The URL can be used to link to this page

Home My WebLink About218-060Winston, Hugh E (CED) From: Winston, Hugh E (CED) Sent: Thursday, June 4, 2020 9:04 AM To: william.r.long@cop.com Cc: Loepp, Victoria T (CED) Subject: KRU 1L-23L1-01 and 11--231-1-03 Permits Expired Hi William, The Permits to drill for both KRU 1L-23L1-01 and KRU IL-23L1-03 which were issued to CPAI on May 30th 2018, have expired under Regulation 20 AAC 25.005 (R). The permits have been marked expired in their history file and in the AOGCC database. Please let me know if you would like any follow up information on these permits. Huey Winston Statistical Technician Alaska Oil and Gas Conservation Commission hugh.winston@alaska.gov 907-793-1241 Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Friday, June 8, 2018 2:39 PM To: Mike.Callahan@conocophillips.com' Cc: Loepp, Victoria T (DOA) Subject: RE: 1L-23L1-03 (PTD # 218-060) API Number Mike You are correct. I coded the API number properly in AOGCC's Permit to Drill ledger and in our database when I assigned it (50-029-22167-63-00), but when I hand -wrote the number on the bottom of the Permit to Drill form, I goofed and entered -00-00 rather than -63-00 as the last four digits of the API number. Please hand -correct ConocoPhillips' copies of the Permit to Drill form and the cover letter for this well, and I will do the same with AOGCC's copies. Please accept my apology for this mistake. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Loepp, Victoria T (DOA) Sent: Wednesday, June 6, 2018 9:18 AM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: FW: 1L-231-1-03 (PTD # 218-060) API Number Hi Steve, Could you please review this? Thanx, Victoria From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Wednesday, June 06, 2018 6:59 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: 11--231-1-03 (PTD # 218-060) API Number Good morning Victoria, I wanted to double check with you on the API number that was assigned to the 11--231-1-03 lateral (approved PTD # 218- 060, attached). The number listed on the approved PTD is 50-029-22167-00-00, but I believe should be 50-029-22167- 63-00. Could you please double check and let me know if the PTD needs to be re -issued or anything needs to be done on my end? Thanks for your help, Mike Callahan CTD Engineer ConocoPhillips Alaska ATO 660 Office: (907) 263-4180 Cell: (907) 231-2176 THE STATE oALASKA GOVERNOR BILL WALKER James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1L-23L1-03 ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-060 Surface Location: 537' FNL, 143' FEL, SEC. 31, T11N, R10E, UM Bottomhole Location: 2155' FSL, 860' FWL, SEC. 6, T10N, R10E, UM Dear Mr. Ohlinger: 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. 191-062, API No. 50-029-22167- 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, Hollis S. French Chair DATED this �� day of May, 2018. STATE OF ALASKA ALA -..A OIL AND GAS CONSERVATION COMMISaiON PERMIT TO DRILL 20 AAC 25.005 RECEIVED MAY 11 2018 1 a. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1 c. 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: ConocoPhillips Alaska Inc Bond No. 5952180 KRU 1 L-23L1-03 3. Address: 6. Proposed Depth: -i ,, 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 12000 TVD55; 5894 Kuparuk River Kuparuk River Oil 4a. Location of Well (Governmental Section): 7. Property Designation: // v ty Surface: 537'FNL, 143' FEL, Sec 31, T11N, R10E, UM • li.t�- ADL 25664 Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 1759' FNL, 479' FWL, Sec 6, T10N, R10E, UM LO/NS 83-139 24-Ma -18 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 2155' FSL, 860' FWL, Sec 6, T1ON, R10E, UM 2501 11990, 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 130' 15. Distance to Nearest Well Open Surface: x- 539925 Y- 5948431 Zoi 4 GL / BF Elevation above MSL (ft): 87' to Same Pool: 469' (2E-07) 16. Deviated wells: Kickoff depth: 10500 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 92 degrees Downhole: 4393 ' Surface: 3760 ' 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" 4.6# L-80 ST-L 2160 9840 5887 12000 5894 Un-Cemented 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 10346 6291 N/A 10249 6238 N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 82' 16" 235 sx AS 1 122' 122' Surface 5263' 9-5/8" 750 sx Type E, 600 sx Class G 5306' 3609' Intermediate Production 10300' 7" 250 sx Class G Prem. 10335' 6285' Liner Perforation Depth MD (ft): 9794 - 9874, 10012 - 10050, Perforation Depth TVD (ft): 5992 - 6035, 6110 - 6131, 6188 - 6193 10156-10165 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 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: William R. Long Authorized Name: James Ohlinger Contact Email: William. R.Lon COP.com Authorized Title: Staff CTD Engineer Contact Phone: 907-263-4372 Authorized Signature: loop Date: Commission Use Only Permit to Drill r �% GJAPI mber: Permit �.�� Approval See cover letter for other Number: ( Date: requirements. 