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Home My WebLink About214-0497. 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 C-29B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 214-049 50-029-21472-02-00 15680 Conductor Surface Liner Liner AICD Liner 9049 3054 3972 7989 4140 1594 12550 13-3/8" 9-5/8" 7" 4-1/2" 2-3/8" 9015 48 - 3102 46 - 4018 3840 - 11829 11538 - 15678 12636 - 14230 48 - 2788 46 - 3461 3329 - 8461 8210 - 9049 9042 - 9054 None 2670 4760 5410 7500 11780 12550, 14250, 14740, 15170 5380 6870 7240 8430 11200 11836 - 15588 4-1/2" 12.6# 13cr85 44 - 11544 8467 - 9050 Structural 80 20" x 30" 49 - 129 49 - 129 4-1/2" HES TNT Perm Packer 11425 8113 Torin Roschinger Operations Manager Leif Knatterud leif.knatterud@hilcorp.com 9075644667 PRUDHOE BAY, PRUDHOE 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 0028305, 0028310 44 - 8215 N/A N/A 320 185 30081 12798 46 0 900 800 880 980 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed 11425, 8113 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 2:15 pm, May 20, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.05.20 12:37:02 - 08'00' Torin Roschinger (4662) RBDMS JSB 052325 DSR-6/3/25JJL 6/13/25 ACTIVITY DATE SUMMARY 4/27/2025 *** WELL S/I ON ARRIVAL *** RAN 20' x 3.66" DUMMY GUNS, 3.70 CENT TO 11900' SLM (heavy p/u weight) RAN 3.66'' CENT, 2'x1-7/8'', 3.70'' CENT TO DEVIATION @ 12553'SLM ***WELL LEFT S/I ON DEPARTURE*** 5/15/2025 *** WELL S/I ON ARRIVAL*** OBJECTIVE: (SET PLUG IN ZONE/ ADPERF) MIRU YELLOW JACKET E-LINE. PT PCE 300 PSI LOW./3000 PSI HIGH ( FUNCTION TEST WLVS ) CORRELATE TO PRACTIVE DIAGNOSTIC SERVICES COIL FLAG LOG DATED 22 APRIL 2015 SET YJOS CIBP AT 12550' CCL-ME=12.7', CCL STOP=12537.3', TAG AFTER SET PERFORATE 11836'-11861' WITH 3.375" 6SPF 60PHASE HSC W/GEODYNAMICS BASIX CHARGES (.46"EHD, 46.32"TTP) CCL-TS=15.8', CCL STOP=11820.2', VERIFY SHOTS FIRED RDMO YELLOWJACKET E-LINE ***WELL S/I ON DEPARTURE*** JOB COMPLETE Daily Report of Well Operations PBU C-29B Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:214-049 6.50-029-21472-02-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 15680 14250 9053 11425 None 8113 Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 80 20" x 30" 49 - 129 49 - 129 Surface 3054 13-3/8" 48 - 3102 48 - 2788 5380 2670 Intermediate 3972 9-5/8" 46 - 4018 46 - 3461 6870 4760 Production 7989 7" 3840 - 11829 3329 - 8461 7240 5410 Liner 4140 4-1/2" 11538 - 15678 8210 - 9049 8430 7500 Perforation Depth: Measured depth: 12750 - 15588 feet True vertical depth:9056 - 9050 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13cr85 44 - 11544 44 - 8215 11425 8113Packers and SSSV (type, measured and true vertical depth) 4-1/2" HES TNT Perm Packer AICD Liner 1594 2-3/8" 12636 - 14230 9042 - 9054 11200 11780 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 856250142553 200 34384 Well Not Online 700 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Wyatt Rivard wrivard@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907.777.8547 Treatment descriptions including volumes used and final pressure: 13. Sr. Area Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9049 Sundry Number or N/A if C.O. Exempt: 321-303 No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Install AICD Operations shutdown Change Approved Program 5 N/A Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028310 PBU C-29B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 14250, 14740, 15170 By Samantha Carlisle at 3:02 pm, Aug 17, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.08.17 14:11:08 -08'00' Stan Golis (880) MGR19AUG2021 RBDMS HEW 8/19/2021 DSR-8/18/21 ACTIVITY DATE SUMMARY 7/9/2021 CTU 9, 1.75" CT - 31.9bbl, Job Objective: PPROF, Mill XN MIRU. RIH with 3.70" Bypass nozzle with well flowing. ...In Progress... 7/10/2021 CTU 9, 1.75" CT - 31.9bbl, Job Objective: PPROF, Mill XN. Continue to RIH with 3.70" bypass nozzle with the well flowing. Tagged CIBP and got weight back at 14255'. PUH and paint safety flag. POOH. Allow well to stablize in the test separator. Make up and RIH with SLB PPROF toolstring w/ ghost. Perform dynamic passes at 40, 60, & 80fpm and stop counts. POOH. Confirm good logging data. RIH with 3.80" left handed milling assembly to mill XN. ...In Progress... 7/11/2021 CTU 9, 1.75" CT - 31.9bbl, Job Objective: PPROF, Mill XN. Continue RIH with 3.80" left handed milling assembly. Mill out XN to 3.800", confirmed with 3.800" centralizer. Continue in hole and dry drift to CIBP at 14250. Based on correction at XN nipple, top of CIBP = 14258.7'. POOH and freeze well with 38bbl of diesel. Flowline freeze protected with 29bbl of 50/50. Pad operator notified of well status. RDMO. ...Job Complete... *** XN Milled to 3.800" *** 7/19/2021 Cost Placeholder for AICD RWO Liner Tangibles (Liner, AICDs, Swell Packers, Blast Joints and LTP) 7/24/2021 T/I/O= 0/300/0 (Pre-RWO L&K) Pumped 5 BBL's of 50/50 methanol followed by 260 BBL's of 1% KCL to load & kill the tubingl. Tag hung on wing @ departure. Valve positions= SV, SSV= shut IAC, OAC, TC= OTG MV= Open. FWHP= 0/320/0 7/24/2021 T/I/O = Vac/250/0. Set CTS #4 w/T-bar. RD 4-1/16" CIW tree and 13-5/8" FMC THA. Set test plug in CTS & removed SBMS seal. Installed 13-5/8" YJ BOP's & shooting flange w/ new BX-160 ring gasket, torque to spec. RDMO. 7/25/2021 Thunderbird Rig #1: Mobilize from R-40 to C-29B. R/U on C-29B. Shell test w/ 2-7/8 x 5-/12" VBR's w/ 2-7/8" Test Jt prior to state witnessed BOP test. AOGCC witnessed BOP test (Lou Laubenstein) Layout liner assy in running order w/ Northern Solutions and Baker. Pull CTS. Well on vac. Pull BPV. Monitor well. Well on 26 BPH losses. ...Continue WSR on 7/26/2021... 7/26/2021 Thunderbird Rig #1 ...Continue WSR from 7/25/2021... Prepare to run 2-3/8" Liner. Well on 19 BPH losses. RIH w/ 2-3/8" AICD Liner on Baker KB45 setting tool using 2 7/8" Ph6 work string. ...Continue WSR on 7/27/2021... 