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Home My WebLink About218-0681. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ______________________ Development Exploratory 3. Address: Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 15,680 feet N/A feet true vertical 15,165 feet N/A feet Effective Depth measured 15,512 feet 12,832 feet true vertical 14,999 feet 12,498 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.3# / L-80 12,940' MD 12,598' TVD Packers and SSSV (type, measured and true vertical depth) DHL Hydr Ret Pkr; NA 12,832' MD 12,498' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: Chad Helgeson, Operations Engineer 323-016 Sr Pet Eng: 8,540psi Sr Pet Geo: Sr Res Eng: WINJ WAG 70 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 chelgeson@hilcorp.com 907-777-8405 N/A Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 147 Gas-Mcf MD 480 Size 432' 0 480146 105 1030 147 9-5/8" 9,020psi 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 218-068 50-133-20262-02-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEDA028083 Beaver Creek / Beaver Creek Oil Pool Beaver Creek Unit (BCU) 05RD2 Plugs Junk measured Length measured true vertical Liner Liner 11,698' 3,387' 2,718' Casing Structural 11,471' 13,778' 4-1/2" 11,698' 14,238' 15,652' 15,138' 432'Conductor Surface Intermediate 20" 13-3/8" 432' 3,511' TVD 5,300psi 10,780psi 1,530psi 3,090psi 9,440psi 12,460psi 3,511' 3,511' Burst Collapse 520psi 1,540psi measured Packer p k ft t Fra O s O 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Samantha Carlisle at 3:33 pm, Feb 21, 2023 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2023.02.21 15:15:58 -09'00' Dan Marlowe (1267) Rig Start Date End Date 1/26/23 1/27/23 01/26/2023 - Thursday YJ Eline on location. Open PTW & PJSM. Begin rig up, spot in equipment. Make up lubricator and BHA #1. Stab on lubricator. PT to 350/3500, pass. Well flowing @ 106 psi. RIH w/ 6.3' x 1.69" GR/CCL, 2' x 1.69" Shock Sub, 24' x 2 1/2" Geo Razor guns w/ 2 3/8" LS charges. 11.5' CCL to top shot. Tag bottom @ 15438'. Pull correlation pass, on depth. CCL stop depth = 15294.5' Shoot zone G2A, 15306' - 15,330'. FTP = 114 psi, 5 min = 115, 10 min = 115, 15 min = 114. POOH. Lay down BHA. All shots fired. Well flowing @ 103 psi. RIH w/ 6.3' x 1.69" GR/CCL, 2' x 1.69" Shock Sub, 12' x 2 1/2" Geo Razor guns w/ 2 3/8" LS charges. 12.5' CCL to top shot. Tag bottom @ 15438'. Pull correlation pass, on depth. CCL stop depth = 15393.5' Shoot zone G2B, 15406' - 15418'. FTP = 98 psi, 5 min = 105, 10 min = 107, 15 min = 109. POOH. Lay down BHA. All shots fired. Well flowing @ 110 psi. RIH w/ 6.3' x 1.69" GR/CCL, 2' x 1.69" Shock Sub, 7' x 1.69" WB, 6' x 2 1/2" Geo Razor guns w/ 2 3/8" LS charges. 17.5' CCL to top shot. Tag bottom @ 15438'. Pull correlation pass, on depth. CCL stop depth = 15414.5' Shoot zone G2B, 15432' - 15438'. FTP = 97 psi, 5 min = 112, 10 min = 118, 15 min = 122. POOH. Lay down BHA. All shots fired. Lay down toolstring. Lay down lubricator. Secure well. LDFN. YJ Eline on location, start equipment, open PTW & PJSM. Make up BHA #4. Pick up lubricator and stab on well. Well flowing @ 120 psi. RIH w/ 6.3' x 1.69" GR/CCL, 2' x 1.69" Shock Sub, 16' x 2 1/2" Geo Razor guns w/ 2 3/8" LS charges. 11.5' CCL to top shot. Pull correlation pass, on depth. CCL stop depth = 14971.5'. Shoot zone G1B, 14983' - 14999'. FTP = 124 psi, 5 min = 131, 10 min = 129, 15 min = 130. POOH. Lay down toolstring. All shots fired. Begin rig down. Lay down lubricator and secure well. Move to BCU-04RD. 01/27/2023- Friday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BCU-05RD2 50-133-20262-02-00 218-068 _____________________________________________________________________________________ Updated by DMA 02-16-23 SCHEMATIC Beaver Creek Unit Well: BCU 05RD2 Completed: 10/24/18 PTD: 218-068 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20"Conductor N/A / N/A / N/A N/A Surface 432 13-3/8Surface 61/K-55/12.415 Surface 3,511 9-5/8"Production 47 / P110 / 8.681 Surface 11,698 7"Liner 32 / L-80 / 6.184 11,53114,238 4-1/2Liner 12.6 / L-80 / DWC/C 3.833 12,93415,652 TUBING DETAIL 3-1/2Tubing 9.3# / L-80 / EUE 2.992 Surface 12,940 JEWELRY DETAIL No Depth MD Depth TVD Item 1 2,5942,594GLM w/ live valve 2 4,5484,548GLM w/ live valve 3 5,9975,997Chemical Injection Mandrel 4 6,1986,198GLM w/ live valve 5 7,5537,553GLM w/ live valve 6 8,7498,745GLM w/ live valve 7 9,8389,790GLM w/ live valve 8 10,93110,788GLM w/ orifice 9 11,94111,689GLM w/ dummy (If used risk of 4-1/2 liner collapse at HPWZ @ 14,800) 10 12,81312,481GLM w/ dummy (If used risk of 4-1/2 liner collapse at HPWZ @ 14,800) 11 12,83212,4987 DLH Hydraulic Retrievable packer 12 12,84312,508X-Landing Nipple 13 12,934 12,592 HRD-E ZXP LTP w/ 5.25 PBR & Seal Assy 14 12,955 12,612 Flex-Lock Liner Hanger, HRD-E ZXPN LTP w/ 5.25 PBR PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status 4-1/2 Pipe 13,015 13,018 12,667 12,6703 10/9/18 Cemented G1B 14,983' 14,999' 14,477' 14,493' 16 1/27/23, 3/1/21 Open - Reperf G2A 15,306 15,316 14,795 14,80510 01/14/22 Open - Reperf G2A 15,320 15,330 14,809 14,81910 01/14/22 Open - Reperf G2A 15,306 15,330 14,795 14,81924 1/26/23, 2/5/21, 3/5/21, 10/20/18 Open - Reperf G2B 15,406' 15,418' 14,894' 14,906' 12 1/26/23, 2/5/21, 3/5/21, 3/29/21 Open - Reperf G2B 15,432 15,437 14,920 14,9255 3/5/21 Open G2B 15,432 15,442 14,930 14,93410 2/5/21 Open G2BL 15,432 15,43814,92014,9266 1/26/23, 1/26/22 Open - Reperf G2BL 15,432 15,456 14,920 14,93424 10/20/18 Open GENERAL WELL INFO API: 50-133-20262-02-00 Initial Completion - 10/1/1983 Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 02/07/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230207 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPE-17 50029226870000 196115 1/17/2023 YELLOW JACKET LDL CLU 10RD 50133205530100 222113 2/3/2023 YELLOW JACKET GPT-PERF BCU 04RD 50133202390100 219011 1/27/2023 YELLOW JACKET PERF BCU 04RD 50133202390100 219011 2/2/2023 YELLOW JACKET PERF BCU 05RD2 50133202620200 218068 1/26/2023 YELLOW JACKET PERF BCU 12A 50133205300100 214070 2/1/2023 YELLOW JACKET PLUG Please include current contact information if different from above. By Meredith Guhl at 9:51 am, Feb 07, 2023 T37492 T37492 T37493 T37494 T37495 T37496 BCU 05RD2 50133202620200 218068 1/26/2023 YELLOW JACKET PERF Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.02.07 10:08:10 -09'00' 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 15,680'N/A Casing Collapse Structural Conductor 520psi Surface 1,540psi Production 5,300psi Liner 10,780psi Liner 8,540psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Chad Helgeson, Operations Engineer chelgeson@hilcorp.com 907-777-8405 Noel Nocas, Operations Manager 907-564-5278 Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft):Tubing Size: 9.3 / L-80 12,940' January 25, 2023 DHL Hydr Ret Pkr & N/A 12,832 (MD) 12,498 (TVD) & N/A See Schematic See Schematic 3-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028083 218-068 50-133-20262-02-00 Beaver Creek Beaver Creek Oil Same CO 237D Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Beaver Creek Unit (BCU) 05RD2 Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 15,166'15,512'14,999'~3,070 psi N/A MD 9,440psi 1,530psi 3,090psi 432' 3,511' 11,471' 432' 3,511' 11,698' Perforation Depth MD (ft): 2,707' 4-1/2"2,718' 7" 9-5/8"11,698' 20" 13-3/8" 432' 3,511' 12,460psi13,778'14,238' 9,020psi15,652'15,138' m n P s 66 t _ Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Carlisle at 9:21 am, Jan 13, 2023 323-016 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361), ou=Users Date: 2023.01.12 19:38:44 -09'00' Noel Nocas (4361) SFD 1/13/2023 DSR-1/17/23 10-404 BJM 1/18/23GCW 01/18/23 JLC 1/18/2023 1/19/23Brett W. Huber. Sr.Digitally signed by Brett W. Huber. Sr. Date: 2023.01.19 08:27:07 -09'00' RBDMS JSB 011923 Well Prognosis Well Name: BCU-05RD2 API Number: 50-133-20262-02-00 Current Status: Producing Oil Well Leg: N/A Estimated Start Date: 1/25/23 Rig: E-Line Reg. Approval Req’d? 403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz Permit to Drill Number: 218-068 First Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Second Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (C) AFE Number: Maximum Expected BHP: ~8500 psi @ 14,477’ TVD (Based on offset G1B sand in BCU-04RD) Max. Potential Surface Pressure: ~3070 psi (Max expected BHP minus 0.375 psi/ft oil gradient) Well Status: Online (last test 12/31/22 @ 103 BOPD / 0 BWPD / 70 MCFD) @ 97 psi Brief Well Summary Well BCU-05RD2 was drilled and completed as a sidetrack of BCU-05RD in 2018. The BCU-05RD2 is completed in the Tyonek G2 sands and has produced a total of 207 MBO. The well IP’d at about 1200 bopd initially – but declined off very quickly and stabilized about 200 bopd until the last several months where it has been producing about 100-200 bopd. Multiple re-perfs and xylene treatments were completed to help overcome decline. The objective of this work is to re-perforate existing sands to increase production. Notes Regarding Wellbore Condition x Minimum ID is 2.81” x Last tag @ 15,440’ RKB w/ 2.125” x 10’ strip gun on 1/26/2022. Bailer full of greasy, oily gunk. Procedure: 1. MIRU E-line and pressure control equipment, PT lubricator 350L/3500H. 2. Re-perforate the Tyonek G sands with the well flowing. Zone Name Top Perf Depth MD Bottom Perf Depth MD Top Perf Depth TVD Bottom Perf Depth TVD Gun Length G1B (reperfs) ±14,983’ ±14,999’ ±14,478’ ±14,491’ ±16 G2A (reperfs) ±15,306’ ±15,330’ ±14,795’ ±14,819’ ±24 G2B (reperfs) ±15,406’ ±15,418’ ±14,892’ ±14,905’ ±12 G2B (reperfs) ±15,432’ ±15,456’ ±14,920’ ±14,943’ ±24 3. RD E-line. 4. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic _____________________________________________________________________________________ Updated by CAH 03/17/22 SCHEMATIC Beaver Creek Unit Well: BCU 05RD2 Completed: 10/24/18 PTD: 218-068 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20"Conductor N/A / N/A / N/A N/A Surface 432’ 13-3/8”Surface 61/K-55/12.415 Surface 3,511’ 9-5/8"Production 47 / P110 / 8.681 Surface 11,698’ 7"Liner 32 / L-80 / 6.184 11,531’14,238’ 4-1/2”Liner 12.6 / L-80 / DWC/C 3.833 12,934’15,652’ TUBING DETAIL 3-1/2”Tubing 9.3# / L-80 / EUE 2.992 Surface 12,940’ JEWELRY DETAIL No Depth MD Depth TVD Item 1 2,594’2,594’GLM w/ live valve 2 4,548’4,548’GLM w/ live valve 3 5,997’5,997’Chemical Injection Mandrel 4 6,198’6,198’GLM w/ live valve 5 7,553’7,553’GLM w/ live valve 6 8,749’8,745’GLM w/ live valve 7 9,838’9,790’GLM w/ live valve 8 10,931’10,788’GLM w/ orifice 9 11,941’11,689’GLM w/ dummy (If used risk of 4-1/2” liner collapse at HPWZ @ 14,800’) 10 12,813’12,481’GLM w/ dummy (If used risk of 4-1/2” liner collapse at HPWZ @ 14,800’) 11 12,832’12,498’7” DLH Hydraulic Retrievable packer 12 12,843’12,508’X-Landing Nipple (RHCP plug body loaded) 13 12,934’12,592’HRD-E ZXP LTP w/ 5.25” PBR & Seal Assy 14 12,955’12,612’Flex-Lock Liner Hanger, HRD-E ZXPN LTP w/ 5.25” PBR PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status 4-1/2” Pipe 13,015’13,018’12,667’12,670’3 10/9/18 Cemented G1B 14,983'14,999'14,477'14,493'16 3/1/21 Open G2A 15,306’15,316’14,795’14,805’10 01/14/22 Open - Reperf G2A 15,320’15,330’14,809’14,819’10 01/14/22 Open - Reperf G2A 15,306’15,330’14,795’14,819’24 2/5/21 Open G2A 15,306’15,330’14,795’14,819’24 3/5/21 Open G2A 15,306’15,330’14,795’14,819’24 10/20/18 Open G2B 15,406'15,418'14,894'14,906'12 2/5/21 Open G2B 15,406'15,418'14,894'14,906'12 3/5/21 Open G2B 15,406'15,418'14,894'14,906'12 3/29/21 Open G2B 15,432’15,437’14,920’14,925’5 3/5/21 Open G2B 15,432’15,442’14,930’14,934’10 2/5/21 Open G2BL 15,432’15,438’14,920’14,926’6’01/26/22 Open - Reperf G2BL 15,432’15,456’14,920’14,934’24 10/20/18 Open GENERAL WELL INFO API: 50-133-20262-02-00 Initial Completion - 10/1/1983 _____________________________________________________________________________________ Updated by CAH 01/12/23 PROPOSED Beaver Creek Unit Well: BCU 05RD2 Completed: 10/24/18 PTD: 218-068 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20"Conductor N/A / N/A / N/A N/A Surface 432’ 13-3/8”Surface 61/K-55/12.415 Surface 3,511’ 9-5/8"Production 47 / P110 / 8.681 Surface 11,698’ 7"Liner 32 / L-80 / 6.184 11,531’14,238’ 4-1/2”Liner 12.6 / L-80 / DWC/C 3.833 12,934’15,652’ TUBING DETAIL 3-1/2”Tubing 9.3# / L-80 / EUE 2.992 Surface 12,940’ JEWELRY DETAIL No Depth MD Depth TVD Item 1 2,594’2,594’GLM w/ live valve 2 4,548’4,548’GLM w/ live valve 3 5,997’5,997’Chemical Injection Mandrel 4 6,198’6,198’GLM w/ live valve 5 7,553’7,553’GLM w/ live valve 6 8,749’8,745’GLM w/ live valve 7 9,838’9,790’GLM w/ live valve 8 10,931’10,788’GLM w/ orifice 9 11,941’11,689’GLM w/ dummy (If used risk of 4-1/2” liner collapse at HPWZ @ 14,800’) 10 12,813’12,481’GLM w/ dummy (If used risk of 4-1/2” liner collapse at HPWZ @ 14,800’) 11 12,832’12,498’7” DLH Hydraulic Retrievable packer 12 12,843’12,508’X-Landing Nipple (RHCP plug body loaded) 13 12,934’12,592’HRD-E ZXP LTP w/ 5.25” PBR & Seal Assy 14 12,955’12,612’Flex-Lock Liner Hanger, HRD-E ZXPN LTP w/ 5.25” PBR PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status 4-1/2” Pipe 13,015’13,018’12,667’12,670’3 10/9/18 Cemented G1B 14,983'14,999'14,477'14,493'16 Proposed G1B 14,983'14,999'14,477'14,493'16 3/1/21 Open G2A 15,306’15,316’14,795’14,805’10 01/14/22 Open - Reperf G2A 15,320’15,330’14,809’14,819’10 01/14/22 Open - Reperf G2A 15,306’15,330’14,795’14,819’24 Proposed G2A 15,306’ 15,330’14,795’14,819’24 2/5/21, 3/5/21, 10/20/18 Open G2B 15,406'15,418'14,894'14,906'12 Proposed G2B 15,406'15,418'14,894'14,906'12 2/5/21, 3/5/21, 3/29/21 Open G2B 15,432’15,437’14,920’14,925’5 3/5/21 Open G2B 15,432’15,442’14,930’14,934’10 2/5/21 Open G2BL 15,432’15,438’14,920’14,926’6’01/26/22 Open - Reperf G2BL 15,432’15,456’14,920’14,934’24 Proposed G2BL 15,432’15,456’14,920’14,934’24 10/20/18 Open GENERAL WELL INFO API: 50-133-20262-02-00 Initial Completion - 10/1/1983 Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 2/15/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 05RD2 (PTD 218-068) Perf 01/26/2022 Please include current contact information if different from above. 37' (6HW Received By: 02/15/2022 By Abby Bell at 11:42 am, Feb 15, 2022 2SHUDWLRQV $EDQGRQ 3OXJ3HUIRUDWLRQV )UDFWXUH6WLPXODWH 3XOO7XELQJ 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ϭϭ͕ϵϰϭ͛ '>DǁͬĚƵŵŵǇ ϭϬ ϭϮ͕ϴϭϯ͛ '>DǁͬĚƵŵŵǇ ϭϭ ϭϮ͕ϴϯϮ͛ ϳ͟>,,ǇĚƌĂƵůŝĐZĞƚƌŝĞǀĂďůĞƉĂĐŬĞƌ ϭϮ ϭϮ͕ϴϰϯ͛yͲ>ĂŶĚŝŶŐEŝƉƉůĞ;Z,WƉůƵŐďŽĚǇůŽĂĚĞĚͿ ϭϯ ϭϮ͕ϵϯϰ͛,ZͲyW>dWǁͬϱ͘Ϯϱ͟WZΘ^ĞĂůƐƐǇ ϭϰ ϭϮ͕ϵϱϱ͛&ůĞǆͲ>ŽĐŬ>ŝŶĞƌ,ĂŶŐĞƌ͕,ZͲyWE>dWǁͬϱ͘Ϯϱ͟WZ WZ&KZd/KEd/> ^ĂŶĚƐdŽƉ ;DͿ ƚŵ ;DͿ dŽƉ ;dsͿ ƚŵ ;dsͿ&d ĂƚĞ^ƚĂƚƵƐ ϰͲϭͬϮ͟WŝƉĞ ϭϯ͕Ϭϭϱ͛ϭϯ͕Ϭϭϴ͛ϭϮ͕ϲϲϳ͛ϭϮ͕ϲϳϬ͛ϯ ϭϬͬϵͬϭϴ ĞŵĞŶƚĞĚ 'ϭ ϭϰ͕ϵϴϯΖ ϭϰ͕ϵϵϵΖ ϭϰ͕ϰϳϳΖ ϭϰ͕ϰϵϯΖ ϭϲ ϯͬϭͬϮϭ KƉĞŶ 'Ϯϭϱ͕ϯϬϲ͛ϭϱ͕ϯϯϬ͛ϭϰ͕ϳϵϱ͛ϭϰ͕ϴϭϵ͛Ϯϰ ϮͬϱͬϮϭ KƉĞŶ 'Ϯϭϱ͕ϯϬϲ͛ϭϱ͕ϯϯϬ͛ϭϰ͕ϳϵϱ͛ϭϰ͕ϴϭϵ͛Ϯϰ ϯͬϱͬϮϭ KƉĞŶ 'Ϯϭϱ͕ϯϬϲ͛ϭϱ͕ϯϯϬ͛ϭϰ͕ϳϵϱ͛ϭϰ͕ϴϭϵ͛Ϯϰ ϭϬͬϮϬͬϭϴ KƉĞŶ 'Ϯϭϱ͕ϰϬϲΖϭϱ͕ϰϭϴΖ ϭϰ͕ϴϵϰΖ ϭϰ͕ϵϬϲΖ ϭϮ ϮͬϱͬϮϭ KƉĞŶ 'Ϯϭϱ͕ϰϬϲΖϭϱ͕ϰϭϴΖ ϭϰ͕ϴϵϰΖ ϭϰ͕ϵϬϲΖ ϭϮ ϯͬϱͬϮϭ KƉĞŶ 'Ϯϭϱ͕ϰϬϲΖϭϱ͕ϰϭϴΖ ϭϰ͕ϴϵϰΖ ϭϰ͕ϵϬϲΖ ϭϮ ϯͬϮϵͬϮϭ KƉĞŶ 'Ϯϭϱ͕ϰϯϮ͛ϭϱ͕ϰϯϳ͛ϭϰ͕ϵϮϬ͛ϭϰ͕ϵϮϱ͛ϱ ϯͬϱͬϮϭ KƉĞŶ 'Ϯϭϱ͕ϰϯϮ͛ϭϱ͕ϰϰϮ͛ϭϰ͕ϵϯϬ͛ϭϰ͕ϵϯϰ͛ϭϬ ϮͬϱͬϮϭ KƉĞŶ 'Ϯϭϱ͕ϰϯϮ͛ϭϱ͕ϰϱϲ͛ϭϰ͕ϵϮϬ͛ϭϰ͕ϵϯϰ͛Ϯϰ ϭϬͬϮϬͬϭϴ KƉĞŶ 'EZ>t>>/E&K W/͗ϱϬͲϭϯϯͲϮϬϮϲϮͲϬϮͲϬϬ /ŶŝƚŝĂůŽŵƉůĞƚŝŽŶͲ ϭϬͬϭͬϭϵϴϯ dс ϭϱ͕ϱϴϬ͛ϬϬ Dͬdсϭϱ͕ϭϲϱ͛ds ϮϬ´ϬϬ <ůĞǀ͗͘ϭϳϴ͘ϰ͛ͬ&ͬ'>ůĞǀ͗͘ϭϲϬ͘ϰ͛ ϳ͟ ϵͲϱͬϴ͟ * Wdсϭϱ͕ϱϭϮ͛ϮϮ DͬWdсϭϰ͕ϵϵϵ͛ds WĞƌĨϭϯ͕ϬϭϱͲϭϯ͕Ϭϭϴ͛ ^ƋƵĞĞǌĞϮϴ>^ ϭϯͲ 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ƚŵ ;DͿ dŽƉ ;dsͿ ƚŵ ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ ϰͲϭͬϮ͟WŝƉĞ ϭϯ͕Ϭϭϱ͛ ϭϯ͕Ϭϭϴ͛ ϭϮ͕ϲϲϳ͛ ϭϮ͕ϲϳϬ͛ ϯ ϭϬͬϵͬϭϴ ĞŵĞŶƚĞĚ 'ϭ ϭϰ͕ϵϴϯΖ ϭϰ͕ϵϵϵΖ ϭϰ͕ϰϳϳΖ ϭϰ͕ϰϵϯΖ ϭϲ ϯͬϭͬϮϭ KƉĞŶ 'Ϯ цϭϱ͕ϯϬϲ͛ цϭϱ͕ϯϯϬ͛ цϭϰ͕ϳϵϱ͛ цϭϰ͕ϴϭϵ͛ цϮϰ ϮͬϱͬϮϭ KƉĞŶ 'Ϯ ϭϱ͕ϯϬϲ͛ ϭϱ͕ϯϯϬ͛ ϭϰ͕ϳϵϱ͛ ϭϰ͕ϴϭϵ͛ Ϯϰ ϯͬϱͬϮϭ KƉĞŶ 'Ϯ ϭϱ͕ϯϬϲ͛ ϭϱ͕ϯϯϬ͛ ϭϰ͕ϳϵϱ͛ ϭϰ͕ϴϭϵ͛ Ϯϰ ϭϬͬϮϬͬϭϴ KƉĞŶ 'Ϯ ϭϱ͕ϰϬϲΖ ϭϱ͕ϰϭϴΖ ϭϰ͕ϴϵϰΖ ϭϰ͕ϵϬϲΖ ϭϮ ϮͬϱͬϮϭ KƉĞŶ 'Ϯ ϭϱ͕ϰϬϲΖ ϭϱ͕ϰϭϴΖ ϭϰ͕ϴϵϰΖ ϭϰ͕ϵϬϲΖ ϭϮ ϯͬϱͬϮϭ KƉĞŶ 'Ϯ ϭϱ͕ϰϬϲΖ ϭϱ͕ϰϭϴΖ ϭϰ͕ϴϵϰΖ ϭϰ͕ϵϬϲΖ ϭϮ ϯͬϮϵͬϮϭ KƉĞŶ 'Ϯ ϭϱ͕ϰϯϮ͛ ϭϱ͕ϰϯϳ͛ ϭϰ͕ϵϮϬ͛ ϭϰ͕ϵϮϱ͛ ϱ ϯͬϱͬϮϭ KƉĞŶ 'Ϯ ϭϱ͕ϰϯϮ͛ ϭϱ͕ϰϰϮ͛ ϭϰ͕ϵϯϬ͛ ϭϰ͕ϵϯϰ͛ ϭϬ ϮͬϱͬϮϭ KƉĞŶ 'Ϯ> цϭϱ͕ϰϯϮ͛ цϭϱ͕ϰϱϲ͛ цϭϰ͕ϵϮϬ͛ цϭϰ͕ϵϯϰ͛ цϮϰ ϭϬͬϮϬͬϭϴ KƉĞŶ 'EZ>t>>/E&K W/͗ϱϬͲϭϯϯͲϮϬϮϲϮͲϬϮͲϬϬ /ŶŝƚŝĂůŽŵƉůĞƚŝŽŶͲϭϬͬϭͬϭϵϴϯ dс ϭϱ͕ϱϴϬ͛ Dͬdсϭϱ͕ϭϲϱ͛ ds ϮϬ´ <ůĞǀ͗͘ϭϳϴ͘ϰ͛ͬ&ͬ'>ůĞǀ͗͘ϭϲϬ͘ϰ͛ ϳ͟ ϵͲϱͬϴ͟ * Wdсϭϱ͕ϱϭϮ͛ DͬWdс ϭϰ͕ϵϵϵ͛ ds WĞƌĨ ϭϯ͕ϬϭϱͲϭϯ͕Ϭϭϴ͛ ^ƋƵĞĞǌĞϮϴ>^ ϭϯͲ ϰͲϭͬϮ͟ dKtΛϭϰ͕Ϯϯϴ͛ 'ϭ +3:a¶ 72&a¶ &%/ David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564- 4422 Received By: Date: Hilcorp North Slope, LLC Date: 06/18/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL: FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type Log Vendor BCU 05RD2 501332026202 218068 2/5/2021 PERF GAMMA RAY Yellowjacket BCU 05RD2 501332026202 218068 3/5/2021 PERF GAMMA RAY Yellowjacket BCU 11 501332052100 203025 6/12/2021 PERF Yellowjacket BCU 11 501332052100 203025 6/12/2021 RCBL Yellowjacket BCU 14A 501332053901 213196 6/14/2021 GPT Yellowjacket BCU 19RD 501332057901 219188 1/13/2021 PERF GAMMA RAY Yellowjacket BCU-19RD 501332057901 219188 4/24/2020 CALIPER Yellowjacket BCU-19RD 501332057901 219188 5/18/2020 PERF GAMMA RAY/GPT Yellowjacket Please include current contact information if different from above. Received By: 06/28/2021 37' (6HW By Abby Bell at 11:08 am, Jun 28, 2021 David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564- 4422 Received By: Date: Hilcorp North Slope, LLC Date: 06/18/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL: FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type Log Vendor BCU 05RD2 501332026202 218068 2/5/2021 PERF GAMMA RAY Yellowjacket BCU 05RD2 501332026202 218068 3/5/2021 PERF GAMMA RAY Yellowjacket BCU 11 501332052100 203025 6/12/2021 PERF Yellowjacket BCU 11 501332052100 203025 6/12/2021 RCBL Yellowjacket BCU 14A 501332053901 213196 6/14/2021 GPT Yellowjacket BCU 19RD 501332057901 219188 1/13/2021 PERF GAMMA RAY Yellowjacket BCU-19RD 501332057901 219188 4/24/2020 CALIPER Yellowjacket BCU-19RD 501332057901 219188 5/18/2020 PERF GAMMA RAY/GPT Yellowjacket Please include current contact information if different from above. Received By: 06/28/2021 37' (6HW By Abby Bell at 11:08 am, Jun 28, 2021 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 04/12/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 05RD2 (PTD 218-068) PERFORATING RECORD 03/29/2021 Please include current contact information if different from above. PTD: 2180680 E-Set: 34953 Received by the AOGCC 04/12/2021 04/12/2021 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 03/31/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 05RD2 (PTD 218-068) Production Profile 03/23/2021 Please include current contact information if different from above. PTD: 2180680 E-Set: 34857 Received by the AOGCC 03/31/2021 03/31/2021 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 15,680 feet N/A feet true vertical 15,165 feet N/A feet Effective Depth measured 15,512 feet 12,832 feet true vertical 14,999 feet 12,498 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3# / L-80 12,940' MD 12,598' TVD Packers and SSSV (type, measured and true vertical depth)DHL Hydr Ret Pkr; NA 12,832' MD 12,498' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Todd Sidoti Authorized Title:Operations Manager Contact Email: Contact Phone:777-8443 WINJ WAG 0 Water-Bbl MD 432' 3,511' 15,652' 2 Oil-Bbl measured true vertical Packer 7" 4-1/2" 14,918' 11,471' 14,413' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Beaver Creek / Beaver Creek Oil PoolN/A measured TVD Tubing Pressure 582 Beaver Creek Unit (BCU) 05RD2 N/A FEDA028083 11,698' Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 218-058 50-133-20262-02-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-056 120 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 234 Gas-Mcf 400 Authorized Signature with date: Authorized Name: 650 Casing Pressure Liner 2,718' 100 15,138' 5 Representative Daily Average Production or Injection Data 432' 3,511' 11,698' 3,387' Conductor Surface Intermediate Liner 8,540psi 10,780psi Casing Structural 20" 13-3/8" 9-5/8" Length 9,440psi 3,090psi Collapse 520psi 1,540psi 5,300psi todd.sidoti@hilcorp.com Senior Engineer:Senior Res. Engineer: 9,020psi Burst 1,530psi 12,460psi 432' 3,511' t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 10:06 am, Apr 09, 2021 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.04.09 09:52:00 -08'00' Taylor Wellman (2143) SFD 4/15/2021 218-068 RBDMS HEW 4/9/2021 432' DSR-4/12/21BJM 7/16/21 Rig Start Date End Date E-line 2/5/21 3/29/21 02/05/2021 - Friday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BCU-05RD2 50-133-20262-02-00 218-068 03/01/2021 - Monday Travel to location. Arrive on location, Contact DSO, Check in, PTW, PJSM. Spot equipment into place. MIRU Eline unit. Make up GR/CCL test wire. Good test. Make up wt bar, Stab on well, PT WLV/LUB 250/4,000. Good Test. Break lub off at QTS, Put tree cap on riser, MIRU hot oil truck to P-sub. Operations shut well in. Come online with crude down well at 3 bpm. WHP 820 psi, 60 bbls away Whp increased to 1145 psi. Appear to be fluid packed. Flush lines with 2 bbls meth. Offline with pump. WHP dropped to 0 psi. Make up 16', 2-1/8" shogun 6 spf, 60° phase 14 gram gun. Stab on well, open up,. RIH, WHP 0, IA 500, OA 0. @ 15,200' pull log up to 14,800'. Send log to town for Correlation. Got approval to shoot G1B 14,983'-14,999'. (Trudi Hallett) RIH to 15,000', Pu getting on CCL depth @ 14,968.2'. CCL t/top shot 14.8', CCL t/bottom shot 30.8'. Shoot G1B 14,983'-14,999'. ITP 5psi, 5 min 0, 10 min 0, 15 min, -11. POOH. Tagged up, swab shut, bleed down, pop off well, All shots fired. RDMO. 03/05/2021 - Friday Travel to location. Contact DSO, Get PTW, have PJSM. Take Yellow jacket Crane and move the wellhouse off BCU-14. Spot Yellow Jacket Eline, MIRU. Make up GR/CCL. Test wire. Good test, Make up 17' 2-3/8" 5 spf, 11gram, 60° phase HC Switch gun. Stab on well, PT low/high 250/2,500. Open well, RIH. WHP 75, IA 525, OA 0. Tag @ 15,442' ELM. Log up to 15,050', Send log to town for correlation. Approved to shoot 15,432'-15,437' and 15,406'-15,418' (Ben Siks) CCL t/ top shot 23', CCL t/bottom shot 28', Shoot G2B 15,432'-15,437', PU to CCL depth for second gun @ 15,399' CCL t/top shot 7', CCL t/bottom shot 19'. Shoot 15,406'-15,418'. ITP 105 psi, 5 min 105 psi, 10 min 105 psi, 15 min 105 psi. POOH. OOH, WHP 142, Swab shut, bleed down, pop off well, all shots fired. Make up 24' 2-3/8" 5spf, 11 gram 60° phase HC gun, Stab on well, Open up, RIH @ 10,250' lost communication with the tools. POOH, OOH, swab shut, bleed down, pop off well. Swap out GR/CCL, Test tool, good test. Stab on well, Open well, RIH @ 15,442' Log up to 15,025', Send log to town for correlation. Approval to shoot 15,306'-15,330' ( Ben Siks). RIH to 15,442', log up getting on CCL depth @ 15,294.5', CCL t/top shot 11.5', CCL t/bottom shot 35.5'. Shoot 15,306'-15,330'. ITP 111, 5 min, 10min, 15min. POOH. OOH, Swab shut, bleed down, pop off well, All shots fired. RDMO Yellow Jacket. Go over to BCU-14 and set wellhouse back on well. Sign In. Mobe to location. PTW and JSA. Spot equipment. Rig up lubricator and PT to 250 psi low and 4,000 psi high, Well flowing 13 bbls at 70 psi. RIH w/ 2-3/8" x 24' HC, 5 spf, 60 deg phase, tie into OHL and tag at 15,444'. We can only shoot 10' of G2-B (re-perf). FL was 10,950'. Town decided to shoot G2-A (re-perf). Ran correlation log and send to town. Get ok to perf from 15,306' to 15,330'. Spotted and shot perf gun with 70 psi. After 5 min - 70 psi, 10 min - 65 psi and 15 - 59 psi. POOH all shots fired/gun wet. RIH w/Gun #2, (G2-B re-perf)2-3/8" x 10', HC 5 spf, 60 deg phase and tie into OHL. Ran correlation log and send to town. Get ok to perf from 15,432' to 15,442' w/103 psi. Spot and fired gun. After 5 min - 103 psi, 10 min - 100 psi and 15 min 95 psi. POOH. All shots fired/gun wet. RIH w/Gun #3 (G2-B) 2-3/8 x 12' HC, 5 spf, 60 deg phase and tie into OHL. Ran correlation log and send to town. Get ok to perf from 15,406' to 15,418' w/106 psi. Spot and fired gun. After 5 min - 111 psi, 10 min - 109 psi and 15 min - 109 psi. POOH. All shots fired/gun wet. Rig down E-line unit and turn well over to field. 15,406' to 15,418' w/106 psi. Spot and fired gun. A Get ok to perf from 15,306' to 15,330'. Spotted and shot perf gun with 70 psi. A Shoot 15,306'-15,330'. Shoot G1B 14,983'-14,999' Shoot 15,406'-15,418'. 15,432' to 15,442' w/103 psi. Spot and fired gun. Rig Start Date End Date E-line 2/5/21 3/29/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BCU-05RD2 50-133-20262-02-00 218-068 03/29/2021 - Monday Sign in. Mobe to location. PTW and JSA. Spot and rig up equipment. PT lubricator 250 psi low and 4,000 psi low. Shooting well flowing. TP - 122 psi, rate 230 bbls/day and 1.7 mill GL Psi. RIH w/ 2-1/2" x 12' Shogun Spiral gun, 4 spf, 60 deg phase. and tie into perf log. Run correlation log and send to town. Get ok to perf from 15,406' to 15,418' w/flowing 122 bpd at 122 psi. Spotted and fired gun. After 5 min - TP -126 psi, flow 203 bpd, 10 min - 133 psi, flow 239 bpd and 15 min - 142 psi, flow 320 bpd. POOH. All shots fired. Rig down equipment and move to BCU 19RD. Get ok to perf from 15,406' to 15,418' w/flowing 122 bpd at 122 psi. Spotted and fired gun. _____________________________________________________________________________________ Updated by DMA 03-31-21 SCHEMATIC Beaver Creek Unit Well: BCU 05RD2 Completed: 10/24/18 PTD: 218-068 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor N/A / N/A / N/A N/A Surface 432’ 13-3/8” Surface 61/K-55/ 12.415 Surface 3,511’ 9-5/8" Production 47 / P110 / 8.681 Surface 11,698’ 7" Liner 32 / L-80 / 6.184 11,531’ 14,918’ 4-1/2” Liner 12.6 / L-80 / DWC/C 3.833 12,934’ 15,652’ TUBING DETAIL 3-1/2” Tubing 9.3# / L-80 / EUE 2.992 Surface 12,940’ JEWELRY DETAIL No Depth Item 1 2,594’ GLM w/ live valve 2 4,548’ GLM w/ live valve 3 5,997’ Chemical Injection Mandrel 4 6,198’ GLM w/ live valve 5 7,553’ GLM w/ live valve 6 8,749’ GLM w/ live valve 7 9,838’ GLM w/ live valve 8 10,931’ GLM w/ orifice 9 11,941’ GLM w/ dummy 10 12,813’ GLM w/ dummy 11 12,832’ 7” DLH Hydraulic Retrievable packer 12 12,843’ X-Landing Nipple (RHCP plug body loaded) 13 12,934’ HRD-E ZXP LTP w/ 5.25” PBR & Seal Assy 14 12,955’ Flex-Lock Liner Hanger, HRD-E ZXPN LTP w/ 5.25” PBR PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status 4-1/2” Pipe 13,015’ 13,018’ 12,667’ 12,670’ 3 10/9/18 Cemented G1B 14,432’ 14,437 13,951’ 13,956’ 5 3/2/21 Open G1B 14,983' 14,999' 14,477' 14,493' 16 3/1/21 Open G2A 15,306’ 15,330’ 14,795’ 14,819’ 24 2/5/21 Open G2A 15,306’ 15,330’ 14,795’ 14,819’ 24 3/5/21 Open G2A 15,306’ 15,330’ 14,795’ 14,819’ 24 10/20/18 Open G2B 15,406' 15,418' 14,894' 14,906' 12 2/5/21 Open G2B 15,406' 15,418' 14,894' 14,906' 12 2/5/21 Open G2B 15,406' 15,418' 14,894' 14,906' 12 3/29/21 Open G2B 15,432’ 15,437’ 14,920’ 14,925’ 5 3/5/21 Open G2B 15,432’ 15,442’ 14,930’ 14,934’ 10 2/5/21 Open G2B 15,432’ 15,456’ 14,920’ 14,934’ 24 10/20/18 Open GENERAL WELL INFO API: 50-133-20262-02-00 Initial Completion - 10/1/1983 G1B 14,432’ 14,437 13,951’13,956’5 3/2/21 Open G1B 14,983' 14,999'14,477'14,493'16 3/1/21 Open G2A 15,306’ 15,330’ 14,795’14,819’24 2/5/21 Open G2A 15,306’ 15,330’ 14,795’14,819’24 3/5/21 Open G2B 15,406' 15,418'14,894'14,906'12 2/5/21 Open G2B 15,406' 15,418'14,894'14,906'12 2/5/21 Open G2B 15,406' 15,418'14,894'14,906'12 3/29/21 Open G2B 15,432’ 15,437’ 14,920’14,925’5 3/5/21 Open G2B 15,432’ 15,442’ 14,930’ 14,934’10 2/5/21 Open * * Error: Interval from 14,432' to 14,437' MD was never perforated. See Hilcorp's email dated 4/19/2021. SFD Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE : 03/05/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 05RD2 (PTD 218-068) PERFORATING RECORD 03/01/2021 Please include current contact information if different from above. PTD: 2180680 E-Set: 34745 Received by the AOGCC 03/08/2021 03/09/2021 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 15,680'N/A Casing Collapse Structural Conductor 520psi Surface 1,540psi Intermediate 5,300psi Liner 10,780psi Liner 8,540psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Todd Sidoti Operations Manager Contact Email: Contact Phone: 777-8443 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): 3,071 50-133-20262-02-00 Beaver Creek Unit (BCU) 05RD2 9,020psi Perforation Depth TVD (ft): Tubing Size: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA 028083 218-068 Beaver Creek / Beaver Creek Oil Pool Length Size CO 237B N/A Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY 15,165' 15,512' 14,999' 9.3# / N-80 TVD Burst 12,940 12,460psi MD 9,440psi11,698' 3,511' 1,530psi 3,090psi 432' 3,511' 11,471' 432' 9-5/8" 3,511' 11,698' 15,652'2,718' 3-1/2" 15,138' 14,918' Perforation Depth MD (ft): See Attached SchematicSee Attached Schematic 3,387' 4-1/2" 14,413'7" 20" 13-3/8" 432' Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: February 10, 2021 todd.sidoti@hilcorp.com DHL Hydr Ret Pkr, NA 12,832' MD / 12,498' TVD, NA Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:44 am, Jan 27, 2021 321-056 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2021.01.26 17:07:23 -09'00' Taylor Wellman DSR-1/27/21SFD 1/27/2021 10-404 Perforate gls 1/28/21 OIL Comm q Yes 1/28/21 dts 1/28/2021 JLC 1/28/2021 RBDMS HEW 1/29/2021 Well Prognosis Well: BCU-05RD2 Date: 1/26/2021 Well Name: BC-05RD2 API Number: 50-133-20262-02-00 Current Status: Producing Oil Well Leg: N/A Estimated Start Date: 2/10/2021 Rig: E-Line Reg. Approval Req’d? 403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 218-068 First Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (M) Second Call Engineer: Ted Kramer (907) 777-8420 (O) (985) 867-0665 (M) AFE Number: Max Expected BHP: ~8,500 psi @ 14,477’ TVD Based on offset G1B sand in BCU-04RD Max Expected WHP: ~3,071 psi Based on expected BHP minus 0.375 psi/ft oil gradient Brief Well Summary Well BCU-05RD2 was drilled and completed as a sidetrack of BCU-05RD in 2018. The BCU-05RD2 is completed in the Tyonek G2 sands and has produced a total of 207 MBO. The well IP’d at about 1200 bopd initially – but declined off very quickly and stabilized about 200 bopd until the last several months where it has been producing about 100-200 bopd. Multiple re-perfs and xylene treatments were completed to help overcome decline. The objective of this work is to re-perforate existing sands, add the G2B and establish flow, then add the Tyonek G1B sand. Notes Regarding Wellbore Condition x Minimum ID is 2.81” x Last tag @ 15,473’ RKB w/ 2.5” x 4’ DD Bailer on 1/23/2021. Bailer full of greasy, oily gunk. Stage 1 Procedure: 1. MIRU E-line and pressure control equipment, PT lubricator to 250 psi low & 4000 psi high. 2. Perforate the following intervals with 2-1/8” Shogun Spiral guns : Tyonek G1 Perfs Top MD Bottom MD Total Top TVD Bottom TVD G2-A (re-perf) ±15,306’ ±15,330’ 24’ ±14,507’ ±14,522’ G2-B (new) ±15,406’ ±15,418’ 12’ ±14,894’ ±14,906’ G2-B (re-perf) ±15,432’ ±15,456’ 24’ ±14,920’ ±14,934’ a. Final perforation intervals will be provided prior to loading guns for exact depths. b. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer (Trudi Hallett), and Geologist (Ben Siks) for confirmation. c. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and 5, 10 & 15 minutes after each perforating run. 3. RD E-line. 4. Turn well over to production. Stage 2 Procedure: 1. MIRU E-line, hot oil truck and pressure control equipment, PT lubricator to 250 psi low & 4000 psi high. 2. Load and top well off with lease crude. 3. Perforate the following interval with 2-1/8” Shogun Spiral guns : G2-A (re-perf)±15,306’ ±15,330’24’±14,507’ ±14,522’ G2-B (new) ±15,406’ ±15,418’12’±14,894’ ±14,906’ NOTE: G1-B will be shot later. G2-B (re-perf) ±15,432’ ±15,456’24’±14,920’ ±14,934’ Well Prognosis Well: BCU-05RD2 Date: 1/26/2021 Tyonek G1 Perfs Top MD Bottom MD Total Top TVD Bottom TVD G1-B (new) ±14,983’ ±15,000’ 16’ ±14,477’ ±14,493’ a. Final perforation interval will be provided prior to loading guns for exact depths. b. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer (Trudi Hallett), and Geologist (Ben Siks) for confirmation. c. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and 5, 10 & 15 minutes after each perforating run. 4. RD E-line. 5. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic G1-B (new) ±14,983’ ±15,000’16’±14,477’ ±14,493’ _____________________________________________________________________________________ Updated by DMA 09-05-19 SCHEMATIC Beaver Creek Unit Well: BCU 05RD2 Completed: 10/24/18 PTD: 218-068 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor N/A / N/A / N/A N/A Surface 432’ 13-3/8” Surface 61/K-55/ 12.415 Surface 3,511’ 9-5/8" Production 47 / P110 / 8.681 Surface 11,698’ 7" Liner 32 / L-80 / 6.184 11,531’ 14,918’ 4-1/2” Liner 12.6 / L-80 / DWC/C 3.833 12,934’ 15,652’ TUBING DETAIL 3-1/2” Tubing 9.3# / L-80 / EUE 2.992 Surface 12,940’ JEWELRY DETAIL No Depth Item 1 2,594’ GLM w/ live valve 2 4,548’ GLM w/ live valve 3 5,997’ Chemical Injection Mandrel 4 6,198’ GLM w/ live valve 5 7,553’ GLM w/ live valve 6 8,749’ GLM w/ live valve 7 9,838’ GLM w/ live valve 8 10,931’ GLM w/ orifice 9 11,941’ GLM w/ dummy 10 12,813’ GLM w/ dummy 11 12,832’ 7” DLH Hydraulic Retrievable packer 12 12,843’ X-Landing Nipple (RHCP plug body loaded) 13 12,934’ HRD-E ZXP LTP w/ 5.25” PBR & Seal Assy 14 12,955’ Flex-Lock Liner Hanger, HRD-E ZXPN LTP w/ 5.25” PBR PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Size Date Status 4-1/2” Pipe 13,015’ 13,018’ 12,667’ 12,670’ 3 3-3/8” 10/9/18 Cemented G2 15,306’ 15,330’ 14,795’ 14,819’ 24 3-1/8” 10/20/18 Open G2 15,432’ 15,456’ 14,920’ 14,934’ 24 3-1/8” 10/20/18 Open GENERAL WELL INFO API: 50-133-20262-02-00 Initial Completion - 10/1/1983 Sa 4-1/2 G G _____________________________________________________________________________________ Updated by TRH 22Jan2021 PROPOSED Beaver Creek Unit Well: BCU 05RD2 Completed: 10/24/18 PTD: 218-068 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor N/A / N/A / N/A N/A Surface 432’ 13-3/8” Surface 61/K-55/ 12.415 Surface 3,511’ 9-5/8" Production 47 / P110 / 8.681 Surface 11,698’ 7" Liner 32 / L-80 / 6.184 11,531’ 14,918’ 4-1/2” Liner 12.6 / L-80 / DWC/C 3.833 12,934’ 15,652’ TUBING DETAIL 3-1/2” Tubing 9.3# / L-80 / EUE 2.992 Surface 12,940’ JEWELRY DETAIL No Depth Item 1 2,594’ GLM w/ live valve 2 4,548’ GLM w/ live valve 3 5,997’ Chemical Injection Mandrel 4 6,198’ GLM w/ live valve 5 7,553’ GLM w/ live valve 6 8,749’ GLM w/ live valve 7 9,838’ GLM w/ live valve 8 10,931’ GLM w/ orifice 9 11,941’ GLM w/ dummy 10 12,813’ GLM w/ dummy 11 12,832’ 7” DLH Hydraulic Retrievable packer 12 12,843’ X-Landing Nipple (RHCP plug body loaded) 13 12,934’ HRD-E ZXP LTP w/ 5.25” PBR & Seal Assy 14 12,955’ Flex-Lock Liner Hanger, HRD-E ZXPN LTP w/ 5.25” PBR PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status 4-1/2” Pipe 13,015’ 13,018’ 12,667’ 12,670’ 3 10/9/18 Cemented G1B ±14,983'±14,999' ±14,477' ±14,493' 16 TBD PROPOSED G2A 15,306’ 15,330’ 14,795’ 14,819’ 24 10/20/18 Open/RE-Perf G2B ±15,406' ±15,418' ±14,894' ±14,906' 12 TBD PROPOSED G2B 15,432’ 15,456’ 14,920’ 14,934’ 24 10/20/18 Open/Re-Perf GENERAL WELL INFO API: 50-133-20262-02-00 Initial Completion - 10/1/1983 TD =15,580’MD / TD = 15,165’TVD 3 20” KB Elev.: 178.4’/ BF/GL Elev.: 160.4’ 7” 4 5 6 12 13 &14 9-5/8” 1 2 G2 PBTD =15,512’ MD / PBTD = 14,999’ TVD Squeeze 28 BBLS CMT into Perfs 13-3/8” 10 7 9 8 11 4-1/2” Est. TOC@ 14,805’ BCU-05RD TOW @ 14,238’ G1B Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 01/12/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 05RD2 (PTD 218-068) COIL FLAG 01/01/2020 Please include current contact information if different from above. PTD: 2180680 E-Set: 34569 Received by the AOGCC 01/13/2021 Abby Bell 01/14/2021 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Xylene Wash Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 15,680 feet N/A feet true vertical 15,165 feet N/A feet Effective Depth measured 15,512 feet 12,832 feet true vertical 14,999 feet 12,498 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3# / L-80 12,940' MD 12,598' TVD Packers and SSSV (type, measured and true vertical depth)DHL Hydr Ret Pkr; NA 12,832' MD 12,498' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Todd Sidoti Authorized Title:Operations Manager Contact Email: Contact Phone:777-8443 odd.sidoti@hilcorp.com Senior Engineer:Senior Res. Engineer: 9,020psi Burst 1,530psi 12,460psi 432' 3,511' 9,440psi 3,090psi Collapse 520psi 1,540psi 5,300psi 8,540psi 10,780psi Casing Structural 20" 13-3/8" 9-5/8" Length 432' 3,511' 11,698' 3,387' Conductor Surface Intermediate Liner Authorized Signature with date: Authorized Name: 500 Casing Pressure Liner 2,718' 5 15,138' 131 Representative Daily Average Production or Injection Data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-447 94 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 100 Gas-Mcf 540 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 218-058 50-133-20262-02-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 1111 Beaver Creek Unit (BCU) 05RD2 N/A FEDA028083 11,698' Plugs Junk measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Beaver Creek / Beaver Creek Oil PoolN/A measured TVD Tubing PressureOil-Bbl measured true vertical Packer 7" 4-1/2" 14,918' 11,471' 14,413' WINJ WAG 5 Water-Bbl MD 432' 3,511' 15,652' 2 t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 2:08 pm, Jan 11, 2021 ggDigitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2021.01.11 10:35:14 -09'00' Taylor Wellman SFD 1/13/20201 218-068 Xylene Wash w/straddle packer RBDMS HEW 1/13/2021 DSR-1/12/21gls 1/14/21 Rig Start Date End Date 12/29/20 1/3/21 Transport Man lift, N2 pump, N2 transport, and coil utility trailer to location.;Standby for Oil pump to arrive from Anchorage for Coil power pack. 12/29/2020 - Tuesday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BCU-05RD2 50-133-20262-02-00 218-068 12/31/2020 - Thursday Travel to location. Contact DSO, Inspect location, get permit signed. Roll out herculite under coil unit and coil pump. Back Coil unit and pump into place. Offload Weaver bros trailers. Rig up hardline, hydraulic hoses, bops and return tank. Test BOPE as per Hilcorp & AOGCC requirements, witnessed waived 12/30/2020 @ 1649 PM by AOGCC Inspections Supervisor Jim Regg, 250/4,000. Emailed BOPE Test Report to AOGCC. Make up CTC, pull test 25k. Set injector on stand, secure well and location. Job in progress. Travel to location. Contact DSO, Inspect location, Get permit, PJSM. Fire up equipment, hook up hoses, Pu Injector, Make up 20' lubricator. Make up HES memory GR/CCL in 2.20" carrier. Head to well, stab on well. pt low/high 250/4,000. (CTC 1.75" X .82') (DFCV 2.125" X .98') (DISCONNECT 2.125" X 1.58') (CARRIER WITH GR/CCL 2.20" X 12.04') (XO 2.2" X .27') (JSN 2.55" X 58') TOL= 16.27'. PT low/high 250/4,000. Small leak on o-ring, pop off replace oring. stab back on well, pt low/high 250/4,000. Open well, swab 18, T/I/O= 131/560/0. RIH. WT CK 2,000'=3K , WT CK 4,500'=9K, WT CK 6,100'=14K, WT CK 8,000'=20K, WT CK 10,000'=25K, WT CK 12,600'=31K, WT CK 15,100'=38K. Tag at 15,364' CTMD. Wait 5 min, log up to 15,240' ctmd, paint flag. log up to 14500' @ 60fpm. Stop for 5 min. POOH. Tagged up, swab closed, bleed down, pop off well. Break off logging tools. Download data. Send Log to town for review. Stack down lubricator and injector. Secure well and location for the night. Job in progress. 01/01/20201 - Friday Rig Start Date End Date 12/29/20 1/3/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BCU-05RD2 50-133-20262-02-00 218-068 01/02/2021 - Saturday Travel to location. Arrive on location, contact DSO, Initiate permit, PJSM. Fire up equipment, PU injector, 20' lubricator, Make up circ sub and xo. line up to pt MHA. SLB fluid pump suction froze, valve on source tank froze too. Got two heaters thawing stuff out. Finally got fluid moving through pump and out to the tank. Fluid pack coil, PT MHA low/high 250/3,500. Stab on well, fluid pack hardline for full body pt. low/high 250/2500. Open well, swab 18, T/I/O= 525/750/0. Stop at the flag, 15,300', Make a correction to mid element. 15,382' mid element. RIH tag at 15,435'. Pu to 15,380', drop 3/8" ball to set packer. Ball on seat @ 24.9 bbls away. Packer appears to be set. Stack down 5k on packer. Come online with 25 bbls xylene. Xylene at the nozzle injecting into lower perfs. WHP 1029, IA 900, OA 0. 7 BBLS away starting to see some communication with WHP. Stack down 5K packer still set. Continue to displace Xylene maintaining 1,000 psi on the wellhead through the choke. ( communication through the perfs or packer leaking). All 25 bbls xylene out of coil into lower perfs. Drop .5" ball to open circ sub. Circ sub open at 62.3 bbls away. Treat upper zone. At 72 bbls away xylene at the circ sub. Start injecting into upper perfs. Able to inject at 1bbl per 10 min. 21.5 Total bbls xylene in upper perfs. whp 3800, IA 900, OA 0, CTP 4000. Bump pressure back up 3,720 psi, 3,180 psi, 1.01 bbls, 67.1, bump pressure back up 4228, 3944, .87 bbls, 69.8, pressure back up. 3,823, 4,147, .57 bpm, 73.3, pressure back up 3,679, 3,942, .20, 79.7. pressure back up 3,813, 4,000, .27, 84.9bbls, pressure back up 3848, 4020, .27, 86.7. Open choke to displace the last 8 bbls, shut choke in. pull 45k to release packer. (Didn't see any overpull). POOH. Come online down tubing to push Xylene into formation, WHP 3,000, IA 900, OA 0. Tagged up, swab shut, bleed down, pop off well. WHP 2,300, IA 875, OA 0. Break off packer, recovered 3/8" ball, Recovered .5" ball on circ sub. Break down MHA, set down 20' lubricator and injector head on stand. Secure well and location. Job in progress. 01/03/2021 - Sunday Arrive on location, Contact DSO, inititate permit. PJSM. Fire up equipment, Cool down N2, PU injector, 10' lubricator. Stab on well, blow coil down to open top tank. RDMO coil, Load trailers with coil equipment stage on edge of pad. Secure well and location. Turn over to production. did packer work? gls _____________________________________________________________________________________ Updated by DMA 09-05-19 SCHEMATIC Beaver Creek Unit Well: BCU 05RD2 Completed: 10/24/18 PTD: 218-068 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor N/A / N/A / N/A N/A Surface 432’ 13-3/8” Surface 61/K-55/ 12.415 Surface 3,511’ 9-5/8" Production 47 / P110 / 8.681 Surface 11,698’ 7" Liner 32 / L-80 / 6.184 11,531’ 14,918’ 4-1/2” Liner 12.6 / L-80 / DWC/C 3.833 12,934’ 15,652’ TUBING DETAIL 3-1/2” Tubing 9.3# / L-80 / EUE 2.992 Surface 12,940’ JEWELRY DETAIL No Depth Item 1 2,594’ GLM w/ live valve 2 4,548’ GLM w/ live valve 3 5,997’ Chemical Injection Mandrel 4 6,198’ GLM w/ live valve 5 7,553’ GLM w/ live valve 6 8,749’ GLM w/ live valve 7 9,838’ GLM w/ live valve 8 10,931’ GLM w/ orifice 9 11,941’ GLM w/ dummy 10 12,813’ GLM w/ dummy 11 12,832’ 7” DLH Hydraulic Retrievable packer 12 12,843’ X-Landing Nipple (RHCP plug body loaded) 13 12,934’ HRD-E ZXP LTP w/ 5.25” PBR & Seal Assy 14 12,955’ Flex-Lock Liner Hanger, HRD-E ZXPN LTP w/ 5.25” PBR PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Size Date Status 4-1/2” Pipe 13,015’ 13,018’ 12,667’ 12,670’ 3 3-3/8” 10/9/18 Cemented G2 15,306’ 15,330’ 14,795’ 14,819’ 24 3-1/8” 10/20/18 Open G2 15,432’ 15,456’ 14,920’ 14,934’ 24 3-1/8” 10/20/18 Open GENERAL WELL INFO API: 50-133-20262-02-00 Initial Completion - 10/1/1983 Sa 4-1/2 G G 1.Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Xylene Wash 2. Operator Name:4. Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 15,680'N/A Casing Collapse Structural Conductor 520psi Surface 1,540psi Intermediate 5,300psi Liner 10,780psi Liner 8,540psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. W ell Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. W ell Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Ted Kramer Operations Manager Contact Email: Contact Phone: 777-8420 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: November 1, 2020 tkramer@hilcorp.com DHL Hydr Ret Pkr, NA 12,832' MD / 12,498' TVD, NA See Attached Schematic 3,387' 4-1/2" 14,413'7" 20" 13-3/8" 432' 9-5/8" 3,511' 11,698' 15,652'2,718' 3-1/2" 15,138' 14,918' Perforation Depth MD (ft): 9,440psi11,698' 3,511' 1,530psi 3,090psi 432' 3,511' 11,471' 432' 15,512'14,999' 9.3# / N-80 TVD Burst 12,940 12,460psi MD Beaver Creek / Beaver Creek Oil Pool Length Size CO 237B N/A Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY 15,165' See Attached Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA 028083 218-068 3,500 50-133-20262-02-00 Beaver Creek Unit (BCU) 05RD2 9,020psi Perforation Depth TVD (ft): Tubing Size: COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): B No No Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:52 am, Oct 20, 2020 320-447 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.10.19 14:19:09 -08'00' Taylor Wellman SFD 10/20/2020 X DLB10/20/2020 DSR-10/20/2020 X VTL 10/21/20 Coil BOP test pressure to 4000 psig X 10-404 Comm. 10/22/2020 dts 10/22/2020 RBDMS HEW 11/9/2020 Well Prognosis Well: BCU-05RD2 Date: 10/02/2020 Well Name: BC-05RD2 API Number: 50-133-20262-02 Current Status: Producing Oil Well Leg: N/A Estimated Start Date: October 16th, 2020 Rig: CTU Reg. Approval Req’d? 403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 218-068 First Call Engineer: Ted Kramer (907) 777-8420 (O) (985) 867-0665 (M) Second Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (M) AFE Number: Maximum Expected BHP: 5,200 psi @ 14,764’ TVD FBHP survey on 8/9/2019 Max. Potential Surface Pressure: ~ 3,500 psi (While pumping) Brief Well Summary Well BCU-05RD was drilled and completed as a sidetrack of the original BCU-05 in 1976. The well was fracture stimulated in 1991 but it is believed that the sand fracture failed due to improper proppant crush resistance. The tubing was replaced in 2014 to remove an unset tubing patch in the old tubing. The sidetrack was recently plugged back and sidetracked again and reached TD on 9/13/18. The well was completed with a 3-1/2” gas lift completion and brought online in Nov. 2019. A decline in production has generated a need for a stimulation. Hilcorp believes that fines and / or asphaltenes are causing a premature decline in production. The purpose of this work/sundry is to soak and jet wash the perforations with Xylene using coil tubing. Notes Regarding Wellbore Condition x Last Tag, 15,491’ KB w/ 1.75” chisel bottom DD bailer E-Line Procedure: 1. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. Note: well will not flow on its own. a. Tree connection is 6.5” OTIS. 2. PU RIH w/ GR/CCL and a weight bar to PBTD. Record Depth. POOH. RD E-line. Coil Procedure 3. MIRU Coil Unit. Pressure test BOP equipment to 4,000 psi high/ 250 psi low. a. Notify AOGCC 24 hours in advance to give them an opportunity to witness. b. Send completed form to AOGCC within 5 days. 4. PU Jet Nozzle/ spin Cat and RIH to the same depth as e-line and lightly tag bottom until weight loss is observed. Set counter to agree with E-line tag for depth control. PU to 15,460’ and pump 1,000’ of Xylene in 4-1/2” casing ( 640 gals. / 15.2 Bbls.). 5. Drop ball. Once ball seats, begin jet washing bottom set of perfs . working a 50’ length up and down from 15,460’ up to 15,410’. Jet wash with 310 gals of Xylene. 6. Pickup to 15,350’. Jet wash with Xylene from 15,350 up to 15, 290’ washing with the remaining 310 gals. of Xylene. POOH W/ Coil. 7. RDMO Coil Unit while allowing Xylene to soak. 8. RU Pump Truck. Pump 40 bbls of diesel forcing Xylene into formation. Pump pressure limit for this pump job is 3,500 psi. If pump limit needs to be exceeded to get fluid away, contact Operations Engineer. The purpose of this work/sundry is to soak and jet wash the perforations with Xylene using coil tubing. Hilcorp believes that fines and / or asphaltenes are causing a premature decline in production. Well Prognosis Well: BCU-05RD2 Date: 10/02/2020 9. RDMO Pump truck. 10. Turn well over to production. Attachments: 1. Actual Schematic 2. Coil BOP Stack _____________________________________________________________________________________ Updated by DMA 09-05-19 SCHEMATIC Beaver Creel Unit Well: BCU 05RD2 Completed: 10/24/18 PTD: 218-068 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor N/A / N/A / N/A N/A Surface 432’ 13-3/8” Surface 61/K-55/ 12.415 Surface 3,511’ 9-5/8" Production 47 / P110 / 8.681 Surface 11,698’ 7" Liner 32 / L-80 / 6.184 11,531’ 14,918’ 4-1/2” Liner 12.6 / L-80 / DWC/C 3.833 12,934’ 15,652’ TUBING DETAIL 3-1/2” Tubing 9.3# / L-80 / EUE 2.992 Surface 12,940’ JEWELRY DETAIL No Depth Item 1 2,594’ GLM w/ live valve 2 4,548’ GLM w/ live valve 3 5,997’ Chemical Injection Mandrel 4 6,198’ GLM w/ live valve 5 7,553’ GLM w/ live valve 6 8,749’ GLM w/ live valve 7 9,838’ GLM w/ live valve 8 10,931’ GLM w/ orifice 9 11,941’ GLM w/ dummy 10 12,813’ GLM w/ dummy 11 12,832’ 7” DLH Hydraulic Retrievable packer 12 12,843’ X-Landing Nipple (RHCP plug body loaded) 13 12,934’ HRD-E ZXP LTP w/ 5.25” PBR & Seal Assy 14 12,955’ Flex-Lock Liner Hanger, HRD-E ZXPN LTP w/ 5.25” PBR PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Size Date Status 4-1/2” Pipe 13,015’ 13,018’ 12,667’ 12,670’ 3 3-3/8” 10/9/18 Cemented G2 15,306’ 15,330’ 14,795’ 14,819’ 24 3-1/8” 10/20/18 Open G2 15,432’ 15,456’ 14,920’ 14,934’ 24 3-1/8” 10/20/18 Open GENERAL WELL INFO API: 50-133-20262-02-00 Initial Completion - 10/1/1983 Sa 4-1/2 G G STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS JAN 2 t 2020 B `l'a.a"G C V 1. Operations Abandon Ll Plug Perforations LJ Fracture Stimulate Ll Pull Tubing LJ Operations shutdown LJ Performed: Suspend ❑ Re -Perforate Q Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑✓ Stmtigraphic❑ Exploratory ❑ Service ❑ 218-068 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-133-20262-02-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028083 Beaver Creek Unit (BCU) 05RD2 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Beaver Creek / Beaver Creek Oil Pool 11. Present Well Condition Summary: Total Depth measured 15,680 feet Plugs measured N/A feet true vertical 15,165 feet Junk measured N/A feet Effective Depth measured 15,512 feet Packer measured 12,832 feet true vertical 14,999 feet true vertical 12,498 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 432' 20" 432' 432' 1,530psi 520psi Surface 3,511' 13-3/8" 3,511' 3,511' 3,090psi 1,540psi Intermediate 11,698' 9-5/8" 11,698' 11,471' 9,440psi 5,300psi Liner 3,387' 7" 14,918' 14,413' 12,460psi 10,780psi Liner 2,718' 4-1/2" 15,652' 15,138' 9,020psi 8,540psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.3# / L-80 12,940' MD 12,598' TVD Packers and SSSV (type, measured and true vertical depth) DHL Hydr Ret Pkr; NA 12,832' MD 12,498' TVD N/A; N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 1 201 2 0 420 77 Subsequent to operation: 248 11 0 460 80 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations Exploratory[:] Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas-77—WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-441 Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer(a)hilcoro cora Authorized Signatur. Date:Zt .j CA.,10)O Contact Phone: 777-8420 Form 10-404 Revised 4/2017 ljl/.Gp2oo �iBDMS'''F JAN 2 3 2020 Submit Original Only I UU �. J ). >. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Weli Permit Number Start Date End Date BCU-05RD2 E -Line 50-133-20262-02 00 218-068 12/28/19 1 1/6/20 Daily Operations: 12/28/2019 -Saturday Sign in. Mobe to location. PTW, ISA and SIMOPS between AKE-Line and 401 Rig. Spot and rig up equipment. PT lubricator to 250 psi low and 4,500 psi high. Shut off gas lift to well. RIH w/ 2" x 24' HC Razor, 6 spf, 60 deg phase and tie into OHL. Tools set down at 15,404'. Could not run any deeper. Decision made to perforate upper zone from 15,306' to 15,330'. Could not get to deeper zone. Ran correlation log and send to town. Get ok to pert from 15,306' to 15,330'. Spot and fire gun with 42.8 psi on tubing. After 5, 10 and 15 min pressure was still the same at 42.7psi. POOH. All shots fired. 01/02/2020 -Thursday WO AKE-Line. Having trouble getting crane started due to cold weather. AKE-Line on location at 0830 hrs. PTW, JSA and SIMOPS with Hilcorp WO Rig. Spotted equipment. Had trouble with PTO air actuator. Had to get heater and thaw out. Rig up lubricator. Pressure test lubricator to 250 psi low and 4,500 psi high. Arm gun. RIH w/ 2" x 24' HC Razor, 6 spf, 60 deg phase and tie into OHL. Had to season line by picking up 100' every 1,000' going in hole. Could not run faster than 250 fpm. Brake drum started smoking and we stopped at 12,000'. Pulled guard and found pad had come off the brake band. Then RIH making sure that one brake drum side would hold drum. Tools set down art 15,407'. We hit down on obstruction 3 times at 200 fpm and did not make any more hole. That was 3'-4' deeper than last tag. Slickline was out here a couple of days ago and said they made it to 15,494' and didn't see anything where we sat down a few days ago at 15,403'. Call town and discussed. Ran correlation log and POOH. We ran in hole with well flow 230 bbl/day, 83 psi 1.3 million GL. Rig down lubricator and turn well over to field. 01/06/2020- Monday Sign in. Mobe to location. PTW and JSA. Spot and rig up equipment. Arm gun and pull into lubricator. PT lubricator to 250 psi low and 4,500 psi high. Well flow 200 bbl at 68 psi. Will shoot with well flowing. RIH w/ 2" x 24' Razor HC, 6 spf, 60 deg phase perf gun and tie into OHL. Tag at 15,514'. Ran correlation log and send to town. Get ok to pert from 15,432' to 15456' w/well flowing 200 bbl/day at 68 psi. Spot and fire gun. After 5 min - 68.48 psi, 10 min - 66.77 psi and 15 min - 66.6 psi with basically the same rate before we perfed. POOH. All shots fired. Rig down lubricator and turn well back over to field. Using AKE-Line to pick shed off BCU -9 to get it out of the way for drilling. ff corn Alaska. LLC KB Dev.:178.4'/ BF/GL Elev.:160.4' TD=1S,SW (MD) /TD= 15,165 M) PBTD=15,517 (MD) / P8TD=14,999'(TVD) SCHEMATIC Beaver Creek Unit Well: BCU 05RD2 Completed: 10/24/18 PTD: 218-068 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor N/A / N/A /N/AN/A 3 Surface 1 432' 13-3/8" Surface 61/K-55/ 12.415 Surface 3,511' 9-5/8" Production 47/P110/ 8.681 Surface 11,698' 7" Liner 32/L-80/ 6.184 11,531' 14,918' 4-1/2" Liner 12.6/L-80/DWC/C 3.833 12,934' 15,652' TUBING DETAIL 3-1/2" Tubing 9.3#/L-80/EUE 1 2.992 1 Surface 12,940' JEWELRY DETAIL No Depth Item 1 2,594' 1 GLM w/ live valve 2 4,548' GLM w/ five valve 3 5,997' Chemical Injection Mandrel 4 6,198' GLM w/ live valve 5 7,553' GLM w/ live valve 6 8,749' GLM w/live valve 7 9,838' GLM w/ live valve 8 10,931' GLM w/ orifice 9 117941' GLM w/dummy 10 12,813 GLMw/dummy 11 12,832' 7" DLH Hydraulic Retrievable packer 12 12,843' X -Landing Nipple (RHCP plug body loaded) 13 12,934' HRD-E D(P LTP w/ 5.25" PBR & Seal Assy 14 12,955' Flex -Lock Liner Hanger, HRD-E ZXPN LTP w/ 5.25" PBR PERFORATION DETAIL ids Top (MD) Btm (MD) Top (TVD) Btm (ND) FT Size Date Status 'Pipe 13,015' 13,018' 12,667' 12,670' 1 3 1 3-3/8" 10/9/18 Cemented 2 15,306' 15,33(Y 14,795' 14,819' 1 24 1 2 12/28/19 Open 2 15,432' 15,456' 1 14,920' 1 14,934' 1 24 1 2 1/6/20 Open GENERAL WELL INFO API: 50-133-20262-02-00 Initial Completion -10/1/1983 Updated by DMA 01-14-20 THE STATE 01ALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beaver Creek Field, Beaver Creek Oil Pool, BCU 05RD2 Permit to Drill Number: 218-068 Sundry Number: 319-411 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, y� Jssihmielowski Commissioner DATED this 13 day of September, 2019. 'IBDMSIL�`LJSEP 16 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVE® SEP 09 2019 AOGCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ t4,L -Perforate Q ' Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Reddll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: • 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development ❑✓ Stratigraphic ❑ Service ❑ 218-068 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-20262-02-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 2378 Will planned perforations require a spacing exception? Yes ❑ No ❑✓ Beaver Creek Unit (BCU) 05RD2 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028083 Beaver Creek / Beaver Creek Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 15,680' 15,165' 15,512' 14,999' -3,723 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 432' 20" 432' 432' 1,530psi 520psi Surface 3,511' 13-3/8" 3,511' 3,511' 3,090psi 1,540psi Intermediate 11,698' 9-5/8" 11,698' 11,471' 9,440psi 5,300psi Liner 3,387' 7" 14,918' 14,413' 12,460psi 10,780psi Liner 2,718' 4-1/2" 15,652' 15,138' 19,020psi 8,540psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3-1/2" 9.3# / L-80 1 12,940' Packers and SSSV Type: DHL Hydr Ret Pkr, NA Packers and SSSV MD (ft) and TVD (ft): 12,832' MD / 12,498' TVD, NA 12. Attachments: Proposal Summary [aj Wellbore schematic ✓ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑✓ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: September 23, 2019 OIL Q WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: So York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer(ftilcor .Com Contact Phone: 777-8420 Authorized Signature: Date: ! S Z COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3) (/� ^ L1' I ElPlug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: 313DMS � SEP 16 2019 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No 5d" Subsequent Form Required: i©-yoy - APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: rt i�" [� J "' Submit Form and Form 10-403 Revised 4/2017 Approved application i i r Rana rrrttt YYN71 to of approval. 