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: [� Other: Q0,0 t-�r-_5r p ,rt�s Lr__ �--p 419Go p 5 Samples req'd: Yes ❑ No❑✓ Mud log req'd: Yes ❑ No❑� r r-?- ✓1'v1 HZS measures: Yes ❑✓� No ❑ Directional svy req'd: Yes ❑ No ❑ Spacing exception req'd: Yes ❑ No[Z Inclination -only svy req'd: Yes ❑ No a Post initial injection MIT req'd: Yes ❑ No[' �rA�7`rd' � allow f�� k�'c�of� rJoi��" t� hC4�y APPROVED BY S 3 Approved by: COMMISSIONER THE COMMISSION Date: {''7 L D Submit Form and Form 10-401 Revised 5/ 017 This permit is va d0-R f rtt, ifNtALof approval per 20 AAC 25.005(g) tachments in Duplicate, ConocoPs philli Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 10, 2018 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 permits to drill four laterals out of the KRU 1 L-23 (PTD# 191-062) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in late May or early June 2018. The objective will be to drill four laterals, KRU 1L-231-1, 1L-231_1-01, 1L-231_1-02, and 1L-231-1-03, targeting the Kuparuk 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 this application are the following documents: — Permit to Drill Application Forms (10-401) for 1 L-231-1, 1 L-231-1-01, 1 L-231-1-02, and 1 L-23L1-03 — Detailed Summary of Operations — Directional Plans for 1 L-231-1, 1 L-231_1-01, 1 L-231_1-02, and 1 L-231_1-03 — Current wellbore schematic — Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-263-4372. Sincerely, William R. Long Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Laterals 1L-23L1, 1L-231-1-01, 1L-231-1-02, & 11--231-1-03 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(t) 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...................................................................................................................................................................6 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6 (Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................ 6 15. Directional Plans for Intentionally Deviated Wells....................................................................... 7 (Requirements of 20 AAC 25.050(b))...................................................................................................................................................... 7 16. Attachments.................................................................................................................................... 7 Attachment 1: Directional Plans for 1L-231-1, 1L-231-1-01, 1L-231-1-02, and 1L-23L1-03laterals ...................................7 Attachment 2: Current Well Schematic for 1 L-23............................................................................................................7 Attachment 3: Proposed Well Schematic for 1L-23L1, 1L-231-1-01, 1L-231-1-02, and 11--231-1-03laterals .....................7 Page 1 of 7 May 10, 2018 PTD Application: 1L-23L1, 1L-23L1-01, 1L-23L1-02, & 1L-23L1-03 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 1 L-23L1, 1 L-23L1-01, 1 L-23L1-02, and 1 L-23L1-03. All 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 Kuparuk reservoir. See attached 10-401 forms for surface and subsurface coordinates of each of the laterals. 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 4,000 psi. Using the maximum formation pressure in the area of 4393 psi at the datum in 2E-05 (i.e. 13.3 ppg EMW), the maximum potential surface pressure in 1 L-23, assuming a gas gradient of 0.1 psi/ft, would be 3,760 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 KRU 1 L-23 was measured to be 3498 psi at the datum (10.6 ppg EMW) on 4/20/2017. The maximum downhole pressure in the 1 L-23 vicinity is the 2E-05 at 4393 psi at the datum or 13.3 ppg EMW. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) No specific gas zones will be drilled; gas injection has been performed in this area, so there is a chance of encountering gas while drilling the 1 L-23 laterals. If significant 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 1 L-23 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 1 L-23 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 7 May 9, 2018 PTD Application: 1L-23L1, 1L-23L1-01, 1L-231_1-02, & 1L-23L1-03 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 1L-23L1 10650' 14400' 5887' 5877' 2'/", 4.7#, L-80, ST-L slotted liner; aluminum billet on to 1L-23L1-01 10080' 12250' 5889' 5887' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on to 1L-23L1-02 10500' 15300' 5877' 5898' 2%", 4.7#, L-80, ST-L slotted liner;aluminum billet on to 1L-231_1-03 9840' 12000' 5887' 5894' 23/", 4.7#, L-80, ST-L slotted liner, - deployment sleeve on to Existing Casing/Liner Information Category OD Weight Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 62.5 H-40 Welded 40' 122' 40' 122' 1640 670 Surface 9-5/8" 36 J-55 BTC 43' 5306' 43' 3609' 3520 2020 Production 7" 26 J-55 BTC-Mod 43' 10335' 43' 6285' 4980 4320 Tubing 3-1/2" 9.3 L-80 EUE 8rd 39' 9810, 39' 6001' 10160 10540 Note: Tubing information is proposed depths, pending completion of the rig workover. 