7/27/2021 Thunderbird Rig 1 Job Scope: Run 2-3/8" AICD retrofit liner accross existing perforations in 4-1/2" liner ...Continue WSR from 7/26/2021... TIH w/ 2-7/8" PH6 work string to set AICD LNR. PU weight 40% high after running through high dogleg section Pump 95 bbls .6% Safelube in 1% KCL down backside @ 150 psi @ .7 bpm. Briefly moved liner @ 155k Up. Cont TIH w/ liner assy. Park bttm of liner @ 14,155'. RIH w/ GR/CCL . Tie-in found short joint to be 52' short of planned depth to set AICD LNR. RIH with additional joint and pups to put LNR on depth for setting. Ran Gamma/CCL to confirm LNR was at setting depth. RD Eline and prep to set PKR. ...Continue WSR on 7/28/2021... Daily Report of Well Operations PBU C-29B Daily Report of Well Operations PBU C-29B 7/28/2021 Thunderbird Rig 1 Job Scope; Run and set AICD liner. ... Continue WSR from 7/28/2021... Pumped 25 bbls diesel down work string, dropped 5/8" Phenolic ball, pumped additional 4 bbls diesel then swapped to 1% KCL. Ball landed 10 bbls early attempted to set PKR 2108 psi on work string. Bled down to 500 psi and lined up to load and test PKR on backside of work string. Caught fluids and saw pressure get up to 900 psi at 1.5 bpm. PKR appears to not be set. Lined back up to pump down work string and brought pressure up to 2600 psi. Held for a few minutes and bled back down to 500 psi, Lined up down backside of work string and pressure tested PKR to 1585 psi. Wyatt Rivard witnessed. Shear and released from PKR at 3400 psi. PUH and get running tool out of PKR Bullhead remaining diesel from work string. watch well for 30 min and start TOH laying down 2-7/8" DP. Limited to 15 fpm due to excessive DP chatter @ faster speeds (induces violent vibration in derrick). Order Lube-776. Pump backside volume 2% Lube-776 in .25 ppb Flo-vis. 26% improvement in PU Wt and 7x increase in POH Speed (POH speed only limited by rig capability) Work Sting w/BOT running tool OOH. Set TWC and release rig. ***Job Complete*** 7/29/2021 RD BOP, RU THA, RU Tree. Leak tested against TWC 500/5000 PSI (Pass). Pulled TWC. Reconnected piping, set well house and reconnected I&E. RDMO. ***Job Complete***. 7/29/2021 T/I/O=0/206/0 Post RWO Load tbg with 250 bbls diesel to sweep kcl and to initiate packer swell. FWHP's=1900/205/0 STATE OF ALASKA Reviewed By: 5"&C— OIL AND GAS CONSERVATION COMMISSION P.I. Supry -VI-0- ZI BOPE Test Report for: PRUDHOE BAY UNIT C -29B " Comm Contractor/Rig No.: Hilcorp Thunderbird I ' PTD#: 2140490 ' DATE: 7/25/2021 Inspector Lou Laubenstein - Insp Source Operator: Hilcorp North Slope, LLC Operator Rep: Bass/Fraizer Rig Rep: Parker/Flores Inspector Type Operation: WRKOV Sundry No: Test Pressures: Inspection No: bopLOL210727073141 Rams: Annular: Valves: ntASP: 321-303 ----- - Related Ins No: Type Test: INIT 250/3000 - 250/2500 ' 250/3000 � 2430 � p TEST DATA MISC. INSPECTIONS: MUD SYSTEM: P/F ACCUMULATOR SYSTEM: _ 0 NA - P/F 0 Visual Alarm Ball Type Time/Pressure P/F Location Gen.: P Trip Tank P _ - P System Pressure 3000 P " Housekeeping: P Pit Level Indicators P P Pressure After Closure 1600 P PTD On Location P Flow Indicator NA NA 200 PSI Attained 24 P " Standing Order Posted P Meth Gas Detector P - P Full Pressure Attained 104 P " Well Sign P - H2S Gas Detector P P Blind Switch Covers: yes _' P ' Drl. Rig P MS Misc 1 FP Nitgn. Bottles (avg): 6 (d), 2300 P Hazard Sec. P Check Valve 0 ACC Misc 0 NA Misc NA FLOOR SAFTY VALVES: BOP STACK: Quantity P/F Upper Kelly _ 0 NA - Lower Kelly 0 NA Ball Type 1 P - Inside BOP 1 P ' FSV Misc 0 NA BOP STACK: CHOKE MANIFOLD: Quantity Size P/F Quantity P/F Stripper 0 -_ NA_ No. Valves _ 11 P Annular Preventer 1 13 5/8" P - Manual Chokes 2 P #1 Rams 1 ' 2 7/8_x_5 1/2 P Hydraulic Chokes 0 NA #2 Rams 1 Bli_n_d_s FP CH Misc 0 NA #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA INSIDE REEL VALVES: #6 Rams 0 NA (Valid for Coil Rigs Only) Choke Ln. Valves 1 - 3.1/8" P Quantity P/F HCR Valves 1 3 1/8" P Inside Reel Valves 0_ NA Kill Line Valves _ 3 " 31 /8" P Check Valve 0 NA BOP Misc 3 - flanges/cushoo-/FP Number of Failures: 5 - Test Results Test Time 7 ' Remarks: Test was completed using a 2 7/8" and 3 1/2" test joints. H2S head on riq floor wasn't connected to the system and had to be reset. Blinds failed to hold DP, they were functioned and passed retest. BOP Misc failures; 1 -Cushion tee on the Kill line was +� orientated wrong an was moved. 2- Flange on the choke line well side leaked, it was tightened and retested. 3- Flange on the choke line Manifold side leaked, it was tightened and retested. David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-5245 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt and return one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 07/22/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Log Date Log Type PBU 15-48C 500292263503 211-030 6/16/2021 CBL PBU B-07A 500292028501 214-091 1/20/2021 CBL PBU C-03C 500292012403 212-058 7/10/2021 PPROF PBU C-29B 500292147202 214-049 7/10/2021 PPROF PBU C-41B 500292238502 213-104 6/26/2021 CBL PBU F-10C 500292041003 213-086 7/11/2021 CBL PBU P2-34 500292255800 195-066 6/17/2021 CBL Please include current contact information if different from above. Received By: 07/23/2021 37' (6HW By Abby Bell at 9:33 am, Jul 23, 2021 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:214-049 6.API Number:50-029-21472-02-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0028305 & 0028310 Property Designation (Lease Number):10. CO 341H 8. PBU C-29B 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Install AICD Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 15680 Effective Depth MD: 13cr85 11. Commission Representative: 15. Suspended Contact Name: Wyatt Rivard Contact Email: wrivard@hilcorp.com Authorized Name: Stan Golis Authorized Title:Sr. Area Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9049 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 11425, 8112 No SSSV Installed Date: Liner 4140 4-1/2" 11538 - 15678 8210 - 9049 8430 7500 Well Status after proposed work: 16. Verbal Approval: 5 Change Approved Program 48 - 3102 48 - 2788 14. Estimated Date for Commencing Operations: BOP Sketch 49 - 129 Structural 6870 Proposal Summary 13. Well Class after proposed work: 4-1/2" HES TNT Perm Packer 12750 - 15588 9056 - 9050 4-1/2" 12.6#44 - 11544 Production 14250 9053 None 49 - 129 13-3/8" 9-5/8" Contact Phone:907.777.8547 Date: 4760 80 20" x 30"Conductor 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 3054 5380 Intermediate 3972 46 - 4018 46 - 3461 7989 7" 3840 - 11829 3329 - 8461 7240 5410 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 2430 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. 