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214-130
Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 4/4/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240404 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 19RD 50133205790100 219188 2/23/2024 YELLOW JACKET GPT-PERF BRU 241-23 50283201910000 223061 11/25/2023 AK E-LINE Perf HV B-13 50231200320000 207151 3/11/2024 YELLOW JACKET GPT KALOTSA 6 50133206850000 219114 3/2/2024 YELLOW JACKET PERF KU 13-06A 50133207160000 223112 3/13/2024 YELLOW JACKET GPT-PERF KU 21-06RD 50133100900100 201097 3/19/2024 YELLOW JACKET GPT-PERF END MPI 2-62 50029216480000 186158 2/14/2024 YELLOW JACKET PERF MPU G-18 50029231940000 204020 3/21/2024 READ Caliper Survey MPU G-18 50029231940000 204020 3/9/2024 AK E-LINE HoistCutter MPU I-24 50029237780000 224001 3/11/2024 AK E-LINE CBL NCIU A-18 50883201890000 223033 12/20/2023 AK E-LINE Perf NCIU A-18 50883201890000 223033 12/18/2024 AK E-LINE GPT/Plug/Perf PAXTON 3 50133205880000 209168 3/6/2024 YELLOW JACKET GPT PAXTON 3 50133205880000 209168 3/8/2024 YELLOW JACKET PERF PAXTON 3 50133205880000 209168 3/12/2024 AK E-LINE PPROF PAXTON 7 50133206430000 214130 2/26/2024 YELLOW JACKET PERF PBU 09-52 50029236180000 218168 3/24/2024 HALLIBURTON PPROF SD-06 50133205820000 208160 2/20/2024 YELLOW JACKET PERF SRU 222-33 50133207150000 223100 12/19/2023 AK E-LINE Perf Please include current contact information if different from above T38683 T38684 T38685 T38686 T38689 T38687 T38690 T38691 T38691T38692 T38963 T38963 T38694 T38694 T38694 T38695 T38696 T38697 T38698 PAXTON 7 50133206430000 214130 2/26/2024 YELLOW JACKET PERF Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.09 13:48:29 -08'00' 1. 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: Install Cap String 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 4,695 feet 3,446 feet true vertical 2,193 feet 3,562 feet Effective Depth measured 3,446 feet N/A feet true vertical 1,820 feet N/A feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Cap String 3/8" 2,500' MD 1,539' TVD Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5# / L-80 3,434' MD 1,816 TVD 170 MD Packers and SSSV (type, measured and true vertical depth)N/A N/A Baker TE-5 TRSV 170 TVD 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: Scott Warner, Operations Engineer 324-054 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG 191 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 N/A scott.warner@hilcorp.com 907-564-4506 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 21 Size 138' 3 21236 0 780 78 measured TVD 5-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 214-130 50-133-20643-00-00 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: ADL0384372 / Fee-Private Ninilchik Field / Beluga-Tyonek Gas Ninilchik Unit Paxton 7 Plugs Junk measured Length Production Liner 3,542' Casing Structural 1,849'3,542' 138'Conductor Surface Intermediate 16" 9-5/8" 138' 1,936' 7,480psi 5,750psi 10,640psi 1,936'1,374' Burst Collapse 3,090psi p k ft t Fra O s 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 Grace Christianson at 9:16 am, Mar 27, 2024 Noel Nocas (4361) Digitally signed by Noel Nocas (4361) Date: 2024.03.26 17:43:04 -08'00' RBDMS JSB 040224 DSR-4/12/24 Updated by DMA 03-20-24 SCHEMATIC Ninilchik Unit Well: Paxton #7 PTD: 214-130 API: 50-133-20643-00-00 PBTD = 3,446’ MD / 1,820’ TVD TD = 4,695’ MD / 2,193’ TVD CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor 109 X-56 Weld 16” Surf 138' 9-5/8" Surf. Csg 40 L-80 BTC 8.835” Surf 1,936’ 5-1/2" Prod Casing 17 P-110HC DQX 4.892” Surf 3,542’ TUBING 2-7/8” Production 6.5 L-80 EUE-8rd 2.441” Surf 3,434’ 2 4 16” 9-5/8” 5.5” JEWELRY DETAIL No. Depth MD Depth TVD ID OD Item 1 170’ 170’ 2.441” 2.875” Baker TE-5 TRSV 2 2,500’ 1,539’ 3/8” Cap String 3/14/24 3 3,434’ 1,816’ -- 3.7” Float shoe/Landing collar 9/15/23 PERFORATION DETAIL New Sand Name Old Sand Name Top MD Btm MD Top TVD Btm TVD Date Status BEL 10 BEL 10 2,345' 2,364' 1,492' 1,498' 10/10/23 Open BEL 10 BEL 10 2,366’ 2,376’ 1,498’ 1,501’ 02/27/24 Open BEL 10 BEL 10 2,387' 2,406' 1,504' 1,510' 10/10/23 Open BEL 13 Beluga IV 2,456’ 2,510’ 1,525’ 1,542’ 12/22/15 Isolated BEL 13 BEL 13 2,456’ 2,485’ 1,525’ 1,534’ 02/27/24 Open BEL 13 BEL 13 2,485’ 2,520’ 1,534’ 1,545’ 02/27/24 Open BEL 16 Beluga IV 2,586’ 2,606’ 1,565’ 1,571’ 11/05/14 Isolated BEL 16 BEL 16 2,586’ 2,613’ 1,565’ 1,573’ 02/27/24 Open BEL 16 Beluga IV 2,606’ 2,618’ 1,571’ 1,574’ 12/22/15 Isolated BEL 16 Beluga IV 2,613' 2,644' 1,573' 1,582' 02/26/24 Open BEL 16 Beluga IV 2,613’ 2,654’ 1,573’ 1,585’ 12/21/15 Isolated BEL 16 BEL 19 2,644' 2,654' 1,573' 1,585' 02/26/24 Open BEL 20 BEL 20 2,763' 2,777' 1,618' 1,622' 10/08/23 Open BEL 30 BEL 30 2,958' 2,980' 1,674' 1,680' 02/26/24 Open BEL 34 BEL 34 3,053' 3,067' 1,701' 1,705' 10/09/23 Open BEL 37 BEL 37 3,109' 3,120' 1,717' 1,721' 10/08/23 Open BEL 37 BEL 37 3,129' 3,134' 1,723' 1,725' 10/08/23 Open BEL 37 BEL 37 3,161' 3,180' 1,733' 1,738' 10/08/23 Open BEL 38 BEL 38 3,185' 3,193' 1,740' 1,742' 10/07/23 Open BEL 41 BEL 41 3,380' 3,394' 1,800' 1,804' 10/07/23 Open 1 TOF at 3,562’ BOF at 3,916’ Fish details: 8-1/2” PDC bit, mud motor, Float sub, stabilizer, MWD collar, Dual gamma ray collar, resistivity collar, Den/Neu collars (with nuclear source), (2) non mag flex collars, (4) jts HWDP, jar, (1) jt HWDP. OPEN HOLE / CEMENT DETAIL 9-5/8" 177BBL’s of cement in 12-1/4” Hole. Returns to Surface 5-1/2” 121BBL’s of cement in 8-1/2” Hole. TOC 755’ Calculated 2-7/8” 41 BBLS’s of 15.3# cement. TOC 830’ 9/18/23 TOC @755’ RKB = 17.6’ Bel 20 TOC @830’ Bel 10 Bel 30-41 Bel 13 Bel 16 2 Page 1/1 Well Name: NINU Paxton 07 Report Printed: 3/20/2024www.peloton.com Alaska Weekly Report - Operations Jobs Actual Start Date: End Date: Report Number 1 Report Start Date 2/19/2024 Report End Date 2/20/2024 Last 24hr Summary MIRU Cap string truck. Function test equipemnt. Pull 2785' of 3/8" SS capillary tubing/Soap string to surface. Remove pack off assembly and install night cap. Report Number 2 Report Start Date 2/26/2024 Report End Date 2/27/2024 Last 24hr Summary PJSM. Well flowing at 138 mcfd, FTP 73 psi. SI well. MIRU Yellow Jacket wireline. P-test WL lubricator to 250/2500 psi - good. Perforate BEL 30 from 2958 - 2980', BEL 16 (RP) from 2644 - 2654', and 2613 - 2644'. LD tools and lubricator. Secure well. SITP 233 psi. SDFN. Report Number 3 Report Start Date 2/27/2024 Report End Date 2/28/2024 Last 24hr Summary PJSM. SITP 242 psi. PU guns and p-test WL lubricator to 250/2500 psi - good. Perforate BEL 16 (RP) from 2586 - 2613'. Perforate BEL 13/BEL 13 (RP) from 2485 - 2520'. Perforate BEL 13 (RP) from 2456 - 2485'. Perforate BEL 10 from 2366 - 2376'. SITP 256 psi. RDMO. Turn well over to Production to flow. Report Number 4 Report Start Date 3/14/2024 Report End Date 3/15/2024 Last 24hr Summary MIRU HAK capillary string truck. PT packoff assembly 250/3500 psi. Run 3/8" capillary tubing to 2500'. Set hanger and static packoff assembly . Rig down spool and hook up to soap skid. Online with Foamer. Field: Ninilchik Sundry #: 324-054 State: ALASKA Rig/Service:Permit to Drill (PTD) #:214-130Permit to Drill (PTD) #:214-130 Wellbore API/UWI:50-133-20643-00-00 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 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? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 4,695'3,562' Casing Collapse Structural Conductor Surface 3,090psi Production Tie Back 7,480psi Liner 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 Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng scott.warner@hilcorp.com 907-564-4506 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 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: Tubing Size: PRESENT WELL CONDITION SUMMARY Scott Warner, Operations Engineer AOGCC USE ONLY Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0384372 / Fee-Private 214-130 50-133-20643-00-00 Hilcorp Alaska, LLC Proposed Pools: 6.5# / L-80 TVD Burst 3,434' 10,640psi 1,374' 138' 1,936' MDLength See Attached Schematic 5,750psi 138'138' 1,936' February 19, 2024 2-7/8" 3,542' Perforation Depth MD (ft): See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 NINU Paxton 7CO 701C Same 1,849'5-1/2" 614 psi 3,542' 3,446' Size Other: Install Cap String, N2 N/A; Baker TE-5 TRSV N/A, N/A; 170 MD / 170 TVD 2,193'3,446'1,820' Ninilchik Beluga/Tyonek Gas 16" 9-5/8" m n P s t N 66 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Coldiron at 2:32 pm, Feb 06, 2024 324-054 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.02.06 14:08:51 - 09'00' Noel Nocas (4361) BJM 2/14/24 DSR-2/13/23SFD 2/7/2024 10-404 *&:JLC 2/14/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.14 16:25:59 -06'00' RBDMS JSB 021524 Well: Paxton 7 Well Name: Paxton 7 API Number: 50-133-20643-00-00 Current Status: Gas Producer Permit to Drill Number: 214-130 Regulatory Contact: Donna Ambruz (907) 777-8305 (O) First Call Engineer: Scott Warner (907) 564-4506 (O) (907) 830-8863 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Maximum Expected BHP: 794 psi @ 1804’ TVD Based on 0.44 psi/ft Max. Potential Surface Pressure: 614 psi Based on 0.1 psi/ft gas gradient to surface Well Status: Online gas producer flowing at 200 mcfd, 1 bwpd, 88 psi FTP Brief Well Summary Paxton-07 was recently worked over in September 2023 when 2-7/8” tubing was cemented to isolate the Beluga 16 & 13 perforations. The well was then completed and brought online in several Beluga sands from the BEL 10 – BEL 41. A cap string was installed in November 2023 allowing soap/foamer to be injected and help unload water. The purpose of this work/sundry is to add perforations to the Beluga 10 through Beluga 30 sands to increase production. Wellbore Condition & History ** Sail angle of 73° from 1500’ to PBTD 9/2023 Pulled tubing, milled packer, cemented 2-7/8” tubing x 5-1/2” top of cement @ 830’ x 2-7/8” top of cement @ 755’ 10/2023 Perforated multiple Beluga sands with tractor 11/2023 Cap string installed @ 2250’ MD Pre-Sundry Steps 1. Pull cap string Procedure: 1. MIRU Eline and Tractor equipment 2. Pressure Test equipment to 2000 psi High\ 250 psi Low 3. Perforate and test the below sands from bottom up, tractor was necessary on last completed perfs due to deviation: Sand Top MD Btm MD Top TVD Btm TVD Interval BEL 10 ±2,366' ±2,376' ±1,498' ±1,501' ±10’ BEL 13 (RP) ±2,456' ±2,510' ±1,525' ±1,542' ±54' BEL 13 ±2,510' ±2,520' ±1,542' ±1,545' ±10' BEL 19 ±2,574' ±2,586' ±1,561' ±1,565' ±12' BEL 19 (RP) ±2,586' ±2,654' ±1,565' ±1,585' ±68' BEL 19 ±2,654' ±2,672' ±1,585' ±1,591' ±18' BEL 30 ±2,958' ±2,980' ±1,674' ±1,680' ±22' p 614 psi Well: Paxton 7 a) Proposed perfs are also shown on the proposed schematic in red font b) Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation c) Use Gamma/CCL to correlate d) Record Tubing pressures before and after each perforating run at 5 min, 10 min, and 15 min intervals post perf shot (If using switched guns, wait 10 min between shots) e) Pending well production, all perf intervals may not be completed f) If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations g) If necessary, use nitrogen to pressure up well during perforating or to depress water prior to setting a plug above perforations h) Frac Calcs: using 12.0 ppg EMW FIT at the surface casing shoe (0.63 psi/ft) frac gradient i) Shallowest Allowable Perf TVD = MPSP/ (0.63-0.1) = 613 psi / 0.53 = 1,156’ TVD 4. RDMO a) If necessary, re run cap string to aid with water production if encountered post perforating. Attachments: 1. Current Schematic 2. Proposed Schematic 3. Standard Well Procedure- N2 Operations Shallowest Allowable Perf TVD = MPSP/ (0.63-0.1) = 613 psi / 0.53 = 1,156’ TVD Perfs are not allowed above the surface casing shoe. -bjm Updated by DMA 02-05-24 SCHEMATIC Ninilchik Unit Well: Paxton #7 PTD: 214-130 API: 50-133-20643-00-00 PBTD = 3,446’ MD / 1,820’ TVD TD = 4,695’ MD / 2,193’ TVD CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor 109 X-56 Weld 16” Surf 138' 9-5/8" Surf. Csg 40 L-80 BTC 8.835” Surf 1,936’ 5-1/2" Prod Casing 17 P-110HC DQX 4.892” Surf 3,542’ TUBING 2-7/8” Production 6.5 L-80 EUE-8rd 2.441” Surf 3,434’ 3 4 16” 9-5/8” 5.5” JEWELRY DETAIL No. Depth MD Depth TVD ID OD Item 1 170’ 170’ 2.441” 2.875” Baker TE-5 TRSV 2 2,270’ 1,469’ Cap String 3 3,434’ 1,816’ -- 3.7” Float shoe/Landing collar 9/15/23 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Date Status BEL 10 2,345' 2,364' 1,492' 1,498' 10/10/2023 Open BEL 10 2,387' 2,406' 1,504' 1,510' 10/10/2023 Open Beluga IV 2,456’ 2,510’ 1,525’ 1,542’ 12/22/2015 Isolated Beluga IV 2,586’ 2,606’ 1,565’ 1,571’ 11/5/2014 Isolated Beluga IV 2,606’ 2,618’ 1,571’ 1,574’ 12/22/2015 Isolated Beluga IV 2,613’ 2,654’ 1,573’ 1,585’ 12/21/2015 Isolated BEL 20 2,763' 2,777' 1,618' 1,622' 10/8/2023 Open BEL 34 3,053' 3,067' 1,701' 1,705' 10/9/2023 Open BEL 37 3,109' 3,120' 1,717' 1,721' 10/8/2023 Open BEL 37 3,129' 3,134' 1,723' 1,725' 10/8/2023 Open BEL 37 3,161' 3,180' 1,733' 1,738' 10/8/2023 Open BEL 38 3,185' 3,193' 1,740' 1,742' 10/7/2023 Open BEL 41 3,380' 3,394' 1,800' 1,804' 10/7/2023 Open 1 TOF at 3,562’ BOF at 3,916’ Fish details: 8-1/2” PDC bit, mud motor, Float sub, stabilizer, MWD collar, Dual gamma ray collar, resistivity collar, Den/Neu collars (with nuclear source), (2) non mag flex collars, (4) jts HWDP, jar, (1) jt HWDP. OPEN HOLE / CEMENT DETAIL 9-5/8" 177BBL’s of cement in 12-1/4” Hole. Returns to Surface 5-1/2” 121BBL’s of cement in 8-1/2” Hole. TOC 755’ Calculated 2-7/8” 41 BBLS’s of 15.3# cement. TOC 830’ 9/18/23 TOC @755’ RKB = 17.6’ Bel IV BEL 20 - BEL 41 TOC @830’ Bel 10 2 3/8” Capillary String (11/10/23) Top Bottom MD 0’ 2,270’ TVD 0’ 1,469’ Updated by DMA 02-05-24 PROPOSED Ninilchik Unit Well: Paxton #7 PTD: 214-130 API: 50-133-20643-00-00 PBTD = 3,446’ MD / 1,820’ TVD TD = 4,695’ MD / 2,193’ TVD CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor 109 X-56 Weld 16” Surf 138' 9-5/8" Surf. Csg 40 L-80 BTC 8.835” Surf 1,936’ 5-1/2" Prod Casing 17 P-110HC DQX 4.892” Surf 3,542’ TUBING 2-7/8” Production 6.5 L-80 EUE-8rd 2.441” Surf 3,434’ 2 4 16” 9-5/8” 5.5” JEWELRY DETAIL No. Depth MD Depth TVD ID OD Item 1 170’ 170’ 2.441” 2.875” Baker TE-5 TRSV 2 3,434’ 1,816’ -- 3.7” Float shoe/Landing collar 9/15/23 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Date Status BEL 10 ±2,366' ±2,376' ±1,498' ±1,501' Proposed TBD BEL 10 2,345' 2,364' 1,492' 1,498' 10/10/2023 Open BEL 10 2,387' 2,406' 1,504' 1,510' 10/10/2023 Open Beluga IV 2,456’ 2,510’ 1,525’ 1,542’ 12/22/2015 Isolated BEL 13 (RP) ±2,456' ±2,510' ±1,525' ±1,542' Proposed TBD BEL 13 ±2,510' ±2,520' ±1,542' ±1,545' Proposed TBD BEL 19 ±2,574' ±2,586' ±1,561' ±1,565' Proposed TBD Beluga IV 2,586’ 2,606’ 1,565’ 1,571’ 11/5/2014 Isolated BEL 19 (RP) ±2,586' ±2,654' ±1,565' ±1,585' Proposed TBD Beluga IV 2,606’ 2,618’ 1,571’ 1,574’ 12/22/2015 Isolated Beluga IV 2,613’ 2,654’ 1,573’ 1,585’ 12/21/2015 Isolated BEL 19 ±2,654' ±2,672' ±1,585' ±1,591' Proposed TBD BEL 20 2,763' 2,777' 1,618' 1,622' 10/8/2023 Open BEL 30 ±2,958' ±2,980' ±1,674' ±1,680' Proposed TBD BEL 34 3,053' 3,067' 1,701' 1,705' 10/9/2023 Open BEL 37 3,109' 3,120' 1,717' 1,721' 10/8/2023 Open BEL 37 3,129' 3,134' 1,723' 1,725' 10/8/2023 Open BEL 37 3,161' 3,180' 1,733' 1,738' 10/8/2023 Open BEL 38 3,185' 3,193' 1,740' 1,742' 10/7/2023 Open BEL 41 3,380' 3,394' 1,800' 1,804' 10/7/2023 Open 1 TOF at 3,562’ BOF at 3,916’ Fish details: 8-1/2” PDC bit, mud motor, Float sub, stabilizer, MWD collar, Dual gamma ray collar, resistivity collar, Den/Neu collars (with nuclear source), (2) non mag flex collars, (4) jts HWDP, jar, (1) jt HWDP. OPEN HOLE / CEMENT DETAIL 9-5/8" 177BBL’s of cement in 12-1/4” Hole. Returns to Surface 5-1/2” 121BBL’s of cement in 8-1/2” Hole. TOC 755’ Calculated 2-7/8” 41 BBLS’s of 15.3# cement. TOC 830’ 9/18/23 TOC @755’ RKB = 17.6’ Bel IV Bel 20 Bel 30 Bel 41 TOC @830’ Bel 10 Bel 13 Bel 19 Bel 10 STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 1/12/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240112 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 221-35 50283201930000 223077 11/4/2023 AK E-LINE CBL END 1-27 50029216930000 187009 11/16/2023 YELLOWJACKET PERF KALOTSA 4 50133206650000 217063 9/28/2023 YELLOWJACKET PERF KALOTSA 8 50133207050000 222003 11/29/2023 YELLOWJACKET PERF KBU 13-8 50133203040000 177029 11/5/2023 YELLOWJACKET PERF KBU 22-06Y 50133206500000 215044 11/9/2023 YELLOWJACKET GPT KBU 22-06Y 50133206500000 215044 11/17/2023 YELLOWJACKET PLUG-PERF KBU 11-08Z 50133206290000 214044 8/24/2023 AK E-LINE GPT/CIBP/PERF KBU 22-06Y 50133206500000 215044 10/9/2023 AK E-LINE CBL KBU 23-05 50133206300000 214061 10/10/2023 AK E-LINE PLT KBU 43-07Y 50133206250000 214019 10/6/2023 AK E-LINE CIBP/PERF MPU I-01 50029220650000 190090 11/18/2023 YELLOWJACKET PERF PAXTON 12 50133207100000 223014 11/20/2023 YELLOWJACKET PERF PAXTON 7 50133206430000 214130 9/18/2023 YELLOWJACKET CBL PAXTON 7 50133206430000 214130 10/7/2023 YELLOWJACKET PERF SRU 224-10 50133101380100 222124 12/27/2023 YELLOWJACKET GPT-PLUG-PERF SRU 224-10 50133101380100 222124 11/4/2023 YELLOWJACKET PERF SRU 231-33 50133101630100 223008 11/8/2023 YELLOWJACKET PERF-PLUG-GPT SRU 231-33 50133101630100 223008 11/3/2023 YELLOWJACKET PERF SRU 231-33 50133101630100 223008 10/17/2023 YELLOWJACKET PLUG-PERF-GPT SRU 232-15 50133207140000 223091 12/6/2023 YELLOWJACKET GPT-PERF SRU 232-15 50133207140000 223091 12/2/2023 YELLOWJACKET SCBL Please include current contact information if different from above. T38273 T38275 T38277 T38278 T38279 T38280 T38280 T38281 T38282 T38283 T38284 T38285 T38286 T38287 T38288 T38288 T38289 T38289 T38289 T38290 T38290 1/18/2024 T38287PAXTON 7 50133206430000 214130 9/18/2023 YELLOWJACKET CBL PAXTON 7 50133206430000 214130 10/7/2023 YELLOWJACKET PERF Kayla Junke Digitally signed by Kayla Junke Date: 2024.01.18 11:52:00 -09'00' 1. 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: Install Cap String 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 4,695 feet 3,446 feet true vertical 2,193 feet 3,562 feet Effective Depth measured 3,446 feet N/A feet true vertical 1,820 feet N/A feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Cap String 2,270' MD 1,469' TVD Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5# / L-80 3,434' MD 1,816 TVD 170 MD Packers and SSSV (type, measured and true vertical depth)N/A N/A Baker TE-5 TRSV 170 TVD 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: 7,480psi 5,750psi 10,640psi 1,936' 1,374' Burst Collapse 3,090psi Production Liner 3,542' Casing Structural 1,849'3,542' 138'Conductor Surface Intermediate 16" 9-5/8" 138' 1,936' measured TVD 5-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 214-130 50-133-20643-00-00 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: ADL0384372 / Fee-Private Ninilchik Field / Beluga-Tyonek Gas Pool Ninilchik Unit Paxton 7 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 30 Size 138' 0 25331 0 720 71 Jake Flora, Operations Engineer 323-568 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 328 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 jake.flora@hilcorp.com 907-777-8442 N/A p k ft t Fra O s 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 Grace Christianson at 8:39 am, Dec 08, 2023 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.12.07 19:43:13 - 09'00' Noel Nocas (4361) Rig Start Date End Date Cap String 11/10/23 11/10/23 11/10/2023 - Friday Rig up capillary string tuck. Install down hole foot valve and stab on well. Pressure test wellhead connection and pack off assembly 250/1000 psi. Run 3/8 SS cap string to 2270. Set hanger and lock down pack off assembly. RDMO. Turn well over to production. Plan forward: RU soap skid and bring online. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Paxton 7 50-133-20643-00-00 214-130 Updated by DMA 12-07-23 SCHEMATIC Ninilchik Unit Well: Paxton #7 PTD: 214-130 API: 50-133-20643-00-00 PBTD = 3,446 MD / 1,820 TVD TD = 4,695 MD / 2,193 TVD CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16 Conductor 109 X-56 Weld 16 Surf 138' 9-5/8" Surf. Csg 40 L-80 BTC 8.835 Surf 1,936 5-1/2" Prod Casing 17 P-110HC DQX 4.892 Surf 3,542 TUBING 2-7/8 Production 6.5 L-80 EUE-8rd 2.441 Surf 3,434 3 4 16 9-5/8 5.5 JEWELRY DETAIL No. Depth MD Depth TVD ID OD Item 1 170 170 2.441 2.875 Baker TE-5 TRSV 2 2,270 1,469 Cap String 2 3,434 1,816 -- 3.7 Float shoe/Landing collar 9/15/23 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Date Status BEL 10 2,345' 2,364' 1,492' 1,498' 10/10/2023 Open BEL 10 2,387' 2,406' 1,504' 1,510' 10/10/2023 Open Beluga IV 2,456 2,510 1,525 1,542 12/22/2015 Isolated Beluga IV 2,586 2,606 1,565 1,571 11/5/2014 Isolated Beluga IV 2,606 2,618 1,571 1,574 12/22/2015 Isolated Beluga IV 2,613 2,654 1,573 1,585 12/21/2015 Isolated BEL 20 2,763' 2,777' 1,618' 1,622' 10/8/2023 Open BEL 34 3,053' 3,067' 1,701' 1,705' 10/9/2023 Open BEL 37 3,109' 3,120' 1,717' 1,721' 10/8/2023 Open BEL 37 3,129' 3,134' 1,723' 1,725' 10/8/2023 Open BEL 37 3,161' 3,180' 1,733' 1,738' 10/8/2023 Open BEL 38 3,185' 3,193' 1,740' 1,742' 10/7/2023 Open BEL 41 3,380' 3,394' 1,800' 1,804' 10/7/2023 Open 1 TOF at 3,562 BOF at 3,916 Fish details: 8-1/2 PDC bit, mud motor, Float sub, stabilizer, MWD collar, Dual gamma ray collar, resistivity collar, Den/Neu collars (with nuclear source), (2) non mag flex collars, (4) jts HWDP, jar, (1) jt HWDP. OPEN HOLE / CEMENT DETAIL 9-5/8" 177BBLs of cement in 12-1/4 Hole. Returns to Surface 5-1/2 121BBLs of cement in 8-1/2 Hole. TOC 755 Calculated 2-7/8 41 BBLSs of 15.3# cement. TOC 830 9/18/23 TOC @755 RKB = 17.6 Bel IV BEL 20 - BEL 41 TOC @830 Bel 10 2 3/8 Capillary String (11/10/23) Top Bottom MD 0 2,270 TVD 0 1,469 1. 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: Run Completion/Cmt Ops/N2 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 4,695 feet 3,446 feet true vertical 2,193 feet 3,562 feet Effective Depth measured 3,446 feet N/A feet true vertical 1,820 feet N/A feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5# / L-80 3,434' MD 1,816 TVD 170 MD Packers and SSSV (type, measured and true vertical depth)N/A N/A Baker TE-5 TRSV 170 TVD 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: Jake Flora, Operations Engineer 323-468 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 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 jake.flora@hilcorp.com 907-777-8442 N/A measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 63 Size 138' 0 0474 0 00 72 measured TVD 5-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 214-130 50-133-20643-00-00 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: ADL0384372 / Fee-Private Ninilchik Field / Beluga-Tyonek Gas Pool Ninilchik Unit Paxton 7 Plugs Junk measured Length Production Liner 3,542' Casing Structural 1,849'3,542' 138'Conductor Surface Intermediate 16" 9-5/8" 138' 1,936' 7,480psi 5,750psi 10,640psi 1,936' 1,374' Burst Collapse 3,090psi p k ft t Fra O s Ot 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 Grace Christianson at 3:58 pm, Oct 17, 2023 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2023.10.17 08:46:47 - 08'00' Dan Marlowe (1267) Rig Start Date End Date 9/7/23 10/10/23 09/07/2023 - Thursday PTSM, Level location for base beam, lay felt & liner, spot Base beam, & level same, spot rig to well center, spot pits, pump, mix tank, & accumulator, R/U circulating lines, start pulling elec. lines, Stand & scope mast, secure same. Take on water to pits, r/u pump line to wellhead, install berm around rig & eq. spot gen & bang board. Check well Tubing 200 psi, Pump 24 bbls down tubing pressure dropped to zero, monitor well on vac. Install BPV, N/D tree & prep wellhead, install blanking sub. N/U BOPE, install choke, kill & accumulator lines, Pressure up accumulator, function test BOPE good. Secure well, SDFN. 09/08/2023- Friday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Paxton 7 50-133-20643-00-00 214-130 09/09/2023 - Saturday PTSM, r/u, circulating head, install floor, stairs & landings. M/U test joint, 2 7/8", install & flood surface lines & eq. shell test BOPE good. Test BOPE as per Hilcorp & AOGCC requirements, test witnessed by AOGCC inspector Bob Noble, tested 250/2500, found first tests pressure too low, re-start tests had 1 FP on inside choke line valve, serviced & re-tested good. Pull landing joint & blanking sub, pump tubing vol. monitor good, pull BPV. R/U E-line w/1 9/16" hole punch, 2' w/8 shots. back out lockdown pins, Pull tension in string set slips w/25k, RIH w/tubing punch, had to pump down through SSSV, correlate to punch under packer, fire hole punch f/2196'-2198'. POOH had to pump to get up through SSV. L/D hole punch, all shots fired, P/U RCT, RIH correlate to depth setting cutter @ 2170', set anchors & fire cutter, good indication cutter fired. POOH up to 137' @ sssv, unable to pass wk string & tool string up while pumping on well, (Bullhead 2 hole volumes) set string down dropping tool string below valve, pump hole volume, clamp wire & l/d sheave, p/u handling tools, pull hanger to floor, cycle sssv land hanger back. r/u e-line sheave, POOH w/ tool string & L/D same, R/D e-line, secure well for night. PTSM, check well on vac. R/U, racking mat, pipe skate & prep floor, pump tubing volume, monitor on vac. Back out lockdowns, pull hanger to floor, lay down same. 13k up/dn wt. POOH standing back 2 7/8" tubing, recover 64 jts & 1 cut joint, 4 pups, 1 chem inj mandrel & SSSV. C/O handling Eq. P/U BHA- overshot dressed for 2 7/8" tubing, xo, bumper sub, oil jar, xo, ox , 2 7/8" PH6 pup 5.65' = 30.29'. RIH p/u 2 7/8" PH6 wk string to tag tof @2170' upwt 13k, dn wt 11k, wk down on top of fish, verify with over pull of 18k, R/U to circulate. Pump 14 bbls calcium carbonite pill chase with 6 bbls bullheading into perfs, pressure increase 350psi, shut down R/D circulating lines. Wk string, rotate 9 turns to the right 2k tq, tq fell off rotating anchor free from 2182' L/D 1 joint, secure well for night. 09/10/2023 - Sunday PJSM Check well on vacuum, Pooh 2170 ft. to surface, P/u wt. 14k. Lay down overshot with fish seal latch out of packer. Pick up BHA #2 milling assembly, 4-3/4 Packer Mill 2 Boot Basket, Bit sub, string magnet, bumper jars, oil jars (6) 3-1/8 drill collars, x-over =232.12 change out handling equipment. RIH with 2-7/8 ph. 6 work string f/ 232 ft to 2187', tagging up on packer at 2187 ft. P/U wt. 14k s/o wt. 12k. Pick up power swivel and rig up same, pick-up single install element on stripping head run in lock downs on rubber. Start milling packer from 2187 ft. with 1k increasing wt. to 5k, at 70 rpm free torque at 500 ft/lbs on bottom torque at 1000 to 1500 ft/ lbs, pumping at 2 bpm at 500 psi, made 10 inches, on packer pick up wt. 16k 10k down. Circulate hole clean (no loss of fluid), secure well for night. Rig Start Date End Date 9/7/23 10/10/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Paxton 7 50-133-20643-00-00 214-130 09/12/2023 - Tuesday PJSM, CHECK well, well on vacuum, fill well with 1.5 bbl. fluid, inspect equipment. RIH with ITCO spear dressed to catch IF of 2-7/8 tbg, from 1119 ft. to 2557 ft. tag top of fish. Push fish down 10 ft. stack out on fish to confirm latch P/up wt. 17k so 12K. Pooh with fish f/ 2567' to 209' change out handling tools for BHA. Rack back 3 stds of collars, lay out 79 ft. of fish, Remainder of packer, 2 pups, x/nipple, joint of 2-7/8 tbg, mule shoe WLRG. Cut mule shoe for Bha, rig up handling equipment. Make up mule shoe on work sting and Rih from surface to 2,606 ft, lay out two bad joints. Rigging up power swivel and circulating head, break circulation at 3.5 bpm at 490 psi, secure for night 09/11/2023 - Monday PJSM check well, well on vacuum, inspect equipment, change out 2" Diaphragm pump. With 3" diaphragm pump. Break circulation, with 8.4 ppg fluid, 6 bbl. to see returns. Mill remaining 19" of packer at 2187 ft. with 2-4k wob, free torque 1800 ft./ lbs, mill torque 2600 ft/lbs, 70 rpm pumping at 2.0 bpm at 550 psi, p/u wt. at 18k s/o wt at 12k mill thru packer check well (well static) wash and reaming down to 2199 ft. Circulate two bottoms up, 71 bbls, circ at 2 bpm at 550 psi, no losses, while milling and circulating. Rih with 2 joints on power swivel f/ 2199 ft to 2259 ft. Rig down power swivel and rack back in derrick, rig up handling equipment, remove element from circulating head. Rih on elevators f/ 2259' to 2557 ft. tag up on packer at 2557 plus 79 ft of tail pipe below packer = 2636' dpm, lay down single and make up head pin on single, make up onto string tag fish with 3k down. Circulate 56 bbls at 2 bpm at 515 psi, confirm fish still at 2557 with 3k down, prep to pooh. Pooh with 2-7/8 ph. 6 work string, from 2557 ft. to 232 ft. Change out handling equipment, for BHA rack back 3 std collars, lay down packer mill, 2 boot baskets and string magnet, make up spear on jars. Make up Itco spear dressed to catch ID of 2-7/8 tbg of 2.441", bumper sub, oil jar, (6) 3-1/8 drill collars, x/o, x/o 209. 30. RIH with 2- 7/8 ph. 6 work string f/ 209 ft. to 1119 ft. secure well for night 09/13/2023 - Wednesday Check well (well on vacuum) inspect equipment. Check parameters pumping at 3.5 bpm at 500 psi, rot wt. 14k, p/u wt. 15k s/o wt. 11k, 60 rpm 300 ft/lbs. torque, wash and ream f/ 2606 ft to 2666 ft. circulating rubber leaking. Back out lock downs and remove rubber from circulating head, replace rubber, install same and Run ln lock downs, continue washing down f/ 2666 ft, to 3439 ft.dpm (set 4k down torque increased to 2500 ft /lbs. no wash off), finial rot wt. 17k, p/up wt. 22k, s/o wt. 12k. pumping at 3.5 bpm at 500 psi pumping 120 vis sweeps as needed. Circulate 5 bbs sweep at 3439 ft surface to surface spotted 10 bbl. sweep on bottom. (no loose of fluid). Lay down one joint, rig down power swivel, rack back 1 std 2-7/8 tbg, mule shoe at 3366 ft. secure well for night. Rig Start Date End Date 9/7/23 10/10/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Paxton 7 50-133-20643-00-00 214-130 PJSM check well IA on vac, top off well, 9 bbl. in tbg and 1.5 bbl. in annulus, inspect equipment. Continue in hole picking up 2-7/8 6.4# EUE L-80 f/ 2740 ft. 3439 ft. M/up SSSV on joint 100 top of valve 169 ft. Tagged bottom at 3439 ft. Corrected Elevation, space out pipe with shoe at 3434 corrected elevation, land hanger with 8k down wt. 17 3/4 bands installed on control line. Rig up cementers, rig down pipe skate clear tongs and equipment off rig floor. PJSM WITH Fox Energy cmt crew, pump 5 bbls water, pressure test line to 1700 psi, Mix and pump 188 sxs on CL G cmt 41.1 bbl slurry, mixed at 15.3 ppg at 1.23 yld, with 5% FCD P 2% FFLs, displace with 1 bbl 8.4 water, drop dart swap to rig pump displace cmt with 19.8 bbls of 8.4 water pump plug to 1060 psi 500 psi finial circulating pressure. Had full returns during cmt job, cmt in place at 1430 hrs. Shut in tbg. Wait on cmt rigging down cmt equipment. Rig up slick line test lubricator to 2500 psi brushed SSSV 3 times AND function 2 times. Waiting on cmt holding 850 psi on tbg, rig down slick line. 09/16/2023 - Saturday Held PJSM, open well tbg pressure 850 bleed pressure to "0" MIT 2-7/8 tbg to 2000 psi 30 minutes on chart with 1/2 bbl. pump (good test) bleed off pressure with 1/2 bbl. back. Clear floor, pull landing joint, set BPV, remove rig floor. Nipple down BOPE and install tree and nipple up same test void to 5k test tree to 5k, rigging down hoses pumping out pits packing up equipment. Held PJSM Scope down derrick lay over same, secure lines on carrier, move carrier off base beam and load out same continue rigging down Burm and liner. Loading out same 09/14/2023 - Thursday PJSM check well, well on vacuum, run in stand out of derrick, make up head pin on single, RIH w/ 3366 ft to 3439 ft. tag PBTD no fill, make up circulate hose. Circulate out 10 bbl. hi vis sweep, at 3.5 bpm / 460 psi, sweep came back clean spot 5 bbl. 120 vis sweep on bottom. Rig down. Circ hose, lay down single, back out lock downs, remove circulating head element. Pooh laying down 2-7/8 PH 6 work string, change out foster tongs due to having trouble breaking out pipe. Change out handling equipment to lay down collars, run 3 stands of collars in hole pooh laying down collars. Change out handling equipment for 2-7/8 EUE completion, make up 3.70 OD, 6.4 -11.5 # EUE P110 float shoe, ON 2-7/8 6.4# l-80 EUE tbg installing 4 blade bow spring centralizers on every other joint unable to get down to 240 ft. pipe would not go, pooh removing centralizers. Run in hole with 2-7/8 6.4# EUE L-80 completion to 2740 ft secure well for night. 09/15/2023- Friday 09/18/2023 - Monday YJ E-line arrives on Paxton pad, spot equipment, obtain PTW and PJSM. MU CBL tool string with roller subs, weight bar, roller centralizers, CBL/GR/CCL. PU tools and lubricator and PT 250/1000psi. Pass. Open swab and RIH. Calibrate CBL in free pipe at 300'. RIH and locate TOC at 830', continue in hole and set down at 1550' due to 70+ deg. deviation. PU 500' and make another attempt to get deeper without success. PU and log main pass to 600'. 95-100% good cement bond. Drop down and make third attempt but set down at 1550'. POOH. OOH. Secure well and RDMO to Pearl pad. 09/23/2023 - Saturday Mobe SLB CTU from Beaver Creek. Approved PTW and held PJSM. MIRU Cruz crane and SLB CTU #13. Spot work tanks and fill supply tank with 100bbls of freshwater. Removed tree cap and N/u tree adapter. Tested BOP's as per sundry: Rams 250-2000psi, Valves 250-2000psi. Preformed drawdown test and closers times. No failures. Serviced equipment and SDFN Rig Start Date End Date 9/7/23 10/10/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Paxton 7 50-133-20643-00-00 214-130 09/24/2023 - Sunday Approve PTW and PJSM, warmed eq. P/u injector, 2 pieces of lubricator, M/u YJ 1.75x1.5" MT Ext CT connector, pull test 30k. M/u BHA as following: DFCV, BiDi Jars, Hyd Disconnect, Cicu Sub, Mud Motor and 2.27" 4 blade concave insert Mill. Stab on well, check motor, PT 250-2000psi, good test. RIH and dry tag at 3426'RKB. Picked up and started pumping 1.2bpm/3200psi, worked mill across proposed BEL41 perfs at 3380-3394'. Returns clean. After BU dropped ball and pumped 37bbls and opened circ sub. Began pumping N2, pumped 62k scf and returned 42bbls from coil and Tbg with N2 returns at surface shut down N2 pump. POOH, pressured Tbg up to 950psi with N2 and SI Tree. L/d YJ milling BHA. N/u BOP's and Installed tree cap. RD SLB CTU and associated equipment. 09/25/2023 - Monday Mobe SLC CTU equipment to yard. Emptied and released Rain for Rent tanks. Plan to perforate well in the AM. 09/26/2023 - Tuesday PJSM and PTW SITP 950psi. MIRU YJ E-line M/U gun gamma, 2.0"OD geodynamics 14', 6spf perf gun with roller boogies (CCL to top shot 12.0') Stab on lubricator and pressure test to 250psi/2,500psi - Test Good Pump 10gal of diesel to lubricate the tubing. Open well and RIH. Work guns down to 3,280ft. Work tools, cannot fall deeper. Pump 50gal of diesel, still no luck getting deeper than 3,280ft. POOH. Add 7' weight bar and skate to gun gamma, 2.0"OD geodynamics 14', 6spf perf gun with roller boogies (CCL to top shot 12.0'). RIH. Work tools to get to 1,919', make multiple attempts pulling up to the vertical section and running back in with no luck. Bleed SITP to 600psi, no luck. POOH. Remove weight bar and skate from the gun and swap to a 9' gun. RIH w/ gun gamma, 2.0"OD geodynamics 9', 6spf perf gun with roller boogies (CCL to top shot 13.0'). Sit down at 1,868', work tools, pump diesel no luck getting deeper. POOH. Swap back to 14' gun. RIH gun gamma, 2.0"OD geodynamics 14', 6spf perf gun with roller boogies (CCL to top shot 12.0'). Sit down at 1,850'. Work tools, no luck. Bleed SITP to 0psi. Work tools to 1,883ft, no luck getting deeper. POOH. R/D YJ E- line and wait on a tractor. Rig Start Date End Date 9/7/23 10/10/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Paxton 7 50-133-20643-00-00 214-130 10/07/2023 - Saturday PJSM and PTW with YJ and Altus SITP 738psi of sales gas. RU YJ and Altus MU Gamma, 2.0"OD geodynamics 14', 6spf perf gun with Altus 2.125"OD Tractor (CCL to top shot 10.0') Stab on well and pressure test lubricator to 250psi/2000psi - Test good RIH with gun and tractor. Fall to 1,852', tractor to 3,425' (PBTD). Pull log and send to town, on depth. Pull on depth and perforate BEL 41 (3,380-3,394'). POOH. All shots fired, gun wet with a little sand. SITP - 645psi 5min - 637psi 10min - 632psi 15min - 627psi. MU Gamma, 2.0"OD geodynamics 8', 6spf perf gun with Altus 2.125"OD Tractor (CCL to top shot 12.0') RIH with gun and tractor. Fall to 1,630', tractor to depth. Pull log and send to town, on depth. Pull on depth and perforate BEL 38 (3,185-3,193'). POOH. All shots fired, gun wet with a little sand. SITP - 493psi, no change in 15min. Pressured up well from 483psi to 746psi over 55min through 3/8 line with sales gas. MU Gamma, 2.0"OD geodynamics 19', 6spf perf gun with Altus 2.125"OD Tractor (CCL to top shot 11.0') RIH with gun and tractor. Fall to 1550', tractor to 2900'. Tractor shorted out, POOH. Secure well, lay down the lubricator. Troubleshoot tractor, suspect bad motor. MU and test backup tractor- Test good, build switch gun. SDFN Rig Start Date End Date 9/7/23 10/10/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Paxton 7 50-133-20643-00-00 214-130 PJSM and PTW SITP 453psi. MU Gamma, 2.0"OD geodynamics 14', 6spf perf gun with Altus 2.125"OD Tractor (CCL to top shot 11.0'). Tractor tests good at surface RIH with gun and tractor. Fall to 1650', tractor to depth. Pull correlation, on depth. Pull on depth and perforate BEL 34 (3,053-3,067'). Tools stuck, work pull up to 2900lbs, pressure up with sales gas, work tools. Tools came free pulling 3,000lbs. SITP - 453psi, no pressure change in 15min Gun dry with a little sand, tractor wheels and arms had quite a bit of sand in them. Discuss plan forward with town, decide to flow the well. Well flows ~500mcfd @ 70psi. Lay down lubricator, flush and test tractor. Decision made to flow the well overnight and perforate BEL10 tomorrow. 10/08/2023 - Sunday PJSM and PTW SITP 550psi. Pressured up well from 488psi to 653psi over 45min through 3/8 line with sales gas. MU Gamma, 2.0"OD geodynamics 19', 6spf perf gun with Altus 2.125"OD Tractor (CCL to top shot 11.0'). Tractor tests good at surface RIH with gun and tractor. Fall to 1650', tractor to depth. Pull correlation log and send to town, on depth. Pull on depth and perforate BEL 37 (3,161-3,180'). POOH. All shots fired, gun is dry. SITP - 543psi, no pressure change in 15min. MU Gamma, 2.0"OD geodynamics 5' and 11' switch guns, 6spf perf gun with Altus 2.125"OD Tractor (CCL to top shot 20' and 8.5'). Flush tractor oil, repair one wheel seal. RIH with gun and tractor. Fall to 1820', tractor to depth. Pull correlation log and send to town, on depth. Pull on depth and perforate BEL 37 (3,129-3,134') & BEL 37 (3109-3120'). POOH. All shots fired, gun is dry SITP - 480psi, no pressure change in 15min on either gun. MU Gamma, 2.0"OD geodynamics 14' gun, 6spf perf gun with Altus 2.125"OD Tractor (CCL to top shot 10.0'). Flush tractor oil RIH with gun and tractor. Fall to 1838', tractor to depth. Pull correlation log, on depth. Tractor won't power on (showing short). Work tools down as far as we can without tractor. Cannot fall to BEL34 depth, call town, decision made to shoot BEL20 zone. Pull on depth and perforate BEL 20 (2,763- 2,777') POOH. All shots fired, gun is dry. SITP - 461psi, 13psi drop in 15min. Secure well, lay down lubricator. Tested tractor at surface and the field checks looked good. Swap to back-up motor SDFN 10/09/2023 - Monday Rig Start Date End Date 9/7/23 10/10/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Paxton 7 50-133-20643-00-00 214-130 10/10/2023 - Tuesday PJSM and PTW Well flowing ~460MCFD @70 psi. MU Gamma, 1.75OD geodynamics 19', 6spf perf gun with Altus 2.125"OD Tractor (CCL to top shot 12.0'). Tractor tests good at surface RIH with gun and tractor. Fall to 1,555', tractor to depth. Pull correlation, send to town, on depth. Pull on depth and perforate BEL 10 (2,387-2,406'). Overpulls up to 1800lbs while POOH. Gun wet, all shots fired Rate climbed from 416MCFD to 520MCFD @ 70psi. MU Gamma, 1.75OD geodynamics 19', 6spf perf gun with Altus 2.125"OD Tractor (CCL to top shot 12.0'). Flush and test tractor. Change out shock sub. RIH with gun and tractor. Fall to 1,555', tractor to depth. Pull correlation, on depth. Pull on depth and perforate BEL 10 (2,345-2,364'). POOH. Gun wet, all shots fired Rate climbed from 506MCFD to 536MCFD @ 70psi. Secure well and hand over to production. RD YJ E-line and Altus tractor Updated by DMA 10-17-23 SCHEMATIC Ninilchik Unit Well: Paxton #7 PTD: 214-130 API: 50-133-20643-00-00 PBTD = 3,446 MD / 1,820 TVD TD = 4,695 MD / 2,193 TVD CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16 Conductor 109 X-56 Weld 16 Surf 138' 9-5/8" Surf. Csg 40 L-80 BTC 8.835 Surf 1,936 5-1/2" Prod Casing 17 P-110HC DQX 4.892 Surf 3,542 TUBING 2-7/8 Production 6.5 L-80 EUE-8rd 2.441 Surf 3,434 2 4 16 9-5/8 5.5 JEWELRY DETAIL No. Depth MD Depth TVD ID OD Item 1 170 170 2.441 2.875 Baker TE-5 TRSV 2 3,434 1,816 -- 3.7 Float shoe/Landing collar 9/15/23 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Date Status BEL 10 2,345' 2,364' 1,492' 1,498' 10/10/2023 Open BEL 10 2,387' 2,406' 1,504' 1,510' 10/10/2023 Open Beluga IV 2,456 2,510 1,525 1,542 12/22/2015 Isolated Beluga IV 2,586 2,606 1,565 1,571 11/5/2014 Isolated Beluga IV 2,606 2,618 1,571 1,574 12/22/2015 Isolated Beluga IV 2,613 2,654 1,573 1,585 12/21/2015 Isolated BEL 20 2,763' 2,777' 1,618' 1,622' 10/8/2023 Open BEL 34 3,053' 3,067' 1,701' 1,705' 10/9/2023 Open BEL 37 3,109' 3,120' 1,717' 1,721' 10/8/2023 Open BEL 37 3,129' 3,134' 1,723' 1,725' 10/8/2023 Open BEL 37 3,161' 3,180' 1,733' 1,738' 10/8/2023 Open BEL 38 3,185' 3,193' 1,740' 1,742' 10/7/2023 Open BEL 41 3,380' 3,394' 1,800' 1,804' 10/7/2023 Open 1 TOF at 3,562 BOF at 3,916 Fish details: 8-1/2 PDC bit, mud motor, Float sub, stabilizer, MWD collar, Dual gamma ray collar, resistivity collar, Den/Neu collars (with nuclear source), (2) non mag flex collars, (4) jts HWDP, jar, (1) jt HWDP. OPEN HOLE / CEMENT DETAIL 9-5/8" 177BBLs of cement in 12-1/4 Hole. Returns to Surface 5-1/2 121BBLs of cement in 8-1/2 Hole. TOC 755 Calculated 2-7/8 41 BBLSs of 15.3# cement. TOC 830 9/18/23 TOC @755 RKB = 17.6 Bel IV BEL 20 - BEL 41 TOC @830 Bel 10 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 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? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 4,695'3,562' Casing Collapse Structural Conductor Surface 3,090psi Production Tie Back 7,480psi Liner 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 Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Other: Install Cap String N/A; Baker TE-5 TRSV N/A, N/A; 170 MD / 170 TVD 2,193'3,446'1,820' Ninilchik Beluga/Tyonek Gas 16" 9-5/8" 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 NINU Paxton 7CO 701C Same 1,849'5-1/2" 631 psi 3,542' 3,446' Size October 27, 2023 2-7/8" 3,542' Perforation Depth MD (ft): See Attached Schematic See Attached Schematic 5,750psi 138'138' 1,936' 138' 1,936' MDLength Hilcorp Alaska, LLC Proposed Pools: 6.5# / L-80 TVD Burst 3,434' 10,640psi 1,374' Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0384372 / Fee-Private 214-130 50-133-20643-00-00 Tubing Size: PRESENT WELL CONDITION SUMMARY Jake Flora, Operations Engineer AOGCC USE ONLY Tubing Grade: jake.flora@hilcorp.com 907-777-8442 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 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: m n P s t N 66 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 2:28 pm, Oct 17, 2023 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2023.10.17 08:47:10 - 08'00' Dan Marlowe (1267) 323-568 DSR-10/19/23SFD 10/19/2023 10-404 BJM 10/20/23*&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.10.23 15:10:54 -08'00'10/23/23 RBDMS JSB 102623 Cap String Install Well Name: Paxton 7 API Number: 50-133-20643-00 Current Status: Gas Producer Permit to Drill Number: 214-130 First Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (O) Max. Potential BHP: 793 psi Based on 0.44 psi/ft gradient at 1804 ft TVD Max. Potential Surface Pressure: 613 psi Based on BHP minus 0.1 psi/ft gas gradient Well Status: Online Gas Producer: Making 400 mcfd @ 707 psi, 1 bwpd Brief Well Summary: Paxton-07 was recently worked over in September 2023 when 2-7/8” tubing was cemented to isolate the Beluga 16 & 13 perforations. The well was then completed and brought online in several Beluga sands from the BEL 10 – BEL 41. While the workover was successful, the well is already slugging due to being right below the unload rate for 2-7/8 tubing. The well has a TRSSSV that will need to be blocked open at surface once the cap string is installed. The SVS is in the horizontal run and will continue to be operational. The purpose of this work/sundry is to install a Capillary String in the well to allow for soap to be injected to help unload water. Wellbore Information: Inclination Sail angle of 73 degrees from 1500’ to PBTD Open Perfs 2345 – 3394’ MD (1492 – 1804’ TVD) (GROSS INTERVAL) Sept 2023 Pulled tubing, milled packer, cemented 2-7/8 tubing Oct 2023 Perforated multiple Beluga sands with tractor, well back online Procedure: 1. Block open / bypass the SSSV at surface 2. RU Cap String Truck. 3. Stab 3/8” capillary line into wellhead pack-off assembly. Make up BHA components. Install pack-off and pressure test against swab valve to 1000 psi. 4. RIH with 3/8” capillary string to ±2550’ MD. (Set cap string as deep as practical) 5. Install slips and connect tubing to chemical injection pump. 6. Set spool of remaining line near well 7. RD cap string unit and turn well over to production. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic Updated by DMA 10-17-23 SCHEMATIC Ninilchik Unit Well: Paxton #7 PTD: 214-130 API: 50-133-20643-00-00 PBTD = 3,446’ MD / 1,820’ TVD TD = 4,695’ MD / 2,193’ TVD CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor 109 X-56 Weld 16” Surf 138' 9-5/8" Surf. Csg 40 L-80 BTC 8.835” Surf 1,936’ 5-1/2" Prod Casing 17 P-110HC DQX 4.892” Surf 3,542’ TUBING 2-7/8” Production 6.5 L-80 EUE-8rd 2.441” Surf 3,434’ 2 4 16” 9-5/8” 5.5” JEWELRY DETAIL No. Depth MD Depth TVD ID OD Item 1 170’ 170’ 2.441” 2.875” Baker TE-5 TRSV 2 3,434’ 1,816’ -- 3.7” Float shoe/Landing collar 9/15/23 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Date Status BEL 10 2,345' 2,364' 1,492' 1,498' 10/10/2023 Open BEL 10 2,387' 2,406' 1,504' 1,510' 10/10/2023 Open Beluga IV 2,456’ 2,510’ 1,525’ 1,542’ 12/22/2015 Isolated Beluga IV 2,586’ 2,606’ 1,565’ 1,571’ 11/5/2014 Isolated Beluga IV 2,606’ 2,618’ 1,571’ 1,574’ 12/22/2015 Isolated Beluga IV 2,613’ 2,654’ 1,573’ 1,585’ 12/21/2015 Isolated BEL 20 2,763' 2,777' 1,618' 1,622' 10/8/2023 Open BEL 34 3,053' 3,067' 1,701' 1,705' 10/9/2023 Open BEL 37 3,109' 3,120' 1,717' 1,721' 10/8/2023 Open BEL 37 3,129' 3,134' 1,723' 1,725' 10/8/2023 Open BEL 37 3,161' 3,180' 1,733' 1,738' 10/8/2023 Open BEL 38 3,185' 3,193' 1,740' 1,742' 10/7/2023 Open BEL 41 3,380' 3,394' 1,800' 1,804' 10/7/2023 Open 1 TOF at 3,562’ BOF at 3,916’ Fish details: 8-1/2” PDC bit, mud motor, Float sub, stabilizer, MWD collar, Dual gamma ray collar, resistivity collar, Den/Neu collars (with nuclear source), (2) non mag flex collars, (4) jts HWDP, jar, (1) jt HWDP. OPEN HOLE / CEMENT DETAIL 9-5/8" 177BBL’s of cement in 12-1/4” Hole. Returns to Surface 5-1/2” 121BBL’s of cement in 8-1/2” Hole. TOC 755’ Calculated 2-7/8” 41 BBLS’s of 15.3# cement. TOC 830’ 9/18/23 TOC @755’ RKB = 17.6’ Bel IV BEL 20 - BEL 41 TOC @830’ Bel 10 Updated by DMA 10-17-23 PROPOSED Ninilchik Unit Well: Paxton #7 PTD: 214-130 API: 50-133-20643-00-00 PBTD = 3,446’ MD / 1,820’ TVD TD = 4,695’ MD / 2,193’ TVD CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor 109 X-56 Weld 16” Surf 138' 9-5/8" Surf. Csg 40 L-80 BTC 8.835” Surf 1,936’ 5-1/2" Prod Casing 17 P-110HC DQX 4.892” Surf 3,542’ TUBING 2-7/8” Production 6.5 L-80 EUE-8rd 2.441” Surf 3,434’ 3 4 16” 9-5/8” 5.5” JEWELRY DETAIL No. Depth MD Depth TVD ID OD Item 1 170’ 170’ 2.441” 2.875” Baker TE-5 TRSV 2 2,550’ 1,554’ Cap String 2 3,434’ 1,816’ -- 3.7” Float shoe/Landing collar 9/15/23 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Date Status BEL 10 2,345' 2,364' 1,492' 1,498' 10/10/2023 Open BEL 10 2,387' 2,406' 1,504' 1,510' 10/10/2023 Open Beluga IV 2,456’ 2,510’ 1,525’ 1,542’ 12/22/2015 Isolated Beluga IV 2,586’ 2,606’ 1,565’ 1,571’ 11/5/2014 Isolated Beluga IV 2,606’ 2,618’ 1,571’ 1,574’ 12/22/2015 Isolated Beluga IV 2,613’ 2,654’ 1,573’ 1,585’ 12/21/2015 Isolated BEL 20 2,763' 2,777' 1,618' 1,622' 10/8/2023 Open BEL 34 3,053' 3,067' 1,701' 1,705' 10/9/2023 Open BEL 37 3,109' 3,120' 1,717' 1,721' 10/8/2023 Open BEL 37 3,129' 3,134' 1,723' 1,725' 10/8/2023 Open BEL 37 3,161' 3,180' 1,733' 1,738' 10/8/2023 Open BEL 38 3,185' 3,193' 1,740' 1,742' 10/7/2023 Open BEL 41 3,380' 3,394' 1,800' 1,804' 10/7/2023 Open 1 TOF at 3,562’ BOF at 3,916’ Fish details: 8-1/2” PDC bit, mud motor, Float sub, stabilizer, MWD collar, Dual gamma ray collar, resistivity collar, Den/Neu collars (with nuclear source), (2) non mag flex collars, (4) jts HWDP, jar, (1) jt HWDP. OPEN HOLE / CEMENT DETAIL 9-5/8" 177BBL’s of cement in 12-1/4” Hole. Returns to Surface 5-1/2” 121BBL’s of cement in 8-1/2” Hole. TOC 755’ Calculated 2-7/8” 41 BBLS’s of 15.3# cement. TOC 830’ 9/18/23 TOC @755’ RKB = 17.6’ Bel IV BEL 20 - BEL 41 TOC @830’ Bel 10 2 Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/17/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231017 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 212-26 50283201820000 220058 9/2/2023 AK E-LINE Perf KBU 14-6Y 50133205720000 207149 9/18/2023 AK E-LINE GPT/Plug KBU 23-05 50133206300000 214061 9/9/2023 AK E-LINE GPT/Perf MP S-21 50029230650000 202009 10/7/2023 READ CaliperSurvey MPU C-23 50029226430000 196016 9/21/2023 AK E-LINE Perf MPU M-22 50029236450000 219111 9/20/2023 AK E-LINE Mechanical Cutter Paxton 7 50133206430000 214130 9/8/2023 AK E-LINE Tubing Punch/RCT PBU 06-16B 50029204600200 223072 10/7/2023 HALLIBURTON RBT PBU D-18B 50029206940200 215001 9/14/2023 BAKER RPM PBU J-19 50029216290000 186135 9/26/2023 AK E-LINE TTBP/Cement PBU J-23A 50029217120100 204193 10/4/2023 BAKER SPN PBU N-18A 50029209060100 208175 9/4/2023 BAKER SPN PBU P1-02A 50029217790100 202065 9/11/2023 BAKER SPN PBU P1-13 50029223720000 193074 9/15/2023 HALLIBURTON IPROF PBU R-12A 50029209210100 211055 9/7/2023 BAKER SPN Please include current contact information if different from above. T38062 T38063 T38065 T38064 T38066 T38067 T38068 T38069 T38071 T38072 T38073 T38074 T38075 T38076 10/20/2023 Tubing Paxton 7 50133206430000 214130 9/8/2023 AK E-LINE Punch/RCT Kayla Junke Digitally signed by Kayla Junke Date: 2023.10.20 08:34:04 -08'00' T38070 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, December 5, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 7 NINILCHIK UNIT PAXTON 7 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/05/2023 7 50-133-20643-00-00 214-130-0 N SPT2141300 1500 70 70 70 70 35 35 35 35 OTHER P Bob Noble 10/14/2023 Producer post rig workover, MIT-IA to 1500 psi per Sundry # 323-468. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:NINILCHIK UNIT PAXTON 7 Inspection Date: Tubing OA Packer Depth 26 1650 1547 1567IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN231014142221 BBL Pumped:0.2 BBL Returned:0.2 Tuesday, December 5, 2023 Page 1 of 1 1-Gas producer CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Chad Helgeson Cc:Donna Ambruz; Jacob Flora Subject:RE: Paxton 7 (PTD# 214-130) Sundry # 323-468 CBL Date:Wednesday, September 20, 2023 9:26:00 AM Chad, Cement looks good with top +/-825’ MD. Hilcorp has approval to perforate per sundry 323-468. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Tuesday, September 19, 2023 10:40 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com>; Jacob Flora <Jake.Flora@hilcorp.com> Subject: Paxton 7 (PTD# 214-130) Sundry # 323-468 CBL Bryan, Please see attached the CBL for the Paxton 7 annulus cement job. We were unable to get all the way to bottom due to deviation with the centralized bond tools, however the log does show 720ft of solid cement from 1546’ to 826’ in the well. We are able to get down the well with tool strings on rollers, but were unable to get there with the centralizers needed for a good bond log. Please send us approval for perforating. If you have any questions or wish to discuss these, please give me a call. Thanks Chad Helgeson Operations Engineer Kenai Asset Team 907-777-8405 - O 907-229-4824 - C The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1 Regg, James B (OGC) From:Regg, James B (OGC) Sent:Friday, September 15, 2023 3:57 PM To:Jacob Flora Cc:Chad Helgeson; Howard Hooter - (C) Subject:RE: Paxton 7 AOGCC 10-403 323-468 PTD 214-130 - BOP Testing Update Ok to proceed as planned; only required to test if you have to run in the well Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907‐793‐1236 From: Jacob Flora <Jake.Flora@hilcorp.com> Sent: Friday, September 15, 2023 2:58 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Chad Helgeson <chelgeson@hilcorp.com>; Howard Hooter ‐ (C) <Howard.Hooter@hilcorp.com> Subject: Paxton 7 AOGCC 10‐403 323‐468 PTD 214‐130 ‐ BOP Testing Update Mr. Regg, We landed the tubing hanger and cemented our 2‐7/8 per program with cement in place at 2:30pm. We pumped the cement thru a landing joint with a cement head at the rig floor. Currently we are trapping the lift pressure on the landing plug to ensure no cement comes back past the float shoe. I would like to leave the cement head on overnight and rig down/ND BOPs in the morning and NU the tree. We have a BOP test due at 9pm tonight and I wanted to make sure the AOGCC is agreeable to this timing given where we are at. Please advise if we need to take a different course of action, Greatly Appreciated, Jake CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Ninilchik Unit Paxton-7PTD 2141300 2 From: Donna Ambruz <dambruz@hilcorp.com> Sent: Tuesday, August 29, 2023 9:22 AM To: Jacob Flora <Jake.Flora@hilcorp.com> Cc: Noel Nocas <Noel.Nocas@hilcorp.com> Subject: Paxton 7 AOGCC 10‐403 323‐468 PTD 214‐130 Approved 08‐28‐23 FYI – Please distribute as necessary. Thank you. Donna Ambruz Operations/Regulatory Tech KEN Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 907.777.8305 ‐ Direct dambruz@hilcorp.com STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________NINILCHIK UNIT PAXTON 7 JBR 10/20/2023 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 Inside choke line valve FP. Test Results TEST DATA Rig Rep:SouleOperator:Hilcorp Alaska, LLC Operator Rep:Reed Rig Owner/Rig No.:Hilcorp 401 PTD#:2141300 DATE:9/8/2023 Type Operation:WRKOV Annular: 250-2500Type Test:INIT Valves: 250-2500 Rams: 250-2500 Test Pressures:Inspection No:bopRCN230909193759 Inspector Bob Noble Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 4.5 MASP: 629 Sundry No: 323-468 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.NA Test Fluid P Misc NA Upper Kelly 1 P Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 8 PNo. Valves 2 PManual Chokes 0 NAHydraulic Chokes 0 NACH Misc Stripper 0 none NA Annular Preventer 1 7"P #1 Rams 1 2 3/8" x 3 1/2 P #2 Rams 1 Blinds P #3 Rams 0 none NA #4 Rams 0 none NA #5 Rams 0 none NA #6 Rams 0 none NA Choke Ln. Valves 1 2 1/16"FP HCR Valves 1 2 1/16"P Kill Line Valves 3 2 1/16"P Check Valve 0 none NA BOP Misc 0 none NA System Pressure P3000 Pressure After Closure P2500 200 PSI Attained P14 Full Pressure Attained P36 Blind Switch Covers:PAll stations Bottle precharge P Nitgn Btls# &psi (avg)P6@ 1760 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators NA NAFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P9 #1 Rams P4 #2 Rams P4 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill NA0 9 9 9 9 9 9999 9 9 9 FP Inside choke line valve FP. 1. 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: Cap String Removal 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 4,695 feet 3,446 feet true vertical 2,193 feet 3,562 feet Effective Depth measured 3,446 feet 2,183 feet true vertical 1,820 feet 1,443 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)2-7/8" 6.4# / L-80 2,266 MD 1,468 TVD 2,183 MD 137 MD Packers and SSSV (type, measured and true vertical depth)SAB-L Pkr 1,443 TVD Baker TE-5 TRSV 137 TVD 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: 7,480psi 5,750psi 10,640psi 1,936' 1,374' Burst Collapse 3,090psi Production Liner 3,542' Casing Structural 1,849'3,542' 138'Conductor Surface Intermediate 16" 9-5/8" 138' 1,936' measured TVD 5-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 214-130 50-133-20643-00-00 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: ADL0384372 / Fee-Private Ninilchik Field / Beluga-Tyonek Gas Pool Ninilchik Unit Paxton 7 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 62 Size 138' 0 620 0 00 209 Jake Flora, Operations Engineer N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 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 jake.flora@hilcorp.com 907-777-8442 N/A p k ft t Fra O s 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 Grace Christianson at 12:17 pm, Aug 28, 2023 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.08.25 15:27:11 - 08'00' Noel Nocas (4361) Rig Start Date End Date 8/2/23 8/2/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Paxton 7 50-133-20643-00-00 214-130 08/02/2023 - Wednesday Move cap string truck form Pearl pad to Paxton pad. PTW, JSA. MIRU. Pull 2550' of 3/8" capillary tubing from well. 1600 lbs up weight. Close swab. RDMO cap string truck. Foot valve recovered and redressed. Updated by JMF 8/9/23 SCHEMATIC Ninilchik Unit Well: Paxton #7 PTD: 214-130 API: 50-133-20643-00 PBTD = 3,446 MD / 1,820 TVD TD = 4,695 MD / 2,193 TVD CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16 Conductor 109 X-56 Weld 16 Surf 138' 9-5/8" Surf. Csg 40 L-80 BTC 8.835 Surf 1,936 5-1/2" Prod Casing 17 P-110HC DQX 4.892 Surf 3,542 TUBING 2-7/8 Production 6.4 L-80 EUE-8rd 2.441 Surf 2,266 2 3 4 16 9-5/8 5.5 JEWELRY DETAIL No. Depth MD Depth TVD ID OD Item 1 124 124 2.441 4.5 Chemical Injection Sub 2 137 137 2.313 4.62 Baker TE-5 TRSV 3 2,183 1,444 2.42 4.56 Baker SAB-L Permanent Packer w/ KBH22 Anchor Seal Latch 4 2,228 1,457 2.313 3.659 X-Nipple 5 2,266 1,468 2.441 2.875 Wireline re-entry guide PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Date Status Beluga IV 2,456 2,510 1,525 1,542 12/22/15 Open Beluga IV 2,586 2,606 1,565 1,571 11/05/14 Open Beluga IV 2,606 2,618 1,571 1,574 12/22/15 Open Beluga IV 2,613 2,654 1,573 1,585 12/21/15 Open BEL 30 BEL 41 ±2,960 ±3,395 ±1,675 ±1,804 FUTURE PROPOSED 1 TOF at 3,562 BOF at 3,916 Fish details: 8-1/2 PDC bit, mud motor, Float sub, stabilizer, MWD collar, Dual gamma ray collar, resistivity collar, Den/Neu collars (with nuclear source), (2) non mag flex collars, (4) jts HWDP, jar, (1) jt HWDP. OPEN HOLE / CEMENT DETAIL 9-5/8" 177BBLs of cement in 12-1/4 Hole. Returns to Surface 5-1/2 121BBLs of cement in 8-1/2 Hole. TOC 755 Calculated 5 TOC @755 RKB = 17.6 Bel IV Bel 30 BEL 41 Top of fill at 2623 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 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? Yes No 9.Property Designation (Lease Number):10.Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 4,695'3,562' Casing Collapse Structural Conductor Surface 3,090psi Production Tie Back 7,480psi Liner 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 Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng jake.flora@hilcorp.com 907-777-8442 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 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: Tubing Size: PRESENT WELL CONDITION SUMMARY Jake Flora, Operations Engineer AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0384372 / Fee-Private 214-130 50-133-20643-00-00 Hilcorp Alaska, LLC Proposed Pools: 6.4# / L-80 TVD Burst 2,266' 10,640psi 1,374'1,936' Size 138' 1,936' MD See Attached Schematic 5,750psi 138'138' Length August 31, 2023 2-7/8" 3,542' Perforation Depth MD (ft): See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 NINU Paxton 7CO 701C Same 1,849'5-1/2" 629 psi 3,542' 3,446' Other: Run Completion / Cementing Ops / N2 Baker SAB-L Packer & Baker TE-5 TRSV 2,183 MD / 1,443 TVD & 137 MD / 137 TVD 2,193' 3,446' 1,820' Ninilchik Beluga/Tyonek Gas 16" 9-5/8" No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 11:55 am, Aug 17, 2023 323-468 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2023.08.17 10:04:09 - 08'00' Dan Marlowe (1267) DSR-8/18/23 Provide AOGCC opportunity to witness MITIA. MDG 8/22/2023 BJM 8/28/23 Perform MITIA to 1500 psi within 30 days after returning well to production after final perf interval added. BOP test to 2500 psi. Nuclear source in the well. Do not clean out cement below 5-1/2" float collar. Notify Nuclear Regulatory commission and AOGCC of any plans to mill cement above the nuclear source. X 10-404 X *&: 08/28/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.08.28 16:22:51 -08'00' RBDMS JSB 082923 Well Prognosis Well Name:Paxton 7 API Number:50-133-20643-00 Current Status:Gas Producer Permit to Drill Number:214-130 First Call Engineer:Jake Flora (907) 777-8442 (O)(720) 988-5375 (C) Second Call Engineer:Chad Helgeson (907) 777-8405 (O) Max. Potential BHP: 814 psi Based on 0.44 psi/ft gradient at 1851 ft TVD Max. Potential Surface Pressure: 629 psi Based on BHP minus 0.1 psi/ft gas gradient Well Status: SI gas producer since June 2023 Brief Well Summary Paxton 7 was drilled and completed in November 2014. The well was initially perforated in the BEL_16 upon completion, resulting in IP rates of 3.3 MMCFD. In December 2015, perforations were added in the lower BEL_16 and the BEL_13. Perforation records are vague pertaining to the perforations shot in the BEL_13 and the additional BEL_16 perfs increased pressure slightly by 3 psi. The combination of perforations in the BEL_13 & BEL_16 brought rate up to 3.0 MMCFD and stabilized the well’s decline. Since the start of 2017, decline has been extremely predictable at 17% and at present is below 1.0 MMCFD. Operations installed a cap string in the well in an attempt to help it unload in March 2022 that kept the well flowing until June 2023 when it could no longer stay unloaded. The cap string was recently pulled in August and a subsequent tag found the sand fill to be in the same place ~2600’. The objective of this sundry is to pull the 2-7/8 completion, cement in a 2-7/8” monobore to isolate the current perfs and test new Beluga zones. Notes Regarding Wellbore Condition: 11/12/14 gauges to 2620’ 11/14/15 bailer to 2603’ 03/03/22 cap string installed to 2550’ 08/02/23 cap string pulled 08/04/23 2.25” DDB to 2623’, ½ full of sand Procedure: 1. Review COAs in Approved Sundry 10-403 Form 2. MIRU 401 workover rig 3. Provide AOGCC 48hrs in advance of BOP test 4. Bullhead the 2-7/8” tubing place well on a vacuum 5. Install TWC 6. ND Tree 7. NU BOP and test to 2000 psi 8. Pull TWC 9. RU E-line, cut tubing just above packer 10. LD 2-7/8” tubing 11. TIH w workstring, mill packer 12. Spear and recover packer 13. Run 2-7/8” completion: a. 2-7/8” tubing with float equipment, set as deep as possible, (PBTD @ 3446’) b. Chemical injection sub to ~2100’ isolate the current perfs 9a. Circulate KWF into the tubing & inner annulus prior to pulling tubing. -bjm May need to wash through fill before or while running tubing. Milling through existing 5.5" float equipment is not allowed due to Radioactive source below the shoe. -bjm Well Prognosis c. TRSSSV to ~150’ 14. RILDS 15. RU cement head to landing joint, pump 40 bbls 15.3ppg cement, drop wiper dart, displace with 20 bbls water to land wiper plug a. Planned TOC in 2-7/8” x 5-1/2” annulus = 750’ b. Pump thru SSSV and CIM control line during cement job 16. Isolate tubing, WOC overnight 17. MIT tubing to 2000 psi 18. ND BOP, NU tree and test 19. RDMO Rig 401 20. RU E-line, log CBL, submit to AOGCC 21. RU Slickline, swab well dry 22. RU E-line, PT Lubricator to 2000 psi 23. Perforate and test the below Beluga sands from the bottom up: Zone Top MD Bottom MD Top TVD Bottom TVD TOTAL [FT] STATUS BEL09 2257 2268 1465 1469 11 Proposed BEL10 2345 2365 1492 1498 20 Proposed BEL10 2387 2406 1504 1510 19 Proposed BEL13 2455 2510 1525 1541 55 Currently OPEN BEL16 2585 2655 1564 1585 70 Currently OPEN BEL20 2763 2777 1617 1621 14 Proposed BEL30 2959 2979 1674 1680 20 Proposed BEL34 3053 3067 1701 1705 14 Proposed BEL37 3109 3120 1717 1720 11 Proposed BEL37 3129 3134 1723 1724 5 Proposed BEL37 3161 3180 1733 1738 19 Proposed BEL38 3185 3193 1740 1742 8 Proposed BEL40 3271 3280 1766 1769 9 Proposed BEL41 3380 3394 1799 1804 14 Proposed BEL44 3517 3547 1841 1851 30 Proposed 24. Turn over to production Contingencies: I) Coil Tubing & Nitrogen Procedure (Contingency if fill is encountered after perforating, or cement stringers after cementing): 1. MIRU Coiled Tubing, notify AOGCC 48 hours in advance of BOP test, PT BOPE to 2000 psi 2. Clean out to TD 3. Blow down well with nitrogen, trap pressure for perforating, RDMO CTU Milling through float equipment is not allowed due to presence of radioactive source below. -bjm Perform MITIA to 1500 psi within 30 days after returning well to production after final perf interval was added. -bjm Well Prognosis II) E-line Procedure (Contingency if water is encountered after perforating): 1. MIRU E-Line, PT lubricator to 2000 psi 2. RIH and set plug above the perforations OR set patch over the wet perforations. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Current Wellhead Diagram (No Planned Change to Wellhead) 4. Rig 401 BOP Diagram 5. Coil tubing BOP Diagram 6. Nitrogen SOP 7. RWO Change Form Updated by JMF 8/9/23 SCHEMATIC Ninilchik Unit Well: Paxton #7 PTD: 214-130 API: 50-133-20643-00 PBTD = 3,446’MD / 1,820’TVD TD = 4,695’ MD / 2,193’ TVD CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16”Conductor 109 X-56 Weld 16”Surf 138' 9-5/8"Surf. Csg 40 L-80 BTC 8.835”Surf 1,936’ 5-1/2"Prod Casing 17 P-110HC DQX 4.892”Surf 3,542’ TUBING 2-7/8”Production 6.4 L-80 EUE-8rd 2.441”Surf 2,266’ 2 3 4 16” 9-5/8” 5.5” JEWELRY DETAIL No. Depth MD Depth TVD ID OD Item 1 124’124’2.441”4.5”Chemical Injection Sub 2 137’137’2.313”4.62”Baker TE-5 TRSV 3 2,183’ 1,444’ 2.42” 4.56” Baker SAB-L Permanent Packer w/ KBH22 Anchor Seal Latch 4 2,228’1,457’2.313”3.659”X-Nipple 5 2,266’1,468’2.441”2.875”Wireline re-entry guide PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Date Status Beluga IV 2,456’2,510’1,525’1,542’12/22/15 Open Beluga IV 2,586’2,606’1,565’1,571’11/05/14 Open Beluga IV 2,606’2,618’1,571’1,574’12/22/15 Open Beluga IV 2,613’2,654’1,573’1,585’12/21/15 Open BEL 30 – BEL 41 ±2,960’ ±3,395’ ±1,675’ ±1,804’ FUTURE PROPOSED 1 TOF at 3,562’ BOF at 3,916’ Fish details: 8-1/2” PDC bit, mud motor, Float sub, stabilizer, MWD collar, Dual gamma ray collar, resistivity collar, Den/Neu collars (with nuclear source), (2) non mag flex collars, (4) jts HWDP, jar, (1) jt HWDP. OPEN HOLE / CEMENT DETAIL 9-5/8" 177BBL’s of cement in 12-1/4” Hole. Returns to Surface 5-1/2” 121BBL’s of cement in 8-1/2” Hole. TOC 755’ Calculated 5 TOC @755’ RKB = 17.6’ Bel IV Bel 30 BEL 41 Top of fill at 2623’ *recommend adding nuclear icon to the fish interval for easy identification (with nuclear source) Updated by JLL 08/14/2023 PROPOSED Ninilchik Unit Well: Paxton #7 PTD: 214-130 API: 50-133-20643-00 PBTD = 3,446’ MD / 1,820’ TVD TD = 4,695’ MD / 2,193’ TVD CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor 109 X-56 Weld 16” Surf 138' 9-5/8" Surf. Csg 40 L-80 BTC 8.835” Surf 1,936’ 5-1/2" Prod Casing 17 P-110HC DQX 4.892” Surf 3,542’ TUBING 2-7/8” Production 6.4 L-80 EUE-8rd 2.441” Surf 2,266’ 2 3 4 16” 9-5/8” 5.5” JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 1 ±150’ ±150’ 2.313” 4.62” Baker TE-5 TRSV 2 ±2,100’ ±1,419’ 2.441” 4.5” Chemical Injection Sub 3 ±3,446’ ±1,820’ -- 4.5” Float shoe/Landing collar PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Date Status Beluga IV 2,456’ 2,510’ 1,525’ 1,542’ 12/22/15 Open Beluga IV 2,586’ 2,606’ 1,565’ 1,571’ 11/05/14 Open Beluga IV 2,606’ 2,618’ 1,571’ 1,574’ 12/22/15 Open Beluga IV 2,613’ 2,654’ 1,573’ 1,585’ 12/21/15 Open BEL 9 – BEL 44 ±2,257’ ±3,547’ ±1,465’ ±1,851’ FUTURE PROPOSED 1 TOF at 3,562’ BOF at 3,916’ Fish details: 8-1/2” PDC bit, mud motor, Float sub, stabilizer, MWD collar, Dual gamma ray collar, resistivity collar, Den/Neu collars (with nuclear source), (2) non mag flex collars,(4)jts HWDP,jar,(1)jt HWDP. OPEN HOLE / CEMENT DETAIL 9-5/8" 177BBL’s of cement in 12-1/4” Hole. Returns to Surface 5-1/2” 121BBL’s of cement in 8-1/2” Hole. TOC 755’ Calculated 2-7/8” Planned TOC ~750’ TOC @755’ RKB = 17.6’ Bel IV Bel 9 BEL 44 Deepest perf permitted is 3394' MD. Milling below the float shoe is not permitted. -bjm 3446' per attached email from J. Flora -bjm (with nuclear source) Ninilchik Unit Paxton #7 Current 01/26/2015 Starting head, Seaboard, 16 ¾ 3M X 16'’ SOW BTM, w/ 2- 2 1/16 5M SSO 16'’ 9 5/8'’ 5 ½’’ Casing spool, Seaboard-S8, 16 3/4 3M X 11 5M, w/ 2- 2 1/16 5M SSO, 9 5/8 P seal bottom Tubing head, Seaboard-S8, 11 5M X 7 1/16 5M, w/ 2- 2 1/16 5M SSO, 7'’ BG seal bottom Ninilchik Unit Paxton #7 20 X 9 5/8 X 5 ½ x 2 7/8 Tree cap, Otis, 2 9/16 5M FE X 6 ½ Otis Quick Union Tubing hanger, SM-E-CCL, 7 X 2 7/8 EUE 8rd lift X susp, w/ 2 1/2'’ Type H BPV profile, 2- ¼ continuous control lines, Alloy material Valve, master, WKM-M, 2 9/16 5M FE, HWO, DD trim Valve, upper master, WKM-M, 2 9/16 5M FE, HWO, DD trim Valve, Swab, WKM-M, 2 9/16 5M FE, HWO, DD trim Valve, Wing, WKM-M, 2 1/16 5M FE, HWO, DD trim 2 7/8'’ 5 ½ x tubing Annulus 9 5/8 x 5 ½ Annulus EQUIPMENT HEIGHT 99.09" ADDITION FOR RING GASKETS TOTAL STACK HEIGHT 2 each @ 0.50" 99.59" OPEN AND CLOSE DATA OPEN CLOSE 2-1/16" 5M HCR 0.61 0.52 HEIGHT DATA AND WEIGHT DATA 7-1/16" 5M ANNULAR 3.21 4.57 7-1/16" 10M RAMS (PER SET) 1.3 1.3 ϳͲϭͬϭϲΗϱDEEh>Z^,&& Z ^dz> , /',d͗ϯϬ͘ϵΗ t /',d͗ϯϬϰϮ>^ ϳͲϭͬϭϲΗϱDdzW hKW , /',d͗ϰϰ͘ϭϵΗ t /',d͗ϲϰϬϬ>^ ϳͲϭͬϭϲΗϱDdzW h^d< ϳͲϭͬϭϲΗϱDZ/>>/E' ^WKK> , /',d͗ϮϰΗ t /',d͗ϭϲϬϬ>^ </>>^/ ͗Ϯ ,ϮͲϭͬϭϲΗϱDD's ,K< ^/ ͗ϭ ,ϮͲϭͬϭϲΗϱDD's Eϭ ,ϮͲϭͬϭϲΗϱD,Z STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. H i l c o r p A l a s k a , L L C Hi l c o r p A l a s k a , L L C Ch a n g e s t o A p p r o v e d S u n d r y P r o c e d u r e Su b j e c t : C h a n g e s t o A p p r o v e d S u n d r y P r o c e d u r e f o r W e l l : P a x t o n 7 ( P T D 2 1 4 - 1 3 0 ) Su n d r y # : An y m o d i f i c a t i o n s t o a n a p p r o v e d s u n d r y w i l l b e d o c u m e n t e d a n d a p p r o v e d b e l o w . C h a n g e s t o a n a p p r o v e d s u n d r y w i l l b e c o m m u n i c a te d t o t h e AO G C C b y t h e r i g w o r k o v e r ( R W O ) “ f i r s t c a l l ” e n g i n e e r . A O G C C w r i t t e n a p p r o v a l o f t h e c h a n g e i s r e q u i r e d b e f o r e i m p l e m e n t i n g t h e c h a n g e . Se c P a g e D a t e P r o c e d u r e C h a n g e N e w 4 0 3 Re q u i r e d ? Y / N HA K Pr e p a r e d By (I n i t i a l s ) HA K Ap p r o v e d By (I n i t i a l s ) AO G C C W r i t t e n Ap p r o v a l R e c e i v e d (P e r s o n a n d D a t e ) Ap p r o v a l : As s e t T e a m O p e r a t i o n s M a n a g e r D a t e Pr e p a r e d : Fi r s t C a l l O p e r a t i o n s E n g i n e e r D a t e CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Jacob Flora To:McLellan, Bryan J (OGC) Subject:RE: [EXTERNAL] Paxton 7 (PTD 220-045) RWO sundry questions Date:Monday, August 28, 2023 9:08:50 AM Hi Bryan, Please see below responses. 1. This well is fairly high angle through the fill interval and it is likely it’s a bridge/dune. I was going to wait until we see how the open perfs hold up before deciding if we will wash the completion down or make an additional cleanout run prior to running the completion. 2. Typo, should say 3446’. 3. The geologist snuck in an extra sand. We are not milling out the shoe track. Lowest sand to be tested is the accessible BEL 41 at 3380-3394’ MD. 4. Not milling shoe track 5. Not milling shoe track Let me know if you have more questions, Thanks, Jake From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Friday, August 25, 2023 11:29 AM To: Jacob Flora <Jake.Flora@hilcorp.com> Subject: [EXTERNAL] Paxton 7 (PTD 220-045) RWO sundry questions Jake, It seems like there are some depth discrepancies in the sundry application for this well. 1. Current schematic shows top of fill at 2623’. Plan is to run the new completion to 3446’ MD with no mention of a cleanout prior to running the new tubing. How will you run new tubing below fill without first cleaning out? 2. 2-7/8” tubing Btm on the proposed schematic shows it to 2266’ MD, not to 3446’ MD as shown in jewelry detail item #3. 3. Proposed base perf at 3547’ MD with proposed tubing float collar at 3446’ MD, with no mention of milling up float equipment. 4. For the contingency CTCO procedure, we need to list the max depth allowed for the cleanout to avoid milling up all the cement on top of the RA source. 5. Have you notified the nuclear regulatory commission of your plans to clean out the well? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. 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EŝŶŝůĐŚŝŬhŶŝƚ tĞůů͗WĂdžƚŽŶηϳ Wd͗ϮϭϰͲϭϯϬ W/͗ϱϬͲϭϯϯͲϮϬϲϰϯͲϬϬ Wdсϯ͕ϰϰϲ͛Dͬϭ͕ϴϮϬ͛ds dсϰ͕ϲϵϱ͛DͬϮ͕ϭϵϯ͛ds ^/E' d/> ^ŝnjĞ dLJƉĞ tƚ 'ƌĂĚĞ ŽŶŶ͘ / dŽƉ ƚŵ ϭϲ͟ ŽŶĚƵĐƚŽƌ ϭϬϵ yͲϱϲ tĞůĚ ϭϲ͟ ^ƵƌĨ ϭϯϴΖ ϵͲϱͬϴΗ ^ƵƌĨ͘ƐŐ ϰϬ >ͲϴϬ d ϴ͘ϴϯϱ͟ ^ƵƌĨ ϭ͕ϵϯϲ͛ ϱͲϭͬϮΗ WƌŽĚĂƐŝŶŐ ϭϳ WͲϭϭϬ, Yy ϰ͘ϴϵϮ͟ ^ƵƌĨ ϯ͕ϱϰϮ͛ dh/E' ϮͲϳͬϴ͟ WƌŽĚƵĐƚŝŽŶ ϲ͘ϰ >ͲϴϬ h ͲϴƌĚ Ϯ͘ϰϰϭ͟ ^ƵƌĨ Ϯ͕Ϯϲϲ͛ ϯͬϴ͟ ĂƉ^ƚƌŝŶŐ ^ƵƌĨ Ϯ͕ϱϱϬ͛ ϭϲ͟ ϵͲϱͬϴ͟ ϴͲϭͬϮ͟ ,ŽůĞ ϱ͘ϱ͟ : t >Zz d/> EŽ͘ĞƉƚŚ D ĞƉƚŚ ds/ K /ƚĞŵ ϭ ϭϮϰ͛ ϭϮϰ͛ Ϯ͘ϰϰϭ͟ ϰ͘ϱ͟ ŚĞŵŝĐĂů/ŶũĞĐƚŝŽŶ^Ƶď Ϯ ϭϯϳ͛ ϭϯϳ͛ Ϯ͘ϯϭϯ͟ ϰ͘ϲϮ͟ ĂŬĞƌd ͲϱdZ^s ϯ Ϯ͕ϭϴϯ͛ ϭ͕ϰϰϰ͛ Ϯ͘ϰϮ͟ ϰ͘ϱϲ͟ ĂŬĞƌ^Ͳ>WĞƌŵĂŶĞŶƚWĂĐŬĞƌǁͬ <,ϮϮŶĐŚŽƌ^ĞĂů>ĂƚĐŚ ϰ Ϯ͕ϮϮϴ͛ ϭ͕ϰϱϳ͛ Ϯ͘ϯϭϯ͟ ϯ͘ϲϱϵ͟ yͲEŝƉƉůĞ ϱ Ϯ͕Ϯϲϲ͛ ϭ͕ϰϲϴ͛ Ϯ͘ϰϰϭ͟ Ϯ͘ϴϳϱ͟ tŝƌĞůŝŶĞƌĞͲĞŶƚƌLJŐƵŝĚĞ W Z&KZd/KE d/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ ^W& ĂƚĞ ^ƚĂƚƵƐ ĞůƵŐĂ/s Ϯ͕ϰϱϲ͛ Ϯ͕ϱϭϬ͛ ϭ͕ϱϮϱ͛ ϭ͕ϱϰϮ͛ ϲ ϭϮͬϮϮͬϭϱ KƉĞŶ ĞůƵŐĂ/s Ϯ͕ϱϴϲ͛ Ϯ͕ϲϬϲ͛ ϭ͕ϱϲϱ͛ ϭ͕ϱϳϭ͛ ϭϮ ϭϭͬϬϱͬϭϰ KƉĞŶ ĞůƵŐĂ/s Ϯ͕ϲϬϲ͛ Ϯ͕ϲϭϴ͛ ϭ͕ϱϳϭ͛ ϭ͕ϱϳϰ͛ ϲ ϭϮͬϮϮͬϭϱ KƉĞŶ ĞůƵŐĂ/s Ϯ͕ϲϭϯ͛ Ϯ͕ϲϱϰ͛ ϭ͕ϱϳϯ͛ ϭ͕ϱϴϱ͛ ϲ ϭϮͬϮϭͬϭϱ KƉĞŶ dK&Ăƚϯ͕ϱϲϮ͛ K&Ăƚϯ͕ϵϭϲ͛ &ŝƐŚĚĞƚĂŝůƐ͗ ϴͲϭͬϮ͟Wďŝƚ͕ŵƵĚŵŽƚŽƌ͕&ůŽĂƚƐƵď͕ƐƚĂďŝůŝnjĞƌ͕DtĐŽůůĂƌ͕ƵĂůŐĂŵŵĂƌĂLJ ĐŽůůĂƌ͕ƌĞƐŝƐƚŝǀŝƚLJĐŽůůĂƌ͕ĞŶͬEĞƵĐŽůůĂƌƐ;ǁŝƚŚŶƵĐůĞĂƌƐŽƵƌĐĞͿ͕;ϮͿŶŽŶŵĂŐĨůĞdž ĐŽůůĂƌƐ͕;ϰͿũƚƐ,tW͕ũĂƌ͕;ϭͿ ũƚ,tW͘ KW E,K> ͬ D Ed d/> ϵͲϱͬϴΗ ϭϳϳ>͛ƐŽĨĐĞŵĞŶƚŝŶϭϮͲϭͬϰ͟,ŽůĞ͘ZĞƚƵƌŶƐƚŽ^ƵƌĨĂĐĞ ϱͲϭͬϮ͟ ϭϮϭ>͛ƐŽĨĐĞŵĞŶƚŝŶϴͲϭͬϮ͟,ŽůĞ͘dKϳϱϱ͛ĂůĐƵůĂƚĞĚ dKΛϳϱϱ͛ Z<сϭϳ͘ϲ͛ hƉĚĂƚĞĚďLJ:>>ϬϱͬϬϯͬϮϮ WZKWK^ EŝŶŝůĐŚŝŬhŶŝƚ tĞůů͗WĂdžƚŽŶηϳ Wd͗ϮϭϰͲϭϯϬ W/͗ϱϬͲϭϯϯͲϮϬϲϰϯͲϬϬ Wdсϯ͕ϰϰϲ͛Dͬϭ͕ϴϮϬ͛ds dсϰ͕ϲϵϱ͛DͬϮ͕ϭϵϯ͛ds ^/E' d/> ^ŝnjĞ dLJƉĞ tƚ 'ƌĂĚĞ ŽŶŶ͘ / dŽƉ ƚŵ ϭϲ͟ ŽŶĚƵĐƚŽƌ ϭϬϵ yͲϱϲ tĞůĚ ϭϲ͟ ^ƵƌĨ ϭϯϴΖ ϵͲϱͬϴΗ ^ƵƌĨ͘ƐŐ ϰϬ >ͲϴϬ d ϴ͘ϴϯϱ͟ ^ƵƌĨ ϭ͕ϵϯϲ͛ ϱͲϭͬϮΗ WƌŽĚĂƐŝŶŐ ϭϳ WͲϭϭϬ, Yy ϰ͘ϴϵϮ͟ ^ƵƌĨ ϯ͕ϱϰϮ͛ dh/E' ϮͲϳͬϴ͟ WƌŽĚƵĐƚŝŽŶ ϲ͘ϰ >ͲϴϬ h ͲϴƌĚ Ϯ͘ϰϰϭ͟ ^ƵƌĨ Ϯ͕Ϯϲϲ͛ ϭϲ͟ ϵͲϱͬϴ͟ ϴͲϭͬϮ͟ ,ŽůĞ ϱ͘ϱ͟ : t >Zz d/> EŽ͘ĞƉƚŚ D ĞƉƚŚ ds/ K /ƚĞŵ ϭ ϭϮϰ͛ ϭϮϰ͛ Ϯ͘ϰϰϭ͟ ϰ͘ϱ͟ ŚĞŵŝĐĂů/ŶũĞĐƚŝŽŶ^Ƶď Ϯ ϭϯϳ͛ ϭϯϳ͛ Ϯ͘ϯϭϯ͟ ϰ͘ϲϮ͟ ĂŬĞƌd ͲϱdZ^s ϯ Ϯ͕ϭϴϯ͛ ϭ͕ϰϰϰ͛ Ϯ͘ϰϮ͟ ϰ͘ϱϲ͟ ĂŬĞƌ^Ͳ>WĞƌŵĂŶĞŶƚWĂĐŬĞƌǁͬ <,ϮϮŶĐŚŽƌ^ĞĂů>ĂƚĐŚ ϰ Ϯ͕ϮϮϴ͛ ϭ͕ϰϱϳ͛ Ϯ͘ϯϭϯ͟ ϯ͘ϲϱϵ͟ yͲEŝƉƉůĞ ϱ Ϯ͕Ϯϲϲ͛ ϭ͕ϰϲϴ͛ Ϯ͘ϰϰϭ͟ Ϯ͘ϴϳϱ͟ tŝƌĞůŝŶĞƌĞͲĞŶƚƌLJŐƵŝĚĞ W Z&KZd/KE d/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ ^W& ĂƚĞ ^ƚĂƚƵƐ ĞůƵŐĂ/s Ϯ͕ϰϱϲ͛ Ϯ͕ϱϭϬ͛ ϭ͕ϱϮϱ͛ ϭ͕ϱϰϮ͛ ϲ ϭϮͬϮϮͬϭϱ KƉĞŶ ĞůƵŐĂ/s Ϯ͕ϱϴϲ͛ Ϯ͕ϲϬϲ͛ ϭ͕ϱϲϱ͛ ϭ͕ϱϳϭ͛ ϭϮ ϭϭͬϬϱͬϭϰ KƉĞŶ ĞůƵŐĂ/s Ϯ͕ϲϬϲ͛ Ϯ͕ϲϭϴ͛ ϭ͕ϱϳϭ͛ ϭ͕ϱϳϰ͛ ϲ ϭϮͬϮϮͬϭϱ KƉĞŶ ĞůƵŐĂ/s Ϯ͕ϲϭϯ͛ Ϯ͕ϲϱϰ͛ ϭ͕ϱϳϯ͛ ϭ͕ϱϴϱ͛ ϲ ϭϮͬϮϭͬϭϱ KƉĞŶ >ϯϬʹ >ϰϭ цϮ͕ϵϲϬ͛ цϯ͕ϯϵϱ͛ цϭ͕ϲϳϱ͛ цϭ͕ϴϬϰ͛ &hdhZ WZKWK^ dK&Ăƚϯ͕ϱϲϮ͛ K&Ăƚϯ͕ϵϭϲ͛ &ŝƐŚĚĞƚĂŝůƐ͗ ϴͲϭͬϮ͟Wďŝƚ͕ŵƵĚŵŽƚŽƌ͕&ůŽĂƚƐƵď͕ƐƚĂďŝůŝnjĞƌ͕DtĐŽůůĂƌ͕ƵĂůŐĂŵŵĂƌĂLJ ĐŽůůĂƌ͕ƌĞƐŝƐƚŝǀŝƚLJĐŽůůĂƌ͕ĞŶͬEĞƵĐŽůůĂƌƐ;ǁŝƚŚŶƵĐůĞĂƌƐŽƵƌĐĞͿ͕;ϮͿŶŽŶŵĂŐĨůĞdž ĐŽůůĂƌƐ͕;ϰͿũƚƐ,tW͕ũĂƌ͕;ϭͿ ũƚ,tW͘ KW E,K> ͬ D Ed d/> ϵͲϱͬϴΗ ϭϳϳ>͛ƐŽĨĐĞŵĞŶƚŝŶϭϮͲϭͬϰ͟,ŽůĞ͘ZĞƚƵƌŶƐƚŽ^ƵƌĨĂĐĞ ϱͲϭͬϮ͟ ϭϮϭ>͛ƐŽĨĐĞŵĞŶƚŝŶϴͲϭͬϮ͟,ŽůĞ͘dKϳϱϱ͛ĂůĐƵůĂƚĞĚ dKΛϳϱϱ͛ Z<сϭϳ͘ϲ͛ Ğů/s ĞůϯϬ dŚƌƵ >ϰϭ 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: Install Cap String 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 4,695 feet 3,446 feet true vertical 2,193 feet 3,562 feet Effective Depth measured 3,446 feet 2,183 feet true vertical 1,820 feet 1,443 feet Perforation depth Measured depth 2,456 - 2,654 feet True Vertical depth 1,525 - 1,585 feet 3/8" Cap String 2,550' MD 1,554' TVD Tubing (size, grade, measured and true vertical depth)2-7/8" 6.4# / L-80 2,266 MD 1,468 TVD 2,183 MD 137 MD Packers and SSSV (type, measured and true vertical depth)SAB-L Pkr 1,443 TVD Baker TE-5 TRSV 137 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 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: Contact Name: Contact Email: Authorized Title:Contact Phone: 7,480psi 5,750psi 10,640psi Burst Collapse 3,090psi 138' 1,374' 1,849'3,542'5-1/2" measuredPlugs Junk measured N/A Length 138' 1,936' Size Conductor Surface Intermediate 16" 9-5/8" Tie Back Liner 3,542' Casing STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 214-130 50-133-20643-00-00 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0384372 / Fee-Private Ninilchik Field / Beluga-Tyonek Gas Pool Hilcorp Alaska LLC 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Ninilchik Unit Paxton 7 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 870115 0 69 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 138' 1,936' N/A 74 Structural TVD 322-071 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: Authorized Name and Digital Signature with Date: WINJ WAG 793 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 15 78 Jake Flora Jake.Flora@hilcorp.com (907) 777-8442Dan Marlowe, Operations Manager L G Form 10-404 Revised 10/2021 Submit Within 30 days of Operations By Meredith Guhl at 10:37 am, Mar 08, 2022 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2022.03.07 17:54:12 -09'00' Dan Marlowe (1267) Updated by JLL 03/07/22 SCHEMATIC Ninilchik Unit Well: Paxton #7 PTD: 214-130 API: 50-133-20643-00 PBTD = 3,446’ MD / 1,820’ TVD TD = 4,695’ MD / 2,193’ TVD CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor 109 X-56 Weld 16” Surf 138' 9-5/8" Surf. Csg 40 L-80 BTC 8.835” Surf 1,936’ 5-1/2" Prod Casing 17 P-110HC DQX 4.892” Surf 3,542’ TUBING 2-7/8” Production 6.4 L-80 EUE-8rd 2.441” Surf 2,266’ 3/8” Cap String Surf 2,550’ 2 3 4 16” 9-5/8” 8-1/2” Hole 5.5” JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 1 124’ 124’ 2.441” 4.5” Chemical Injection Sub 2 137’ 137’ 2.313” 4.62” Baker TE-5 TRSV 3 2,183’ 1,444’ 2.42” 4.56” Baker SAB-L Permanent Packer w/ KBH22 Anchor Seal Latch 4 2,228’ 1,457’ 2.313” 3.659” X-Nipple 5 2,266’ 1,468’ 2.441” 2.875” Wireline re-entry guide PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) SPF Date Status Beluga IV 2,456’ 2,510’ 1,525’ 1,542’ 6 12/22/15 Open Beluga IV 2,586’ 2,606’ 1,565’ 1,571’ 12 11/05/14 Open Beluga IV 2,606’ 2,618’ 1,571’ 1,574’ 6 12/22/15 Open Beluga IV 2,613’ 2,654’ 1,573’ 1,585’ 6 12/21/15 Open 1 TOF at 3,562’ BOF at 3,916’ Fish details: 8-1/2” PDC bit, mud motor, Float sub, stabilizer, MWD collar, Dual gamma ray collar, resistivity collar, Den/Neu collars (with nuclear source), (2) non mag flex collars, (4) jts HWDP, jar, (1) jt HWDP. OPEN HOLE / CEMENT DETAIL 9-5/8" 177BBL’s of cement in 12-1/4” Hole. Returns to Surface 5-1/2” 121BBL’s of cement in 8-1/2” Hole. TOC 755’ Calculated 5 TOC @755’ RKB = 17.6’ Rig Start Date End Date Cap Truck 3/3/22 3/3/22 03/03/2022 - Thursday PTW, JSA. Warm up truck. Rig down blow down tank and move out of the way. Back in cap string truck. Remove soap launcher. Rig up cap truck and test foot valve set at 2450 psi. Make up pack off assembly and install foot valve. Stab on well. PT 250/3000 psi. Good test. RIH with 3/8" capillary tubing to 2550' and set in tension. Install hanger. Pressure up pack off assembly and leave 1800 psi. Close manual pack offs. Rig off injector head and set in rack. Pick and set spool next to wellhead. Rig down capillary string truck and park on edge of pad. 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Fax: 907 777-8510 E-mail: snolan@hilcorp.com MAR 0 9 2017 DATE 03/07/2017AOGCC DATA LOGGED /11/2017 K BENDER To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL Paxton 7 Prints: Production Profile GR/CCL/PRESS/TEMP/GRADIO/ILS/CAL/SPIN/DEFT CD: Final Well Data DLIS Data 2/27/2017 4:29 PM File folder LAS Data 2/27/2017 4:29 PM File folder Log 2/27/2017 4:29 PM File folder SCANNED APR 0 7 2017 Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: • • co \\"\-. `,2, oo ` t`R rn R r` N O (") O O O O O O O `q UM 2 oxx _ x LL x a a a a a a a 5 �, I ~ m ❑ m -o H H HF- F F- H Tel � ❑ ❑o O O O O O O O T _ ' N. v U U > > x w w w w w w w11 Z n) r; N n N N t -a E H F I- H . I.. F Ll m y Z Z Z Z Z Z n r-- 2 I I I I I I Q o in LL 0 0 0 0 0 0 c c c O 0 0 C9 0 0 0 CO ! 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STATE OF ALASKA AIL OIL AND GAS CONSERVATION CO SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown J Performed: Suspend ❑ Perforate Cl Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development ❑I Exploratory LI 214-130 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-133-20643-00 7.Property Designation(Lease Number): 8.Well Name and Number: Fee Private,ADL384372 Paxton 7 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Ninilchik/Beluga-Tyonek Gas 11. Present Well Condition Summary: Total Depth measured 4,695 feet Plugs measured N/A fee7ef C E I V E D true vertical 2,193 feet Junk measured 3,562 feet FR 0 12016 Effective Depth measured 3,447 feet Packer measured 2,183 feet true vertical 1,820 feet true vertical 1,443 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 16" 138' 138' Surface 1,918' 9-5/8" 1,936' 1,374' 5,750 psi 3,090 psi Intermediate Production 3,524' 5-1/2" 3,542' 1,849' 10,640 psi 7,480 psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.4#/L-80 2,266'MD 1,468'TVD Baker SAB-L 2,183'MD 1,443'TVD Packers and SSSV(type,measured and true vertical depth) Baker TE-5 TRSV 137'MD 137'TVD 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: 0 1027 4 0 105 Subsequent to operation: 0 3008 0 0 376 14.Attachments(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory Development[2] Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑✓ WDSPL[I] Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG LI 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-734 Contact Taylor Nasse-777-8354 Email tnasse(c�hilcorp.com Printed Name Chad Helgeson Title Operations Manager 1 SignaturePhone 907-777-8405 Date 21/1 6" I ‘/- /41"---''. Form 10-404 Revised 5/2015 3174 RBDMS LL r" 0 2 2016 Submit Original Only • • Hilcorp Alaska LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Paxton 7 E-Line 50-133-20643-00 214-130 12/21/15 12/22/15 Daily Operations: 12/21/2015 - Monday Spot equip PTW and JSA. Rig up lubricator and pressure test to 250 psi low and 2,500 psi high. RIH w/2" x 20' HC Nova 6 spf 60 deg phase and tie into Halliburton RCBL log dated Nov 1 2014. Had trouble getting past X nipple at 2,228'. RIH and set down at 2,636'. Pick back up and couldn't get past 2,604'. Tried several times. Called town and decided to run the 40'gun for extra wt and to see if it goes. POOH Take 20'gun off and put 40'gun on line. RIH w/2" x 40' HC Nova 6spf 60 deg phase and tie into Halliburton RCBL log dated Nov 1 2014. Ran correlation log and sent to town. Couldn't get past 2,658'. Got ok to perf but lost 4' when we went back to get on depth. Spotted shot from 2,613' to 2,654'. Fired gun with 354.1 psi and went to 357 psi and after 5 min was 358 psi. POOH. All shots fired. RIH w/2" x 20' HC Nova 6 spf 60 deg phase and tie into Halliburton RCBL log dated Nov 1 2014 and set down at 2,640'. Run correlation log and tried to go back down and tool was not wanting to go. Checked line and found outer armor loose at 2,500'. Called town and discussed. Decided to pull and cut about 3,000' of line in am.There was a good chance of stranding line trying to get thru grease tubes again and after we shot. Line was probably getting loose with each run in hole and finally got loose enough to see. SLB is running up against their 16 hour work window so they will be back at 7 am in the morning to pull cut line and make 3 perf runs. Disarm perf gun and rig for standy. Well will be kept shut in. TP - 354.8 psi. 12/22/2015-Tuesday Spool off 3,000' of damaged cable, string flow tubes, build logging head. Made three runs and perforated 2,606'- 2,618'112'), 2,497'-2,510' (13'), and 2,456-2,497' (41') w/2" PJN guns. POOH. RDMO. Turn well over to production. . 0 Ninilchik Unit A SCHEMATIC Well: Paxton #7 PTD: 214-130 API: 50-133-20643-00 llilcorp Alaska,LLC RKB=17.6' CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16" 1 16" Conductor 109 X-56 Weld 16" Surf 138' 9-5/8" Surf.Csg 40 L-80 BTC 8.835" Surf 1,936' 5-1/2" Prod Casing 17 P-110HC DQX 4.892" Surf 3,542' I TUBING 1 II 2-7/8" Production 6.4 L-80 EUE-8rd 2.441" Surf 2,266' 2 0 TOC @755' JEWELRY DETAIL No. Depth ID OD Item 1 124' 2.441" 4.5" Chemical Injection Sub +' 2 137' 2.313" 4.62" Baker TE-5 TRSV - 3 2,183' 2.42" 4.56" Baker SAB-L Permanent Packer w/ 9-5/8" KBH22 Anchor Seal Latch 4 2,228' 2.313" 3.659" X-Nipple MON611001111 41011110101M Y' 5 2,266' 2.441" 2.875" Wireline re-entry guide 3 4 5 PERFORATION DETAIL A Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Date Status 8-1/2" Beluga IV 2,456' 2,510' 1,525' 1,542' 6 12/22/15 / Open Hole Beluga IV 2,586' 2,606' 1,565' 1,571' 12 11/05/14 Open Beluga IV 2,606' 2,618' 1,571' 1,574' 6 12/22/15 / Open Beluga IV 2,613' 2,654' 1,573' 1,585' 6 12/21/15/ Open OPEN HOLE/CEMENT DETAIL 9-5/8" 177BBL's of cement in 12-1/4"Hole. Returns to Surface 5.5" " 5-1/2" 121BBL's of cement in 8-1/2"Hole. TOC 755'Calculated TOF at 3,562' Fish details: 8-1/2"PDC bit,mud motor,Float sub,stabilizer,MWD collar,Dual gamma ray VA y collar,resistivity collar,Den/Neu collars(with nuclear source),(2)non mag flex collars,(4)its HWDP,iar,(1)it HWDP. Ili BOF at 3,916' PBTD=3,446'MD/1,820'ND TD=4,695'MD/2,193'TVD Updated by DMA 01-07-16 ti OF •Tye • • (---- ��\\1%%,tv THE STATE Alaska Oil ane Gas s�--*1,� °fA T jAsKA Conservation Commission *Pt x=-_ � 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 \T Main: 907.279.1433 Off'ALASY`p' Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager Hilcorp Alaska, LLC , 1.4. ( .— i 3 0 3800 Centerpoint Drive, Suite 1400 Y 1 Anchorage, AK 99503 Re: Ninlichik Field, Beluga-Tyonek Gas Pool, Paxton 7 Sundry Number: 315-734 Dear Mr. Helgeson: Enclosed is the approved application for 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, alet4 Cathy . Foerster Chair DATED this 15'1day of December, 2015 Encl. RBDMs r4; 1 ? 2015 • • STATE OF ALASKA D L L , ALASKA OIL AND GAS CONSERVATION COMMISSION bct-S (Z( is`IS APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑7 • Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: Hilcorp Alaska, LLC 4.Current Well Class: 5. Permit to Drill Number: Exploratory ❑ Development ❑✓ . 214-130 • 3.Address. 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-20643-00 - 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O.701 Paxton 7 - Will planned perforations require a spacing exception? Yes ❑ No El 9.Property Designation(Lease Number): 10. Field/Pool(s): Fee Private,ADL384372 • Ninilchik/Beluga-Tyonek Gas - 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): 4,695' ' 2,193' • 3,447' 1,820' 525psi N/A 3,567 Casing Length Size MD TVD Burst Collapse Structural Conductor 138' 16" 138' 138' N/A N/A Surface 1,936' 9-5/8" 1,936' 1,374' 5,750 psi 3,090 psi Intermediate Production 3,523' 5-1/2" 3,542' 1,849' 10,640 psi 7,480 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.4#/L-80 2,266 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker SAB-L/Baker TE-5 TRSV 2,183'/137'MD and 1,443'/13T TVD 12.Attachments: Proposal Summary ❑ Wellbore schematic n 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development n • Service ❑ 14. Estimated Date for 15.Well Status after proposed work: Commencing Operations: December 18,2015 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS E WAG LI GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Taylor Nasse-777-8354 Email tnasseehilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature ly.� �� - Phone 907-777-8405 Date r 1;///-,._ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. (6 1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 51:3Ez 2O R Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Er Subsequent Form Required: /Q - I 0 Li ej,84.1.7 ynAPPROVED BY _Approved by: / � COMMISSIONER THE COMMISS_IOONNDate: lZ_ S(Z'/41lJ Submit Form and Form 10-403 Revised 11/2015 Approve ApproveGgi3Gli,141,A,Laths Wthe date of approval. Attachments in Duplicate • • Well Prognosis Well: Paxton#7 'Licari)Alaska,LL Date: 12/04/2015 Well Name: Paxton#7 API Number: 50-133-20643-00 Current Status: Producing Leg: Estimated Start Date: December 18, 2015 Rig: Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-130 First Call Engineer: Taylor Nasse (907) 777-8354(0) (907)903-0341 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (C) AFE Number: Estimated Bottom Hole Pressure: —682 psi at 1,587 TVD (Assumed 0.43 psi/ft gradient) Max. Potential Surface Pressure: —525 psi (0.10 psi/ft gas gradient) Brief Well Summary Paxton#7 is a grass roots well drilled by the Saxon 147 rig. 9-5/8" surface casing has been set and the rig was drilling the 8-1/2" hole section when a lost circulation zone was encountered and the BHA became stuck. The 5-1/2" production casing was run and cemented to top of the fish and the well completed with 2-7/8"tubing. The well was originally perforated in the Beluga IV and is currently flowing at 1.0 MMSCFD at 110 psig. Objective of Work: Add additional perforations in the Beluga sands . Notes Regarding Wellbore Condition • Make GR run and tag bottom prior to performing work. • Shut in well prior to performing work. E-Line Procedure 1. MIRU e-line and pressure control equipment. PT lubricator to 250 psi low/2,500 psi high. 2. Perforate the Beluga sands with 2" 6 SPF 60 deg phased perf guns. Depths are from the Halliburton RCBL performed on November lsi, 2014. Send the correlation pass to the Reservoir Engineer, Operations Engineer,and Geologist for confirmation. Proposed Perforated Intervals Sands Top (MD) Btm (MD) FT Beluga IV ±2,346 ± 2,405 ±59 Beluga IV ± 2,456' ±2,510' ±54 Beluga IV ±2,606' ±2,659' ±53 3. POOH. 4. Flow each zone through test separator and record water and gas rates. 5. If any of the sands are wet,the zone will be isolated with a plug or tubing patch. 6. RD e-line. 7. Turn well over to production. Attachment: Current and Proposed Wellbore Schematics • • Ninilchik Unit SCHEMATIC well: Paxton #7 PTD: 214-130 API: 50-133-20643-00 Hilcorp Alaska,LLC RKB= 17.6' CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16" ' 16" Conductor 109 X-56 Weld 16" Surf 138' 9-5/8" Surf.Csg 40 L-80 BTC 8.835" Surf 1,936' li, 5-1/2" Prod Casing 17 P-110HC DQX 4.892" Surf 3,542' 1 TUBING " • 2-7/8" Production 6.4 L-80 EUE-8rd 2.441" Surf 2,266' ' 2 LP TOC @755'a m JEWELRY DETAIL No. Depth ID OD Item ; 1 124' 2.441" 4.5" Chemical Injection Sub 2 137' 2.313" 4.62" Baker TE-5 TRSV PIBaker SAB-L Permanent Packer w/ 9-5/8 Ir » 3 2,183' 2.42" 4.56" KBH22 Anchor Seal Latch 4 2,228' 2.313" 3.659" X-Nipple { 5 2,266' 2.441" 2.875" Wireline re-entry guide . or. ii 4 a NPERFORATION DETAIL r 5 Sands Top(MD) Btm(MD) Top(ND) Btm(ND) SPF Date Status 8.1/2 Beluga IV 2,586' 2,606' 1,565' 1,571' 12 11/05/14 Open Hole i� kt ��a'�, -',..4%, OPEN HOLE/CEMENT DETAIL 9-5/8" 177BBL's of cement in 12-1/4"Hole. Returns to Surface r A. r., 5.5" � , 5-1/2" 121BBL's of cement in 8-1/2"Hole. TOC 755'Calculated 1..., . - TOF at 3,562' Fish details: 8-1/2"PDC bit,mud motor,Float sub,stabilizer,MWD collar,Dual gamma ray "I 111111tf collar,resistivity collar,Den/Neu collars(with nuclear source),(2)non mag flex Qcollars,(4)its HWDP,jar,(1)it HWDP. BOF at 3,916' PBTD=3,446'MD/1,820'ND TD=4,695'MD/2,193'ND Updated by DMA 12/02/14 Ninilchik Unit • PROPOSED • Well: Paxton #7 PTD: 214-130 1 nSCHEMATIC API: 50-133-20643-00 Llilcorp Alaska,LLC RKB=17.6' CASING DETAIL 0 i `i Size Type Wt Grade Conn. ID Top Btm 16"2i, 16" Conductor 109 X-56 Weld 16" Surf 138' 9-5/8" Surf.Csg 40 L-80 BTC 8.835" Surf 1,936' 5-1/2" Prod Casing 17 P-110HC DQX 4.892" Surf 3,542' j I TUBING 1 ) 2 2-7/8" Production 6.4 L-80 EUE-8rd 2.441" Surf 2,266' TOC @755' JEWELRY DETAIL No. Depth ID OD Item f1 124' 2.441" 4.5" Chemical Injection Sub 2 137' 2.313" 4.62" Baker TE-5 TRSV Baker SAB-L Permanent Packer w/ 3 2,183' 2.42" 4.56" KBH22 Anchor Seal Latch 9-5/8" 4 2,228' 2.313" 3.659" X-Nipple 1 5 2,266' 2.441" 2.875" Wireline re-entry guide 3 PI <,' vs 4 tt PIF M. a` 5 PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) SPF Date Status 8-1/2" i.,'). „;p Beluga IV 2,346' 2,405' 1,492' 1,510' 12 TBD Proposed • Hole A'., Beluga IV 2,456' 2,510' 1,525' 1,542' 12 TBD Proposed + Beluga IV 2,586 2,606' 1,565' 1,571' 12 11/05/14 Open Beluga IV 2,606' 2,659' 1,571' 1,587' 12 TBD Proposed yr 4 "' OPEN HOLE/CEMENT DETAIL , 9-5/8" 177BBL's of cement in 12-1/4"Hole. Returns to Surfacef 5-1/2" 121BBL's of cement in 8-1/2"Hole. TOC 755'Calculated 5.5" s i A. , 7 TOF at 3,562' Fish details: 8-1/2"PDC bit,mud motor,Float sub,stabilizer,MWD collar,Dual gamma ray 11111111, collar,resistivity collar,Den/Neu collars(with nuclear source),(2)non mag flex Icollars,(4)its HWDP,iar,(1)it HWDP. BOF at 3,916' \%.• -..../ PBTD=3,446'MD/1,820'ND TD=4,695'MD/2,193'ND Updated by TWN 12/04/15 • Jig-Ls° Seth Nolan Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive 153 Anchorage, AK 99503 Tele: 907 777-8308 ira, rls u.t4;i.1.11. Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATE 04/24/2015 To: Alaska Oil & Gas Conservation Commission Meredith Guhl Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL Paxton 7 3 boxes: Dry Cuttings Transmitted herewith are cuttings from PAXTON 7 WELL BOX SAMPLE INTERVAL PAXTON 7 BOX 1 OF 3 1940' - 3040' PAXTON 7 BOX 2 OF 3 3040' - 3960' PAXTON 7 BOX 3 OF 3 3960' - 4965' Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Rec-' -. :y. Date: RECEIVED OP 410 APR 242015 AOGCC STATE OF ALASKA • ALADA OIL AND GAS CONSERVATION COMMISSION GAS WELL OPEN FLOW POTENTIAL TEST REPORT 1a.Test: El Initial El Annual J Special lb.Type Test: Li Stabilized Li Non Stabilized [d Multipoint ❑ Constant Time ❑ Isochronal f] Other: 2. Operator Name: 5. Date Completed: 11. Permit to Drill Number: Hilcorp Alaska, LLC 11/5/2014 214-130 3.Address: 6. Date TD Reached: 12.API Number: 3800 Centerpoint Drive, Suite 1400,Anchorage,AK 99503 10/4/2014 50-133-20643-00 4a. Location of Well(Governmental Section): 7. KB Elevation above MSL(feet): 13.Well Name and Number: Surface: 3016'FEL,855'FNL, Sec 13,T1S, R14W,AK,SM 167 Paxton 7 Top of Productive Horizon: 8. Plug Back Depth(MD+TVD): 14. Field/Pool(s): 575'FSL,2213'FWL, Sec 12,T1S, R14W,SM,AK 3,446'MD/1,820'TVD Total Depth: 9.Total Depth(MD+TVD): Ninilchik/Beluga-Tyonek Gas 2438'FNL,2109'FWL, Sec 12,T1S, R14W, SM,AK 4,695'MD/2,193'TVD 4b. Location of Well(State Base Plane Coordinates NAD 27): 10. Land Use Permit: 15. Property Designation: Surface: x- 206309 y- 2230478 Zone- 4 N/A Fee Private,ADL 384372 TPI: x- 206196 y- 2232047 Zone- 4 16.Type of Completion(Describe): Total Depth: x- 206244.382 y- 2234118.641 Zone- 4 2-7/8"Production String,5-1/2"Production Casing Perforated 17. Casing Size Weight per foot, lb. I.D. in inches Set at ft. 19. Perforations: From To 5-/2" '7 4.892 3,542 2,586'-2,606' 18.Tubing Size Weight per foot, lb. I.D. in inches Set at ft. 2-7/8" 6.4# 2.441 2,266 20. Packer set at ft: 21.GOR cf/bbl: 22.API Liquid Hydrocardbons: 23.Specific Gravity Flowing Fluid(G): 2,183 N/A N/A 0.56 24a. Producing through: 24b. Reservoir Temp: 24c. Reservoir Pressure: 24d. Barometric Pressure(Pa): El Tubing [ Casing 58 F° 520 psia @ Datum 1567' TVDSS psia 25. Length of Flow Channel(L): Vertical Depth(H): Gg: %CO2: %N2: %H2S: Prover: Meter Run: Taps: N/A N/A 0.56 0 0 0 26. FLOW DATA TUBING DATA CASING DATA • Prover Choke Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. Line X Orifice Size(in.) Size(in.) psig Hw F° psig F° psig F° Hr. 1. X 421 60 WED 3 2. X 371 60 3 3. X 342 60 1.-.b 1 J 3 4. X 311 60 /� 3 h. 5. X OGCC , Basic Coefficient Flow Temp. Super Comp. (24-Hour) Pressure Gravity Factor Rate of Flow No. Fb or Fp hwPm Pm Factor Fg Factor Ql Mcfd 1. . 2. • 3. . 4. . 5. _ Temperature for Separator for Flowing No. PrT Tr z Gas Fluid Gg G 1. 2. 3. Critical Pressure 4. Critical Temperature 5. Form 10-421 Rev. 7/2009 CONTINUED ON REVERSE SIDRBDMS I'tl3 L 3 2015bmit in Duplicate Pc Pc2 • if 520 pf2 270,400 No. Pt Pt2 Pc2-Pt2 Pw Pw2 Pc2-Pw2 Ps Ps2 Pf2-Ps2 1. 436 190,096 80,304 2. 386 148,996 121,404 3. 357 127,449 142,951 4. 326 106,276 164,124 5. 25. AOF (Mcfd) 6,423 n 1.51 Remarks: I hereby ce .fy that the going is true and correct to the best of my knowledge. Signed Title Reservoir Engineer Date 2/16/2015 DEFINITIONS OF SYMBOLS AOF Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producin face were reduced to zero psia Fb Basic orifice factor Mcfd/ hwPm Fp Basic critical flow prover or positive choke factor Mcfd/psis Fg Specific gravity factor, dimensionless Fpv Super compressibility factor= -1-17 dimensionless Ft Flowing temperature factor, dimensionless G Specific gravity of flowing fluid (air=1.000), dimensionless Gg Specific gravity of separator gas (air=1.00), dimensionless GOR Gas-oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F) per barrel oil (60 degrees F) hw Meter differential pressure, inches of water H Vertical depth corresponding to L, feet(TVD) L Length of flow channel, feet(MD) n Exponent(slope) of back-pressure equation, dimensionless Pa Field barometric pressure, psia Pc Shut-in wellhead pressure, psia Pf Shut-in pressure at vertical depth H, psia Pm Static pressure at point of gas measurement, psia Pr Reduced pressure, dimensionless Ps Flowing pressure at vertical depth H, psia Pt Flowing wellhead pressure, psia Pw Static column wellhead pressure corresponding to Pt, psia Q Rate of flow, Mcfd (14.65 psia and 60 degrees F) Tr Reduced temperature, dimensionless T Absolute temperature, degrees Rankin Z Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual of Back-Pressure Testing of Gas Wells, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. Form 10-421 Revised 7/2009 Side 2 • • Z l0 Ln N 01 m < Ni l0 N (N N n O 0 m l0 d- N d- O l0 l0 l0 to tD N O U as '. I , I o cc)2 N LL O a i ' m Q -_. N m m m m U \1:1 d' <--1 r-1 ciLci f II In in in in ; O LL C c-i r-I ci rl a Q O a 0 O in N N Cr) Cr 01 <-1 < O .-i N d- (0 00 N d- l0 '-• a-i v-i r-I QN �^< IA a- rI N0 < N a0 0 0 0 ++ !"IN N N N O N c9to lf) L l Ln \ \aaLLLL O g O 0 CL H o 0 Q o O Us u • l0 lD N lD �-' . — d- m sr) m (0 - Q CC • CL c5 0- a-+ a: = Zr m 2 c 3 1 ii 0N O Ol -I 00 N N 0 01 d 01 0 c-1 <-1 N N V- U U N (13O LL O N Q) .�-1 Ci N 0 .-1 lt m O c L >= L N c O 0 0 .V I Q. r\-I m d0 00 O sZ3 d o Z a- D r-i 0 tD r-i II v o V, LL (Zvsd Zvld) a� > c0 (0 0 li > N 0 C7 a --_ a/y-1.;D �dy Dinger Hilcorp Alaska, 5 �/ Drilling Tech 3800 Centerpoint Drive o? g Suite 1400 Anchorage, AK 99503 t Ifrump.t1 t.kL.1.1A, Tele: 907 777-8389 E-mail: cdinger@hilcorp.com DATE: 1/23/2015 To: Alaska Oil & Gas Conservation Commission Meredith Guhl Petroleum Geology Assitant 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL Paxton 7 CD : Definitive Survey Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittalorFAX to 907 777.8580 Received By: Date: RECEIVED E Angela K. Singh JAN 23 ?Eltc AOGCC • :;eth Nolan Hilcorp Alaska, LLC 2-52- GeoTech 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 it,!.•i„y th.k.t.LI I Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATA LOGGED /l3/20.1 M.K.BEND DATE 01/09/2015 To: Alaska Oil & Gas Conservation Commission Meredith Guhl Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL Paxton 7 Survey Data CD: Final Well Data a Files Currently on the Disc (4) Paxton#7-Definitive Survey 1;9/2015 2:05 PM PDF Document 781 KB Paxton#7- Gec 1/9/2015 2:05 PM Text Document 6 KB Paxton#7- GIS 1/9/2015 2:05 PM Text Document 6 KB L2111 Paxton#7 wp6.a Actual Surveys 1,/9/2015 2,05 PM Microsoft Excel M... 761 KB Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: .� RECEIVED I O4ate: JAN 9 2015 AOGCC STATE OF ALASKA ALP,OIL AND GAS CONSERVATION COMOSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas 0 ' SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ lb.Well Class: 20AAC 25.105 20AAc 25.110 Development 0 - Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp.,Susp.,or 12. Permit to Drill Number: Hilcorp Alaska,LLC Aband.: 11/5/2014 • - 214-130/314-560 3.Address: 6. Date Spudded: 13.API Number: 3800 Centerpoint Drive,Suite 1400 Anchorage,AK 99503 9/25/2014 • 50-133-20643-00 4a. Location of Well(Governmental Section): 7. Date TD Reached: 14.Well Name and Number: Surface: 3016'FEL,855'FNL, Sec 13,T1S, R14W,AK,SM - 10/4/2014 • Paxton 7 ' Top of Productive Horizon: 8. KB(ft above MSL): 166.6 ' 15. Field/Pool(s): 575'FSL,2213'FWL,Sec 12,T1S, R14W,SM,AK GL(ft above MSL): 148 • Total Depth: 9. Plug Back Depth(MD+TVD): Ninilchik/Beluga-Tyonek Gas - 2438' FNL, 2109' FWL, Sec 12,T1S, R14W,SM,AK 3446'MD/1820'TVD 4b. Location of Well(State Base Plane Coordinates, NAD 27): 10.Total Depth(MD+TVD): 16. Property Designation: Surface: x- 206309 - y- 2230478 Zone- 4 • 4695'MD/2193'TVD - " Fee Private,ADL384372- TPI: x- 206196 y- 2232047 Zone- 4 11.SSSV Depth(MD+TVD): 17. Land Use Permit: Total Depth: x- 206244.382 • y- 2234118.641 • Zone- 4 137'MD/137'TVD Surface Agreement w/parcel owner 18. Directional Survey: Yes ❑1 No ❑ 19.Water Depth, if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) N/A 21. Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: FEL 2"/5"MD/TVD, LWD COMBO 2"MD/TVD, GRL 2"MD/TVD, DEL 2"MD/TVD, ROP DGR EWR-Phase 4 N/A ALD CTN MD, DGR EWR-Phase 4 ALD CTN TVD, RCBL,TMD3D NEUTRON SURVEY 23. CASING, LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 16" 109 X-56 Surf 138' Surf 138' Driven N/A 9-5/8" 40 L-80 Surf 1936' Surf 1374' 12-1/4" 128 bbl 12.5#,48.6 bbl 15.2# 5-1/2" 17 P-110 Surf 3542' Surf 1850' 8-1/2" 121 bbl 15.7# 24. Open to production or injection? Yes n No ❑ 25. TUBING RECORD If Yes, list each interval open (MD+TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 2-7/8" 2,266' 2,183'MD/1,444'TVD 6 shots per foot 2586-2606 MD(1565-1571 TVD) r---- -•..a.. RECEIVED 26. ACID, FRACTURE,CEMENT SQUEEZE, ETC. PtE t•t0i>! Was hydraulic fracturing used during completion? Yes ❑ No ❑✓ IO DEC 0 5 2014 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED _MED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift, etc.): 11/5/2014 Flowing Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 11/7/2014 24 Test Period -0.0 2,718 0 N/A N/A Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 449 0 24-Hour Rate -0. 0 2,718 - 0 N/A 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question, list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. Form 10-407 Rev sed 10/2171? rC?NTINl1Fn nN REVERSE } ����J b JAN �.`�I/ Ynl�(' • • • 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes H-: No If yes, list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Top Beluga 2344 1491 Beluga 20 coal 2727 1607 Beluga 35 2740 1611 Beluga 40 3335 1786 Beluga 43 coal 3505 1838 Beluga 45 3529 1845 Beluga 45 coal 3724 1905 Beluga 50 coal 4205 2048 Beluga 50 4243 2060 Beluga 50 channel 4666 2185 Formation at total depth: 31. List of Attachments: Well Schematic, MW vs Depth, Days vs Depth, Definitive Directional Survey, Drilling Composite Report,Casing and Cmt reports for all strings 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Luke Keller Email: Ikeller@hilcorp.com Printed Name: Luke Keller // Title: Drilling Engineer Signature: Phone: 907-777-8395 Date: INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases 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. Item 1b: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection, Salt Water Disposal,Water Supply for Injection,Observation,or Other. 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 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level 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 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well 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. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. 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. Form 10-407 Revised 10/2012 . . Ninilchik Unit • SCHEMATIC Well: Paxton #7 PTD: 214-130 API: 50-133-20643-00 Hilcorp Alaska,LLC RKB=17.6' CASING DETAIL 16"1- Size Type Wt Grade Conn. ID Top Btm 16" Conductor 109 X-56 Weld 16" Surf 138' 9-5/8" Surf.Csg 40 L-80 BTC 8.835" Surf 1,936' 5-1/2" Prod Casing 17 P-11OHC D CU( 4.892" Surf 3,542' 1 TUBING 2-7/8" Production 6.4 L-80 EUE-8rd 2.441" Surf 2,266' , 2 TOC @755' JEWELRY DETAIL No. Depth ID OD Item 1 124' 2.441" 4.5" Chemical Injection Sub 2 137' 2.313" 4.62" Baker TE-5 TRSV Baker SAB-L Permanent Packer w/ 3 2,183' 2.42" 4.56" KBH22 Anchor Seal Latch 9-5/8" A. s 4 2,228' 2.313" 3.659" X-Nipple 5 2,266' 2.441" 2.875" Wireline re-entry guide 3 4 5 PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) SPF Date Status 8-1/2" Beluga IV 2,586' 2,606' 1,565' 1,571' 12 11/05/14 Open Hole OPEN HOLE/CEMENT DETAIL ::::f-' 9-5/8" 177BBL's of cement in 12-1/4"Hole. Returns to Surface ,, • 5-1/2" 121BBL's of cement in 8-1/2"Hole. TOC 755'Calculated 5.5" ;,L- -'i i TOF at 3,562' Fish details: 8-1/2"PDC bit,mud motor,Float sub,stabilizer,MWD collar,Dual gamma ray iiiiiN, collar,resistivity collar,Den/Neu collars(with nuclear source),(2)non mag flex 1, collars,(4)its HWDP,iar,(1)it HWDP. BOF at 3,916' ‘..... .....1 PBTD=3,446'MD/1,820'TVD TD=4,695'MD/2,193'ND Updated by DMA 12/02/14 • _ ' •C 7 N • 3 a) O c6 (n a N Q a) C M a) o O N U y 3 a m = a a) .L-• as a) .n , U` Y 4= C -C-2. O C7)Zr) us O 7 N o O N U O •O O (O O C F- 7 > Q) - (n 47. -a �'O• = Y J y N N o N RS Cr) 7 -0 U 7 d) 7 a) O- 7 p- N a) O L (n ui 0 .c ,- off$ E c 92 E E - c L ' c 3 O a) o D (t ai ? 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E C p o 0_,_ 0 0 --E v' >p- - c) co-co 18 —-0(3 _ co,_ EX -(C) 0 U -a N U o - 7 a) H (6 - 0 C (1St -O M 0 0 o)a -O 3 a > d N > d a) Y CL co N E 0 v 3 a E � My No '� ad ro -- Ea _0 � 0 _ w a) C7 � C� al � oU �r a) 3 n) °)0 0 0 m aro) > a U .E cq ro 0 a) cn. 70-b H L aa_co a 0 co a > a) 0 coo Q 0 0aoo -a Z Qa .0 > via) ZI moo a) CC � 0cn - 0 co 0 0 ca c0 (C) .- cnu) caU) - v 0__a v v v v 0 0 0 0 N N N N Cr) 0 N N M O O a) a) r- • L _c M U) s C1 C") _ - N ..=.: o © m > o o. a a) 3 ,� o-M o _c O p) II - a, 0. co co 0 D 73 (a o f a) C Q a N E -� . a) 0 o U C • t ter- 0 0 D E c _o C � a)A- U .( 0_ eLC1 4) C ,- _ N 45 'a C it <co �+ ID f` C N >.p a. E 3 •-- U N 0 r 0 O N ,L O -)C C o -a a) a_ ir) > a a) � O o 0 U . op NO N a) _ C O E 30 (O ca •- o , c N � a) (am a U _o � 0 0- u Cl. O 0 < f o o E a- E C .0 aj 0 c6 p a p Ck- m M CV O _ U• O (0)O O C1 C C'W .�.. 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'C O a (a ' 0 .0 N .0 0)-a — 0 ai `� a` (I) o m_ Q c rn p ° E O C a) = o C = > o N c a) O E o (` = a o E U >,.0 o -0 a-2 'U 3 0) m o a N '� 3 O o 0 o c m a' 'ill 0 lis' U i w o c 3 c C a • E N - C O- a) O) O 'a 0 0 0 o U a (0 c (U CN (n E N U (0 O co C O E a) O o 'a 2 0 `) c) O co > -a > 'C (� � M - L E a) E U°)) u- N o � m (n C > N o N N w. O. O -a n- -0 c_ O - Q. C (o •(a > 0)L o m E o '5 (a '5 U c 2 C to C O N 3 co 0) O` p) L 5 D o a' o a' 0 -o coop (0 E O ca• w c c a) -c ,_ 3 m._0 2 D 3 E coo ami a (f°n a Q C0 0 o co � -o c D a mU0 oaC)N0 C > � > -a -O 0" N d' a) 0 a-E-0- a1 a) "a • C .b (O 0) (0 N = n1- 0QNc (n E 3 a JJCLaOoNZ (= m V' O o N N N (n aHilcorp Energy Company .... litAILY • DRILLING REPORT REPORT NO. LEASE WELL NO. COUNTY/PARISH WELL STATE DATE 3 ADL384372&Private Paxton 7 Kenai Peninsula Borough NINU Paxton 7 AK 9/24/2014 RIG AFE NO. AFE BUDGET DAILY COST CDC RIG PHONE Saxon Rig 8147 1412365D 4564878 5146,791 $341,525 907-283-1365 ACTIVITY TYPE: DRLG Drilling RU Rig Up DEPTH:MD/TVD PROGRESS/HRS PROP.TD.AST SHOE TEST PPG DAYS SINCE SPUD AFE DAYS FIELD SUPERVISOR ENGINEER 7098 3 'essak/Barber/MCDowe Luke Keller ACTIVITY SUMMARY AT: HRS SURVEY: MD ANGLE AZIMUTH TVD SECTION N/S E/W DOGLEG Continue to R/U on Paxton#7 TIME LOG ELAPSED ACTIVITY COMMENTS FROM TO TIME 6:00 6:30 0.5 Safety Meeting Conduct ng evacuation drill. 6:30 18:00 11.5 RU/RD Continue to rig up top drive.C/O washpipe.R/U hydraulic lines for top drive.Set and rig up degasser,flow line,mud lines,fill water tank and pits with water.RN bails and elevators. Install geronimo line.RN tongs.Weld on shale shaker bed.Function top drive and iron ruffneck.Trouble shoot elect.problems with ruffneck Adjust top drive hydraulic pressures. Total safety on location,setup,calibrate and test all gas alarms.AOGCC rep Lou Grimaldi will witness diverter function test. R/U power and communications to canrig and sperry. Off load S'drill pipe.Continue to R/U misc.equipment.Work on rig acceptance checklist. 18:00 6'00 12.0 RU/RD Make 567 bbls 8.8 ppg spud mud in pits.Make up mudsaver quill.Install saver sub and clamps on topdrive.Nipple up dNerter system& annular. R/U Pipe spinners,service and function.Charge pulsation dampener M/P#2 with nitrogen.bad gauge on dampener bleed dowm to change out.Continue to work on rig acceptance checklist. Currently 95%rigged up. TOTAL 24.00 LITHOLOGY: MAX GAS B.G.GAS CON GAS TRIP GAS Accidents Pollution none Plan Next 24 Hr Report Attach no Finish rig up.Complete rig acceptance checklist.Function diverter.Spud well. MUD RECORD CASING RECORD PUMP BPM TYPE DATA GPM SIZE GRADE WT CONN DEPTH DV ID NUMBER1 2 TIME 16 X-56 109 Weld 80 15 MAKE TSM TSM DEPTH MODEL 1000 1000 TEMP STROKE 9 9 WEIGHT LINER SZ 5.50 5.50 VISC SPM PV TOP OF LINER© GAUSTK 2.84 2.84 VP BIT NO. SUR PSI GELS BHA# SIZE API WL MFG. SLOW PUMP DATA HTHP DESCRIPTION OD ID FEET TYPE Pump# PSI 1 PSI2 PSI 3 Eff% CAKE SERIAL NO. 1 95 SOLIDS NOZZLES 2 95 ADJSOL TFA SPM fan PSI1/2/3 OIL% DEPTH OUT DRILL STRING CAPACITY WTR% DEPTH IN STROKES SD% TOTAL FT. MBT HOURS POM AVG ROP pH WOB Pm ANN VEL DEPTH PF/MF ROT.RPM TORQUE Clmud AV DP CSG PICK UP Clwtr AV DP OP HL ROTATIONAL Cal AV DC SLACK OFF LIME TOT CUM HR %LGS GAUGE JAR HOURS ES INNER MUD MOTOR HRS OUTER LOCATION RP DULL CHAR. CUM HR BHA LID MUD TOTAL LENGTH(FT) HYDRAULICS FUEL 8279 GAL ADD(DIESELGAL) TOT WEIGHT(LBS) DEPTH FT CREW BOAT FUEL GAL SOLIDS EQUIPMENT NOZ.AREA IN' POT.WATER GAL SHAKER#1 DRK 2 d Pb PSI TUG FUEL GAL SHAKER#2 BRDT FIRS HHP BIT HP BARITE SKS DERRICK#1 DRKS FIRS H.S.I. HP/IN' FUEL USED 301 GAL MUD CLEAN CENT HRS JET VEL FT/SEC HEAVY H2O GAL BOP TESTED PERSONNEL ON BOARD IMP FORCE WEATHER Misc HEC 2 %Pb WIND 4 mi MPH DAILY CUM NEXT TEST DUE RIG 16 BOATS SEAS 29 TEMP MUD 563 563 SERVICE 16 MN PRES CONS Clear DIESEL FUNC.DUE TOTAL 34 MN FORECAST Clear and Sunny TOTAL $63 MN www.wellez.com WellEz Information Management LLC ver 050514bf • Hilcorp Energy Company .. likAILY • DRILLING REPORT REPORT NO. LEASE WELL NO. COUNTY/PARISH WELL STATE DATE 4 ADL384372&Private Paxton 7 Kenai Peninsula Burough NINU Paxton 7 AK 9/25/2014 RIG AFE NO. AFE BUDGET DAILY COST CDC RIG PHONE Saxon Rig#147 1412365D 4564878 $88,487 $430,011 907-283-1365 ACTIVITY TYPE: DRLG Drilling Spud Spud DEPTH:MD/TVD PROGRESS/HRS PROP.TD AST SHOE TEST PPG DAYS SINCE SPUD APE DAYS FIELD SUPERVISOR ENGINEER 138 138 138 7098 4 Yessak/McDowell Luke Keller ACTIVITY SUMMARY AT: HRS SURVEY: MD ANGLE AZIMUTH TVD SECTION N/S E/W DOGLEG Pick up DP.Stand back in derrick TIME LOG ELAPSED ACTIVITY COMMENTS FROM TO TIME 6:00 18:00 12.0 RU/RD Continue to RN diverter system.Set diverter,Bolt up and tighten diverter.Set diverter warning signs in place.Function test both mud pumps Install bell nipple and lines. RN pason to MWD an Canrig.Fill atigan tank with water.Ready 5"drill pipe and 12 1/4"BHA#1.Organize rig and location.Continue to complete rig acceptance checklist Install 1"tee on open and close ports on annular to operate knife value. 18:00 18:30 0.5 Safety Meeting Pm-spud Mtg&rig avec. 18:30 21:30 3.0 RU/RD Install Hyd jumper hoses front annular'T'to diverter knife valve.remove 22.5 degree bend from doerter line per request from AOGCC. install diverter line. Test diverter system with 5"DP.8 1320 psi on annular 21:30 2200 05 Tstg BOPNhN system pressure=2995 pressure after closure=1550 200 psi recharge time=28 sec.full recharge time=93 sec. Annular closing time=24 sec.with the knife valve opening in 11 sec. Test witnessed by AOGCC inspector Lou Grimaldi. 22:00 2:30 4.5 RU/RD Work on rig acceptance check list.Test PVT Equipment and flow sensors.Adjust tourque tube turn buckles to center T D over hole.Rig up pipe spinners.Strap and tally.Drill pipe. 2:30 8:00 3.5 Other PJSM,with demonstration on the safe operation and use of spinner hawks.Pick up DP.build stands&rack back in derrick.Rig Accepted 0:600 09252014 TOTAL 24.00 LITHOLOGY: MAX GAS B.G.GAS CON GAS TRIP GAS Accidents Pollution none Plan Next 24 Hr Report Attach no Makeup BHA 8 Spud Paxton#7 MUD RECORD CASING RECORD PUMP BPM TYPE Spud DATA GPM SIZE GRADE WT CONN DEPTH DV ID NUMBER1 2 TIME 5:30 16 X.56 109 Weld 139 15 MAKE TSM TSM DEPTH MODEL 1000 1000 TEMP 45 STROKE 9 9 WEIGHT 8.70 LINER SZ 5.50 5.50 VISC 65.0 SPM PV 8.0 TOP OF LINER @ GAUSTK 2.64 2.64 YP 21 BIT NO. 1 SUR PSI GELS 14 BHA# SIZE 1225 API Al 1 MFG. HDBS SLOW PUMP DATA @ HTHP DESCRIPTION OD ID FEET TYPE QHCIGRC Pump# PSI1 PSI2 PSI3 Eff% CAKE 2/- MilttootMricone 12.25 3.378 1.08 SERIAL NO. 12474444 1 95 SOLIDS 1 8"sperryDrill 8 5 3211 NOZZLES 3X18 1X12 2 95 ADJSOL 8"DM Collar 8 3.5 9.21 TFA 0.856 SPM for PSI 1/2/3 OIL% 8"EWR-P4 Collar 8 2 23.17 DEPTH OUT DRILL STRING CAPACITY WTR% 99 8"TM HOC 8.15 4 9.35 DEPTH IN 130 STROKES SD% 8"Flex Collar 7.38 2.813 30.19 TOTAL FT. -130 MBT 20 8"Flex Collar 7.78 2.813 29.95 HOURS POM Bottle neck xo sub 7.67 2.188 2.2 AVG ROP pH 10.4 Non mag flex collar 8.59 2.5 30.97 WOB Pm 09 Non mag flex collar 6.7 2.5 30.83 ANN VEL DEPTH PF/MF 1/0 (2)jts 5"HWDP 5 3 63 ROT.RPM TORQUE Clmud Hyd.jar with bumper 6.22 2.25 30.33 AV DP CSG PICK UP Clwtr (7)Its 5"HWDP 5 3 220.5 AV DP OP HL ROTATIONAL Cal AV DC SLACK OFF LIME TOT CUM HR %LGS GAUGE JAR HOURS ES INNER MUD MOTOR HRS OUTER LOCATION RP DULL CHAR. CUM HR BHA LIQ MUD TOTAL LENGTH(FT) 512.89 HYDRAULICS FUEL 8181 GAL ADD(DIESELGAL) TOT WEIGHT(LBS) 38342 DEPTH 138 FT CREW BOAT FUEL GAL SOLIDS EQUIPMENT NOZ.AREA INC POT.WATER GAL SHAKER#1 DRK 2 d Pb PSI TUG FUEL GAL SHAKER#2 BRDT Hes HHP BIT HP BARITE SKS DERRICK#1 DRKS MRS H.S.I. HP/IN' FUEL USED 98 GAL MUD CLEAN CENT MRS JET VEL FT/SEC HEAVY H2O GAL BOP TESTED PERSONNEL ON BOARD IMP FORCE WEATHER Misc HEC 2 %Pb WIND 4 mi MPH DAILY CUM NEXT TEST DUE RIG 18 BOATS SEAS 39 TEMP MUD $5,153 05216 SERVICE 16 MN PRES CONE Clear DIESEL FUNC.DUE TOTAL 34 MN FORECAST Cool&clear TOTAL $5,216 MN wows wellez.com WellEz Information Management LLC ver 050514b1 • Hilcorp Energy Company • likAILY DRILLING REPORT REPORT NO. LEASE WELL NO. COUNTY/PARISH WELL STATE DATE I1I 5 ADL384372 8 Private Paxton 7 Kenai Peninsula Burough NINU Paxton 7 AK 9/26/2014 RIG AFE NO. AFE BUDGET DAILY COST CDC RIG PHONE ' Saxon Rig*147 1412365D 4564878 $119,505 $549,517 907-283-1365 ' ACTIVITY TYPE: DRLG Drilling Drilling Drilling DEPTH:MD/ND PROGRESS/HRS PROP.TD,AST SHOE TEST PPG DAYS SINCE SPUD AFE DAYS FIELD SUPERVISOR ENGINEER 410 410 272 7098 1 5 Yessak/McDowell Luke Keller ACTIVITY SUMMARY AT: 05:45 HRS SURVEY: MD ANGLE AZIMUTH ND SECTION N/S E/W DOGLEG Drilling @ 410' 278.07 1.22 39.38 276.W 1.12 1.41 1.06 0.83 215.54 0.76 51.43 215.54 0.37 0.68 0.34 1.47 185.82 0.34 64.76 185.82 021 045 0.19 0.2 TIME LOG ELAPSED ACTIVITY COMMENTS FROM TO TIME 8:00 9:00 3.0 (drI)Trips Rig accepted on Paxton#7 @ 06:00 hrs.PJSM,train crews for operating pipe spinners.Finish PN 5"DP 66 total,9jts 5"HOOP and jars, racking back in derrick. 9:00 1200 3.0 UnPlanned Attempt to Install 14"ID wear bushing,cannot get past casing head flange @ 22.3',notify Hilcorp wellhead specialist.Found ring gasket under DSA not setting in ring groove on flange. 1200 1600 4.0 UnPlanned PJSM,R/D bell nipple.RN pickup slings on annular,Remove bolts under DSA and at knife value.P/U annular.Remove damaged API ring gasket,Inspect ring groove per wellhead hand. Install new API ring gasket.Lower stack.tighten flange.Re-install bell nipple and diverter line.Install wear bushing.Function test divarter, annular closed in 28 sec,knife value opened 14 sec. 18:00 18:00 2.0 (drl)Trips PJSM,MN BHA#1.M/U 121/4"b6,1.5 deg mud motor.DM collar,EWR P4 collar.Scribe motor to MVO,offset @ 180.88 deg. 18:00 20:00 2.0 (dri)7rips PJSM,MN ERW-P4 collar TM HOC upload smart tools MN 8"flex collar,bottleneck XO 20:00 22:00 2.0 Recalibrate Ta.RPM,adjust torque,fill pipe 8 surface lines Circ-tighten gland nuts. 22:00 22:30 0.5 UnPlanned Trouble shoot pump throttle controls. 2230 0:30 20 Drilling Tag spud well,dell F/138'T/224'with I-MOP using reduced pump rate near conductor.VOB=5K,330 GPM,50 RPM 575 PSI W/17% w. 0:30 230 2.0 (dri)Trips Survey @(2)survey points.MVO tools getting good detection.flow check well,stand back(2)stds HOOP PN 8"flex 8 63/4'non mag flex collars. 2:30 4:00 1.5 Drilling Drill F224'T/316'ROT.62'slide 30' 4:00 4:30 0.5 (dd)Trips stand back 1 std HVVDP P/U jars. 430 6:00 1.5 Drilling Drill F/316'T/410'VOB=8K,SSP=1450,pumping at 500 gpm with 4500 torque.PN wt=48K S/O wt=46K and ROT wt=46K ROP= 54'/hr.currently 1.64'below the line 8.49'right of the line. I TOTAL 24.00 LITHOLOGY: MAX GAS B.G.GAS 4 CON GAS TRIP GAS Accidents None Pollution None Plan Next24 Hr Report Attach no Drill to casing point @ 2000' MUD RECORD CASING RECORD PUMP 11.81 BPM TYPE Spud DATA 496 GPM SIZE GRADE WT CONN DEPTH DV ID NUMBER1 2 TIME 5:30 16 X-56 109 Weld 139 15 MAKE TSM TSM DEPTH 204 MODEL 1000 1000 TEMP. 45 STROKE 9 9 WEIGHT 8.70 LINER SZ 5.50 5.50 VISC 1340 SPM 94 94 PV 21.0 TOP OF LINER @ GAL/STK 2.64 2.64 VP 42 BIT NO. 1 SUR PSI 1344 1344 GELS 23 BHA# SIZE 12.25 API VL 1 MFG. HDBS SLOW PUMP DATA @ HTHP DESCRIPTION OD ID FEET TYPE QHC1GRC Pump# PSI 1 PSI2 PSI3 Eff% CAKE 2/- Milltooth/Tricone 1225 3.378 1.08 SERIAL NO. 12474444 1 95 SOLIDS 1 8"sperryDrill 8 5 32.11 NOZZLES 3X18 1X12 2 95 ADJSOL 8"DM Collar 8 3.5 9.21 TFA 0.856 SPM ler PSI 1//e OIL% B"EVR-P4 Collar 8 2 23.17 DEPTH OUT 410 DRILL STRING CAPACITY WTR% 99 8"TM HOC 8.15 4 9.35 DEPTH IN 138 STROKES 116 SD% 8"Flex Collar 7.38 2.813 30.19 TOTAL FT. 272 MBT 25 8"Flex Collar 7.78 2.813 29.95 HOURS 2.3 POM Bottle neck co sub 7.67 2.188 22 AVG ROP pH 10.4 Non mag flex collar 6.59 2.5 30.97 fOB 5 Pm 08 Non mag flex collar 6.7 2.5 30.83 ANN VEL 58.4 DEPTH 410 PF/MF 1/1 (2)Ps 5"HOOP 5 3 63 ROT.RPM 115 TORQUE 4500 Clmud Hyd.jar with bumper 6.22 225 30.33 AV DP CSG 630.3 PICK UP 48000 CMQr (7)jts 5"MOP 5 3 220.5 AV DP OP HL 651.5 ROTATIONAL 46000 Cal AV DC 77.9 SLACK OFF 46000 LIME TOT CUM HR 2.3 %LGS GAUGE JAR HOURS ES INNER MUD MOTOR HRS 2 25 OUTER LOCATION RP DULL CHAR. CUM HR BHA 225 LIQ MUD TOTAL LENGTH(FT) 512.89 HYDRAULICS FUEL 7127 GAL ADD(DIESELGAL) TOT WEIGHT(LBS) 38342 DEPTH 410 FT CREW BOAT FUEL GAL SOLIDS EQUIPMENT NOZ.AREA .856 IN' POT.WATER GAL SHAKER#1 80/8010/DRK 2 d Pb 288.979 PSI TUG FUEL GAL SHAKER#2 80/80110/BRDT HRS HHP BIT HP BARITE SKS DERRICK#1 DRKS HRS H.S.I. HP/IN' FUEL USED 1054 GAL MUD CLEAN CENT 1.5 HRS JET VEL 185.4063 FT/SEC HEAVY H2O GAL BOP TESTED PERSONNEL ON BOARD IMP FORCE WEATHER Misc 09242014 HEC 2 %Pb WIND 6 Mi/hr MPH DAILY CUM NEXT TEST DUE RIG 16 BOATS SEAS 28 TEMP MUD $1,919 $7,135 10/092014 SERVICE 17 MN PRES CORD Clear DIESEL FUNC.DUE TOTAL 35 MN FORECAST Partly cloudy TOTAL $7,135 MN wvw.wellaz.com WellEa Information Management LLC ver 050514bl • Hilcorp Energy Company II ItAILY DRILLING REPORT REPORT NO. LEASE WELL NO. COUNTY/PARISH WELL STATE DATE 6 ADL384372 8 Private Paxton 7 Kenai Peninsula Burough NINU Paxton 7 AK 9272014 RIG AFE NO. PEE BUDGET DAILY COST CDC RIG PHONE Saxon Rig#147 1412365D 4584878 $123,585 $673,102 907-283-1385 ACTIVITY TYPE: DRLG Drilling Drilling Drilling DEPTH:MD/TVD PROGRESS/HRS PROP.TD AST SHOE TEST PPG DAYS SINCE SPUD PEE DAYS FIELD SUPERVISOR ENGINEER 1510 1259 1100 7098 2 6 Yessak/McDowell Luke Keller ACTIVITY SUMMARY AT: 06;00 HRS SURVEY: MD ANGLE AZIMUTH TVD SECTION N/S E/W DOG LEG Drilling ahead from 1510' 1404.49 84.51 358.53 1217.51 499.16 34.78 500.17 7.45 1341.03 59.78 358.43 1187.88 443.09 -33.27 444.08 7.08 1278.59 55.38 357.93 1154.4 390.42 -31.61 391.39 7.51 1215.63 50.68 357.54 1116.53 340.18 -29.62 341.11 8.83 1152.47 45.14 356.49 107421 293.4 -27.2 294.27 6.64 TIME LOG ELAPSED ACTIVITY COMMENTS FROM TO TIME 6:00.12:00 6.0 Drilling Drilling 12 1/4"surface hole front 410'to 702'pumping 525 gpm,1532 psi.WOB 8-12K.70 RPM,5500-5800 torq.P/U 52K,5/0 52K,ROT 9 50K.MW 8.85 ppg,vis 166,no losses 12:00 18:00 6.0 Drilling Drilling from 702'to 974"pumping 504 gpm,1580 psi.VVOB 7-12K PN 55K,5/0,ROT 50K MW 9 ppg.vis 147.Pump hi vis sweeps @ 500' 800'AND 950'with 75%increase in cuttings. Sweeps back at calculated stks.No losses. 18:00 0:00 60 Drilling Drill F/974'T/1246'WOB=15K pumping @ 500 gpm, with 1550 spp. 0:00 0:30 0.5 Rig Service Service rig.check fluid levels,grease break linkage. 0:30 6:00 55 DrillingDrill F/1248'T/1510'with 15-18K WEB pumping @ 525 gpm,1720 SPP 8 8000 tq on.and 5200 tq off btm.P/U wt=62K,SIO wt=52K, ROT wt=54K.sweeps @ 1120'100%and @ 1320'75%increase in cutting Sweeps back at calculated stks. 90 bbls hauled to disposal,Paxton 7 total 360 bbls Slides=13.09 hrs 8 ROT.=3.82 hrs Latest Survey;10.74'below 8 14'left of the line. Max bgg=106 TOTAL 24.00 LITHOLOGY: MAX GAS B.G.GAS 106 CON GAS TRIP GAS Accidents None PolluBon none Plan Next 24 Hr Report Attach no Drill T/T.D.@ 2000'wiper trip,UD BHA,RN 8 run 9 5/8"casing. MUD RECORD CASING RECORD PUMP 12.25 BPM TYPE Spud DATA 514 GPM SIZE GRADE WT CONN DEPTH DV ID NUMBER 1 2 TIME 5:30 16 X-56 109 Weld 139 15 MAKE TSM TOM DEPTH 1338 MODEL 1000 1000 TEMP 84 STROKE 9 9 WEIGHT 9.00 LINER SZ 5.50 5.50 VISC 150.0 SPM 98 97 PV 29.0 TOP OF LINER @ GAL/STK 2.64 264 YP 32 BIT NO. 1 SUR PSI 1344 1344 GELS 11 BHP# SIZE 1225 API WL 1 MFG. HDBS SLOW PUMP DATA@ HTHP DESCRIPTION OD ID FEET TYPE QHCIGRC Pump# PSI1 PSI2 PSI3 Eff% CAKE 1/- Mil5ooth/Tricone 1225 3.378 1.08 SERIAL NO. 124744441 95 SOLIDS 2 8"sperryDnll 8 5 32.11 NOZZLES 3X18 1X12 2 95 ADJSOL 8"DM Collar 8 3.5 9.21 TFA 0.856 SPM for PSI 12/3 OIL% 8"EVVR-P4 Collar 8 2 23.17 DEPTH OUT 1510 DRILL STRING CAPACITY WTR% 98 8"TM HOC 8.15 4 9.35 DEPTH IN 138 STROKES 28.81 SD% 8"Flex Collar 7.38 2.813 30.19 TOTAL FT. 1372 MBT 26 8"Flex Collar 7.78 2.813 29.95 HOURS 2.3 POM Bottle neck xo sub 7.67 2.188 2.2 AVG ROP pH 10 Non mag flex collar 6.59 2.5 30.97 WOB 10K Pm 0.8 Non mag flex collar 6.7 2.5 30.83 ANN VEL 102.9 DEPTH 1510 PF/MF 0/1 (2)its 5"HI DP 5 3 63 ROT.RPM 135 TORQUE 8000 Clmud Hyd.jar with bumper 6.22 2.25 30.33 AV DP CSG 520.3 PICK UP 62000 Clwtr (7)jts 5"HWDP 5 3 220.5 AV DP OP HL 682.8 ROTATIONAL 54000 Cal AV DC 149.5 SLACK OFF 52000 LIME TOT CUM HR 2.3 %LGS 5 GAUGE JAR HOURS 18.91 ES INNER MUD MOTOR HRS 26.91 OUTER LOCATION RP DULL CHAR. CUM HR BHA 18.29 LIQ MUD TOTAL LENGTH(FT) 512.89 HYDRAULICS FUEL 9913 GAL ADD(DIESELGAL) TOTWEIGHT(LBS) 38342 DEPTH 1510 FT CREW BOAT FUEL GAL SOLIDS EQUIPMENT NOZ.AREA .856 INC POT.WATER GAL SHAKER#1 100/100/8 DRK 2 d Pb 299.361 PSI TUG FUEL GAL SHAKER#2 80/80/70!BRDT NRS HHP BIT 307.3792 HP BARITE SKS DERRICK#1 DRKS HRS H.S.I. 2.609352 HP/IM FUEL USED 1219 GAL MUD CLEAN CENT 12 HRS JET VEL 192.3097 FT/SEC HEAVY H2O GAL BOP TESTED PERSONNEL ON BOARD IMP FORCE WEATHER Misc 09242014 HEC 2 %Pb WIND 2 MI/hr MPH DAILY CUM NEXT TEST DUE RIG 16 BOATS SEAS 45 TEMP MUD $3,969 $11,104 10/09/2014 SERVICE 17 MN PRESCOND Overcast DIESEL FUNC.DUE TOTAL 35 MN FORECAST Overcast TOTAL 511,104 MN www wellez.com WellEz Information Management LLC ver 050514bf itAILYHilcorpDRIompanyy ID mREPORT REPORT NO. LEASE WELL NO. COUNTY/PARISH WELL STATE DATE 7 ADL384372&Private Paxton 7 Kenai Peninsula Burough NINU Paxton 7 AK 928/2010 RIG AFE NO. AFE BUDGET DAILY COST CDC RIG PHONE Saxon Rig#147 1412365D 4564878 $106,098 $779,200 907-283-1365 ACTIVITY TYPE: DRLG Drilling WiperTrp Wiper Trip DEPTH:MD/TVD PROGRESS/HRS PROP.TO AST SHOE TEST PPG DAYS SINCE SPUD APE DAYS FIELD SUPERVISOR ENGINEER 1945 1377 435 7098 3 7 Yessak/McDowell Luke Keller ACTIVITY SUMMARY AT: 06:00 HRS SURVEY: MD ANGLE AZIMUTH TVD SECTION N/S E/W DOGLEG Wiper trip.currently at 1290' 1908.55 75.25 0.46 1366.88 977.6 -40.37 978.44 0.62 1845.39 75.63 0.46 1351.5 918.41 -40.85 919.31 0.74 1783.28 75.23 022 1335.88 858.3 -41.21 859.27 1.69 1720.09 74.22 359.86 1319.23 797.34 -4125 798.37 0.98 1656.07 74.09 359.22 1301.75 735.76 -40.76 736.81 1.37 TIME LOG ELAPSED ACTIVITY COMMENTS FROM TO TIME 600 8:00 2.0 Drilling Drill 12 1/4"surface hole from 1510'to 1571',pump sweep around,sweep came back 300 stks early,100%increase in cuttings.Pump survey 9 Flow check well.No flow. 8:00 10:30 2.5 Wiper Trip Pull wiper trip from 1571'to 565',pull on elevators 51571'seeing 20-25k overpulls©1310'.Puna out from 1310'to 565',grabber dies on top drive not holding. 