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Home My WebLink About220-009From:Guhl, Meredith D (OGC) To:Taylor, Jenna; Conklin, Amy A; Hobbs, Greg S Subject:Expired CRU Permits Date:Wednesday, April 27, 2022 1:48:00 PM Hello, The following Permits to Drill, issued to ConocoPhillips Alaska, have expired under Regulation 20 AAC 25.005 (g). The PTDs will be marked expired in the AOGCC database. CRU CD5-11L1, PTD 220-008, Issued 27 January 2020 CRU CD5-11L1-01, PTD 220-009, Issued 27 January 2020 CRU CR4-215L1-01, PTD 220-022, Issued 6 March 2020 If you have any questions, please contact me. 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. Loepp, Victoria T (CED) From: Sent: To: Cc: Subject: Attachments: Follow Up Flag: Flag Status: Current CTD Schematic attached. Regards, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office:907-265-6218 Cell:907-444-7886 700 G St, ATO 670, Anchorage, AK 99501 McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Wednesday, February 19, 2020 11:16 AM Loepp, Victoria T (CED) Davies, Stephen F (CED) RE: [EXTERNAL]RE: CRU CD5-11L1,-L1-01(PTDs: 220-008, 220-009) CTD Operations Shutdown approval CD5-11 Current CTD Schematic.pdf Follow up Completed From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, February 19, 2020 9:41 AM To: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Cc: Davies, Stephen F (CED) <steve.davies@alaska.gov> Subject: [EXTERNAL]RE: CRU CD5-111-1,-L1-01(PTDs: 220-008, 220-009) CTD Operations Shutdown approval Ryan, Could you please send a WBS for the current status of the well? Thanx, Victoria From: Loepp, Victoria T (CED) Sent: Wednesday, February 19, 2020 9:39 AM To: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Cc: Davies, Stephen F (CED) <steve.davies@alaska.gov> Subject: CRU CD5-111-1,-L1-01(PTDs: 220-008, 220-009) CTD Operations Shutdown approval Ryan, Since the casing has not been exited and drilling of the laterals has not been initiated, please submit a 10-404 sundry for the 10-403 sundry to set the mechanical whipstock in the motherbore, CRU CD5-11(PTD 215-198, Sundry 320- 022). Once the workover is complete, CPAI may initiate drilling under the existing PTDs for CD5-11L1 and CD5-11L1-01. Approval of a shutdown of operations is approved. Thanx for the notification. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp(a-)alaska.gov 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 Victoria Loepp at (907)793-1247 or Victoria. Loepp@alaska.gov From: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Sent: Wednesday, February 19, 2020 9:13 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; Davies, Stephen F (CED) <steve.davies@alaska.gov> Cc: Starck, Kai<Kai.Starck@conocophillips.com>; Ohlinger, James J <James.J.Ohlinger@conocophillips.com> Subject: CD5-11 CTD Operations Update (PTD #'s: 220-008, 220-009) Victoria/Stephen, I'd like to give you an update on CTD operations on CRU CD5-11 and our current plan forward. Rig accept for Nabors CDR3-AC on CD5-11 was February 11 at 12:00 hrs. After setting an IBP in the 4-1/2" liner to seal off pressure from the A -Sand, we set an inner wedge in the 3-1/2" tubing at 9225' MD. Unfortunately, while attempting to mill the window the wedge fell downhole and the 3-1/2" casing was not exited. The wedge was pushed downhole and subsequent attempts to fish it were unsuccessful. After that, the decision was made to set a second whipstock, 3- 1/2" XL tray with and openhole anchor, at 9212' MD. The whipstock set was successfully, however when we began milling our low -side window, the 3-1/2" tubing was exited but we were unable to exit the 7-5/8" casing and ended up tracking casing in the annular space between the 3-1/2" tubing and 7-5/8" casing. Without any options for moving our KOP up or milling the window in a different fashion we do not see a path forward for completing CTD operations at this time on this well (PTD #'s: 220-008, 220-009) and will be rigging down and moving off. Our intention is to work this well over in the near future to set up a favorable window exit for CDR3 and return back to complete the CTD operations before the end of the ice road season. We are requesting verbal approval for a Sundry for Operations Shutdown at this time, with the intention of returning back to this well to complete the CTD project under the existing permits. Please call me if you have any questions or request any additional information. Regards, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska 2 � k m 06 ƒ $ 3 k co � % Cl) o o } 2 9 co co co m § f \ § Y.co 7& m a 2 \e m £ § J D_ G I co co k a/£ S 2 2 2 p 2 2 ctsc 7 a % } R$ j CL CL � cm k 2 8~® § q O $ o 2 f P m& k k CD m ak \ R* $ E 2 o/ c - k E ƒ k m # e ca c cc \ 0 � (o � / \ \ to � _Ile _Ile cc i A m W A m§ m m 2 # E 2 2 � � � c k� ƒ0 a_ %$ /0 0 c0 2� $� r—§ �« /�k 20 A / > THE STATE 00111 Walk GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Alpine Oil Pool, CRU CD5-11L1-01 ConocoPhillips Alaska, Inc. Permit to Drill Number: 220-009 Surface Location: 350' FNL, 2632' FEL, SEC. 18, T11N, R4E, UM Bottomhole Location: 2236' FNL, 4933' FEL, SEC. 08, Tl 1N, R4E, UM Dear Mr. Ohlinger: Alaska Oil and Gas 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the permit to redrill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 215-198, API No. 50-103-20726- 00-00. Production should continue to be reported as a function of the original API number stated above. 