14250, 14740, 15170 7/10/21 By Samantha Carlisle at 8:32 am, Jun 21, 2021 321-303 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.06.21 07:16:02 -08'00' Stan Golis (880) MGR24JUN21 SFD 6/21/2021 BOPE test to 3000 psi. Annular to 2500 psi. DSR-6/21/21 10-404 dts 6/24/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.06.25 11:47:51 -08'00' RBDMS HEW 6/25/2021 FCO and RWOLiner Install C-29B PTD:214-049 Well Name:C-29B API Number:50-029-21472-02 Current Status:Producing Rig:TBird 1, CTU,EL Estimated Start Date:7/10/2021 Estimated Duration:30 days Reg.Approval Req’std?N/A Date Reg. Approval Rec’vd:N/A Regulatory Contact:Abbie Barker Permit to Drill Number:214-049 First Call Engineer:Wyatt Rivard (907) 777-8547 (O)(509) 670-8001 (M) Second Call Engineer:Noel Nocas (907) 564-5278 (O)(907) 229-9532(M) Post Work Est. Rates:15 MMSCFD, 700 BOPD, 100 BWPD into HP Current Bottom Hole Pressure:3218 psi @ 8,800’ TVD 7.1 PPGE | SBHPS taken 12/24/2016 Maximum Expected BHP:3310 psi @ 8,800’ TVD 7.3 PPGE | Average Ivishak BHP) Max. Anticipated Surface Pressure:2430psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:1200 psi (Taken on 2/13/21) Min ID:3.8” ID XN @ 11532’ MD Max Angle:95 Deg @ 129171’ Reference Log:SLB Vision Services MWD Log dated 5-13-2014 to 6-9-2014 Brief Well Summary: C-29B is a natural flow sidetrack completed with a 4-1/2” horizontal liner extending ~1750’MD through zone 2A before crossing a fault and traveling an additional ~1000’ through zone 1B. All zone 1B perfs have been isolated and the well is producing through six distinct zone 2A intervals added in Feb 2021. The GOR trend from these intervals indicates that gas breakthrough may have occurred through one or more perf intervals. Going forward an Automated Inflow Control Device (AICD) liner will be installed to control/isolate gas production from individual zones while maximizing production from lower GOR intervals. Objective: x Utilize CTU to production log then mill out XN profile and cleanout/drift ahead of liner install. x Utilize Thunderbird – 1 to run 2-3/8” AICD retrofit liner across existing perforations in 4-1/2” production liner. Notes Regarding Wellbore Condition x MIT-T and MIT-IA passed to 3500 psi on rig on 6-18-2014 Sundry Procedure (Approval Required to Proceed) Coil Tubing – PPROF, Mill XN & Drift 1. MIRU Coiled Tubing Unit and spot ancillary equipment. a. Coordinate with PPC and Pad Op to have well tested prior to and during logging job 2. MU GR/CCL/SPIN/Press/Temp and gas hold-up tool. 3. RIH to ~12650' MD. a. Bring well online while RIH for stabilization. Goal is to produce the well as close to possible to actual producing conditions. 4. Once well stable, log down and up passes from ~12650’ to ~14210’ at 40, 60 and 80 fpm. a. Take one pass up to ~11450’ to confirm no gas entry occurring at LTP. 5. Take 5 min stop counts between perf intervals at ~14210’, 14000’, 13810’, 13550’,13200’, 12880’, 12650’ MD and 11450’ MD 6. POOH and confirm good data. 7. MU 3.8” mill and cleanout BHA. 8. RIH and mill 4-1/2” XN at 11532’ MD to 3.8” ID ahead of 3.67” OD AICD liner install. FCO and RWOLiner Install C-29B PTD:214-049 9. Once XN milled out, continue 3.8” drift to CIBP set at 14250’ MD. Cleanout as needed, obtain updated tag of CIBP. POOH. 10. RDMO Pre-RWO*Note: Depending on timing of rig move, well kill and BOP installation steps may be performed on rig rather than pre-rig. 11. RU hot oil and PT lines to 3000 psi. 12. Bullhead 300 bbls of 8.4 ppg 1% KCl or equivalent down tubing to the formation. a. Wellbore volume = .0152 bpf x 12750ft = 194 bbls. 13. Confirm well is dead. Freeze protect tubing as needed with diesel, crude or 60/40. b. Freeze protect is up to the discretion of the Wellsite Supervisor depending on timing for arrival of the rig. 14. RD hot oil truck. 15. Clear and level pad area in front of well. Spot rig mats and containment. 16. RD well house and flowlines. Clear and level area around well. 17. Verify 0 psi on the annulus and tubing pressure. 18. Set BPV w/insert (TWC) and test. ND Tree and THA. 19. NU BOPE configured top down: Annular, 2-7/8”x5-1/2” VBRs, Blinds and integral flow cross. a. Note: 2-3/8” AICD Liner is comprised primarily of blast joints (3.063” OD), ported intervals (two- way communication) and swell packers. 2-7/8” x 5-1/2” VBRs will seal across blast joints. A pre- staged 2-7/8” safety joint will be used for sealing during makeup of all other liner components. RWO 20. MIRU Thunderbird 1 workover rig and ancillary equipment 21. Bleed TBG/IA pressures to ~0psi. Kill well w/8.4 ppg 1% KCl or equivalent as needed. 22. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hours in advance of BOP test. b. Perform Test per “Thunderbird # 1 Test Procedure” c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram and Annular on 2-7/8” and 3-1/2” test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 23. Pull TWC 24. PU 2-3/8” AICD liner as detailed on proposed liner tally and run liner with 2-7/8” work string. a. Pickup an open TIW valve, 2-7/8” Safety Joint and XO prior to making up liner. b. In the event that well begins to flow while making up blast joints (3.063” OD), an open TIW can be installed and 2-7/8”x5-1/2” VBRs closed on blast joint then TIW closed. c. For all other liner components, (2-3/8” base pipe, swell packers, AICDs, etc.) install safety joint with open TIW, lower safety joint and close pipe rams, close TIW. 25. Tag CIBP at 14250’ MD for rough depth correction. a. PU and position Liner Top Packer at ~12,634’ MD based on proposed liner tally. 26. Rig up Eline for liner depth tie-in. with lubricator 3000 psi FCO and RWOLiner Install C-29B PTD:214-049 27. RIH with GR/CCL and confirm liner spaceout with respect to perforation reference log. a. SLB Vision Services MWD Log dated 5-13-2014 to 6-9-2014 28. RDMO Eline 29. Circulate 50 bbls diesel down the work string taking returns up the backside to leave swell packers in hydrocarbon. a. Workstring volume = 12600’ * .0052 bpf = 66 bbls b. 2-3/8” Liner Volume = 1600’ * .0040 bpf = 7 bbls c. 2-3/8”x4-1/2” Annular volume = 1600’ * .0097 bpf = 16 bbls 30. Drop ball and displace with 10 bbls diesel followed by 1% KCL to set Liner Top Packer and release liner 31. POOH with workstring. 32. Bleed tubing pressure back to ~0 psi. Set TWC. 33. RDMOThunderbird WO Rig and ancillary equipment. Move to next well location. 