10:30 11:00 0.5 UnPlanned Flow check and monitor well.CIO grabber dies on top drive.New dies were installed at begining of well. 11:00.12:00 1.0 Wiper Trip Continue pumping out of the hole from 565'to 288'at jars. 1200 13:30 1.5 Rig Repair Hydraulic system overheating due to washed hydraulic valve to pipe spinners.C/O hyd.valve.Monitor well. 13:30 15:00 1.5 Wiper Trip RIH from 288'to 1505',Fill pipe,safety ream last stand.No fill,Load sweep in pipe. 15:00 18:00 3.0 Drilling Drilling from 1571'to 1633',BU gas 188u.Sweep back 200 stks early with 200%increase in cuttings.Mud wt 9.4 ppg.vis 165.Clean suction screens on#1 and#2 MP. 18:00 0:00 6.0 Drilling Drill F/1636'1/1884'rotating.VJOB=15K,Pumping®525 GPM,80 RPM,SPP=1850,W/8500-9500 tq on btm 8 7500 off 0:00 0:30 0.5 Circ&Cond C/O bad cap gasket M/P#2 pod it 3 suction side. 0:30 1:30 1.0 Drilling Drill F/1884'T/1904' 1:30 2:00 0.5 Circ 8 Cond Circ-btms up.canrig checking samples.sand/coal @ 1904' 2:00 3:00 1.0 DrillingDrill F/1904'T/T.D.a 1945'landed in silt and clay stone.WOB=15K,Pumping at 525 GPM,W/80 RPM,SPP=1300 OT on btm=9000 6 6000 off. 3:00 4:00 1.0 Circ&Cond Pump sweep.back 7.2 bbls early with 100%increase in cuttings. 400 6:00 20 (drI Trips Flow check well.pooh on elevators F/1945'T/1760'pull 15 to 20K over MAI T.D.back ream OOH,pumping 440 gpm,W/1300 SPP,40 RPN and 5 to 6000 tq.end of tour depth 1290' 180 bbls hauled to disposal,Paxton 7 total 450 bbls Slides=264 hrs&ROT.=11.18 hrs Latest Survey;693'Above 8.22'left of the line. TOTAL 2400 LITHOLOGY: MAX GAS B.G.GAS 188 CON GAS TRIP GAS Accidents None Pollution none Plan Next 24 Hr Report Attach no Finish wiper trip up to BHA RIH to casing point TD.a 1945'pump sweep POOH L/D BHA RA, MUD RECORD CASING RECORD PUMP BPM TYPE Spud DATA GPM SIZE GRADE WT CONN DEPTH DV ID NUMBER 1 2 TIME 5'.30 18 X-56 109 Weld 139 15 MAKE TSM TSM DEPTH 1945 MODEL 1000 1000 TEMP 86 STROKE 9 9 WEIGHT 9.50 LINER SZ 5.50 5.50 VISC 142.0 SPM PV 26.0 TOP OF LINER @ GAL/STK 264 2.64 YP 48 BIT NO. 1 SUR PSI 1344 1344 GELS 23 BHA# SIZE 1225 API Mk 1 MFG. HDBS SLOW PUMP DATA HTHP DESCRIPTION OD ID FEET TYPE QHC1GRC Pump# PSI1 PSI2 PSI3 Eff% CAKE 1/- Milltooth/Tricone 12.2$ 3.378 1.08 SERIAL NO. 12474444 1 95 SOLIDS 6 8"sperryDrill 8 5 32.11 NOZZLES 3X18 1X12 2 95 ADJSOL 8"DM Collar 8 3.5 9.21 TFA 0.856 SPM for PSI 12/3 OIL% 8"EWR-P4 Collar 8 2 23.17 DEPTH OUT 1945 DRILL STRING CAPACITY WTR% 94 8"TM HOC 8.15 4 9.35 DEPTH IN 138 STROKES 486 SD% 0.75 8"Flex Collar 7.38 2.813 30.19 TOTAL FT. 1807 MBT 24 8"Flex Collar 7.78 2.813 29.95 HOURS 29.5 POM Bottle neck xo sub 7.67 2.188 2.2 AVG ROP 44.9 pH 9 Non mag flex collar 6.59 2.5 3097 WOB 15K Pm 0.2 Non mag flex collar 6.7 2.5 30.83 ANN VEL 99.2 DEPTH 1945 PF/MF 0/1 (2)jts 5"HVVDP 5 3 63 ROT.RPM 135 TORQUE 15K Clmud Hyd.jar with bumper 6.22 2.25 30.33 AV DP CSG 99.2 PICK UP 62000 Cfvrtr (7)jts 5"HWOP 5 3 220.5 AV DP OP HL 1441 ROTATIONAL 50000 Cal AV DC 144.1 SLACK OFF 44000 LIME TOT CUM HR 29.5 %LGS 8.7 GAUGE JAR HOURS 28.09 ES INNER MUD MOTOR HRS 26.89 OUTER LOCATION RP DULL CHAR. CUM HR BHA 29.47 LIG MUD TOTAL LENGTH(FT) 512.89 HYDRAULICS FUEL 8443 GAL • PDD(DIESELGAL) TOT WEIGHT(LBS) 38342 DEPTH 1945 FT CREW BOAT FUEL GAL • SOLIDS EQUIPMENT NOZ.AREA .856 INC POT.WATER GAL SHAKER#1 100/100/8 DRK 2 d Pb PSI TUG FUEL GAL • SHAKER#2 80/80/701 BRDT HRS HHP BIT 307.3792 HP BARITE SKS i DERRICK#1 DRKS Hes H.S.I. 2.609352 HP/IN' FUEL USED 1470 GAL MUD CLEAN CENT 6 HRS JET VEL FT/SEC HEAVY H2O GAL BOP TESTED PERSONNEL ON BOARD IMP FORCE WEATHER Misc 09242014 HEC 2 %Pb WIND 3 Mi MPH DAILY CUM NEXT TEST DUE RIG 16 BOATS SEAS TEMP MUD $3,161 514,265 10/092014 SERVICE 13 MN PRES GOND Partly cloudy 41F DIESEL FUNC.DUE TOTAL 31 MN FORECAST Sunny/Warmer TOTAL $14,265 MN www.wsllez.cem WallEz Information Management LLC ver 050514bf • Hilcorp Energy Company • ‘. WAILY DRILLING REPORT REPORT NO. LEASE WELL NO. COUNTY/PARISH WELL STATE DATE 8 ADL384372&Private Paxton 7 Kenai Peninsula Burough NINU Paxton 7 AK 9/29/2014 RIG AFE NO. AFE BUDGET DAILY COST CDC RIG PHONE Saxon Rig#147 1412365D 4584878 997,663 $876,863 907-283-1365 ACTIVITY TYPE: DRLG Drilling CrntCsg Cementing Casing DEPTH:MD/VD PROGRESS/HRS PROP.TD AST SHOE TEST PPG DAYS SINCE SPUD AFE DAYS FIELD SUPERVISOR ENGINEER 1945 1377 7098 4 8 Yessak/McDowell Luke Keller ACTIVITY SUMMARY AT: 06:00 HRS SURVEY: MD ANGLE AZIMUTH TVD SECTION N/S E/W DOGLEG Rigging up to cement 9.625'surface casing. 1906.55 75.25 0.46 1366.88 977.61 -40.04 978.43 0.62 1845.39 75.63 0.48 1351.5 918.42 -40.51 919.31 0.74 1783.28 75.23 022 1335.88 858.31 -40.87 85926 1.69 1720.09 74.22 359.88 1319.23 797.35 -40.91 798.36 0.98 1858.07 74.09 359.22 1301.75 735.77 -40.42 736.81 1 TIME LOG ELAPSED ACTIVITY COMMENTS FROM TO TIME 6:00 7:30 1.5 Wiper Trip Wiper trip with 12 1/4"BHA,POH on elevators horn 1290'to HWDP @ 502'with no further issues.Correct hole fill. 7:30 9:00 1.5 Wiper Trip Flowcheck well,no flowTlH from 502'to 1888',fill pipe,safety morn lest stand tagging TD/1945'.No fill.Correct fluid displacement. 9:00 10:30 1.5 Circ&Cord Pump hi vis sweep with nut plug marker,105u gas @ BU.Sweep back @ calculated stks with 50%increase in cuttings @ shaker.Circulate wellbore clean.MW 9.6 ppg 160 vis.No losses. 1030 17:30 7.0 tlrl TriFlowcheck well,no Sow.POH from 1945',flaw check well at HVMDP.Stand back 5 stds HWDP with jars,1 stand 6"flex collars,L/D directional ( ) ps tools,download data.No issues POH. (drl)Trips Bit grade=2/2/WT/A/E/I/NO/TO:Clear and cleanup rig floor 17:30 18:30 1.0 (com)RU/Run(RN and pull 14"ID wear ring.Land and mark hanger.Landed at 23.0' 18:30 21:30 3.0 (tlfl)RU/Run Ca R/D elevators 8 bails.C/O saver sub to CDS-40,rig up weatherford 9.625 casing running eguipment prep.to run casing.Bring (22)centralizers to rig floor. 21:30 22:00 0.5 Rig Service Service Drawworks,Brake linkage,T.D.Crown sheaves&Blocks. 2200 230 4.5 (dR)RURtun Ca M/U shoe track 8 baker loc.install stop rings and centralizers.Break circ-check floats.RIH with 47 jts T/1936'9.625 casing MN tq=9700 ft/16s filling on each joint 8 top off every 10. 2:30 3:00 0.5 (dn)RU/Run Ca M/U hanger&land with camron rep.PN to circ-&condition mud 3:00 4:30 1.5 Circ&Gond Ciro&condition mud.Stage pumps up to 7bbls/min @ 110 stks/min.with 480 psi 8 292 GPM.up wt=84K,down wt=38K,Remove casing running equp.and PN Cementing equip.to rig floor. YP.=26,M.W.=9.5ppg 4:30 6.00 1.5 Cementing 8 N Land hanger,breakout of CTR,M/U cmt.head,and iron Crew Change. 540 bbls hauled to disposal,Paxton 7 total 990 bbls. TOTAL 24.00 LITHOLOGY: MAX GAS B.G.GAS 124 CON GAS TRIP GAS Accidents None Pollution none Plan Next24 Hr Report Attach no Cement surface casing.RID.set casing hanger packoff N/D diverter system N/U BOPs. MUD RECORD CASING RECORD PUMP BPM TYPE Spud DATA GPM SIZE GRADE WT CONN DEPTH DV ID NUMBER 1 2 TIME 5:30 16 X-56 109 Weld 139 15 MAKE TSM TSM DEPTH 1945 MODEL 1000 1000 TEMP 82 STROKE 9 9 WEIGHT 9.60 LINER SZ 5.50 5.50 VISC 181.0 SPM PV 29.0 TOP OF LINER @ GAL/STK 2.64 2.64 YP 53 BIT NO. 1 SUR PSI GELS 22 BHA# SIZE 1225 API WL MFG. HDBS SLOW PUMP DATA@ HTHP DESCRIPTION OD ID FEET TYPE QHCIGRC Pump# PSI 1 PSI2 PSI3 Eff% CAKE 1/- SERIAL NO. 12474444 1 95 SOLIDS 7.5 NOZZLES 3X18 1X12 2 95 ADJSOL TFA 0.856 SPM for PSI11213 OIL% DEPTH OUT 1945 DRILL STRING CAPACITY WTR% 92 DEPTH IN 138 STROKES SD% 1 TOTAL FT. 1807 MBT 25 HOURS 29.5 POM AVG ROP 44.9 pH 9.2 WOB Pm 0.3 ANN VEL DEPTH PF/MF 0/1 ROT.RPM 135 TORQUE Clmud AV DP CSG PICK UP Clwtr AV DP OP HL ROTATIONAL Cal AV DC SLACK OFF LIME TOT CUM HR 295 %LGS 9.5 GAUGE I JAR HOURS ES INNER 2 MUD MOTOR HRS OUTER 2 LOCATION A RP TD DULL CHAR.WT,E CUM HR BHA LIQ MUD TOTAL LENGTH(FT) HYDRAULICS FUEL 7563 GAL ADD(DIESELGAL) TOT WEIGHT(LBS) DEPTH 1945 FT CREW BOAT FUEL GAL SOLIDS EQUIPMENT NOZAREA .856 IN' POT.WATER GAL SHAKER#1 100/100/8DRK2 dPb PSI TUG FUEL GAL SHAKER#2 80/80/701 BRDT HRS HHP BIT HP BARITE SKS DERRICK#1 DRKS HRS FL SI HP/IN' FUEL USED 880 GAL MUD CLEAN CENT 6 FIRS JET VEL FT/SEC HEAVY H2O GAL BOP TESTED PERSONNEL ONBOARD IMP FORCE WEATHER Mist 09/24/2014 HEC 2 %Pb WIND 5 m/hr MPH DAILY CUM NEXT TEST DUE RIG 16 BOATS SEAS TEMP MUD $1,563 $15,827 10/09/2014 SERVICE 19 MN PRES CORD Clear32F DIESEL FUNC.DUE TOTAL 37 MN FORECAST Clear&cool TOTAL $15,827 MN w+vw.wellez.com WellEz Information Management LLC ver 050514bf Hilcorp Energy Company • II 111AILY DRILLING REPORT • REPORT NO. LEASE WELL NO. COUNTY/PARISH WELL STATE DATE 9 ADL384372 8 Private Paxton 7 Kenai Peninsula Borough NINU Paxton 7 AK 9/30/2014 RIG AFE NO. AFE BUDGET DAILY COST CDC RIG PHONE Saxon Rig#147 1412365D 4564878 $160,544 51,037,407 907-283-1365 ACTIVITY TYPE: DRLG Drilling NUBOPE NU BOPE DEPTH:MD/TVD PROGRESS/HRS PROP.TD AST SHOE TEST PPG DAYS SINCE SPUD AFE DAYS FIELD SUPERVISOR ENGINEER 1945 1377 7098 5 9 Yessak/McDowell Luke Keller ACTIVITYSUMMARYAT: 0600 HRS SURVEY: MD ANGLE AZIMUTH TVD SECTION N/S E/W DOGLEG Nipple up Bops. 1906.55 75.25 046 1366.88 977.61 -40.04 978.43 0.62 1845.39 75.63 0.46 1351.5 918.42 -40.51 919.31 0.74 1783.28 75.23 022 1335.88 858.31 40.87 859.26 1.69 1720.09 74.22 359.86 1319.23 797.35 -40.91 798.36 0.98 1656.07 74.09 359.22 1301.75 735.77 -40.42 736.81 1 TIME LOG ELAPSED ACTIVITY COMMENTS FROM TO TIME 600 7:00 1.0 Cementing 8M Crew change.PJSM for cementing operations with DSM,cement and rig crews,MI,Tool pusher,DSM and rig support. 700 8:30 1.5 Other Making equipment checks,Found that bell nipple flange was leaking.Tighten and seal leak. 830 13:00 4.5 Cementing 8 N Start cementing operations,Drop lower plug and chase with 5 bbls of water.Pressure test lines to 500 psi low and 2500 psi high.Mix and pump 40 bbls of 10 ppg seal bond spacer a 4 bpm,160 psi. Batch 12.5 ppg type 1 lead cement at 09:15hm Pump 128.6 bbls of lead cement pumping @ 3.8 bpm 220 psi,followed with 48.6 bbls 15.2 ppg type 1 tail cement at 3.8 bpm increasing to 4.2 bpm,260 psi. Drop and chase upper plug with 10 bbls of water,start seeing spacer at returns-dump returns.With cementers-displace cement with 9.5 ppg kal-shield mud pumping 5 bpm,150 psi. Note:cement at returns after 46 bbls of displacement mud pumped.Start injecting black water into annulas to contaminate returns.120 bbls away,slow down pump to 2 bpm,488 psi @ FCP. Plug bumped®144.5 bbl,4 bbls over calculated displacement Pressure up to 1034 psi,hold pressure for 5 min.No pressure drop,bleed off pressure.3/4 bbl bled back.Float held.CIP @ 11:05 hrs. NOTE:Full returns throughout cement job.60 bbls cement 30 bbls of mud interface,40 bbls mud spacer and 25 bbls of black water dumped during cement job.Flush lines,R/D cementers. 13:00 14:30 1.5 Cementing 8 N Install packoff per Cameron rep.L/D landing joint 14:30 16:00 1.5 Cementing 8 M R/D Weatherford CRT. 16:00 22:30 6.5 NU/ND BOPE PJSM,WD diverter system.Continue to haul off spud mud 8 clean pits. 22:30 1:30 3.0 Install Wellheal N/U Seaboard multi-bowl wellhead assy.Install packoff 9.625"P-seals Test void 300/3000 psi.30 min.Pr.cameron rep. 1:30 6:00 4.5 NU/ND BOPE N/U Bope.P/U and stack lower rams,mud cross,double gate and annular,torque bolts. Start building 9.5 Kla-Sheild mud. 720 bbls hauled to disposal,Paxton 7 total 1710 bbls. TOTAL 24.00 LITHOLOGY: MAX GAS B.G.GAS CON GAS TRIP GAS Accidents Pollution none Plan Next 24 Hr Report Attach no Continue to NN Bops,Test Bope. MUD RECORD CASING RECORD PUMP BPM TYPE Kla Sheild DATA GPM SIZE GRADE WT CONN DEPTH DV ID NUMBER 1 2 TIME 5:30 16 X-56 109 Weld 139 15 MAKE TSM TSM DEPTH 1945 9-5/8 L-80 40 BTC 1936 75.25 8.835 MODEL 1000 1000 TEMP 70 STROKE 9 9 WEIGHT 1060 LINER SZ 5.50 5.50 VISC 55.0 SPM PV 16.0 TOP OF LINER @ GAL/STK 2.64 2.64 VP 30 BIT NO. 1 SUR PSI GELS 12 BHA# SIZE 12.25 API VtL MFG. HDBS SLOW PUMP DATA HTHP DESCRIPTION OD ID FEET TYPE QHC1GRC Pump# PSI1 PSI2 PSI3 Eff% CAKE 1/- SERIAL NO. 12474444 1 95 SOLIDS 10 NOZZLES 3X18 1X12 2 95 ADJSOL TFA 0.856 SPM for PSI 12/3 OIL% DEPTH OUT 1945 DRILL STRING CAPACITY WTR% 89 DEPTH IN 138 STROKES SD% 0.1 TOTAL FT. 1807 MBT 11 HOURS 29.5 POM AVG ROP 44.9 pH 10.2 WOB Pm 0.3 ANN VEL DEPTH PF/MF 1/4 ROT.RPM 135 TORQUE Clmud AV DP CSG PICK UP Cloth AV DP OP HL ROTATIONAL Cal AV DC SLACK OFF LIME TOT CUM HR 29.5 %LGS 1.7 GAUGE I JAR HOURS ES INNER 2 MUD MOTOR HRS OUTER 2 LOCATION A RP TD DULL CHAR.WT,E 1 CUM HR BHA LIQ MUD TOTAL LENGTH(FT) HYDRAULICS FUEL 8969 GAL ADD(DIESELGAL) TOT WEIGHT(LBS) DEPTH 1945 FT CREW BOAT FUEL GAL SOLIDS EQUIPMENT NOZ.AREA .856 NaIPOT.WATER GAL SHAKER#1 100/100/8 DRK 2 d Pb PSI TUG FUEL GAL SHAKER#2 80/80/701 BRDT FIRS HHP BIT HP BARITE SKS DERRICK#1 DRKS FIRS H.S.I. HP/IN' FUEL USED 594 GAL MUD CLEAN CENT 6 HRS JET VEL FT/SEC HEAVY H2O GAL BOP TESTED PERSONNEL ON BOARD IMP FORCE WEATHER Misc 09242014 HEC 2 %Pb WIND N10 mi MPH DAILY CUM NEXT TEST DUE RIG 16 BOATS SEAS TEMP MUD $6,090 521,917 10/092014 SERVICE 19 MN PRESCOND Clear 45F DIESEL FUNC.DUE TOTAL 37 MN FORECAST Clear sunny TOTAL $21,917 MN ewvw.wellez.corn WellEz Information Management LLC ver 050514bf .. rir � Hilcorp Energy Company • AILY DRILLING REPORT REPORT NO. LEASE WELL NO. COUNTY/PARISH WELL STATE DATE 10 ADL384372&Private Paxton 7 Kenai Peninsula Burough NINU Paxton 7 AK 10/1/2014 RIG PFE NO. AFE BUDGET DAILY COST CDC RIG PHONE Saxon Rig#147 1412365D 4564878 $118,596 $1,156,003 907-283-1365 ACTIVITY TYPE: DRLG Drilling TIH Tripping in Hole DEPTH:MD/TVD PROGRESS/HRS PROP.TD AST SHOE TEST PPG DAYS SINCE SPUD PEE DAYS FIELD SUPERVISOR ENGINEER 1945 1377 7098 6 10 Lott/Yessak Luke Keller ACTIVITYSUMMARYAT: 06:00 HRS SURVEY: MD ANGLE AZIMUTH TVD SECTION N/S E/W DOGLEG PN 5"Drill pipe. TIME LOG ELAPSED ACTIVITY COMMENTS FROM TO TIME 6.00 18:00 12.0 NU/ND BODE N/U 11"5m BOPE,unload and prep 5"dril pipe,continue to condition 9.5 ppg kla-shield mud. 18:00 21:30 3.5 NU/ND BOPE Continue to NN BOPE.Install 2 7/8"x 5"VBR in upper BOP.Function test BOPE. 2130 200 4.5 Tstg BOPANH/l PJSM,R/U test equipment.Open annulas valve.Flood lines with water.Perform BOP body test to 3500 psi.AOGCC rep Matt Herrera on location to witness test.Total safety calibrate and test gas alarms. Using 5"test jt,Test annular to 250/2500 psi 5 min ea.Test upper and lower 2 7/e"x 5"VBR,Blind ram,HCR choke,HCR kill,2 kill valves,3' manual valve,upper and lower!BOP, 13 choke manifold valves,FOSV and dart valve to 250/3500 psi 5 min ea.Perform accumulator draw doom test&choke bleed off test.Chart all tests.No failures.Close annulus valve,R/D test equip. 2:00 2:30 0.5 Other Blow down choke and top drive.R/U and Install 9"ID wear bushing. 2:30 3:00 0.5 Rig Service Service rig. 3:00 4:00 1.0 Other CIO saver sub,R/U bails and elevators. 4:00 6:00 2.0 (drl)Trips PJSM,drift and RIH with 5"drill pipe,rack back in derrick.(148 jts total) 360 bbls hauled to disposal,Paxton 7 total 2070 bbls. TOTAL 24.00 LITHOLOGY: MAX GAS B.G.GAS CON GAS TRIP GAS Accidents Pollution No pollution Plan Next 24 Hr Report Attach P/U and rack 5000'drll pipe in derrick.Test 9 5/8"casing.MN 8 112"bha MUD RECORD CASING RECORD PUMP BPM TYPE Kla Sheild DATA GPM SIZE GRADE WT CONN DEPTH DV ID NUMBER 1 2 TIME 21:00 16 X-56 109 Weld 139 15 MAKE TOM TSM DEPTH 1945 9-5/8 L-80 40 BTC 1936 7525 8.835 MODEL 1000 1000 TEMP 54 STROKE 9 9 WEIGHT 9.50 LINER SZ 5.50 5.50 VISC 50.0 SPM PV 11.0 TOP OF LINER @ GAL/STK 2.64 264 YP 25 BIT NO. SUR PSI GELS 9 BHA# SIZE API IAL MFG. SLGN PUMP DATA @ HTHP DESCRIPTION OD ID FEET TYPE Pump# PSI 1 PSI2 PSI3 E8 CAKE 1 SERIAL NO. 1 95 SOLIDS 6 NOZZLES 2 95 ADJSOL TFA SPM for PSI 1/2/3 OIL% DEPTH OUT DRILL STRING CAPACITY WTR% 94 DEPTH IN STROKES SD% 0.1 TOTAL FT. MBT 4 HOURS POM AVG ROP pH 9.1 NDB Pm 1 ANN VEL DEPTH PF/MF 1/3 ROT.RPM TORQUE Clmud AV DP CSG PICK UP CMTr AV DP OP HL ROTATIONAL Cal 30000 AV DC SLACK OFF LIME TOT CUM HR %LGS 2.2 GAUGE JAR HOURS ES INNER MUD MOTOR HRS OUTER LOCATION RP DULL CHAR. CUM HR BHA LIQ MUD TOTAL LENGTH(FT) HYDRPIIUCS FUEL 6086 GAL ADD(DIESELG4L) TOTWEIGHT(LBS) DEPTH 1945 FT CREWBOAT FUEL GAL SOLIDS EQUIPIIENT NOZAREA .856 IW POT.WATER GAL SHAKER#1 100/100/1 DRK 2 d Pb PSI TUG FUEL GAL SHAKER#2 120/120/1 BRDT HRS HHP BIT HP BARITE SKS DERRICK#1 DRKS HRS H.S.I. HP/IN' FUEL USED 883 GAL MUD CLEAN CENT 24 HRS JET VEL FT/SEC HEPVY H2O GAL BOP TESTED PERSONNEL ON BOARD IMP FORCE WEATHER Misc 10/01/2014 HEC 2 %Pb WIND 6 MPH DAILY CUM NEXT TEST DUE RIG 16 BOATS SEAS 53 TEMP MUD $63 $21,980 10115/2014 SERVCE 19 MN PRES CONS Clew DIESEL FUNC.DUE TOTAL 37 MN FORECAST Clew TOTAL $21,980 10/15/2014 MN www.wellez.com WellEz Inbrmation Management LLC ver 050514bf • iiiItHilcorp Energy Company • AILY DRILLING REPORT REPORT NO. LEASE WELL NO. COUNTY/PARISH WELL STATE DATE 11 ADL384372&Private Paxton 7 Kenai Peninsula Borough NINU Paxton 7 AK 10/2/2014 RIG AFE NO. AFE BUDGET DAILY COST CDC RIG PHONE Saxon Rig#147 1412365D 4564878 $131,551 $1,287,554 907-283-1365 ACTIVITY TYPE: DRLG Drilling DdgCmt Drlg Cod DEPTH:MD/TVD PROGRESS/HRS PROP.TD AST SHOE TEST PPG DAYS SINCE SPUD AFE DAYS FIELD SUPERVISOR ENGINEER 1945 1377 7098 7 11 Lott/Yessak Luke Keller ACTIVITYSUMMARYAT: 06:00 HRS SURVEY: MD ANGLE AZIMUTH TO SECTION N/S E/W DOGLEG Drill FE @ 1847' TIME LOG ELAPSED ACTIVITY COMMENTS FROM TO TIME 6:00 15:30 9.5 (dri)Trips Continue to drift and P/U 110 joints of 5"drill pipe and 6 HOOP.Rack back in derrick 15:30 18:30 3.0 Tstq BOPAAM/l Rig up and test 9 5/8"casing to 2900 psi and chart for 30 min.Good test,Bleed off pressure.Drain gas buster.Blow down choke maniflod aro hoes.Rip test equipment. 18:30 1:00 65 (dd)Trips PJSM,load tools tong floor,MN 8 12"bha#2,M/U PDC bit,1.5 deg mud motor w/stab,It sub,stab,DM collar.scribe motor to MWD with a 12923 deg offset,M/U DGR collar,EWR-P4 collar, HCIM,ALD,CTN,HOC collars,down load data,PJSM,install sources.MN 2 NM Flex Collars,Test MWD.M/U 4 its HVuDP,jar with bumper, it jts 1-MuDP=657.41' 1:00 2:30 1.5 Cut/Slip Drill Lh PJSM,slip and cut 80'of drilling line,re-set and test crown-o-matic. 2:30 3:00 0.5 Rig Service Service top drive,draworks and blocks. 3:00 5:00 2.0 (dn)Trips Drift and single in with 34 its of 5"drill pipe from 657.10 1732',continue to TIH with stands to 1791',NI pipe.Wash and tag @ 1847' 5:00 6:00 1.0 Dulling Cement Drill FE©1647'pumping 450 gpm 1100 psi. 90 bbls hauled to disposal,Paxton 7 total 2160 bbls. TOTAL 24.00 LITHOLOGY: MAX GAS 8.G.GAS CON GAS TRIP GAS Accidents Pollution No pollution Plan Next 24 Hr Report Attach Drill 2E new formation to 1965'.Perform F.I.T.to 12 ppg EMW.Drill 8 1/2"production hole. MUD RECORD CASING RECORD PUMP 10.55 BPM TYPE Kla Sheild DATA 443 GPM SIZE GRADE WT CONN DEPTH DV ID NUMBER1 2 TIME 21:00 16 X-56 109 Weld 139 15 MAKE TSM TOM DEPTH 1945 9-5/8 L-80 40 ETC 1936 75.25 8.835 MODEL 1000 1000 TEMP 55 STROKE 9 9 WEIGHT 9.60 LINER SZ 5.50 5.50 VISC 60.0 SPM 86 82 PV 11.0 TOP OF LINER @ GAUSTK 2.64 2.64 YP 21 BIT NO. 2 SUR PSI 1000 1000 GELS 6 BHA# SIZE 8.5 API NL 45 2 MFG. HDBS SLOW PUMP DATA @ 1840 HTHP DESCRIPTION OD ID FEET TYPE PDC MM65M Pump# PSI 1 PSI2 PSI 3 Eff% CAKE 1 PDC BIT,6X12 JET: 8.5 2.25 0.9 SERIAL NO. 12474819 1 204 95 SOLIDS 7 IUD MOTOR 1.5 DEC 8.312 4.952 26.33 NOZZLES 6 X 12 2 198 95 ADJSOL FLOAT SUB 6.58 2.75 2.14 TFA 0.663 SPM for PSI 1/2/3 43 44 OIL% 1 INTREGAL BLADE 8.312 2.5 7.69 DEPTH OUT 1945 DRILL STRING CAPACITY WTR% 92 DM COLLAR 6.75 3.125 92 DEPTH IN 1945 STROKES 435 SD% 0.1 DGR COLLAR 6.75 1.82 6.42 TOTAL FT. MBT 4 EWR-P4 COLLAR 6.75 2 12.04 HOURS POM HCIM COLLAR 6.75 1.92 6.65 AVG ROP pH 9.9 ALD COLLAR/STAB 8.25 1.92 16.26 NAB Pm 2.6 CTN COLLAR 6.75 1.905 11.85 ANN VEL DEPTH 1945 PF/MF 2/6 TM HOC COLLAR 6.9 3.25 10.04 ROT.RPM TORQUE Clmud NM FC 6.59 2.5 30.97 AV DP CSG PICK UP 68000 Ctwtr NM FC 6.7 2.5 30.83 AV DP OP HL ROTATIONAL 52000 Cal 40000 4 JTS 5"HNDP 5 3 121.73 AV DC SLACK OFF 40000 LIME ,RS W/BUMPER SL 6.22 2.25 30.33 TOT CUM HR %LGS 1.8 11 JTS 5"HOOP 5 3 333.83 GAUGE JAR HOURS ES INNER MUD MOTOR HRS OUTER LOCATION RP DULL CHAR. CUM HR BHA LIQ MUD TOTAL LENGTH(FT) 657.41 HYDR/WUCS FUEL 9690 GAL ADD(DIESELCAL) TOTWEIGHT(LBS) 43080 DEPTH 1945 FT CREWBOAT FUEL GAL SOLIDS EQUIPfsENT NOZAREA .6627 IN' POT.WATER GAL SHAKER#1 100/100/I DRK 2 d Pb 395.4457 PSI TUG FUEL GAL SHAKER#2 120/120/1 BRDT HAS HHP BIT 267.9113 HP BARITE SKS DERRICK#I DRKS HRS H.S.I. 4.723714 HP/IN' FUEL USED 404 GAL MUD CLEAN CENT HRS JET VEL 213.9125 FT/SEC HEA/Y H2O GAL BOP TESTED PERSONNEL ON BOARD IMP FORCE WEATHER Misc 10/01/2014 HEC 2 %Pb WIND ENE MPH DAILY CUM NEXT TEST DUE RIG 16 BOATS SEAS 40 TEMP MUD $9,166 $31,146 10/15/2014 SERVICE 19 MN PRES GOND Clear DIESEL FUNC.DUE TOTAL 37 MN FORECAST Clear • TOTAL $31,146 10/15/2014 MN www.wellez.com WellEz Information Management LLC ver 050514bf GHi!corp Energy Company AILY DRILLING REPORT 1111/ REPORT NO. LEASE WELL NO. COUNTY/PARISH WELL STATE DATE 12 ADL384372 8 Private Paxton 7 Kenai Peninsula Burough NINU Paxton 7 AK 10/3/2014 RIG PEE NO. PEE BUDGET DAILY COST CDC RIG PHONE Saxon Rig#147 1412365D 4564878 $171,719 51,459272 907-283-1365 ACTIVITY TYPE: DRLG Dulling Drilling Drilling DEPTH:MD/TVD PROGRESS/HRS PROP.TD AST SHOE TEST PPG DAYS SINCE SPUD AFE DAYS FIELD SUPERVISOR ENGINEER 3460 1824 1515 7098 10/2/2014 12 8 12 Lott/Yessak Luke Keller ACTIVITYSUMMARYAT: 06:00 HRS SURVEY: MD ANGLE AZIMUTH TVD SECTION N/S E/W DOGLEG Drilling 8 12"production hole 0 3460 3268.75 71.86 358.97 1765.17 2278.93 -93.57 2280.85 3.82 3204.69 72.5 35649 1745.56 2218 -91.15 221987 0.99 314223 73.12 356.51 1727.1 2158.44 -87.51 216022 065 3078.65 73.25 356.92 1708.71 2097.68 -84.02 209938 024 3015.19 73.34 357.05 1690.47 2036.98 -80.82 2038.58 0.62 TIME LOG ELAPSED ACTIVITY COMMENTS FROM TO TIME 6:00 9:30 3.5 Dulling Cement Drl FE 8 Crra to 1847'(FC)to 1945'(Shoe).Drill 20'of new hole to 1965'. 930 10:00 0.5 Circ 8 Gond Circulate and condition for FIT Test 10:00 10:30 0.5 Tstg BOP/WI-14 Conduct FIT Test to 12.0 ppg EMW with 180 psi applied 0 surface.Good Test. Drill f/1965'to 2491'(526')AROP=70 fph 1030 18:00 7.5 Dnlling 5-10K WOO,80 TD RPM,170 Mtr RPM 500 GPM,1800 SPP,Diff 120 PSI,10.0 MW,55 Vis.PU 72K,SO 48K,Rot 55K,On Btm TO 9.06.Off Btm TO 0.06. Note:Started increasing MW from 9.7 to 10.0 0 2300'with BGG 0 1250. Drill f/2491'to 3025'(534')AROP=89 fph 18:00 0:00 6,0 Drilling 5-10K NOB,70 TD RPM,170 Mtr RPM 500 GPM,1800 SPP,Diff 110 PSI,10.2 MW,60 Vis,PU 746 SO 50K,Rot 56K,On Btm TO 9.0K,Off Btm TO 6.46. Pump tandem sweeps every 300'drilled.average 100%increase on first sweep,150%increase on second.Note:Increase MW from 10 ppg to 10.2 ppg 0 2600'due to increase in BGG 0 149u. 0:00 0:30 0.5 Rig Service Service Rig. Drill 1/3025'to 3460'(435')AROP=79 fph 0:30 6:00 5.5 Drilling 10-16K WOB,80 TD RPM,166 Mtr RPM 488 GPM,1880 SPP.Diff 200 PSI,10.4 MW,64 Vis,PU 84K,SO 50K,Rot 58K,On Btm TQ 9.5K,Off Btm TO 6.66. Note:Increase MW from 10.2 ppg to 10.4 ppg 0 3150 due to increase in BOG @ 149u.Current BGG 80u.Currently 931'above the line and .2'right of the line.9.06 rotate hrs and 1.04 slide hrs. 270 bbls hauled to disposal.Paxton 7 total 2430 bbls. TOTAL 24.00 LITHOLOGY: Tuffaceous sihstone,tuff claystone,sand MAX GAS 1298 B.G.GAS 252 CON GAS TRIP GAS Accidents Pollution No pollution Plan Next 24 Hr Report Attach Drill to 3500',pull wiper to 9 5/6"casing shoe. MUD RECORD CASING RECORD PUMP 11.87 BPM TYPE Kla Sheild DATA 499 GPM SIZE GRADE WT CONN DEPTH DV ID NUMBER1 2 TIME 21:00 16 X-56 109 Weld 139 15 MAKE TOM TOM DEPTH 2740 95/8 L-80 40 BTC 1936 75.25 8.835 MODEL 1000 1000 TEMP 78 STROKE 9 9 WEIGHT 1020 LINER SZ 5.50 5.50 VISC 58.0 SPM 115 74 PV 15.0 TOP OF LINER 0 GAL/STK 264 264 YP 23 BIT NO. 2 SUR PSI 1880 1880 GELS 5 BHA# SIZE 8.5 API Wl 4.4 2 MFG. HDBS SLOW PUMP DATA 0 3245 HTHP 9.2 DESCRIPTION OD ID FEET TYPE PDC MM65M Pump# PSI 1 PSI2 PSI3 Eff% CAKE 1 7 DC BIT,6X12 JET: 8.5 2.25 0.9 SERIAL NO. 124748181 264 95 SOLIDS 9 IUD MOTOR 1.5 DEl 8.312 4.952 2633 NOZZLES 6 X 12 2 193 95 ADJSOL FLOAT SUB 8.58 275 2.14 TFA 0.683 SPM for PSI 12/3 44 32 OIL% 1 INTREGAL BLADE 8.312 2.5 7.69 DEPTH OUT 3460 DRILL STRING CAPACITY WTR% 90 DM COLLAR 6.75 3.125 92 DEPTH IN 1945 STROBES 860 SD% 0.1 DGR COLLAR 6.75 1.92 6.42 TOTAL FT. 1515 MBT 4 EWR-P4 COLLAR 6.75 2 12.04 HOURS 10.1 POM HCIM COLLAR 6.75 1.92 6.85 AVG ROP 83 pH 10 ALD COLLAR/STAB 8.25 1.92 16.26 WOB 10-16k Per 2.5 CTN COLLAR 6.75 1.905 11.85 ANN VEL 229.1 DEPTH 3460 PF/MF 3/7 TM HOC COLLAR 6.9 3.25 10.04 ROT.RPM 166 TORQUE 9500 Clmud NM FC 6.59 2.5 30.97 AV DP CSG 528.6 PICKUP 84000 Chvtr NM FC 6.7 2.5 30.83 AV DP OP HL 700.7 ROTATIONAL 58000 Cal 40000 4 JTS 5"HVVDP $ 3 121.73 AV DC 444.3 SLACK OFF 50000 LIME IRS W/BUMPER Sl 6.22 225 30.33 TOT CUM HR 10.1 %LGS 12 11JTS5"HWDP 5 3 333.83 GAUGE JAR HOURS 21.68 ES INNER MUD MOTOR HRS 21.68 OUTER LOCATION RP DULL CHAR. CUM HR BHA 21.68 LIQ MUD TOTAL LENGTH(FT) 657.41 HYDRAULICS FUEL 8036 GAL ADD(DIESELGAL) TOT WEIGHT(LBS) 43080 DEPTH 3480 FT CREW BOAT FUEL GAL SOLIDS EQUIPMENT NOZ.AREA .6627 IN" POT.WATER GAL SHAKER#1 100/100/1 ORK 2 d Pb 531.7683 PSI TUG FUEL GAL SHAKER#2 120/120/1 BRDT HRS HHP BIT 440.7141 HP BARITE SKS DERRICK#1 DRKS HRS H.S.I. 7.770509 HP/IN' FUEL USED 1654 GAL MUD CLEAN CENT HRS JET VEL 240.6515 FT/SEC HEAVY H2O GAL BOP TESTED PERSONNEL ON BOARD IMP FORCE WEATHER Misc 10/01/2014 HEC2 %Pb WIND 12 Mab DAILY CUM NEXT TEST DUE RIG 16 BOATS SEAS 50 TEMP MUD 06,047 537,193 10/15/2014 SERVICE 19 MN PRES COND Clear DIESEL FUNC.DUE TOTAL 37 MN FORECAST Partly cloudy TOTAL $37,193 10/152014 MN www.wellez.com WellE&Information Management LLC ver 050514bf El "IDA ILYHileolpDRILLING Energy Company REPORT REPORT NO. LEASE WELL NO. COUNTY/PARISH WELL STATE DATE 13 AD1384372&Private Paxton 7 Kenai Peninsula Borough NINU Paxton 7 AK 10/4/2014 RIG AFE NO. AFE BUDGET DAILY COST CDC RIO PHONE Saxon Rig#147 14123650 4564878 5180,482 51.639,754 907-283-1365 ACTIVITY TYPE: DRLG Drilling LostCirc Lost Ciro DEPTH:MD/PAD PROGRESS/H RS PROP.TD AST SHOE TEST PPG DAYS SINCE SPUD AFE DAYS FIELD SUPERVISOR ENGINEER 4695 2194 1235 7098 10/2/2014 12 9 13 Lott/Yessak Luke Keller ACTIVITY SUMMARY AT: 06:00 HRS SURVEY: MD ANGLE AZIMUTH TVD SECTION N/S EIW DOGLEG Loss circulation®4695,Build and pomp LCM pill 4531.84 72.85 357.36 2145.2 34822 -146.48 3485.28 1.06 4468.3 72.95 358.08 212652 3421.52 -14405 3424.55 0.63 4405.56 7301 357.65 2108.15 3361.57 -141.8 3384.56 1.94 4342.24 72.66 356.42 2089.47 3301.16 -138.67 3304.07 0.83 4279.09 7277 356.96 2070.7 324096 -135.19 3243.78 1.35 TIME LOG ELAPSED ACTIVITY COMMENTS FROM TO TIME 6:00 6:30 0.5 Drilling Drill 81/2"production hole from 3465to 3502' 6:30 7:00 0.5 Ciro&Cond Sweep end circulate hole clean.Flow check well. 7'00 8:00 1.0 Wiper Trip TOH on elevators from 3500'to 2959'.En cooler tight hole with 20K to 40Kover pull.Work pipe free. Wash and ream from 2959'to 2850'.Attempt to straight pull with 30K over pulls. 8'00 8'30 0.5 Ciro&Cond Circulate to clear cuttings from wellbore 5/2850'.Hole unloaded with 100%increase in cutting.at BUS. TOH on elevators from 2850'to 2671'. Wash and ream from 2871'to 2550 8:30 1190 2.5 Wiper Trip Straight pull from 2550'to 2274' Wash and ream from 2274'to 2212' Straight pull from 2217 to 2050'(work tight spot @ 2122') Wash and ream from 2050'to 2039'. Straight pull from 2039'to 95/8 casi ng shoe@ 1936'. Monitor well for flow. 1100 12:00 1,0 Rig Service Service Rig. Calibrate torque on iron roughneck. 1200 12:30 0.5 Wiper Trip TIH from 1930 to 2860 wi th no issues. 12:30 13:00 0.5 Ciro&Cond Fill pipe end CBU from 2660'Hole unloaded with 100160 increase in cuttings®BUS. 13:00 13:30 0.5 Wiper Trip Continue TIH from 2660'.Load sweep i n pipe and wash last stand to bottom and en coutered 4'of fill. Drill f/3507 to 3877(370)AROP=82 fph 1330 18:00 4.5 Drilling 10-113K WOB,80 TD RPM,163 Mtr RPM 481 GPM,1922 SPP,Diff 100 PSI,10.4 MW,64 Via,PU 92K,SO 52 K.Rot 60K On Btm TO 10K,OR Btm TO 6.8K. Drill f/3872'to 4317'(445)AROP=74 fph 18:00 0:00 60 Drilling 10-16KWOB,69 TO RPM,163 Mtr RPM 482 GPM,2000 SPP,Di R 220 PSI,10.4 MW,61 Vis,PU 94K 50 54 K,Rot 62K,On Ban TO 11K Off Ban TO 6.8K. Continue to seep hole every 250 drilled,average 100%cuttings back on first sweep and 150%on second sweep. Dell 0 4317'to 4695(378')AROP=84 fp h 0:00 4:30 4.5 Drilling 10-18K WOB,70180 TD RPM,163 Mtr RPM 482 GPM,2000 SPP,Di R 220 PSI.10.4 MW,61 Vis,PU 96K,SO 54K,Rot 64K,On Ban TO 11K,Off Ban TQ 7.4K. .46 slide hrs,10.2 rotate h rs.Currently.33'above the line and 3.1'left of the line. 4:30 600 1.5 Lost Circ Lost all returns,Pull stands to 4550'filling back&de,Work pipe and continue filling from kill line.Build and pomp 30 Ws,40 PPB safecarb, mix 2 medium LCM pill. 270 bbls hauled to disposal,Paxton 7 total 2700 bbl s. TOTAL 24.00 LITHOLOGY: Tuffaceous&Ketone,tuff claystone,sand MAX GAS 718 B.G.GAS 159 CON GAS TRIP GAS 72 Accidents Pollution No pollution Plan Next 24 Hr Report Attach Control loss circulation. MUD RECORD CASING RECO RD PUMP 11.18 BPM TYPE Kia Sheild DATA 470 GPM SIZE GRADE WT CONN DEPTH DV ID NUMBER 1 2 TIME 22:00 16 X-56 109 Weld 139 15 MAKE TSM TSM DEPTH 4195 9-5/8 L-80 40 BTC 1936 7525 8.835 MODEL 1000 1000 TEMP 87 STROKE 9 9 WEIGHT 10.40 LINER SZ 550 5.50 VISC 62.0 SPM 104 74 PV 22.0 TOP OF LINER 5/ GAL/STK 2.64 2.64 YP 27 BIT NO. 2 SUR PSI 2000 2000 GELS 7 BHA# SIZE 8.5 API Wil 4.8 2 MFG. HOBS SLOW PUMP DATA @ 4500 HTHP 98 DESCRIPTION OD ID FEET TYPE PDCMM6SM Pump# PSI 1 PSI2 PSI3 Eff% CAKE 1 "DC BIT,6X12 JETS 8.5 2.25 06 SERIAL NO. 12474819 1 303 95 SOLIDS 11 IUD MOTOR 1.5 DE,8.312 4.952 2633 NOZZLES 60122 244 95 ADJSOL FLOAT SUB 6.58 2.75 2.14 TFA 0.683 SPM for PSI 1/2/3 42 32 OIL% 2 INTREGAL BLADE 8.312 2.5 7.69 DEPTH OUT 4695 DRILL STRING CAPACITY WTR% 87 DM COLLAR 6.75 3.125 9.2 DEPTH IN 1945 STROKES 1250 5D% 0.1 DGR COLLAR 6.75 1.92 6.42 TOTAL FT. 2750 MBT 8 EWR-P4 COLLAR 8.75 2 1204 HOURS 20.8 POM HCIM COLLAR 6.75 1.92 6.85 AVG ROP 80 pH 10.5 ALD COLLAR/STAB 8.25 1.92 18.26 WOB 8-158 Pm 3 CTN COLLAR 6.75 1.905 11.85 ANN VEL 247.4 DEPTH 4695 PF/MF 4/10 TM HOC COLLAR 69 3.25 10.04 ROT.RPM 163 TORQUE 11400 Clmud NM FC 8.59 2.5 30.97 AV DP CSG 816.1 PICKUP 96000 Clwa NM FC 8.7 2.5 30.83 AV DP OP HL 819.1 ROTATIONAL 64000 Cal 49000 4 JTS 5"HWDP 5 3 121.73 AV DC 427.4 SLACK OFF 54000 LIME ORS W./BUMPER SL 8.22 2.25 30.33 TOT CUM HR 20.8 %LGS 3.5 11 JTS 5"HWDP 5 3 333.83 GAUGE JAR HOURS 40.36 ES INNER MUD MOTOR HRS 40.36 OUTER LOCATION RP DULL CHAR. CUM HR BHA 40.36 LIQ MUD TOTAL LENGTH(FT) 657.41 HYDRAULICS FUEL 6783 GAL ADD(DIESELGAL) TOT WEIGHT(LB5) 43080 DEPTH 4695 FT CREW BOAT FUEL GAL SOLIDS EQUIPMENT NOZ.AREA .6827 IN' POT.WATER GAL SHAKER 01 100/100/1 DRK2 d Pb 4559173 PSI TUG FUEL GAL SHAKER#2 120/120/1 BRDT HHS HHP BIT 457.4098 HP BARITE SKS DERRICK#1 DRKS HRS H.S.I. 8.084877 HP/IN' FUEL USED 1253 GAL MUD CLEAN CENT 6.5 HRS JET VEL 2266454 FT/SEC HEAVY H2O GAL BOP TESTED PERSONN EL ON BOARD IMP FORCE WEATHER Misc 10/01/2014 HEC 2 %Pb WIND 4 MPH DAILY CUM NEXT TEST DUE RIG 16 BOATS SEAS 50 TEMP MUD $18,353 555,546 10/1512014 SERVICE 19 MN PRES CONO Partly Cloudy DIESEL FUNC.DUE TOTAL 37 MN FORECAST Partly Cloudy TOTAL $55.546 10/15/2014 MN www.wellez.com WellEz Information Management LLC ver 050514bf . a ii_ Hilcorp Energy Company AILY DRILLING REPORT 1111/ REPORT NO. LEASE WELL NO. COUNTY/PARISH WELL STATE DATE 14 ADL384372 8 Private Paxton 7 Kenai Peninsula Burough NINU Paxton 7 AK 10/512014 RIG AFE NO. AFE BUDGET DAILY COST CDC RIG PHONE Saxon Rig*147 1412365D 4564878 $159,871 $1,799,625 907-283-1365 ACTIVITY TYPE: DRLG Drilling Stuck Stuck Pipe DEPTH:MD/ND PROGRESS/HRS PROP.TD AST SHOE TEST PPG DAYS SINCE SPUD APE DAYS FIELD SUPERVISOR ENGINEER 4695 2193 7098 10/2/2014 12 10 14 Lott/Yessak Luke Keller ACTIVITYSUMMARYAT: 06:00 HRS SURVEY: MO ANGLE AZIMUTH TVD SECTION N/S E/W DOGLEG Wre line,run free point tools. 4595.38 72.8 357.39 2163.96 354285 -14926 3545.99 0.09 TIME LOG ELAPSED ACTIVITY COMMENTS FROM TO TIME 6.00 17'30 11.5 Lost Circ Loss circulation @ 4695'.Pulled 3 stands above suspected lost zone to 4543'Pump 30 bbls,40 PPB safecarb,ma 2 medium LCM pill pumping 2 bpm 233 psi. Rotate and reciprocate pipe slowly while attempting to establish circulation©4543'. Wash out of hole to 4000'pumping 2 bpm with 300 psi and intermrent returns @ 1/4 BPM. Park©3900.Rotate 60 rpm,reciprocate pipe slowly.Pump 84 bbls 100 ppb fine safe cart LCM pill.Load LCM in Annulus @ 1 bpm staging up to 2-3 bpm attempting to establish circulation. Pump 2nd 80 bbls/100 ppb LCM pill same way with same results.Lost rotator and reciprocation. 17:30 2030 3.0 Stuck Pipe Attempt to free stuck pipe @ 3915'.Jar On,work torque do drill string with no movement.Up jar 7 times with no movement Continue do jarring and working torque do drill string. 20:30 23:00 2.5 Stuck Pipe Mobilize E-Line and fishing tools,Continue to jar down and work torque down string,attempt to free pipe. 23:00 430 5.5 Stuck PiPollard Wt-on location,PJSM,load tools to rig floor,Hang sheave in derrick.Break off single,underbalanced,DP flowing back,Make single Pe backup,pump 15 bbl 11 ppg pill. Continues to flowback,Monitor DP pressure,build to 150 psi in 20 minutes,Make and pump 60 bbl 11 ppg pill,pump©2 bpm,120 psi, enough to displace DP.Break out single,DP state,no flow. 4:30 8'00 1.5 Stuck Pipe M/U pump In sub,centralizer,free point,centralizer,slack jar,CCL 3 weight bars,test tools,Park DP @ 67K nuetral wt RIH with free point tools to 1506',pump in the hole from that point, Pumping 1 bpm,60 psi increasing to 4 bpm at 460 psi,unable to get down further.POH for plug cup. 0 bbls hauled to disposal,Paxton 7 total 2700 blots. TOTAL 24.00 LITHOLOGY: Tuffaceous slltstone,tuff claystone,sand MAX GAS 684 B.G.GAS 233 CON GAS TRIP GAS Accidents Pollution No pollution Plan Neat 24 Hr Report Attach Perform backoff operations,MN fishing BHA. MUD RECORD CASING RECORD PUMP BPM TYPE Kle Sheild DATA GPM SIZE GRADE WT CONN DEPTH DV ID NUMBER 1 2 TIME 21:00 16 XS6 109 Weld 139 15 MAKE TSM TSM DEPTH 4695 9-5/8 L-80 40 BTC 1936 75.25 8.835 MODEL 1000 1000 TEMP 58 STROKE 9 9 WEIGHT 8.90 LINER SZ 5.50 5.50 VISC 38.0 SPM PV 1.0 TOP OF LINER @ GAL/STK 2.64 264 YP 8 BIT NO. 2 SUR PSI GELS 2 BHA# SIZE 8.5 API WL 10 2 MFG. HDBS SLOW PUMP DATA @ 4500 HTHP DESCRIPTION OD ID FEET TYPE PDC MM65M Pump* PSI 1 PSI 2 PSI 3 Eft CAKE 1 'DC BIT,6X12 JETS 8.5 225 0.9 SERIAL NO. 12474819 1 95 SOLIDS 4 IUD MOTOR 1.5 DE(8.312 4.952 26.33 NOZZLES 6 X 12 2 95 ADJSOL FLOAT SUB 6.58 2.75 2.14 TFA 0663 SPM for PSI 1/2/3 303 244 OIL% INTREGAL BLADE 8.312 2.5 7.69 DEPTH OUT 4695 DRILL STRING CAPACITY VVIR% 96 DM COLLAR 6.75 3.125 92 DEPTH IN 1945 STROKES SD% DGR COLLAR 6.75 1.92 6.42 TOTAL FT. 2750 MBT 4 EVA-P4 COLLAR 6.75 2 12.04 HOURS 20.8 POM HCIM COLLAR 6.75 1.92 6.85 AVG ROP pH 10 ALD COLLAR/STAB 8.25 1.92 16.26 WOB Pm 0.8 CTN COLLAR 6.75 1.905 11.85 ANN VEL 247.4 DEPTH 4695 PF/MF 12 TM HOC COLLAR 6.9 3.25 10.04 ROT.RPM TORQUE Clmud NM FC 6.59 2.5 30.97 AUDI.COG PICK UP Clwtr NM FC 6.7 2.5 30.83 AV DP OP HL ROTATIONAL Cal 11000 4 JTS 5"HWDP 5 3 121.73 AV OC 427.4 SLACK OFF LIME (RSW/BUMPER SL 6.22 2.25 30.33 TOT CUM HR 20.8 %LGS 3.1 11 JTS 5"HVVDP 5 3 333.83 GAUGE JAR HOURS 40.36 ES INNER MUD MOTOR HRS OUTER LOCATION RP DULL CHAR. CUM HR BHA 40.36 LIQ MUD TOTAL LENGTH(FT) 657.41 HYDRAULICS FUEL 5450 GAL ADD(DIESELGAL) TOT WEIGHT(LBS) 43080 DEPTH 4695 FT CREW BOAT FUEL GAL SOLIDS EQUIPMENT NOZ.AREA .6627 IN' POT.WATER GAL SHAKER#1 100/100/1 DRK2 dPb PSI TUG FUEL GAL SHAKER#2 120/120/1 BRDT HRS HI-IP BIT HP BARITE SKS DERRICK*1 DRKS #80 H.S.I. HP/IM FUEL USED 1333 GAL MUD CLEAN CENT HRS JET VEL FT/SEC HEAVY H2O GAL BOP TESTED PERSONNEL ON BOARD IMP FORCE WEATHER Misc 10/01/2014 HEC 2 %Pb WIND 7 MPH DAILY CUM NEXT TEST DUE RIG 16 BOATS SEAS 42 TEMP MUD $56,769 $112,314 10/15/2014 SERVICE 19 MN PRES CORD Light rain DIESEL FUNC.DUE TOTAL 37 MN FORECAST PC TOTAL $112,314 10/152014 MN wnw.wellez.corn WellEz Information Management LLC ver 050514bf • GHilcorp Energy Company AILY DRILLING REPORT • REPORT NO. LEASE WELL NO. COUNTY/PARISH WELL STATE DATE 15 ADL384372 8 Pri vats Paxton 7 Kenai Peninsula Burough NINU Paxton 7 AK 10/6/2014 RIG AFE NO. AFE BUDGET DAILY COST CDC RIG PHONE Saxon Rig 3147 14123650 4564878 $116,843 31,916,468 907-283.1365 ACTIVITY TYPE: DRLG Drilling Fishing Fishing DEPTH:MD/TVD PROGRESS I HRS PROP.TO AST SHOE TEST PPG DAYS SINCE SPUD PEE DAYS FIELD SUPERVISOR ENGINEER 4695 2193 7098 10/2/2014 12 11 15 Lott/Yessak Luke Keller ACTIVITY SUMMARY AT: 06.00 HRS SURVEY: MD ANGLE AZIMUTH TVD SECTION N/S EIW DOGLEG MN string shot assembly. TIME LOG 5/00550 ACTIVITY COMMENTS FROM TO TIME E-Line could not pass 1506'with free point assembly.POH with E-Line tools 8:00 12:00 60 Stuck Pipe Reconfigure tool string with pump down swedge. RIH pumping 1-6 BPM.Eline could not get past 1900. TOH with Free Point tool string. Lay down Free Point assembly. PJSM with all personal. Rig up for Back off operations.RIH with E-Line to 200' 12'(%1 14:00 2.0 Stuck Pipe Trap and work 50%(13,000 ft/lbs)of MU TO down drill string.Stage u p to 75%of MU TO(19,000 ft/lbs) f bs)(3 R ounds)Drill string backed o estimated 2600.(1600 high.)Screw back into fish. 14:00 15:00 1.0 Stuck Pipe Rig down and move E-Line aside. 15:00 18:00 1.0 Stuck Pipe Circulate drill string volume to ensure no obstructions in drill string.3 BPM 280 psi. Apply and work max TD torque down Drill string to backed off connection. 1600 19.00 30 Stuck Pipe RU E-ine tools,bad shot and RIH 5001 T rap and work 50%(12000 fibs)of MU TO down drill string with 21/2 rounds. RIH with String ShoUCCL tool string.Had to pump E-Line tools down @ 2-7 BPM.Set down on Flex Collar @ 3746'1ALM. Log CCL and locate HWDP above and below Jars.Park @ 3680'CCL,placing the string shot in the center of the HWDP connecbnon 2 jts below the jars @ 3684'. Fire Shot with good indication of detonation POOH with E-Line to 200'.Work pipe multiple times with no indication of Back of.Still holding 50%M U TO.Increase TO to 60%(1500 0 fibs))Work pipe multiple times with no back off 19:00 22:00 3.0 Stuck Pipe Release TO.Break off E-Line Lubricator.Reload String shot RIH with String shpt to 500'.Apply 65%MU TO(18250 ft/lbs).Work TO down string.RIH with string shot to 1500' Pump string shot 2-7 bpm tagging flex collar @ 3746'WLM,log CCL and park @ 3680'between jar and flex collar @ HWDP tool jt.Fire string shotGood i ndication shot fired. POH 500 with E-line,work torque downhole multiple times with no backoff. 2200 0:00 2.0 Stick Pipe PGH.Release T0.Break off E-Line Lubricator,swivel and pump in sub.MN opdrive,slackof o make sure jar was in closed position,it was In open position,close jars,pull 220k o fire jars. Make 3 attem ps before jars would fire set down to 30k string wt,Close jars.M/U swivel assembly adding floor valve et bottom. 000 1:00 1.0 Stuck Pipe MN to drill string,giving enough room slacking off o allow jars to remain dosed while applying and working torque.MN lubricator and new string shot.RI H to 1000' h W 3:30 2.5 Stuck Pipe Trap and work 60%left hand torque downhole(15000 Nibs)park pipe @ 35k.Pump string shot 2-7 bpm to 3748'WLM @ flex collar.Lc-. CCL and perk 66 3619'®Bottom of jar and top of HWDP. Fire string shot.good indication shot fired.Work pipe several times to 120k end down to 25k with no change in torque and no backoff. 3'30 6:011 25 Stuck Pipe POH with e-line to 5001 release torque.R/O lubricator,swivel,pump in sub and floor valve.MN top drive and function jars.Free point calculation®2823'.jars are firing®3619' Consult with town.decision made to backoff above jars at previous backoff point @ estimated 2550'.MN string shot assembly. 