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225-007
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 D-08B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 225-007 50-029-20372-02-00 12327 Surface Intermediate Liner Liner Liner 9077 2638 6874 2686 246 3012 11943 13-3/8" 9-5/8" 7" 4-1/2" 3-1/2" x 3-1/4" x 2-7/8" 8835 31 - 2669 29 - 6903 6744 - 9430 9262 - 9508 9315 - 12327 31 - 2669 29 - 6204 6081 - 8521 8369 - 8591 8417 - 9077 None 2670 4760 5410 7500 10530 11943 5380 6870 7240 8430 10160 11752 - 11995 4-1/2" 12.6# 13Cr80 27 - 9271 8726 - 8867 Conductor 79 20" x 30" 31 - 110 31 - 110 4-1/2" Baker S-3 Perm Packer 9214 8326 Torin Roschinger Operations Manager Finn Oestgaard finn.oestgaard@hilcorp.com 907.564.5026 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 0028285, 0028286 27 - 8377 N/A N/A 177 412 21842 27217 1757 0 1184 2020 802 782 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed 9214, 8326 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.06.04 10:16:14 - 08'00' Torin Roschinger (4662) By Grace Christianson at 10:35 am, Jun 04, 2025 JJL 6/13/25 RBDMS JSB 061225 ACTIVITY DATE SUMMARY 5/21/2025 LRS CTU #1 - 1.50" Blue Coil Job Objective: Post CTD Re-Perf: Drift/Log/CIBP/ Perfs Travel to location. MIRU CTU #1. ...Job in Progress*** 5/22/2025 LRS CTU #1, 1.5" CT, 0.134" WT. Job Objective: Drift/Log/CIBP/ Perfs Rig Mobilization. MIRU CTU #1 Pump 7/8" drift Ball, Weekly BOP test. 250psi Low/4000psi High. NU & Function Test BOP's . Make up 1.69 NS CTC/MHA, HES 2.200" GR/CCL, and 2.25" DJN. Load well with 190 bbl of 1% KCL. Log from 12001 CTM to 9075 CTM. Flag pipe at 11874 for CIBP and guns. POOH. Correlate log data. MU & RIH with NS 2.875" CIBP. ...Job in Progress*** 5/23/2025 LRS CTU #1 - 1.50" Blue Coil Job Objective: Post CTD Re-Perf: Drift/Log/CIBP/ Perfs Load & pump 3/8" ball, Set CIBP top at 11,943'. Stack~ 5k surface weight. PT Plug to 1000psi - good set. Pooh pumping displacement. Lay down CIBP setting BHA. Hold man down drill with day crew. Make up and RIH with 2" HES Maxforce perf gun (15' loaded). Peforate 11752-11767. POOH and FP well with 18 bbl of 50/50. Lay down perf gun and notify DSO of well status. RDMO. ***Job Complete*** ***Man down drill with day crew*** Daily Report of Well Operations PBU D-08B Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 5/29/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250529 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 19RD 50133205790100 219188 5/10/2025 AK E-LINE GPT/CIBP/Perf HVB 13A 50231200320100 224160 3/16/2025 YELLOWJACKET SCBL IRU 241-01 50283201840000 221076 5/7/2025 AK E-LINE Plug/Perf KBU 22-06Y 50133206500000 215044 5/6/2025 AK E-LINE Perf KBU 22-06Y 50133206500000 215044 5/7/2025 AK E-LINE Perf KBU 24-06RD 50133204990100 206013 4/8/2025 YELLOWJACKET GPT-PLUG MPI 1-61 50029225200000 194142 5/10/2025 AK E-LINE Perf MPU E-42 50029236350000 219082 5/3/2025 AK E-LINE Patch MPU S-55 50029238130000 225006 5/13/2025 AK E-LINE CBL OP16-03 50029234420000 211017 4/25/2025 READ LeakDetect PAXTON 13 50133207330000 225021 4/29/2025 YELLOWJACKET SCBL PBU 01-12B 50029202690200 223090 4/8/2025 HALLIBURTON RBT PBU D-08B 50029203720200 225007 3/22/2025 BAKER MRPM PBU H-17B (REVISION)50029208620100 197152 4/10/2025 HALLIBURTON RBT-COILFLAG PBU J-25B 50029217410200 224134 3/10/2025 BAKER MRPM PBU K-19C (REVISION)50029225310300 224004 3/27/2025 BAKER MRPM PBU K-19C 50029225310300 224004 3/27/2025 HALLIBURTON RBT SRU 241-33B 50133206960000 221053 3/12/2025 YELLOWJACKET PERF Revision Explanation: Both wells had wrong side stack well name and API#/PTD on previous upload H-17b was marked as H-17A and K-19C was marked as K-19B. Well name now reflets correct sidetrack and has correct SPI# and PTD. T40489 T40490 T40491 T40492 T40492 T40493 T40494 T40495 T40496 T40497 T40498 T40499 T40500 T40501 T40502 T40503 T40503 T40504 PBU D-08B 50029203720200 225007 3/22/2025 BAKER MRPM Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.29 14:33:01 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 4/10/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#2025010 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 211-26 50283201280000 208112 1/27/2025 AK E-LINE PPROF T40287 END 1-41 50029217130000 187032 3/13/2025 HALLIBURTON MFC40 T40288 END 2-14 50029216390000 186149 3/12/2025 HALLIBURTON MFC40 T40289 END 3-33A 50029216680100 203215 3/23/2025 HALLIBURTON COILFLAG T40290 GP AN-17A 50733203110100 213049 12/29/2024 AK E-LINE Perf T40291 KALOTSA 3 50133206610000 217028 3/3/2025 AK E-LINE PPROF T40292 KU 12-17 50133205770000 208089 1/28/2025 AK E-LINE Perf T40293 MPI 2-14 50029216390000 186149 2/17/2025 AK E-LINE Plug/Cement T40294 NCIU A-21 50883201990000 224086 3/28/2025 AK E-LINE Plug-Perf T40295 ODSN-25 50703206560000 212030 3/7/2025 HALLIBURTON CORRELATION T40296 PBU 02-08B 50029201550200 198095 3/17/2025 HALLIBURTON RBT T40297 PBU D-08B 50029203720200 225007 3/22/2025 HALLIBURTON RBT T40298 PBU J-25B 50029217410200 224134 3/10/2025 HALLIBURTON RBT T40299 PBU K-12D 50029217590400 224099 3/18/2025 HALLIBURTON RBT T40300 PBU K-19B 50029225310200 215182 3/27/2025 HALLIBURTON RBT T40301 PBU L1-15A 50029219950100 203120 3/27/2025 HALLIBURTON PPROF T40302 PBU M-207 50029238070000 224141 3/18/2025 HALLIBURTON IPROF T40303 PBU P1-04 50029223660000 193063 3/28/2025 HALLIBURTON PPROF T40304 PBU W-220A 50029234320100 224161 3/11/2025 HALLIBURTON RBT T40305 Revision explanation: Fixed API# on log and .las files Please include current contact information if different from above. T40298PBU D-08B 50029203720200 225007 3/22/2025 HALLIBURTON RBT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.10 13:48:56 -08'00' David Douglas Hilcorp North Slope, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 04/04/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: PBU D-08B PTD: 225-007 API: 50-029-20372-02-00 FINAL LWD FORMATION EVALUATION LOGS (03/08/2025 to 03/17/2025) Multiple Propagation Resistivity & Gamma Ray (2” & 5” MD/TVD Color Logs) Pressure While Drilling (PWD) Final Definitive Directional Surveys SFTP Transfer - Data Main Folders: SFTP Transfer - Data Sub-Folders: Please include current contact information if different from above. 