34. ND BOPE. NU the THA and tree. Test tubing hanger void and tree to 500 psi low/5,000 psi high. 35. Pull TWC. Post-Rig Procedure: 36. RU and bullhead 250 bbls diesel down the tubing into formation to freeze protect and prevent 1% KCL from swapping behind liner and hampering packer swell 37. Leave well SI for a minimum of 14 days prior to putting well on production to allow swell packers to swell. 38. Obtain AOGCC witnessed SVS test within 5 days of putting well online Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic 4. Blank RWO MOC Form 5. C-29B Tie-In Log FCO and RWOLiner Install C-29B PTD:214-049 As-Built Schematic FCO and RWOLiner Install C-29B PTD:214-049 Proposed Schematic FCO and RWOLiner Install C-29B PTD:214-049 FCO and RWOLiner Install C-29B PTD:214-049 FCO and RWOLiner Install C-29B PTD:214-049 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approve d By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date FCO and RWOLiner Install C-29B PTD:214-049 C-29B Tie-In Log FCO and RWOLiner Install C-29B PTD:214-049 C-29B Tie-In Log 1 Winston, Hugh E (CED) From:Carlisle, Samantha J (CED) Sent:Monday, June 21, 2021 11:06 AM To:Winston, Hugh E (CED) Subject:FW: [EXTERNAL] RE: PBU C-29B (PTD #214-049) 10-403 Sundry Request Attachments:C-29B Appr Sundry 03-31-20.pdf From: Abbie Barker <Abbie.Barker@hilcorp.com> Sent: Monday, June 21, 2021 8:43 AM To: Carlisle, Samantha J (CED) <samantha.carlisle@alaska.gov> Cc: Stan Golis <sgolis@hilcorp.com>; Wyatt Rivard <wrivard@hilcorp.com> Subject: RE: [EXTERNAL] RE: PBU C‐29B (PTD #214‐049) 10‐403 Sundry Request All, Hilcorp North Slope will not be utilizing Sundry # 320‐142 (attached) that was granted to BP on 3/31/20. The online records do not indicate that this sundry was ever closed or expired. If the status of that sundry is still open, please cancel it. Hilcorp North Slope will be executing similar work but under Sundry #320‐472 (completed with 404 filed) and the requested Sundry earlier this morning. Apologies that I did not get this information into my earlier email. Thank you, Abbie Abbie Barker Regulatory Tech, Prudhoe Bay West Team Hilcorp North Slope Email: Abbie.Barker@hilcorp.com Office: (907)564‐4915 Cell: (907)351‐2459 From: Carlisle, Samantha J (CED) <samantha.carlisle@alaska.gov> Sent: Monday, June 21, 2021 8:32 AM To: Abbie Barker <Abbie.Barker@hilcorp.com> Cc: Stan Golis <sgolis@hilcorp.com>; Wyatt Rivard <wrivard@hilcorp.com> Subject: [EXTERNAL] RE: PBU C‐29B (PTD #214‐049) 10‐403 Sundry Request Received for processing From: Abbie Barker <Abbie.Barker@hilcorp.com> Sent: Monday, June 21, 2021 8:32 AM To: Carlisle, Samantha J (CED) <samantha.carlisle@alaska.gov> RBDMS HEW 6/22/2021 2 Cc: Stan Golis <sgolis@hilcorp.com>; Wyatt Rivard <wrivard@hilcorp.com> Subject: PBU C‐29B (PTD #214‐049) 10‐403 Sundry Request Hello, Please see attached for 10-403 Sundry Request for C-29B Fill Cleanout & AICD Installation RWO. If you have any questions or need additional information, please let me know. Thank you, Abbie Abbie Barker Regulatory Tech, Prudhoe Bay West Team Hilcorp North Slope Email: Abbie.Barker@hilcorp.com Cell: (907)351‐2459 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. David Douglas Hilcorp 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 907 777.8510 Received By: Date: Hilcorp North Slope, LLC Date: 06/14/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL: FTP Folder Contents: Log Print Files and LAS Data Files: Well API PTD # Log Date Log Type Log Vendor 09-05B 500292021502 219001 5/7/2021 SCMT SCHLUMBERGER 13-19 500292069000 181180 5/4/2021 SCMT SCHLUMBERGER C-29B 500292147202 214049 1/26/2021 SCMT SCHLUMBERGER E-17A 500292047001 204204 4/28/2021 SCMT SCHLUMBERGER E-34A 500292243701 214096 5/3/2021 SCMT SCHLUMBERGER L-106 500292305500 201223 6/5/2021 PPROF SCHLUMBERGER V-109 500292312000 202202 6/11/2021 PPROF SCHLUMBERGER Z-34 500292346900 212061 5/22/2021 SCMT SCHLUMBERGER Z-35 500292288400 198093 5/23/2021 SCMT SCHLUMBERGER Please include current contact information if different from above. 06/14/2021 Received By: 37' (6HW By Abby Bell at 3:24 pm, Jun 14, 2021 Samuel Gebert Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 02/15/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU C-29B (PTD 214-049) RPM 01/25/2021 ANALYSIS RAW DATA Please include current contact information if different from above. Received by the AOGCC 02/16/2021 PTD: 2140490 E-Set: 34699 02/16/2021 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:214-049 6.50-029-21472-02-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 15680 14250 9053 11425 8112 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" x 30" 49 - 129 49 - 129 Surface 3054 13-3/8" 48 - 3102 48 - 2788 5380 2670 Intermediate 3972 9-5/8" 46 - 4018 46 - 3461 6870 4760 Liner 7989 7" 3840 - 11829 3329 - 8461 7240 5410 Perforation Depth: Measured depth: 12750 - 15588 feet True vertical depth:9056 - 9050 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr85 44 -11544 44 - 8215 11425 8112Packers and SSSV (type, measured and true vertical depth) 4-1/2" HES TNT Perm Packer Liner 4140 4-1/2" 11538 - 15678 8210 - 9049 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 9456033741990 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Wyatt Rivard wrivard@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:(907)777-8547 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations 5 Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9049 Sundry Number or N/A if C.O. Exempt: 320-472 No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Extended Perf w CTU Operations shutdown Change Approved Program 5 N/A Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend 5Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028305 & 028310 PBU C-29B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 14250, 14740, 15170 No Test as of 2/8/21 360 By Samantha Carlisle at 5:36 pm, Feb 08, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.02.08 16:37:29 -09'00' RBDMS HEW 2/8/2021 MGR19FEB2021 SFD 2/9/2021DSR-2/9/21 ACTIVITY DATE SUMMARY 1/24/2021 CTU-6 1.75" X.156" Coil CV=37.8bbl RPM and SCMT Log / Extended AdPerf MIRU. RIH w/3.68" JSN dummy drift. Tag 14770 ctm, paint blue safety flag 14700' POOH. Chrome drag, pump safelube CTBS POOH. MU and RIH with Baker RPM logging tool ***IN PROGRESS*** 1/25/2021 CTU-6 1.75" X.156" Coil CV=37.8bbl RPM and SCMT Log / Extended AdPerf RIH with Baker RPM logging tool. MU/RIH w/ SLB SCMT. Log 13,000-11,500' POOH MU/RIH W/ 3.59" CIBP ***IN PROGRESS*** 1/26/2021 CTU-6 