0 oohs hauled to disposal,Paxton 7 total 2700 oohs. TOTAL 24.00 LITHOLOGY: Tuffaceous siltstone,tuft claystone.sand MAX GAS B.G.GAS CON GAS TRIP GAS Accidents Pollution No pollution Plan Next24 Hr Report Attach RIH with string shot assembly,backoff pipe. MUD RECORD CASING RECORD PUMP BPM TYPE KIa Sheild DATA GPM SIZE GRADE WT CONN DEPTH DV ID NUMBER 1 2 TIME 20:00 18 X-56 109 Weld 139 15 MAKE TSM TSM DEPTH 4695 55/8 L-80 40 BTC 1938 75.25 8535 MODEL 1000 1000 TEMP 61 STROKE 9 9 WEIGHT 9.50 LINER SZ 5.50 5.50 VISC 40.0 SPM PV 10.0 TOP OF LINER @ GAUSTK 264 284 YP 18 BIT NO. 2 SUR PSI GELS 3 BHAH SIZE 8.5 APIA/ 7.4 2 MFG. HOBS SLOW PUMP DATA® HTHP DESCRIPTION OD ID FEET TYPE PDCMM85M Pump PSI1 P512 PSI 3 Ef% CAKE 1 'DC BIT,6X12 JET: 8.5 2.25 0.9 SERIAL NO. 12474819 1 95 SOLIDS 6 IUD MOTOR 1.5 DE,8.312 4.952 26.33 NOZZLES 8 X 12 2 95 ADJSOL FLOAT SUB 8.58 2.75 2.14 TFA 0.663 &PMfer P811rz13 OIL% 1 INTREGAL BLADE 8.312 2.5 7.69 DEPTH OUT 4695 DRILL STRING CAPACITY WTR% 94 DM COLLAR 6.75 3.125 9.2 DEPTH IN 1945 STROKES SO% DGR COLLAR 6.75 1.92 8.42 TOTAL FT. 2750 MBT 4 EWR-P4 COLLAR 6.75 2 12.04 HOURS 20.8 POM HCIM COLLAR 8.75 1.92 8.85 AVG ROP pH 9.7 ALD COLLAR/STAB 825 1.92 18.26 WDB Pm 1.25 CTN COLLAR 8.75 1.905 11.85 ANN VEL 247.4 DEPTH 4695 PF/MF 1/2 TM HOC COLLAR 6.9 3.25 10.04 ROT.RPM TORQUE Clmud NM FC 6.59 2.5 30.97 AV DP CSG PICK UP Clwtr NM FC 8.7 25 3083 AV DP OP HL ROTATIONAL Cal 20000 4JTS5"HWDP 5 3 121.73 AV DC 427.4 SLACK OFF LIME rRS WI BUMPER SL 8.22 225 30.33 TOT CUM HR 20.8 %LGS 1.7 11 JTS 5"HWDP 5 3 333.83 GAUGE JAR HOURS 40 10 ES INNER MUD MOTOR NRS OUTER LOCATION RP DULL CHAR. CUM HR BHA 40.36 LIO MUD TOTAL LENGTH(FT) 657.41 HYDRAULICS FUEL 4898 GAL ADD(DIESELGAL) TOT WEIGHT(LBS) 43080 DEPTH 4895 FT CREW BOAT FUEL GAL SOLIDS EQUIPMENT NOZ.AREA .6827 IN' POT.WATER GAL SHAKER 51 150/100/1 DRK 2 d Pb PSI TUG FUEL GAL SHAKER 52 120/120/1 BRDT HRS HHP BIT HP BARITE SKS • DERRICK 01 DRKS HRS H.S.I. HPSN' FUEL USED 552 GAL MUD CLEAN CENT HRS JET VEL FT/SEC HEAVY H2O GAL BOP TESTED PERSONS EL ON BOARD IMP FORCE WEATHER Miec 10/01/2014 HEC 2 %Pb WIND4 MPH DAILY CUM NEXT TEST DUE RIG 16 BOATS SEAS 44 TEMP MUD $13,741 3127,422 10/15/2014 SERVICE 19 MN PRES cOND Clew DIESEL FUNC.DUE TOTAL 37 MN FORECAST Clear TOTAL 3127,422 10/15/2014 MN www.wellez.com WellEz Information Management LLC ver 050514bf Hilcorp Energy Company II WAILY DRILLING REPORT IP REPORT NO. LEASE WELL NO. COUNTY/PARISH WELL STATE DATE 16 ADL384372 8 Private Paxton 7 Kenai Peninsula Burough NINU Paxton 7 AK 10/72014 RIG AFE NO. APE BUDGET DAILY COST CDC RIG PHONE Saxon Rig 6 147 14123650 4564878 5190,559 52,107,028 907-283-1365 ACTIVITY TYPE: DRLG Drilling Stuck Stuck Pipe DEPTH:MD/TVD PROGRESS/HRS PROP.TO AST SHOE TEST PPG DAYS SINCE SPUD APE DAYS FIELD SUPERVISOR ENGINEER 4695 2193 7098 102/2014 12 12 18 Lott/Yessak Luke Keller ACTIVITY SUMMARY AT: 06:00 HRS SURVEY: MD ANGLE AZIMUTH TVD SECTION N/S E/W DOGLEG Continue with backoff operations. TIME LOG ELAPSED ACTIVITY COMMENTS FROM TO TIME 8 O0 15:30 9.5 Stick Pipe Consulted with town,decision made to backoff above jars at previous backolf point©estimated 2550.MN sbing shot asserr6ly.RIH to 1000 Apply left hand torque to drill stung.Stage torque up from 50%to 75%MU Torque.(13,000-19.500( RIH with E-Line Sting Shot/CCL tool string.Pump E-Line tools down drill sting staging pump up to 9 BPM w/1300 psi. Regained circulator while pumping E-Line tools down doll string. POOH and park(5 200'with E-Line.Circulate well CS S8 bpm.Getting 10.4 ppg mud back.Circulate 9.3 ppg in/out staging pump up to 10 bpm and back down to 5 bpm.Losing 60 BPH while pump 5 B PM. Shut down pump and rig down E-Line lubricator and swivel.Screw into single above rotary. Work and attempt free pipe.Attemptto establish rotation.Losses 6)60 BPH while pumping 5 BPM. Pump and spot Lo Torqe Pill in annulus around 8HA.Soak Pill while working pipe.Hold 25,000 RH TO while working pipe.Attempt to establish rotation. Break circulation periodically while soaking Lube pill and working pipe.(1 1/2 hrs)Bring pumps beck on line®108PM working pipe and attempting to jar down with no sucess. Down jars not firing.Stacking entire string and 10K of TD weight,Did see slight travel of bumper sub fa 80K PN weight 15:30 1730 20 Stuck Pipe Startsging up on string K 190staginge p to 180K over string weight.Did get movment while jarring up t$280K Moved pipe up hole 2 ft with 66 jar 17:30 1830 1.0 Stuck Pipe poet jarring derrick inspection.Crew change and PJSM on jarring ops. 10:30 20:30 2.0 Stick Pipe Startjaring up on string staging up to 180K over string weight@ 280K No movement with 25 jar hits ranging from 100K-190K over.Pumping 5 bpm with 80 bph loss rate. Every 5 hits let jars cool for 5 minutes then resume jarring.Total of 91 jar hits.Note:well flowing back,pump string volume with no gas 6) returns,well giving fluid back 23 bph. 20 30 0:30 4.0 Stuck Pips R/U for backoft operations,M/U floor valve,swivel,string shot and pump in sub.RIH to 1000'.Apply left hand torque,Work torque downhole 120k p/u and 90 k 5/0.75%6)18000 ft/lbs. Park with 90k string wt well stpped giving fluid back,total 32 bots and remains static. Pump shot downhole 2-8 bpm to flex collars at 3746,Locate HWDP collar(5 3880,fire shot with good indication shot fired,work pipe between 120k p/u and 90k S/0 for 45 min.No backoft. POH with shot to 500',Release torque,R/D string shot,ludricator,swivel.pump in sub and floor valve, 0:30 4:00 3.5 Stuck Pipe MN top drive.Break circulation,good returns.Shut off pump.Apply left hand torque,work torque downhole,75%at 18000 ftflbs.Tool jt connection broke at saver sub.Set slips, VD single,inspect saver sub and top tool jt on drill pipe.adjust spring in grabber box.Inspect grabber box dies. 4:00 8:00 20 Stuck Pipe MN single and top drive.Break circulation,good returns.Shut off pump.Apply left hand torque,work torque downhole,75%at 18000 f/lbs. Increase left hand to 80%,20000 ft/lbs. Work torque downhole 90k S/O,120K PN,Park with torque trapped.Break circulation pumping 5 bpm to confirm returns. 180 bbls hauled to disposal,Paxton 7 total 2880 bots.Losses to well in last 24 hrs 788 Ms. Total losses at 3816 bola. TOTAL 24.00 LITHOLOGY: Tuffaceous sdtstone.tuff claystone,sand MAX GAS 8.0.GAS CON GAS TRIP GAS Accidents Pollution No pollution Plan Next 24 Hr Report Attach Backoff pipe.POH for fishing tools, MUD RECORD CASING RECORD PUMP BPM TYPE Kla Sheild DATA GPM SIZE GRADE WT CONN DEPTH DV ID NUMBER 1 2 TIME 2200 16 0-56 109 Weld 139 15 MAKE TOM TOM DEPTH 4895 9-5/8 L-80 40 BT0 1938 75.25 8.835 MODEL 1000 1000 TEMP 55 STROKE 9 9 WEIGHT 9.00 LINER SZ 5.50 5.50 VISC 41.0 SPM PV 90 TOP OF LINER® GAL/STK 284 2.64 YP 18 BIT NO. 2 SUR PSI GELS 3 BHA* SIZE 8.5 API WL 7A 2 MFG, HDBS SLOW PUMP DATA 6 HTHP DESCRIPTION OD ID FEET TYPE PDC MM65M Pump* PSI1 PSI2 PSI3 Eft% CAKE 1 'OC BIT,8X12 JET) 8.5 225 0.9 SERIAL NO. 124 7481 9 1 95 SOLIDS 4 IUD M0TOR 1.5 DE,8.312 4,952 28.33 NOZZLES 8X12 2 95 ADJSOL FLOAT SUB 8.58 2.75 214 TFA 0.883 SPM for PSI 1/2/3 OIL% 2 INTREGAL BLADE 8.312 25 769 DEPTH OUT 4885 DRILL STRING CAPACITY W TR% 94 DM COLLAR 6.75 3.125 9.2 DEPTH IN 1945 STROKES SD% DGR COLLAR 8.75 1.92 6.42 TOTAL FT. 2750 MBT 3 EWR-P4 COLLAR 8.75 2 1204 HOURS 20.8 POM HCIM COLLAR 8.75 1.92 6.85 AVG ROP pH 9.5 4W COLLAR/STAB 8.25 1.92 18.28 WOB Pm 1 CTN COLLAR 8.75 1.905 11.85 ANN VEL 247.4 DEPTH 4695 PF/MF 1/2 TM HOC COLLAR 8.9 325 10.04 ROT.RPM TORQUE Clmud NM FC 6.59 2.5 30.97 AV DP CSG PICKUP Clwtr NM FC 8.7 2.5 30.83 AV DP OP HL ROTATIONAL Cal 18000 4JTS 5"HWDP 5 3 121.73 AV DC 427.4 SLACK OFF LIME mRSW/BUMPER SL 6.22 2.25 30.33 TOT CUM HR 20.8 %LGS 1.8 11 JTS 5"11WDP 5 3 333,83 GAUGE JAR HOURS 40 36 ES INNER MUD MOTOR HRS OUTER LOCATION RP DULL CHAR. CUM HR BHA 40.38 LIQ MUD TOTAL LENGTH(FT) 657,41 HYDRAULICS FUEL 7965 GAL ADD(DIESELGAL) TOT WEIGHT(LBS) 43090 DEPTH 4695 FT CREW BOAT FUEL GAL SOLIDS EQUIPMENT NOZ.AREA .6627 IN' POT.WATER GAL SHAKER MI 100/100/1 DRK2 d Pb PSI TUG FUEL GAL • SHAKER#2 120/120/1 BRDT NRS HHP BIT HP BARITE SKS DERRICK#1 DRKS NRS H.S.I. HP/IN. FUEL USED 937 GAL MUD CLEAN CENT HRS JET VEL FT/SEC HEAVY H2O GAL BOP TESTED PERSONNEL ON BOARD IMP FORCE WEATHER Miss 10/012014 HEC 2 %Pb WIND 6 MPH DAILY CUM NEXT TEST DUE RIG 16 BOATS SEAS 44 TEMP MUD 548,408 $175,830 10/15/2014 SERVICE 19 MN PRES GOND Clear DIESEL FDNC.DUE TOTAL 37 MN FORECAST Clear TOTAL 5175,830 10/152014 MN www,wellez.com WellEz Information Management LLC ver 050514bf • 4111CHilcorp Energy Company AILY DRILLING REPORT • REPORT NO. LEASE WELL NO. COUNTY/PARISH WELL STATE DATE 17 ADL384372 8 Private Paxton 7 Kenai Peninsula Burough NINU Paxton 7 AK 10/82014 RIG AFE NO. AFE BUDGET DAILY COST CDC RIG PHONE Saxon Rig#147 1412365D 4564878 5158,106 $2263,133 907-283-1365 ACTIVITY TYPE: DRLG Drilling Ashing Fishing DEPTH:MD/TVD PROGRESS/HRS PROP.TD AST SHOE TEST PPG DAYS SINCE SPUD AFE DAYS FIELD SUPERVISOR ENGINEER 4695 2193 7098 10/2/2014 12 13 17 Lott/Barber Luke Keller ACTIVITYSUMMARYAT: 08:00 HRS SURVEY: MD ANGLE AZIMUTH TVD SECTION N/S E/W DOGLEG TIH W/Fishing BHA TIME LOG ELAPSED ACTIVITY COMMENTS FROM TO TIME 8:00 10'00 4.0 Stuck Pipe PJSM,Continue with backoff operations. Apply left hand torque to drill string.Stage torque up from 50%to 75%MU Torque.(13,000-19,500)Park with 40K S/O WT. RIH with E-Line to top of Flex Collars. Log CCL and locate HWDP above the Jars.Park String shot in connection @ 3562'(1 jt above Jars). Fire Shot with good indication of detonation. Lost all left hand torque and gained 15K string wt Set slips and rotate 6 rounds to the left with rotary table to verify beck off. Break circulation and CBUx2 @ 14 BPM with 200 psi.No gas @ bottoms up.Decrease pump to 5 BPM and S/0 and tag TOF @ 3562' 10:00 11:00. 1.0 Fishing Operati POOH with and rig down E-Line. 11:00 1230 1.5 Circ 8 Cond MU TD.Circulate,Rotate and reciprocate pipe @ max rates to clean up hole.14 BPM 255 psi,TD RPM 120.Pump HI vis sweep to surface with 100%increase in cuttings at shaker.Mostly fines. Stand back 1 stand from 3562'to 3526'. 12:30 13:00 0.5 (drl)Misc MN TO,rotate and circulate @ 12 BPMm,230 psi. Perform Derrick inspection before tripping out of hole. 13:00 14:00 1.0 Fishing Opemti TOH from 3526'to 2700'. 14:00 14:30 0.5 Circ 8 Cond MU TD.Circulate,Rotate and reciprocate pipe @ max rates.14 BPM 255 psi,TD RPM 80. Pump Hi vis sweep to surface with 50-75%increase in cuttings at shaker.Pies of clay,fines. 14:30 15:30 1.0 Fishing Operat Continue to TOH from 2700'to 1300'(55 deg bend in casing) 15:30 16:00 0.5 Circ 8 Cond MU TO.Circulate,Rotate and reciprocate pipe @ max rates.14 BPM 175 psi,TD RPM 80. 16:00 17:00 1.0 TOH from 1300'to surface.Recovered 10 jts 5"HWDP,leaving 1 jt ontop ofjars @ 3562'. TOF=3562.' 17:00 20:00 3.0 Clean up rig floor.Lay out,strap and Tally Fishing BHA. 20:00 2200 20 (dri)Tnps MN fishing BHA.Screw in sub(cut lip),Circ sub(2750 psi burst),bumper sub,xo sub,(5)6'DC's,xo sub,and intensifiers.Fishing BHA= 82.26'. 22:00 23:00 1.0 (dri)Tripc TIH out of derrick F/187 T/483'MD.Break,clean and inspect all connections during trip in hole.Hole taking 1.5 BPH whale circulating cross top of hole. 23:00 0:30 1.5 Cut/Slip Drill Li]Cut and slip 90'drilling line. 0:30 4:00 3.5 (drl)Trips TIN F/483'-T/2446'MD out of derrick.Break,clean and inspect all connections. 4:00 6:00 2.0 (dn)Tnps Cont TIH F/2446'-T/3117'MD picking up 5"HWOP off catwalk.Drift and inspect.29k ft/lbs tq. TOTAL 24.00 LITHOLOGY: Tuffaceous siltstone,tuff claystone,sand MAX GAS B.G.GAS CON GAS TRIP GAS Accidents None Pollution None Plan Next 24 Hr Report Attach N/A Latch fish @ 3562'MD and jar free MUD RECORD CASING RECORD PUMP BPM • TYPE Kla Sheild DATA GPM SIZE GRADE WT CONN DEPTH DV ID NUMBER 1 2 TIME 21:00 16 X-56 109 Weld 139 15 MAKE TSM TSM DEPTH 4695 9-5/8 L-80 40 BTC 1936 75.25 8.835 MODEL 1000 1000 TEMP 56 STROKE 9 9 WEIGHT 9.W LINER SZ 5.50 5.50 VISC 48.0 SPM PV 10.0 TOP OF LINER @ GAUSTK 2.64 264 YP 19 BIT NO. 2 SUR PSI GELS 4 BHA# SIZE 8.6 PPI WL 7.5 2 MFG. HDBS SLOW PUMP DATA @ HTHP DESCRIPTION OD ID FEET TYPE PDC MM65M Pump# PSI 1 PSI 2 PSI 3 Eff% CAKE 1 'DC BIT,6X12 JET: 8.5 225 0.9 SERIAL NO. 12474819 1 95 SOLIDS 4 IUD MOTOR 1.5 DB 8.312 4.952 26.33 NOZZLES 6 X 12 2 95 ADJSOL FLOAT SUB 6.58 2.75 214 TFA 0.663 SPM for PSI 12/3 OIL% 2 INTREGAL BLADE 8.312 2.5 7.69 DEPTH OUT 4695 DRILL STRING CAPACITY WTR% 94 DM COLLAR 6.75 3.125 9.2 DEPTH IN 1945 STROKES SD% DGR COLLAR 8.75 1.92 6.42 TOTAL FT. 2750 MBT 3 EV4R-P4 COLLAR 6.75 2 1204 HOURS 20.8 POM HCIM COLLAR 6.75 1.92 6.85 AVG ROP pH 9.5 ALD COLLAR/STAB 8.25 1.92 16.26 WOB Pm 2.9 CTN COLLAR 8.75 1.905 11.85 ANN VEL 247.4 DEPTH 4695 PF/MF 2/5 TM HOC COLLAR 6.9 325 10.04 ROT.RPM TORQUE Clmud NM FC 6.59 2.5 30.97 AV DP CSG PICKUP Clwtr NM FC 6.7 2.5 30.83 AV DP OP HL ROTATIONAL Cal 24000 4 JTS 5"HWDP 5 3 121.73 AV DC 427.4 SLACK OFF LIME IRS W/BUMPER SL 6.22 2.25 30.33 TOT CUM HR 20.8 %LGS 1.4 11 JTS 5"MOP 5 3 333.83 GAUGE JAR HOURS 40.36 ES INNER MUD MOTOR HRS OUTER LOCATION RP DULL CHAR. CUM HR BHP 40.36 LIQ MUD TOTAL LENGTH(FT) 657.41 HYDRAULICS FUEL 7094 GAL ADD(DIESELGAL) TOT WEIGHT(LBS) 43080 DEPTH 4695 FT CREW BOAT FUEL GAL SOLIDS EQUIPMENT NOZ.AREA .6827 IN' POT.WATER GAL SHAKER#1 100/100/1 DRK2 dPb PSI TUG FUEL GAL SHAKER#2 120/120/1 BRDT HRS HHP BIT HP BARITE SKS DERRICK#1 DRKS HRS H.S.I. HP/IN' FUEL USED 871 GAL MUD CLEAN CENT HRS JET VEL FT/SEC HEAVY H2O GAL BOP TESTED PERSONNEL ON BOARD IMP FORCE WEATHER Misc 10/01/2014 HEC 2 %Pb WIND MPH DAILY CUM NEXT TEST DUE RIG 16 BOATS SEAS 27 1EM1 MUD $27,452 $203,283 10/15/2014 SERVICE 19 MN PRES COND Good DIESEL FUNC.DUE TOTAL 37 MN FORECAST Clear TOTAL $203,283 MN www.wellez.com WellEz Information Management LLC ver 050514b1 ilcolp Company • III �AILYHDRILLINGEnergy REPORT • REPORT NO. LEASE WELL NO. COUNTY/PARISH WELL STATE DATE 18 ADL384372 8 Private Paxton 7 Kenai Peninsula Burough NINU Paxton 7 AK 10/92014 RIG AFE NO. AFE BUDGET DAILY COST CDC RIG PHONE Saxon Rig#147 1412365D 4564878 5130,970 $2,394,103 907-283-1365 ACTIVITY TYPE: DRLG Drilling Fishing Fishing DEPTH:MD/TVD PROGRESS/HRS PROP.TD.AST SHOE TEST PPG DAYS SINCE SPUD AFE DAYS FIELD SUPERVISOR ENGINEER 4695 2193 7098 10/2/2014 14 18 Lott/Barber Luke Keller ACTIVITY SUMMARY AT: 0600 HRS SURVEY: MD ANGLE AZIMUTH TVD SECTION N/S E/W DOGLEG Fishing operations TIME LOG ELAPSED ACTIVITY COMMENTS FROM TO TIME 6:00 900 30 Fishing Opereti Continue TIH off catwalk w/MOP and DC's as per BHA detail.Wash down F/3500'@ 218 gpm,177 psi,no rotary.Reduced rate to 2 bpm and tagged TOF @ 3559'MD. Pumps on=78k dn,92k up.Pumps off=80k dn,100k up. 9.00 17:00 60 Fishing Opereti Engage TOP @ 3559'MD.Work to dn string(25k Nibs).Establish circulating through bit @ 80 gpm,85 psi. Increase rate 125 gpm,195 psi. Tried circulating @ 5 bpm,observed 60 BPH losses. Attempt to free fish jarring down.Maintain circulation throughout down jarring wah minimal losses @ 125 gpm,230 psi. 10-12 has per cycle then let jars cool.Continue same.No movement Bumper sub open @ 100k, 17:00 23:30 6.5 Fishing Operati Begin jarring up operations.Cock jars @ 60k dn,PN @ 285k,85 gpm,145 psi.No losses observed.No movement. 23'30 1:30 2.0 Fishing Opereti Spot 15 bbl lube pill around BHA.Continue jarring operations with pumps off.Circulate 2-3 bbls every 30 mins to ensure no packing off issues.No movement. i 1 30 600 4.5 Fishing Operati Crculate @ 572 gpm,1285 psi,28%.Attempted to charge formation and dump psi while working pipe to reduce differential sticking.No losses to formation. TOTAL 24.00 LITHOLOGY: Tuffaceous siastone,tuff cleystone,sand MAX GAS B.G.GAS CON GAS TRIP GAS Accidents Pollution N/A Plan Next 24 Hr Report Attach N/A Continue fishing to retrieve drilling assy MUD RECORD CASING RECORD PUMP BPM TYPE Kla Sheild DATA GPM SIZE GRADE WT CONN DEPTH DV ID NUMBER 1 2 TIME 21:00 16 X-56 109 Weld 139 15 MAKE TSM TOM DEPTH 4695 9-5/8 L-80 40 BTC 1936 7525 8.835 MODEL 1000 1000 TEMP 50 STROKE 9 9 WEIGHT 9.00 LINER SZ 5.50 5.50 VISC 44.0 SPM PV 7.0 TOP OF LINER @ GAUSTK 2.64 2.64 VP 18 BIT NO. 2 SUR PSI GELS 4 OHMS SIZE 8.5 API WL 6.6 2 MFG. HDBS SLOW PUMP DATA @ HTHP DESCRIPTION OD ID FEET TYPE PDC MM65M Pump# PSI 1 PSI 2 PSI 3 Eff% CAKE 1 PDC BIT,8X12 JET: 8.5 2.25 09 SERIAL NO. 12474819 1 95 SOLIDS 4 I UD MOTOR 1.5 DH 8.312 4952 26.33 NOZZLES 6 X 12 2 95 ADJSOL FLOAT SUB 6.58 2.75 2.14 TFA 0.663 SPM for PSI 1/2/3 OIL% 4 INTREGAL BLADE 8.312 2.5 769 DEPTH OUT 4695 DRILL STRING CAPACITY WTR% 92 DM COLLAR 6.75 3.125 9.2 DEPTH IN 1945 STROKES SD% DGR COLLAR 6.75 1.92 6.42 TOTAL FT. 2750 MBT 3 EVaR-P4 COLLAR 6.75 2 12.04 HOURS 20.8 POM HCIM COLLAR 6.75 1.92 6.85 AVG ROP pH 9.5 ALD COLLAR/STAB 8.25 1.92 16.26 WOB Pm 2.9 CTN COLLAR 6.75 1905 11.85 ANN VEL 247.4 DEPTH 4695 PF/MF 2/5 TM HOC COLLAR 6.9 3.25 10.04 ROT.RPM TORQUE Clmud NM FC 6.59 2.5 30.87 AV DP COG PICK UP Clwtr NM FC 6.7 2.5 3083 AV DP OP HL ROTATIONAL Cal 31000 4 JTS 5"HWDP 5 3 121.73 AV DC 427.4 SLACK OFF LIME IRB W/BUMPER SL 8.22 2.25 30.33 TOT CUM HR 20.8 %LGS 1.4 11 JTS 5"HWOP 5 3 333.83 GAUGE JAR HOURS 40.36 ES INNER MUD MOTOR HRS OUTER LOCATION RP DULL CHAR. CUM HR BHA 40.36 LIQ MUD TOTAL LENGTH(FT) 657.41 HYDRAULICS FUEL 10538 GAL ADD(DIESELGAL) TOT WEIGHT(LBS) 43080 DEPTH 4695 FT CREW BOAT FUEL GAL SOLIDS EQUIPMENT NOZ.AREA 6627 INC POT.WATER GAL SHAKER#1 100/100/1 DRK 2 d Pb PSI TUG FUEL GAL SHAKER#2 120/120/1 BRDT FIRS HHP BIT HP BARITE SKS DERRICK#1 DRKS FIRS H.S.I. HP/IM' FUEL USED 682 GAL MUD CLEAN CENT FIRS JET VEL FT/SEC HEAVY H2O GAL BOP TESTED PERSONNEL ON BOARD IMP FORCE WEATHER Misc 10/012014 HOC 2 %Pb WIND MPH DAILY CUM NEXT TEST DUE RIG 16 BOATS SEAS 36 TEMP MUD $11,194 $214,477 10/152014 SERVICE 19 MN PRES CONS Good DIESEL FUNC.DUE TOTAL 37 MN FORECAST Partly cloudy TOTAL $214,477 MN www.wellez.com WeIIEZ Information Management LLC ver 050514bf , Hilcorp Energy Company II 4 ALLY DRILLING REPORT ID REPORT NO. LEASE WELL NO. COUNTY/PARISH WELL STATE DATE 19 ADL384372 8 Private Paxton 7 Kenai Peninsula Borough NINU Parton 7 AK 10/10/2014 RIG PFE NO. AFE BUDGET DAILY COST CDC RIG PHONE Saxon Rig#147 1412365D 4564878 $145,640 $2,539,743 907-283-1365 ACTIVITY TYPE: DRLG Drilling TIH Tripping in Hole DEPTH:MD/TVD PROGRESS/HRS PROP.TD AST SHOE TEST PPG DAYS SINCE SPUD AFE DAYS FIELD SUPERVISOR ENGINEER 4695 2193 7098 10/2/2014 15 19 Lott/Barber Luke Keller ACTIVITYSUMMARYAT: 06:00 HRS SURVEY: MD ANGLE AZIMUTH TVD SECTION N/S E/W DOGLEG TIH wl cleanout assy TIME LOG ELAPSED ACTIVITY COMMENTS FROM TO TIME 6:00 7:00 1.0 Fishing Operas Continue jarring operations.285k up,30k dn,22k ft/lbs right hand tq,116 gpm,201 spp. 7:00 10:00 3.0 Fishing Operas R/U Pollard E-Line for backoff operations.UD single,P/U 15'pup,M/U swivel,side entry. 10:00 12:30 25 Fishing Operas Pump down E-Line @ 380 gym,680 spp to a depth of 3562'MD.Work left hand tq in string(19500 fl/lbs tq).Set off shot @ 1 it above jars. Lost all left hand tq.R/D E-Line. 12:30 13:00 0.5 Fishing Operas CBU @ 3562'MD.Pump @ 375 gpm,367 psi with no losses. 13:00 13:30 0.5 Fishing Operas Perform derrick inspection.No issues noted. 13:30 23:30 10.0 Fishing Operas TOH F/3562'MD laying down drill pipe and fishing BHA.Pulled clean,hole took proper displacement. 2330 0:00 0.5 Rig Service Rig service 0:00 6:00 6.0 (dd)Trips M/U deanout assy and TIH F/surface to 3220'MD.Worked through bridge at 2890'MD.No other issues TOTAL 24.00 LITHOLOGY: Tuffaceous sillstone,tug claystone,sand MAX GAS B.G.GAS CON GAS TRIP GAS Accidents None Pollution N/A Plan Nett 24 Hr Report Attach N/A CBU @ TOF.TOH laying down drill pipe MUD RECORD CASING RECORD PUMP BPM TYPE Kla Shedd DATA GPM SIZE GRADE WT CONN DEPTH DV ID NUMBER 1 2 TIME 0:00 16 X-56 109 Weld 139 15 MAKE TSM TSM DEPTH 4695 9-5/8 L-80 40 BTC 1936 75.25 8.835 MODEL 1000 1000 TEMP 50 STROKE 9 9 WEIGHT 9.00 LINER SZ 550 5.50 VISC 47.0 SPM PV 7.0 TOP OF LINER @ GAUSTK 264 264 YP 17 BIT NO. 2 SUR PSI GELS 4 BHA# SIZE 8.5 API WI 6.4 2 MFG. HDBS SLOW PUMP DATA @ HTHP DESCRIPTION OD ID FEET TYPE PDC MM65M Pump# PSI 1 PSI2 PSI 3 Eft% CAKE 1 PDC BIT,6X12 JET/ 8.5 2.25 0.9 SERIAL NO. 12474819 1 95 SOLIDS 4 IUD MOTOR 1.5 DEC 8.312 4.952 26.33 NOZZLES 6 X 12 2 95 ADJSOL FLOAT SUB 6.58 2.75 2.14 TFA 0.663 SPM for PSI 1/2/3 OIL% 3 INTREGAL BLADE 8.312 25 7.69 DEPTH OUT 4695 DRILL STRING CAPACITY WTR% 93 DM COLLAR 6.75 3.125 9.2 DEPTH IN 1945 STROKES SD% DGR COLLAR 6.75 1.92 6.42 TOTAL FT. 2750 MBT 3 EWR-P4 COLLAR 6.75 2 12.04 HOURS 20.8 POM HCIM COLLAR 6.75 1.92 6.85 AVG ROP pH 9.8 ALD COLLAR/STAB 8.25 1.92 16.26 VVOB Pm 2.9 CTN COLLAR 6.75 1.905 11.85 ANN VEL 247.4 DEPTH 3916 PF/MF 2/5 TM HOC COLLAR 6.9 3.25 10.04 ROT.RPM TORQUE Clmud NM FC 6.59 2.5 30.97 AV DP CSG PICKUP Clwtr NM FC 6.7 2.5 30.83 AV DP OP HL ROTATIONAL Cal 31000 4 JTS 5"HWDP 5 3 12173 AV DC 427.4 SLACK OFF LIME IRS W/BUMPER SL 6.22 2.25 30.33 TOT CUM HR 20.8 %LGS 1.4 11 JTS 5"HVWP 5 3 30.34 GAUGE JAR HOURS 51.84 ES INNER MUD MOTOR HRS OUTER LOCATION RP DULL CHAR. CUM HR BHA 51.84 LIQ MUD TOTAL LENGTH(FT) 353.92 HYDRAULICS FUEL 9570 GAL ADD(DIESELGAL) TOT WEIGHT(LBS) 43080 DEPTH 4695 FT CREW BOAT FUEL GAL SOLIDS EQUIPMENT NOZ.AREA .6627 IN. POT.WATER GAL SHAKER#1 100/100/1 DRK 2 d Pb PSI TUG FUEL GAL SHAKER#2 120/120/1 BRDT HRS HHP BIT HP BARITE SKS DERRICK#1 DRKS HRS H.S.I. HP/IM FUEL USED 968 GAL MUD CLEAN CENT HRS JET VEL FT/SEC HEAVY H2O GAL BOP TESTED PERSONNEL ON BOARD IMP FORCE WEATHER Misc 10/01/2014 HEC 2 %Pb VIAND MPH DAILY CUM NEXT TEST DUE RIG 16 BOATS SEAS 37 TEMP MUD $26,944 $241,421 10/15/2014 SERVICE 19 MN PRESCOND Snow/Wet DIESEL FUNC.DUE TOTAL 37 MN FORECAST Overcast TOTAL $241,421 MN www.wellez.com WellEz Information Management LLC ver 050514bf Hllcorp Energy Company .. itAILY DRILLING REPORT IP REPORT NO. LEASE WELL NO. COUNTY/PARISH WELL STATE DATE 20 ADL384372&Private Paxton 7 Kenai Peninsula Borough NINU Paxton 7 AK 10/11/2014 RIG PFE NO. AFE BUDGET DAILYCOST CDC RIG PHONE Saxon Rig#147 1412365D 4564878 $88,781 $2,628,524 907-283-1365 ACTIVITY TYPE: DRLG Drilling RunCsg RU/Run Csg DEPTH:MD/TVD PROGRESS/HRS PROP.TD AST SHOE TEST PPG DAYS SINCE SPUD AFE DAYS FIELD SUPERVISOR ENGINEER 4695 2193 7098 10/2/2014 16 20 Lott/Barber Luke Keller ACTIVITY SUMMARYAT: 06:00 HRS SURVEY: MD ANGLE AZIMUTH TVD SECTION N/S E/W DOG LEG Running 5.5"casing TIME LOG ELAPSED ACTIVITY COMMENTS FROM TO TIME 6:00 7:30 1.5 Wash&Ream Wash0'of fill.and ream down to F/2980'10 TOF @ 3562'MD.Pump @ 415 gpm,370 psi,80 rpm.Tagged top of fish with no rotary.Circulated out 1 7:30 9:00 1.5 Circ&Cond Circulate and condition hole.Pump @ 511 gpm,370 psi,80 rpm,7.5k tq. 9:00 13:30 4.5 (dd)Trips Flow check(static).Pump Dry job,drop drill pipe Wiper(mud dog)and TOH F/3562'to surface laying pipe and BHA Pulled clean.Hole took proper displacement. 13:30 15:30 2.0 (dd)Trips TIH With remaining pipe in derrick T/2440'MD. 15:30 20:00 4.5 (dd)Trips Flow check(static).Pump dry job,drop drill pipe wiper and TOH F/2440'-T/surface laying drill pipe and BHA.Hole took proper displacement. 20:00 22:00 2.0 (dd)RU/Run Cu Pull wear bushing,Dummy run hanger 20.47'RKB to load shoulder.Clean and clear rig floor 22:00 23:30 1.5 NU/ND BOPE PJSM,C/O upper pipe rams to 5.5". 23:30 1:00 1.5 Tstg BOP/WHII R/U test equipment.Test 5.5"upper pipe rams.250 low and 3500 high w/5 min hold on each.Test good.R/D test equipment. 1:00 1:30 0.5 Rig Service Service rig 1:30 3:30 2.0 (dri)RU/Run Cu RID devators,bails.R/U Whatherford casing equipment. 3:30 6:00 2.5 (dri)RU/Run Cu Run 5.5"CDC,P-110,17#casing as per detail T/1190'MD.Bekedock shoe track.Check floats(good).11.8k tq on connections. TOTAL 24.00 LITHOLOGY: Tuffaceous siltstanne,tuff claystone,sand MAX GAS B.G.GAS CON GAS TRIP GAS Accidents None Pollution N/A Plan Next 24 Hr Report Attach N/A Land 5.5"casing,cement same. MUD RECORD CASING RECORD PUMP BPM TYPE Kla Sheild DATA GPM SIZE GRADE WT CONN DEPTH DV ID NUMBER 1 2 TIME 0:00 16 X-56 109 Weld 139 15 MAKE TSM TSM DEPTH 3552 9-5/8 L-80 40 BTC 1936 75.25 8.835 MODEL 1000 1000 TEMP 52 STROKE 9 9 WEIGHT 9.00 LINER SZ 5.50 5.50 VISC 59.0 SPM PV 9.0 TOP OF LINER @ GAUSTK 264 2.64 YP 19 BIT NO. 2 SUR PSI GELS 7 BHA# SIZE 8.5 API NL 4.8 2 MFG. HDBS SLOW PUMP DATA @ HTHP DESCRIPTION OD ID FEET TYPE PDC MM65M Pump# PSI 1 PSI2 PSI 3 Eff% CAKE 1 PDC BIT,6X12 JETS 8.5 225 0.9 SERIAL NO. 12474819 1 95 SOLIDS 4 IUD MOTOR 1.5 DEI 8.312 4.952 26.33 NOZZLES 6 X 12 2 95 ADJSOL FLOAT SUB 6.58 2.75 2.14 TFA 0.663 SPM for PSI 1/2/3 OIL% 3 INTREGAL BLADE 8.312 2.5 7.69 DEPTH CUT 4695 DRILL STRING CAPACITY WTR% 93 DM COLLAR 6.75 3.125 9.2 DEPTH IN 1945 STRCKES SD% DGR COLLAR 6.75 1.92 6.42 TOTAL FT. 2750 MBT 3 EWR-P4 COLLAR 6.75 2 12.04 HOURS 20.8 POM HCIM COLLAR 6.75 1.92 6.85 AVG ROP pH 9.8 ALD COLLAR/STAB 8.25 1.92 16.26 NOB Pm 2.4 CTN COLLAR 6.75 1.905 11.85 ANN VEL 247.4 DEPTH 3916 PF/MF 2/5 TM HOC COLLAR 6.9 3.25 10.04 ROT.RPM TORQUE Clmud NM FC 6.59 2.5 30.97 AV DP CSG PICK UP Ckvtr NM FC 6.7 2.5 30.83 AV DP OP HL ROTATIONAL Cal 32000 4 JTS 5"HV/DP 5 3 121.73 AV DC 427.4 SLACK OFF LIME IRS W/BUMPER SL 6.22 2.25 30.33 TOT CUM HR 20.8 %LGS 1.8 11 JTS 5"MOP 5 3 30.34 GAUGE JAR HOURS 51.84 ES INNER MUD MOTOR HRS OUTER LOCATION RP DULL CHAR. CUM HR BHA 51.84 LIQ MUD TOTAL LENGTH(FT) 353.92 HYDRAUUCS FUEL 8664 GAL ADD(DIESELGAL) TOTWEIGHT(LBS) 43080 DEPTH 4695 FT CREWBOAT FUEL GAL SOLIDS EQUIPMENT NOZAREA 6627 IN. POT.WATER GAL SHAKER#1 100/100/1 DRK 2 d Pb PSI TUG FUEL GAL SHAKER#2 120/120/1 BRDT HRS HHP BIT HP BARITE SKS DERRICK#1 DRKS HRS H.S.I. HP/IN' FUEL USED 906 GAL MUD CLEAN CENT ARS JET VEL FT/SEC HEAVY H2O GAL BOP TESTED PERSONNEL ON BOARD IMP FORCE WEATHER Misc 10/01/2014 HEC 2 %Pb 1MND MPH DAILY CUM NEXT TEST DUE RIG 16 BOATS SFAS 39 TEMP MUD $5,122 $246,543 10/15/2014 SERVICE 19 MN PRES GOND Wet DIESEL FUNC.DUE TOTAL 37 MN FORECAST Rain/Snow TOTAL $246,543 MN www.wellez.com WellEz Inbrmabon Management LLC vw 050514bf Hilcorp Energy Company "'DAILY DRILLING REPORT • REPORT NO. LEASE WELL NO. COUNTY/PARISH WELL STATE DATE 21 ADL384372 8 Private Paxton 7 Kenai Peninsula Burough NINU Pardon 7 AK 10/12/2014 RIG AFE NO. PEE BUDGET DAILYCOST CDC RIG PHONE Saxon Rig k 147 1412365D 4564878 $1,830,820 $4,483,343 907-283-1365 ACTIVITY TYPE: DRLG Ddfling NUBOPE NU BOPE DEPTH:MD/ND PROGRESS/HRS PROP.TD AST SHOE TEST PPG DAYS SINCE SPUD PRE DAYS FIELD SUPERVISOR ENGINEER 4695 2193 7098 1022010 17 21 Lott/Barber Luke Keller ACTIVITYSUMMARYAT: 06:00 HRS SURVEY: MD ANGLE AZIMUTH TVD SECTION N/S E/W DOGLEG Nipple up tbg spool and BOPE TIME LOG ELAPSED ACTIVITY COMMENTS CONTINUED ON SHEET 2 FROM TO TIME 6:00 8'00 20 (eenr)RU/Rrn(Continue to non 5.5"CDC,P-110,171 casing as per detail 1/11912 to 195T 8:00 8:30 0.5 Circ 8 Cond Circulate 1 hole volume just outside the shoe @ 1957'@ 325 gpm with 340 SPP. 8:30 10:30 2.0 (con)RU/Rin I Continue to run®Sing from 1957'to 3519'.Stepping to CBU @ 2450 and 3029. PU tag joint and wash down to 3562' 10:30 11:00 0.5 Circ 8 Cond Circulate and condition mud for cement job.Lower VP to 20Pumping @ 275 GPM with 435 SPP. 11:00 11:30 0.5 (com)RU/Rrn(Lay down tag joint.PU casing hanger.Land out casing hanger.Placing the shoe @ 3547,FC @ 3446'and the RA Marker @ 257T. Ran 5 12"171 P-110 CDC nag as follows: Float Shoe, 2 Shoe Jts(91 80'), Float Collar, 11:30 19 Joints, Marker Joint 67 Joints Casing Hanger Centralizer placed 10'above FS.10'above FC and one per/t to 2000 Tag bottom at 3562' Casing shoe landed at 3547 Top of FC at 3446' Details. Washed csg 6 3500 to 3562', Filled pipe and broke circulation every 500', CBU @ the shoe with 0 Units Max Gas, CBU from 3560'and had 0 Units Max Gas Did not encounter any hole problems from the Shoe to Bottom. Rig up Plug Drop Head and hard lines.Continue to circulate hole through bypass with ng pump. 1130 14:30 3.0 Cementing&V PJSM with Baker Hughes Cementers. 14:30 17:00 25 Ciro 8 Cond Perform cmt job as follows: Drop Um plug,pump 5 blots FW,load top plug Pressure test lines to 4500 psi,Pump 40 blots of spacer at 10 ppg. Mix and pump 576 sxs(120 bbls)of Bass G cement at 15.7 ppg.Drop top plug and displace amt w/80 blots of 8.6 ppg 6%KCl.Catch cement 30 blots into displacement. Bump plug with 500 psi(1350 psi)over final circulating pressure.Bleed off pressure with 12 bbl back.Floats held. Details:Full retums through out job.Pump Cement @ 4.3 BPM Average.Pump Displacement @ 4.4 BPM Avenge.Calculated Displacement 80.1 bbls,Actual Displacement 80 bbls.7 bbls spacer to surface. Final circulation pressure prior to bumping plug 426 psi at 2 bpm.CIP @ 16:40 hrs.Calculated TOC @ 755'. 17:00 18:00 1.0 Tstg BOP/WH/I Pressure Test 5 12'Casing to 3500 psi and chart for 30 min.Test good. 1500 19:00 1.0 Cementing 6 V WRab up and RID BJ cement equipment. 19:00 19:30 0.5 Install Wellheat Install 5.5"packoff as per Cameron 1930 2100 1.5 (0)RU/Run Ca RID Weatherford CRT,service loop,and associated equipment from floor. 2100 0:00 3.0 NU/ND BOPE Clear rig floor of all unneeded equipment.PJSM,Nipple down 11"stack.Remove both 17 spacer spools. 000 4:30 0.5 NU/ND ROPE Install tbg head and 17x7"GSA.Nipple up ROPE 4:30 5:00 0.5 TsgBOPMR71I Test reckon I/5k w/15 min hold. TOTAL 23.00 LITHOLOGY: Tuffaceous siltstone,tuff daystone.sand MAX GAS B.G.GAS CON GAS TRIP GAS Accidents Pollution N/A Plan Next 24 Hr Report Attach N/A Test upper rams.Scraper run MUD RECORD CASING RECORD PUMP BPM TYPE DATA GPM SIZE GRADE WT CONN DEPTH DV ID NUMBER 1 TIME 0.00 16 X-56 109 Weld 139 15 MAKE TSM TSM DEPTH 9-5/8 LA0 40 BTC 1936 7525 8635 MODEL 1000 1000 TEMP STROKE9 9 WEIGHT LINER SZ 5.50 5.50 VISC SPM PV TOP OF LINER @ GAUSTK 2.64 VP BIT NO. SUR PSI GELS BHA1 SIZE API NL MFG. SLOW PUMP DATA @ HTHP DESCRIPTION OD ID FEET TYPE Pump 1 PSI 1 PSI 2 PSI3 En% CAKE SERIAL NO. 1 SOLIDS NOZZLES 2 ADJSOL TFA SPM for PSI line OIL% DEPTH OUT DRILL STRING CAPACITY WTR% DEPTH IN STROKES SD% TOTAL FT. MBT HOURS POM AVG ROP pH WDB Pm ANN VEL DEPTH PF/MF ROT.RPM TORQUE Clmud AV DP CSG PICK UP Clwb AV DP OP HL ROTATIONAL Cal AV DC SLACK OFF LIME TOT CUM HR %LGS GAUGE JAR HOURS ES INNER MUD MOTOR HRS OUTER LOCATION RP DULL CHAR. CUM HR DHA LIQ MUD TOTAL LENGTH(FT) HYDRAULICS FUEL 8072 GAL ADD(DIESELGAL) TOT VVEIGHT(LBS) DEPTH 4695 FT CREWBOAT FUEL GAL SOLIDS EQUIPMENT NOZ AREA .6627 IN' POT.WATER GAL SHAKER 11 100/100/1 DRK 2 d Pb PSI TUG FUEL GAL SHAKER 12 120/120/1 BRDT HRS HHP BIT HP BARITE SKS DERRICK#1 DRKS Hos H.S.I. HP/IN' FUEL USED 592 GAL MUD CLEAN CENT HRS JET VEL FT/SEC HEAVY H2O GAL BOP TESTED PERSONNEL ON BOARD IMP FORCE WEATHER Misc 10/012014 HEC 2 %Pb WND Calm MPH DAILY CUM NEXT TEST DUE RIG 16 BOATS SEAS 43 T0.1P =MUD $1,950 $248,493 10/15/2014 SERVICE 19 MN PRER GOND Wet DIESEL FUNC.DUE TOTAL 37 MN FORECAST Rain TOTAL $248,493 MN www.wellez.wm WellEz Information Management LLC._. ver 050514bf Hilcorp Energy Company • eltAILY DRILLING REPORT 4111/ REPORT NO. LEASE WELL NO. COUNTY/PARISH WELL STATE DATE 22 ADL384372 8 Private Paxton 7 Kenai Peninsula Borough NINU Paxton 7 AK 10/13/2014 RIG AFE NO. PFE BUDGET DAILY COST CDC RIG PHONE Saxon Rig#147 1412365D 4564878 $112,873 $4,576,217 907-283-1365 ACTIVITY TYPE: Drill/Completing DEPTH:MD/TVD PROGRESS/HRS PROP.TD.AST SHOE TEST PPG DAYS SINCE SPUD A F E DAYS FIELD SUPERVISOR ENGINEER 4695 2193 7098 10/2/2014 18 22 Lott/Barber Luke Keller ACTIVITY SUMMARY AT: 06:00 HRS SURVEY: MD ANGLE AZIMUTH TVD SECTION N/S E/W DOGLEG RIH w/packer assy TIME LOG ELAPSED ACTIVITY COMMENTS FROM TO TIME 6,00 6:30 0.5 Install Wellhear Finish testing Packoff to 5000 psi.R/D landing joint. 6:30 10:30 4.0 NU/ND BOPE NU BOPE and associated equipment. 10:30 12:30 2.0 Tstg BOPNVH5 Rig up 2 7/8"pipe size test equipment.Test upper VBR,s to 250,3500 psi.RD test equipment.Install Wear Bushing. 12:30 16:00 3.5 (com)Miscellan Rig up handling tubing handling equipment.Lay out,strap and tally 2 7/8"tubing and scraper assembly.PJSM on running tubing. 16,00 20:30 4.5 (com)Trips PU Scraper for 5 1/2"casing.RIH picking up 2 7/8"tubing from catwalk T/2339'MD. 20:30 21:00 0.5 (com)Trips Work scraper F/2239'-T/2167'MD.22k up,21k dn,128 gpm,177 psi,4%'low.Circulated 1.5 BU. 21:00 23:00 2.0 (com)Trips Continue TIH F/2239'-T/3408'MD. 23:00 0:00 1.0 (com)Miscellan Took wt©3408'MD.Wash down from 3408'-T/3438'MD.Pump @ 123 gpm,224 psi,3%tow. 0:00 1:00 1.0 (com)Miscellan Circulate and condition brine.Displace to clean brine(8.7 ppg,6%KCL).Pump @ 161 gpm,377 psi,6%flow.Pumped a total of 110 bbls. 1:00 2:00 1.0 (com)Trips TOH F/3438'-T/2170'laying down tubing. 2:00 4:00 2.0 (com)Trips TOH standing back tubing F/2170 to surface.Laydown baker scraper assy.Remove wear bushing 4:00 4:30 0.5 Rig Repair Rig service 4:30 6:00 1.5 (com)Miscellan Laydown 1 std from derrick.Bring jewelry to rig floor for packer assy.PJSM,M/U packer assy. TOTAL 24.00 LITHOLOGY: Tuffaceous siltstone,tuff claystone,sand MAX GAS B.G.GAS CON GAS TRIP GAS Accidents None Pollution N/A Plan Next 24 Hr Report Attach N/A Run completion assy MUD RECORD CASING RECORD PUMP BPM TYPE Brine DATA GPM SIZE GRADE WT CONN DEPTH DV ID NUMBER 1 2 TIME 13:00 16 X-56 109 Weld 139 15 MAKE TSM TSM DEPTH 3542 9-5/8 L-80 40 BTC 1936 7525 8.835 MODEL 1000 1000 TEMP 48 STROKE 9 9 WEIGHT 8.70 LINER SZ 5.50 5.50 VISC 26.0 SPM PV TOP OF LINER @ GAL/STK 2.64 2.64 YP BIT NO. 2 SUR PSI GELS BHA# SIZE 8.5 API WL 2 MFG. HDBS SLOW PUMP DATA HTHP DESCRIPTION OD ID FEET TYPE PDC MM65M Pump# PSI 1 PSI 2 PSI 3 Eff% CAKE 'DC BIT,6X12 JET: 8.5 2.25 0.9 SERIAL NO. 124748191 95 SOLIDS IUD MOTOR 1.5 DE(8.312 4.952 26.33 NOZZLES 6 X 122 95 ADJSOL FLOAT SUB 6.58 2.75 2.14 TFA 0.663 SPM for PSI1/2/3 OIL% INTREGAL BLADE 8.312 2.5 769 DEPTH OUT 4695 DRILL STRING CAPACITY WfR% DM COLLAR 6.75 3.125 92 DEPTH IN 1945 STROKES SD% DGR COLLAR 6.75 1.92 6.42 TOTAL FT. 2750 MBT EWR-P4 COLLAR 6.75 2 12.04 HOURS 20.8 POM HCIM COLLAR 6.75 1.92 6.85 AVG ROP pH 9 ALD COLLAR/STAB 8.25 1.92 16.26 NOB Pm CTN COLLAR 6.75 1.905 11.85 ANN VEL 247.4 DEPTH 3916 PF/MF TM HOC COLLAR 6.9 3.25 10.04 ROT.RPM TORQUE Omud NM FC 6.59 2.5 30.97 AV DP CSG PICKUP Owtr NM FC 6.7 2.5 30.83 AV DP OP HLI ROTATIONAL Cal 32000 4 JTS 5"HWDP 5 3 121.73 AV DC 427.4 SLACK OFF LIME tRSW/BUMPER SL 6.22 2.25 30.33 TOT CUM HR 20.8 %LGS 11 JTS 5"HWDP 5 3 30.34 GAUGE JAR HOURS 51.84 ES INNER MUD MOTOR HRS OUTER LOCATION RP DULL CHAR. CUM HR BHA 51.84 LIQ MUD TOTAL LENGTH(FT) 353.92 HYDRAULICS FUEL 7019 GAL ADD(DIESELGAL) TOT WEIGHT(LBS) 43080 DEPTH 4695 FT CREW BOAT FUEL GAL SOLIDS EQUIPMENT NOZ.AREA .6627 IN' POT.WATER GAL SHAKER#1 100/100/1 DRK2 dPb PSI TUG FUEL GAL SHAKER#2 BRDT HRS HHP BIT HP BARITE SKS DERRICK#1 DRKS HRS H.S.I. HP/IN' FUEL USED 1053 GAL MUD CLEAN CENT HRS JET VEL FT/SEC HEAVY H2O GAL BOP TESTED PERSONNEL ON BOARD IMP FORCE WEATHER Misc 10/01/2014 HEC 2 %Pb WIND MPH DAILY CUM NEXT TEST DUE RIG 16 BOATS SEAS 41 TEMP MUD $1,354 $249,846 10/15/2014 SERVICE 19 MN PRESCOND Wet DIESEL FUNC.DUE TOTAL 37 MN FORECAST Overcast TOTAL $249,846 MN www.wellez.com WellEz Information Management LLC ver 050514bf IICHilcorp Energy Company AILY DRILLING REPORT • REPCRT NO. LEASE WELL NO. COUNTY/PARISH YELL STATE DATE 23 ADL384372&Private Paxton 7 Kenai Peninsula Borough NINU Parton 7 AK 10/14/2014 RIG APE NO. AFE BUDGET DAILY COST CDC RIG PHONE Saxon Rig*147 1412365D 4564878 $209,145 $4,785,362 907-283-1365 ACTIVITYTYPE: DRLG Drilling Mobe Mobe/Dernobe DEPTH:MD/TW PROGRESS/HRS PROP.TD AST SHOE TEST PPG DAYS SINCE SPUD PEE DAYS FIELD SUPERVISOR ENGINEER 4695 2193 7098 102/2014 19 23 Lott/Barber Luke Keller ACTIVITYSUMMARYAT: 06:00 HRS SURVEY: MD ANGLE AZIMUTH TVD SECTION N/S E/W DOGLEG RDMO TIME LOG ELAPSED ACTIVITY COMMENTS FROM TO TIME 6:00 9:00 3.0 (com)RU/Run(Mo packer assy as follows-mule shoe,pup,x nipple,pup,1 jt tbg,pup,44SA8L36X27 Packer,anchor(sealAatch),pup.and TIH T/2118' 9:00 12:00 3.0 (com)RU/Run(RN Pollard for control line.M/U pup,TE-5 SV,pup,pup,chemical injection sub,pup,3 jts tbg and hanger.Landout with hanger @ final set depth of 2265'@ shoe.Packer top @ 2182.56'MD. Test control lines TI 5,000 psi w/10 min hold(test good).Displaced 6%KCL w/Congor 303A prior to landing out in wellhead. 12:00 16:00 4.0 (cem)RU/Run(Drop ball and rod,pump down @ 1 bpm.Landout @ 1200 psi.Psi up to 5000 psi,set packer and attempt to test tbg.Psi kept bleeding off. Troubleshoot and determined it was surface equipment. Test annulus to 2,000 psi w/30 min hold(test good).Chart and record.R/D test equipment.Plan to test tbg once night cap is installed. 16:00 16:30 0.5 (com)Miscellan Instal BPV as per Cameron. 16:30 17:00 0.5 (drl)RU/Run Ce R/D power tongs,slips,elevators and xo's. 17:00 0:00 7.0 NU/ND ROPE NA)BOP equipment.Break down stack for upcoming rig move. 0:00 3:30 3.5 Install Wellhea<Instal production and master valve.Test void 5k w/15 min hold.Psi up sssv T/4200 psi.(900 psi to start opening and 2100 psi full open sssv in Baker hop). 3:30 6:00 2.5 Tstg BOPAMiA RN and test 2 7/8",L-80,6.5 ppf,8 rd EUE Test to 3500 psi wl 30 min hold.Chart and record same.R/D test equipment. TOTAL 24.00 LITHOLOGY: Tuffaceous sikstone,tuff daystone,sand MAX GAS B.G.GAS CON GAS TRIP GAS Accidents Pollution N/A Plan Ned 24 Hr Report Attach WA Rig move to Fats Creek#6 MUD RECORD CASING RECO RD PUMP BPM TYPE Brine DATA GPM SIZE GRADE Wf CONN DEPTH DV ID NUMBER 1 2 TIME 13:00 16 X-56 109 Weld 139 15 MAKE TSM TSM DEPTH 3542 9-5/8 L-80 40 BTC 1936 75.25 8.835 MODEL 1000 1000 TEMP 48 5-1/2 P-110 17 CDC 3542 72.14 4.892 STRCI(E 9 9 WEIGHT 8.70 LINER SZ 5.50 5.50 VISC 26.0 SPM PV TOP OF LINER@ GAUSTK 2.64 2.64 YP BIT NO. SUR PSI GELS BHA# SIZE API Ed. MFG. SLOW PUMP DATA @ HTHP DESCRPTION OD ID FEET TYPE Pump* PSI 1 PSI2 PSI3 Eff% CAKE SERIAL NO. 1 95 SOLIDS NOZZLES 2 95 ADJSOL TFA SPM for PSI 11213 OIL% DEPTH OUT DRILL STRING CAPACITY WIN% DEPTH IN STROKES SD% TOTAL FT. MBT HOURS POM AVG ROP pH 9 WOB Per ANN VEL DEPTH PF/MF ROT.RPM TORQUE Claud AV DP CSG PICKUP Clwtr AV DP OP HL ROTATIONAL Cal 320W AV DC SLACK OFF LIME TOT CUM HR %LGS GAUGE JAR HOURS ES INNER MUD MOTOR HRS OUTER LOCATION RP DULL CHAR. CUM HR BHA LIQ MUD TOTAL LENGTH(FT) HYDRALUCS FUEL 6709 GAL ADD(DIESELGAL) TOT WEIGHT(LBS) DEPTH 4695 FT CREW BOAT FUEL GAL SOLIDSEQUIPIENT NOZAREA .6627 thP POT.WATER GAL SHAKER#1 100/100/1 DRK2 d Pb PSI TUG FUEL GAL SHAKER#2 BRDT HRS HHP BIT HP BARITE SKS DERRICK#1 DRKS HRS H.S.I. HPAN' FUEL USED 310 GAL MUD CLEAN CENT HRS JET VEL FT/SEC HEAVY H2O GAL BOP TESTED PERSONNELON BOARD IMP FORCE WEATHER Misc 10/01/2014 HEC 2 %Pb WIND MPH DAILY CUM NEXT TEST DUE RIG 16 BOATS SEAS 32 TEMP MUD $1,354 $249,846 10/152014 SERVICE 19 MN PRES CORD Good DIESEL FUNC.DUE TOTAL 37 MN FORECAST Panty cloudy TOTAL $249,846 MN www.wellez.com WellEz Information Management LLC ver 050514bf • Hilcorp Energy Company • • �AILY DRILLING REPORT • REPORT NO. LEASE WELL NO. COUNTY/PARISH WELL STATE DATE 24 ADL384372 8 Private Paxton 7 Kenai Peninsula Burough NINU Paxton 7 AK 10/15/2014 RIG AFE NO. AFE BUDGET DAILY COST CDC RIG PHONE Saxon Rig#147 1412365D 4564878 $10,214 $4,795,577 907-283-1365 ACTIVITY TYPE: DRLG Drilling CstUp Cost Update DEPTH:MD/TVD PROGRESS/HRS PROP.TO.AST SHOE TEST PPG DAYS SINCE SPUD AFE DAYS FIELD SUPERVISOR ENGINEER 7098 10/2/2014 20 24 Lott/Barber Luke Keller ACTIVITY SUMMARY AT: 06:00 HRS SURVEY: MD ANGLE AZIMUTH TVD SECTION N/S E/W DOGLEG FINAL REPORT COST ONLY TIME LOG ELAPSED ACTIVITY COMMENTS FROM TO TIME FINAL REPORT COST ONLY TOTAL LITHOLOGY: MAX GAS B.G.GAS CON GAS TRIP GAS Accidents Pollution Plan Next 24 Hr Report Attach MUD RECORD CASING RECORD PUMP BPM TYPE Brine DATA GPM SIZE GRADE 1/VT CONN DEPTH DV ID NUMBER 1 2 TIME 13:00 /6 X-56 109 Weld 139 15 MAKE TSM TSM DEPTH 3542 9-5/8 L-80 40 BTC 1936 7525 8.835 MODEL 1000 1000 TEMP 48 5-1/2 P-110 17 CDC 3542 72.14 4.892 STROKE 9 9 WEIGHT 8.70 LINER SZ 5.50 5.50 VISC 26.0 SPM PV TOP OF LINER @ GAL/STK 2.64 2.64 VP BIT NO. SUR PSI GELS BHA# SIZE API/AL MFG. SLOW PUMP DATA @ HTHP DESCRIPTION OD ID FEET TYPE Pump# PSI 1 PSI2 PSI 3 Elf CAKE SERIAL NO. 1 95 SOLIDS NOZZLES 2 95 ADJSOL TFA SPM for PSI 1l2J3 OIL% DEPTH OUT DRILL STRING CAPACITY WTR% DEPTH IN STROKES SD% TOTAL FT. MBT HOURS POM AVG ROP pH 9 WOB Pm ANN VEL DEPTH PF/MF ROT.RPM TORQUE Omud AV DP CSG PICK UP Clwtr AV DP OP HLI ROTATIONAL Cal 32000 AV DC SLACK OFF LIME TOT CUM HR %LGS GAUGE JAR HOURS ES INNER MUD MOTOR HRS OUTER LOCATION RP DULL CHAR. CUM HR BHA LIQ MUD TOTAL LENGTH(FT) HYDRAULICS FUEL 6709 GAL PDD(DIESELGAL) TOT WEIGHT(LBS) DEPTH FT CREW BOAT FUEL GAL SOLIDS EQUIPMENT NOZ.AREA .6627 IM POT.WATER GAL SHAKER#1 100/100/1 DRK 2 d Pb PSI TUG FUEL GAL SHAKER#2 BRDT FIRS HHP BIT HP BARITE SKS DERRICK#1 DRKS HRS H.S.I. HP/IM FUEL USED GAL MUD CLEAN CENT MRS JET VEL FT/SEC HEAVY H2O GAL BOP TESTED PERSONNEL ON BOARD IMP FORCE WEATHER Misc 10/01/2014 HEC 2 %Pb WIND MPH DAILY CUM NEXT TEST DUE RIG 16 BOATS SEAS TEMP MUD $1,354 $249,846 10/15/2014 SERVICE 19 MN PRESCOND DIESEL FUNC.DUE TOTAL 37 MN FORECAST TOTAL $249,846 MN www.wellez.com WellEz Information Management LLC ver 050514b1 • Hilcorp Energy Company • AILY DRILLING REPORT REPORT NO. LEASE WELL NO. COUNTY/PARISH WELL STATE DATE 25 ADL384372&Private Paxton 7 Kenai Peninsula Borough NINU Paxton 7 AK 11/2/2014 RIG PFE NO. AFE BUDGET DAILY COST CDC RIG PHONE Saxon Rig#147 1412365D 4564878 610,214 $4,805,791 907-283-1365 ACTIVITY TYPE: DEPTH:MD/TVC PROGRESS/HRS PROP.TD AST SHOE TEST PPG DAYS SINCE SPUD AFE DAYS FIELD SUPERVISOR ENGINEER 7098 10/2/2014 38 42 Lott/Barber Luke Keller ACTIVITY SUMMARY AT: 06:00 HRS SURVEY: MD ANGLE AZIMUTH TVD SECTION N/S E/W DOGLEG TIME LOG ELAPSED ACTIVITY COMMENTS FROM TO TIME TOTAL LITHOLOGY: MAX GAS B.G.GAS CON GAS TRIP GAS Accidents Pollution Plan Next 24 Hr Report Attach MUD RECORD CASING RECORD PUMP BPM TYPE Brine DATA GPM SIZE GRADE WT CONN DEPTH DV ID NUMBER1 2 TIME 13:00 16 X-56 109 Weld 139 15 MAKE TSM TSM DEPTH 3542 9-5/8 L-80 40 BTC 1936 75.25 8.835 MODEL 1000 1000 TEMP 48 5-1/2 P-110 17 CDC 3542 72.14 4.892 STROKE 9 9 . WEIGHT 8.70 LINER SZ 5.50 5.50 VISC 26.0 SPM PV TOP OF LINER @ GAL/STK 2.64 2.64 YP BIT NO. SUR PSI GELS BHA# SIZE API IAL MFG. SLOW PUMP DATA @ HTHP DESCRIPTION OD ID FEET TYPE Pump# PSI 1 PSI2 PSI 3 ER CAKE SERIAL NO. 1 95 SOLIDS NOZZLES 2 95 ADJSOL TFA SPM for PSI 1/2/3 OIL% DEPTH OUT DRILL STRING CAPACITY WTR% DEPTH IN STROKES SD% TOTAL FT. MBT HOURS POM AVG ROP pH 9 VVOB Per ANN VEL DEPTH PF/MF ROT.RPM TORQUE Clmud AV DP CSG PICK UP Clwtr AV DP OP HLI ROTATIONAL Cal 32000 AV DC SLACK OFF LIME TOT CUM HR %LGS GAUGE JAR HOURS ES INNER MUD MOTOR HRS OUTER LOCATION RP DULL CHAR. CUM HR BHA LID MUD TOTAL LENGTH(FT) HYDRAULICS FUEL 6709 GAL ADD(DIESELGAL) TOT WEIGHT(LBS) DEPTH FT CREW BOAT FUEL GAL SOLIDS EQUIPMENT NOZ.AREA .6627 IN POT.VVATER GAL SHAKER#1 100/100/1 DRK 2 d Pb PSI TUG FUEL GAL SHAKER#2 BRDT HRS HHP BIT HP BARITE SKS DERRICK#1 DRKS HRS H.S.I. HP/IM FUEL USED GAL MUD CLEAN CENT HRS JET VEL FT/SEC HEAVY H2O GAL BOP TESTED PERSONNEL ON BOARD IMP FORCE WEATHER Misc 10/01/2014 HEC2 %Pb WIND MPH DAILY CUM NEXT TEST DUE RIG16 BOATS SEAS TEMP MUD $1,354 $249,846 10/15/2014 SERVICE19 MN PRES CORD DIESEL FUNC.DUE TOTAL 37 MN FORECAST TOTAL $249,846 MN www.wellez.com WellEz Information Management LLC ver 050514bf • i Hilcorp Energy Company Ninilchik Unit Paxton Paxton #7 501332064300 Sperry Drilling Definitive Survey Report 16 October, 2014 .,, �., . ... W .. HAlLLWBURTON >perry Drilling III Halliburton • Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Paxton#7 Project: Ninilchik Unit TVD Reference: As-Built @ 166.85usft Site: Paxton MD Reference: As-Built @ 166.85usft ' Well: Paxton#7 North Reference: True Wellbore: Paxton#7 Survey Calculation Method: Minimum Curvature ' Design: Paxton#7 Database: Sperry EDM-NORTH US+CANADA Project Ninilchik 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 Paxton#7 Well Position +N/-S 0.00 usft Northing: 2,230478.07 usft . Latitude: 60°5 44.522 N +E/-W 0.00 usft Easting: 206,309.36 usft • Longitude: 151°36'32.769 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 148.35 usft Wellbore Paxton#7 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2014 9/20/2014 16.60 73.10 55,182 Design Paxton#7 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 18.