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. 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, IV,- er . Price air DATED this I day of January, 2020. STATE OF ALASKA AL. .:A OIL AND GAS CONSERVATION COMM - -,ON PERMIT TO DRILL 20 AAC 25.005 JAN 16 2020 1 a. Type of Work: • Drill ❑ Lateral ❑� Redrill ❑ Reentry ❑ 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ Stratigraphic Test ❑ Development - Oil ❑� - Service - Winj ❑ Single Zone ❑ ' Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ 1 c. Specify if well is proposed for: Coalbed Gas ❑ Gas Hydrates ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: Blanket ❑� • Single Well ❑ Bond No. 5952180 11. Well Name and Number: CRU CD5-11 L1-01 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 12,500' ° TVD: 7424' 12. Field/Pool(s): Colville River Unit / Alpine Oil Pool 4a. Location of Well (Governmental Section): Surface: 350' FNL, 2632' FEL, Sec. 18, T11 N, R4E, UM Top of Productive Horizon: 4730' FNL, 3679' FEL, Sec. 08, T11 N, R4E, UM Total Depth: 2236' FNL, 4933' FEL, Sec. 08, T11 N, R4E, UM 7. Property Designation: ; �'; 2--3 w -AA09 -ASRC-NPR2, ASCR-NPR4 8. DNR Approval Number: LONS 09-009 13. Approximate Spud Date: 2/1/2020 9. Acres in Property: 3122, 12615, 15912 14. Distance to Nearest Property: 16,100' - 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 349347 y- 5965862 ' Zone- 4 10. KB Elevation above MSL (ft): 71' GL / BF Elevation above MSL (ft): 34' 15. Distance to Nearest Well Open Ito Same Pool: 42' (CD5-10) 16. Deviated wells: Kickoff depth: 9330 feet Maximum Hole Angle: 103 degrees 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Downhole: 4712 • Surface: 3969 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.7# L-80 ST-L 3230' 9270' 7446' 12,500' 7424' Slotted/Solid 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): 17,236' Total Depth TVD (ft): 7601' Plugs (measured): N/A Effect. Depth MD (ft): 17,226' Effect. Depth TVD (ft): 7601' Junk (measured): N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 78' 20" 12 yds 115' 115' Surface 2215' 10-3/4" 37 bbls 11.0#, 58 bbls 15.8# 2252' 2169' Intermediate 9788' 7-5/8" 173 bb;s 15.8# Class G 9823' 7513' Liner 7572' 4-1 /2" N/A 17226' 7602' Perforation Depth MD (ft): N/A Perforation Depth TVD (ft): N/A Hydraulic Fracture planned? Yes❑ No 0 20. Attachments: Property Plat ❑ BOP Sketch ❑ Diverter Sketch ❑ Drilling Program Time v. Depth Plot ❑ Shallow Hazard Analysis Seabed Report ❑ Drilling Fluid Program R] 20 AAC 25.050 requirements El 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Ryan McLaughlin Authorized Name: James Ohlinger Contact Email: R an.MCLau hlin COP.cOm Authorized Title: Staff CTD Engineer Contact Phone: 907-265-6218 Authorized Signature: Date: 111410,40 Commission Use Only Permit to Drills Number:?—� API Number: 50- �j j ��%� 1 �C� % vim ^ Permit Approval Date: I\ W See cover letter for other requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methan-/e4 gas hydrates, or gas contained in shales: Other. Samples req'd: Yes ElNo L �3.� Mud log req'd: Yes ❑ No [y"' �hnv7ar �� H2Smeasures: Yes ✓❑' NoF_; t' Directional svyreq'd:Yes [;� No❑ o ��C 5 + O / f"in xception req'd: Yes ❑ No Inclination -only svy req'd: Yes❑ No[✓f(6Post initial injection MIT req'd: Yes ❑ Now'` fffo b r- �o/%7 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date. / 2� �Jaff St7,ft Form andForm to-aot e s oil this erm t is valid for 24 months from the date of approval per 2 a n Duplicatle ConocoPhilli s p Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 16, 2020 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for sundry and permits to drill two laterals out of the CRU CD5-11 (PTD# 215-198) using the coiled tubing drilling rig, Nabors CDR3-AC. - CTD operations are scheduled to begin in February 2020. The objective will beo drill two laterals CRU CD5- 11 L1 and CD5-11 L1-01 targeting the Alpine C-sand interval. , To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. Attached to the permit to drill applications are the following documents: — Permit to Drill Application Forms (10-401) for CD5-11 L1 and CD5-11 L1-01 — Detailed Summary of Operations — Directional Plans for CD5-11 L1 and CD5-11 L1-01 — Current wellbore schematic — Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-265-6218. Sincerely, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Laterals CD5-11 L1 and CD5-11 L1-01 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b))................................................................................................................... 2 2. Location Summary.......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2)).................................................................................................................................................. 2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005(c)(3))................................................................................................................................................. 