1��\��chments in Duplicate Polo M-& 9(u1t9 H Mears Alaska, LU Well Prognosis Well: BCU-05RD2 Date:9/05/2019 Well Name: BC-05RD2 API Number: 50-133-20262-02 Current Status: Producing Oil Well Leg: N/A Estimated Start Date: September 23nd, 2019 Rig: E -Line Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: G2 Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 218-068 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Second Call Engineer: Bo York (907) 777-8345 (0) (907) 727-9247 (M) AFE Number: Maximum Expected BHP: Max. Potential Surface Pressure: Brief Well Summary 5,200 psi @ 14,764' TVD — 3,723 psi FBHP survey on 8/9/2019 (0.10 psi/ft gas gradient) Well BCU-05RD was drilled and completed as a sidetrack of the original BCU -05 in 1976. The well was fracture stimulated in 1991 but it is believed that the sand fracture failed due to improper proppant crush resistance. The tubing was replaced in 2014 to remove an unset tubing patch in the old tubing. The sidetrack was recently plugged back and sidetracked again and reached TD on 9/13/18. The well was completed with a 3-1/2" gas lift completion and brought online in Nov. 2019. A decline in production has generated a need for a stimulation re- perf. The purpose of this work/sundry is to re -perforate the intervals currently producing. Notes Regarding Wellbore Condition • Last Tag, 15,491' KB w/ 1.75" chisel bottom DD bailer E -Line Procedure: 1. MIRU E -line, PT lubricator to 4,500 psi Hi 250 Low. a. Tree connection is 6.5" OTIS. 2. PU RIH w/ perfguns re -perforate the following intervals Zone Top Md Btm Md Top Btm TVD TVD G2 15,306 15,330 14,794 14,818 G2 15,432 15,456 14,920 14,944 3. RD E -line. 4. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic K 118cory Alaeku. LLC KB Elev.:178.4'/ BF/GL Elev.:160.4' TD= 15,589 MD/TD =15,165' TVD PBTD=15,512' MD / PBTD =14,999' TVD SCHEMATIC Beaver Creel Unit Well: BCU 05RD2 Completed: 10/24/18 PTD: 218-068 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor N/A/N/A/N/A N/A Surface 432' 13-3/8" Surface 61/K-55/ 12.415 Surface 3,511' 9-5/8" Production 47/P110/ 8.681 Surface 11,698' 7" Uner 32 / L-80 / 6.184 11,531' 14,918' 4-1/2" Liner 12.6 / L-80 / DWC/C 3.833 12,934' 15,652' TUBING DETAIL 3-1/2" Tubing 9.3k/L-80/EUE 2.992 Surtace 12,944 JEWELRY DETAIL No Depth Item 1 2,594' GLM w/ live valve 2 4,548' GLM w/ live valve 3 5,997 Chemical Injection Mandrel 4 6,198' GLM w/ live valve 5 7,553' GLM w/ live valve 6 8,749' GLM w/ live valve 7 9,838' GLM w/ live valve 8 10,931' GLM w/ orifice 9 11,941' GLMw/dummy 10 12,813' GLMw/dummy 11 12,832' 7" DLH Hydraulic Retrievable packer 12 12,843' X -Landing Nipple (RHCP plug body loaded) 13 12,934' HRD-E ZXP LTP w/ 5.25" PSR & Seal Assy 14 12,955' Flex -Lock Liner Hanger, HRD-E ZXPN LTP w/ 5.25" PBR PERFORATION DETAIL nds Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Size Date Status !" Pipe 13,015' 13,018' 12,667' 12,670' 3 3-3/8" 10/9/18 Cemented i2 15,306' 15,330' 14,795' 14,819' 24 3-1/8" 10/20/18 Open 32 15,432' 15,456' 14,920' 14,934' 24 3-1/8" 10/20/18 Open GENERAL WELL INFO API: 5D-133-20262-02-00 Initial Completion -10/1/1983 Updated by DMA 09-05-19 K mm Al"ka. LLC KB Elev.: 17&4'/ BF/G1 Elev.: 160.4' PROPOSED SCHEMATIC TD=15,580' (MD) /TD=15,165'(TVD) PBTD=15,512' (MD) / PBTD = 14,99YM) Beaver Creel Unit Well: BCU O5RD2 Completed: 10/24/18 PTD: 218-068 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor N/A/N/A/N/A N/A Surface 432' 13-3/8" Surface 61/K-55/ 12.415 Surface 3,511' 9.5/8" Production 47/P110/ 8.681 Surface 11,698' 7" Liner 32 / L-80 / 6.184 11,531' 14,918' 4-1/2" Liner 12.6 / L-80 / DWC/C 3.833 12,934' 15,652' TUBING DETAIL 3-1/2" Tubing 9.3#/L-80/EUE 1 2.992 1 Surface I 12,940' JEWELRY DETAIL No Depth Item 1 2,594' GLMw/live valve 2 4,548' GLM w/ live valve 3 5,997' Chemical Injection Mandrel 4 6,198' GLMw/live valve 5 7,553' GLM w/live valve 6 8,749' GLMw/live valve 7 9,838' GLMw/live valve 8 10,931' GLMw/orifice 9 1 11,941' 1 GLMw/dummy 10 12,813' 1 GLMw/dummy 11 12,832' 7" DLH Hydraulic Retrievable packer 12 12,843' X-Landin Nipple (RHCP plug body loaded) 13 12,934' HRD-E ZXP UP w/ 5.25" POR & Seal Assy 14 12,955' Flex -Lock Liner Hanger, HRD-E ZXPN LTP w/ 5.25" PBR PERFORATION DETAIL rids Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Size Date Status I" Pipe 13,015' 13,018' 12,667' 12,674 3 1 3-3/8" 10/9/18 Cemented 32 ±15,306' ±15,330' ±14,795' ±14,819' 24 TBD Open 32 ±15,432' ±15,456' ±14,920 ±14,934' 24 TBD Open GENERAL WELL INFO API: 50-133-20262-02-00 Initial Completion -10/1/1983 Revised By: TRH 9/05/2019 BCU 05RD2 Beaver Creek Unit Kenai Peninsula Borough, Alaska August 26 — September 18, 2018 Approved by: Benjamin Silks Distribution Date: Nov 5, 2018 Provided by: 00111 NABORS Compiled by: Ralph Winkelman Sarah Chamlee 218068 3U 030 BCU05RD2 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment T e /Position Total Downtime Comments Computers — Surface Logging i3) Rigwatch Server, Rigwatch Remote DML, LWD WITS, Rigwatch Remote Ditch gas QGM gas trap; Flame ionization total gas & chromatography, Hook Load / Weight on bit WITS from Pason Mud Flow In Calculated value derived from Strokes/Minute and Pump Output Mud Flow Out WITS from Pason Pit Volumes, Pit Gain/Loss WITS from Pason Pump Pressure WITS from Pason Pump Stroke Counters 2 WITS from Pason Rate of Penetration Calculated from Pason RPM WITS from Pason Tor ueWITS from Pason WITS To/ From Pason Ri watch Remote HP Compaq) 1.2 Crew Mud Logging Unit Type: Arctic Mud Loaaina Unit Number: ML038 Sample Logging Geologists Years' Days' Catchers/Loggers Years Da s2 Ralph Winkelman 27 24 Ashley Tuttle 5 18 Sarah Chamlee 8 24 Steven Wright 0.5 18 Years' experience as Mudlogger ` Days at wellsite between rig up and rig sown oT iogging unit A NABORS 2 ML BCU05RD2 GENERAL WELL DETAILS 2.1 WellObiectives BCU 05RD2 is an oil producer planned to be re -drilled in a North -Easterly direction from the existing BCU 05RD utilizing the existing casing program down to 14500' MD/14008' TVD. At 14500' MD the parent wellbore will be sidetracked and a new wellbore drilled penetrating several Hemlock targets. A 1500' x 5-7/8" open hole section is planned. A 4-1/2" 12.6# L-80 DWC/C production liner will be run, cemented, and perforated based on data obtained while drilling the interval. The well will be completed with 3-1/2" production tubing string. Operator: HILCORP ALASKA, LLC Well Name: BCU 05RD2 Field: Beaver Creek Unit County: Kenai Peninsula Borough State: Alaska Company Representatives: Robert Wall, Rance Pederson, John Nicholson, Oliver Amend Location: Surface Coordinates 15763' FNL, 1465' FWL, Sec 34, T7N, R10W, SM, AK Ground ( Pad ) Elevation 160.4' AMSL Rotary Table Elevation 18' RKB —178.4' AMSL Classification: Development — Oil API #: 50-133-20262-02-00 Permit #: 218-068 Rig Namelrype: Hilcorp 169 / Land / Double Spud Date 9/6/2018 Total Depth Date: 9/12/2018 Total Depth 15,680' Primary Targets Hemlock H1 through H5 Total Depth Formation: Hemlock Completion Status: LWD-MWD Services. Halliburton / Sperry Drilling Services Directional Drilling Halliburton / Sperry Drilling Services Drilling Fluids Service Halliburton / Baroid Wireline Logging Service Schlumberger MPD Schlumberger A NABORS OML BCU05RD2 2.2 Hole Data Hole Section Max Depth TD Formation MW Dev Csg Pog 'inc Dia Shoe Depth LOT MD ft ND ft MID ND fl ft TOW 14238' 13777.7' Tyonek 9.5 28.6 7" 14251' 13789.1 12.5 5 7/8" 15680' 15165.7 Hemlock 10.5 6.21 4 Y::" 15527' 15015' N/A 2.3 Daily Activity Summary August 26, 2018: Winkelman arrives on location and begins rig up. August 27, 2018: Full crew present and finish rigging up. August 28, 2018 Run in hole from 5092' to 9585', rig service (grease blocks, TDS, wrench, drawworks, check all fluids), continue to run in hole from 9585' to 10732', change out die block and install grabber box pin, assist MPD with equipment, adjust link tilt, continue to run in hole from 10732' to 11911' with no issues at liner top, continue picking up pipe from 11911' to 12740', tagged with 10k, pump with 46 strokes to establish circulation. Reamed from 12740' to 12745', continue running in from 12745' to 13004', tagged 13004' with 10k, reamed from 13004' to 13009', run in from 13020' to 13065', reamed from 13065' to 13100', run in from 13115' to 14397', stack 10k on stump per Baker hand, circulate sweep; incident occurred at 24:48: motor stalled on drawworks and top drive contacted rig floor damaging bails and elevators, contacted key personnel and continue to circulate sweep. August 29, 2018 Continue to circulate sweep, lay down elevators and bails, inspect top drive, crown and derrick, wait on another set of bails, clean cellar area and stack, prepare for installing herculite in morning, work on number 2 pump, monitor well with hole fill, function test top drive, ensuring it functions and works correctly, pull out on elevators from 14387' to 12833', inspect IDS 350 and bail assembly, cracks on link tilt area with no cracks on load bearing area, run in hole from 12833' to 13137' with no issues, pull out from 13137' to 10607', Hilcorp inspectors arrive and inspect top drive, wire wheel paint off damaged area checking for cracks with mag particle, assist MPD rig up, change out cylinders on link tilt, install bails, install new bearings on primary top drive generator, pull out from 10607' to 5025'. August 30, 2018 Pulled out from 10607' to 5091' and cut 125' of drill line. Reset C -0-M. Lay down drill pipe sideways (62 4.5" joints), changed out dies in wrench, continued laying down 4.5" & 4" drill pipe, laid down heavy weight drill pipe, drilling jars, upper mill, and flex joint. Lower mill (left bit, bit sub, double pin in hole total length of 4.35') ran top drive at surface while NOV Tech listened and it checked out. Pre -job safety meeting with Pollard hands and crew members on wire line operations. Rigged up Pollard wire line equipment (sheaves and tools), ran in hole with 5.7" junk basket from surface to 14420', pulled out from 14420' to surface with line motor, rigged down junk basket and made up tools to run in hole with cast iron bridge plug and set it at 14418' for top and 14420' for the bottom of the plug. Pulled out of the hole from 14418' to surface, mixed cement in buckets. Pre -job safety meeting, then ran in hole with wireline. 1s' cement run, pulled out of hole at 1855', mixed cement on rig floor for next run while pulling out of hole. 3 runs total with 17.4 gallons of cement per run while simultaneously working on GeoSpan and attached herculite to cellar, sucked out poor boy, dumped cement at 14360', for all 3 runs and rigged down wireline. A NABORS WL Ililnny Wi.. 1.lA BCU05RD2 August 31, 2018 Rigged up to test casing to 2500psi, chart 30 min per Company Man and well plan,11bbl pumped and 9.5bbi bled back (simultaneous operations: Pollard Wireline changed out to cast iron bridge plug). Rigged up test equip and Pollard wireline, ran in with cast iron bridge plug: tight spot @13901', pulled out and found top piece of cast iron bridge plug came loose and was not straight, tightened up and ran in hole with cast iron bridge plug from 5200'-13090', cast iron bridge plug hung up, pulled up 3850 lbs to get free. Pull out of hole from 13090' to surface. Changed out bridge plug from 5.69" OD to 5.61" OD, ran in hole with 5.61" OD cast iron bridge plug from surface to 13090' (tagged @ 13090'), pulled out of hole from 13090' to surface, rigged down Pollard Group. Remove wear bushing, install test plug and test joint. Pressure down accumulator and open upper doors/remove 4.5 solid boys and install variable bore rams. Fill blowout preventer and choke manifold with water and perform shell test to 4500psi. Wait on State Hand to witness blowout preventer test, tested blowout preventer per state requirements and witnessed by state hand, tested gas alarms. September 1, 2018 Test blowout preventer, upper pipe rams leaking, repairs. Work on pumps. Perform shell test to 4500psi, oil leaking from tattle tail, remove plug from blind rams and inspect emergency packing. Perform shell test to 4500psi, leaking: CM #7, needle valve on test manifold gauge, and 2 gland nuts, repairs. Perform shell test to 4500psi, choke manifold #13 leaking, repairs. Perform shell test to 4500psi, leaking choke HCR in packing area, repairs. Test chart recorder, good. Test manifold, not good, repair. Continue to test BOP. September 2, 2018 Continue to test BOP and record per state regulations, lower IBOP valve on top drive failed, install new lower IBOP valve, install saver sub on top drive, change out bottoms rams to 4" solid body rams, change out top rams to 4.5" solid body rams, change out lover valve on top drive, change out grabber dies in block to remove saver sub, found grooves in top pipe ram cavities --emery cloth down, install new die blocks on top drive grabber box and wire all bolts on lock rings; perform shell test to 4500psi; upper, lower IBOP, TIW, manual kill and choke to 4500 psi for 5 minutes, remove 4.5" test joint and install 4" test joint, change out wash pipe on top drive, check play on top drive with NOV tech, install 4" test joint and test plug and bleed air out, test lower pipe rams, blind rams, CM 10, 12,7, mezzanine kill valve, rig down test equipment, remove catch can and trip nipple, install test plug, test MPD equipment to 200psi for 5 minutes, 1200 psi for 5 minutes, flow line flange leaking, bled off pressure and tighten up flange, re -test Schlumberger lines, rig down test equipment, test GeoSpan equipment, pull test plug, install wear ring, pick up BHA per Baker, build BHA on bottom of first joint of HWDP, install lift ring on annular, install trip nipple, install mouse hole, change elevators from 4" for lift sub to 4.5" for jars, change back, finish BHA. September 3, 2018 Pick up and run in to 2228', pick up 1 joint 4.5" drill pipe, unstring drill line and re -spool ensuring wraps are tight, install protective wrap on service loop, inspect kelly hose, continue to run in hole to 7692', attempt to change kelly hose but did not have proper adaptors, re -install old Kelly hose and install omni wrap on bad spots, continue to run in to 12953', install Kelly hose, run up and down derrick to ensure it is correct, fill lines and test Kelly hose to 1200psi, continue to run in to 13050', mill out per Baker hand. September 4, 2018 Mill from 13060' to 13085', pump sweep, pull out from 14319' to 2785', lay down 4.5" drill pipe from 2785' to 2230' (18 joints), lay down 4" drill pipe from 2230' to surface (64 joints of 4", 5 joints of heavy weight, 1 drilling jars), rig service, rig up Pollard, first run 5.71" gauge run, run through 13090' with no issues, run to 14356' with no issues, pull out with no tight spots, make up Baker cast iron bridge plug, run in and set at 14239', pull out and lay down Pollard, begin picking up whipstock BHA per Baker hand. September 5, 2018 Continue picking up whipstock BHA per Baker hand, pick up 4" drill pipe from shed to 766', make up TIW, shallow test MWD, continue picking up 4" drill pipe to 1591', change out elevators to 4.5", pick up 4.5" to 2310', run 4.5" from derrick to 11419' filling pipe every 2000'; service top drive, blocks, drawworks; run 4.5" pipe to 12662', fill pipe, change out saver sub, continue to run in. A NABORS ou\ Ililrr, \41..11., BCU05RD2 September 6, 2018 Continue to run in to 14173', kelly up and orient whipstock, wash down to top of plug, tag top of plug at 14255', shear at 15k down weight, anchor set, verify 10k overpull, sheared down oat 30k, pre -job safety meeting for displacing to 9.5 ppg OBM, start 20bbl spacer, stage all hands for displacement including Peak vac truck drivers, displace water base mud with OBM, line up and flood MPD lines with OBM, circulate and condition mud in preparation to mill, establish milling parameters as per Baker rep, mill from 14238' to 14251', drill rat hole from 14251' to 14271', pump 20bbl sweep, rig up for FIT, fill lines, line up and do FIT, cart 10 minutes 2150 psi 12.5ppg equivalent, pumped 153 strokes and 9.4 bbls, bled back 8.5 bbl, rig down test equipment, continue to drill rat hole from 14271' to 14282' September 7, 2018 Drill from 14282' to 14299', circulate bottoms up, monitor well for 15 minutes, pump dry job, pull out to 11700', encounter tight hole from 131200' to 13050', monitor well, pump dry job, continue pulling out to 5867', observe improper hole fill, flow check for 30 minutes, slight flow that died off, pull 8 stands, observe improper hole fill, flow check well, slight flow that died off, pull 5 stands with good displacement, pull to 3092', circulate out dry job, continue to pull out to 3369', pull out sideways to 2100'. September 8, 2018 Change out elevators, put cross over on TIW valve, prepare to lay down 4" drill pipe, continue to pull out sideways with 4" drill pipe from 2100' to top of BHA, lay down BHA per directional driller and Baker hand, clear rig floor of all tools, service rig (top drive, blocks, crown, drawworks, driveline bolts, wrench, pipe skate), repair leak on bell nipple clamp, load BHA onto pipe racks, pick up short tools to rig floor, troubleshoot top drive hydraulic issues, pick up BHA as per directional driller from surface to 356', plug into tools and perform surface test at 200 GPM, pick up first joint of 4" and shallow test tools at 200 GPM, run in from 387' to 2081', pick up4" drill pipe from skate, fill pipe, continue to pick up pipe from skate from 2081' to 2381', change out to 4.5" elevators, pick up 4.5" from skate from 2381' to 3713', run in from derrick from 3713' to 4126' filling pipe every 1500'. September 9, 2018 Continue to run in, install 7" well commander at 4369', continue to run in with 4.5" to 11825', fill pipe, test tools per DD, slip and cut drill line, cut 99718 wraps, calibrate blocks, calibrate hookload, install omni cover on Kelly hose and cover on service loops, continue to trip in to 14244', drill out under -gauge hole from 14244' to 14299', drill from 14299' to 14337'. September 10, 2018 Drill from 14337' to 14338', service rig, drill from 14428' to 14743', pull out to 14171', monitor well, service top drive, drawworks, crown, wrench, pumps, install MPD bearing per Swaco hands. September 11, 2018 Run in to 14728', tight spot at 14451', 14' hole fill, circulate and drill 14' hole fill, drill to 14783', encounter -10bph water flow at 14783', start holding back pressure with MPD at 500psi (10.6 ppg), drill to 15050', weight up to 10.5ppg, drill to 15228'. September 12, 2018 Drill from 15228' to 15610', troubleshoot top drive cooling pump failure, line up cooling system on one pump and top off cooling tank, continue drilling to 15664', circulate and get surveys to determine TD, mad pass from 15608' to 15664' per MWD hand, continue to drill to 153680', circulate bottoms up. September 13, 2018 Continue to circulate, pump out to 15170', building psi and releasing, pump in to 15670', circulate sweep, continue circulating and build 141.9ppg pill, pump pill, spot 60bbl pill in open hole, back pressure 500psi, pull to 14176', monitor well and circulate at 14176' to build mud from 10.6ppg to 11 ppg, shut in well, monitor and track psi, build 632psi after 20 minutes, 692psi after 30 minutes, open choke and get flow rate at 10bbl/hr, circulate and weight up system to 11.5ppg. A NABORS 6 ol, BCU05RD2 September 14, 2018 Circulate and weight up to 11.5ppg, pump 70bbl high vis pill, pullout to 11518', pump through kill line to keep hole full, holding 300psi back pressure, pump 80bbl 13.5ppg pill and spot at 11512', monitor well, build to 135psi in 20 minutes, pull out to 10050', pull MPD bearing/rotating head, installed flow nipple and tarp drip pan, continue pull out to 5660', lay down singles to 2300', change out elevators, lay down 4" drill pipe to top of BHA. September 15, 2018 Continue to lay down BHA, clean rig floor, pull wear ring, prepare to run 4.5" liner, change out elevators, rig up Weatherford power tongs, pick up shoe track and run in with 4.5" liner per running order, run to 2667', make up liner hanger, rig down Weatherford, change elevators, rig up to single in with 4.5" drill pipe, run two joints and pumped tubing volume to break circulation at 2765', run in to 5369' with singles, continue running from derrick to 9224'. September 16, 2018 Continue to run in hole with liner, install MPD bearing, run in to 14171', circulate bottoms up, continue running in to 14460', work tight spot, circulate, begin to test choke manifold. September 17, 2018 Continue to run in and work tight spots with casing, pick up cement head and pump cement per Halliburton, did not bump, set hanger, rig down cement head. September 18, 2018 Loggers released from location. A NABORS OM, BCU05RD2 3 GEOLOGICAL DATA 3.1 Lithostratigraphy Tops picked by Hilcorp Geoloqist: Benjamin Silks FORMATION PROGNOSED ACTUAL MD ft TVD ft SSTVD ft MD ft TVD ft SSTVD ft TK Tyonek T5 7 14301.99 13840.05 -13661.65 14316 13848.4 -13670 TK Tyonek T5 8 14370.03 13900.06 -13721.66 14380 13905.4 -13727 TK Tyonek T5 9 14458.21 13977.85 -13799.45 14462 13981.4 -13803 TK Tyonek T5 10 14528.61 14040.09 -13861.69 14529 14044.4 -13866 TK Tyonek T5 11 14578.74 14084.54 -13906.14 14579 14089.4 -13911 TK Tyonek T5 12 14623.64 14124.54 -13946.14 14619 14125.4 -13947 TK Tyonek T5 13 14690.28 14184.18 -14005.78 14684 14187.4 -14009 Top Tyonek G 14760.00 14242.65 -14064.25 14744 14244.4 -14066 HP H2O Sand 14794.90 14274.38 -14095.98 14774 14273.4 -14095 BC G1 A 14953.84 14421.58 -14243.18 14926 14420.4 -14242 BC G1 B 15004.76 14469.53 -14291.13 14970 14466.4 -14288 BC G1 C 15025.07 14488.76 -14310.36 14998 14490.4 -14312 BC G1 D 15066.70 14528.32 -14349.92 15038 14530.4 -14352 BC G1 E 15162.93 14620.51 -14442.11 15134 14624.4 -14446 BC G1 F 15246.86 14701.58 -14523.18 15218 14707.4 -14529 BC G2 A 15292.66 14746.02 -14567.62 15261 14750.4 -14572 BC G2 B 15436.04 14885.48 -14707.08 15405 14892.4 -14714 BC G2 C 15488.58 14936.59 -14758.19 15459 14946.4 -14768 BC G2 D 15509.30 14956.73 -14778.33 15472 14959.4 -14781 Hemlock 15563.54 15009.50 -14831.10 15535 15021.4 -14843 BC H1 15609.66 15054.35 -14875.95 15579 15065.4 -14887 BC H2 15667.82 15110.93 -14932.53 15642 15128.4 -14950 BC H3 15720.75 15162.42 -14984.02 Not drilled Not drilled Not drilled BC H4 15758.52 15199.16 -15020.76 Not drilled Not drilled Not drilled BC H5 15791.50 15231.23 -15052.83 Not drilled Not drilled Not drilled NABORS U I.." ,Yi.. LN BCU05RD2 3.2 Litholoav Details As per Hilcorp direction, Nabors Drilling Solutions provided full service mudlogging program, with lithology descriptions of interval -collected rock cuttings samples in the Tyonek and Hemlock Formations, was initiated at 20' intervals starting at 14260'. The Kenai Group formations of Alaska's Cook Inlet Basin, which include the Sterling, Beluga, Tyonek and Hemlock were deposited in a variable -energy fluvial system within a large closed fore -arc basin. The stratigraphic column consists of very dominant thin to massive sections of sandstone and claystone- siltstone, which are interrupted by extensively -distributed thinner zones of coal and carbonaceous rocks, locally to generally abundant thin layers of original and re -deposited volcanic ash, and minor beds of basal or modal conglomerate. Gradational upward -fining sequences and bi-modal zones are abundant within the sandstones. Stratovolcanoes, perpetually forming along the fore -arc's margins; produced abundant widely -distributed deposits of vitric air fall volcanic ash; which became a major directly -derived source, and/or a consistent lithogenic influence, for all Tertiary soft -sediment rocks in the Cook Inlet Basin. Note that the special modifying term "tuffaceous" in the NDS Lithology Descriptions was created to address the diversity of volcanic -origin rocks in the Cook Inlet basin, and its use may include everything from discernible micro -shard concentrations of disaggregated volcanic glass to rare layers of vitric ignimbrite. Well began at 14238' milling casing window. Sandy Siltstone (14280'-14300') = Pale brown to medium light gray; with a lumpy appearance, brittle yet blocky, massive earthy with a silty to clayey texture, with some laminae, commonly grades between claystone and silty sandstone. Sandstone (14315'-14400') = Dominant medium gray grading between light to medium dark, common brownish hues from diesel contamination; individual grains are clear to translucent gray, cloudy, opaque white, peppered with dark gray to black from carbon material, rare light orange, rare green; dominant fine to medium; subround to subangular; moderate sphericity; soft to easily friable occasional grading to firm friable; common grading to silty with occasional matrix support; dominant point long contact; dominant no visible bedding; occasional aligned carbon material; dominant quartz and feldspar with occasional altered to kaolin; no discernable oil shows above background diesel. Sandstone (14410'-14480') = Dominant medium to medium light gray, rare light gray, common brownish hues from diesel contamination; individual grains are clear, translucent gray to cloudy, opaque white, rare light orange, peppered with carbon material; dominant fine to med, occasional upper medium; fair to well sorted; subround to subangular; moderate sphericity, easily friable to friable, occasional firm friable; common point long contact; grading to matrix support with increase silt content; dominant no visible bedding, with occasional weak alignment of carbonaceous material; dominant quartz and feldspar with occasional all to kaolin; no discernable oil shows above background diesel. Sand/Tuffaceous Sandstone (14480'-14570') = Medium to medium light gray with yellowish gray secondary hues overall with individual grains dominantly clear to translucent quartz and volcanic glass; very fine upper to very coarse lower, dominantly fine upper to lower; angular to subangular; moderately well sorted; unconsolidated with common ash supported pieces; firm to moderately hard, waxy; light brownish gray; heavy OBM contamination; dull yellowish gold, uniform fluorescence; slow dull milky cut fluorescence; weak, slow, pale straw visible cut; no free oil; no oil indicators above OBM background levels. Coal (14570'-14610') = Black with brownish black secondary hues; firm to hard; brittle to dense; planar fracture dominant; massive to platy and flaky; resinous to slightly earthy luster; smooth texture; bituminous; no outgassing observed; heavy OBM contamination. A NABORS O4l H Il� \4i.. 1.11 BCU05RD2 Tuffaceous Claystone/Tuffaceous Siltstone (14610'-14680') = Note heavy OBM staining, medium to medium dark gray with brownish gray secondary hues, very firm to moderately hard; brittle at times; irregular, wedge shaped, slightly earthy to waxy luster; silty to clayey texture; trace dark brown to black carbonaceous laminations and inclusions; no oil indicators present above OBM background levels. Tuffaceous Sandstone/Sand (14680'-14740') = Medium to medium light gray with abundant darker secondary hues; note heavy OBM staining; firm to brittle waxy; individual grains dominantly clear to translucent quartz and volcanic glass very fine upper to medium lower; moderately to well sorted; subround to subangular; moderate sphericity; easily friable to occasionally firm friable, no oil indicators present above background OBM. Sand (14740'-14850') = Medium light to light gray overall with individual grain dominantly clear to translucent quartz and volcanic glass, light to medium gray to greenish gray, trace black and dusky red; very fine upper to coarse lower, dominantly fine upper to medium lower; angular to subangular with trace subrounded; moderate sphericity; dominantly unconsolidated with scattered ash supported grains; yellowish gray; firm to moderately hard; waxy; no oil indicators above OBM background levels. Sand/Tuffaceous sandstone (14850'-14930') = Medium light to light gray with individual grains dominantly clear to translucent quartz and volcanic glass very fine upper to medium upper, dominantly fine; angular to subangular; moderate sphericity; poor to fair sorting; unconsolidated with scattered tuffaceous sandstone; yellowish gray with abundant darker secondary hues; firm to crumbly, ashy supporting matrix; waxy luster; fine to medium; trace thin coal beds; no oil indicators above OBM levels. Tuffaceous sandstone/sand (14930'-15000') = Medium light gray with yellowish gray and darker secondary hues; firm to crumbly and friable, irregular shaped waxy appearance from ash supporting matrix; fine to medium grain; individual grains dominantly clear to translucent quartz and volcanic glass with abundant multicolored liths; very fine upper to trace very coarse lower, dominantly fine upper to medium lower; angular to subangular; poor to fair sorting; unconsolidated; dull yellow fluorescence; very slow, dull, milky white cut fluorescence; no free oil no oil indicators above OBM background. Coal (15000'-15050') = Black; moderately hard to brittle; flaky to platy; planar fracture dominant with trace conchoidal; resinous luster, smooth texture bituminous; no outgassing observed; present as thin beds in dominantly sand/tuffaceous sandstone formation. Sandstone (15080'-15180') = Medium light gray to light gray with occasional brownish hues; grains are dominantly glassy, clear to cloudy, gray to opaque white, scattered black from lithology fragments and carbonaceous material; dominantly medium, fine to rare upper coarse; fair sorting, subround to dominant angular, moderate to occasionally low sphericity; common frosted surface features, easily friable to occasional firm friable with scattered bit disaggregated sand grains; grade between tightly packed with point long contact to occasional float grains with increased ash and silt content; commonly grading to sandy siltstone; dominant quartz with feldspar and lithic fragments, occasional alteration to kaolinite; interbedded with coal and occasional floating carbonaceous material, occasional possible light brown oil stain, possible OBM contamination; no discernable oil shows above background OBM. Coal (15220') = Black with slight brownish hues; moderately hard; tough to crunchy; dominant blocky to planar fracture, occasionally sub -conchoidal; tabular to elongated cuttings habit; dull to resinous luster; dominant smooth texture; seen as thin beds in sandstone with common scattered carbonaceous material in siltstone and claystone. Siltstone (15240'-15270') = Grade from sandstone to sandy siltstone and claystone; overall medium to medium light gray with slight brownish hues; floating sand grains are very fine to fine, dominant quartz; trace carbonaceous material; grades back to silty sandstone at 15270'. A NABORS 10 MI IIiM\4d-�II. BCN5RD2 Sandstone (15295'-15340') =Medium light gray to light gray with overall brownish hues and off white from tuffaceous content, individual grains are cloudy to clear, gray to opaque white, scattered lithology fragments; very fine to medium, rare upper medium/lower coarse; fair to well sorted; angular to subangular, occasional very angular; moderate to low sphericity; common frosted surface features; easily friable to firm friable, rare moderate hard; common loose bit disaggregated grains; grades between tightly packed with point long contact to floating in silt/tuffaceous matrix; dominant quartz and feldspar with some alteration to kaolin; oil shows above standard OBM background; instant milky yellowish white cut fluorescence; moderate brown visible cut; moderate to light brown residual ring; oil shows skewed by OBM. Sand/Tuffaceous Sandstone (15340'-15490') = Medium light to light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, light to medium gray to greenish gray; very fine upper to very coarse lower, dominantly fine upper to medium upper; angular to subangular; poor to fair sorting; dominantly unconsolidated with tuffaceous sandstone; medium light gray with darker secondary hues; firm to friable; waxy appearance; no free oil; uniform dull yellow fluorescence; slow yellowish white cut fluorescence; slow pale straw visible cut; poor oil indicators; shows masked by OBM. Sand (15490'-15580') = Medium light to light gray with individual grains dominantly clear to translucent quartz and volcanic glass, light to medium gray to greenish gray and trace dusky red; very fine upper to trace very coarse upper, dominantly fine; angular to trace subrounded, dominantly subangular; moderate sphericity; poor to fair sorting; disaggregated with ashy supporting matrix common; medium to medium light gray with abundant darker secondary hues; fragile; trace very thin coal beds/lithic coal in samples, continued OBM masking oil show indicators, none to very poor oil indicators present. Sandstone (15620'-15680') = Overall medium light gray with slight light gray and brown hues; individual grains are glassy, clear, cloudy, gray, opaque and light red, bluish, greenish lithology fragments; scattered black fair carbon material; very fine to upper medium with rare upper coarse; fair to poor sorted; dominant subangular with angular and subround; moderate to low sphericity; common frosted surface features, easily friable to firm friable with common soft and bit disaggregated when increase in ash content; common grade to and interbedded with very fine grained sandstone/sandy siltstone; scattered coal; shows above background OBM contamination: slight milky yellowish white cut fluorescence; light to medium brown visible cut; light brown residual ring; no other discernible oil shows. A NABORS 11 WL BCU05RD2 3.3 Sampling Program Set Type and Purpose Interval Frequency Distribution Benjamin Silks A Washed and Dried 14240'— 15680' 20' Hilcorp Alaska LLC Reference 3800 Center Point Drive, Suite 100 Anchorage, AK 99503 Benjamin Siks B Washed and Dried 14240'— 15680' 20' Hilcorp Alaska LLC Reference 3800 Center Point Drive, Suite 100 Anchorage, AK 99503 Kenny Henry Drilling Solutions C Wet SampleNabors 15200'— 15680' 20' 4400 West Admiral Doyle Drive Cuttings New Iberia, LA 70560 Kenny Henry Drilling Solutions D Mud SampleNabors 15200'— 15680' 100' 4400 West Admiral Doyle Drive Reference New Iberia, LA 70560 Dry samples 14240'— 15100', 15100'— 15680' (2 boxes per set) A NABORS 12 WL BCU05RD2 4 DRILLING DATA 4.1 Surveys Measured Depth ft Incl. Azim. True Vertical Depth ft Latitude (ft) N+, S- Departure (ft) E+, W- Vertical Section Incr ft Dogleg Rate °/100ft 14205.43 28.75 64.46 13749.07 1751.35 1125.05 2044.88 1.27 14238.00** 28.59 64.81 13777.65 1758.05 1139.16 2059.46 0.71 14281.15 28.9 69.33 13815.48 1766.12 1158.26 2078.46 5.09 14314.01 28.41 72.94 13844.32 1771.22 1173.17 2092.42 5.47 14343.19 27.11 76.39 13870.15 1774.82 1186.27 2104.04 7.09 14403.98 23.81 84.9 13925.04 1779.17 1211.96 2124.89 8.09 14460.5 21.16 94.91 13977.28 1779.31 1233.5 2139.81 8.22 14523.01 19.71 96.89 14035.86 1777.08 1255.21 2153.13 2.57 14582.18 18.42 96.72 14091.78 1774.79 1274.4 2164.68 2.17 14644.28 18.78 98.24 14150.64 1772.21 1294.04 2176.32 0.96 14713.22 18.2 100.68 14216.02 1768.63 1315.6 2188.56 1.4 14769.61 16.92 103.46 14269.78 1765.08 1332.24 2197.44 2.71 14839.18 16.02 106.04 14336.5 1760.07 1351.31 2206.93 1.67 14902.09 13.97 106.64 14397.26 1755.5 1366.93 2214.36 3.27 14964.29 12.02 110.5 14457.87 1751.08 1380.19 2220.29 3.43 15026.43 11.07 113.54 14518.75 1746.43 1391.72 2224.85 1.81 15089.18 9.64 120.6 14580.48 1741.35 1401.77 2228.08 3.05 15149.71 9.29 117.89 14640.18 1736.49 1410.44 2230.52 0.94 15213.79 8.4 123.64 14703.5 1731.48 1418.91 2232.71 1.95 15276.05 8.01 123.3 14765.13 1726.58 1426.32 2234.26 0.64 15338.35 7.6 126.03 14826.85 1721.77 1433.28 2235.56 0.89 15399.8 7.64 123.23 14887.76 1717.14 1439.99 2236.81 0.61 15497.31 7.58 122.75 14984.4 1710.11 1450.82 2239.17 0.09 15586.46 7.08 123.36 15072.83 1703.91 1460.35 2241.23 0.56 15647.48 6.21 124.26 15133.44 1699.98 1466.22 2242.42 1.44 15680* 6.21 124.26 15165.77 1698 1469.13 2242.99 0 **Tie in *Projected A NABORS 13 a O v d N V 0 F - o z LL o z a o o Z U W a fr Q LLL N ai � V N _ N r O � Y _ co d LL D ~ W 000 N coO Z — v a W ~ x M N 0 ? � M A H 0 N r LO N L H w mm M m F � @ Y [0 N ro r m Z J r N = � 3 J O m @ a) > @ —j(D N � M 0 7 0 �N,, 11 II F II nn a- LL UM N O J m « °' i U , C N O U 0o j C O N 0 n 11 11 '2 N N M O a) r 0) O c N VE M 7n MMMMM(0 l0 OaD aD nN u�(O0 W W �_ 0 M N M M M M M OD M M M n N 0 7 N N 0 0 fA E �MMMMMMMOaD aa ON��MM Q M m M M M M M M M MN .... n ON M aJ M O M n�OpNN M M M M CD N�NtO MaJnM�M(D V7 J rn �a07 sf lOMMN Z M M O N N N N N N � Q N r 0 0 0 0 0 0 0 0 0 7 W N N N N N N co l0 u0 M c 0 N n O 0 O 0 M 0 M O 0 7 7 v 7 7 7 7 N M N N � 7 n 0 0 N N H "-"- --"-".. N N N N N M M O f6 wNGDaDmw OaW a�In� N�00MOO�� ,,too nu)wo m nc6m6",1 rr eororomo�ao M 7 mo�mow�onnnnnmm nco MM v: W N �0 �06 n n N O O�M�1�� M (A r N N 6 W LL a N N N N N N N N N N N N N N N N 00 a J = 77 V 77777 N aJ (0 aJ aJ f0 V7M 0tONN F O vavvvvvvavavvvvvv7vi lri = J 7 �� O0t0 t07 MM77 � � O R) 7 7 N N N 4/ (7 r 7 M f7 l0 CC 7 N N N N Z O I� r W O. OMOD to M mcoomcovoo�MlnMnu�u,nn n n n n t t) O M n N n V (O a D M M V 7 aM NON n n7N O� n (0 a W 77On n n V%` j y Co nmm�nm0 (D N IDm�mmmnnoom N O N �jOJ M M M M M M M M M M (MO M M M O O O 000000000))M 777 77777 nN a0N N n �� t �r 777 77777 MM Mm V' It U)Mt0 MND dt ,0,0 aJ (00 a) V o't0 M 0,1M MM000000 M V) V) V)O aJ (O aJ MM MN 7"a0 as WW WM �C 7777aa 7777 OD aD aDNN V 777NN 77777777 W -------------- W aDM W NMnN(owwwwa W W N t0 0000NN X010 M10 MMO �0 �0 O NM M�NM RNt01� 000 -s -a co -a ID - O r, � � r` LO O j m � `ya 'c a) O Y O a .2 ;i! N O II E O }"az CL Y II } O Q C a) E � 3 J O m @ a) > @ —j(D N � YUs y� a) a) '2 @ . @ Il LL II 2 11 II F II > U m @ a- LL N O J m « °' i U , C N O U 0o j C O t t U n 11 11 '2 >li(AU Z4 'o L � s Q U Q im 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O N V l0 w O N V CO C C C V ti .Ni � .moi .moi .moi a ri ri ri rl rl 8r or r Bra -s �—r 4r, -O z 8r0 -s z- 61 Fro —6 �-A r Flo —6 2- �r 8l0 —6 F9 l 8r0 -6 �-S r 8l0 —6 2-d r 8rp —6 �-F r dl0 -6` r-2 r 8l0 -6 �—r l 8l0 -6 �-O r 8r0 -6` O - gr 6 O� -R 9 —6 r0 —s 8r o- -9 R -6 70 g r—S—s l0 2� 8 -6 l0 �—F g -6 r0 r—� g —6 r0 F -r g —6 l0 �-r F 8l0 —A I -O 8 F -S l0 r-6 8l0 —8 �-8 8ro —8 z- d'r0 F -A o-9 o r-8 0 m Z s� Hilcorp BCU 05RD2 �11D► NABORS DML Digital Mudlogging � �� Hydrocarbon Show Report #1 Tvonek G2A API Number 133-20262-02-00 During Show Average Maximum SHOW Date: 9/12/18 Time: 05:36-07:56 Rig Hilcorp 169 33.9 5648 5764 6424 Start End Borough Kenai Peninsula 96.2 Interval 15300' MD 15336' MD State Alaska Country USA 10.6 36' 14789' TVD 14824' TVD Parameter Before Show Average During Show Average Maximum After Show I Average ROP(ft/hr) Torque(ft/lbs) WOB(klbs) RPM Pump Pressure Flow In(gal/min) Mud Weight(ppg) Chlorlds(mg/L) 41.5 31.2 91.3 33.9 5648 5764 6424 5947 9.6 9.4 10.1 9.8 99.6 94.0 99.3 96.2 2629 2761 2813 2721 208.5 217.1 220.0 216.5 10.5 10.6 10.6 10.6 I - - - - Gases Total (units) C1 (ppm) C2 (ppm) C2 (ppm) C4 (ppm) Cs (ppm) 44.7 47.2 54.8 1 44.1 5066.1 5785.1 7171.4 5052.7 14.9 58.5 106.6 19.0 3.8 15.4 36.0 4.6 2.8 6.7 13.6 3.2 1.3 2.1 5.1 1.7 E Wu -15301 -15305 -15309 -15313 15323 -15328 Free Oil In Mud Visible Cut RY Ave I Nigh Masked By OBM loco Masked OBM Intensity Med-Dark Colorl Brown Intensity Colorl Medium Y_ Ino --- - / C NDENSA E Apparent 10 1 i � NO PRODUC IVE C1/C3 C7/C4 Ct/C5 Residual Fluorescence Porosity Amount % Distribution Intensity Color C7/C2 Lithology Description Sandstone = Medium light gray to light gray with overall brownish hues and off white from tuffaceous content; individual grains are cloudy to clear, gray to opaque white, scattered lithology fragments; very fine to medium, rare upper medium/lower coarse; fair to well sorted; angular to subangular, occasional very angular; moderate to low sphericity; common frosted surface features; easily friable to firm friable, rare moderate hard; common loose bit disaggregated grains; grades between tightly packed with point long contact to floating in silt/tuffaceous matrix; dominant quartz and feldspar with some alteration to kaolin. Oil Indicators From Cuttings And Mud Mud Type Enviromul OBM Show Rating Petroleum Odor Free Oil In Mud Visible Cut Residual Cut (Dry Ring) Ave I Nigh Masked By OBM Oty Fluor Pops Color Size Masked OBM Intensity Med-Dark Colorl Brown Intensity Colorl Medium 0.6 0.8 Sheen Brown Apparent Sample Fluorescence Cut Fluorescence Residual Fluorescence Porosity Amount % Distribution Intensity Color Oil Stein Speed Fast Intensityl Strg Opaque Color Yel-White Intensityl Moderate Color Lt -Orange Amount % Distribution I Colorl Permeability 1 Outgassing I None Notes I Heavily skewed by OBM/diesel Show Description/Comments Oil shows above standard OBM background: instant milky yellowish white cut fluorescence; moderate brown visible cut; moderate to light brown residual ring; oil shows skewed by OBM. Ratio ROP Increase To Gas Increase Geologist (s) Sarah Chamlee 0.75 1.06 H 0 BCU O5RSRD2 Hilco Hydrocarbon Show Report #1 Tyonek G2A Pixler Plot 010 NABORS DML D;gital Mudlgagmq Geologist (s) Sarah Chamlee 15301 —15303 —15307 —15309 —15325 —15327 —15313 —15316 —15331 —15334 10000 1000 - — - - - / / / / / / / / / / / / / / / C. 100 CL / CONDENSATE / OIL WINDOW 70 NON PRODUCTIVE 1 C1/C2 C1/C3 G1/C4 C1/C5 Geologist (s) Sarah Chamlee Hilcorp 14 BCU 05RD2 011► NABOBS DML Digital Mudlogging C� Hydrocarbon Show Report #2 Tvonek G2 B -C API Number 133-20262-02-00 •7 CHOW Date: 9/12/18 Time: 12:52-13:53 Rig Hilcorp 169 102.8 7315 14.9 Start End Borough Kenai Peninsula Interval 15425' MD 15481' MD State Alaska Country USA 56' 14913' TVD 10000 14970' TVD Parameter Before Show Average During Show Average Maximum After Show I Average ROP(ft/hr) Torque(ft/lbs) WOB(klbs) RPM Pump Pressure Flow In(gal/min) Mud Welght(ppg) Chlorlde(mg/L) 47.8 6372 14.4 60.5 6616 13.9 102.8 7315 14.9 71.5 6906 13.6 100.4 102.1 105.0 106.7 2743 2833 2897 2871 216.9 220.2 220.5 219.1 10.6 10.6 10.6 10.6 - - - Gases Total (units) C1 (ppm) C2 (ppm) C3 (ppm) 04 (ppm) CB (ppm) 53.0 y 59.2 63.2 55.7 5614.3 6309.6 7076.4 5846.2 27.4 68.0 109.3 23.5 8.6 31.6 60.6 7.8 13.0 22.6 32.6 16.8 9.6 12.5 19.1 13.3 E Lithology Description Sand/Tuffaceous Sandstone = Medium light to light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, light to medium gray to greenish gray; very fine upper to very coarse lower, dominantly fine upper to medium upper; angular to subangular; poor to fair sorting; dominantly unconsolidated with tuffaceous sandstone; medium light gray with darker secondary hues; firm to friable; waxy appearance. Oil Indicators From Cuttinas And Mud Mud Twe Enviromul OBM Show Rating Petroleum Odor Free Oil in Mud -15425 -15438 -15441 Residual Cut (Dry Ring) -15459 -15468 -15477 Masked By OBM arty Pops Color Size DRY GAS Intensity Color loco Intensity Color 0.4 0.6 Sheen Straw Apparent Semple Fluorescence Cut Fluorescence Residual Fluorescence Porosity -CNDEHSAE 50 Oil Stain Amount % Distribution Color Speed 1 Stow Intensity Strong Color Yet -White Intensity Color Even Permeability i Outgassing None Yellow Notes I Heavily skewed by OBM/diesel i to ---F---N6F 1PRODUC1IVE C1/C2 C11C3 Cl/C4 clics Lithology Description Sand/Tuffaceous Sandstone = Medium light to light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, light to medium gray to greenish gray; very fine upper to very coarse lower, dominantly fine upper to medium upper; angular to subangular; poor to fair sorting; dominantly unconsolidated with tuffaceous sandstone; medium light gray with darker secondary hues; firm to friable; waxy appearance. Oil Indicators From Cuttinas And Mud Mud Twe Enviromul OBM Show Rating Petroleum Odor Free Oil in Mud Visible Cut Residual Cut (Dry Ring) Ave High Masked By OBM arty Pops Color Size Masked OBM Intensity Color Pale Intensity Color 0.4 0.6 Sheen Straw Apparent Semple Fluorescence Cut Fluorescence Residual Fluorescence Porosity Amount % Distribution Intensity Color 50 Oil Stain Amount % Distribution Color Speed 1 Stow Intensity Strong Color Yet -White Intensity Color Even Permeability Dull Outgassing None Yellow Notes I Heavily skewed by OBM/diesel Show Description/Comments No free oil; uniform dull yellow fluorescence; slow yellowish white cut fluorescence; slow pale straw visible cut; poor oil indicators; shows masked by OBM. Ratio ROP Increase To Gas Increase 1.27 1.12 Geologist (s) Ralph Winkelman Hilcorp It BCU OSRD2 HiIOF Hydrocarbon Show Report #2 `^ ^ Tyonek G2 B -C Pixler Plot Ohl NABORS DML Digital Mudlogging Geologist (a) Ralph Winkelman 15425 —15429 —15436 —15442 —15445 —15450 —15455 — 15458 —15465 —15472 —15477 —15460 10000 DRY GAS l000 / / a 100 CL CONDENSATE / -� OIL WINDOW 10 NON PRODUCTIVE 1 C7/C2 C1/C3 C1/C4 C1/C5 Geologist (a) Ralph Winkelman Hilcorp BCU 05RD2 11111NABOBS DML Digital Mud/ogging Hydrocarbon Show Report #3 Hemlock H-1-2 4PI Number 133-20262-02-00 During Show Average Maximum SHOW Date: 9/12/18 Time: 19:41-22:33 91g Hilcorp 169 47.2 6578 6284 7104 Start End Borough Kenai Peninsula 97.7 Interval 15610' MD 15662' MD Btate Alaska Country USA 10.7 52' 15095' TVD 15147' TVD Parameter Before Show Average During Show Average Maximum After Show Average ROP(tt/hr) Torque(M/lbs) WOB(kibe) RPM Pump Pressure Flow In(gal/min) Mud Welght(ppg) Chlorid!(mg/L) 29.2 1 29.7 64.5 47.2 6578 6284 7104 7022 14.8 14.7 15.1 13.1 111.6 101.9 111.7 97.7 2746 2701 2753 2838 216.9 213.4 217.4 221.6 10.7 10.7 10.7 10.7 - - - Gases Total (units) C7 (ppm) C2 (ppm) C3 (ppm) C4 (ppm) CB (ppm) 51.7 51.9 54.5 54.9 5057.4 5254.4 5818.8 6448.7 23.0 28.8 48.8 20.9 8.5 8.2 13.1 6.5 16.0 13.8 16.7 0 13.6 12.9 16.0 0 Vu 15610 -15622 -15632 Free Oil in Mud -15640 -15658 -15660 Residual Cut (Dry Ring) Ave I High Masked By OBM DRY GAS Intensity Color ,000 Intensity Colorl Light 0.3 0.4 Sheen Brown Brown Apparent Sample Fluorescence Cut Fluorescence Residual Fluorescence Porosity Amount "Oil Distribution IntensityDistribution Color Stain Speed Intensity Color Quick Intensity Weak -Mod Color Yellow Amount % Colorl Moderate Permeability Yel-White Outgassing I None Masked OBM I Notes Heavily skewed by OBM/diesel /CIDNIOMWE - i i N. ,o NO PRODUC IVE - CUM C1/C3 CI/C4 clic5 Lithology Description Sandstone = Overall medium light gray with slight light gray and brown hues; individual grains are glassy, clear, cloudy, gray, opaque and light red, bluish, greenish lithology fragments; scattered black fair carbon material; very fine to upper medium with rare upper coarse; fair to poor sorted; dominant subangular with angular and subround; moderate to low sphericity; common frosted surface features; easily friable to firm friable with common soft and bit disaggregated when increase in ash content; common grade to and interbedded with very fine grained sandstone/sandy siltstone; scattered coal. Oil Indicators From Cuninas And Mud Mud Tvoe Enviromul OBM Grow Rating Petroleum Odor Free Oil in Mud Visible Cut Residual Cut (Dry Ring) Ave I High Masked By OBM uor Oty Masked OBM Plops Color Size Intensity Color Light -Med Intensity Colorl Light 0.3 0.4 Sheen Brown Brown Apparent Sample Fluorescence Cut Fluorescence Residual Fluorescence Porosity Amount "Oil Distribution IntensityDistribution Color Stain Speed Intensity Color Quick Intensity Weak -Mod Color Yellow Amount % Colorl Moderate Permeability Yel-White Outgassing I None Masked OBM I Notes Heavily skewed by OBM/diesel Show Description/Comments Shows above background OBM contamination: slight milky yellowish white cut fluorescence; light to medium brown visible cut; light brown residual ring; no other discernible oil shows. Ratio ROP Increase To Gas Increase Geologist (s) Sarah Chamlee 1.02 1.00 H 0 BCU O5RSRD2 Hilcor Hydrocarbon Show Report #3 ^^r^ Hemlock H1-2 Pixler Plot WUI NABORS DML Digital Mudlogging Geologist (s) Sarah Chamlee 16510 —15615 —15619 —15625 —15628 —15635 —15640 —156.15 —15649 —15653 —15657 —15661 10000 DRY GAS 1000 i i i � E E 100 - CL i i CONDENSATE J OIL WINDOW 10 � NON PRODUCTIVE 1 C1/C2 C7/C3 C1/C4 c1/C5 Geologist (s) Sarah Chamlee 4110 NABORS DML Digital Mudlogging Hilcorp Alaska, LLC Beaver Creek BCU 05RD2 HilcorD 169 DAILY WELLSITE REPORT DATE: 8/27/18 TIME: 24:00 PRESENT OPERATION: RIH PRESENT DEPTH: 14,538 DEPTH YESTERDAY: 14,538' SAMPLE DEPTH: 14,538' 24 HOUR FOOTAGE: O' REPORT FOR: Robert Wall CASING DATA @° BIT DATA BHA TYPE: I Drill String k -Revs: @ CONDITION No. Size Type S/N Jets IN OUT Footage Hours I -O -Char -Loc -B -G -Char -Pull SURVEY DATA DEPTH INCLINATION AZIMUTH TVD VSECTION +N/S- COORDINATES +E/W- DLS MWD/LWD SUMMARY INTERVAL: to TOOLS: MUD REPORT DEPTH MUD TYPE MUD BASE Flowline Temp 0 OF MW VIS PV YP Gels FL Cake Unc Sol Sd pH Oil Pf/Mf Cl- MBT Ca+ Cor Sol DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ N/A FT/HR SURFACE TORQUE @ @ N/A FT/LBS WEIGHT ON BIT @ @ N/A KLBS TOPDRIVE RPM @ @ N/A RPM PUMP PRESSURE @ @ N/A PSI FLOW IN @ @ N/A GPM GAS SUMMARY (units) HIGH LOW AVERAGE GASES TRIP WIPER No Circulation @ @ DITCH H2S(ppm) @ @ H2S Zone Gas Survey CHROMATOGRAPHY (ppm) Downlink Down Time CONNECTION HIGH = 0 METHANE (C-1) @ @ ETHANE (C-2) @ @ AVG = 0 PROPANE (C-3) @ @ Current= 0 CURRENT Background= BUTANE (C-4) @ @ PENTANE (C-5) @ @ (DITCHWS) Average = I HYDROCARBON SHOWS Moderate INTERVAL LITHOLOGY/REMARKS GAS OIL DESCRIPTION LITHOLOGY Current Formation: General Lithology: Current Lithology % : LAG SUMMARY Annular Volume bbl / % Theoretical / @ SPM / strokes @ DAILY ACTIVITY SUMMARY Pick up and single in with 4.5" DP, POOH and rack back 28 stands in derrick, pick up BHA, RIH picking up heavy weight, level derrick, continue RIH METAL AM WEIGHT PM NABORS PERSONNEL n, vvinnelman, n. iuwe, o. voanuec, o. va1911t REPORT BY Sarah Chemise DAILY COST $3,045 01111NABORS DML Digital Mudlogging Hllcorp Alaska, LLC Beaver Creek Unit BCU 05RD2 Hilcoro 169 DAILY WELLSITE REPORT DATE: 9/28/18 TIME: 24:00 PRESENT OPERATION: Circulating PRESENT DEPTH: 14,583' DEPTH YESTERDAY: 14,583' SAMPLE DEPTH: 14,583' 24 HOUR FOOTAGE: 0' REPORT FOR: Robert Wall & Oliver Amend CASING DATA 20"cond @432' 133/8" @ 3511' 95/8" @ 11,698' 7" @ 14,915' BIT DATA BHA TYPE: Cleanout Assembly I CONDITION No. Size Type S/N Jets IN OUT Footage Hours 1 -0 -Char -Loc -B -G -Char -Pull SURVEY DATA DEPTH INCLINATION AZIMUTH TVD VSECTION +N/S- COORDINATES +E/W- DLS MWDILWD SUMMARY INTERVAL: to TOOLS: MUD REPORT DEPTH MUD TYPE MUD BASE Flowline Temp of MW VIS PV YP Gels FL Cake Unc Sol Sol pH Oil Pf/Mf Cl- MBT Ca+ Cor Sol DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ N/A Fr/HR SURFACE TORQUE @ @ N/A FT/LBS WEIGHT ON BIT @ @ N/A KLBS TOPDRIVE RPM @ @ N/A RPM PUMP PRESSURE @ @ N/A PSI FLOW IN @ @ N/A GPM GAS SUMMARY (units) HIGH LOW AVERAGE GASES TRIP WIPER CIRCULATING GAS 317,0 @ 25.0 @ 95.0 DITCH Zone Gas Survey CHROMATOGRAPHY (ppm) Downlink Down Time CONNECTION HIGH= METHANE C-1) @ @ ETHANE (C-2) @ @ AVG = PROPANE (C-3) @ @ Current = CURRENT Background = 25 BUTANE (C-4) @ @ PENTANE (C-5) @ @ DITCH Average = 95 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS OIL DESCRIPTION LITHOLOGY Current Formation: General Lithology: Current Lithology°/ : LAG SUMMARY Annular Volume 681 bbl / /Theoretical 100% / 65 min @ 196 SPM / 12747 strokes @ 13487' DAILY ACTIVITY SUMMARY RIH from 5092'to 9585', rig service (grease blocks, TDS, wrench, drawworks, check all fluids), cont to RIH from 9585' to 10732', change out die block and install grabber box pin, assist MPD with equipment, adjust link tilt, cont to RIH from 10732' to 11911' with no issues at liner top, cont picking up pipe from 11911' to 12740', tagged with 10k, pump with 46 strokes to establish circulation. Reamed from 12740' to 12745', continue RIH from 12745' to 13004', tagged 13004' with 10k, reamed from 13004' to 13009', RIH from 13020' to 13065', reamed from 13055' to 13100', run in from 13115' to 14397', circulate sweep. NABORS PERSONNEL H. win Kelman, A. f ume, a. unaimee, a. miyin REPORT BY Sarah Chemise DAILY COST $3,045 NABORS DML Digital Mudlogging Hllcorp Alaska, LLC Beaver Creek Unit BCU 05RD2 Hilcorn 169 DAILY WELLSITE REPORT DATE: 8/29/18 TIME: 24:00 PRESENT OPERATION: POOH PRESENT DEPTH: 14,397' DEPTH YESTERDAY: 14,397' SAMPLE DEPTH: 14,397' 24 HOUR FOOTAGE: 0' REPORT FOR: Robert Wall & Oliver Amend CASING DATA 20"cond @432' 133/8" @ 3511' 95/8" @ 11,698' 7" @ 14,915' BIT DATA BHA TYPE: I CONDITION No. Size Type S/N Jets IN OUT Footage Hours 1 -0 -Char -Loc -B -G -Char -Pull SURVEY DATA DEPTH INCLINATION AZIMUTH TVD VSECTION +N/S- COORDINATES +E/W- DLS MWD/LWD SUMMARY INTERVAL: to TOOLS: MUD REPORT DEPTH MUD TYPE MUD BASE Flowline Temp OF MW VIS PV YP Gels FL Cake Unc Sol Sd pH Oil Pf/Mf Cl- MBT Ca+ Cor Sol DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ NIA FT/HR SURFACE TORQUE @ @ N/A FT/LBS WEIGHT ON BIT @ @ N/A KLBS TOPDRIVE RPM @ @ N/A RPM PUMP PRESSURE @ @ N/A PSI FLOW IN @ @ N/A GPM GAS SUMMARY (units) HIGH LOW AVERAGE GASES TRIP WIPER CIRCULATING GAS 676.0 @ 13.0 @ 25.0 DITCH Zone Gas Survey CHROMATOGRAPHY (ppm) Downlink Down Time CONNECTION HIGH = METHANE (C-1) @ @ ETHANE (C-2) @ @ AVG = PROPANE (C-3) @ @ Current = CURRENT Background= n/a BUTANE C-4) @ @ PENTANE (C-5) @ @ oircH Average = 25 HYDROCARBON SHOWS INTERVAL I LITHOLOGY/REMARKS GAS OIL DESCRIPTION LITHOLOGY Current Formation: General Lithology: Current Lithology°/ : LAG SUMMARY Annular Volume 681 bbl / % Theoretical 100/ / 60 min @ 196 SPM / 11808 strokes @ 13497' DAILY ACTIVITY SUMMARY Cont to circ sweep, LD elevators and bails, inspect TO, crown, derrick, wait on another set of balls, work on number 2 pump, monitor well with hole fill, function test TD, ensure functions and works correctly, POOH on elevators 14387'-12833', inspect IDS 350 and bail assy, cracks on link tilt area with no cracks on load basting area, RIH 12833'-13137'w/no issues, POOH 13137'- 10607', Hilcorp inspectors arrive and Inspect TO, wire wheal paint off damaged area, check for cracks w/mag panicle, assist MPD RU, CO cylinders on link tilt, Install balls, install new bearings on primary TD gen, POOH 10607'-5025'. NABORS PERSONNEL H. wmKeiman, N. Uwe, o. wmwee, o. rr„yu, REPORT BY Sarah Chamlee DAILY COST $3,045 01p NABORS DML Digital Mudlogging Hllcorp Alaska, LLC Beaver Creek Unit BCU 05RD2 Hilenrn 169 DAILY WELLSITE REPORT DATE: 8/30/18 TIME: 24:00 PRESENT OPERATION: RD Wireline PRESENT DEPTH: 14,428' DEPTH YESTERDAY: 14,428' SAMPLE DEPTH: 14,428' 24 HOUR FOOTAGE: 0' REPORT FOR: Robert Wall & Oliver Amend CASING DATA 20" Gond @ 432' 133/8" @ 3511' 95/8" @ 11,698' 7" @ 14,915' CONDITION BIT DATA BHA TYPE: I No. Size Type S/N Jets IN OUT Footage Hours 1 -0 -Char -Loc -B -G -Char -Pull SURVEY DATA DEPTH INCLINATION AZIMUTH TVD V SECTION +N/S- COORDINATES +E/W- DLS MWD/LWD SUMMARY INTERVAL: to TOOLS: MUD REPORT DEPTH MUD TYPE MUD BASE Flov4ne Temp OF MW VIS PV YP Gels FL Cake Unc Sol Sal pH Oil Pf/Mf Cl- MBT Ca+ Cor Sol DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION @ @ N/A FT/HR SURFACETOROUE @ @ N/A FT/LBS WEIGHT ON BIT @ @ N/A KLBS TOPDRIVE RPM @ @ NIA RPM PUMP PRESSURE @ @ N/A PSI FLOW IN @ @ N/A GPM GAS SUMMARY (units) HIGH LOW AVERAGE GASES TRIP WIPER No Circulation @ @ DITCH Zone Gas Survey CHROMATOGRAPHY (ppm) Downlink Down Time CONNECTION HIGH = METHANE (C-1) @ @ ETHANE (C-2) @ @ AVG = PROPANE (C-3) @ @ Current= CURRENT Background = BUTANE (C-4) @ @ PENTANE (C-5) @ @ DITCH Average = HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS OIL DESCRIPTION LITHOLOGY Current Formation: General Lithology: Current Lithology°/ : LAG SUMMARY Annular Volume 681 bbl / % Theoretical 100% / 60 min @ 196 SPM / 11808 strokes @ 14428' DAILY ACTIVITY