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Home My WebLink About221-0431 Guhl, Meredith D (OGC) From:Guhl, Meredith D (OGC) Sent:Tuesday, August 22, 2023 8:34 AM To:Monty Myers Cc:Joseph Lastufka Subject:MPU L-06AL1, PTD 221-043, Permit Expired Hello Monty, Permit 221‐043 for MPU L‐06AL1, issued on May 20, 2021, has expired under RegulaƟon 20 AAC 25.005 (g). The PTD will be marked expired in the AOGCC database. Thank you, Meredith Meredith Guhl (she/her) Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793‐1235 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 Meredith Guhl at 907‐793‐1235 or meredith.guhl@alaska.gov. 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, Inc. 3800 Centerpoint Drive, Suite 400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk Oil Pool, MPU L-06AL1 Hilcorp Alaska, LLC Permit to Drill Number: 221-043 Surface Location: 2119' FNL, 318' FWL, Sec. 08, T13N, R10E, UM, AK Bottomhole Location: 1277' FSL, 203' FWL, Sec. 04, T13N, R10E, UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jeremy M. Price Chair DATED this ___ day of May, 2021. Jeremy Price Digitally signed by Jeremy Price Date: 2021.05.20 13:44:26 -08'00' 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name: 5. Bond: Blanket Single Well 11. Well Name and Number: Bond No. 3. Address:6. Proposed Depth:12. Field/Pool(s): MD: 12,200' TVD: 7,138' 4a. Location of Well (Governmental Section): 7.Property Designation: Surface: Top of Productive Horizon:8.DNR Approval Number:13.Approximate Spud Date: Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10.KB Elevation above MSL (ft): 56.0'15.Distance to Nearest Well Open Surface: x-544920 y- 6031351 Zone-4 17.0' to Same Pool: 1,730' 16.Deviated wells: Kickoff depth: 11,621 feet 17.Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 97 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 4-1/2" 3-1/4" 6.6# L-80 TCII 870' 10,430' 11,300' 6,869' 7,104' 3" 2-3/8" 6.5# L-80 STL/Hyd511 1,780' 10,420' 12,200' 6,863' 7,138' 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): None TVD 115' 4,590' 7,002' 6,869' - 7,104' 6,863' - 7,410' ~11,621' - 12,121' ~7,156' - 7,410' Hydraulic Fracture planned? Yes No 20. Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements Contact Name: Trevor Hyatt Monty Myers Contact Email:trevor.hyatt@hilcorp.com Drilling Manager Contact Phone:777-8396 Date: Permit to Drill API Number: Permit Approval Number:Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 10,420' - 12,121' 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Surface Perforation Depth TVD (ft): GL / BF Elevation above MSL (ft): Perforation Depth MD (ft): 6,314' 485 sx Permafrost 'C' 115' 6,314'9-5/8" 316 Bbls PF 'E', 67 Bbls Class 'G' Effect. Depth MD (ft): Effect. Depth TVD (ft): Authorized Title: Authorized Signature: 2-3/8" 10,567' Uncemented Solid Liner Uncemented Solid / Slotted Liner Liner Liner 10,567' ~870' ~1,701' Intermediate Authorized Name: Conductor/Structural 13-3/8"80' ~12,121'~7,410' LengthCasing None STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 3333 2127' FSL, 926' FWL, Sec. 04, T13N, R10E, UM, AK 1277' FSL, 203' FWL, Sec. 04, T13N, R10E, UM, AK 88-002 3800 Centerpoint Drive, Suite 400, Anchorage, AK 99503 Hilcorp Alaska, LLC 2119' FNL, 318' FWL, Sec. 08, T13N, R10E, UM, AK ADL 025509 & 047434 5093 18.Casing Program: Top - Setting Depth - Bottom 3-1/4" 7" Total Depth MD (ft): Total Depth TVD (ft): 022224484 Specifications 4033 Cement Volume MDSize Plugs (measured): (including stage data) Uncemented Solid Liner Uncemented Solid / Slotted Liner ~12,121' ~7,410' May 25, 2021 50-029-22003-60-00 10,830' MPU L-06AL1 Milne Point Field Kuparuk Oil Pool Cement Quantity, c.f. or sacks Commission Use Only See cover letter for other requirements. 