2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005(c)(4))................................................................................................................................................. 2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5)).................................................................................................................................................. 2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6)).................................................................................................................................................. 3 7. Diverter System Information.......................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(7)).................................................................................................................................................. 3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(8)).................................................................................................................................................. 3 9. Abnormally Pressured Formation Information............................................................................. 4 (Requirements of 20 AAC 25.005(c)(9)).................................................................................................................................................. 4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................4 11. Seabed Condition Analysis............................................................................................................ 4 (Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................4 12. Evidence of Bonding...................................................................................................................... 4 (Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................ 4 13. Proposed Drilling Program............................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................ 4 Summaryof Operations...................................................................................................................................................4 LinerRunning...................................................................................................................................................................5 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6 (Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................ 6 15. Directional Plans for Intentionally Deviated Wells....................................................................... 6 (Requirements of 20 AAC 25.050(b))...................................................................................................................................................... 6 16. Attachments....................................................................................................................................6 Attachment 1: Directional Plans for CD5-11L1 and CD5-11L1-01 laterals......................................................................6 Attachment 2: Current Well Schematic for CD5-11.........................................................................................................6 Attachment 3: Proposed Well Schematic for CD5-11 L1 and CD5-11 L1-01 laterals........................................................6 Page 1 of 6 January 6, 2020 PTD Application: CD5-11 L1 & CD5-11 L1-01 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are CD5-11 L1 and CD5-11 L1-01. The laterals will be classified as "Development -Oil" wells. . 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the C sand package in the Alpine reservoir. See attached 10-401 form for surface and subsurface coordinates of the CD5-11 L1 and CD5-11 L1-01. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4,800 psi. Using the maximum formation pressure in the area of 4712 psi at the window in CD5-11 (i.e. 12.2 ppg EMW), the maximum potential surface pressure in CD5-11, assuming a gas gradient of 0.1 psi/ft, would be 3969 psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in CRU CD5-11 was 1880 psi based on the last Shut in bottomhole pressure reading on 8/1/2018 measured from a downhole gauge. The maximum downhole pressure expected while drilling based on offset wells and pressure management plans is 4712 psi which equates to 12.2 ppg EMW. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) The offset injection wells to CD5-11 have injected gas, so there is a possibility of encountering free gas while drilling the CD5-11 laterals. If gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) . The major expected risk of hole problems in the CD5-11 laterals will be shale instability across faults. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The CD5-11 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 6 January 6, 2020 PTD Application: CD5-11 L1 & CD5-11 L1-01 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top Liner Btm Liner Top Liner Btm Liner Details MD MD TVDSS TVDSS CD5-11 L1 9330' 13,100' 7395' 7410' 2-3/8", 4.7#, L-80, ST-L slotted liner; aluminum billet on to CD5-11L1-01 9270' 12,500' • 7375' 7353' 2-3/8", 4.7#, L-80, ST-L slotted liner and solid liner Existing Casing/Liner Information Category OD Weight f Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 20" 78.6 B Welded Surface 115' Surface 115' Surface 10-3/4" 45.5 L-80 H d 563 Surface 2252' Surface 2169' 5210 2470 Production 7-5/8" 29.7 L-80 BTCM Surface 9823' Surface 7513' 6890 4790 Tubing 3-1/2" 9.3 L-80 EUE-M Surface 1 9704' Surface 7505' 10160 10540 Liner 4-1/2" 12.6 L-80 H d 563 9654' 1 17,226 7501' 7602' 8430 7500 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride -based PowerVis mud (8.6 ppg) — Drilling operations: Chloride -based PowerVis mud (8.6 ppg). This mud weight may not hydrostatically overbalance the reservoir pressure; overbalanced conditions will be maintained using MPD practices described below. — Completion operations: The well will be loaded with 11.8 ppg NaBr completion fluid in order to provide formation over -balance and shale stability while running completions. If higher pressures are encountered the NaBr will be weighted up, or completion fluid will be switched to potassium formate. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the CD5-11 laterals we will target a constant BHP of 11.8 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 3 of 6 January 6, 2020 PTD Application: CD5-11 L1 & CD5-11 L1-01 Pressure at the CD5-11 Window (9225' MD, 7428' TVD) Using MPD Pumps On 1.8 b m Pumps Off C-sand Formation Pressure 4.9 1880 psi 1880 psi Mud Hydrostatic 8.6 3321 psi 3321 psi Annular friction i.e. ECD, 0.08 si/ft 738 psi 0 psi Mud + ECD Combined no chokepressure) 4059 psi Overbalanced -2179psi) 3321 psi Overbalanced -1441 psi Target BHP at Window 11.8 4558 psi 4558 psi Choke Pressure Required to Maintain Target BHP 499 psi 1237 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background CRU well CD5-11 is an Alpine A -Sand producer equipped with 3-1/2" tubing and 7-5/8" intermediate casing. The CTD sidetrack will utilize two laterals to target the Alpine C-sands to the north and south of CD5-11. Nabors CDR3-AC will set a mechanical whipstock inside the 3-1/2" tubing at the planned kick off point of 9225' MD. The CD5-11 L1 lateral will exit through the 3-1/2" tubing and 7-5/8" casing at 9225' MD and be drilled to a TD of 13,100' MD, targeting the C-sand to the South. It will be completed with 2-3/8" slotted liner from TD up to 9,330' MD with an aluminum billet for kicking off the CD5-11 L1-01 lateral. The CD5-11 L1-01 lateral will drill to a TD of 12,500' MD targeting the C-sand to the North. It will be completed / with 2-3/8" slotted and solid liner from TD up into the 3-1/2" tubing at 9270' MD. Page 4 of 6 January 6, 2020 PTD Application: CD5-11 L1 & CD5-11 L1-01 Pre-CTD Work 1. Prep site for Nabors CDR3-AC rig. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. CD5-11 L1 Lateral (C sand - South) a. Set retrievable inflatable packer in liner at 9800' MD b. Set top of whipstock at 9225' MD. c. Mill 2.80" window at 9225' MD. d. Drill 3" bi-center lateral to TD of 13,100' MD. e. Run 2-3/8" slotted liner with aluminum billet from TD up to 9330' MD. CD5-11L1-01 Lateral (C sand -North) a. Kick off of the aluminum billet at 9330' MD. b. Drill 3" bi-center lateral to TD of 12500' MD. c. Run 2-3/8" slotted liner and solid liner from TD up to 9270' MD. d. Pull and retrieve whipstock e. Pull and retrieve inflatable packer 4. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig. Post -Rig Work 1. Return well to production. Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the swab valve on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using the swab valve on the Christmas tree, deployment ram on the BOP, check valve and ball valve in the BHA, and a slick -line lubricator. This pressure control equipment listed ensures reservoir pressure is contained during the deployment process. During BHA deployment, the following steps are observed. — Initially the swab valve on the tree is closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valve. The swab valve is opened and the BHA is lowered in place via slick -line. — When the BHA is spaced out properly, the deployment ram is closed on the BHA to isolate reservoir pressure via the annulus. A closed ball valve and check valve isolate reservoir pressure internal to the BHA. Slips on the deployment ram prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment ram. — The coiled tubing is made up to the BHA with the ball valve in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the ball valve is opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment ram is opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running — The CD5-11 laterals will be displaced to an overbalancing fluid prior to running liner. See "Drilling Fluids" section for more details. — While running 2-3/8" slotted liner, a joint of 2-3/8" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2-3/8" rams will provide secondary well control while running 2-3/8" liner. Page 5 of 6 January 6, 2020 PTD Application: CD5-11 L1 & CD5-11 L1-01 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the Alpine Waste Injection Facility for grind and inject disposal. • Incidental fluids generated from drilling operations will also be injected at the Alpine Waste Injection Facility in disposal well (CD1-01A) or trucked to Kuparuk 1 B disposal facilities if the Alpine facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Alpine Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plans — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire open hole section. — Distance to Nearest Property Line Lateral Name Distance CD5-11L1 17,000' CD5-11 L1-01 16,100' — Distance to Nearest Well within Pool Lateral Name Distance Well CD5-11L1 1192' CD5-08 CD5-11L1-01 42' CD5-10 16. Attachments Attachment 1: Directional Plans for CD5-11L1 and CD5-11L1-01 laterals Attachment 2: Current Well Schematic for CD5-11 Attachment 3: Proposed Well Schematic for CD5-11 L 1 and CD5-11 L 1-01 laterals Page 6 of 6 January 6, 2020 4) s rn x L a m O_ CD5-11: 34.1 + 36.5 @ 70.60usft (Doyon 19) ConocoPhilli s p ConocoPhillips Alaska Inc WNS Western North Slope CD5 Alpine West Pad CD5-11 CD5-11 L1-01 Plan: CD5-11 L1-01 wp03 (Draft A) Standard Planning Report 04 January, 2020 Baker Hughes 8 ConocoPhillips Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc WNS Project: Western North Slope Site: CD5 Alpine West Pad Well: CD5-11 Wellbore: CD5-11Ll-01 Design: CD5-11 L1-01_wp03 (Draft A) ConocoPhillips Planning Report Baker Hughes Local Co-ordinate Reference: Well CD5-11 TVD Reference: Mean Sea Level MD Reference: CD5-11: 34.1 + 36.5 @ 70.60usft (Doyon 19) North Reference: True Survey Calculation Method: Minimum Curvature Project Western North Slope, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Fs a CD5 Alpine West Pad Site Position: Northing: 5,965,782.04 usft Latitude: 70' 18' 48.988 N From: Map Easting: 349,218.85usft Longitude: 1510 13' 19.334 W Position Uncertainty: 0.00 usft Slot Radius: 13.200 in Grid Convergence: -1.15 ° Well CD5-11 Well Position +N/-S 0.00 usft Northing: 5,965,861.70 usft Latitude: 70' 18' 49.797 N +E/-W 0.00 usft Easting: 349,346.71 usft Longitude: 151' 13' 15.651 W Position Uncertainty 0.00 usft Wellhead Elevation: 33.26 usft Ground Level: 34.10 usft Wellbore CD5-111-1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BG G M2018 12/31 /2019 15.80 80.71 57,356 Design CD5-11L1-01_wp03(Draft A) Audit Notes: Version: Phase: PLAN Tie On Depth: 9,330.00 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (I -34.10 0.00 0.00 315.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (usft) (I (°) (usft) (usft) (usft) (°/100usft) (°1100usft) (°/100usft) (°) Target 9,330.00 90.12 132.84 7,394.93 901.33 4,229.16 0.00 0.00 0.00 0.00 9,390.00 103.23 109.02 7,387.87 870.84 4,279.70 45.00 21.85 -39.70 -60.00 9,550.00 89.43 37.67 7,367.63 914.70 4,421.37 45.00 -8.62 -44.59 -95.00 9,685.00 90.59 336.93 7,367.60 1,042.42 4,437.74 45.00 0.86 -44.99 -89.00 10,085.00 90.05 308.94 7,365.30 1,358.44 4,199.06 7.00 -0.13 -7,00 -91.00 10,595.00 90.48 334.44 7,362.88 1,755.31 3,885.49 5.00 0.08 5.00 89.00 11,000.00 90.45 314.19 7,359.57 2,082.52 3,650.45 5.00 -0.01 -5.00 -90.00 11,500.00 90.41 339.19 7,355.76 2,497.04 3,378.02 5.00 -0.01 5.00 90.00 11,850.00 90.09 321.69 7,354.24 2,800.29 3,206.01 5.00 -0.09 -5.00 -91.00 12,500.00 90.07 354.19 7,353.29 3,394.66 2,965.14 5.00 0.00 5.00 90.00 11412020 11:38:46AM Page 2 COMPASS 5000.14 Build 85H ConocoPhillips ConocoPhillips Planning Report Baker Hughes Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well CD5-11 Company: ConocoPhillips Alaska Inc WNS TVD Reference: Mean Sea Level Project: Western North Slope MD Reference: CD5-11: 34.1 + 36.5 @ 70.60usft (Doyon 19) Site: CD5 Alpine West Pad North Reference: True Well: CD5-11 Survey Calculation Method: Minimum Curvature Wellbore: CD5-11L1-01 Design: CD5-11L1-01 wp03(DraftA) Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (1) (°) (usft) (usft) (usft) (usft) (°/100usft) (°) (usft) (usft) 9,330.00 90.12 132.84 7,394.93 901.33 4,229.16 -2,353.13 0.00 0.00 5,966,677.93 353,592.79 TIP/KOP 9,390.00 103.23 109.02 7,387.87 870.84 4,279.70 -2,410.43 45.00 -60.00 5,966,646.43 353,642.71 Start OLS,45.00 TFO -95.00 9,400.00 102.79 104.43 7,385.62 868.04 4,289.03 -2,419.01 45.00 -95.00 5,966,643.45 353,651.97 9,500.00 94.82 59.54 7,369.51 881.86 4,384.14 -2,476.48 45.00 -96.04 5,966,655.36 353,747.33 9,550.00 89.43 37.67 7,367.63 914.70 4,421.37 -2,479.59 45.00 -103.29 5,966,687.44 353,785.21 Start DLS 45.00 TFO -89.00 9,600.00 89.85 15.18 7,367.95 959.19 4,443.48 -2,463.76 45.00 -89.00 5,966,731.47 353,808.21 9,685.00 90.59 336.93 7,367.60 1,042.42 4,437.74 -2,400.85 45.00 -88.86 5,966,814.80 353,804.14 Start DLS 7.00 TFO -91.00 9,700.00 90.57 335.88 7,367.45 1,056.17 4,431.74 -2,386.89 7.00 -91.00 5,966,828.66 353,798.42 9,800.00 90.45 328.89 7,366.56 1,144.72 4,385.42 -2,291.52 7.00 -91.01 5,966,918.11 353,753.89 9,900.00 90.31 321.89 7,365.89 1,226.96 4,328.65 -2,193.22 7.00 -91.07 5,967,001.48 353,698.79 10,000.00 90.17 314.89 7,365.47 1,301.68 4,262.28 -2,093.46 7.00 -91.12 5,967,077.51 353,633.94 10,085.00 90.05 308.94 7,365.30 1,358.44 4,199.06 -2,008.62 7.00 -91.15 5,967,135.51 353,571.87 Start DLS 5.00 TFO 89.00 10,100.00 90.07 309.69 7,365.28 1,367.94 4,187.45 -1,993.70 5.00 89.00 5,967,145.25 353,560.46 10,200.00 90.15 314.69 7,365.09 1,435.08 4,113.38 -1,893.85 5.00 89.00 5,967,213.85 353,487.75 10,300.00 90.24 319.69 7,364.74 1,508.41 4,045.45 -1,793.95 5.00 89.01 5,967,288.53 353,421.31 10,400.00 90.32 324.69 7,364.25 1,587.39 3,984.16 -1,694.77 5.00 89.03 5,967,368.71 353,361.62 10,500.00 90.40 