SUMMARY POOH from 10607' to 5091' & out 125' of drill line. LD 62 4.5" joints. Cont. LD 4.5" & 4" drill pipe, HWDP, jars, upper mill, & flex joint. Lower mill (left bit, bit sub, double pin in hole ran TD, NOV checked out.). PJSM w/ Pollard. RU Pollard W/L equip. RIH wl 5.7 junk basket to 14420'. POOH from 14420. RD junk basket, MU tools to RIH w/ CIBP, set 14418' top 14420' bottom. POOH from 14418 to surface. Mixed cement in buckets. PJSM, RIH w/ W/L. 1 at cement run POOH @ 1855', mixed cement on rig floor for next run POOH. 3 runs total with 17.4 gallons of cement per run. Dump cement at 14360', for all 3 runs & RD W/L. NABORS PERSONNEL H. WlnKalman, A. f ume, a. onarmee, o. vvrigur REPORT BY Sarah Cherries DAILY COST $3,045 fill NABORS DML Digital Mudlogging Hllcorp Alaska, LLC Beaver Creek Unit BCU 05RD2 Hilcoro 169 DAILY WELLSITE REPORT DATE: 8/31/18 TIME: 24:00 PRESENT OPERATION: Test BOPS PRESENT DEPTH: 14,428' DEPTH YESTERDAY: 14,426' SAMPLE DEPTH: 14,426' 24 HOUR FOOTAGE: 0� REPORT FOR: Robert Wall & Oliver Amend CASING DATA 20" cond @ 432' 13 3/8" @ 3511' 9 5/8" @ 11,698' 7" @ 14,915' BIT DATA I BHA TYPE: I CONDITION No. Size Type SIN Jets IN OUT Footage Hours 1 -0 -Char -Loc -B -G -Char -Pull SURVEY DATA DEPTH INCLINATION AZIMUTH TVD VSECTION +N/S- COORDINATES +E/W- DLS LITHOLOGY Current Formation: General Lithology: Current Uthology% : LAG SUMMARY Annular Volume 681 bbl / % Theoretical 100% / 60 min @ 196 SPM / 11808 strokes @ 14428' DAILY ACTIVITY SUMMARY Test casing 2500psi, chart 30min per CO Man & well plan. Pollard C/O to CIBP 11 BBL pmpd; 9.5BBL bled back. RU test equip & Pollard RIH w/ CIBP: Tight spot @13901', POOH top piece of CIBP came loose/not straight, tightened up, RIH W/ CIBP 5200'-13090' CIBP hung up, pulled up 3850 Itis, POOH to surf, C/O CIPS F/5.69 OD to 5.61 OD. RIH w/ 5.61 OD CIBP, tagged 13090'. POOH F/13090 to surf. RD Pollard, remove wear bushing. Install test plug, test JNT. Pressure down accumulator, open upr doors/remove 4.5 solid boys & Install VBRS. Fill BOP & choke manifold w/ water, perform shell test 4500psi, test BOP NePn PQ GFRR[1NNFI R. Winkelman. A. Tutee, S. Chemise, S. Wright REPORT BY Sarah Chemise DAILY COST $3,045 —._ — Zone Gas Survey CHROMATOGRAPHY (ppm) MWD/LWD SUMMARY INTERVAL: to TOOLS: METHANE (C-1) @ @ MUD REPORT DEPTH MUD TYPE MUD BASE Flowline Temp OF MW VIS PV YP Gels FL Cake Unc Sol Current = Sol pH Oil Pt/Mt Cl- MBT Ca+ Cor Sol @ DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION @ @ N/A FT/HR SURFACE TORQUE @ @ N/A FT/LBS WEIGHT ON BIT @ @ N/A KLBS TOPDRIVE RPM @ @ N/A RPM PUMP PRESSURE @ @ N/A PSI FLOW IN @ @ N/A GPM GAS SUMMARY (units) HIGH LOW AVERAGE I GASES TRIP WIPER No Circulation @ @ DITCH LITHOLOGY Current Formation: General Lithology: Current Uthology% : LAG SUMMARY Annular Volume 681 bbl / % Theoretical 100% / 60 min @ 196 SPM / 11808 strokes @ 14428' DAILY ACTIVITY SUMMARY Test casing 2500psi, chart 30min per CO Man & well plan. Pollard C/O to CIBP 11 BBL pmpd; 9.5BBL bled back. RU test equip & Pollard RIH w/ CIBP: Tight spot @13901', POOH top piece of CIBP came loose/not straight, tightened up, RIH W/ CIBP 5200'-13090' CIBP hung up, pulled up 3850 Itis, POOH to surf, C/O CIPS F/5.69 OD to 5.61 OD. RIH w/ 5.61 OD CIBP, tagged 13090'. POOH F/13090 to surf. RD Pollard, remove wear bushing. Install test plug, test JNT. Pressure down accumulator, open upr doors/remove 4.5 solid boys & Install VBRS. Fill BOP & choke manifold w/ water, perform shell test 4500psi, test BOP NePn PQ GFRR[1NNFI R. Winkelman. A. Tutee, S. Chemise, S. Wright REPORT BY Sarah Chemise DAILY COST $3,045 Zone Gas Survey CHROMATOGRAPHY (ppm) Downlink Down Time CONNECTION HIGH = METHANE (C-1) @ @ ETHANE (C-2) @ @ AVG = PROPANE (C-3) @ @ Current = CURRENT Background = BUTANE (C-4) @ @ PENTANE(C-5) @ @ DITCH Average= HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS OIL DESCRIPTION LITHOLOGY Current Formation: General Lithology: Current Uthology% : LAG SUMMARY Annular Volume 681 bbl / % Theoretical 100% / 60 min @ 196 SPM / 11808 strokes @ 14428' DAILY ACTIVITY SUMMARY Test casing 2500psi, chart 30min per CO Man & well plan. Pollard C/O to CIBP 11 BBL pmpd; 9.5BBL bled back. RU test equip & Pollard RIH w/ CIBP: Tight spot @13901', POOH top piece of CIBP came loose/not straight, tightened up, RIH W/ CIBP 5200'-13090' CIBP hung up, pulled up 3850 Itis, POOH to surf, C/O CIPS F/5.69 OD to 5.61 OD. RIH w/ 5.61 OD CIBP, tagged 13090'. POOH F/13090 to surf. RD Pollard, remove wear bushing. Install test plug, test JNT. Pressure down accumulator, open upr doors/remove 4.5 solid boys & Install VBRS. Fill BOP & choke manifold w/ water, perform shell test 4500psi, test BOP NePn PQ GFRR[1NNFI R. Winkelman. A. Tutee, S. Chemise, S. Wright REPORT BY Sarah Chemise DAILY COST $3,045 0D► NABORS DML Digital Mudlogging Hilcorp Alaska, LLC Beaver Creek Unit BCU 05RD2 Hilcorp 169 DAILY WELLSITE REPORT DATE: 9/1/18 TIME: 24:00 PRESENT OPERATION: Test BOPS PRESENT DEPTH: 14,428' DEPTH YESTERDAY: 14,428' SAMPLE DEPTH: 14,428' 24 HOUR FOOTAGE: 0' REPORT FOR: Robert Wall & Oliver Amend CASING DATA 20" cond @ 432' 13 3/8" @ 3511' 9 5/8" @ 11,698' 7" @ 14,915' BIT DATA BHA TYPE: I CONDITION No. Size Type S/N Jets IN OUT Footage Hours 1 -0 -Char -Loc -B -G -Char -Pull SURVEY DATA DEPTH INCLINATION AZIMUTH TVD VSECTION +N/S- COORDINATES +E/W- DLS MWD/LWD SUMMARY INTERVAL: to TOOLS: MUD REPORT DEPTH MUD TYPE MUD BASE Flowline Temp OF MW VIS PV YP Gels FL Cake Unc Sol Sd pH Oil Pf/Mf Cl- MST Ca+ Cor Sol DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION @ @ N/A FT/HR SURFACE TORQUE @ @ N/A FT/LBS WEIGHT ON BIT @ @ N/A KLBS TOPDRIVE RPM @ @ N/A RPM PUMP PRESSURE @ @ N/A PSI FLOW IN @ @ N/A GPM GAS SUMMARY (units) HIGH LOW AVERAGE GASES TRIP WIPER No Clrculatlon @ @ DITCH Zone Gas Survey CHROMATOGRAPHY (ppm) Downlink Down Time CONNECTION HIGH = METHANE (C-1) @ @ ETHANE (C-2) @ @ AVG = PROPANE (C-3) @ @ Current = CURRENT Background = BUTANE (C-4) @ @ PENTANE (C-5) @ @ DMCH Average = HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS OIL DESCRIPTION LITHOLOGY Current Formation: General Lithology: Current Lithology°/ : LAG SUMMARY Annular Volume 681 bbl / /Theoretical 100% / 60 min @ 196 SPM / 11808 strokes @ 14428' DAILY ACTIVITY SUMMARY Test blowout preventer, upper pipe rams leaking, repairs. Work on pumps. Perform shell test to 4500psl, oil leaking from tattle tail, remove plug from blind rams and inspect emergency packing. Perform shell test to 4500psi, leaking: CM #7, needle valve on test manifold gauge, and 2 gland nuts, repairs. Perform shell test to 4500psi, choke manifold #13 leaking, repair. Perform shell test to 4500psi, leaking choke HCR In packing area, repairs. Test chart recorder, good. Test manifold, not good, repair. Continue to test NABORS PERSONNEL H. WlnKelman, A. Iutrle, S. Gnamlee, S. vvngnt REPORT BY Sarah Chamlee DAILY COST $3,045 0#111 NABORS DML Digital Mudlogging Hllcorp Alaska, LLC weaver Creek Unit BCU 05RD2 Hilcorp 169 DAILY WELLSITE REPORT DATE: 9/2/18 TIME: 24:00 PRESENT OPERATION: MU BHA PRESENT DEPTH: 14,428' DEPTH YESTERDAY: 14,428' SAMPLE DEPTH: 14,428' 24 HOUR FOOTAGE: 0' REPORT FOR: Robert Wall & Oliver Amend CASING DATA 20" Gond @ 432' 13 3/8" @ 3511' 95/8" @ 11,698' 7" @ 14,915' BIT DATA BHA TYPE: I CONDITION No, Size Type S/N Jets IN OUT Footage Hours 1 -0 -Char -Loc -B -G -Char -Pull SURVEY DATA DEPTH INCLINATION AZIMUTH TVD VSECTION +N/S- COORDINATES +E/W- DLS MWD/LWD SUMMARY INTERVAL: to TOOLS: MUD REPORT DEPTH MUD TYPE MUD BASE Flowline Temp of MW VIS PV YP Gels FL Cake Unc Sol Sd pH Oil Pf/Mt Cl- MBT Ca+ Cor Sol DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION @ @ N/A FT/HR SURFACE TORQUE @ @ N/A FT/LBS WEIGHT ON BIT @ @ N/A KLBS TOPDRIVE RPM @ @ N/A RPM PUMP PRESSURE @ @ N/A PSI FLOW IN @ @ N/A GPM GAS SUMMARY (units) HIGH LOW AVERAGE GASES TRIP WIPER No Circulation @ @ DITCH Zone Gas Survey CHROMATOGRAPHY (ppm) Downlink Down Time CONNECTION HIGH = METHANE (C-1) @ @ ETHANE (C-2) @ @ AVG = PROPANE (C-3) @ @ Current = CURRENT Background = BUTANE (C-4) @ @ PENTANE (C-5) @ @ DITCH Average = HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS OIL DESCRIPTION LITHOLOGY Current Formation: General Lithology: Current Lithology°/ : LAG SUMMARY Annular Volume 681 bbl / % Theoretical 100% / 60 min @ 196 SPM / 11808 strokes @ 14428' DAILY ACTIVITY SUMMARY Continue to test BOP and record per state regulations, lower ]BOP valve on top drive failed, install new lower IBOP valve, perform shell test to 4500psi; continue to test BOP, test MPD equipment, flow line flange leaking, bled off pressure and tighten up flange, re -test Schlumberger lines, rig down test equipment, test GeoSpan equipment, pull test plug, install wear ring, pick up BHA per Baker rep, build BHA on bottom of first joint of HW DP, install lift ring on annular, install trip nipple, install mouse hole, change out elevators from 4" for lift sub to 4.5" for jars, change back, finish BHA. NABORS PERSONNEL R. Winkelman, A. Tuttle, S. Chamlee, S. Wright REPORT BY Sarah Chamlee DAILY COST $3,045 f lP NABORS DML Digital Mudlogging Hilcorp Alaska, LLC Seaver Creek Unit BCU 05RD2 Hilcorp 169 DAILY WELLSITE REPORT DATE: 9/3/18 TIME: 24:00 PRESENT OPERATION: Milling/R11-1 PRESENT DEPTH: 14,428' DEPTH YESTERDAY: 14,428' SAMPLE DEPTH: 14,428' 24 HOUR FOOTAGE: 0' REPORT FOR: Rance Pederson & John Nicolson CASING DATA 20" Gond @ 432' 133/8" @ 3511' 95/8" @ 11,698' 7" @ 14,915' BIT DATA BHA TYPE: CONDITION No. Size Type S/N Jets IN OUT Footage Hours 1 -0 -Char -Lac -B -G -Char -Pull SURVEY DATA DEPTH INCLINATION AZIMUTH TVD V SECTION +N/S- COORDINATES +E/W- DLS MWD/LWD SUMMARY INTERVAL: to TOOLS: MUD REPORT DEPTH MUD TYPE MUD BASE Flowline Temp OF MW VIS PV YP Gels FL Cake Unc Sol Sol pH Oil Pf/Mt Cl- MBT Ca+ Cor Sol DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ N/A FT/HR SURFACE TORQUE @ @ N/A FT/LBS WEIGHT ON BIT @ @ N/A KLBS TOPDRIVE RPM @ @ N/A RPM PUMP PRESSURE @ @ N/A PSI FLOW IN @ @ N/A GPM GAS SUMMARY (units) HIGH LOW AVERAGE GASES TRIP WIPER CIRCULATING GAS 1110 @ 4.0 @ 9.0 DITCH Zone Gas Survey CHROMATOGRAPHY (ppm) Downlink Down Time CONNECTION HIGH = METHANE (C-1) @ @ ETHANE (C-2) @ @ AVG = PROPANE (C-3) @ @ Current= CURRENT Background = BUTANE (C-4) @ @ PENTANE (C-5) @ @ DITCH Average = HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS OIL DESCRIPTION LITHOLOGY Current Formation: General Lithology: Current Lithology°/ : LAG SUMMARY Annular Volume 681 blot / %Theoretical 100% / 60 min @ 196 SPM / 11808 strokes @ 14428' DAILY ACTIVITY SUMMARY Pick up and run in to 2228', pick up 1 joint 4.5" drill pipe, unstring drill line and re -spool ensuring wraps are tight, install protective wrap on service loop, inspect kelly hose, continue to run in hole to 7692', attempt to change kelly hose but did not have proper adaptors, re -install old Kelly hose and install omni wrap on bad spots, continue to run in to 12953', install Kelly hose, run up and down derrick to ensure it is correct, fill lines and test Kelly hose to 1200psi, continue to run in to 13050', mill out per Baker hand. NABORS PERSONNEL H. Winkelman, A. Iume, 5. cnamlee, a. "rign[ REPORT BY Sarah Chemise DAILY COST $4,245 CASING DATA 20"cond @432' 95/8" @ 11,531' 7.000" @ 14,918' BIT DATA BHA TYPE: Whipstock/Mills CONDITION No. Size Type S/N Jets IN OUT Footage Hours I -O -Char -Loc -B -G -Char -Pull SURVEY DATA DEPTH INCLINATION AZIMUTH TVD VSECTION +N/S- COORDINATES +E/W- DLS MWD/LWD SUMMARY INTERVAL: DAILY WELLSITE REPORT 111) NABORS TOOLS: DML Digital Mudlogging MUD REPORT DEPTH MUD TYPE DATE: 9/4/18 TIME: 24:00 Hilcorp Alaska, LLC PRESENT OPERATION: PU whipstock BHA Beaver Creek Unit PRESENT DEPTH: 14,428' DEPTH YESTERDAY: 14,428' BCU 05RD2 SAMPLE DEPTH: 14,428' 24 HOUR FOOTAGE: 0' Hilcorp 169 REPORT FOR: Rance Pederson & John Nicolson CASING DATA 20"cond @432' 95/8" @ 11,531' 7.000" @ 14,918' BIT DATA BHA TYPE: Whipstock/Mills CONDITION No. Size Type S/N Jets IN OUT Footage Hours I -O -Char -Loc -B -G -Char -Pull SURVEY DATA DEPTH INCLINATION AZIMUTH TVD VSECTION +N/S- COORDINATES +E/W- DLS MWD/LWD SUMMARY INTERVAL: to TOOLS: MUD REPORT DEPTH MUD TYPE MUD BASE Flowline Temp of MW VIS PV YP Gels FL Cake Unc Sol Sd pH Oil Pf/Mf Cl- MBT Ca+ Cor Sol DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION @ @ N/A FT/HR SURFACE TORQUE @ @ N/A FT/LBS WEIGHT ON BIT @ @ N/A KLBS TOPDRIVE RPM @ @ N/A RPM PUMP PRESSURE @ @ N/A PSI FLOW IN @ @ N/A GPM GAS SUMMARY (units) HIGH LOW AVERAGE GASES TRIP WIPER CIRCULATING GAS 138.0 @ 4.0 @ 7.0 DITCH Zone Gas Survey CHROMATOGRAPHY (ppm) Downlink Down Time CONNECTION HIGH = METHANE (C-1) @ @ ETHANE (C-2) @ @ AVG = PROPANE (C-3) @ @ Current = CURRENT Background = BUTANE (C-4) @ @ PENTANE (C-5) @ @ DITCH Average = HYDROCARBON SHOWS INTERVAL T LITHOLOGY/REMARKS GAS OIL DESCRIPTION I LITHOLOGY General Lithology: Current Lithology°/ : LAG SUMMARY Annular Volume 681 bbl / % Theoretical 100% / 60 min @ 196 SPM / 11808 strokes @ 14428' DAILY ACTIVITY SUMMARY Mill from 13060' to 13085', pump sweep, pull out from 14319' to 2785', lay down 4.5" drill pipe from 2785' to 2230' (18 joints), lay down 4" drill pipe from 2230' to surface (64 joints of 4", 5 joints of heavy weight, 1 drilling jars), rig service, rig up Pollard, first run 5.71" gauge run, run through 13090' with no issues, run to 14356' with no Issues, pull out with no tight spots, make up Baker cast iron bridge plug, run in and set at 14239', pull out and lay down Pollard, begin picking up whipstock BHA per Baker hand. NARnR9 PFRSONNEL R. Winkelman. A. Tuttle. S. Chamlee, S. Wrioht REPORT BY Sarah Chemise DAILY COST $3,045 fill NABORS DML Digital Mudlogging Hllcorp Alaska, LLC Beaver Creek Unit BCU 05RD2 Hilcorp 169 DAILY WELLSITE REPORT DATE: 9/5/18 TIME: 24:00 PRESENT OPERATION: RIH W/Whipstock PRESENT DEPTH: 14,238' DEPTH YESTERDAY: 14,238' SAMPLE DEPTH: 14,238' 24 HOUR FOOTAGE: 0' REPORT FOR: Rance Pederson & John Nicolson CASING DATA 20"cond @432' 95/8" @ 11,531' 7.000" @ 14,918' BIT DATA BHA TYPE: Whipstock/Mills ICONDITION No. Size Type S/N Jets IN OUT Footage Hours I -O -Char -Loc -B -G -Char -Pull SURVEY DATA DEPTH INCLINATION AZIMUTH TVD V SECTION +N/S- COORDINATES ,E W DLS MWD/LWD SUMMARY INTERVAL: 14,238' to TOOLS: MUD REPORT DEPTH MUD TYPE MUD BASE Flowline Temp of MW VIS PV YP Gels FL Cake Unc Sol Sd pH Oil Pt/Mf CI- MBT Ca+ Cor Sol DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ N/A FT/HR SURFACE TORQUE @ @ N/A FT/LBS WEIGHT ON BIT @ @ N/A KLBS TOPDRIVE RPM @ @ N/A RPM PUMP PRESSURE @ @ N/A PSI FLOW IN @ @ N/A GPM GAS SUMMARY (units) HIGH LOW AVERAGE CIRCULATING GAS 11.0 @ 2.0 @ 7.0 CHROMATOGRAPHY (ppm) METHANE (C-1) @ @ ETHANE (C-2) @ @ PROPANE (C-3) @ @ BUTANE (C-4) @ @ PENTANE (C-5) @ @ GASES TRIP WIPER DITCH Zone Gas Survey Downlink Down Time CONNECTION HIGH = AVG = Current = CURRENT Background = DITCH Average = HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS OIL DESCRIPTION LITHOLOGY Current Formation: General Lithology: Current Lithology°/ : LAG SUMMARY Annular Volume 653 bbl I % Theoretical 100% / 58 min @ 196 SPM / 11322 strokes @ 14238' DAILY ACTIVITY SUMMARY Continue picking up whipstock BHA per Baker hand, pick up 4" drill pipe from shed to 766', make up TIW, shallow test MWD, continue picking up 4" drill pipe to 1591', change out elevators to 4.5", pick up 4.5" to 2310', run 4.5" from derrick to 11419' filling pipe every 2000; service top drive, blocks, drawworks; run 4.5" pipe to 12662', fill pipe, change out saver sub, continue to run in. NABORS PERSONNEL H. Winkelman, A. Iuttle, S. Ohamlee, 5. Wright REPORT BY Sarah Chemise DAILY COST $3,045 fill NABORS DML Digital Mudlogging Hilcorp Alaska, LLC Heaver Creek Unit BCU 05RD2 Hilcorp 169 DAILY WELLSITE REPORT DATE: 9/6/18 TIME: 24:00 PRESENT OPERATION: Milling PRESENT DEPTH: 14,282' DEPTH YESTERDAY: 14,238' SAMPLE DEPTH: 14,282' 24 HOUR FOOTAGE: 44' REPORT FOR: Rance Pederson & John Nicolson CASING DATA 20" Gond @ 432' 9518" @ 11,531' 7.000 " @ 14,918' BIT DATA BHA TYPE: Milling Assembly CONDITION No. Size Type S/N Jets IN OUT Footage Hours 1 -0 -Char -Loc -B -G -Char -Pull 1 5.875" Mills 14238' SURVEY DATA DEPTH INCLINATION AZIMUTH TVD V SECTION +N/S- COORDINATES +E/W-DDLS F MWD/LWD SUMMARY INTERVAL: 14,238' to TOOLS: MUD REPORT DEPTH 14235' MUD TYPE OBM MUD BASE Oil Flowline Temp OF MW 9.5 VIS 65 PV 18 YP 13 Gels 9/17/22 FL Cake 2 Unc Sol Sd 0.01 Alk Pm Oil Oil/1-12O36.2/13.£ Cl- 9.18 E -Stab 890 Lime 7.51 Cor Sol 11.8 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 17.8 @ 14,270' 0.3 @ 14,239' 7.3 7,8 FT/HR SURFACE TORQUE 5314 @ 14,281' 2697 @ 14,239' 4268 4315 FT/LBS WEIGHT ON BIT 11.9 @ 14,274' 0.6 @ 14,249' 7.5 8.0 KLBS TOPDRIVE RPM 105 @ 14,243' 81 @ 14,239' 103 104 RPM PUMP PRESSURE 1630 @ 14,276' 1463 @ 14,241' 1548 1551 PSI FLOW IN 246 @ 14,272' 242 @ 14,267' 243 243 GPM GAS SUMMARY (units) HIGH LOW AVERAGE GASES TRIP WIPER DITCH GAS 26.8 @ 14,242' 2.5 @ 14,239' 13.3 DITCH Zane Gas Survey CHROMATOGRAPHY (ppm) Downlink Down Time 34 CONNECTION HIGH = METHANE (C-1) 5038 @ 14,242' 339 @ 14,280' 906 ETHANE (C-2) 7 @ 14,242' 2 @ 14,257' 4 AVG = PROPANE (C-3) 4 @ 14,246' 1 @ 14,279' 3 Current = CURRENT Background = 12 BUTANE (C-4) 5 @ 14,250' 1 @ 14,241' 3 PENTANE (C-5) 3 @ 14,253' 0 @ 14,272' 1 (DrrcH) Average= 12 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS I OIL DESCRIPTION LITHOLOGY Current Formation: Tyonek General Lithology: sandy siltstone, siltstone, sandstone, tuffaceous claystone Current Lithology°/ : 20% sandstone, 20% siltstone, 30% tuffaceous claystone, 30% tuffaceous siltstone LAG SUMMARY Annular Volume 670 bbl / % Theoretical 100% / 115 min @ 101 SPM / 11617 strokes @ 14281 DAILY ACTIVITY SUMMARY Continue to run in to 14173', kelly up and orient whipstock, wash down to top of plug, tag top of plug at 14255', shear at 15k down weight, anchor set, verify 10k overpull, sheared down at 30k, pre -fob safety meeting for displacing to 9.5 ppg OBM, start 201bbl spacer, displace water base mud with OSM, line up and flood MPD lines with OBM, circulate and condition mud in preparation to mill, mill from 14238' to 14251', drill rat hole from 14251' to 14271', pump 20bbl sweep, rig up for FIT, chart 10 minutes 2150 psi 12.5ppg equivalent, rig down test equipment, continue to drill rat hole from 14271' to 14282'. NABORS PERSONNEL R. Winkelman, A. Tuttle, S. Chamlee, S. Wright REPORT BY Sarah Chamlee DAILY COST $3,045 4111 NABORS DML Digital Mudlogging Hilcorp Alaska, LLC Seaver Creek Unit BCU 05RD2 Hilcorp 169 DAILY WELLSITE REPORT DATE: 9/7/18 TIME: 24:00 PRESENT OPERATION: POOH PRESENT DEPTH: 14,299' DEPTH YESTERDAY: 14,281' SAMPLE DEPTH: 14,299' 24 HOUR FOOTAGE: 18' REPORT FOR: Rance Pederson & John Nicolson CASING DATA 20"cond @ 432' 9518" @ 11,531' 7.000" @ 14,918' BIT DATA BHA TYPE: Milling Assembly CONDITION No. Size Type S/N Jets IN OUT Footage Hours 1 -0 -Char -Lac -B -G -Char -Pull 5.875" Mills 14,238' 14,299' 61' 12.4 SURVEY DATA DEPTH INCLINATION AZIMUTH TVD VSECTION +N/S- COORDINATES +E/W- DLS MWD/LWD SUMMARY INTERVAL: 14,238' to 14299' TOOLS: Milling Assembly MUD REPORT DEPTH 14,299' MUD TYPE Enviromul (OBM) MUD BASE Oil Flowline Temp OF MW 9.55 VIS 71 PV 19 YP 10 Gels 7/13/16 FL 4.6 Cake 2 CaC12 9.18 Sd 0.01 Alk Pm Oil Oil/H20 86/13 NaCl 4.78 E -Stab 875 Lime 7.12 Cor Sol 13.13 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 18.0 @ 14,298' 1.8 @ 14,288' 9.9 N/A FT/HR SURFACE TORQUE 4778 @ 14,298' 3346 @ 14,295' 4250 N/A FT/LBS WEIGHT ON BIT 12.7 @ 14,288' 11.4 @ 14,286' 11.8 N/A KLBS TOPDRIVE RPM 102 @ 14,298' 102 @ 14,284' 102 N/A RPM PUMP PRESSURE 1628 @ 14,288' 1516 @ 14,296' 1567 N/A PSI FLOW IN 246 @ 14,291' 245 @ 14,299' 246 N/A GPM GAS SUMMARY (units) HIGH LOW AVERAGE GASES TRIP WIPER DITCH GAS 16.6 @ 14,299' 11.5 @ 14,285' 14.3 DITCH Zone Gas Survey CHROMATOGRAPHY (ppm) Downlink Down Time CONNECTION HIGH = 0 METHANE (C-1) 831 @ 14,295' 158 @ 14,292' 500 ETHANE (C-2) 8 @ 14,298' 2 @ 14,292' 5 AVG = 0 PROPANE (C-3) 6 @ 14,295' 1 @ 14,292' 3 Current= CURRENT Background = BUTANE (C-4) 6 @ 14,295' 1 @ 14,283' 4 PENTANE (C-5) 6 @ 14,295' 0 @ 14,283' 2 (DITCH) Average= HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS OIL DESCRIPTION LITHOLOGY Current Formation: Tyonek General Lithology: sandy siltstone, siltstone, tuffaceous claystone Current Lithology % : 20% sandstone, 20% siltstone, 40% tuffaceous claystone, 20% tuffaceous siltstone LAG SUMMARY Annular Volume 671 bbl / %Theoretical 100% / 115 min @ 101 SPM / 11634 strokes @ 14299 DAILY ACTIVITY SUMMARY Drill from 14282' to 14299', circulate bottoms up, monitor well for 15 minutes, pump dryjob, pullout to 11700', encounter tight hole from 131200' to 13050', monitor well, pump dry job, continue pulling out to 5867', observe Improper hole till, flow check for 30 minutes, slight flow that died off, pull 8 stands, observe improper hole fill, flow check well, slight flow that died off, pull 5 stands with good displacement, pull to 3092', circulate out dry job, continue to pull out to 3369', pull out sideways to 2100'. NABORS PERSONNEL R. Winkelman, A. Tuttle, S. Chamlee, S. Wright REPORT BY Sarah Chamlee DAILY COST $3,045 40I NABORS DML Digital Mudlogging Hilcorp Alaska, LLC Beaver Creek Unit BCU 05RD2 Hilcorp 169 DAILY WELLSITE REPORT DATE: 9/8/18 TIME: 24:00 PRESENT OPERATION: RIH PRESENT DEPTH: 14,299' DEPTH YESTERDAY: 14,299' SAMPLE DEPTH: 14,299' 24 HOUR FOOTAGE: O' REPORT FOR: Rance Pederson & John Nicolson CASING DATA 20" Gond @ 432' 9 5/8" @ 11,531' 7.000" @ 14,918' window @ 14,251' BIT DATA BHA TYPE: Milling Assembly CONDITION No. Size Type S/N Jets IN OUT Footage Hours 1 -0 -Char -Loc -B -G -Char -Pull 5.875"Mills 14,238' 14,299' 61' 12.4 1 5.875 " Baker Hughes KMX323T 5272934 3x14 14,299' SURVEY DATA DEPTH INCLINATION AZIMUTH TVD V SECTION +N/S- COORDINATES +E/W- DLS MWD/LWD SUMMARY INTERVAL: 14,299' to TOOLS: Geo -Pilot MUD REPORT DEPTH 14,299' MUD TYPE Enviromul (OBM) MUD BASE Oil Flowline Temp OF MW 9.65 VIS 67 PV 17 YP 10 Gels 7/13/15 FL 4.6 Cake 2 CaC12 10.15 Ed 0.01 Alk Pm Oil Oil/H2O 87/12 NaCl 4.79 E -Stab 1031 Lime 11.27 Cor Sol 13.9 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION @ @ N/A FT/HR SURFACE TORQUE @ @ N/A Fr/LBS WEIGHT ON BIT @ @ N/A KLBS TOPDRIVE RPM @ @ N/A RPM PUMP PRESSURE @ @ N/A PSI FLOW IN @ @ N/A GPM GAS SUMMARY (units) HIGH LOW AVERAGE GASES TRIP WIPER CIRCULATING GAS 9.0 @ 5.0 @ 5.0 DITCH Zone Gas Survey CHROMATOGRAPHY (ppm) Downlink Down Time CONNECTION HIGH = METHANE (C-1) @ @ ETHANE (C-2) @ @ AVG = PROPANE (C-3) @ @ Current = BUTANE (C-4) @ @ CURRENT Background = 6 PENTANE (C-5) @ @ DITCH Average = HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS OIL DESCRIPTION LITHOLOGY Current Formation: Tyonek General Lithology: sandy siltstone, siltstone, tuffaceous claystone Current Uthology % : 20% sandstone, 20% siltstone, 40% tuffaceous claystone, 20% tuffaceous siltstone LAG SUMMARY Annular Volume 671 bbl / %Theoretical 100% / 115 min @ 101 SPM / 11634 strokes @ 14299' DAILY ACTIVITY SUMMARY Prepare to LD 4" drill pipe, continue to pull out, LD 4" drill pipe from 2100' to top of BHA, LD BHA per Baker hand, clear rig floor of all tools, service rig, repair leak on bell nipple clamp, load BHA onto pipe racks, pick up short tools to rig floor, troubleshoot top drive hydraulic issues, pick up BHA per Baker from surface to 358', plug Into tools and perform surface test, pick up first joint of 4" and shallow test tools, run in from 387' - 2081', PU 4" drill pipe, fill plpa, continue to pick up pipe from 2081'- 2381', CO to 4.5" elevators, pick up 4.5" from skate 2381'- 3713', RIH from derrick 3713' - 4126' filling pipe every 1500'. NABORS PERSONNEL R. Winkelman, A. Tuttle, S. Chemise, S. Wright REPORT BY Sarah Chemise DAILY COST $3,045 0pl NABORS DML Digital Mudlogging Hilcorp Alaska, LLC Beaver Creek Unit BCU O5RD2 Hilcorp 169 DAILY WELLSITE REPORT DATE: 9/9/18 TIME: 24:00 PRESENT OPERATION: Drilling PRESENT DEPTH: 14,337' DEPTH YESTERDAY: 14,299' SAMPLE DEPTH: 14,337' 24 HOUR FOOTAGE: 38' REPORT FOR: Rance Pederson & John Nicolson CASING DATA 20" cond @ 432' 95/8" @ 11,531' 7.000" @ 14,918' window @ 14,251' BIT DATA BHA TYPE: Rotary Steerable CONDITION No. Size Type S/N Jets IN OUT Footage Hours 1 -0 -Char -Loc -B -G -Char -Pull 5.875" Mills 14,238' 14,299' 61' 12.4 1 5.876" Baker Hughes KMX323T 5272934 3x14 14,299' SURVEY DATA DEPTH INCLINATION AZIMUTH TVD VSECTION +N/S- COORDINATES +E/W- DLS MWD/LWD SUMMARY INTERVAL: 14,299' to TOOLS: Geo -Pilot MUD REPORT DEPTH 14,329' MUD TYPE Enviromul (OBM) MUD BASE Oil Flowline Temp 82 of MW 9.5 VIS 67 Pv 18 YP 11 Gels 8/14/16 FL 4.6 Cake 2 CaC12 8,88 Sd 0.01 Alk Pm Oil OiVH2O 87/13 NaCl 3.85 E -Stab 885 Lime 8.55 Cor Sol 13.9 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 65.2 @ 14,320' 4.2 @ 14,333' 15.6 N/A FT/HR SURFACE TORQUE 4315 @ 14,301' 3665 @ 14,333' 3957 N/A FT/LBS WEIGHT ON BIT 10.7 @ 14,322' 6.6 @ 14,305' 9.4 N/A KLBS TOPDRIVE RPM 73 @ 14,317' 63 @ 14,303' 70 N/A RPM PUMP PRESSURE 2265 @ 14,324' 1708 @ 14,323' 2142 N/A PSI FLOW IN 251 @ 14,324' 237 @ 14,329' 245 N/A GPM GAS SUMMARY (units) HIGH LOW AVERAGE GASES TRIP WIPER DITCH GAS 15.0 @ 14,304' 9.3 @ 14,337' 12.7 DITCH 35 Zone Gas Survey CHROMATOGRAPHY (ppm) Downlink Down Time CONNECTION HIGH = 0 METHANE (C-1) 628 @ 14,305' 309 @ 14,331' 436 ETHANE (C-2) 5 @ 14,300' 2 @ 14,337' 3 AVG = 0 PROPANE C-3) 4 @ 14,305' 1 @ 14,337' 2 Current= 0 CURRENT Background= 13 BUTANE (C-4) 3 @ 14,302' 0 @ 14,337' 1 PENTANE (C-5) 1 @ 14,300' 1 @ 14,308' 1 (DITCH) Average= 13 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS I OIL DESCRIPTION LITHOLOGY Current Formation: Tyonek General Lithology: sandstone, siltstone, tuffaceous claystone Current Uthology % : 20% tuffaceous sandstone, 40% sandstone, 30% siltstone, 10% tuffaceous claystone LAG SUMMARY Annular Volume 672 bbl / % Theoretical 100% / 115 min @ 101 SPM / 11652 strokes @ 14340' DAILY ACTIVITY SUMMARY Continue to run in, install 7" well commander at 4369', continue to run in with 4.5" to 11625', fill pipe, test tools per DD, slip and cut drill line, cut 99718 wraps, calibrate blocks, calibrate hockload, install omni cover on Kelly hose and cover on service loops, continue to trip in to 14244', drill out under -gauge hole from 14244' to 14299', drill from 14299' to 14337'. NABORS PERSONNEL R. Winkelman, A. Tuttle, S. Chamlee, S. Wright REPORT BY Sarah Chemise DAILY COST $3,045 #10 NABORS DML Digital Mudlogging Hllcorp Alaska, LLC Beaver Creek Unit BCU 05RD2 Hilcorp 169 DAILY WELLSITE REPORT DATE: 9/10/18 TIME: 24:00 PRESENT OPERATION: Install MPD Bearing PRESENT DEPTH: 14,743' DEPTH YESTERDAY: 14,337' SAMPLE DEPTH: 14,743' 24 HOUR FOOTAGE: 406' REPORT FOR: Rance Pederson & John Nicolson CASING DATA 20"coed @432' 95/8" @ 11,531' 7.000" @ 14,918' Window @ 14,251' BIT DATA BHA TYPE: Rotary Steerable CONDITION No. Size Type S/N Jets IN OUT Footage Hours 1 -0 -Char -Loc -B -G -Char -Pull 5.875" Mills 1 1 14,238' 14,299' 61' 12.4 1 5.875" Baker Hughes KMX323T 1 5272934 3214 1 14,299' SURVEY DATA DEPTH INCLINATION AZIMUTH TVD VSECTION +N/S- COORDINATES +E/W- DLS 14582.18 18.42 96.72 14091.78' 2164.77' 1744.79' 1274.40' 2.17 14644.28 18.78 97.51 14150.64' 2176.51' 1772.34' 1294.06' 0.70 MWD/LWD SUMMARY INTERVAL: 14,299' to TOOLS: Geo -Pilot MUD REPORT DEPTH 14,743' MUD TYPE Enviromul (OBM) MUD BASE Oil Flowline Temp 0 of MW 9.53 VIS 58 PV 17 YP 9 Gels 8/14/16 FL 4.6 Cake 2 CaC12 7.24 Sd 0.01 Alk Pm Oil Oil/1-120 88/12 NaCl 5.38 E -Stab 995 Lime 4.92 Cor Sol 14.4 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 149.2 @ 14,582' 3.1 @ 14,687' 36.5 N/A FT/HR SURFACE TORQUE 5237 @ 14,590' 3735 @ 14,344' 4585 N/A FT/LBS WEIGHT ON BIT 14.9 @ 14,490' 1.4 @ 14,553' 8.1 N/A KLBS TOPDRIVE RPM 142 @ 14,614' 70 @ 14,351' 131 N/A RPM PUMP PRESSURE 2296 @ 14,447' 1312 @ 14,657' 2066 N/A PSI FLOW IN 249 @ 14,343' 208 @ 14,676' 235 N/A GPM GAS SUMMARY (units) HIGH LOW AVERAGE GASES TRIP WIPER DITCH GAS 32.4 @ 14,537' 7.5 @ 14,341' 18.4 DITCH Zone Gas Survey CHROMATOGRAPHY (ppm) Downlink Down Time METHANE (C-1) 4014 @ 14,468' 216 @ 14,428' 850 CONNECTION HIGH = 0 ETHANE (C-2) 18 @ 14,535' 0 @ 14,419' 4 AVG = 0 PROPANE (C-3) 5 @ 14,537' 0 @ 14,351' 2 Current= 0 BUTANE (C-4) 4 @ 14,625' 0 @ 14,341' 1 CURRENT Background = 16 PENTANE (C-5) 3 @ 14,716' 0 @ 14,446' 1 (DITCH) Average = 18 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS OIL DESCRIPTION LITHOLOGY Current Formation: Tyonek General Lithology: sandstone, siltstone, tuffaceous claystone Current Lithology°/ : 20% tuffaceous sandstone, 80% sandstone LAG SUMMARY Annular Volume 677 bbl / %Theoretical 100% / 116 min @ 101 SPM / 11738 strokes @ 14743' DAILY ACTIVITY SUMMARY Drill from 14337'to 14338', service rig, drill from 14428'to 14743', pull out to 14171', monitor well, service lop drive, drawworks, crown, wrench, pumps, install MPD bearing per Swaco hands. Note: last 40' logged after trip. NABORS PERSONNEL R. Winkelman, A. Tuttle, S. Chamlee, S. Wright REPORT BY Sarah Chamlee DAILY COST $3,045 011111 NABORS DML Digital Mudlogging Hilcorp Alaska, LLC Beaver Creek Unit BCU 05RD2 Hilcorp 169 DAILY WELLSITE REPORT DATE: 9/11/18 TIME: 24:00 PRESENT OPERATION: Drilling PRESENT DEPTH: 15,228' DEPTH YESTERDAY: 14,743' SAMPLE DEPTH: 15,228' 24 HOUR FOOTAGE: 485' REPORT FOR: Rance Pederson & John Nicolson CASING DATA 20" cond @ 432' 95/8" @ 11,531' 7.000 " @ 14,918' Window @ 14,251' BIT DATA BHA TYPE: Rotary Steerable CONDITION No. Size Type S/N Jets IN OUT Footage Hours I -O -Char -Loc -B -G -Char -Pull 5.875" Mills 14,238' 14,299' 61' 12.4 1 5.875" Baker Hughes KMX323T 5272934 3x1a 14,299' SURVEY DATA DEPTH INCLINATION AZIMUTH TVD V SECTION +N/S. COORDINATES+E/W- DLS 14713.22 18.20 99.69 14216.01' 1769.07' 1315.67' 2189.01' 1.30 14769.61 16.92 102.65 14269.78' 1765.79' 1332.36' 2198.12' 2.76 14839.18 16.02 105.33 74336.50' 1761.04' 1351.50' 2207.83' 1.70 14902.09 13.97 106.00 1367.17' 1 2215.43' 1 3.27 1 14397.26' 1756.65' MWD/LWD SUMMARY INTERVAL: 14,299' to TOOLS: Geo -Pilot MUD REPORT DEPTH 15,213' MUD TYPE Enviromul (OBM) MUD BASE Oil Flowline Temp 102 of MW 1038 VIS 68 PV 24 YP 15 Gels 11/22/24 FL 4.6 Cake 2 CaCl2 9.66 Sd 0.01 Alk Pm Oil Oil/H2O78.9/21.1 NaCl 4.27 E -Stab 787 Lime 4.66 Cor Sol 15.8 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 172.8 @ 15,047' 1.0 @ 14,864' 42.7 25.0 FT/HR SURFACE TORQUE 6778 @ 15,131' 4038 @ 14,803' 5392 5148 FT/LBS WEIGHT ON BIT 15.3 @ 14,963' 0.3 @ 14,800' 10.5 9.3 KLBS TOPDRIVE RPM 152 @ 14,907' 80 @ 15,228' 114 95 RPM PUMP PRESSURE 2946 @ 15,085' 1471 @ 14,750' 2344 2641 PSI FLOW IN 225 @ 14,982' 208 @ 15,011' 217 216 GPM GAS SUMMARY (units) HIGH LOW AVERAGE GASES TRIP WIPER DITCH GAS 149.2 @ 14,799' 15.0 @ 14,777' 68.5 DITCH Zone Gas Survey CHROMATOGRAPHY (ppm) Downlink Down Time CONNECTION HIGH = 37 METHANE (C-1) 26574 @ 14,799' 423 @ 14,773' 10448 ETHANE (C-2) 41 @ 15,044' 2 @ 14,744' 21 AVG = 20 PROPANE (C-3) 11 @ 15,003' 1 @ 14,759' 5 Current = 11 BUTANE (C-4) 7 @ 14,988' 0 @ 14,793' 3 CURRENT Background= 46 PENTANE (C-5) 4 @ 15,197' 0 @ 15,139' 1 (DITCH) Average = 68 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS OIL DESCRIPTION LITHOLOGY Current Formation: Tyonek General Lithology: sandstone, tuffaceous siltstone, tuffaceous claystone, coal stringers Current Lithology% : 10% coal, 10% tuffaceous claystone, 20% tuffaceous siltstone, 30% sandstone, 30% tuffaceous sandstn LAG SUMMARY Annular Volume 684 bbl / %Theoretical 100/ / 138 min @ 86 SPM / 11860 strokes @ 15253' DAILY ACTIVITY SUMMARY Run in to 14728', tight spot at 14451', 14' hole fill, circulate and drill 14' hole fill, drill to 14783', encounter -10bph water flow at 14783', start holding back pressure with MPD at 500psi (10.6 ppg), drill to 15050', weight up to 10.5ppg, drill to 15228'. NABORS PERSONNEL R. Winkelman, A. Tuttle, S. Chamlee, S. Wright REPORT BY Sarah Chamlee DAILY COST $3,095 W11I NABORS DML Oigiral Mudlogging Hilcorp Alaska, LLC -.Seaver Creek Unit BCU 05RD2 Hilcorp 169 DAILY WELLSITE REPORT DATE: 9/12/18 TIME: 24:00 PRESENT OPERATION: Circulating PRESENT DEPTH: 15,680' DEPTH YESTERDAY: 15,228' SAMPLE DEPTH: 15,680' 24 HOUR FOOTAGE: 452' REPORT FOR: Rance Pederson & John Nicolson CASING DATA 20"cond @432' 95/8" @ 11,531' 7.000" @ 14,918' Window @ 14,251' BIT DATA BHA TYPE: Rotary Steerable CONDITION No. Size Type SIN Jets IN OUT Footage Hours 1 -0 -Char -Loc -B -G -Char -Pull 5.875" Mills 1 14,238' 14,299' 61' 12.4 1 5.876 " Baker Hughes KMX323T 5272934 3x14 14,299' 15,680' 1,381' SURVEY DATA DEPTH INCLINATION AZIMUTH TVD V SECTION +N/S- COORDINATES+E/W- DLS 15497.31 7.58 122.75 14984.40'L1703.91' ' 1450.82' 2239.17' 0.09 15586.46 7.08 123.36 15072.83' 1460.35' 2241.23' 0.56 15647.48 6.21 124.26 15133.44'' 1466.22' 2242.42' 1.44 15680.00 6.21 124.26 15165.77'' 1469.13' 2242.99' MWD/LWD SUMMARY INTERVAL: 14,299' to 15,680' TOOLS: Geo -Pilot MUD REPORT DEPTH 15680' MUD TYPE Enviromul (OBM) MUD BASE Oil Flowline Temp 106 OF MW 10.7 VIS 64 PV 26 YP 13 Gels 11/21/23 FL 4.6 Cake 2 CaC12 10.15 Sd 0.01 Alk Pm Oil Oil/H2O75.8/24.£ NaCl 5.93 E -Stab 807 Lime 5.7 Cor Sol 18.1 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 128.2 @ 15,539' 2.1 @ 15,400' 38.1 N/A FT/HR SURFACE TORQUE 7890 @ 15,679' 2441 @ 15,363' 6088 N/A FT/LBS WEIGHT ON BIT 16.8 @ 15,501' 5.3 @ 15,331' 12.3 N/A KLBS TOPDRIVE RPM 122 @ 15,504' 80 @ 15,234' 101 N/A RPM PUMP PRESSURE 2955 @ 15,672' 2162 @ 15,276' 2745 N/A PSI FLOW IN 229 @ 15,671' 206 @ 15,311 216 N/A GPM GAS SUMMARY (units) HIGH LOW AVERAGE GASES TRIP WIPER DITCH GAS 71.3 @ 15,486' 37.4 @ 15,248' 51.4 DITCH Zone Gas Survey CHROMATOGRAPHY (ppm) Downlink Down Time CONNECTION HIGH = 16 METHANE (C-1) 9177 @ 15,486' 3546 @ 15,380' 5518 ETHANE (C-2) 109 @ 15,446' 12 @ 15,250' 32 AVG = 0 PROPANE (C-3) 61 @ 15,444' 2 @ 15,285' 11 Current = 16 CURRENT Background = 45 BUTANE (C-4) 33 @ 15,445' 1 @ 15,294' 12 PENTANE (C-5) 19 @ 15,448' 0 @ 15,234' 9 (DITCH) Average = 50 HYDROCARBON SHOWS shows skewed by OEM INTERVAL LITHOLOGY/REMARKS GAS OIL DESCRIPTION 15300.15335 sandstone, tuffaceous sandstone, siltstone 42.7 To 54.8 milky yelsh white cut fl, mod brown vis cut and ring 15425.15475 55.5 To 63.2 slow yelsh white cut fl, pale straw vis cut sandstone, tuffaceous sandstone, siltstone 15608.15660 50.2 To 54.5 milky yelsh white cut 11; mod brown vis cut, sl ring sandstone, tuffaceous sandstone, siltstone LITHOLOGY Current Formation: Hemlock General Lithology: sandstone, tuffaceous siltstone, tuffaceous claystone, coal stringers Current Lithology% : 10% coal, 10% tuffaceous claystone, 20% tuffaceous siltstone, 30% sandstone, 30% tuffaceous sandstn LAG SUMMARY Annular Volume 684 bbl / % Theoretical 100% / 138 min @ 86 SPM / 11860 strokes @ 15253' DAILY ACTIVITY SUMMARY Drill from 15228' to 15610', troubleshoot top drive cooling pump failure, line up cooling system on one pump and top off cooling tank, continue drilling to 15664', circulate and get surveys to determine TD, mad pass from 15608' to 15664' per MWD hand, continue to drill to 153680', circulate bottoms up. NABORS PERSONNEL R. Winkelman, A. Tuttle, S. Chamlee, S. Wright REPORT BY Sarah Chemise DAILY COST $3,095 0111 NABORS DML Digital Mudlogging Hllcorp Alaska, LLC Beaver Creek Unit BCU 05RD2 Hilcorp 169 DAILY WELLSITE REPORT DATE: 9/13/18 TIME: 24:00 PRESENT OPERATION: Circulating/Weight Up PRESENT DEPTH: 15,680' DEPTH YESTERDAY: 15,680' SAMPLE DEPTH: 15,680' 24 HOUR FOOTAGE: 0' REPORT FOR: Rance Pederson & John Nicolson CASING DATA 20"cond @432' 95/8" @ 11,531' 7.000" @ 14,918' Window @ 14,251' BIT DATA BHA TYPE: Rotary Steerable CONDITION No. Size Type S/N Jets IN OUT Footage Hours I -O -Char -Loc -B -G -Char -Pull 5.875" Mills 14,238' 14,299' 61' 12.4 1 5272934 3x14 1,381' 50.2 5.875 " Baker Hughes KMX323T 14,299' 15,680' SURVEY DATA DEPTH INCLINATION AZIMUTH TVD VSECTION +N/S- COORDINATES +E/W DLS 15497.31 7.58 122.75 14984.40' 1710.11' 1450.82' 1 2239.17' L 0.09 15586.46 7.08 123.36 15072.83' 1703.91' 1460.35' 2241.23' 0.56 15647.48 6.21 124.26 15133.44' 1699.98' 1466.22' 2242.42' 1.44 6.21 1698.00' 1469.13' 2242.99' 15680.00 124.26 15165.77' MWD/LWD SUMMARY INTERVAL: 14,299' to 15,680' TOOLS: Geo -Pilot MUD REPORT DEPTH 15680' MUD TYPE Enviromul (OBM) MUD BASE Oil Flowline Temp 110 OF MW 11.32 VIS 64 PV 28 YP 17 Gels 12/21/23 FL 4.6 Cake 2 CaCl2 11.12 Sd 0.01 Alk Pm Oil Oil/H2O72.3/27.-, NaCt 4.9 E -Stab 710 Lime 3.37 Cor Sol 19.2 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION @ @ N/A FT/HR SURFACE TORQUE @ @ N/A FT/LBS WEIGHT ON BIT @ @ N/A KLBS TOPDRIVE RPM @ @ N/A RPM PUMP PRESSURE @ @ N/A PSI FLOW IN @ @ N/A GPM GAS SUMMARY (units) HIGH LOW AVERAGE GASES TRIP WIPER CIRCULATING GAS 152.0 @ 27.0 @ 45.0 DITCH 152 Zone Gas Survey CHROMATOGRAPHY (ppm) Downlink Down Time CONNECTION HIGH = METHANE (C-1) @ @ ETHANE (C-2) @ @ AVG = PROPANE (C-3) @ @ Current= CURRENT Background = 4h. BUTANE (C-4) @ @ PENTANE (C-5) @ @ DncR Average = HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS OIL DESCRIPTION LITHOLOGY Current Formation: Hemlock General Lithology: sandstone, tuffaceous siltstone, tuffaceous claystone, coal stringers Current Lithology°/ : 10% coal, 10% tuffaceous claystone, 20%tuffaceous siltstone, 30% sandstone, 30% tuffaceous sandstn LAG SUMMARY Annular Volume 690 bbl / %Theoretical 100% / 139 min @ 86 SPM / 11964 strokes @ 15680' DAILY ACTIVITY SUMMARY Continue to circulate, pump out to 15170', building psi and releasing, pump in to 15670', circulate sweep, continue circulating and build 141.9ppg pill, pump pill, spot 60bb1 pill in open hole, back pressure 500psi, pull to 14178', monitor well and circulate at 14176' to build mud from 10.6ppg to 11 ppg, shut in well, monitor and track pal, build 632psi after 20 minutes, 692psi after 30 minutes, open choke and get flow rate at 10bbllhr, circulate and weight up system to 11.5ppg. NABORS PERSONNEL R. Winkelman, A. Tuttle, S. Ohamlee, S. Wright REPORT BY Sarah Chemise DAILY COST $3,045 #I NABORS DML Digital Mudlogging Hllcorp Alaska, LLC Beaver Creek Unit BCU 05RD2 Hilcorp 169 DAILY WELLSITE REPORT DATE: 9/14/18 TIME: 24:00 PRESENT OPERATION: POOH PRESENT DEPTH: 15,680' DEPTH YESTERDAY: 15,660' SAMPLE DEPTH: 15,680' 24 HOUR FOOTAGE: 0' REPORT FOR: Rance Pederson & John Nicolson CASING DATA 20"cond @ 432' 95/8" @ 11,531' 7.000" @ 14,918' Window @ 14,251' BIT DATA BHA TYPE: Rotary Steerable CONDITION No. Size Type S/N Jets IN OUT Footage Hours I -O -Char -Loc -B -G -Char -Pull 5,875" Mills 14,238' 14,299' 61' 12.4 50.2 1 5.875" Baker Hughes KMX323T 5272934 3x14 14,299' 15,680' 1,381' SURVEY DATA DEPTH INCLINATION AZIMUTH TVD V SECTION +N/S- COORDINATES+E/W- OLS 15497.31 1 7.58 122.75 1 14984.40' 1 1710.11' 1450.82' 1 2239.17' 0.09 15586.46 7.08 123.36 75072.83' 1703.91' 1460.35' 2241.23' 0.56 15647.48 6.21 124.26 15133.44' 1699.98' 1466.22' 2242.42' 1.44 15680.00 6.21 124.26 15165.77' 1698.00' 1469.13' 2242.99' MWD/LWD SUMMARY INTERVAL: 14,299' to 15,680' TOOLS: Geo -Pilot MUD REPORT DEPTH 15680' MUD TYPE Enviromul (OBM) MUD BASE Oil Flowline Temp 110 of MW 11.55 VIS 70 PV 29 YP 15 Gels 12/22/24 FL 4.6 Cake 2 CaC12 8.21 Sd 0.01 Alk Pm Oil Oil/H20 74/26 NaCl 8.69 E -Stab 722 Lime 3.11 Cor Sol 21.5 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ N/A FT/HR SURFACE TORQUE @ @ N/A FT/LBS WEIGHT ON BIT @ @ N/A KLBS TOPDRIVE RPM @ @ N/A RPM PUMP PRESSURE @ @ N/A PSI FLOW IN @ @ N/A GPM GAS SUMMARY (units) HIGH LOW AVERAGE GASES TRIP WIPER CIRCULATING GAS 48,0 @ 14.0 @ 15.0 DITCH Zone Gas Survey CHROMATOGRAPHY (ppm) Downlink Down Time CONNECTION HIGH = METHANE (C-1) @ @ ETHANE (C-2) @ @ AVG = PROPANE (C-3) @ @ Current= CURRENT Background = 14 BUTANE (C-4) @ @ PENTANE (C-5) @ @ DITCH Average= HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS OIL DESCRIPTION LITHOLOGY Current Formation: Hemlock General Lithology: sandstone, full aceous siltstone, tuffaceous claystone, coal stringers Current Lithology % : 10% coal, 10% tuffaceous claystone, 20% tuffaceous siltstone, 30% sandstone, 30% tuffaceous sandstn LAG SUMMARY Annular Volume 690 bbl / % Theoretical 100% / 139 min @ 86 SPM / 11964 strokes @ 15680' DAILY ACTIVITY SUMMARY Circulate and weight up to 11.5ppg, pump 70bbl high vis pill, pull out to 11518', pump through kill line t0 keep hole full, holding 300pst back pressure, pump 801bbl 13.5ppg pill and spot at 11512', monitor well, build to 135psi In 20 minutes, pull out to 10050', pull MPD bearing/rotating head, installed flow nipple and tarp drip pan, continue pull out to 5660', lay down singles to 2300', change out elevators, lay down 4" drill pipe to top of BHA. NABORS PERSONNEL H. WInKeiman, z,. Unamlee REPORT BY Sarah Chemise DAILY COST $2,055 011I NABORS DML Digital Mudlogging Hllcorp Alaska, LLC Beaver Creek Unit BCU 05RD2 Hilroro 169 DAILY WELLSITE REPORT DATE: 9/15/18 TIME: 24:00 PRESENT OPERATION: RIH with liner PRESENT DEPTH: 15,680' DEPTH YESTERDAY: 15,680' SAMPLE DEPTH: 15,680' 24 HOUR FOOTAGE: 0' REPORT FOR: Rance Pederson & John Nicolson CASING DATA 20"cond @432' 95/8" @ 11,531' 7.000" @ 14,918' Window @ 14,251' BIT DATA BHA TYPE: Liner CONDITION No. Size Type S/N Jets IN OUT Footage Hours 1 -0 -Char -Loo -B -G -Char -Pull 5.875" Mills 14,238' 14,299' 61 12.4 14,299' 15,680' 1,381' 50.2 1 -1 -NO -A -F -I -NO -TD 1 5.875" Baker HughesKMX323T 5272934 3x14 SURVEY DATA DEPTH INCLINATION AZIMUTH TVD V SECTION +N/S- COORDINATES +E/W- DLS 15497.31 7.58 122.75 14984.40' 1710.11' 1450.82' 2239.17' 0.09 15586,46 7.08 123.36 15072.83' 1703.91' 1460.35' 2241.23' 0.56 15647.48 6.21 124.26 15133.44' 1699.98' 1466.22' 2242.42' 1.44 15680.00 6.21 124.26 15165.77' 1698.00' 1469.13' 2242.99' MWD/LWD SUMMARY INTERVAL: 15,680' to 15,680' TOOLS: MUD REPORT DEPTH 15680' MUD TYPE Enviromul (OBM) MUD BASE 011 Flowline Temp 110 OF MW 11.55 VIS 77 PV 29 YP 15 Gels 12/22/24 FL 4.6 Cake 2 CaC12 8,21 Sd 0.01 Alk Pm Oil Oil/1120 74/26 NaCl 8.69 E -Stab 709 Lime 2.98 Cor Sol 21.5 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ N/A FT/HR SURFACE TORQUE @ @ N/A FT/LBS WEIGHT ON BIT @ @ N/A KLBS TOPDRIVE RPM @ @ N/A RPM PUMP PRESSURE @ @ N/A PSI FLOW IN @ @ N/A GPM GAS SUMMARY (units) HIGH LOW AVERAGE GASES TRIP WIPER CIRCULATING GAS 24,0 @ 20.0 @ 21.0 DITCH Zone Gas Survey CHROMATOGRAPHY (ppm) Downlink Down Time CONNECTION HIGH = METHANE (C-1) @ @ ETHANE (C-2) @ @ AVG = PROPANE (C-3) @ @ Current= CURRENT Background = -. BUTANE (C-4) @ @ PENTANE (C-5) @ @ DITCH Average = HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS OIL DESCRIPTION LITHOLOGY Current Formation: Hemlock General Lithology: sandstone, tuffaceous siltstone, tuffaceous claystone, coal stringers Current Lithology % : 10% coal, 10% tuffaceous claystone, 20% tuffaceous siltstone, 30% sandstone, 30% tuffaceous sandstn LAG SUMMARY Annular Volume 682 bbl / %Theoretical 100% / 138 min @ 86 SPM / 11825 strokes @ 15680' DAILY ACTIVITY SUMMARY Continue to lay down BHA, clean rig floor, pull wear ring, prepare to run 4.5" liner, change out elevators, rig up Weatherford power tongs, pick up shoe track and run in with 4.5" liner per running order, run to 2667', make up liner hanger, rig down Weatherford, change elevators, rig up to single in with 4.5" drill pipe, run two joints and pumped tubing volume to break circulation at 2765', run in to 5369' with singles, continue running from derrick to 9224'. NABORS PERSONNEL H. W inNelman, s. unamlee REPORT BY Sarah Chamlee DAILY COST $2,055 fill NABORS DML Digital Mudlogging Hilcorp Alaska, LLC �3eaver Creek Unit BCU 05RD2 Hilcorp 169 DAILY WELLSITE REPORT DATE: 9/16/18 TIME: 24:00 PRESENT OPERATION: RIH With liner PRESENT DEPTH: 15,680' DEPTH YESTERDAY: 15,680' SAMPLE DEPTH: 15,680' 24 HOUR FOOTAGE: 0' REPORT FOR: Rance Pederson & John Nicolson CASING DATA 20" Gond @ 432' 95/8" @ 11,531' 7.000" @ 14,918' Window @ 14,251' BIT DATA BHA TYPE: Liner I CONDITION No. Size Type S/N Jets IN OUT Footage Hours 1 -0 -Char -Loc -B -G -Char -Pull 5.875" Mills 14,238' 14,299' 61' 12.4 1 5.875" Baker Hughes KMX323T 5272934 1 3x14 1 14,299' 15,680' 1,381' 50.2 1 -1 -NO -A -F -1 -NO -TD SURVEY DATA DEPTH INCLINATION AZIMUTH TVD VSECTION +N/S- COORDINATES +E/W- DLS 15497.31 7.58 122.75 14984.40' 1710.11' 1450.82' 2239.17' 0.09 15586.46 7.08 123.36 15072.83' 1703.91' 1460.35' 2241.23' 0.56 15647.48 6.21 124.26 15133.44' 1699.98' 1466.22' 2242.42' 1.44 15680.00 6.21 124.26 15165.77' 1698.00' 1469.13' 2242.99' MWD/LWD SUMMARY INTERVAL: 1500' to 15,680' TOOLS: MUD REPORT DEPTH 15680' MUD TYPE Enviromul (OBM) MUD BASE Oil Flowline Temp 110 of MW 11.6 VIS 67 PV 34 YP 17 Gels 14/23/31 FL 5.2 Cake 2 CaC12 12.57 Sol 0.01 Alk Pm Oil Oil/1120 67/33 NaCl 4.09 E -Stab 525 Lime 1.62 Cor Sal 19.7 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION @ @ N/A FT/HR SURFACE TORQUE @ CCD N/A FT/LBS WEIGHT ON BIT @ @ N/A KLBS TOPDRIVE RPM @ @ N/A RPM PUMP PRESSURE CO) @ N/A PSI FLOW IN @ @ N/A GPM GAS SUMMARY (units) HIGH LOW AVERAGE GASES TRIP WIPER CIRCULATING GAS 544.0 @ 59.0 @ 200.0 DITCH 1354 Zone Gas Survey CHROMATOGRAPHY (ppm) Downlink Down Time METHANE (C-1) @ @ CONNECTION HIGH = ETHANE (C-2) @ @ AVG = PROPANE (C-3) @ @ Current = BUTANE (C-4) @ @ CURRENT Background = 150 PENTANE (C-5) @ @ DITCH Average = HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS OIL DESCRIPTION LITHOLOGY Current Formation: Hemlock General Lithology: sandstone, tuffaceous siltstone, tuffaceous claystone, coal stringers Current Lithology% : 10% coal, 10%tuffaceous claystone, 20% tuffaceous siltstone, 30% sandstone, 30% tuffaceous sandstn LAG SUMMARY Annular Volume 682 bbl / %Theoretical 100% / 138 min @ 86 SPM / 11825 strokes @ 15680' DAILY ACTIVITY SUMMARY Continue to run in hole with liner, install MPD bearing, run in to 14171', circulate bottoms up, continue running In to 14460', work tight spot, circulate, begin to test choke manifold. NABORS PERSONNEL R. Winkelman, S. Chamlee REPORT BY Sarah Chamlee DAILY COST $2,055 Permit to Drill 2180680 MD 15680 TVD REQUIRED INFORMATION DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Well Name/No. BEAVER CK UNIT 05RD2 Operator HILCORP ALASKA LLC 15166 Completion Date 10/24/2018 Vol Mud Log .'W' .N cf Completion Status Samples 112 Current Status 1 -OIL API No. 50-133-20262-02-00 UIC No Directional Survey Yes DATA INFORMATION List of Logs Obtained: ROP/DGR/EWR-Phase 4/CTN/ALD/ABG MD/TVD, Mudlogs, CBL x 2 (from Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments 0 0 Log C 30029 Log Header Scans 0 0 2180680 BEAVER CK UNIT 05RD2 LOG HEADERS ED C 30029 Digital Data 14236 15680 11/20/2018 Electronic Data Set, Filename: BCU 05RD2 LWD Final.las ED C 30029 Digital Data 11/20/2018 Electronic File: BCU 05RD2 LWD Final MD.cgm ED C 30029 Digital Data 11/20/2018 Electronic File: BCU 05RD2 LWD Final TVD.cgm ED C 30029 Digital Data 11/20/2018 Electronic File: BCU 5RD2 - Definitive Survey.pdf ED C 30029 Digital Data 11/20/2018 Electronic File: BCU 5RD2 - Definitive Survey.txt ED C 30029 Digital Data 11/20/2018 Electronic File: BCU 5RD2 - GIS.txt ED C 30029 Digital Data 11/20/2018 Electronic File: BCU 05RD2 LWD Final MD.emf ED C 30029 Digital Data 11/20/2018 Electronic File: BCU 05RD2 LWD Final TVD.emf ED C 30029 Digital Data 11/20/2018 Electronic File: BCU 05RD2 LWD Final MD.pdf ED C 30029 Digital Data 11/20/2018 Electronic File: BCU 05RD2 LWD Final TVD.pdf ED C 30029 Digital Data 11/20/2018 Electronic File: BCU 05RD2 LWD Final MD.tif ED C 30029 Digital Data 11/20/2018 Electronic File: BCU 05RD2 LWD Final TVD.tif ED C 30029 Digital Data 11/20/2018 Electronic File: EMFView3_1.zip ED C 30029 Digital Data 11/20/2018 Electronic File: Readme.txt ED C 30030 Digital Data 14110 15710 11/20/2018 Electronic Data Set, Filename: BCU05RD2.las ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2 Nabors AM Report 8- 27-2018.pdf AOGCC Page 1 of 9 Mooday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/2512019 Permit to Drill 2160660 Well Name/No. BEAVER CK UNIT 05RD2 MD 15680 ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C Operator HILCORP ALASKA LLC API No. 50-133-20262-02-00 TVD 15166 Completion Date 10/24/2018 Completion Status 1 -OIL Current Status 1 -OIL UIC No 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2 Nabors AM Report 8- 28-2018.pdf 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2 Nabors AM Report 8- 29-201 S.pdf 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2 Nabors AM Report 8- 30-2018.pdf 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2 Nabors AM Report 8- 31-2018.pdf 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2 Nabors AM Report 9- 1-2018.pdf 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2 Nabors AM Report 9- 10-2018.pdf 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2 Nabors AM Report 9- 11-2018.pdf 30030 Digital Data 11/20/2018 Electronic File: BCU 05R02 Nabors AM Report 9- 12-2018.pdf 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2 Nabors AM Report 9- 13-2018.pdf 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2 Nabors AM Report 9- 14-2018.pdf 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2 Nabors AM Report 9- 15-2018.pdf 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2 Nabors AM Report 9- 16-2018.pdf 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2 Nabors AM Report 9- 2.2018.pdf 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2 Nabors AM Report 9- 3-2018.pdf 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2 Nabors AM Report 9- 4-2018.pdf, 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2 Nabors AM Report 9- 5-2018.pdf 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2 Nabors AM Report 9- 6-2018.pdf 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2 Nabors AM Report 9- 7-2018.pdf AOGCC Page 2 of 9 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2125f2019 Permit to Drill 2180680 Well Name/No. BEAVER CK UNIT 05RD2 MD 15680 TVD 15166 Completion Date 10/24/2018 Operator HILCORP ALASKA LLC Completion Status 1 -OIL Current Status 1 -OIL API No. 50-133-20262-02-00 UIC No ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2 Nabors AM Report 9- 8-2018.pdf ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2 Nabors AM Report 9- 9-2018.pdf ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2.dbf ED C 30030 Digital Data 11/20/2018 Electronic File: bcu05rd2.hdr ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2.mdx ED C 30030 Digital Data 11/20/2018 Electronic File: bcu05rd2r.dbf ED C 30030 Digital Data 11/20/2018 Electronic File: bcu05rd2r.mdx ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2 SCL.DBF ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2_SCL.MDX ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2_tvd.dbf ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2_tvd.mdx ED C 30030 Digital Data 11/20/2018 Electronic File: English.scl ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2 Final Well Report.pdf ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2 - 5in Drilling Dynamics Log MD.pdf ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2 - 51n Drilling Dynamics Log TVD.pdf ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2 - 5in Formation Log MD.pdf ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2 - 51n Formation Log TVD.pdf ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2 - 5m Gas Ratio Log MD.pdf ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2 - 5in Gas Ratio Log TVD.pdf ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2 - Sin LW D Combo Log MD.pdf ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2 - 5in LW D Combo Log TVD.pdf ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2 - Drilling Dynamics Log MD.pdf AOGCC Page 3 of 9 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 212512019 Permit to Drill 2180680 Well Name/No. BEAVER CK UNIT 05RD2 Operator HILCORP ALASKA LLC API No. 50-133-20262-02-00 MD 15680 TVD 15166 Completion Date 10/24/2018 Completion Status 1-0I1- Current Status 1 -OIL UIC No ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2 - Drilling Dynamics Log TVD.pdf ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2 - Formation Log MD.pdf ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2 - Formation Log TVD.pdf ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2 - Gas Ratio Log MD.pdf ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2 - Gas Ratio Log TVD.pdf ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2 - LWD Combo Log MD.pdf ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2 - LWD Combo Log TVD.pdf ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2 - 5in Drilling Dynamics Log MOM ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2 - 5in Drilling Dynamics Log TVD.tif ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2 - 5in Formation Log MD.tif ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2 - 51n Formation Log TVO.tif ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2 - 5in Gas Ratio Log MOM ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2 - 5in Gas Ratio Log TVD.tif ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2 - Sin LWD Combo Log MOM ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2 - Sin LWD Combo Log TVD.tif ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2 - Drilling Dynamics Log MD.tif ED C 30030 Digital Data 1112012018 Electronic File: BCU05RD2 - Drilling Dynamics Log TVD.tif ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2 - Formation Log MD.tif AOGCC Page 4 of 9 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2180680 Well Name/No. BEAVER CK UNIT 05RD2 Operator HILCORP ALASKA LLC API No. 50-133.20262.02-00 MD 15680 TVD 15166 Completion Date 10/24/2018 Completion Status 1 -OIL Current Status 1 -OIL UIC No 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2 - Formation Log TVD.tif FED 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2 - Gas Ratio Log MD.tif 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2 - Gas Ratio Log TVD.tif ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2 - LW D Combo Log MD.tif ED C 30030 Digital Data 11/20/2018 Electronic File: BCU05RD2 - LW D Combo Log TVD.tif ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15000.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15020.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15040.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15060.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15080.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15100.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15100a.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15120.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15140.jpg i ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15160.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15180.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15200.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15200a.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15210.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15220.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15230.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15240.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15250.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15260.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15270.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15280.jpg AOGCC Page 5 of 9 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2180680 Well Name/No. BEAVER CK UNIT 05RD2 Operator HILCORP ALASKA LLC API No. 50-133-20262-02.00 MD 15680 TVD 15166 Completion Date 10/24/2018 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15290.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15300.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15310.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15320.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15330.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15340.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15350.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15360.jpg I ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15380.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15400.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15420.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15440.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15460.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15480.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15500.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15520.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15540.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15560.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15580.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15600.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15620.