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224-044
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: 01/10/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL: WELL: PBU 18-29CL1 +PB1 +PB2 +PB3 PTD: 224-044 API: 50-029-22316-60-00 (18-29CL1) 50-029-22316-71-00 (18-29CL1PB1) 50-029-22316-72-00 (18-29CL1PB2) 50-029-22316-73-00 (18-29CL1PB3) FINAL LWD & MAD FORMATION EVALUATION LOGS (10/27/2024 to 12/06/2024) x Multiple Propagation & Azimuthal Resistivity, Gamma Ray (2” & 5” MD/TVD Color Logs) x Final Definitive Directional Surveys SFTP Transfer – Main Folders: PBU 18-29CL1 +PB1 +PB2 +PB3 Subfolders: Please include current contact information if different from above. T39946 T39947 T39948 T39949 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.10 14:06:16 -09'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PRUDHOE BAY UNIT 18-29CL1 JBR 01/29/2025 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:2 2 3/8" and 3/5" test joints used for testing. Choke methane gas detector failed on the audible. The rig electrician chose to recalibrate all of the gas detectors even though that was the only failure. We retested all and they all passed. The HCR choke failed to hold dp during test 9. Serviced the valve and it retested good. Test Results TEST DATA Rig Rep:R. Coyne/E. GregoryOperator:Hilcorp North Slope, LLC Operator Rep:D. Johnson/R. Burnett Rig Owner/Rig No.:Nabors CDR2AC PTD#:2240440 DATE:12/5/2024 Type Operation:DRILL Annular: 250/3500Type Test:BIWKLY Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopGDC241203104508 Inspector Guy Cook Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 15.5 MASP: 2460 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" 5000 P #1 Rams 1 Blind/Shear P #2 Rams 1 2 3/8" Solid P #3 Rams 1 2 3/8"x3.5" V P #4 Rams 1 2 3/8" Solid P #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2 1/16" 5000 P HCR Valves 2 2 1/16" 5000 FP Kill Line Valves 2 2 1/16" 5000 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P2200 200 PSI Attained P12 Full Pressure Attained P55 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P10@1990 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators P PFlow Indicator P FPMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 1 P Annular Preventer P4 #1 Rams P3 #2 Rams P2 #3 Rams P2 #4 Rams P2 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9999 9 9 9 9 9 9 9 FP FP Choke methane gas detector failed HCR choke failed to hold dp By Grace Christianson at 10:54 am, Nov 22, 2024 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2024.11.22 10:21:41 - 09'00' Sean McLaughlin (4311) 324-665 DSR-11/22/24A.Dewhurst 22NOV24 10-407 * BOPE test to 3500 psi. * Post rig service coil perforating limit gun length no greater than 500' * Sag River perforation to remain on production. * Future abandonment will allow cementing across PB oil pool confining zones. MGR22NOV24*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.11.25 10:02:09 -08'00'11/25/24 RBDMS JSB 112524 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: November 22, 2024 Re:PBU 18-29C L1 Sundry for change of approved program Approval is requested for drilling a CTD sidetrack lateral from well 18-29C with the Nabors CDR2 Coiled Tubing Drilling. Proposed plan for PBU 18-29C L1 Producer: See 18-29C Sundry request for complete pre-rig details - Prior to drilling activities, screening will be conducted to drift for whipstock and MIT. CDR2 Operations Completed to Date: The rig moved in, tested BOPE and killed the well. The rig set the 4-1/2" packer whipstock and milled a single string 3.80" window + 10' of formation in the 4-1/2" liner. The well kicked off drilling in the Ivishak Zone 1. The BSAD was encountered twice resulting in two sidetracks off anchored billets. The drilling BHA got stuck twice inside the 4-1/2” liner ~600 above the window location (able to work free with time). The condition of the 4-1/2” liner is suspect, resulting in the decision to set a new whipstock ~700’ MD above the first window. Revised Plan: Set a 4-1/2" whipstock and mill a single string 3.80" window + 10' of formation in the 4-1/2" liner (above 4-1/2” liner problem area). The well will kick off drilling in the Ivishak Zone 4 and land in Zone 1. The lateral will continue in Zone 1 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 Ivishak perfs, but leave the upper Sag perfs open. The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is attached for reference. Completed Pre-Rig Work: x Reference 18-29C Sundry submitted in concert with this request for full details. 1. Coil : Dummy WS drift 2. Fullbore : MIT-IA (as needed) 3. Valve Shop : Pre-CTD Tree Work 4. Operations : Remove wellhouse and level pad. Completed Rig Work: 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,460 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Set 4-1/2" packer whipstock at 13,030’ MD (90 deg ROHS). 3. Mill 3.80” Window. 4. Drill production lateral: 4.25" OH ~1,537’ MD (12 deg DLS planned). - Two billet sidetracks and stuck inside liner above window multiple times Future Rig Work: 5. Set 4-1/2" whipstock at 12,320’ MD (0 deg ROHS). 6. Mill 3.80” Window plus 10’ of rathole. 7. Drill production lateral: 4.25" OH, ~3,727' (12 deg DLS planned). 8. Run 3-1/2” x 3-1/4” x 2-7/8” 13Cr liner (swap to VBRs and test prior to running liner) 9. Pump primary cement job: 47 bbls, 14.8 ppg Class G, TOC at TOL. 10. Only if not able to do with service coil extended perf post rig – Perforate Liner 11. Freeze protect well to a min 2,200' TVD. 12. Close in tree, RDMO. Post Rig Work: 1. Valve Shop : Valve & tree work 2. Slickline : SBHPS, set LTP (if necessary). Set live GLVs. 3. Service Coil : Post rig RPM and perforate (~1000’) - see extended perf procedure attached. 4. Testing : Portable test separator flowback. 