329.69 7,363.62 1,671.40 3,929.99 -1,597.06 5.00 89.05 5,967,453.79 353,309.15 10,595.00 90.48 334.44 7,362.88 1,755.31 3,885.49 -1,506.27 5.00 89.08 5,967,538.56 353,266.35 Start DLS 6.00 TFO -90.00 10,600.00 90.48 334.19 7,362.84 1,759.81 3,883.32 -1,501.55 5.00 -90.00 5,967,543.11 353,264.27 10,700.00 90.48 329.19 7,362.01 1,847.82 3,835.91 -1,405.79 5.00 -90.00 5,967,632.04 353,218.64 10,800.00 90.47 324.19 7,361.18 1,931.35 3,781.01 -1,307.90 5.00 -90.04 5,967,716.66 353,165.43 10,900.00 90.46 319.19 7,360.36 2,009.79 3,719.03 -1,208.62 5.00 -90.09 5,967,796.32 353,105.04 11,000.00 90.45 314.19 7,359.57 2,082.52 3,650.45 -1,108.69 5.00 -90.13 5,967,870.41 353,037.94 Start DLS 6.00 TFO 90.00 11,100.00 90.45 319.19 7,358.78 2,155.26 3,581.88 -1,008.77 5.00 90.00 5,967,944.50 352,970.84 11,200.00 90.44 324.19 7,358.00 2,233.69 3,519.90 -909.49 5.00 90.04 5,968,024.16 352,910.46 11,300.00 90.43 329.19 7,357.24 2,317.23 3,465.00 -811.59 5.00 90.08 5,968,108.77 352,857.25 11,400.00 90.42 334.19 7.356.49 2,405.24 3,417.58 -715.84 5.00 90.12 5,968,197.70 352,811.61 11,500.00 90.41 339.19 7,355.76 2,497.04 3,378.02 -622.95 5.00 90.15 5,968,290.28 352,773.90 Start DLS 5.00 TFO -91.00 11,600.00 90.32 334.19 7,355.13 2,588.85 3,338.46 -530.06 5.00 -91.00 5,968,382.85 352,736.19 11,700.00 90.23 329.19 7,354.65 2,676.85 3,291.04 -434.30 5.00 -91.03 5,968,471.78 352,690.56 11,800.00 90.13 324.19 7,354.34 2,760.40 3,236.14 -336.40 5.00 -91.06 5,968,556.41 352,637.35 11,850.00 90.09 321.69 7,354.24 2,800.29 3,206.01 -286.89 5.00 -91.07 5,968,596.90 352,608.02 Start DLS 5.00 TFO 90.00 11,900.00 90.09 324.19 7,354.16 2,840.19 3,175.88 -237.37 5.00 90.00 5,968,637.39 352,578.70 12,000.00 90.09 329.19 7,354.01 2,923.73 3,120.98 -139.48 5.00 90.00 5,968,722.01 352,525.49 12,100.00 90.09 334.19 7,353.86 3,011.74 3,073.57 -43.72 5.00 90.01 5,968,810.95 352,479.86 12,200.00 90.08 339.19 7,353.71 3,103.55 3,034.01 49.17 5.00 90.02 5,968,903.52 352,442.15 12,300.00 90.08 344.19 7,353.57 3,198.46 3,002.60 138.49 5.00 90.03 5,968,999.03 352,412.66 12,400.00 90.08 349.19 7,353.43 3,295.74 2,979.59 223.55 5.00 90.03 5,969,096.75 352,391.60 12,500.00 90.07 354.19 7,353.29 3,394.66 2,965.14 303.72 5.00 90.04 5,969,195.93 352,379.14 Planned TD at 12500.00 11412020 11:38 46AM Page 3 COMPASS 5000 14 Build 85H ConocoPhillips Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc_WNS Project'. Western North Slope Site: CD5 Alpine West Pad Well: CD5-11 Wellbore: CD5-111-1-01 Design: CD5-11 L1-01_wp03 (Draft A) Casing Points Measured Vertical Depth Depth (usft) (usft) 12,500.00 7,353.29 2-3/8" ConocoPhillips Planning Report Local Co-ordinate Reference! TVD Reference: MD Reference: North Reference: Survey Calculation Method: Name Baker Hughes g Well CD5-11 Mean Sea Level CD5-11: 34.1 + 36.5 @ 70.60usft (Doyon 19) True Minimum Curvature Casing Hole Diameter Diameter (in) (in) 2.375 3.000 L- — - - Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 9,330.00 7,394.93 901.33 4,229.16 TIP/KOP 9,390.00 7,387.87 870.84 4,279.70 Start DLS 45.00 TFO -95.00 9,550.00 7,367.63 914.70 4,421.37 Start DLS 45.00 TFO -89.00 9,685.00 7.367.60 1,042.42 4,437.74 Start DLS 7.00 TFO -91.00 10,085.00 7,365.30 1,358.44 4,199.06 Start DLS 5.00 TFO 89.00 10,595.00 7,362.88 1,755.31 3,885.49 Start DLS 5.00 TFO -90.00 11,000.00 7,359.57 2,082.52 3,650.45 Start DLS 5.00 TFO 90.00 11,500.00 7,355.76 2,497.04 3,378.02 Start DLS 5.00 TFO -91.00 11,850.00 7,354.24 2,800.29 3,206.01 Start DLS 5.00 TFO 90.00 12,500.00 7,353.29 3,394.66 2,965.14 Planned TD at 12500.00 11412020 11.38:46AM Page 4 COMPASS 5000.14 Build 85H ConocoPhillips ConocoPhillips Anticollision Report Baker Hughesto Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Reference Site: CD5 Alpine West Pad Site Error: 0.00 usft Reference Well: CD5-11 Well Error: 0.00 usft Reference Wellbore CD5-11 L1-01 Reference Design: CD5-11L1-01_wp03(Draft A) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well CD5-11 CD5-11: 34.1 + 36.5 @ 70.60usft (Doyon 19) CD5-11: 34.1 + 36.5 @ 70.60usft (Doyon 19) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production Offset Datum Reference CD5-11L1-01_wp03 (Draft A) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 9,330.00 to 12,500.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum ellipse separation of 6,000.00 usft Error Surface: Combined Pedal Curve Warning Levels Evaluated at: 2.79 Sigma Casing Method: Added to Error Values Survey Tool Program Date 1/2/2020 From To (usft) (usft) Survey (Wellbore) Tool Name Description 9,330.00 12,500.00 CD5-11 11-01_wp03 (Draft A) (CD5-11 1-1-0 MWD OWSG OWSG MWD - Standard Summary Site Name Offset Well - Wellbore - Design CD5 Alpine West Pad CD5-07 - CD5-07 - CD5-07 CD5-07 - CD5-07 - CD5-07 CD5-07 - CD5-07 - CD5-07 CD5-08 - CD5-08 - CD5-08 CD5-08 - CD5-08 - CD5-08 CD5-10 - CD5-10 - CD5-1(Y - - CD5-10 - CD5-10 - CD5-10 CD5-10 - CD5-10 - CD5-10 CD5-11 - CD5-11 - CD5-11 CD5-11 - CD5-11 11 - CD5-11 L1_wp05 (Draft A) CD5-11 -CD5-11L1 -CD5-11L1_wp05 (Draft A) Reference Offset Distance Measured Measured Between Between Separation Warning Depth Depth Centres Ellipses Factor (usft) (usft) (usft) (usft) 11,700.00 8,725.00 1,314.72 1,203.49 11.819 CC 11,746.80 8,875.00 1,319.30 1,197.68 10.847 ES 11,834.22 