65 Bbls Class 'G' 10,430' - 11,300' ooo oo oo oo Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) 5.18.2021 By Samantha Carlisle at 3:33 pm, May 18, 2021 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2021.05.18 14:20:08 -08'00' Monty M Myers MGR19MAY2021 BOPE test to 3500 psi. Annular to 3500 psi. DSR-5/18/21 221-043 SFD 5/19/2021 dts 5/19/2021 JLC 5/20/2021 5/20/21 Jeremy Price Digitally signed by Jeremy Price Date: 2021.05.20 13:44:46 -08'00' To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: May 18, 2021 Re: MPU L-06A & AL1 Permit to Drill Request Approval is requested for drilling a CTD sidetrack lateral from well MPU L-06 with the Nabors CDR2 Coiled Tubing Drilling rig on or around May 2021. Proposed plan for MPU L-06A & AL1 Producer: Prior to drilling activities, the wellbore will be prepared for a sidetrack (see L-06 Sundry request). The 2-7/8” kill string has been pulled, cement milled, and a 4-1/2” production string run. An E-line unit will set a 4-1/2” x 7” CTD whipstock in the Kuparuk interval. A ~2,133’ MD coil tubing drilling, dual lateral, sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. A single string window exit + 10’ of rathole will be milled out of the 7”. The first lateral (L-06A) will kick off in the Kuparuk C, build through the B and land in the A to cross a major fault into the Kuparuk C to the south. If determined necessary (problematic shales open), intermediate TD will be called once confirmed in the Kuparuk C sand and a 3-1/2” x 3-1/4” solid protection liner will be run. The rig will downsize from 2-3/8” to 2” coil and mill out the bottom shoe of the protection string. The well will then continue in this new fault block down into the Kuparuk A to TD. The lateral will then be completed with 2-3/8" L-80 slotted liner with a liner top billet set in the C sand. The second lateral (L-06AL1) will then kick off the liner top billet and drill a lateral in the Kuparuk C to the south. The lateral will then be completed with a 2-3/8” L-80 solid/slotted liner from liner top to TD. If it is determined that problematic shale is not crossed at the fault crossing, the two laterals will be drilled as originally planned bighole (2-3/8” coil) 4.06” - 4.25” hole and 2-7/8” solid/slotted liner ran in both laterals. The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is attached for reference. Pre-Rig Work: 1. Reference MPU L-06 Sundry submitted in concert with this PTD request 2. General work scope of Pre-Rig work: a. Rig: Pull kill string b. Rig: Mill cement and retainer to 10,600’ MD c. Rig: Run 4-1/2” production string d. E-line: Set 4-1/2” x 7” whipstock top at ~10,562’ MD, 25 deg ROHS Rig Work: 3. MIRU and test BOPE to 3500 psi. MASP with gas (0.10 psi/ft) to surface is 3333 psi a. Give AOGCC 24hr notice prior to BOPE test b. Test against swab and master valves (No TWC) c. Load pits with drilling fluid d. Open well and ensure zero pressure 4. Mill 3.80” single string window (out of 7”) plus 10’ of rathole. a. Top of planned window (whipstock pinch point) at 10567’, 25 ROHS. b. Mill window with 0.6° bend motor c. Pressure deployment is required for the window milling run i. SBHPS 04/10/12 4,033 psi at 7,001’ TVD (11.1 ppg EMW) d. Hold 11.8 ppg MPD while milling window (L-06AL1) lateral inp the Kuparuk C to the south. PTD 221-011 5. Drill L-06A Build – Protection String Section a. 3” BHA with GR/RES / Bi-center Bit (4.06” - 4.25”) b. 40° DLS build section – 437’ MD / Planned TD 11,004’ MD c. 12° DLS lateral section – 296’ MD / Planned TD 11,300’ MD (past fault) d. Drill through Kuparuk C, B, A and land in C sand on other side of fault e. Drill with a constant bottom hole pressure for entire sidetrack f. Pressure deployment will be utilized g. After TD and on the last trip out of hole lay in completion/kill weight fluid in preparation for liner run h. No flow test prior to laying down drilling BHA i. If determined no problematic shale crossed at fault, continue to L-06A TD (12,120’ MD) with bighole and don’t run protection string. Then go to step 14. 