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15620a.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15620b.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15630.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15640.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15640a.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15650.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15660.jpg ED C 30030 Digital Data 11/20/2018 Electronic File: BCU 05RD2_15660a.jpg AOGCC Page 6 of 9 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2180680 Krell Name/No. BEAVER CK UNIT 05RD2 MD 15680 TVD 15166 ED C 30030 Digital Data ED C 30030 Digital Data ED C 30030 Digital Data ED C 30030 Digital Data ED C 30030 Digital Data ED C 30030 Digital Data ED C 30030 Digital Data ED C 30030 Digital Data ED C 30030 Digital Data ED C 30030 Digital Data ED C 30030 Digital Data Completion Date 10/24/2018 Operator HILCORP ALASKA LLC API No. 50133-20262-02-00 Completion Status 1 -OIL ED C 30030 Digital Data Log C 30030 Log Header Scans 0 0 Log C 30031 Log Header Scans 0 0 ED C 30031 Digital Data 15008 11484 ED C 30031 Digital Data ED C 30031 Digital Data ED C 30068 Digital Data 13096 15507 ED C 30068 Digital Data 15481 13070 ED C 30068 Digital Data 15465 15193 ED C 30068 Digital Data 13022 12840 ED C 30068 Digital Data 13020 12860 Current Status 1 -OIL UIC No 11/20/2018 Electronic File: BCU 05RD2_15670.jpg 11/20/2018 Electronic File: BCU 05RD2_15670a.jpg 11/20/2018 Electronic File: BCU 05RD2_15680.jpg 11/20/2018 Electronic File: BCU 05RD2_15420.zip 11/20/2018 Electronic File: BCU 05RD2_15500.zip 11/20/2018 Electronic File: BCU 05RD2_15580.zip 11/20/2018 Electronic File: BCU 05RD2_15620.zip 11/20/2018 Electronic File: BCU 05RD2_1563D-15650.zip 11/20/2018 Electronic File: BCU 05RD2_15660.15680.zip 11/20/2018 Electronic File: BCU 05RD2 Show Report 1 15300-15336.pdf 11/20/2018 Electronic File: BCU 05RD2 Show Report 2 15425-15481.pdf 11/20/2018 Electronic File: BCU 05RO2 Show Report 3 15610-15662.pdf 2180680 BEAVER CK UNIT 05RD2 LOG HEADERS 2180680 BEAVER CK UNIT 05RD2 LOG HEADERS 11/20/2018. Electronic Data Set, Filename: BCU- 05RD2_CBL_170CT18.las 11/20/2018 Electronic File: BCU-05RD2_CBL_170CT18.pdf 11/20/2018 Electronic File: BCU- 05RD2_CBL _170CT18_img.tiff 12/5/2018 Electronic Data Set, Filename: BCU- 05RD2_ACE_28SEP18_ProcessedLog.las 12/5/2018 Electronic Data Set, Filename: BCU- 05RD2_CAST_28SEP18_MAIN.las 12/5/2018 Electronic Data Set, Filename: BCU- 05RD2_CAST_28SEP18_REPEAT.las 12/5/2018 Electronic Data Set, Filename: BCU- 05RD2 PERF_09OCT18_Correlation.las 12/5/2018 Electronic Data Set, Filename: BCU- 05RD2_PE RF_09OCT18_Shooting.las AOGCC Page 7 of 9 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2180680 Well Name/No. BEAVER CK UNIT 05RD2 Operator HILCORP ALASKA LLC API No. 50-133-20262-02-00 MD 15680 TVD 15166 Completion Date 10/24/2018 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 30068 Digital Data 13092 12846 12/5/2018 Electronic Data Set, Filename: BCU- 05RD2_PLUG_09OCT18_Correlation. las ED C 30068 Digital Data 13047 12892 12/5/2018 Electronic Data Set, Filename: BCU- 05RD2_PLUG_09OCT18_Setting.las ED C 30068 Digital Data 12956 12709 12/5/2018 Electronic Data Set, Filename: BCU- 05RD2_RETAI N ER_09OCT18_Cortelation.las ED C 30068 Digital Data 12917 12717 12/5/2018 Electronic Data Set, Filename: BCU- 05RD2_RETAI N E R_09OCT18_Setting.las ED C 30068 Digital Data 12/5/2018 Electronic File: BCU- 05RD2_ACE_28SEP 18_ProcessedLog.dlis ED C 30068 Digital Data 12/5/2018 Electronic File: BCU- 05RD2_ACE_28SEP18_ProcessedLog.pdf ED C 30068 Digital Data 12/5/2018 Electronic File: BCU- 05RD2_ACE_28SEP18_Processedlog.tif ED C 30068 Digital Data 12/5/2018 Electronic File: BCU-05RD2_CAST_28SEP18.pdf ED C 30068 Digital Data 12/5/2018 Electronic File: BCU- 05RD2_CAST_28SEP18_img.tiff ED C 30068 Digital Data 12/5/2018 Electronic File: BCU-05RD2_PLUG- PERF_09OCT18.pdf ED C 30068 Digital Data 12/5/2018 Electronic File: BCU-05RD2_PLUG- PERF_09OCT 18_img.tiff Log C 30068 Log Header Scans 0 0 2180680 BEAVER CK UNIT 05RD2 LOG HEADERS ED C 30068 Digital Data 11468 15450 12/18/2018 Electronic Data Set, Filename: BCU- 05RD2_TMD3D_080CT18_ProcessedLog.las ED C 30068 Digital Data 12/18/2018 Electronic File: BCU- 05RD2_TMD3D_08OCT18_ProcessedLog.pdf ED C 30068 Digital Data 12/18/2018 Electronic File: BCU- 05RD2_TMD3D_080CT 18_PmcessedLog.tif _ Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments Cuttings 14240 15680 10/31/2018 1676 INFORMATION RECEIVED AOG('< Page 8 of 9 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2180680 Well NametNo. BEAVER CK UNIT 05RD2 Operator HILCORP ALASKA LLC API No. 50-133-20262-02-00 MD 15680 TVD 15166 Completion Date 10/24/2018 Completion Status 1-0I1- Current Status 1 -OIL UIC No Completion Report 6 Directional / Inclination Data &Y Mud Logs, Image Files, Digital Data Core Chips Y / Production Test InformationO NA Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files Core Photographs Y Geologic Markers/Tops 10 Daily Operations Summary ,�O Cuttings Samples I Y Y Laboratory Analyses Y /Q COMPLIANCE HISTORY Completion Date: 10/24/2018 Release Date: 7/11/2018 Description Date Comments Comments: Compliance Reviewed By: Date: AOGCC Page 9 of 9 Monday, February 25, 2019 Seth Nolan Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATE 12/17/2018 2 1806 8 300-"5 To: Alaska Oil & Gas Conservation Commission Abby Bell Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 Data Resubmittal TMD3D WATER FLOW LOG ANALYSIS 12/17/2018 11:02 AM File folder Please include current contact information if different from above. Please acknowledgecelpt by sign�g and r"rni one copy of this transmittal or FAX to 907 777.8337 iii " /I��'.��►/ll/ ,,��; 21 806-1 30068 Ifa'„rp :UaAa. 1.11, DATE 12/04/2018 Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 CAST -CBL -PERF CAST_28SEP18 PLUG-PERF_090CT18 TMD3D WATER FLOW LOG FIELD DATA I ANALYSIS RECEIVED DEC 0 5 2018 AOGCC 11/13/20181:50M File folder 11/13/20181:50 PM File folder 11/13/2018 3:37 PM File folder 11/13/2018 3:37 PM File folder Please include current contact information if different from above. Please acknowledge r4eiptby signy(Vand ret"ming copy of this transmittal or FAX to 907 777.8337 Received By: / jr // , d /) �// \ A Date: nilrnrp Ab,Au, 11JA: DATE 12/04/2018 21 806 Debra Oudean Hilcorp Alaska, LLC 30 06 0 GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 5RD2 (PTD 218-068) CAST -CBL -PERF CAST 28SEP18 . PLUG -PERF 09OCT18 TMD3D WATER FLOW LOG I FIELD -DATA I ANALYSIS RECEIVED DEC 0 5 20% AOGCC 11/13/20181:50 PM File folder 11/13/20181:50 PM File folder 11/13/2018 3:37 PM File folder 11/13/2018 3:37 PM File folder Please include current contact information if different from above. Please copy of this transmittal or FAX to 907 777.8337 Received By: / /' J/ , f Date: Hilrnrp :14�rka, 1.LC: DATE 11/19/2018 Seth Nolan Hilcorp Alaska, LLC GeOTech 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 Fax: 907 777-8510 E-mail: snolan@hilcorp.com To: Alaska Oil & Gas Conservation Commission Abby Bell Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTA BCU 5RD2 Print: Mudlog Final Report CD: 1 . _Log Veneers 9/18/2018 6:17 PM File folder CGM 9/18/2018 6:17 PM File folder . Definitive Survey 9/18/2018 6:17 PM File folder . EMF 9/18/2018 6:17 PM File folder . LAS 9/18/2018 6:17 PM File folder . PDF 9/18/2018 6:17 PM File folder . TIFF 9/18/2018 6:17 PM File folder CD: 2 . Daily Reports 11/6/2018 4:32 PM File folder . DML Data 11/6/2018 4:32 PM File folder Final Well Report 11/6/2018 4:32 PM File folder . LAS Data 11/6/2018 4:32 PM File folder . Log PDFs 11/6/2018 4:32 PM File folder . Log TIFFS 11/6/2018 4:32 PM File folder . Sample Photography 11/6/2018 4:32 PM File folder . Show Reports 11/6/2018 4:32 PM File folder RECEIVED NOV 2 0 2018 AOGCC 21 8088 30029 Please include current contact information if different from above. Please acknowledgeKeceipt by signingnd re rning one copy of this transmittal or FAX to 907 777.8510 Received 8y: / ) // // „ //// \ I I Date: DATE 11/19/2018 Seth Nolan Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 Fax: 907 777-8510 E-mail: snolan@hilcorp.com To: Alaska Oil & Gas Conservation Commission Abby Bell Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 5RD2- Print: Mudlog Final Report CD: 1 I. jog Viewers 9/1812018 6:17 PM File folder ..f CGM 9/18/2018 6:17 PM File folder .}, Definitive Survey 9/18/2018 6:17 PM File folder I . EMF 9/18/2018 6:17 PM File folder `. LAS 9/18/2018 6:17 PM File folder PDF 9/18/2018 6:17 PM File folder . TIFF 9/18/2018 6:17 PM File folder CD: 2 j . Daily Reports 11/6/2018 4:32 PM File folder . DML Data 11/6/2018 4:32 PM File folder j . Final Well Report 11/6/2018 4:32 PM File folder . LAS Data 11/6/2018 4:32 PM File folder j . Log PDFs 11/6/2018 4:32 PM File folder a . Log TIFFs 11/6/2018 4:32 PM File folder . Sample Photography 11%6/2018 4:32 PM File folder Show Reports 11/6/2018 4:32 PM File folder RECEIVED NOV 2 0 2018 AOGCC 30030 Please include current contact information if different from above. Please acknowledgeKeceipt by signingnd re rning one copy of this transmittal or FAX to 907 777.8510 Received By: / ) // // „ //// \ I I Date: DATE 11/01/2018 Seth Nolan Hilcorp Alas,..., LLC GeoTech 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 Fax: 907 777-8510 E-mail: snolan@hilcorp.com To: Alaska Oil & Gas Conservation Commission Meredith Guhl Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 5RD2 CD: CBL BCU-05RD2_CBL_170CT18.las 10/30/20188:43 AM BCU-05RD2_C8L_170CT18.pdf 10/30/2018 11:33 AM BCU-05RD2_C6L_170CT18 img.tiff 10/30/201811:33 AM Please include current contact information if different from above. RECEIVED E® NOV 2 U 20% AOGCC LAS File 5,472 KB Adobe Acrobat Doc... 8,563 KB TIFF File 30,51618 2 180 68 30031 Please acknowledge rAceipy by signing and rettyrning one copy of this transmittal or FAX to 907 777.8510 Received By: / i // /1q /// , /// I Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ECEIVED NOV 19 2n1R WELL COMPLETION OR RECOMPLETION REPORT AN OG 1a. Well Status: Oil Q Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 20AAC 25.105 20nnc 25A10 GINJ ❑ WINJ ❑ WAG[—] WDSPL ❑ No. of Completions: _ 1 1b. Well Class: p Development ❑✓ Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: Hilcorp Alaska, LLC 6. Date Comp., Susp., or Aband.: 10/24/2018 14. Permit to Drill Number/ Sundry: 218-068 /318-406 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 7. Date Spudded: September 6, 2018 15. API Number: 50-133-20262-02-00 4a. Location of Well (Governmental Section): Surface: 1267' FNL, 1465' FWL, Sec 34, T7N, R1 OW, SM, AK Top of Productive Interval: 525' FSL, 2353' FEL, Sec 27, T7N, R1 OW, SM, AK Total Depth: 496' FSL, 2310' FEL, Sec 27, T7N, R1 OW, SM, AK 8. Date TD Reached: September 12, 2018 16. Well Name and Number: BCU-05RD2 9. Ref Elevations: KB: 178.4' GL:160.4' BF:160.4' 17. Field / Pool(s): Beaver Creek Unit Beaver Creek Oil Pool 10. Plug Back Depth MD/TVD: 15,512' MD 115,1100' TVD 18. Property Designation: FEDA028083 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 317312 y- 2433991 Zone- 4 TPI: x- 318765 y- 2435695 Zone- 4 Total Depth: x- 318807 y- 2435666 Zone- 4 11. Total Depth MD/TVD: 15,680' MD / 15,166' TVD 19. DNR Approval Number: N/A 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: N/A 5. Directional or Inclination Survey: Yes (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 14,238' MD / 13,778' TVD 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of lags to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary ROP, DGR, EWR-Phase 4, CTN, ALD, ABG MD1TVD, Drilling Dynamics Log MD/TVD, Formation Log MD/TVD, Gas Ratio Log MD/TVD, LWD Combo Log MD/TVD, CBL 9/28/18, CCL 10/17/18 23, CASING, LINER AND CEMENTING RECORD SETTING DEPTH TVD WT. PER GRADE SETTING DEPTH MD HOLE SIZE CASING FT TOP BOTTOM TOP BOTTOM AMOUNT CEMENTING RECORD PULLED 4-1/2" 12.6# L-80 12,934' 15,652' 12,592' 15,138' 5-7/8" 180 sx (150 sx squeezed into perts under Liner Top Pkr) 24. Open to production or injection? Yes Q No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 15,306'- 15,330' MD 114,795'- 14,819' TVD i;OMPLETION 15,432'- 15,456' MD / 14,920' - 14,934' TVD DATE 3-1/8", 6 SPF, 10/20/18 10 124 it VERIFIED ,�-- 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3-1/2" 12,940' 12,832' MD / 12,498' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes No Q Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) 1AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 11/3/2018 Method of Operation (Flowing, gas lift, etc.): Gas Lift Date of Test: 11/10/2018 Hours Tested: 24 Production for Test Period Oil -Bbl: 1153 Gas -MCF: 10 Water -Bbl: 0 Choke Size: N/A Gas -Oil Ratio: 8.9 Flow Tubing Press. 80 Casing Press: 1040 Calculated 24 -Hour Rate —* Oil -Bbl: 1153 Gas -MCF: 10 Water -Bbl: 0 Oil Gravity - API (corr): 34 Form 10-407 Revised 5/2017 / 30' CONTINUED ON PAC,�EE 2 RBDMS NtU KIN Z 1 2018Submit ORIGINIAL only 2/d/ ►4 14- 28. CORE DATA Conventional Corals): Yes ❑ No ❑✓ Sidewall Cores: Yes ❑ No Q If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑v If yes, list intervals and formations tested, briefly summarizing test results. Permafrost -Top Permafrost - Base N/A N/A Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval G2 15,306' 14,795' information, including reports, per 20 AAC 25.071. Tyonek T5-8 14,380' 13,903- T5-113 14,684' 14,188' Tyonek G 14,751' 14,252' High PSI H2O Sand 14,777' 14,277' G1 14,926' 14,420' G2 15,260' 14,750' Hemlock 15,535' 15,022' Ht 15,581' 15,068' H2 15,120' 15,633' Formation at total depth: Hemlock 31. List of Attachments: Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys, Csg and Cmt Report. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production orwell test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Monty Myers Contact Name: Cody Dinger Authorized Title: Drilling Manager Contact Email: Cdin of hilCOf .COm Authorized Contact Phone: 777-8389 Signature: Date: It • 19 - l S INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only LLC KB Elev.: 178.4'/ BF/GL Elev.: 160.4' 20' ■ Type Wt/ Grade/ Conn 1 d 2 13-3/8"; Conductor N/A/N/A/N/A 3 Surface 4 13-3/8" 5 61/K-55/ 6 Surface 3,511' l �r y"7J Production 47/P110/ 8.681 �J a 95/8" t 32/L-80/ 4 k l 14,918' F1h, is �. s 10 2�3y, 11 � r 13 &14 I Z'i 3N Squeeze 28 BBLS CMI' into Perls SCHEMATIC Beaver Creel Unit Well: BCU O5RD2 Completed: 10/24/18 PTD: 218-068 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor N/A/N/A/N/A N/A Surface 432' 13-3/8" Surface 61/K-55/ 12.415 Surface 3,511' 9-5/8" Production 47/P110/ 8.681 Surface 11,698' 7" Liner 32/L-80/ 6.184 11,531' 14,918' 4-1/2" Liner 12.6/L-80/DWC/C 3.833 12,934' 15,652' TUBING DETAIL 3-1/2" Tubing 9.3#/L-80/EUE 1 2.992 1 Surface 1 12,940' JEWELRY DETAIL No Depth Item 1 2,594' GLM w/ live valve 2 4,548' GLM w/ live valve 3 5,997' Chemical Injection Mandrel 4 6,198' GLM w/ live valve 5 7,553' GLM w/ live valve 6 8,749' GLM w/ live valve 7 9,838' GLM w/ live valve 8 10,931' GLM w/ orifice 9 11,941' GLM w/ dummy 10 12,813' GLM w/ dummy 11 12,832' 7" DLH Hydraulic Retrievable packer 12 12,843' X -Landing Nipple(RHCP plug body loaded) 13 12,934' HRD-E ZXP LTP w/5.25" PBR & Seal Assy Z ND c -TP 14 12,955' Flex -Lock Liner Hanger, HRD-E ZXPN UP w/ 5.25" PBR * L -(-;w i,,At (- 12 -'FS,) r A'0 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Size Date Status 4-1/2" Pipe 13,015' 13,018' 12,667' 12,670' 3 3-3/8" 10/9/18 Cemented G2 15,306' 15,330' 14,795' 14,819' 24 3-1/8" 10/20/18 Open G2 15,432' 15,456' 14,924 14,934' 14 3-1/8" 10/20/18 Open Est. TOC@ 14,805' V GOL., I G2 4-1/2' v fSLs 1 TD =15,580' (MD) /TD=15,165'(TVD) PBTD =15,512' (IVU) / PBiD=15,100'(lVD) GENERAL WELL INFO API: 50-133-20262-02-00 Initial Completion -10/1/1983 Revised By: GD 10/10/2018 Hilcorp Energy Company Composite Report Well Name: BCU-05RD2 Field: Beaver Creek Unit County/State: Kenai, Alaska i (LAT/LONG): evation (RKB): 18 API #: 50-133-20262-02-00 Spud Date: 9/6/2018 Job Name: 1810833D BCU-05RD2 Drilling Contractor RIG 169 AFE #: AFE $: Activity Date '' Ops Summary ` ,.. 9/5/2018 TIH with Baker Gen II WindowMaster whipstock/anchor assembly (ramp is 13.33' long), 5.875" starter mill, 5.75" lower mill, 6.55' flex jnt, 5.979" upper mill, one jnt 4" HWOP, Sperry DM and TM collars, Gyro -Data UBHO sub, and 2023' of 4" DP from 1591' to 2123'. C/O handling equipment to 4 1/2".;PU and single in hole with 18 jnts 41/2" CDS-40 DP, 2123' to 2310'.;Cont TIH on 4 1/2" DP stands from 2310' to 11,419', filling pipe every 2009. Sperry getting good detection on their tools each time we filled pipe.;Service, rig, topdrive and drawworks.;Cont TIH on 41/2" stands from 11,419'to 12,662 Had Baker Rep on location to watch as we entered top of liner at 11,698' ( no issue) Continue RIH to 12662' while filling pipe saver sub started Ieaking.;Remove and replace Saver sub damaged threads! lay down joint# 340 and replace with joint of equal Iength.;Cont. F 12,665-14,156' Pump @ 250gpm 735psi and orient whipstock to 52 deg. right. Continue RIH and tag CIBP at 14255.6. Set down 15k and engage anchor P!U and pulled 1 Ok to verify anchor set . S/O set 35k down to shear off and set whipstock placing top at 14238 bottom at 14255'.;PJSM: Line up mud pumps and pits to displace well bore with 9.5ppg taking water returns to cutting box vacuum trucks 11 and pits 3&7 then transfer water to UR tanks. Pump 20bbl hvs spacer followed by 863 bbls OBM . Pump at 6bbls min 1085psi Up Wt 180 Dn,Wt. 182 At 14238 '7 MD. 13,777 TVD.;Complete displacement. Clean clear pits.;OBM on location: 1,235 bbls OBM Diesel on Location: 268 bbls 916/2018 Cont cleaning all produced water from pits while circulating OBM with both pumps to help shear new mud. 227 gpm-1415 psi. Starter mill sitting at 14,230' (8' above whipstock ramp). Fluid packed Swaco MPD plumbing with OBM in case needed later (purged water from their system).;Running on pump #2 at 241 gpm- 1622 psi, 80 rpm -3500 fl/lbs off boft torque. Increased rpm to 103-3300 10 4400 fibs on bottom and began milling window from 14,238' to 14,271' at 3 to 6 ft hr ROP. Capturing and weighing metal at shakers. Adding diesel and building OBM volume. MW 9.5/vis 57.;Up wt 178K, dwn wt 178K, rot wt 178K. Mud loggers seeing 5 to 10% cement in cuttings samples. We did have one small spike of gas up to 31 units, BGG at 15 units,;Pumped a 20 bbl hi -vis sweep at 14,271' to clean hole for FIT. 340 gpm-2988 psi, 108 rpm -3063 Nibs off bott torque. Worked mill assembly in/out window as per Baker Rep with no issue. #2 mud pump discharge manifold leaking shut down pump, continue circulating out hi -vis sweep at 225 gpm.;P/U to 14238' R U test lines and chart for Fit test at 13,777 TVD . Circulate & purge all test lines. Using mud pump pressure up to 2149psi 14,238 MD 13,777 TVD 9.5 MW 2149psi =12.5 EMW. Pumped 9.4 bbl Bled back 8.5 bbls. R/D all test Ilnes.;Mill/Drill F- 14,271 -14,299 at 90 spm 241 gpm 1616 psi Up Wt. 178k. Dn. Wt. 178k Rt wt. 178k. To. 3.5-6knbs. 102rpm ROP 6- 10 FPH.. Mw. 9.5J Vis 57 Continue building volume at 10 bbls per hr. Work mills through window no issues window clean.;Circulate B/U at 14238' at 180spm 342gpm 2880psi. No increase in cuttings returning over the shakers on B/U. Max gas on B/U 27units Up Wt. 180k Dn. Wt. 178k Rt. 178k Take slow pump rates at 14,238 Md 13,777 TVD Pump # 1 @ 47stks.=398psi @ 57stks.=524psi Pump # 2 @ 47stks=400psi @ 57stks=528psi.;Monitor well for 15min. well state no gain or loss. Pump dry job pooh F-1 4238'- 13360'.;OBM on location: 1,235 bbls OBM Diesel on Location: 268 bbls Daily Metal 1211bs Cumulative Metal 130lbs 9/7/2018 Continue POOH from 13 360'to 11,709' with milling assembly. Saw +I- 5K drag pulling upper mill through tight spot at 13,060'. Alternating breaks on 41/2" DP.;Stopped at 11,698' (T' liner top) and pumped a 20 bbl hi -vis sweep around at 335 gpm-2131 psi, rotated 100 rpm. Had +/- 15% increase in fine cuttings to surface. Shut down pumps, flow checked 15 min, fluid dropped +/-10" and went static, pumped dry job.;Cont POOH on alternate breaks, from 11,698'to 5867' with no issue, hole fill right on. At 5867'5 stand hole fill was 1 bbl under.;Monitored well. Fluid level came up 5-6 inches and went static. Monitored 40 minutes, well static and falling in drill string. Pulled 5 more stands, hole took 1/2 bbl. Shut down and monitored well. Initial flow at 0.71 bph and continued to taper off to static over 15 minutes. Pulled 5 stands with;hole fill pump off. After 5 stands filled hole. Hole took 2 bbls. Pulled 5 stands with hole f11 pump on. Hole took 112 bbl. Acts like dry job u -tubing. Tried pulling slow with and without hole fill pump. Hole fill good with no pump, off with pump on. Pulled to 5083'.;Cont POOH slow from 5083'to 3920' with the same issues on hole fill.; MU topdrive and pumped dry job out of drill string. Monitor well.;Cont. POOH F-3726' Hole fill stabilized after pumping dry job out of pipe . At 3369' POH laying down 4 112 drill pipe At 2380' C/O to 4" DP elevators and slips . POH laying down 4" drill pipe. Hole fill correct to calculated value. Wellbore static no gain or Iosses,;Lay down window milling BHA. Upper mill was in Gage 5.979 od lower mill in Gage 7.50 Starter mill 114 out of Gage. Remove pulser from MWD and lay down same . Well static no gain or losses. Total hole fill Calculated at 95bbls actual 94bbls on complete trip from 14,238'.;Clean clean rig floor Service rig. Crown , blocks, top drive drawworks ,iron ruffneck and Skate Inspect drive line bolts to Dwks.;OBM on location: 1,235 bbls OBM Diesel on Location: 274 bbls Daily Metal 13lbs Cumulative Metal 149lbs Hauled o bbls fluid to G&I 9/8/2018 Remove drip catcher tarp under rotary table and check trip nipple clamp. No leaks, re -install tarp. Stage BHA items on pipe racks. Check suction valves in pit 7 and trip tank, no issues.;Held PJSM with DD/MWD and rig crew on PU BHA.;PU Geo -Pilot to rig floor and stage in mousehole. Topdrive not functioning, getting hydraulic alarms on Drillers console. Notify NOV tech, changed filters on topdrive and HPU. Turns out hydraulic system is on a 5 minute timer. Got that squared away, no further issues.;MU Sperry Geo -Pilot with 5 7/8" Kymera bit, DM, ILS, Slim Phase 4, ALD, CTN, PWD and HOC collars. MU float sub and XO. MU topdrive and PU. Plug in and upload MWD, then shallow pulse test. Good test. PJSM and load nukes. Remove topdrive, PU and run two NM flex DC's, float sub, UBHO sub,;XO, 3 jnts 4" HWDP, jars, 2 jnts 4" HWDP.;PU 1 st jnt 4" DP, MU topdrive and perform shallow test at 200 gpm. Good test ;PJSM, cont PU single in hole with 63 more its. 4" DP to 2386' Change out 4" drill pipe handling tools to 4 1/2 Continue PIU and single in hole 40jts of 41/2 DP to 3, 628 continue TIH to 4369' with stands from derrick.;Install T' OD Swaco well commander putting it 4,396' from bit, and 229' above 7" liner top at TD of 15,86T. Continue TIH from 4396to 10,548' filling pipe every 2500'. No gain losses. Correct hole displacement.;OBM on location: 1,235 bbls OBM Diesel on Location: 274 bbls Daily Metal: O lbs Cumulative Metal: 149 Ilm Hauled 0 bbls fluid to G&I Cumulative to G&I: 2005 BBLS. 9/9/2018 Load 44 jnts 4.5" DP on rack and strap same for PU.;PU single in hole 44 ints 4.5" DP (to allow drilling to TO with stands), from 10,548! to 11,825'. MU topdrive and filled pipe. Up wt 148K, on wt 148K. MWD tools reading good.;PJSM, slip and cut 99 drill line. Had to spool off new line and re -spool due to dog nut spun and was seated improperly. Calibrated block height and hook load. Installed 33' OMNI wrap on Kelly hose. Peak racked 41/2" liner and removing thread protectors.;Cont TIH from 11,893'to 14,231'. MU topdrive and filled pipe. Obtained SPR's. Up wt 220K, dwn wt 200K, rot wt 210K. Shut down pumps.;S/O and ease out through window with no issue. String taking weight at 14,281' (under gauge hole from mill assembly). PU to 14,274' and break circ at 244 gpm-2148 psi, 50 rpm4000 Wilts off bott torque. Ease down reaming under gauge hole to 14,285'. Keeping diff psi below 150 and 2K wob.;Cont to wash/ream down slowly from 14,285'to 14,299'. Rotating web 1 to 6K, 241 gpm-2177 psi, 60 rpm -3356 (flits torque, 117 psi diff, MW 9.5/vis 59, BGG 15 units.At 14,299'-14,337 Increase WOB- 9-10k 70rpm Up.Wt. 220kllbs Dn.wt 218k/Ibs Rt.Wt.216k/Ibs Rop.4.5-12 fph Tq.3450 Wlbs.;Directional Drill F- 14,337-14,458' at 14,354 increase Rt to 120rpm P -rate inc. to 12-34 fph 100spm 245gpm 2280psi 4100fUlbs tgUp. Wt 208k/Ibs Dn. Wt. 204k /lbs Rt. Wt.2061dIbs Max gas 35units no gain or loss At 14458 Increase rotary to 140 rpm Tq 4738F/lbs. Inclination at 14458' 23.26 deg.;OBM on location: 1,235 bbls OBM Diesel on Location: 274 bbls Daily Metal: 3 lbs Cumulative Metal: 152 Ibs Hauled 0 bole fluid to G&I Cumulative to G&1:2005 BBLS. 9/10/2018 Cent drilling 5 718" hole from 14 458' to 14,600'. WOB 5-1 OK 245 gpm-2237 psi, 56 psi diff, 140 rpm4570 ft/lbs on bott torque, 8 to 1 DO R/hr ROP, MW 9.51vis 66, ECD's at 9.8 ppg, BGG 13 units. Old wellbore at this depth had inc of 28°, we are at 24", released gyro -data Rep.;Drill from 14,600' to 14,738', WOB 8-15K, 216 gpm-1828 psi, 20-60 psi cliff, 124 rpm -4830 ftllbs on bott torque, 16 to 90 Whir ROP, MW 9.51vis60, ECD's at 9.8 ppg, BGG 19 units. Had a spike of 32 units. Assembly trying to walk right and drop. Using 80 to 100% deflection on Geo -Pilot. No water flow.;Drill from 14,738'to 14,743'. Discussed with Drilling Manager about pulling wiper trip to window to install MPD bearing. At 14,743' we are +/-12 to 17' above top of Tyonek G zone and 46 to 51' above the HP -H20 zone. Decision made to pull wiper Rip into 7" casing and install MPD bearing prior to;drilling stand down and into HP zone, and to inspect draw works brakes and Iinkages.;Racked back one stand, Circulated to clear open hole at 210 gpm-1680 psi, up wt 228K, dwn wt 234K, rot wt 234K. Monitored well, no flow. ;Pump POOH from 14,739'to 14,171 Up Wt. 230k/lbs Dn Wt. 232k/Ibs 65spm 1200psi 158Gpm Hole clean no pack offs or over pulls. No Gain or loss Correct hole fill Note Area of under gage hole F-14,299 up to 14,286 Clean no Overpulls.;Monitor well with trip tank. Service rig. Top Drive, Blocks, Crown, Iron roughneck and Drawworks . Hang Blocks and Top Drive Remove covers and inspect brakes on drawworks. Adjust brake linkage pick up brake bands off flanges clean up Flanges and brake blocks. Unhang blocks & TD.;Remove flow nipple Stab bearing into stand and set in body of MPD head.;Rih F-14,171' -14,739. at 14,451 ' set 10-15k down Kelly up and wash rotate clean up down to 14,605 Continue RIH to 14,677 on elevators Set down 10k Kelly up wash and ream at 75rpm 215gpm Hole attempting to pack off P/U and clean down to 14,728' Tag 14' of fill wash and ream down to 14,739.;Drill rotate ahead F-14,739 to 14780 214gpm 1825psi 88spm Rt. 125rpm Tq 4,750 ftfibs. Up wt. 214k /Ibs Dn.Wt. 21 Bk/lbs Rt.Wt. 2141k/Ibs Max gas- 16units Distance to plan 52.65'1 27.52low 44.89 nght.;OBM on location: 1,235 bbls OBM Diesel on Location: 274 bbls Daily Metal:21 lbs Cumulative Metal: 173Ibs Hauled 42 bbls fluid to G&I Cumulative to G&1:2047 BBLS.;Hauled 281obls soilds to Gil Cumulative solids hauled to GA 28bbls 9/11/2018 Continue directional drilling 5 7/6" hole from 14,780' to 14,893', MPD bearing installed but not circ through their choke. WOB 8-10K, 214 gpm-1831 psi, 120 rpm 5000 fUlbs on bolt torque, 13-80 R/hr ROP, MW 9.5/vis 64, ECD's at 9.88 ppg, BGG 19 units. At 14,801', in the HP -H20 sand, while making;a connection, we had 10.7 bph flow. Appears we tapped into HP -H20 at+/- 14,783' md. Resumed drilling through the MPD system. With bottoms up after that connection, had a max of 184 units gas that slowly tapered off to 90 units and held steady there. With bottoms up chlorides dropped from 265K to;164K, gels increased, oiVwater ratio dropped to 80120, vis increased from 63 to 74, and MW dropped from 9.5 to 9.4. Holding 114 psi backpressure to achieve 10 ppg ECD, increased diesel to 5 bph in active system and began treating mud as per Mud Engineer, increasing mud weight to 9.8 ppg.;Sperry Geo -Pilot also having issues. Not responding to commands. Assembly still dropping and walking right in rotation, but projection shows us to still be headed within target radius. Approved to cont drilling ahead, DO cont trouble shooting. WOB 8-12K.;Drilled 5 7/8" hole from 14,893'to 15,057'. WOB 12K, 215 gpm-2511 psi, 103 rpm -5700 ftnbs on bott torque, 23-60 f 1hr ROP, MW 10/vis 66, increased back pressure to 623 to achieve 11.1 ppg ECD, BGG 79. Seeing +/- 34 units over BGG connection gas all afternoon. Diesel at 5 bph. Geo -Pilot still not;responding to commands but we are still on target for TO target. Assembly still dropping +/- Will 00 and walking right +/- 6°/100. At 15,057' we lost all back pressure. Swaco MPD choke washed out. Swapped to their backup choke, notified Drilling Manager, decision made to increase mud weight to;10.5 ppg. Still seeing gains of 4 to 11 bph holding 600 psi back ground pressure and 11.3 ppg ECD's. Swaco has no spare parts to rebuild primary choke at this time.;Drilled 5 7/8" hole from 15,05T to 15,228' Start increasing mud weight from 9.6 to 10.5 while holding 500psi back pressure with MPD Gains are decreasing F241bbls per hour down to 8bbls per hr. while building mud weight to 10.5ppg ;Mud weight is 10.5 in and out. Influx of water down to 5bbls per hr holding 520psi back pressure with MPD = 11.8 ECD Pr. rate 9-35 fph 7-1 Ok 80-1 OOrpm 215gpm 2665psi Tq 5150 ftllbs Up Wt. 222k/Ibs Dn Wt. 202 k/Ibs Rt 200K/lbs.;Drill 5 7/8 hole from 15,228'15,346' 210 gpm,2665 psi 215gpm 2650psi 87spm 10.6Mw 495psi back pressure MPD = 11.8ECD P Rate 9-32 ft/hr water influx stopped no gains in pits. Adding 10bbls per Hr. diesel to mud system. Dn wt. 202 up Wt.218 Rt. Wt. 200 Tq 5350FUlbs No gains or Iosses.;OBM on location: 1,235 bbls OBM Diesel on Location: 175 bole Daily Metal:9 lbs Cumulative Metal: 182 lbs Hauled 42 bbls fluid to G&I Cumulative to G&1:2047 BBLS.;Hauled 28bbls soilds to G/I Cumulative solids hauled to Gil 28bbls 9/12/2018 Continued to drill 5 7/8" hole from 15,346 to 15,484'. 10-15K wob, 216 gpm-2754 psi, 44 psi diff, 100 rpm-5400 fit/lbs on bott torque, 8-25 R/hr ROP, holding 450 to 500 psi back pressure on MPD to give us 11.8 ppg ECD, MW 10.5/vis 67, BGG 53 units, diesel at 10 bph into active, drilling sand.;Drill 5 7/8" hole from 15,485' to 15,610'. 10-15K wob, 216 gpm-2792 psi, 120 rpm-6500 to 8800 ft/lbs on bolt torque, 11-100 tVhr ROP, holding 500 psi backpressure on MPD to maintain 11.8 ppg ECD, MW 9.5/vis 63, BGG 62 units, diesel at 10 bph. Into the hemlock formation at 15,523' md.;Troubleshoot topdrive glycol pump leaking on coolant skid. Took pump offline (conning on one pump).; Drill 5 718" hole from 15,610 to 15,664'. Sperry slim phase 4 tool not working. Cycled pump a couple times, got tool working, made madd pass from 15,609' down to 15,664'. Cont drilling 5 7/8" hole to TO at 15,680';Circulate B/U at 15680' 240 gpm 3185 psi 100spm reciprocate pipe 215up 215dn. B/U gas;POH wipe trip F-15,680' -15,238 Pump out W 47spm 1524psi attempt to continue wiper trip MPD having to hold 850 -875 Back pressure . Shut MPD system in saw 50psi build up in 2min or less. RIH f-14238-15671'. to condition mud . Note: no over pulls or pack off on wiper trip. In or Out;Circulate and condition mud at 15671 Mud wt. 10.5 vis 63 215gpm 3010pst adding 15bb1 diesel per hr. OII water ratio 75.8124.2 Max gas on B/U 151 units;OBM on location: 1,235 bbls OBM Diesel on Location: 292 bbls Daily Metal: 9lbs Cumulative Metal: 182 lbs Hauled 49 bbls fluid to G&I Cumulative to G&1:2096 bbls;Hauled 21 bbls solids to G/I Cumulative solids hauled to G/l: 49 bills 9/13/2018 Discussed with Drilling Manager on spotting weighted ill in open hole section 14 238' to 15,680') prior to pulling up hole into casing. Decision made to build 60 bills 11.9 ppg pill, start mixing and cant to circ at 238 gpm ppgpsi, holding 271 psi back pressure to maintain 11.8 ppg ECD,;60 rpm-4569 Ribs off bolt torque and reciprocate. Up wt 230K, dwn wt 213K, running diesel at 15 bph.;Held PJSM with rig crew on tripping with MPD, pumping spotting weighted pill. Lined up rig pump on kill line. Pumped at 214 gpm-22393 psi, pulled one stand, up weight 240K just to make sure we could pull with no rotation or pump. Pulled fine. Slacked off to bottom. Lined up on weighted pill.;Pumped 60 bbls 11.9 ppg weighted pill at 211 gpm-2562 psi, holding 500 psi back pressure to maintain 11.8 ppg ECD, 3600 strokes. Shut down and lined up rig pump on Will line. Opened kill HCR and broke circ across the top.;POOH from 15,680'to 14,176' (2 stands inside casing). Pulled entire trip with no pump no rotary. We did have to MU topdrive each stand due to some slight backflow from DP starting 8' in the air. Held 750 psi while pulling, 680 psi while sitting static. No issue pulling BHA through window. Stopped;at 14,176' and shut down pump. Closed MPD choke to monitor for well pressum.;lnitial shut in was 687 psi which built to 917 and climbing over 20 minutes. Notified Drilling Manager, resumed circulating through MPD system due to pressure build, decision made to increase mud weight to 11.0 ppg in wellbore on short system ;Lined up pump on drill string, start weight up in suction pit, taking returns to same pit (#7). Pumping at 208 gpm-2141 psi (to turn on PWD tool and monitor ECD's). Final circ pressure = 2198 psi. Initial back pressure = 614 psi, final back pressure = 280 psi. BGG 52 units. With 11.0 ppg in/out,;shut down pump and closed MPD choke. Initial shut in pressure= 470 psi that built to 694 psi over 30 minutes. Bled to zero and obtained flow rate at 10 bph. Notified Drilling Manager. Decision made to weight up to 11.5 ppg, then spot hi-vis pill at window. Resume circ down drill string while mixing;lncrease mud weight F- 11.0 to 11.5 in well bore. Mix 13.5140 bbl 223 vis pill and spot 70bbls in 7" liner up to 11,531' 4780 stks 220 gpm 2850 psi. Holding 95 psi back pressure = 12.2 ECD with MPD while pumpmg;POH on Elevators F 14176 -11,512" filling over the top with kill line Holding 254psi back pressure=12.2ECD with MPD system Up Wt. 205k/Ibs No gain/ Ioss;Line up to pump 13.5 hi As pill at 11,512';OBM on location: 1,235 bbls OBM Diesel on Location: 233 bbls Daily Metal: 9lbs Cumulative Metal: 182 Iles Hauled 49 bills fluid to G&I Cumulative to G&I: 2096 bbls;Hauled 21 bible solids to G/I Cumulative solids hauled to G/I: 49 bbls 9/14/2018 At 11,512', pumped and spotted 70 bbls of hi-vis 13.5 ppg pill in the 9 5/8" casing, above the 7" liner. 216 gpm-1965 psi. Shut down pump and closed MPD choke. Initial pressure of 10 psi built to 80 psi over 10 minutes. Opened choke.;Lined up rig pump on kill line and POOH slow to clear drill string from hi-vis pill. Once clear pulling faster. First 10 stands hole fill was right on 2.4 bbls per 5 stands, then went to 5 bbls per 5 stands. With MPD choke full open and pump at idle, no change in hole fill. Stopped at 8729'.; Removed drip catcher tarp under rotary table, loosened MPD clamp and removed bearing. Installed trip nipple and drip catcher tarp. Had slight flow. Lined up on trip tank.;Cont POOH from 8729' on trip tank, hoe fill was slightly over/under at times, but for the most part 2.4 bbis per 5 stands. LD 41 /2" DP at 5660'. LD well commander at 4413'. Gave BLM 48 hour notice for casing/cement(BOP test, set up two frac tanks for upcoming diesel displacement.;Cont to POOH LD 64 more jnts 41/2" singles to 2382'. CO handling equipment and LD 4" OF, HWDP, jars, and XO's to BHA.;Lay down sperry Geo-pilot BHA HWDP, Jars , Flax collar, remove pulser and sources Turn off MWD/LWD and lay down. Break out bit lay down geopilot. Shut well in. Flow check on well . flowing 5bbis per hour.;Clean clear rig floor Monitor well pressure build up 384 in one hour Bleed off to O;OBM on location: 1,235 bbls OBM Diesel on Location: 233 bbls Daily Metal: 9Iles Cumulative Metal: 182 Iles Hauled 49 bbis fluid to G&I Cumulative to G&I: 2145 bbls;Hauled 21 bills solids to G/1 Cumulative solids hauled to Gil, 70 bible 9/15/2018 Bled 384 psi off wellbore, opened blinds, ran in retrieval tool and pulled wear ring. Cont to clean and clear rig Floor. Well flowing at 5 bph. Closed blinds.;RU Weatherford tongs/elevators, staged centralizers, pup joints and liner for PU.;Held PJSM with rig crew, Peak crew and Weatherford. First time this crew PU run liner on this rig.;PU and MU 4joint shoe track. Filled and checked Floats (ok). Cont PU single in hole with a total of 62 ints 12.6# L-80 4 1/2" DWC liner and 7 pu n jnts, torqued to 6200 R/Ibs. Ran 36 composite centralizers on all full joints to be set in open hole.;PU/MU Baker 5" x 7" HRD-E ZXHD liner top packer/flexdock �r hanger assembly, set up with 7 shear screws, shear force of 34,300 Iles. Mixed and poured pal mix, RD Weatherford tongs/elevators. PU singled in with 2 jnts CDS-40 DP.;MU topdrive, broke circ at 193 gpm-147 psi. Circulated one string volume. Up wt 52K, dwn wt 52K. Cont to PU single in hole drifting singles from - *W 2767'to 4314'.;Cont PU single in hole from 4314'to 5369' drifting singles. Start TIH from derrick and drift to 2.87 from 5369'to Fill Pipe at 5800' Mud weight out �. 11.6 Cont TIH to 7975 Fill Pipe 11.5in 11.6 out TIH to 11513';Circulale and condition Mud all 1,333'(Above the 7" liner top) Initial Circ pressure 345psi 145gpm increase rate to 94spm 220gpm 600psi Mud weight in11.6 Dumping all returning mud contaminated 120bbis total .Mud returning over shakers 10.51 Circ 7343stks;Continue TIH F- 11333 -13,129 Well flow increased to 10bbls stop and install MPD bearing;OBM on location: 1,235 bbls OBM Diesel on Location: 233 bbls Daily Metal: 91bs Cumulative Metal: 182 Itis Hauled 40 bbls fluid to G&I Cumulative to G&I: 2185 bbls;Hauled 10 bbls solids to G/I Cumulative solids hauled to G/I: 80 bbls 9/16/2018 Installed MPD bearing at 13,152'. Initial well flow at 10 bph down to 8.5 bph. Stayed lined upon 6" flowline.;TIH from 13,152'to 14,171'. This keeps the 5" x 7" liner hanger just above the 7" liner top for circulating with less restriction.;Broke circ at 4 bpm -950 psi holding 165 psi back pressure on MPD system to give us EMW of 12.1 at the window. Up wt 184K, dwn wt 177K, rot wt 182K. Prior to bottoms up started overboarding contaminated mud. MW out was anywhere from 8.9 to 12.1 ppg and very thick.;Total volume to cuttings box= 371 tibia. Transferred 11.0 mud from upright tank into pit 9 and brought weight up to 11.5 ppg, transferred that into pit 7 suction pit. Was able to reduce pump rate to idle and keep pumping through entire circ. Rotating parameters 10 RPM -3200 f8bs, 20 RPM -3050 ft/Ibs,;30 RPM = 3200 ft/lbs. No change in up/dwn weights after CBU. Had a max of 1355 units gas at bottoms up, that dropped off quickly to 31 units. With 11.5 ppg intout, shut down pump and had no flow.;TIH on elevators from 14,171'to 14,455'. No issues exiting window. Down weight 187K. At 14,455' we set down solid20K. Formation log shows a coal seam. Up wt 200K picked up clean. Set down picked up again 5 times with no headway. Pulled up hole 60' and MU topdrive.;Attempted to break circ at pump idle 2.7 bpm with a standpipe pressure limit of 1000 psi as per Baker linerhanger Rep. Pump pressure would spike to 900 psi, flow rate dropped off, shut down pump. Took a good 30 minutes of pump on and off, and working string in sweet spots where trapped pressure;would bleed off as flow returned. Started rotating 20 rpm -3100 ft/lbs torque and things got better. Worked stand a dozen times full length but could not get over 2.7 bpm. Washed/reamed right down through set down depth and never saw a thing to 14,460'.;Racked back that stand and MU topdrive. We were able to stage pump rate up to 4 bpm -950 psi with 44 to 45% flow and work entire stand with and without rotation. Began adding diesel to active pit at 5 bpm to try and bring oil/water back to 70/30 ratio.;Worked that stand until bottoms up. Had max 544 units gas about 2000 strokes prior to bottoms up. At bottoms up had a good amount of fine sand/calcium carbonate and coal chips dime and nickel size. With hole cleaned up down to 14,470', made connection.;Continue TIH F- 14,470'- 14,484' Wash and ream 47spm 650psi 20rpm to clean up F- 14470' down to 14,484', Seeing some pack off, P/U and clean up setting up to 20k to clean hole. Continue TIH to 14,714', unable to pass. Vary pump rates F-47spm 114gpm to 57spm 147gpm;Continue to work 14,714'to 14,715', back ream at 20-30 rpm, pump 47-60 spm 850psi 114 -154 gpm. Torque up to 5200f llbs. No problem with pack offs. Continue to clean up. Up wt 203 On wt 193k. Max gas 420 units. Tested choke manfold prior to midnight at 250/4500psi, 5 min test all passed.;Total Safety was out at 18:00 and tested gas alarms. Sent AOGCC Rep Jim Regg an update at 21:00 him on hole conditions and depth.;Hauled 37bbls solids to G/I Cumulative 117bb1s Hauled 538bbls fluid to G/I Cumulative 2798bbls OBM vertical tank 380bbl Diesel 200bb1s 9/17/2018 Cont washing/reaming on tight hole with 41/2" liner assembly, from 14,714' to 14,716'. 114 gpm-870 psi, 20 to 25 rpm when rotating, 3700 to 5900 ft/lbs off bottom torque. Very little issue with packing off, even if setting down 20K on string. Trying various pump rates, RPM'S, with/Without pump and;rotary. Adding diesel to active pit 7 and maintaining MW at 11.5 ppg. Still +/- 2 bph gain. Up wt 190K, dwn wt 188K, Rot wt 182K. Discussed using MPD to hold 300 psi back pressure with Drilling Manager to see if well would open up. Got the OK.;Shut down pump. Well flowing at 4.5 bph. Lined up rig pump on kill line at 2.7 bpm. Applied 300 psi on wellbore to give us an EMW of 12.1 ppg. SIO to 14,716' and set down 40K on tight spot. PU to 230K and pulled free. SIO to set down 50K and string slid right through tight spot to 14,731'. Contlnued;TIH holding 300 psi backpressure to 14,854'. MU topdrive, lined up pump to circ down drill string. Filled pipe and circulated holding 185 psi backpressure. Able to rotate at 20 RPM. Pumped 100 bbls and shut down. Cont TIH holding 300 psi backpressure from 14,854' to 14,954'.;Cont TIH from 14,954'to 15,230' holding 300 psi back pressure. Down wt 188K, up wt 221 K. Did have to pump down drill pipe and work string numerous times at 15,174'. Also used a single jnt to have some room to stroke pipe. Ran last few stands down holding 370 psi backpressure. Tagged fill at 15,660';TD at 15,680'. Broke circulation at 15,660' and seeing pressure spikes and torque stall. PU to 15,651' and everything cleared up, able to rotate and circulate. Notified Drilling Manager, was told we had 200' rat hole, so decision made to LD top single and PU 15' pup.;LD top single, MU 15' pup and Baker cement head, MU topdrive. S/O and tagged bottom (fill) at 15,660'. PU 9' off bottom and parked shoe at 15,651', to set up cement head at proper height for LD 1/ after cementing. Broke circ at 114 gpm-1400 psi, rotating 20 rpm -4500 fit/lbs torque. Start RU Halliburton;hardline and chicksans to rig floor. RU chicksans to { cement head, manifold and wash up hose to cuttings box.;Held PJSM with Halliburton, Peak and rig crew.;Halliburton pumped 5 bbls water to flush lines, then 5 bbls to fill lines. Shut in at Baker cement head and PT lines at 500 psi low, 4800 psi high. Good tests. MPD lined up on their choke skid, holding 150 psi back (./•1''.`rf` pressure, well not Flowing. Lined up Baker cement head to Halliburton, pumped 25 bbls;12.5 ppg spacer at 3 b m-1746 psi, Baker released plut, and Halliburton followed that with 52 bbls 180 sx 15.3 ppg Class "G" Lead cement at 3 m 1750 to 1775 si with full returns and shut down. Added 2.9 ppb LCM to cement IjV1J,l"M prior to the job. Halliburton then displaced with 11.5 ppg OBM mud at 4;bpm-1500 psi ICP. Saw dart latch wiper plug. With 10 bbls to go, reduced rate to 2.5 bpm 1500 psi and but did not see plug bump landing collar at 227.5 bbls into displacement (calculated at 223 bbls). FCP 1500 psi. Pressure bled off. Pressured up to 1500 psi again (1 bbl) and pressure bled off.;Well was flowing on backside, flow never stopped back to the pump truck. Floats not holding.;Baker Rep decided to safety off and set hanger as we could not pressure up to set. Rotated to the left 6 rounds and picked straight up. Slacked off on blocks from 200K to 120K, giving us a good indication hanger was set. PU 5'to clear dogs from hanger top and had good indication we released;liner string. SIO to 120K to set packer with good indication of shear. PU, rotated at 15 rpm, 2600 Nibs torque, S/O and set down to 120K to ensure weight transfer to set packer. Top of liner hanger at 12,954.93', top of landing collar at 15,527.94'. CIP at 23:59 on 9-17-18.;Halliburton pressured up to 1500. Increased pressure to 2000 psi (500 over fcp) and held for 3 zj� tiy"' minutes. Bled back 2.5 bbls to truck and floats held (pumped 2.5 bbls). Eventually opened MPD choke during job as flow show indicated we were pushing mud/cement away. Gained 2 bbls throughoutjob.;LD Halliburton hardline, LD Baker cement head, MU topdrive (no back flow on drill string). Pressured up to 500 psi on drill string and PU 11'. Once psi dropped rig started pumping and did one bottoms up at 416 gpm-3071 psi. Saw no spacer w/dye, estimate 10 bbls cement at shakers.;Shut down pump, installed wiper ball in drill string, MU topdrive and pumped second full circulation at 300 gpm-1761 psi. Max gas on B/U 40 units;Monitor well for 15min, no flow, remove MPD bearing, install trip nipple and drip pan.;Hauled 1 bbls solids to G/I Cumulative 128bbis Hauled 239bbis fluid to G/I 9/18/2018 Cont install trip nipple and drip pan for tripping.;Flow check. Static. Pump 12.7 ppg dryjob. Trip out of the hole from 12,819'to 11,478'. Up weight 170k. Hole fill as calculated.;Break down cement head. Make up test plug.;Drain stack. Land test plug. Rig up to test BOPE. Start to change out lower rams from 4" to 4.5" . Observe well began flowing out of IA. Began as a trickle and increased to 4.7 BPH.;Rig down test equipment. Pull test plug. Lay down test joint. Stab FOSV. Monitor well. Pressure built to 75 PSI in 15 mins.;Bleed pressure off and circulate surface to surface. 250 GPM, 875 PP ICP, 925 PP FCP, no pit gain.;Shul down pump. Monitor well. Still flowing 4.7 BPH. Shut UPR's pressure up to 2000 PSI. Shut down and trap 1475 PSI. Held for 5mins. Bleed off. Pumped 6 BBLS, got back 6 BBLS. Pressure up to 2150 PSI, dump pressure in attempt to close floats. Close well in. Pressure built to 475 psi in 30 mins.;Was still climbing. Bleed back to zero. Gained 2.1 BBLS. Close well in. Monitor well, and bleed off pressure when it got to 400 PSI. Gained another 2 bbls. Contacted Jim Regg AOGCC Supervisor. He gave a verbal BOPE lest waiver until the well is secure.;R/D Flow nipple install MPD bearing Circulate and Increase mud weight F- 11..3 to 12.2 ppg. Circ, at 420gpm 173spm 2341 psi Mud weight in 12.3 out 12.2 Mixed a total of 1452 sx.;Remove MPD bearing, Install 2 X overs and Float sub in string at stand # 185111477' Install MPD bearing Montor well for 30 min. Well flowing 1 bbl per hour;TIH f-11477' - 12912' Top of 4 1/2 liner Holding 150psi static 75psi dynamic, also pumping through the kill line . Up wt. 165k/Ibs;Circulate and condition mud at 12912' 346gpm 2461 psi 143spm Mud weight out 12.2 Mud weight in 12.3;Hauled 0 bbls solids to G/1 Cumulative 128bbis Hauled 239bbls fluid to G/I Cumulative 3,007bbls OBM vertical tank 380bbl Diesel 60bbls 9119/2018 Circulating and conditioning the wellbore to 12.2 ppg MW in/out.;Monitor well. Pressure built to 95 psi in 30 mins.;Slip and cut drill line, 86'. Holding back pressure with MPD. 200 psi. No pit gain.;Service rig. Grease crown, blocks, top drive, draw works. Check oil level in all engines.;Monitor well . Well flowing @ 1.5 BPH. Weight up mud from 12.2 ppg to 12.4 ppg. With 12.4 ppg mud wellbore was static.;Remove rotating head and install trip nipple.;Pick up test joint and plug. Hang string off of bottom of test plug. Set test plug with IA open. Well static. Install TO and dart valves.;Pressure down accumulator. Remove lower rams 4" and install 4.5" solid body. Remove upper rams, 4.5" and install 2.875" X 5" vadables.;Close upper pipe ram doors, close Driller side lower pipe ram door. Replace ram shaft scraper ring, and packing back up ring retainer. Weatherford BOPE Tech assisted Rig Mechanic.;Complete repairs to Ram seal door, Run all test lines, Purge all lines preform shell test 250/4500psi Monitor well with IA valve. Well static.;Test annular upper tbop, Dart valve, mezzanine kill valve,Upper pipe rams lower loop tiw,inside kill valve,lower pipe rams Blind rams inside choke valve, kill line her valve,Manual choke and auto choke. 250/4500 5min test. Choke side her valve failed Replace with new one all other tests passed.;Hauledl bbls solids to G/I Cumulative 139bbls Hauled 129bbls fluid to G/1 Cumulative 3,136bbls OBM vertical tank 380bbl Diesel 70bbls 9/20/2018 Pressure up accumulator. Fill BOP stack with water. Test new choke HCR to 250 low 450 psi high. Good. 5 mins each test, charted.;Rig down test equipment. Install trip nipple, pull test plug, break off XO's used to hang string ;CBU. 2125 psi, 312 gpm, MW in/out 12.4 ppg. No loss l no gain. No difference in water percentage seen on bottoms up. Record slow pump rates. Monitor well. Static. Pump dryjob.;Change out saver sub. Firsttime for this crew. Lay down MPD bearing.;Trip out of the hole from 12,860'to 7212' MD. Hole fill as calculated.;Continue trip out of the hole F-7212- 682' Lay down 22 joints 41/2 drillpipe. Correct hole fill No gain or Iosses.;Break out and lay down ZXP liner running tool Dog sub was sheared confirming mechanical Release. No visible damage, Baker Rep on rig floor as tool was broken out and inspected.;Clean clear rig floor OBM, P/U TD cement head and break off pups and TO valve.;Make up test joint and plug set wear ring. Had problems installing wear ring adjusted lock down screws.;PJSM: Rig up weatherford Tongs 2 7/8 drill pipe handling tools.;Make up 3.750 Bit Xovers 41/2 casing scrapper assembly and TIH picking up 2 7/8 drill pipe from pipe racks to 465'.;HauledO bbls solids to Gil Cumulative 139bbls Hauled 129bbls fluid to Gil Cumulative 3,136bbls OBM vertical tank 371 bbl Diesel 70bbls 9/21/2018 Trip in the hole picking up 2 7/8" work string. 10.4# X-95 w/ 2 318" HT SL -1-190 connections. Pick up 83 joints total. From 480 to 2598' MD.;Make up MI Swaco Multiback 7" casing scraperw/ magnetJbrushes/scraper. and XO's. LOA=21.72 ;Trip in the hole with 4.5" CDS 40 DP. From 2598' to 3301'. Picked up 22 joints via skate that were laid down.;Trip in the hole out of the derrick from 3301' to 4013' with 4.5" CDS 40 DP.;Pick up bit sub with float & XO's . To provide back pressure if MPD is needed.;Trip in the hole out of the derrickfrom 4013'to 9452' MD with 4.5" CDS 40 DP. Good hole fill. Halliburton staged their Logging truck on the storage pad ;Continue TIH F-9457- 11476 Fill pipe and take parameters Up Wt. 135k/Ibs Dn. Wt. 154k/lbs Rt. Wt. 141 k/lbs Tq 10 rpm = 1500fvlbs 20rpm = 1700 ft/Ibs 30rpm = 2000fl Take slow pump rates. Continue TIH f-11476- 12954'Top of 41/2 liner. Parameters at 12954' Up Wt 1501dIbs Dn Wt. 152k/Ibs.;Washl rotate through the top of 4 1/2 liner, no problems liner top clear Continue TIH on elevators to 13,855' Begin washing and rotating to cleanup cement stringers 10rpm 47spm 1250psi Tq.1750 tt/Ibs Tag up at 1404T Unable to Dass. Increase pump rate to 4bbls min 2750psi setting 4k down.;Make 8 attempts varying weights and pump rates from 2.5 to 4.5 bbls min Set 3k down and hold without any movement. Torque F-2150-3125fblbs.;Circulate Btu at 14 14036' 4bbls min 70spm 2816psi Tq= 2150ft/lbs.;Hauled0 bbls solids to GA Cumulative 139bbis Hauled blots fluid to j M� u ( 7 Cumulative 3,1363312is � V l G OBM vertical tank 371 bbl w Diesel 70blols 9/22/2018 Continue to circulate surface to surface @ 14047' MD. No rubber or cement seen on Bu strokes. 2860 PP, 166 GPM, MW= 12.5 / in and out. No increase in water percentage. Running 5 BPH diesel, adding emulsifier.;Ream / Drill from 14047 to 14048'. 2780 PP, 166 GPM, 25 RPM, 2200 fulbs torque off 12500 to 3000 fibs on bottom. Torque limiter set on 5,000 ft/lbs. Maintain 2 to 5k WOB. Depth of 14047.5' pressure spike of 500 psi to 3300 psi seen, torque spike of 500 it/Ibs seen.;Pick off bottom and allow pressure to drop. Zero stroke counter.;Black rubber from wiper dart seen at shakers at bottoms up. Continue to ream / Drill on plug to 14048.5' MD. 3035 PP, 173 GPM, 310 5 K WOB, Torque 2400 tt/Ibs off / 2500 to 3000 il/los on. More and more rubber seen at shakers.;Conflnue to ream / Drill on plug and cement from 14048.5' to 14312' MD. Break free of the plug @ 14049'. Drilled cement @ 307hr. 2940 PP, 169 GPM, 5k WOB, 2500 Ill torque.;Cont. to drill cement in side 41/2 liner F-14312-14395' 20.75'hr 30rpm Tq- 2350- 2571 ftllbs. 2560-3150 psi 70spm 167gpm 4-5k/Ibs wob @ 14388 torque dropped to 2321ff/lbs penetration rate down to 1.5'-3.5'per hr. Decision made to pull bit due to hours Total footage 349' 15hm rotating 38fph avg.;Pump 20bbl hi -vis sweep at 14396167gpm 3035psi 70spm reciprocate & rotate string . Sweep returned with no increase in cuttings. Take slow pump rates, Monitor well 30 min, Static. Pump dry job.;POOH f- 14395'- 10622" Up wt 176k/lbs Dn Wt. 174k/lbs, Monitor hole fill with trip tank No Gains or Iosses.;Hauled6 bbls solids to Gil Cumulative bots r� bola Hauled 189 3,312 fluid to G/I� ren y Cumulative 3,3253312 OBM vertical tank 371 bbl 912312018 Continue to trip out of the hole for a new bit. Trip from 10,622' MD to 4671'. Stood back in derrick. Hole fill as calculated. Stood back 11,200' of CDS 40 DP. Lay down float sub assembly. (4013').;Lay down 66 joints of 4.5" CDS 40, to 7" Multiback casing scraper. Remove 2lbs of metal from magnet on assembly. Lay down. All tools safely retrieved and in good shape. ( Dragon Wagon from Rig 169 spilled 30 gallons of OBM in the Kenai Gas field while enroule across the field to the G & I plant. Rig;crew assisted in clean up. All agencies were contacted. All material cleaned up.;Rig up Weatherford power tongs and elevators to lay down 2 7/8" work string ;Lay down 60 joints of 2 7/8" 10.4# pipe. Good hole fill. SIMOPS: Rolling OBM in upright # 2. Electrician fixed camera in derrick.;POOH laying down 23jts 2 7/8 drillpipe. Break out bit, graded 3 -3 -Wt- A -B -I -BT -HR in Correct hole fill no gain or Iosses.;Sewice rig. Top Drive swivel, blocks crown and drawworks inspect drive line bolts.;Make up weatherford 3.75 mill with 3X18 jets, and 4 1/2 liner scraper RIH picking up 2 718 drill pipe from pipe racks 83jts R/D 2 718 dp handling tools continue TIH p/u 7" casing scraper then 4112 drillpipe from pipe racks 66jts total . Cont. TIH with stands F-4673- 7714'.;Hauled9 bbls solids to Gil Cumulative 154 bbls Hauled 81 bola fluid to Gil Cumulative 3,406bbls OBM vertical tank 371 blot Diesel 70bbls 9/2412018 Trip in the hole from 7776' MO to 11,492' MD. Hilcorp boiler man arrived to inspect boiler #1. Troubleshoot liner wash sensor. Pump #1. Bad wire. Fill pipe. Calculated hole fill. Record parameters. 1833 PP, 157 GPM, Flow 47%, 10RPM= 1500 ftnbs, 20 RPM= 180 flubs, 30 RPM= 1950 fUlbs.;Rotate weight-- 138k, Up weight= 138k, Down weight= 140k.;Trip in the hole from 11,492' to 12,917'. Repair MP rod wash alarm, MP#1.;Slip and cut 95 feet of drill line. Roll upright tank. #3. Off load GLM's.;12,915'. Circulate and condition mud system. MW 12.2+ on bottoms up, 63/28. Barite sag. MW in 12.45 ppg. Record parameters. 2212 PP, 170 GPM, 47% flow. 172k up. 170k dn. 10 RPM 2000 fNbs, 20 RPM 2200Ribs. 30 RPM 3400 ft/lbs, 40 RPM 2300 Ribs, 50 RPM 2500 fVlbs.;Trip in the hole out of the derrick From 12,916 to 13,974' MD Crew change.;Cont, tih f-13,974'to 14,334 Record parameters 2650pp 44%flow. 178k/Ibs up.170dn 176rt. Tq. 10rpm=2400fUlbs 20=2400fl/Ibs 30=2600ft/lbs 40=2640fibs Wash and rotate down to 14395'.;Ddll /mill cement inside 41/2 liner F-14,395' -14,592' 40rpm 2560psi Started having problems with pump stalling vary pump rate 70spm 65spm62spm 60spm 55spm, and rotary 50rpm40rpm 30rpm. adjusted bit weight F- 51dIbs 4.5 k11bs 3.5k/Ibs and 1.5k/Ibs.;Found that 30rpm 55spm 142gpm 1.5wob tq 2565 were able to drill with out stalling pumps. Drill ahead F 14,429-14,458' Drill firm cement F-14,458'-14,592' 1.8-2.8/lbs WOB Attempt to set more weight on mill PR decreased to 91ph still pumping at 555pm 1339pm 2160- 2800psi.;Confinue to drill/ Mill ahead with 30 rpm 55spm 137gpm 1.5-2.8wob 22-34fph . 