the spaceout, we can now run tubing movement calculators to predict movement of tubing tail as fluid pressures/temperatures change: Given the above inputs sourced by the most accurate means possible (Stimplan modelling for final BHT, latest SBHPS for starting BHT, max surface pressures dictated by pressure envelope calculaitons), we should see 4.3 feet of movement UP. With the current spaceout and PBR length, L-116A should be OK to frac. Add to this data that the well has been frac’d before with a max treating pressure of 8100 psi. 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ĂŶĚďƌŝŶŐĐĞŵĞŶƚĂůůƚŚĞǁĂǇďĂĐŬŝŶƚŽƚŚĞŵŽƚŚĞƌďŽƌĞ͘^ĞƌǀŝĐĞ ĐŽŝůĂŶĚĨƌĂĐĐƌĞǁƐǁŝůůƚŚĞŶĨƌĂĐƚŚĞǁĞůůŝŶƚŚƌĞĞƉůĂŶŶĞĚƐƚĂŐĞƐ͘KŶĐĞĨƌĂĐƚƵƌĞƚƌĞĂƚŵĞŶƚƐĂƌĞ ĐŽŵƉůĞƚĞ͕ĂĨŝŶĂůŵŝůůƌƵŶƚŽdǁŝůůďĞƉĞƌĨŽƌŵĞĚƚŚĞŶŐĂƐůŝƐ ƚǀĂůǀĞƐǁŝůůďĞŝŶƐƚĂůůĞĚĂŶĚ ƚŚĞǁĞůůǁŝůů ďĞWKW͛ĚƚŚƌŽƵŐŚǁĞůůƚĞƐƚĞƌƐƚŽŽďƚĂŝŶŝŶŝƚŝĂůǁĞůůƌĂƚĞƐ͘ ,ŝůĐŽƌƉƌĞƋƵĞƐƚƐ ĂǀĂƌŝĂŶĐĞƚŽƐĞĐƚŝŽŶƐϮϬϮϱ͘Ϯϴϯ͕Ă͕ϯͲ ϰǁŚŝĐŚƌĞƋƵŝƌĞŝĚĞŶƚŝĨŝĐĂƚŝŽŶŽĨĨƌĞƐŚ Ͳ ǁĂƚĞƌĂƋƵŝĨĞƌƐĂŶĚĂƉůĂŶĨŽƌďĂƐĞͲǁĂƚĞƌƐĂŵƉůŝŶŐ͘ WůĞĂƐĞĚŝƌĞĐƚƋƵĞƐƚŝŽŶƐŽƌ ĐŽŵŵĞŶƚƐƚŽ ĂǀŝĚtĂŐĞƐ͘ ĨĨŝĚĂǀŝƚŽĨEŽƚŝĨŝĐĂƚŝŽŶ;ϮϬϮϱ͘Ϯϴϯ͕Ă͕ϭͿ͗ WĂƌƚŶĞƌƐŶŽƚŝĨŝĞĚ ϭϮͬϬϵͬϮϬϮϭ͗ ŽŶŽĐŽWŚŝůůŝƉƐ ǆǆŽŶDŽďŝů ŚĞǀƌŽŶ ĞƉĂƌƚŵĞŶƚŽĨEĂƚƵƌĂůZĞƐŽƵƌĐĞƐ WůĂƚ/ĚĞŶƚŝĨǇŝŶŐtĞůůƐ ;ϮϬϮϱ͘Ϯϴϯ͕Ă͕ϮͿ͗ WůĂƚŽĨǁĞůůƐǁŝƚŚŝŶŽŶĞͲŚĂůĨŵŝůĞŽĨ ƉůĂŶŶĞĚ>Ͳϭϭϲ ǁĞůůďŽƌĞ ƚƌĂũĞĐƚŽƌǇ͘ >ŝƐƚŽĨǁĞůůƐŝŶWůĂƚϮϬϮϱ͘Ϯϴϯ͕ Ă͕ Ϯ ^ǁEĂŵĞ tĞůůůĂƐƐĞƐ tĞůů^ƚĂƚƵƐĞƐĐ >ͲϮϬϭ>ϯWϭ ĞǀĞůŽƉŵĞŶƚ WůƵŐŐĞĚĂĐŬ&ŽƌZĞĚƌŝůů /'E/<^/<hD/ϭ ǆƉůŽƌĂƚŽƌǇ ďĂŶĚŽŶĞĚ >ͲϮϬϭWϭ ĞǀĞůŽƉŵĞŶƚ WůƵŐŐĞĚĂĐŬ&ŽƌZĞĚƌŝůů >ͲϬϭ ĞǀĞůŽƉŵĞŶƚ ďĂŶĚŽŶĞĚ >ͲϮϬϭWϮ ĞǀĞůŽƉŵĞŶƚ WůƵŐŐĞĚĂĐŬ&ŽƌZĞĚƌŝůů >ͲϬϭ ĞǀĞůŽƉŵĞŶƚ KŝůWƌŽĚƵĐĞƌ^ŚƵƚͲ/Ŷ >ͲϮϬϮ ĞǀĞůŽƉŵĞŶƚ KŝůWƌŽĚƵĐĞ ƌ'ĂƐ>ŝĨƚ >ͲϬϮ 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DŝƐĐŝďůĞ/ŶũĞĐƚŽƌKƉĞƌĂƚŝŶŐ >ͲϮϬϰ>ϯ ĞǀĞůŽƉŵĞŶƚ KŝůWƌŽĚƵĐĞƌ'ĂƐ>ŝĨƚ >ͲϭϬϰ ĞǀĞůŽƉŵĞŶƚ KŝůWƌŽĚƵĐĞƌ'ĂƐ>ŝĨƚ >ͲϮϬϰ>ϰ ĞǀĞůŽƉŵĞŶƚ KŝůWƌŽĚƵĐĞƌ'ĂƐ>ŝĨƚ >ͲϭϬϱ ^ĞƌǀŝĐĞ DŝƐĐŝďůĞ/ŶũĞĐƚŽƌKƉĞƌĂƚŝŶŐ >ͲϮϬϱ ĞǀĞůŽƉŵĞŶƚ ďĂŶĚŽŶĞ Ě >ͲϭϬϲ ĞǀĞůŽƉŵĞŶƚ KŝůWƌŽĚƵĐĞƌ^ŚƵƚͲ/Ŷ >ͲϮϬϱ ĞǀĞůŽƉŵĞŶƚ KŝůWƌŽĚƵĐĞƌ'ĂƐ>ŝĨƚ >ͲϭϬϳ ĞǀĞůŽƉŵĞŶƚ KŝůWƌŽĚƵĐĞƌ'ĂƐ>ŝĨƚ >ͲϮϬϱ>ϭ ĞǀĞůŽƉŵĞŶƚ ďĂŶĚŽŶĞ Ě >ͲϭϬϴ ^ĞƌǀŝĐĞ DŝƐĐŝďůĞ/ŶũĞĐƚŽƌKƉĞƌĂƚŝŶŐ >ͲϮϬϱ>Ϯ ĞǀĞůŽƉŵĞŶƚ ďĂŶĚŽŶĞĚ >ͲϭϬϵ ^ĞƌǀŝĐĞ tĂƚĞƌ/ŶũĞĐƚŽƌ/ŶũĞĐƚŝŶŐ >ͲϮϬϱ>ϯ ĞǀĞůŽƉŵĞŶƚ ďĂŶĚŽŶĞĚ >ͲϭϭϬ ĞǀĞůŽƉŵĞŶƚ KŝůWƌŽĚƵĐĞƌ^ŚƵƚͲ/Ŷ >ͲϮϬϱ>ϰ ĞǀĞůŽƉŵĞŶƚ ďĂŶĚŽŶĞĚ >Ͳϭϭϭ ^ĞƌǀŝĐĞ tĂƚĞƌ/ŶũĞĐƚŽƌ/ŶũĞĐƚŝŶŐ >ͲϮϬϱ>ϱ ĞǀĞůŽƉŵĞŶƚ ďĂŶĚŽŶĞĚ >ͲϭϭϮ ĞǀĞůŽƉŵĞŶƚ KŝůWƌŽĚƵĐĞƌ'ĂƐ>ŝĨƚ >ͲϮϬϱWϭ ĞǀĞůŽƉŵĞŶƚ WůƵŐŐĞĚĂĐŬ&ŽƌZĞĚƌŝůů >Ͳϭϭϰ ĞǀĞůŽƉŵĞŶƚ ďĂŶĚŽŶĞĚ >ͲϮϬϲ ĞǀĞůŽƉŵĞŶƚ KŝůWƌŽĚƵĐĞƌ'ĂƐ>ŝĨƚ >Ͳϭϭϰ ĞǀĞůŽƉŵĞŶƚ KŝůWƌŽĚƵĐĞƌ^ŚƵƚͲ/Ŷ >ͲϮϭϬ ^ĞƌǀŝĐĞ tĂƚĞƌ/ŶũĞĐƚŽƌ/ŶũĞĐƚŝŶŐ >Ͳϭϭϱ ^ĞƌǀŝĐĞ tĂƚĞƌ/ŶũĞĐƚŽƌ/ŶũĞĐƚŝŶŐ >ͲϮϭϬWϭ ^ĞƌǀŝĐĞ WůƵŐŐĞĚĂĐŬ&ŽƌZĞĚƌŝůů >Ͳϭϭϲ ĞǀĞůŽƉŵĞŶƚ KŝůWƌŽĚƵĐĞƌ^ŚƵƚͲ/Ŷ >ͲϮϭϭ ^ĞƌǀŝĐĞ tĂƚĞƌ/ŶũĞĐƚŽƌ^ŚƵƚͲ/Ŷ >Ͳϭϭϳ ^ĞƌǀŝĐĞ DŝƐĐŝďůĞ/ŶũĞĐƚŽƌKƉĞƌĂƚŝŶŐ >ͲϮϭϭWϭ ^ĞƌǀŝĐĞ WůƵŐŐĞĚĂĐŬ&ŽƌZĞĚƌŝůů >Ͳϭϭϴ ĞǀĞůŽƉŵĞŶƚ KŝůWƌŽĚƵĐĞƌ'ĂƐ>ŝĨƚ >ͲϮϭϮ ^ĞƌǀŝĐĞ tĂƚĞƌ/ŶũĞĐƚŽƌ/ŶũĞĐƚŝŶŐ >Ͳϭϭϴ>ϭ ĞǀĞůŽƉŵĞŶƚ KŝůtĞůů >ͲϮϭϮWϭ ^ĞƌǀŝĐĞ WůƵŐŐĞĚĂĐŬ&ŽƌZĞĚƌŝ ůů >Ͳϭϭϵ ^ĞƌǀŝĐĞ ďĂŶĚŽŶĞĚ >ͲϮϭϮWϮ ^ĞƌǀŝĐĞ WůƵŐŐĞĚĂĐŬ&ŽƌZĞĚƌŝůů >Ͳϭϭϵ ^ĞƌǀŝĐĞ DŝƐĐŝďůĞ/ŶũĞĐƚŽƌKƉĞƌĂƚŝŶŐ >ͲϮϭϯ ^ĞƌǀŝĐĞ tĂƚĞƌ/ŶũĞĐƚŽƌ/ŶũĞĐƚŝŶŐ >ͲϭϭϵWϭ ^ĞƌǀŝĐĞ WůƵŐŐĞĚĂĐŬ&ŽƌZĞĚƌŝůů >ͲϮϭϰ ^ĞƌǀŝĐĞ ďĂŶĚŽŶĞĚ >ͲϭϮϬ ĞǀĞůŽƉŵĞŶƚ KŝůWƌŽĚƵĐĞƌ^ŚƵƚͲ/Ŷ >ͲϮϭϰ ^ĞƌǀŝĐĞ tĂƚĞƌ/ŶũĞĐƚŽƌ/ŶũĞĐƚŝŶŐ >ͲϭϮϭ ĞǀĞůŽƉŵĞŶƚ ďĂŶĚŽŶĞĚ >ͲϮϭϱ ^ĞƌǀŝĐĞ DŝƐĐŝďůĞ/ŶũĞĐƚŽƌKƉĞƌĂƚŝŶŐ >ͲϭϮϭ ĞǀĞůŽƉŵĞŶƚ KŝůWƌŽĚƵĐĞƌ^ŚƵƚͲ/Ŷ >ͲϮϭϲ ^ĞƌǀŝĐĞ DŝƐĐŝďůĞ/ŶũĞĐƚŽƌKƉĞƌĂƚŝŶŐ >ͲϭϮϮ ĞǀĞůŽƉŵĞŶƚ KŝůWƌŽĚƵĐĞƌ'ĂƐ>ŝĨƚ >ͲϮϭϳ ^ĞƌǀŝĐĞ tĂƚĞƌ/ŶũĞĐƚŽƌ/ŶũĞĐƚŝŶŐ >ͲϭϮϯ ^ĞƌǀŝĐĞ DŝƐĐŝďůĞ/ŶũĞĐƚŽƌ^ŚƵƚͲ/Ŷ >ͲϮϭϴ ^ĞƌǀŝĐĞ tĂƚĞƌ/ŶũĞĐƚŽƌ^ŚƵƚͲ/Ŷ >ͲϭϮϯWϭ ĞǀĞůŽƉŵĞŶƚ WůƵŐŐĞĚĂĐŬ&ŽƌZĞĚƌŝůů >ͲϮϭϵ ^ĞƌǀŝĐĞ DŝƐĐŝďůĞ/ŶũĞĐƚŽƌKƉĞƌĂƚŝŶŐ >ͲϭϮϰ ĞǀĞůŽƉŵĞŶƚ KŝůWƌŽĚƵĐĞƌ,ǇĚƌĂƵůŝĐWƵŵƉ >ͲϮϮϬ ^ĞƌǀŝĐĞ tĂƚĞƌ/ŶũĞĐƚŽƌ/ŶũĞĐƚŝŶŐ >ͲϭϮϰWϭ ĞǀĞůŽƉŵĞŶƚ WůƵŐŐĞĚĂĐŬ&ŽƌZĞĚƌŝůů >ͲϮϮϭ ^ĞƌǀŝĐĞ tĂƚĞƌ/ŶũĞĐƚŽƌ/ŶũĞĐƚŝŶŐ >ͲϭϮϰWϮ ĞǀĞůŽƉŵĞŶƚ WůƵŐŐĞĚĂĐŬ&ŽƌZĞĚƌŝůů >ͲϮϮϮ ^ĞƌǀŝĐĞ DŝƐĐŝďůĞ/ŶũĞĐƚŽƌKƉĞƌĂƚŝŶŐ >ͲϮϬϬ ĞǀĞůŽƉŵĞŶƚ ^ƵƐƉĞŶĚĞĚ >ͲϮϮϯ ^ĞƌǀŝĐĞ DŝƐĐŝďůĞ/ŶũĞĐƚŽƌ^ŚƵƚͲ/Ŷ >ͲϮϬϬ ĞǀĞůŽƉŵĞŶƚ KŝůWƌŽĚƵĐĞƌ^ŚƵƚͲ/Ŷ >ͲϮϱϬ ĞǀĞůŽƉŵĞŶƚ KŝůWƌŽĚƵĐĞƌ^ŚƵƚͲ/Ŷ >ͲϮϬϬ>ϭ ĞǀĞůŽƉŵĞŶƚ ^ƵƐƉĞŶĚĞĚ >ͲϮϱϬ>ϭ ĞǀĞůŽƉŵĞŶƚ KŝůWƌŽĚƵĐĞƌ'ĂƐ>ŝĨƚ >ͲϮϬϬ>Ϯ ĞǀĞůŽƉŵĞŶƚ ^ƵƐƉĞŶĚĞĚ >ͲϮϱϬ>Ϯ ĞǀĞůŽƉŵĞŶƚ KŝůWƌŽĚƵĐĞƌ'ĂƐ>ŝĨƚ >ͲϮϬϭ ĞǀĞůŽƉŵĞŶƚ KŝůWƌŽĚƵĐĞƌ'ĂƐ>ŝĨƚ >ͲϮϱϬWϭ ĞǀĞůŽƉŵĞŶƚ WůƵŐŐĞĚĂĐŬ&ŽƌZĞĚƌŝůů >ͲϮϬϭ>ϭ ĞǀĞůŽƉŵĞŶƚ KŝůtĞůů >ͲϱϬ ĞǀĞůŽƉŵĞŶƚ KŝůWƌŽĚƵĐĞƌ^ŚƵƚͲ/Ŷ >ͲϮϬϭ>ϭWϭ ĞǀĞůŽƉŵĞŶƚ WůƵŐŐĞĚĂĐŬ&ŽƌZĞĚƌŝůů >ͲϱϬWϭ ĞǀĞůŽƉŵĞŶƚ WůƵŐŐĞĚĂĐŬ&ŽƌZĞĚƌŝůů >ͲϮϬϭ>Ϯ ĞǀĞůŽƉŵĞŶƚ KŝůtĞůů EtϭͲϬϭ ǆƉůŽƌĂƚŽƌǇ ďĂŶĚŽŶĞĚ >ͲϮϬϭ>ϯ ĞǀĞůŽƉŵĞŶƚ KŝůtĞůů ǆĞŵƉƚŝŽŶĨŽƌ&ƌĞƐŚǁĂƚĞƌƋƵŝĨĞƌƐ;ϮϬϮϱ͘Ϯϴϯ͕Ă͕ϯͲ ϰͿ͗ tĞůů >Ͳϭϭϲ ŝƐŝŶƚŚĞtĞƐƚKƉĞƌĂƚŝŶŐƌĞĂŽĨWƌƵĚŚŽĞĂǇ͘WĞƌƋƵŝĨĞƌǆĞŵƉƚŝŽŶKƌĚĞƌEŽ͘ϭĚĂƚĞĚ:ƵůǇ ϭϭ͕ϭϵϴϲǁŚĞƌĞ^ƚĂŶĚĂƌĚůĂƐŬĂWƌŽĚƵĐƚŝŽŶŽŵƉĂŶǇƌĞƋƵĞƐƚĞĚƚŚĞůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶ ŽŵŵŝƐƐŝŽŶƚŽŝƐƐƵĞĂŶŽƌĚĞƌĞǆĞŵƉƚŝŶŐƚŚŽƐĞƉŽƌƚŝŽŶƐŽĨĂůůĂƋƵŝĨĞƌƐůǇŝŶŐĚŝƌĞĐƚůǇďĞůŽǁƚŚĞtĞƐƚĞƌŶ KƉĞƌĂƚŝŶŐƌĞĂĂŶĚ<WĂĚƌĞĂŽĨƚŚĞWƌƵĚŚŽĞĂǇhŶŝƚĨŽƌůĂƐƐ///ŶũĞĐƚŝŽŶĂĐƚŝǀŝƚŝĞƐ͘&ŝŶĚŝŶŐƐϭͲ ϰ ƐƚĂƚĞ͗ ϭ͘ dŚŽƐĞƉŽƌƚŝŽŶƐŽĨĨƌĞƐŚǁĂƚĞƌĂƋƵŝĨĞƌƐŽĐĐƵƌƌŝŶŐďĞŶĞĂƚŚƚŚĞtĞƐƚĞƌŶKƉĞƌĂƚŝŶŐĂŶĚ<ƉĂĚĂƌĞĂƐ ŽĨƚŚĞWƌƵĚŚŽĞĂǇhŶŝƚĚŽŶŽƚĐƵƌƌĞŶƚůǇƐĞƌǀĞĂƐĂƐŽƵƌĐĞŽĨĚƌŝŶŬŝŶŐǁĂƚĞƌ͘ Ϯ͘ dŚŽƐĞƉŽƌƚŝŽŶƐŽĨĨƌĞƐŚǁĂƚĞƌĂƋƵŝĨĞƌƐŽĐĐƵƌƌŝŶŐďĞŶĞĂƚŚƚŚĞtĞƐƚĞƌŶKƉĞƌĂƚŝŶŐĂŶĚ<ƉĂĚĂƌĞĂƐ ŽĨƚŚĞWƌƵĚŚŽĞĂǇhŶŝƚĂƌĞƐŝƚƵĂƚĞĚĂƚĂĚĞƉƚŚĂŶĚůŽĐĂƚŝŽŶƚŚĂƚŵĂŬĞƐƌĞĐŽǀĞƌǇŽĨǁĂƚĞƌĨŽƌ ĚƌŝŶŬŝŶŐǁĂƚĞƌƉƵƌƉŽƐĞƐĞĐŽŶŽŵŝĐĂůůǇŝŵƉƌĂĐƚŝĐĂďůĞ͘ ϯ͘ dŚŽƐĞƉŽƌƚŝŽŶƐŽĨĨƌĞƐŚǁĂƚĞƌĂƋƵŝĨĞƌƐŽĐĐƵƌƌŝŶŐďĞŶĞĂƚŚƚŚĞtĞƐƚĞƌŶKƉĞƌĂƚŝŶŐĂŶĚ<ƉĂĚĂƌĞĂƐ ŽĨƚŚĞWƌƵĚŚŽĞĂǇhŶŝƚĂƌĞƌĞƉŽƌƚĞĚƚŽŚĂǀĞƚŽƚĂůĚŝƐƐŽůǀĞĚƐŽůŝĚƐĐŽŶƚĞŶƚŽĨϳϬϬϬŵŐͬ/Žƌ ŵŽƌĞ͘ ϰ͘ ǇůĞƚƚĞƌŽĨ:ƵůǇϭ͕ϭϵϴϲ͕WͲ ZĞŐŝŽŶϭϬĂĚǀŝƐĞƐƚŚĂƚƚŚĞĂƋƵŝĨĞƌƐŽĐĐƵƌƌŝŶŐďĞŶĞĂƚŚƚŚĞ tĞƐƚĞƌŶKƉĞƌĂƚŝŶŐĂŶĚ<ƉĂĚĂƌĞĂƐŽĨƚŚĞWƌƵĚŚŽĞĂǇhŶŝƚƋƵĂůŝĨǇĨŽƌĞǆĞŵƉƚŝŽŶ͘/ƚŝƐ ĐŽŶƐŝĚĞƌĞĚƚŽďĞĂŵŝŶŽƌĞǆĞŵƉƚŝŽŶĂŶĚĂŶŽŶͲƐƵďƐƚĂŶƚŝĂůƉƌŽŐƌĂŵƌĞǀŝƐŝŽŶŶŽƚƌĞƋƵŝƌŝŶŐŶŽƚŝĐĞ ŝŶƚŚĞ&ĞĚĞƌĂůZĞŐŝƐƚƌĂƌ͘ WĞƌƚŚĞĂďŽǀĞĨŝŶĚŝŶŐƐ͕ΗdŚŽƐĞƉŽƌƚŝŽŶƐŽĨĨƌĞƐŚǁĂƚĞƌĂƋƵŝĨĞƌƐůǇŝŶŐĚŝƌĞĐƚůǇďĞůŽǁƚŚĞtĞƐƚĞƌŶ 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dŚĂŶŬƐĂŶĚƐƚĂǇƐĂĨĞ͕^ƚĞǀĞĂǀŝĞƐůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ;K'ͿKE&/Ed/>/dzEKd/͗dŚŝƐĞͲŵĂŝůŵĞƐƐĂŐĞ͕ŝŶĐůƵĚŝŶŐĂŶǇĂƚƚĂĐŚŵĞŶƚƐ͕ĐŽŶƚĂŝŶƐŝŶĨŽƌŵĂƚŝŽŶĨƌŽŵƚŚĞůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ;K'Ϳ͕^ƚĂƚĞŽĨůĂƐŬĂĂŶĚŝƐĨŽƌƚŚĞƐŽůĞƵƐĞŽĨƚŚĞŝŶƚĞŶĚĞĚƌĞĐŝƉŝĞŶƚ;ƐͿ͘/ƚŵĂǇĐŽŶƚĂŝŶĐŽŶĨŝĚĞŶƚŝĂůĂŶĚͬŽƌƉƌŝǀŝůĞŐĞĚŝŶĨŽƌŵĂƚŝŽŶ͘dŚĞƵŶĂƵƚŚŽƌŝǌĞĚƌĞǀŝĞǁ͕ƵƐĞŽƌĚŝƐĐůŽƐƵƌĞŽĨƐƵĐŚŝŶĨŽƌŵĂƚŝŽŶŵĂǇǀŝŽůĂƚĞƐƚĂƚĞŽƌĨĞĚĞƌĂůůĂǁ͘/ĨǇŽƵĂƌĞĂŶƵŶŝŶƚĞŶĚĞĚƌĞĐŝƉŝĞŶƚŽĨƚŚŝƐĞͲŵĂŝů͕ƉůĞĂƐĞĚĞůĞƚĞŝƚ͕ǁŝƚŚŽƵƚĨŝƌƐƚƐĂǀŝŶŐŽƌĨŽƌǁĂƌĚŝŶŐŝƚ͕ĂŶĚ͕ƐŽƚŚĂƚƚŚĞK'ŝƐĂǁĂƌĞŽĨƚŚĞŵŝƐƚĂŬĞŝŶƐĞŶĚŝŶŐŝƚƚŽǇŽƵ͕ĐŽŶƚĂĐƚ^ƚĞǀĞĂǀŝĞƐĂƚϵϬϳͲϳϵϯͲϭϮϮϰŽƌƐƚĞǀĞ͘ĚĂǀŝĞƐΛĂůĂƐŬĂ͘ŐŽǀ͘&ƌŽŵ͗^ĞĂŶtĂŐŶĞƌф^ĞĂŶ͘tĂŐŶĞƌΛŚŝůĐŽƌƉ͘ĐŽŵх^ĞŶƚ͗dŚƵƌƐĚĂǇ͕&ĞďƌƵĂƌǇϭϳ͕ϮϬϮϮϴ͗ϰϮDdŽ͗ĂǀŝĞƐ͕^ƚĞƉŚĞŶ&;K'ͿфƐƚĞǀĞ͘ĚĂǀŝĞƐΛĂůĂƐŬĂ͘ŐŽǀх͖ƌŽĚŝĞtĂŐĞƐфĂǀŝĚ͘tĂŐĞƐΛŚŝůĐŽƌƉ͘ĐŽŵхĐ͗ZŝǆƐĞ͕DĞůǀŝŶ';K'ͿфŵĞůǀŝŶ͘ƌŝǆƐĞΛĂůĂƐŬĂ͘ŐŽǀх^ƵďũĞĐƚ͗Z͗΀ydZE>΁Wh>Ͳϭϭϲ;WdϮϮϭͲϬϴϮ͖^ƵŶĚƌǇϯϮϮͲϬϱϭͿͲYƵĞƐƚŝŽŶƐĂŶĚZĞƋƵĞƐƚƐ^ƚĞǀĞ͕,ĞƌĞ͛ƐƚŚĞƌĞƉůǇĨƌŽŵƌŽĚŝĞǁŝƚŚŵǇĂĚĚŝƚŝŽŶƐ͗dŚĂŶŬƐĨŽƌĐŽŵďŝŶŝŶŐŵĂŝůƐ͘ϭͿŽƚƚŽŵŽĨϮͲϯͬϴ͟ϰ͘ϳη>ͲϴϬ,ǇĚƌŝůůϱϭϭƐŽůŝĚůŝŶĞƌΛϵϭϴϬ͕͛ǁĞĂƌĞǁŽƌŬŝŶŐŽŶƵƉĚĂƚĞĚtƐϮͿtĞŚĂǀĞĂϮϬϬϴh^/dƐŚŽǁŝŶŐŐŽŽĚĐĞŵĞŶƚĂůůƚŚĞǁĂǇƵƉƚŽϮϲϱϲ͛DŽƌͲϮϰϵϴ͛dsƐƐ͘dŚĞĐĞŵĞŶƚĐůŽƐĞƌƚŽƚŚĞƐŚŽĞŝƐŵƵĐŚďĞƚƚĞƌƋƵĂůŝƚǇ͘dŚĞdKĨŽƌƚŚĞϮͲϯͬϴ͟ůŝŶĞƌǁĞũƵƐƚůĂŶĚĞĚŝƐĐĂůĐƵůĂƚĞĚĂƚƚŚĞůŝŶĞƌƚŽƉďĞĐĂƵƐĞǁĞƚŚŝŶŬǁĞŐŽƚĂŐŽŽĚĐĞŵĞŶƚũŽďƉƵŵƉĞĚǁŚŝůĞƚŚĞƌŝŐǁĂƐƚŚĞƌĞ͘dŚĞdKǁŝůůďĞĐŽŶĨŝƌŵĞĚǁŚĞŶǁĞƉƌĞƐƐƵƌĞƚĞƐƚƚŚĞůŝŶĞƌůĂƉ͘ϯͿ/ƐŚŽƵůĚŚĂǀĞŝŶĐůƵĚĞĚƚŚŝƐŝŶƚŚĞŽƌŝŐŝŶĂůĂƉƉůŝĐĂƚŝŽŶ͘&ŽƌŵĂƚŝŽŶ DdŽƉ DŽƚ dsƐƐdŽƉ dsƐƐŽƚdsdŚŝĐŬŶĞƐƐƐƚ&ƌĂĐ'ƌĂĚƉƐŝͬĨƚ>ŝƚŚ͘ĞƐĐ͘d,ZΎ ϲϯϮϲ ϲϱϯϯ ͲϲϬϰϯ ͲϲϮϱϬ ϮϬϳ Ϭ͘ϳϮ ^ŚĂůĞd<>Ύ ϲϱϯϯ ϲϱϴϯ ͲϲϮϱϬ ͲϲϮϵϵ ϰϵ Ϭ͘ϳϮ ^ŚĂůĞ<>'DΎ ϲϱϴϯ ϲϲϲϲ ͲϲϮϵϵ ͲϲϯϴϮ ϴϯ Ϭ͘ϳϮ ^ŚĂůĞd<hWΎ ϲϲϲϲ ϲϲϳϭ ͲϲϯϴϮ Ͳϲϯϴϳ ϱ Ϭ͘ϳϮ ^ŚĂůĞd<ϰΎ ϲϲϳϭ ϲϲϴϴ Ͳϲϯϴϳ ͲϲϰϬϰ ϭϳ Ϭ͘ϲϬ ^^d<ϯΎ ϲϲϴϴ ϲϲϵϭ ͲϲϰϬϰ ͲϲϰϬϴ ϰ Ϭ͘ϲϮ ^^d<ϯΎ ϲϲϵϭ ϲϳϬϱ ͲϲϰϬϴ ͲϲϰϮϮ ϭϰ Ϭ͘ϲϮ ^^d<ϯΎ ϲϳϬϱ ϲϳϮϮ ͲϲϰϮϮ Ͳϲϰϯϴ ϭϲ Ϭ͘ϲϮ ^^d<ϯΎ ϲϳϮϮ ϲϳϰϱ Ͳϲϰϯϴ Ͳϲϰϲϭ Ϯϯ Ϭ͘ϲϮ ^^d<ϯΎ ϲϳϰϱ ϲϳϱϱ Ͳϲϰϲϭ Ͳϲϰϳϭ ϭϬ Ϭ͘ϲϮ ^^ d<ϮΎ ϲϳϱϱ ϲϳϲϮ Ͳϲϰϳϭ Ͳϲϰϳϵ ϴ Ϭ͘ϲϰ ^^d<ϮΎ ϲϳϲϮ ϲϳϳϬ Ͳϲϰϳϵ Ͳϲϰϴϲ ϳ Ϭ͘ϲϰ ^^d<ϮΎ ϲϳϳϬ ϲϳϳϲ Ͳϲϰϴϲ Ͳϲϰϵϯ ϳ Ϭ͘ϲϰ ^^d<ϮΎ ϲϳϳϲ ϲϳϴϯ Ͳϲϰϵϯ Ͳϲϰϵϵ ϲ Ϭ͘ϲϰ ^^d<ϮΎ ϲϳϴϯ ϲϳϴϵ Ͳϲϰϵϵ ͲϲϱϬϱ ϲ Ϭ͘ϲϰ ^^d<ϭΎ ϲϳϴϵ ϲϴϬϭ ͲϲϱϬϱ Ͳϲϱϭϳ ϭϮ Ϭ͘ϲϲ ^^d<ϭΎ ϲϴϬϭ ϲϴϭϯ Ͳϲϱϭϳ ͲϲϱϯϬ ϭϯ Ϭ͘ϲϲ ^^d<ϭΎ ϲϴϭϯ ϲϴϯϮ ͲϲϱϯϬ Ͳϲϱϰϴ ϭϴ Ϭ͘ϲϲ ^^>hΎ ϲϴϯϮ ϲϵϰϰ Ͳϲϱϰϴ Ͳϲϲϲϭ ϭϭϯ Ϭ͘ϳ ^ŝůƚƐͬ^^d<ϱΎ ϲϵϰϰ ϲϵϲϭ Ͳϲϲϲϭ Ͳϲϲϳϳ ϭϲ Ϭ͘ϳ ^ŝůƚƐͬ^^d<ϰΎ ϲϵϲϭ ϳϬϯϭ Ͳϲϲϳϳ Ͳϲϳϰϳ ϳϬ Ϭ͘ϳ ^ŝůƚƐͬ^^dD>sΎ ϳϬϯϭ Ͳϲϳϰϳ Ϭ͘ϳϮ ^ŚĂůĞϰͿ/͛ŵĐƵƌƌĞŶƚůǇŽŶƚŚĞƐůŽƉĞĂŶĚĂǁĂǇĨƌŽŵĂŶǇŵĂƉƐ͕^ĞĂŶŚĂƐĂďĞƚƚĞƌŝĚĞĂŽŶƚŚĞĚŝƐƚĂŶĐĞƐĨƌŽŵƚŚĞǁĞůůďŽƌĞƐƐŽĂƐƐŽŽŶĂƐ/ŐĞƚĂĚŝƐƚĂŶĐĞĨƌŽŵŚŝŵ͕/ĐĂŶƌĞƉŽƌƚŵĞĐŚĂŶŝĐĂůĐŽŶĚŝƚŝŽŶƐ͘ĞůŽǁŝƐƚŚĞǁĞůůůŝƐƚƚŚĂƚ^ĞĂŶŐĂǀĞŵĞŝŶĐůƵĚŝŶŐƚŚĞWϭƐƚŚĂƚ/ŽŵŝƚƚĞĚ͘/ůĞĨƚƚŚĞŵŽĨĨƚŚĞŽƌŝŐŝŶĂůĂƉƉůŝĐĂƚŝŽŶďĞĐĂƵƐĞƚŚĞǇĂƌĞŝŶǌŽŶĞƐŝĚĞƚƌĂĐŬƐǁĞůůďĞůŽǁƚŚĞƉƌŽĚƵĐƚŝŽŶĐĂƐŝŶŐƐŚŽĞ͕ďƵƚ/ǁŝůůŝŶĐůƵĚĞƚŚĞŵŽŶĨƵƚƵƌĞĂƉƉůŝĐĂƚŝŽŶƐ͘;^ĞĂŶͿ͗^ƚĞǀĞ͕ŐŽŽĚĐĂƚĐŚŽŶƚŚĞ>ͲϬϮ͕>ͲϭϬϲ;ĂŶĚǁŚĞŶĚƌŝůůĞĚͿĂƌĞǁŝƚŚŝŶŚĂůĨͲŵŝůĞƌĂĚŝƵƐ͘>ͲϬϭĂŶĚ>ͲϭϮϰĂƌĞŶŽƚǁŝƚŚŝŶŚĂůĨͲŵŝůĞƌĂĚŝƵƐ͘/ĚŽŶŽƚďĞůŝĞǀĞ>ͲϬϮWϮĞǆŝƐƚƐ͘dŚĞƌĞŵĂŝŶĚĞƌŽĨƚŚĞǁĞůůƐŽŶǇŽƵƌůŝƐƚƐŚŽƵůĚďĞŝŶƌŽĚŝĞ͛ƐƚĂďůĞ͘ĂǀŝĚ͞ƌŽĚŝĞ͟tĂŐĞƐ KƉƐŶŐŝŶĞĞƌ͗ϳϭϯ͘ϯϴϬ͘ϵϴϯϲ&ƌŽŵ͗ĂǀŝĞƐ͕^ƚĞƉŚĞŶ&;K'ͿфƐƚĞǀĞ͘ĚĂǀŝĞƐΛĂůĂƐŬĂ͘ŐŽǀх^ĞŶƚ͗tĞĚŶĞƐĚĂǇ͕&ĞďƌƵĂƌǇϭϲ͕ϮϬϮϮϲ͗ϱϬWDdŽ͗ƌŽĚŝĞtĂŐĞƐфĂǀŝĚ͘tĂŐĞƐΛŚŝůĐŽƌƉ͘ĐŽŵхĐ͗ZŝǆƐĞ͕DĞůǀŝŶ';K'ͿфŵĞůǀŝŶ͘ƌŝǆƐĞΛĂůĂƐŬĂ͘ŐŽǀх͖^ĞĂŶtĂŐŶĞƌф^ĞĂŶ͘tĂŐŶĞƌΛŚŝůĐŽƌƉ͘ĐŽŵх^ƵďũĞĐƚ͗Z͗΀ydZE>΁Wh>Ͳϭϭϲ;WdϮϮϭͲϬϴϮ͖^ƵŶĚƌǇϯϮϮͲϬϱϭͿͲYƵĞƐƚŝŽŶƐĂŶĚZĞƋƵĞƐƚƐƌŽĚŝĞͬ^ĞĂŶ͗/ŚĂǀĞĂŶŽƚŚĞƌƋƵĞƐƚŝŽŶ͕ƐŽ/͛ǀĞĐŽŵďŝŶĞĚĂůůŽĨŵǇůĂƚĞƐƚƋƵĞƐƚŝŽŶƐĂŶĚƌĞƋƵĞƐƚƐŝŶƚŽƚŚŝƐĞŵĂŝůƐŽƚŚĂƚŶŽƚŚŝŶŐŝƐŽǀĞƌůŽŽŬĞĚ͘/ĚŽŚĂǀĞƐŽŵĞĂĚĚŝƚŝŽŶĂůƌĞƋƵĞƐƚƐ͗ϭ͘ŽƵůĚ,ŝůĐŽƌƉĂůƐŽƉůĞĂƐĞƐƵƉƉůǇĐĂƐŝŶŐĂŶĚĐĞŵĞŶƚŝŶŐŝŶĨŽƌŵĂƚŝŽŶĨŽƌ>Ͳϭϭϲ͍Ϯ͘tŚĂƚĂƌĞ,ŝůĐŽƌƉ͛ƐŵĞĂƐƵƌĞĚĚĞƉƚŚƐĨŽƌƚŽƉƐŽĨĐĞŵĞŶƚŝŶ>ͲϭϭϲĂŶĚ>Ͳϭϭϲ͍,ŽǁǁĞƌĞƚŚĞƐĞǀĂůƵĞƐĚĞƚĞƌŵŝŶĞĚ͍ϯ͘ŽƵůĚ,ŝůĐŽƌƉĂůƐŽƉůĞĂƐĞƉƌŽǀŝĚĞĨƌĂĐŐƌĂĚŝĞŶƚŝŶĨŽƌŵĂƚŝŽŶĨŽƌƚŚĞƉůĂŶŶĞĚĨƌĂĐƚƵƌĞǌŽŶĞŝŶƚŚĞ<ƵƉĂƌƵŬĂŶĚĂůƐŽĨŽƌƚŚĞƵŶĚĞƌůǇŝŶŐĐŽŶĨŝŶŝŶŐDŝůƵǀĞĂĐŚĂŶĚ<ŝŶŐĂŬ^ŚĂůĞ͍ϰ͘/ŶĂĚĚŝƚŝŽŶƚŽƚŚĞǁĞůůƐůŝƐƚĞĚŝŶdĂďůĞϰŽĨ,ŝůĐŽƌƉ͛Ɛ^ƵŶĚƌǇƉƉůŝĐĂƚŝŽŶ͕ĚŽĂŶǇŽĨƚŚĞĨŽůůŽǁŝŶŐǁĞůůƐŽƌƉůƵŐŐĞĚͲďĂĐŬǁĞůůďŽƌĞƐƚƌĂŶƐĞĐƚƚŚĞĐŽŶĨŝŶŝŶŐǌŽŶĞƐǁŝƚŚŝŶŽŶĞͲŚĂůĨŵŝůĞŽĨƚŚĞ>ͲϭϭϲǁĞůů͍/ĨƐŽ͕ƉůĞĂƐĞƌĞƉŽƌƚŽŶƚŚĞŵĞĐŚĂŶŝĐĂůĐŽŶĚŝƚŝŽŶŽĨĞĂĐŚ͘W/ WĞƌŵŝƚ KƉĞƌĂƚŽƌ tĞůůEĂŵĞ tĞůůEŽ͘ ^ƚĂƚƵƐ ůĂƐƐ dϱϬϬϮϵϮϯϬϭϭϬϭ ϮϭϰϭϱϯϬ W Wh >ͲϬϭ ϭͲK/> s ϭϰϳϯϬϱϬϬϮϵϮϯϬϰϴϬϬ ϮϬϭϮϬϳϬ W Wh >ͲϬϮ WΘ s ϭϯϱϳϮϱϬϬϮϵϮϯϬϰϴϳϬ ϮϬϰϭϰϵϬ W Wh >ͲϬϮWϭ WůƵŐďĂĐŬ E ϭϯϯϱϮϱϬϬϮϵϮϯϬϰϴϳϭ ϮϬϰϭϰϵϬ W Wh >ͲϬϮWϮ WůƵŐďĂĐŬ E ϭϯϭϱϯϱϬϬϮϵϮϯϬϱϱϬϬ ϮϬϭϮϮϯϬ W WhKZ>/^ >ͲϭϬϲ ϭͲK/> s ϳϰϱϱϱϬϬϮϵϮϯϬϱϱϬϭ ϮϮϭϭϬϭϬ W WhKZ>/^ >ͲϭϬϲ WE s ϴϴϰϬϱϬϬϮϵϮϯϬϯϮϬϬ ϮϬϭϭϯϲϬ W WhKZ>/^ >Ͳϭϭϰ WΘ s ϴϮϳϬϱϬϬϮϵϮϯϮϱϱϬϬ ϮϬϱϬϰϯϬ W WhKZ>/^ >ͲϭϮϰ ϭͲK/> s ϭϬϳϳϰ 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avid Douglas Hilcorp Alaska, 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 or fax to 907 564-4422. Received By: Date: Hilcorp North Slope, LLC Date: 03/01/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: PBU L-116A PTD: 221-082 API: 50-029-23025-01-00 FINAL LWD FORMATION EVALUATION LOGS (02/07/2022 to 02/11/2022) Multiple Propagation Resistivity & Gamma Ray (2” & 5” MD/TVD Color Logs) Final Definitive Directional Surveys SFTP Transfer - Data Folders: Please include current contact information if different from above. 