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 18.50 0.00 0.00 357.64 Survey Program Date 10/16/2014 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 185.82 2,002.00 Actual Surveys(Paxton#7) MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 09/19/2014 2,002.00 4,595.38 Actual Surveys(Paxton#7) MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 09/19/2014 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 18.50 0.00 0.00 18.50 -148.35 0.00 0.00 2,230,478.07 206,309.36 0.00 0.00 UNDEFINED 185.82 0.34 64.76 185.82 18.97 0.21 0.45 2,230,478.27 206,309.82 0.20 0.19 MWD+SC+sag(1) 215.54 0.76 51.43 215.54 48.69 0.37 0.68 2,230,478.43 206,310.05 1.47 0.34 MWD+SC+sag(1) 276.07 1.22 39.38 276.06 109.21 1.12 1.41 2,230,479.16 206,310.79 0.83 1.06 MWD+SC+sag(1) 339.14 2.33 22.42 339.10 172.25 2.82 2.32 2,230,480.84 206,311.75 1.93 2.73 MWD+SC+sag(1) 397.44 3.70 13.93 397.32 230.47 5.75 3.23 2,230,483.74 206,312.73 2.47 5.61 MWD+SC+sag(1) 458.62 5.05 359.81 458.32 291.47 10.36 3.69 2,230,488.34 206,313.30 2.81 10.19 MWD+SC+sag(1) 523.18 7.46 357.03 522.49 355.64 17.38 3.47 2,230,495.37 206,313.25 3.76 17.23 MWD+SC+sag(1) 585.40 10.79 355.82 583.91 417.06 27.23 2.83 2,230,505.22 206,312.85 5.36 27.09 MWD+SC+sag(1) 646.59 14.82 355.40 643.57 476.72 40,75 1.79 2,230,518.76 206,312.14 6.59 40.64 MWD+SC+sag(1) 709.13 19.18 355.24 703.36 536.51 58.97 0.29 2,230,537.01 206,311.09 6.97 58.90 MWD+SC+sag(1) 773.36 23.15 351.84 763.25 596.40 81.99 -2.38 2,230,560.09 206,308.98 6.47 82.02 MWD+SC+sag(1) 835.94 26.56 351.54 820.02 653.17 108.01 -6.18 2,230,586.20 206,305.81 5.45 108.17 MWD+SC+sag(1) 10/16/2014 5:23:36PM Page 2 COMPASS 5000.1 Build 70 SHalliburton • Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Paxton#7 Project: Ninilchik Unit TVD Reference: As-Built @ 166.85usft Site: Paxton MD Reference: As-Built @ 166.85usft Well: Paxton#7 North Reference: True Wellbore: Paxton#7 Survey Calculation Method: Minimum Curvature Design: Paxton#7 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 899.26 31.60 351.29 875.34 708.49 138.43 -10.78 2,230,616.73 206,301.95 7.96 138.76 MWD+SC+sag(1) 963.27 35.30 352.45 928.74 761.89 173.35 -15.75 2,230,651.76 206,297.83 5.87 173.86 MWD+SC+sag(1) 1,027.12 37.81 353.40 980.03 813.18 211.09 -20.43 2,230,689.60 206,294.08 4.03 211.75 MWD+SC+sag(1) 1,090.59 41.08 355.55 1,029.04 862.19 251.22 -24.28 2,230,729.81 206,291.20 5.58 252.01 MWD+SC+sag(1) 1,152.47 45.14 356.49 1,074.21 907.36 293.40 -27.20 2,230,772.05 206,289.31 6.64 294.27 MWD+SC+sag(1) 1,215.63 50.66 357.54 1,116.53 949.68 340.18 -29.62 2,230,818.87 206,288.03 8.83 341.11 MWD+SC+sag(1) 1,278.59 55.38 357.93 1,154.40 987.55 390.42 -31.61 2,230,869.15 206,287.27 7.51 391.39 MWD+SC+sag(1) 1,341.03 59.78 358.43 1,187.86 1,021.01 443.09 -33.27 2,230,921.84 206,286.88 7.08 444.08 MWD+SC+sag(1) 1,404.49 64.51 358.53 1,217.51 1,050.66 499.16 -34.76 2,230,977.93 206,286.76 7.45 500.17 MWD+SC+sag(1) 1,467.85 67.70 358.41 1,243.17 1,076.32 557.06 -36.31 2,231,035.85 206,286.63 5.04 558.09 MWD+SC+sag(1) 1,529.94 71.02 358.43 1,265.05 1,098.20 615.14 -37.91 2,231,093.95 206,286.44 5.35 616.18 MWD+SC+sag(1) 1,593.05 73.61 358.79 1,284.22 1,117.37 675.24 -39.37 2,231,154.07 206,286.44 4.14 676.29 MWD+SC+sag(1) 1,656.07 74.09 359.22 1,301.75 1,134.90 735.77 -40.42 2,231,214.60 206,286.87 1.00 736.81 MWD+SC+sag(1) 1,720.09 74.22 359.86 1,319.23 1,152.38 797.35 -40.91 2,231,276.18 206,287.87 0.98 798.36 MWD+SC+sag(1) 1,783.28 75.23 0.22 1,335.88 1,169.03 858.31 -40.87 2,231,337.12 206,289.40 1.69 859.26 MWD+SC+sag(1) 1,845.39 75.63 0.46 1,351.50 1,184.65 918.42 -40.51 2,231,397.20 206,291.22 0.74 919.31 MWD+SC+sag(1) 1,906.55 75.25 0.46 1,366.88 1,200.03 977.61 -40.04 2,231,456.37 206,293.14 0.62 978.43 MWD+SC+sag(1) 1,937.95 75.11 0.21 1,374.91 1,208.06 1,007.97 -39.86 2,231,486.71 206,294.05 0.89 1,008.75 MWD+SC+sag(1) 2,002.37 73.89 359.17 1,392.12 1,225.27 1,070.04 -40.19 2,231,548.77 206,295.23 2.45 1,070.79 MWD+SC+sag(2) 2,065.55 73.94 359.12 1,409.63 1,242.78 1,130.74 -41.10 2,231,609.48 206,295.80 0.11 1,131.47 MWD+SC+sag(2) 2,128.48 73.03 358.34 1,427.52 1,260.67 1,191.06 -42.44 2,231,669.81 206,295.93 1.87 1,191.80 MWD+SC+sag(2) 2,191.87 72.73 357.88 1,446.18 1,279.33 1,251.61 -44.43 2,231,730.39 206,295.41 0.84 1,252.38 MWD+SC+sag(2) 2,255.32 72.68 357.88 1,465.04 1,298.19 1,312.15 -46.67 2,231,790.96 206,294.64 0.08 1,312.96 MWD+SC+sag(2) 2,317.10 72.59 357.45 1,483.48 1,316.63 1,371.06 -49.08 2,231,849.92 206,293.68 0.68 1,371.92 MWD+SC+sag(2) 2,380.86 72.51 357.07 1,502.60 1,335.75 1,431.82 -51.98 2,231,910.73 206,292.25 0.58 1,432.74 MWD+SC+sag(2) 2,443.51 72.34 357.19 1,521.52 1,354.67 1,491.47 -54.97 2,231,970.44 206,290.71 0.33 1,492.47 MWD+SC+sag(2) 2,507.27 72.50 357.14 1,540.78 1,373.93 1,552.18 -57.98 2,232,031.20 206,289.18 0.26 1,553.25 MWD+SC+sag(2) 2,570.91 72.38 357.08 1,559.98 1,393.13 1,612.77 -61.04 2,232,091.85 206,287.60 0.21 1,613.92 MWD+SC+sag(2) 2,634.26 72.28 356.94 1,579.20 1,412.35 1,673.05 -64.19 2,232,152.19 206,285.92 0.26 1,674.28 MWD+SC+sag(2) 2,698.39 72.84 357.35 1,598.43 1,431.58 1,734.16 -67.24 2,232,213.35 206,284.36 1.07 1,735.46 MWD+SC+sag(2) 2,761.66 72.79 357.02 1,617.12 1,450.27 1,794.53 -70.20 2,232,273.78 206,282.87 0.50 1,795.90 MWD+SC+sag(2) 2,824.74 73.00 357.87 1,635.67 1,468.82 1,854.76 -72.89 2,232,334.05 206,281.64 1.33 1,856.19 MWD+SC+sag(2) 2,888.87 73.35 357.60 1,654.23 1,487.38 1,916.10 -75.32 2,232,395.43 206,280.71 0.68 1,917.57 MWD+SC+sag(2) 2,951.83 73.32 357.46 1,672.29 1,505.44 1,976.36 -77.92 2,232,455.74 206,279.58 0.22 1,977.89 MWD+SC+sag(2) 3,015.19 73.34 357.05 1,690.47 1,523.62 2,036.98 -80.82 2,232,516.42 206,278.15 0.62 2,038.58 MWD+SC+sag(2) 3,078.65 73.25 356.92 1,708.71 1,541.86 2,097.68 -84.02 2,232,577.17 206,276.43 0.24 2,099.36 MWD+SC+sag(2) 3,142.23 73.12 356.51 1,727.10 1,560.25 2,158.44 -87.51 2,232,638.00 206,274.43 0.65 2,160.22 MWD+SC+sag(2) 3,204.69 72.50 356.49 1,745.56 1,578.71 2,218.00 -91.15 2,232,697.63 206,272.23 0.99 2,219.87 MWD+SC+sag(2) 3,268.75 71.86 358.97 1,765.17 1,598.32 2,278.93 -93.57 2,232,758.60 206,271.30 3.82 2,280.85 MWD+SC+sag(2) 3,331.94 71.98 358.93 1,784.78 1,617.93 2,338.99 -94.67 2,232,818.67 206,271.66 0.20 2,340.91 MWD+SC+sag(2) 10/16/2014 5:23:36PM Page 3 COMPASS 5000.1 Build 70 • Halliburton • Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Paxton#7 Project: Ninilchik Unit TVD Reference: As-Built @ 166.85usft Site: Paxton MD Reference: As-Built @ 166.85usft Well: Paxton#7 North Reference: True Wellbore: Paxton#7 Survey Calculation Method: Minimum Curvature Design: Paxton#7 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 3,396.01 72.00 358.50 1,804.59 1,637.74 2,399.91 -96.04 2,232,879.60 206,271.78 0.64 2,401.83 MWD+SC+sag(2) 3,459.31 72.14 358.48 1,824.07 1,657.22 2,460.11 -97.62 2,232,939.83 206,271.66 0.22 2,462.05 MWD+SC+sag(2) 3,520.19 72.12 358.14 1,842.75 1,675.90 2,518.03 -99.33 2,232,997.77 206,271.36 0.53 2,519.99 MWD+SC+sag(2) 3,584.42 72.00 357.75 1,862.54 1,695.69 2,579.10 -101.52 2,233,058.87 206,270.66 0.61 2,581.09 MWD+SC+sag(2) 3,647.83 71.87 357.70 1,882.20 1,715.35 2,639.34 -103.92 2,233,119.15 206,269.73 0.22 2,641.38 MWD+SC+sag(2) 3,711.33 72.75 357.85 1,901.50 1,734.65 2,699.79 -106.26 2,233,179.64 206,268.85 1.40 2,701.87 MWD+SC+sag(2) 3,774.27 72.85 357.43 1,920.11 1,753.26 2,759.86 -108.74 2,233,239.76 206,267.84 0.66 2,762.00 MWD+SC+sag(2) 3,837.63 72.77 357.27 1,938.83 1,771.98 2,820.33 -111.54 2,233,300.27 206,266.52 0.27 2,822.53 MWD+SC+sag(2) 3,900.83 72.75 357.04 1,957.57 1,790.72 2,880.61 -114.54 2,233,360.61 206,264.99 0.35 2,882.88 MWD+SC+sag(2) 3,963.95 72.72 357.24 1,976.30 1,809.45 2,940.81 -117.54 2,233,420.87 206,263.45 0.31 2,943.16 MWD+SC+sag(2) 4,027.26 72.66 356.87 1,995.14 1,828.29 3,001.18 -120.65 2,233,481.29 206,261.81 0.57 3,003.60 MWD+SC+sag(2) 4,089.73 72.57 356.45 2,013.80 1,846.95 3,060.69 -124.12 2,233,540.87 206,259.79 0.66 3,063.20 MWD+SC+sag(2) 4,153.00 72.53 356.56 2,032.78 1,865.93 3,120.94 -127.80 2,233,601.19 206,257.58 0.18 3,123.55 MWD+SC+sag(2) 4,215.94 72.34 356.19 2,051.77 1,884.92 3,180.82 -131,59 2,233,661.15 206,255.24 0.64 3,183.54 MWD+SC+sag(2) 4,279.09 72.77 356.96 2,070.70 1,903.85 3,240.96 -135,19 2,233,721.36 206,253.11 1.35 3,243.78 MWD+SC+sag(2) 4,342.24 72.66 356.42 2,089.47 1,922.62 3,301.16 -138.67 2,233,781.62 206,251.09 0.83 3,304.07 MWD+SC+sag(2) 4,405.56 73.01 357.65 2,108.15 1,941.30 3,361.57 -141.80 2,233,842.10 206,249.44 1.94 3,364.56 MWD+SC+sag(2) 4,468.30 72.95 358.06 2,126.52 1,959.67 3,421.52 -144.05 2,233,902.08 206,248.65 0.63 3,424.55 MWD+SC+sag(2) 4,531.84 72.85 357.36 2,145,20 1,978.35 3,482.20 -146.48 2,233,962.81 206,247.70 1.06 3,485.28 MWD+SC+sag(2) 4,595.38 72.80 357.39 2,163.96 1,997.11 3,542.85 -149.26 2,234,023.50 206,246.40 0.09 3,545.99 MWD+SC+sag(2) 4,695.00 72.80 357.39 2,193.42 , 2,026.57 3,637.91 -153.59 2,234,118.64 206,244.38 0.00 3,641.15 PROJECTED to TD Checked By: Patrick Walker _,,,,,,,,.,,_w Approved By: Cary Taylor = Date: 10/16/2014 5:23:36PM Page 4 COMPASS 5000.1 Build 70 411 411 Paxton #7 - GIS Station, MD_ft, TVDSS_ft, TVD_ft, x_ft, Y_ft, Comment 1, 18. 50, -148.35, 18. 50, 206309.36, 2230478.07, 2, 185.82, 18.97, 185.82, 206309.82, 2230478.27, 3, 215.54, 48.69, 215.54, 206310.05, 2230478.43, 4, 276.07, 109.21, 276.06, 206310.79, 2230479.16, 5, 339.14, 172.25, 339.10, 206311.75, 2230480.84, 6, 397.44, 230.47, 397.32, 206312.73, 2230483.74, 7, 458.62, 291.47, 458.32, 206313.30, 2230488.34, 8, 523.18, 355.64, 522.49, 206313.25, 2230495.37, 9, 585.40, 417.06, 583.91, 206312.85, 2230505.22, 10, 646.59, 476.72, 643. 57, 206312.14, 2230518.76, 11, 709.13, 536.51, 703.36, 206311.09, 2230537.01, 12, 773.36, 596.40, 763.25, 206308.98, 2230560.09, 13, 835.94, 653.17, 820.02, 206305.81, 2230586.20, 14, 899.26, 708.49, 875.34, 206301.95, 2230616.73, 15, 963.27, 761.89, 928.74, 206297.83, 2230651.76, 16, 1027.12, 813.18, 980.03, 206294.08, 2230689.60, 17, 1090. 59, 862.19, 1029.04, 206291.20, 2230729.81, 18, 1152.47, 907.36, 1074.21, 206289.31, 2230772.05, 19, 1215.63, 949.68, 1116.53, 206288.03, 2230818.87, 20, 1278.59, 987.55, 1154.40, 206287.27, 2230869.15, 21, 1341.03, 1021.01, 1187.86, 206286.88, 2230921.84, 22, 1404.49, 1050.66, 1217. 51, 206286.76, 2230977.93, 23, 1467.85, 1076.32, 1243.17, 206286.63, 2231035.85, 24, 1529.94, 1098.20, 1265.05, 206286.44, 2231093.95, 25, 1593.05, 1117.37, 1284.22, 206286.44, 2231154.07, 26, 1656.07, 1134.90, 1301.75, 206286.87, 2231214.60, 27, 1720.09, 1152.38, 1319.23, 206287.87, 2231276.18, 28, 1783.28, 1169.03, 1335.88, 206289.40, 2231337.12, 29, 1845.39, 1184.65, 1351. 50, 206291.22, 2231397.20, 30, 1906. 55, 1200.03, 1366.88, 206293.14, 2231456.37, 31, 1937.95, 1208.06, 1374.91, 206294.05, 2231486.71, 32, 2002.37, 1225.27, 1392.12, 206295.23, 2231548.77, 33, 2065.55, 1242.78, 1409.63, 206295.80, 2231609.48, 34, 2128.48, 1260.67, 1427.52, 206295.93, 2231669.81, 35, 2191.87, 1279.33, 1446.18, 206295.41, 2231730.39, 36, 2255.32, 1298.19, 1465.04, 206294.64, 2231790.96, 37, 2317.10, 1316.63, 1483.48, 206293.68, 2231849.92, 38, 2380.86, 1335.75, 1502.60, 206292.25, 2231910.73, 39, 2443.51, 1354.67, 1521.52, 206290.71, 2231970.44, 40, 2507.27, 1373.93, 1540.78, 206289.18, 2232031.20, 41, 2570.91, 1393.13, 1559.98, 206287.60, 2232091.85, 42, 2634.26, 1412.35, 1579.20, 206285.92, 2232152.19, 43, 2698.39, 1431. 58, 1598.43, 206284.36, 2232213.35, 44, 2761.66, 1450.27, 1617.12, 206282.87, 2232273.78, 45, 2824.74, 1468.82, 1635.67, 206281.64, 2232334.05, 46, 2888.87, 1487.38, 1654.23, 206280.71, 2232395.43, 47, 2951.83, 1505.44, 1672.29, 206279. 58, 2232455.74, 48, 3015.19, 1523.62, 1690.47, 206278.15, 2232516.42, 49, 3078.65, 1541.86, 1708.71, 206276.43, 2232577.17, 50, 3142.23, 1560.25, 1727.10, 206274.43, 2232638.00, 51, 3204.69, 1578.71, 1745. 56, 206272.23, 2232697.63, 52, 3268.75, 1598.32, 1765.17, 206271.30, 2232758.60, 53, 3331.94, 1617.93, 1784.78, 206271.66, 2232818.67, 54, 3396.01, 1637.74, 1804.59, 206271.78, 2232879.60, 55, 3459.31, 1657.22, 1824.07, 206271.66, 2232939.83, 56, 3520.19, 1675.90, 1842.75, 206271.36, 2232997.77, 57, 3584.42, 1695.69, 1862. 54, 206270.66, 2233058.87, 58, 3647.83, 1715.35, 1882.20, 206269.73, 2233119.15, 59, 3711.33, 1734.65, 1901. 50, 206268.85, 2233179.64, 60, 3774.27, 1753.26, 1920.11, 206267.84, 2233239.76, 61, 3837.63, 1771.98, 1938.83, 206266. 52, 2233300.27, 62, 3900.83, 1790.72, 1957.57, 206264.99, 2233360.61, Page 1 411 410 Paxton #7 - GIS 63, 3963.95, 1809.45, 1976.30, 206263.45, 2233420.87, 64, 4027.26, 1828.29, 1995.14, 206261.81, 2233481.29, 65, 4089.73, 1846.95, 2013.80, 206259.79, 2233540.87, 66, 4153.00, 1865.93, 2032.78, 206257. 58, 2233601.19, 67, 4215.94, 1884.92, 2051.77, 206255.24, 2233661.15, 68, 4279.09, 1903.85, 2070.70, 206253.11, 2233721.36, 69, 4342.24, 1922.62, 2089.47, 206251.09, 2233781.62, 70, 4405. 56, 1941.30, 2108.15, 206249.44, 2233842.10, 71, 4468.30, 1959.67, 2126. 52, 206248.65, 2233902.08, 72, 4531.84, 1978.35, 2145.20, 206247.70, 2233962.81, 73, 4595.38, 1997.11, 2163.96, 206246.40, 2234023. 50, 74, 4695.00, 2026. 57, 2193.42, 206244.38, 2234118.64, Page 2 k • 2 • 0 a w 0Eu mo J t e �. 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O �f' 00 M N N '.O N 00 O 01 N N 0 01 O N v1 M 00 M O ct 00 ^. 4 00 "4 Iyl 00 N 4 00 .-+ vO 01 O 01 4 N .. e4 vO N 01 O lO M N 01 Myl 01 N v1 00 .4 vl v1 A y M 01 `0 N 00 vl N d• O '.O M 01 v1 N 'n 00 'd' .-• N N M M O 1D N 00 v_1 N t O 1D M 01 01 10 1O N 00 00 01IO O * N N M M 4 M v1 v1 0 N N 00 00 00 01 01 01 O O N N M 4 4 v1 v1 10 N N N N N NIM M M M M M M M M M M M M M M M M M M M 4 4 4 4 4 4 4 4 4 4 4 I ), M 4 v1 1D N o0 01 O .. N M 4 v1 10 N 00 01 O N M 4 v1 \O N OD 0\ O N M 'ct v1 10 N o0 01 ct erth eterv1 v1 v1 h v1 v1 v1 v1 v1 h vD10 10 10 �O .0 \O 10 1D 10 N N N N N N N N N N cA • • Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No. Ninilchik,Paxton#7 Date 29-Sep-14 County South Kenai State Alaska Supv. Douglas Yessak/Kevin McDowell CASING RECORD TD 1945.00 Shoe Depth: 1936.00 PBTD: 1849.24 _ Casing(Or Liner)Detail Setting Depths No.of Jts. Size W't. Grade THD Make Length Bottom Top shoe 9 5/8 BTC Weatherford 1.89 1,936.14 1,934.25 2 jts 9 5/8 40 L-80 BTC 83.46 1,934.25 1,850.79 Float collar 9 5/8 BTC Weatherford 1.55 1,850.79 1,849.24 45 jts 9 5/8 40 L-80 BTC 1,822.86 1,849.24 26.38 PUP 1T 9 5/8 40 L-80 BTC 2.94 26.38 23.44 HGR 16 3/4 x 11 BTC Sea board 0.44 23.44 23.00 RKB 23.00 23.00 0.00 0.00 0.00 0.00 Totals 0.00 0.00 0.00 Totals Csg Wt.On Hook: 85,000 Type Float Collar: Weatherford#303 No.Hrs to Run: 5 hrs Csg Wt.On Slips: 76,520 Type of Shoe: Weatherford#402 Casing Crew: Weatherford Fluid Description: 9.5 ppg Kla-shield mud Liner hanger Info(Make/Model): Liner top Packer?: Yes X No Liner hanger test pressure: Centralizer Placement: 80'spacing,22 ran,top centralizer on jt#39 at 357 ft. CEMENTING REPORT Preflush(Spacer) Type: Seal bond Density(ppg) 10 Volume pumped(BBLs) 40 Lead Slurry Type: Type 1 Density(ppg) 12.5 Volume pumped(BBLs) 128.6 Mixing/Pumping Rate(bpm): 3.9 Tail Slurry Type: Type 1 (, Density(ppg) 15.2 Volume pumped(BBLs) 48.6 Mixing/Pumping Rate(bpm): 4.2 N Post Flush(Spacer) y Type: Density(ppg) Rate(bpm): Volume: ce LL Displacement: Type: Drilling mud Density(ppg) 9.5 Rate(bpm): 5 Volume(actual/calculated): 140.34/144.5 FCP(psi): 488 Pump used for disp: Cement pump Plug Bumped? X Yes No Bump press 1034 Casing Rotated? Yes X No Reciprocated? Yes X No 100%Returns during job Yes Cement returns to surface? X Yes No Spacer returns? X Yes No Vol to Surf: 40 bbls spacer,60 bbls lead cmt Cement In Place At: 11:05 Date: 9/29/2014 Estimated TOO: Surface Method Used To Determine TOC: Visual Preflush(Spacer) Type: Density(ppg) Volume pumped(BBLs) Lead Slurry Type: Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): Tail Slurry ui Type: Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): N Post Flush(Spacer) 0 o Type: Density(ppg) Rate(bpm): Volume: Displacement: Type: Density(ppg) Rate(bpm): Volume(actual/calculated): FCP(psi): Pump used for disp: Plug Bumped? Yes No Bump press Casing Rotated? Yes No Reciprocated? Yes No %Returns during job Cement returns to surface? Yes No Spacer returns? Yes No Vol to Surf: Cement In Place At Date: Estimated TOO: Method Used To Determine TOC: WELLHEAD Make Sea board Type Casing head Serial No. 6A-10-00-1-2 Size 16 3/4 x 11 W.P. 3M X 5M Test Head To 3000 PSIG 30 MIN test OK Remarks: Plug bumped 4.16 bbls over calculated.Float held. • • Hifcorp Energy Company CASING&CEMENTING REPORT Lease&Well No. Paxton#7 Date 11-Oct-14 County Ninilchik State Alaska Supv. Shane Barber/Kevin McDowell CASING RECORD TD 4695.00 Shoe Depth: 3542.00 PBTD: 3446.00 Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top SHOE 5.5" P-110 CDC Davis Lynch 3.08 3,542.47 3,539.39 2 5.5" 17 P-110 _ CDC US STEEL 91.80 3,539.39 3,447.59 Float collar 5.5" P-110 CDC Weatherford 1.25 3,447.59 3,446.34 19 5.5" 17 P-110 _ CDC US STEEL 859.23 3,446.34 2,587.11 RA PUP 5.5" 17 P-110 CDC US STEEL 9.80 2,587.11 2,577.31 57 5.5" 17 P-110 CDC US STEEL 2,554.10 2577.31 23.21 Hanger 5.5" 17 P-110 CDC US STEEL 3.81 23.21 19.40 RKB 5.5" 17 P-110 CDC US STEEL 19.40 19.40 0.00 Totals Csg Wt.On Hook: 45,000 Type Float Collar: Weatherford No.Hrs to Run: 6 Csg Wt.On Slips: 30,000 Type of Shoe: Reamer Casing Crew: Weatherford Fluid Description: 9 ppg KLA Shield Liner hanger Info(Make/Model): NA Liner top Packer?: _Yes X No Liner hanger test pressure: NA Centralizer Placement: 35-Every 44'From 3542 T/2000' CEMENTING REPORT Preflush(Spacer) Type: SEAL BOND Density(ppg) 10 Volume pumped(BBLs) 41 Lead Slurry Type: Class G Density(ppg) 15.7 Volume pumped(BBLs) 121.1 Mixing/Pumping Rate(bpm): 4.2 Tail Slurry Type: Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): w Post Flush(Spacer) Type: Density(ppg) Rate(bpm): Volume: LL Displacement: Type: 6%KCL Density(ppg) 8.6 ppg Rate(bpm): 3.3 Volume(actual/calculated): 80/80.1 FCP(psi): 437 Pump used for disp: Baker Plug Bumped? X Yes No Bump press 1138 Casing Rotated? Yes X No Reciprocated? Yes x No %Returns during job 100 Cement returns to surface? Yes x No Spacer returns? Yes x No Vol to Surf: 7 Cement In Place At: 16:40 Date: 10/11/2014 Estimated TOC: 755' Method Used To Determine TOC: Calculated by amount of spacer return to surface and lift psi Preflush(Spacer) Type: Density(ppg) Volume pumped(BBLs) Lead Slurry Type: Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): Tail Slurry w Type: a Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): 0 Post Flush(Spacer) o Type: Density(ppg) Rate(bpm): Volume: wDisplacement: Type: Density(ppg) Rate(bpm): Volume(actual/calculated): FCP(psi): Pump used for disp: Plug Bumped? _Yes No Bump press Casing Rotated? Yes No Reciprocated? Yes_No %Returns during job Cement returns to surface? Yes_No Spacer returns? Yes_No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Post Job Calculations: Calculated Cmt Vol @ 0%excess: 89 Total Volume cml Pumped: 120 Cmt returned to surface: 0 Calculated cement left in wellbore: 120 OH volume Calculated: 66 OH volume actual: 66 Actual%Washout: 0 • 0AILY DRHilcolpILLIEnergy Company • NG REPORT REPORT NO. LEASE WELL NO. COUNTY/PARISH WELL STATE DATE 1 ADL384372&Private Paxton 7 Kenai Peninsula Burough NINU Paxton 7 AK 9/22/2014 RIG AFE NO. APE BUDGET DAILYCOST CDC RIG PHONE Saxon Rig#147 1412365D 4564878 $118,681 $118,681 907-283-1365 ACTIVITY TYPE: DRLG Drilling RU Rig Up DEPTH:MD/TVD PROGRESS/HRS PROP.TD.AST SHOE TEST PPG DAYS SINCE SPUD AFE DAYS FIELD SUPERVISOR ENGINEER 7098 1 Barber/McDowell Luke Keler AC11VITYSUMMARYAT: HRS SURVEY: MD ANGLE AZIMUTH TVD SECTION N/S E/W DOGLEG Rigging up Saxon rig*147 TIME LOG ELAPSED ACTIVITY COMMENTS FROM TO TIME 6:00 18:00 12.0 Mob/Demob R/D&unpin derrick,unspod drilling line.R/D dog house,wed pumps&tanks prep to lower dog house.remove break linkage shut down Gers.unplug elect.Raise walkways Inspect derrick before lilting. Move rig off of Paxton#8 1800 6:00 12.0 Mob/Demob Install Seaboard slip-on 16 3/4"3M Casing head Assy(Conductor cut @ 63"below G/L).and orient.Level pad UD.felt&heralite.Set rig mats.N/U DSA Spacer spool and diverter.Set pony sub TOTAL 24.00 LITHOLOGY: MAX GAS B.G.GAS CON GAS TRIP GAS Accidents None Pollution none Plan Next 24 Hr Report Attach no Continue to R/U Saxon Rig*147 MUD RECORD CASING RECORD PUMP BPM TYPE DATA GPM SIZE GRADE WT CONN DEPTH DV ID NUMBER 1 2 TIME t6 X-56 109 Weld 80 15 MAKE TSM TSM DEPTH MODEL 1000 1000 TEMP STROKE 9 9 WEIGHT LINER SZ 5.50 5.50 VISC SPM PV TOP OF LINER @ GAL/STK 2.64 2.64 YP BIT NO. SLR PSI GELS BHA# SIZE API 1AL MFG. SLOW PUMP DATA @ HTHP DESCRIPTION OD ID FEET TYPE Pump# PSI 1 PSI 2 PSI 3 Eff% CAKE SERIAL NO. 1 95 SOLIDS NOZZLES 2 95 ADJSOL TFA SPM for PSI 1/2/3 OIL% DEPTH OUT DRILL STRING CAPACITY WTR% DEPTH IN STROKES SD% TOTAL FT. MBT HOURS POM AVG ROP pH WOB Pm ANN VEL DEPTH PF/MF ROT.RPM TORQUE Clmud AV DP CSG PICK UP Clwtr AV DP OP HL ROTATIONAL Cal AV DC SLACK OFF LIME TOT CUM HR %LGS GAUGE JAR HOURS ES INNER MUD MOTOR HRS OUTER LOCATION RP DULL CHAR. CUM HR BHA LIQ MUD TOTAL LENGTH(FT) HYDRAULICS FUEL 5059 GAL ADD(DIESELGAL) TOT WEIGHT(LBS) DEPTH FT CREW BOAT FUEL GAL SOLIDS EQUIPMENT NOZ.AREA IN' POT.WATER GAL SHAKER#1 DRK 2 d Pb PSI TUG FUEL GAL SHAKER#2 BRDT HRS HHP BIT HP BARRE SKS DERRICK/A DRKS HRS H.S.I. HP/IN' FUEL USED 443 GAL MUD CLEAN CENT HRS JET VEL FT/SEC HEAVY H2O GAL BOP TESTED PERSONNEL ON BOARD IMP FORCE WEATHER Misc HEC 2 %Pb WIND 3 mi MPH DAILY CUM NEXT TEST DUE RIG 16 BOATS SEAS 42 TEMP MUD SERVICE t6 MN PRES CONS Scattered douds DIESEL FUNC.DUE TOTAL 34 MN FORECAST Sumy TOTAL MN www.wellez.com WellEz Information Management LLC ver 050514bf Hilcorp Energy Company• II ir �AILYDRILLING REPORT 411/ REPORT NO. LEASE WELL NO. COUNTY/PARISH WELL STATE DATE 2 ADL384372&Private Paxton 7 Kenai Peninsula Borough NINU Paxton 7 AK 9/23/2014 RIG AFE NO. AFE BUDGET DAILY COST CDC RIG PHONE Saxon Rig#147 1412365D 4564878 $76,052 $194,733 907-283-1365 ACTIVITY TYPE: ORLG Drilling RU Rig Up DEPTH:MD/ND PROGRESS/HRS PROP.TD AST SHOE TEST PPG DAYS SINCE SPUD AFE DAYS FIELD SUPERVISOR ENGINEER 7098 2 'essak/Barber/McDowe Luke Keller ACTIVITYSUMMARYAT: HRS SURVEY: MD ANGLE AZIMUTH TVD SECTION N/S E/W DOGLEG RN Saxon rig#147 TIME LOG ELAPSED ACTIVITY COMMENTS FROM TO TIME 6:00 12:00 6.0 RU/RD Set Sub,doghouse boiler,fuel tank and gen house.Set and pin derrick.Start hooking up service lines.R/U handl berm containment around rig.spot surface Hydril in teller. 12:00 18:00 6.0 RU/RD Set pump houses,pts,Sperry,Canrig,and 3rd gen.Continue rigging up all service lines.Rig 100%set.Peak released @ 14:30.AOGCC notifications sent in via Email. 18:00 6:00 12.0 RU/RD Spool drilling line.dress,raise,and scope up derrick.spot cat walk.P/U and instal torque tube.install'T'bar&tum buckles settop drive on rig floor and install.R/U top drive hydraulics. Function test top drive.Hook up kelly hose.continue rigging up pumps and pits. TOTAL 24.00 LITHOLOGY: MAX GAS B.G.GAS CON GAS TRIP GAS Accidents None Pollution none Plan Next 24 Hr Report Attach no Continue with rigging up 147 MUD RECORD CASING RECORD PUMP BPM TYPE DATA GPM SIZE GRADE WT CONN DEPTH DV ID NUMBER1 2 TIME 16 X-56 109 Weld 80 15 MAKE TSM TSM DEPTH MODEL 1000 1000 TEMP STROKE 9 9 WEIGHT LINER SZ 5.50 5.50 VISC SPM PV TOP OF LINER @ GAL/STK 2.64 2.64 YP BIT NO. SUR PSI GELS BHA# SIZE API W. MFG. SLOW PUMP DATA @ HTHP DESCRIPTION OD ID FEET TYPE Pump# PSI 1 PSI 2 PSI 3 EH CAKE SERIAL NO. 1 95 SOLIDS NOZZLES2 95 ADJSOL TFA SPM for P011/2/3 OIL% DEPTH OUT DRILL STRING CAPACITY WTR% DEPTH IN STROKES SD% TOTAL FT. MBT HOURS POM AVG ROP pH WDB Pm ANN VEL DEPTH PF/MF ROT.RPM TORQUE Clmud AV DP CSG PICK UP CMTr AV DP OP HL ROTATIONAL Cal AV DC SLACK OFF UME TOT CUM HR %LGS GAUGE JAR HOURS ES INNER MUD MOTOR HRS OUTER LOCATION RP DULL CHAR. CUM HR BHA LIQ MUD TOTAL LENGTH(FT) HYDRAUUCS FUEL 4584 GAL ADD(DIESELGAL) TOTWEIGHT(LBS) DEPTH FT CREWBOAT FUEL GAL SOLIDS EQUIPhENT NOZAREA IN. POT.WATER GAL SHAKER#1 DRK 2 d Pb PSI TUG FUEL GAL SHAKER#2 BRDT HRS HHP BIT HP BARITE SKS DERRICK#I DRKS abs H.S.I. HP/IM FUEL USED 475 GAL MUD CLEAN CENT HRS JET VEL FT/SEC HEAVY H2O GAL BOP TESTED PERSONNEL ON BOARD IMP FORCE WEATHER Misc HEC 2 %Pb WIND 9 mi MPH DAILY CUM NEXT TEST DUE RIG 16 BOATS SEAS 30 TEMP MUD SERVICE 16 MN PRES CONS Partly cloudy DIESEL FUNC.DUE TOTAL 34 MN FORECAST Sunny TOTAL MN www.wellez.com WellEz Inbrmation Management LLC ver 050514br • • Paxton #7 Days Vs Depth o _ Paxton 7 ACTUAL Paxton 7 Plan 1000 2000 3000 a. w „ 4000 Cw 5000 6000 7000 8000 � 0 5 10 15 20 25 30 Days • • Paxton #7 MW Vs Depth 0 Paxton 7 ACTUAL 500 Paxton 7 Plan 1000 1500 2000 .... .. 2500 3000 3500 o r a 4000 4500 5000 5500 6000 6500 7000 7500 8 9 10 11 12 13 14 Mud Density(ppg) Pr6Z14(300 Regg, James B (DOA) From: Paul Chan <pchan@hilcorp.com> Sent: Friday, November 07, 2014 9:40 AM To: Regg,James B (DOA); Schwartz, Guy L(DOA) Cc: Chad Helgeson; Luke Saugier;Taylor Nasse Subject: Paxton #7 (PTD 214-130) and Paxton #8 (PTD 214-107) Pressure Testing Requirements Jim/Guy Reference: Paxton#7 (PTD 214-130) and Paxton#8 (PTD 214-107) Hilcorp Alaska is reporting that pressure testing of well control equipment for conductor line operations, as required under 20 AAC 25.287 and the approved sundries, did not occur on the Paxton#8 (October 30) and Paxton#7 (October 31 and November 1)wells. Both wells were cased and cemented. The Paxton#7 well was completed with 2-7/8"tubing/packer with 8.6 ppg kill weight fluid. The Paxton #7 well had not been perforated at the time of logging operations. The Paxton#8 completion hasn't been run and the well is currently not perforated. The Paxton#8 well also had 8.6 ppg kill weight fluid in the casing at the time of logging operations. The cased hole logging suites were being run in preparation for completion activities. Hilcorp Alaska regrets the oversight in not pressure testing the well control equipment as required and will review our procedures and policies to ensure that events like this are not repeated. Sincerely Paul Chan Senior Operations Engineer Kenai Asset Hilcorp Alaska LLC (907) 777—8333 (w) (907)444—2881 (c) (907) 345—3161 (h) 1 Seth Nolan Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 Ffilrurp Alarkn.i t !RECEIVED Fax: 907 777-8510 E-mail: snolan@hilcorp.com ‘I14 '. AOGCCDATA LOGGED s /%I/2011k M.K.BENDER DATE 11/13/2014 To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL Paxton 7 E log data Prints: DGR EWR-Phase 4 ALD CTN TVD ROP DGR EWR-Phase 4 ALD CTN MD CD: Final Well Data CGM 10/13/2014 9:10 A... File folder DUS+LAS 10/13/2014 9:10 A... File folder k, EMF 10/13/2014 9:09 A... File folder i► PDF 9/24/2014 3:53 PM File folder }► TIFF 10/13/2014 9:09 A... File folder Please include current contact information if different from above. Please ackno ledge receipt by si ning and returning one copy of this transmittal or FAX to 907 777.8337 Received sy Date: • • 2_`24 - 59 Seth Nolan Hilcorp Alaska, LLCM '3 GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 fiilrurp.4.141.1..rrkn.1.11 Fax: 907 777-8510 DATA LOGGED A/\'Voi14 E-mail: snolan@hilcorp.com K BENDER NV 1 4 2014 AOGCC DATE 11/13/2014 To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL Paxton 7 Mudlog Data Prints: End of Well Report 2" MD Formation Evaluation Log 2"TVD Formation Evaluation Log 5" MD Formation Evaluation Log 5"TVD Formation Evaluation Log 2" MD LWD Combo Log 2"TVD LWD Combo Log 2" MD Gas Ratio Log 2"TVD Gas Ratio Log 2" MD Drilling Engineering Log 2"TVD Drilling Engineering Log CD: Final Well Data • riles Currently on the Disc (6) . Daily Reports 11/1312014 9:53 AM File folder DML Data 11/13/2014 9:53 AM File folder Final Well Report 11/1312014 9:53 AM File folder ji LAS Data 11;1312014 9:53 AM File folder , Log PDFs 11/13/2014 9:53 AM File folder Log TIFFs 11,13/2014 9:53 AM File folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: o_64tegie: ��'.G+N'tw 6' �Q 41P4 '\\►1/%��a THE STATE A.,� a��ra elt� ittit =, y — 333 Wesi Seventh Avenue 46111 --:17----.7- l GOVERNOR SEAN PARNELI, Anchorage, Alaska 99501 3572 '7'' �;; .,a Main: 907 279 1433 0 pv 4. L,F F�_!-: 907.17., e; Paul Chan Senior Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Ninilchik Field, BelugalTyonek Gas Pool, Paxton 7 Sundry Number: 314-560 Dear Mr. Chan: Enclosed is the approved application for 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, Li f90--e e- 4/L__ Cathy PAFoerster Chair DATED this2 Tay of October, 2014. Encl. • • R C IVFP STATE OF ALASKA OCT 15 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION ):5\-'\1(.A')-3114 APPLICATION FOR SUNDRY APPROVALS . rt.f-, r6 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well❑ Change Approved Program ❑ Suspend❑ Plug Perforations ❑ " 'Perforate E . Pull Tubing❑ Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate ❑ Alter Casing❑ Other: Initial Completion_ ❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5. Permit to Drill Number Exploratory ❑ Development E 214-130 . 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service El6.API Number. Anchorage,Alaska 99503 50-133-20643-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 701 Paxton 7 - Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10. Field/Pool(s): 06'0.../ ,.-4...--'7-7 v,,t44 6,i... • Fee Private,ADL384372 • Ninilchik/SD r. . _. ,7i'\ j4)./3.-76" 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 4,695' 2,193' 3,447' 1,820' N/A 3,562' Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 80' 80' N/A N/A Surface 1,936' 9-5/8" 1,936' 1,374' 5,750 psi 3,090 psi Intermediate Production 3,523' 5-1/2" 3,542' 1,849' 10,640 psi 7,480 psi • Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): None None 2-78" 6.4#/L-80 2,267' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker SAB-L/Baker TE-5 TRSV 2,184'/138'MD and 1,444'/138'TVD 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development E Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 10/22/14 Commencing Operations: Oil ❑ Gas ❑✓ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing rue and correct to the best of my knowledge. Contact Paul Chan Phone: 907-777-8333 Email pchan@hilcorp.com Printed Name .•:10 Title Senior Operations Engineer Signature , Phone 907-777-8333 Date 1 of (S.1/ c COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No [ Subsequent Form Required: /0 °—q C7 S';,--,--e ode 7,-4 APPROVED BY (--// Approved by:( / ���`�L� COMMISSIONER THE COMMISSION Date: `Z `� -it z' I ( Submit Form and RBE 84014 ised�/12{j OR+G ++A"b for 12 me nths from the date of approval. ,� Attackments in Duplicate • , . . 11 • Well Prognosis Well: Paxton#7 Hilcoru Alaska,LL Date: 10/14/2014 Well Name: Paxton#7 API Number: 50-133-20643-00 Current Status: SI Leg: Estimated Start Date: October 22, 2014 Rig: Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-130 First Call Engineer: Paul Chan (907) 777-8333 (0) (907) 345-3161 (H) (907)444-2881 (C) Second Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (C) AFE Number: 1412365C Estimated Bottom Hole Pressure: 1,511 psi at 2,476 ND (Assumed 0.43 psi/ft gradient) Max. Anticipated Surface Pressure: —1,263 psi (0.10 psi/ft gas gradient) Brief Well Summary Paxton#7 is a grass roots well drilled by the Saxon 147 rig. 9-5/8" surface casing has been set and the rig was drilling the 8-1/2" hole section when a lost circulation zone was encountered and the BHA became stuck. The ,'' 5-1/2" production casing was run and cemented to top of the fish and the well completed with 2-7/8"tubing. Objective of Work: Initial perforations in the Beluga sands • E-Line Procedure 1. MIRU e-line and pressure control equipment. PT lubricator to 250 psi low/3,500 psi high. Note that the well is pressurized with nitrogen. 2. If necessary, bleed nitrogen pressure down as requested by the RE to establish a drawdown on the formation. 3. Perforate the Beluga sands with 2" 6 SPF 60 deg phased perf guns. Depths are from the Halliburton triple combo composite run while drilling the well. The perforated interval will be adjusted once the GR/CCL jewelry log has been. Send the correlation pass to Paul Chan and David Buthman for confirmation. Gross Proposed Perforated Intervals Sands Top (MD) Btm (MD) FT Beluga I ±2,346' ±2,351' ±5 Beluga II ±2,390 ±2,395 ±5 Beluga IIla ±2,456' ±2,466' ±10 Beluga IIIb ±2,504' ±2,509' ±5 Beluga IV ±2,586' ±2,606' ±20 4. POOH. 5. Flow well through test separator and record water and gas rates 6. RD e-line. 7. Turn well over to production. Attachment: Proposed Wellbore Schematic • Ninilchik Unit ti "harmed Rev1 Well: Paxton #7 PTD: 214-130 API: 50-133-20643-00 CASING DETAIL ' ' ' Size Type Wt Grade Conn. ID Top Btm 16" 16" Conductor 109 X-56 Weld 16" Surf 80' 9-5/8" Surf.Csg 40 L-80 BTC 8.835" Surf 1,936' CI 5-1/2" Prod Casing 17 P-110HC DQX 4.892" Surf 3,542' ISI TUBING - 2 1 2-7/8" Production 6.4 L-80 EUE-8rd 2.441" Surf 2,267' OPEN HOLE/CEMENT DETAIL 9-5/8" 9-5/8" 177BBL's of cement in 12-1/4"Hole. Returns to Surface 5-1/2" 121BBL's of cement in 8-1/2"Hole. TOC 755'Calculated • s 3 1 ,,,, 4 - JEWELRY DETAIL No. Depth ID OD Item 1 125' Chemical Injection Sub 14 2 138' Baker TE-5 TRSV • 3 2,184' Baker SAB-L Permanent Packer m:i. 4 ., -: i. 4 2,267' Wireline re-entry guide , TOF at 3,562' 8-1/2" �\/ P(311-4.)i Kr c 17-- PERFORATION�DET I� / AL HoleSands Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Date Status iI Beluga I ±2,346' ±2,351' ±1,492' ±1,494' ±5 Proposed ^ I Beluga II ±2,390 ±2,395 ±1,505' ±1,507' ±5 Proposed t���, ', Beluga Illa ±2,456' ±2,466' ±1,525' ±1,528' ±10 Proposed 1 ilk, Beluga IIIb ±2,504' ±2,509' ±1,540' ±1,541' ±5 Proposed \ Beluga Iv ±2,586' ±2,606' ±1,565' ±1,571' ±20 Proposed BOF at 3,916' Fish details: 8-1/2" PDC bit, mud motor, Float sub,stabilizer,MWD collar, Dual gamma ray collar, resistivity collar, Den/Neu collars(with nuclear source),(2)non mag flex collars, (4)jts HWDP,jar, (1)jt HWDP. 5.5" 1%. ..J PBTD=3,472 MD/1,820'TVD TD=4,695'MD/2,193'TVD Updated by DMA 10/15/2014 • • Davies, Stephen F (DOA) From: David Duffy <dduffy@hilcorp.com> Sent: Friday, October 10, 2014 2:09 PM To: Davies, Stephen F (DOA); Paul Chan Subject: RE: Paxton 7 (PTD#214-130): Sundry Application - Question Yes. Although we did not reach the target Beluga sands,this completion will still conform with the spacing requirements of CO 71. From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Friday, October 10, 2014 1:27 PM To: Paul Chan; David Duffy Subject: Paxton 7 (PTD # 214-130): Sundry Application - Question Paul and David, Sorry to hear about the lost BHA containing radioactive sources in Paxton 7. Please confirm that the shallower-than- anticipated perforations in Paxton 7 conform with the spacing requirements of Conservation Order No. 701. Thanks, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 1 7,---i---;07 •��\\1t4-11,,,,N\ %i, THE STATE AA' ;��L� ��: ‘-':(o`_ E' 7�o s ,,ii, , A ;' kk`- (-----\ t 7, s# .f_---7_,-,--.4_,_= _ 31)3 West Seventh Aver -“"may*`... GOVERNOR SL \ AR;�':? i_1_ Anchorage, Alaska 99501-3572 i7 cc n� 907 279 1433 q`7-� �ui. .� 907 226 7549 Paul Chan Sr. Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Ninilchik Field, Beluga Tyonek Gas Pool, Paxton 7 Sundry Number: 314-554 Dear Mr. Chan: Enclosed is the approved application for 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 . Foerster Chair DATED this /6 ti of October, 2014. Encl. A • • STATE OF ALASKA UL I 0 0 L0i4 ALASKA OIL AND GAS CONSERVATION COMMISSION dam' / 6 f( —// 'S �(,�,w APPLICATION FOR SUNDRY APPROVALS AOGCC 1t7120 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod ❑ Repair We❑ Change Approved Program❑ Suspend❑ Plug Perforations ❑ Perforate❑ Pull TubinE Time Extension❑ Operations Shutdowi❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casin❑ Other: Initial Completion_ El. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number Hilcorp Alaska, LLC Exploratory ❑ Development J - 214-130 - 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic LI Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-20643-00 - 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O.701 - �❑ Paxton 7 . Will planned perforations require a spacing exception? Yes El No 9.Property Designation(Lease Number): 10. Field/Pool(s): r Fee Private,ADL384372 - Ninilchik/,§D B rt�E"ffi►s h " ' " ��',7`< 11. PRESENT WELL CONDITION SUMMARY J (J'jj Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): -4,695' -2,193' -3,472' -1,828' N/A 3562' Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" -80' -80' N/A N/A Surface 1936' 9-5/8" 1936' -1374' 5,750 psi 3,090 psi Intermediate Production -3,516 5-1/2" -3,516' -1841' 10,640 psi 7,480 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A 2-78" 6.4#/L-80 -2,245' Packers and SSSV Type: Packers and SSSV MD(t)and TVD(ft): Baker SAB-L/TRSV -2,170'/-160'MD and 1440'/160'TVD 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphin Development n' Service ❑ 14.Estimated Date for 15.Well Status after propsed work: 10/14/14 Commencing Operations: Oil ❑ Gas ❑� WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: /0•/3•/d1 WIND ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: CSvc GSTOR ElSPLUG CI17. I hereby certify that the foregoing is true and cor ect to the best of my knowledge. Contact Paul Chan Phone: 907-777-8333 ' Email pchan@hilcorp.com Printed a -- "03 I a Title Sr.Operations Engineer Signature '4 Phone 907-777-8333 Date t°(°1 L � ' I COMMISSION USE ONLY ll Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\x_ 551—( Plug Integrity ❑ BOP Test 2/ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 35�-6 c .5` Pr-- 7 Si...,-.�„ T��u- reel .4 P.e.r farms.-. �e-t Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: 1O –Vo 7 04'4-'49 W 4-7--a;st--) APPROVED BY ‘'47 Approved by: P '/SF's- COMMISSIONER THE COMMISSION Date: /D ,/ 26 64 il•/Y Submit Form and Form 10-403(Revised 10/2012) Rilt at C#tly�i valid for 12 months from the date of a al. Attachments in Duplicate I i'N H� RSC OCT 2 0 2� � r .. • Well Prognosis Well: Paxton#7 Hilcorp Alaska,LL Date: 10/9/2014 Well Name: Paxton#7 API Number: 50-133-20643-00 Current Status: Drilling Production Hole Leg: Estimated Start Date: October 14, 2014 Rig: Saxon 147 t Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-130 First Call Engineer: Paul Chan (907)777-8333 (0) (907) 345-3161 (H) (907)444-2881 (C) Second Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (C) AFE Number: 1412365C Estimated Bottom Hole Pressure: -1,511 psi at 2,476 TVD (Assumed 0.43 psi/ft gradient) Max. Anticipated Surface Pressure: -1,263 psi (0.10 psi/ft gas gradient) Brief Well Summary Paxton#7 is a grass roots welled currently being drilled by the Saxon 147 rig. 9-5/8" surface casing has been set and the rig was drilling the 8-1/2" hole section when a lost circulation zone was encountered and the BHA became stuck. The drill string has been recovered and the plan is to run 5-1/2" production to the top of the fish. The original plan was to have the Moncla 401 rig run the completion after the well was cased and cemented, but Hilcorp AK has decided to have Saxon 147 run the completion. Objective of Work Run GR/CCL/CBL/Neutron log after Saxon runs and cements the 5-1/2" long string. Complete the well with 2- /8" tubing and jewelry. Completion Procedure: 1. Test 2-7/8' x 5-1/2"VBR with a 2-7/8"test joint to 250 psi low/3,500 psi high. LD test joint. 2. PU bit and scraper for 5-1/2" 17#casing on 2%8"tubing string. Rabbit the tubing before RIH 3. RIH and reciprocate scraper across packer set depth by making a 4 stand short trip from 2050'to 2300' 2 times(packer set depth of 2170' MD from proposed directional plan). Continue RIH to -3450' PBTD and circulate the hole clean at maximum rate with 120°F heated brine. 4. POOH and stand back tubing. 5. MIRU e-line. PT to 250 psi low/3500 psi high. 6. Run GR/CCL/CBL/Neutron logs on rollers: a. Run Neutron log from PBTD to-2200' MD. b. Run GR/CCL from PBTD to surface. All 5-1/2" casing/tubing details should be notated on the log(RA tags and marker joints, see schematic and casing/cementing report for details). c. Run CBL cement bond log with GR/CCL from PBTD to 1436' MD(500' above 9-5/8" shoe). Depending upon results from the initial CBL run, a pressure pass may also be required. 