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: Water based Power-Vis milling fluid (8.6 ppg) — Drilling operations: Water based Power -Pro drilling 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: BHA's will be deployed using standard pressure deployments and the well will be loaded with 11.4 ppg NaCl/NaBR completion fluid in order to provide formation over -balance and maintain wellbore stability while running completions. If higher formation pressures are encountered the completion brine will be weighted up with sodium bromide or 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 and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5000 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 1 L-23 laterals we will target a constant BHP of 11.4 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 Page 3 of 7 May 9, 2018 PTD Application: 1L-2311-1, 1L-23L1-01, 1L-2311-1-02, & 1L-23L1-03 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. Pressure at the 1 L-23 Window 9845' MD, 6019' TVD Using MPD Pumps On 1.8 b m Pumps Off Formation Pressure 10.6 3318 psi 3318 psi Mud Hydrostatic 8.6 2692 psi 2692psi" Annular friction i.e. ECD, 0.080 si/ft 788 psi 0 IDSi Mud + ECD Combined no chokepressure) 3480 psi overbalanced —162psi) 2692 psi underbalanced —626psi) Target BHP at Window 11.4 3568 psi 3568 psi Choke Pressure Required to Maintain Target BHP 88 psi 876 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 The 1L-23 CTD producer project targets the C sand to increase throughput and recovery in the I area. Four laterals will be drilled from the 1L-23 parent well in the C-sand, two to the west and two to the south. Nabors CDR3 will mill a 2.80" window off a wedge at 9845'. All laterals will be completed with 2-3/8" slotted liner from TD with the last lateral liner top located inside the production casing. Page 4 of 7 May 9, 2018 PTD Application: 1L-23L1, 1L-23L1-01, 1L-23L1-02, & 1L-23L1-03 Pre-CTD Work 1. Perform rig workover to run new 3-1/2" completion with space for a high expansion wedge and a backup tandem wedge. 2. Prep site for Nabors CDR3-AC. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. Set high expansion wedge. 3. IL-23L1 Lateral (C sand - West) a. Mill 2.80" window at 9845' MD. b. Drill 3" bi-center lateral to TD of 14400' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 10650' MD. 4. 1L-23L1-01 Lateral (C sand - West) a. Kickoff of the aluminum billet at 10650' MD. b. Drill 3" bi-center lateral to TD of 12250' MD. c. Run 2%" slotted liner with aluminum billet from TD up to 10080' MD. 5. 1L-23L1-02 Lateral (C sand - South) a. Kickoff of the aluminum billet at 10080' MD. b. Drill 3" bi-center lateral to TD of 15300' MD. c. Run 2%" slotted liner with aluminum billet from TD up to 10500' MD. 6. 1L-23L1-03 Lateral (C sand - South) - a. Kickoff of the aluminum billet at 10500' MD. b. Drill 3" bi-center lateral to TD of 12000' MD. c. Run 2%" slotted liner with deployment sleeve from TD up to 9840' MD. 7. Freeze protect, ND BOPE, and RDMO Nabors CDR3-AC. Post -Rig Work 1. Return to production. Page 5 of 7 May 9, 2018 PTD Application: 1L-23L1, 1L-23L1-01, 1L-23L1-02, & 1L-2311-1-03 Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are 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 valves. The swab valves are opened and the BHA is lowered in place via slick -line. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are 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 — 1 L-23 CTD laterals will be displaced to an overbalance completion fluid (as detailed in Section 8 "Drilling Fluids Program") prior to running liner. — While running 2%" slotted liner, a joint of 2%" 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 23/" rams will provide secondary well control while running 2%" liner. 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 grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1 B disposal facilities) or Prudhoe DS-4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). Page 6 of 7 May 9, 2018 PTD Application: 1L-231-1, 11--23L1-01, 1L-23L1-02, & 1L-23L1-03 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 (measured to KPA boundary at closest point) Lateral Name Distance 1 L-231-1 13120' 1 L-23L1-01 13500' 1L-2311-1-02 9320' 1 L-23L1-03 . 