9,225.00 1,358.58 1,218.33 9.687 SF 9,777.16 12,350.00 1,226.21 1,157.67 17.892 CC, ES 11,814.14 10,150.00 1,357.71 1,207.24 9.023 SF 11,049.39 9,250.00 42.24 -52.99 0.444 STOP Drilling, ES 11,069.52 9,275.00 34.20 -44.50 0,435 STOP Drilling, SF 11,090.37 9,300.00 30.89 -19.37 0.615 STOP Drilling, CCU' 9,347.59-9,35D-OD- --31 2$ a2775- 423 STOP n nng,�C, ES, SF 9,347.34 9,350.00 10.38 -58.05 0.152 STOP Drilling, CC, SF 9,390.00 9,400.00 23.53 -68.31 0.256 STOP Drilling, ES Offset Design CD5 Alpine West Pad - CD5-07 - CD5-07 - CD5-07 Offset Site Error: 0.00 usft Survey Program: 67-GYD-GCSS, 761-MWD+IFR2+SAG+MS, 2326-MWD+IFR2+SAG+MS, 10667-MWD+IFR2+SAG+MS, 15517-MWD+IFR2+SAG+MS Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Distance Measured Vertical Measured Vertical Reference Offset Azimuth Offset Wellbore Centre Between Between Minimum Separation Warning Depth Depth Depth Depth from North +NI-S +E7-W Centres Ellipses Separation Factor (usft) (usft) (usft) (usft) (usft) (usft) (1 (uyrtt) (usft) (usft) (usft) (usft) 11,617.50 7,425.61 8,050.00 6,087.41 94.13 70.72 -4.71 2.840.87 3,816.54 1,443.55 1,380.09 63.46 22.746 11,619.99 7425.60 8,075.00 6,104.16 94.24 71.01 -3AI 2.852.47 3,831.02 1,434.98 1,369.85 65.14 22.030 11,622.58 7.425.59 8,100.00 6,120.96 94.35 71.30 -3.11 2,864.22 3,845.33 1,426.72 1,359.88 66.84 21.346 11,625.27 7,425.57 8,125.00 6,137.80 94.47 71.60 -2.31 2,876.13 3,859.46 1,418.75 1,350.19 68.56 20.693 11,628.04 7,425.56 8,150.00 6,154.68 94.59 71.89 -1.50 2,888.21 3,873.39 1,411.10 1,340.80 70.31 20.071 11,630.96 7,425.54 8,175.00 6,171.61 94.72 72.17 -069 2,900.49 3,887.08 1,403.74 1,331.67 72.07 19.477 11,634.05 7425.53 8,200.00 6,188.61 94.85 72.44 0.12 2,913.03 3,900.45 1,396.65 1,322.80 73.86 18.910 11,637.32 7,425.51 8,225.00 6,205.66 94.99 72.72 0.92 2,925.83 3,913.51 1,389.84 1,314.18 75.66 18.370 11,640.76 7,425.50 8,250.00 6,222.77 95.14 72.99 1.72 2,938.88 3,926.24 1,383.30 1,305.83 77.47 17.855 11,644.27 7,425.48 8,275.00 6,239.95 95.29 73.25 2.52 2,952.04 3,938.74 1,377.02 1,297.73 79.30 17.365 11,647.81 7,425.46 8,300.00 6,257.23 95.44 73.51 3.32 2,965.28 3,951.05 1,371.01 1,289.88 81.13 16.898 11,651.37 7,425.44 8,325.00 6,274.59 95.60 73.77 4.13 2,978.58 3,963.16 1,365.26 1,282-29 82.98 16.454 11,654.96 7,425.43 8,350.00 6.292.05 95.75 74.02 4.94 2,991.93 3,975.08 1.359.78 1,274,95 84.82 16.031 11.658.53 7,425.41 8.375.00 6.309.62 95.91 74.27 5.77 3,005.29 3,986.81 1,354.53 1,267.86 86.67 15.628 11,662.10 7,425.39 8,400.00 6.327.31 96.06 74.52 6.59 3,018.65 3,998,37 1,349.52 1,261.00 88.52 15.245 11,665.66 7.425.38 8,425.00 6,345.12 96.22 74.76 7.42 3,032.00 4,009.75 1,344,75 1,254.38 90.37 14.881 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 1/2/2020 9:00:08AM Page 2 COMPASS 5000.14 Build 85H 4! L 7 x W Y O m 00p HLL 000000,E LL LL LL LL LL LL N oOHHF- Hf-Hr a o 0 o p O o o p LO L7Icc o cn cn cn�cn cn rn �I' JFo ca:9:9:3m:9:°;g m ¢��cncn�cnrncn�a Lf) r M O Q) O a D t O .6 N t o M MO M V V O LQ N M N N N N N N Z o 0 0 0 0 Cl o p o 0 Im 000000OpoO � ooLo(3, cSoo 0 '� cornmrncoIMP rnrnrn rn LC) V 0 ap 0 0 0 0 0 0 0 0 0 0 (� O O O O O O O O O O O r� M 1� O�r M a p N p � OOri+O)�Oi�u'J V C - .- M aD t� V' N O V Cl! tf) (D Cl) O i t N N t t] N c o 0 7 =_ W O 1 r t o N W D) O a) Q Cl) O N -It N M w W M IN Q�p lI--u] V N r Jcz) OCq GO �NOO u] 1-N N W o1 a0 ocoOO LO LO Lry C n LJ t0 I a p `o t!') p'I,:Loa00co D7 r Z( G LO M p M m O M MLO r +- M M M M M M M Cl! 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(0 m J fn U J X r x rn U U) a O � $iOCOLo N N N N N N N N N y N N N Y N r r Y Y Y Y C c0 N V M m Cl) A m A m m J m m mcu 0 0 O # co O N to O L rn LO N N Ql I Davies, Stephen F (CED) From: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Sent: Thursday, January 23, 2020 7:18 AM To: Davies, Stephen F (CED) Cc: Boyer, David L (CED) Subject: RE: [EXTERNAL]CRU CD5-11L1 (PTD 220-008) and CD5-11L1-01 (PTD 220-009) - Questions Attachments: cd5_11_CTD_sidetrack_PTD_lease_plat_20200122.mxd Hello Steve, Apologies for the confusion. The CTD laterals will not go into the lease in question (ASRC-AA092344) as indicated in the PTD application. The only leases that will be crossed are ASRC-NPR2 and ASRC-NPR4. I've attached a lease plat for CD5- 11 that will hopefully clear this up. Regards, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office:907-265-6218 Cell:907-444-7886 700 G St, ATO 670, Anchorage, AK 99501 From: Davies, Stephen F (CED) <steve.davies@alaska.gov> Sent: Tuesday, January 21, 2020 9:04 AM To: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Cc: Boyer, David L (CED) <david.boyer2@alaska.gov> Subject: [EXTERNAL]CRU CD5-111-1 (PTD 220-008) and CD5-111-1-01 (PTD 220-009) - Questions Ryan, While reviewing the Permit to Drill applications for CD5-111-1 and CD5-111-1-01, I checked the Federal lease number CPAI provided on the applications--AA092344--in BLM's Case File management system (acronym "ACRES", which is accessible at https://sdms.ak.blm.gov/acres/acres menu). I found that the Case Status for that particular lease is listed as "Closed," with a Last Action description of "763 Expires" dated 31-Aug-2019, and a last General Remark of "Conveyed to Arctic Slope Regional Corporation (ASRC)." The land description for this