2850-3500kAbs tq. Back ream after stand is drilled down at t00rpm to clean up liner. ROP 35.5 feet per hour avg.;Hauled9 bbls solids to G/I Cumulative 163 bbls Hauled 181 bbls fluid to G/I Cumulative 3,587bbis OBM vertical tank 371 bbl Diesel 70bbls 912512018 Milling cement inside 4.5" DWC/C 12.60 liner from 14,587'to 14,684'.w/ BHA #6. Set op off pressure on MP to 90% of rating. 3500 psi to 3750 psi. Able to increase SPM's from 57 to 61 and stay on bottom. TO on 2800, TQ off 2400, 45% flow 147 GPM, 2520 PP, 50 RPM.;190k up weight, 188k down weight. Attempt to drill with higher flow rale and the pump would die with the increased pump pressure generated at the mill face. Baker ZXP liner top packer shipped from the slope. Back up Hughes 3.75° mill tooth bit also shipped out today.;Milling cement inside 4.5" DWC/C 12.6# liner from 14,684'to 14,783'.w/ BHA #6.2550 PP, 147 GPM, 50 RPM, 3000 TQ on, 2450 TQ off, 1.5 to 2.2k WOB, MW in/out= 12.45 ppg. Treat mud system with 3 BPH diesel, and keep dusted up to 12.45 ppg. We brought the oil water ratio up.;from 61/39 to 65/35. Mud is stabilized. Kick while drilling drill. CRT= 100 secs. Wellbore remains static. Rolled OBM in tank 0, fixed lights in derrick. ODS. Changed lovejoy coupler in MP#1.;Drill/Mill cement inside liner F-14,789' - 14812' 2550pp,147gpm,50rpm,3000 k/lbs 1.5-2.2wob,Mw 12.5 in and out.;Service rig, Top Drive, Swivel,Blocks, Crown and Dmwworks. Inspect drive line bolts on drawworks drive.;Drill/Mill cement inside of 41/2 liner F- 14,812'-14,942 2550pp.60spm.50rpm 300f /lbs To. 1.5-2.5wob Mw.12.5 Up Wit 90k Dn.Wt 188k.Rt.Wtl 78k rop 27.8fph. Repaired and remounted lights in Derrick.;Drill/Mill Cement inside 4 1/2 liner F-14,942' 15016' 2300pp55spm.50rpm.3000-3400fl/IbsTq 1.5-2.9wob Take slow pump rates at 15,000'. ROP last 24hr5 25fph.;Pumps started to stall at 15011' Change pump rates from 60spm down to 50spm and rotary speed from 60rpm down to 50rpm every time we exceed 2500psi the pumps stall on or off bottom .Set one stand back and stabilize pump and rotary speeds while circulating a bottoms up.;Hauled9 bbls solids to GA Cumulative 163 bbls Hauled 80 bbls fluid to G/I Cumulative 3,667bb(s OBM vertical tank 371 bbl Diesel 55bbls 9/26/2018 Depth: 14985'. Circulate bottoms up with 136 GPM, 2466 PP, 50 RPM, 2800 ft/Ibs TQ, MW 12.45 ppg in/out. 41 %flow. Running two shakers, both stayed covered althe end as the cemenlwas carried out of the hole. Begin to add diesel to bring oil/water ratio back to 70/30.;Milling cement from 15016'to 15018'.w/ 136 GPM, 2466 PP, 50 RPM, 2800 ft/lbs TQ, off 3100 fl/lbs on bottom. Stalled pump out as we tagged bottom. Pick up to inspect discharge and suction screens on MP#1 & MP #2.;Check discharge and suctions screens both pumps. MP #1 suction screen 60% plugged, discharge good. MP#2 suction screen 50%, discharge good. Put pumps back logether.;Depth: 15018'.Attemptto begin milling cement with 136 GPM, 2466 PP, 50 RPM, 2600 fl/Ibs TO, off 3100 ft/lbs on bottom torque. Still stalling even with only 1k WOB. Call out Halliburton pump truck to assist in pumping.;Rack back one stand. C & C off bottom. Depth 14,985 (Unable to drill with current mud properties) Add 7.5 BPH diesel. Add 65 SXS barite/hour to maintain 12.4 ppg. Rotate and reciprocate. 2530 PP, 140 GPM, 30 RPM, TQ 2700 ft/lbs. Haul off OBM from pits 1,2,4,5,6 to G & I.;Add 7.5 BPH diesel. Add 65 SXS barite/hour to maintain 12.4 ppg. Rotate and reciprocate. 2530 PP, 140 GPM, 30 RPM, TO 2700 ft(lbs. Surface to surface strokes. able to reach 62 SPM 2685 PP without killing pump. Pick up one stand and go to bottom.;Mill ,.Q\ from15018'. to 15022' W/ 136 GPM, 2466 PP, 50 RPM, 2800 ft/lbs TQ, off 3100 ft/lbs on bottom torque. Still stalling. Halliburton on location and rigged up. Pick up off boltom.;Prejob with crew and Halliburton pump truck operators. Lineup to go downhole with cement unit. Pressure test lines to 600 psi low, 4500 psi high. r/ psi. Pump downhole with Halliburton ;Establish flowrates and pressures with Halliburton. 1 BPM 693 PSI, 2 BPM 1153 PSI, 3 BPM 1950 PSI.;Mill cement with BHA#6 inside 4.5" DWC1C 12.6 # liner from 15,022' to 15,044' MD. Pumping with Halliburton Elite pump truck, @ 4 BPM, 3159 PP, 50 RPM, 2930 TQ, 2.1 K WOB, 20'Ihr. Adding 7.5 BPH diesel, keeping MW at 12.45 in/out.;Mill Cement F-15,044-15,251' pumping with Halliburton pump truck @ 4bbls min 3150psi 50rpm 3350Tq 2 281dIbs on mill ROP= 34.5fVph Adding diesel at 7.5bbls per hr. maintaining mud weight at 12.5 in and out.;At 21:52hrs While Floorhand was working in the derrick making a connection he cut the lip off his middle finger, left hand. Toolpusher transported him to the Soldotna Hospital. Safety stand down was held withal] crew members ,Third party service hands and Toolpusher.;Mill Cement F-15,251'to 15,442.bbls mm3175pp 50rpm,3425ft/Ibs tq. 2.5-2.8k/Ibs on mill mud weight 12.5 in and out Continue to add 7.5bbls blots diesel and mix bar to maintain mud weight. For mill run at 15,440' 1045' drilled in 34hrs =30.7feet per hour ROP No gain or Iosses.;Hauled36 bbls solids to G/I Cumulative 199 bbls Hauled 324 bbls fluid to G/I Cumulative 3,991 bbls OBM vertical tank 371 bbl Diesel 167bbis 9127/2018 Mill cement with BHA#6 inside 4.5" DWC/C 12.6# liner from 15,439'to 15,485' MD. Pumping with Halliburton Elite pump truck, @4 BPM, 3115 PP, 50 RPM, 3100 Polbs TO, 2.1 K WOB, Flow 45%,12.5 ppg MW intout. 3071hr. Adding 7.5 BPH diesel.;Begin to circulate hole clean. @ 4 BPM, 2954 PP, 50 RPM, 2750 Polbs off bottomTQ. Flow 44%, 12.5 ppg MW in/out. Rotate and reciprocate. Bring RPM readings up to 100 on the up stroke, 50 RPM down. Adding 7.5 BPH diesel. 65 SXS barite per hour. Decide to drill 27 feet deeper.;Mill cement with BHA#6 inside 4.5" DWC/C 12.6# liner from 15,485'to 15,512' MD. Pumping with Halliburton Elite pump truck, @4 BPM, 3082 PP, 50 RPM, 3100 fblbs TQ, 1 K WOB, Flow 45%, 12.5 ppg MW in/out. 1071hr. Adding 7.5 BPH diesel.;Prejob with Halliburton and All American crew. Pump 20 BBL high vis pill with nut plug marker. 215 minutes for surface to surface.;Circulate hole clean. @ 4 BPM, 2983 PP, 50 RPM, 2775 ft/Ibs off bottomTQ, Flow 44%,12.45 ppg MW in/out. Rotate and reciprocate. Bring RPM readings up to 100 on the up stroke, 50 RPM down. Adding 7.5 BPH diesel. 65 SXS barite per hour.;Circulate Hi-Vis sweep out of the hole. Came up strung outwith no increase in cuttings load. OII water ratio brought up to 65/35. From 62/38.;Monitor well. .25 BPH seepage loss observed. Record SPR's 1 BPH 455 PSI / 2 BPH 843 PSI, MW 12.45 ppg iniout. Pump 20 BBL dry job 2#'s over.;POOH from 15512' MD to' 4,606'. Cleaned pits 5,6,9. Stop at 11,493 pipe started pulling wet.Shut Halliburton pump in Pump 20bbl dry job with rig pump. Continue POH . Repair Hydraulic hose on Iron roughneck.;Continue POH laying down CDS-40 41/2 drill pipe F 4606 to 2590 65jts layed down Inspect 7" casing scraper no visible damage and scraper was clean no metal. No gain or losses correct hole fill.;PJSM; Rig up weatherford 2 7/8 drill pipe handling tools and tongs.;Hauled 9 bbls solids to Gil Cumulative 208 bbls Hauled 171 bbls fluid to G/I Cumulative 4,162bbls OEM vertical tank 371 bbl Diesel 601bbls 9/28/2018 PJSM w/ Weatherford casing crew and floor hands. Lay down 83 joints of 2 7/8" 10.4# X-95 work string. Inspect and lay down casing scraper. Remove 2#'s metal from magnets. Grade mill. 3-3-WT-A-X-1-PN-TD. Cement plugged nozzle.;Rig down Weatherford tongs, clean and clear rig floor.;Remove catch can and trip nipple. Install MPD test plug to flush all MPD lines with 70 BELS soapy water.;Blow air through choke manifold, and MPD equipment / Remove MPD test plug. Halliburton Eline arrive. Spottruck.;Pick up 7" casing scraper. Break off XO's top and bottom. Driller observed off driller side blind ram rubber protruding out 2 inches. Alerted TP and CoMan. Decide to open doors and inspect elements.;Remove wear bushing. Install test plug.;Pressure down accumulator / Open both blind ram doors.. Driller side looked good. Trim loose thin rubber section above sealing face on ODS. Sealing face still 100%. Reinstall both blocks, close up doors.;Fill BOPE with water. Bleed air out, test lines. Pressure up stack. Leaky gland nut bleed pressure off. Tighten nut. Test blinds 250 psi low, 4500 psi high. charted 10 mins each. Pull test plug. Set wear bushing.;Rig up Halliburton E line equipment.;Rig up Halliburton E-line sheaves and line. Make up 3.50" OD junk basket and 3.7" OD gauge ring.;RIH with junk basket and 3.7" OD gauge ring on Haliburton E-line. Tagged up at 12,964' WLM attempt to work through top of 4 1/2" liner with no success . Drill pipe measurement is 12,954' POOH with Gauge nng.;Removed Junk basket then added a 3.7" OD centralizer to Gauge ring assembly. RIH passed through 41/2" liner top at 12,965' WLM. Continued to RIH and tagged up at 15,513' WLM .POH and lay down Gauge ring tools.;Make up logging suite with CCL,GR, Centralizer, HCBLM, Centralizer, Hal-cast-M-Electronic and M-31/8" Scan tools . RIH on Halliburton E-line to 4050' run Diagnostic check on M-3112 spinner tool. POH and lay logging assembly.;Make up new logging suite with back up M-3 1/8" spinner tool. Calibrate string. and set on rig floor. SIMOPS: Changed out 3 liners and swabs on #2 mud pump also processed 86bbls of OBM.;RIH with CBL suite CCL,GR,Cent,HCBLM, Cent, Hal- cast-M electronic and M-3 Scanner/ spinner to preform CBL.;Hauled 29 bbls solids to G/1 Cumulative 237 bbls Hauled 410 bbis fluid to Gil Cumulative 4,572bbls OBM vertical tank 1-. 751obl Diesel 176bbls;OBM vertical tank 2. 134bbts Diesel /LVT vertical 176bbls �✓ G Daily metal 0 cumulative 182lbs 9/29/2018 RIH with CBL suite CCL GR,Cent HCBLM, Cent, Hal-cast-M electronic and M-3 Scanner/ spinner to preform CBL. From 7800' MD to 15,012'. Begin logging Dn @ 9,300 to 15,490.;Log pulling out from 15,490'to 12,900'w/ CBL suite CCL,GR,Cent,HCBLM, Cent, Hal-cast-M electronic and M-3 Scanner/ spinner to preform CBL. TOC=14805'.;POOH with logging tools from 12,900'to surface. W/ CCL,GR,Cent,HCBLM, Cent, Hal-cast-M electronic and M-3 Scanner/ spinner tool string.;Lay down Halliburton logging tools. Rig down sheaves, rig down Eline truck. Release wireline crew.;Clean up OBM on rig floor / Change out liners in MP#1 from 5" to 4.5".;Load 20 joints at a time on catwalk. 4.5" CDS 40 DP. Strap and pick up Baker "TBR" Dress and polish mill, 5.17" OD Polish mill. 5.96" OD Top dress mill assembly. 17.75', and XO 1.36to DP.;P/U singles on 4.5' DP off catwalk. 65 total. Place float sub on top of joint #52.;Continue TIH F- 2,191' with stands from derrick,stop at 6,501' , 10572 Enter 7" liner top at 11,531' and reduce running speed to 12940' Establish UP/Dn/Wt/ 172/172/170/ pp=305 psi 47 spm tq=2825 ft/lbs Run Dress/Polish mill assembly and no go at 12967.;Work mill 4 X times at 30rpm 47spm 305psi 2800 ft/lbs torque clean up PBR liner top packer.;Pull up to 12960' pump 20 bbl hi-vis sweep at 104spm 1300psi 251 gpm Mud weight 12.5 in and out vis 95. Mix 20bbl 14.5ppg dry joh ;Hauled 116 bbls solids to Gil Cumulative 353 bbls Hauled 284 bbls fluid to Gil Cumulative 4,856 bbls OBM vertical tank 1-. 150bb1 Diesel 160bbIs;OBM vertical tank 2. 134bbis Diesel /1-VT vertical 150bbls Daily metal 0 9/30/2018 In hole with BHA#7 @ ZXP linger top packer W/ Baker Polish mill. 12954'. Circulate and condition. Circulate Hi-Vis sweep out of the hole. 1276 PP, 250 GPM, 12.5 ppg MW in/out, 60%flow.;Monitor well. Well static. Pump dry job. 2# lbs over. Pump 18 bbls.;Dropped 2.25" drift with wireline on bottom. POOH from 12954'to 8898. Did not take proper fill on last 5. Driller alerted CoMan. Monitor well. measure well flowing .522 BPH, 22 mins later tapering off, flowing .17 BPH. Dry job falling. Did see a 5k over Pull @ 11805 inside 7".;Continue to trip from 8898'to 2008'. Proper hole fill. Changed out inner air filter on floor motor.;Lay down singles from 2008' MD to 1699'. UD 4.5" CDS 40. Calculated displacement-74.52 BELS. Actual 82.75 BBLS. 8.23 BBLS over displacement.;Cont. laying down singles F- 1699'to Baker 5.17 Dress/Polish mill. Inspect no go collar saw good indication that it contacted top of Baker 4 1/2 ZXP. packer. at 12,967' Lay mill down Float sub and X-overs.;Service rig, Top Drive, Blocks and Crown. Inspect Drawworks dive line bolts and Brake linkage. Open up T/D grabber box and inspect quill 8 saver sub.;Make up Baker Liner Top Isolation Packer RIH picking up 65jts CDS40 drill pipe to 2150' continue TIH F- 2150 - 11,360' ' with stands from derrick, filling pipe every 4000' Clean pits 4,5,6,and 9 while TIH No gain or loss pipe displacement correct.;Hauled 0 bbls solids to Gil Cumulative 353 bbls Hauled 0 bbls fluid to Gil Cumulative 4,856 bbls OBM vertical tank 1-. 150bb1 Diesel 150bbls Trip in the hole from 11200 to 12913' MD. With Baker liner 'o' o isolation acker: Record parameters. Comedown to 12954'. With MP #1, 47 SPM /435 psi. 31% Flow, 94 GPM, P/U 176rc, SI 68 , AOM / 881 PSI, With 415PM slack off until seals entered TOL. See pressure increase. Shut off pump bleed off, leave bleeder open.;Slack off to NO GO, Mark pipe, set down 25K, mark pipe, P/U to 170K, mark pipe. Broke off TD, drop 7/8" steel ball. (8:52). Wait until 09:30, pump 335 strokes and pump ball on seat.;Bleed off pressure. Set down to 25k mark. Pressure up to 1325 PSI with MP#1, switch to test pump and bring pressure up to 3700 PSI. Set Packer. Bled off pressure, P/U to 2' above up weight. Line up to test backside.;With test pump, pump in IA, bring pressure to 1000 PSI, chart for 10 mins, Good. Bled off pressure. Picker up 5.5' to expose dog sub. Set 10k down to confirm set. Good. Lay down working joint, Not in string.;Rack back one stand. Line up to pump down both sides. Pressure up to 1000 PSI with test pump. Hold for 10 mins. Good. Pumped 5 bbls of water. Bled off pressure, open UPR's, rig down test equipment.;Circulate 1000 strokes to balance mud. 12.6 ppg out, 12.5 ppg in. 1093 PP, 164 GPM.;Slip and cut drilling line. 226 feet. Monitor well on trip tank. Well static.;Break circulation and pump 18 bbl dry job 2#'s over.;Trip out of the hole standing back CDS 40 DP. From 12850' MD to 8574' MD. Proper hole fill.;Continue pooh F- 8574' -2150' Lay down 65 jts. of 41/2 CDS-40 Drill pipe. Break down the baker running tool with dog sub shifted, lay down same.;Clean / clear rig floor. PJSM: Rig up Weatherford 2 7/8 Drill Pipe handling tools and tongs.;Make up testjoint pull wear ring.;TIH with mule shoe/Bk sub and Pick up 84 jts of 2 7/8 drill pipe from pipe racks to 2615' TIH P/U 251ts out of 65jts 4 1/2 drill pipe from pipe racks to 3394'.;Hauled 25 bbls solids to G/I Cumulative 378 bbls Hauled 225 bbls fluid to GA Cumulative 5,081 bbls DBM vertical tank 1-. 233bbl Diesel 150bbIs;OBM vertical tank 2.Obbls Diesel /LVT vertical 198bbls Daily metal cumulative 182lbs Hilcorp Energy Company Composite Report Well Name: BCU-05RD2 Field: Beaver Creek Unit County/State: Kenai, Alaska i (LAT/LONG): Pumped at 182 gpm-2089 psi with no issues. Shut down pump.,Cont TIH from 13,649'to 15,510' and MU topdrive.,Broke circ with #1 pump, up to 130 gpm-3 evation (RKB): 18 API #: 50-133-20262-02-00 Spud Date: Job Name: 1810833C BCU-05RD2 Completion Contractor AFE #: AFE $: 44vity Date 90—S, 10/2/2018 Continue to pick up single in 40 more jnts CDS-40 from 3394' to 4603' (65 total jnts PU). Clean and clea rig floor, removed thread protectors.,Cont TIH from derrick, from 4603' to 13,649', no issue entering 7" or 4 12" liner tops -MU topdrive and fill pipe. Ran pump #1 (4 1/2" liners) to ensure we could circulate. Pumped at 182 gpm-2089 psi with no issues. Shut down pump.,Cont TIH from 13,649'to 15,510' and MU topdrive.,Broke circ with #1 pump, up to 130 gpm-3 bpm -2080 psi, then swapped to #2 pump (5" liners) and cont circ at 179 gpm-4.2 bpm -3102 psi. Balance Mud weight 12.4 in and out. Condition and shear mud for Casing/Linertest.,Rig up and test Casing /Liner to 500psi,1000,1500,2000 ,2500psi and 3000psi Hold final test at 3500psi for 30 min. 210 psi pressure loss over 30min. Bleed off pressure slowly Volume pumped 24bbls to obtain 3500psi 24bbls bled back.,Circulate and centrifuge 12.4ppg mud at 74spm 2705psi I 80gpm Feed centrifuge at 3.5bbls min adding IObbls of diesel per hour to active system. Mud weight cut from Centrifuge to 9.2 returning to active system. On first bottoms up Mud wt. out=12.2ppg Mud Wt. in 11.5ppg.,Hauled 18 bbls solids to G/I Cumulative 396 bbls Hauled 72 bbls fluid to Gfl Cumulative 5,153 bbls OBM vertical tank 1-369 bbls Diesel 0 bbls,OBM vertical tank 2. 386bbls Diesel /LVF vertical 0 bbls Daily metal 0 Cumulative 1821bs Total 313 Bbls sent to Weaver Brothers 10/32018 Cont circulating well at 180 gpm-2750 psi, MW in = 11.7 ppg, MW out = 12.1 ppg. Adding diesel at 10 bph, running centrifuge to cut MW. Feed rate at 3 bpm. Gave AOGCC 24 hour notice for upcoming BOP test on 10/4/18. Received 10,000 gals diesel for displacement.,Cont circulating well at 180 gpm-2211 psi, MW in = 9.6 ppg, MW out = 10.1 ppg. Adding diesel at 10 bph, running centrifuge to cut MW. Feed rate at 4 bpm. Received 10,000 gals diesel for displacement.,Cont circulating well at 180 gpm-1899 psi, MW in = 9.2 ppg, MW out= 9.6 ppg. Adding diesel at 10 bph, running centrifuge to cut MW. Received the last 5,000 gals diesel for displacement. Prep to displace well to diesel.,Pump pits 3 & 7 to uprights prior to displacing. Pump 40 bbl Hi -Vis spacer pill followed by 30 bbls of diesel with # 1 mud pump to flush out. Switch to # 2mp and begin displacement of well at 6 bbls min, 99 stks 3096 psi. Pressure built up to 3250 psi switch to # 1 mud pump at 96 spm-2944psi, 4.7bbl min.,Cont. displacement with # 1 mud pump 96 spm 2944 psi 4.7bb1 min, bleeder leaking on #1 pump, switch back to # 2 mud pump and increase pump rate up to 100 spm 5.7 bbls min 2825psi.,Confinue displacement until a total of 970bbis of 6.9 diesel pumped and 847 of 9.5mud displaced. Shut down transfer 9.2 mud from pits to tank farm. Monitor well for 1.5 hours No flow, well static while transferring mud to tank farm.,Attempt to poh, Diesel was u tubing up the drill pipe. Circulate a Drill pipe to balance. then pumped a kcl dry job. Break out top drive with the drill pipe in a vacuum. POOH F- 15510 -14930'. Flow started coming up the drill pipe, with the back side dropping close in the drill pipe and the well started flowing on the back side. Preform flow check with vis cup well flowing at 22bbls per hr.,Shut well with annular and monitor casing pressure build up. Pressure built up to 403 psi in 10 min. at 0600hrs.,Hauled 215 bbls solids to G/I Cumulative 611 bbls Hauled 165 bbls fluid to G/I Cumulative 5,318 bola OBM Tiger tank 1- 294 bbls Diesel 89 bbls,OBM vertical tank 2. 386bbls Diesel /LVT vertical 0 bbls Daily metal Cumulative 1821bs Total 313 Bbls sent to Weaver Brothers 101412018 Cont monitoring wellbore pressure with annular closed. 403 psi at 06:00, muleshoe 582' off bottom. After discussing with town, decision made to reverse circ to see what we have at bottoms up. Pressure at 2939 psi at 08:00 (shut in 2 hours).,Bled off well through choke manifold well continues to flow at 22 boh broke off topdrive, good amount of backflow up DP, stabbed TIW with headpin and closed same, MU swing and 2" HP hose to bleeder line (tied in to flow line). Lined up on pump #1 (41/2" liners), closed upper rams, start reverse circ at pump idle, 2.2 bpm-460 psi. 5 min into circ, the 4" valve on pump #2 leaking through grease zirt. Shut down pump #1.,Changed out 4" valve on #2 pump.,Resume reverse circ with #1 pump, 2.2 bpm-356 psi, flow show 24%. Pump pressure slowly increased to 835 psi as we neared bottoms up at 3398 strokes, and seeing water in returns. Bottoms up strokes = 3959. ES dropped from 270 to 6. MW increased from 6.7 ppg to 8.1 ppg and we started overboard returns to cuttings box. Pump pressure maxed out at 987 psi then started to drop. Saw some flow show increase from 25% to 30%at,times, likely small amount of gas with the water. Had 15 bbl gain over 1.5 hours circ, prior to overboard returns. At 4400 strokes we saw 8.3 ppg then started to drop back down. By 5098 strokes saw 6.9 ppg and taking returns back to pits. Dumped a total 73 bbis water. Cont to circ while discussing with Drilling Manager. FCP at 2.2 bpm-813 psi, 27% flow. Decision made to perform pressure test on casing.,Shut down pump, closed TIW, RU test pump in Will line, opened up choke line to choke manifold, lined up on pump #1 to kill line. Start pump and brought pressure up to 3200 psi on wellbore, shut down pump and shut in kill line. Monitored pressure at choke manifold, recording every 5 minutes. Lost 200 psi over 30 minutes. Notified town. Decision made to increase test pressure and repeat test.,Using test pump, brought pressure up to 3325 and shut down. Monitored pressure at choke manifold, recording every 5 minutes. Lost 75 psi over 30 minutes. Noted Drilling Manager.,Bled off wellbore through choke manifold. Flow holding steady at 22 bph. RD test pump hoses and blew down.,Closed ' oWke line, lined up TIW to resume reverse circ, 165 gpm-1260 psi. At bottoms up, 3959 strokes, dumped another 13 bbls water. Discussed with Drilling Manager, decision made to displace well back to OBM and kill water flow. Shut down pump, closed TIW, RD circ hose and head pin. MU topdrive on TIW and opened TIW. Notified AOGCC Reps Jim Regg and Jeff Jones via e-mail of well flow issue.,Resumed circulating the long way, start building hi-vis spacer in pill pit, transferred excess diesel into tank farm, transferred OBM into pits for displacement. 169 gpm-688 psi, 40% flow.,Com transferring fluids for displacement and building spacer, 177 gpm-1089 psi, 41%flow. Held PJSM with Mud Engineer and rig team for displacement.,Displace well to 9.3 ppg OBM at 212 gpm-714 psi ICP, 48% flow. Continue circulating Spacer returned as caculated 17,470stks continue circ. and balance mud weight 9.1 in and out At 17,495stks 1009 bbis displaced Mw 9.1 in and out. Shut down pump and monitor flow. Well flowing at a rate of 30-35bbis per hour.,Continue to circulate and increase mud weight from 9.1-9.5 at 104stks 247gpm 2834psi. Mud weight 9.5 in and out. Shutdown pump preform a flow check, Well flowing at 30bbls per with 9.5Mw.,Confinue to circulate at 102spm 5.8bbls min. 2881 psi Increase mud weight F-9.5 to 10.ppg . shutdown pumps and flow check well, flow at 22bbls with Drill pipe in a vacuum.,RIH F- 14,931 to 15484' No flow, well static.,Circulate and balance mud weight at 94stk 227gpm 2974psi at 15487'.,Hauled 4 bbls solids to G/I Cumulative 615 bbis Hauled 86 bbls fluid to Gil ¢.,r Cumulative 5,404 bbis OBM Tiger tank 1-102 bbis Diesel Frac Tank 465 bbls,Diesel vertical tank 2. 386bbts Diesel verticalt 386 bbis Daily metal 0 10/5120118 Cont circulating and dusting up surface volume unfit 10 ppg in/out. 226 gpm-2960 psi. Mule shoe at 15,487'. With good 10.0 ppg in/out shut down and flow checked well. Flow holding steady at 5 bph. Discussed with Drilling Manager, decision made to pull up hole and spotweighted cap.,Flow still at 5 bph, pulled up hole from 15,487'to 12,685' inside 7" liner. Up wt 200K. Stopped at 12,685' and flow check. Still steady 5 bph. At this point, calculated hole fill = 21.3 bbls, actual hole fill = 5.3 bbls. During trip transferred 50 bbls OBM into pit 9 to build weighted cap.,Cont pulling up hole from 12,685 to 11,459' inside 9 518" casing. Up wt 160K. Calculated hole fill for this portion = 9.8 bbis, actual hole fill = 3 bbls. Flow check at 11,459' still steady 5 bph. MU topdrive.,Circulated at 220 gpm-1809 psi while finish building 50 bbl hi-vis weighted cap. Held PJSM with Mud Engineer and rig team on spotting cap.,Pumped 50 bbis 13 ppg/135 vis pill then chased with 122 bbls 10.0 ppg OBM, leaving 10 bbls weighted cap inside drill string, to balance out while RU test plug. Broke off topdrive. Well still flowing 5 bph. 50 bbis would give us+/- 934' of coverage around 41/2" DP inside 9 518" casing, 683' coverage with no DP.,MU XO's, test plug and 4 1/2" test joint, RU test pump hoses and chart recorder. Well flowing at 5 bph.,Land test plug, install hose on annulus to pits to monitor flow during testing BOPE. Shell test stack against blind rams at 250/4500. Good shell test. Notified AOGCC Rep. Witness waived by Jeff Jones at 19:20 hrs. Well flowing at 7bbls per hr. Perform flow measurements every hour. Total safety calibrated tested LEL H2s and alarm system all passed. Test Pason PVT and Flow system all passed.,Test BOP 25014500psi with a 10min hold high and low. Test variable with 41/2 drill pipe Test blind rams, upper ibop, manual valve, Choke manifold , Kill and choke HCR valves and manuals choke and kill side. Test mezzanine kill line valve. Test annular with 4 1/2 drill pipe 250/2500 10min hold Mix 50 bbl 15ppg hi vis mud cap while testing BOP .,Attempted to test 2 7/8 pipe with upper variable pipe rams, test failed Troubleshoot problem. Test plug seal failed . Remove test plug and replace seal and set in well head.,Hauled 12 bbis solids to Gil Cumulative 627 bbis Hauled 158 fluid to Gil Cumulative 5,562 bbls OBM Tiger tank 1- 94 bbis Diesel Frac Tank 465 bble,Diesel vertical tank 2.382bbls Diesel verticals 382 bbis Daily metal 0 Cumulative 182 the Total 313 Bbls sent to Weaver Brothers 1016/2018 Flood stack and function rams/bag to purge any air from cavities. Test upper rams on 2 7/8" jnt at 250/4500 psi for 10 min each. Test annular on 2 7/8" jnt at 250/2500 psi for 10 min each. Test auto and manual chokes. Perform drawdown test. 2 faillpass tests, 14 hour test fime.,RD test equipment, blow down choke line and manifold. Stab 41/2" test joint and MU in test plug. Pull test plug to floor, break off and LD same. Well flowing at 7 bph.,MU topdrive and CBU at 205 gpm-1765 psi. Pressure slowly increased to 1882 psi closer to bottoms up we got. Did not see any significant amount of water returns. Did not overboard any mud/water. Bottoms up strokes = 11,169, shut down pump at 11,902 strokes and flow check at 21 bph. Pumped water from bottom of diesel upright tank into cuttings box, for diesel re -use Iater.,Line up and pump 70 bbls 15 ppg/242 vis pill, then chased with 10 ppg OBM 2500 strokes and shut down. Well flowing at 10 bph.,POOH from 11,459' to 8055'. Up wt 145K. Flow check at 9591' = 10 bph. Calculated hole fill to 8055' = 27.6 bbls, actual hole fill = 13.4 bbls. Received 3 ISO's of OBM from Weaver Bros yard.,Cont POOH from 8055'to 2636' Pipe came wet at 5265' Pump 10bbls 11.0ppg dry job. Calculated hole fill to 2636. 35.9bbls actual=24.7bbls Flow check at 2636' well flowing at 5bbls per hour.,PJSM: Rig up weathertord 2 7/8 drill pipe handling tools Slips, elevator and tongs.,Service rig inspect and adjust brakes and lube drawworks.,POH laying down 84jts of 2 7/8 SLh-90 Drill pipe F-2,636'to surface, take a flow check, well flowing at 5bbls per hour Total hole fill F 11,459 -surface Calculated 84.1 bbls actual 35.2 bbls = gain in hole of 49.9bbls.,Clean clear rig floor and rig down weathertord 2 7/8 drill pipe handling tools Well flowing at Shiba per hour.,TIH with 4 1/2 Drill Pipe open ended to 6856 Calculated pipe displacement to 6865 45.1 bbls actual 65.5bbls= 20bbl gain in 4 him of tripping. Well flowing at 5bbls per hr..,Hauled 4 bbls solids to G/I Cumulative 631 bbls Hauled 86 fluid to G/1 Cumulative 5,648 bbls OBM Tiger tank 1- 94 bbls Diesel Frac Tank 465 bbls,Diesel vertical tank 2. 336bbis Diesel verticall 382 bbls Daily metal 0 Cumulative 182 lbs Rec'd 303bbic OBM from Weaver Brothers 10/7/2018 Cont TIH with 41/2" DP from 6856to 11,446' and parked drill string 85' above 7" liner top. Flow rate at 7 bph. MU TIW and pump in sub on stump, MU 2" hose to bleeder Iine.,Clear and prep catwalk for a -line work, clean and clear rig floor, Halliburton a -line on location at 10:00. Held PJSM, RU tool string on catwalk, RU sheaves and packoff, function tested tool.,RIH on a -line through the 41/2" DP with 30'tool string, consisting of through tubing telemetry cartridge, TMD3D tool, production gamma ray, collar locator, capacitance temperature flow and caged full bore spinner to 14,820'.,Start logging up hole from 14,820' to 14,400'. Clean throughout the rig, build new weighted mud cap in pit 10 at 15 ppg.,Cont logging up hole from 14,400' to 11,500' Run in hole to 15,450' and log up to 11,500 taking flow surveys Well continues to flow at 71bbls per hour. Crew working on cleaning rig and mixing 15ppg mud cap pill.,Hauled 4 bbls solids to G/I Cumulative 635 bbls Hauled 266 fluid to G/I Cumulative b OBM Tiger tank bbls ank 1 1-944 Diesel Frac Tank 336 bbls,OBM vertical tank 2. 151 bbis OBM verticall 336 bbls Ll Daily metal 0 Cumulative 182 lbs 10/82018 Pulled Halliburton TMD3D tool on a -line into drill string at 11,446' and POOH. RD release Halliburton loggers. Sent logdata to town.,Cut and slipped 95' drill Iine.,Sewiced rig, topdrive, iron roughneck. Cleaned in cellar area and pits area while waiting on orders.,Reverse circulated at 206 gpm-900 psi to condition mud for POOH. Dumped a total of 255 bbls water and contaminated OBM unfit decent enough to take returns back to pits.,Transfer 50bbls contaminated OBM to tank farm. Pump 70bbl 15ppg Hi -Vis mud cap pill at 209 gpm 670 psi.,POOH F-11,446 -10,019 Pipe started coming wet. Pump 10bbl 15ppg dry job. continue POH F-10,019-2,028' POH L/D 65jts of 41/2 Drill Pipe. Hole fill calculated 74.8 Actual 32.7 42 blots Well flowing at 7bbls per hr.,Clear and clean rig floor OBM.,Hauled 8 bbls solids to G/I Cumulative 643 bbls Hauled 332 fluid to GA Cumulative 6,246 bbls OBM Tiger tank 1- 94 bbls Diesel Frac Tank 465 bbls,OBM vertical tank 1. 336bbis OBM vertical tank 2 158bbls. Diesel UR 1 272bbls 10/92018 Cleaned up rig floor after POOH. Halliburton a -line on location at 07:00, spotted truck, PJSM, RU sheaves, built CIBP run tool on catwalk. Shut in well to monitor pressure build and hold back un -necessary water influx while waiting on procedure and approval to start remediation of 4 W liner leak. C/O #1 charge pump in hopper room #1, transferred excess 10.1 ppg mud inlo,tank farm, transferred 94 bbls 9.0 ppg mud into pits 9-10 a blend with left over 15 ppg mud. Start building 230 bbls 12.0 ppg mud to chase squeeze cement with later. Received approval from BUM and ACGCC just after 14:00 hrs. Pressure on wellbore built to 1270 psi and holding the last 1.5 hrs. Bled off wellbore.,RIH in hole with 4 W' CIBP at 150 ft/min. Correlated depth and set CIBP at 13,020' WLM. S/O and verified plug set, PU and saw 100 lbs less wire weight. POOH. Had no change in flow after setting plug. Still steady 7 bph.,MU 3' x 6 spf zero phased gun, RIH, at 250fpm. Correlate Depth and perforate f-13,015-13,018 WLM Surface indication guns fired. POH and L/D spent guns. No change in flow rate after guns fired. Well still flowing at 7bbls per hour,M/U Halliburton 5.5 EZ drill retainer on E -Line RIH at 150fpm reduce rate to 50fpm entering 7" liner at 11,531' Correlated depth to ccl and gamma ray logs Set at 1291 O' WLM. Saw line tension drop and well stopped flowing. POOH lay down retainer setting tools RID Halliburton sheaves, line and truck.,Make up Halliburton EZ drill stinger assembly and rih picking up 65JTS OF 41/2 DP.from pipe racks to 2015' Continue TIH f-2015 with stands to 10,907' Monitor well Static. Continue to mix mud and increase Mw. from 10.2 to 12ppg while TIH Calculated hole fill 71.75bbis actual 73.4bbls to 10,888'.,Stop TIH and adjust Drawworks Brakes.,Hauled 3 bbls solids to GA Cumulative 646 bbls Hauled 57 fluid to G/I Cumulative 6,303 bbls OBM Tiger tank 1- 14 bbls Diesel Frac Tank 465 bbls,OBM vertical tank 1. 280bbls OBM vertical tank 2 326bbls. Diesel UR 1 272bbls Diesel UR 2 285bbls 10/10/2018 Cont to TIH with cement retainer stinger on 4 1/2" DP from 10,907'to 12,844' and parked drill string 66' above cement retainer, in the T' liner. Cont to transfer excess OSM out to tank farm.,MU topdrive and circulate/condition mud at 213 gpm-790 psi, adding diesel at 15 bph and maintaining MW at 10.1 ppg. Trying to get oil/water ratio back up from 50/50%. Did not dump any mud at bottoms up. Halliburton cement retainer rep on location at 10:30, cementers on location at 11:00.,Shut down pump and opened bleeder for slack off and sting into retainer. PU single, MU topdrive with bleeder open and S/O to 12,907' with no sign of retainer set at 12,910' WLM. Dwn wt 172K, up wt 176K. PU 10' pup, MU topdrive with bleeder open, S/O and engaged retainer at 12,911' DPM. Once we stung in, flow at flow line was up and down, 3 bph, 5 bph, no flow then 7 bph.,Cont to S/O and set 30K down on retainer as per Halliburton Rep. Still seeing 7 bph flow through bleeder. Marked pipe at 12,911' and with 30K set down, pulled up hole slow closing retainer valve and un -stung. Flow dropped to 0 bph. Broke of 10' jnt and MU topdrive on stdng.,Cont to circ/cond mud at 12,879'. 206 gpm-919 psi with good 10.1 ppg in hole. Started building 40 bbls 12.5 ppg weighted spacer as per Halliburton cementers, in clean pit #6. Cont treating active system with diesel and barite. RU Halliburton hardline to rig floor, manifold and cleanup hose to cuttings box.,With weighted spacer built, held PJSM with rig crew, cementers, retainer hand and Peak crew on cement squeeze.,Shut down pump, MU 10' pup on drill string, MU valve and hardline to pump in sub on stump. MU TIW (closed) on top of pump in sub, MU topdrive on TIW and closed lower IBOP valve. Halliburton fluid packed hardline and manifold to cuttings box to verify clear lines. Pressure tested lines at 1200 psi low/7500 psi high, good tests. Closed annular to hold back pressure.,Halliburton pumped 10 bbls 12.5 ppg spacer at 2 bpm, followed with 30 bbis (150 sx) 15.8 ppg cement at 3 bpm -2160 psi while we held +I- 1200 to 2200 psi back pressure with auto choke. Followed cement with another 10 bbls 12.5 ppg spacer at 3 bpm -2010 psi, 2200 psi back pressure. Halliburton displaced with 12.0 ppg OBM from 4 to 5.5 bpm -2582 to 2300 psi, holding 2150 psi back pressure.,W ith 10 bbis to go slowed to 2 bpm -859 psi. Shut down Halliburton pump with 188 bbls pumped, putting the first 5 of 10 bbl spacer outside OR Fully closed the choke. Slacked off on drill string and engaged retainer at 12,911'. Cont to S/O and set down 30K. Halliburton pump pressure at 539 psi. Bled off backpressure to 0 psi and opened annular. Halliburton began pumping/squeezing at 2 bpm.,W ith 10 bbls away 4100 psi, 15 bbls away 4440 psi, 22 bbis away 4780 psi, (pump rate at 1.5 bpm) 25 bbls away 4880 psi, 27 bbls away 4920 psi (opened choke and prep to close bag), 28 bbls away 4950 psi, 29 bbis away 4975 psi, 30 bbls away 5000 psi, 31 bbis away 5030 psi, 32 bbis away 5040 psi, 33 bbls away 5040 psi and shut down (28 bbis cement through retainer) closed bag. About this time Peak lead twisted ankle in pits.,Pump pressure dropped from 5040 psi to 4738 psi. Pulled drill string up hole and un -stung from retainer, saw pressure dump from 4738 to 0 psi at pump truck. Broke off hardline from closed valve on pump in sub, cracked open valve and drill string on vac (12.0 ppg mud in drill string, 10.1 on backside). CIP at 19:10 on 10-10-18. Removed valve from pump in sub, broke off 10' pup from drill string and staged in mousehole.,Opened bag, closed choke HCR. Pulled up hole from 12,907', up wt 176K. Pulled 5 stands and parked at 12,586'.,Inserted wiper ball in drill string, MU topdrive, start circ at 260 gpm- 1332 psi. Continue to circulate and balance mud weight 10.1 in and out. No trace of cement returned over shakers on bottoms up.,Monitor well for 30 min. well static no flow. PIU Pup/ cement head break out tiw and side entry sub. Blow down choke lines Pump dry job.,POH F- 12,586' to 5596' No gain or losses Hole fill as calculated.,Hauled 0 bbls solids to G/I Cumulative 646 bbls Hauled 30 fluid to G/I Cumulative 6,333 bbls OBM Tiger tank 1- 252 bbis Diesel Frac Tank 465 bbls,OBM vertical tank 1. 280bbls 10/11/2018 Cont POOH with 7" cement retainer stinger assembly, from 5596'to 709.,Cont POOH LO 22 jnts 4 1/2" OF, XO and retainer stinger. Stinger in good shape.,Clean rig floor, remove stinger from floor, staged new bit, bit sub and float.,MU 5 7/8" MX -1 mill tooth bit, bit sub with float and start TIH picking up 22 singles DP previously LD, to 700'. Cont TIH with stands filling pipe every 2500'. Had Asset Team Leader, Reservoir Engineer and Beaver Creek Production Foreman on location for rig tour. Stopped at 7442' and filled pipe.,Cont TIH from 7442'to 9923' Correct pipe displacement.,At 992T Slip and cut 78' of drilling line. Tighten up drive line bolts. Fill pipe.,F- 9923-12,592' Fill pipe Wash down F-12,592 to 12,912' Saw no trace of cement. washing Down Tag up on retainer at 12,912'.,Drill retainer F-12912'to 12913.5' Pump at 1609pm 758psi Rot. 75rpn 2875tq 1-2k on bit for the first 10inches Increase bit weight from 2.5k tp to 16k Vary pump rates 160 gpm to 228gpm rotary 75 to 100rpm Torque between 2875 klb/ fp to 6100 kib/fp Pickup and clear bit and reset pattern.Did see Trace of cement after we drilled into the Retainer.,Hauled 0 bbls solids to G/I Cumulative 646 bbis Hauled 90bbls fluid to GA Cumulative 6,423 bbis OBM Tiger tank 1- 313 bbls Diesel Frac Tank 465 bbls,OBM vertical tank 1.280bbls OBM vertical tank 2 378bbis. Diesel URI 272bbis Diesel UR 2 336 bbls 10/12/2018 Continued to drill on cement retainer in T' liner, at 12,914'. WOB 12K, 112 gpm-370 psi, 77 rpm -3700 to 6000 ft/lbs on bott torque, alternating parameters. Shaker hand catching rubber chunks and seeing brass on shaker, but started seeing coal chips. Captured V4 cup of coal chips, PU off bottom and notified town.,Pumped sweep around at 235 gpm-934 psi, 100 rpm -2520 ft/lbs off bott torque. At bottoms up had a good amount of rubber, coal chips pretty much disappeared before getting bottoms up, Cleaned ditch magnets prior to bottoms up, nothing out of ordinary on those after bottoms up. After bottoms up shut down and did 15 minute flow check. No flow -Resumed drilling on retainer alternating bit weight, pump rate and rpm's. For most part 12 to 20K wob, 113 gpm-360 psi, 45 rpm -1800 to 6600 f llbs on bott torque. At 14:00 hrs we punched through retainer at 12,916'.,W fth bit weight at 12K, rpm at 80 and pump rate at 196 gpm, drilled cement down to 12,940' with no sign of liner top (PBR has 5.25" ID, bit has 5 7/8" OD). Notified Drilling Manger, decision made to ease down and find liner top. Cant drilling cement down to 12,946with 1-2K on bit. At 12,946', bit weight suddenly increased to SK and would not drill off. Marked pipe, PU 5', S/O to mark and saw bit weight increase to,1 K with no drill off. Calling liner top packer top at 12,946'. Did not see any more coal on shaker.,Started another sweep around. 220 gpm-838 psi, 100 rpm -3000 fl/Ibs off bott torque wit bit at 12,944'. C32 gen set lost a bele and died. Swapped over to "GO" gen set for topdrive. Shut down pump for flow check.,Monitor well for flow, staged Weatherford tongs on rig floor for 2 7/8" PU later. No flow.,Take slow pump rates at 12,942 Md # 1 MP. 47stks = 281 psi #2 MP 57stks = 460psi Monitor well for 30min. no flow. Pump out of the hole F- 12 940' -12,799' POH on elevators to 11,531' 7' liner top. Up Wt. 180 knbs On Wt. 178k/lbs,Circulate 20bbi weighted Hi -Vis sweep at 99spm 240gpm 719psi t00rpm saw a 15% increase in material over the shakers some rubber and cement sand. Inspected magnets 2/3# metal recovered.,POH F-11531'to 348N Hale fill calculated 51.15 Actual 56.4 No gain or Iosses.,Hauled 0 bbls solids to G4 Cumulative 646 bbls Hauled 170 bbis fluid to G/I Cumulative 6,593 bbis OBM Tiger tank 1- 313 bbls Diesel Frac Tank 465 bbls,OBM vertical tank 1. 280 bbls OBM vertical tank 2 378 bbls. Diesel URI 384 bbls Diesel UR 2 368 bbls 10/13/2018 Continued to POOH with 7" retainer drill out assembly from 3484'to surface. LD bit sub and tri -cone. Bit graded at 1 -1 -WT-A-E-1-RR-BHA.,Clean rig floor, hung Weatherford tongs, RU 2 7/8" handling equipment, held PJSM with rig crew and Weatherford crew.,MU 3.75" STX-3 tri -cone with no jets, two x 3 1/2" OD junk baskets, bit sub and XO. PU and singled in hole with total 84 jnts 2 7/8" workstring to 2625'. Up wt 46K, dwn wt 46K.,RD Weatherford tongs and change handling equipment over to 4 12".,MU XO, start TIH on 41 /2" DP from derrick, from 2625' to 7461'. Up wt 100K, dwn wt 100K.,Cont TIH from 7461' to 12850' Fill pipe and establish perimeters up. wt.170K dn. wt.165k Torque at 20rpm =2300k ft/los 30rpm = 26001kR/Lbs 40rpm =2600k ft/Ibs Pump rate 47spm 650psi TIH in hole and tag up at 12945'top of 41/2 liner Set 1.1 k down unable to pass.,Drill on retainer junk at 12945' 1.1-2.5wob 20-30rpm 47stks 650psi 250oKft/lbs to 3500k ft/lbs Vary bit weights rotary and pump rate Drill down to 12,946 Continue to drill on retainer junk at 12946'.,Circulate B/U at 12,945 191gpm 8Ospm 2066psi On bottoms up saw brass/ rubber and some shards of plastic.,Drill on retainer junk at 12,946' Broke through 412 liner top at 12,946 Drill cement down to 13,025' Contacted top of CIBP at 13025' Drill on CIBP at 64spm 1279pm 1.8-2.5wob rot 38rpm.,Hauled 0 bbls solids to G/1 Cumulative 646 bbls Hauled 320 bbls fluid to G/1 Cumulative 6,6913 bbls OBM Tiger tank 1- 424 bbls Diesel Frac Tank 465 bbls,OBM vertical tank 1.280 bbls OBM vertical tank 2 378 bbls. Diesel URI 384 bbls Diesel UR 2 368 bbls 1011412018 Drilled on 4 %" CIBP at 13,025', alternating wob, gpm, rpm. Best torque results using 4K wob, 159 gpm-1471 psi, 75 rpm -2500 to 2900 Polbs torque. Pumped a 20 bbl hi -vis hi -weight sweep around while drilling on plug. Just before sweep back to surface we broke through the CIBP and coni to wash/ream the stand down to 13,041'. Worked stand through perfs and CIBP.,set depth a couple times. Up wt 168K, dwn wt 162K, good and clean, increased pump rate to 191 gpm-1914 psi, rpm to 100-2394 fl/Ibs torque, and parked string at 13,041'.,Cont to circ until sweep to surface. MW increased from 10.0 ppg to 10.5 ppg and we dumped 23 bbls heavier mud. Did not see much of anything but cement come back with sweep. Shut down pump.,Monitored well for flow 30 min. No flow. Well static.,Cont to wash/ream chasing plug to bottom, from 13,041'to 14,034'. 131 gpm-1000 psi, 40 rpm -1500 to 1900 ft/Ibs torque. At 14,034' getting backflow up drill pipe. Up wt 186K, dwn wt 182K.,MU topdrive and circulated 30 minutes. 182 gpm-2228 psi, 43 rpm -2640 Mbs torque. Shut down still have back flow up DP, pumped 20 bbls 12.0 ppg down DP, no more back flow. Received 10,000 gals diesel in tank farm for displacement. Greased wash pipe and tightened Kelly hose connection on topdrive.,Cont to wash/ream down from 14,034'to 14,703', 180 gpm-1711 psi, 20 rpm -632 ft/Ibs torque. MU topdrive and TIH from 14,703' to 15,316', up wt 196K, dwn wt 194K.,Washed and reamed last 3 stands down from 15,316' and tagged up with 3K wob at 15,505'. Cont to work string and circulate at 154 gpm- 1933 psi, 95 rpm -3491 ft/lbs torque. Up wt 200K, dwn wt 197K to clean up bottom of hole.,Cont to work string and circulate increasing pump rate to 179 gpm- 2229 psi, 95 rpm -3400 ft/Ibs torque. Wash and ream down to 15,510' Called TO.,Circulate at 15510' 86spm 2383psi 171 gpm 95rpm 3450k ft/lbs torque and pump a 40 bbl weighted hi vis sweep Continue circulating to balance mud weight 10.1 in and out for casing test. Dumped 100bbls of mud and the 40 bbls sweep.,Shut down pumps and monitor well for flow. No flow observed. Well static.,Rig up test lines Test casing in 3 stages 400psi/ 5 min 800psi /5min.. Hold 1200psi test for 30min all tests good. Used mud pump to test 400 and 800psi switched to test pump for the 1200psi test. All test recorded on chart, all test passed.,Circulate and Centrifuge mud weight in well bore and surface system from 10.2 to 9.1 or less at 78spm 2500psi 156gpm Centrifuging (9.4 MW. in 8.3 out.) Mud Wt going in the hole 9.3ppg out 10.0 ppg.,Hauled 8 blols solids to G/I Cumulative 646 bbls Hauled 242 bbls fluid to G/I Cumulative 7,155 bbls OBM Tiger tank 1- 289 bbls Diesel Frac Tank 465 bbls,OBM vertical tank 1. 264 bbls OBM vertical tank 2 344 bbls. Diesel UR 1 372 bola Diesel UR 2 383 bbls 10115/2018 With bit at 15,510', continue to circ and cond mud, running centrifuge and cuffing mud weight for displacement. Mud weight at 8.6 ppg in/out. Circ at 177 gpm- 1847 psi, 45 rpm -2970 ft/lbs torque. Hauling off OBM from pits and tank farm to make room for displacement. Cleaned pill pit and trip tank. Transferred diesel into pits 4,5, and 6.,With 8.6 in/out, shut down pump. 30 minute flow check well is static. Shipped out OBM dry product to Baroid yard.,Resumed circulating at 178 gpm-1884 psi, cont running centrifuge until MW at 8.5 in/out. Cont cleaning pits and shipping OBM. Built first 20 bbls of 40 bbl hi -vis spacer. Received 2000 gals rig fuel and 1000 gals into tank farm.,Continue Building spacers 40bbls total. waft on Vacuum trucks back up at G/I.,PJSM: Begin displacement of well by pumping a 401bbl. 400vis spacer followed by 1014bbls 6.7 diesel calculated hole and pipe volume was 847bbl continue pumping until diesel weight was 6.7 in and 6.8 out and diesel cleaned up. initial circulating rate 80spm 162gpm 1854psi as spacer cleared the bit pressure increased to 3400psi reduce pump rate to 65spm 138gpm 3399psi after 15min increased pump rate 192gpm 1845psi.,Continue displacement at 192gpm with the pressure dropping down to 1725psi.,Monitor well for flow saw a slight flow, started taking flow measurements well flowing at.1 blots per hr. Continued monitor the well and took flow measurements every 15min Flow diminished to less than ,i bola per hr. Suspect thermal expansion.,Rack back one stand had flow back in the drill pipe Make up the top drive monitor well.,Service rig adjust brakes mix and pump 20bbl kcl dry job.,POOH F- 15467- 15156' Up Wt. 215 S/O Wt. 205.,Hauled 47 bbls solids to G/I Cumulative 701 bbls Hauled 963 bbls fluid to G/I Cumulative 8,118 bbls,OBM UR 1-0 bbls OBM UR 2-0 bbls OBM Frac Tank -152 bbls Diesel UR 1-372 bbls Diesel UR 2-375 bbls 10/16/2018 POOH with 3.75" drill out assembly from 15,156' to 4675'. Up wt pulling off bottom 218K with diesel in the hole. At 4675' LD 66 jnts 41/2" OP to 2627'. Used Peak vac truck to pull water from cellar boxes infield, and from oil loading dock. Cont to haul OBM from tank farm to G&I. Shipped out Sperry Geo-Span equipment. Sent BOP test notification to AOGCC.,At 2627', RU Weatherford tongs and 2 7/8" handling equipment. Held PJSM, cont POOH LD 2 718" from 2627' to 1533'. Cont to clean pits and haul off OBM. Called out Halliburton a-line crew for CBL. AOGCC waived witness of BOP test at 15:16 pm.,Cont to POOH LD 2 7/8" workstring from 1533'to surface. LD junk baskets and tri-cone. Bit graded at 8-8-LC-A-N-2-NR-TD Recovered chunks of brass and cast iron from junk baskets.,Cleared and cleaned rig Floor, RD Weatherford tongs.,PJSM: Spot Halliburton logging truck R!U E- line T bar, sheaves and wire line Make up logging tools and calibrate.,RIH With Halliburton CCL/GR/MIT/CBL/rEMP/ Logging suite on E-line . Run CBL and caliper log f- 11,450' to15,050'. While logging cleaned pits 1,2.4,5,9, and pit 10.,R/D Halliburton E- Line sheaves and tools. Found a 41/2 od X 1' wide ring caught above the upper centralizer on the logging tool string.,Dram stack makeup testjoint and test plug, set in wellhead R/U test Iines.,Hauled 0 bbis solids to G/I Cumulative 701 bbis Hauled 1010 bbis fluid to Gf Cumulative 9,128 bbls,OBM UR 1-320 bbis OBM UR 2-380 bbis OBM Frac Tank-0 bbls Diesel UR 1-0 bbls Diesel UR 2-0 bbls Diesel Frac Tank 127 bbis 10117/2018 RU BOP test equipment and chart recorder. Flooded surface lines and purged air.,Test ROPE with 4 1/2" testjnt, performed draw down test, pulled 41/2" testjnt, tested blinds, then swapped to 2 7/8" testjnt and tested annular and upper variable rams. Total Safety on location at noon and tested gas alarm system. Witness of BOP test was waived by BUM on 10-15 at 11:44 am, and waived by AOGCC on 10-16 at 15:16 pm. Total test time 8.5 hrs.,RD test equipment, blow down choke line and manifold. Shipped out one trailer dry mud product and two 500 bbl Rain for Rent tanks during testing. Also flushed and cleaned centrifuge and feed pump for rig move.,PJSM with Tri-Point Rep and rig crew, MU test packer assembly and XO on single jnt, start PU single in hole a total 66 its. 4 112" DP. to 2060'.,Continue TIH with stands F-2060'- 9066 at a reduced rate to prevent flow up the Drill Pipe.,PJSM: 131 k up M. 124k On. Wt. Set Tri Point packer at 9066' by one right hand rotation set 20k down P/U to 150k to confirm packer set. Pressure up on back side to 1250psi and test packer for leaks test good Rig up Schlumberger N2 lines. and pressure test to 4500psi for 3min. P/U 4' to open sleeve on the packer. Begin pumping N2 at 1000 scf/1 bbl.,Displacing Drill string through choke to Poor boy degasser Increase N2 to 1500/scf= 1.5bbls min 2400psi displacing 128bbls of diesel in drill string at 130bbis Slack off and set 20k down on Packer and close sleeve. Flow out stopped confirming Sleeve closed Total of 138,000 cf = 1500gal N2 pumped with 130 bbis of diesel displaced.,Hauled 0 bbis solids to GA Cumulative 701 bbis Hauled 930 bbis fluid to G/I Cumulative 10.058 bbls,OBM UR 1-0 bbls OBM UR 2-0 bbis OBM Frac Tank-0 bbis Diesel UR 1-0 bbis Diesel UR 2-0 bbls 10/1812018 S/0 and closed bypass on test packer, closed valve at surface, RD SLB hardline and valve. RU 2" HP hose from pump in sub to kill line at mezzanine. Lined up to bleed nitrogen from drill string through BOP stack, choke manifold and poorboy degasser. Starting with 2250 psi, bled drill string down to 1750 psi and shut in at choke. Monitored pressure on drill string for 15 minutes with no loss or gain.,Continued to bleed off drill string to zero psi.,RD 2" HP hose, Production Lead Op installed echometer on pump in sub and took fluid level readings. First 2 readings: 8600' and 8564'.,RD echometer, installed chart recorder sensor on pump in sub, monitored for any pressure build on chart and gauge 2 hours. No indication of pressure built.,Disconnected chart sensor, installed echometer, took 3 readings at 8526', 8522' and 8519' (average of 8427). Notified Completions Engineer. Took 2 more checks at 8382' and 8405'. Notified Completion Engineer. Got approval to RD, release packer and POOH.,RD echometer, RD pump in sub and TIW, MU topdrive on stump, bleeder closed. Lined up trip tank on hole, opened choke to ensure no trapped pressure on backside, opened annular. Pulled to 140K opening bypass and releasing packer. Cont fill on backside with trip tank, eased bleeder open and began u-tube Fluid into drill pipe. Initial SPP 124 psi, bled down to 42 psi.,Closed bleeder and pumped down drill pipe surface to surface to fill DP, hole and balance fluid in well. 186 gpm-169 psi. 2000 strokes prior to bottoms up closed annular and look returns through choke and degasser for any possible nitrogen/air to surface. Pumped 2000 strokes beyond surface to surface and shut down. Flow check= well static. Opened annular, closed choke.,Hang blocks for cut and slip, spool off and cut 95' drill line, check driveline bolts.,Cont. Slip and out drilling line re calibrate Block height and pason weight indicator.,Monitor well POH f-9066'- 5648' Up Wt. 139k/lbs On Wt. 136k/lbs. Hole fill correct to 5,648' No gain or Iosses.,Trouble shoot and replace Idler Bearing between drill pipe spinner rollers.,Continue to POH F-5648'- POH and Lay down 41/2 drill pipe from 2050' —1085' Correct hole fill no gain or Iosses.,Problem with Iron Roughneck Electrical controls Trouble shoot and repair.,Continue POH laying down 4 12 drill pipe F-1085'-427' total of 59 its L/D at 0600hrs. Correct hole fill no gain or loss. Well static.,Hauled 0 bbls solids to G/I Cumulative 701 bbls Hauled 0 bbis fluid to GA Cumulative 10,058 bbis 10/19/2018 Pulled out of hole from 217' and LD test packer. Packer in good condition.,Serviced rig while cleaning rig floor and staging TCP equipment for PU. MU safety joint and staged on catwalk.,Held PJSM with Tri-Point Rep and rig crew.,PU ran in hole with 180' of TCP assembly and RU Weatherford. MU 3 jnts 2 7/8" workstring, RA tag sub, then singled in with 81 more jnts 2 7/8" workstring to 2802'. RD Weatherford tongs.,PU single in hole with 66 jnts 4 %" DP from 2802' to 4506', then TIH from derrick to 11,531'top of 7" liner slow down running speed upon entering liner top TIH to 12946 top of 4 12 liner. Enter liner top W/O problems. Continue TIH at slower running speed inside 41/2 Liner.,15,4532 Park pipe with Tripoint Perforating assembly Up Wt.205klibs On. Wt. 182k/lbs Pipe displacement correct no gain or Iosses.,PJSM: Rig up Pollard E-Line and rih with Gamma Ray and CCL for correlation Iog.,Hauled 0 bbis solids to G/I Cumulative 701 bbls Hauled 0 bbis fluid to G/I Cumulative 10,058 bbis 10/2011018 POOH with Pollard a -line and RD/released same. Sent log to geologist and confirmed gun set depth.,Pulled up hole setting RA marker at 15,182', top gun assembly at 15,306'to 15,330', bottom gun assembly at 15,432'to 15,456'. MU topdrive and fluid packed surface lines at 94 gpm-537 psi taking returns down flow line. Shut down and closed annular, fluid packed choke line, manifold and degasser at 94 gpm-550 psi. Shut down pump and closed choke.,Held PJSM, using pump #1, pressured up on wellbore to 2050 psi, held 10 seconds and bled down to 1133 psi, per Tri -Point Rep. Had good indication guns fired via Tri -Point headphones. Monitored pressure 15 minutes with a loss of 125 psi. Notified Completion Engineer, bled off pressure with no flow show at degasser. (Note: Now that we have perforated well, we are on a weekly BOP test schedule. Next BOP test due on 10-27).,Circulated 10 minutes through choke at 94 gpm-439 psi initially, pressure dropped to 390 psi over 10 minutes. Shut down pump to monitor for flow. Well flowing at 7 bph. Closed choke and monitored pressure build for one hour. 375 psi on casing, 425 psi on DP over one hour.,Circulated through choke holding 380 psi back pressure, pumping 112 gpm-890 psi, to try and reduce any additional influx. At bottoms up could see and smell gun residue, which then turned to what appeared to be a diesel and crude mixture. Did see some vapor at vent line on degasser at bottoms up. Returns cleaned up 2000 strokes beyond bottoms up with less crude show. Had no gain while circulating.,Shut down and monitored for flow. Flow increased from nothing to 10 bph over 10 minutes and was up to 21 bph over an additional 10 minutes. Notified Completions Engineer. Decision made to attempt injectiv'ity.,Opened annular and pulled string up hole 30', up wt 218K. No issue at all pulling up through parts. Closed annular and choke, pressured up to 2000 psi with 8.5 bbls pumped and shut down. Very little pressure lost over 5 minutes. Notified Completion Enginser.,Bled off, opened annular and CBU again at 218 gpm-1309 psi to see what we get for bottoms up. Started seeing a good amount of grey mousse substance on shaker. 