1.75" X.156" Coil CV=37.8bbl RPM and SCMT Log / Extended AdPerf RIH and set Baker 3.59" CIBP @ 14,250' PUH P.T. 1500psi. POOH. Cut 100' pipe/packoffs/chain insp. MU/RIH with gun#1 SLB 2.88" PJ HMX. Perforate 14,036'- 14,166' Con't on 1/27/21 1/27/2021 CTU-6 1.75" X.156" Coil CV=37.8bbl Job Scope: RPM and SCMT Log / Extended AdPerf. Finish pulling OOH. MU/RIH with gun stage #2 SLB 2.88" PJ HMX. Tag CIBP, correct depth. PUH and perforate 13690' -13790' & 13830' - 13940'. Pooh. Shots fired, ball recovered. Undeploy gun#2. MU/RIH with gun stage #3: SLB 2.88" x 200' PJ HMX. Tagged the plug at 14061 ctm, 14042 up depth, depth was not zeroed at surface hence the difference. Corrected the depth to bottom shot depth of 14249.35. PUH to 13460' MD. Launched 1/2" ball with 60/40 methanol. Ball seated at 38 bbls away, had to take returns to get the ball to bottom. Freeze protected the surface lines after ball sheared out. Perforated 13260-13460'.Lined up on 1% KCL w/ safelube and kept the hole full while POOH. ***Job continued on 1/28/21*** 1/28/2021 CTU-6 1.75" X.156" Coil CV=37.8bbl Job Scope: RPM and SCMT Log / Extended AdPerf. Finished POOH. Laid down the gun, all shots fired. Perform weekly BOP test. Swap 60/40 Transport. Make up BOP. C/O Packoffs, inspect Chain. Cut ~100' of pipe. MU BOT Coil Connect. ***Job Continued on 1/29/2021*** Daily Report of Well Operations PBU C-29B Daily Report of Well Operations PBU C-29B 1/29/2021 CTU-6 1.75" X.156" Coil CV=37.8bbl Job Scope: RPM and SCMT Log / Extended AdPerf. Gun Run # 4, Perforated 12930-13130 with 2-7/8" 6 spf 60 degreee phasing gun. POOH keeping the well full with 1% KCL w/ safelube. Pump across the top to verify no flow. Pull / LD Perf gun run #4. (10 guns) . MU/RIH with Gun Run #5, Perforated 12,750' - 12,830' with SLB Power Jet 2906, 2-7/8" 6 spf 60 degreee phasing guns Positive fire for gun, POOH maintaining hole fill. Flow check, Verify Well dead, Break and LD Guns. ***Job Complete*** Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:214-049 6.API Number:50-029-21472-02-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028305 & 028310 Property Designation (Lease Number):10. CO 341H 8. PBU C-29B 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations 5 Fracture Stimulate Repair Well Operations shutdown Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 15680 Effective Depth MD: 13Cr85 11. 11/11/2020 Commission Representative: 15. Suspended Contact Name: Wyatt Rivard Contact Email: wyatt.rivard@hilcorp.com Authorized Name: Stan Golis Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9049 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill 5Perforate Perforate New Pool 11425, 8112 Date: Liner 4140 4-1/2" 11538 - 15678 8210 - 9049 8430 7500 Well Status after proposed work: 16. Verbal Approval: 5 Change Approved Program 48 - 3102 48 - 2788 14. Estimated Date for Commencing Operations: BOP Sketch 49 - 129 Structural 6870 Proposal Summary 13. Well Class after proposed work: 4-1/2" HES TNT Perm Packer 14320 - 15588 9051 - 9050 4-1/2" 12.6#44 - 11544 Production 14740 9049 14740, 15170 None 49 - 129 13-3/8" 9-5/8" Contact Phone:(907)777-8547 Date: 4760 80 20" x 30"Conductor 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 3054 5380 Intermediate 3972 46 - 4018 46 - 3461 7989 7" 3840 - 11829 3329 - 8461 7240 5410 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 2430 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. Extended Perf with CTU By Samantha Carlisle at 9:32 am, Nov 06, 2020 320-472 Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2020.11.06 08:38:34 - 09'00' Stan Golis 10-404 SFD 11/6/2020 DSR-11/10/2020MGR09NOV20 Yesn Required? Comm 11/12/2020 dts 11/12/2020 JLC 11/12/2020 RBDMS HEW 11/12/2020 Plug and Add Perf C-29B PTD:214-049 Well Name:C-29B CTU Plug & Add Perf API Number:50-029-21472-02 Current Status:Producing Rig:CTU & Surface Deployed TCP Guns Estimated Start Date:11/20/2020 Estimated Duration:6days Reg.Approval Req’std?N/A Date Reg. Approval Rec’vd:N/A Regulatory Contact:Abbie Barker Permit to Drill Number:2140490 First Call Engineer:Wyatt Rivard (907) 777-8547 (O)(509) 670-8001 (M) Second Call Engineer:Noel Nocas (907) 777-8449 (O)(907) 947-9533 (M) AFE Number:IOR 1050 Current Bottom Hole Pressure:3218 psi @ 8,800’ TVD 7.1 PPGE | SBHPS taken 12/24/2016 Maximum Expected BHP:3310 psi @ 8,800’ TVD 7.3 PPGE | Average Ivishak BHP) Max. Anticipated Surface Pressure:2430psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:1800 psi (Taken on 5/19/20) Min ID:3.725” ID XN @ 11532’ MD Max Angle:95 Deg @ 129171’ Reference Log:SLB Vision Services MWD Log dated 5-13-2014 to 6-9-2014 Brief Well Summary: C-29B is a natural flow sidetrack completed with a 4-1/2” horizontal liner extending ~1750’MD through zone 2A before crossing a fault and traveling an additional ~1000’ through zone 1B. The well’s initial and 2 nd stage zone 1B perforations have been isolated with CIBPs and the single, open, zone 2A interval has reached marginal GOR. Going forward, existing perforations will be isolated then six zone 2A intervals will be perforated to restore the well to an economic GOR. These six intervals have been selected to allow for future installation of Automated Inflow Control Device (AICD) liner technology. Perforations will be produced until gas breakthrough is observed at which time a 2-3/8” AICD liner can be installed to isolate/control gas production from individual perforated intervals while maximizing production from lower GOR intervals. Objective:Utilize CTU to plug existing 2A perfs. Surface deploy TCP guns then convey to bottom with CTU to add new perfs and restore well to an economic GOR. Sundry Procedure (Approval Required to Proceed): Note: 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. Coil Tubing 1. MIRU Coiled Tubing Unit w/ 1.75“ coil and spot ancillary equipment. 2. MU Cement Bond Logging tools and RIH. 3. Log CBL up from 14,350’ to 12300’ MD. 4. POOH and confirm good data. 5. MU pulsed neutron logging tools (Sigma mode) and RIH. * existing perforations will be isolated then six zone 2A intervals will be perforated t natural flow s Plug and Add Perf C-29B PTD:214-049 6. Log sigma mode up from 14350’ to 12300’ MD, stopping at ±14,200’ MD to paint flag. 7. POOH and confirm good data. 8. Bullhead 250 bbls of 8.4 ppg 1% KCl or 8.5 ppg seawater down the tubing to the formation. a. Wellbore volume = 14320’ X .0152bpf= 218 bbls 9. Confirm well is dead. Freeze protect tubing as needed. 