6. Run 3-1/4” L-80 solid liner (protection string) with bullnose shoe a. Top of liner left inside 4-1/2” tubing b. Have 2-3/8” safety joint with TIW valve ready to be picked up while running liner 7. Swap equipment and reel from 2-3/8” to 2” coil 8. Test BOPE 250 psi low and 3,500 psi high for rams / 3,500 psi high for annular (MASP of 3,333 psi) a. Provide 24-hour notice to AOGCC to witness b. Test against swab and master valves (No TWC) 9. Mill out 3-1/4” shoe with 2.74” Mill + 10’ of rathole 10. Drill – First Lateral (L-06A) a. 2-3/8” BHA with GR/RES / Bi-center Bit (3”) b. 12° DLS lateral section – 821’ MD / Planned TD 12,121’ MD c. Drill with a constant bottom hole pressure for entire sidetrack d. Pressure deployment will be utilized e. After TD and on the last trip out of hole lay in completion/kill weight fluid in preparation for liner run f. No flow test prior to laying down drilling BHA 11. Run 2-3/8” L-80 solid/slotted liner (L-06A) a. Have 2-3/8” safety joint with TIW valve ready to be picked up while running liner b. Liner top billet (top of liner to be ~11,621’ MD) c. Liner may be run in two sections if weight transfer or hole conditions is poor 12. Drill – Second Lateral (L-06AL1) a. 2-3/8” BHA with GR/RES / Bi-center Bit (3”) b. 12° DLS lateral section – 579’ MD / Planned TD 12,200’ MD c. Drill with a constant bottom hole pressure for entire sidetrack d. Pressure deployment will be utilized e. After TD and on the last trip out of hole lay in completion/kill weight fluid in preparation for liner run f. No flow test prior to laying down drilling BHA 13. Run 2-3/8” L-80 solid/slotted liner (L-06AL1) a. Have 2-3/8” safety joint with TIW valve ready to be picked up while running liner b. Liner may be run in two sections if weight transfer or hole conditions is poor c. After releasing from the liner swap the well over to 2% KCl d. Freeze protect well from ~2200’ MD (min) e. RDMO 14. ***If no problematic shale is crossed at fault continue with lateral on bighole as follows. 15. Run 2-7/8” L-80 slotted liner (L-06A) a. Have 2-3/8” safety joint with TIW valve ready to be picked up while running liner b. Liner top billet (top of liner to be ~11,621’ MD) c. Liner may be run in two sections if weight transfer or hole conditions is poor PTD 221-043 PTD 221-011 – Second Lateral (L-06AL1) PTD 221-011 16. Drill – Second Lateral (L-06AL1) a. 3” BHA with GR/RES / Bi-center Bit (4.06” - 4.25”) b. 12° DLS lateral section – 579’ MD / Planned TD 12,200’ MD c. Drill with a constant bottom hole pressure for entire sidetrack d. Pressure deployment will be utilized e. After TD and on the last trip out of hole lay in completion/kill weight fluid in preparation for liner run f. No flow test prior to laying down drilling BHA 17. Run 2-7/8” L-80 solid/slotted liner (L-06AL1) a. Have 2-3/8” safety joint with TIW valve ready to be picked up while running liner b. Liner may be run in two sections if weight transfer or hole conditions is poor c. After releasing from the liner swap the well over to 2% KCl d. Freeze protect well from ~2200’ MD (min) e. RDMO Post Rig: 1. V: Tree work