2000 strokes prior to bottoms up, shut down pump and lined up to take returns through choke and degasser in case we had any gas. Circulating through choke at 114 gpm-435 psi. Had another good show of crude oil at bottoms up. Handheld monitor showed,1 ppm 1-12S and 20ppm Co, Chloride check at 100 ppm. ES volts at 1100 indicating no water in returns. Captured numerous bottled samples of crude/diesel. Seeing no separation in those samples. Had no gain during circulating. Went 2000 strokes over bottoms up and shut down pump. Opened annular.,Broke off single with 15' pup on top and staged in mousehole. POOH from 15,485 to 15,207' (4 stands) to get gun assembly clear of pens. Up wt 218K, had no issue pulling up and out of perf zones. PU single with pup from mousehole, broke off pup jnt and LD. MU topdrive.,Closed annular and choke. Monitored well for pressure build over an hour. 375 psi on casing, 320 psi on DP. Discussed with Completions Engineer and Drilling Managers on kill options and recipes. Decision made to build 150 bbls 8.1 ppg, 6% KCL hi -vis weighted cap pill to use once inside 9 5/8" casing.,Bled off well, opened annular. On pump #2, circulated at 215 gpm-1230 psi while building pill. Flow show increased F-48% to 85% at 8800stks Shut down pump, lined up and circulate through choke and degasser at 112gpm 780psi holding 350psi back pressure on casing, gas monitor showed 24% LEL with oil and diesel returning over shakers.,Continued circulating through choke 2000stks past B/U, flow returned to 48% with 6.7diesel returning over shakers no oil or gas. Opened well upend continued circulating at 217gpm-1289psi while wating for 150bbl pill to be mixed up. Well flow increased to 68% shut down pump and circulate through choke and degasser. Getting surges of gas from gas buster to the shaker possum belly, seeing vapors from vent Iine.,Hand held gas monitor showing 24% LEL. Pumping at 112gpm-785psi holding 350-365psi back pressure. Still getting crude oil and gas returning over shaker at a moderate rate. Continue circulating while mixing and waiting for the pill to shear. Checking separation of pill with clear bottles, adding emulsifier and lime as needed to pill.,Hauled 0 bbls solids to GA Cumulative 701 bbls Hauled 90 bbls fluid to Gil 10/21/2018 Continued to circulate with bottom of TCP assembly at 15,202'. Pumping 112 gpm-775 psi holding 360 psi back pressure with choke. Building/shearing a 150 bbl hi -wt pill (8.3 ppg) in pits 9 and 10. Having issue with getting pill sheared (helps with emulsion, reduces separation). Transferred pill into pits 5 and 6 where we could use two charge pumps, hopper and gun lines to aid,with shearing the pill.,Lined up and pumped 132 bbls 8.3 ppg pill, then chased with 111 bbls 6.7 diesel to spot in annulus and be slightly over balanced in drill string to pull pipe dry. Held back pressure while pumping and spotting pill.,Broke off topdrive, drill pipe on vac, pulled up hole from 15,202' to 10,795'. Up wt 205K. Fluid dropping on backside while pulling, pipe pulling dry. At 10,795' we are +/- 1 00'above 8.3 ppg pill. Stopped tripping for crew change and prep to lay down pipe. Calculated hole fill = 32 bbls, actual hole fill = 37 bbls.,Monitored well during crew change. Well started to flow at 1.6 bph over 15 minutes, and up to 3.5 bph over an additional 15 minutes. Closed annular, lined up on choke and monitored for any pressure build. Casing built to 119psi over an hour, DP built to 177psi over an hour. Cont to prep 70 bbl hi -wt pill while monitoring pressures. Notified Drilling Manager.,Pump 73bbl 8.1 ppg. pill at 114gpm 114stks.min. while holding 125psi back pressure through choke and degasser Shut down and bleed off pressure on casing. Attempted to break off top drive but had flow up the drill pipe. Shut well in.,Monitor pressure build up in casing and drill pipe after 1 hr drill pipe pressure was up to 155psi and casing built up to 75psi. Call Drilling Manager and discuss options . Decision made to mix and pump 100bbls of 9.8 brine pill.,Bleed pressure off drill pipe and casing. Begin circulating at 114gpm 415psi while holding 75psi on Casing while building 100bbl 9.eppg Sodium Chloride pill Having surges in Fluid returning over shakers from gasbuster. Handheld gas monitor showing 24ppm LEL.,Pump 100bls of 9.8 Brine pill 112gpm 405psi while holding 70psi back pressure circulating through choke and gasbuster.,Hauled 4 bbis solids to Gil Cumulative 705 bbls Hauled 66 bbls fluid to Gil Cumulative 10,214 bbls 10/22/2018 Chased the 9.8 brine pill with 120 bible and spotted with TCP assembly sitting at 10,795'. Opened choke and annular, DP static, well flowing at 1/. bph. Monitored well until it slowed to % bph.,POOH, up wt 130K. LID 4112" DP, from 10.796to 9276, +/-100' above 9.8 pill. Hole stopped taking displacement. Seeing some back flow up drill pipe. MU topdrive.,Monitored well 15 minutes, fluid dropped 1/2" in wellbore, still some backflow up drill pipe.,Continued to POOH from 9276 to 9124' and back flow got worse. MU topdrive and CBU at 226 gpm-882 psi taking returns down flow line. Had no sign of gas at bottoms up. Shut down and monitored, well static.,MU topdrive and CBU at 226 gpm-882 psi taking returns down flow line. Had no sign of gas at bottoms up. Shut down and monitored, well static. Used 10 bbls of 7.9 pill and pumped down drill pipe for dry job.,Cont to POOH from 9124' to 6490' LD 4 1/2" OP.,Cont to POOH LD 41/2" DP from 6490' to 4936'. Hole fill looked much better at this point. MU topdrive at 4936'.,Break circ. at 212 GPM, 770 PSI, CBU with no sign of Gas. Saw dry job at surface and dumped over board. Shut down well and monitor for 15 Min. well static. Spot 50 bbl 7.9 ppg weighted pill balanced.,Started POOH and D.P. was flowing slightly. Had to Kelly up on each joint to lay down 4.5" D.P. F/ 4,936' to 4,046' MD to get above weighted pill. Pumped a 10 bbl 7.8 ppg dry job. 4.5" D.P. went dry. Cont. to POOH LID 4.5" D.P. F/ 4,046'to 2,833' MD.,PJSM W/ all parties. R/U Weatherford tools and Equip. Monitored well for 45 Min during meeting and R/U, lost 0.5 bbl. POOH 2 7/8" D.P. F/ 2,833' to 1,119' MD.,Hauled 16 bbls solids to G/1 Cumulative 721 bbls Hauled 64 bbls fluid to Gfl Cumulative 10,278 bbls 10/2312018 Held PJSM on LD 2 7/8" and prepped safety joint on catwalk for upcoming gun assembly. Cont to POOH LD 2 7/8" workstring from 1119' to 180'. Well static.,Held PJSM with Tri-Point Rep on handling spent guns. POOH LD gun string.,Clean and clear rig floor, Cleared catwalk of gun tools. Staged GLM's, packer assembly and 31/2" tubing for PU. C/O handling equipment. Held PJSM.,Lined up well on choke to check for any pressure build prior to open blind rams, no pressure. MU WLEG on joint#1, ran two more joints and MU "X" nipple/packer assembly. MU first GLM and started PU single in hole with 3 1/2" 9.3# L-80 EUE tubing to 4025'.,Held PJSM with fresh crew and Weatherford. Cont PU single in hole from 4029 to 6931'. WU CIM and hold Slickline PJSM.,While holding PJSM with rig crew & 3rd party crew on rigging up Slick Line, observed flow from tubing string. Break from meeting & UD CIM, stab & WU floor valve w/ XO, Shut well in. WU TD & Monitor SIPP - No pressure recorded on SIPP or SICP. Open standpipe bleeder to flowline, no returns observed. Open annular preventer, fluid level had dropped to upper ram cavity. Continue monitor well while R/U Slick Line.,Well appeared to be static and just out of balance.,Break circulation @ 3bbls/min. ICP -121 psi. Diverted 47 blots of heavy fluid (7.6ppg) to pits 5 & 6 when returned to surface at 4000 stks pumped. Circulate until even wt 6.9ppg m& out, 9274 stks. Peak Circ. pressure= 174psi, FCP = 119psi.,Lay down floor valve and XO, Monitor well for 10 Min. - static - M/U CIM & hookup control line. Continue single in hole with 3 1/2" 9.3# L-80 EUE tubing from 6931'to 7696 installing SS Band at every coupling.,Hauled 0 bbis solids to G/1 Cumulative 721 bbls Hauled 0 bbls fluid to G/1 Cumulative 10,278 bbis 10/24/2018 Continued to PU single in hole with our 3 %" completion string from 7696'to 12,912'. Ran a total of 406 full length joints and 3 pups. Ran 207 SS bands from CIM at 6000'to hanger. Torqued 31/2" 8 rnd tubing to 3200 ft/Ilos. Up wt 106K, dwn wt 106K. MU hanger and landing joint, NOS Reps terminated 1/4" control line at hanger.,S/O and 5' foot in hanger, landed on RKB depth 18.50', placing top of packer at 12,832'. Dropped ball and rod while RILD's, RU to set packer and test tubing, fluid packed surface Iines.,Using mud pump #1, pressured up on tubing, against ball/rod to 3520 psi and held 20 minutes as per Tri-Point Rep, to set hydraulic packer. Pressure held solid. Bled down pressure to zero, lined up on chart recorder. Using mud pump #1, pressured up to 4500 psi and held 30 minutes on chart. Good test. Bled tubing down to 2000 psi.,RU test pump on upper annulus. Pressured up on annulus to 2000 psi and held 30 minutes on chart. Good test. Bled annulus down to zero then bled tubing pressure down to zero.,RD test equipment and remove landing joint. NOS Wellhead Rep install TWC. R/D TIW valve, XO & Pup in sub. R/D casing tongs.,Hold PJSM, Clean rig floor, Wash BOP stack. Build cleaning pill w/soap and pump through BOPE, Choke, Kill & Mud Pit lines. Empty stack and blow down Iines.,Remove drip pan, De-energize koomy and remove control lines from stack. Remove flow paddle and pull flow line. Remove choke and kill lines from stack. Remove riser and orbital valves from MPD head.,Hauled 0 bbis solids to G/I Cumulative 721 bbls Hauled 90 bbls fluid to G/l Cumulative 10,368 bbls 10125/2018 NO Swaco MPD head, loaded Weatherford equipment and Swaco MPD equipment and shipped same, shipped out mud products, RD Total Safety equipment, shipped Sperry shack and tool box, shipped Tri-Point basket, shipped trailer of new 3 %" tubing to Tuboscope, removed BOP stack from wellhead, installed dry hole tree/adaptor flange, started termination of 1/4" control Iine,at adaptor flange.,Finished termination of control line at adaptor flange, shipped trash fluid to G&I, built soap water pill for flushing through surface lines and pits, tested void and tree at 250/5000 psi for 10 minutes each. Installed mousehole and started breaking down stands in derrick, LD remainder 4 %" DP. Transferred cleanest dirty diesel to production loading dock, cont loading barite on trailer for Seaview Pad, flushed pits 45-6,with soap water.,Continued to break down stands in mousehole and LD 41/2" DP. Clear and clean rig floor.,Clean rig in prep for RDMO. Pressure wash Derrick, Topdrive & Rig floor. Continue with cleaning of mud tanks, flushing and blowing down lines. Re-install removed wall from modules.,Hauled 4 bible solids to G/I Cumulative 725 bbis Hauled 576 bbls fluid to G/I 1n 94d hhI, 1012912018 Meet with Rig. Peak crews cleaning pit Iiner.,Pollard and Wellhead hand on location. Hold safety meeting and fill out PTW. Assist rig crew with removing pit liner and felt. Rig up Slick line unit. Pick lubricator and remove back pressure valve from tree. Install production flow cross.,Pressure test 1500 PSI-GOOD. Rih w/ 2" JDC to 12893' kb, latch prong w/t, pressure drops 50 psi pooh. Ooh w/ prong.,Rih w/ 3 " GS to 12896' kb, latch plug, pooh. Ooh with plug missing 2 pieces of v-packing. Rih w/ 3 112 X-line w/ 3112 PX plug to 12896' kb, set plug pooh. Ooh plug set Rih w/ 2 1/2 sb w/ prong to 12893'kb w/t pooh - ooh prong set Rib w/ 3 GS w/ catcher sub w/ 2.5 g ring on btm to 12891'kb, set catcher, pooh.,Rih w Daniels KOT w/ 1 1/4 JDs to 4560' kb, set down, wtt fall pass to 10990' cant set down, pooh. Ooh w/ station 2. Rih w/ ok-5 w/ 1 1/4 ids to 7562' kb, set down, shear off, pooh. Ooh sheared. Rih w/ same to 10990' kb, locate, set down, latch valve, pooh, ooh w/ oriface valve.,Ooh w/ oriface valve. Rib w/ 3 1/2 ok-5 w/ jk w/ 1" bk live valv to 4560' kb, set valve, pooh, ooh no valve. Rih w/ 3 1(2 ok-5 w/ jk w/ 1" bk pocket protector to 10,990' kb. Ooh Lay down, stand by. Well Circulate 900barrels through well. 1013012018 Hold safety meeting. PTW.,Fire pump truck. Warm up truck and circulate fluid throughout pump.,Pressure test PX plug to 1000 psi for 10 minutes. Good solid test. Online down tubing taking returns up IA. Circulate out diesel and brine pill with lease water. 4 bbls/min 60 psi. Pressure increased to 165 psi towards end of circulation. 785 bible circulated. Brine pill segregated into tank 4.,Rig up Gas lift line to IA. Install choke from IA to tank.,Start lifting wellbore fluids with Wass. 175bbislifted. 10/31/2018 PTW, JSA. Continue unloading well. Rig up SSV, choke, Flow line. Rig up gas Iift.,Continue to unload well. 464 bbis returned from Gas Iift.,Potlard Slick line on location. PTW, JSA. Rig up Slick line. Shut in Gas lift. 1000 psi on IA. 120 PSI SITP. Bleed down IA to open top tank. Shut in with 0 psi.,Rih w/ 3 1/2 ok-5 w/ 1 114 JDS to 11,030' kb. Pull up to station #7. Take sample from diesel tank bottom. Looks like brine water. Hookup 1" pump line to open top tank. Pump 42 bbis of water from diesel tank. Returns changed from tan to dark brown. Good diesel at tank. Shutdown. Lineup with 2" line down tubing. Online pump 150 bbis of diesel down tubing. Shutdown pump. latch protecting sleeve, pooh.,Ooh w/ Kot and pocket protector.Rih w/ 31/2 ok-5 w1 jk w/ 1" oriface (3/8" port) to (fluid @ 3300) to 10,990' kb, set onface, pooh. OOH no valve. Valve is set.,Rih wl 3 " Gs to 12892'kb w/t pooh - ooh w/ catchter sub- has live valve inside. Review Gas lift design. Gas lift valve pressure set for 1213 indicating it came from GLM#4. Previous slick line run on 11/29/18 SL set down at 7562' (GLM#4) POOH tool pin sheared. Confirmed GLM#4 valve dropped into catcher sub on 10/29/18 prior to well circulation. Tool was sheared which gave indication that valve was set.,Drop catcher sub. Rih w/3 1/2 ok-5 w/ 1" LIB to 4560' kb, wtt pooh. Ooh w/ valve mark. Read Gaslift data sheet, valve is from station #4.,Rih w/ 31/2 ok-5 w/ jk w/ 1" valve (1213 PTRO) to station #4 @ 4560' kb, w/t set valve pooh. Cob. Rih w/ 3" GS to 12892' kb. Latch catcher sub. POOH. catcher sub empty. , rih w/ 2.63" jdc to pull plug rod @ 11,000' Stopped and pulled OOH as per towns orders. Wait further direction to potentially circulate well again due to having station 4 open instead of pumping through station #7.,Throughout the night rigged down hot oil truck, 1502 lines. Choke skid. suction lines. After pumping 150 bbis diesel down tubing IA pressure increased to 150 psi. Hilcorp Alaska, LLC Beaver Creek Unit Beaver Creek Unit BCU 5RD2 501332026202 Sperry Drilling Definitive Survey Report 17 September, 2018 HALLIBURTON Sperry Orllling n Halliburton Definitive Survey Report Company: Hiloom Alaska, LLC Local Coordinate Reference: Well Beaver CK Units Project: Beaver Creek Unit TVD Reference: BCU 5RD2 wp01 IRKS @ 178.40usft (HEC 169) Site: Beaver Creek Unit MD Reference: BCU 5RD2 wp01 IRKS @ 178.40usft (HEC 169) Well: Beaver CK Unit 5 North Reference: True Wellbore: BCU 5RD2 Survey Calculation Method: Minimum Curvature Design: BCU 5RD2 Database: Sperry EDM - NORTH US + CANADA Project Beaver Creek Unit 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 Well Beaver CK Unit 5 Tie On Depth: 14,205.40 Vertical Section: Depth From (TVD) -N/-S Well Position -NIS 0.00 usft Northing: 2,433,991.43 usft Latitude: 18.00 +E/ -W 0.00 usft Basting: 317,312.59 usft Longitude: Position Uncertainty 06/18/1974 0.00 usft Wellhead Elevation: 160.40 usft Ground Level: Wellbore BCU 5RD2 14,403.98 Survey#1(BCU 5RD2) 2_MWD_Interp Azi+Sag H003Mb: Interpolated azimuth +sag carrection 08/20/2018 Magnetics Model Name 2_MWD+IFRI+MS+Sag Sample Date Declination V) Dip Angle (`) 18.00 BGGM2018 8/15/2018 15.71 73.62 Design BCU 5RD2 2,433,991.43 317,312.59 000 000 Audit Notes 60.6583924 -151.0182963 160.40 usft Field Strength (rT) 55,319 Version: 1.0 Phase: ACTUAL Tie On Depth: 14,205.40 Vertical Section: Depth From (TVD) -N/-S +E/ -W Direction (usft) (usft) (usft) (1) 18.00 0.00 0.00 43.49 Survey Program Date 9/13/2018 From TO Map Map (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 105.40 7,965.40 BCU 5 Unknown Mag & Gyro Combo (SC 2 -Unknown A02911a: Unknown survey tool 06/18/1974 8,005.40 14,205.40 BCU 5 CB -GMS Surveys (BCU 5) 2 -CB -Film -GMS A022Ga: Film camera gyro multi -shot 11/28/1974 14,238.00 14,403.98 Survey#1(BCU 5RD2) 2_MWD_Interp Azi+Sag H003Mb: Interpolated azimuth +sag carrection 08/20/2018 14,460.50 15,647.48 MWD+IFRI+MS+sag(BCU 5RD2) 2_MWD+IFRI+MS+Sag A010Mb: IFR dec & multi -station analysis +sag 09/11/2018 Survey 9/17/2018 6:5O:28PM Page 2 I COMPASS 5000.1 Build 81E Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Besting DLS Section (usft) (1) V) (usft) (usft) (usft) (usft) (ft) (ft) (-/loP) (ft) Survey Tool Name 18.00 0.00 0.00 18.00 -160.40 0.00 0.00 2,433,991.43 317,312.59 000 000 UNDEFINED 105.40 0.08 105.38 105.40 -73.00 -0.02 0.06 2,433,991.41 317,312.65 0.09 0.03 2_Unknown (1) 20540 0.08 109.56 205.40 27.00 -0.06 0.19 2,433,991.37 317,312.78 0.01 0.09 2_Unknown (1) 305.40 0.17 95.71 305.40 127.00 -0.10 0.41 2,433,991.33 317,312.99 0.09 0.21 2_Unknown (1) 405.40 0.08 90.97 405.40 227.00 -0.11 0.62 2,433,991.31 317,313.21 0.09 0.35 2_Unknown(1) 505.40 0.08 313.11 505.40 327.00 -0.07 0.64 2,433,991.35 317,313.23 0.15 0.39 2_Unknown(1) 605.40 0.25 269.31 605.40 427.00 -0.02 0.37 2,433,991.40 317,312.96 0.20 0.24 2_Unknown (1) 673.40 0.25 228.00 673.40 495.00 -0.12 0.11 2,433,991.31 317,312.70 0.26 -0.01 2_Unknown(1) 767.40 0.50 173.00 767.40 589.00 -0.67 0.01 2,433,990.76 317,312.59 0.44 -0.48 2_Unknown (1) 86040 0.25 250.00 860.39 681.99 -1.14 -0.13 2,433,990.29 317,312.44 0.54 -0.91 2_Unknown (1) 954.40 0.25 263.00 954.39 775.99 -1.23 -0.53 2,433,990.21 317,312.4 0.06 -1.26 2-Unknown(1) 9/17/2018 6:5O:28PM Page 2 I COMPASS 5000.1 Build 81E Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well Beaver CK Unit 5 project: Beaver Creek Unit TVD Reference: BCU 5RD2 wp01 RKB @ 178.40usft (HEC 169) Site: Beaver Creek Unit MD Reference: BCU 5RD2 wp01 RKB @ 178.40usft (HEC 169) Well: Beaver CK Unit 5 North Reference: True Wellbore: BCU 5RD2 Survey Calculation Method: Minimum Curvature Design: BOU 5RD2 Database: Sperry EDM - NORTH US+CANADA Survey 9/1712018 6:50:28PM Page 3 COMPASS 5000.1 Build 81E Map Map Vertical MD Inc Azi TVD NDSS +NIS +E/ -W Northing Easting DIS Section (usft) (1) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°11001 (ft) Survey Tool Name 1,048.40 0.50 227.W 1.48.39 869.99 -1.54 -1.03 2,433,989.91 317,311.54 0.35 -1,82 2_Unknown(1) 1,142.40 0.50 199.00 1,142.39 963.99 -2.21 -1.46 2,433,989.25 317,311.09 0.26 -2.61 2_Unknown (1) 1,236.40 0.50 90.00 1,236.39 1,057.99 -2.59 -1.19 2,433,908.86 317,311.36 0.87 -2.70 ]_ Unknown (1) 1,330.40 0.25 83.00 1,330.38 1,151.98 -2.57 -0.57 2,433,906.87 317,311.98 0.27 -2.26 2_Unknown (1) 1,424.40 0.25 351.00 1,424.38 1,245.98 -2.34 -0.40 2,433,989.10 317,312.15 0.38 -1.97 2_Unknown (1) 1,518.40 0.00 351.0 1,518.38 1,339.98 -2.14 -0.43 2,433,989.30 317,312.12 027 -185 2_Unknown(1) 1,612.40 0.25 164.00 1,612.38 1,433.98 -2.34 -0.38 2,433,989.10 317,312.18 0.27 -1.95 2_Unknown (1) 1,706.40 0.25 177.00 1,706.38 1,527.98 -2.74 -0.31 2,433,988.70 317,312.24 0.06 -2.20 2_Unknown (1) 1,800.40 0.25 175.00 1,800.38 1,621.98 -3.15 -0.28 2,433,988.29 317,312.26 0.01 -2.48 2_Unknown (1) 1,894.40 0.25 128.00 1,894.38 1,715.98 -3.48 -0.10 2,433,987.96 317,312.43 0.21 -2.59 2_Unknown(1) 1,988.40 0.00 128.00 1,988.38 1,809.98 -3.60 0.06 2,433,987.83 317,312.59 0.27 -2.57 2_Unknown (1) 2,081.40 0.25 120.00 2,081.38 1,90298 -3.70 0.24 2,433,987.72 317,312.77 0.27 -2.53 2_Unknown (1) 2,175.40 0.25 77.00 2,175.38 1,996+98 -3.76 0.61 2,433,987.66 317,313.14 0.19 -2.31 2_Unknown (1) 2,269.40 0.25 219.00 2,269.38 2,090.98 3.87 0.68 2,433,987.55 317,313.21 0.50 -2.34 2_Unknown(1) 2,363.40 0.50 194.00 2,363.38 2,184.98 4.43 0.46 2,433,986.99 317,312.98 0.31 -2.90 2_Unknown (1) 2,456.40 0.25 337.00 2,456.38 2,277.98 4.64 0.28 2,433,986.79 317,312.80 0.77 3.17 2_Unknown(1) 2,550.40 0.25 274.00 2,550.38 2,371.98 4.44 -0.01 2,433,987.00 317,312.51 0.28 -3.22 2_Unknown (1) 2,644.40 0.25 23.00 2,644.37 2,465.97 4.23 -0.13 2,433,987.20 317,312.39 0.43 3.16 2_Unknown (1) 2,738.40 0.25 14.00 2,738.37 2,559.97 -3.84 0.00 2,433,987.59 317,312.53 0.04 -2.79 2_Unknown (1) 2,832.40 0.17 40.00 2,832.37 2,653.97 -3.54 0.14 2,433,987.89 317,312.67 0.13 -247 2_Unknown (1) 2,926.40 0.25 35.00 2,926.37 2,747.97 -3.26 0.35 2,433,988.16 317,312.88 0.09 -2.13 2_Unknown (1) 3,020.40 1.00 39.00 3,020.37 2,841.97 -2.46 0.98 2,433,988.96 317,313.53 0.80 -1.11 2_Unknown(1) 3,113.40 1.00 73.00 3,113.35 2,934.95 -1.59 2.27 2,433,989.80 317,314.83 0.63 0.41 2_Unknown (1) 3,207.40 1.00 72.00 3,207.34 3,02894 -1.10 3.03 2,433,990.27 317,316.40 0.02 1.84 2 Unknown(1) 3,301.40 0.50 62.00 3,301.33 3,122.93 -0.65 4.97 2,433,990.70 317,317.55 0.55 2.95 2_Unknown (1) 3,395.40 0.50 39.0 3,395.33 3,216.93 -0.14 5.59 2,433,991.20 317,318.18 0.21 3.75 2_Unknown (1) 3,489.40 0.25 74.00 3,489.32 3,310.92 0.24 6.05 2,433,99157 317,318.64 0.35 4.33 2_Unknown (1) 3,507.40 0.25 19.00 3,507.32 3,328.92 0.28 6.10 2,433,991.62 317,318.69 1.28 4.40 2_Uaknawn(1) 3,516.40 0.24 27.31 3,516.32 3,337.92 0.32 6.11 2,433,991.65 317,318.71 0.41 4.44 2_Unknown (1) 13 318" 3,541.40 0.25 51.00 3,541.32 3,362.92 0.40 6.18 2,433,991.73 317,318.78 0.41 4.54 2_Unknown (1) 3,635.40 0.25 359.00 3,635.32 3,456.92 0.73 6.34 2,433,992.07 317,318.94 0.23 4.89 2_Unknown (1) 3,729.40 0.25 328.00 3,729.32 3,550.92 1.11 6.22 2,433,992.45 317,318.83 0.14 5.09 2_Unknown (1) 3,823.40 0.00 0.00 3,823.32 3,644.92 1.29 6.12 2,433,992.62 317,318.72 0.27 5.14 2_Unknown (1) 3,917.40 0.00 0.0 3,917.32 3,738.92 1.29 6.12 2,433,992.62 317,318.72 0.00 5.14 2_Unknown (1) 4,011.40 0.00 0.00 4,011.32 3,832.92 1.29 6.12 2,433,992.62 317,318.72 0.00 5.14 2_Unknown(1) 4,104.40 0.25 242.00 4,104.32 3,925.92 1.19 5.94 2,433,992.53 317,318.54 0.27 4.95 2_Unknown (1) 4,198.40 0.25 210.00 4,198.32 4,019.92 0.92 5.65 2,433,992.26 317,318.26 0.15 4.56 2_Unknown (1) 4,292.40 0.25 260.00 4,292.32 4,113.92 0.70 5.35 2,433,992.05 317,317.95 0.22 4.19 2_Unknown (1) 4,386.40 0.00 180.06 4,386.32 4,207.92 0.67 5.15 2,433,992.02 317,317.75 0.27 4.03 2_Unknown (1) 9/1712018 6:50:28PM Page 3 COMPASS 5000.1 Build 81E Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Weil Beaver CK Unit 5 Project: Beaver Creek Unit TVD Reference: BCU 5RD2 wp01 RKB @ 178.40usft (HEC 169) Site: Beaver Creek Unit MD Reference: BCU 5RD2 wp01 RKB @ 178.40usft (HEC 169) Well: Beaver CK Unit 5 North Reference: True Wellbore: BCU 5RD2 Survey Calculation Method: Minimum Curvature Design: BCU 5RD2 Database: Sperry EDM - NORTH US +CANADA Survey Vertical Section (ft) Survey Tool Name 4.16 2_Unknown(1) 4.30 2_Unknown(1) 4.28 2-unknown(1) 4.34 2_Unknown (1) 4.54 2_Unknown (1) 4.74 2_Unknown (1) 4.81 2 Unknown(1) 4.80 2_Unknown (1) 5.05 2_Unknown (1) 5.56 2_Unknown (1) 6.02 2_Unknown (1) 6.42 2_Unknown (1) 6.77 2-Unknown(1) 6.78 2_Unknown (1) 6.52 2_Unknown (1) 6.03 2_Unknown (1) 5.23 2_Unknown (1) 4.78 2_Unknown (1) 4.88 2 Unknown(1) 4.90 2_Unknown (1) 4.60 2_Unknown (1) 4.19 2_Unknown (1) 3.83 2_Unknown (1) 3.40 2_Unknown (1) 2.91 2_Unknown (1) 2.26 2_Unknown (1) 1.90 2_Unknown (1) 1.90 2_Unknown (1) 1.88 2_Unknown (1) 1.94 2 -Unknown (1) 1.84 2_Unknown (1) 1.57 2_Unknown(1) 1.42 2_Unknown(1) 1.41 2_Unknown (1) 1,41 2_Unknown (1) 1.30 2_Unknown (1) 1.06 2_Unknown (1) 0.89 2_Unknown (1) 0.63 2_Unknown(1) 0.51 2_CS-Fllri(2) 9/1712018 6:50:28PM Page 4 COMPASS 5000.1 Build 81E Map Map MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS (usft) (•) (•) (usft) (usft) (usft) (usft) (ft) (ft) il-Mol') 4,480.40 0.25 355.00 4,480.32 4,301.92 0.87 5,13 2,433,992.22 317,317.73 0.27 4,574.40 0.25 313.00 4,574.32 4,395.92 1.22 4.96 2,433,992.57 317,317.57 0.19 4,667.40 0.25 310.00 4,667.32 4,488.92 1.49 4.66 2,433,992.84 317,317.27 0.01 4,761.40 025 332.00 4,761.32 4,582.92 1.80 4.40 2,433,993.16 317,317.02 0.10 4,855.40 0.25 357.00 4,855.32 4,676.92 2.19 4.30 2,433,993.55 317,316.92 0.12 4,949.40 0.25 330.00 4,949.32 4,770.92 2.57 4.18 2,433,993.93 317,316.81 0.12 5,043.40 0.25 317.00 5,043.31 4,864.91 2.90 3.94 2,433,994.26 317,316.57 0.06 5,137.40 0.25 307.00 5,137.31 4,958.91 3.17 3.64 2,433,994.54 317.316.28 0.05 5,230.40 0.50 356.00 5,230.31 5,051.91 3.70 3.45 2,433,985.07 317,316.09 0.41 5,324.40 0.50 348.00 5,324.31 5,14591 4.51 3.33 2,433,995.88 317,315.99 0.07 5,418.40 0.50 346.00 5,418.30 5,239.90 5.30 3.15 2,433,996.69 317,315.82 0.02 5,512.40 0.25 19.00 5,512.30 5,333.90 5.90 3.12 2,433,997.28 317,315.60 0.34 5,606.40 0.25 4.00 5,606.30 5,427.90 6.30 3.20 2,433,997.67 317,315.88 0.07 5,700.40 0.25 267.00 5,700.30 5,521.90 6.49 3.01 2,433,997.87 317,315.70 0.40 5,793.40 0.25 282.00 5,793.30 5,614.90 6.52 2.61 2,433,997.91 317,315.30 0.07 5,887.40 0.50 244.00 5,887.30 5,708.90 6.38 2.04 2,433,997.78 317,314.72 0.36 5,981.40 0.75 270.00 5,981.29 5,802.89 6.20 1.05 2,433,997.62 317,313.74 0.40 6,075.40 0.50 311.00 6,075.29 5,896.69 6.47 0.13 2,433,997.90 317,312.82 0.53 6,169.40 0.50 330.00 6,169.28 5,990.88 7.10 -0.39 2,433,998.53 317,312.31 0.18 6,263.40 0.50 300.00 6,263.28 8,064.88 7.66 -0.95 2,433,999.10 317,311.76 0.28 6,356.40 0.50 282.00 6,35628 6,177.88 7.94 -1.70 2,433,999.40 317,311.02 0.17 6,450.40 0.50 285.00 6,450.27 6,271.87 8.14 -2.49 2,433,999.60 317,310.22 0.03 6,544.40 0.50 290.00 6,544.27 6,365.87 8.38 3.27 2,433,999.86 317,309.45 0.05 6,638.40 0.50 274.00 6,638.27 6,459.87 8.55 -4.07 2,434,000.04 317,308.65 0.15 6,73240 0.75 291.00 6,732.26 6,553.86 8.80 5.05 2,434,000.31 317,307.67 0.33 6,826.40 0.50 220.00 6,826.26 6,647.86 8.71 -5.89 2,434,000.23 317,306.84 0.80 6,919.40 0.50 319.00 6,919.25 6,740.85 8.70 -6.42 2,434,000.23 317,306.31 0.82 7,013.40 0.75 310.00 7,013.25 6,834.85 9.41 -7.16 2,434,000.95 317,305.58 0.28 7,107.40 0.75 315.00 7,107.24 6,928.84 10.24 -8.06 2,434,001.79 317,304.69 0.07 7,201.40 0.50 320.00 7,201.24 7,022.84 10.99 5.76 2,434,002.55 317,304.00 0.27 7,295.40 0.25 266.00 7,295.23 7,116.83 11,29 -9.23 2,434,002.86 317,303.54 0.43 7,389.40 0.25 278.00 7,389.23 7,210.83 11.30 -9.64 2,434,002.88 317,303.13 0.06 7,482.40 0.50 309.00 7,482.23 7,303.83 11.58 -10.16 2,434,003.17 317,302.62 0.34 7,576.40 0.25 320.00 7,576.23 7,397.83 12.00 -10.61 2,434,003.59 317,302.17 0.28 7,670.40 0.25 307.00 7,670.23 7,491.83 12.28 -10.90 2,434,003.88 317,301.88 0.06 7,764.40 0.25 290.00 7,764.23 7,585.83 12.47 -11.26 2,434,004.08 317,301.53 0.08 7,858.40 0.25 261.00 7,858.23 7,679.83 12.51 -11.65 2,434,004.12 317,301.13 0.13 7,952.40 0.25 220.00 7,952.22 7,773.82 12.32 -11.99 2,434,003.94 317,300.80 0.19 7,965.40 0.25 237.00 7,965.22 7,786.82 12.29 -1203 2,434,003.90 317,300.75 0.57 8,005.40 1.83 310.23 8,005.22 7,826.82 12.65 -12.59 2,434,004.27 317,300.20 4.44 Vertical Section (ft) Survey Tool Name 4.16 2_Unknown(1) 4.30 2_Unknown(1) 4.28 2-unknown(1) 4.34 2_Unknown (1) 4.54 2_Unknown (1) 4.74 2_Unknown (1) 4.81 2 Unknown(1) 4.80 2_Unknown (1) 5.05 2_Unknown (1) 5.56 2_Unknown (1) 6.02 2_Unknown (1) 6.42 2_Unknown (1) 6.77 2-Unknown(1) 6.78 2_Unknown (1) 6.52 2_Unknown (1) 6.03 2_Unknown (1) 5.23 2_Unknown (1) 4.78 2_Unknown (1) 4.88 2 Unknown(1) 4.90 2_Unknown (1) 4.60 2_Unknown (1) 4.19 2_Unknown (1) 3.83 2_Unknown (1) 3.40 2_Unknown (1) 2.91 2_Unknown (1) 2.26 2_Unknown (1) 1.90 2_Unknown (1) 1.90 2_Unknown (1) 1.88 2_Unknown (1) 1.94 2 -Unknown (1) 1.84 2_Unknown (1) 1.57 2_Unknown(1) 1.42 2_Unknown(1) 1.41 2_Unknown (1) 1,41 2_Unknown (1) 1.30 2_Unknown (1) 1.06 2_Unknown (1) 0.89 2_Unknown (1) 0.63 2_Unknown(1) 0.51 2_CS-Fllri(2) 9/1712018 6:50:28PM Page 4 COMPASS 5000.1 Build 81E Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well Beaver CK Unit 5 Project: Beaver Creek Unit TVD Reference: BCU 5RD2 wp01 RKB @ 178.40usft (HEC 169) Site: Beaver Creek Unit MD Reference: BCU SR02 wp01 RKB @ 178.40usft (HEC 169) Well: Beaver CK Unit 5 North Reference: True Wellbore: BCU 5RD2 Survey Calculation Method: Minimum Curvature Design: BCU 5RD2 Database: Sperry EDM - NORTH US +CANADA Survey 911711018 6:50:28PM Pages COMPASS 5000.1 Build 81E Map Map vertical MD Inc Azi TVD TVDSS +N/S +E/ -W Northing Easting DLS Section (usft) V) (1) (usft) (usft) (usft) (usft) (ft) (ft) ("1100•) (ft) Survey Tool Name 8,105.40 3.17 312.40 8,105.12 7,926.72 15.55 -15.85 2,434,007.22 317,296.98 1.34 0.37 2_CS-Film-GMS(2) 8,205.40 3.92 323.86 8,204.93 8,026,53 20.17 -19.91 2,434,011.91 317,293.00 1.03 0.93 2_CB-Film-GMS (2) 8,305.40 5.08 332.17 8,304.62 8,126.22 26.85 -23.99 2,434,018.64 317,289.02 1.33 2.97 2_CB-Film-GMS (2) 8,405.40 5.92 333.38 8,404.16 8,22576 35.37 -28.37 2,434,027.24 317,28437 0.85 6.14 2_CB-Film-GMS(2) 8,505.40 6.83 336.66 8,503.54 8,325.14 45.44 -33.04 2,434,037.38 317,280.26 0.98 10.23 2_CB-Film-GMS (2) 8,605.40 8.25 34096 8,602.67 8,424.27 57.69 -37,73 2,434,049.69 317,275.76 1.53 15.88 2_CB-Film-GMS(2) 8,705.40 9.08 344.23 8,701.53 8,523.13 72.06 -42.22 2,434,064.13 317,271.50 0.96 23.22 2_CB-Film-GMS (2) 8,805.40 10.42 349.54 8,800.09 8,621.69 88.55 46.00 2,434,080.68 317,267.97 1.61 32.58 2_CB-Film-GMS (2) 8,905.40 13.08 356.98 8,897.99 8,719.59 108.75 48.24 2,434,100.90 317,266.04 3.06 45.69 2_CB-Film-GMS (2) 9,00540 13.83 359.63 8,995.24 8,816.84 132.00 48.92 2,434,124.16 317,265.73 0.97 62.10 2_CB-Film-GMS(2) 9,105.40 14.75 3.94 9,092.15 8,913.75 156.65 -08.12 2,434,148.80 317,266.91 1.41 80.53 2_313-Film-GMS(2) 9,205.40 15.17 6.18 9,188.76 9,010.36 182.36 45.84 2,434,174.47 317,269.59 031 100.76 2_CB-Fi1m-GMS(2) 9,305.40 16.33 9.16 9,285.01 9,106.61 209.25 42.19 2,434,201.29 317,273.65 1.41 122.T 2_CB-Film-GMS(2) 9,405.40 16.67 9.48 9,380.89 9,202.49 237.28 -37.59 2,434,22924 317,278.68 0.35 146.27 2 -CB -Film -GMS (2) 9,505.40 17.67 11.94 9,476.43 9,29803 266.27 -32.09 2,434,258.15 317,284.63 1.24 171.10 2-CB-Film-GMS(2) 9,605.40 18.50 14.41 9,571.49 9,393.09 296.49 -25.00 2,434,288.25 317,292.19 1.13 197.90 2_CB-FI1.-GMS (2) 9,705.40 19.92 16.01 9,665.92 9,487.52 328.23 -16.35 2,434,319.85 317,301.33 1.51 226.88 2_CB-Film-GMS (2) 9.805.40 20.25 18.44 9,759.84 9,581.44 36102 -6.18 2,434,352.48 317,312.01 090 257.67 2_213 -Film -GMS (2) 9,905.40 21.42 19.55 9,853.30 9,674.90 394.65 5.41 2,434,385.92 317,324.11 1.23 290.04 2_CB-Film-GMS (2) 10,005.40 21.33 19.74 9,946.43 9,76803 428.97 17.66 2,434,420.05 317,336.89 0.11 323.37 2_CB-FIIm-GMS(2) 10,105.40 22.17 19.87 10,039.31 9,860.91 463.84 30.22 2,434,45432 317,349.99 0.84 357.31 2_CB-Film-GMS (2) 10,205.40 22.83 21.36 10,131.69 9,953.29 499.65 43.69 2,434,490.31 317,364.02 0.87 392.57 2_CB-FilmGMS(2) 10,305.40 24.67 22.58 10,223.22 10,044.82 536.99 58.78 2,434,527.41 317,379.67 1.90 430.04 2_CB-FilmGMS (2) 10,405.40 24.58 24.41 10,314.13 10,135.73 575.20 75.38 2,434,565.36 317,396.87 0.77 469.19 2_CB-Film-GMS(2) 10,50540 24.67 25.18 10,405.03 10,226.63 613.03 92.86 2,434,602.91 317,414.93 0.33 508.65 2-CB-Film-GMS(2) 10,605.40 25.33 26.06 10,495.66 10,317.26 651.13 111.14 2,434,640.72 317,433.79 0.76 548.88 2_CB-Film-GMS (2) 10,705.40 26.00 26.42 10,585.80 10,407.40 689.98 130.29 2,434,679.26 317,453.54 0.69 590.24 2_CB-FilmGMS (2) 10,805.40 26.75 27.27 10,675.39 10,496.99 729.61 150.35 2,434,718.58 317,474.22 0.84 632.80 2_CB-FilmGMS (2) 10,905.40 26.50 28.19 10,764.78 10,586.38 769.28 171.20 2,434,757.92 317,495.68 0.48 675.93 2 -CB -Film -GMS (2) 11,005.40 26.50 29.36 10,854.28 10,675.88 808.39 19258 2,434.796.68 317,517.76 0.52 719.09 2 -CS -Film -GMS (2) 11,105.40 2650 29.36 10,943.77 10,765.37 84127 214.56 2,434,835.23 317,540.23 0.00 762.36 2 -CB -Film -GMS (2) 11,205.40 27.06 31A0 11,033.04 10,854.64 886.15 237.35 2,434,873.74 317,563.63 4.09 806.25 2-CB-Film-GMS(2) 11,305.40 27.25 32.11 11,122.01 10,943.61 924.97 261.38 2,434,912.18 317,588.25 0.37 850.95 2_CB-FIIm-GMS(2) 11,405.40 28.33 31.68 11,210.47 11,032.07 964.55 286.01 2,434,951.38 317,613.49 1.10 896.62 2_CB-Film-GMS (2) 11,505.40 27.25 31.78 11,298.94 11,120.54 1,004.21 310.53 2,434,990.64 317,638.62 1.08 942.26 2-CB-Film-GMS(2) 11,605.40 27.33 33.56 11,387.81 11,209.41 1,042.80 335.28 2,435,028.84 317,663.96 0.82 987.29 2_CB-Film-GMS (2) 11,705.40 26.00 31.79 11,477.18 11,298.78 1,080.56 359.52 2,435,066.22 317,668.78 1.55 1,031.37 2_CB-Film-GMS (2) 11,717.40 25.92 31.97 11,487.96 11,309.56 1,085.02 362.29 2,435,070.64 317,691.63 0.94 1,036.52 2_28 -Film -GMS (2) 95/81, 11,805.40 25.33 33.30 11,567.31 11,388.91 1,117.07 382.81 2,435,102.37 317,712.64 0.94 1,073.89 2_CB-Film-GMS(2) 11,905.40 26.58 34.78 11,657.22 11,478.82 1;153.33 407.32 2,435,138.24 317,737.70 1.41 1,117.06 2_CB-Film-GMS(2) 911711018 6:50:28PM Pages COMPASS 5000.1 Build 81E Halliburton Definitive Survey Report Company: Project: Site: Well: Wellbore: Design: Hilcorp Alaska, LLC Beaver Creek Unit Beaver Creek Unit Beaver CK Unit 5 BCU 5RD2 BCU 5RD2 Local Co-ordinate Reference: Well Beaver CK Unit 5 TVD Reference: BCU 5RD2 wp01 RKB @ 178.40usft (HEC 169) MD Reference: BCU 5RD2 wp01 RKB @ 178.40usft (HEC 169) North Reference: True Survey Calculation Method: Minimum Curvature Database: Sperry EDM - NORTH US + CANADA Survey Map Map vertical MD Inc Azl TVD TVDSS +NIS +EJ -W Northing Easting DLS Section (usft) (1) (1) (usft) (usft) (usft) (usft) (ft) (ft) (`/100-) (ft) Survey Tool Name 12,005.40 25.42 35.82 11,747.10 11,568.70 1,189.11 432.64 2,435,173.62 317,763.57 1.25 1,160.45 2C13-Film-GMS(2) 12,105.40 24.92 36.50 11,837.61 11,659.21 1,223.45 457.73 2,435,207.56 317,789.19 0.58 1,202.63 2_CB-Film-GMS (2) 12,205.40 24.62 37.12 11,928.41 11,750.01 1,256.99 482.84 2,435,240.71 317,814.81 0.40 1,244.24 2_CB-Film-GMS (2) 12,305.40 24.83 37.41 12,019.24 11,840.84 1,290.28 508.16 2,435,273.60 317,840.65 0.24 1,285.82 2_CB-Film-GMS (2) 12,405.40 24.67 38.11 12,110.05 11,931.65 1,323.38 533.80 2,435,306.30 317,866.79 0.33 1,327.48 2_CB-Film-GMS(2) 12,505.40 24.83 40.76 12,200.87 12,022.47 1,355.70 560.39 2,435,338.20 317,893.88 1.12 1,369.23 2 -CB -Filar GMS (2) 12,605.40 24.42 39.02 12,291.78 12,113.38 1,387.67 58].11 2,435,369.75 317,921.09 0.83 1,410.81 2_CB-Film-GMS(2) 12,705.40 24.83 39.29 12,382.68 12,204.28 1,41998 613.42 2,435,401.64 317,947.90 0.43 1,452.36 2_CB-Film-GMS(2) 12,805.40 23.58 42.08 12,473.89 12,295.49 1,451.07 640.12 2,435,432.32 317,975.08 1.69 1,493.30 2_CB-Fi1m-GMS (2) 12,905.40 22.92 44.42 12,565.77 12,387.37 1,479.83 667.16 2,435,460.65 318,002.55 1.14 1,532.76 2_CB-Film-GMS (2) 13,005.40 22.33 44.77 12,658.08 12,479.68 1,507.22 694.16 2,435,487.62 318,029.98 0.61 1,571.23 2_CS-Film-GMS (2) 13,105.40 20.67 50.91 12,751.13 12,572.73 1,531.84 72125 2,435,511.82 318,057.44 2.79 1,607.73 2_CB-Film-GMS(2) 13,205.40 20.50 56.22 12,844.75 12,666.35 1,552.71 749.50 2,435,532.25 318,086.01 1.87 1,642.31 2_CB-Film-GMS (2) 13,305.40 21.25 57.35 12,938.19 12,759.79 1,572.22 779.32 2,435,551.29 318,116.12 0.85 1,676.99 2_CB-Film-GMS (2) 13,405.40 23.50 58.87 13,030.65 12,852.25 1,592.31 811.65 2,435,570.88 318,148.76 2.32 1,713.81 2-CB-Film-GMS(2) 13,505.40 24.50 60.00 13,122.01 12,943.61 1,612.98 846.67 2,435,591.00 318,184.09 1.10 1,752.91 2_CB-Film-GMS (2) 13,605.40 25.42 63.49 13,212.67 13,034.27 1,632.93 883.84 2,435,610.37 318,221.56 1.74 1,792.96 2_CB-Film-GMS(2) 13,705.40 25.58 64.50 13,302.93 13,124.53 1,65181 92253 2,435,628.64 318,260.54 0.46 1,833.29 2 -CB -Film -GMS (2) 13,805.40 26.50 64.61 13,392.78 13,214.38 1,670.67 962.17 2,435,646.89 318,300.46 0.92 1,874.25 2_CB-Film-GMS (2) 13,905.40 25.75 6345 13,482.56 13,304.16 1,689.94 1,001.76 2,435,665.55 318,340.34 0.91 1,915.48 2_CB-FIIm-GMS(2) 14,005.40 27.17 63.20 13,572.08 13,393.68 1,709.95 1,041.57 2,435,684.93 318,380.46 1.42 1,957.39 2 -C8 -Film -GMS (2) 14,10560 27.58 63.39 13,660.88 13,482.46 1,730.61 1,082.64 2,435,704.95 318,421.85 042 2,00066 2 -CS -Film -GMS (2) 14,205.40 28.75 64.46 13,749.04 13,570.64 1,751.35 1,125.04 2,435,725.03 318,464.56 1.27 2,044.88 2_CB-Film-GMS (2) 14,238.00 28.59 64.81 13,777.64 13,599.24 1,758.05 1,139.18 2,435,731.51 318,478.79 0.71 2,059.47 2_ MWD_Inlerp Ali+Sag(3) 14,281.15 28.90 69.33 13,815.48 13,637.08 1,766.13 1,158.28 2,435,739.29 318,498.02 5.09 2,078.47 2_MWD_Interp Axi+Sag(3) 14,314.01 28.41 72.94 13,844.32 13,665.92 1,771.22 1,173.18 2,435,744.16 318,513.00 5.47 2,092.43 2MWD_Interp Axi+Sag(3) 14,343.19 27.11 76.39 13,870.14 13,691.74 1,774.82 1,186.28 2,435,747.55 318,526.15 7.08 2,104.06 2_ MWD_Interp Axl+Sag(3) 14,375.00 25.32 80.59 13,898.68 13,720.28 1,777.64 1,200.04 2,435,750.16 318,539.95 899 2,115.57 2_ MWD_Interp Azi+Sag(3) 7' TOW 14,403.98 23.81 84.90 13,925.04 13,746.64 i,T79.18 1,211.98 2,435,751.51 318,551.91 8.09 2,124.90 2_MWD _Interp Ac+Sag(3) 14,460.50 21.16 94.91 13,977.28 13,798.88 1,779.32 1,233.52 2,435,751.31 318,573.45 8.22 2,139.83 2_MWD+IFRI+MS+Sag(4) 14,523.01 19.71 96.89 14,035.85 13,857.45 1,777.09 1,255.23 2,435,748.75 318,595.12 2.57 2,153.15 2_MWD+IFR1+MS+Sag(4) 14,582.18 18.42 96.72 14,091.78 13,913.38 1,774.80 1,274.42 2,435,746.16 318,614.27 2.18 2,164.69 2_MWD+IFRI+MS+Sag(4) 14,644.28 18.78 98.24 14,150.63 13,972.23 1,772.22 1,294.05 2,435,743.28 318,633.86 0.97 2,176.34 2_MWD+IFRI+MS+Sag(4) 14,713.22 18.20 100.68 14,216.01 14,037.61 1,768.63 1,315.62 2,435,739.36 318,655.37 1.40 2,188.57 2_MWD+IFR1+MS+Sag(4) 14,769.61 16.92 103.46 14,269.78 14,091.38 1,765.09 1,332.25 2,435,735.56 318,671.94 2.71 2,197.45 2_MWD+IFR1+MS+Sag(4) 14,839.18 16.02 10684 14,336.49 14,158.09 1,760.08 1,351.32 2,435,730.25 318,690.93 1.67 2,206.95 2_MWD+IFRI+MS+Sag(4) 14,902.09 13.97 106.64 14,397.26 14,218.86 1755.50 1,366.94 2,435,725.44 318,706.48 3.27 2,214.38 2_MWD+IFR1+MS+Sag(4) 14,964.29 12.02 110.50 14,457.86 14,279.46 1,75199 1,380.20 2,435,720.82 318,719.67 3.43 2,220.30 2_MWD+IFRI+MS+Sag.(4) 15,026.43 11.07 113.54 14,518.75 14,340.35 1,746.44 1,391.73 2,435,715.99 318,731.13 1.81 2,224.86 2_MWD+IFRI+MS+Sag(4) 91172018 6:50:28PM Page 6 COMPASS 5000.1 Build BIE Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well Beaver CK Unit 5 Project: Beaver Creek Unit TVD Reference: BCU 5RD2 wp01 RKB @ 178.40usft (HEC 169) Site: Beaver Creek Unit MD Reference: BCU 5RD2 wool RKB @ 178.40usft (HEC 169) Well: Beaver CK Unit 5 North Reference: True Wellbore: BCU 5RD2 Survey Calculation Method: Minimum Curvature Design: BCU 5RD2 Database: 'Sperry EDM - NORTH US+CANADA Survey Map Map vertical MD Inc Azi TVD TVDSS +NlS +El -W Northing Easting DLS Section (usft) (') (1) (usft) (usft) (usft) (usft) (ft) (ft) ('1100') (ft) Survey Tool Name 15,089.18 9.64 120.60 14,580.47 14,402.07 1,741.36 1,401.78 2,435,710.75 318,741.09 3.04 2,228.09 2_MWD+IFR1+MS+Sag(4) 15,149.71 9.29 117.89 14,640.18 14,461.78 1,736.49 1,410.46 2,435,705.75 318,749.70 0.94 2,230.53 2_MWD+IFR1+MS+Sag(4) 15,213.79 8.40 123.64 14,703.50 14,525.10 1,731.48 1,418.93 2,435,700.61 318,758.09 1.96 2,232.73 2_MWD+IFRI+MS+Sag(4) 15,276.05 8.01 123.30 14,765.12 14,586.72 1,726.58 1,426.34 2,435,695.60 318,765.42 0.63 2,23427 2_MWD+IFRI+MS+Sag(4) 15,338.35 7.60 126.03 14,826.84 14,648.44 1,721.77 1,433.30 2,435,690.68 318,772.30 DA9 2,235.57 2_MWD+IFRI+MS+Sag(4) 15,399.80 7.64 12323 14,887.75 14,709.35 1,717.14 1,440.00 2,435,685.95 318,778.93 0.61 2,236.83 2_MWD+IFR1+MS+Sag(4) 15,497.31 7.58 122.75 14,984.40 14,806.00 1,710.11 1,450.84 2,435,678.75 318,789.65 0.09 2,239.18 2_MWD+IFR1+MS+Sag(4) 15,586.46 7.08 123.36 15,072.82 14,894.42 1,703.91 1,46037 2,435,672.41 318,799.09 0.57 2,241:24 2_MWD+IFRI+MS+Sag(4) 15,647.48 6.21 124.26 15,133.43 14,955.03 1,699.98 1,466.24 2,435.668.39 318,804.90 1.44 2,242.43 2_MWD+IFRI+MS+Sag(4) 15,680.00 621 124.26 15,165.76 14,987.36 1,698.00 1,469.15 2,435,666.36 318,807.77 0.00 2,243.00 PROJECTED to TD Checked By: Mitch Laird - Approved By: Chelsea Wright r Date: g/17/2O18 9/172018 6:50:28PM Page 7 COMPASS 5000.1 Build 81E Lease 8 Well No. County Hilcorp Energy Company CASING & CEMENTING REPORT BCU-05RD2 Kenai State Alaska Supv. CASING RECORD uners2 TD 15,680.00 Shoe Depth: 15,651.00 PBTD: No. Jts. Delivered 87 No. Jts. Run 62 Fig. Delivered Fig. Run Length Measurements W/O Threads Ftg. Cut Jt. Ftg. Balance RKB 18.00 RKB to BHF RKB to CHF Date Run 17 -Sep -18 R Pederson / J Nicholson No. As. Returned 25 Fig. Returned RKB to THF Csg Wt. On Hook: 219 Type Float Collar: Antelope No. Hrs to Run: Casing (Or Liner) Detail Csg Wt. On Slips: Type of Shoe: Bullnose Setting Depths Jts. Component Size Wt. Grade THD Make Length Bottom Top Baker HRD-E ZXHD 5"x 7" Shoe 5 Liner hanger test pressure: X Yes —No Vol to Surf: BTC Antelope 1.41 15,651.70 15,650.29 2 Liner 41/2 12.6 L-80 DWC 80.76 15,650.29 15,569.53 Float Collar 5 BTC Antelope 1.33 15,569.53 15,568.20 1 Liner 41/2 12.6 L-80 DWC 39.18 15,568.20 15,529.02 Landing Collar 5 DWC JD Hobbs 1.08 15,529.02 15,527.94 59 Liner 41/2 12.6 L-80 DWC 2,539.83 15,527.94 12,988.11 Pup Joint 41/2 12.6 L-80 DWC 4.03 12,988.11 12,984.08 Liner Hanger 7 DWC Baker 29.15 12,984.08 12,954.93 Csg Wt. On Hook: 219 Type Float Collar: Antelope No. Hrs to Run: lacement: Csg Wt. On Slips: Type of Shoe: Bullnose Casing Crew: Weatherford Rotate Csg X Yes No Recip Csg _ Yes X No Ft. Min. 11.5 PPG Fluid Description: OBM Bump Plug? _Yes X No Bump press ig Rotated? X Yes Liner hanger Info (Make/Model): Baker HRD-E ZXHD 5"x 7" Liner top Packer?: X Yes _ No Liner hanger test pressure: X Yes —No Vol to Surf: Floats Held No Centralizer Placement: 36 centralizers on first 36 joints, free floating Estimated TOC: —Yes _ Shoe @ 15651 Preflush (Spacer) Type: Mud J Slurry Class G sity (Ppg) 15.3 Slurry ity (ppg) Flush (Spacer) CEMENTING REPORT FC @ 15,527.00 Density (ppg) Top of Liner 12954 12.5 Volume pumped (BBLs) 25 Sacks: 180 Yield: Volume pumped (BBLs) 52 Mixing / Pumping Rate (bpm): Volume pumped (BBLs) Sacks: Yield: Mixing / Pumping Rate (bpm): 1.64 3 Post Job Calculations: Calculated Cmt Vol @ 0% excess: 50 Total Volume cmt Pumped: 52 Cmt returned to surface: 0 Calculated cement left in wellbore: 52 OH volume Calculated: OH volume actual: Actual % Washout: www.wellez.net WellEz Information Management LLC ver 04818br Density (ppg) Rate (bpm): Volume: _ lacement: OBM Density (ppg) 11.5 Rate (bpm): 4 Volume (actual / calculated): 228. (psi): 1500 Pump used for disp: Halliburton Bump Plug? _Yes X No Bump press ig Rotated? X Yes No Reciprocated? _Yes X No % Returns during job 100 =nt returns to surface? X Yes —No Spacer returns? X Yes —No Vol to Surf: 0 int In Place At: 23:59 Date: 9/17/2018 Estimated TOC: 14,805 od Used To Determine TOC: CBL Post Job Calculations: Calculated Cmt Vol @ 0% excess: 50 Total Volume cmt Pumped: 52 Cmt returned to surface: 0 Calculated cement left in wellbore: 52 OH volume Calculated: OH volume actual: Actual % Washout: www.wellez.net WellEz Information Management LLC ver 04818br BC 5rd2 Remediation of 4 %:" Liner Leak Procedure 1. RU E line. MU BP on E line with CCL. 2. RIH with BP. Correlate on depth and set at 13,020' WLM 3. POH. Pick up tubing punch, 3' at 6 spf @ zero phasing. 4. RIH with punch. Tag BP and PU guns to perf from 13,015'- 13,018'WLM. 5. Fire guns & POH. 6. PU 7" cement retainer and RIH. 7. Correlate 7" retainer and set at 12,910' WLM. 8. POH and RD E line. 9. PU 4 %" DP and retainer stinger assembly. 10. RIH to above retainer. C&C mud until good 10.2 ppg mud in and out. 11. RU cementers. Mix and pump 5 bbls water followed by 30 bbls of 15.8 ppg squeeze cement followed by 5 bbls water. 12. Spot 5 bbls water and cement to the cement stinger with 183.5 bbls of 12 ppg mud. 13. Stab into the retainer and establish injection with the 5 bbls of water and squeeze away 28 bbls of cement. 14. Unsting from retainer and pump last 2 bbls of cement on top of the retainer. 15. POH 5 stands, drop foam ball in DP and circulate while rotating to clean up DP. On bottoms up look for signs of cement. 16. Monitor hole for sign of flow. 17. POH. 18. PU 6" milltooth bit and RIH to 12,850' MD. C&C mud if minimum 24 hours from CIP has been met. Check surface samples as well. 19. Wash down stand until takes weight. PU and begin rotating. 20. Drill up retainer at 12,910' WLM. 21. Drill out to TOL in 7" @ 12,954' DPM. CBU or until mud returns clean. 22. Monitor well for flow. 23. POH. 24. PU 3 3/8" mill and clean out BHA. RIH and drill out cement and BP. Push any remnants of BP to landing collar @ 15,529' MD. 25. Monitor well for flow. No flow C&C mud. 26. Pressure test to 1200 psi in 400 psi increments for 20 min. 27. If PT was successful swap wellbore to diesel and POH. / 28. RU a -line and run Cement Bond Log from 14,850'-12,955'. 29. Continue at step #5 in Sundry 318-406 (perforate and run completion). Schwartz, Guy L (DOA) From: Paul Mazzolini <pmazzolini@hilcorp.com> Sent: Tuesday, October 9, 2018 7:18 AM To: Schwartz, Guy L (DOA) Subject: BC 5 rd2 Update Guy, Good morning. Monty is away and I am filling in for him. Here is an update on the BC Srd2 saga. Yesterday PNL logs were run in the well to find the leak allow the Tyonek high pressure water sand to flow into the wellbore. The log shows the leak occurring about 12,980' MD which is where the liner hanger equipment is placed with the top of the initial 4 %2" liner located at 12,955' MD. Plan forward is to squeeze cement to remediate the leak and gain integrity for the 4 %2" liner and wellbore. Basic steps: 1. Set abridge plug in the 4'/2" liner +/- 13,050' MD 2. Perf 4 %" liner 13,010'-13,020' 3. Set retainer in 7" casing +/- 12,900' MD 4. Squeeze cement through retainer and hold pressure A more detailed procedure is being built and will be submitted to you before any work will begin. Present status at rig: Tripped out of hole with drill pipe. Waiting on Eline to run BP. Well shut in but will flow at 7 BPH with 10.2 ppg mud in hole. I will call you this morning to discuss. Mazz Schwartz, Guy L (DOA) From: Rance Pederson - (C) <rpederson@hilcorp.com> Sent: Thursday, October 4, 2018 3:06 PM To: Regg, James B (DOA) Cc: Jones, Jeffery B (DOA) Subject: Hilcorp Rig 169 Update Mr Regg, Early this morning we displaced well BCU 05RD2 to diesel, in prep to make our perf gun run after testing BOPE. After pulling 500' of drill pipe, well started flowing at 22 bbls per hour. This is after having installed a second 7" liner top packer. We have circulated out and dumped 71 bbls water, pressured up on casing twice with little to no pressure loss over 30 minutes each time. We are currently sitting at 14,931' circulating and waiting on orders from town. Will most likely displace well back to our OBM stored on site and kill the well again. Looks like we will have to do some testing with test packer or sonic tools on a -line and try to determine where we are taking water influx. Once well is dead testing BOPE will be our top priority. I will update both you and Mr Jones as we progress. Rance Pederson Drilling Foreman Beaver Creek Unit 907-776-6776 DATE 10/26/2018 Seth Nolan Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 Fax: 907 777-8510 E-mail: snolan@hilcorp.com To: Alaska Oil & Gas Conservation Commission Meredith Guhl Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA SAMPLE INTERVAL TRANSMITTA 14240-15100 BCU 5RD2 2 boxes: Dry Cuttings Transmitted herewith are cuttings from KBU 31-06x WELL SAMPLE INTERVAL BCU 5RD2 14240-15100 BCU 5RD2 15100-15680 Please include current contact information if different from above. aiB-c)(og )(' 4('q Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By• / V l Date: 11/2-116 Schwartz, Guy L (DOA) From: Sent: To: Cc: Subject: Schwartz, Guy L (DOA) Tuesday, October 09, 2018 2:17 PM 'Paul Mazzolini' mmyers@hilcorp.com RE: BC 5rd2 Liner Leak Remediation Pro Paul, You have approval to repair the 4 1/2 " liner top leak as proposed in your attached procedure using cement. Hopefully this will isolate the water source and allow the well to be completed as originally proposed. The liner must pressure test to at least 1200 psi and pass a drawdown test with diesel in the wellbore. Update the MOC form with the changes. Good luck. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at (907-793-1226 ) or (Guy.schwortz@alaska.aov). From: Paul Mazzolini <pmazzolini@hilcorp.com> Sent: Tuesday, October 09, 2018 12:58 PM To: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Subject: BC 5rd2 Liner Leak Remediation Guy, Please find the attached remediation Procedure for the 4 W liner leak on BC 5 rd2 for your review and approval. Also, attached are the log section that shows the area of the leak entering the 4 %z" liner as well as the 4 %" casing tally and liner hanger equipment. I would like to get verbal approval to RIH and set the BP in the 4 %:" liner so as to allow rig operations to move forward. Thanks in advance for your time. Regards Paul BC 5rd2 Remediation of 4'/2" Liner Leak Procedure 1. RU E line. MU BP on E line with CCL. 2. RIH with BP. Correlate on depth and set at 13,020' WLM 3. POH. Pick up tubing punch, 3' at 6 spf @ zero phasing. 4. RIH with punch. Tag BP and PU guns to perf from 13,015' - 13,018' WLM. 5. Fire guns & POH. 6. PU 7" cement retainer and RIH. 7. Correlate 7" retainer and set at 12,910' WLM. 8. POH and RD E line. 9. PU 4 ''/z" DP and retainer stinger assembly. 10. RIH to above retainer. C&C mud until good 10.2 ppg mud in and out. 11. RU cementers. Mix and pump 5 bbls water followed by 30 bbls of 15.8 ppg squeeze cement followed by 5 bbls water. 12. Spot 5 bbls water and cement to the cement stinger with 183.5 bbis of 12 ppg mud. 13. Stab into the retainer and establish injection with the 5 bbis of water and squeeze away 28 bbis of cement. 14. Unsting from retainer and pump last 2 bbis of cement on top of the retainer. 15. POH 5 stands, drop foam ball in DP and circulate while rotating to clean up DP. On bottoms up look for signs of cement. 16. Monitor hole for sign of flow. 17. POH. 18. PU 6" milltooth bit and RIH to 12,850' MD. C&C mud if minimum 24 hours from CIP has been met. Check surface samples as well. 19. Wash down stand until takes weight. PU and begin rotating. 20. Drill up retainer at 12,910' WLM. 21. Drill out to TOL in 7" @ 12,954' DPM. CBU or until mud returns clean. 22. Monitor well for flow. 23. POH. 24. PU 3 3/8" mill and clean out BHA. RIH and drill out cement and BP. Push any remnants of BP to landing collar @ 15,529' MD. 25. Monitor well for flow. No flow C&C mud. 26. Pressure test to 1200 psi in 400 psi increments for 20 min 27. If PT was successful swap wellbore to diesel and POH. (L Z 28. RU a -line and run Cement Bond Log from 14,850'-12,955'. 29. Continue at step #5 in Sundry 318-406 (perforate and run completion). n rl L O uY ko V C C O O 0.0 Q. 0 ~ 0 ~ 1I.X11 n M ,= O p N O uY ko V C C O O 0.0 Q. 0 ~ 0 ~ 1I.X11 n M O_ O " l0. ' %D o CD 0 O THE STATE 01ALASKA GOVERNOR BILL WALKER Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beaver Creek Field, Beaver Creek Oil Pool, BCU 05RD2 Permit to Drill Number: 218-068 Sundry Number: 318-406 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage. Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.olaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. Foerster Commissioner DATED this J' day of October, 2018. RODMCCACT 0 2 2018 STATE OF ALASKA SEP 1 7 2018 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC, 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Strap Well ❑ Alter Casing ❑ Other: Initial Completion Q 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development D • Stratigraphic ❑ Service ❑ 218-068 - 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-20262-02-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 237B Will planned perforations require a spacing exception? Yes ❑ No ❑✓ Beaver Creek Unit (BCU) 05RD2 9. Property Designation (Lease Number): 10, Field/Pool(s): FEDA028083 Beaver Creek / Beaver Creek Oil Pool it. PRESENT WELL CONDITION SUMMARY Total Depth MO (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 15,680' 15,165 15,680' 15,165' 3,723' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 432' 20" 432' 432' 1,530psi 520psi Surface 3,511' 13-3/8" 3,511' 3,511' 3,090psi 1,540psi Intermediate 11,698' 9-5/8" 11,698' 11,465' 9,440psi 5,300psi Liner 3,387' 7" 14,918' 14,377' 12,460psi 10,780psi Liner -2,680' 4-1/2" 15,680' 15,165' 9,020psi 8,540psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3-1/2" , 2-3/8" 9.39 / L-80, 4.7# / L-80 12,960' / 14,940' Packers and SSSV Type: Tripoint DLH Pkr, NA Packers and SSSV MD (ft) and TVD (ft): 14,880' MD - 14,376' TVD, NA 12. Attachments: Proposal Summary Q Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic ❑ Development Service ❑ 14. Estimated Date for PC, 15. Well Status after proposed work: September28, 2018 Commencing Operations: OIL ❑� WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson 777-8405 Contact Name: Taylor Nasse Authorized Title: Operations Manager Contact Email: tnasseQhilcorp.com Contact Phone: 777-8354 Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: U Plug Integrity ❑ BOP Test D Mechanical Integrity Test ❑ Location Clearance ❑ Other:�y5a, Pt.: eocA /ez4'� RBDMS5(-' 22018 ;F 2500,osL /}..r.. %K Izs 1— Post Initial Injection MIT Req'd? Yes No //// t . / I/ \ W ex � / Spacing Exception Required? Yes ❑ No d Subsequent Form Required: / t) ^ t] % ( APPROVED BY IO(� I X Approved by: COMMISSIONER THE COMMISSION Date: 'U D � � I ✓ Su mtt Du lice d Form 10-403 Revised 41 17 Approved applicati d dlt�s t e date of approval. cnm Is in Du lira H Hileorp Alaska, LG Well Prognosis Rev. 0 Well: BC 05RD2 Date: 9/16/2018 Well Name: BC-05RD2 API Number: 50-133-20262-02 Current Status: Drilled, Running Casing Leg: N/A Estimated Start Date: September 22nd, 2018 Rig: Rig # 169 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 218-068 First Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 903-0341 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) L AFE Number: Maximum Expected BHP: 5,200 psi @ 14,764' TVD Static Buildup on 11/19/16 (Extrapolated) Max. Potential Surface Pressure: — 3,723 psi (0.10 psi/ft gas gradient) Brief Well Summary Well BCU-OSRD was drilled and completed as a sidetrack of the original BCU -05 in 1976. The well was fracture stimulated in 1991 but it is believed that the sand fracture failed due to improper proppant crush resistance. The tubing was replaced in 2014 to remove an unset tubing patch in the old tubing. The sidetrack was recently plugged back and sidetracked again and reached TD on 9/13/18. The purpose of this work/sundry is to perforate and complete the new sidetrack. �/ Notes Regarding Wellbore Condition • Rig #169 rigged up on well and currently running 4-1/2" liner. • Pressure test casing to 3,500 psig will be completed. • Continue BOP testing frequency from Drilling Program (PTD 218-068) through completion. • A cement bond log will be ran prior to perforating and completing the well. • psvr • The well will be filled with diesel prior to perforating. Rig #169 Procedure: Note: This procedure begins after step 17.5 of the 10-401 Permit to Drill approved on 7/11/18. 1. Install necessary BOP equipment for running the completion and test (if not previously installed). a. Double ram should be dressed with 2-3/8" x 5" VBR in top cavity, blind ram in btm cavity. b. Single ram should be dressed with 2-3/8" x 5" VBR. c. Test any new BOP components to 250/4500 psi for 10/10 min. Test annular to 250/2500 psi for 10/10 min w/ 2-3/8" and 3-1/2" test joints. d. Ensure to leave "A" section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. Confirm the correct valves are opened. 2. LD BOP test equipment. 3. MIRU E -line on drilling rig, PT lubricator to 4,000 psi Hi 250 Low. 4. RIH and run Cement Bond Log from PBTD to "'13,000' MD (top of 4-1/2" liner). POOH. LD CBL tool. a. Send logs to town for correlation log. D>� b. Final perf depths will be based on CBL results-" 5. PU Perf guns and RIH to 15,500'. L/o��ggg on depth to perforate t ollowing G-2 Sands: TC GIF &e.+�n)(-o w/ ras� K IIil.m AI.A.x U - Zone Top Md Btm Md Top Btm TVD TVD G2 15,306 15,330 14,794 14,818 G2 15,432 15,456 1 14,920 14,944 Well Prognosis Rev. 0 Well: BC OSRD2 Date:9/16/2018 6. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. 7. Fire guns. 8. POOH. 9. Close upper rams and pressure up with diesel to establish injection and verify connection to reservoir. 10. Monitor fluid level and pressure. Circulate KW fluid as needed to ensure well is stable. 11. RD a -line. 12. PU 4-1/2" hydraulic packer and completion jewelry and RIH w/ completion on 2/3/8" and 3-1/2" tubing. Minimize excess pipe dope when running completion. Completion jewelry per proposed schematic: e. WL entry guide f. X -nipple (RHCP plug body loaded) g. 4-1/2" Packer ,- h. Gaslift mandrels i. 3-1/2" x 2-3/8" crossover j. X -nipple k. Gaslift mandrels (live) I. 3-1/2" Tubing Hanger 13. RIH at slow to moderate speed after entering 4-1/2" liner at —13,000. Space out packer at ^14,880. 14. Drop setting bar/ball. 15. Pressure up tubing to set the packer and hold for 15 minutes. 16. Land tubing in hanger. Close the lockdown pins. 17. Test tubing to 4,500 psi for 30min with chart. 18. Test annulus to1,e500'psi for 30 min with chart. 2apOP' 19. LD landingjoint. Set BPV. ND BOPE. NU Tree. Pull BPV. 20. Set TWC. Test hanger to 250/5,000 psi. Test Tree to 250/5,000 psi. Pull TWC. 21. RD Rig #169 Drill Rig. 22. Turn well over to Hilcorp Operations. Attachments 1. Proposed Schematic 2. BOPE Schematic 3. Wellhead Schematic 4. Blank RWO Procedure Change Form BC - Pad d3 3 1,195' WL, 1,41,495' FWL, Hllcarg Alaska, LLC Sec. 34, T7N, R10W, S.M. 175-055 50-133-20262-02 s: A-028083 lion: 173' (18'AGL) T2-/19/1975109/09/2018 (RD2) 15,680' (RD2) ased: TBD Tree cap = 6-112" Otis I�i1:90325 ,IC,Wrel Depth Valve Tvge Tight spot on casing wall 13,060'-13,086' milled w/ 5.797" mill 13,073' Tag w/ 5.75" OD overshot (3/ 13,123' Tag w/ 5.50" UB (3/28/1 TD PBTD 15,680' MD -15,600' MD 15,165' TVD -15,086' TVD PROPOSED SCHEMATIC Conductor Casing 20" H40 94 ppf Too Bottom MD 0' 432' TVD 0' 432' Surface Casing 13-3/8" K-55 61 ppf TBD Top Bottom MD 0' 3,511' TVD 0' 3,511' Intermediate Casing 9-5/8" P-110 47 ppf Tog_ Bottom MD 0' Ti TVD 0' 11,465' Liner 7" P-110 32 ppf TOP Bottom MD 11,531' 14,918' TVD 11,322' 14,377' Liner 4-1/2" L-80 12.6 ppf TOP Bottom MD -13,000' -15,680' TVD -12,653' -15,165' Tubing 3-1/2" L-80 9.3 ppf Tgla Bottom MD 0' -12,960' TVD 0' -12,623' Tubing 2-3/8" L-80 9.3 ppf TBD Tim Bottom MD -12,960' -14,940' TVD -12,623' -14,435' Well Name &Number: Beaver Creek Unit#5RD2 Lease: I A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:L USA An le @KOP and Depth: 28° @ 14,238' 1 Angle/Perfs: 7° Maximum Deviabon: 29.0° @ 14,281' Date Completed: TBD Ground Level (above MSL): 155' RKB (above GL): 18' Revised By: Taylor Nasse Downhole Revision Date: TBD Schematic Revision Date:1 9/14/2018 H 9i"rp Ala.ka. IIA: Beaver Creek BC-05RD2 BOP 09/17/2018 Rig #169 BOP stack Beaver Creeko BC #5RD2 Proposed xilMrp AI..