11990' — Distance to Nearest Well within Pool Lateral Name Distance Well IL-23L1 1574' 2E-07 1 L-23L1-01 1574' 2E-07 1L-23L1-02 469' 2E-07 1L-2311-1-03 469' 2E-07 16. Attachments Attachment 1: Directional Plans for 1 L-23L 1, 1 L-23L 1-01, 1 L-23L 1-02, and 1 L-23L 1-03 laterals. Attachment 2. Current Well Schematic for 1 L-23. Attachment3: Proposed Well Schematic for IL-23L1, 1L-23L1-01, 1L-23L1-02, and IL-23L1-03laterals. Page 7 of 7 May 9, 2018 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 1 L Pad 1 L-23 1 L-231-1-03 Plan: 1 L-23L1-03_wp01 Standard Planning Report 24 April, 2018 BER T, HES GEcompanv `- ConocoPhillips BA_ jtER ConocoPhillips Planning Report BAT a GE company Database: EDTAlaska Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 1 L Pad Well: 1 L-23 Wellbore: 1 L-2311-03 Design: 1 L-23 L 1-03_wp01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1 L-23 Mean Sea Level 1 L-23 @ 130.00usft (1 L-23) True Minimum Curvature Project Kuparuk River Unit, 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 Site Kuparuk 1 L Pad Site Position: Northing: 5,949,190.90usft Latitude: 70° 16' 19.650 N From: Map Easting: 539,916.78usft Longitude: 149° 40' 37.763 W Position Uncertainty: 0.00 usft Slot Radius: 0.000in Grid Convergence: 0.30 ° Well 1 L-23 Well Position +N/-S 0.00 usft Northing: 5,948,431.07 usft - Latitude: 70° 16' 12.176 N +E/-W 0.00 usft Easting: 539,924.55 usft Longitude: 149° 40' 37.655 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1L-23L1-03� Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2017 7/1/2018 16.98 80.86 57,457_ Design 1L-23L1-03_wp01 Audit Notes: Version: Vertical Section: Phase: PLAN Tie On Depth Depth From (TVD) +Nl-S +El-W (usft) (usft) (usft) 0.00 0.00 0.00 10, 500.00 Direction (I 135.00 Plan Sections Measured TVD Below 7 - Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100ft) (°/100ft) (°/100ft) (°) Target 10,500.00 92.37 203.08 5,876.91 -6,500.59 -4,378.58 0.00 0.00 0.00 0.00 10,628.00 79.09 195.33 5,886.43 -6,620.74 -4,420.52 12.00 -10.38 -6.06 210.00 10,810.00 90.40 176.54 5,903.22 -6,799.92 -4,438.87 12.00 6.21 -10.33 300.00 11,010.00 90.57 152.54 5,901.51 -6,991.27 -4,385.94 12.00 0.08 -12.00 270.50 11,150.00 90.54 135.74 5,900.14 -7,104.32 -4,304.21 12.00 -0.02 -12.00 270.00 11,550.00 90.36 183.74 5,896.77 -7,468.67 -4,169.70 12.00 -0.04 12.00 90.00 12,000.00 90.21 129.74 5,894.32 -7,866.94 -3,998.47 12.00 -0.03 -12.00 270.00 412412018 5:15:16PM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips BVER ConocoPhillips Planning Report 11 IGHES a GE company Database: EDT Alaska Sandbox Local Co-ordinate Reference: Well 1 L-23 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 L-23 @ 130.00usft (1 L-23) Site: Kuparuk 1L Pad North Reference: True Well: 1L-23 Survey Calculation Method: Minimum Curvature Wellbore: 1L-23L1-03 Design: 1 L-23L1-03_wp01 �( Planned Survey Measured TVD Below' Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +NI-S +E/-W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100ft) (°) (usft) (usft) 10,500.00 92.37 203.08 5,876.91 -6,500.59 -4,378.58 1,500.48 0.00 0.00 5,941,907.99 535,580.94 TIP/KOP 10,600.00 81.99 197.06 5,881.82 -6,594.22 -4,412.82 1,542.49 12.00 -150.00 5.941,814.18 535,547.20 10,628.00 79.09 195.33 5,886.43 -6,620.74 -4,420.52 1,555.79 12.00 -149.70 5,941,787.63 535,539.64 Start 12 dls 10,700.00 83.49 187.81 5,897.34 -6,690.40 -4,434.75 1,594.98 12.00 -60.00 5,941,717.90 535,525.78 10,800.00 89.77 177.56 5,903.24 -6,789.94 -4,439.39 1,662.09 12.00 -58.86 5,941,618.35 535,521.67 10,810.00 90.40 176.54 5,903.22 -6,799.92 -4,438.87 1,669.52 12.00 -58.25 5,941,608.37 535,522.24 3 10,900.00 90.49 165.74 5,902.52 -6,888.71 -4,425.03 1,742.09 12.00 -89.50 5.941,519.66 535,536.56 11,000.00 90.56 153.74 5,901.61 -6,982.35 -4,390.46 1,832.75 12.00 -89.58 5,941,426.22 535,571.62 11,010.00 90.57 152.54 5,901.51 -6,991.27 -4,385.94 1,842.25 12.00 -89.69 5.941,417.32 535,576.19 4 11,100.00 90.56 141.74 5,900.62 -7,066.75 -4,337.17 1,930.10 12.00 -90.00 5,941,342.11 535,625.34 11,150.00 90.54 135.74 5,900.14 -7,104.32 -4,304.21 1,979.97 12.00 -90.11 5,941,304.72 535,658.50 5 11,200.00 90.54 141.74 5,899.67 -7,141.88 -4,271.25 2,029.84 12.00 90.00 5,941,267.34 535,691.66 11,300.00 90.52 153.74 5,898.74 -7,226.28 -4,217.97 2,127.20 12.00 90.06 5,941,183.23 535,745.38 11,400.00 90.47 165.74 5,897.88 -7,319.92 -4,183.40 2,217.85 12.00 90.17 5,941,089.79 535,780.44 11,500.00 90.40 177.74 5,897.11 -7,418.70 -4,169.06 2,297.84 12.00 90.27 5,940,991.09 535,795.31 11,550.00 90.36 183.74 5,896.77 -7,468.67 -4,169.70 2,332.72 12.00 90.36 5,940,941.13 535,794.93 6 11,600.00 90.36 177.74 5,896.46 -7,518.64 -4,170.34 2,367.61 12.00 -90.00 5,940,891.16 535,794.56 11,700.00 90.35 165.74 5,895.84 -7,617.42 -4,155.99 2,447.60 12.00 -90.04 5,940,792.46 535,809.43 11,800.00 90.32 153.74 5,895.26 -7,711.06 -4,121.42 2,538.25 12.00 -90.11 5,940,699.02 535,844.49 11,900.00 90.27 141.74 5,894.75 -7,795.46 -4,068.14 2,635.61 12.00 -90.18 5,940,614.91 535,898.21 12,000.00 90.21 129.74 5,894.32 •-7,866.94 -3,998.47 2,735.42 12.00 -90.24 5,940,543.80 535,968.25 Planned TD at 12000.00 412412018 5:15.16PM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Planning Report B F�UGHES il a GE company Database: EDTAlaska Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 1 L Pad Well: 1 L-23 Wellbore: 1 L-231-1-03 Design: 1 L-23L1-03_wp01 Targets Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1 L-23 Mean Sea Level 1 L-23 @ 130.00usft (1 L-23) True Minimum Curvature Target Name hit/miss target Dip Angle Dip Dir. TVD +NI-S +EI-W Northing Easting Shape (1) C) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 1L-23 CTD Polygon Nor 0.00 0.00 0.00 -12,103.031,136,059.79 5,942,355.00 1,675,921.00 70' 0' 17.325 N 140' 34' 43.175 W plan misses target center by 1140081.36usft at 12000.00usft MD (5894.32 TVD,-7866.94 N,-3998.47 E) Polygon Point 1 0.00 0.00 0.00 5,942,355.00 1,675,921.00 Point 2 0.00 -344.77 519.25 5,942,013.02 1,676,442.02 Point 3 0.00 -746.82 141.09 5,941,609.01 1,676,066.04 Point 0.00 -1,118.58-484.93 5,941,233.97 1,675,442.06 Point 5 0.00 -1,303.40-1,474.01 5,941,043.93 1,674,454.07 Point 0.00 -499.96-4,967.18 5.941,828.75 1,670,957.03 Point 0.00 1,232.92-4,337.01 5,943,564.78 1,671,577.94 Point 8 0.00 -181.49-672.03 5,942,169.97 1,675,250.01 Point 9 0.00 0.00 0.00 5,942,355.00 1,675.921.00 1L-231-1-03 T01 0.00 0.00 5.903.00 -13,062.161,135,686.66 5,941,394.00 1,675,553.00 70° 0' 8.556 N 140° 34' 57.857 W plan misses target center by 1139696.97usft at 12000.O0usft MD (5894.32 TVD,-7866.94 N,-3998.47 E) Point 1L-23L1_Fault2 0.00 0.00 5,897.00 -12,533.331,134,788.36 5,941,918.00 1,674,652.00 70° 0' 15.003 N 140° 35' 21.089 W plan misses target center by 1138796.39usft at 12000.00usft MD (5894.32 TVD,-7866.94 N,-3998.47 E) Polygon Point 1 5,897.00 0.00 0.00 5,941,918.00 1,674,652.00 Point 5,897.00 1.00 1.00 5,941,919.01 1,674,652.99 1L-231-1-02_Faultl_M 0.00 0.00 0.00 -15,728.221,136,772.64 5,938,734.00 1,676,653.00 69° 59' 41.081 N 140° 34' 38.431 W plan misses target center by 1140813.42usft at 12000.00usft MD (5894.32 TVD,-7866.94 N,-3998.47 E) Rectangle (sides W1.00 H2,000.00 D0.00) 11--231-1-03 T03 0.00 0.00 5,894.00 -14.162.61 1,136,125.87 5,940,296.00 1,675,998.00 69° 59' 57.229 N 140° 34' 50.093 W plan misses target center by 1140141.72usft at 12000.O0usft MD (5894.32 TVD,-7866.94 N,-3998.47 E) Point 1L-23L1_Fault1 0.00 0.00 5,889.00 -12,671.301,135,533.71 5,941,784.00 1,675,398.00 70° 0' 12.575 N 140° 35' 0.528 W plan misses target center by 1139542.31 usft at 12000.O0usft MD (5894.32 TVD,-7866.94 N. -3998.47 E) Polygon Point 1 5,889.00 0.00 0.00 5,941,784.00 1,675,398.00 Point 2 5,889.00 1.00 1.00 5,941,785.01 1,675,398.99 1L-231-1-03 T02 0.00 0.00 5,899.00 -13,544.441,135,918.13 5,940,913.00 1,675,787.00 70° 0' 3.535 N 140° 34' 53.348 W plan misses target center by 1139930.73usft at 12000.00usft MD (5894.32 TVD,-7866.94 N,-3998.47 E) Point 1L-231-1_Fault2_M 0.00 0.00 0.00 -12,533.331,134,788.36 5,941,918.00 1,674,652.00 70° 0' 15.003 N 140° 35' 21.089 W plan misses target center by 1138811.65usft at 12000.00usft MD (5894.32 TVD,-7866.94 N,-3998.47 E) Rectangle (sides W10.00 H2,000.00 D0.00) 1L-23 CTD Polygon Sou 0.00 0.00 0.00 -12,473.541,135,582.77 5,941,982.00 1,675,446.00 70' 0' 14.424 N 140° 34' 58.292 W plan misses target center by 1139605.79usft at 12000.00usft MD (5894.32 TVD,-7866.94 N,-3998.47 E) Polygon Point 1 0.00 0.00 0.00 5,941,982.00 1,675,446.00 Point 0.00 -676.75-251.58 5,941,303.99 1,675,198.04 Point 3 0.00 -1,859.21 1.23 5,940,123.01 1.675,457.09 Point 0.00 -2,051.23 380.27 5,939,933.02 1,675,837.11 Point 5 0.00 -2,442.92 314.20 5,939,541.02 1,675,773.12 Point 6 0.00 -5,424.97 1,020.62 5,936,563.05 1,676,495.28 Point 7 0.00 -4,717.35 3,012.56 5,937,281.16 1,678,483.24 Point 0.00 -3,504.28 1,692.78 5,938,487.09 1,677,157.18 Point 9 0.00 -675.70 689.53 5,941,310.03 1,676,139.04 Point 10 0.00 -175.10 777.17 5,941.811.04 1,676,224.01 Point 11 0.00 236.83 417.29 5,942,221.02 1,675,861.99 Point 12 0.00 0.00 0.00 5,941,982.00 1,675,446.00 1L-231-1-02_Faultl 0.00 0.00 5,940.00 -15,728.221,136,772.64 5,938,734.00 1,676,653.00 69° 59' 41.081 N 140° 34' 38.431 W 412412018 5:15:16PM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips Database: EDTAlaska Sandbox Company: ConocoPhillips (Alaska) Inc -Kup2 Project: Kuparuk River Unit Site: Kuparuk 1 L Pad Well: 1 L-23 Wellbore: 1 L-231-1-03 Design: 1 L-23L1-03_wp01 ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1 L-23 Mean Sea Level 1 L-23 @ 130 00usft (1 L-23) True Minimum Curvature B t IGHES a GE company plan misses target center by 1140798.20usft at 12000.00usft MD (5894.32 TVD,-7866.94 N,-3998.47 E) Polygon Point 1 5,940.00 0.00 0.00 5,938,734.00 1,676,653.00 Point 2 5,940.00 1.00 1.00 5,938,735.01 1,676,653.99 1L-23L1_Faultl_M 0.00 0.00 0.00-12,671.301,135,533.71 5,941,784.00 1,675,398.00 70' 0' 12.575 N 140' 35' 0.528 W plan misses target center by 1139557.56usft at 12000.00usft MD (5894.32 TVD,-7866.94 N,-3998.47 E) Rectangle (sides W10.00 1-11,500.00 D0.