as necessary 2. S: Install LTP Managed Pressure Drilling: The history of CTD at KRU in the Kuparuk reservoir, has demonstrated the benefits of a managed pressure drilling technique. Due to uncertainties about the bottom hole pressures to be encountered as this sidetrack is drilled, managed pressure drilling techniques will be employed on this well. The intent is to provide constant bottom hole pressure by using minimum 8.7 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow use of lighter drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A MPD choke for regulating surface pressure is located between the WC choke manifold and the mud pits and will be independent of the WC choke. Deployment of the BHA under trapped wellhead pressure will be necessary. Pressure deployment of the BHA will be accomplished utilizing 3” (bighole) & 2-3/8” (slimhole) pipe/slip rams (see attached BOP configurations). The annular preventer will act as a secondary containment during deployment and not as a stripper. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected for MPL-06A & AL1: x Latest reservoir pressure in the parent well: 4033 psi (11.1 ppg) MPD Pressure at the MPU L-06 Planned Window (10562’ MD - 7001’ TVD) Pumps On Pumps Off A Target BHP at Window (ppg)4,296 psi 4,296 psi 11.8 B Annular friction - ECD (psi/ft)634 psi 0 psi 0.06 (slimhole) C Mud Hydrostatic (ppg)3,167 psi 3,167 psi 8.7 B+C 3,801 psi 3,167 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain 495 psi 1,129 psi Target BHP at window and deeper ggp Latest reservoir pressure in the parent well: 4033 psi (11.1 ppg) qp managed pressure drilling techniques will be employed on this well. minimum 8.7 ppg drilling fluid gq py PTD 221-043 Operation Details: Reservoir Pressure: x The maximum reservoir pressure for L-06A & AL1 is expected to be 4033 psi at 7001’ TVD (11.1 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 3333 psi. Mud Program: x Drilling: Minimum MW of 8.6 ppg KCL with Geovis for drilling. Managed pressure used to maintain constant BHP. x KWF will be stored on location. The tankage will contain 1.5 wellbore volumes of KWF (11.3 ppg expected) to exceed the maximum possible BHP to be encountered as the lateral is drilled. Adjust with real time BHP monitoring. x Completion: A minimum MW 11.3 ppg KWF to be used for liner deployment. Will target 11.8 ppg to match managed pressure target. Disposal: x All cuttings & mud generated during drilling operations will be hauled to the Milne Point “B” pad G&I facility. Hole Size: x 4.06” - 4.25” bicenter hole for build and lateral to cross fault (potential to drill both laterals with this size if no protection string is ran). x 3” bicenter hole after 3-1/4” protection string is ran across fault. Liner Program: Protection String and downsize to 2” coil (slimhole) scenario L-06A x 3-1/4” 6.6#, L-80 solid liner: 10,430’ MD – 11,300’ MD x 2-3/8”, 6.5#, L-80 slotted liner: 11,621’ MD – 12,121’ MD L-06AL1 x 2-3/8”, 6.5#, L-80 solid liner: 10,420’ MD – 11,550’ MD x 2-3/8”, 6.5#, L-80 slotted liner: 11,550’ MD – 12,200’ MD No Protection String and stay on 2-3/8” coil (bighole) scenario L-06A x 2-7/8”, 6.5#, L-80 slotted liner: 11,621’ MD – 12,121’ MD L-06AL1 x 2-7/8”, 6.5#, L-80 solid liner: 10,420’ MD – 11,550’ MD x 2-7/8”, 6.5#, L-80 slotted liner: 11,550’ MD – 12,200’ MD x No Cement. A liner top packer will be run post rig to facilitate production from the new fault block. 