221-082 T36382 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.03.01 12:39:13 -09'00' Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Monty M Myers Drilling Manager Hilcorp North Slope, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Prudhoe Bay Field, Borealis Oil Pool, PBU L-116A Hilcorp North Slope, LLC Permit to Drill Number: 221-082 Surface Location: 2372' FSL, 3743' FEL, Sec. 34, T12N, R11E, UM, AK Bottomhole Location: 1608' FNL, 2097' FEL, Sec. 34, T12N, R11E, UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCCwithin 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jeremy M. Price Chair DATED this ___ day of October, 2021. Jeremy Price Digitally signed by Jeremy Price Date: 2021.10.08 14:20:41 -08'00' 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name: 5. Bond: Blanket Single Well 11. Well Name and Number: Bond No. 3. Address:6. Proposed Depth: 12. Field/Pool(s): MD: 9,308' TVD: 6,481' 4a. Location of Well (Governmental Section): 7.Property Designation: Surface: Top of Productive Horizon:8.DNR Approval Number:13.Approximate Spud Date: Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10.KB Elevation above MSL (ft): 76.2'15.Distance to Nearest Well Open Surface: x-583174 y- 5978094 Zone- 4 48.2' to Same Pool: 670' 16.Deviated wells: Kickoff depth: 6,675 feet 17.Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 111 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 3-1/4" 2-3/8" 6.5# L-80 Hyd511 2,833' 6,475' 6,269' 9,308' 6,481' 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): None TVD 28' - 109' 27' - 2,572' 24' - 6,966' Hydraulic Fracture planned? Yes No 20. Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements Contact Name: Trevor Hyatt Monty Myers Contact Email:trevor.hyatt@hilcorp.com Drilling Manager Contact Phone:777-8396 Date: Permit to Drill API Number: Permit Approval Number:Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 7,000' January 1, 2022 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Surface Perforation Depth TVD (ft): GL / BF Elevation above MSL (ft): Perforation Depth MD (ft): 2,626' 260 sx Arctic Set (Approx.) 28' - 109' 27' - 2,653'7-5/8" 443 sx AS Lite, 175 sx Class 'G' Effect. Depth MD (ft): Effect. Depth TVD (ft): Authorized Title: Authorized Signature: 217 sx LiteCreteProduction Liner 7,149' Intermediate Authorized Name: 6,675' - 6,835' Conductor/Structural 20"81' 7,190'6,983' LengthCasing None Cement Volume MDSize Plugs (measured): (including stage data) 92 sx Class 'G' 7,032' 6,825' 2560 18.Casing Program: Top - Setting Depth - BottomSpecifications 3,488 Total Depth MD (ft): Total Depth TVD (ft): 107205344 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 2,828 1740' FNL, 731' FWL, Sec. 34, T12N, R11E, UM, AK 1608' FNL, 2097' FEL, Sec. 34, T12N, R11E, UM, AK 00-001 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 Hilcorp North Slope, LLC 2372' FSL, 3743' FEL, Sec. 34, T12N, R11E, UM, AK ADL 028239 PBU L-116A Prudhoe Bay Field Borealis Oil Pool Cement Quantity, c.f. or sacks Commission Use Only See cover letter for other requirements.50-029-23025-01-00 6,468' - 6,628' 24' - 7,173'5-1/2" x 3-1/2" ooo o o ooo o o o Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) 9.30.2021Digitally 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: 2021.09.30 13:28:14 -08'00' Monty M Myers By Meredith Guhl at 1:42 pm, Sep 30, 2021 MGR08OCT2021 DLB 10/05/2021 DLB X 2,828 221-082 X X DSR-9/30/21 X X X BOPE Test to 3500 psi for service coil window milling. Separate sundry required for perforating. Variance to 20 AAC 25.112(i) alternate plug placement approved. BOPE test to 3500 psi for CT drilling on CDR2. X dts 10/8/2021 JLC 10/8/2021 10/8/21 Jeremy Price Digitally signed by Jeremy Price Date: 2021.10.08 14:20:19 -08'00' To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: September 30, 2021 Re: PBU L-116A Permit to Drill Approval is requested for drilling a CTD sidetrack lateral from well PBU L-116 with the Nabors CDR2 Coiled Tubing