225-007 T40279 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.04 14:45:13 -08'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PRUDHOE BAY UNIT D-08B JBR 04/28/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 3"PS operator Koomey hose failed and was replaced, good test otherwise. Test Results TEST DATA Rig Rep:Madson/McGrathOperator:Hilcorp North Slope, LLC Operator Rep:Igtanloc/Williams Rig Owner/Rig No.:Nabors CDR3AC PTD#:2250070 DATE:3/7/2025 Type Operation:DRILL Annular: 250/3500Type Test:INIT Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopAGE250309142151 Inspector Adam Earl Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 8.5 MASP: 2399 Sundry No: Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 2 P Inside BOP 0 NA FSV Misc 0 NA 12 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 1 2 3/8"P Annular Preventer 1 7 1/16"P #1 Rams 1 Blind/shear P #2 Rams 1 2 3/8" PS P #3 Rams 1 2 3/8" x 3 1/2 P #4 Rams 1 2 3/8 PS P #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2 1/16"P HCR Valves 2 2 1/16"P Kill Line Valves 1 2 1/16"P Check Valve 0 P BOP Misc 2 2" Piper P System Pressure P3050 Pressure After Closure P2250 200 PSI Attained P25 Full Pressure Attained P55 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P4@ 1675 ACC Misc FP1 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 1 P Annular Preventer P12 #1 Rams P12 #2 Rams P3 #3 Rams P3 #4 Rams P4 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9 9 9999 9 9 9 9 9 ACC Misc FP Koomey hose failed 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 Sean Mclaughlin Drilling Manager Hilcorp North Slope, LLC 3800 Centerpoint, Suite 1400 Anchorage, AK, 99503 Re: Prudhoe Bay, Prudhoe Oil, PBU D-08B Hilcorp North Slope, LLC Permit to Drill Number: 225-007 Surface Location: 3370’ FNL, 1067’ FEL, Sec. 23, T11N, R13E, UM, AK Bottomhole Location: 1444’ FNL, 2407’ FEL, Sec. 26, T11N, R13E, UM, AK Dear Mr. McLaughlin 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 all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. 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, Jessie L. Chmielowski Commissioner DATED this day of )HEUXDU\, 2025. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.10 15:23:39 -09'00' By Grace Christianson at 10:13 am, Jan 30, 2025 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.01.29 16:13:44 - 09'00' Sean McLaughlin (4311) 50-029-20372-02-00 *Variance as per 20 AAC 25.112(i): Approved for alternate abandonment plug placement on parent well contingent upon fully cemented liner on upcoming sidetrack. *Variance to 20 AAC 25.036 (c)(2)(A)(iv) approved for work performed before 3/31/25 with documented well control drills performed by all crews deploying tubulars <2.375" OD without properly sized pipe rams. *Send liner lap results to AOGCC. A.Dewhurst 05FEB25 *AOGCC Witnessed BOP Test to 3500 psi, Annular 2500 psi minimum. *Post rig service coil perforating approved for BHA length < 500'. *Window milling approved on service coil 225-007 DSR-1/31/25JJL 2/10/25 *&: 2/10/2025 2/10/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.10 15:23:53 -09'00' RBDMS JSB 021225 12,319' To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz Drilling Engineer Date: January 29, 2025 Re:D-08B Permit to Drill Approval is requested for drilling a CTD sidetrack lateral from well D-08A with the Nabors CDR2/CDR3 Coiled Tubing Drilling. Proposed plan for D-08B Producer: See D-08A Sundry request for complete pre-rig details - Prior to drilling activities, screening will be conducted to drift for whipstock and MIT. E-line or coil will mill the XN-nipple. E-line will set a 4-1/2" packer whipstock. Coil will mill window pre-rig. If unable to set the whipstock or milling the window, for scheduling reasons, the rig will perform that work. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 or CDR3 rig. The rig will move in, test BOPE and kill the well. If unable to set whipstock pre-rig, the rig will set the 4-1/2" packer whipstock. A single string 3.80" window + 10' of formation will be milled. The well will kick off drilling in the Ivishak and land in Ivishak Zone 2. The lateral will continue in Zone 4, 3 and 2 to TD. The proposed sidetrack will be completed with a 3-1/2"x3- 1/4"x2-7/8” 13Cr solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This completion will completely isolate and abandon the parent Prudhoe Pool 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 D-08A Sundry submitted in concert with this request for full details. 1. Slickline : Pull dream catcher & tubing patch, drift for whipstock 2. E-Line : Mill XN nipple @ 9,259' & Set Baker 4-1/2" Packer Whipstock at 9,510' MD 160 degrees ROHS 3. Coil : Mill 3.80" Window 4. Valve Shop : Pre-CTD Tree Work 5. Operations : Remove wellhouse & level pad Rig Work: (Estimated to start in March 1st 2025) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,399 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Mill 3.80” Window (if not done pre-rig). 3. Drill build section: 4.25" OH, ~701' (18 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~2106' (12 deg DLS planned). Swap to KWF for liner. 5. Run 3-1/2” x 3-1/4” x 2-7/8” 13Cr solid liner (swap to VBRs and test prior to running liner) 6. Pump primary cement job: 36 bbls, 14.8 ppg Class G, 1.33 (ft3/sk), TOC at TOL*. 7. Only if not able to do with service coil extended perf post rig – Perforate Liner 8. Freeze protect well to a min 2,200' TVD. 9. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) Post Rig Work: 1. Valve Shop : Valve & tree work 2. Service Coil : Liner Lap test, Post rig RPM (rush process), CBL, Perforate ~20-40' of 2" guns *Send liner lap test results to AOGCC. 