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 Two BOP diagrams are attached. MPD and pressure deployment is planned. x Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. x The annular preventer will be tested to 250 psi and 3,500 psi. x An X-over shall be made up to a 2-3/8” safety joint including a TIW valve for all tubulars ran in hole. x 1.5 wellbore volumes of KWF will be on location at all times during drilling operations. x Exemption request to 20 AAC 25.036 - Liner rams in the BOPE. A 2-3/8” safety joint will be utilized while running 2-3/8” slotted liner, 3-1/4” solid liner (protection string) or 2-7/8” solid/slotted liner (no protection string scenario). The desire is to keep the same standing orders for the entire liner run and not change shut in techniques (run safety joint with pre-installed TIW valve). When closing on a 2-3/8” safety joint 2 sets of 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 97° x Inclination at kick off point is 56°. x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. x Distance to nearest property line – 10,612’ x Distance to nearest well within pool – 1,675’ (C-17) 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 No perforating, slotted liner. Anti-Collision Failures: x No failures for L-06A or AL1 Hazards: x MPU L-pad is considered a high H2S pad. The highest recorded H2S well on the pad was from MPU L-32 (410 ppm) in 2009. The maximum recorded value on L-06 is 3 ppm (12/17/2009). Drilling L-06A into a new fault block has a low H2S risk. x Fault crossing. Potential to go from an 11.1 ppg EMW to 8.5 ppg EWM. Use mud viscosity to mitigate differential sticking and losses. x Medium lost circulation risk. Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka 907-223-3087 Potential to go from an 11.1 ppg EMW to 8.5 ppg EWM. MPU L-pad is considered a high H2S pad. 6WDQGDUG3URSRVDO5HSRUW 0D\ 3ODQ038/$/ZS +LOFRUS$ODVND//& 0LOQH3RLQW 03W/3DG 03/ 038/$/ 6667683370007167733375007667True Vertical Depth (250 usft/in)5667 5833 6000 616763336500 6667 6833 7000 7167 7333 7500 7667 7833Vertical Section at 56.60° (250 usft/in)MPU L-06A-L1 wp06 Polygon10000105001100011091MPL-061 1 00 0 115001200012121MPU L-06A wp061200012200MPU L-06AL1 wp06KOP : Start Dir 12º/100' : 11621' MD, 7156.41'TVD : 20° LT TFTotal Depth : 12200' MD, 7137.6' TVDWELL DETAILS: MPL-06 NAD 1927 (NADCON CONUS) Alaska Zone 04Ground Level:17.00+N/-S +E/-W Northing EastingLatittude Longitude0.00 0.006031350.910544919.97070° 29' 47.468 N149° 37' 57.645 WCASING DETAILSTVD TVDSSMD SizeName7137.607081.6012200.00 2-3/82 3/8" x 4 1/2"FORMATION TOP DETAILSNo formation data is availableProject: Milne PointSite: M Pt L PadWell: MPL-06Wellbore: MPU L-06AL1Design: MPU L-06AL1 wp06SECTION DETAILSSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation1 11621.00 87.93 234.94 7156.41 3707.06 5639.37 0.00 0.00 6748.68 KOP : Start Dir 12º/100' : 11621' MD, 7156.41'TVD : 20° LT TF2 11696.00 96.38 231.85 7153.59 3662.42 5579.26 12.00 -20.00 6673.933 11771.00 95.52 240.86 7145.79 3621.14 5517.23 12.00 95.00 6599.414 11846.00 91.68 232.70 7141.08 3580.17 5454.68 12.00 -115.00 6524.645 11971.00 90.33 247.65 7138.88 3518.19 5346.56 12.00 95.00 6400.266 12111.00 90.31 230.85 7138.09 3446.85 5226.68 12.00 -90.00 6260.917 12200.00 90.31 241.53 7137.60 3397.40 5152.84 12.00 90.00 6172.04 Total Depth : 12200' MD, 7137.6' TVDSURVEY PROGRAMDate: 2021-05-18T00:00:00 Validated: Yes Version: Depth FromDepth To Survey/PlanTool100.00 10567.00 1 : Schlumberger GCT multishot (MPL-06) 3_Gyro-CT_pre-1998_Csg10567.00 11621.00 MPU L-06A wp06 (MPU L-06A) 3_MWD11621.00 12200.00 MPU L-06AL1 wp06 (MPU L-06AL1) 3_MWD 330033503400345035003550360036503700375038003850390039504000South(-)/North(+) (100 usft/in)4900 4950 5000 5050 5100 5150 5200 5250 5300 5350 5400 5450 5500 5550 5600 5650 5700 5750 5800 5850West(-)/East(+) (100 