Drilling. Proposed plan for L-116A Producer: See L-116 Sundry request for complete pre-rig details - Prior to drilling activities, a 3-1/2" Packer Whipstock will be set pre-rig with E-line in the 3-1/2" casing. The top parent perforations will remain open (6,675'-6,682' MD – above whipstock packer element). The parent perforations below 6,682’ MD will be abandoned. Service Coil will mill a single string window in the 3-1/2” casing (if scheduling needs arise, the rig will mill the window). A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. The well will kick off drilling in the Kuparuk C, build through C and land in Kuparuk B. The well will build back up and drill the lateral in Kuparuk C to TD. The proposed sidetrack will be completed with a 2-3/8” L-80 solid liner, cemented in place and selectively perforated and fracked post rig (see future L-116A Frac Sundry). This completion will completely isolate and abandon the parent Kuparuk perfs. The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is attached for reference. Pre-Rig Work: x Reference L-116 Sundry submitted in concert with this request for full details. x General work scope of Pre-Rig work: 1.Slickline: Dummy WS drift, dummy GLMs, run caliper, set/pull TTP for MIT 2.Fullbore: MIT-IA and MIT-T 3.E-line: Set 3-1/2” Packer Whipstock* 4.Service Coil: Mill Window Rig Work - (Estimated to start in January 2022): 1. MIRU and test BOPE to 3500 psi. MASP with gas (0.10 psi/ft) to surface is 2,828 psi a. Give AOGCC 24hr notice prior to BOPE test b. Test against swab and master valves (No TWC) c. Load pits with drilling fluid d.Open well and ensure zero pressure 2.Only if not done pre-rig - Mill 2.80” single string window (out of 3-1/2”) plus 10’ of rathole. a. Top of window (whipstock pinch point) at 6,675’ MD. b.Mill window with straight motor c. Hold 11.8 ppg MPD while milling window 3.Drill – Build & Lateral a.2-3/8” BHA with GR/RES / Bi-center Bit (3.25”) b.42° DLS build section – 262’ MD / Planned TD 6,937’ MD c. 12° DLS lateral section – 2,371’ MD / Planned TD 9,308’ MD d.Drill with a constant bottom hole pressure for entire sidetrack e.Pressure deployment will be utilized f.After TD and on the last trip out of hole lay in completion/kill weight fluid in preparation for liner run g.No flow test prior to laying down drilling BHA Sundry 321-523 24 hour notice to AOGCC to witness BOPE test before window milling begins. PTD 221-082 4. Run and Cement 2-3/8” L-80 solid liner a. Have 2-3/8” safety joint with TIW valve ready to be picked up while running liner b. Release from liner and come out of hole. c. Make up cementing BHA and sting into liner shoe. Swap the well over to 2% KCl. d.Cement liner with 19 bbls, 15.3 ppg Class G (TOC to TOL).* e.Freeze protect well from ~2200’ MD (min) f. RDMO Post Rig: 1. V: Valve & tree work 2.S: Set LTP* (if necessary) 3.C: Post rig perforate (~90’), three stage frac, FCO/mill to TD (see future L-116A Frac Sundry) 4.S: Set live WFRVs * Approved alternate plug placement per 20 AAC 25.112(i) Managed Pressure Drilling: The history of CTD at KRU in the Kuparuk reservoir, has demonstrated the benefits of a managed pressure drilling technique. Due to uncertainties about the bottom hole pressures to be encountered as this sidetrack is drilled, managed pressure drilling techniques will be employed on this well. The intent is to provide constant bottom hole pressure by using minimum 8.6 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow use of lighter drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A MPD choke for regulating surface pressure is located between the WC choke manifold and the mud pits and will be independent of the WC choke. Deployment of the BHA under trapped wellhead pressure will be necessary. Pressure deployment of the BHA will be accomplished utilizing 3” (bighole) & 2-3/8” (slimhole) pipe/slip rams (see attached BOP configurations). The annular preventer will act as a secondary containment during deployment and not as a stripper. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected: MPD Pressure at the Planned Window (6,675’ MD - 6,392’ TVD) Pumps On Pumps Off A Target BHP at Window (ppg)3,922 psi 3,922 psi 11.8 B Annular friction - ECD (psi/ft)601 psi 0 psi 0.09 C Mud Hydrostatic (ppg)2,859 psi 2,859 psi 8.6 B+C Mud + ECD Combined 3,459 psi 2,859 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain 463 psi 1,064 psi Target BHP at window and deeper Operation Details: Reservoir Pressure: x The maximum reservoir pressure is expected to be 3,488 psi at 6,600’ TVD (10.2 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,828 psi. EMW needed = 8.6 ppg. Managed Pressure Drilling procedure employed with CTD. DLB End of PTD 221-082 Separate fracturing sundry required. Mud Program: x Drilling: Minimum MW of 8.6 ppg KCL with Geovis for drilling. Managed pressure used to maintain constant BHP. x KWF will be stored on location. The tankage will contain 1.5 wellbore volumes of KWF to exceed the maximum possible BHP to be encountered as the lateral is drilled. Adjust with real time BHP monitoring. x Completion: A minimum MW 10.3 ppg KWF to be used for liner deployment. Will target 11.8 ppg to match managed pressure target. Disposal: x All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4 or Pad 3 at DS 6. x Fluids >1% hydrocarbons or flammables must go to Pad 3. x Fluids >15% solids by volume must go to GNI. x Fluids with solids that will not pass through 1/4” screen must go to GNI. x Fluids with PH >11 must go to GNI. Hole Size: x 3.25” hole for the entirety of the production hole section. Liner Program: x 2-3/8”, 6.5#, L-80 solid/cemented liner: 6,475’ MD – 9,308’ MD (2,833’ liner) x The primary barrier for this operation: Kill Weight Fluid to provide overbalance as necessary x A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Well Control: x BOP diagram is attached. MPD and pressure deployment is planned. x Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. x The annular preventer will be tested to 250 psi and 3,500 psi. x An X-over shall be made up to a 2-3/8” safety joint including a TIW valve for all tubulars ran in hole. x 1.5 wellbore volumes of KWF will be on location at all times during drilling operations. Directional: x Directional plan attached. Maximum planned hole angle is 111°. Inclination at kick off point is 3°. x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. x Distance to nearest property line – 7,000’ x Distance to nearest well within pool – 670’ Logging: x MWD directional, Gamma Ray, and Resistivity will be run through the entire open hole section. x Real time bore pressure to aid in MPD and ECD management. Perforating: x ~90’ perforated post rig. Anti-Collision Failures: x No failures Hazards: x PBU L-pad is an H2S pad. The highest recorded H2S well on the pad was from L-110 (1,110 ppm) in 2021. Last recorded H2S on L-116 was 108 ppm in 2018 x Two fault crossings expected. x Medium lost circulation risk. Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka 907-223-3087 May require higher mud weight to provide overbalance. Assure well dead prior to running liner. 