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224-069
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: 09/26/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: PBU L2-29B PTD: 224-069 API: 50-029-21505-02-00 FINAL LWD FORMATION EVALUATION LOGS (08/19/2024 to 08/23/2024) Multiple Propagation Resistivity & Gamma Ray (2” & 5” MD/TVD Color Logs) Pressure While Drilling (PWD) Final Definitive Directional Surveys SFTP Transfer - Data Main Folders: Please include current contact information if different from above. 224-069 T39591 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.27 08:05:36 -08'00' Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Monty M. Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK, 99503 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU L2-29B Hilcorp Alaska, LLC Permit to Drill Number: 224-069 Surface Location: 1961' FSL, 1010' FWL, Sec 18, T11N, R15E, UM, AK Bottomhole Location: 566' FSL, 637' FWL, Sec 07, T11N, R15E, UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for 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 June 2024. Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2024.06.21 09:16:31 -08'00' 21st Drilling Manager 05/22/24 Monty M Myers By Grace Christianson at 8:45 am, May 23, 2024 A.Dewhurst 20JUN24 DSR-5/23/24MGR10JUN2024 * BOPE test to 3500 psi. * Service coil perforating approved with open hole deployment of perforating guns not to exceed 500' in length. 50-029-21505-02-00224-069 *&:JLC 6/21/2024 Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2024.06.21 09:17:09 -08'00' 06/21/24 06/21/24 x JSB RBDMS JSB 062424 To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz Drilling Engineer Date: May 22, 2024 Re:L2-29B Permit to Drill Approval is requested for drilling a CTD sidetrack lateral from well L2-29A with the Nabors CDR3 Coiled Tubing Drilling. Proposed plan for L2-29B Producer: See L2-29A Sundry request for complete pre-rig details - Prior to drilling activities, coil will drill out the CIBP at 9316' and perform a whipstock drift to planned setting depth. A coil tubing drilling sidetrack will be drilled with the Nabors CDR3 rig. The rig will move in, test BOPE and kill the well. The rig will set the 3-1/4" packer whipstock. A single string 2.74" window + 10' of formation will be milled. The well will kick off drilling in the Ivishak Zone 1 and continue in Zone 1 to TD. The proposed sidetrack will be completed with a 2-3/8” 13Cr solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). 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 L2-29A Sundry submitted in concert with this request for full details. 1. Slickline : Dummy GLVs, MIT 2. Coil : Mill CIBP, Drift for Whipstock, GR/CCL/Caliper 3. Valve Shop : Pre-CTD Tree Work 4. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in August 2024) 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 3-1/4" Packer Whipstock at 10450' @ 80 deg RHOS. Mill 2.74” Window. 3. Drill production lateral: 3.25" OH, ~2280' (12 deg DLS planned). 4. Run 2-3/8” 13Cr liner to TD with BSELRT and 3.70" Deployment sleeve. 5. Pump primary cement job: 13.5 bbls, 15.3 ppg Class G, TOC at 10950’ MD(500’ outside of window) 6. Only if not able to do with service coil extended perf post rig – Perforate Liner 7. Freeze protect well to a min 2,200' TVD. 8. 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 perforate (~1000’). 