usft/in)MPU L-06A-L1 wp06 Polygon625 06500MPL-0 6 7 2 5 0 7 4 1 0 M P U L -0 6 A w p 0 6 2 3/8" x 4 1/2"7 1 3 8 M P U L -0 6 A L 1 w p 0 6KOP : Start Dir 12º/100' : 11621' MD, 7156.41'TVD : 20° LT TFTotal Depth : 12200' MD, 7137.6' TVDCASING DETAILSTVDTVDSS MDSize Name7137.60 7081.60 12200.00 2-3/8 2 3/8" x 4 1/2"Project: Milne PointSite: M Pt L PadWell: MPL-06Wellbore: MPU L-06AL1Plan: MPU L-06AL1 wp06WELL DETAILS: MPL-06Ground Level: 17.00+N/-S +E/-W Northing EastingLatittudeLongitude0.00 0.006031350.910544919.970 70° 29' 47.468 N149° 37' 57.645 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well MPL-06, True NorthVertical (TVD) Reference: MPL-06 Ref Elevation @ 56.00usftMeasured Depth Reference:MPL-06 Ref Elevation @ 56.00usftCalculation Method:Minimum Curvature 3URMHFW &RPSDQ\ /RFDO&RRUGLQDWH5HIHUHQFH 79'5HIHUHQFH 6LWH +LOFRUS$ODVND//& 0LOQH3RLQW 03W/3DG 6WDQGDUG3URSRVDO5HSRUW :HOO :HOOERUH 03/ 038/$/ 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'LVWDQFH%HWZHHQ3URILOHV'LVWDQFH%HWZHHQ3URILOHV(OOLSVH6HSDUDWLRQ'LVWDQFH%HWZHHQFHQWUHVLVWKHVWUDLJKWOLQHGLVWDQFHEHWZHHQZHOOERUHFHQWUHV$OOVWDWLRQFRRUGLQDWHVZHUHFDOFXODWHGXVLQJWKH0LQLPXP&XUYDWXUHPHWKRG0D\ &203$663DJHRI 0.001.002.003.004.00Separation Factor11635 11668 11700 11733 11765 11798 11830 11863 11895 11928 11960 11993 12025 12058 12090 12123 12155 12188 12220 12253Measured Depth (65 usft/in)MPC-17MPU L-06A wp06No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.WELL DETAILS:MPL-06 NAD 1927 (NADCON CONUS)Alaska Zone 04Ground Level: 17.00+N/-S +E/-W Northing Easting Latittude Longitude0.000.006031350.910544919.970 70° 29' 47.468 N149° 37' 57.645 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well MPL-06, True NorthVertical (TVD) Reference: MPL-06 Ref Elevation @ 56.00usftMeasured Depth Reference:MPL-06 Ref Elevation @ 56.00usftCalculation Method: Minimum CurvatureSURVEY PROGRAMDate: 2021-05-18T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool100.00 10567.00 1 : Schlumberger GCT multishot (MPL-06) 3_Gyro-CT_pre-1998_Csg10567.00 11621.00 MPU L-06A wp06 (MPU L-06A) 3_MWD11621.00 12200.00 MPU L-06AL1 wp06 (MPU L-06AL1) 3_MWD0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)11635 11668 11700 11733 11765 11798 11830 11863 11895 11928 11960 11993 12025 12058 12090 12123 12155 12188 12220 12253Measured Depth (65 usft/in)NO GLOBAL FILTER: Using user defined selection & filtering criteria11621.00 To 12200.00Project: Milne PointSite: M Pt L PadWell: MPL-06Wellbore: MPU L-06AL1Plan: MPU L-06AL1 wp06CASING DETAILSTVD TVDSS MD Size Name7137.60 7081.60 12200.00 2-3/8 2 3/8" x 4 1/2" _____________________________________________________________________________________ Revised By: JNL 5/18/2021 PROPOSED Milne Point Unit Well: MPU L-06A / AL1 Last Completed: TBD PTD: 211-011 / TBD L-06AL1 TD = 12,200’ (MD) / TD = 7,138’ (TVD) PBTD = 12,200’ (MD) / PBTD = 7,138’ (TVD)2-3/8” Solid to Slotted Liner @11,550’ AL1 Billet set @11,621’ GENERAL WELL INFO API: 50-029-22003-01-00 & 50-029-22003-60-00 Drilled and Completed by Pool Rig 102 - 11/27/1990 Pull ESP, set CIBP, Run Killstring by Doyon 16 - 5/21/2012 RWO Tubing Swap: 2/19/2021 A & AL1 Sidetrack: TBD TD =12,121’ (MD) /TD =7,410’(TVD) Halliburton HOS Cementer at 1,881’ Orig. KB Elev. = 56.0’ Ground Elev. = 17.0’ RKB-THF: 23.95’ (Doyon 16) 7” 3 5 7 2-7/8” Est. TOC at 8,820’ 9-5/8” Top of 3-1/4” Liner @10,430’ Est. TOC at 2,000’ 6 PBTD = 12,121’(MD) / PBTD=7,410’(TVD) Top of 2-3/8” Liner @10,420’ RA Tag at 10,304’ Arctic Pack Top of Window @10,567’ 4 2 1 ` CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 48# / H-40 / Weld 12.715 Surface 115' 0.157 9-5/8" Surface 36# / J-55 / BTC 