3. Slickline : Contingent LTP set (dependent on Liner lap test) & set GLV's Managed Pressure Drilling: Managed pressure drilling techniques will be employed on this well. The intent is to provide constant bottom hole pressure by using minimum 8.4 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 and is 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”/3-1/8” (big hole) & 2-3/8” (slim hole) 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 (9510' MD -8,539' TVD) Pumps On Pumps Oī A Target BHP at Window (ppg)4,351 psi 4,351 psi 9.8 B ŶŶƵůĂƌĨƌŝĐƟŽŶ- ECD ;ƉƐŝͬŌͿ 571 psi 0 psi 0.06 C DƵĚ,LJĚƌŽƐƚĂƟĐ;ƉƉŐͿ 3,819 psi 3,819 psi 8.6 B+C Mud + ECD Combined 4,389 psi 3,819 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain -38 psi 533 psi Target BHP at window and deeper Operation Details: Reservoir Pressure: x The estimated reservoir pressure is expected to be 3,279 psi at 8,800 TVD. (7.2 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,399 psi (from estimated reservoir pressure). Mud Program: x Drilling: Minimum MW of 8.4 ppg KCL with viscosifier for drilling. Managed pressure used to maintain constant BHP. Disposal: x All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4. x Fluids >1% hydrocarbons or flammables must go to GNI. 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 4.25" hole for the entirety of the production hole section. Liner Program: x 3-1/2", 9.3#, 13Cr Solid: 9,300' MD – 9,320' MD (20' liner) x 3-1/4", 6.6#, 13Cr Solid: 9,320' MD – 10,240' MD (920' liner) x 2-7/8", 6.5#, 13Cr Solid: 10,240' MD – 12,319' MD (2,079' 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 2,500 psi. x 1.5 wellbore volumes of KWF will be on location at all times during drilling operations. x Solid 2-7/8” Liner Running Ram Change: Change out 3” pipe/slip rams (for drilling) to 2-3/8” x 3-1/2” VBR rams for liner run. Test VBR rams to 250 psi and 3,500 psi. x A X-over shall be made up to a 2” safety joint including a TIW valve for all tubulars ran in hole. x 2” safety joint will be utilized while running solid or slotted liner. The desire is to keep the same standing orders for the entire liner run and not change shut in techniques from well to well (run safety joint with pre- installed TIW valve). When closing on a 2” safety joint, 2 sets of pipe/slip rams will be available, above and below the flow cross providing better well control option. x Request variance to 20 AC 25.036(c)(2)(A)(iv) to deploy tubulars < 2.375” OD without properly sized pipe rams. x 2” safety joint will be utilized while running 1” / 1-1/4” CS hydril. x Blind/Shear rams will be utilized in place of pipe rams sized for CTD jointed pipe operations as a worst- case shut-in scenario (in place 1” / 1-1/4” CS hydril pipe rams). x The well will be full of KWF prior to running liner or jointed pipe operations. x The BHA will be circulated out of hole prior to laying down BHA for jointed pipe operations. x The well will be flow checked after laying in KWF, before laying down BHA and before making jointed pipe. Directional: x Directional plan attached. Maximum planned hole angle is 112°. Inclination at kick off point is 25°. x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. x Distance to nearest property line – 23,800 ft x Distance to nearest well within pool – 1430 ft (A-44i) 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 40' perforated post rig – See attached extended perforating procedure. x 2" Perf Guns at 6 spf x If post rig extended perforating with service coil is not an option, the well will be perforated with the rig or post rig under this PTD. x The well will be perforated between the CTD whipstock and TD of the newly drilled CTD well, completely in the Prudhoe Pool. x Formations: Top of Prudhoe Pool is at 9422’ MD in the parent. Anti-Collision Failures: x D-08B WP05 fails anti-collision with the D-16 parent bore. D-16 was abandoned and sidetracked above the reservoir at 8416' MD to drill the D-16A wellbore. The current active wellbore is D-16B Hazards: x DS/Pad is not an H2S pad. The last H2S reading on D-08A: 18 ppm on 10/4/2024. x Max H2S recorded on DS/Pad: 34 ppm.. x 1 fault crossings expected. x Low lost circulation risk. Ryan Ciolkosz CC: Well File Drilling Engineer Joseph Lastufka (907-244-4357) Pre-Rig – Service Coil – Window Milling The approved sundry and permit to drill will be posted in the Operations Cabin of the unit during the entire window milling operation. Notes for window milling: x Window milling with service CTU operations will fully comply with 20 AAC 25.286(d)(3), including the use of pressure control equipment, all BHAs fully lubricated and at no point will any BHA be open-hole deployed. Window Milling Procedure: 1. Kill well with 1% KCL if necessary. Well may already be killed from previous operations. 2. MU and RIH with window milling assembly – Window mill followed by string reamer. NOTE: Confirm milling BHA configuration prior to job execution due to variations in different service provider’s window milling BHAs. 3. RIH & TAG whipstock pinch point, calculate distance till string reamer is out of the window, paint coil flag and note in WSR. 4. Mill window per vendor procedure. – Make note of any WHP changes while milling window in the WSR. 5. Make multiple reciprocating passes through the kickoff point to dress liner exit and eliminate all burs. Perform gel sweeps as necessary to keep window clean. Maximum approved distance to reciprocate beyond the window is 15 ft to ensure confidence the window is prepared for the sidetrack.DO NOT RECIPROCATE DEEPER than 15 ft. 6. Confirm exited liner & string reamer dressed entire window with coil flag and note bottom of window and total milled depth in WSR. 7. FP well to 2,500’ TVD with 60/40 MeOH while POOH. 8. Once on surface inspect BHA, measure OD of mill and string reamer & document in WSR. 9. RDMO 10. Communicate to Operations to tag wing valve “Do Not POP”. Pre-Rig – Service Coil – Window Milling – BOP Diagram Post-Rig Service Coil Perforating Procedure: Coiled Tubing Notes: x Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. x Note: The well will be killed and monitored before making up the initial perfs guns. 