4. Testing : Portable test separator flowback. Sundry 324-304 PTD 224-069 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 (10450' MD -8,675' TVD) Pumps On Pumps Oī A Target BHP at Window (ppg)4,421 psi 4,421 psi 9.8 B ŶŶƵůĂƌĨƌŝĐƟŽŶ- ;ƉƐŝͬŌͿ 366 psi 0 psi 0.09 C DƵĚ,LJĚƌŽƐƚĂƟĐ;ƉƉŐͿ 3,879 psi 3,879 psi 8.6 B+C Mud + ECD Combined 4,245 psi 3,879 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain 176 psi 541 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 Give AOGCC 24hr notice prior to BOPE test (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 3.25" (2.74" pass) hole for the entirety of the production hole section. Liner Program: x 2-3/8", 4.6#, 13Cr Solid: 9,050' MD – 12,730' MD (3,680' 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 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. Directional: x Directional plan attached. Maximum planned hole angle is 92°. Inclination at kick off point is 88°. x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. x Distance to nearest property line – 26,300 ft x Distance to nearest well within pool – 980 ft 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 1000' perforated post rig – See attached extended perforating procedure. x 1.56 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. x Top of Ivishak MD in the parent wellbore: 9151’ MD Anti-Collision Failures: x No anti-collision issues with L2-29B Hazards: x L2 is an H2S pad. The last H2S reading on L2-29A: 30 ppm on 05/26/2019. x Max H2S recorded on DS/Pad: 110 ppm. x 2 fault crossings expected. x Medium lost circulation risk. Ryan Ciolkosz CC: Well File Drilling Engineer Joseph Lastufka (907-244-4357) p Top of Ivishak MD in the parent wellbore: 9151’ MD The last H2S reading on L2-29A: 30 ppm on 05/26/2019. 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 $) $) $) !!! !!!! !! !!!! ! !! !!!!! !! ! !!!!! ! !! ! D $)PLAN: L2-29B_BHL PLAN: L2-29B_TPH PLAN: L2-29B_SHL ADL028307 ADL028321 ADL028302 ADL034632 DSL2 U011N014E U011N015E Sec. 13 Sec. 18 (599) Sec. 12 Sec. 7 (596) Prudhoe Bay Unit 18-18 18-26B 18-18A Map Date: 5/22/2024 Prudhoe Bay Unit L2-29B Well wp03 E0280560 Feet Legend $)PLAN: L2-29B_BHL !PLAN: L2-29B_SHL D PLAN: L2-29B_TPH $)Other Bottom Holes (BHL) Other Well Paths Pad Footprint CO_341J AIO_4G Document Path: O:\AWS\GIS\Products\Alaska\NS\Wells\TRS_Distance\mxds\2024\NorthSlope_L2-29B wp03.mxd 1500200025003000350040004500South(-)/North(+) (1000 usft/in)-2500 -2000 -1500 -1000 -500 0 500 1000 1500 West(-)/East(+) (1000 usft/in)7200760080008400880092009441L2-298655L2-29A48005200L2-268689L2-11PB2L2-1144004800520056006000L2-304000L2-28PB 1480052005600600064006800720076008000L2-33L2-32800084008696L2-11PB144004800520056006000L2-0780008400865 618-02C P B118-02C 18-18APB1869018-18BPB1871018-18868018-18A18-18B1 8-2 6B8672L2-29B wp03Top of Window - 10450'MDTD - 12730'MD85008550860086508700True Vertical Depth (100 usft/in)0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 Vertical Section at 35.00° (400 usft/in)L2-29L2-29AL2-29B wp03Top of Window - 10450'MDTD - 12730'MDSecMD Inc AziTVD+N/-S+E/-W Dleg TFaceVSect1 10450.00 87.94 62.57 8675.18 2450.11 -1490.76 0.00 0.00 1151.952 10470.00 88.26 64.35 8675.85 2459.04 -1472.88 9.00 80.00 1169.523 10540.00 89.73 72.62 8677.08 2484.69 -1407.82 12.00 80.00 1227.844 10680.00 88.87 89.40 8678.81 2506.49 -1270.05 12.00 93.00 1324.735 10825.00 89.22 106.80 8681.23 2486.15 -1127.07 12.00 89.00 1390.076 10965.00 90.41 90.04 8681.68 2465.73 -989.07 12.00 -86.00 1452.507 11105.00 90.39 73.24 8680.69 2486.01 -851.06 12.00 -90.00 1548.278 11265.00 90.04 54.04 8680.08 2556.72 -708.37 12.00 -91.00 1688.049 11465.00 90.65 30.05 8678.85 2704.16 -575.40 12.00 -88.50 1885.0810 11610.00 90.47 47.45 8677.42 2816.80 -485.00 12.00 90.50 2029.2111 11790.00 90.44 25.85 8675.98 2960.36 -378.20 12.00 -90.00 2208.0612 11930.00 91.57 9.08 8673.51 3093.41 -336.33 12.00 -86.00 2341.0613 12085.00 91.01 350.49 8669.98 3247.69 -336.91 12.00 -91.50 2467.1014 12265.00 90.21 12.07 