8.921 Surface 6,314’ 0.0773 7" Production 26# / L-80 / BTC 6.276 Surface 10,567’ 0.0383 3-1/4” Solid Liner 6.6 # / L-80 / TCII 10,430’ 11,300’ A:2-3/8” Slotted Liner 6.5# / L-80 / Hyd511 11,621’ 12,121’ AL1:2-3/8” Solid/Slotted Liner 6.5# / L-80 / STL & Hyd511 10,420’ 12,200’ TUBING DETAIL 4-1/2” Tubing 12.6# / L-80 / TXP BTC 3.92 Surface 10,472’ 0.0152 JEWELRY DETAIL No Depth Item 1 31’ 4-1/2” Tubing Hanger 2 10,280’ Gauge Carrier 3 10,288’ HES X-line Sliding Sleeve, 3.813” Seal Bore ID 4 10,296’ Ported Pressure Sub 5 10,356’ 7” x 4-1/2” Premier Production Packer 6 10,425’ X Nipple, 3.813” 7 10,434’ WELG, bottom at 10,472’ SLOTTED LINER DETAIL KUP Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status L-06A: L-06AL1: OPEN HOLE / CEMENT DETAIL 30" 485 sks Permafrost “C” 12-1/4" 316 bbl Permafrost E, 67 bbl Class ‘G’ 8-1/2” 65 bbl Class “G” 4-1/4” Uncemented Solid Liner A: 3” Uncemented Solid / Slotted Liner AL1: 3” Uncemented Solid / Slotted Liner WELL INCLINATION DETAIL KOP @ 700’ Max Hole Angle = 57° @ 4,600’ Max Hole Angle through perforations = 55° A Top of Window @10,567 AL1 Top of Window @ 11,621’ Max Holengle through perforations = 55° TREE & WELLHEAD Tree 4-1/16” 5K CIW (dry hole) Wellhead FMC 11"x 4-1/2" Hanger, 4.5" TCII top/btm w/ 2- 3/8'' ports Well Bighole Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 6.0 ft Top of Annular Element 6.7 ft Bottom Annular 8.0 ft CL Blind/Shears 9.3 ft CL 2-3/8" Pipe/Slips 10.1 ft B1 B2 B3 B4 Choke Line Kill Line CL 3" Pipe/Slips 12.6 ft CL 2-3/8" Pipe/Slips 13.4 ft CL of Top Swab 16.0 ft Swab Test Pump Hose T1 T2 Swab 1 CL of Flow Cross 17.4 ft Master CL of Master 18.8 ft LDS IA OA LDS Ground Level CDR2-AC 4 Ram BOP Schematic 15-Jan-21 CDR2 Rig's Drip Pan 7-1/16" 5k Flange X 7" Otis Box Hydril 7 1/16" Annular 2-3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8"Pipe/Slips Blind/Shear 7-1/16" 5 Mud Cross 3" Pipe/Slips Well Slimhole Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 6.0 ft Top of Annular Element 6.7 ft Bottom Annular 8.0 ft CL Blind/Shears 9.3 ft CL 2" Pipe/Slips 10.1 ft B1 B2 B3 B4 Choke Line Kill Line CL 2-3/8" Pipe/Slips 12.6 ft CL 2" Pipe/Slips 13.4 ft CL of Top Swab 16.0 ft Swab Test Pump Hose T1 T2 Swab 1 CL of Flow Cross 17.4 ft Master CL of Master 18.8 ft LDS IA OA LDS Ground Level CDR2-AC 4 Ram BOP Schematic 21-Nov-17 CDR2 Rig's Drip Pan 7-1/16" 5k Flange X 7" Otis Box Hydril 7 1/16" Annular 2" Pipe/Slips 7-1/16" 5k Mud Cross 2" Pipe/Slips Blind/Shear 7-1/16" 5 Mud Cross 2-3/8" Pipe/Slips Revised 2/2015 TRANSMITTAL LETTER CHECKLIST WELL NAME: ______________________________________ PTD: _____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD: ____________________________ POOL: ______________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit No. _____________, API No. 50-_______________________. Production should continue to be reported as a function of the original API number stated above. Pilot Hole In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name (_______________________PH) and API number (50-_____________________) from records, data and logs acquired for well (name on permit). Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. (_____________________________) as Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for well ( ) until after ( ) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (________________________) must contact the AOGCC to obtain advance approval of such water well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (_______________________________) in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well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