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 and spot ancillary equipment. 2. MU nozzle drift BHA (include SCMT and/or RPM log as needed). 3. RIH to PBTD. a. Displace well with weighted brine while RIH (minimum 8.4 ppg to be overbalanced). 4. POOH (and RPM log if needed) and lay down BHA. 5. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH with guns. 6. There will be no perforations to bullhead kill the well. Well will already be loaded w/ weighted brine or KCl per previous steps. Re-load well at WSS discretion. 7. At surface, prepare for deployment of TCP guns. 8.Confirm well is dead. Bleed any pressure off to return tank. Kill well w/ KWF, weighted brine as needed (minimum 8.4 ppg). Maintain continuous hole fill taking returns to tank until lubricator connection is reestablished. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 9.Pickup 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. 10. Break lubricator connection at QTS and begin makeup of TCP guns and blanks per schedule below.Max BHA length per PTD is 500ft. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. a. Perforation details i.Perf Interval:The well will be perforated between the CTD whipstock and TD of the newly drilled CTD well, completely in the Ivishak pool. ii.Perf Length:500’ iii.Gun Length:500’ iv.Weight of Guns (lbs):2300lbs (4.6ppf) 11. MU lubricator and RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate perforation intervals (TBD). POOH. a. Note any tubing pressure change in WSR. 12. 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. 13. Pump pipe displacement while POOH.Stop at surface to reconfirm well dead and hole full. 14. Review well control steps with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. Standing orders flow chart included with this sundry request. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 15. Freeze protect well to 2,000’ TVD. 16. RDMO CTU. Coiled Tubing BOPs Standing Orders for Open Hole Well Control during Perf Gun Deployment Equipment Layout Diagram -3500-3000-2500-2000-1500-1000South(-)/North(+) (1000 usft/in)-3000 -2500 -2000 -1500 -1000 -500 0 500 West(-)/East(+) (1000 usft/in)64 00 680 0 7 2 00760080008400D-31A600064006800720076008000840088009082D-319 0 6 2 D -0 1 B w p1 1 6 4 0 0 6800720076008000840088009171D-08A8000840088009088D-16A88008893D-16BPB168007200760080008400880092009325D-1688008860D-16B4800 520056006000640068007200760080008 4 0 0 8 8 0 0 9 2 0 0 9 3 78 D-0 852005600D-09880092009300A-0688008811A-06A88009067D-08B wp05Top of Window - 9510'MDEnd 18 DLS - 10213'MDCrest - 11500'MD 8570'tvdssTD - 12319'MD860087008800890090009100True Vertical Depth (200 usft/in)600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 Vertical Section at 175.00° (400 usft/in)D-08AD-08B wp05Top of Window - 9510'MDEnd 18 DLS - 10213'MDCrest - 11500'MD 8570'tvdssTD - 12319'MDSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect1 9510.00 25.70 40.50 8593.14 -1127.76 -1564.28 0.00 0.00 987.132 9530.00 24.02 42.01 8611.29 -1121.44 -1558.74 9.00 160.00 981.323 9600.00 12.88 61.57 8677.64 -1107.08 -1542.28 18.00 160.00 968.454 9774.00 32.34 136.68 8840.02 -1132.34 -1492.04 18.00 96.00 997.995 10059.47 67.37 188.88 9028.19 -1331.44 -1457.70 17.91 69.54 1199.326 10212.50 90.00 173.00 9058.20 -1480.00 -1459.31 17.91 -36.49 1347.187 10398.81 112.00 177.09 9022.85 -1661.03 -1443.36 12.00 10.00 1528.918 10528.95 112.00 193.93 8974.10 -1780.70 -1454.90 12.00 90.00 1647.129 10768.95 112.00 162.87 8884.20 -2000.43 -1448.75 12.00 -90.00 1866.5510 10988.95 112.00 191.34 8801.78 -2202.06 -1438.55 12.00 90.00 2068.3011 11208.95 112.00 162.87 8719.37 -2403.69 -1428.34 12.00 -90.00 2270.0512 11313.95 112.00 176.46 8680.04 -2499.24 -1410.92 12.00 90.00 2366.7613 11499.83 90.00 172.68 8644.77 -2679.72 -1393.52 12.00 -170.00 2548.0714 11669.83 69.92 176.37 8674.26 -2845.45 -1377.47 12.00 170.00 2714.5715 11838.96 50.00 171.86 8758.53 -2990.36 -1363.12 12.00 -170.00 2860.1816 11949.00 50.00 189.10 8829.26 -3074.34 -1363.83 12.00 90.00 2943.7717 12134.00 50.00 160.12 8948.18 -3213.93 -1350.65 12.00 -90.00 3083.9818 12319.00 50.00 189.10 9067.09 -3353.52 -1337.48 12.00 90.00 3224.19Project: Prudhoe BaySite: DWell: D-08Wellbore: D-08BPlan: D-08B wp05WELLBORE DETAILSParent Wellbore:D-08ATop of Window: 9510.00D-08B wp05Depth From Depth To Survey/Plan Tool103.00 6803.04 1 : Sperry-Sun BOSS gyro multi (D-08) 3_Gyro-SR-GMS16903.00 9510.00 D-08A (D-08A) 3_MWD9510.00 12319.00 D-08B wp05 (D-08B) 3_MWDWELL DETAILSNorthing: 5957631.00Easting: 654123.00Lattitude: 70° 17' 28.1670 NLongitude: 148° 45' 8.0651 WD-08B wp05SECTION DETAILSHilcorp Alaska, LLCSURVEY PROGRAMNAD 1927 (NADCON CONUS)US State Plane 1927 (Exact solution)Alaska Zone 04PROJECT DETAILSREFERENCE INFORMATIONCoordinate(N/E) Reference: Well D-08, True NorthVertical (TVD) Reference: KB @ 74.54usft (D-08A:)Measured Depth Reference: KB @ 74.54usft (D-08A:)Section (VS) Reference: Slot - (0.00N, 0.00E)Calculation Method: Minimum CurvatureREFERENCE INFORMATION !""# $ % # & " # ' () ' * * + ,# -$ ! 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"#$%&'% () *+ . , ' + - . /- - ' "#$%&'% () *+ / $ ' 0 / - $ 7 '9 ; 789 < &$ 789 546* 7 '9 - / $ . 7 '9 - 4 . 7 '9 5/6 7 '9 , ) $ 7 '9 () ' " >>?