8668.04 3426.57 -332.91 12.00 92.00 2615.9315 12385.00 89.39 357.70 8668.46 3545.82 -322.72 12.00 -93.25 2719.4616 12525.00 89.42 340.90 8669.93 3682.88 -348.63 12.00 -90.00 2816.8717 12730.00 89.47 5.50 8671.95 3884.87 -372.73 12.00 90.00 2968.51Project: LisburneSite: L2Well: L2-29Wellbore: PLAN: L2-29BPlan: L2-29B wp03WELLBORE DETAILSParent Wellbore:L2-29ATop of Window: 10450.00L2-29B wp03Depth From Depth To Survey/Plan Tool60.00 3993.95 1 : Schlumberger GCT multishot (L2-29PB1) 3_Gyro-CT_pre-1998_Csg14006.85 9312.50 1 : Schlumberger GCT multishot (L2-29) 3_Gyro-CT_pre-1998_Csg19328.00 10450.00 BHGE CTK MWD 4-1/2" (L2-29A) 3_MWD10450.00 12730.00 L2-29B wp03 (PLAN: L2-29B) 3_MWDWELL DETAILSNorthing: 5963854.62Easting: 692695.43Lattitude: 70° 18' 20.6091 NLongitude: 148° 26' 19.6864 WL2-29B wp03SECTION DETAILSHilcorp Alaska, LLCSURVEY PROGRAMNAD 1927 (NADCON CONUS)US State Plane 1927 (Exact solution)Alaska Zone 04PROJECT DETAILSREFERENCE INFORMATIONCoordinate(N/E) Reference: Well L2-29, True NorthVertical (TVD) Reference: KB @ 52.00usft (L2-29 OKB)Measured Depth Reference: KB @ 52.00usft (L2-29 OKB)Section (VS) Reference: Slot - (0.00N, 0.00E)Calculation Method: Minimum CurvatureREFERENCE INFORMATION ! 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Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2.0" Pipe / Slips B3 B4 B1 B2 Choke Line CL 2-3/8" Pipe / Slip CL 2.0" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2.0" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2.0" Pipe/Slips 2-3/8" Pipe / Slip HF 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. PRUDHOE OIL PRUDHOE BAY PBU L2-29B 224-069 WELL PERMIT CHECKLISTCompanyHilcorp North Slope, LLCWell Name:PRUDHOE BAY UN LIS L2-29BInitial Class/TypeDEV / PENDGeoArea890Unit11650On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2240690PRUDHOE BAY, PRUDHOE OIL - 640150NA1 Permit fee attachedYes ADL028321, ADL028307, and ADL0346322 Lease number appropriateYes3 Unique well name and numberYes PRUDHOE BAY, PRUDHOE OIL - 640150 - governed by 341J4 Well located in a defined poolYes5 Well located proper distance from drilling unit boundaryNA6 Well located proper distance from other wellsYes7 Sufficient acreage available in drilling unitYes8 If deviated, is wellbore plat includedYes9 Operator only affected partyYes10 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 waitNA14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (ForNA15 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 This well is a in zone CTD sidetrack from an existing wellbore with pressure integrity.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 csgYes21 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 well. Full integrity above sidetrack.23 Casing designs adequate for C, T, B & permafrostYes CDR3 has adequate tankage and good trucking support.24 Adequate tankage or reserve pitYes Sundry 324-30425 If a re-drill, has a 10-403 for abandonment been approvedYes Halliburton collision scan shows manageable collision risk.26 Adequate wellbore separation proposedYes 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 PBU S-pad is an H2S pad >100 ppm. Monitoring will be required.33 Is presence of H2S gas probableNA34 Mechanical condition of wells within AOR verified (For service well only)No L2 is an H2S pad. The last H2S reading on L2-29A: 30 ppm on 05/2019.35 Permit can be issued w/o hydrogen sulfide measuresYes Anticipated pore pressure of 7.2 ppg EMW. MPD with 8.6 ppg mud to maintain ECD of 9.8 ppg36 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]ApprADDDate6/20/2024ApprMGRDate6/10/2024ApprADDDate6/19/2024AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate*&:JLC 6/21/2024