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” (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 (12,320' MD -8,375' TVD) Pumps On Pumps Oī A Target BHP at Window (ppg)4,268 psi 4,268 psi 9.8 B ŶŶƵůĂƌĨƌŝĐƟŽŶ- ECD ;ƉƐŝͬŌͿ 739 psi 0 psi 0.06 C DƵĚ,LJĚƌŽƐƚĂƟĐ;ƉƉŐͿ 3,745 psi 3,745 psi 8.6 B+C Mud + ECD Combined 4,485 psi 3,745 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain 0 psi 523 psi Target BHP at window and deeper Operation Details: Reservoir Pressure: x The estimated reservoir pressure is expected to be 3,340 psi at 8,800 TVD. (7.3 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,460 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: 12,130' MD – 12,300' MD (170' liner) x 3-1/4", 6.6#, 13Cr/Solid: 12,300' MD – 12,750' MD (450' liner) x 2-7/8", 6.5#, 13Cr/Solid: 12,750' MD – 16,047' MD (3,297' 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 3/8" safety joint including a TIW valve for all tubulars ran in hole. x 2 3/8" 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 3/8" safety joint, 2 sets of pipe/slip rams will be available, above and below the flow cross providing better well control option. Directional: x Directional plan attached. Maximum planned hole angle is 91°. Inclination at kick off point is 29°. x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. x Distance to nearest property line – 33,700 ft x Distance to nearest well within pool – 270 ft Logging: x MWD directional, Resistivity and Gamma Ray will be run through the entire open hole section. x Real time bore pressure to aid in MPD and ECD management. Perforating: x 1000' perforated post rig – See attached extended perforating procedure. x 2.0" 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 Ivishak pool. Anti-Collision Failures: x 18-25 fails – P&A’d at surface Hazards: x DS 18 is an H2S pad. H2S reading on 18-29C: 10 ppm in 2019. x Max H2S recorded on DS/Pad: 18-01A at 450 ppm in 2019. x 2 fault crossings expected. x Medium lost circulation risk. Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka (907-223-3087) 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 Prudhoe 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 PB1: 13431' - 13600' PB2: 14350' - 15464' PB3: 13030' - 14566' 12,320' 12,320' - _' 4-1/2" Whipstock 12,300' 12,300' 16,047' 12,750' 12,750' PB1: 13431' - 13600' PB2: 14350' - 15464' PB3: 13030' - 14566' 4-1/2" Whipstock 13,030' Well 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 830084008500860087008800True Vertical Depth (200 usft/in)6200 6400 6600 6800 7000 7200 7400 7600 7800 8000 8200 8400 8600 8800 9000 9200 9400 9600 9800 10000 Vertical Section at 85.00° (400 usft/in)18-29C18-29CL1PB218-29CL1PB118-29CL1 wp07Top of Window - 12320'MDTD - 16047'MD-2000-1500-1000-50005001000South(-)/North(+) (1000 usft/in)6500 7000 7500 8000 8500 9000 9500 10000 West(-)/East(+) (1000 usft/in)L 2 -0 8 A 8662L2-08B 88009194L2-08873618-25A87468 6 9 318-3 4 874618-25APB1874318-258400 8 6 9 9 1 8 -29C 8 7 1 3 1 8-2 9CL 1 PB 2 872218-29CL1PB118-1218-12B7600 80008400 88008964L3-157 2 0 0 7 6 0 0 800084008800L3-25875511-28B873211-30A874111-308400 869 918-29CL1 wp07Top of Window - 12320'MDTD - 16047'MDSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect1 12320.00 28.75 89.69 8369.92 -646.65 6248.99 0.00 0.00 6168.852 12340.00 30.55 89.69 8387.30 -646.60 6258.88 9.00 0.00 6178.713 12410.00 38.95 89.69 8444.77 -646.38 6298.75 12.00 0.00 6218.444 12712.29 70.00 113.56 8619.89 -704.60 6531.79 12.00 40.00 6445.525 12812.29 74.47 125.26 8650.49 -751.36 6614.49 12.00 70.00 6523.846 13079.89 88.00 95.71 8692.07 -841.46 6859.26 12.00 -68.00 6759.827 13170.00 88.08 84.89 8695.16 -841.94 6949.18 12.00 -89.75 6849.358 13350.00 88.31 106.50 8700.90 -859.69 7127.14 12.00 89.75 7025.099 13530.00 89.16 84.91 8704.92 -877.48 7305.14 12.00 -88.00 7200.8710 13700.00 90.09 105.29 8706.04 -892.52 7473.57 12.00 87.50 7367.3511 13950.00 89.83 75.29 8706.23 -893.79 7720.72 12.00 -90.50 7613.4412 14185.00 90.08 103.49 8706.42 -891.32 7953.35 12.00 89.50 7845.4013 14446.00 89.94 72.17 8706.37 -881.58 8210.92 12.00 -90.25 8102.8414 14686.00 89.95 100.97 8706.61 -867.38 8447.98 12.00 90.00 8340.2415 14926.00 90.07 72.17 8706.56 -853.19 8685.04 12.00 -89.75 8577.6316 15121.00 90.07 95.57 8706.31 -832.52 8877.58 12.00 90.00 8771.2417 15422.00 90.50 59.46 8704.77 -768.52 9166.61 12.00 -89.25 9064.7518 15602.00 90.46 81.06 8703.25 -708.08 9335.02 12.00 90.00 9237.7919 15822.00 90.53 54.66 8701.31 -625.89 9536.99 12.00 -89.75 9446.1520 16047.00 90.47 81.66 8699.33 -542.94 9743.90 12.00 90.00 9659.50Project: Prudhoe BaySite: 18Well: 18-29Wellbore: 18-29CL1Plan: 18-29CL1 wp07WELLBORE DETAILSParent Wellbore:18-29CTop of Window: 12320.0018-29CL1 wp07Depth From Depth To Survey/Plan Tool100.00 12320.00 18-29C GYD Continuous (18-29C) 3_Gyro-CT_Csg12320.00 16047.00 18-29CL1 wp07 (18-29CL1) 3_Gyro-CT_CsgWELL DETAILSNorthing: 5960392.23Easting: 691687.70Lattitude: 70° 17' 46.8194 NLongitude: 148° 26' 51.6405 W18-29CL1 wp07SECTION DETAILSHilcorp Alaska, LLCSURVEY PROGRAMNAD 1927 (NADCON CONUS)US State Plane 1927 (Exact solution)Alaska Zone 04PROJECT DETAILSREFERENCE INFORMATIONCoordinate(N/E) Reference: Well 18-29, True NorthVertical (TVD) Reference: KB @ 44.10usft (18-29C)Measured Depth Reference: KB @ 44.10usft (18-29C)Section (VS) Reference: Slot - (0.00N, 0.00E)Calculation Method: Minimum CurvatureREFERENCE INFORMATION ! 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*" +,- *" ! . . %( "% ! /& !!" #$%%&' () * - !0 +', - -. / 0- /- *"#$%%&' () * & *" 1 0 / % - & 8% *: <" !! 89: #=!%& 89: 657. 8% *: / &!0 8% *: / 5 !0 8% *: 67 8% *: %( ,!" - & 8% *: +,- % * - >? ,"! :&', '&'' :&', '&'' '&'''&'': :,&,'< :' = & = &'='&'' '&'' ''&'' '&=' ''&'' '&'% '& < &=:: :,&<< :' = & <<& ''&% '& ''&'' '&=% ''&'' '& '&,% :=&<: ::& :< :' = &'<<& ''&'< '&,< =''&'' '&=: =''&'' '& &=% <:&': ::&=:< :' = & , <<& ''&'< &=: %''&'' '&= = & '&%= & : %&'<: :<&,<< :' = &,<=<<& '&': & <''&'' '&=% % & '&:% &<: < &= : :<&:< :' = &< %<<& '&': &: :''&'' '& < & '&, =&' <:&': :%&:%< :' = &=:<<<& '&': =&% ,''&'' '&= : & '& =&< ,:& : :%&=< :' = &==:<<& '& =&:< ''&'' '&% , & '&,% %& ,:& : :=&<'< :' = &= ,<<& '& %& , ''&'' '&%: & '&,% %& :=&':: : &,%< :' = &=:<<&'& <&'= '''&'' '&=, & '& <&: %,&': : &'<< :' = &, <<&'&< <&,% ''&'' '&< ' & &' :&' % &:=: :&:=< :' = '& '<<&'& :&, ''&'' '& & & :&%' %<&,: :&=%< :' = '&< <<&'&', :&% =''&'' '& : & &% :&,' =&<=: :&'%< :' = '&< <<&'&% :&' %''&'' '& : = & & :&,::%& : :'& < :' = '&, =<<&'& :& ' <''&'' '&== % & &= :&::,& : :&'< :' = &:, %<<&'&' :&< :''&'' '&< < & , =&, :&< :&=<: :& :< :' =& <<<&,'& < :&,, ,''&'' '&:< : & , %& :&<%&%: :&:=< :' =,& :<<&,'&: :&< ''&'' '&:' , & : <&= <&:<%,&=%: : &< :' =:& < ,<<&:'&' :&', ''&'' '&<, & : <& : <&'<%'&,: : &'< :' =:&% <<&:'&', <&<< '''&'' '&, & < :&,% %& < &= : :=&: < :' =<&= <<&<'& ' %& ''&'' '& ' & % ,&<: =& :&':: :%&,< :' =%&< '<<&%'& =&= ''&'' '&% & = &% &' %& :: :<& < :' ==&, <<&='&'= &,= =''&'' '&, & & : '& & : :,&'<< :' = & < <<& '&' &: %''&'' '&: = & '&= '&'<=:&' : :&'< :' = & =<<&'&= '&% <''&'' '&< % & '& '&=:& : :&, < :' =&== %<<&'&' '&< :''&'' '&< < & ' &: &%<= &= : : &%<< :' ='&:< <<<&''&' '&%= ,''&'' '&, : & ' &<% & < '&=:: : & ,< :' =, &,= :<<&''& % '&< ''&'' =&' , &= %&,= &% ==&< : ::&::< :' =,,&%, ,<<&,= & : &,' ''&'' <&' &<, &' ,&': =&%<: :&=< :' =, & : <<&%,& &: = '''&'' <&<' &< %& %& % ='&:: :,%&'< :' =:,&'' <<&'<'&% :&=< = ''&'' <& : = ' &:< =& & : ='&%:: :::&<<< :' =:'&%,= '<%&<<'&%: %&< = ''&'' ,&,= = ,& = =& =&'% &': :<,&::< :' =< &<== <=&=&, =%&= = =''&'' '&, = :&,' % &=: % &<, :&%: :%:&%< :' =%&'= < &:' &%: %:&, = %''&'' %&' = = %&%: :<& % <:& :& %: :==&,< :' = <&< = =<'&=:%&<' :&: = <''&'' ,&%% = % '&: :& , &< ,&,': :,&=:< :' ='=&% = %%:&< =&=: , & = :''&'' ,& , = <<& : ' &% &: :&':: < ,&:,< :' '&% = <%&: &< ' &'< = ,''&'' '&:% = :'&=, =%&,< =& = %&%': <,,& << :' <%&:== :=:& ,%&: <& < = ''&'' & ' = ,,=& :,&=< =& ' &'': <:'&=< :' &:'= , &<& %<& = ''&'' <&< = :%&%: '<&, %<&=< &<<: <%,&:<< :' &,== '&=:=&'% : &,% % '''&'' ,&=: = <=& : %&< < &< &%,: <=%&<< :' %'&= ' &:&,, '&<= % ''&'' ,& % '% &: & , &'% =&=': < =&,< :' ' <&,,= &,: &=, :&< % ''&'' :&:< % = &'< ==:&,< , &% <&:: <:&:< :' '<&'=% ',& <=&< '&: % =''&'' <& : % &'' ='&= '&% ,:&,: <:& < :' '',&=% ,,& '%&' & : % %''&'' <&= % = &% % &< , &,,: &=': < <&,,< < :<&=% :&=:& '& ' )" ( " ! *" +,- *" ! . . %( "% ! /& !!" #$%%&' () * - !0 +', - -. / 0- /- *"#$%%&' () * & *" 1 0 / % - & 8% *: <" !! 89: #=!%& 89: 657. 8% *: / &!0 8% *: / 5 !0 8% *: 67 8% *: %( ,!" - & 8% *: +,- % * - ?@>A ,"! % <''&'' <&, % %' &,% %:&=% <<& % &%: <%%&=%< < ,&% =<&:%<&<% %& % :''&'' :& ' % % &:, % :& & = &:': <,'&:'< < & '% %%&<,%&=< , &:% % ,''&'' &'% % <&, < & < ,&<='&=%: :'=&:%< < :'& % <=,&:%&:' %=&= % ''&'' = &' % ::& : << & <,&: %& ': :%%&='< < =&:% : %&:<&', ':& % ''&'' =%&%< % ,<& <&:% &% &',: : & %< < '=&< % ,',&, & = : &,% < '''&'' =&, % = &' :,& %'& ':&=<: ,%%&==< < ,,:&= % ,,& <& % =&'% < ''&'' % &' % '& ' :%=& = & , &<': '%&'<< < ,<&'% :%&'%&' %=&%: < ''&'' %%&, % '&: ::&== :%&,' & ': :&<< < , &=%% =:&,:=&<, '<&=' < =''&'' %,&=, < '<'& = : '& ' = &,,':& =: =,& < < ,'& =< '':&==&=: ,&,= < %''&'' % & , < :& , ,' & ='<&% '=&': '&'< < : &< ', &,=&<< % &%< < <''&'' < & = < , &' , %&:= =&::''&'<: ',&: < < :,,&:< =%& =& = =,&'< < :''&'' <:&' < =,&: ,=:&: %:& ,&'=: :&< < ::,&:< =&< %&< = <&< < ,''&'' < & < &% ,%%&:% <%<&, =& =: < &=<< < ::&'< %,&'%%&'< %,& < ''&'' : &,% < == &:, ,%&% :==& ' '&, : == &,%< < ::'&<=< <&<,%&< <:<&< < ''&'' ::&:, < = &= ,%&%= , =&< &:,: %='&< < :: &<%< ==& %&'% :<<&: : '''&'' ::& % < % &=% ,%,& <& , &:,: < &,=< < ::<&%'< =,& %'&%= ,%:& : ''&'' :<& , < %: &< ,%,&<' ':&,' & : :=&< < ::&%< %&,<'&=' =&' : ''&'' ::&=, < <'=& < ,% &< &< & %: ,'%&<,< < ::&=< %< &< & < &': : =''&'' :,& : < <% &: ,<=&%= ' & , =&': , :&%,< < :::& < % &< & ' '&< : %''&'' :,&:< < <'& , ,<&%: & =&<: &,< < ::%& < <=:&,'&= &< : <''&'' ::&% < : &:< ,: &', ,%&== &= : '& < < :: & :< <,<&<<&, '=&': : :''&'' ::&,' < :< &' ,:=&< =::& '&<: = ', &:< < ::=&,< :%& '&: %&%: : ,''&'' :<&,= < : &% ,:%&= %<,&, '&=%: = :%&=<< < ::<&=< :<<&= '& =<&<< : ''&'' :<&: < ,%'&% ,:<& <%& '&,=: = <<&<%< < :::&<< : :&= '&= %,:&== : ''&'' ::&, < ,'&< ,::&< :%'&< &'%: = =%,&%< < ::,&,,< ,=:&%&'< <:,&%: , '''&'' :,&=' < &%< ,:&'< ,= &: '&,,: = %= & =< < ::&:,< ,,<&=<'&<' :< &' , ''&'' :,&<% < <,&% ,: &': %& % '&% : = <=&<<< < :,'&'< =&,%'&=< ,<'& , , ''&'' ::&= < ,&'= ,: &< :& % '&:: = : =&<=< < :,&=< < & =& : % &<, , =''&'' ::& < =:&,% ,: & ''&, '& : = ,<& < < :,=&,< &:%'&<: ==& , , %''&'' :,&< < ,<& = ,,'& ' '&' '& : = ',&<<< < :,<& < =&='& , ' <& , <''&'' :<&,= : '%&:% ,,'&% & '&': = &% < < :,&'=< ,'&<% & ,&% , :''&'' ::&== : '<<& : ,,'&<: %& '&' : = '&,:< < :'& =: '&:'&:' '&%% , ,''&'' ::&= : ' <&' ,,'&%' =,:&'< &, : % ' &%< < : &, : '<'& '&:' &: , ''&'' :,& : =%& ,: &: %:&' &=': % ,%&%:< < :<&<: ' '&' '&% = &: , ''&'' :,&', : ,=&'% ,:&= <:'& &' : % ::&<'< < : &<': & %'& ' %=&% '''&'' :,&:, : &< ,::&,% :< &%,& %: % =<&,< < : =&%%: :,&% '&: <,<&<< ''&'' ::& : <'&< ,:<&%< ,%%&,' &%:: % %<'&,< < : ,&': ':&'<'& ::,&<% ''&'' :<&% : '&<= ,:<&<< =:& '&:: % <% &=< < : &=': %:&%=&, ,<&:: =''&'' :<&%' : == &' ,:,&'= ,& &: % :==& :< < ,''&<: ,& '&%: % &= %''&'' ::&'= : =,=& ,:& = '& < &: % , %&%'< < ,''&:': = & '&:= = &,< <''&'' ::&% : %=&% ,,'&: = ' &,, &'<: % <& =< < ,'&<: =: &='&%, = '='&,, :''&'' ::& % : %<=&' ,, &: = '&: '&, : % ',&,,< < ,' &' : %'& '&< = &= ,''&'' :,&: : % &< ,,=&=' = =&, '&: : < '''&' < < ,'=& %: %%,&% '&,, = =& = ''&'' :&'= : < & ,, &, = =:&%&,%: < ' &< < < ,':& : %<&&,, = =':& < ''&'' :,&, : <::& ,,'&= = %, && : < <& < < ,'& %: < &, '&<< = = &,= )" ( " ! *" +,- *" ! . . %( "% ! /& !!" #$%%&' () * - !0 +', - -. / 0- /- *"#$%%&' () * & *" 1 0 / % - & 8% *: <" !! 89: #=!%& 89: 657. 8% *: / &!0 8% *: / 5 !0 8% *: 67 8% *: %( ,!" - & 8% *: +,- % * - A@A> ,"! '''&'' :,&<, : :'%& ,:,& = <,&<:,&%: < ,,&%<< < ,:&% : <:'&,'&%' = % & ''&'' ::& : :%=&<: ,:=& < = ::=&: ,&=%: < =: &%<< < , &,: < &%:'& = <=& ''&'' ::&< : :=&' ,<&<, = ,<<&% :& : < %:&'=< < , &,=: := &'''&: = :,<&' =''&'' ::&=: : , =&', ,< &, = %:& '<& %: < << &==< < ,=,&<: :,& ,'& = ,::&:: %''&'' :,& , : ,: &%% ,%%& = =&%%& : < :%=&:,< < ,%&': ,&=%&= = <&<, <''&'' :,&: : ''&:' ,=<&:' % '='&%%%& :: < ,=<&=:< < ,< &,': ,<:&<''&< = <&'' :''&'' :,& : =& , , :&=' % &:%& : < ,& :< < ,,&=<: , %&,'&'< % '%=&: ,''&'' :&' : ,<& ,,&: % %& <&= : < &='< < , &<: =&,&'= % =:&= ''&'' :,&= : =&%' ,&', % =',&==:& : : '&<< < , & : : &=''& % & : ''&'' :,&: : <&=' ,'<&, % = &,,&': : '=&, < < , &'': ',& ''&,, % = &%: ' '''&'' :,& : &,= ,'&% % % & <& : : <&=< < '<& : %<&:=&'< % %=&: ' ''&'' ::&:: , ' & : &, % <=& ',& : : ,&::< < '&: : %& '&<< % <'<&<: ' ''&'' :<& , ': &', : <& = % :,<&%,&::: : =, &'<< < :&<, ' %& ,'&,= % < ,&'= ' =''&'' ::&: , ' &', : &' % ,:,&'&%=: : %,'&<=< < & ,, ':%& ,& % :&<< ' %''&'' :<& , % &': : &< % <&:=&= : : <: &'<< < :& ', '%& :'& % ,'&'% ' <''&'' :,& , &< ::&<% % <'&= ,& : : :<=&:=< < = & ', %%&,<&, % ,&:< ' :''&'' ::&% , & % : & = < '% &,,&<: : ,%<&=<< < =&:, %&%'&,: % :=&%: ' ,''&'' :<&%, , :& % :,&%: < ==&%':&: : =:&%=< < %%& <, %&%&, < '<%&,= ' ''&'' :%&:, , =&' :,=& < =& =:&%: : :&, < < < &<, ::& '& < %<&=, ' ''&'' :%& , =<%& ::,&%% < ==& :& : , ':&:,< < :'&<,, ='&''&%: < =<&< '''&'' :=&=, , = & ::& < < %'=&< <& ': , ':&'< < : &'%, =<%&'& : < = <&= ''&'' :&% , %%%&: :<<& % < % & :&= : , %& =< < ,,&=, %''&< &'' < %=& ''&'' <&< , % %&: :<'&= < <,&=%,& : , '&% < < %&=<, %<'&<=&' < <''&%= =''&'' <<&=, , <% & :%,& < :: &'&<': , =:%& < < &< , <'<& =&=' < <%& %''&'' <'& < , :' &, :%:&=: < ,% &' '& : , %%%&',< < &<:, <:<&',%&:= < ::=& ' <''&'' %%&< , :,:& :%:&:' < :& < '&,: , <& < < %& , := &':&' < ,=,&,: :''&'' =&, , ,<'&, :%:&: < &% &'': , <%&,,< < :&=<, ,':&::& < '%&% ,''&'' ==&', , =&: :%<& < %&%%& %: , :%=&=< < & , ,,&< <&:< < : &: ''&'' & = , ,& < :%%&' < =&<&,,: , : %& < < '& %, ,=&<=&% < %& ''&'' & ''%&:< :%=&= : '%&,% &< : , ,%=&<=< < '=&, :'&<<'&<' < : &:, '''&'' ='&'= ' &, :%=& % : ' '& = &:,: , , &, < < '=& '%,&:&< : '&:= ''&'' & ,&=' :%<&%= : %'& &,<: , % &,=< < '=&:: =%& ''&': : ':&=' ''&'' &< :<& :%:&% : '&<= '&:: , &=<< < '=&, &' '&, : '&:= =''&'' & =< &%' :%:&,' : = &=% &': , %&%< < '%& ='&=''&,= : < & = = '&'' &,< =: & :%:&:< : %& &: : , <'&,< < '<& ' = <& '& : :&< + *.! ?B/- =%'&'' ='&<< =,&=' :%:&:' : <& &: : , :'&:,< < '<&<' =%=& ' &'' : ,&, =<'&'' =&,< = <&: :%:&<, : :%&'< &: : , :<&%< < '<&:: =<&,: &'' : =&: =,<&'' =%&,< %:&,, :%:&<' : ,,&,: &: : , , &<%< < ':&' =, &:, &'' : ,&< %''&'' =,&,< %=:& :%:&% : &<% &: : , %&=< < ':&<% = & &'' : & : %'&'' =& < %%%&,, :%:&= : &,< &: : '''&<< < ':&,% %''&:, &'' : &%% % <&'' %'&=% %<:&= :%:&% : ='&= &%: ''&'< < ':& % & &'' : ,& , %<'&'' % &, %,<&'= :%,&= : = %&, %& %: ' :&:<< < ':&%, %='& = &'' : %%&= %,<&'' %<&: % =&'= :%& : =% &= :&,:: '%=& << < '<& % %%& = &'' : :&%= <''&'' %,&:< <'& , :<&% : =:'&': &',: ':& =< < '=& ' %::&, &'' : , &' )" ( " ! *" +,- *" ! . . %( "% ! /& !!" #$%%&' () * - !0 +', - -. / 0- /- *"#$%%&' () * & *" 1 0 / % - & 8% *: <" !! 89: #=!%& 89: 657. 8% *: / &!0 8% *: / 5 !0 8% *: 67 8% *: %( ,!" - & 8% *: +,- % * - >A ,"! < <&'' <'& < :&,' :<%& : =,&:''& ': ''&<:< < ''&=< % &:' &'' : ,& : <<'&'' < &,< <% & , :<& % : = ,&,'=& : ' &,,< < :&,' % &, &'' : =<& % <,<&'' <<&=< <<:& < ::=& : %,&=%'<&'%: &<< < & , < &< &'' : ==<&': :''&'' <,& <,'&: :: &: : %=,&% ':&,,: = &,=< < ,&'< < :&< &'' : =<%&<: : <&'' :'&: <=&%< :,:& : %<,& '&%: :'&=,< < &' <= &=< &'' : =,%&%' :<'&'' :=& < <& ' :=&=, : %,&,%' & ,: &=< < ,%&=: <<&' &'' : = %&<= :,<&'' :<& , :'<& : &=: : % &,&%:: ' &,'< < ::& <:& &'' : %%& ,''&'' :&:, :<&<< ,''&', : < & &: %& < < <&,< <,&%< &'' : %=<&= , & ,'&'' : & ,'%&:' : <=&, =&<:: =%& << < <%&% <,<&, &'' : %%<&< , <&'' ,'&<= : %& ,' &<= : <% &: <&': %<& < < % &% <'&' &'' : %<<& : ,<'&'' ,&:' := &=' , '&' : <:=&%&'%: :,&= < < = & <& ' &'' : %,:&' ,,<&'' , &, := & : ,=& : <%&<< '& ,: &= < < &: < <&: &'' : % <&, ''&'' ,=& :%,&% ,%%&:: : :'%&,: =&<: ='& < < :&=' :'=&'% &'' : <%&, & ,%&%, :<'&% ,<&=: : :%&% <& :: =& < < ' &< :':&= &'' : < =&% <&'' ,<&'< :<=&= ,<&= : : %&:' =&': = &'< < '=&: :' &,= &'' : <==&=' <'&'' ,:& ::'&'% ,,& : :%<&'< '& %: =% &,< < , '&, :<& % &'' : << &<% ,<&'' ,,&%' ::<&,< ,=& , : :::& =&: =,&=<< < ,, & , : &:< &'' : <, &:' ''&'' ,&: :,'& % , %& : : :&',<&=: = =&%:< < ,:&< : :&% &'' : < =&%' <&'' , &, :,<&: '%& : ,'&< &<%: %:&:< < ,< &%: :=&< &'' : :%& <'&'' &% :, &,= =& : ,==&<' &,: %= &=,< < ,<&: :=<&:= &'' : :=,&' ,<&'' &%= :=&=' '& = : ,<:& ',&'%: %:=&'=< < ,%=& < := & ' &'' : :< &,= = '''&'' =&,% ::&= ,&:% : ,'&'%&= : %,&' < < ,=,&< :% & &'' : : & % = ' <&'' <&': :&,< ==& : '<& '&: : <&%:< < ,= & :%%&:< &'' : ,':&: = '<'&'' :&%' : '&: =,&:: : &:< & : <=:&' < < , &', :%:&< &'' : ,='&:< = ',<&'' ,&,% : & %'& : : <%&%' :& %: <:'& < < , :&% :%,&, &'' : ,<<&' = ', & &'' : &', %&%: : < & : <&,: <:<&, < < , :&'= :%,& , &'' : ,< & = ''&'' &' : &,, %=&'% : , & =&=': <<&<< < , %& : :%&:, &'' : ,, &:% = <&'' &'= : =&:% %=&= : '%& : '& : :'&=< < , %& :% &<% &'' : '%&%% = <'&'' &': : %&% %=&=' : & %,& : :=<&, < < , <& :<'&= &'' : &=, = ,'&'' &' : <&: %& % : % &%& : :<<&: < < , ,&< :<&': &'' : % &=< = ,<&'' &' : <&== %&< : <%&:<&% : ::'&:<< < , &= :<& = &'' : <%&=< = ''&'' &' : :&: %'& : , &&% : :<&<:< < ,='&=% :< &': &'' : , &= = <&'' & : :& %'& , ''%&' &<': ,'&<=< < ,='& :< & &'' : '%& = <'&'' &< : ,&' %&< , ' &'% %&<': ,=<&<< < ,='&= :<=&,' &'' : & < = ,<&'' & : &:' %%& , '<=& ,&<': ,:'&%< < , &== :<%&<' &'' : <=&% = =''&'' & : &= %&'= , ',&<,''&<': ,<&< < , <&'< :<<& &'' : ,,&, = = <&'' & : ,''&< <=& = , '=&'''=&<': ' &,%< < , '&% :<:&'< &'' , ''&: = =<'&'' &= ,''& ' < &: , ,&%':&<': =%&'=< < ,%&:% :<:&' &'' , ' <&' = =,<&'' &% ,'&: ::&: , <& ,'=&<': <&= < < ,'&, :<,&< &'' , '%&<, = %''&'' &<= ,' & ,&=: , ,<&, ''&<': & < < ,'%& :<& &'' , ', &%, = % <&'' &:% ,' & ' ,<& , , ''&%' ,&<': ',&::< < ,''& = :<&' &'' , ' :&, = %<'&'' &,: ,'=&%: ,,& , <& < %&<: = &<,< < : & < :< &=: &'' , & % = %,<&'' & ,'=& , & , <'& &<: <,&<<< < : & :< & &'' , %<& = <''&'' &' ,'%&%% , & ' , ,<& '&<: &<=< < : & ::'&=% &'' , ,'& = < <&'' &% ,'%&% ,,& ' , =''&:<&<: '',&%<< < ,''&< ::'&,% &'' , <&, )" ( " ! *" +,- *" ! . . %( "% ! /& !!" #$%%&' () * - !0 +', - -. / 0- /- *"#$%%&' () * & *" 1 0 / % - & 8% *: <" !! 89: #=!%& 89: 657. 8% *: / &!0 8% *: / 5 !0 8% *: 67 8% *: %( ,!" - & 8% *: +,- % * - AA> ,"! = <='&'' &: ,'%& ,,&% , ='<&%%& : ' &% < < ,'&%' ::'& &'' , ''&, = <<'&'' & , ,'<& ,:& , = <&' ,&=: '= &==< < ,'=& : ::&' &'' , '&: = <,<&'' &%' ,'<&% ,<&:' , =<'&' '&=: '<,&='< < ,'%&% ::&= &'' , %<&' = :''&'' &<% ,'<&, ,:&= , =,<&', =&=: ' & < < ,'%& , ::&: &'' , ,'&: = : <&'' &:, ,'<& ,&% , = & :&=': ',& %< < ,' & ::&, &'' , <& < = :<'&'' & ,'<& & , % %&,% &=': = &' < < ,''&'< ::& &'' , = &:= = :,<&'' & < ,':&'< :&<: , %% &='' &=': <:&,<< < : <& ::& < &'' , =%=&: = ,''&'' '&' ,':&'% &< , %,=&<,'<& : &,< < : '&:: ::& % &'' , =:,&=< = , <&'' '&': ,':&' &% , % ,&<' & : '<&< < < :<&= ::& &'' , = &' = ,<'&'' '&'= ,'<& '=&: , < &%' & : ='& << < :& : ::& &'' , %<&': = ,,<&'' '&' ,'<& ':&<< , <%,&, :& : <<&'< < :,&< ::& &'' , %= &%% = ''&'' & ,'<& '&:% , <, &' =& : '&'<< < :,,&': ::& &'' , %:%&', = <&'' & : ,'<& ' &% , < ,&', '& : ='<&'%< < :,:& ::& &'' , %& = <'&'' & = ,':&' '& ' , : &':,& : =='&'< < :,&', ::& &'' , <=&% = ,<&'' & ' ,':&'< ',&': , :%:& %& : =<%& < < :'&<% ::& < &'' , <=&= = ''&'' & ,':&' '=& = , :,&, & : =, &:'< < :%&= :: &'' &'' , <:=& = <&'' &< ,':&: &<' , : :&= ,& : %'%&'< < : &=: :: &': &'' , <&,' = <'&'' &= ,':& = =&, , , '&, ,<& : % & :< < : <&: :: &= &'' , :=&%% = ,<&'' &< ,':&=' &' , ,%<&':,& : %< &%%< < ,' &' :: & ' &'' , :=& % '''&'' & ,':&=: =&:< , ,: &::& : %,:& < < ,',&' :: & : &'' , ::=&' % ' <&'' & ,':&% '&< , , %&%:%& : <'&:=< < ,'&% :: &= &'' , :&': % '<'&'' & = ,':&%% ,&: , &= ,& : < :&<'< < ,=&= :: &=% &'' , ,=&'< % ',<&'' & : ,':&%, ,&< , %%&= '& : <<&%,< < ,%&% :: &=, &'' , ,=&'' % ''&'' & ,':&% ,& = , : &=, =& : <,:&%:< < ,%&== :: &= &'' , ,: & % <&'' '&' ,':&% &' , %& :& : :'&% < < , & :: &= &'' , ,,&%< % <'&'' '&'% ,':&%: %&% , &'% & : : :& :< < ,'& :: &=: &'' , &= % ,<&'' '&', ,':&%% &' , %=&:'' & : :<'& =< < ,':&', :: &=% &'' , =<& % <&'' '&' ,':&% &= , <=&=<'=&% : ::'&,=< < ,'%&' :: &= &'' , %<&%' % ''&'' '&', ,':&%' %&< , :,& '&: : :,<&%%< < ,'& :: &=' &'' , < &: % <&'' '&': ,':&=, &' , &< &: : ,''&<< < : ,&%' :: & , &'' , =& % <'&'' '&'< ,':&=< ' &< ',&= <&: : , <&' < < : %& ' :: & < &'' , '& < % ,<&'' '&'= ,':&== '=& '% &= &: : ,% & < < : =&, :: & = &'' , = & = % =''&'' '&' ,':&= '%&<' ':,&= &: : ,,%& < < : =&= :: & &'' , <,&, % = <&'' '&' ,':&= '=&, ' & :&: : , & %< < : <& < :: & &'' , &,% % =<'&'' & ,':&= '&: ,& '=&: : %&,< < : ,& :: & &'' '',&,= % =,<&'' & ,':&= & %& ,'&: : % &%<< < ,' &' :: & &'' '= &,' % %''&'' & , ,':&== =&<= ::&< ,,&: : ,=&< < ,',&= :: & = &'' '<,&<, % % <&'' & < ,':&=< ,&<: '&',%&: : ,& < < ,=& ' :: & < &'' ' & , % %%:&'' & % ,':&=, &< '& , &,: ,& :< < , '&%' :: & , &'' ' &% % %<'&'' & % ,':&=, '&=, %&,%, &:<: &,%< < , &,' :: & , &'' ':&,< % %,<&'' & % ,':&%' ,=&<% =&,,<&:<: %<&:'< < , &% :: &=' &'' =&=' % <''&'' & % ,':&%= :,& :=&:,&:<: : & < < ,=<&= :: &== &'' <:&': % < <&'' & % ,':&%< :=&, ,&,&:<: %&==< < ,%'& :: &=< &'' '& , % <<'&'' & % ,':&% :'&,= = &:'%&:<,'' ' &',< < ,%=&= :: &= &'' '<& < % <,<&'' & % ,':&<' < &'< ==,&<%,&:<,'' '%=& :< < ,%:&% :: &%' &'' ='& < )" ( " ! *" +,- *" ! . . %( "% ! /& !!" #$%%&' () * - !0 +', - -. / 0- /- *"#$%%&' () * & *" 1 0 / % - & 8% *: <" !! 89: #=!%& 89: 657. 8% *: / &!0 8% *: / 5 !0 8% *: 67 8% *: %( ,!" - & 8% *: +,- % * - AA>? ,"! % :''&'' & % ,':&<= <&: =: &<% '&:<,'' ':& =< < ,%,&< :: &%= &'' <<& % : <&'' & % ,':&<< < &: =,&< =&:<,'' ' =& < < ,%:&< :: &%< &'' '&: % :<'&'' & < ,':&<, :&, % &% :&:<,'' &,< < ,%<& % :: &%, &'' ='<& % :,<&'' & < ,':&:' :<&% %=,&: &:<,'' %=&: < < ,% &== :: &<' &'' = &:= % ::&'' & < ,':&: :,&= %%,& ''& ,,'' <%&<:< < ,%'&:= :: &< &'' =%'& % % ,''&'' & : ,':&: : &< %:&,: & ,'' :&%'< < ,=&< :: &< &'' =<=&,< % , <&'' & , ,':&:% ,=& % %:&<= :& ,'' =& %< < ,=<&,, :: &<% &'' =,&= % ,<'&'' & ,':&:< ,<&= <&%% =& ,'' & '< < ,=%&= :: &<< &'' %' &,: % ,,<&'' '&'' ,':&:< ,:& <=:&% '& ,'' %=& < < ,=%&, :: &<< &'' % ,&< % ''&'' '&' ,':&:< ,<&< <:&%,& ,'' :&:< < ,=<&== :: &<< &'' %< &< % <&'' '&' ,':&:% ,=&,< <:&=%%& ,'' =&'=< < ,=,&' :: &<% &'' %,,&< % <'&'' '&'% ,':&:= ,'&: :&%& ,'' =,&,%< < ,%&<, :: &<= &'' <' &<' % ,<&'' '&'< ,':&: ::& :=<&,<,& ,'' =% & < < ,%:&: :: &< &'' < ,&= % ''&'' '&': ,':&< :'&%, ::'&',<& ,'' =::&%'< < ,< & < :: &% &'' << &= % :&'' '&', ,':&<: <=& :<&'%, &,,'' = &,< < ,:'&, :: &%: &'' <,,&:= % <'&'' '&', ,':&<= %:&% ,'&':,<&'<,'' %%&'< < ,:& :: &%= &'' :'&< % ,<&'' '&', ,':&% %'&: ,= &=,,&'<,'' %=&:< < ,,%&:< :: &= &'' : <& < '''&'' '&', ,':&%: =:&', ,<:& <&'<,'' %: &: < < ,, & :: &=: &'' :<'&,: < ' <&'' '&', ,':&%= = &= ,&,%%&'<,'' %,&=< < ,=&: :: &== &'' :,<&,% < '<'&'' '&', ,':&%' ='& ' ':&::,&'<,'' < &< < ,:& : :: &=' &'' ,''&,= < ',<&'' '&', ,':&=, ='& : =&:< '&'<,'' <=,&%< < ,,&< :: & , &'' , <&: < ''&'' '&', ,':&=% ='& % <:&:% =&'<,'' <: &%< < ,,&% :: & % &'' ,<'&< < &'' '&', ,':&= = &< ,,&< <&<,,'' <=&< < ,:&%% :: & &'' ,,& % < <&'' '&', ,':&= = & &<: <&' ,'' <,&'< < ,:&, :: & &'' ,,<&, < <'&'' '& ,':& : =%&%: ':&< &' ,'' : &'< < ,<& % :: &: &'' , & < ,<&'' '&< ,':& =%&, =&< &' ,'' :=,&',< < ,<&: :: & &'' %&,, < ''&'' '& ,':&= ==&:, <:&%:&' ,'' :: &'< < ,,&=' :: &'= &'' % &,% < <&'' '& = ,':&'% =&= &=,=&' ,'' ::& < < , '& ::& % &'' ,%&,% < <'&'' '& , ,'<& = ,&:: '':&' '&' ,'' ,&%<< < , %&< ::&= &'' &: < ,<&'' '&=' ,'<& &, '='&:',,&' ,'' ,=<& < < ''&% ::&, &'' %&<= < =''&'' '&=% ,'<&:, :&<' '<%&,%&' ,'' ,< &:< < ':& , ::&<, &'' % & < = <&'' '&=, ,'<&< ' &' ',&::,&','' ,=&<< < <&': ::&% &'' ,=&:' < =<'&'' '&% ,'<&=% ''&= ' &' :&','' ':&,< < %&=, ::& % &'' ,&,' < =,<&'' '&%% ,'<&: , '&= <&'=:<&','' &= < < =%& ::&': &'' ' &% < %''&'' '&%, ,'%& : ,, & : %,&% : &','' <&%< < %:&<: ::'&: &'' '%%&: < % &'' '&<' ,'%&,, ,:&< ::&:< &%:,'' ,'&%'< < <,&, ::'&:, &'' ':%&,< < % <&'' '&<' ,'%&,< ,:,&' : & '< & ,'' , & << < < &=, ::'&:< &'' ':,&%: < %<'&'' '&<' ,'%&<= ,<<&' &=: & ,'' %&<:< < ,& ::'&%= &'' ' '&=< < %,<&'' '&% ,'%&= ,%%&, =&:::<& ,'' :&'< < =&= ::'& &'' =&,% < <''&'' '&% ,'%&' ,=%&<= =:&, :& ,'' = &:< < =&<< ::'&'' &'' =,&<< < < <&'' '&% ,'=& , :& :'& :,& ,'' : & < < ' &<: :< &, &'' :&,= < <<'&'' '&% ,'=&:, ,& % %& ',%& ,'' :&:,< < '&=< :< &<, &'' :& < <,<&'' '&%, ,'=&%, ,=&'= ='&% ,,& ,' ''&'< < :& :< &=, &'' '& < :' &'' '&%: ,'=& < ,'&' ==<&' &':,' '=,& '< < &<' :< &< &'' =,&, < : <&'' '&%, ,'=&': ,'=& : =<,&:<,&=',' '< &,< < ,& ' :<& : &'' :'&: )" ( " ! 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From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:FW: PBU 18-29CL1 (PTD #224-044) - New Whipstock Set Date:Thursday, November 21, 2024 5:06:10 PM From: Rixse, Melvin G (OGC) Sent: Thursday, November 21, 2024 4:16 PM To: Trevor Hyatt <Trevor.Hyatt@hilcorp.com> Cc: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com>; Jose Vazquez <Jose.Vazquez@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>; Boman, Wade C (OGC) <wade.boman@alaska.gov>; Lau, Jack J (OGC) <jack.lau@alaska.gov>; Boman, Wade C (OGC) <wade.boman@alaska.gov>; Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: RE: PBU 18-29CL1 (PTD #224-044) - New Whipstock Set Trevor, Hilcorp is approved to set a new whipstock and mill the window on PBU18-29CL1 at ~ 12,320’ MD per this email. A 10-403 for change to approved program with revised directional program should be submitted to AOGCC prior to drilling > 15’ of new hole to the original planned TD location. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Trevor Hyatt <Trevor.Hyatt@hilcorp.com> Sent: Thursday, November 21, 2024 3:41 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Boman, Wade C (OGC) <wade.boman@alaska.gov> Cc: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com>; Jose Vazquez <Jose.Vazquez@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Subject: PBU 18-29CL1 (PTD #224-044) - New Whipstock Set CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Mel, After sticking the BHA in casing above our original whipstock / window at 13030’ MD multiple times, it has been decided that we will set a whipstock and mill at ~12,320’ MD, approximately 710’ above the initial whipstock (still inside the 4-1/2” liner in the production zone). We request verbal approval to set the whipstock and mill the window. We realize this change of kickoff requires a Revised Permit to Drill. We will provide the updated directional survey, permitting package and schematics with the revised PTD as soon as possible in the morning. Please let me know if you have any questions or require additional information. Thank you. Trevor Hyatt Hilcorp Alaska, LLC Drilling Engineer Trevor.Hyatt@hilcorp.com Cell: 907-223-3087 From: Trevor Hyatt <Trevor.Hyatt@hilcorp.com> Sent: Thursday, November 21, 2024 3:26 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Boman, Wade C (OGC) <wade.boman@alaska.gov> Cc: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com>; Jose