> ) 43&$ & 43&$ & & & ='% 24;& ' 3'$ =;2& %%& % & & 2 ;& & ' 2 ;& & 2 & ;4''& ='% 244&3$' 3'$ =; &334 &%= & $ & 2 4 ;& &2 4 ;& & % &2=4' &4 ='% 244& %' 3'$ =; &3=24 &%= & ' & 4 ; ;& &4 ; ;& &22 &%24' & 3 ='% 244&'3' 3'$ =; & 44 &%= &2 & % ;& &2 % ;& &4' &'323;&2 ='% 244&%2' 3'$ =; &$;;4 &%= &2$ &4 ' ;& &4$ ' ;& &%% & ;4%%&$3 ='% 244&2 ' 3'$ =; &'%%4 &%= &44 &;$ = ;& &%; = ;& & ' 2&4'42%&=3 ='% 242&$=' 3'$ =; &2;'4 &%= &4% &$% $ ;& &% $ 4&33 2&%4 2&=344 &2 ='% 242&;%' 3'$ =43&'%=4 &%' & ' 2&4$ ;& &%4 4&33 2&3$ 4&2=44 & 3 ='% 24 & ' 3'$ =4 &33$4 &%' & 4 2&$$ 3 ;& &44 3 4&33 4&%% 4&;32$$&$ ='% 24 &==' 3'$ =4 &'2 4 &%' &; 4&44 2 ;& & $ 2 4&33 4&== 4&;;244&2 ='% 24 &$;' 3'$ =4 &4334 &%' &23 4&%' 2 2 ;& & $ 2 2 4&33 4&$; 4&4;24;& ='% 24 & ;' 3'$ =4 &4;2 4 &%' & 4&'4 2 4 ;& &4 2 4 4&33 4& 4&%44= &;3 ='% 24 &=%' 3'$ =4 &2'2 24 &%' &;; 4&' 2 ; ;& &; 2 ; 4&33 4&3 4&3=4%=&43 ='% 24 &2 ' 3'$ =4$&3=2 44 &%' &2; 4&$2 2 % ;& &;$ 2 % 4&33 ;&;2 ;&'44;4& ='% 223&''' 3'$ =4$&=42 ;4 &%' & 3 4&33 2 ' ;& &%4 2 ' 4&3 ;&$; %& =4;4&23 ='% 223& 4' 3'$ =4$&232 %4 &%% & ' ;&;= 2 = ;& &4$ 2 = 4&3 %&2 %&'%4;4&43 ='% 22 &''' 3'$ =4=& 22 '4 &%% &2' ;&=3 2 $ ;& &44 2 $ 4&3 %&;2 %&324'2&43 ='% 22 &2 ' 3'$ =4=&'32 =4 &%% & 3 ;& = 2 ;& &;4 2 4&3 %&;; '&;$4$$&=2 ='% 22$&$;' 3'$ =4=&'=2 $4 &%% &2= ;& ' 2 3 ;& &%4 2 3 4&3 %&4$ =& 24$;&% ='% 22$& ' 3'$ =4=&=22 4 &%% &2 ;&$; 4 ;& &;' 4 4&3 %&22 =&='43=&3 ='% 22=&%%' 3'$ =4=&$'2 34 &%% &2$ ;&'4 4 2 ;& &;; 4 2 4&3$ ;&=3 =&322&= ='% 22=&2$' 3'$ =4$&2$4 4 &%; &;= ;& $ 4 4 ;& &% 4 4 4&3$ ;&2% =&'$'2&3 ='% 22=&%3' 3'$ =4$&$;4 24 &%; &;$ 4&'' 4 ; ;& &$' 4 ; 4&3$ 4&$ '&=2$;& ='% 22$&%%' 3'$ =4 &234 44 &%; &;' 4&4 4 % ;& &$' 4 % 4&3= 4&%' %&;% %&23 ='% 22 &$4' 3'$ =4 &%=4 ;4 &%4 &2% 4& = 4 ' ;& &=; 4 ' 4&3' 4&2$ ;&2 =$&23 ='% 223& $' 3'$ =4 &$$4 %4 &%2 &4% 2& 4 = ;& &2' 4 = 4&3' 2&3' 4&'% 3&23 ='% 24 &' ' 3'$ =4 &334 '4 &%2 &%3 2&$; 4 $ ;& &4' 4 $ 4&3' 2&3= 4&2334&22 ='% 24 & '' 3'$ =4 &334 =4 &%2 &2 2&$= 4 ;& 4&24 4 4&3; ;&'2 ;& 42;&= ='% 24 & ' 3'$ =4$&%;4 $4 &;3 4&4= ;&4% 4 3 ;& '& $ 4 3 4&$4 3& ; '&3%4 '&=3 ='% 22$&4'' 3'$ =42& '4 4 &2 4&3 &% ; ;& $&2$ ; 4&2% 2 &%% 2 &3;4 3&= ='% 224&%'' 3'$ =24&;%4 34$&= 4&2% 2$&%4 ; 2 ;& &=4 ; 2 2&4 43&$$ 2 &=%42 &2 ='% 2 %&3$' 3'$ = & =; 4=&==2& = 4 & ; ; 4 ;& 2 &; ; 233& 4 %4&4' 43&%244;& ='% 3%&%=' 3'$ ' &2'; 24'&4 2&3% ;3&'; ; ; ;& 2;&; ; 43$&=$ '$&4; %;&'%44;&= ='% &='' 3'$ '$4&3 ; 44;&2;;& ';&42 ; % ;& 2%&%$ ; ;3%&$; $'& = '3&= 44 &$3 ='% =%& ' 3'$ ''%&$;; ;4 &23 2&4 =3&' ; ' ;& 2=&$4 ; %32& % 3'&;4 $$&;'442&;3 ='% %$&=4' 3'$ ';%&24; %2=&' 4&4= &42 ; = ;& 23&'; ; ' =& $ 22 &; 3 &44444&$3 ='% 4$&4;' 3'$ '2 &=%; '22&';4& % 2 3&;$ ; $ ;& 44&3; ; =$3&4$ 2%%& = 244&3444;&23 ='% ;& 3' 3'$ % ;&==; = %&$;;&% 2;;&'3 ; ;& 4'&$' ; $$ &;$ 2$%&=3 2'2&;'44%& ='; 3$'&4 ' 3'$ %';&4'; =3'& ;4& % 2= & % ; 3 ;& 43&2$ ; '3& 3 4 &2' 2 ;& $44;& ='; 3%%&4'' 3'$ %23&2'; $ %&'';&%' 232&% % ;& ;4&%' ; 3%%&3$ 4%'&=2 42$&3344;& ='; 32 &2 ' 3'$ ; 2& ; $ &%;;&4 44'&=$ % 2 ;& ;%&' % 4 &;% 4 =& = 4''&'$444&$3 ='; $;&;=' 3'$ ;;3&$3; 3';& 4&2; 4=4&=3 % 4 ;& ;%&3' % 22 &%3 ;4 & 43%&4 444&' ='; ;'&=2' 3'$ 43$& =% ;'&3' &%2 ; 2&22 % ; ;& ;%&3 % 234&% ;$ & % ;;;& =44;& ='; $3$&=4' 3'$ 4'%&4%% 22$&3% &43 ;;3&= % % ;& ;%&$$ % 4$%&'= %22&34 ;$2&32444&=3 ='; $'3&=%' 3'$ 422&'$% 4 & 4 &44 ;$$&3% % # & " # ' () ' * * + ,# -$ ! "#$%&'% () *+ . , ' + - . /- - ' "#$%&'% () *+ / $ ' 0 / - $ 7 '9 ; 789 < &$ 789 546* 7 '9 - / $ . 7 '9 - 4 . 7 '9 5/6 7 '9 , ) $ 7 '9 () ' " >?> ) % ' ;& ;%&=4 % ;'=&$ %';&$= %2 &' 444&=3 ='; $42&34' 3'$ 2= &3'% 4 4&4% &2' %2=&4' % = ;& ;'&'4 % %; &=4 %3'& %%3&'$44;& ='; = ;&$4' 3'$ 24=& %% ;=%& &34 %'%& 4 % $ ;& ;'&$; % '23&32 '; &;' % 3&%%44;&;3 ='; =%%&$;' 3'$ 4&$$% %%'&;$ &;2 %3;&=% % ;& ;=&2 % = & = ' &3 '43& 444;&' ='; = '&4%' 3'$ ;3&;;% '4=&;4 &%' ';4&'3 % 3 ;& ;$&;$ % = &3' =4;& 3 '$2&'=44%& 3 ='; '=%&% ' 3'= 33'&'$% = =&%2 2&%' '$2&$ ' ;& ;$&%' % $= &;3 ===& ' =2%&'244'&2 ='; '44&;;' 3'= 3'2&$%% = '& ' &2' =2 &$= ' 2 ;& ; & % ;3&%% $ 3&3$ =' & 44'&;3 ='; %$3&$%' 3'= 3 $&$%% $=%&3 &=' =%3&34 ' 4 ;& ; &$ % 32$& 4 $';&4$ $ 4&'244=&23 ='; %;=&2;' 3'= =;&'%% %;&4 &$3 = 3&2$ ' ; ;& ;3&=$ % 33'&;; $3=&= $% &%444$& ='; ;32&24' 3'= 23&4 % 34 &$3 2&2 $4 &%4 ' % ;& % &;$ ' $2&32 % &;; $3'&=%44$&' ='; ;%%& 2' 3'= $$%&= % 33$&;$ &$$ $=$&$3 ' ' ;& %2&; ' 2%$&'4 %&2= %%&4;44 &;3 ='; 43$&2;' 3'= $43&$ ' $4&3 2&2$ $&42 ' = ;& %2&34 ' 444&4' 34 &43 3;&3444 &;3 ='; 4% &;=' 3'= = %&='' 2%$&$2 &'% %=& ' ' $ ;& %2&$ ' 43=&$ 3$4&%; 3%;& 44 &=3 ='; 233&;4' 3'= =;3&' ' 444&4% &; =&%$ ' ;& %2&$ ' ;$2&% 2 2=&%= 33;& 444 &' ='; 2' &; ' 3'= '3%&%'' 43=& = &2' 34'&3 ' 3 ;& %2&' ' %%=& 3 2 = &2 2 %;&34443&43 ='; 2 2&22' 3'= '%3&$4' ;$2&'' &'= 3='&2= = ;& %2&4 ' '42& = 2 2 ;&43 2 3%&24443&;3 ='; '2& 2' 3'= ' '&'3' %%=&'4 &;2 2 ;&$% = 2 ;& % &3' ' '3=&% 2 2%'&== 2 2%%&%24; &;3 ='; 4&% ' 3'= %=4&42' '42& = &$% 2 %2&'= = 4 ;& % &3$ ' =$2&34 2 2 $& 2 23%&=4443&= ='4 3';& $' 3'= %23& '' '3$&; &'4 2 $3&2= = ; ;& %2&2; ' $%$&;; 2 4; &;4 2 4%%&==443&=3 ='4 3 ;&32' 3'= ;$'&'2' =$4&$3 &2$ 2 22$&2= = % ;& % &3' ' 44&$= 2 4$4&== 2 43%& '4; & ='4 '%&=2' 3'= ;;4&2'' $% &44 &4$ 2 2'%&3$ = ' ;& % &3 ' 3 &;4 2 ;2%&$$ 2 ;%'& ;4; & ='4 '&; ' 3'= 4 3& ;' 4;&$ & ' 2 234&'% = = ;& % &$ ' 3$%& 4 2 ;'=& 4 2 ;3'& %443& 3 ='4 $'=&2$' 3'= 4%'&3$' 33&% &42 2 4; & $ = $ ;& % &4 = ' &22 2 ;3 &'; 2 %%%&$%4; &2 ='4 $ $&;%' 3'= 4 ;&4'' 3$'&'$ &'4 2 4=$&43 = ;& ;3& ' = 24=&=3 2 %;3&32 2 %3;&3=443&$3 ='4 =' &3 ' 3'= 2= & $= '4&2' &% 2 ; %&4; = 3 ;& ;3&$= = 4 ;&'2 2 % 2&22 2 '%4&3$4; &2 ='4 =2 & ;' 3'= 22 &= = 24 &3$ &44 2 ;%2& = 3%2&'3 ;3&'' = 4;;&4; 2 %3=&; 2 '=4&;%4;;&$4 ='4 '32&$ ' 3'= 2 ;&2 = 2' &=3 =& 2 2 ;'%&%% = 3$=& 2 ;$&$% = 4= &22 2 ' &' 2 ' & ;4;$&2'='4 '$%&;%' 3'= 3 &'%= 2 '&'$ &2' 2 ;='& ' $ $&; ;=&'; = 4 '&24 2 '2 &;2 2 '3=&444% &%=='4 '' &;=' 3'= &% = 42 &' $&%' 2 ;$;&%2 $ ;=&$% ;'&'3 = ; & = 2 '4=&%2 2 =22&% 4%;&$ ='4 '%;&4$' 3'= $2&33= 4;%&;4 $&4% 2 ; &2' $ $ &4 ;%& % = ;;=&;; 2 ';%&43 2 =4 & $4%$&' ='4 '4=& %' 3'= =;&$'= 4=2&$3 & 2 ; =&%3 $ 3 &%; ;;&2; = ;'3& ' 2 ';3&$3 2 =%;&% 4'2&44 ='4 '22&''' 3'= '$&3'= 4 '&;2 $& ; 2 ;3 &=3 $ 2; & 4 ;4&; = ; =&%; 2 '%%&=$ 2 ='3& ;4''&'$='4 %3'&;2' 3'= '4&$%= ;22& 3 $& 3 2 ;3%&2; $ 2=4&%= ;2&; = %2%& 2 '% &34 2 =$=&;34''&$ ='4 %$ & %' 3'= % &2== ;;3&%=;& 3 2 ;3=&32 $ 23%&'% ;2&22 = %%2&%% 2 '';&2= 2 =34&%=4'%&$2 ='4 %=4& =' 3'= %;&'3= ;==&3 2&$2 2 ;33&$% $ 444& ; ;2&2 = %='&=$ 2 ''=&3 2 $ =&' 4''&'3 ='4 %% & 4' 