10. MU 4-1/2” composite bridge plug and RIH and correct to flag. 11. Contact OE Wyatt Rivard 1(509) 670-800 or Noel Nocas at 1(907) 947-9533 prior to setting plug/perforating for final approval of tie ins as intervals may have changed slightly based on CBL/SIGMA data. 12. Set composite plug mid-joint at ±14,250’ MD and test to 1500 psi. POOH. 13. At surface, prepare for deployment of TCP guns. 14. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/8.4 ppg 1% KCl or 8.5 ppg as needed. Maintain continuous hole fill taking returns to tank until lubricator connection is reestablished. 15. Pickup 1.75” safety joint and 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. 16. Break lubricator connection at QTS and begin makeup of TCP guns and blanks per Table 1: C-29B ProposedAd-Perf Gun Runs below. Confirm intervals with OE, as intervals may be adjusted based on CBL and SIGMA logs. Table 1: C-29B Proposed Ad-Perf Gun Runs Gun Run # Perf Top Perf Bottom Perf Length 5 ±12730 ±12830 ±100 4 ±12950 ±13150 ±200 3 ±13280 ±13460 ±180 2 ±13710 ±13790 ±80 ±13830 ±13940 ±110 1 ±14006 ±14166 ±160 Total ±830 17. RIH with Gun Run 1 and tag composite bridge plug at ±14,250’ MD correlation. Pickup and perforate intervals per Table 1: C-29B Proposed Ad-Perf Gun Runs. POOH. a. Note any tubing pressure change in WSR. 18. POOH. Stopping at surface to reconfirm well dead and hole full. 19. Review well control steps with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 20. Repeat steps 16 through 19 for Gun Runs 2-5 per Table 1: C-29B Proposed Ad-Perf Gun Runs above. 21. RDMO CTU. 22. RTP or FP well. Assure excess fluids available if needed to keep hole full. Standing orders flow chart included with this sundry request. * See note above in red regarding kill methods if pressure observed on surface after perforating. Plug and Add Perf C-29B PTD:214-049 Attachments: 1. As-built Schematic 2. Proposed Schematic 3. Coil Tubing BOPE Schematic 4. Equipment Layout Diagram 5. Standing Orders for Open Hole Well Control during Perf Gun Deployment 6. Tie In Log/Perf Sheet Plug and Add Perf C-29B PTD:214-049 Plug and Add Perf C-29B PTD:214-049 Proposed Schematic Plug and Add Perf C-29B PTD:214-049 Coiled Tubing BOPs Plug and Add Perf C-29B PTD:214-049 Equipment Layout Diagram Plug and Add Perf C-29B PTD:214-049 Standing Orders for Open Hole Well Control during Perf Gun Deployment Plug and Add Perf C-29B PTD:214-049 C-29B Tie-In Log Plug and Add Perf C-29B PTD:214-049 C-29B Tie-In Log Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: November 4, 2020Subject: Changes to Approved Sundry Procedure for Well C-29BSundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “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 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:214-049 6.API Number:50-029-21472-02-00 PRUDHOE BAY, PRUDHOE OIL BP Exploration (Alaska), Inc 5. Field/Pools:9. Well Name and Number: ADL 028305 & 028310 Property Designation (Lease Number):10. CO 341H 8. PBU C-29B 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 15680 Effective Depth MD: 13Cr85 11. May 1, 2020 Commission Representative: 15. Suspended Contact Name: Hyatt, Trevor Contact Email: Trevor.Hyatt@bp.com Authorized Name:Allen, Kenneth W Authorized Title:Engineering Team Lead Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9049 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill 5Perforate Perforate New Pool 11425 / 8113 No SSSV Installed Date: Liner 4140 4-1/2" 11538 - 15678 8210 - 9049 Well Status after proposed work: 16. Verbal Approval: 5 Change Approved Program 48 - 3102 48 - 2788 14. Estimated Date for Commencing Operations: BOP Sketch 49 - 129 Structural 6870 Proposal Summary 13. Well Class after proposed work: 4-1/2" HES TNT Packer 14320 - 15588 9051 - 9050 4-1/2" 12.6#44 - 11544 Liner 14740 9049 14740, 15170 None 49 - 129 13-3/8" 9-5/8" Contact Phone:+1 907 564 4627 Date: 4760 80 20" x 30"Conductor 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 3054 5380 Intermediate 3972 46 - 4018 46 - 3461 7989 7" 3840 - 11829 3329 - 8491 7240 5410 Address:P.O. Box 196612 Anchorage, AK 99519-6612 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 2340 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. $,&'/LQHUZ6ZHOO 3DFNHUV Kenneth Allen Digitally signed by Kenneth Allen Date: 2020.03.30 13:40:34 -08'00' By Samantha Carlisle at 8:03 am, Mar 31, 2020 320-142 SFD 3/31/2020 10-404 DSR-3/31/2020 *BOPE test to 3500 psi. MGR31MAR20DTS 3/30/2020 03/31/2020 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt CTD Engineer Date: March 26, 2020 Re: C-29B Sundry Approval Request Sundry approval is requested to re-complete C-29B with new perforations and Automated Inflow Control Device (AICD)/Swell packer completion inside the 4-1/2” Liner. Proposed plan for C-29B: The C-29B workover will be performed by Nabors CDR2. The plan is to perforate ~672’ (in Zone 2A) of 4-1/2” production liner and run a 2-3/8” AICD/Swell Packer liner inside the existing liner. This completion will straddle perforation zones with AICDs and swell packers. This retrofit liner is designed to automatically regulate gas production by perf interval or zone. The following describes the work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current well and proposed workover is attached for reference. Pre-Rig Work (scheduled to begin May, 2020) 1. C Drift and Calliper. Run RPM and SCMT. 2. V Pre-CTD Tree work and pad prep Rig Work (scheduled to begin June, 2020) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP: 2340psi) 2. Perforate ~672’ MD with 2-7/8” perf guns, 6 SPF, random, 60° phasing* 3. Perform 4-1/2” liner clean out run 4. Run 2-3/8” 13Cr, AICD/Swell Packer liner inside 4-1/2” liner 5. Freeze protect well to a min 2,200' TVDss. 