►.. E.E.E: 09/17/2018 Beaver Creek BC N5RD2 20 x 733/8 x95/8 x3% BHTA, Otis, 3 1/8 5M FE x 6.5" Otis quick union top Valve, Swab, CIW-FLS, 3 1/8 SM FE, H W 0, EE trim Valve, Master, CIW-FLS, 31/85M FE, HWO, EE trim Valve, Master, CIW-FLS, 3 1/8 5M FE, H W0, EE trim Tubing head, FMC -TC -BG, 13 5/8 5M x 115M, w/ 2- 21/16 5M S5O Casing spool, OCT- C -22 -BP - 00, 21 Y." 2M x135/SSM, w/ 2- 3 1/8 5M EFO Starting head, OCT -C22, 211/4" 2M x 20" SOW, w/ 2- 2 1/16 5M EFO 13 3/8" 95/8- W, 5/8"%„ Tubing hanger, FMC -TC -EN - CCL, 11 x 3 % EUE 8rd lift and cusp, w/ 3" type H-BPV profile, 2-%npt control line port, 6Y. EN G\�� N\'1'�aJgc � i 31IgoPat2 Adapter, FMC -ASP -CCL, 115M stdd x 3 1/8 5M, w/ 2- 1" npt control line exits r�� a) �do 4-7o c U �6 m c � U C7O O am f0 � L U U V C � d N a E r E CL 5 C c dN aro E 2 d M a 3 0 - M �• TE � a a) c _z 3 O �a) m c> an zw oa m o � c a'9 a v r m m o U c m y ._ o rn a m N c a� m U 0 C� U o_ Co N t Y o Uw i m 0 o a rn `° CL CL �° 0 m �a N d co N o c D � m 3 a " i U mU ao U N (D w �o � m E v a c 0 C a == d a a U a a o- �.l XO CL Q m '0 ea a O m y Q w 3 R Q w A m m c U Q U O it U V y fp Q OQ F4 r�� do U �6 m c U C7O O am ¢ as V d N a CL 5 dN 2 d M a M �• C) a � _z m c> zw m rn c a r U 7 a m U 0 o_ Y 0 m rn CL CL 0 m N El V m 'O d m Q N W m D LL Schwartz, Guy L (DOA) From: Taylor Nasse <tnasse@hilcorp.com> Sent: Monday, October 01, 2018 11:38 AM To: Schwartz, Guy L (DOA) Cc: Chad Helgeson; Donna Ambruz Subject: BC-05RD2 (PTD 218-068) CBL results Attachments: BC5RD2 CBL.pdf Hi Guy - Attached are the results of the CBL that we ran this weekend on BC-05RD2. Overall, the cement looks great starting from 14,805' to bottom and it looks like we have good isolation between the high pressure water zone that ends at around 14,806' and the G-2 intervals that we propose to perforate starting at 15,306'. If you have any questions or need additional information, please feel free to contact me. Thanks, Taylor W. Nasse, PE Operations Engineer Kenai Asset Team Hilcorp Alaska, LLC (907) 777-8354 office (907) 903-0341 cell 11 1 n11) Z►606, Regg, James B (DOA) From: Robert Wall - (C) <rwall@hilcorp.com>JI I ✓� Sent: r Friday, September 28, 2018 5:59 PM 7 To: Regg, James B (DOA); 'Eagle, Amanda'; BLM_AK_AKSO_EN ERGYSECTION_NOTIFICATIONS@BLM.GOV Cc: Monty Myers Subject: Rig 169 Hilcorp notice of BOPE repair and retest. 9.28.2018 Attachments: Hilcorp Rig 169 Notice of BOP Repair.9.28.2018. test..docx Jim, Please find enclosed a description of our actions taken today after observing element rubber out of place, off driller side blind rams. Robert Wall Drill Site Manager Hilcorp Alaska, LLC HAK 169 907-776-6776 U Notice of BOP Repair • Date/Time: 9/28/2018 at 13:00 hrs. Completed: 17:30. • Well: BCU 05RD2 • Location: Beaver Creek Field • PTD: 218-068 • Rig Name: Hilcorp 169 • Operator Contact: Robert Wall 907-776-6776 rwall@hilcorp.com • Summary: After laying down BHA #6 Mill assembly that milled cement inside the 4.5" DWC/C 12.6# liner. The MPD system and the rig choke system were flushed with 80 bbls soapy water. The blinds were then closed to protect the wellbore while a XO was broke off of the 7" scraper. Blinds were opened after the XO work was complete. The Driller looked down hole and saw a piece of the rubber on the off Driller side blind ram out of place. • Actions Taken: The test joint was picked up, test plug installed and set in the wellbore. Ram doors opened up, and both the ram blocks removed. Both rubber elements were inspected. Driller side rubber was good, off driller side rubber was trimmed to a straight line. Top thin margin of rubber had peeled down, sealing face was still 100% good. The Blinds were closed up, and tested. 250 psi low, 4500 psi high, charted each for 10 mins. Good test. • Actions to be taken: Continue to inspect all rams between wells and replace rubbers proactively. A new set of blind ram rubbers will be installed prior to the next full test on October the 4th. 2018. THE STATE 01ALl SKA GOVERNOR BILL WALKER Monty Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beaver Creek Field, Beaver Creek Oil Pool, BCU-05RD2 Hilcorp Alaska, LLC Permit to Drill Number: 218-068 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fox. 907.276.7542 www.aogcc.alaska. gov Surface Location: 1267' FNL, 1465' FWL, SEC. 34, T7N, RI OW, SM, AK Bottomhole Location: 538' FSL, 2124' FEL, SEC. 27, T7N, R10W, SM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to redrill the above referenced development 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 1' day of July, 2018. STATE OF ALASKA I ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Type of Work: . 16Proposed Well Class: Ex lorato Gas L0 AAU 25.005 P ❑ Lateral ❑ [rill ❑� Reentry❑ ❑ Stratigraphic Test ❑ �'- Service- WAG Development - Oil • Service - Winj ❑ Service -Disp Single operator Name: Exploratory -Oil ❑ Development - Gas ❑ Service -Su I ❑ PPY Zone Multiple Zone Dip Alaska, LLC 15. Distance to Nearest Well Open 5. Bond: Blanket Q • Single Well 0 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 Location of Well (Governmental Section): ace: 1267' FNL, 1465' FWL, Sec 34, T7N, R10W, SM, AK Of Productive Horizon: I Depth: 643' FSL, 2331' FEL, Sec 27, T7N, R10W, SM, AK 538' FSL, 2124' FEL, Sec 27, T7N, R10W, SM, AK ocation of Well (State Base Plane Coordinates - NAD 27): ice: x-317312.59' y- 2433991.43' Zone -4 Maximum Hole Angle: 28 Grade Bond No. 022035244 - RECEIVED JUN o 4 2018 Specify if well is proposed for: tibed Gas ❑ Gas Hydrates ❑ tthermal ❑ Shale Gas ❑ BCU-05RD2 MD: 15,867' TVD: 15,300' Beaver Creek Unit erty Designation: Hewwrcfc oil Pool FEDA028083t ✓e.rC.xX f4 13. Approximate Sputl Date: EEE4EE 7/15/2018 14. Distance to Nearest Property: 10KB Elevation above MSLft8.4' 2331'to nearest unit boundary GL / BF Elevation above MSL (ft): 15. Distance to Nearest Well Open 7. Maximum Pottpiwl Pressures in .4' to Same Pool: 3, 122'to BCU 04 psig (see 20 AAC^ >ownhole: 7.SU ^2�5.0 5) Surface' 4y/2/,'5' MD PRESENT WELL CONDITION SUMMARY (To be completed for Reddll and 15,655' 15,061' I .. N/A 11 G7 8 Lower G Hydraulic Fracture planned? Yes ❑ No Q 20. Attachments: Property Plat 0 BOP Sketch Diverter Sketch M. Verbal Approval: Commission Representative: ?2. I hereby certify that the foregoing is true and the proced leviated from without prior written approval. rermit to Number: 15,607' tentvol 1000 sx 2500 sx 2520 sx 1010 sx 450 sx Drilling Program Seabed Report Date: In Use Only MD TVD 1,867' 15,300' ry Operations) Effect. Depth 1 15,015' MD 432' Time V. Depth Plot fiI Fluid Program Date Contact Name: Contact Email: Contact Phone: or 15,446 / 15,307' (Fill) 11 Shallow Hazard 20 AAC 25.050 reau "" .-r /_ /^ API Number: Permit Approval �./ G� 50- / j�j — uj�Z ^(jam 4) ID' See cover letter for other Date: II I requirements. Of approval .: If box is checked, well may not be used to explore for, test, or produce coalbed meth, gas hydrates, or gas contained in shales: 1B6 in 6 �'��' -T-0 l.) S-� ^ ,5 � Samples req'd: Yes ❑ No '" Mud log req'd: Yes❑ Noo HzS measures: Yes ❑ No Directional svy req'tl: Yesd Nooi Spacing exception req'd: Yes ❑ No� Inclination -only sly req'd: Yes❑ No Post initial injection MIT req'd: Yes❑ NOR Approved by: COMMISS IO NE R +rtG k 14 �a 20(8 ESO Rh1 * r�d�� k. Form 70-401 Revised 5/2 A T 017 This permit is valid for 'fix\ APPROVED BY THE COMMISSION per 20 AAC 25.005(g) Dater It r Ile Submit Form and Attachments in Duplicate U Hilcorp �� cmmr 6/4/2018 Monty Myers Drilling Engineer Commissioner Alaska Oil & Gas Conservation Commission 333 W. Th Avenue Anchorage, Alaska 99501 Re: BCU-05RD2 H ilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 Tel 907 777 8431 Email mmyem@hilcorp.com Dear Commissioner, BCU 05RD2 is an oil producer planned to be re -drilled in a North-easterly direction from the existing BCU 05RD utilizing the existing casing program down to 14500' MD / 14008' TVD. At 14500' MD the parent wellbore will be sidetracked and new wellbore drilled penetrating several Hemlock targets. A 1500'x 5-7/8" open hole section is planned. A 4-1/2" 12.6# L-80 DWC/C prod liner will be run, cemented, and perforated based on data obtained while drilling the interval. The well will be completed with 3-1/2" production tubing string. Drilling operations are expected to commence approximately July 151h, 2018. If you have any questions, please don't hesitate to contact myself at 777-8431 or Paul Mazzolini at 777-8369. Sincerely, Monty Myers Drilling Engineer Hilcorp Alaska, LLC Page 1 of i Hilcorp Alaska, LLC BCU-05RD2 Drilling Program Beaver Creek R! dby: M o t 15_ ZN1. s Revision 0 May 20, 2018 K Ilileorp Alaska, r.l.0 Contents 1.0 Well Summary BCU 05RD2 Drilling Procedure Rev 0 2.0 Management of Change Information............................................................................................3 3.0 Tubular Program............................................................................................................................4 FIT Procedure................................................................................................................................38 4.0 Drill Pipe Information.....................................................................................................................4 Choke Manifold Schematic...........................................................................................................39 5.0 Internal Reporting Requirements..................................................................................................5 Casing Design Information...........................................................................................................40 6.0 Planned Wellbore Schematic..........................................................................................................6 7.0 Drilling Summary ............................................................................................................................7 30.0 8.0 Mandatory Regulatory Compliance / Notifications.....................................................................8 31.0 9.0 R/U and Preparatory Work..........................................................................................................11 32.0 10.0 BOP N/U and Test.........................................................................................................................12 11.0 Mud Program and Density Selection Criteria............................................................................13 12.0 Whipstock Running Procedure....................................................................................................14 13.0 Whipstock Setting Procedure.......................................................................................................17 14.0 Drill 5-7/8" Hole Section...............................................................................................................19 15.0 Run 4-1/2" Production Liner........................................................................................................22 16.0 Cement 4-1/2" Production Casing...............................................................................................25 17.0 Wellbore Clean Up & Displacement............................................................................................29 18.0 Run Completion Assembly...........................................................................................................30 19.0 RDMO............................................................................................................................................30 20.0 BOP Schematic..............................................................................................................................31 21.0 Wellhead Schematic......................................................................................................................32 22.0 Days vs Depth.................................................................................................................................33 23.0 Geo-Prog.........................................................................................................................................34 24.0 Anticipated Drilling Hazards.......................................................................................................36 25.0 Rig Layout......................................................................................................................................37 26.0 FIT Procedure................................................................................................................................38 27.0 Choke Manifold Schematic...........................................................................................................39 28.0 Casing Design Information...........................................................................................................40 29.0 5-7/8" Hole Section MASP............................................................................................................41 30.0 Spider Plot (Governmental Sections)...........................................................................................42 31.0 Surface Plat (As-Built)..................................................................................................................43 32.0 Surface Plat (As Built-Zoomed)...................................................................................................44 33.0 Directional Program(WP02)........................................................................................................45 U lhkoq, Alaska. LIX 1.0 Well Summary BCU 05RD2 Drilling Procedure Rev 0 Well BCU 05RD2 Pad & Old Well Designation Sidetrack of existing well BCU 05RD (PTD#91-241) Planned Completion Type 4-1/2" 12.6# L-80 Liner Target Reservoirs Hemlock HI through H5 ' Planned Well TD, MD / TVD •15867' MD / 15300' TVD PBTD, MD / TVD 15763' MD / 15200' TVD Surface Location (Governmental) 1267' FNL, 1465' FWL, Sec 34, T7N, RI OW, SM, AK Surface Location (NAD 27) X=317312.59, Y=2433991.43 Surface Location (NAD 83) X=1457333.75, Y=2433752.33 Top of Productive Horizon (Governmental) 643' FSL, 2331' FEL, Sec 27, T7N, RI OW, SM, AK TPH Location AD 27) X=318789.1, Y=2435813.23 TPH Location AD 83) X=1458810.33, Y=2435813.23 BHL (Governmental) 538' FSL, 2124' FEL, Sec 27, T7N, RI OW, SM, AK BHL (NAD 27) X=318994.77, Y=2435705.2 BHL AD 83) X=1459015.99, Y=2435466.02 AFE Number 1810833D AFE Drilling Das 30 AFE Drilling Amount $5.18 MM Drilling / $944 M Completion Work String 4-1/2" 16.6# S-135 CDS-40 RKB — AMSL 18' KB — 178.4' AMSL Ground Elevation 160.4' AMSL BOP Equipment 11" 5M Townsend Type 90 Annular BOP 11" 5M Townsend Type 82 Double Ram 1 I" 5M Townsend Tye 82 Single Ram Page 2 Revision 0 May 2018 U fliL'orp \la.ka, LLC 2.0 Management of Change Information BCU 05RD2 Drilling Procedure Rev 0 H Hilcorp Alaska, LLC Hj1corp Changes to Approved Permit to Drill Date: May 20, 2018 Subject: Changes to Approved Permit to Drill for BCU 05RD2 File #: BCU 05-RD2 Drilling Program Any modifications to BCU 05-RD2 Drilling Program will be documented and approved below. Changes to an approved APD will be communicated and approved by the AOGCC prior to continuing forward with work. Approval: Monty M Myers Drilling Manager Date Prepared: Drilling Engineer Page 3 Revision 0 May 2018 H nil.p Al.kn, LIA: 3.0 Tubular Program BCU 05RD2 Drilling Procedure Rev 0 4.0 Drill Pipe Information off'%70D(iin) Section ID (in) T.11D in TJ OD ` (in) , Conn Bu ' . si k-1 5-7/8" 4" 3.34" 2-9/16" 4-7/8" 15.65 S-135 HT -38 18400 13800 403 5-7/8" 1 4-1/2" 3.826" 2-11/16" 5-1/4" 16.6 5-135 CDS-40 17693 16769 595k All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Revision 0 May 2018 H nil.rp Alaska, LIX 5.0 Internal Reporting Requirements BCU 05RD2 Drilling Procedure Rev 0 18.1 Fill out daily drilling report and cost report on Wellez. i. Report covers operations from 6am to 6am ii. Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area— this will not save the data entered, and will navigate to another data entry tab. iii. Ensure time entry adds up to 24 hours total. iv. Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. 18.2 Afternoon Updates i. Submit a short operations update each work day to pmazzolini@hilcorp.com, mmyers@hilcoEp.com and cdinger(ii),hilcorp.com 18.3 Intranet Home Page Morning Update i. Submit a short operations update each morning by lam on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. Each rig will be assigned a username to login with. 18.4 EHS Incident Reporting i. Notify EHS field coordinator. 1. This could be one of (3) individuals as they rotate around. Know who your EHS field coordinator is at all times, don't wait until an emergency to have to call around and figure it out!!!! a. John Coston: O: (907) 777-6726 C: (907) 227-3189 b. Matt Hogge: O: (907) 777-8418 C: (907) 227-9829 2. Spills: Keegan Fleming: 0:907-777-8477 C:907-350-9439 ii. Notify Drlg Manager 1. Monty M Myers: O: 907-777-8431 C: 907-538-1168 iii. Submit Hilcorp Incident report to contacts above within 24 hrs 18.5 Casing Tally i. Send final "As -Run" Casing tally to minyers@hilcoa2.com and cdinger@ ilcorp.com 18.6 Casing and Cmt report i. Send casing and cement report for each string of casing to mmyers@hilcorp.com and edinger@hilco!p.com Page 5 Revision 0 May 2018 U IRicnrp .M.A., LIA: 6.0 Planned Wellbore Schematic BC - Patl 3 3 1,195' , W , R10 F S.M.In",. Ad..". I.II Sec. 34, WN, R10W, S. e mKfi TBD API W, TBD Prop. Des. A-028083 I ale a on: 173' (18'AGL) Saud: 12/19/1975 L 15,655 Rla Released: 323M 976 2 0ebrle on lasing wall 13,073' Tag w/ 5.75. OD overshot (3/24/1 13,123' Tag W/ &W 118 (3/28/14) 15,861 MD 15.300' mo 15,783'MD 15,200' TVD BCU 05RD2 Drilling Procedure Rev 0 PROPOSED SCHEMATIC cmOu[lor casbw 2Y HdU 9•ppi 792 @RB9m MD 0 432' TVD a 43z' 1339- Too 6@qg MD a 3.511 TVD 0' 3,511' Fw PT --11110 M11 11.465' MD V 11,698' TVD a 11,465' Liner 7- P-110 M ppr 79Qagum Kenai PeP»9YM Bprou9h MD 11,531' 14,91&' TVD 14,500 14,006' LIM 4-12- L-00 12.6 pet 199 Bells MD 14,400' 15,661 TVD 13,38a 15,3W Pump 40 bbls of 15.8 ppg class cement. Planned cement top Is at the top of the finer at 14,400' Well Name&Numb.[ Beaver Creek UbK a5BD2 Laaae: •-028083 County or I.a. Kenai PeP»9YM Bprou9h 506eIPrw. Alaska cuaa*y I use M91e OPann D.1N 2V@14-• Aagi P,rrs: 28° Maimum Deviabon 28 1114tSY Dale Cpmplauw6 G_rouna L.1 (ab. Mgt). I 15S' RKB(abwe GLI 18' Revlsea Bzl _ M.5l3era I Downhole RwAslonD cl I scaerwa-CReasiancaawl 5242018 Page 6 Revision 0 May 2018 R Ililvo,, Alw+kn. LL(I 175-055 50-133-20262-01 A-028083 m: 173' (18'AGL) 15,655' axed: 3/23/1976 Tree cap = 6-1/2" Otis GGG��as Lift Data rynn1 rn,rn� � R.Inill�1'9925 1N.0 of ell:OBk2 Depth Valve Type Port GLM cess. MaeVa ve / $; rens. Va ve rans.Va ve $" mss. Va ve {j{ fm8e�ss:1V/Va ve / OnOCVe�ve !' BC - 5RD Pad 3 1,195' FNL 1,41,495' FWL, Sec. 34, T7N, R10W, S.M. � Ilii its In Debris on casing wall 13,073' Tag w/ 5.75" OD overshot (3/24/14) J 13,123' Tag w/ 5.50" LIB (3/28/14) J SCHEMATIC Conductor Casino 20" H40 94 ppf TOP Bottom MD 0' 432' TVD 0' 432' Surface Casino 13-3/8" K-55 61 ppf 5 16 167 0.810 911 gin 1210 738_ Bottom MD 0' 3,511' TVD 0' 3,511' 8 W 194 0.773 827 am 1310 IPOR-19POC-11PPOR-1 Intermediate Casing 10 t 9 20 197 0.]88 ORIFICE -1 9-5/8" P-110 47 ppf LL 20M IVL MM MD 2.992" Tagged w/ 2.70' GR @ 15,272' on 04/20/17 TVD 0' 11,465' Liner 7" P-110 32 ppf 2.813" TOR Bottom MD 11,531' 14,918' TVD 11,322' 14,377' Liner 5" P-110 18 ppf Tim Bottom MD 14,693' 15,655' TVD 14,182' 15,061' u in 3-1/2" L-80 9.3 ppf 8RD Top Bottom MD 0' 14,596' TVD 0' 14,089' Well Name & Number: Beaver Creek Unit #5RD Lease: A-028083 -1230 Kenai Peninsula Bo rou h StatelProv: 6 -- 5 1 16 98 0.923 1036 1197 ;POR-1IIPOCa1PPOR-1 2 16 119 0.895 1001 1140 1225 IPOR-1nPOC-1IPPOR-1 USA Angle @KOP and Depth: 3 16 137 0.855 967 LOBS 1220 IPOR-10POO-1IPPOR-1 Maximum Devia9on: 29.0° 14,200' 7 4 16 153 0.830 937 1036 1215 IPOR-t4POO11PPOR-1 3/3012014 Ground Level (above MSL): 5 16 167 0.810 911 gin 1210 IRKS above Gi-: 16' I:POR-111MC.LPPOR-1 g - g 6 20 179 0.]93 882 971 1340 MR-10POG VI P -1 Donna Ambruz Downhole Revision Date: ' 1 20 199 0.]81 am 906 1325 IPOR-14POG-I PMR -1 Schematic Revision Date: 2/21/2018 8 W 194 0.773 827 am 1310 IPOR-19POC-11PPOR-1 10 t 9 20 197 0.]88 ORIFICE -1 /'1377 LL 20M to- Ding Hanger (naw) 21' 2.992" Tagged w/ 2.70' GR @ 15,272' on 04/20/17 ,18" X7" Liner Hanger -11.698' ? emical Injection Mandrel (Naw) 14,509 2.813" Nipple (New) 14,586' 2.813" - <er'SC-1!' Packer & Seal bore Ext 14,596' 4.000" <er Snap Latch Seal Assy (new. drifted to 2.80')14,595' 2992' Tvonek Paris: s'kNipple 14,62T 2.813" JdQ TVD Net Ft Zone ISLE PAW Status <er'F-1' 8340 Packer & Seal bore Ext. 14,66T 4.000' <er Tubing locator- Snap Latch Seal Assy 14,661' 2.992' _ 15,010'-15,025' 14,466-14,478' 15' GI -B 6 02/10/18 Open W Seal May, in TIW PBR & Liner Hanger 14.693' 3.000" 15,016-15,030' 14,469'-14,482' 15' G-1 6 - 15,D62.15,0]2' 14,510'-14,519' 10' GlC 6 02/10/18 Open 15,150'45,180' 14,589-14,616' 30' GI -D6 02/09/18 Open �+'•+• 15,344-15,390' 14,768'-14,811' 46' Lower Multiple I1+� Zea-5'x1-V2"cutter bar ,�15,395'-15.430' 14,818-14,849' 35' Low,G Raperfs (4176/14) 15,450'-15,508' 16,868-14,923' 50' LowarG Unknown depth. Lost 30' 441 string er) (42.2114).. 15,244' SLM (4/21/14). ("7/ >/ Baker Setting Tool 1.0" rod Q 15,325'. Beaton to TD PBTD bottom. Max OD is 1.360" at bottom. 17' Long. 15,655' MD 15,607' MD E -line patch setting tool used to set Otis patch. 15,061 -TVD 15,015'TVD Tag w/1.25'DD bailer at 15,480' SLM(11/21/13). Well Name & Number: Beaver Creek Unit #5RD Lease: A-028083 County or Parish: Kenai Peninsula Bo rou h StatelProv: Alaska Country: USA Angle @KOP and Depth: 26° 14,918' Angle/Perfs: 28° Maximum Devia9on: 29.0° 14,200' Date Completed: 3/3012014 Ground Level (above MSL): 155' IRKS above Gi-: 16' Revised By. Donna Ambruz Downhole Revision Date: 411-1!014 Schematic Revision Date: 2/21/2018 N Ililq. .AWA., [AA: 7.0 Drilling Summary BCU 05RD2 Drilling Procedure Rev 0 BCU 05RD2 is an oil producer planned to be re -drilled in a North-easterly direction from the existing BCU 05RD utilizing the existing casing program down to 14500' MD / 14008' TVD. At 14500' MD the parent wellbore will be sidetracked and new wellbore drilled penetrating several Hemlock targets. A 1500' x 5-7/8" open hole section is planned. A 4-1/2" 12.6# L-80 DWC/C prod liner will be run, cemented, and perforated based on data obtained while drilling the interval. The well will be completed with 3-1/2" production tubing string. Drilling operations are expected to commence approximately July 15th, 2018. All waste & mud generated during drilling and completion operations will be hauled to the Kenai Gas Field G&I facility for disposal / beneficial reuse depending on test results. A separate sundry notice will be submitted to cover P&A and wellbore preparation for the sidetrack and for running the completion assembly General sequence of operations pertaining to this approved drilling procedure: 1. MOB Rig #169to 05RD. f = 2. Kill well, Set BW, ND tree, NU BOPE and test. 3. BOLDS, Pull hanger and LD 3-1/2" tubing completion. 4. RU E -line to set CIBP. RIH w/ CIBP and set at 14,500' (5' above a collar) 5. RD E -line and test casing/CIBP to 2500 psi 6. RU Managed Pressure Drilling system ✓ 7. PU 5.875" window milling assembly and DP and cleanout to CIBP 8. POOH standing back, PU Whipstock, and mills and TIH to CIBP 9. Orient whipstock and set at 45 deg right of high side. 10. Displace well to 9.5 ppg OBM 11. Mill 5-7/8" window and 20' of new formation at 145001 . 12. Perform FIT to 12.5 ppg 13. Drill 5-7/8" production hole from 14500' to 15867' MD. 14. Perform short trip and condition mud. POOH 15. LD Directional Tools. RIH w 4-1/2" liner. Set liner and cement. Circ wellbore clean. 16. POOH, laying down DP and liner running tools, 17. PU 4-1/2" casing scraper assembly and TIH to landing collar. 18. Circ casing clean. POOH laying down DP. 19. Run 3-1/2" upper completion. Land hanger and test. 20. ND BOPE, NU tree and test void 21. RDMO Page 7 Revision 0 May 2018 BCU Drilling Procedure Rev 0 llikorp Al.ka, UA: 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the below AOGCC regulations. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. • BOPs shall be tested at (2) week intervals during the drilling of BCU 05RD2. Ensure to provide AOGCC 24 firs notice prior to testing BOPS. • The initial test of BOP equipment will be to 250/4500 psi & subsequent tests of the BOP equipment will be to 250/4500 psi for 10/10 min (annular to 50% rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. • If the BOP is used to shut in on the well in a well control situation, we must test ALL BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system" • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements" • Ensure both AOGCC and BLM approved drilling permit is posted on the rig floor and in Co Man office. Variance Requests: • Onshore Oil and Gas Order No. 1, Section III. D. 3. C. o Hilcorp requests approval to install a 2-1/16" 5M HCR valve on kill line in lieu of a check valve. Operator suspects a freeze plug risk associated with installation of a check valve in the kill line. o Hilcorp requests approval to utilize flexible choke and kill lines in lieu hard piping. `��l PSS X323 o The calculated MASP for this wellbore when completely ev ated to gas is 40,&elsi. However, _ for Beaver Creek (Hemlock), we assume that the well can,jj�.�,e.�ver flow 100% gas, due to the water in the reservoir. We reduce this MASP calcgjation to 3, .@ psi which assumes that only 2/3 of the wellbore is evacuated to gas and 1/3 to Page 8 Revision 0 iimrp May 2018 H Ilil. vp Al.k., LIX BCU 05RD2 Drilling Procedure Rev 0 Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) • 1 I" x 5M Townsend Annular BOP • 11" x 5M Townsend Double Ram Initial Test: 250/4500 o Blind ram in bum cavity (Annular 2500 psi) • Mud cross 5-7/8" • 11" x 5M Townsend Single Ram • 3-1/8" 5M Choke Line Subsequent Tests: • 2-1/16" x 5M Kill line 250/4500 • 3-1/8" x 2-1/16" 5M Choke manifold (Annular 2500 psi) • Standpipe, floor valves, etc • Primary closing unit: Control Technologies accumulator unit, 5 station, 120 gallon (12 x 11 gal bottles). • Primary closing hydraulic pressure is provided by an electrically driven triplex pump. Emergency pressure is provided by bottled nitrogen. Required AOGCC Notifications: • Well control event (BOPS utilized to shut in the well to control influx of formation fluids). • 24 hours notice prior to spud. '� • 24 hours notice prior to testing BOPS • 24 hours notice prior to casing running & cement operations.' • Any other notifications required in APD. Required BLM Notifications: • 48 hours before spud. Follow up with actual spud date and time. • 48 hours before casing running and cmt operations • 48 hours before BOPE tests • 48 hours before logging, coring, & testing • Any other notifications required in APD. Additional requirements may be stipulated on APD. Page 9 Revision 0 May 2018 H uik.q Al.kz, LAA: Regulatory Contact Information: BCU 05RD2 Drilling Procedure Rev 0 AOGCC Jim Regg / AOGCC Inspector / (0): 907-793-1236 / Email: jim.regg@alaska.gov Guy Schwartz / Petroleum Engineer / (0): 907-793-1226 / (C): 907-301-4533 / Email: guy.schwartz@alaska.gov Mel Rixse / Petroleum Engineer / (0): 907-793-1231 / Email: melvin.rixse@alaska.gov Victoria Loepp / Petroleum Engineer / (0): 907-793-1247 / Email: victoria.loeVI2@alaska.g0v Primary Contact for Opportunity to witness: AOGCC.Inspectors alaska.gov Test/Inspection notification standardization format: hUI2:Hdoa.alaska.gov/oizc/forms/TestWitnessNotifhtml Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) BLM Amanda Eagle / BLM Petroleum Engineer / (0): 907-271-3266 (C): 907-538-2300 Email: aeagle@blm.gov Mutasim Elganzoory / BLM Petroleum Engineer / (0): 907-271-4224 Email: melganzoorvkblm.gov Use the below email address for BOP notifications to the BLM: BLM AK AKSO EnergySection Notifications@blm.gov Page 10 Revision 0 May 2018 H Ililrarp Alaska, LLC 9.0 R/U and Preparatory Work BCU 05RD2 Drilling Procedure Rev 0 e�vF 9.1 A separate sundry will be submitted that will include the following: /5g P • P&A lower perfs with a cement plug / �V, • Pull tubing Gj J tJ 9.2 Level pad and ensure enough room for layout of rig footprint and R/U. 9.3 Layout Herculite on pad to extend beyond footprint of rig. 9.4 R/U Rig #169, spot service company shacks, spot & R/U company man & toolpusher offices. 9.5 After rig equipment has been spotted, R/U handi-berm containment system around footprint of rig. 9.6 Mix mud for 5-7/8" hole section. 9.7 Check wellhead for pressure 9.8 Load well with 8.4 ppg KWF 9.9 Set BPV 9.10 Nipple down tree 9.11 Set test Plug in wellhead prior to N/U BOP to ensure nothing can fall into the wellbore if it is accidentally dropped. 9.12 Verify 5" liners installed in mud pumps. • HHF-1000 Pumps are rated at 3457 psi (80%) with 5" liners and can deliver 306 gpm at 120 spm. This will allow us to drill the 5-7/8" hole section with (1) mud pump. Page 11 Revision 0 May 2018 H nil.,p AI.A., LLC 10.0 BOP N/U and Test BCU 05RD2 Drilling Procedure Rev 0 10.1 * BOPE was NU and tested on prior decompletion sundry. We will test BOPE on 7 day cycle until the window is milled, at that point we will switch to the step 11. 10.2 N/U 11"x 5M BOP as follows: • BOP configuration from Top down: 1: mud cross/1 I" x 5M single ram. • Double ram should be dressed with • Single ram should be dressed with 4 • NIU bell nipple, install flowline. 14 day test cycle. Continue on to ram/11" x 5M in btm cavity. 10.3 Run BOP test assy, land out test plug (if not installed previously). • Test BOP to 250/4500 psi for 10/10 min. Test annular to 250/2500 psi for 10/10 min. • Ensure to leave "A" section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. Confirm the correct valves are opened!!! • Test rams on a 4-1/2" and 4" test joint. • Ensure gas monitors are calibrated and tested in conjunction w/ BOPE. 10.4 R/D BOP test assy. 10.5 Continue mixing mud for 5-7/8" hole section. 10.6 Set wearbushing in wellhead. Ensure ID of wearbushing > 5.875". Page 12 Revision 0 May 2018 H ltileoq .Alaska, LIA: 11.0 Mud Program and Density Selection Criteria 11.1 5-7/8" Production hole mud program summary: BCU 05RD2 Drilling Procedure Rev 0 Primary weighting material to be used for the hole section will be Calcium Carbonate to minimize solids. We will have barite on location to weight up the active system 1ppg above highest anticipated MW in the event of a well control situation. Pason PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. System Type: 9.5 ppg 80/20 Enviromul mineral oil based drilling fluid. Properties: System Formulation: 80/20 Enviromul MOBM Product Mud Weight LVT 0.662 bbl Water .172 bbl 1NVERMUL NT 4 ppb MD Owl Viscosity PV YP HTHP WPS ES 14,500-15,867' 9.5-10.5. 50-80 25-35 15-22 <5 250-270K >580 System Formulation: 80/20 Enviromul MOBM Product Concentration LVT 0.662 bbl Water .172 bbl 1NVERMUL NT 4 ppb EZ MUL NT 4 ppb GELTONE V 6-10 ppb Lime 7 ppb DURATONE HT 2 ppb Calcium Chloride 21 ppb BAROID 41 9.5 ppg (as needed) BARACARB 5 3-5 ppb BARABLOK 2 ppb BAROTROLPLUS 4 ppb 11.2 Program mud weights are generated by reviewing data from producing & shut in offset wells, estimated BHP's from formations capable of producing fluids or gas and formations which could require mud weights for hole stabilization. 11.3 A guiding philosophy will be that it is less risky to weight up a lower weight mud than be --- overbalanced and have the challenge to mitigate lost circulation while drilling ahead. Page 13 Revision 0 May 2018 N nacorp Almka, u.c 12.0 Whipstock Running Procedure BCU 05RD2 Drilling Procedure Rev 0 12.1 M/U window milling assembly and TIH w/ approx. 1600' of 4" DP off of pipe rack. • Use a 5-7/8" taper mill and a 5-7/8" string mill above to ensure whipstock assy will pass freely. • Ensure BHA components have been inspected previously. • Caliper and drift all BHA components before running them in the hole. • Drift DP prior to RIH. • Lightly wash and ream any tight spots noted. 12.2 TIH to CIBP (14,500' MD). Note that this was a wireline measurement so actual depth tagged may vary slightly. Keep up with the # of joints picked up so we know where we are. 12.3 Pressure test casing to 2500 psi / 30 min. Chart record casing test & keep track of the amount of fluid pumped. Stage up to 2500 psi in 500 psi increments. 12.4 CBU & circ at least (1) hi -vis sweep to remove any debris created by the clean out run. Anything left in the wellbore could affect the setting of the Whipstock. [L►.IM�6]l 12.6 Makeup mills on a joint of HWDP. 12.7 RIH & set in slips. 12.8 Make up float sub, install float. 12.9 Make up UBHO sub. 12.10 Orient UBHO to starter mill. 12.11 Leave assembly hanging in the elevators, and stand back on floor. 12.12 Bring Whipstock to rig floor on the pipe skate. Do not slam into bottom of Whipstock with pipe skate. 12.13 Pick up Whipstock per Baker rep using the Baker Whipstock handling system using air hoist. Allow assy to hang while Baker Rep inspects and removes shear screws as needed and any safety screws. Note: Anchor should be pinned with 6 shear screws initially. Shear screws are rated for 6,630 lbs each. REMOVE 3 screws for a set down shear of 6,630 x 3 = 19,890 lbs. Note: Attach mills to with (l) 35k mill shear bolt. Page 14 Revision 0 May 2018 H lil.rp Alaska. LLC. 12.14 If needed, open BOP Blinds. BCU 05RD2 Drilling Procedure Rev 0 12.15 Run the Whipstock in the hole, install safety clamp as per Baker Rep, and install hole cover wrap. 12.16 Release pick up system at this point, Make up mills. 12.17 With the top drive, pick the assembly and position the starting mill to align with the hole in the slide. The Baker Rep will instruct the driller when the slot is lined up, the shear bolt then can be made up by the Baker Rep. 12.18 The assembly can now be picked up to ensure that the shear bolt is tight. 12.19 Remove the handling system. 12.20 Slowly run in the hole as per Baker Rep. Run extremely slow through the BOP & wear bushing. 12.21 Run in hole at 1 '/� to 2 minutes per stand. 12.22 Fill every 30 stands or as needed, do not rotate or work the string unnecessarily. 12.23 Call for Baker Rep. 15 — 10 stands before getting to bottom. 12.24 Orient at least 30'-45' above the CIBP. �_ / y q 7 0 Page 15 Revision 0 May 2018 U llilengi Alaska. LLC BCU 05RD2 Drilling Procedure Rev 0 WindowMaster G2 System on TorqueMaster BTA nn m 'U xlloxrs Baker Oil Tools Gen II Whipstock Customer. Hilcorp Well # IPog # 7" 32# 6.004" ID 5.969" Drift I 4A2' Whipstock M5010006 w/o 4314` OD Anchor 16565/9599 w/o 511nr OD 4 311 OD � Ae• 112' ID ,!AW OD 5.84' Upper Mill sa j3.8V 5.969' 00 4131ir OD TS 4 W On 1.60' 1 U1 ID 4W OD 635' Flex Joint T OA7' 4314' OD 16A9' 43 OD 1 Irl ID1.60' i 4Ar OD Lower Mill 533' SN OAO' 1 53/1' OD 199• 4111 OD 1111 ID 4111 OD OJS Window Mill s1 1A0• 5 718' OO 1932' CONNECTIONS ON TUBULARS ARE SUBJECT TO CHANGE. BHA'S SHOW SPECIFIC CONNECTIONS AS AN EXAMPLE ONLY Page 16 Revision 0 May 2018 H 11ilcurp Alaska, I.U: 13.0 Whipstock Setting Procedure BCU 05RD2 Drilling Procedure Rev 0 13.1 With the bottom of the Whipstock 30 — 45' above the CIBP, measure and record P/U and S/O weights. We will orient Whipstock face using highside MWD. 13.2 Orient Whipstock to desired direction by turning DP in'/4 round increments. P/U and S/O on DP to work all torque out (Being careful not to set BTA). Whipstock Orientation Diagram: YMITAI GSOLYAI Desired orientation of the Whipstock face is in 25 to 60 degrees azimuth. Hole Angle at window interval (14500' MD) is < 28 deg. The wellbore trajectory is also planned to kick off at 71 degrees azimuth and turn to 121 degrees. Highside of the casing at 14500' is 67 degrees azimuth. 13.3 Once Whipstock is in desired orientation, slack off and tag CIBP to set Bottom Trip Anchor. 13.4 Set down 12-15K on anchor to trip, P/U 5-7K maximum overpull to verify anchor is set. The window mill can then be sheared off by slacking off weight on the Whipstock shear bolt. (25k shear value). 13.5 P/U 5-10' above top of Whipstock. 13.6 Displace to 9.5 ppg 80/20 enviromul mineral oil based drilling fluid. 13.7 Record P/U, S/O weights, and free rotation. Slack off to top of whipstock and with light weight and low torque. Mill window. Utilize 4 ditch magnets on the surface to catch metal cuttings. 13.8 Install catch trays in shaker underflow chute to help catch iron. 13.9 Keep iron in separate bb1s. Record weight of iron recovered on ditch magnets. Page 17 Revision 0 May 2018 H Oik.o p Ala.: k4 1.1.1: 13.10 Estimated metal cuttings volume from cutting window: BCU 05RD2 Drilling Procedure Rev 0 7„ 3 Ys REG -P X MILL 32# N-80 Cuttings Weight Window 3 Y2 IF -B X 3'/z REG -B 5.5 6.5 FLEX JOINT Length Casing Weight Min (Ibs) Avg (Ibs) Max (Ibs) 13 32# 290 300 321 13.11 Drill approx. 20' rat hole to accommodate the drilling assembly. Ream window as needed to assure there is little or no drag. After reaming, shut off pumps and rotary (if hole conditions allow) and pass through window checking for drag. 13.12 Circulate Bottoms Up until MW in = MW out. 13.13 Conduct FIT to 12.5 ppg EMW. t/ • (12.5 — 9.5) * 0.052 * 13830' tvd = 2158 psi 13.14 Kick Tolerance • (12.5 -9.5) * (13830/15121) = 2.74 Note; Offset field test data predicts frac gradients at the window to be between 12 ppg and 15 ppg. A 12.5 ppg FIT results in a 2.74 ppg kick tolerance while drilling the interval with a 9.5 ppg fluid density. 13.15 Slug pipe and POOH. Gauge Mills for wear. 13.16 Should a second run be required pick up the following BHA. Back Un Mills Connection Lenath O.D. WINDOW MILL 3 Ys REG -P X MILL 0.98 6.63 NEW LOWER WATERMELON MILL 3 Y2 IF -B X 3'/z REG -B 5.5 6.5 FLEX JOINT 3'/z IF -B X 3'/2 IF -P 6.5 4.75 UPPER WATERMELON MILL 3'/i' IF -13 X 3'/" IF -P 5.83 6.63 FLOAT SUB 3'/" IF -13 X 3 %" IF -P 3.00 4.75 XO sub and 30'ts-HWDP 4" HT38-B X 3'/" IF -P 900' 5.25 CONNECTIONS ON TUBULARS ARE SUBJECT TO CHANGE. BHA's SHOW SPECIFIC CONNECTIONS AS AN EXAMPLE ONLY.! Page 18 Revision 0 May 2018 K Hil.,j, AI.A., GA; 14.0 Drill 5-7/8" Hole Section BCU 05RD2 Drilling Procedure Rev 0 14.1 Ensure that the managed pressure drilling (MPD) system is rigged up and functional prior to drilling through the high pressure Tyonek water sands in this area. We expect to encounter the sand at approximately 14,755' TMD (14,243' TVD). 14.2 PIU 5-7/8" directional drilling assy. 14.3 Ensure BHA Components have been inspected previously. 14.4 Drift & caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 14.5 Ensure TF offset is measured accurately and entered correctly into the MWD software. 14.6 Confirm that the bit is dressed with a TFA of 0.301 sq. in. (TFA should be fixed) Have DD run hydraulics models to ensure optimum TFA. We want to pump at 200 - 450 gpm. 14.7 Production section will be drilled with Geopilot 5200. Must keep up with 3 deg/100 DLS in the drop section of the wellbore. 14.8 Primary bit will be the Baker Hughes Kymera 5-7/8" KMX323T. Ensure to have a back up PDC bit available on location. Page 19 Revision 0 May 2018 H Ililrorp Alaaka, LLC Hughes Christensen KymeraTM Hybrid Bits Best of Both Worlds Designed to take advantage of the best attributes of both, Kyntera combines roller cone and fixed cutter elements. Improved Directional Control Relative to PDC bits, Kymera lower overall torque and minimized torque fluctuations to inq face control and reduce vibrations, Lower vibration The unique design of Kymera bits provides an stable drilling platform that mitigates vibration present in roller PDC environments. Better toolface control Superior directional bit for motor or rotary applications with better toolface control and steerability than a P[ Faster and More Durable When drilling interbedded and harder I formations, relative to PDC bits, this unique design provides increased durability in transition zones and smoother, faster drilling in hard rock Bit Specifications Number of Blades, Cones 3,2 Primary Cutter Size 0 in (0 mm) Cutter Quantity (Total, Face) (0, 0) BCU 05RD2 Drilling Procedure Rev 0 PRODUCT OVERVIEW Gauge / Makeup Length 3.5 in (88.9 mm) / 9.502 in (241.4 mm) Bit Breaker Connection N 3-1/2 Reg Pin Cutting Structure (Inner, Hcek Gauge)Conk/Conic/DX PDC 4 1/8" Bit Sub 5.2 - 5.7kft4b (7.0 - 7.7kNm) Makeup Torque 41/4"Sit Sub 6.3-6.9kft-Ib(8.6-9AkNm) Number of Nozzles 2PORT, ICSP 4112"Bit Sub 7.6-84kft4b(103-11.4kNm) Fixed TFA 0.301 sq.in (193.55 sq.mm) Approx. Shipping Weight52 lbs (23.6 kg) Bearing /Seal Package )owl wnnsert / Ref. Pan Number X24201 Single Energizer MFS Operating Recommendations* Hydraulic Row rate: 200450 gpm(750-17001pm). Rotation Speed: For Raary and Motor Applications. Max. WeiPht On Bit: 29 k1b (12 To or kdaN) •Th nngar of o' .6'h' RPM vAd maa gpm abrn is rtyrt¢netivca(ppcaloRnunp Mnx¢n. Nor ill. -1— 11 Wogivv— v, lik or loam drilling coa. biros a—rdrd dude apps, limon ofioth.6, and RPNI k run rimWumeul"Conu, 11,val Brterllughea nprtacmade for rtm—nor'—in pvurarta. Rtt—M wlido eonnnl of Ovid w be &,,vununlY 1% or — Di¢laime, of L..h liy: Thor infamorion u pmridod for 'ners infv-1—p o,—oNY W n WI -W to k accunm as of do drw krtof, buever. tlaYer Nugka Ircorpned W iu anilutta do -1—v-1 uvmmin or vrM--of-YYW rol-I act iNwmoaionaNdiulaim all eaPrtn Out imPliN—vdvo .top—roalion p Ne fullnanum ,novrohle 1Y lau. wclWinp Aviv of xrckMaMliry, fi. fora Iunicoh, purpx or me. dde. muioddr, rovm, xcurxY, corrtclaas oreompk¢nery of @e iMomulion pmaided krtin. All inlorwdneufrmdrkdlii eod uiJem aM'Iicnvebdialribme Tk uvragrevrbwmea111uN1irin nYrNmrk ue of ur ¢liaise onrush inforroalion BAKER HUGHES INCORFORATEO AND ITS AFFILIATES MIALL NOT BE LIABLE FOR ANY DIRECT, INDIRECT. SPECIAL PUNITIVE, EXEMPLARY OR CONSEQUENTIAL 1 HAM - Page 20 Revision 0 May 2018 N llik.q nk.ka, u.c 14.9 TIH to window. Shallow test MWD on trip in. BCU 05RD2 Drilling Procedure Rev 0 14.10 TIH through window, ensure Halliburton MWD service rep on rig floor during this operation. • Do not rotate string while bit is across face of Whipstock. 14.11 Drill 5-7/8" hole to 15,867' MD using rotary steerable assembly. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Utilize ECD while pumping to minimize waterflow from Tyonek sands • Utilize MPD to minimize Tyonek water flow <--- • On trips spot weighted pills inside window and hi vis pills at TD to control waterflow • Try to keep waterflow below 10 bph while tripping �-- • Utilize Inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team, try to avoid sliding through coal seams. Work through coal seams once drilled. • Keep swab and surge pressures low when tripping. • See attached mud program for hole cleaning and LCM strategies. • Ensure solids control equipment functioning properly and utilized to keep LGS to a minimum without excessive dilution. • Adjust MW as necessary to maintain hole stability. • Ensure mud engineer set up to perform HTHP fluid loss. • Maintain API fluid loss < 6. • Take MWD surveys every stand drilled. • Minimize backreaming when working tight hole 14.12 Hilcorp Geologists will follow mud log closely to determine exact TD. 14.13 At TD pump a sweep and a marker to be used as a fluid caliper to determine annulus volume for cement calculations. CBU, and pull a wiper trip back to the window. 14.14 TOH with drilling assembly, handle BHA as appropriate. Page 21 Revision 0 May 2018 15.0 Run 4-1/2" Production Liner BCU 05RD2 Drilling Procedure Rev 0 15.1 R/U Weatherford 4-1/2" casing running equipment. • Ensure 4-1/2" DWC/C x 4-1/2" CDS-40 crossover on rig floor and M/U to FOSV. • R/U fill up line to fill casing while running. • Ensure all casing has been drifted and tally verified prior to running. • Be sure to count the total # of joints before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/ vendor & model info. 15.2 P/U shoe joint, visually verify no debris inside joint. 15.3 Continue M/U & thread locking shoe track assy consisting of: • (1) Shoe joint w/ shoe bucked on & threadlocked (coupling also thread locked). • (1) Baker locked joint. • (1) Joint with float collar bucked on pin end & threadlocked (coupling also thread locked). • (1) Joint with landing collar bucked up. • Fiberglass 4-1/2" X 5-5/8" Solid body centralizers will be pre-installed on shoe joint, FC joint, and LC joint. • Install 4-1/2" X 5-5/8" fiberglass injection molded solid body centralizers, one per joint, and leave centralizers free floating so that they can slide up and down the joint. These are available at Mike Leslie's warehouse. • Ensure proper operation of float shoe & FC. 15.4 Continue running 4-1/2" production liner to TD • Fill casing while running using fill up line on rig floor. • Use "API Modified" thread compound. Dope pin end only w/ paint brush. • Install solid body centralizers on every other joint to window. Leave the centralizers free floating. Utilize a collar clamp until weight is sufficient to keep slips set properly. 4-1/2" DWC/C NIX torques Casio OD Minimum Maximum Yield Torque 4-1/2" 1 5800 ft -lbs 1 6500 ft -lbs 7200 ft -lbs Page 22 Revision 0 May 2018 0 Ililco,p ANA.. LLC Technical Specifications Connection Type: Size(O.D.): Weight (Wall): DWC/C Tubing 4-112 in 12.60 Ib/ft (0.271 in) standard Connection Performance Properties 288,000 Joint Strength (Ibs) 14,290 Reference String Length (ft) 1.6 Design Factor 314,000 API Joint Strength (Ibs) 288,000 Compression Rating (Ibs) 7,500 API Collapse Pressure Rating (psi) 8,430 API Internal Pressure Resistance (psi) 81.5 Maximum Uniaxial Bend Rating [degrees/100 ft] Appoximated Field End Torque Values 5,800 Minimum Final Torque (ft-Ibs) 6,500 Maximum Final Torque (ft-Ibs) 7,200 Connection Yield Torque (ft-Ibs) BCU 05RD2 Drilling Procedure Rev 0 Grade: L-80 "ww -USA VAM USA 4424 W. Sam Houston Pkwy. Suite 150 Houston, TX 77041 Phone: 713-4793200 Fax: 713-4793234 E-mail: VAMUSAsalesa�vam�.corn Page 23 Revision 0 May 2018 Material L-80 Grade 80,000 Minimum Yield Strength (psi) 95,000 Minimum Ultimate Strength (psi) 7,700 Pipe Dimensions 4.500 Nominal Pipe Body O.D. (in) 3.958 Nominal Pipe Body I.D.(in) 0.271 Nominal Wall Thickness (in) 12.60 Nominal Weight (lbs/ft) 12.25 Plain End Weight (Ibslft) 3.600 Nominal Pipe Body Area (sq in) Connection Performance Properties 288,000 Joint Strength (Ibs) 14,290 Reference String Length (ft) 1.6 Design Factor 314,000 API Joint Strength (Ibs) 288,000 Compression Rating (Ibs) 7,500 API Collapse Pressure Rating (psi) 8,430 API Internal Pressure Resistance (psi) 81.5 Maximum Uniaxial Bend Rating [degrees/100 ft] Appoximated Field End Torque Values 5,800 Minimum Final Torque (ft-Ibs) 6,500 Maximum Final Torque (ft-Ibs) 7,200 Connection Yield Torque (ft-Ibs) BCU 05RD2 Drilling Procedure Rev 0 Grade: L-80 "ww -USA VAM USA 4424 W. Sam Houston Pkwy. Suite 150 Houston, TX 77041 Phone: 713-4793200 Fax: 713-4793234 E-mail: VAMUSAsalesa�vam�.corn Page 23 Revision 0 May 2018 Pipe Body Performance Properties 288,000 Minimum Pipe Body Yield Strength (Ibs) 7,500 Minimum Collapse Pressure (psi) 8,430 Minimum Internal Yield Pressure (psi) 7,700 Hydrostatic Test Pressure (psi) Connection Performance Properties 288,000 Joint Strength (Ibs) 14,290 Reference String Length (ft) 1.6 Design Factor 314,000 API Joint Strength (Ibs) 288,000 Compression Rating (Ibs) 7,500 API Collapse Pressure Rating (psi) 8,430 API Internal Pressure Resistance (psi) 81.5 Maximum Uniaxial Bend Rating [degrees/100 ft] Appoximated Field End Torque Values 5,800 Minimum Final Torque (ft-Ibs) 6,500 Maximum Final Torque (ft-Ibs) 7,200 Connection Yield Torque (ft-Ibs) BCU 05RD2 Drilling Procedure Rev 0 Grade: L-80 "ww -USA VAM USA 4424 W. Sam Houston Pkwy. Suite 150 Houston, TX 77041 Phone: 713-4793200 Fax: 713-4793234 E-mail: VAMUSAsalesa�vam�.corn Page 23 Revision 0 May 2018 Connection Dimensions 5.000 Connection O.D. (in) 3.958 Connection I.D. (in) 3.833 Connection Drift Diameter (in) 3.94 Make-up Loss (in) 3.600 Critical Area (sq in) 100.0 Joint Efficiency (%) Connection Performance Properties 288,000 Joint Strength (Ibs) 14,290 Reference String Length (ft) 1.6 Design Factor 314,000 API Joint Strength (Ibs) 288,000 Compression Rating (Ibs) 7,500 API Collapse Pressure Rating (psi) 8,430 API Internal Pressure Resistance (psi) 81.5 Maximum Uniaxial Bend Rating [degrees/100 ft] Appoximated Field End Torque Values 5,800 Minimum Final Torque (ft-Ibs) 6,500 Maximum Final Torque (ft-Ibs) 7,200 Connection Yield Torque (ft-Ibs) BCU 05RD2 Drilling Procedure Rev 0 Grade: L-80 "ww -USA VAM USA 4424 W. Sam Houston Pkwy. Suite 150 Houston, TX 77041 Phone: 713-4793200 Fax: 713-4793234 E-mail: VAMUSAsalesa�vam�.corn Page 23 Revision 0 May 2018 U Ililurcp Alaska, I.G: BCU 05RD2 Drilling Procedure Rev 0 15.7 Ensure to run enough liner to provide at least 100' overlap inside 7" casing. Ensure hanger/pkr will not be set in a 7" connection. 15.8 Before picking up Baker ZXP liner hanger / packer assy, count the 4 of joints on the pipe deck to make sure it coincides with the pipe tally. 15.9 M/U Baker ZXP liner top packer. Fill liner tieback sleeve with "XANPLEX", ensure mixture is thin enough to travel past the HRD tool and down to the packoff. Wait 30 min for mixture to set UP. 15.10 RIH one stand and circulate a minimum of one liner volume. Note weight of liner. 15.11 RIH w/ liner on DP no faster than 1 min / stand. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 15.12 M/U top drive and fill pipe while lowering string every 10 stands. 15.13 Set slowly in and pull slowly out of slips. 15.14 Circulate 1-1/2 drill pipe and liner volume at 9-5/8" window prior to going into open hole. Stage pumps up slowly and monitor for losses. Do not exceed 60% of the nominal liner hanger setting pressure. 15.15 Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, 20, & 30 rpm. 15.16 Continue to fill the string every 10 joints while running liner in open hole. Do not stop to fill casing. 15.17 P/U the cmt stand and tag bottom with the liner shoe. P/U 2' off bottom. Note slack -off and pick-up weights. Record rotating torque values at 10, 20, & 30 rpm. 15.18 Stage pump rates up slowly to circulating rate without exceeding 60% of the liner hanger setting pressure. Circ and condition mud with the liner on bottom. Reduce the low end rheology of the drilling fluid by adding water and thinners. 15.19 Reciprocate & rotate string if hole conditions allow. Circ until hole and mud is in good condition for cementing. Page 24 Revision 0 May 2018 U 161rnrp AIuA , IAX 16.0 Cement 4-1/2" Production Casing BCU 05RD2 Drilling Procedure Rev 0 • Cement will be mixed using batch mixer to ensure consistent density 16.1 Hold a pre job safety meeting over the upcoming curt operations. 16.2 Attempt to reciprocate the casing during cmt operations until hole gets sticky. 16.3 Pump 15 bbls 12.5 ppg spacer. 16.4 Test surface cmt lines to 4500 psi. 16.5 Pump remaining 10 bbls 12.5 ppg spacer. 16.6 Mix and pump 40 bbls of 15.3 ppg class "G" cmt per below recipe with 2 lbs/bbl of loss circulation fiber. Ensure cmt is pumped at designed weight. Job is designed to pump 50% OH excess but if fluid caliper dictates otherwise we may increase excess volumes. Cement volume is designed to bring cement to 14,500' TMD in annulus between 7" casing and 5-7/8" hole. 16.7 Displacement fluid will be drilling mud. —199 bbls of displacement fluid in drill pipe and 21 bbls in liner. (.01378 * 14400 = 199), (.01522 * 1377 = 21), Total 220 Cement Calculations 5-7/8" OH x 7" Liner: (15867'— 14400') x 0.01386 x 1.5 = 38.5 bbls Shoe Track: 90' x 0.01522 = 1.5 bbls Total Volume (bbls): 38.5 + 1.5 = 40 bbls Total Volume (113): 40 bbls x 5.615 ft3/bbl = 224.6 ft3 Total Volume (sx): 224.6 ft3 / 1.34 ft3/sk = 173 sx Page 25 Revision 0 May 2018 I U lld,c q. Alaska. 1.1.1: Slurry Information: BCU 05RD2 Drilling Procedure Rev 0 System VariCEM Density 15.3 lb/gal Yield 1.34 ft3/sk Mixed Water 5.879 gal/sk Mixed Fluid 5.879 gal/sk Expected Thickening 70 Be at 05:00 hr:mn API Fluid Loss <25 mL in 30.0 min at 155degF / 1000 psi Additives Code Description Concentration G D046 D202 D400 D154 Cement Anti Foam Dispersant Gas Control Agent Extender 94 lb/sk 0.2% BWOC 1.5% BWOC 0.8% BWOC 8.0% BWOC 16.8 Drop DP dart and displace with 9.5 ppg OBM drilling mud. 16.9 Pump cement at max rate of 5 bbl/min. Reduce pump rate to 3 bpm prior to latching DP dart into liner wiper plug. Note plug departure from liner hanger running tool and resume pumping at full displacement rate. Displacement volume can be re -zeroed at this point 16.10 If elevated displacement pressures are encountered, position liner at setting depth and cease reciprocation. Monitor returns & pressure closely while circulating. Notify Drilling Foreman immediately of any changes. Reduce pump rate as required to avoid packoff. 16.11 Bump the plug and pressure up to up as required by Baker procedure to set the liner hanger (15% above nominal setting pressure. Hold pressure for 3-5 minutes. 16.12 Slack off total liner weight plus 30k to confirm hanger is set. 16.13 Do not overdisplace by more than 'h shoe track (—1 bbls). Shoe track volume is 1.8 bbls. 16.14 Pressure up to 4200 psi to release the running tool (HRD-E) from the liner Page 26 Revision 0 May 2018 H Ilil.q Aluuka, I.U: 16.15 Bleed pressure to zero to check float equipment. BCU 05RD2 Drilling Procedure Rev 0 16.16 P/U, verify setting tool is released, and expose setting dogs on top of tieback sleeve 16.17 Rotate slowly and slack off 50k downhole to set ZXPN. 16.18 Pressure up drill pipe to 500 psi and pickup to remove the RS packoff bushing from the RS nipple. Bump up pressure as req'd to maintain 500 psi DP pressure while moving pipe until the pressure drops rapidly, indicating pack -off is above the sealing area (ensure that 500 psi will be enough to overcome hydrostatic differential at liner top). 16.19 Immediately with the loss of pressure and before DP reaches zero, initiate circulation while picking up to position the bottom of the stinger inside the tieback sleeve. Increase pump rate to wellbore clean up rate until the sleeve area is thoroughly cleaned. 16.20 Pick up to the high -rate circulation point above the tieback extension, mark the pipe for reciprocation, do not re -tag the liner top, and circulate the well clean. 16.21 Watch for cement returns and record the estimated volume. Rotate & circulate to clear curt from DP. 16.22 POOH, LDDP. Verify the liner top packer received the required setting force by inspecting the rotating dog sub. Backup release from liner hanger: 16.23 If the HRD-E tool still does not release hydraulically, left-hand (counterclockwise) torque will have to be applied to the tool. This torque acts to shear brass screws. Bleed off pump pressure and ensure that the tool is in the neutral position. Apply left-hand torque as required to shear screws. 