particular lease is T011N, R003E, Sections 19, 20, 24, 25, and 30, but wells CD5-111-1 and CD5-111-1-01 lie within Sections 8, 17, and 18 of T011N, R004E. Maybe I've done something wrong. Could you please check this lease number for me? Also, the lease maps that AOGCC has for the CD5 Drill Site area are poorly labeled. Could CPAI please provide AOGCC a map for this area that is clearly labeled with State, Native, and Federal lease boundaries and lease numbers? Thank you. I appreciate your help. Regards, Steve Davies AOGCC TRANSMITTAL LETTER CHECKLIST WELL NAME: [�( �-C�S �l Z_ PTD: Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD:j/(/l �1�,J t--r/ POOL: (�_/L C Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. API No. 50-/b3-2�� 7 �_D j (If last two digits Production should continue to be reported as a function of the original t/ in API number are API number stated above. between 60-69 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 Pilot Hole name ( PH) and API number (50- - - -� from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Spacing Approval to produce/inject is contingent upon issuance of a Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non- production or production testing of coal bed methane is not allowed for Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. 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 (Company Name) in the attached application, the following well logs j' ✓ are also required for this well: Well Logging Requirements 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 l within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool COLVILLE RIVER, ALPINE OIL - 120100 Well Name: COLVILLE RIV UNIT CD5-llL1-01pro ram g D_E_ V__ _ __ Well bore seg PTD#: 2200090 Company ConocoPhi�s Alaska. Inc. Initial Class/Type DEV / PEND GeoArea 890 Unit 50360 On/Off Shore On Annular Disposal Administration 1 Permit fee attached NA 2 Lease number appropriate_ Yes Surface location in ASRC-N_PR4, top prod interval_ and TD_in ASRC-NPR2. 3 Unique well name and number Yes 14 Well located in -a defined pool Yes COLVILLE RIVER, -ALPINE -OIL - 120100, governed by CO 443C. 15 Well located proper distance from drilling unit boundary Yes - CO No. 443C contains no spacing_ restrictions with respect to drilling- unit boundaries. 6 Well located proper distance_ from other wells_ Yes CO No. 443C has no interwell spacing restrictions 7 Sufficient acreage available in drilling unit Yes CO No. 443C has no_ interwell spacing restrictions. Wellbore will be more than 500' 8 If deviated, is welibore plat included Yes from an external property line -where ownership or landownership changes. 9 Operator only affected party Yes As planned, well will conform to spacing requirements. 10 Operator has appropriate bond in force Yes ill Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes 113 Can permit be approved before 15-day wait Yes SFD 1/23/2020 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA --------------- ----------- 15 All wells_within 1/4_mile area of review identified (For service well only) NA_ 16 Pre -produced injector: duration of pre production less than 3 months (For service well only) - - NA_ - - - 17 Nonconven. gas conforms to AS31,05.030Q.1.A),0.2.A-D) NA_ 18 Conductor string NA_ Conductor set for CRU CD5-11 Engineering 19 Surface casing protects all -known USDWs NA Surface casing set for CRU_CD5-1.1 120 CMT vol adequate to circulate on conductor & surf csg NA Surface casing set and fully cemented 21 CMT vol adequate to tie-in long string to surf csg NA 22 CMT will cover all known productive horizons No Productive_ interval will be completed with uncemented slotted liner 23 Casing designs adequate for C,_T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig has steel tanks, all -waste to approved disposal wells j25 If a re -drill, has a 10-403 for abandonment been approved NA_ - 26 Adequate welibore separation proposed Yes Anti -collision analysis complete; CD5-10 in zone 27 �28 If diverter required, does it meet regulations_ NA Appr Date Drilling fluid program schematic & equip list adequate Yes Max formation_ pressure is 4712 psig(12.2 ppg EMW); will drill_w/ 8.6 ppg EMW and maintain overbal w/ MPD_ VTL 1/27/2020 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MPSP is 3969 psig; will test BOPs to 4800 psig 31 Choke manifold complies w/API_ RP-53 (May 84) Yes I32 Work will occur without operation shutdown Yes - - - 133 Is presence of H2S gas_ probable Yes H2S measures required 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen_ sulfide measures No - - - - - - - 112S has been encountered in Alpine Oil Pool wells drilled from _CD_5_Pad. _H2S measures required. Geology 36 Data presented on potential overpressure zones Yes Maximum expected reservoir pressure is about 12.2 ppg EMW; will be drilled with 8.6_ ppg mud Appr Date 37 Seismic analysis_ of shallow gas zones NA using coiled tubing and Managed Pressure Drilling technique to maintain borehole stability SFD 1/23/2020 138 Seabed condition survey (if off -shore) NA in shale sections and manage reservoir_ pressure. 39 Contact name/phone for weekly_ progress reports [exploratory only] NA Geologic Engineering Public Commissioner: lDate: Commissioner- /Date Commission r Date �/