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 12,000.00 5,894.32 2 3/8" 2375 3.000 Plan Annotations Measured Vertical Depth Depth (usft) (usft) 10,500.00 5,876.91 10,628.00 5,886.43 10,810.00 5,903.22 11,010.00 5,901.51 11,150.00 5,900.14 11,550.00 5,896.77 12,000.00 5,894.32 Local Coordinates +N/-S +E/-W (usft) (usft) Comment -6,500.59 -4,378.58 TIP/KOP -6,620.74 -4,420.52 Start 12 cis -6,799.92 -4,438.87 3 -6,991.27 -4,385.94 4 -7,104.32 -4,304.21 5 -7,468.67 -4,169.70 6 -7,866.94 -3,998.47 Planned TD at 12000.00 412412018 5:15:16PM Page 5 COMPASS 5000.14 Build 85 Baker Hughes INTEQ BA_ I(ER ConocoPhillips Travelling Cylinder Report IGHES BAT GE company Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 1 L Pad Site Error: 0.00 usft Reference Well: 1 L-23 Well Error: 0.00 usft Reference Wellbore 1L-231_1-03 Reference Design: 1L-23L1-03_wp01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1 L-23 1 L-23 @ 130.00usft (1 L-23) 1 L-23 @ 130.00usft (1 L-23) True Minimum Curvature 1.00 sigma OAKEDMP2 Offset Datum Reference 1L-23L1-03_wp01 Filtertype: GLOBAL FILTERAPPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 10,500.00 to 12,000.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,387.00 usft Error Surface: Pedal Curve Survey Tool Program Date 4/12/2018 From To (usft) (usft) Survey (Wellbore) Tool Name Description 200.00 9,800.00 1L-23 (1L-23) GCT-MS Schlumberger GCT multishot 9,800.00 10,080.00 10, 080.00 1 L-23 L 1 _wp02 (1 L-23 L 1) 10,500.00 1L-23L1-02_wp01 (1L-23L1-02) M WD MVVD M WD - Standard MWD- Standard 10,500.00 12,000.00 1L-23L1-03_wp01 (11-2311-03) MWD MWD- Standard - - Casing Points -- ---- -- -- --- _ Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name () (11) 12,000.00 6,024.32 2 3/8" 2-3/8 3 Summary Site Name Offset Well - Wellbore - Design Kuparuk 1 L Pad 1 L-17 - 1 L-17A - 1 L-17A 1L-23- 1L-231_1 - 1L-231_1_wp02 1 L-23 - 1 L-23 L 1-01 - 1 L-23 L 1-01 _wp04 1 L-23 - 1 L-231_1-02 - 1 L-231_1-02_wp01 1 L-24 - 1 L-24 - 1 L-24 1 L-24 - 1 L-24A - 1 L-24A 1 L-24 - 1 L-24AL 1- 1 L-24AL 1 1 L-24 - 1 L-24AL 1-02 - 1 L-24AL 1-02 1 L-24 - 1 L-24AL 1-02P B 1- 1 L-24AL 1-02P B 1 1 L-24 - 1 L-24APB1 - 1 L-24APB1 1 L-25 - 1 L-25 - 1 L-25 1 L-25 - 1 L-25A - 1 L-25A 1 L-25 - 1 L-25ALl-01 - 1 L-25ALl-01 1 L-25 - 1 L-25AL 1-01 P B 1- 1 L-25AL 1-01 P B 1 1 L-25 - 1 L-25ALl-02 - 1 L-25ALl-02 1 L-25 - 1 L-25AL 1 -02PB2 - 1 L-25ALl-02PB2 1 L-25 - 1 L-25APB1 - 1 L-25APB1 Kuparuk 2E Pad 2E-05 - 2E-05 - 2E-05 2E-07 - 2E-07 - 2E-07 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warring Depth Depth Distance (usft) from Plan (usft) (usft) (usft) (usft) Out of range 10,502.07 10,700.00 321.18 1.87 319.31 Pass - Minor 1/10 10,503.62 10,700.00 320.31 1.88 318.43 Pass - Minor 1/10 10,806.46 10,800.00 45.04 1.23 44.01 Pass - Minor 1/10 Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range 12,000.00 9,825.00 515.76 335.45 191.43 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 4/12/2018 4:42:44PM Page 2 COMPASS 5000.14 Build 85 z �Z6 �QNo g> � a N � o Y Y ' �y 2 2 J N M xh YYr�o p�3aa1 a 3.- M J 0. N o O �-1 N N M N a o a F c 0 1 S g a w? _ O 0 � N m "1 ^ v N a N N m a J 0 a .a I a a - a N � J I O O 0 0 O 0 O 0 O O 0 0 O 0 O 0 O 0 O o 0 0 O 0 O 0 O 0 O 0 (ui/$sn 009) (+)uuuN/(-)ulnOS ) 600 1200 1800 2400 3000 3600 4200 C 4800 5400 + v R 5000 5600 7200 7800 3400 )000 )600 10200 10800 � � Q � L, c ti J M O V rn 0 0 Cl m N 0 CO a F- m0� a� O Y C c CL m m ¢Hints �.n ,.od v p� 1`t[JNO� V Cn 0 6 i N C n N U Z > t2 t2'R �2 N N �o CO Cl)(d ti � a I O O O O O O O 0 0 0 0 LO0 0 0 N J N J ~ d' O ti f r co N M N N N rn0000000 o a, o o o o 0 0 0 ~ 0 C'j r .N- C-� ?) oON I� C'r OIL LO L1J a0 0 N u) ch W CT C I!) I�NMaOOcfl O] N N M Cn —1 LL Q C3) CO LQI-Cn N M 10m LO Zoom r.�mc W + ON O)(,, p) Oc[J c0 .J Cn'-MNr V' INN W Cl! rnt` cfl c cn000wrn o E > ooCl al c 0 r � p) L f) ('��tDN l(J M Cn �2 �2 �R T LU O + 0 o 0 0 0 0 0 0 o 0 0 0 0 0 0 O° 0 0 0 0 0 0 C, cN0 a 0 0 t2 1 0 O_ O s - r_ N W c) _O C� UrNM V U]CO (� Zo ID a a w NI a 0 0 0 0 0 EO'CEO-11I Z-111 N a c r c �:7 0.. Z £0-I'ItZ-11-- -------- - N O:t W wi ---- .a --- � 9 a a � N N � _ 6450 6300 6150 6000 5850 5700 5550 5400 5250 5100 4950 4800 4650 4500 4350 4200 4050 p 3900 - CD C) 3750 If) 3600 C 3450 U 3300 Cn 3150 a� 3000 2850 2700 2550 2400 2250 2100 1950 1800 1650 1500 1350 1200 1050 900 750 O O O O O O O O O O J N (ui/ljsn OS[) g1daQ poilian aniy IW � -C »a >0 0 E 0 ( gmoS)(+)oNl(-)glos 2 / \ X-- KUP PROD 1L-23 ConoeoPhillips Alaska, Inc. • ell Attributes Max Angle & MD TD Walla—API/UWI 500292216700 Field Name KUPARUK RIVER UNIT Wellbore Slalus PROD nd C) MD(ftKe) Act 62.82 3,100.00 Htm IRKH) 1Q346.0 Comment H2S SSSV: TRDP (ppm) Data 20 12/21/2015 Annotation End LasI WO: Data KB-Grd (tl) Rig Release Data 8/24/1992 42.99 5/14/1991 iL-23,4/25/20185:51:43AM Last Tag Vertical schematic actual Annotation Depth Last Tag: RKB 10,147.0 (RKB) End 4/21/2018 Data Last fergusp Mod By HANGER; 39.4 CONDUCTOR; 44.0-78 0 SAFETYVLV; 1,978.1 GAS LIFT; 2,057.E GAS LIFT; 3,779.8 GAS LIFT; 4,938.2 SURFACE; 43.0-5,306.3- GAS LIFT; 5.815.0 GAS LIFT; 6,716.5 GAS LIFT; 7,707.3 GAS LIFT; 8,671.2 GAS LIFT; 9,588 3 CHEM CUT; 9,616.0 PBR; 9,638 U PACKER; 9,651.7 NIPPLE; 9,668.0 SOS; 9,700.9 APERF; 9,794.0-9,874.0 RPERF;9,796.0-9,874.0� IPERF; 10,012 0-10,050 0 FRAC; 10:012:0 a RPERF; 10,012.0.10,050.0 FISH; 10,060.0 IPERF; 10,1 10,165.0 FRAC; AC; 10,156.0 PRODUCTION; 43.2-10,342.9 Last Rev Reason Annotation End Dale Laat Mad By Rev Reason: Cut Tbg 4/24/2018 condijw I I Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) Tap 15.060 (RKB) 44.0 Set Depth (kKB) Sel Depth 78.0 (TVD)... WlLen 78.0 (I... 62.58 Gratle H-40 Top Thread WELDED Casing Description SURFACE OD (in) 95/8 ID (in) Top 8.921 (RKB) 43.0 Set Depth (ftK8) Set Depth 5,306.3 (TVD)... WVLen 3,609.3 (I... 36.00 J-55 Gratle Top Thre rd BTC Casing Description PRODUCTION OD (in) 7 ID (in) I Top 6.276 (RKB) 43.2 Set Depth (kKB) Set Depth 10,342.91 (TVD)...I WtlLen 6,289.71 (I 1131de 26.00 J-55 Top Thread BTC-MOD Tubing Strings Tubing Description String Mjl; . ID (in) Top (ftK8) Sol Depth (ft.. Sel Depth (TVD) (... Wl (Ibkl) Grade Top Connection TUBING WO 3 1/2 2.992 39.4 9,701.8 5,942.3 9.30 J-55 EUEBrd=D Completion Details Top (kKB) Top (TVD) (RKB) Top Intl r; It.. Des Com Nominal ID (in) 39.4 39.4 0.03 HANGER FMC GEN IV TUBING HANGER 3,500 1,978.1 1,833.4 41.30 SAFETY VLV CAMCO TRDP-4A-RO SAFETY VALVE 2.812 9,638.0 5,908.3 57.89 PBR BAKER PBR 3.000 9,651.7 5,915.6 57.86 PACKER BAKER HB RETRIEVABLE PACKER 2.890 9,668.0 5,924.3 57.82 NIPPLE CAMCO D NIPPLE SEAL BORE NO GO ((rouble getting 20' Ped Guns thru D-nipple 911192; REPERF 9/2/92) 2.750 9,700.9 5,941.8 57.73 SOS BAKER SHEAR OUT SUB 2.992 Other In Hole (Wirellne retrievable plugs, valves, pumps, fish, etc.) Top (kKB) Top (TVD) (ftK8) Top Intl (°) Des Co. Run Date ID (in) 9,616.0 5,896.E 57.95 1 CHEM CUT CUT TUBING W/ 2.625" OD CHEMICAL CUTTER 4I24/2018 1.994 10,060.0 6,135.8 57.39 FISH 1 1/2" GLV Fell to Rathole 4/6/1995 1 0.000 - Perforations & Slots Tap (RKB j Btm ftNB ( ) ToftKB D) ( ) FilmKB O) ) Zane Shot Den Dale (sh )"SIN 1 Type Com 9,794.0 9,874.0 5,991.9 6,035.2 C-4, iL-23 8/17/1991 6.0 APERF 2 1/8" Flow Jet; 0 deg. phasing 9,796.0 9,874.0 5,992.9 6,035.2 C-4, -23 UNIT B, I 9/2/1992 4.0 RPERF 2.5" Hollow Came; 180 deg. ph; Oriented 14 deg. CCW 10,012.0 10,050.0 6,110.0 6,130.5 A-5,1L-23 3/29/2018 6.0 RPERF 2.0"OD POWERJET OMEGA, 6 SPF, 60 DEG PHASED. 10,012.0 10,050.0 6,110.0 6,130.5 A-5,1L-23 6/19/1991 4.0 IPERF 4112" Carrier; 180 deg. ph; Oriented 12 deg. CCW 10,156.0 10,165.0 6,18Z7 6,192.5 A-4,1L-23 6/19/1991 4.0 IPERF 4112" Carrier; 180 deg. ph; Oriented 12 deg. CCW Stimulations & Treatments Proppant Designed (lb) Proppant In Fonnaticn (Ib) Date 8/t11991 Stimulations & Treatments It # op(kK8) T Btm (kK8) Data Slim/Treat Fluid Vol Clean Pump (bbl)Vol Slurry (bbl) 11 10,156.01 10,165.0 8/111991 Proppant Designed (III) Proppant In Formation (Ib) Da[e 81111991 Stimulations & Treatments Stg M Top (kK8) Btm (kKB) Date StinVTreal Fluid Vol Clean Pump (bbl) Vol Slurry (bbl) 1 10,012.0 10,050.0 8/1/1991 Mandrel Inserts St on ati N Top (IRKS) Top (TVD) (kKBI Make Model OD (in) Sam Valve Latch Type Type Port Sim (in) TRO Run (psi) Run Date Co. 1 2,057.6 1,892.3 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 4/222018 2 3,779.8 2,805.1 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 12/14/1992 3 4,938.2 3,406.4 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 4/212018 4 5,815.0 3,899.6 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 9/19/2005 5 6,716.5 4,397.2 MMH FMHO 1 S LIFT DMY BK 0.000 0.0 4/212018 6 7,707.3 4,905.5 MMH FMHO 1 DMY BK 0.000 0.0 4/212018 7 8,671.2 5,402.E MMH FMHO 1 !GAS �LIFT DMY BK2 0.000 0.0 8/8/2005 8 95883 5,881.9 CAMCO MMG-2 1 1/2 OPEN IRK 0.0 4/22/2018 Notes: General & Safety End Date I Annotation 10/5/2010 NOTE: View Schematicwl Alaska Schematic9.0 \ / : _ E e C) m r) � U � _ § 0- 0 a_ S � � � § �\ _�\ -� / \// (/\ aoo aoo E 5 E _ \ \ 0 EK / f / \ \[ / ) co w \\ cc 2 § / f �- co ) \ § * k [ )\ _ \ = Gi f } ( §k 0 § _§ _; \ k § k ; _ o k /§ _ \ - } c _ \j) j 2} j \ ^^ k §# ) 0 i 11 / TRANSMITTAL LETTER CHECKLIST WELL NAME: JCS, lZ -'2-3L1 d--S 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 The permit is for a new wellbore segment of existing well Permit LATERAL No. / - - 66 Z--, API No. 50- 2_Z&,7-4: I'D- [n. (If last two digits Production should continue to be reported as a function of the original 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. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception 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: production or production testing of coal bed methane is not allowed for Non -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 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 within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 PTD#:2180600 Coml Administration —17 1 Appr Date SFD 5/14/2018 Engineering Appr Date VTL 5/29/2018 Geology Appr Date SFD 5/14/2018 4 5 6 7 8 9 10 11 12 13 14 15 16 Initial Well Name: KUPARUK RIV UNIT 1L-231-1-03 Program DEV _-- Well bore seg :ND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Nonconven. gas conformstoAS31.05.030(l.1_.A),Q.2.A-D) - - - - - - - - - - - - - - - - - NA_ - - - _ _ - _ _ _ _ _ _ _ _ _ _ - _ - _ _ _ _ _ - - - - - - - _ _ - - - - - - - - - Permitfeeattached- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - ----------------------------------------- Lease number appropriate_ _ _ - _ _ Yes - . - _ _ - Top -Productive Interval & TD lie in_ADL0025664. - - - - - - - - - - Uniquewell name and numb er- - - - - - - - - - - - - - - - - - - - - - - - - - _ Yes. - - - - _ Well located in_a_defined_pool- - - - - - - - Yes - - - - Kuparuk River Oil Pool, governed by Conservation Order No. 432D - - - _ ---------------------- Well located proper distance from drilling unit_boundary_ - - - - - - - - Yes - - - - - - - Conservation Order No. 432D has no interwell- spacing_restrictions. Wellbore_will_ be more than 500' from - _ _ _ - - Well located proper distance from other wells- - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - an external property line_where-ownership or landownersho_changes. As proposed, -well will_ - Sufficient acreage_avail_able in_dril_ling unit_ - - - _ _ _ - - - Yes - - - conform to_spacing-requirements. If -deviated, is wellbore plat -included - - - - - _ _ - Yes - - _ . - - - . - - _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Operator only affected party - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - Operator has -appropriate bond in force - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - Permitcanbeissuedwithoutconservationorder_ - - Yes- - - - - - - - - - - - - - - - - - - - - - - - - - - ----- ---- - - - - - Permit can be issued without administrativ_e_approval - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Can permit be approved before 15-day wait_ - - - - - - - _ _ _ Yes -------------------------------------------- Well located within area and -strata authorized by Injection Order # (put_ 10# in_comments)_ (For-! NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - All wells -within _1/4_mile area of review identified (For service well only) - NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ _ - _ - - - - - Pre -produced injector: duration of pre production Less than 3 months_ (For service well only) - NA_ _ _ _ _ _ _ _ _ _ _ - ----------------------------------------------- 18 Conductor string- provided - - - - - - _ NA_ _ _ - - _ _ _ Conductor set-in KRU 1L-23 _ _ _ - - - 19 Surface casing, protects all -known USDWs - - - - - - - - - - - - N_A_ Surface casing set in KRU 1 L-23 20 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_ - - - - - - - Pr_oductiv_e_interval will be completed with _uncemented slotted liner_ .... 23 Casing designs adequate for C,_T, B &_ permafrost_ - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ - _ - - - - - - _ _ _ _ - - - - - - 24 Adequate -tankage _orreserve pit - - -- - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes- - - . - --Righassteeltanks;allwaste_toapproveddisposalwells_ _ - - - - - - - - - - - - - - - -- - - - - - - - - _ - - - 25 If_a_re-drill_, has_a 10-403 for abandonment been approved - - - - NA_ - - - - - _ - - - - - - - - - - - - - - - 26 Adequate wellbore separation _proposed _ - - - - - - - - - - - - Yes - - - Anti -collision analysis complete; no major risk failures - - . - - - - - - - - - - - - - - - - - - - - - - - - - - - - 27 If_diverter required, does it meet regulations_ _ _ _ - _ - - NA_ - ------------------------------------------------------------------------- 28 Dulling fluid_ program schematic & equip -list -adequate - - - - - - - - - Yes Max fromation_ pressure is_4393 psig(13.3 ppg-EMW); will drill_w/ 8.6_ppg EMW and -maintain ov_erbal_w/ MPD - - - 29 BOPEs,_do they meet regulation - - - - - - - - - - - - - - - - - - - - Yes -------------------- ---- 30 BOPE_press rating appropriate; test to -(put psig in comments).. ------------ Yes - MPSP is 3760 psig; will test BOPs_to 4000_psig - - - - - _ - _ - - - - - - - 31 Choke manifold complies w/API_RP-53 (May 84)- - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . - - - - - - - - - - 32 Work will occur without operation shutdown_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 33 Is presence of 112S 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_ - - Wells _on_1L-Pad are H2S-bearing._H2S_measures required._ - - - - - - - _ - - - - - - _ _ _ _ _ _ - - - - - - 36 Data- presented on potential overpressure zones - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - Expected r_eservoirpressure is 10.6ppg EMW_(with a maximum of_13,3_ppg EMW)._ Well will be _ _ _ _ - - - - 37 Se ismic_analysis_ of shallow gas_zones- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA_ drilled using 8.6_ppg _m_ud,_a coiled -tubing rig, and_ managed_pressure drilling technique to _ - - _ _ _ _ _ - - - 38 Seabed condition survey (if off -shore) - _ _ _ _ _ _ _ _ _ NA_ - _ - - _ control formation pressures -and maintain -shale stability. - _ _ _ _ - _ - - - - - - - - - - - - - - 39 Contact name/phone for weekly -progress reports- [exploratory only] - - - - - - - - - - - - - - - - NA_ - - - _ - - _ Onshore development well branch, _ _ _ - - - _ - - - - - - _ - _ _ _ _ _ _ - - - . _ - - - _ - - _ - - - - - - - - Geologic Engineering Public Commissioner: Date: Commissioner: Date C sio Date ors S 13,1 l ,