6. Close in tree, RDMO. *Proposed perforation intervals: Depths (from - to) Feet 12,732' 12,828' 96' 13,281' 13,473' 192' 13,712' 13,936' 224' 14,006' 14,166' 160' Post-Rig Work: 1. V: Valve & tree work 2. S: Set 45KB + PTSA LTP, install generic GLVs 3. T: Portable test separator flowback. Trevor Hyatt CC: Well File CTD Engineer Joe Lastufka 564-4627 24 hour notice for AOGCC to witness. Proposed AICD Swell packer Perforation Bottom of liner ~14,615' Top of liner ~12,618' 2-3/8" 13Cr HYD511, w/ Blast joints across the preforation interval Well Bighole Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 6.0 ft Top of Annular Element 6.7 ft Bottom Annular 8.0 ft CL Blind/Shears 9.3 ft CL 2-3/8" Pipe/Slips 10.1 ft B1 B2 B3 B4 Choke Line Kill Line CL 2-3/8" x 3-1/2" VBRs 12.6 ft CL 2-3/8" Pipe/Slips 13.4 ft CL of Top Swab 16.0 ft Swab Test Pump Hose T1 T2 Swab 1 CL of Flow Cross 17.4 ft Master CL of Master 18.8 ft LDS IA OA LDS Ground Level CDR2-AC 4 Ram BOP Schematic 21-Nov-17 CDR2 Rig's Drip Pan 7-1/16" 5k Flange X 7" Otis Box Hydril 7 1/16" Annular 2-3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8"Pipe/Slips Blind/Shear 7-1/16" 5 Mud Cross 2-3/8" x 3-1/2" VBRs RECEIVED • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS N REPORT OF SUNDRY WELL OPERATIONS NOV 16 2017 1. Operations Performed Abandon 0 Plug Perforations ® Fracture Stimulate 0 Pull Tubing ❑ Operatio q��+� �� 0 Suspend 0 Perforate Ed Other Stimulate 0 Alter Casing 0 Change Ap d1Plb�xdttl♦./ ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well ❑ Re-enter Susp Well 0 Other: Set CIBP RI 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 214-049 3. Address: P.O.Box 196612 Anchorage, Development RI Exploratory ❑ AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21472-02-00 7. Property Designation(Lease Number): ADL 0028310 8. Well Name and Number: PBU C-29B 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 15680 feet Plugs measured 14740/15170 feet true vertical 9049 feet Junk measured feet Effective Depth: measured 14740 feet Packer measured 11425 feet true vertical 9049 feet Packer true vertical 8113 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural • Conductor 80 20"x 30" 49-129 49-129 Surface 3054 13-3/8"72#L-80 48-3102 48-2788 4930 2670 Intermediate 3972 9-5/8"47#L-80 46-4018 46-3461 6870 4760 Production Liner 4140 4-1/2"12.6#13Cr8 11538-15678 8210-9049 9020 8540 Liner 7989 7"26#L-80 3840-11829 3329-8461 7240 5410 Perforation Depth: Measured depth: 14320-14352 feet 14352-14416 feet 14416-14480 feet 14760-14970 feet 15200-15588 feet True vertical depth: 9051-9050 feet feet 9050-9050 feet 9050-9050 feet 9050-9052 feet 9053-9050 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr85 44-11545 44-8216 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 6 Treatment descriptions including volumes used and final pressure: SCANNED D E`' 2 8 2.017 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 406 30015 24 1440 796 Subsequent to operation: Shut-In 1420 1270 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development m Service ❑ Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil a Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Glasheen,Brian P Contact Name: Glasheen,Brian P Authorized Title: Production E %n�f Contact Email: Brian.Glasheen@bp.com Al. Authorized Signature: V Date: 11/( 3 ��, Contact Phone: +1 907 564 5905 Form 10404 Revised 04/2017VL I Z/71/7 -// AI 1,477/7 �/��f [^,�E7 7 1,`, y�t'I 2 FL�a Submit Original Only • Packers and SSV's Attachment PBU C-29B SW Name Type MD TVD Depscription C-29B PACKER 3839.86 3329.17 7" Baker ZXP PKR/HGR C-29B TBG PACKER 11425.4 8112.69 4-1/2" HES TNT Perm Packer C-29B PACKER 11538.01 8210.04 5" Baker ZXP Top Packer • • c -c Lri o NCD 4- C O 3 Ln O O D .- Q CC TD O_ • (a O O O I C Q J It ai a O o c U a� D m Q ° o w o U 't 2 O_ D o 0 J c a O a "- 0 15 Np 0 toui0 N1- O V P-)) oco I > O=� O o 92 O <- D 2 c O , Ul Q O u) - E p Q ca O a ryas� ) L W c L12 a) c O �'c m� Q O C U 03 L a) 0 0a C ca 0 A- N D 0 U-L C - Q •a'-' co -pV a) 00 (a C _ _n ' p a) UU)) V' O N - Q _ a) a) to (n v.. C 4= U s -(7) O_ I C U) CO C Y = 0 co W D m CO O• o _m v) p �V m CO >" Z Y Q) Q J a) v) _- C O 4-+ CC -7 Y .E U O +-� O w U _ o i L p Lo C " 1E .c O rn N ..- OLo , 4) ) cn I I C n o N r- o o N O o C Q E Q L m CL Q. Q C 7 C O O O O -a O Q 0 "D Q) '� w- I- O) P U -o C 0 O mcf) Q 0 0 LL 7 QQ 8 w Q Q 0 - 0 Q D ro ‘- = � awU) o d a. a O C GD N m O n >. I- CO Q) m 0 CO I m 6 U � � � � U c O i o U2EQ 'ON .E ' a) O) E N _C O a) d o f0 D o ocu) oLo •- ca • o o _o o c t m J p p J I J U N p J = O O d 4- O CD'> 0_ U O 4- •- aj = O Q 0. o � = O• ,- O 0 Q`- . 0m � a) 0 .E.' 0_ Ce a) U 3 co o _ a) o _, m m U aci L a) a c a 0 V" L.0 : o_ C › Q. O) Q OU Q (a >, O O_ (aco N o 1- a) o co U) o co 4- (NJ.- v.,O J N + O 6, J p�j @ 000 V (n H - m ,- oho 0 J 0 O Cl W U _ V , U rP' V 1--O _ - O +- C O O _ a) 0 V -� O U O (n O O a) a) 7 CO a) 0 U CC . Uob 0Oio �) � °6 Co . U � ~ coto in c � 6 N Q 'n Q ami `n o aEi c = ai �? I ai Lo o)co m v E O N i V' r p CLQ L CL 03 L 0N V" _O c- O Co O co r N ,- c co O 0 O aD C 4-,, O CO ca O 4- U y� 4- - y,y D L J N�y 't 't L yy D a] c t L o L * D O O -0 w c �l Q_ Q _ X• a) a) O_ "'` U U (a a) a) O_ TM L v) a] Iw U) O � oD � -0 c o_ O_ t � CL 0_ � D u91 � Q_ o c~.) 2En � � Q«, Ua = C W *k * : U2E to o CO NI- « UQ d CO 4k L1.1 QN N- N- N- 0 0 0 0 0 � NN N N CO O CD N N F-• O O O O U Q • S � T E L co E Q) n CD C O W 5 CD N O o Q. a) J CO Q) O V N U � C N o O O Q) coOOZ 2 L O - lip N 00 N co N v— TREE= 4-1/16"CNV • WI3 LHEAD= FMC 2 9 B SAFETY NOTES: WELL ANGLE>70°@ 12586'"'" ACTUATOR= BAKER C SEE PG 2 FOR PREV WELLBORE***CHROME TSG 0 B.ELEV= 67.65' &LNR***MAX DOGLEG:18.8'0, 13270'""* BF.BEV= 38.72' ill 20"COPD — 110' Fi KOP= 850' Max Angie= 95°@12917' Datum MD= 12341' I I 2176' -14-1/2"0115 X t4P D=3.813" Datum TVD= 8800'SS 13-3/8"CSG,72#,L-80 BTC,D=12.347' H 3085' 3840 —9-5/8"X 7"BKR ZXPN LTP,D=6.18" 9-5/8' M-1PSTOC K(05/12/14) — 4018' N � II 3861 9-5/8"X 7"BKR FLEX LOCK HGR,D=6.23" 9-5/8"CSG,47#,L-80 BUTT,D=8.681" —I —4018 _ 9-5/8"SIDETRACK WINDOW(C-29B) 4018'-4035' Minimum ID =3.726" @ 11532' 4-1/2" OTIS XN NIPPLEI\ GAS LETMAPDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3825 3318 43 MMG DOME RK 16 06/01/15 I 3 7302 5300 61 KBG2 DOME BK 16 06/01/15 L 2 9811 6727 35 KBG2 DM' BK 0 06/17/14 1 11118 7847 30 KBG2 DM' BK 0 06/17/14 I I 11396' H4-1/2"OTIS X NIP,D=3.813" k�4 2 11425 --17"X 4-1/2"HES TNT PKR,D=3.856' 11461' —14-1/2"OTIS X NP,D=3.813" 11532 —I4-1/2"OTIS XN NQ,D=3.725" TCW OF 4-1/2"LNR — 11538" 11538 —1 7"X 5"BKR HID E ZXPN LTP w (iIEBK,D=4.34" J 49><"TBG, 12.6#,13CR-85 VAM TOP, 11544' '- '' 11544 H4-1/2"WLEG,D=3.935" bolI IN 0152 bpf,D=3.958" 51 --I ELMD TT NOT LOGGED NOTE PERFORATIONS BEHIND 7 LNR 11562 —7^X 5"BKR DG FLEX-LOCK HGR (5",5 SPF)@11596',11601',11690'& 11695' gill w/LNR X0,D=3.92" 7"CSG,26#,L-80 HYD 563/BTC-M, 11829' 