6WDQGDUG3URSRVDO5HSRUW 6HSWHPEHU 3ODQ/$ZSD +LOFRUS$ODVND//& 3UXGKRH%D\ / 3ODQ/ 3ODQ/$ 5550570058506000615063006450660067506900True Vertical Depth (300 usft/in)-150 0 150 300 450 600 750 900 1050 1200 1350 1500 1650 1800 1950 2100 2250 2400 2550 2700Vertical Section at 51.66° (300 usft/in)L-116A wp02 polygonL-116A wp02 CP1.5L-116A wp02 CP2L-116A wp02 CP3L-116A wp02 CP4L-116A wp02 CP16000650070007190L-1163 1/2" TOW2 3/8" x 3 1/4"7 0 0 0 7 5 0 0 8000 850090009308L-116A wp08aKOP: Start Dir 9º/100' : 6675' MD, 6468.32'TVD : 180.5° RT TFStart Dir 42º/100' : 6695' MD, 6488.29'TVDStart Dir 12º/100' : 6937.51' MD, 6627.05'TVDTotal Depth : 9308' MD, 6481.36' TVDHilcorp Alaska, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Ellipsoid SeparationWarning Method: Error RatioWELL DETAILS: Plan: L-116Ground Level: 48.20+N/-S +E/-WNorthingEastingLatitudeLongitude0.000.005978093.86583173.75 70° 21' 0.4380 N 149° 19' 29.0152 WSURVEY PROGRAMDate: 2021-09-23T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool106.73 6675.00 L-116 Srvy #1 MWD+IFR+MS (L-116) 3_MWD (BP MWD+IFR+MS-WOCA)6675.00 9308.00 L-116A wp08a (Plan: L-116A) 3_MWDREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: L-116, True NorthVertical (TVD) Reference:Kelly Bushing / Rotary Table @ 76.20usftMeasured Depth Reference:Kelly Bushing / Rotary Table @ 76.20usftCalculation Method: Minimum CurvatureProject:Prudhoe BaySite:LWell:Plan: L-116Wellbore:Plan: L-116ADesign:L-116A wp08aCASING DETAILSTVD TVDSS MD SizeName6469.32 6393.12 6676.00 3-1/2 3 1/2" TOW6481.36 6405.16 9308.00 2-3/8 2 3/8" x 3 1/4"SECTION DETAILSSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target1 6675.00 3.65 281.79 6468.32 1170.02 -805.40 0.00 0.00 94.102 6695.00 1.85 281.30 6488.29 1170.22 -806.35 9.00 180.50 93.483 6937.51 100.00 101.30 6627.05 1138.86 -649.41 42.00 180.00 197.12AnnotationKOP: Start Dir 9º/100' : 6675' MD, 6468.32'TVD : 180.5° R77)Start Dir 42º/100' : 6695' MD, 6488.29'TVDStart Dir 12º/100' : 6937.51' MD, 6627.05'TVD4 7027.51 110.80 101.30 6603.19 1121.88 -564.45 12.00 0.00 253.225 7087.51 110.63 109.00 6581.94 1107.23 -510.33 12.00 90.00 286.586 7222.51 109.77 91.75 6535.01 1084.58 -386.28 12.00 -90.00 369.837 7322.51 107.48 104.18 6502.961071.41 -292.67 12.00 99.00 435.088 7642.51 85.49 72.29 6466.10 1082.98 18.99 12.00 -122.00 686.709 7817.51 88.29 93.13 6475.69 1105.00 191.34 12.00 83.00 835.5510 8067.51 91.01 63.25 6477.26 1155.59 433.26 12.00 -85.01 1056.6711 8267.51 90.92 87.25 6473.83 1206.12 625.23 12.00 90.00 1238.5912 8467.51 90.84 63.25 6470.70 1256.66 817.21 12.00 -90.00 1420.5213 8792.51 85.63 101.93 6481.09 1297.89 1133.12 12.00 98.00 1693.8814 9017.51 89.72 75.22 6490.38 1303.51 1355.78 12.00 -82.001872.0015 9242.51 92.92 102.04 6485.08 1308.88 1578.58 12.00 83.00 2050.0816 9308.00 93.58 94.19 6481.36 1299.66 1643.25 12.00 -85.00 2095.09 Total Depth : 9308' MD, 6481.36' TVD 7008751050122514001575175019252100227524502625280029753150South(-)/North(+) (350 usft/in)-875 -700 -525 -350 -175 0 175 350 525 700 875 1050 1225 1400 1575 1750 1925 2100 2275West(-)/East(+) (350 usft/in)L-116A wp02 CP1L-116A wp02 CP4L-116A wp02 CP3L-116A wp02 CP2L-116A wp02 CP1.5L-116A wp02 polygon350037504000425045004750525057506982L-1163 1/2" TOW2 3/8" x 3 1/4"6481L-116A wp08aKOP: Start Dir 9º/100' : 6675' MD, 6468.32'TVD : 180.5° RT TFStart Dir 42º/100' : 6695' MD, 6488.29'TVDStart Dir 12º/100' : 6937.51' MD, 6627.05'TVDTotal Depth : 9308' MD, 6481.36' TVDCASING DETAILSTVDTVDSS MDSize Name6469.32 6393.12 6676.00 3-1/2 3 1/2" TOW6481.36 6405.16 9308.00 2-3/8 2 3/8" x 3 1/4"Project: Prudhoe BaySite: LWell: Plan: L-116Wellbore: Plan: L-116APlan: L-116A wp08aWELL DETAILS: Plan: L-116Ground Level: 48.20+N/-S+E/-WNorthing Easting Latitude Longitude0.00 0.005978093.86 583173.7570° 21' 0.4380 N 149° 19' 29.0152 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: L-116, True 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'LVWDQFH%HWZHHQ3URILOHV'LVWDQFH%HWZHHQ3URILOHV(OOLSVH6HSDUDWLRQ'LVWDQFH%HWZHHQFHQWUHVLVWKHVWUDLJKWOLQHGLVWDQFHEHWZHHQZHOOERUHFHQWUHV$OOVWDWLRQFRRUGLQDWHVZHUHFDOFXODWHGXVLQJWKH0LQLPXP&XUYDWXUHPHWKRG6HSWHPEHU &203$663DJHRI 0.001.002.003.004.00Separation Factor6750 6900 7050 7200 7350 7500 7650 7800 7950 8100 8250 8400 8550 8700 8850 9000 9150 9300 9450 9600Measured Depth (300 usft/in)L-116L-101No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.WELL DETAILS:Plan: L-116 NAD 1927 (NADCON CONUS)Alaska Zone 04Ground Level: 48.20+N/-S +E/-W Northing EastingLatitudeLongitude0.000.005978093.86583173.7570° 21' 0.4380 N149° 19' 29.0152 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: L-116, True NorthVertical (TVD) Reference:Kelly Bushing / Rotary Table @ 76.20usftMeasured Depth Reference:Kelly Bushing / Rotary Table @ 76.20usftCalculation Method: Minimum CurvatureSURVEY PROGRAMDate: 2021-09-23T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool106.73 6675.00 L-116 Srvy #1 MWD+IFR+MS (L-116) 3_MWD (BP MWD+IFR+MS-WOCA)6675.00 9308.00 L-116A wp08a (Plan: L-116A) 3_MWD0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)6750 6900 7050 7200 7350 7500 7650 7800 7950 8100 8250 8400 8550 8700 8850 9000 9150 9300 9450 9600Measured Depth (300 usft/in)GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference6675.00 To 9308.00Project: Prudhoe BaySite: LWell: Plan: L-116Wellbore: Plan: L-116APlan: L-116A wp08aLadder / S.F. PlotsCASING DETAILSTVD TVDSS MD Size Name6469.32 6393.12 6676.00 3-1/2 3 1/2" TOW6481.36 6405.16 9308.00 2-3/8 2 3/8" x 3 1/4" Well Slimhole Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 6.0 ft Top of Annular Element 6.7 ft Bottom Annular 8.0 ft CL Blind/Shears 9.3 ft CL 2" Pipe/Slips 10.1 ft B1 B2 B3 B4 Choke Line Kill Line CL 2-3/8" Pipe/Slips 12.6 ft CL 2" Pipe/Slips 13.4 ft CL of Top Swab 16.0 ft Swab Test Pump Hose T1 T2 Swab 1 CL of Flow Cross 17.4 ft Master CL of Master 18.8 ft LDS IA OA LDS Ground Level CDR2-AC 4 Ram BOP Schematic 21-Nov-17 CDR2 Rig's Drip Pan 7-1/16" 5k Flange X 7" Otis Box Hydril 7 1/16" Annular 2" Pipe/Slips 7-1/16" 5k Mud Cross 2" Pipe/Slips Blind/Shear 7-1/16" 5 Mud Cross 2-3/8" Pipe/Slips Revised 2/2015 TRANSMITTAL LETTER CHECKLIST WELL NAME: ______________________________________ PTD: _____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD: ____________________________ POOL: ______________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit No. _____________, API No. 50-_______________________. Production should continue to be reported as a function of the original API number stated above. Pilot Hole In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name (_______________________PH) and API number (50-_____________________) from records, data and logs acquired for well (name on permit). Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. (_____________________________) as Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for well ( ) until after ( ) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (________________________) must contact the AOGCC to obtain advance approval of such water well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (_______________________________) in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. 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