Vazquez <Jose.Vazquez@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Subject: PBU 18-29CL1 (PTD #224-044) - Plugback and Sidetrack #2 Mel / Wade, PBU 18-29CL1 (PTD #224-044) Update: While drilling the lateral section we crossed into the BSAD shale. It is not possible to drill ahead with shale instability. We sidetracked off a billet (at 14,350’ MD) and drilled a short section (to 14,566’ MD). A wiper trip was performed, and the BHA became stuck inside the 4- 1/2” liner for a second time. The new plan is to set a new whipstock and mill a new window above the problem 4-1/2” liner section. I’ll send a new email with those details. Please let me know if you have any questions. Sidetrack detail below: Sidetrack Date Depth Interval (ft) Length (ft) PB2 11/21/2024 14,350 – 15,464 MD 1114 Trevor Hyatt Hilcorp Alaska, LLC Drilling Engineer Trevor.Hyatt@hilcorp.com Cell: 907-223-3087 From: Trevor Hyatt Sent: Wednesday, November 6, 2024 10:28 AM To: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>; Boman, Wade C (OGC) <wade.boman@alaska.gov> Cc: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com>; Jose Vazquez <Jose.Vazquez@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Subject: PBU 18-29CL1 (PTD #224-044) - Plugback and Sidetrack Mel / Wade, PBU 18-29CL1 (PTD #224-044) Update: While drilling the lateral section we crossed into the BSAD shale. It is not possible to drill ahead with shale instability. Currently we are sidetracking off a billet and will continue drilling ahead in the planned lateral section towards TD staying above the BSAD. Please let me know if you have any questions. Sidetrack detail below: Sidetrack Date Depth Interval (ft) Length (ft) PB1 11/6/2024 13,431 – 13,600 MD 169 Trevor Hyatt Hilcorp Alaska, LLC Drilling Engineer Trevor.Hyatt@hilcorp.com Cell: 907-223-3087 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 herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Drilling Manager 06/06/24 Monty M Myers 324-333 By Grace Christianson at 11:31 am, Jun 06, 2024 10-407 * Approved for post CDR2 service coil perforating. Perf gun BHA not to exceed 500' in length. MGR12AUG2024 DSR-6/7/24SFD 6/17/2024*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.08.12 15:38:52 -08'00'08/12/24 RBDMS JSB 081324 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: June 6, 2024 Re:PBU 18-29C L1 Permit to Drill Approval is requested for drilling a CTD sidetrack lateral from well 18-29C with the Nabors CDR2 Coiled Tubing Drilling. Proposed plan for PBU 18-29C L1 Producer: See 18-29C Sundry request for complete pre-rig details - Prior to drilling activities, screening will be conducted to drift for whipstock and MIT. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. The rig will set the 4-1/2" packer whipstock and mill a single string 3.80" window + 10' of formation in the 4- 1/2" liner. The well will kick off drilling in the Ivishak Zone 1. The lateral will continue in Zone 1 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 Ivishak perfs, but leave the upper Sag perfs open. 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 18-29C Sundry submitted in concert with this request for full details. 1. Coil : Dummy WS drift 2. Fullbore : MIT-IA (as needed) 3. Valve Shop : Pre-CTD Tree Work 4. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in August) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,460 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Set 4-1/2" packer whipstock* at 13,030’ MD (90 deg ROHS). 3. Mill 3.80” Window. 4. Drill production lateral: 4.25" OH, ~3,052' (12 deg DLS planned). 5. Run 3-1/2” x 3-1/4” x 2-7/8” 13Cr liner (swap to VBRs and test prior to running liner) 6. Pump primary cement job: 40 bbls, 15.3 ppg Class G, 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. Slickline : SBHPS, set LTP* (if necessary). Set live GLVs. 3. Service Coil : Post rig RPM and perforate (~1000’) - see extended perf procedure attached. 4. Testing : Portable test separator flowback. Seet PTD 224-044 Already approved. - mgr - mgr 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” (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 (13,030' MD -8,700' TVD) Pumps On Pumps Oī A Target BHP at Window (ppg)4,434 psi 4,434 psi 9.8 B ŶŶƵůĂƌĨƌŝĐƟŽŶ- ECD ;ƉƐŝͬŌͿ 782 psi 0 psi 0.09 C DƵĚ,LJĚƌŽƐƚĂƟĐ;ƉƉŐͿ 3,891 psi 3,891 psi 8.6 B+C Mud + ECD Combined 4,672 psi 3,891 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain 0 psi 543 psi Target BHP at window and deeper Operation Details: Reservoir Pressure: x The estimated reservoir pressure is expected to be 3,340 psi at 8,800 TVD. (7.3 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,460 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: 12,130' MD – 13,020' MD (890' liner) x 3-1/4", 6.6#, 13Cr/Solid: 13,020' MD – 13,230' MD (210' liner) x 2-7/8", 6.5#, 13Cr/Solid: 13,230' MD – 16,082' MD (2,852' 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 3/8" safety joint including a TIW valve for all tubulars ran in hole. x 2 3/8" 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 3/8" safety joint, 2 sets of pipe/slip rams will be available, above and below the flow cross providing better well control option. Directional: x Directional plan attached. Maximum planned hole angle is 92°. Inclination at kick off point is 92°. x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. x Distance to nearest property line – 33,700 ft x Distance to nearest well within pool – 270 ft Logging: x MWD directional and Gamma Ray will be run through the entire open hole section. x Real time bore pressure to aid in MPD and ECD management. Perforating: x 1000' perforated post rig – See attached extended perforating procedure. x 2.0" 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 Ivishak pool. Anti-Collision Failures: x 11-30A fails – in reservoir below production packer and below CIBP in 2-7/8” production liner. x 18-25 fails – P&A’d at surface Hazards: x DS 18 is an H2S pad. H2S reading on 18-29C: 10 ppm in 2019. x Max H2S recorded on DS/Pad: 18-01A at 450 ppm in 2019. x 2 fault crossings expected. x Medium lost circulation risk. Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka (907-223-3087) DS 18 is an H2S pad. g well will be perforated gp Max H2S recorded on DS/Pad: 18-01A at 450 ppm p completely in the Ivishak pool. p 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 Well 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 2.0" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip 9.54 ft CL 2.0" 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 3.0" Pipe / Slip HF nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Monty M. Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK, 99503 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 18-29CL1 Hilcorp Alaska, LLC Permit to Drill Number: 224-044 Surface Location: 1474' FNL, 86' FEL, Sec 24, T11N, R14E, UM, AK Bottomhole Location: 1912' FNL, 569' FEL, Sec 20, T11N, R15E, UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced well. The permit is for a new wellbore segment of existing well Permit Number 209-055, API Number 50-029- 22316-03-00. Production from or injection into this wellbore must be reported under the original API Number stated above. 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, Brett W. Huber, Sr. Chair, Commissioner DATED this day of May 2024. 16th 3-1/2"x3-1/4" Drilling Manager 05/03/24 Monty M Myers By Grace Christianson at 12:08 pm, May 03, 2024 * BOPE test to 3500 psi. * Post rig service coil perforating limit gun length of no greater than 500'. * Sag River perforations to remain on production. * Future abandonment will allow cementing across PB oil pool confining zones. 50-029-22316-60-00224-044 DSR-5/6/24MGR10MAY2024A.Dewhurst 14MAY24 JLC 5/16/2024 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: May 2, 2024 Re:PBU 18-29C L1 Permit to Drill Approval is requested for drilling a CTD sidetrack lateral from well 18-29C with the Nabors CDR2 Coiled Tubing Drilling. Proposed plan for PBU 18-29C L1 Producer: See 18-29C Sundry request for complete pre-rig details - Prior to drilling activities, screening will be conducted to drift for whipstock and MIT. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. The rig will set the 4-1/2" packer whipstock and mill a single string 3.80" window + 10' of formation in the 4- 1/2" liner. The well will kick off drilling in the Ivishak Zone 1. The lateral will continue in Zone 1 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 Ivishak perfs, but leave the upper Sag perfs open. The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is attached for reference. Pre-Rig Work: Reference 18-29C Sundry submitted in concert with this request for full details. 1. Coil : Dummy WS drift 2. Fullbore : MIT-IA (as needed) 3. Valve Shop : Pre-CTD Tree Work 4. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in August) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,460 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Set 4-1/2" packer whipstock* at 13,030 MD (90 deg ROHS). 3. Mill 3.80 Window. 4. Drill production lateral: 4.25" OH, ~3,052' (12 deg DLS planned). 5. Run 3-1/2 x 3-1/4 x 2-7/8 13Cr liner (swap to VBRs and test prior to running liner) 6. Pump primary cement job: 40 bbls, 15.3 ppg Class G, 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. Slickline : SBHPS, set LTP* (if necessary). Set live GLVs. 3. Service Coil : Post rig RPM and perforate (~1000) - see extended perf procedure attached. 4. Testing : Portable test separator flowback. * Prudhoe Bay Oil Pool to be isolated on future abandonment. Sag River perforations to remain open. - mgr 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 (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 (13,030' MD -8,700' TVD) Pumps On Pumps O A Target BHP at Window (ppg)4,434 psi 4,434 psi 9.8 B - ECD 782 psi 0 psi 0.09 C 3,891 psi 3,891 psi 8.6 B+C Mud + ECD Combined 4,672 psi 3,891 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain 0 psi 543 psi Target BHP at window and deeper Operation Details: Reservoir Pressure: The estimated reservoir pressure is expected to be 3,340 psi at 8,800 TVD. (7.3 ppg equivalent). Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,460 psi (from estimated reservoir pressure). Mud Program: Drilling: Minimum MW of 8.4 ppg KCL with viscosifier for drilling. Managed pressure used to maintain constant BHP. Disposal: All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4. Fluids >1% hydrocarbons or flammables must go to GNI. Fluids >15% solids by volume must go to GNI. Fluids with solids that will not pass through 1/4 screen must go to GNI. Fluids with PH >11 must go to GNI. Hole Size: 4.25" hole for the entirety of the production hole section. Liner Program: 3-1/2", 9.3#, 13Cr/Solid: 12,130' MD 13,020' MD (890' liner) 3-1/4", 6.6#, 13Cr/Solid: 13,020' MD 13,230' MD (210' liner) 2-7/8", 6.5#, 13Cr/Solid: 13,230' MD 16,082' MD (2,852' liner) The primary barrier for this operation: Kill Weight Fluid to provide overbalance as necessary. A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Well Control: BOP diagram is attached. MPD and pressure deployment is planned. Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. The annular preventer will be tested to 250 psi and 2,500 psi. 1.5 wellbore volumes of KWF will be on location at all times during drilling operations. 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. A X-over shall be made up to a 2 3/8" safety joint including a TIW valve for all tubulars ran in hole. 2 3/8" 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 3/8" safety joint, 2 sets of pipe/slip rams will be available, above and below the flow cross providing better well control option. Directional: Directional plan attached. Maximum planned hole angle is 92°. Inclination at kick off point is 92°. Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Distance to nearest property line 33,700 ft Distance to nearest well within pool 270 ft Logging: MWD directional and Gamma Ray will be run through the entire open hole section. Real time bore pressure to aid in MPD and ECD management. Perforating: 1000' perforated post rig See attached extended perforating procedure. 2.0" Perf Guns at 6 spf 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. The well will be perforated between the CTD whipstock and TD of the newly drilled CTD well, completely in the Ivishak pool. Anti-Collision Failures: 11-30A fails in reservoir below production packer and below CIBP in 2-7/8 production liner. 18-25 fails P&Ad at surface Hazards: DS 18 is an H2S pad. H2S reading on 18-29C: 10 ppm in 2019. Max H2S recorded on DS/Pad: 18-01A at 450 ppm in 2019. 2 fault crossings expected. Medium lost circulation risk. Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka (907-223-3087) $) $)$) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $)$) $) $) $) $) $) $) $ $) $) $) $)$) $) $) $)$) $) $)$) $) $) $) $) $) $) $) $) $) $) $) $) $)$) $)$) $) $) $) $) $) $)$) $) $) $)$)$) $) $) $) $) $$ $)$) $) $) $) $) $) $) $) $) $) $) $) $) $) $ $) $) $) $) $) $) $) $) $)$) $)$) $) $) $) $) $) $) $) $) $) $) $)$) $) $) $) $) $)$ $) $) $) $) $) $)$) $) $) $) $) $) $) $) $) $)$) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $)$) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $)$) $) $) $) $)$) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $)$) $ $) $) PRUDHOE BAY UN LIS L3-05 02-01 02-01A 02-01B 02-02 02-02A 02-04A 02-09 02-09A 02-09B 02-09C 02-09D 02-10 02-10A 02-13 02-13A 02-13B 02-18 02-18A 02-22 02-22A 02-29 02-29A 02-29B 02-29C 02-31 02-31A 02-32C 02-33A 02-34 02-34A02-34B 02-36A 02-37 02-38 02-38A 02-39 02-39A 05-01 05-01A 05-01B 05-01C 05-02 05-02A 05-10C 05-11 05-11A 05-12 05-12A 05-12B 05-13 05-13A 05-13B 05-14 05-14A 05-15 05-15A 05-15B 05-16 05-16A 05-16B 05-16C 05-17 05-17A 05-18 05-18A 05-23 05-23A 05-23B 05-24 05-26 05-26A 05-28 05-28A 05-28B 05-30 05-31 05-31A 05-31B 05-32 05-32A 05-33A 05-33B 05-34 05-35 05-35A 05-35B 05-36 05-36A 05-38 11-05 11-05A 11-06 11-06A 11-13 11-13A 11-14 11-23 11-23A 11-23B 11-24 11-24A 11-25 11-25A 11-26 11-27 11-28 11-28A 11-28B 11-30 11-30A 11-31 11-31A 11-34 11-38 11-38A 11-39 18-01 18-01A 18-02 18-02A 18-02B 18-02C 18-03 18-03A 18-03B 18-03C 18-04 18-04B 18-04C 18-06B18-08A 18-11 18-11A 18-11DPN 18-12 18-12A 18-12B 18-12C 18-13 18-13A 18-13B 18-13C 18-14 18-14A 18-14B 18-14C 18-15A 18-15B 18-15C 18-16 18-16A 18-16B 18-18 18-18A18-18B 18-19 18-20 18-21 18-21A 18-21B 18-22 18-22A 18-23 18-23A 18-24 18-24A 18-24B 18-25 18-25A 18-26 18-26A 18-26B 18-28 18-29 18-29A 18-29B 18-29C 18-30 18-30A 18-31 18-31A 18-32 18-32A 18-32B 18-33 18-33A 18-34 18-35 EBAYST-01 L3-01 L3-05 L3-06 L3-11 L3-15 L3-23 L3-25 LPC-01 LPC-02 NGI-01 NGI-02 NGI-07A NGI-12 PSI-01 PSI-05 PSI-06 PSI-07 T-03C 11-27A_PROP Prudhoe Bay Unit Sec. 9 Sec. 21 Sec. 13 Sec. 17 Sec. 16 Sec. 12 Sec. 8 Sec. 33 Sec. 32 Sec. 36 Sec. 25 Sec. 24 Sec. 28 Sec. 29 Sec. 20 Sec. 18 (599) Sec. 7 (596) Sec. 31 (607) Sec. 19 (601) Sec. 30 (604) U011N015E U011N014E LPC NGI DSL2 DS2 OSP - C PAD DS5 PAD 10 DS18 ADL028307 ADL028302 ADL028308 ADL028326 ADL028321 ADL028322 ADL028325 ADL034631 ADL034632 Gas Cap PA Oil Rim PA Lisburne PA 18-29CL1_SHL 18-29CL1_TPH 18-29CL1_BHL Map Date: 5/2/2024 Prudhoe Bay Unit 18-29CL1 Well wp02 0 1,500 3,000 Feet Legend 18-29CL1_SHL 18-29CL1_TPH $)18-29CL1_BHL 18-29CL1_Well Track $)Other Bottom Holes (BHL) Other Well Paths Pad Footprint PA Boundary CO_341J AIO_4G Document Path: O:\AWS\GIS\Products\Alaska\NS\Wells\TRS_Distance\mxds\2024\NorthSlope_18-29CL1_wp02.mxd$) South(-)/North(+) (1000 usft/in)6500 7000 7500 8000 8500900095001000088008964L3-15True Vertical Depth (100 usft/in)6200 6400 6600 6800 7000 7200 7400 7600 7800 8000 8200 8400 8600 8800 9000 920094009600980010000 Well 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 2.0" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip 9.54 ft CL 2.0" 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 3.0" Pipe / Slip HF nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee 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. 224-044 PRUDHOE BAY PBU 18-29CL1 PRUDHOE OIL 029-22316-03-00209-055 WELL PERMIT CHECKLISTCompanyHilcorp North Slope, LLCWell Name:PRUDHOE BAY UNIT 18-29CL1Initial Class/TypeDEV / PENDGeoArea890Unit11650On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2240440PRUDHOE BAY, PRUDHOE OIL - 640150NA1 Permit fee attachedYes ADL028307 and ADL0283212 Lease number appropriateYes PBU 18-29CL13 Unique well name and numberYes PRUDHOE BAY, PRUDHOE OIL - 640150 - governed by 341J4 Well located in a defined poolYes 33,700'5 Well located proper distance from drilling unit boundaryNA6 Well located proper distance from other wellsYes 5,040 acres7 Sufficient acreage available in drilling unitYes8 If deviated, is wellbore plat includedYes9 Operator only affected partyYes 10720534410 Operator has appropriate bond in forceYes11 Permit can be issued without conservation orderYes12 Permit can be issued without administrative approvalYes13 Can permit be approved before 15-day waitNA14Well located within area and strata authorized by Injection Order # (put IO# in comments) (For servNA15 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)Yes This well is a in zone CTD sidetrack from an existing wellbore with pressure integrity.18 Conductor string providedYes All drilling on this sidetrack will below existing surface casing shoe.19 Surface casing protects all known USDWsYes This well is a in zone CTD sidetrack from an existing wellbore with pressure integrity.20 CMT vol adequate to circulate on conductor & surf csgYes This well is a in zone CTD sidetrack from an existing wellbore with pressure integrity.21 CMT vol adequate to tie-in long string to surf csgYes Fully cemented production liner. Parent well isolates the reservoir.22 CMT will cover all known productive horizonsYes This well is a in zone CTD sidetrack from an existing wellbore with pressure integrity.23 Casing designs adequate for C, T, B & permafrostYes CDR2 has adequate tankage and good trucking support.24 Adequate tankage or reserve pitNA This is an additional lateral25 If a re-drill, has a 10-403 for abandonment been approvedYes Halliburton collision scan shows manageable collision risk.26 Adequate wellbore separation proposedNA All drilling below the surface casing shoe. No diverter required.27 If diverter required, does it meet regulationsYes MPD but reservoir pressure below water gradient.28 Drilling fluid program schematic & equip list adequateYes CT Packoff, flow cross, annular, blind shear, CT pipe slips, flow cross, BHA pipe slips, CT pipe slips29 BOPEs, do they meet regulationYes 7-1/16" 5000 psi stack pressure tested to 3500 psi.30 BOPE press rating appropriate; test to (put psig in comments)Yes Flanged choke and kill lines between dual combi's w remote choke31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownYes DS 18 is an H2S pad. Monitors required.33 Is presence of H2S gas probableNA This is a development well.34 Mechanical condition of wells within AOR verified (For service well only)No Measures required. Reading of 10ppm at this well (18-29C) in 2019.35 Permit can be issued w/o hydrogen sulfide measuresYes Expected reservoir pressure is 7.3 ppg EMW. MPD + 8.6 ppg mud to maintain 9.8 ppg EMW.36 Data presented on potential overpressure zonesNA37 Seismic analysis of shallow gas zonesNA38 Seabed condition survey (if off-shore)NA39 Contact name/phone for weekly progress reports [exploratory only]ApprADDDate14-May-24ApprMGRDate10-May-24ApprADDDate13-May-24AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateTwo fault crossings anticipated.JLC 5/15/2024