0383 bpf,D=6.276" 14007 H 4.1/2"PLJF'JOINT w/RA TAG PERFORATION SUMMARY ■ REF LOG: SLB MWD on 06/_./14 74 14720 H4 1/2"PI;Q JOINT w/RA TAG ANGLE AT TOP PERE: 91°@ 14320' 0 4-9/2" DCP(10/98/17) _ 1474__�—_ W IB Note:Refer to Production DB for historical pert data �■ SEE SW EITB?VAL Opn/Sqz DATE SQZ 2.75" 6 14320-14480 0 10/19/17 r' 15170 —j4-1/2"BKR CBP(04/23/15) 2.88"r 6 14760-14970 0 04/26/15 2.88"IF 6 15200-15588 C 06/16/14 PBTD(RIG TAGG06/14/14) — 15588' +- ® , 4-1/2"LNR, 12.6#,13CR- ,VAM TOP H 15678' .0152 bpf,D=3.958" DATE REV BY COMvB'ITS DATE REV BY COMVBJTS PRUDHOE BAY UNIT 02/14/86 N22E INITIAL COMPLETION 07/09/14 SWCJJNC GLV C1O(07/07/14) V flL: C-29B 04/20/86 N22E RWO 08/22/14 RKT/JMD GLV C/O(08/09/14) PERMT No:"2140490 12/20/96 NOR 1 CTD SIDETRACK(C-29A) 05/04/15 JCFJMD SET CUP/ADPERFS(04/23-26/15) AR No: 50-029-21472-02 06/06/08 014 RWO 06/26/15 JMM'JMD GLV C/O(06/01/15) SEC 19,T11N,R14E,1901'FPL&884'Fa 06/19/14 PKR 273 SIDETRACK(C-29B) 10/24/17_M/JMD SET CBPYADFERFS(10/18-19/17) 07/01/14 TT/PJC FINAL ODE APPROVAL BP Exploration(Alaska) STATE OF ALASKA ' .SKA OIL AND GAS CONSERVATION COMIN,.._.3ION N. REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon U Plug Perforations LJ Fracture Stimulate U Pull Tubing U Operations shutdown ❑ Performed Suspend ❑ Perforate El Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pod❑ Repair Well ❑ Re-enter Susp Well ❑ Other d_/13P ter 2.Operator 4 Well Class Before Work 5 Permit to Drill Number BP Exploration(Alaska),Inc Name Development 0 Exploratory 214-049-0 3 Address P O Box 196612 Stratigraphic ❑ Service❑ 6 API Number Anchorage,AK 99519-6612 50-029-21472-02-00 7 Property Designation(Lease Number): 8 Well Name and Number ADL0028310 PBU C-29B 9 Logs(List logs and submit electronic and pnnted data per 20AAC25 071) 10 Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary. ^c Total Depth measured 15680 feet Plugs measured 15170 feet E C E I �I`' E D true vertical 9048 76 feet Junk measured None feet MAY 2 8 2015 Effective Depth measured 15170 feet Packer measured See Attachment feet true vertical 9054 21 feet true vertical See Attachment feet ACG CC Casing Length Size MD TVD Burst Collapse V Structural None None None None None None Conductor 80 20"x 30" 48 71-128 71 48 71 -128 7 0 0 Surface 3053 65 13-3/8"72#L-80 48 21 -3101 86 48 21 -2788 17 4930 2670 Intermediate 3971 86 9-5/8"47#L-80 46.14-4018 46 14-3460 98 6870 4760 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 14760-14970 feet 15200-15588 feet True Vertical depth 9049 6-9052.05 feet 9053 43-9049 77 feet SCANNED .J u u 2 06 Tubing(size,grade,measured and true vertical depth) 4-1/2"12 6#13Cr85 44 14-11544 67 44 14-8215 79 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12 Stimulation or cement squeeze summary Intervals treated(measured) Treatment descriptions including volumes used and final pressure 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 350 27820 6 0 784 Subsequent to operation. 413 33704 5 0 161 14 Attachments 15 Well Class after work Copies of Logs and Surveys Run ❑ Exploratory ❑ Development 0 Service Li Stratigraphic ❑ Daily Report of Well Operations D 16 Well Status after work Oil E Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt N/A Contact Garry Catron Email Garry.Catron@BP.Com Printed Name Garry Catron Title PDC PE Signature II aAA Mi Phone 564-4424 Date 5/28/2015 VrL. /ie/lam RBDMS JUN - 3 101& 4 7/0C- Form 10-404 Revised 10/2012 Submit Onginal Only Packers and SSV's Attachment ADL0028310 SW Name Type MD TVD Depscription C-29B PACKER 3839.86 3329.17 7" Baker ZXP PKR/HGR C-29B PACKER 11425.4 8112.69 4-1/2" HES TNT Perm Packer C-29B PACKER 11538.01 8210.04 5" Baker ZXP Top Packer m o, 0000Q R N ; U) (D I) C Lf) co N co V Or N (53 N cO N O O) O m (O r— O) O) CIO CO I� O M co O O Cp N CO CO CO r- • V O N CO CO O) N CO 1 1 1 1 , 1 H r O O N O CO N 1- O 4 V co CO C I,. ccd- C1.1 CO CO - L[) LC) .0 • r O CI it r' CO O ICC M Moo CCY CO v v co C O HL) 0• 2o °O QU 0° U O M J M J Cb O C d M *k J (NI Ik N X It CD f- CO CO O y O N C\O C.) - - LO r- (V ? 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U 3 ° d co ami m 3 0 oa rn� c * _ 3 D _c x o - _c 2 c ° a C a) ib 2 0 O a) a uN) L 2 0 0 2 a) win o U d eo coNu) ti o E co co W• E_ ch a Q CC I- O a ° O 2 Et 6) U c Q ots O v a) •• Q a'S 2 0 a N Q E a) N O O p0 ' N = c C a) p ' a) O CW N 7 Op a) 2 2 j > t a) O * c 0 Co •O C) N a CO c m (6 :� N o_ CO C 'o_ E -§ O a C a 0 ~ a) C °6 Q 2 C =- co m x 0) E C CD -E-' - m o 't _ c E 0 2 N c 2 c -a Q' co E .- •c U U U F- m* ~ O c a) * O 'c p V * r o O O O@ * U U .S U cn a: U U F- _ ate * 0 0 :.= -0 C ° U E E : O O O O N N N N M V to O N N N N d .7 N 0 a) Q d a p O co N O c 0 J cn 0 < 0_ d cc �o 0 L_ m J Y0 a) in En o LO 0 N LC) N co 7o co Tr CO N M TREE= 4-1/16"CNV VII3_LFEAD= RC 2 9 B , _TY NOTES: WELL ANGLE>70°@ 12586'""" ACTUATOR= BAKER C SEE PG 2 FOR PREV WELLBORE""'CI-112041E TBG OKB.EL EV= 67.65' &LNR"'MAX DOGLEG:18.8°0 13270"'" BF.ELEV= 38.72' 20'CONK) --I 110' J I — KOP= 850 Max Angle= 95°@ 1291T Datum MD= 12341' I ' 2176' —14-12"OTIS X NP,D=3.813" Datum TVD= 8800'SS 13-3/8"CSG,72#,L-80 BTC,D=12.347' —I 3085' 3840 H9-5/8"X 7"BKR ZXPN LW,D=6.18" 9-5/8"WiPSTOCK(05/12/14) —I 4018' 3861 II 9-5/8"X 7"BKR FLEX LOCK HGR,D=6.23" 9-5/8"CSG,47#,L-80 BUTT,D=8.681" --I —4018 1� 9-5/8'SIDETRACK WINDOW(C-298) 4018'-4035' Minimum ID =3.726" @ 11632' l 4-1/2" OTIS XN NIPPLE r GAS LFT MAMDRELS ST MD TVD DEV TYPE VLV LATCH FORT DATE 3 4 3825 3318 43 No1M3 DMY RK 0 08/09/14 3 7302 5300 61 KBG2 DMY BK 0 08/09/14 2 9811 6727 35 KBG2 DMY BK 0 06/17/14 1 11118 7847 30 KBG2 DM' BK 0 06/17/14 ' ' 11396' H4-12"OTIS X NP,D=3.813" X 11425 —)7'X 4-12"HES TNT PKR,D=3.856' ' 11461' —H4-12'OTIS X MP,D=3.813" ' 11532 —14-1/2"OTIS XN NP,D=3.725' TOP OF 4-1/2"LNR - 11538' 11538 —7"X 5'BKR I-IRD-E ZXRV LIP w fTEBK,D=4.34" 4-1/2"TBG,12.6#,13CR-85 VAM TOP, — 11544' 11544 —14-1/2"WLEG,D=3.935" .0152 bpf,D=3.958' � H ELN)TT NOT LOGGED NOTE PERFORATIONS BEHIND r LNR: ____: !r, 11562 —7"X 5'BKR 00 FLEX-LOCK HGR (5",5 SPF)@11596',11601',11690'&11695' 4' r �; w/LNR XO,D=3.92" r i. 7"CSG,26#,L-80 HYD 563/BTC-M, H 11829' , 0383 bpf,D=6.276" '�! 14007 H 4-12'PUP JONT w/RA TAG i PERFORATION SUMMARY " t 14720 —14-12"PUP JOINT w/RA TAG REF LOG: SLB MWD on 06/_/14 ~ v ANGLE AT TOP PERF: 90°@ 14760' 15170 —14-12'BKR CBP(0423/15) Note:Refer to Production DB for historical perf data ~, ,;