7. RDMO e-line • Well Prognosis Well: Paxton#7 Hilcorp Alaska,LL Date: 10/9/2014 8. RIH with 2-7/8' tubing to 2200' MD and reverse circulate in 33 bbls of 8.6 ppg KCI brine with 15 gals of corrosion inhibitor. POOH and stand back tubing. 9. Prepare to PU tubing. Run 2-%8' 6.4#L-80 tubing w/packer and 2%8"tailpipe as detailed below. Rabbit the tubing and jewelry before RIH. RU control line spoolers as needed. • 2-7/8' WLEG @ —2,245' MD with shear disk • 1 joint 2-7/8" 6.4# L-80 tubing • 1 joint 2-7/8' 6.4#L-80 tubing • 5-%2'x 2-%8" Hydraulic set packer w/handling pups set at^'2,170' MD • 2-%8' 6.4#L-80 tubing • 10' 2-%8' 6.4#L-80 handling pupS� • 2-%8"TRSV @"'160' MD Sc • 10'21V16.4# L-80 handling pup • 10' 2%8" 6.4# L-80 handling pup • 2-7/8' Chemical injection sub @ —130' MD • 10' 2-7/8' 6.4# L-80 handling pup • 4 joints 2-%8' 6.4# L-80 tubing • Tubing hanger with handling pup 10. RIH with completion. Record PU and SO weights. Fill tubing every stand. 11. MU tubing hanger,control lines, and landing joint. 12. Land tubing hanger and RILDS. LD landing joint. Test tubing hanger packoff. 13. Pressure up on the tubing and set the packer. 14. Test tubing to 3,500 psi for 30 min. Bleed off pressure to 1500 psi. ,/ 15. Test the IA to 2,000 psi for 30 min. Bleed off IA. 16. Increase tubing pressure to 4500 psi and shear the disk. Bleed off tubing pressure. 17. Set TWC. ND BOPE. NU adapter flange and tree. PT tree. RU lubricator and pull TWC. Coiled Tubing Procedure 18. RU CTU, nitrogen, and flow back tanks. Notify AOGCC 24 hours prior to testing at http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html 19. Shell test BOPE/lubricator to 250psi low/4,500psi high(unless due for weekly BOPE test—then a full BOPE test will be done). 20. RIH with CT and blow the well dry with nitrogen. Strap tank before and after blowing the well down. 21. Leave well with SITP of 2,000 psi. POOH. 22. RDMO CTU. Attachment: Proposed Wellbore Schematic 0 Ninilchik Unit 1 tanned (Rev1) well: Paxton #7 PTD: 214-130 API: 50-133-20643-00 Hilairp Alaska,1.1A: CASING DETAIL 16" d 'L Size Type Wt Grade Conn. ID Top Btm Mud Weight Conductor— 16" Driven to Set 109 X-56 Weld 16" Surf 80' 2 r Depth I � `• 9-5/8" Surf.Csg 40 L-80 BTC 8.835" Surf 1936' 8.8 ppg • 1 t , 5-1/2" Prod Casing 17 P-110HC DQX 4.892" Surf 3,516 9.5 ppg TUBING A 2-7/8" Production 6.4 L-80 EUE-8rd 2.441" Surf 2245' f 9-5/8" Drilling Info Hole Section Casing MW Workstring a ® 12-1/4" 9-5/8" 8.8 ppg 4-1/2" 3 *,, 8-1/2" 5-1/2" 9.5 ppg 4-1/2" 4 , . x" JEWELRY DETAIL w No. Depth ID OD Item 1 ^160' SCSSV 4 2 -130' CIM 3 "'2170' Prod Pkr 1. . L . 4 "'2345' Wireline re-entry guide ,V1 TOF at 3562' 8-1/2" �� Planned Reservoir Objectives Hole A V.' Zone Top(MD) Top(ND) Est Pressure EMW Gradient W 6 Q k, .k. Top Beluga - 2,100 1419 618 8.3 .43 ;/ w j� It l/ IT t0' Fish details: ‘l ) ( l�' 8-1/2"PDC bit,mud motor,Float sub, stabilizer, Oji MWD collar,Dual gamma ray collar,resistivity collar, Den/Neu collars(with nuclear source),(2)non mag BOF at 3916' flex collars,(4)jts HWDP,jar,(1)jt HWDP. 5.5" J PBTD=3,472 MD/1,834'TVD TD=4,695'MD/2,193'TVD Updated by PC 10/9/2014 x • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday, October 15, 2014 9:44 AM To: 'Paul Chan' Subject: RE: Paxton#7 (PTD 214-130) Paul, Thanks for documenting the phone call to give verbal approval with this email. Guy Schwartz Senior 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.schwartz@alaska.gov). Original Message From: Paul Chan (mailto:pchan@hilcorp.com] Sent:Wednesday, October 15, 2014 9:40 AM To:Schwartz, Guy L(DOA) Subject: FW: Paxton#7(PTD 214-130) Guy I let the rig know that we had verbal approval from the AOGCC to run the completion Thanks Paul Chan Senior Operations Engineer Kenai Asset Hilcorp Alaska LLC (907)777-8333 (w) (907)444-2881 (c) (907) 345-3161 (h) Original Message From: Paul Chan Sent: Monday, October 13, 2014 8:21 AM To:James Lott-(C); Wade Hudgens-(C);Shane Barber- (C) 1 • • • • Cc: Chad Helgeson;Taylor Nasse; Stan Porhola; Luke Keller Subject: FW: Paxton#7(PTD 214-130) James/Shane/Wade I have just received verbal approval from Guy Schwartz to run the completion. Thanks Paul Chan Senior Operations Engineer Kenai Asset Hilcorp Alaska LLC (907)777-8333 (w) (907)444-2881 (c) (907)345-3161 (h) Original Message From:Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, October 13, 2014 8:15 AM To: Paul Chan Subject: Re: Paxton#7 (PTD 214-130) Call me this morning Cell 301-4533 Guy Sent from my iPhone >On Oct 10, 2014, at 5:51 PM, "Paul Chan" <pchan@hilcorp.corn>wrote: >Guy > Hilcorp Alaska respectfully requests a change in the well prognosis(attached)for completing the Paxton#7 well as submitted in the 10-403 Sundry Application dated October 9,2014(attached). Hilcorp AK would like to substitute the previously submitted Well Prognosis with the attached well prognosis. > I have revised the Well Prognosis as follows: > 1) Run the cased hole logs post-rig as e-line tractors are not available in the next few days. Performing the e-line logs post-rig will also allow us to only have to call out the e-line tractor once. Additionally, running the CBL post-rig will allow the cement to develop more compressive strength prior to the logging run. > 2) Set the packer by dropping a ball/rod (instead of using a shear disk). >3) Inserted the slickline and e-line steps to be done post-rig. > I have also included the 10-403 Change Approved Program (because of the fish)for your reference. > Please let me know if the AOGCC concurs with the proposed substitution. 2 • . • 410 • >Additionally,our estimated date to run the completion was October 14, but with the changes in the Well Prognosis, the rig could be running the completion as early as Sunday October 12. I will contact the AOGCC if the completion date is accelerated. >Thanks > Paul Chan >Senior Operations Engineer > Kenai Asset > Hilcorp Alaska LLC >(907) 777-8333 (w) >(907)444-2881 (c) >(907) 345-3161 (h) ><Paxton#7 2014-10 Rig Completion Rev 1.docx><Paxton 7 AOGCC 10-403 >Submitted 10-09-14.pdf> ><10-403 Submittal 10-9-2014.pdf> 3 2\ k3a // THE STAT A.i c L • t l _ _- 333 West SeventY� AvEnue G0vLRN0R STAN 'ARN11 1. Anchorage, Alaska 99501 3572 �?� � 4<y Mc le 907 279 14`.i3 P 907.7;4 I1, Luke Keller Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Ninilchik Field, Beluga Tyonek Gas Pool, Paxton 7 Sundry Number: 314-553 Dear Mr. Keller: Enclosed is the approved application for 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 Chair DATED this JO day of October, 2014. Encl. • ! RECEIVELo STATE OF ALASKA OCT 0 9 2014 o V1ALASKA OIL AND GAS CONSERVATION COMMISSION 67-s 10115r/19 1011611'� APPLICATION FOR SUNDRY APPROVALS AUGO c> 20 AAC 25.280 1.Type of Request: Abandon i'.Plug for Redrill ❑ Perforate New Pool ❑ Repair Well❑ Change Approved Program ❑. Suspend ❑ ' ' Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ a Time Extension ❑ Operations Shutdown ElRe-enterSusp.Well 111 Stimulate ❑ Alter Casing ❑ Other: A 13H4 id 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: AA S,1-4.rc4- i Hilcorp Alaska,LLC Exploratory ❑ Development Q 214-130 ' 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 76 3800 Centerpoint Drive,Ste 1400,Anchorage AK 99503 50-133-20643-00-00 • 664 e./41. 7. If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Not perforating - Paxton#7 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): Fee- Private, ADL384372 - Ninilchik,SD Beluga Undef Gas - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 4695 ft - 2193 ft - 3516 ft 1841 ft None 3,516 Casing Length Size MD TVD Burst Collapse Structural Conductor 139 16 139 139 N/A N/A Surface 1936 9.625 1936 1374 5750 psi 3090 psi Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑✓ Service ❑ 14.Estimated Date for 10/9/2014 . 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas E . WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: AO.cf./II - WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: 5��+�'u r �, GSTOR [11 SPLUG El 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Luke Keller Email Ikeller(c�hilcorp.com Printed Name Luke Keller Title Drilling Engineer 3i S--c..Zr__ (907)777-8395 Date Oct 9th,2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 kms- X53 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No 0 Subsequent Form Required: /0- YO 7(6,-.....,,P W APPROVED BY Approved by: Z4-7 COMMISSIONER THE COMMISSION Date: /0—/ 1 y lb'/ y/lf Submit Form and Form 10-403(Revised 10/2012) GRieftNsAirr 12 months from the date of pproval. / /(Attachments in Duplicate RBL MS OCT 2 0 2014 ., r-;�, '�.to..;�1 410 Luke Keller • Hilcorp Alaska, LLC Drilling Engineer P.O. Box 244027 Anchorage,AK 99524-4027 Tel 907 777 8395 Email Ikeller@hilcorp.com Hilcorp Alaska,11€ October 9th, 2014 RECc Commissioner Alaska Oil &Gas Conservation Commission OCT 0 9 2014 333 W. 7t"Avenue Anchorage, Alaska 99501 AOGCC Re: Paxton#7 Dear Commissioner, Enclosed for review and approval is a 10-403"Abandonment of BHA and Change to Procedure" for the latest plan to complete Paxton#7. While drilling the production hole on Paxton#7 @ 4,695' MD, returns were lost and the BHA subsequently became stuck while attempting to pull out of the hole with the directional/LWD assy. Bottom of the fish is located at 3916', TOF is located at 3562' MD. 6 days were spent trying to free the BHA, but efforts have been unsuccessful. The directional/LWD assembly consists of: 8-1/2" PDC bit, mud motor, Float sub, stabilizer, MWD collar, Dual gamma ray collar, resistivity collar, Den/Neu collars(with nuclear source), (2) non mag flex collars, (4)jts HWDP,jar, (1)jt HWDP. Hilcorp is prepared to abandon further attempts at BHA recovery; and Plug/complete the well as detailed below. There is some encouraging gas pay which exists in the upper Beluga that Hilcorp would like to make attempts at producing. 1. Conduct another back-off at screw in sub at 3,562' MD. 2. TOH and L/D fishing assy. 3. M/U 8-1/2"clean out BHA and clean out wellbore to TOF at 3,562' MD. 4. Run 5-1/2"casing with 90'shoe track to TOF. 5. Conduct primary cmt job with 15.2 ppg slurry to surface. Cmt calculations as follows: If you have any questions, please don't hesitate to contact myself at 777-8395 or Paul Mazzolini at 777-8369. Sincerely, Luke Keller Drilling Engineer Hilcorp Alaska,LLC Page 1 of 1 • • rAlaska , LLC 111 ��il�o Paxton #7 BHA Abandonment & Casing Running Procedure Ninilchik Field Version 1 Oct 9th, 2014 • • Paxton #7 Hifrorp Alaska,LLC 1.0 Wellbore Prep for running casing. 1.1 Back off from fish, TOH & L/D fishing assy, DCs, and extra HWDP. 1.2 M/U clean out assy: • TIH to TOF at 3,562' MD. • CBU, rotate and reciprocate string. • TOH and L/D drill pipe and BHA. 1.3 Install and test 5-1/2"casing rams. Test to 3500 psi. 2.0 Run 5-1/2" Production Casing 2.1 R/U 5-1/2"casing running equipment. • Ensure 5-1/2" CDC x CDS 40 crossover on rig floor and M/U to FOSV. • R/U fill up line to fill casing while running. • Ensure to R/U Tesco or Weatherford CRT so that string can be rotated if necessary while running. • Ensure all casing has been drifted on the deck prior to running. • Be sure to count the total# of joints on the deck 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. 2.2 P/U shoe joint, visually verify no debris inside joint. 2.3 Continue M/U&thread locking shoe track assy consisting of: • (1) Shoe joint w/ shoe bucked on&threadlocked(coupling also thread locked). Install (2) solid body centralizers on shoe joint prior to bucking on float shoe. The centralizers should be held in place 10' from each end via stop rings on either side. • (1) Thread locked joint(coupling thread locked). • (1) Joint with float collar bucked on pin end &threadlocked (coupling also thread locked). Install (1) solid body centralizer on float collarjoint prior to bucking on float collar. • Install a solid body centralizer on landing collar joint. Leave centralizers free floating so that they can slide up and down the joint. • Ensure proper operation of float shoe and float collar prior to running in the hole. 2.4 Continue running 5-1/2"prod casing. • Fill casing while running using fill up line on rig floor. • Use"Best 0 Life 2000"thread compound. Dope pin end only w/paint brush. • Install solid body centralizers on every joint to 2,000 MD. None above 2000'. Leave the centralizers free floating. • Paxton #7 Drilling & Completion Procedure 1{ilcorp Alaska,LLC • Utilize a collar clamp until weight is sufficient to keep slips set properly. 5-1/2" CDC M/U torques Casing OD Minimum Maximum Yield Torque 5.5" 12,000 ft-lbs 13,800 ft-lbs 15,500 ft-lbs Technical Specifications Connection Type: Size(O.D.): Weight(Wail): Grade: ID /C Casing 5-1/2 in 17.00 Ibltt(0.304 in) P-110 standard Material A P-110 Grade 110,000 Minimum Yield Strength(psi) seminionowLISA 125,000 Minimum Ultimate Strength(psi) V e SA 4424 W Sem Houston Pte,Suva 150 Pipe Dimensions Housian,TX 77041 5.500 Nominal Pipe BodyU.D. n Fox;7 .7-79 234 4 4.892 Nominal Pipe Body LD.(in) e-knalL VJMUS:+ APne arn-U$® 0.304 Nominal Wall Thickness(In) 17.00 Nominal Weight(Ibs/tt) 16.89 Plain End Weight Obs/R} re 4.962 Nominal Pipe Body Area(sq in) Pipe Body Performance Properties 4 + 548,000 Minimum Pipe Body Yield Strength(Itis) 7,480 Minimum Collapse Pressure(psi) 10,840 Minimum Internal Yield Pressure(psi) 9,700 Hydrostatic Test Pressure(psi) Connection Dimensions a, 6.050 Connection Q.D.(in) 4.892 Connection I.D.(in) 4./767 Connection Drift Diameter(in) 4.13 Make-up Loss On) 4,962 Critical Area(sq in) 100.0 Joint Efficiency(%) Connection Performance Properties 546,000 Joint Strength(lbs) 22.,940 Reference String Length(ft) 1.4 Design Factor 568,000 API Joint Strength(lbs) L . 546,000 Compression Rating(lbs) 7,480 API Collapse Pressure Rating(psi) 10,640 API Internal Pressure Resistance(psi) 917 Maximum Uniaxial Bend Rating(degrees/100 ft) Appoximated Field End Torque Values 12,000 Minimum Final Torque(ft-lbs) 13,800 Maximum Final Torque(11-lbs) 15,500 Connection Yield Torque(ft-lbs) Page 2 Version 1 July,2014 . • Paxton#7 Drilling &Completion Procedure Hilcorp Alaska,LLC 2.5 M/U casing hanger joint to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe approx 10—20' above TD. Strap the landing joint while it is on the deck and mark the joint at(1) ft intervals to use as a reference when landing the hanger. 2.6 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 2.7 R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat(slightly)to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 2.8 After circulating, lower string and land hanger in wellhead again. Page 3 Version 1 July,2014 • • Paxton#7 Drilling & Completion Procedure Hi'carp Alaska,LLC 3.0 Cement 5-1/2" Production Casing 3.1 Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud& water can be delivered to the cmt unit at acceptable rates. • How to handle cmt returns at surface, regardless of how unlikely it is that this should occur. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cmt operation. • Document efficiency of all possible displacement pumps prior to cement job. 3.2 Attempt to reciprocate the casing during cmt operations. 3.3 Pump 5 bbls 10 ppg SealBond spacer. 3.4 Test surface cmt lines to 4500 psi. 3.5 Pump remaining 15 bbls 12 ppg SealBond spacer. 3.6 Mix and pump lead and tail cmt per below recipe. Ensure cmt is pumped at designed weight. Job is designed to pump 100% OH excess. 441% ¢ UtriliMagWa‘ � � 4114 B b 9-5/8"x 5-1/2" Overlap: 1936' x 0.046= 89 500 8-1/2"OH x 5-1/2" Long String: (3,516— 1,936')x 0.0408 x 2 = 129 724 Shoe Track(Tail): 90' x 0.023 = 2.1 12 Total Volume (Tail): 218 1236 Page 4 Version 1 July,2014 • i r Paxton #7 Drilling &Completion Procedure Iliicorp Alaska,LLC System Conventional Density 15.2 lb/gal Yield 1.25 ft3/sk Mixed Water 5.7 gal/sk Mixed Fluid 5.71 gal/sk Code Description Concentration Type1 Cement 941b/sk WBWOB Static Free De-Foamer 0.005 lbs/sk R-3 Retarder 0.9%bwoc CD-32 Dispersant 0.6% bwoc Additives FP-6L De-Foamer 1 gal/100 sk Bonding BA-10A 1% bwoc agent Na Extender 0.5%bwoc Metasillicate 3.7 Drop top plugdart and displace with 6%KCl. 3416' x .023 =79 bbls 3.8 Do not overdisplace by more than %2 shoe track. Shoe track volume is 1.7 bbls. 3.9 Bleed pressure to zero to check float equipment. 3.10 Pressure up again to 3500 psi and hold for 30 min to test production bore. Page 5 Version 1 July,2014 • • Paxton #7 Drilling & Completion Procedure Iiilcarp Alaska,LLC 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 a. Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid b. Note if casing is reciprocated or rotated during the job c. Calculated volume of displacement,actual displacement volume,whether plug bumped&bump pressure,do floats hold d. Percent mud returns during job,if intermittent note timing during pumping of job.Final circulating pressure e. Note if pre flush or cement returns at surface&volume f. Note time cement in place g. Note calculated top of cement h. Add any comments which would describe the success or problems during the cement job Send final "As-Run" casing tally &casing and cement report to lkeller@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC 4.0 Completion Ops 18.1 A separate sundry is being prepared(10-9-2014)which details the running of the the production tubing and completion of the well. 18.2 A general completion procedure is as follows: • Make scraper run to PBTD with 2-7/8"prod tubing. • Run CBL • Run 2-7/8"production tubing • RDMO drilling rig • Perforate well(rigless) 18.3 Saxon rig#147 will be used to complete the wellbore. Page 6 Version 1 July, 2014 • • • HALLIBURTON DIRECTIONAL SURVEY REPORT Hilcorp Alaska, LLC Paxton#7 Ninilchik Kenai Borough Alaska USA AK-XX-0901508043 Surveys from surface to TD are Sag corrected. Final survey is a projection to TD. Measured Vertical Vertical Depth Inclination Direction Depth Latitude Departure Section Dogleg (feet) (degrees) (degrees) (feet) (feet) (feet) (feet) (deg/100ft) 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 TIE-IN 18.50 0.00 0.00 18.50 0.00 N 0.00 E 0.00 0.00 185.82 0.34 64.76 185.82 0.21 N 0.45 E 0.19 0.20 215.54 0.76 51.43 215.54 0.37 N 0.68 E 0.34 1.48 276.07 1.22 39.38 276.06 1.12 N 1.40 E 1.06 0.83 339.14 2.33 22.42 339.10 2.82 N 2.32 E 2.73 1.92 397.44 3.70 13.93 397.32 5.75 N 3.22 E 5.61 2.47 458.62 5.05 359.81 458.32 10.35 N 3.69 E 10.19 2.80 523.18 7.46 357.03 522.49 17.38 N 3.46 E 17.22 3.76 585.40 10.79 355.82 583.91 27.22 N 2.83 E 27.08 5.37 646.59 14.82 355.40 643.57 40.74 N 1.78 E 40.63 6.58 709.13 19.18 355.24 703.36 58.95 N 0.29 E 58.89 6.97 773.36 23.15 351.84 763.25 81.97 N 2.38 W 82.00 6.47 835.94 26.56 351.54 820.03 108.00 N 6.19 W 108.16 5.45 899.26 31.60 351.29 875.34 138.42 N 10.79 W 138.75 7.97 963.27 35.30 352.45 928.75 173.35 N 15.76 W 173.85 5.85 1027.12 37.81 353.40 980.03 211.08 N 20.43 W 211.74 4.03 1090.59 41.08 355.55 1029.04 251.21 N 24.28 W 251.99 5.59 1152.47 45.14 356.49 1074.21 293.39 N 27.20 W 294.26 6.65 1215.63 50.66 357.54 1116.53 340.17 N 29.63 W 341.10 8.82 1278.59 55.38 357.93 1154.40 390.41 N 31.61 W 391.38 7.51 1341.03 59.78 358.43 1187.86 443.08 N 33.28 W 444.08 7.08 1404.49 64.51 358.53 1217.50 499.15 N 34.76 W 500.16 7.46 1467.85 67.70 358.41 1243.16 557.05 N 36.31 W 558.08 5.03 1529.94 71.02 358.43 1265.05 615.13 N 37.91 W 616.17 5.35 1593.05 73.61 358.79 1284.22 675.23 N 39.37 W 676.28 4.14 1656.07 74.09 359.22 1301.75 735.76 N 40.42 W 736.80 1.01 1720.09 74.22 359.86 1319.23 797.34 N 40.91 W 798.35 0.98 1783.28 75.23 0.22 1335.87 858.30 N 40.87 W 859.25 1.69 1845.39 75.63 0.46 1351.49 918.41 N 40.52 W 919.30 0.74 1906.55 75.25 0.46 1366.87 977.61 N 40.04 W 978.42 0.62 1937.95 75.11 0.21 1374.90 1007.96 N 39.86 W 1008.75 0.90 2002.37 73.89 359.17 1392.11 1070.03 N 40.19 W 1070.78 2.45 2065.55 73.94 359.12 1409.61 1130.74 N 41.10 W 1131.47 0.11 2128.48 73.03 358.34 1427.50 1191.05 N 42.44 W 1191.79 1.88 2191.87 72.73 357.88 1446.16 1251.60 N 44.44 W 1252.37 0.84 2255.32 72.68 357.88 1465.03 1312.14 N 46.68 W 1312.95 0.08 2317.10 72.59 357.45 1483.47 1371.06 N 49.08 W 1371.91 0.67 2380.86 72.51 357.07 1502.59 1431.81 N 51.98 W 1432.74 0.59 2443.51 72.34 357.19 1521.50 1491.46 N 54.97 W 1492.46 0.33 2507.27 72.50 357.14 1540.76 1552.17 N 57.98 W 1553.24 0.26 2570.91 72.38 357.08 1559.96 1612.77 N 61.04 W 1613.92 0.21 2634.26 72.28 356.94 1579.19 1673.05 N 64.19 W 1674.27 0.27 2698.39 72.84 357.35 1598.41 1734.15 N 67.24 W 1735.45 1.07 2761.66 72.79 357.02 1617.10 1794.53 N 70.20 W 1795.89 0.50 2824.74 73.00 357.87 1635.65 1854.76 N 72.89 W 1856.18 1.33 2888.87 73.35 357.60 1654.22 1916.09 N 75.31 W 1917.57 0.68 2951.83 73.32 357.46 1672.27 1976.35 N 77.91 W 1977.88 0.22 3015.19 73.34 357.05 1390.44 2036.98 N 80.82 W 2038.58 0.62 3078.65 73.25 356.92 1708.66 2097.68 N 84.02 W 2099.36 0.24 •]A An no '17 40 .]GC GA 4,0,/I7 •IAGO 4A 1.1 OW GA 1A1 0ACO 04 O Cr 3331.94 71.98 358.gek 1784.75 2338.99 N 94.67 Vii 2340.91 0.19 33,96.01 72.00 358. 1804.56 2399.91 N 96.04 2401.82 0.65 3459.31 72.14 358.48 1824.05 2460.11 N 97.63 W 2462.04 0.23 3520.19 72.12 358.14 1842.73 2518.03 N 99.34 W 2519.98 0.53 3584.42 72.00 357.75 1862.51 2579.10 N 101.53 W 2581.09 0.61 3647.83 71.87 357.70 1882.18 2639.33 N 103.93 W 2641.37 0.22 3711.33 72.75 357.85 1901.47 2699.78 N 106.27 W 2701.87 1.42 3774.27 72.85 357.43 1920.09 2759.86 N 108.75 W 2761.99 0.67 3837.63 72.77 357.27 1938.81 2820.32 N 111.55 W 2822.52 0.26 3900.83 72.75 357.04 1957.55 2880.61 N 114.54 W 2882.88 0.36 3963.95 72.72 357.24 1976.28 2940.81 N 117.55 W 2943.15 0.31 4027.26 72.66 356.87 1995.12 3001.17 N 120.66 W 3003.59 0.56 4089.73 72.57 356.45 2013.78 3060.69 N 124.13 W 3063.20 0.66 4153.00 72.53 356.56 2032.75 3120.93 N 127.81 W 3123.55 0.19 4215.94 72.34 356.19 2051.75 3180.82 N 131.60 W 3183.54 0.63 4279.09 72.77 356.96 2070.68 3240.95 N 135.20 W 3243.77 1.34 4342.24 72.66 356.42 2089.45 3301.15 N 138.68 W 3304.06 0.84 4405.56 73.01 357.65 2108.14 3361.57 N 141.81 W 3364.56 1.93 4468.30 72.95 358.06 2126.50 3421.52 N 144.05 W 3424.55 0.63 4531.84 72.85 357.36 2145.19 3482.20 N 146.48 W 3485.28 1.06 _ 4595.38 72.80 357.39 2163.95_ 3542.84 N 149.26 W 3545.98 0.09 CALCULATION BASED ON MINIMUM CURVATURE METHOD SURVEY COORDINATES RELATIVE TO WELL SYSTEM REFERENCE POINT TVD VALUES GIVEN RELATIVE TO DRILLING MEASUREMENT POINT VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION IS COMPUTED ALONG A DIRECTION OF 357.64 DEGREES(TRUE) A TOTAL CORRECTION OF 16.60 DEG FROM MAGNETIC NORTH TO TRUE NORTH HAS BEEN APPLIED HORIZONTAL DISPLACEMENT IS RELATIVE TO THE WELL HEAD. HORIZONTAL DISPLACEMENT(CLOSURE)AT 4595.38 FEET IS 3545.98 FEET ALONG 357.59 DEGREES(TRUE) Surveys from surface to TD are Sag corrected. Final survey is a projection to TD. Date Printed:04 October 2014 i Ninilchik Unit lanned (Rev1) Well: Paxton #7 PTD: 000-000 API: 50-000-00000-00 nilcorp Alaska,LLC CASING DETAIL ,x;. Mud 16' , � . Size Type Wt Grade Conn. ID Top Btm Weight .•. . r Conductor— 14.0 i 16" Driven to Set 109 X-56 Weld 16" Surf 80' Depth p y *, •r,,, 9-5/8" Surf.Csg 40 L-80 BTC 8.835" Surf 1936' 8.8 ppg •;•' 5-1/2" Prod Casing 17 P-110HC DQX 4.892" Surf 3,516 9.5 ppg iV,4 j TUBING i J 2-7/8" Production 6.4 L-80 IBT 2.441" Surf 2220' :V ,ra I 1' - ' Drilling Info T Hole Section Casing MW Workstring 1 f , 12-1/4" 9-5/8" 8.8 ppg 4-1/2" r ,. 8-1/2" 5-1/2" 9.5 ppg 4-1/2" 4,r r�" 1 •. JEWELRY DETAIL � ' , � 1 No. Depth ID OD Item 1 'l'*':111 t,--1 4i 1 150' SCSSV `° 2 2000' CIM x �' 3 3 2200' Prod Pkr "" - ' 4 2220' Wireline re-entry guide YI—c7pr/ , TOF at 3562' Planned Reservoir Objectives / Hole \� 1 ,01/ Zone Top(MD) Top(ND) Est Pressure EMW Gradient y �,C'' Y,:, Top Beluga 2,100 1437 618 8.3 .43 n\`It r , 1 // Y I� 11 BILI',, I W 6' \ .x\,,,,,,,.1 1 0 , Fish details: \ if 8-1/2"PDC bit,mud motor,Float sub,stabilizer, MWD collar,Dual gamma ray collar,resistivity collar, Den/Neu collars(with nuclear source), (2)non mag .— BOF at 3916' flex collars,(4)jts HWDP,jar, (1)jt HWDP. ss PBTD=3,472 MD/1,834'TVD TD=4,695'MD/2,193'TVD Updated by LEK 10/9/2014 • • 4 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday, October 09, 2014 11:11 AM To: 'Luke Keller' Cc: James Lott- (C); Paul Mazzolini; Luke Saugier;Jeff Allen; David Buthman; Shane Barber- (C) Subject: RE: Paxton #7 (PTD#:214-130) Forward Plan Luke, You have verbal approval to abandon BHA with nuclear source as proposed below. Make sure NRC is also notified and aware of your plan to leave a RA source in wellbore. The final schematic should clearly indicate that there is a BHA(with Nuclear source) directly below the casing shoe so nobody tries to drillout the casing shoe in the future. Guy Schwartz Senior 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(Guv.schwartz@alaska.gov). From: Luke Keller [mailto:Ikeller@hilcorp.com] Sent: Thursday, October 09, 2014 9:34 AM To: Schwartz, Guy L(DOA) Cc: James Lott- (C); Paul Mazzolini; Luke Saugier; Jeff Allen; David Buthman; Shane Barber- (C) Subject: Paxton #7 (PTD#: 214-130) Forward Plan Guy, While drilling the production hole on Paxton#7 @ 4695' MD, returns were lost and the BHA subsequently became stuck while attempting to pull out of the hole with our directional/ LWD assy. Bottom of the fish is at 3916',TOF is at 3562' MD. We have spent the last 6 days trying to free the BHA, but have been unable to do so. The directional/LWD assembly consists of:8-1/2" PDC bit, mud motor, Float sub,stabilizer, MWD collar, Dual gamma ray collar, resistivity collar, Den/Neu collars(with nuclear source), (2) non mag flex collars, (4)jts HWDP,jar, (1)jt HWDP. V We are ready to abandon further attempts at BHA recovery; and Plug/complete the well as detailed below. There is some encouraging gas pay that exists in the upper Beluga which we still have access to. 1. Conduct another back-off at screw in sub at 3,562' MD. 2. TOH and L/D fishing assy. 3. M/U 8-1/2" clean out BHA and clean out wellbore to TOF at 3,562' MD. 4. Run 5-1/2"casing with 90'shoe track to TOF. 5. Conduct primary cmt job with 15.2 ppg slurry to surface. Cmt calculations as follows: Section: Calculation: Vol (BBLS) Vol (ft3) 9-5/8" x 5-1/2" Overlap: 1936' x 0.046 = 89 500 8-1/2" OH x 5-1/2" casing: (3,516— 1,936')x 0.0408 x 2= 129 724 Shoe Track: 90' x 0.023 = 2.1 12 • S We feel that this will be an effective, permanent abandonment of the BHA and by pumping some extra cmt we should have cement that also travels downward across the BHA to provide effective long term isolation. I will follow up this email with a 10-403 sundry to incorporate these changes to procedure and abandonment of directional/LWD drilling assy. Thank you, Luke Keller Drilling Engineer Hilcorp Alaska, LLC 907-777-8395 2 OF 747r 0 0 , , ,,,,cot'-,1',1%%% �, THE STATE i6,±aE P , cJi.1_ .,ract It 5 _ 333 West Seventh Avenue i' � GOVERNOR SF AN PARNEI 1 Anchorage Alaska 99501-3572 1 `_* Male: 907.279 ,z33 A .AS1°> ,es 9C 276.,`, Luke Keller Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Ninilchik Field, SD Beluga Undefined Gas Pool, Paxton#7 Hilcorp Alaska, LLC Permit No: 214-130 Surface Location: 3016' FEL, 855' FNL, SEC. 13, T1S, R14W, SM, AK Bottomhole Location: 498' FNL, 2067' FWL, SEC. 12, T1S, R14W, SM, AK Dear Mr. Keller: Enclosed is the approved application for permit to drill the above referenced development well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce is contingent upon issuance of a conservation order approving a spacing exception. Hilcorp Alaska, LLC assumes the liability of any protest to the spacing exception that may occur. 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 a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, .0./I- -7 Daniel T. Seamount, Jr. Commissioner DATED this ay of August, 2014. s. ._L -teeiil I V :CO STATE OF ALASKA A CA OIL AND GAS CONSERVATION COMNIDON AUG i 4 2014 PERMIT TO DRILL � 20 AAC 25.005 ' F�''1 "' la.Type of Work: 1 b. Proposed Well Class: Development-Oil ❑ Service- Winj 9 Single Zone 9 . lc.Specify if well is proposed for: Drill 9• Lateral 9 Stratigraphic Test 9 Development-Gas❑Q • Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redril❑ Reentry ❑ Exploratory ❑ Service- WAG 9 Service-Disp ❑ Geothermal 9 Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 0 Single Well 9 11.Well Name and Number: Hilcorp Alaska,LLC Bond No. 022035244 •• Paxton#7- 3.Address: 6. Proposed Depth: 12. Field/Pool(s): 3800 Centerpoint Drive Ste 1400,Anchorage AK 99503 MD: 7,098' . TVD: 3,500' . Ninilchik 4a. Location of Well(Governmental Section): 7.Property De--irJination(Lease Number): Ninilchik,SD Beluga Undef Gas- Surface: 3016'FEL,855'FNL,Sec 13,T1S,R14W,AK,SM t�,fr/t'Q$_ADL384372 /15 4,L•>'(/ Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 260'FSL,2154'FWL,Sec 12,T1S,R14W,SM,AK Surface agreement w/parcel fee owner 9/14/2014 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 498'FNL,2067'FWL,Sec 12,T1S,R14W,SM,AK 3507.84(ADL 384372) ' 4,715.43 to Unit Boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 166.6 feet• 15.Distance to Nearest Well Open Surface: x-206309 - y-2230478 . Zone-4 GL Elevation above MSL: 148 feet . to Same Pool: 2658'to Paxton 4 16.Deviated wells: Kickoff depth: 251 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 73 degrees Downhole: 1,15.515ir t!i// Surface:154-rjisi //5S ,/ 5 2 -/yZ 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Cond 16" 109 X-56 Weld 80' Surf Surf 80' 80' Driven 12-1/4" 9-5/8" 40 L-80 BTC 2,000' Surf Surf 2,000' 1,407' 180bbl/1011ft3 8-1/2" 5-1/2" 17 P-110 CDC 7,098' Surf Surf 7,098' 3,500' 295.7bbl/1660.7ft3 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat Q BOP Sketch Q Drilling Program Q Time v.Depth Plot Q Shallow Hazard Analysis❑ Diverter Sketch 0 Seabed Report 9 Drilling Fluid Program Q 20 AAC 25.050 requirements9 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Luke Keller Email Ikeller@hilcorp.com Printed Name Luke Kelle Title :::::::er ia.s. Signature Phone Date 8/14/2014 Commission Use Only Permit to Drill ,-, i,,/i.go, API Number / Permit Approval /I See cover letter for other Number: 50-t J 013 ice- ,/'a✓ Date: j JYJ requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: 3 Other: 5 sc r %,',T Samples req'd: Yes 9 Nos Mud log req'd:Yes❑ No Q' H2S measures: Yes 9 NoP Directional svy req'd:YesJf ' No❑ J �a r e_., r)--,,, - .27A. Spacing exception req'd: Yes[s]' No❑ Inclination-only svy req'd:Yes❑ No[a" APPROVED BY J Approved by: de)d/-------..... ....147 COMMISSIONER THE COMMISSION Date: 411/2d 12 " /,/ Submit Form and Form 10-401( vised 10/2012) This perm vR tf3 riot( s At:date of approval(20 AAC 25.005(g)) Attachments in Duplicate III Luke Keller 4111 Hilcorp Alaska, LLC 111 Drilling Engineer P.O. Box 244027 Anchorage, AK 99524-4027 Tel 907 777 8395 j'' +"- P°s Email Ikeller@hilcorp.com AUG 14 2014 August 14, 2014 AOGCC Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: Paxton#7 Dear Commissioner, Enclosed for review and approval is the application for the Permit to Drill the Paxton#7 Development gas well. Paxton #7 is a twin to the Paxton 3 Beluga 50 gas sandstone. The base plan is an S-turn wellbore with a shallow kickoff at 251' MD, building up to a maximum inclination of 73 deg, then dropping back to 32 degrees by TD. Drilling operations are expected to commence approximately Sept 14th, 2014. The Saxon Rig# 147 will be used to drill and case the wellbore with the 5-1/2" long string. All known potential fresh water zones exist above 200'. This information is based off salinity calculations of neighboring water wells. Chlorides are 1100 ppm at the 171 — 194' sand, 1800 ppm at the 505—535' sand, and 6000 ppm at the 1040' sand. Furthermore, the TGAS (total gas)curve from offset mud logs begins registering shallow gas at depths just below the sandstone bed at 200'. . / Surface casing will be run to 2,000' MD / 1,407' TVD and cemented to surface to ensure protection of these resources. Cement returns to surface will confirm TOC at surface. If cmt returns to surface are not observed, a Temp log will be run between 6— 18 hrs after CIP to determine TOC. Necessary remedial action will then be discussed with AOGCC authorities. 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. If you have any questions, please don't hesitate to contact myself at 777-8395 or Paul Mazzolini at 777-8369. Sincerely, /1/......" Luke Keller Drilling Engineer ` Hilcorp Alaska, LLC Page 1 of 1 ■ • • Hilcorp Alaska, LLC Paxton #7 Drilling & Completion Program Ninilchik Field Version 1 July 31St, 2014 • • Paxton #7 Drilling Procedure Hiirorp Alaska,LLC Contents 1.0 Well Summary 2 2.0 Management of Change Information 3 3.0 Tubular Program: 4 4.0 Drill Pipe Information: 4 5.0 Internal Reporting Requirements 5 6.0 Planned Wellbore Schematic 6 7.0 Drilling/Completion Summary 7 8.0 Mandatory Regulatory Compliance/Notifications 8 9.0 R/U and Preparatory Work 10 10.0 N/U 21-1/4"2M Diverter 11 11.0 Drill 12-1/4"Hole Section 14 12.0 Run 9-5/8" Surface Casing 18 13.0 Cement 9-5/8" Surface Casing 21 14.0 BOP N/U and Test 24 15.0 Drill 8-1/2"Hole Section 25 16.0 Run 5-1/2"Production Casing 30 17.0 Cement 5-1/2"Production Casing 33 18.0 RDMO 36 19.0 Perf and Frac 36 20.0 BOP Schematic 37 21.0 Wellhead Schematic 38 22.0 Days Vs Depth 39 23.0 Formation Tops 40 24.0 Anticipated Drilling Hazards 41 25.0 Saxon Rig 147 Layout 43 26.0 FIT Procedure 44 27.0 Choke Manifold Schematic 45 28.0 Casing Design Information 46 29.0 8-1/2"Hole Section MASP 47 30.0 Spider Plot(NAD 27) (Governmental Sections) 48 31.0 Surface Plat(As Staked) (NAD 27) 49 32.0 Offset MW vs TVD Chart 50 33.0 Drill Pipe Specification Sheet 51 • • Paxton #7 Drilling & Completion Procedure Rilcorp Alaska,LLC 1.0 Well Summary Well Paxton#7 Pad&Old Well Designation Paxton#7 is a grass roots well on the Paxton Pad. 2-7/8"Production tubing, SCSSV at 150', CIM above Planned Completion Type packer. Target Reservoir(s) Beluga/Tyonek. Planned Well TD,MD/TVD 7,098' MD/3,500' TVD. - PBTD,MD/TVD 7,000' MD/3,418' TVD. Surface Location(Governmental) 3016' FEL, 855' FNL, Sec 13, T1S,R14W,AK, SM Surface Location(NAD 27) X=206309,Y=2230478 • Surface Location(NAD 83) Top of Productive Horizon (Governmental) 260'FSL,2154'FWL, Sec 12, T1S,R14W, SM,AK TPH Location(NAD 27) X=206227.52,Y=2231536.46 • TPH Location(NAD 83) BHL(Governmental) 498'FNL,2067'FWL, Sec 12, T1S,R14W, SM,AK BHL(NAD 27) X=206249.71,Y=2236058.85 BBL(NAD 83) AFE Number 1412365D AFE Drilling Days 4 MOB,20 Drlg AFE Completion Days AFE Drilling Amount $4,564,678 AFE Completion Amount Maximum Anticipated Pressure (Surface) 1511 psi(Drilling) Maximum Anticipated Pressure (Downhole/Reservoir) 1155 psi Work String 4-1/2" 16.6# S-135 CDS-40(Saxon Owned String) KB elevation above MSL 18.6' + 148' = 166.6' . GL elevation above MSL 148' - BOP Equipment 11" 5M T3-Energy Annular BOP 11" 5M T3-Energy Double Ram 11" 5M T3-Energy Single Ram Page 2 Version 1 July,2014 . Paxton #7 Drilling & Completion Procedure flavor!)Ala,ka.LLf: 2.0 Management of Change Information Hilcorp Alaska, LLC IIilrorp Alavka, Changes to Approved Permit to Drill Date: 7-31-2014 Subject: Changes to Approved Permit to Drill for Paxton#7 File#: Paxton #7 Drilling and Completion Program Any modifications to Paxton#7 Drilling& Completion Program will be documented and approved Changes to an approved APD will be he BLM and AOGCC. 4277--0 k! �rj tl-cc Sec Page Date Procedure Change Approvec By Approval: Drilling Manager Date Prepared_ Drilling Engineer Date Page 3 Version 1 July, 2014 S • Paxton #7 Drilling & Completion Procedure 1Iil.orp Alaska.U.(: 3.0 Tubular Program: Hole OD (in) ID (in) Drift Conn Wt Grade Conn Burst Collapse Tension Section (in) OD (in) (#/ft) (psi) (psi) (k-lbs) Cond l6" 15" - - 109 X-56 Weld 12-1/4" 9-5/8" 8.835" 8.75" 10.625" 40 L-80 BTC 5750 / 3090 916 8-1/2" 5-1/2" 4.892" 4.767" 6.05" 17 P-110 CDC 10640 ,/ 7480 546 4.0 Drill Pipe Information: Hole OD (in) ID (in) TJ ID TJ OD Wt Grade Conn Burst Collapse Tension Section _ (in) (in) (#/ft) (psi) (psi) _ (k-lbs) All 4.5" 3.826 2.6875" 5.25" 16.6 S-135 CDS40 17,693 16,769 468k All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Version 1 July, 2014 i Paxton #7 Drilling & Completion Procedure Ililcorp Alaska,1,11; 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on Wellez. • Report covers operations from 6am to 6am • 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. • Ensure time entry adds up to 24 hours total. • Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. 5.2 Afternoon Updates • Submit a short operations update each work day to pmazzolini@hilcorp.com, lkeller@hilcorp.com andjbarrett@hilcorp.com 5.3 Intranet Home Page Morning Update • Submit a short operations update each morning by 7am 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. 5.4 EHS Incident Reporting • 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: 0: (907)777-6726 C: (907)227-3189 b. Mark Tornai: 0: (907)283-1372 C: (907) 748-3299 c. Thad Eby: 0: (907)777-8317 C: (907)602-5178 2. Spills: Kate Kaufman: 0:907-777-8329 C:907-244-8292 • Notify Drlg Manager 1. Paul Mazzolini: 0: 907-777-8369 C: 907-317-1275 • Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally • Send final"As-Run"Casing tally to lkeller@hilcorp.com and jbarrett@hilcorp.com 5.6 Casing and Cmt report • Send casing and cement report for each string of casing to lkeller@hilcorp.com and jbarrett@hilcorp.com Page 5 Version 1 July, 2014 • 11 Paxton #7 Drilling & Completion Procedure nikorr,11a,ka.LIA: 6.0 Planned Wellbore Schematic CASING DETAIL .L s:,-....e. M.Lici Type '4'.-. Grace i:::-- ID —CI: weight ondurt.or— 15' Driven to Set 109 ',..E.E. .2+.E: f.E. Surf 5: # #' Depth 1 • .. ,/ 5-5:5# Surf.Csg 40 L-60 ETC 5.555 Surf - ,', Prod Casing 17 R-110HC DZ.,. 4.552 Surf 7..D.2E' 9.5 oos TUBING 3: :-7:E 4, Z-7•5' Production 5.4 L-50 15T 2.441' surf 5::.:',7' TOC ac Drilling info Arfr 41 16-CrtY • , Hole Se:r :- Casing MW W.P.cr-MtEin c-515' 5.5 ppg 4-1/2.' , .. , 4 5-1ff 9.5 fag 4-1/2' JEWELRY DETAIL 4. , Depth ID OD Item 153 SCSSV . .. . •::::, , 2803CIM .; 333-3 Prod Pkr „... 3023 Wireline re-entry guide Hole ... , ?:4:44714: Planned Reservoir Objectives 4 i: :one Top(MD:, Top(TVD) E2t Pressure _ E',' '.. ':Iirif,e-•:. ' ".-''lTop seluga 2.,10D - 1437 5i5 E E 4E • `44,4•'- - '%:. Beluga.50 5,0E5 - .7:.4: 920 E 5 .45 , - Beluga 5'0 5,506 - :475 1055 55 41 .. - ..f •" ,.', . ; .. PBTD=7,000'MD I 3,415'T11) TD=7,093'MD I 3,500'TVD Page 6 Version 1 July, 2014 • Paxton #7 Drilling & Completion Procedure .%!a.k i.IA,c 7.0 Drilling / Completion Summary Paxton#7 is a twin to the Paxton 3 Beluga 50 gas sandstone. The base plan is an S-turn wellbore with a shallow kickoff at 251' MD,building up to a maximum inclination of 73 deg,then dropping back to 32 degrees by TD. • Drilling operations are expected to commence approximately Sept 14th,2014. The Saxon Rig# 147 will be used to drill and case the wellbore with the 5-1/2"long string. All known potential fresh water zones exist above 200'. This information is based off salinity calculations of neighboring water wells. Chlorides are 1100 ppm at the 171 — 194' sand, 1800 ppm at the 505 — 535' sand, and 6000 ppm at the 1040' sand. Furthermore, the TGAS (total gas) curve from offset mud logs begins registering shallow gas at depths just below the sandstone•bed at 200'. Surface casing will be run to 2,000' MD/ 1,407' TVD and cemented to surface to ensure protection of these resources. Cement returns to surface will confirm TOC at surface. If cmt returns to surface are not observed, a Temp log will be run between 6 — 18 hrs after CIP to determine TOC. Necessary remedial action will then be discussed with AOGCC authorities. 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. General sequence of operations: 1. MOB Saxon Rig# 147 to well site 2. N/U 21-1/4"x 2M diverter. 3. Drill 12-1/4"hole to 2000' MD. Run and cmt 9-5/8" surface casing. • 4. N/D diverter,N/U &test 11"x 5M T3-Energy BOP. 5. Drill 8-1/2"hole section to TD. Run and cmt 5-1/2"production long string. 6. N/D BOP,N/U temp abandonment cap, RDMO. Reservoir Evaluation Plan: 1. Surface hole: GR+Res LWD 2. Production Hole: GR+Res+Den/Neu+ Sonic porosity LWD • 3. Mud loggers from spud to TD. Page 7 Version 1 July, 2014 • • Paxton #7 Drilling & Completion Procedure HiIcor!)Aia.ka,1.r,c 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 and completion of Paxton #7. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. • The initial test of BOP equipment will be to 250/3500 psi & subsequent tests of the BOP equipment will be to 250/3500 psi for 5/5 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 AOGCC approved drilling permit is posted on the rig floor and in Co Man office. AOGCC Regulation Variance Requests: • No variance requests at this time. Page 8 Version 1 July, 2014 ! • Paxton #7 Drilling & Completion Procedure Hilcarp Alaska,LLC Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) 12-1/4" • 21-1/4"x 2M Hydril MSP diverter Function Test Only • 11"x 5M T3-Energy(Model 7082)Annular BOP 0 Test:250/3 5050 • 11"x=5M T3-Energy Double Ram (AnnularInitial 2500 psi) o Blind ram in btm cavity • Mud cross 8-1/2" • 11"x 5M T-3 Energy Single Ram • 3-1/8"5M Choke Line Subsequent Tests: • 2-1/16"x 5M Kill line 250/3500 • 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. Regulatory Contact Information: 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 Victoria Ferguson/Petroleum Engineer/(0): 907-793-1247/Email:Victoria.ferguson@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format:http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification/Emergency Phone: 907-793-1236(During normal Business Hours) Notification/Emergency Phone: 907-659-2714(Outside normal Business Hours) Page 9 Version 1 July,2014 • • Paxton #7 Drilling & Completion Procedure Hilcorp Alaska,LLC 9.0 R/U and Preparatory Work 9.1 Set 16" conductor at 60' below ground level. 