3'= ;3&''= ;32&2;2&=2 2 % 4&4% $ ;2$&%4 43&%2 = '%$&; 2 '$ &;2 2 $'4&434'2&=2 ='4 % ;&% ' 3'= 4'&42= %$4& %4&$$ 2 %22&=4 $ % 3&3= 4;&2$ = =; &;4 2 ' 2&%3 2 $32&==4'$&;;='4 ;=%&4$' 3'= 2;&4;= '''&$ $&4$ 2 %23&;4 $ ' ;&= 2 &=$ = $2$& % 2 ' $&34 2 4%&%$4= & %='4 ;;2&'3' 3'= =&2;= =%;&; %&3 2 %44& $ $ '3=&== 2=& ; = =&' 2 '34&%; 2 '2& ;4= &%2 ='4 ; %&;%' 3'= 2& == $;4& %4& % 2 %4%&3$ $ =32& = 22&$ = 3 &3$ 2 '3=& = 2 $%&%24=2&% ='4 4 2& %' 3'' 33=&3== 4%&%;%&%$ 2 %4=&=4 $ $ ;&$$ 3&34 = 3 3&4$ 2 '3'&'; 2 32&; 4 %& $='4 4=%& =' 3'' 33$&2'= 32%&$;'& 2 2 %4%&=2 $ $ &; $&; $ 4&$% 2 '3 &;% 2 3 %&%;; 2&34 ='4 4'2&$2' 3'= 4& $$ &4 ;& 2 %2 &; $ 3$2& ' &' $ 2$'&%4 2 ' &3 2 324&=4;;;&$$='4 4%;&;;' 3'= 22&;%$ 2 & %& ; 2 % &2 =%& 22&%2 $ 4==&42 2 '='&=2 2 32'&3$;' & =='4 4;3&=$' 3'= 4=&'=$ 232&=$'&%' 2 ;34&== 2' &=$ 2'& ' $ ;' &;3 2 '%%&%2 2 324&3;2'& $='4 4%4&4 ' 3'= %$& 2$ 4 ;& ''&$; 2 ;$2& 2 % # & " # ' () ' * * + ,# -$ ! "#$%&'% () *+ . , ' + - . /- - ' "#$%&'% () *+ / $ ' 0 / - $ 7 '9 ; 789 < &$ 789 546* 7 '9 - / $ . 7 '9 - 4 . 7 '9 5/6 7 '9 , ) $ 7 '9 () ' " @A@A?@@ ) 4'4&2; 2=&=3 $ %% &;2 2 '42& = 2 3 4&3 43&'3 ='4 4'2&$%' 3'= $2&;=$ ;$;&$$%&;$ 2 ;%3&%4 ;%%&$2 4 &=2 $ ';=& % 2 %3$&2; 2 '&$$% &$4 ='4 4= &%'' 3'= 3'&=;$ %=2&' '&$ 2 ;4$& %;$& $ 4%&3; $ =42&34 2 %$ &% 2 =2&'4%;&=4 ='4 434&2=' 3'= 244&$ $ '%$&; %&$3 2 ; 4&=% '; &=2 4;&= $ $ =&%$ 2 %%4&$= 2 ;'&;=%;& %='4 ;2$&$;' 3'= 2'2& 4$ =;2&3;2&%= 2 4$$&;2 =44&=; 4;&$3 $ $3 &$; 2 %2'&'$ 2 2 &; %4&43 ='4 ;%4&4;' 3'= 2$ &$4$ $2=&23 &;3 2 4'4&% $2'& 4%&; $ $'&2= 2 ; $&% 2 $ '&43% &3;='4 ;==&==' 3'= 4 $&;3$ &=4 & 2 2 44=&'4 3&2 4'&;$ $ 3= &'= 2 ;'$&=; 2 $'3&; %2&;2 ='4 ;34& ;' 3'= 4;$&=3$ =& 4 2&2' 2 233&2; 3 4& 2 4%&34 %'&;2 2 ;4$& % 2 $;4&3;%2&$4 ='4 %2$&$ ' 3'= 4= & 2$ 3$ &$$ &'4 2 2$2&$' 33=&;2 4'&;2 243&3$ 2 43 &2= 2 $ =&' %2&% ='4 %%;&'2' 3'= 43 &44 ''&%; &%; 2 2%%&%3 3 3& = 4'&'; 42%&%$ 2 4=$&$= 2 = &;'% & 3 ='4 %=3&22' 3'= ;43&2' 2;3&3; &= 2 22=&% 3 2 ;&=$ 4$&4 43 &'4 2 4;'& 4 2 =';&= ;3& 4 ='4 %3'&4 ' 3'= ;=2&=; 44;&3 2&$ 2 $& 3 4$=&$% 4'& ; 4& 3 2 4 %& $ 2 =4$&$=; &% ='4 '4 &; ' 3'= ;3;&3 ; $&''4&%= 2 '$&=4 3 ;%$&'% 4;&'3 %%=&=4 2 2 2&%$ 2 = 3&;3;3& =='4 '; &43' 3'= %2=& $ ;$4& 4&2= 2 ;=&$2 3 %4$&2$ 4=&4; '2 & % 2 2''&$; 2 ' $&3 ;3& =='4 ''3&4'' 3'= %%;& ' %%%&; ;&;4 2 24&3; 3 %'=&%' 4=&'= '%'& = 2 2%'&$' 2 '$3&';% & ='4 '=$&% ' 3'= %';&23 %$ &'4 2&2 2 ;&$; 3 '2 & 4'&$ '3;&2% 2 24$&$= 2 '=%&4 % &' ='4 ' 4&4 ' 3'= %$2&%3 '2 &= 2&=; 3 $&2; ( '* =B- 3 '; & 4%& 4 =22&43 2 242&%% 2 '' &$%%4& 2 ='4 ' $&=3' 3'= %$$&3; ';=&$'3& 3 2&;4 3 '' & 4 &=$ =43&$ 2 22'&3% 2 '';&' %'&' ='4 '34& 4' 3'= % ;&'; '''&4%2 & 3$=&43 3 '$'& 2=&=; =';&%$ 2 22 &=4 2 '%$&'%'2&$2 ='4 '3 &=$' 3'= % &3$ '$ &3;2 & 3$2&'4 3 = & 24& =$$&=% 2 2 $& 2 '%4&4 =2&'$='4 = ;& '' 3'= %34&=4 = ;&2 2 & 3= &%' 3 =4'& 2;&2 $ 4& 2 2 2 '&;; 2 ';$& 2 2&' ='4 = 3& 3' 3'= %3%&%$ =4$&%$2 & 3=$&2$ 3 =' & 2%& $4=&4 2 2 '&%2 2 ';2& 43 & $='4 =2'& ' 3'= %3%&'4 ='2&$%2 & 3=$&$$ 3 =$'& 2$&'$ $' &43 2 2 $&;2 2 '4%&;%222& %='4 =42&$3' 3'= %34&$' =$'&$'2 & 3$ &4% 3 $ & 4 & $$;& 3 2 222& 4 2 '2$& 4242&2%='4 =43&23' 3'= % 3&4 =33&;'2 & 3$%&' 3 $4'& 4%&'= $3=&3' 2 22=&'4 2 ' 3&2 24$& ='4 =;$&42' 3'= % ;& = $44&%2 2 & 3 &$% 3 $' & 4 &%= 23&;4 2 24;&$$ 2 ' &=%2;4&34 ='4 =%'& 4' 3'= %$=&$3 $%%&$ 2 & 3 &$ 3 $$%& ;4&;% % & 4 2 2;4&;% 2 %34& %2;=&= ='4 ='%&'3' 3'= %= &% $='&% 2 & 33$&33 3 $$'& ;4&% % & $ 2 2;4&$; 2 %32&= 2;=&33 ='4 ='%&3$' 3'= %= & 4 $==&;;2$&32 33 &%2 3 & ;%&44 =2&$$ 2 2%;&;' 2 % ;& 42%%&%'='4 ==;& %' 3'= %'$&'$ $ $&4;2$&32 2 3&$% 3 4'& ;=&%% 4&2$ 2 2''&' 2 %$'&;'2'2&2 ='4 =$2&$=' 3'= %%'&'2 $&=;2$&32 2 44&= 3 ' & ;3& 3 2&3' 2 2=3&;% 2 %= &$22'$&23 ='4 =$ &=$' 3'= %;2& 4$&%2 2$&32 2 ;=& 3 $'& %2& ; 34 &33 2 2 %&'' 2 %=;&2=2=4&'%='4 = %&'%' 3'= %2=&$3 %=&%'2$&32 2 '4&'4 3 3 & %%& 3 3;3&2$ 2 4 2&24 2 %' &$42=$&; ='4 = 3&;4' 3'= % &;4 =%&=;2$&32 2 =3&%2 3 34'& % &24 3'=&; 2 42 &3% 2 %''&%22$2&'$='4 =34&33' 3'= ; 4&'$ 2& %2$&32 2 $&%' 3 3' & '2&' 3$4&'2 2 4;$&32 2 %';&4$2$'&%4 ='4 =3'&'4' 3'= ;=;&=' 3$&3$2$&32 2 2 =&'% 3 3$'& '%&33 3 $&%$ 2 4'$&32 2 %'4&432$ &34 ='4 =3=&3 ' 3'= ;%;&= 324&3;2$&32 2 24=&'% 2 & ' &' 3 2&2$ 2 4$ & 2 2 %'4&' 2 4&2;='4 =3$&2;' 3'= ;44&$$ 34=&=;2$&32 2 2%$&;' 2 4'& =4&4; 3 2;&'2 2 ; &' 2 %';& 2 '&2 ='4 =3=&23' 3'= ; 2& = 3; &3$2$&32 2 2= & % 2 ' & ='&3' 3 4%&%% 2 ;44& % 2 %'=&%;2 $& ='4 =3%&2 ' 3'= 4$ &= 3%3&3 2$&32 2 23 & $ 2 '3&%$ =$&;$ 3 4 &23 2 ;;2&%% 2 %'$&$ 2 & ='4 =3;& 2' 3'= 4$ & = 3';&='2$&32 2 233&;4 2 $'& =3&=4 3 ;;& 2 ;%'&$' 2 %'3&$22 $&24 ='4 =32&43' 3'= 4''&$2 3'3&;%2$&32 2 42;&% 2 2 & $;&4$ 3 %2& % 2 ;=3&;4 2 %=4& $2 %&;3 ='4 = 3&%2' 3'= 4;4&2 3=$&; 2$&32 2 4;=&= 2 24'& $=&3' 3 % &4= 2 ;3;&%% 2 %=;&;=2 2&$'='4 = &=4' 3'= 4 $&3= 3$;&$4 2$&32 2 4= &= 2 2' & &== 3 ';&22 2 %2$&3= 2 %=;&'=2$3&4 ='4 = &34' 3'= 2 ;&%% 3$ &'$2$&32 2 4 '& % # & " # ' () ' * * + ,# -$ ! "#$%&'% () *+ . , ' + - . /- - ' "#$%&'% () *+ / $ ' 0 / - $ 7 '9 ; 789 < &$ 789 546* 7 '9 - / $ . 7 '9 - 4 . 7 '9 5/6 7 '9 , ) $ 7 '9 () ' " =?A ) 2 2$'& %&;3 3 '=&;$ 2 %%4&$4 2 %=4&=$2$=&$ ='4 =3 &;4' 3'= 2' &$ 3 2& ;2$&32 2 ; 3&$' 2 4 & &2; 3 ' & 2 %=$&' 2 %= &$ 2$%&4;='4 =34& ' 3'= 2;;& 3 3 ;&%=2$&32 2 ;;%&=3 2 424&' 3 & 3 ' &4 2 % & 2 %'3&;22$;& ='4 =3%&%%' 3'= 242&' 3 ;&==2$&3 2 ;%$&23 4="==AB- 2 44'& 32&% 3 ' & % 2 %34&%2 2 %'$& 22$;&4=='4 =3=&23' 3'= 2 3&24 3 ;&' 24& 2 ;'3&= 2 4' & 3%&%; 3 '=&$' 2 '2$&44 2 %''& 2$;&$ ='4 =33&'4' 3'= %&; 3 4&42 24& 2 ; %&=; 2 4$'& 3$&;3 3 '%&2 2 '%2&3' 2 %'4&%42$%&;2 ='4 $ 4&= ' 3'= '3&$2 3$3&=%24& 2 % 3&%3 2 ; & 2 &;% 3 ' &;; 2 '==&'% 2 %' & 2$%& %='4 $ '&%%' 3'= ;'&2 3$'&$3 24& 2 %;%&23 2 ;4'& 2 ;&43 3 %'&42 2 '3 &32 2 %% & 2$'&;3 ='4 $ & 4' 3'= 2 & ' 3$ &=$24& 2 %' &== 2 ;' & 2 =&4% 3 ; & % 2 =2'& 4 2 %%=&2$2$'&3%='4 $2 &;%' 3'' 3 =&$3 3=%&; 24& 2 % 4& ; 2 ;$'& 2 3&23 3 ;2&4; 2 =; &$ 2 %%%&=22$=&'4 ='4 $24&% ' 3'' 3=;& $ 3'=&=3 24& 2 ' =&=% 2 ;3 & 2 224& 3 44& ' 2 ==2& ; 2 %%;&;=2$$& 3 ='4 $2%&2 ' 3'' 3% & = 3% &;2 24& 2 '4 &32 2 % & 224& 3 44&%2 2 ==4&2; 2 %%;&;22$$&4%='4 $2%&2$' 3'' 3;3&$' 3%$& $24& 2 '; & 2 2 %4'& 224& 3 2;& % 2 = '&; 2 %%4& '2 &%$='4 $2'&22' 3'' 32=&= 3; &' 24& 2 '';&2% 2 %' & 224& 3 ;&= 2 $ &%= 2 %%;&=32 ;&$2 ='4 $2%&$%' 3'' 3;&%; 343&2%24& 2 '$=&2% 2 %$'& 224& 33%&;2 2 $;2&'% 2 %%'& %2 =&3%='4 $2;& =' 3'' $ &;2 323&$$24& 2 '3 &3% 2 ' & 224& 3 %&3' 2 $'%&%= 2 %%3&4323 &2 ='4 $2 & ' 3'' %$&;; 32 &%2 24& 2 =42&%$ 2 '4'& 224& 3$'&' 2 $$$&2% 2 %'%& ;23;&%2 ='4 $ '& 2' 3'' 4%&'' 3 2& %24& 2 =%;&=' 2 '4 &3' 224& 3$%&2 2 $ &$ 2 %'%&3 23;&3;='4 $ '& 4' 3'' 4 &3 33&'=24& 2 =%$&24 2 '' & 224& 3==&44 2 $33&$' 2 %'3&2%232&4 ='4 $ 2&2$' 3'' 2& ' 32&= 24& 2 =='&$; 2 '$'& 224& 3'=& ' 2 44&= 2 %=;& 2 $&3$='4 =3$&$ ' 3'' $$ &34 4&;2 24& 2 = &2= 2 = & 224& 3%$&%3 2 %'&=% 2 %='&'=2 %&$;='4 =3'&=3' 3'' $''& % $4&3'24& 2 $2 & 2 =4'& 224& 3; &24 2 = &$ 2 %==& 42 2&' ='4 =3%&3 ' 3'' $;4&= =;&' 24& 2 $;;& ; 2 =' & 224& 34 &$= 2 32&3= 2 %==&$$2$ &4=='4 =3'&%;' 3'' $ 3&'2 '%&44 24& 2 $'=&34 2 =$'& 224& 323&;3 2 32'& 3 2 %='&%42$'& ;='4 =3$&4=' 3'' = =&%2 %%& '24& 2 $ & 3 2 $ & 224& 32 & 4 2 3; &24 2 %=4&$=2$2&$3 ='4 $ &;3' 3'' ==;&%' ;'&% 24& 2 ;&4' 2 $4'& 224& 3 &== 2 3= &3' 2 %' & 2= &'=='4 $ %& 2' 3'' =% &$ 4=&24 24& 2 4=&;' 2 $' & 224& 32&43 2 3 ;&'; 2 %';&'=2='&;4 ='4 $2 &'2' 3'' =2 &4; 2=&$'24& 2 %3&; 2 $= &3' 224& %&4 4 &%; 2 %% &$'2=4& $='4 $2'&=$' 3'' = 2&%% 3&==24& 2 ==&'' 2 $$'& 224& 2&3; 4 '& 2 %%$&2;2=;&='='4 $2$&;3' 3'' '3=&2 $&;3 24& 2 $4& % 2 & 224& $4&'= 4 4 &42 2 %%2&4%2==& 3 ='4 $4;&$'' 3'' '$;& 4 $3 & 4 24& 2 3%& 2 4'& 224& =;&4 4 ' &3; 2 %;=&=42$ &24 ='4 $4 & ;' 3'' ''2&42 $ &==24& 2 32$&32 2 ' & 224& ';& ; 4 $;& = 2 %;;&432$;&;=='4 $;4&=;' 3'' '4 &;% $$3&43 24& 2 3%2& ' 2 $'& 224& %%&%$ 4 3=&3' 2 %;2&4=2$=&'3 ='4 $;'&2;' 3'' ' '&; $=3&3;24& 2 3=%&4; 2 3 & 224& ;'&2 4 24 &22 2 %; &'%2$3& ;='4 $;=&;;' 3'' % 4&2= $= &'=24& 2 3 $&;$ 2 34'& 224& 4'&$% 4 2%;&4 2 %;2&242 ;& =='4 $;=&44' 3'' %' &33 $'2&4 24& 4 2 &% 2 3' & 224& 2=&;$ 4 2==&; 2 %;;& 22 =&; ='4 $;%& ' 3'' %;'& ' $%2& ;24& 4 ;;&4% 2 3$'& 224& $& 2 4 2 3&;% 2 %;=&4 2 3&';='4 $;4& ' 3'' %24& % $;4&%$24& 4 ''& ; 2 3 &3' 224& 2&$ 4 4 4& = 2 %; &''232&;%='4 $; & ' 3'' % & $4$&4%24& 4 = &; 22 & 224& $3$&=% 4 424&2; 2 %% &%%2 3&32 ='4 $4 &;4' 3'' ; 3&3$ $4;&2 24& 4 $ &2$ 22 4'& 224& $ &4 4 4;'& = 2 %%;&$ 2 =&=$='4 $4'&%'' 3'' ;==&3$ $2;&$%24& 4 2 &$4 22 ' & 224& $$ &32 4 4' &2' 2 %%'& 42 ;&%%='4 $4;& ' 3'' ;%;& ' $ %&;$24& 4 24;&'% 22 $'& 224& $=3&'' 4 4 2&;2 2 %%=&'=2 &4 ='4 $4;&=4' 3'' ;4 &= =3'& 2 24& 4 2%=&'= 22 2 & 224& $= &2 4 ; %&% 2 %%'&3 2$=&3$='4 $4%&=$' 3'' 43$&'; = '&=%24& 4 2=3&=3 22 24'& 224& $' & 4 4 ;4$&' 2 %%%&2 2$;&$;='4 $4$& 4' 3'' 4$%&%$ =$=&4 24& 4 234& = % # & " # ' () ' * * + ,# -$ ! "#$%&'% () *+ . , ' + - . /- - ' "#$%&'% () *+ / $ ' 0 / - $ 7 '9 ; 789 < &$ 789 546* 7 '9 - / $ . 7 '9 - 4 . 7 '9 5/6 7 '9 , ) $ 7 '9 () ' " CCC?= ) 22 2' & 224& $%2&%' 4 ;' &'% 2 %% &342$ &' ='4 $; &=$' 3'' 4'2&'3 ===&32 24& 4 42=& 2 22 2$'& 224& $;4& 3 4 ;$;&4 2 %;=&%'2=$&4=='4 $;'&= ' 3'' 44 &3% ='$&''24& 4 4;3& = 22 4 & 224& $44&$4 4 ;3'&$; 2 %; &$22=%& ;='4 $%2& 2' 3'' 4 =&=4 =% &2 24& 4 4=2&34 22 4 &3' 224& $23&;$ 4 % ;&=3 2 %4 &;%2=4& $='4 $%%&;;' 3'' 23 &$2 =%%& ;24& 4 4$ & ' 22 44'& 224& $2;&;= 4 %2$&33 2 %4%&442=%&3'='4 $% &$'' 3'' 2 %&' =; & 4 24& 4 4 %&== 22 4' & 224& $ ;&33 4 %% &'; 2 %2 & ;2= &2 ='4 $'%&= ' 3'' 2=4& =43&%'24& 4 ; $&' 22 4$'& 224& =3%&=; 4 %=;&;% 2 %2%&$;2$2&%4 ='4 $'3&2$' 3'' 2;3&;= =4 & 3 24& 4 ;; &== 22 ; & 224& = '&4= 4 % =&;% 2 %22&342$%&='='4 $=4&%'' 3'' 22=&%4 =2 &$4 24& 4 ;';& ; 22 ;2;&3' 224& = & % 4 %33&4% 2 %2 &342$=&%=='4 $=;&$4' 3'' 2 ;&'' = '&' 24& 4 ;==&$= 22 ;4'& 22 &=3 =$=& 2 4 ' 3&'2 2 %2 &4=2$=&42 ='4 $=%&'3' 3'' 3;&43 = 2&%$24& 4 ;$$& ' 22 ;' & 2 $&$% ==$&$3 4 ';;& ' 2 % &'32$'&=$='4 $==&$%' 3'' =3&$3 '3;&4'24& 4 % &=' 22 ;$'& 2 %&$ == &$3 4 ''=&3$ 2 % =&==2$'&2%='4 $=3&2'' 3'' %'&32 ' =&4'24& 4 %4%&=' 22 % & 2 2& 4 =''& % 4 ' 2&4 2 % %&%32$%&=;='4 $$2& 4' 3'' 42&$; ' &' 24& 4 %% &3$ 22 %4'& 3 & = =' &'' 4 = '&= 2 % 4& 32$%&2;='4 $$%&$4' 3'% 33$&;4 '$=& 2 24& 4 %$;&'= 22 %' & 3'&3 =%$&;% 4 =; &;; 2 ;33&%'2$;&=%='4 $$$& $' 3'% 3$4&$; '$4& 24& 4 %3 &;' 22 %$'& 34&3% =%'&%2 4 =''& 2 ;3=&' 2$;&2=='4 $ 2&4%' 3'% 3% & % '$ & $24& 4 '4;&4= 22 %33& ; 3 & =%%&$$ 4 =$3&$2 2 ;3;&'42$4&= ='4 $ %& ' 3'% 34;&% '$ &4;24& 4 '% & = # ==B-@B, 22 '4'& $& ; =%'&%; 4 $ %&= 2 ;3 &%;2$;&4 ='4 $ &%2' 3'% 3 &' '$ & 3 24& 4 '$;&42 22 '' & %& $ =%$&;$ 4 $43&%% 2 ; $&'32$;&$;='4 $32&$'' 3'% $;& 3 '$4& ;24& 4 '3 &24 22 '$'& 2&24 =' &'3 4 $'%& 3 2 ; '& 2$%&4=='4 $3%& '' 3'% %3&43 '$=& '24& 4 =44&3 22 = & $ &2$ =''& 4 $$ &'$ 2 ; 4&='2$%&$3 ='4 $3$&$ ' 3'% 4%& $ ' &'%24& 4 =%$&%3 22 =4'& $'&42 == & % 4 4& 2 2 ; &'=2$'&;%='4 &43' 3'% &=3 ' =&; 24& 4 =$2& 4 22 =' & $4&4= ==$& % 4 4=&$; 2 ;$ &$;2$'&32 ='4 4&=2' 3'% $$=& '3;&; 24& 4 =3'& 2 22 ==3& ; =3&34 =$%&4= 4 %'&%' 2 ;$$&%$2$=&;$='4 %&4'' 3'% $' &22 '33&$4 24& 4 $2%&'$ 22 =$'& =3&;2 =$=& = 4 ' &43 2 ;$$&2=2$=&4=='4 %&==' 3'% $';&43 = 2&'4 24& 4 $23&%2 22 $ & ==&;= = '&%3 4 $;&; 2 ;$'&';2$'&=3 ='4 =&$=' 3'% $; &4% =2 &3'24& 4 $%4&'= 22 $4'& =;&%2 =3=&2 4 3'&3% 2 ;$;&$22$'& 3 ='4 3& %' 3'% $ $&$4 =42&'=24& 4 $='&23 22 $' & = &%= $ $& = 4 32$&32 2 ;$2&$22$%&%=='4 22&' ' 3'% = '& =;;&;4 24& 4 $ $&4' 22 $$'& '$&'4 $4 &$% 4 3;3&44 2 ;=3&'42$;&$3 ='4 2%&24' 3'% ==%&'% =%=&4 24& 4 &=$ 22 & '%&'$ $;%&$ 4 3'3& 4 2 ;=$&2'2$;& ='4 2=&32' 3'% =%%& == &2=24& 4 43&% 22 4'& '2&=% $%3&$2 4 3$3&=' 2 ;=%&=22$4&;4 ='4 23& =' 3'% =4%&44 =$'&2$24& 4 %3&;$ 22 ; &3= ' & $' &'; 4 33 &;= 2 ;=;&242$2& =='4 42&'=' 3'% =2;&'% = ;&33 24& 4 = &2 22 ' & ' & $='&=; 4 33 &$' 2 ;=4& '2$;&'3 ='4 44& 2' 3'% = '&2$ =32& 3 24& 4 = &=; 22 $'& ' & $ 2&$ ; 2$& % 2 ;= &'$2$$&'2 ='4 4%&= ' 3'% ' =&24 $ $&2=24& 4 $&$ 22 3 & ' & $3$&$$ ; ;=&33 2 ;= &;32 2&%4 ='4 4'&4'' 3'% '==&3 $4;&4;24& 4 3 =& $ 22 34'& ' & 2;& % ; '=&2 2 ;=2&'42 '&;%='4 4%&'4' 3'% '%$& ' $;3&; 24& 4 34'& 2 22 3%3& ' & 43&4= ; $%&;% 2 ;=;& ;2 3&2 ='4 44&' ' 3'% '43&' $'%&$4 24& 4 3%;&$$ 22 3' & ' & 43&32 ; $'&2 2 ;=;&3'2 &3%='4 44&% ' 3'% '4 & 2 $''&;$24& 4 3%%&'4 22 3$'& ' & %'&3 ; 3%&2 2 ;==&4$2 '& 4 ='4 4 &'%' 3'% ' 3&$$ $$2&%%24& 4 3=;&4' 24 & ' & =4& ' ; 22;&44 2 ;=$&; 2 2&22 ='4 23&32' 3'% %3 &=; $ $&'2 24& 4 3 4&42 24 4'& ' & $ &22 ; 2;4&;$ 2 ;=$& 22$$&23 ='4 4 &'3' 3'% %$2&' ;&'$24& ; 2&; 24 ' & ' & 3%&2 ; 2'2&%' 2 ;='&%42$;&4 ='4 44&'$' 3'% %'4&%' 23&=%24& ; 4 &%' 24 $'& ' & 32 &4' ; 2$ &; 2 ;=4&';2=3&;=='4 4'& %' 3'% %;;&'3 ;'&$2 24& ; ;3&'= 24 2 & ' & 34=&;4 ; 2 3& = 2 ;' &;=2='&%'='4 ; &% ' 3'% %2%&33 '2&$ 24& ; ' &'% % # & " # ' () ' * * + ,# -$ ! "#$%&'% () *+ . , ' + - . /- - ' "#$%&'% () *+ / $ ' 0 / - $ 7 '9 ; 789 < &$ 789 546* 7 '9 - / $ . 