16.24 NOTE: Some hole conditions may require movement of the drillpipe to "work" the torque down to the setting tool. 16.25 After screws have sheared, the top sub and body of the setting tool will turn 1/4 turn. Then proceed slacking off set -down weight to shear second set of shear screws. The top sub will drop 1-3/4 inches. At this point, the bottom sub no longer supports the collet fingers. Pick straight up with workstring to release collet from the profile. Page 27 Revision 0 May 2018 H ni6,. p Alaska, LU BCU 05RD2 Drilling Procedure Rev 0 Ensure to report the following on Wellez: • Pre flush type, volume (bbls) & weight (ppg) • Cement slurry type, lead or tail, volume & weight • Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration • Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement, actual displacement volume, whether plug bumped & bump pressure, do floats hold • Percent mud returns duringjob, if intermittent note timing during pumping of job. Final circulating pressure • Note if pre flush or cement returns at surface & volume • Note time cement in place • Note calculated top of cement • Add any comments which would describe the successor problems during the cement job Note: Send Csg & cmt report + "As -Run" liner tally to mmvers(a)hilcorn.com Page 28 Revision 0 May 2018 H llilc.rp A64., LIA: 17.0 Wellbore Clean Up & Displacement BCU 05RD2 Drilling Procedure Rev 0 17.1 M/U casing clean out assy complete with casing scraper assys for each size casing in the hole. • 3-3/4" bit or mill • Casing scraper & brush for 4-1/2" 12.6# casing (MI Swaco - Multiback) • +/- 1500' 2-3/8" workstring. • Casing scraper & brush for 7" 32# casing (MI Swaco - Multiback) • (2000') 4-1/2" DP • Casing scraper & brush for 7" 32# casing (MI Swaco - Multiback) • 4-1/2" DP to surface. 17.2 TIH & clean out well to landing collar (+/- 15,777' MD). • Circulate as needed on trip in if string begins to take weight. • Circulate hi -vis sweeps as necessary to carry debris out of wellbore. Ensure 3-3/4" bit is worked down to the landing collar. Space out the cleanout BHA so that the 3-3/4" bit reaches the 4-1/2" landing collar when crossover is +/- 30' above the 4-1/2" liner top. The primary objective of the clean out run is to ensure the TCP assy will reach intended depth. 17.3 After wellbore has been cleaned out satisfactorily using mud, test casing to 3500 psi / 30 min. Ensure to chart record casing test. 17.4 Displace drilling fluid in wellbore with a hi -vis pill followed by fresh water. • Catch drilling fluid in rain -for -rent tanks for use on a fixture well. • Circulate fresh water into wellbore until clean up is satisfactory. Do not recirculate fluid, • After a couple circulations using FW, short trip the assy to bring the upper 7" multi -back assy to surface. • RIH again & tag landing collar w/ 3-3/4" bit. Continue circulation as necessary until fluid cleans up. Make another short trip if necessary. • Pump a chemical train followed by diesel completion fluid. 17.5 TOH w/ clean out assy. LDDP on the trip out. L/D the 4-1/2" work string. Page 29 Revision 0 May 2018 H Oil.,p Al.aU, LLC 18.0 Run Completion Assembly 18.1 Perforate required intervals as per separate sundry 18.2 Run 3-1/2" tubing as per separate Approved Completion Sundry 19.0 RDMO 19.1 Install BPV in wellhead. RILDs. 19.2 ND BOPE, NU tree, test void iW%AI —1 Uwe] BCU 05RD2 Drilling Procedure Rev 0 Page 30 Revision 0 May 2018 H uil..p AI.A., LLC 20.0 BOP Schematic BCU 05RD2 Drilling Procedure Rev 0 Page 31 Revision 0 May 2018 H Ililrnrp .Alaska, TAX BCU 05RD2 Drilling Procedure Rev 0 21.0 Wellhead Schematic Beaver Creek BCt SBD 20%133/8%95/8% 3k Tree cap, Otis 31/8 SM FE 868 No Quiet Union Tubing hanger. FMC -TC- IA EN Ct. tl x 3 A EUE LR ane sus0, w/ 3" TVpe 8 Orofile.'L control line port. 7.115"neck Mali FMC -ASP -CCL I I SM stEB %31/8 SM, prelapeG for 7.1 SS"eatentleA neck Tubiry Mad FMC -TC. 135/8 SM X 11 SM, w/ 2-21/16 SM EFO. BG 4ottoro VaM. OC'T-20.21/16 SM FE, N V0 Casing spool OCT 22-81a, 21 %2M %13 S/8 SM, ./2.21/16 SM SSO, W bottom prep Casing bnB. OCT -22. 21 M2M%SOW, w/ 2-21/16 SM EEO Page 32 RC\'151011 0 May 2018 H Ilikorp AI.A., LId: 22.0 Days vs Depth 61 2000 4000 6000 'Y 8000 BCU 05RD2 Drilling Procedure Rev 0 Days Vs Depth 9 Y 10000 12000 14000 16000 18000 0 5 10 15 20 25 30 35 40 Days Page 33 Revision 0 May 2018 23.0 Geo-Prog BCU 05RD2 Drilling Procedure Rev 0 DP at 14500' MD, drill -1500' MD using OBM and stepping out -250' away from current production point. 3rgeting Tyonek G sands and seconardy targets in the upper Hemlock formation. This sidetrack will ovide us with undamaged reservoir (drilling fluids), and new SWC data for further BCU development. TOP NANE I LITH0L02VI!jjj��1� I - TOP_NONEK_G Water 14,755 14,242.5 HP -H20 -SAND Water 14,789 14,273.8 BC -GI -A Water 14,944 14,418.9 BC_G1_B Oil 14,995 14,467.8 BC_G1_C Oil 15016.51 14,488.0 BC -GI -D Oil 15057.83 14,527.6 BC_G1_E Oil 15154 21 14,620.2 BC -GI -F Oil 15,240 14,702.7 BC_G2_A Oil 15,286 14,746.4 BC_G2_B Oil 15,432 14,886.6 3C_G2_C Oil 15,486 14,939.0 BC_G2_D Oil 15,508 14,959.9 HEMLOCK Oil 15,564 15,014.1 1, BC -H1 Oil 15,611 15,058.8 BC -H2 Oil 15,669 15,114.7 BC -H3 Oil 15,721 15,164.0 BC -H4 Oil 15,759 15,200.9 BC H5 Oil 15,793 15,233.4 Beaver Creek ALASKA KB 178.4 18.0 160.4 N"TWING I EAST/NG I I EMW Pressure -14064 2,435,801.90 318,709.50 6328.82 8.5 -14095 2,435,804.00 318,722.30 7750.00 10.4 -14241 2,435,808 40 318,775.70 6123,43 8.2 -14289 2,435,808.00 318,791.50 6144.44 8.2 -14310 2,435,807.60 318,797.80 6153.13 8.2 -14349 2,435,806.20 318,809.50 6170.15 82 -14442 2,435,802.30 318,836.10 6209.95 8.2 -14524 2,435,798.80 318,859.80 6245.44 8.2 14568 2,435,797.00 318,872.40 6264.22 8.2 -14708 2,435,791.10 318,912.70 6324.51 8.2 -14761 2.435,788.80 318,927 70 6347.07 82 -14782 2,435,788.00 318,933.80 6356.06 8.2 -14836 2,435,785.70 318,949.30 6379.35 8.2 -14880 2,435,783.80 318,962.20 6398.55 8.2 -14936 2,435,781.40 318,978.20 6422.60 8.2 -14986 2,435,779.40 318,992.40 6443.80 8.2 -15022 2,435,777.80 319,003.00 6459.67 8.2 -15055 2,435,776 40 319,012.40 6473.66 82 Page 34 Revision 0 May 2018 U Irik.rp Alaska, LLC BCU 05RD2 Drilling Procedure Rev 0 • • This well is to be drilled from the Beaver Creek Pad 3. Please provide drilling and myselfwith the final surface location when the location has been identified and staked. NO INFORMATION CONCERNING THIS WELL IS TO BE RELEASED TO ANYONE EXCEPT THE EMPLOYEES OF HI LCORP OR THEIR PARTNERS. Page 35 Revision 0 May 2018 H nil.rp Alaska. LrA: 24.0 Anticipated Drilling Hazards BCU 05RD2 Drilling Procedure Rev 0 Water Flow: The Tyonek water sands will be open. Ensure to treat the initial flow as gas. After we are confident we are only dealing with water from the sands we will utilize managed pressure drilling to control the flow of water while drilling. During trips we will use heavy pills and viscous pills to control the flow and trip in and out of the well. Lost Circulation: Ensure 500 lbs of medium/coarse fibrous material, 500 lbs SteelSeal (Angular, dual -composition carbon -based material), & 500 lbs different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Hole Cleaning: Maintain rheology w/ viscofrer as necessary. Sweep hole w/ 20 bbls flowzan as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain programmed mud specs. Coal Drilling: The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The need for good planning and drilling practices is also emphasized as a key component for success. • Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. • Use asphalt -type additives to further stabilize coal seams. • Increase fluid density as required to control running coals. • Emphasize good hole cleaning through hydraulics, ROP and system rheology. • Minimize swab and surge pressures • Minimize back reaming through coals when possible H2S: 1-12S is not present in this hole section. No abnormal temperatures or pressures are present in this hole section. Page 36 Revision 0 May 2018 H Ilii orp .AI.A., U.0 25.0 Rig Layout BCU 05RD2 Drilling Procedure Rev 0 Page 37 Revision 0 May 2018 K Ilikvrp M.A., Uk 26.0 FIT Procedure Formation Intelarity Test (FIT) and Leak -Off Test (LOT) Procedures Procedure for FIT: BCU 05RD2 Drilling Procedure Rev 0 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1 -minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre -determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre -determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 38 Revision 0 May 2018 H nil,.q Al.ks, LLC 27.0 Choke Manifold Schematic AF/11�1 /� � /fl(- /47: BCU 05RD2 Drilling Procedure Rev 0 v umur wm w us¢is Page 39 Revision 0 May 2018 Calculation & Casing Design Factors Beaver Creek Unit DATE: 5/30/2018 WELL: BCU-05RD2 FIELD: Beaver Creek Unit DESIGN BY: Monty M Myers n Criteria: Hole Size Mud Density: Hole Size 5-7/8" Mud Density: 9.5 ppg Hole Size Mud Density: Drilling Mode MASP: 4215 psi (See attached MASP determination & calculation) Production Mode MASP: 4896 psi (See attached MASP determination & calculation) Collapse Calculation: Section Calculation 1,2 Normal gradient external stress (0.44 psi/ft) and the casing evacuated for the internal stress Casing Section Calculation/Specification 1 2 3 4 Casing OD 4-1/2" Top (MD) 14,400 Top (TVD) 13,830 Bottom (MD) 15,867 Bottom (TVD) 15,300 Length 1,467 Weight (ppf) 12.6 Grade L-80 Connection DWC/C Weight w/o Bouyancy Factor (Ibs) 257,524 Tension at Top of Section (lbs) 257,524 Min strength Tension (1000 lbs) 288 Worst Case Safety Factor (Tension) 1.12 Collapse Pressure at bottom (Psi) 6,732 Collapse Resistance w/o tension (Psi) 7,500 Worst Case Safety Factor (Collapse) 1.11 MASP (psi) 4,215 Minimum Yield (psi) 8,430 Worst case safety factor (Burst) 2.00 Maximum Anticipated Surface Pressure Calculation jr 5-7/8" Hole Section BCU 05RD2 Kenai, Alaska MD TVD Planned Top: 0 0 Planned TD: 15867 15300 Anticipated Formations and Pressures: �G. y� 7! z 7/ Formation TVD Est Pressure Oil/Gas/Wet PPG Grad HPTyonekH2O 14274 7,750 Water 10.4 0.54 HEMLOCK 15,014 6,379 Oil/Water 8.2 0.42 BC HI 15,059 6,399 Oil/Water 8.2 0.42 BC H2 15,115 6,423 Oil/Water 8.2 0.42 BC_1-13 15,164 6,444 Oil/Water 8.2 0.42 BC H4 15,201 6,460 Oil/Water 8.2 0.42 BC HS 15,233 6,474 Oil/Water 8.2 0.42 TD 15,300 6500 Oil/Water 8.2 0.42 Offset Well Mud Densities Well MW range Top (TVD) Bottom (TVD) Date BCU OS 11 - 13ppg 12,500 16,250 2014 Beaver Creek 14A 9.0 - 9.4 ppg 5,000 9,450 2014 Beaver Creek 7A 9.0-9.3 2,400 8,929 2014 Assumptions: 1. Maximum planned mud density for the 5-7/8" hole section is 10.5 ppg. 2. Calculations assume reservoirs contain 100% gas (worst case). 3. Calculations assume worst case event is complete evacuation of wellbore to gas. 4. Anticipated fracture gradient at 14008' TVD = 12.5 ppg EMW Fracture Pressure at 5-7/8" window considering a full column of gas from window to surface: 14008 (ft) x 0.65(psi/ft)= 9105 psi 9105 (psi) - [0.1(psi/ft)*14008(ft)]= 7704 psi MASP from pore pressure; entire wellbore evacuated to gas from TD 14274 (ft) x 0.54(psi/ft)= 7750 psi 7750(psi) - [0.1(psi/ft)*14274 (ft)]=l 6323 psi 7750(psi) - [(2/3)*0.1(psi/ft)*14274(ft)]+[(1/3)*0.54(psi/ft)*14274(ft)]= 4215 psi Alternate Drilling MASP Summary: �S� 1. MASP while drilling 5-7/8" production hole is governed by SIBHP minus 2/3 wellbore evacuated to gas from TD. 2. MASP during production mode is governed by SIBHP minus entire wellbore evacuated to gas from TD. 30.0 Spider Plot (Governmental Sections) BCU 05RD2 Drilling Procedure Rev 0 Beaver Creek Unit ]a BCU-05RD2 ,Ala.k.. L1.1 wp_02 0 500 1,000 1,500 Feet Alaska State Plane Zone 4. NAD27 A Map Date: 5212018 Page 42 Revision 0 May 2018 acu 11 SHL? 1 1 BCU 5RD2_TPH BCU03BH ecu3 Bo eHL � ' BCU SRD2_BHL i � i 1 / j II i II i 1 i 1 11 i , , rI -------- ____BCU 5RD2_SHL ��. •r =� BCU ♦` ecu \\\ BEAVER CRE UNI j `♦\ \♦` A02 083 Bcu l2w enn / I � ecu os ♦� �♦ --_ / 1 BCU 23 BHLV S007 010 \ `. ED;/ `\ BCU 13 BHI`! ``\\ `\\ BCU 19 eHL� BCU a9 BHLSI `\ `\\ 1\\ ♦ ` BCU -25 SH4 BCU 24 BHIL *CUI4A HU C BCU14 � i ecu 1e BH i \ Legend BCU p1A& Bcu of BHI-• „= 0 BCU5RD2 SHL • Other Surface Well Locations X BCU 5RD2_TPH • Other Bottom Hole Locations I + BCU 5RD2_BHL — Well Paths --- — O Oil and Gas Unit Boundary Beaver Creek Unit ]a BCU-05RD2 ,Ala.k.. L1.1 wp_02 0 500 1,000 1,500 Feet Alaska State Plane Zone 4. NAD27 A Map Date: 5212018 Page 42 Revision 0 May 2018 m 31m Surface Pk(As-Built) Eua«s Drilling mace Rev o r � .) � � • [ § Q % �. , \z ` ).`: | | /a|m` @ ~^ ] \ ~® m ■�� | / | y , y «�® �\ �xxx��y ) ; \ Al ?mq\ \ ;..�.,��...� mU § / § )WG+/ z f ))t| § E ` TA § ]!! § a § IE | u um, � MARATHON aCO+_ , � AS -BUILT 3 . 41, 411, . FAC &«e6 Revision 0 yaa H Ilileorp Almka, IAX BCU 05RD2 Drilling Procedure Rev 0 32.0 Surface Plat (As Built -Zoomed) ABOVE GROUND CONDUIT RACKS E rCONCRETE PAD flax 7. METAL BUILDING O 15.5' X 12.5' B.C.U. No. 11 ANTENNA 6' DIA. SILO 1'. r N: 243382226 E: 1457321.77 ELEV: 160.6' I WELL HOUSE 12.6' X 12. O a LINE HEATER -METER BOX CONCRETE PAD% CONTROL PANEL CONTROL PANEL EMERGENCYSHUT PRODUCED \ FLUIDS rz BUILDING 23.7 X 25.a No. 9 UNE O O• ./ HEATER 20.7 x 7.1' 10.0•x32.7 O PRODUCED FLUIDS TANK ` LINED CONTAINMENT AREA \ �10,OpX 0 BUILDING 1o.ax2B,d• 10.7x26.4• NG` / / BUILDING 28.4' 29.4' \ / /jam 10.0'X26.4' B.C.U. No. 10 V DDA. SILO ON: 243384928 F. 1457382.87 ELEV: 160.4' BEAVER CREEK UNIT PAD 3 ®J Page 44 Revision 0 TOP OF PERIMETEN CONTAIMENTOERM B.C.U. NO. 19 W DA WELL CEDAR ONLY O N 2433747.15 E: 1457496.74 ELEV 160.5- TOP 60.5 May 2018 BASIN B.C.U. Nog B.C.U. No. SRD 8' DIA WELL 50.0 N: 2433756.16 E: 1457406,97 145OA.3.90 SIL )E: ELEV: 180.4'N: 2433743.90 1457339.97 ELEV: 160.r 4 -- • B.C.U. No.3 N:2433711.79 E: 1457345.34 8C No. 18 ELEV: 160.5 WDDA. WELL SILO ® N: 2433674.56 E: 1457426.78 ELEV: 160.r Page 44 Revision 0 TOP OF PERIMETEN CONTAIMENTOERM B.C.U. NO. 19 W DA WELL CEDAR ONLY O N 2433747.15 E: 1457496.74 ELEV 160.5- TOP 60.5 May 2018 BASIN H Ilii.q, Al.ku, LIA: 33.0 Directional Program (WP02) BCU 05RD2 Drilling Procedure Rev 0 Page 45 Revision 0 May 2018 Hilcorp Alaska, LLC Beaver Creek Unit Beaver Creek Unit Beaver CK Unit 5 BCU 5RD2 Plan: BCU 5RD2 wp02 Standard Proposal Report 20 May, 2018 HALLIBURTON Sperry Drilling Services NALLIBURTON Spercy O�illing r r ( West( -)/East(+) (400 usit/in) 0 200 400 600 800 1000 1: H 1 1 0 1667 3333 5000 6667 8333 10000 11667 13333 15000 Vertical Section at 43.58° (2500 usft/in) HALLIBURTON SporrY Orlllincl Project: Beaver Creek Unit Site: Beaver Creek Unit Well: Beaver CK Unit 5 Wellbore: BCU 5RD2 Design: BCU 5RD2 wp02 13500 13650 13800- 13950 3800-13950 14100 Hilcerp Alaska, LLC Calculation Method: Minimum Curvature EOor System: ISCWSA Scan Method: Closest Approach 3D Error Surface: Elliptical Conic blaming Method: Error Ratio REFERENCE INFORMATION Coordinate NE) Reference: Well Beaver CK Unit 5, True North Vertical (TVD) Reference: BCU 5RD2 wp01 RKB @ 178.40us8 (HEC Measured Depth Reference: BCU 5RD2 vvp01 RKB @ 178.40us8 (HEC Calculation Method Minimum Curvature SECTION DETAILS Sec MD Inc Azi TVD +N/ -S -E/-W Dleg TFace VSecl Target 1 14500.00 28.16 67.04 14008.58 1808.53 1252.15 0.00 0.00 2173.31 2 14517.00 28.52 71.27 14023.54 1811.40 1259.69 12.00 80.00 21 B0.59 3 14547.00 28.52 71.27 14049.90 1816.00 1273.25 0.00 0.00 2193.27 4 15277.66 15.29 121.73 14731.64 1821.42 1523.41 3.00 147.00 2369.65 5 15726.10 15.29 121.73 15164.22 1759.25 1623.97 0.00 0.00 2393.93 BCU 5RD2 wp01 Tgt1 6 15866.86 15.29 121.73 15300.00 1739.73 1655.53 (ion 0.00 2401.55 \Start.Dir 120°/100': 14500;MID, 14008.58'TVD: 80' RTTFr End Dir : 14517'MD, 14023.54'TVD 7" TO Start Dir 3°/100': 14547' MD, 14049.9'TVD TOP TYONEK G _ _ 14250 _ - _ - _ _ _ - _ - __ HP -H20 -SAND c 14400BC_Gt_A �BC_G1_B c 0 o-BC_G1_C a 14550 BC G1 D 5. E BC G1 - - - y _ _ BC G1_F_ _ �91a7oo - - - BC_G2_A d 214e50BC G2 B It - BC G2 C 15000 BC-G2_D- - - - -- - - - - - - --- HEMLOCK" - -" - - - - - - - -- - BC_H1 --- - - --- -- - -- 5150 BC-H2 BC H3_BC_H4- - - - - - - - - - - ---- -BC--H5 - - -- - - - - - 41/2"x57/8") End Dir : 15277.66' MD, 14731.64' TVD WI 15500 15500 15500 BCU 5RD 1 55 BCU 5RD2 01 Tgtt Total Depth : 15866.86' MD, 15300' TVD BCU 5RD2 wp02 V15000 BCU 5 16247 CASING DETAILS TVD TVDSS MD Size 14008.58 13830.18 14500.00 7"TOW 15300.00 15121.60 15866.86 4 1/2" x 5 7/8" FORMATION TOP DETAILS 7VDPath TVDssPath MDPath Formopon 14242.40 14064.00 14761.07 TOP TYONEK G 14273.40 14095.00 1479474 HP -H2O SANG 14419.40 14241.00 14951.12 BC G1 A 14467.40 14289.00 15001.87 BC G1_B 14488.40 14310.00 15023.99 BC Gi_C 14527.40 14349.00 15064.95 BC G1 D 14620.40 14442.00 15162.11 BC_G1_E 14702.40 14524.00 15247.33 BC_G1_F 14746.40 14568.00 15292.96 BC G2 A 14886.40 14708.00 15438.09 SC_G2 B 14939.40 14761.00 15493.03 BC_G2_C i4960A0 14782.00 15514.80 5C_G2_D 5014.40 14836.00 15570.78 HEMLOCK 1505840 14880.00 1561640 BC HI 15114.40 14938.00 1567445 SC H2 15164.40 14988.00 15726.29 BC_H3 1520040 15022.00 15763.61 BC_H4 15233.40 15055.00 1579782 BC_115 1650 1800 1950 2100 2250 2400 2550 2700 2850 3000 3150 3300 3450 3600 3750 Vertical Section at 43.58` (300 usftlin) WELL DETAILS: Beaver CK Unit 5 Ground Level: 157.54 +N/ -S +EI -W Northing Easting Latttlude Longitude 0.00 0.00 2433991.43 317312.59 60.6583924 -151.0182963 gA0p0 SURVEY PROGRAM Depth From Depth To SurveylPlan Tool 105.40 7965.40 BCU 5 Unknown Mag 8 Gyro Combo (BCU 5) 2_Uni n. \ 8005.40 14500.00 BCU 5 CB -GMS Surveys (BCU 5) 2_CB-Film-GMS 14500.00 15866.86 BCU 5RD2 P02 (BCU 5RD2) 2-MWD+AX+Sag \Start.Dir 120°/100': 14500;MID, 14008.58'TVD: 80' RTTFr End Dir : 14517'MD, 14023.54'TVD 7" TO Start Dir 3°/100': 14547' MD, 14049.9'TVD TOP TYONEK G _ _ 14250 _ - _ - _ _ _ - _ - __ HP -H20 -SAND c 14400BC_Gt_A �BC_G1_B c 0 o-BC_G1_C a 14550 BC G1 D 5. E BC G1 - - - y _ _ BC G1_F_ _ �91a7oo - - - BC_G2_A d 214e50BC G2 B It - BC G2 C 15000 BC-G2_D- - - - -- - - - - - - --- HEMLOCK" - -" - - - - - - - -- - BC_H1 --- - - --- -- - -- 5150 BC-H2 BC H3_BC_H4- - - - - - - - - - - ---- -BC--H5 - - -- - - - - - 41/2"x57/8") End Dir : 15277.66' MD, 14731.64' TVD WI 15500 15500 15500 BCU 5RD 1 55 BCU 5RD2 01 Tgtt Total Depth : 15866.86' MD, 15300' TVD BCU 5RD2 wp02 V15000 BCU 5 16247 CASING DETAILS TVD TVDSS MD Size 14008.58 13830.18 14500.00 7"TOW 15300.00 15121.60 15866.86 4 1/2" x 5 7/8" FORMATION TOP DETAILS 7VDPath TVDssPath MDPath Formopon 14242.40 14064.00 14761.07 TOP TYONEK G 14273.40 14095.00 1479474 HP -H2O SANG 14419.40 14241.00 14951.12 BC G1 A 14467.40 14289.00 15001.87 BC G1_B 14488.40 14310.00 15023.99 BC Gi_C 14527.40 14349.00 15064.95 BC G1 D 14620.40 14442.00 15162.11 BC_G1_E 14702.40 14524.00 15247.33 BC_G1_F 14746.40 14568.00 15292.96 BC G2 A 14886.40 14708.00 15438.09 SC_G2 B 14939.40 14761.00 15493.03 BC_G2_C i4960A0 14782.00 15514.80 5C_G2_D 5014.40 14836.00 15570.78 HEMLOCK 1505840 14880.00 1561640 BC HI 15114.40 14938.00 1567445 SC H2 15164.40 14988.00 15726.29 BC_H3 1520040 15022.00 15763.61 BC_H4 15233.40 15055.00 1579782 BC_115 1650 1800 1950 2100 2250 2400 2550 2700 2850 3000 3150 3300 3450 3600 3750 Vertical Section at 43.58` (300 usftlin) MALUBUATON Project: Beaver Creek Unit Site: Beaver Creek Unit Well: Beaver CK Unit S r We#(-)IFast(+) (150 usfthn) 157 M We#(-)IFast(+) (150 usfthn) Halliburton H A L L I B U RTO N Standard Proposal Report Database: Sperry EDM - NORTH US + CANADA Local Co-ordinate Reference: Well Beaver CK Unit 5 Company: Hilcorp Alaska, LLC TVD Reference: BCU 5RD2 wp01 RKB @ 178.40usft (HEC 169) , Project: Beaver Creek Unit MD Reference: BCU 5RD2 wp01 RKB @ 178.40usft (HEC 169) Site: Beaver Creek Unit North Reference: True , Well: Beaver CK Unit 5 Survey Calculation Method: Minimum Curvature - Wellbore: BCU 5RD2 From: Map Design: BCU 5RD2 wp02 Longitude: Project Beaver Creek Unit 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 W02018 6:03:12PM Page 2 COMPASS 5000.1 Build 81E Site Beaver Creek Unit Site Position: Northing: 2,430,086.36usft Latitude: 60" 38'51 316 N From: Map Easting: 314,428.19usft Longitude: 151"2'2.502W Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.90 ' Well Beaver CK Unit 5 Well Position +N/S 0.00 usft Northing: 2,433,991.43 usft Latitude: 60° 39'30.213 N +E/ -W 0.00 usft Easting: 317,312.59 usft Longitude: 5.867 W 151° '5 Position Uncertainty 0.00 usft Wellhead Elevation: 157.54 usft Ground Level: 157.54 usft Wellbore BCU 5RD2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength M (°) (nT) BGGM2018 7/1/2018 15.75 73,62 _ 55,327 - J Design BCU 5RD2 wp02 Audit Notes: Version: Phase: PLAN Tic On Depth: 14,500.00 Vertical Section: Depth From (TVD) -NIS +E/ -W Direction (usft) (usft) (usft) (") 20.86 0.00 0.00 43.58 -- �- --- Plan Sections Measured Vertical TVD Dogleg Build Tum Depth Inclination Azimuth Depth System +N/S +E/ -W Rate Rate Rate Tool Face (usft) (1 (°) (usft) usft (usR) (usft) ('/100usft) (°/100usit) (°1100usft) (°) 14,500.00 28.16 67.04 14,008.58 13,830.18 1,808.53 1,252.15 0.00 0.00 0.00 0.00 14,517.00 28.52 71.27 14,023.54 13,845.14 1,811.40 1,259.69 12.00 2.08 24.75 80.00 14,547.00 28.52 71.27 14,049.90 13,871.50 1,816.00 1,273.25 0.00 0.00 0.00 0.00 15,277.66 15.29 121.73 14,731.64 14,553.24 1,821.42 1,523.41 3.00 -1.81 6.91 147.00 15,726.10 15.29 121.73 15,164.22 14,985.82 1,759.25 1,623.97 0.00 0.00 0.00 0.00 15,866.86 15.29 121.73 15,300.00 15,121.60 1,739.73 1,655.53 0.00 0.00 0.00 0.00 W02018 6:03:12PM Page 2 COMPASS 5000.1 Build 81E Halliburton H A LL I B U R TO N Standard Proposal Report Database: Sperry EDM - NORTH US + CANADA Local Co-ordinate Reference: Well Beaver CK Unit 5 Company: Hilcorp Alaska, LLC ND Reference: BCU 5RD2 wp01 RKB @ 178.40usft (HEC 169) Project: Beaver Creek Unit MD Reference: BCU 5RD2 wp01 RKB @ 178.40usft (HEC 169) Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 5 Survey Calculation Method; Minimum Curvature Wellbore: BCU 5RD2 Depth Inclination Design: BCU 5RD2 wp02 Noss +N/ -S Planned Survey .. Measured Vertical Map Map Depth Inclination Azimuth Depth Noss +N/ -S +E/ -W Northing Easing DLS Vert Section (usft) (•) (°) (usft) usft (usft) (usft) (usft) (usft) -157.54 20.86 0.00 0.00 20.86 -157.54 0.00 0.00 2,433,991.43 317,312.59 0.00 0.00 105.40 0.08 105.38 105.40 -73.00 -0.02 0.06 2,433,991.41 317,312.65 0.09 0.03 205.40 0.08 109.56 205.40 27.00 -0.06 0.19 2,433,991.37 317,312.78 0.01 0.09 305.40 0.17 95.71 305.40 127.00 -0.10 0.40 2,433,991.33 317,312.99 0.09 0.21 405.40 0.08 90.97 405.40 227.00 -0.11 0.62 2,433,991.31 317,313.21 0.09 0.35 505.40 0.08 313.11 505.40 327.00 -0.07 0.64 2,433,991.36 317,313.23 0.15 0.39 605.40 0.25 269.31 605.40 427.00 -0.02 0.37 2,433,991.40 317,312.96 0.20 0.24 673.40 0.25 228.00 673.40 495.00 -0.12 0.11 2,433,991.31 317,312.70 0.26 -0.01 767.40 0.50 173.00 767.40 589.00 -0.67 0.01 2,433,990.76 317,312.59 0.44 -0.48 860.40 0.25 250.00 860.39 681.99 -1.14 -0.13 2,433,990.29 317,312.44 0.54 -0.91 954.40 0.25 263.00 954.39 775.99 -1.23 -0.53 2,433,990.21 317,312.04 0.06 -1.26 1,048.40 0.50 227.00 1,048.39 869.99 -1.54 -1.03 2,433,989.91 317,311.53 0.35 -1.82 1,142.40 0.50 199.00 1,142.39 963.99 -2.20 -1.46 2,433,989.25 317,311.09 0.26 -2.61 1,236.40 0.50 90.00 1,236.39 1,057.99 -2.59 -1.19 2,433,988.86 317,311.36 0.87 -2.70 1,330.40 0.25 83.00 1,330.38 1,151.98 -2.57 -0.57 2,433,988.87 317,311.98 0.27 -2.26 1,424.40 0.25 351.00 1,424.38 1,245.98 -2.34 -0.40 2,433,989.10 317,312.15 0.38 -1.97 1,518.40 0.00 351.00 1,518.38 1,339.98 -2.14 -0.44 2,433,989.30 317,312.12 0.27 -1.85 1,612.40 0.25 164.00 1,612.38 1,433.98 -2.33 -0.38 2,433,989.10 317,312.18 0.27 -1.95 1,706.40 0.25 177.00 1,706.38 1,527.98 -2.74 -0.31 2,433,988.70 317,312.24 0.06 -2.20 1,800.40 0.25 175.00 1,800.38 1,621.98 -3.15 -0.28 2,433,988.29 317,312.26 0.01 -2.47 1,894.40 0.25 128.00 1,894.38 1,715.98 -3.48 -0.10 2,433,987.96 317,312.43 0.21 -2.59 1,988.40 0.00 128.00 1,988.38 1,809.98 -3.60 0.06 2,433,987.83 317,312.59 0.27 -2.57 2,081.40 0.25 120.00 2,081.38 1,902.98 -3.70 0.23 2,433,987.72 317,312.77 0.27 -2.52 2,175.40 0.25 77.00 2,175.38 1,996.98 -3.76 0.61 2,433,987.66 317,313.14 0.19 -2.30 2,269.40 0.25 219.00 2,269.38 2,098.98 -3.87 0.68 2,433,987.55 317,313.21 0.50 -2.34 2,363.40 0.50 194.00 2,363.38 2,184.98 -4.43 0.45 2,433,986.99 317,312.98 0.31 -2.90 2,456.40 0.25 337.00 2,456.38 2,277.98 -4.64 0.28 2,433,986.79 317,312.79 0.77 -3.17 2,550.40 0.25 274.00 2,550.38 2,371.98 -4.43 -0.01 2,433,987.00 317,312.51 0.28 -3.22 2,644.40 0.25 23.00 2,644.37 2,465.97 -4.23 -0.13 2,433,987.20 317,312.39 0.43 -3.16 2,738.40 0.25 14.00 2,738.37 2,559.97 -3.84 0.00 2,433,987.59 317,312.53 0.04 -2.79 2,832.40 0.17 40.00 2,832.37 2,653.97 -3.54 0.14 2,433,987.89 317,312.67 0.13 -2.47 2,926.40 0.25 35.00 2,926.37 2,747.97 -3.26 0.34 2,433,988.16 317,312.88 0.09 -2.13 3,020.40 1.00 39.00 3,020.37 2,841.97 -2.46 0.98 2,433,988.96 317,313.53 0.80 -1.11 3,113.40 1.00 73.00 3,113.35 2,934.95 -1.59 2.26 2,433,989.81 317,314.83 0.63 0.41 3,207.40 1.00 72.00 3,207.34 3,028.94 -1.10 3.83 2,433,990.27 317,316.40 0.02 1.84 3,301.40 0.50 62.00 3,301.33 3,122.93 -0.65 4.97 2,433,990.70 317,317.55 0.55 2.96 3,395.40 0.50 39.00 3,395.33 3,216.93 -0.14 5.59 2,433,991.20 317,318.18 0.21 3.75 3,489.40 0.25 74.00 3,489.32 3,310.92 0.24 6.05 2,433,991.57 317,318.64 0.35 4.34 3,507.40 0.25 19.00 3,507.32 3,328.92 0.28 6.10 2,433,991.62 317,318.69 1.28 4.41 3,516.40 0.24 27.31 3,516.32 3,337.92 0.32 6.11 2,433,991.65 317,318.71 0.41 4.44 13 3/8' 3,541.40 0.25 51.00 3,541.32 3,362.92 0.40 6.18 2,433,991.73 317,318.77 0.41 4.55 3,635.40 0.25 359.00 3,635.32 3,456.92 0.73 6.33 2,433,992.07 317,318.93 0.23 4.90 3,729.40 0.25 328.00 3,729.32 3,550.92 1.11 6.22 2,433,992.45 317,318.83 0.14 5.10 3,823.40 0.00 0.00 3,823.32 3,644.92 1.29 6.11 2,433,992.62 317,318.72 0.27 5.15 520/2018 6:03: f2PM Page 3 COMPASS 5000.1 Build 81E Halliburton H A L L I B U R TO N Standard Proposal Report Database: Sperry EDM - NORTH US + CANADA Local Co-ordinate Reference: Well Beaver CK Unit 5 Company: Hilcorp Alaska, LLC TVD Reference: BCU 5RD2 wp01 RKB @ 178.40usft (HEC 169) Project: Beaver Creek Unit MD Reference: BCU 5RD2 wp01 RKB @ 178.40usft (HEC 169) Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 5 Survey Calculation Method: Minimum Curvature Wellbore: BCU 5RD2 Depth Inclination Design: BCU 5RD2 wp02 TVDss -NIS Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss -NIS +EI -W Northing Easting Di Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 3,738.92 3,917.40 0.00 0.00 3,917.32 3,738.92 1.29 6.11 2,433,992.62 317,318.72 0.00 5.15 4,011.40 0.00 0.00 4,011.32 3,832.92 1.29 6.11 2,433,992.62 317,318.72 0.00 5.15 4,104.40 0.25 242.00 4,104.32 3,925.92 1.19 5.93 2,433,992.53 317,318.54 0.27 4.95 4,198.40 0.25 210.00 4,198.32 4,019.92 0.92 5.65 2,433,992.26 317,318.25 0.15 4.56 4,292.40 0.25 260.00 4,292.32 4,113.92 0.71 5.35 2,433,992.05 317,317.95 0.22 4.20 4,386.40 0.00 180.00 4,386.32 4,207.92 0.67 5.14 2,433,992.02 317,317.74 0.27 4.03 4,480.40 0.25 355.00 4,480.32 4,301.92 0.87 5.13 2,433,992.22 317,317.73 0.27 4.17 4,574.40 0.25 313.00 4,574.32 4,395.92 1.22 4.96 2,433,992.57 317,317.57 0.19 4.30 4,667.40 0.25 310.00 4,667.32 4,488.92 1.49 4.65 2,433,992.84 317,317.27 0.01 4.29 4,761.40 0.25 332.00 4,761.32 4,582.92 1.80 4.40 2,433,993.16 317,317.02 0.10 4.34 4,855.40 0.25 357.00 4,855.32 4,676.92 2.19 4.29 2,433,993.55 317,316.92 0.12 4.54 4,949.40 0.25 330.00 4,949.32 4,770.92 2.57 4.18 2,433,993.93 317,316.81 0.12 4.74 5,043.40 0.25 317.00 5,043.31 4,864.91 2.90 3.94 2,433,994.26 317,316.57 0.06 4.81 5,137.40 0.25 307.00 5,137.31 4,958.91 3.17 3.64 2,433,994.54 317,316.27 0.05 4.80 5,230.40 0.50 356.00 5,230.31 5,051.91 3.70 3.44 2,433,995.07 317,316.09 0.41 5.05 5,324.40 0.50 348.00 5,324.31 5,145.91 4.51 3.33 2,433,995.88 317,315.99 0.07 5.56 5,418.40 0.50 346.00 5,418.30 5,239.90 5.31 3.15 2,433,996.69 317,315.82 0.02 6.01 5,512.40 0.25 19.00 5,512.30 5,333.90 5.90 3.11 2,433,997.28 317,315.79 0.34 6.42 5,606.40 0.25 4.00 5,606.30 5,427.90 6.30 3.20 2,433,997.68 317,315.88 0.07 6.76 5,700.40 0.25 267.00 5,700.30 5,521.90 6.49 3.00 2,433,997.87 317,315.69 0.40 6.77 5,793.40 0.25 282.00 5,793.30 5,614.90 6.52 2.60 2,433,997.91 317,315.29 0.07 6.52 5,887.40 0.50 244.00 5,887.30 5,708.90 6.38 2.03 2,433,997.78 317,314.72 0.36 6.03 5,981.40 0.75 270.00 5,981.29 5,802.89 6.20 1.05 2,433,997.62 317,313.74 0.40 5.22 6,075.40 0.50 311.00 6,075.29 5,896.89 6.47 0.13 2,433,997.90 317,312.82 0.53 4.78 6,169.40 0.50 330.00 6,169.28 5,990.88 7.10 -0.39 2,433,998.53 317,312.31 0.18 4.87 6,263.40 0.50 300.00 6,263.28 6,084.88 7.66 -0.95 2,433,999.10 317,311.76 0.28 4.89 6,356.40 0.50 282.00 6,356.28 6,177.88 7.95 -1.70 2,433,999.40 317,311.02 0.17 4.59 6,450.40 0.50 285.00 6,450.27 6,271.87 8.14 -2.49 2,433,999.60 317,310.22 0.03 4.17 6,544.40 0.50 290.00 6,544.27 6,365.87 8.38 -3.28 2,433,999.86 317,309.44 0.05 3.81 6,638.40 0.50 274.00 6,638.27 6,459.87 8.55 4.07 2,434,000.04 317,308.65 0.15 3.39 6,732.40 0.75 291.00 6,732.26 6,553.86 8.80 -5.05 2,434,000.31 317,307.67 0.33 2.89 6,826.40 0.50 220.00 6,826.26 6,647.86 8.71 5.89 2,434,000.23 317,306.83 0.80 2.25 6,919.40 0.50 319.00 6,919.25 6,740.85 8.70 -6.42 2,434,000.23 317,306.31 0.82 1.88 7,013.40 0.75 310.00 7,013.25 6,834.85 9.41 -7.16 2,434,000.95 317,305.58 0.28 1.88 i 7,107.40 0.75 315.00 7,107.24 6,928.84 10.24 -8.07 2,434,001.79 317,304.68 0.07 1.86 7,201.40 0.50 320.00 7,201.24 7,022.84 10.99 -8.76 2,434,002.55 317,304.00 0.27 1.92 7,295.40 0.25 266.00 7,295.23 7,116.83 11.29 -9.23 2,434,002.86 317,303.53 0.43 1.81 7,389.40 0.25 278.00 7,389.23 7,210.83 11.30 -9.64 2,434,002.88 317,303.13 0.06 1.54 7,482.40 0.50 309.00 7,482.23 7,303.83 11.59 -10.16 2,434,003.17 317,302.61 0.34 1.39 7,576.40 0.25 320.00 7,576.23 7,397.83 12.00 -10.61 2,434,003.59 317,302.17 0.28 1.38 7,670.40 0.25 307.00 7,670.23 7,491.83 12.28 -10.90 2,434,003.88 317,301.88 0.06 1.38 7,764.40 0.25 290.00 7,764.23 7,585.83 12.47 -11.26 2,434,004.08 317,301.53 0.08 1.27 7,858.40 0.25 261.00 7,858.23 7,679.83 12.51 -11.65 2,434,004.12 317,301.13 0.13 1.03 7,952.40 0.25 220.00 7,952.22 7,773.82 12.32 -11.99 2,434,003.94 317,300.79 0.19 0.66 7,965.40 0.25 237.00 7,965.22 7,786.82 12.29 -12.03 2,434,003.90 317,300.75 0.57 0.61 5/20/2018 6:03.12PM Page 4 COMPASS 5000.1 Build 81E HALLIBURTON Database: Sperry EDM - NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Beaver Creek Unit Site: Beaver Creek Unit Well: Beaver CK Unit 5 Wellbore: BCU 5RD2 Design: BCU 5RD2 wp02 Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss (usft) (') (') (usft) usft 8,005.40 8,105.40 8,205.40 8,305.40 8,405.40 8,505.40 8,605.40 8,705.40 8,805.40 8,905.40 9,005.40 9,105.40 9,205.40 9,305.40 9,405.40 9,505.40 9,605.40 9,705.40 9,805.40 9,905.40 10,005.40 10,105.40 10,205.40 10,305.40 10,405.40 10,505.40 10,605.40 10,705.40 10,805.40 10,905.40 11,005.40 11,105.40 11,205.40 11,305.40 11,405.40 11,505.40 11,605.40 11,705.40 11,717.40 95181, 11,805.40 11,905.40 12,005.40 12,105.40 12,205.40 Halliburton Standard Proposal Report Local Co-ordinate Reference: Well Beaver CK Unit 5 TVD Reference: BCU 5RD2 wp01 IRKS @ 178.40usft (HEC 169) MD Reference: BCU 5RD2 wp01 IRKS @ 178.40usft (HEC 169) North Reference: True Survey Calculation Method: Minimum Curvature Map Map -NIS +E/ -W Northing Easting DLS Vert Section (usft) (usft) (usft) (usft) 7,826.82 1.83 310.23 8,005.22 7,826.82 12.65 -12.59 2,434,004.27 317,300.20 4.44 0.48 3.17 312.40 8,105.12 7,926.72 15.55 -15.85 2,434,007.22 317,296.98 1.34 0.33 3.92 323.86 8,204.93 8,026.53 20.17 -19.91 2,434,011.91 317,293.00 1.03 0.89 5.08 332.17 8,304.62 8,126.22 26.85 -23.99 2,434,018.64 317,289.02 1.33 2.91 5.92 333.38 8,404.16 8,225.76 35.37 -28.37 2,434,027.24 317,284.77 0.85 6.07 6.83 336.66 8,503.54 8,325.14 45.44 -33.04 2,434,037.38 317,280.26 0.98 10.15 8.25 340.96 8,602.67 8,424.27 57.69 -37.73 2,434,049.69 317,275.76 1.53 15.78 9.08 344.23 8,701.53 8,523.13 72.06 -42.22 2,434,064.13 317,271.49 0.96 23.10 10.42 349.54 8,800.09 8,621.69 88.55 -46.01 2,434,080.68 317,267.96 1.61 32.43 13.08 356.98 8,897.99 8,719.59 108.75 -48.25 2,434,100.90 317,266.04 3.06 45.52 13.83 359.63 8,995.24 8,816.84 132.00 48.92 2,434,124.16 317,265.73 0.97 61.90 14.75 3.94 9,092.15 8,913.75 156.65 -48.12 2,434,148.80 317,266.90 1.41 80.31 15.17 6.18 9,188.76 9,010.36 182.36 -45.84 2,434,174.47 317,269.59 0.71 100.51 16.33 9.16 9,285.01 9,106.61 209.25 -42.19 2,434,201.30 317,273.65 1.41 122.50 16.67 9.48 9,380.89 9,202.49 237.28 -37.59 2,434,229.25 317,278.68 0.35 145.97 17.67 11.94 9,476.43 9,298.03 266.27 -32.09 2,434,258.15 317,284.63 1.24 170.77 18.50 14.41 9,571.49 9,393.09 296.49 -25.00 2,434,288.25 317,292.19 1.13 197.55 19.92 16.01 9,665.92 9,487.52 328.23 -16.35 2,434,319.85 317,301.33 1.51 226.50 20.25 18.44 9,759.84 9,581.44 361.02 -6.18 2,434,352.48 317,312.00 0.90 257.27 21.42 19.55 9,853.30 9,674.90 394.65 5.40 2,434,385.92 317,324.11 1.23 289.62 21.33 19.74 9,946.43 9,768.03 428.98 17.66 2,434,420.05 317,336.89 0.11 322.93 22.17 19.87 10,039.31 9,860.91 463.84 30.21 2,434,454.72 317,349.98 0.84 356.84 22.83 21.36 10,131.69 9,953.29 499.65 43.69 2,434,490.31 317,364.02 0.87 392.08 24.67 22.58 10,223.22 10,044.82 536.99 58.77 2,434,527.41 317,379.67 1.90 429.52 24.58 24.41 10,314.13 10,135.73 575.20 75.38 2,434,565.36 317,396.87 0.77 468.65 24.67 25.18 10,405.03 10,226.63 613.03 92.86 2,434,602.91 317,414.93 0.33 508.10 25.33 26.06 10,495.66 10,317.26 651.13 111.13 2,434,640.72 317,433.79 0.76 548.30 26.00 26.42 10,585.80 10,407.40 689.98 130.28 2,434,679.26 317,453.54 0.69 589.65 26.75 27.27 10,675.39 10,496.99 729.61 150.35 2,434,718.58 317,474.21 0.84 632.19 26.50 28.19 10,764.78 10,586.38 769.28 171.20 2,434,757.92 317,495.68 0.48 675.30 26.50 29.36 10,854.28 10,675.88 808.39 192.68 2,434,796.68 317,517.76 0.52 718.43 26.50 29.36 10,943.77 10,765.37 847.27 214.55 2,434,835.23 317,540.23 0.00 761.69 27.08 31.40 11,033.04 10,854.64 886.15 237.35 2,434,873.74 317,563.63 1.09 805.56 27.25 32.11 11,122.01 10,943.61 924.97 261.38 2,434,912.18 317,588.25 0.37 850.25 28.33 31.68 11,210.47 11,032.07 964.55 286.01 2,434,951.38 317,613.49 1.10 895.91 27.25 31.78 11,298.94 11,120.54 1,004.21 310.53 2,434,990.64 317,638.62 1.08 941.53 27.33 33.56 11,387.81 11,209.41 1,042.80 335.28 2,435,028.85 317,663.96 0.82 986.55 26.00 31.79 11,477.18 11,298.78 1,080.56 359.52 2,435,066.22 317,688.78 1.55 1,030.62 25.92 31.97 11,487.96 11,309.56 1,085.02 362.29 2,435,070.64 317,691.62 0.94 1,035.76 25.33 33.30 11,567.31 11,388.91 1,117.07 382.81 2,435,102.37 317,712.63 0.94 1,073.12 26.58 34.78 11,657.22 11,478.82 1,153.33 407.32 2,435,138.24 317,737.70 1.41 1,116.28 25.42 35.82 11,747.10 11,568.70 1,189.11 432.64 2,435,173.62 317,763.57 1.25 1,159.66 24.92 36.50 11,837.61 11,659.21 1,223.45 457.73 2,435,207.56 317,789.19 0.58 1,201.83 24.62 37.12 11,928.41 11,750.01 1,256.99 482.83 2,435,240.71 317,814.81 0.40 1,243.44 5/202018 6:03:12PM Page 5 COMPASS 5000.1 Build SlE HALLIBURTON Database: Sperry EDM - NORTH US+CANADA Company: Hilcorp Alaska, LLC Project: Beaver Creek Unit Site: Beaver Creek Unit Well: Beaver CK Unit Wellbore: BCU 5RD2 Design: BCU 5RD2 wp02 Planned Survey Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Measured Map Map Vertical +E/ -W Depth Inclination Azimuth Depth TVDss -N/-S (usft) (•) (usft) (1 (usft) usft (usft) 12,305.40 24.83 37.41 12,019.24 11,840.84 1,290.28 12,405.40 24.67 38.11 12,110.05 11,931.65 1,323.38 12,505.40 24.83 40.76 12,200.87 12,022.47 1,355.70 12,605.40 24.42 39.02 12,291.78 12,113.38 1,367.67 12,705.40 24.83 39.29 12,382.68 12,204.28 1,419.98 12,805.40 23.58 42.08 12,473.89 12,295.49 1,451.07 12,905.40 22.92 44.42 12,565.77 12,387.37 1,479.83 13,005.40 22.33 44.77 12,658.08 12,479.68 1,507.22 13,105.40 20.67 50.91 12,751.13 12,572.73 1,531.84 13,205.40 20.50 56.22 12,844.75 12,666.35 1,552.71 13,305.40 21.25 57.35 12,938.19 12,759.79 1,572.22 13,405.40 23.50 58.87 13,030.65 12,852.25 1,592.31 13,505.40 24.50 60.00 13,122.01 12,943.61 1,612.98 13,605.40 25.42 63.49 13,212.67 13,034.27 1,632.93 13,705.40 25.58 64.50 13,302.93 13,124.53 1,651.81 13,805.40 26.50 64.61 13,392.78 13,214.38 1,670.67 13,905.40 25.75 63.45 13,482.56 13,304.16 1,689.94 14,005.40 27.17 63.20 13,572.08 13,393.68 1,709.95 14,105.40 27.58 63.39 13,660.88 13,482.48 1,730.61 14,205.40 28.75 64.46 13,749.04 13,570.64 1,751.35 14,305.40 28.25 65.53 13,836.92 13,658.52 1,771.52 14,405.40 28.00 66.12 13,925.°12 13,746.72 1,790.83 14,500.00 ' 28.16 67.04 14,008.58 13,830.18 1,808.53 Start Dir 12-1100': 14500' MD, 14008.58'IVD : 80" RT TF - 7" TOW 14,517.00 28.52 71.27 14,023.54 13,845.14 1,811.40 End Dir : 14517' MD, 14023.54' TVD 2,435,814.51 318,755.86 3.00 14,547.00 28.52 71.27 14,049.90 13,871.50 1,816.00 Start Dir 3°1100' : 14547' MD, 14049.9rVD 2,435,813.23 318,789.10 14,600.00 27.20 73.16 14,096.76 13,918.36 1,823.57 14,700.00 24.79 77.24 14,186.65 14,008.25 1,834.82 14,761.07 23.37 80.10 14,242.40 14,064.00 1,839.73 TOP_TYONEK_G / 14,794.74' 22.62 81.82 14,273.40 14,095.00 1,841.80 HP-H20_SAND 14,800.00 22.50 82.10 14,278.26 14,099.86 1,842.08 14,900.00 20.40 87.96 14,371.33 14,192.93 1,845.33 14,951.12 19.41 91.40 14,419.40 14,241.00 1,845.44 BC -GI -A 15,000.00 18.53 95.01 14,465.63 14,287.23 1,844.57 15,001.87 18.50 95.16 14,467.40 14,289.00 1,844.51 BC_Gt B 15,023.99 18.13 96.91 14,488.40 14,310.00 1,843.79 BC -GI -C 15,064.95 17.48 100.33 14,527.40 14,349.00 1,841.92 BC -GI -0 Halliburton Standard Proposal Report Well Beaver CK Unit 5 BCU 5RD2 wp01 IRKS @ 178.40usft (HEC 169) BCU 5RD2 wp01 RKB @ 178.40usft (HEC 169) True Minimum Curvature 5/202018 6:03:12PM Page 6 COMPASS 5000.1 Build 81E Map Map +E/ -W Northing Easting DLS Vert Section (usft) (usft) (usft) 11,840.84 508.16 2,435,273.60 317,840.65 0.24 1,285.01 533.80 2,435,306.30 317,866.79 0.33 1,326.66 560.39 2,435,338.20 317,893.88 1.12 1,368.40 587.11 2,435,369.75 317,921.09 0.83 1,409.98 613.42 2,435,401.65 317,947.90 0.43 1,451.52 640.12 2,435,432.32 317,975.07 1.69 1,492.46 667.15 2,435,460.65 318,002.55 1.14 1,531.93 694.16 2,435,487.62 318,029.98 0.61 1,570.39 721.25 2,435,511.82 318,057.44 2.79 1,606.89 749.50 2,435,532.25 318,086.01 1.87 1,641.49 779.31 2,435,551.29 318,116.12 0.85 1,676.18 811.64 2,435,570.88 318,148.75 2.32 1,713.01 846.67 2,435,591.00 318,184.09 1.10 1,752.14 883.83 2,435,610.37 318,221.56 1.74 1,792.21 922.52 2,435,628.65 318,260.54 0.46 1,832.55 962.17 2,435,646.89 318,300.46 0.92 1,873.54 1,001.75 2,435,665.55 318,340.34 0.91 1,914.80 1,041.57 2,435,684.93 318,380.46 1.42 1,956.73 1,082.64 2,435,704.95 318,421.85 0.42 2,000.02 1,125.04 2,435,725.03 318,464.56 1.27 2,044.27 1,168.28 2,435,744.53 318,508.10 0.71 2,088.69 1,211.29 2,435,763.17 318,551.40 0.37 2,132.32 1,252.15 2,435,780.23 318,592.53 0.49 2,173.31 1,259.69 2,435,782.98 318,600.11 12.00 2,180.59 1,273.25 2,435,787.37 318,613.74 0.00 2,193.27 1,296.83 2,435,794.58 318,637.43 3.00 2,215.01 1,339.15 2,435,805.17 318,679.92 3.00 2,252.34 1,363.57 2,435,809.70 318,704.41 3.00 2,272.73 1,376.56 2,435,811.57 318,717.44 3.00 2,283.18 1,378.56 2,435,811.82 318,719.44 3.00 2,284.76 1,414.94 2,435,814.51 318,755.86 3.00 2,312.20 1,432.34 2,435,814.35 318,773.26 3.00 2,324.27 1,448.20 2,435,813.23 318,789.10 3.00 2,334.57 1,448.79 2,435,813.16 318,789.69 3.00 2,334.94 1,455.70 2,435,812.33 318,796.59 3.00 2,339.18 1,468.08 2,435,810.27 318,808.94 3.00 2,346.35 5/202018 6:03:12PM Page 6 COMPASS 5000.1 Build 81E HALLIBURTON Halliburton Standard Proposal Report Database: Company: Project: Site: Well: Wellbore: Design: Sperry EDM - NORTH Hilcorp Alaska, LLC Beaver Creek Unit Beaver Creek Unit Beaver CK Unit 5 BCU 5RD2 BCU 5RD2 wp02 US + CANADA Local Co-ordinate Reference: Well Beaver CK Unit 5 TVD Reference: BCU 5RD2 wp01 RKB @ 178.40usft (HEC 169) MD Reference: BCU 5RD2 wp01 RKB @ 178.40usft (HEC 169) North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey -Shape V) V) (usft) (usft) (usft) (usft) (usft) BCU 5RD2 wp01 Tgt1 0.00 0.00 15,164.22 1,759.25 1,623.97 2,435,725.20 318,963.52 - plan hits target center - Circle (radius 50.00) Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +EI -W Northing Easting DLS Vert Section (usft) (•) (1) (usft) usft (usft) (usft) (usft) (usft) 14,382.48 15,100.00 16.98 103.44 14,560.88 14,382.48 1,839.78 1,478.24 2,435,807.98 318,819.06 3.00 2,351.81 15,162.11 16.21 109.40 14,620.40 14,442.00 1,834.80 1,495.23 2,435,802.73 318,835.98 3.00 2,359.92 BC_G1_E 15,200.00 15.83 113.28 14,656.82 14,478.42 1,831.00 1,504.97 2,435,798.78 318,845.66 3.00 2,363.88 15,247.33 15.46 118.36 14,702.40 14,524.00 1,825.45 1,516.46 2,435,793.05 318,857.05 3.00 2,367.77 EIC G1_F 15,277.6_6 15.29 121.73 14,731.65 14,553.25 1,821.42 1,523.42 2,435,788.92 318,863.95 3.00 2,369.66 End Dir : 15277.66' NO, 14731.64' TVD 15,292.96 15.29 121.73 14,746.40 14,568.00 1,819.30 1,526.85 2,435,786.75 318,867.34 0.00 2,370.48 BC_G2_A 15,300.00 15.29 121.73 14,753.19 14,574.79 1,818.33 1,528.42 2,435,785.75 318,868.91 0.00 2,370.86 15,400.00 15.29 121.73 14,849.66 14,671.26 1,804.46 1,550.85 2,435,771.54 318,891.11 0.00 2,376.28 15,438.09 15.29 121.73 14,886.40 14,708.00 1,799.18 1,559.39 2,435,766.12 318,899.57 0.00 2,378.34 BC_G2_B 15,493.03 15.29 121.73 14,939.40 14,761.00 1,791.56 1,571.71 2,435,758.32 318,911.77 0.00 2,381.32 BC_G2_C 15,500.00 15.29 121.73 14,946.12 14,767.72 1,790.60 1,573.27 2,435,757.33 318,913.32 0.00 2,381.69 15,514.80 15.29 121.73 14,960.40 14,782.00 1,7138.54 1,576.59 2,435,755.22 318,916.60 0.00 2,382.49 BC_G2_D 15,570.78 15.29 121.73 15,014.40 14,836.00 1,780.78 1,589.14 2,435,747.27 318,929.03 0.00 2,385.53 HEMLOCK 15,600.00 15.29 121.73 15,042.58 14,864.18 1,776.73 1,595.70 2,435,743.12 318,935.52 0.00 2,387.11 15,616.40 15.29 121.73 15,058.40 14,880.00 1,774.46 1,599.37 2,435,740.79 318,939.16 0.00 2,387.99 BC_H1 15,674.45 15.29 121.73 15,114.40 14,936.00 1,766.41 1,612.39 2,435,732.54 318,952.05 0.00 2,391.14 BC H2 15,700.00 15.29 121.73 15,139.04 14,960.64 1,762.87 1,618.12 2,435,728.91 318,957.72 0.00 2,392.52 15,726.10 15.29 121.73 15,164.22 14,985.82 1,759.25 1,623.97 2,435,725.20 318,963.52 0.00 2,393.93 15,726.29 15.29 121.73 15,164.40 14,986.00 1,759.22 1,624.01 2,435,725.17 318,963.56 0.00 2,393.94 BC -1-13 15,763.61 15.29 121.73 15,200.40 15,022.00 1,754.05 1,632.38 2,435,719.87 318,971.85 0.00 2,395.96 8L H4 15,797.82 15.29 121.73 15,233.40 15,055.00 1,749.31 1,640.05 2,435,715.01 318,979.44 0.00 2,397.82 BC -HS 15,800.00 15.29 121.73 15,235.51 15,057.11 1,749.00 1,640.54 2,435,714.70 318,979.93 0.00 2,397.94 15,866.86 - 15.29 121.73 15,300.00 , 15,121.60 1,739.73 1,655.53 2,435,705.20 318,994.77 0.00 2,401.55 Total Depth : 15866.86' MD, 15300' TVD .4 112" x 5 718" Targets Target Name -hitimiss target Dip Angle Dip Dir. TVD +N/-9 +E/ -W Northing Easting -Shape V) V) (usft) (usft) (usft) (usft) (usft) BCU 5RD2 wp01 Tgt1 0.00 0.00 15,164.22 1,759.25 1,623.97 2,435,725.20 318,963.52 - plan hits target center - Circle (radius 50.00) 5202018 6:03:12PM Page 7 COMPASS 5000.1 Build 81E HALLIBURTON Database: Sperry EDM - NORTH US+CANADA Company: Hilcorp Alaska, LLC Project: Beaver Creek Unit Site: Beaver Creek Unit Well: Beaver CK Unit 5 Wellbore: BCU 5RD2 Design: BCU 5RD2 wp02 Casing Points Measured Vertical Depth Depth (usft) (usft) 14,500.00 14,008.58 7' TOW 14,500.00 14,008.58 Plan Annotations Well Beaver CK Unit 5 Measured Vertical Depth Depth (usft) (usft) 14,500.00 14,008.58 14,517.00 14,023.54 14,547.00 14,049.90 15,277.66 14,731.65 15,866.86 15,300.00 Halliburton Standard Proposal Report Local Coordinate Reference: Well Beaver CK Unit 5 TVD Reference: BCU 5RD2 wp01 RKB @ 178.40usft (HEC 169) MD Reference: BCU 5RD2 wp01 RKB @ 178.40usft (HEC 169) North Reference: True Survey Calculation Method: Minimum Curvature Casing Hole Diameter Diameter Name 7 8-1/2 Local Coordinates +NIS +E/ -W (usft) (usft) Comment 1,808.53 1,252.15 StartDir 12°/100': 14500' MD, 14008.58TVD : 80° RTTF 1,811A0 1,259.69 End Dir : 14517' MD, 14023.54' TVD 1,816.00 1,273.25 Start Dir Wit 00': 14547'MD, 14049.9'TVD 1,821.42 1,523.42 End Dir : 15277.66' MD, 14731.64' TVD 1,739.73 1,655.53 Total Depth: 15866.86' MD, 15300' TVD 5/202018 6:03:12PM Page 8 COMPASS 5000.1 Build 81E Hilcorp Alaska, LLC Beaver Creek Unit Beaver Creek Unit Beaver CK Unit 5 BCU 5RD2 PTD 174-018 BCU 5RD2 wp02 Sperry Drilling Services Clearance Summary Anticollision Report 20 May, 2018 aossst Approach 30 Froxlmly scan on Cunant Survey Data (NOM Rehrencel Reference 0ealgn: Bever Crank Unit - Beaver CK Unit 5 -BCU SRD2-BCU 5RD2 "D2 Well Coordinatea: 2,03,01.43 N. 317,312.59 E (50' 39' 30.21' N,151' 01.05.8)' W) Data. H.I9hl: BLU 5RD2 wp01 RKB @ 178.40uaR (HEC 189) Sun Rang.: 14,500.00 to 15,858.98 watt Measured Depth. Scan Radius Is 1,784.0 usff . Clearance Factor cutoff Is UnIlmKed. Mas Ellipse Separation Is Unlimited Goodish, Sale Factor Applied Version:SOOo.1 Build: 51E Scan Type: Scan Type: 2500 r r HALLIBURTON Sperry Drilling Services HALLIBURTON Anticollision Report for Beaver CK Unit 5 - BCU 5RD2 vil Hilcorp Alaska, LLC Beaver Creek Unit Llosesl Approach 3D Proximity Bonn on Current Survey Dab (North Reference) Reference Design: Beaver Creek Unit -Beaver CK Unit 5 -BCU 5R@ -BCU SRD2 wp02 Bonn Range: 14,500.00 to 15,866.36 tech. Measuretl Depth. Scan Radius is 1,78160 van. Clearance Factor ounce is Unlimited Max Ellipse Separation is Unlimited Measured Minimum @Measareit Ellipse elMeasured Clearance Summary Based on Blnc Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (use) (use) (usb) (usN) use Beaver Creek Unit Bolivar CK Unit 5 -BCU 5- BCU 5 14,800.00 16.31 14,80.00 Deaver CK Unit 5 -BCU SRO - BCU 5RD 14.00000 1631 14,800.00 SumeyfoolOroeranl From To Surveyntan fine, (use) 10540 7,965.40 8,00540 14,500.00 14,590.00 15,866.66 BCU 5RD2 wp02 Ellipse enm terms are consisted across surrey tool tie -on polnis. Calculated ellipses incorporate surface all Separation is the actual distance between el4psoids. Distance Between centres is the stalgbt line distance bouseen wellbcre contras. Cla sance Factor= Dlelance 3e1hereen Profiles I (Distance Between Profks - Ellipse Sepaafron). All station coordinates were calculated using the Minimum Curvature method. 3.68 14,794.06 1.292 Cleaance Factor Pass - 3.68 14,79408 1,292 Clearance Factor Pass - Surrey Most 2_Unknown 2 CB -191m !VIS z MMIAXfSag M May, M18 - 1807 Page 2 of 4 COMPASS Project: Beaver Creek Uni( REFERENCE INFORMATION er1 Dn[ nesm CK Uit5 N 1931(NADC(N CCMIS) AIvb�2me01 HALLIHURTON Site: Beaver Creek Unit coomn�•N Quo Nxe.,,..: w I Bm— CN wN S. T—Nen c "a le¢1: 1515, Well: BBaVer CK Units lows axe.,,w: PwsO..01 a8a g ne.mx 0. last x-s +IW Nore,H �w tsu. 1-0. Bpecry ��Illing Mae 0..'Wti qnp aCUF IRXa@•re•Nx plEclE61 ON ON N3399143 ll"131359 69.65839N -1510182W c.N Wellbore: BCU 5RD2 °" ' ' ""'""` "" Plan: BCU 5RD2 wp02 sURVEv PROGRAM GLOBAL FILTER: Jen user tlTsaedlm 8 MeeP9 clilma t4500.00To Isoe06 NW From NP. To Surve '- Tool ® Ladder/S.F. Plots 10540 7005.40 BLIISUnMam Mag801ia LwnEo lBCU 513_UnMown CASING DECdS M$ .gy aUCsl .540 14500.00 BLU6UBM 2w-U4'=. 14500.00 1516686 BLUSRINvMIBCUSRD21 27mWm•5a0 'ND TVDSS Cm Six Name 1.8581383OAS PWOW ].000 ]'TOW 153NO 1512160 15866.86 4500 4in'.v 5W us 1 0160.00 d I I X120.00 m BV5 a w 80.00 I � U i , I 40.00 � Ecus ! m 5RD U ;V 0.00 14100 14250 14400 14550 14]00 1/850 15000 15150 15300 15450 15615750 15800 18050 16200 16350 16500 18850 16800 Measured Depth (300 usf /in) 4.50 _ `o 300 LL I To n Collision Risk Procedures Req. Collision Avoidance Req. 1 No-Do Zone -. Stop Dnlling I 000 14000 14200 14400 14600 14800 15000 15200 15400 15600 15800 16000 16200 16400 16E00 16800 Measured Depth (300 usfUin) N Ililrnrp AlaekP, U.C. 6.0 Planned Wellbore Schematic BC - Pad 3 1,196' PNL„ 1,406' FWL, II:ImrP.Un.44. LIF gee. 34, T7N, R10W, S.M. Pam1K •: TBD AN t Teo Pn1D, Das A -0280B3 ?* KBOWntlen: 173' (18'AGL) ' Spud: 12M911975 810.5elSksed 32311976 l x r3-135// a17p Q•%. sAeN /� GFA' Debrtsoncasln,wall 13,0]3' Tag w/ 5.75' on mershat 13/24/14) 13,123' Tag w/ 550" LIB (3/x/14) — 7.0 7Tr BCU 05RD2 Drilling Procedure Rev 0 PROPOSED SCHEMATIC Dunauaw 20' "a B4po1 =0L JI Kana( Pe0lnsuMBamu90 MD D Untn, TVD 0' 432' 53319¢ Oealna 13318' 81Botlomppi in-5 155' I R103(aOae GL)', MO 0 3,511' 7VD 0' 3,511' rw Im5111 0 aP- 9-52' 10 PTT-pa1pa1�0 47 pptppt MD w 11,89H' TVD 0' 11,405' Lin T P-110 32 opt MD 11,531' 14,91T WD 14,500' 14,00.008' I 0-1214-1 " L40 12.0 ppl lee 84BNIl 14,400' 15,86T TVD 13,380' 15,300' pyo 7 9/ 9 /y YSoi o lo -1 1y qes — /3 5 i 'Pump 40 bbis of 15.8 ppg classG / l cement. Planned cement top is at the E > — top of the liner at 14,400' P//<i ! 1^V!'P ,,• ls6.S� 1 IR pe]o 15,a0TMp 15-7 riv 15,3pB'TVD 1s,2ar rvo Well Named NumOec 9 rCreak unit R5RD2 Lease: A.028083 O .rt,"Pansk: Kana( Pe0lnsuMBamu90 0uteNrw. Abnke D Untn, u3A Mille �1(DP and DepM: 20• 14$00' IM91W.ffs'1 20• DM 0 2"'214.54T I Dale Camplele0a I GfnunEL 1( MSy' 155' I R103(aOae GL)', 18' RMse4 Byl N. MaereI O9wnn91e RMI O t'I I 3rn RMI Date 51298010 Page 6 Revision 0 May 2018 Rixse, Melvin G (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Friday, June 15, 2018 9:32 AM To: Rixse, Melvin G (DOA) Subject: RE: Beaver Creek 5RD2 PTD(218-068) - Tyonek High Pressure Water Yes sir that is correct. (7750 psi / 14274 ft)/.052 = 10.4 Monty M Myers Drilling Engineer 907.538.1168 (c) 907.777.8431 (o) From: Rixse, Melvin G (DOA) [mailto:melvin.rixse@alaska.gov) Sent: Friday, June 15, 2018 9:28 AM To: Monty Myers <mmyers@hilcorp.com> Subject: RE: Beaver Creek 5RD2 PTD(218-068) -Tyonek High Pressure Water Monty, Just to confirm: 10.4 ppg @ approximately 14,274' TVD? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e- mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231) or (Melvin Rixse@alaska.govI. From: Monty Myers [mailto:mmyers@hilcorp.com) Sent: Friday, June 15, 2018 9:10 AM To: Rixse, Melvin G (DOA) <melvin rixse@alaska.aov> Subject: RE: Beaver Creek 5RD2 PTD(218-068) - Tyonek High Pressure Water Good morning Mel, The HP water is expected. It is expected to be about a 10.4 ppg equivalent formation pressure. We will handle it the same way as we will in Swanson. We will have a full blown MPD system rigged up for it. Monty M Myers Drilling Engineer 907.538.1168 (c) 907.777.8431 (o) From: Rixse, Melvin G (DOA) [mailto:melvin rixseC@alaska.govj Sent: Thursday, June 14, 2018 3:21 PM To: Monty Myers <mmyersC@hilcorp.com> Subject: Beaver Creek 5RD2 PTD(218-068) - Tyonek High Pressure Water Monty, For your PTD request for BC - 5RD2, my geologist stated that you anticipate drilling into a high pressure water sand pressurized to -7750 psi @ 14,274' TVD. I am not sure where this value came from. Can you confirm that this is or is not expected? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin Rixse@alaska.zov). Davies, Stephen F (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Friday, June 8, 2018 2:04 PM To: Davies, Stephen F (DOA) Subject: RE: BCU 05-RD2 (PTD #218-068) - Questions Good afternoon Steve, My apologies for taking a few days to respond. As far as I am aware we have not encountered any H2S while drilling any wells in Beaver Creek. I was personally involved in sidetracking BC #7 and drilling BC #23, 24, 25. However, these wells are not open to the Hemlock formation. The only 2 wells we have open to the Hemlock are BC #4 and #5. Talking to our geologist, he hasn't seen reports of any H2S from any wells either. The operations manager has also stated that we see no H2S in production from Beaver Creek. Let me know if you have any additional questions. Have a great weekend! Monty M Myers Drilling Engineer 907.538.1168 (c) 907.777.8431(o) From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Wednesday, June 6, 2018 5:27 PM To: Monty Myers <mmyers@hilcorp.com> Subject: BCU 05-RD2 (PTD #218-068) - Questions Monty, Has Hilcorp encountered any H2S while drilling to, or producing from, the Beaver Creek Oil Pool (Hemlock Formation)? If yes, could you please provide a list of the wells containing H2S, the most recent measured H2S values for each well, and the depths at which those measured values were recorded? Thank you, Steve Davies AOGCC 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.daviesPalaska.gov. AOGCC PTD No. 218-068 Coordinate Check 6 June 2018 INPUT Geographic, NAD27 BCU 05-RD2 Latitude: 60 39 31.21300 Longitude:151 01 05.86700 OUTPUT State Plane, NAD27 5004 -Alaska 4. U.S. Feet v1 Northing/V: 24 34 092.98 6 Easting/X: 319314.140 Convergence: -0 53 15.67623 Scale Factor: 0.999937978 Remark: Corpscon v6.0.1, U.S. Army corps of Engineers TRANSMITTAL LETTER CHECKLIST WELL NAME: erect-tc PTD: Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: &tom Vt,,j- POOL: &CyYr/ ('IP,91- C)tI 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- _ function the (If last two digits Production should continue to be reported as a of original in API number are API number stated above. between 60-69 hi 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 permig. 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 BEAVER CREEK, BEAVER CREEK OIL - 80100 Well Name: BEAVER_CK UR11T 05RD2 Program DEV _ Well bore seg ❑ PTD#: 2180680 Company HILCORP ALASKA LLC -. _ Initial Class/Type _ DEV /-PEND GeoArea 820 Unit 50212 On/Off Shore On _ Annular Disposal 7 1 2 3 4 5 6 7 Appr Date 1 1 SFD 6/8/2018 12 I13 14 15 16 Engineering Appr Date MGR 6/19/2018 Geology Appr Date SFD 6/8/2018 18 19 Nonconven.. gas conforms to AS31.05,0300 t.A),0 2.A -D) - - NA. Public Comm" loner Permit fee attached- - - - - NA Lease number appropriate- - - - Yes Unique well name and number - - Yes - - - - ---- - - - - - - - - - - - Well located in defined pool.. - .... Yes BEAVER CREEK, BEAVER CREEK OIL - 80100 governed by CO 2378 issued May 6, 2016 Well located proper distance from drilling unit boundary - - Yes Rule 3(b): Well. spacing -in the Beaver Creek Oil Pool shall be 40 acres.. No wellbore -may be opened Well located proper distance from other wells - - - - Yes nearer than 660 feet from the nearest open wellbore in the same pool.. No wellbore may be opened - Sufficient acreageavailablein drilling unit Yes nearer than $00 feel from the exterior boundary of the Beaver Creek. Unit where owners and landowners If. deviated, is wellbore plat. included - - - - - Yes are not the same on both sides of the line. As planned, well conforms to spacing requirements... Operator only affected party... - Yes Operator hasappropriatebond in force - - Yes .Permit can be issued without conservation order _ _ _ - - - Yes Permit can be Issued without administrative. approval _ _ _ _ - _ _ _ _ _ _ _ _ - _ Yes Can permit be approved before 15 -day wart.. - - - - - .... Yes Well.located within area and strata authorized by. Injection Order # (put 10# in. comments). (For. NA... All wells. within. 114. mi[e 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.. Conductor stringprovided- - - . _ - - - _ _ .. NA Surface casing protects all known USDWs - - - - - -- - - - - - - - - ----- NA - Redrill of. production hole only CMT. vol adequate to circulate. on conductor& surf csg ...... . . . ......... . . . NA. - - Redrill of.production hole only GMTvoladequate to tie-in long string to surf csg. - - - - - - - -- - - - ----- - - - NA - Redrill of production hole only CMT will coverall knownproductivehorizons- - - -- -- - - - - - - - - - - - - - - -- Yes .... Production horizon is the Beaver Creek- - , , .. _ . _ Casing designs adequate for CJ, B & permafrost. - ......... ................. Yes....-..... . Adequate tankage or reserve pit ........ . . . . ..... . . . . . ...... Yes - - - - If a re -drill, has 10-403 for abandonment been approved -- - - - - - - - - - - - - - --- - - - Yes Adequate wellbore separationproposed- - - - - - - ---- - - Yes - - - - - - - - - - - Ifdiverter required, does it meet regulations - - - NA - - - - No diverter required . Drilling Fluid program schematic& equip list adequate . ....... . . . . ..... . Yes- BOPEs do they meet regulation - - - - - . ........ . . . . . . . . . .... . . Yes BOPE. press rating appropriate: Jest to -(put psig in comments)- - - - - - - - - - --- - - - - - Yes - BOPS test. to 4500 psi..... - . Choke manifold complies w/API RP -53 (May 84) - - - - - - - . - - - Yes - - Will -need two full opening valves upstream. of choke manifold .Work will occur without operation shutdown- - - - ------- - - - - - - - - - - Yes Is presence of H2$ gas probable - - - - - - ----- - - - - - - - - - - - .... No. - - - .... No H2S in the area - ....... . Mechanical condition of wells within AOR verified (For service well only) - - - - - - -- - - - - - - NA . , ...... - _ _ _ - _ - _ - - - - - - _ . _ - _ - - - - _ _ ...... Permit can be issued w/o hydrogen sulfide measures . . . . . . . . ......... Yes .... - - - H2S has not been encountered in the Hemlock at BCU.. Datapresentedon potential overpressure zones - - - - - - - - ---- - - - - - - - -- Yes .... - - - High-pressure water sands will be encountered below KOP for this wellbore. Anticipated pressure is 7750. psi, Seismic analysis. of shallow gas.zones- - - - - - - - - .... .. - - - - - .. NA- - - - - - - - or about 10.45 ppg. EMW. Planned mud weight for drilling ranges from 9.5 to 10.5.ppg. Operator plans Seabed condition survey (if off -shore) - - ----- - - - - - - - - - - ---- - - - - - - - - -- NA ... - - to use Managed PressureDrillingTechnique to pontroltlow from water sands while drillingproductionhole.. Contact name/phone for weekly -progress reports. [exploratory only] ...... Geologic Engineering Commissioner: Date: Commissioner: Date Public Comm" loner Date