7 '9 - 4 . 7 '9 5/6 7 '9 , ) $ 7 '9 () ' " C@? ) 24 24'& ' & 3%4&;3 ; 4 $&%4 2 ;'4&342=2&';='4 ;=&44' 3'% ;3=&$' =$& '24& ; $$&; 24 2;%& ' & 3% &2 ; 42;&3; 2 ;' &='2= &24 ='4 ; &=2' 3'% ;3 &43 $;&=%24& ; ;&3 24 2' & ' & 3' &%= ; 44'&'' 2 ;%=&$%2=4&=;='4 %4&$=' 3'% ;$ &$= ;&34 24& ; 3'&3 24 2$'& ' & 3$%&'; ; 4%%& 2 2 ;%2&='2==&''='4 % &4;' 3'% ;= &%2 33&33 24& ; 22%&$; 24 4 & ' & 33 &= ; 4=4&$$ 2 ;;$& ;2$ &%=='4 '4&%;' 3'% ;%2&$; 32=& =24& ; 2;;&$' 24 44'& ' & 3 =&=$ ; 4 2&$' 2 ;;'&;22$%&; ='4 ''&;'' 3'% ;44& 2 3;4&2;24& ; 2'4& 24 4' & ' & 3 44&$% ; ; & = 2 ;;%& 2$ &43 ='4 '=&3=' 3'% ; ;&$; 3% &4 24& ; 2$4& 4 24 4$'& ' & 3 ; & 2 ; ;4 & 2 ;;%&2$2 4&42 ='4 '$&4$' 3'% 4 %&'3 3=%&4$24& ; 232& 3 24 ; & ' & 3 '%& ; ;;3&2 2 ;;'&'=2 =&24 ='4 '=&4$' 3'% 4='&%$ 3 &;%24& ; 4 3&33 24 ;23& ' & 3 =$& 3 ; ;';&'4 2 ;;$&% 2 3&2 ='4 '%&=%' 3'% 4'2& 2 334&''24& ; 44%&23 (=A=B- % # & " # ' () ' * * + ,# -$ ! 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ell 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 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2-3/8" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 3.0" Pipe / Slip 9.54 ft CL 2-3/8" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3-1/8" Pipe / Slip Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2-3/8" Pipe / Slips B6 B5 B8 B7 Choke Line Kill Line CL 3" Pipe / Slip CL 2-3/8" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line Normally Disconnected 2" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3" Pipe / Slip neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Revised 7/2022 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 Number _____________, API Number 50-______________________. Production from or injection into this wellbore must be reported under the original API Number stated above. Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce or inject is contingent upon issuance of a conservation order approving a spacing exception. The 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-foot sample intervals from below the permafrost or from where samples are first caught and 10-foot 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 this well until after the Operator has designed and implemented a water-well testing program to provide baseline data on water quality and quantity. The Operator must contact the AOGCC to obtain advance approval of such a 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 the Operator 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 all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. 225-007 PRUDHOE BAY PRUDHOE OIL PBU D-08B WELL PERMIT CHECKLIST Company Hilcorp North Slope, LLC Well Name:PRUDHOE BAY UNIT D-08B Initial Class/Type DEV / PEND GeoArea 890 Unit 11650 On/Off Shore On Program DEVField & Pool Well bore seg Annular DisposalPTD#:2250070 PRUDHOE BAY, PRUDHOE OIL - 640150 NA1 Permit fee attached Yes ADL028285 and ADL0282862 Lease number appropriate Yes3 Unique well name and number Yes PRUDHOE BAY, PRUDHOE OIL - 640150 - governed by CO 341J4 Well located in a defined pool Yes5 Well located proper distance from drilling unit boundary NA6 Well located proper distance from other wells Yes7 Sufficient acreage available in drilling unit Yes8 If deviated, is wellbore plat included Yes9 Operator only affected party Yes10 Operator has appropriate bond in force Yes11 Permit can be issued without conservation order Yes12 Permit can be issued without administrative approval Yes13 Can permit be approved before 15-day wait NA14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For NA15 All wells within 1/4 mile area of review identified (For service well only) NA16 Pre-produced injector: duration of pre-production less than 3 months (For service well only) NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D) Yes18 Conductor string provided Yes19 Surface casing protects all known USDWs Yes20 CMT vol adequate to circulate on conductor & surf csg NA21 CMT vol adequate to tie-in long string to surf csg Yes22 CMT will cover all known productive horizons Yes23 Casing designs adequate for C, T, B & permafrost Yes24 Adequate tankage or reserve pit Yes Variance approved in PTD25 If a re-drill, has a 10-403 for abandonment been approved Yes26 Adequate wellbore separation proposed NA27 If diverter required, does it meet regulations Yes28 Drilling fluid program schematic & equip list adequate Yes Variance approved in PTD29 BOPEs, do they meet regulation Yes30 BOPE press rating appropriate; test to (put psig in comments) Yes31 Choke manifold complies w/API RP-53 (May 84) Yes32 Work will occur without operation shutdown No33 Is presence of H2S gas probable NA34 Mechanical condition of wells within AOR verified (For service well only) No D-Pad wells are H2S-bearing. H2S measures are required.35 Permit can be issued w/o hydrogen sulfide measures Yes Expected reservoir pressure gradient is 7.2 ppg EMW. MPD to maintain an ECD of 9.8 ppg EMW.36 Data presented on potential overpressure zones NA37 Seismic analysis of shallow gas zones NA38 Seabed condition survey (if off-shore) NA39 Contact name/phone for weekly progress reports [exploratory only] Appr ADD Date 2/10/2025 Appr JJL Date 2/10/2025 Appr ADD Date 2/5/2025 Administration Engineering Geology Geologic Commissioner:Date:Engineering Commissioner:Date Public Commissioner Date ($8JLC 2/10/2025