9.2 Dig out and set impermeable cellar. 9.3 Install Seaboard slip-on 16-3/4" 3M"A" section. Ensure to orient wellhead so that tree will line up with flowline later. 9.4 Level pad and ensure enough room for layout of rig footprint and R/U. 9.5 Layout Herculite on pad to extend beyond footprint of rig. 9.6 R/U Saxon Rig# 147, spot service company shacks, spot & R/U company man &toolpusher offices. 9.7 Mud loggers ARE required on the surface hole section. 9.8 After rig equipment has been spotted, R/U handi-berm containment system around footprint of rig. 9.9 Mix mud for 12-1/4"hole section. 9.10 Set test plug in wellhead prior to N/U diverter to ensure nothing can fall into the wellbore if it is accidentally dropped. 9.11 Install 5-1/2" liners in mud pumps. • TSM 1000 mud pumps are rated at 3633 psi (85%)/333 gpm(100%) with 5-1/2" liners. Page 10 Version 1 July,2014 • • Paxton #7 Drilling & Completion Procedure Mem p 4I ,kA,ILC 10.0 N/U 21-1/4" 2M Diverter 10.1 N/U 21-1/4"Hydril MSP 2M diverter System. • N/U 16-3/4" 3M x 21-1/4" 2M DSA(Hilcorp) on 16-3/4" 3M wellhead. • N/U 21-1/4"diverter"T". • Knife gate, 16"diverter line. • Ensure diverter R/U complies with AOGCC reg 20.AAC.25.035(C). 10.2 Function test diverter. Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. 10.3 Ensure to set up a clearly marked"warning zone" is established on each side and ahead of the vent line tip. "Warning Zone"must include: • A prohibition on vehicle parking • A prohibition on ignition sources or running equipment • A prohibition on staged equipment or materials • Restriction of traffic to essential foot or vehicle traffic only. 10.4 Set 15.375" ID wearbushing in wellhead. Page 11 Version 1 July,2014 • • Paxton #7 Drilling & Completion Procedure riilcnrp;11as1<a.IJC 10.5 Rig&diverter line orientation on Paxton pad: ------------ 1// ,/ f: / �.,� aAXT WELL / PAXTON*5 WE LL c ncEce�tr.R E 13161.03E 1 440,li /f EEJ'iSFAC //\\\ %0'' / 1. \\ ..,Y� 3 PAXTON*8 WELL r '� E.EJ MEG / tom Owed r line 1 / - .�,� "' <'�+4 NAxroNe7wEu '- 1, N4 E S.%0 -a _ •0. . EEY:MEC / r �i 4Soitstv,,,,,i.„ s / 4 Al `' f 4 �� 1 Page 12 Version 1 July,2014 Drilling & CompletioPaxton #7n Procedure Hilt ofp 11.14.a.IAA 10.6 Diverter Schematic fill 1tMU ! I 31: iI [ I Ill Annular Prevcntc-.r 21-`f "2M f r iii iii I!1 all Kn fe Gate $ I 41111 It III •, 16"Diverter line Diverter Tee,21-1,4"x 21-W x 2M wl 16"ANSI 150 outlet II IIaurn irtt 16-%"3M x 21-'W 2M DSA anew r I rte _ � : Seaboard 16-Y3M Or11114' elILi? Casing head Assy Page 13 Version 1 July, 2014 • • II Paxton #7 Drilling & Completion Procedure IIikorir Al„ka,1.r,r, 11.0 Drill 12-1/4" Hole Section. 11.1 P/U 12-1/4" directional drilling assy: • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Workstring will be 4.5" 16.6# S-135 CDS40 • Ensure motor setting can achieve 6 deg/100' DLS in surface hole. Minimum of 1.5 deg AKO is required. 11.2 12-1/4" BHA (GR and Res LWD are included in below BHA): COMPONENT D f " 1 H-E., i,at= t..�:M 11..:_.- 1G.-•.: 3_:: 12"..;..f,".. .:7-1 ❑C-5 cE;L 1.« 1.=. 2 8"SperryDriil Lobe 4/5-5.3 sig 8.000 5.000 121.08 B 6-51S`REG 28.99 30.18 Stabilizer 11.500 3 Integral Blade Stabilizer 8.000 2.813 12.125 150.12 B 6-5i8`REG 6.00 36.19 4 8"DM Collar(Directional) 8.000 3.500 147A0 B 6-508'REG 9.20 45.39 5 8"DGR Collar (Gamma) 8.000 1.920 142.70 B 6.5113'REG 4.55 49.94 6 8'EWR-P4 Collar(Resistively) lif 8.000 2.000 151.00 B 6-5w REG 12.19 62.13 7 8"HCIM Collar(Processor) 8.000 1.920 149.90 B 6-518'REG 4.97 67.10 8 8"7M-HOC(Pulser) 8.150 4.000 145.20 B 6.518"REG 15.77 82.87 9 Orienting Sub MHO 8.000 3.000 147.22 B 6-518'REG 3.50 86.37 10 Non Mag Flex Drill Collar 8.000 3.000 147.22 B 6-518'REG 30.00 116.37 11 Non Mag Flex Drill Collar 8.000 3.000 147.22 B 6-518"REG 30.00 146.37 12 X-O 6-5/8 Reg Pin X 4-112"IF Box 8.000 2.813 150.12 B 4-112'IF 3.50 149.87 13 8 Joints 5"HWDP 5.000 3.000 49.30 240.00 389.87 14 Weatherford 6-114"Hyd Jar 6.250 2.250 91.01 B 4-112"IF 30.00 419.87 15 19 Joints 5"HWDP 5.000 3.000 49.30 570.00 989.87 Total:___ 989.87 V BIT DATA Bit Number Nozzles :1 x 12.3x18 Bit Size (in) : 12.250 TFA (in2) :0.8560 Manufacturer : HDBS Dull Grade In Model Dull Grade Out . Serial Number . MOTOR DATA x" Motor Number : 2 Bend (deg) : 1.15 OD (in) : 8.000 Nozzles (32nd) : 0.0 Manufacturer : Sperry Drilling Avg Diff Press . Model SperryDrifi Cumul Cir firs • Serial Number . Page 14 Version 1 July, 2014 • Paxton #7 II Drilling & Completion Procedure It itrorp,-11o.ka.LIA 11.3 Primary Bit: t. .1 -114MQHC1 R+n i4: PRODUCT SPECIFICATIONS 'ADC Code 117W ' Total Tooth Count 67 " Gage Row Tooth Count 39 y % 10 « Journal Angle 3r Offset(1116") 6 Jet Nozzle Types "; Standard 83244 " Extended 302447 Center Jet (If Center Jetted)501813 T.J.Connection 6-5;8"(API Reg.) Recommended Make-Up Torque' 28000:32000 Ft•Ibs. Bit Weight(Boxed) 250 Lbs.(113 Kg.) Bit Breaker (Mat.#ifLegacy#) 5153531506463 ti PRODUCT FEATURES #"'"*"..N ,.::� li\i • New patented DiamondT"t Clawaif tooth bit design. 411P44;•';: Tungstencarbide'surf inserts in gage teeth for added gage protection. , • Newly formulated,proprietary hardfacing€ on cutting structure and , 4l' ' 44(4141W' gage maximizes carbide and diamond volume for ultimate wear resistance. • High-speed bearing designed for high rpm and high-energy applications. • Innovative mechanical pressure compensating system provides *€ reliable pressure equalization and relief for maximum bearing and seal life. • Raised tungsten carbide inserts and proprietary-hardfacing provides maximum arm protection in abrasive and directional applications while minimizing drill string torque. • QauadPackk Plus Series incorporates its successful"longevity" features and patented engineered hydraulics system for optimal cleaning efficiency. • Center jet feature to prevent bit balling problems Material#622394 *Calculations based on recommendations from API and tool-joint manufacturers. 0 2012 Halliburton.All rights reserved.Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. July, 2014 Page 15 Version 1 • Paxton #7 Drilling & Completion Procedure 111110111 ala'. a.l.rfi 11.4 4-1/2" Workstring&HWDP will come from Saxon. Jars will come from Weatherford. 11.5 Begin drilling out from 16" conductor at reduced flow rates to avoid broaching the conductor. 11.6 Drill 12-1/4"hole section to 2,000' MD. Confirm this setting depth with the geologist and Drilling Engineer while drilling the well. This setting depth will protect the build section of the well with the surface casing. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 500 - 550 gpm. Ensure shaker screens are set up to handle this flowrate. • Utilize Inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team. • Keep swab and surge pressures low when tripping. • Make wiper trips every 500' or every couple days unless hole conditions dictate otherwise. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. / • TD the hole section in a good shale btwn 1900' MD and 2000' MD. • Take MWD surveys every stand drilled (60' intervals). 11.7 12-1/4"hole mud program summary: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system(1) ppg above highest anticipated MW. We will start with a simple gel+FW spud mud at 8.8 ppg. 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: 8.8—9.5 ppg Pre-Hydrated Aquagel/freshwater spud mud Properties: Depths Density Viscosity Plastic Viscosity Yield Point API FL LGS 80-2000' 8.8—9.5 • 85-150 20-40 25-45 <10 <15% System Formulation: M-1 Gel + FW spud mud Product Concentration Fresh Water 0.905 bbl M-I Gel Export 20 ppb M-I Wate As needed Soda Ash 0.5 ppb Caustic Soda 0.1 ppb Busan 1060 0.04ppb Page 16 Version 1 July, 2014 • • Paxton #7 Drilling & Completion Procedure (lileorp Alaska,LLC 11.8 At TD; pump sweeps, CBU, and pull a wiper trip back to the 16" conductor shoe. 11.9 TOH with the drilling assy, handle BHA as appropriate. 11.10 No open hole logging program planned for Paxton#7. Page 17 Version 1 July, 2014 S • la Paxton #7 Drilling & Completion Procedure Hilcorp Alaska,LLC 12.0 Run 9-5/8" Surface Casing 12.1 R/U and pull 15.375"wearbushing. 12.2 R/U Weatherford 9-5/8" casing running equipment. • Ensure 9-5/8"BTC x CDS 40 XO on rig floor and M/U to FOSV. • R/U fill-up line to fill casing while running. • Ensure all casing has been drifted on the location prior to running. • Be sure to count the total # of joints on the location 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. 12.3 P/U shoe joint, visually verify no debris inside joint. 12.4 Continue M/U&thread locking shoe track assy consisting of: • (1) Shoe joint w/float shoe bucked on (thread locked). ct., • (1) Joint with coupling thread locked. • (1)Joint with float collar bucked on pin end &thread locked. • Install (2) centralizers on shoe joint over a stop collar. 10' from each end. • Install (1) centralizer,mid tube on thread locked joint and on FC joint. • Ensure proper operation of float equipment. 12.5 Continue running 9-5/8" surface casing • Fill casing while running using fill up line on rig floor. • Use "API Modified"thread compound. Dope pin end only w/paint brush. • M/U connections to the base of the triangle stamped on the pin end. Note M/U torque values required to achieve this position. • After making up several connections, use the torque required to M/U to base of triangle as the M/U torque and continue running string. • Install (1) centralizer every other joint to 300'. Do not run any centralizers above 300' in the event a top out job is needed. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 9-5/8" BTC Estimated M/U Torque Casing OD Est Torque to Reach Triangle Base 9-5/8" 9,630 ft-lbs Page 18 Version 1 July,2014 i • Paxton #7 Drilling & Completion Procedure II iI nrp Alaska.LEA: Tenaris Casing and Tubing Performance Data Choose pipe size,wall thickness and steel grade to view API connection options and performance data. Size ® ri Grade ® Connection ri Unit Pipe Body Data GEOMETRY �;.z A Nominal OD 9.625 in Wall Thickness 0.395 in API Drift Diameter 8.679 in Nominal Weight 40.00Ibsyft Nominal ID 8.835 in Alternate Drift Diameter 8.75 in Plain End Weight 38.97 Ibsift Nominal Cross Section 11.454 sq in PERFORMANCE Steel Grade L80 Minimum Yield 80,000 psi Minimum Ultimate 95,000 psi Body Yield Strength 916,000 lbs Internal Yield Pressure 5,750 psi Collapse Pressure 3,080 psi .I Connection Data GEOMETRY Regular OD 10.625 in Threads Per Inch 5 Make-Up Thread Turns 1 II+ .°1 .n .... N$hb .( ➢'.� ,, _.Tl gms 4 4,4-4Steel Grade L80Minimum Yield 80,000 psi Minimum Ultimate 95,000 psi (Joint Strength 947,000 lbs Internal Pressure 5,750 psi Resistance TenarisHVdril Premium Connections Print I Contact Us Ver 8.6 12.6 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.7 Slow in and out of slips. 12.8 P/U casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe as close to TD as possible. Strap the landing joint while it is on the deck and mark the joint at(1) ft intervals to use as a reference when landing the hanger. 12.9 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. Page 19 Version 1 July,2014 • I Paxton #7 Drilling & Completion Procedure Ililcorp Alaska,LLC 12.10 R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 12.11 After circulating, lower string and land hanger in wellhead again. 411- Page Page 20 Version 1 July,2014 • • Paxton #7 Drilling & Completion Procedure II ileorp,tk1ska.LLC 13.0 Cement 9-5/8" Surface Casing 13.1 Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud& water can be delivered to the cmt unit at acceptable rates. • How to handle cmt returns at surface. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cmt operation. 13.2 Document efficiency of all possible displacement pumps prior to cement job 13.3 R/U cmt head(if not already done so). Ensure top and bottom plugs have been loaded correctly. 13.4 Pump 5 bbls 10 ppg spacer. Test surface cmt lines. 13.5 Pump remaining 35 bbls 10 ppg spacer. 13.6 Drop bottom plug. Mix and pump cmt per below recipe. 13.7 Cement volume based on annular volume+ 50% open hole excess. Job will consist of lead& tail, TOC brought to surface. Estimated Total Cement Volume: Section: Calculation: Vol (BBLS) Vol (ft3) LEAD: 80' x .129 bpf= 10.3 57.8 16" Conductor x 9-5/8" casing annulus: LEAD: (1500' —80') x .0558 bpf x 1.5 = 119 668 12-1/4" OH x 9-5/8" Casing annulus: Total LEAD: 129.3 726 -to sX TAIL: (2000'-1500')x .0558 bpf x 1.5 = 42 236 12-1/4" OH x 9-5/8" Casing annulus: TAIL: 90 x .096 bpf = 8.7 48.8 9-5/8" Shoe track: Total TAIL: 50.7 bbl 285 ft3 �2J sX a Page 21 Version 1 July, 2014 • Paxton #7 Drilling & Completion Procedure Ilikorr Cement Slurry Design: Lead Slurry (1500' MD to surface) Tail Slurry (2000' to 1500' MD) System Extended Conventional Density 12.5 lb/gal 15.2 lb/gal Yield 2.13 ft3/sk r/ 1.25 ft3/sk Mixed 12.02 gal/sk 5.7 gal/sk Water Mixed Fluid 12.03 gal/sk 5.71 gal/sk Code Description Concentration Code Description Concentration Type1 Cement 94 lb/sk WBWOB Type1 Cement 94 lb/sk WBWOB Static Free De-Foamer 0.005 lbs/sk Static Free De-Foamer 0.005 lbs/sk CaCI Accelerator 2% bwoc CaCI Accelerator .25%bwoc Additives CD-32 Dispersant 0.4%bwoc CD-32 Dispersant 0.5% bwoc FL-52 Fluid Loss Add 0.3% bwoc FL-52 Fluid Loss Add 0.2% bwoc FP-6L De-Foamer 1 gal/100 sk FP-6L De-Foamer 1 gal/100 sk Na Extender 2% bwoc Metasillicate 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Keep the hanger elevated above the wellhead while working. If the hole gets "sticky", land the hanger on seat and continue with the cement job. 13.9 After pumping cement, drop top plug and displace cement with 9.5 ppg Kla-shield. 13.10 Ensure cement unit is used to displace cmt so that volume tracking is more accurate. 13.11 Displacement calculation: 1900' x .0758 bpf= 144 bbls 13.12 Monitor returns closely while displacing cement. Adjust pump rate if necessary. If hanger flutes become plugged, open wellhead side outlet in cellar and take returns to cellar. Be prepared to pump out fluid from cellar. Have some sx of sugar available to retard setting of cement. 13.13 Do not overdisplace by more than %2 shoe track volume. Total volume in shoe track is 8.7 bbls. 13.14 Be prepared for cement returns to surface. If cmt returns are not observed to surface, be prepared to run a temp log btwn 6— 18 hours after CIP. 13.15 Be prepared with small OD top out tubing in the event a top out job is required. The AOGCC will require us to run steel pipe through the hanger flutes. The ID of the flutes is 1.5". Page 22 Version 1 July, 2014 • Paxton #7 Drilling & Completion Procedure Hi!corp Alaska,LLC 13.16 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold,pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held. 13.17 R/D cement equipment. Flush out wellhead with FW. 13.18 Back out and L/D landing joint. Flush out wellhead with FW. 13.19 M/U pack-off running tool and pack-off to bottom of Landing joint. Set casing hanger packoff. Run in lock downs and inject plastic packing element. 13.20 Lay down landing joint and pack-off running tool. 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 a. Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid b. Note if casing is reciprocated or rotated during the job c. Calculated volume of displacement, actual displacement volume,whether plug bumped&bump pressure, do floats hold d. Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure e. Note if pre flush or cement returns at surface&volume f. Note time cement in place g. Note calculated top of cement h. Add any comments which would describe the success or problems during the cement job Send final "As-Run" casing tally & casing and cement report to lkeller@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 23 Version 1 July,2014 r i Paxton #7 Drilling & Completion Procedure II ilcarp,-ilaka.LLC 14.0 BOP N/U and Test 14.1 N/D the diverter. 14.2 N/U Seaboard multi-bowl wellhead assy. Install packoff 9-5/8" P-seals. Test to 3000 psi. 14.3 N/U 11"x 5M T3-Energy BOP as follows: • BOP configuration from Top down: 11"x 5M T3-Energy annular BOP/11"x 5M T3-Energy Model 6011i double ram/11"x 5M mud cross/11"x 5M T3-Energy Model 6011i single ram • Double ram should be dressed with 2-7/8 x 5-1/2" VBRs in top cavity, blind ram in btm cavity. • Single ram should be dressed with 2-7/8 x 5-1/2" VBRs • N/U bell nipple, install flowline. • Install (2) manual valves & a check valve on kill side of mud cross. • Install (1)manual valve on choke side of mud cross. Install an HCR outside of the manual valve. 14.4 Run 4-1/2"BOP test assy, land out test plug(if not installed previously). • Test BOP to 250/3500 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. • Ensure to leave "B" section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. 14.5 R/D BOP test assy. 14.6 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.7 Mix 9.5 ppg Kla-Shield mud system. 14.8 R/U mud loggers for production hole section. 14.9 Set 10" ID wearbushing in wellhead. 14.10 Rack back as much 4-1/2"DP in derrick as possible to be used while drilling the hole section. 14.11 Keep 5-1/2" liners in mud pumps. Page 24 Version 1 July, 2014 • Paxton #7 Drilling & Completion Procedure llikorp,alaska,LLC 15.0 Drill 8-1/2" Hole Section 15.1 P/U 8-1/2" directional BHA. 15.2 Ensure BHA components have been inspected previously. 15.3 Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 15.4 TF offset is measured accurately and entered correctly into the MWD software. 15.5 Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. 15.6 Workstring will be 4.5" 16.6# S-135 CDS40. Page 25 Version 1 July, 2014 4111 • Paxton #7 Drilling & Completion Procedure rlileorp:1Ia'ka.LLC 15.7 8-1/2" BHA (Includes GR+Res+Den/Neu+ Dipole Sonic LWD components): COMPONENT DATA Item OD 1D Gauge Weight Top Length Cumulative e �,,-„e, a «ion Serial Number IntiA ti% ".''.e;., (en)_ {an) (in), Peg) Connection (ft) Length,(tti 1111 HDBS-FX65D PDC 8.400 2.500 8.500 172 13 P 4-112"REG 1.00 1.00 © SperryDri."I Lobe 718-6.0 stg 7.000 4.952 93.13 B 4-1±2'IF 27.38 28.38 11111 Stabilizer111111111111 11111111 1111111111111 M � 1 Non Mag Float Sub1111111111111 6.753 2.753 1111111 13'71 3.00 "-. 1111 Integral Blade Stabilizer(NM) 6.750 2.813 8.375 130 77 1=3 5.00 10121211 6 314"DM(Directional) i 111111111111.11 6.750 133.40 In= 9.20 Mil 6 6 314"BAT (Sonic) V® 6.750 ®_ 97.700 20.30 65.89 MN 6 314'DGR(Gamma) + 6.750 1 920 97.80 B 4-1±2"IF MEM 70.44 gai 6314'EWR-P4 (Resistivety) • 6.750 2.0100 134.30 II= 12.10 MEM KM 6 3.4'HCIM (Processor) 6.750 1.92C 131.70 B 4-112"IF 447 MIME ® 6 314"ALD (Density) ' ® 6 753 1920ICBM 104.30 NE1 -111111111111111111111111111111111 11111 6 3.'4'CTN(Neutron; ,. 6.750 1.905 MIN 102.30 En 6 3?4"TM-HOC(Pulsar) 6 900 3.250 103.60 B 4-112"IF 15.59 Ell Non Mag Flex Drill Collar11111111111 6.750 2.813 111111=11111=11 30.0' 159.48 ® Non Mag Flex Drill Collar 6 750 2.813 100 77 B 4-ti2"IF 30.00 189.48 8 Joints 5'HWDPMEM 5.000 3.x000 240.00 16 Weatherford 6-14"Jars 6.250 ®_ 91.01 B 4-112"IF 30.00 .1122. Ilel 19 Joints 5"HWDP _ 5.000 3.00 _ 49.30 MI. 570.00 Mal Total. 1029.48 BIT DATA Bit Number Nozzles :5x13 Bit Size (in) : 8.503 TFA {int) :0.6481 Manufacturer . Dull Grade in . Model Dull Grade Out - Serial Number . MOTOR DATA ,. Motor Number : I Bend (deg) : 0.00 OD (in) : 7.000 Nozzles (32rd) : 0.0 Manufacturer : Spery D-ilng Avg Gift Press .• Model : SperryD-il Cumul Cir Hrs . Serial Number . Page 26 Version 1 July, 2014 • • Paxton#7 Drilling & Completion Procedure I I ileorp,t la,k a. 15.8 Primary Bit: 8-1/2" (216mm) MM65M PRODUCT SPECIFICATIONS Cutter Type SelectCutter IADC Code M324 Body Type MATRIX Total Cutter Count 41 '1. " Cutter Distribution 13mm 16mm Face 1 29 Iv 44A Gauge S 0 Up Drill 6 0 r t Number of Large Nozzles 0 , Number of Medium Nozzles 0 Number of Small Nozzles 6 Number of Micro Nozzles 0 Number of Ports(Size) 0 i " " Number of Replaceable Ports(Size) 0 Junk Slot Area(sq in) 14.6E Normalized Face Volume 42.13"0 API Connection 4-1/2 REG.PIN Recommended Make-Up Torques 12,461—17,766 Ft*lbs. Nominal Dimensions** 44,4, «4+ 4Af Make-Up Face to Nose 10.73 in-273 mm 4.4 /' Gauge Length 2.5 in-64 mm Sleeve Length 0 in-0 mm Shank Diameter 6 in-152 mm Break Out Plate(Mat.t'i'Legacytr) 16195444010 Approximate Shipping Weight 160Lbs.-73Kg. SPECIAL FEATURES 1/32"Relieved Gage,Combination BackreamiUp-Drill Cutters. Secondary Cutting Element-"R"Feature,TSP Gage Material#803275 'Bit specific recommended make-up torque is a function of the bit 1.D_and actual bit sub O.D.utilized as specified in API RPM Section A.8.2 **Design dimensions arc nominal and may vary slightly on manufactured product.Halliburton Drill Bits and Services models arc continuously reviewed and refined. Product specifications may change without notice. 0 2013 Halliburton.All rights reserved.Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. Page 27 Version 1 July, 2014 • i Paxton #7 Drilling & Completion Procedure Hitcom•p Alaska.LLC 15.9 8-1/2"hole section mud program summary: Weighting material to be used for the hole section will be salt and calcium carbonate. Additional calcium carbonate will be on location to weight up the active system (1)ppg above highest anticipated MW. 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 Kla-Shield fresh water based drilling fluid with 6%KCl. Properties: Depths Density Plastic Viscosity Yield Point Chlorides API FL pH 2000'-7100' 9.5 10-20 15-25 60,000—70,000 <8 9.0- 10 System Formulation: M-1 Swaco Kla-Shield with 6% KCl Product Concentration/Function Water Base Fluid Busan 1060 0.4 ppb Biocide Soda Ash 0.25 ppb PH/Hardness Control Flowzan 1.0 ppb Viscosifier/Rheology KCL 21.8 ppb weight/inhibition NaCI Salt 20.0ppb weight/inhibition Poly Pac Sup UL 0.75 ppb API Fluid Loss EMI-2009 2-3%v/v Clay/Shale inhibitor Safe-Carb 40 If needed for weight increase over Conqor 404 9.0ppg Asphasol Supreme Corrosion Mitigation Sack Black 4ppb Shale/Coal Stabilizer 3ppb-Gilsonite Shale/Coal Stabilizer 15.10 TIH w/ 8-1/2" directional assy to TOC. Shallow test MWD and LWD on trip in. Note depth TOC tagged on AM report. 15.11 R/U and test casing to 2900 psi/30 min. Ensure to record volume/pressure and plot on FIT graph. AOGCC reg is 50% of burst= 5750/2 =2875-2900 psi. 15.12 Drill out shoe track and 20' of new formation. 15.13 CBU and condition mud for FIT. Page 28 Version 1 July,2014 • Paxton #7 Drilling & Completion Procedure 11ilr011) 11, 1,a.Ii. 15.14 Conduct FIT to 12 ppg EMW. Note: Offset field test data predicts frac gradient at the 9-5/8"shoe to be btwn 16- 17 ppg EMW. A 12 ppg FIT results in a 2.5 ppg kick margin while drilling with the planned MW of 9.5 pp& i 15.15 Drill 8-1/2"hole section to 7,098' MD/3,500' TVD. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 400 - 450 gpm. Ensure shaker screens are set up to handle this flowrate. • 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. • Make wiper trips every 500' or every couple days unless hole conditions dictate otherwise. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. Keep HTHP fluid loss < 10. • Take MWD surveys every stand drld. Surveys can be taken more frequently if deemed necessary. • Mudlog from Top Beluga to Total Depth, 20' samples in zones of interest, two sets of cuttings, chromatograph,pixler plots. 15.16 At TD; pump sweeps, CBU, and pull a wiper trip back to the 9-5/8" shoe. 15.17 TOH with the drilling assy, lay down drill pipe on the way out. L/D stands out of the derrick prior to running 5-1/2" long string. 15.18 No open hole logs planned for Paxton#7 production hole. 15.19 Monitor the well at all times while Laying down drill pipe. Page 29 Version 1 July, 2014 i • Paxton #7 Drilling & Completion Procedure II ilrorp Alaska,LLC 16.0 Run 5-1/2" Production Casing 16.1. R/U 5-1/2"casing running equipment. • Ensure 5-1/2" CDC x CDS 40 crossover on rig floor and M/U to FOSV. • R/U fill up line to fill casing while running. • Ensure to R/U Tesco or Weatherford CRT so that string can be rotated if necessary while running. • Ensure all casing has been drifted on the deck prior to running. • Be sure to count the total # of joints on the deck 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. 16.2. P/U shoe joint, visually verify no debris inside joint. 16.3. Continue M/U&thread locking shoe track assy consisting of: • (1) Shoe joint w/shoe bucked on&threadlocked(coupling also thread locked). Install (2) solid body centralizers on shoe joint prior to bucking on float shoe. The centralizers should be held in place 10' from each end via stop rings on either side. • (1) Thread locked joint(coupling thread locked). • (1)Joint with float collar bucked on pin end&threadlocked (coupling also thread locked). Install (1) solid body centralizer on float collar joint prior to bucking on float collar. • Install a solid body centralizer on landing collar joint. Leave centralizers free floating so that they can slide up and down the joint. • Ensure proper operation of float shoe and float collar prior to running in the hole. 16.4. Continue running 5-1/2"prod casing. • Fill casing while running using fill up line on rig floor. • Use "Best 0 Life 2000"thread compound. Dope pin end only w/paint brush. • Install solid body centralizers on every joint to 2,000 MD. None above 2000'. Leave the centralizers free floating. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 5-1/2" CDC M/U torques Casing OD Minimum Maximum Yield Torque 5.5" 12,000 ft-lbs 13,800 ft-lbs 15,500 ft-lbs Page 30 Version 1 July,2014 S ! Paxton #7 Drilling & Completion Procedure Ili!carp Alaska,LLC Technical Specifications Connection Type: Size(O.D.): Weight(Wall): Grade: DWC/C Casing 5-112 in 17.00 Ibtft(0.304 in) P-110 standard Material P-110 Grade 110,000 Minimum Yield Strength(psi) 11111111111111111111111EFUSA 125,000 Minimum Ultimate Strength(psi) vA+n_usa 4424 W.Sam Houston Pkwy,Suite 150 Pipe Dimensions Houston,TX 77041 Phone:713-479•320O 5.500 Nominal Pipe Body O.D. (in) Fax:713-479-3234 4.892 Nominal Pipe Body I.D.(in) E-mail::OM lISMal vam-usa.cor'i 0.304 Nominal Wall Thickness (in) 17.00 Nominal Weight (lbs/ft) 16.89 Plain End Weight(lbs/ft) 4.962 Nominal Pipe Body Area (sq in) Pipe Body Performance Properties 546,000 Minimum Pipe Body Yield Strength (lbs) s=. 7,480 Minimum Collapse Pressure(psi) 10,640 Minimum Internal Yield Pressure(psi) 9,700 Hydrostatic Test Pressure(psi) Connection Dimensions 6.050 Connection O.Q.(in) �= 4.892 Connection I.D. (in) °*'_. 4.767 Connection Drift Diameter(in) . 4.13 Make-up Loss(in) ;. 4.962 Critical Area (sq in) 100.0 Joint Efficiency(%) Connection Performance Properties 546,000 Joint Strength(lbs) 22,940 Reference String Length(ft) 1,4 Design Factor f" . 568,000 API Joint Strength(lbs) 546,000 Compression Rating(lbs) 7,480 API Collapse Pressure Rating (psi) 10,640 API Internal Pressure Resistance (psi) 91.7 Maximum Uniaxial Bend Rating [degrees1100 ft] Appoximated Field End Torque Values 12,000 Minimum Final Torque(ft-lbs) 13,800 Maximum Final Torque(ft-lbs) 15,500 Connection Yield Torque(ft-lbs) 16.5. M/U casing hanger joint to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe approx 10—20' above TD. Strap the landing joint while it is on the deck and mark the joint at (1) ft intervals to use as a reference when landing the hanger. Page 31 Version 1 July, 2014 • Paxton #7 Drilling & Completion Procedure 'Licari)Alaska,LLC 16.6. Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 16.7. R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat(slightly)to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 16.8. After circulating, lower string and land hanger in wellhead again. Page 32 Version 1 July, 2014 • Paxton #7 Drilling & Completion Procedure Iiilcorp Alaska,LLC 17.0 Cement 5-1/2" Production Casing 17.1. Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud&water can be delivered to the cmt unit at acceptable rates. • How to handle cmt returns at surface, regardless of how unlikely it is that this should occur. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cmt operation. • Document efficiency of all possible displacement pumps prior to cement job. 17.2. Attempt to reciprocate the casing during cmt operations. 17.3. Pump 5 bbls 10 ppg SealBond spacer. 17.4. Test surface cmt lines to 4500 psi. 17.5. Pump remaining 15 bbls 12 ppg SealBond spacer. 17.6. Mix and pump lead and tail cmt per below recipe. Ensure cmt is pumped at designed weight. Job is designed to pump 30% OH excess. VSs" w T _ Section: Calculation: VolS) Vol (ft3) (B9-5/8"x 5-1/2" Overlap(Lead): 500' x 0.046= 23 1291 1,74 8-1/2" OH x 5-1/2" Liner(Lead): (4,500—2,000')x 0.0408 x 1.3 = 132.6 745 1 8-1/2" OH x 5-1/2" Liner(Tail): (7,100' —4,500')x 0.0408 x1.3 = 138 775, Shoe Track(Tail): 90' x 0.023 = 2.1 12 Total Volume (Lead): 155.6 873.7 8a" Total Volume (Tail): 140.1 787 6,2-s x Page 33 Version 1 July, 2014 H • Paxton #7 Drilling & Completion Procedure Ililrorp Ala,ka.1110 Lead Slurry (4500' to 1500') Tail Slurry (7,100' to 4,500' MD) System Extended Conventional Density 13.5 lb/gal 15.2 lb/gal Yield 1.82 ft3/sk ✓ 1.25 ft3/sk Mixed Water 9.21 gal/sk 5.7 gal/sk Mixed Fluid 9.22 gal/sk 5.71 gal/sk Code Description Concentration Code Description Concentration Class G Cement 94 lb/sk Type1 Cement 94 Ib/sk WBWOB WBWOB BA-90 Low den. additive 10% bwoc Static Free De-Foamer 0.005 lbs/sk BA-56 Gas Migration 2.5% bwoc R-3 Retarder 0.9%bwoc CD-32 Dispersant 0.4% bwoc CD-32 Dispersant 0.6% bwoc Additives Free water ASA-301 0.1%bwoc FP-6L De-Foamer 1 gal/100 sk control Bonding FP-6L De-Foamer 1 gal/100 sk BA-10A 1% bwoc agent Metasillicate Extender 0.5% bwoc Metaa lsa illicate Extender 0.5% bwoc Static Free De-Foamer 0.005 lbs/sk 17.7. Drop DP dart and displace with 6% KCl. 7000' x .023 = 161 bbls 17.8. Do not overdisplace by more than V2 shoe track. Shoe track volume is 1.7 bbls. 17.9. Bleed pressure to zero to check float equipment. 17.10. Pressure up again to 3500 psi and hold for 30 min to test production bore. Page 34 Version 1 July, 2014 • Paxton #7 Drilling & Completion Procedure Hilcorp Alaska,LLC 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 i. Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid j. Note if casing is reciprocated or rotated during the job k. Calculated volume of displacement,actual displacement volume,whether plug bumped&bump pressure,do floats hold 1. Percent mud returns during job, if intermittent note timing during pumping of job.Final circulating pressure m. Note if pre flush or cement returns at surface&volume n. Note time cement in place o. Note calculated top of cement p. Add any comments which would describe the success or problems during the cement job Send final "As-Run" casing tally & casing and cement report to lkeller@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 35 Version 1 July, 2014 • • Paxton #7 Drilling & Completion Procedure IIilcnrp Alaska.Ilk 18.0 RDMO 18.1 N/D BOP, install tubinghead. Install dummy hanger in tubing head and N/U Temp abandonment cap. Ensure dummy hanger has a 4" ID to allow CBL to be run rigless. 18.2 RDMO Saxon rig#147 18.3 After rig has departed, run CBL to determine TOC behind 5-1/2"production casing. Send the CBL to the AOGCC for review. 19.0 Perf and Frac ti 19.1 A separate sundry will be submitted to the AOGCC that will cover the below operations: • R/U workover rig • Run production tubing/pkr/CIM & SCSSV. • Perforating and flowback. • And hydraulic fracturing or other stimulation that may be necessary to produce the well commercially. Page 36 Version 1 July, 2014 • • II Paxton #7 Drilling & Completion Procedure 1IiI of ll Ia,ka.LH: 20.0 BOP Schematic I -,, Iii lit lil tit Hit T3-Energy Saxon Rig 147 9,4:6N o12. 11"5M "- : T-3 Energy BOP taiCtit lit tittit 1 T3-Ener, Mo iitt....� ,';f. :311!1. Manual Manual M<<.I L I 11.85' Valve Valve Va..'e- w[ t IttlttltI tit III Kill alb i i w °' , t1t��h:e at ppe,.:* i, 0 Line l.. . i i . � ,11 L �I L r .4,10'1; s -1 111.1#!'If!tlft%a �= -- T3-Energy Model 60111 ala ' trade Lw_ III III lei ISI ttI Spacer spool g5, 115MX1151N lit lit tit tit lit i Seaboard-MBS systemEll I i. .441I:;- I. 16l,3MX115M at (ani * r ,..;wmul -1111 FIN: it -i ,'"SII; 1 SII9-5:8" 1) Page 37 Version 1 July,2014 • Paxton #7 Drilling & Completion Procedure iiiieo p:ai:ia,a.LIA; 21.0 Wellhead Schematic Ninilthik Unit New drill system-Seaboard Saxon Rig 147 16x95/8x5112 i.rcrsl 222.1 7.71 • I. •, Md lit .f ff Tubing head,Seaboard-58, P1' 115M X 7 1/16 5M, r; m+/2-21/165M550 )1 , 1 :` 7"P seal bottom4 141 01, ma 18111 Casing spool,Seaboard-58, Ilk 1r 163/431v1.X115M, w/2-2 1/16 SM SSO, N II : •(o �.i i-I• 9 5/8 P seal bottom • .04 stomitr Starting head,Seaboard, . 1 11 16%3M X 16"SOW BTM, w/2-21/16 5M 550 M111 16" 9 5/8" 51a.I Page 38 Version 1 July,2014 • Paxton #7 Drilling & Completion Procedure Ililrorp aPa,ka.Ii. 22.0 Days Vs Depth Days Vs Depth 0 -Paxton#7 FellsCreek#5 2000 4000 s v ECQO 5 7 3000 10000 12000 0 5 10 15 20 25 30 35 40 Days Page 39 Version 1 July,2014 0 • Paxton #7 Drilling& Completion Procedure Hileorp Alaska,LLC 23.0 Formation Tops ANTICIPATED FORMATION TOPS&GEOHAZARDS EXPECTED Intersection Points TOP TOP NAME FLUID MD(FT) TVD(FT) TVDSS(FT) Est.Pressure X _Y +,•'- Surface Loc 0 ' 206222r 2230463 Top Beluga Fm GAS 3037 1,437 -1.267 ' 618 - Beluga 50 GAS 4524 2.140 -1;970 ' 920 206981.0 2234515.0 10 Beluga 60 GAS 4987 2,476 -2,306 ' 1065 r r Total Depth 5500 2,872 2,702 , 206225 2235084 =Primary Objective Secondary Objective TARGET RADIUS 100 FT / Page 40 Version 1 July, 2014 • • Paxton #7 Drilling & Completion Procedure Iiileorp Alaska,LLC 24.0 Anticipated Drilling Hazards 12-1/4" Hole Section: Lost Circulation: Ensure adequate amounts of LCM are available. Safe-carb 10, 20, 40, 250, & 750. Ensure G-seal, Pecan nut plug, and Mix II are also available for more severe lost returns incidents. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of Safe-carb 10 &20 to the active system at 1 —2 ppb. Hole Cleaning: Maintain rheology w/gel and gel extender. Sweep hole with gel or flowzan sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Maintain YP btwn 25 —45 to optimize hole cleaning and control ECD. Wellbore stability: Lithology through this zone is a composite of pebble conglomerate and sand in the upper intervals with intermittent clay matrix. Carbonaceous material and coal may be noted. Gravel sizes that are larger than normal can cause hole-cleaning problems. If encountered, be prepared to increase the viscosity. Excessive quantities of gravel and sand may indicate wellbore instability. Increase properties up to a YP of—50 -—60 lbs/100ft2 to combat this issue. Maintain low flow rates for the intial 200' of drilling to reduce the likelihood of washing out the conductor shoe. To help insure good cement to surface after running the casing, condition the mud to a YP of 25 —30 prior to cement operations. Do not lower the YP beyond 25 to avoid trouble with sands that may be found on this well. Have Desco DF, SAPP, and water on hand to ensure the desired rheologies can be achieved. H2S: H2S is not present in this hole section. No abnormal pressures or temperatures are present in this hole section. Page 41 Version 1 July,2014 • Paxton #7 Drilling & Completion Procedure Hilcarp Alaska,LLC 8-1/2" Hole Section: Lost Circulation: Ensure adequate amounts of LCM are available. Safe-carb 10, 20, 40, 250, & 750. Ensure G-seal, Pecan nut plug, and Mix II are also available for more severe lost returns incidents. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of Safe-carb 10 &20 to the active system at 1 —2 ppb. Hole Cleaning: Maintain rheology w/flowzan. Sweep hole w/20 bbls hi-vis pills as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain YP btwn 20 - 30 to optimize hole cleaning and control ECD. Wellbore stability: Maintain 1 ppb total of PolyPac Supreme UL to maintain a thin/strong wall cake and keep HTHP filtrate below 9 ml/30 min. Maintain MW as necessary using additions of Barite. Maintain 6 ppb EMI-2009 for shale/clay inhibition. Maintain 4 ppb Asphasol Supreme& 3 ppb Sack Black for Shale/Coal stabilizer. Maintain 6%KC1 in system for shale inhibition. 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 (Asphasol Supreme, Sack Black). • Increase fluid density as required to control a"running coal". • Emphasize good hole cleaning through hydraulics, ROP and system rheology. In the event that sloughing coal is encountered, consider spotting a 30 ppb Asphasol Supreme pill across the coal seam. The pill can be safely "squeezed" into the coal by closing the bag and applying pressure not to exceed the total annular pressure loss. H2S: / H2S is not present in this hole section. No abnormal temperatures are present in this hole section. Page 42 Version 1 July,2014 • 11 Paxton #7 Drilling & Completion Procedure IIileorp Ala 4a.IAA: 25.0 Saxon Rig 147 Layout 123'.•-7" 36'-U" - 55-6" 30'-U" III IIII PRE-YIX TANK !TOTAL Y-'L Tay BEL,} _ _ ter. _ --I- 7-a, ....,1111111111111 i ln�. i fii 7+ III IIl��I IiIIU!1 ®79t1ry YAL�D EJMF M2 IAIX - 1- --,cin»''— {IF�irntii IIIIj (-O r 1 _T ---. 11111III'IIII " mimmummaliiiiiimili D. 1:4161417511f.'' Ill� Qr.- �lllll�rl�l .��� � _.. i 11.... 1 111 1 - � „,,,,101; IMIM IlMMIM IIMM I 11 I Ir —1:19 ,� i �� 1�r�ral ai�i,1.1 Il moo v„MP , ■A.,�G .•.J ■ • • - = 1: _ '''":„.w., 111171! 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IIIIIIII I:II a II lI IJ111111II111II1lI11I1111I111I1111I111I111I11111111II MIME i i i11111 1111f111�111111111�11111 11111lIltIl 1.0 1 ,� ... }� �� 11111 ' �� Int Inlnln Mb, �, 1 '• , r RR TMI i! !I!IuIñIIJ © i ,�ow GE11ERATOk8 eua c rcx,Ho.:sE/WAIFR TPriii/tOOLRISOM 53'-0” 45-0" 85-0" 11 85'-5" Page 43 Version 1 July,2014 i • Paxton #7 Drilling & Completion Procedure {{'rleorp Alaska,LLC 26.0 FIT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 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. 7 Page 44 Version 1 July,2014 0 111 Paxton #7 Drilling & Completion Procedure nileorp Alaska,LIC 27.0 Choke Manifold Schematic i (a;• e. FO -. i;• e . • f- 4 �� i. a. AM IlMt111 4� 1_.,„/A)= te ' id' (') N0 Ila fete. i ''-',4:114'..-4-: til i M !J , >L+`. v .11111111r11 1 �1 P 1 MIN 143 :Alia f l,4 !�' Ili ., • Irl [ .. II • i 1/ c SIi Q g d 6y I .,... .P_} ; rI re,iri PP SrJ � ��S r ,, - he t ,:e_Lo.1„,z,, 6,1 • it II 1l& 115 _ .; It 711111: , ' R Mini f 1 Page 45 Version 1 July,2014 • S Paxton #7 Drilling & Completion Procedure i &or!):Uaska. 28.0 Casing Design Information Design Criteria: Hole Size 12-1i4" Mud Density: 8.8 ppg Hole Size 8-112" Mud Density: 9.5 ppg Hole Size Mud Density: Drilling Mode MASP: 1155 psi(see attached MASP determination&calculation) MASP: Production Mode MASP: 1155 psi(see attached MASP determination&calculation) Collapse Calculation: Section Calculation 1 Normal gradient external stress(0.494 psifft)and the casing evacuated for the internal stress Casing Section Calculation/Specification 1 2 Casing OD 9-5'8" 5-112" Top(MD) 0 0 Top(TVD) D 0 Bottom(MD) 2,000 7,098 Bottom (TVD) 1,407 3.500 Length 2,000 7.098 Weight(ppf) 40 17 Grade L-80 P-110 Connection BTC CDC Weight w/o Bouyancy Factor(lbs) 80,000 120,666 Tension at Top of Section(lbs) 80,000 120,666 Min strength Tension(1000 lbs) 916 546 Worst Case Safety Factor(Tension) 11.45 4.52 Collapse Pressure at bottom(Psi) 695 1.729 Collapse Resistance w/o tension(Psi) 3,090 7.480 Worst Case Safety Factor(Collapse) 4.45 4.33 MASP(psi) 1,155 1,155 Minimum Yield (psi) 5,750 10,640 Worst case safety factor(Burst) 4.98 9.21 Page 46 Version 1 July, 2014 410 • Paxton #7 Drilling & Completion Procedure llilcarp Alaska.LE C 29.0 8-1/2" Hole Section MASP Maximum Anticipated Surface Pressure Calculation 8-112"Hole Section pslc Paxton#7 Ninilchik Unit MD TVD Planned Top: 2000 1407 Planned TO: 7098 3500 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad Top Beluga Fm 1,437 618 GAS 8.3 0.430 Beluga 50 2,140 920 GAS 8.3 0.430 Belu a 60 2,476 1065 GAS 8.3 0.430 TD 3,500 1511 Gas 8.3 0.430 -- TD Offset Well Mud Densities Well MW range Top(TVD) Bottom(TVD) Date Falls Creek#1 11.6-13.1 3,500 10,000 1960 Falls Creek#2 10.5-11 3,500 6,300 1966 Falls Creek#3 9.4-9.5 3,500 8,400 2003 Falls Creek#4 9-9.5 v 3,500 6,000 2004 - Falls Creek#5 95-9.7 3,520 9,715 2014 Corea Creek#1 9.5-10.9 3,500 9,000 1996 Frances#1 9.5-9.8 3,500 10.000 2013 Paxton#1 9.2-9.4 3,600 8,000 2004 Paxton#2 9.2-9.4 3,604 9,500 2008 Assumptions: 1. Fracture gradient at shoe is estimated at 0.936 psi/ft based on field test data. 2. Maximum planned mud density for the 8-1/2"hole section is 9.5 ppg. 3. Calculations assume"Unknown"reservoir contains 100%gas(worst case). 4. Calculations assume worst case event is complete evacuation of wellbore to gas Fracture Pressure at 9-5/8"shoe considering a full column of gas from shoe to surface: 1407(ft)x 0.936(psi/ft)= 1317 psi 1317(psi)-[0.1(psi/ft)'1407(ft))= 1177 psi MASP from pore pressure(unknown gas sand at TO,at 8.3 ppg,encountered while drilling) 3,500(ft)x 0.43(psi/ft). 1505 psi 1si)-(0.1(psafft)"3500(ft))= 1155 psi Page 47 Version 1 July, 2014 0 II Paxton #7 Drilling & Completion Procedure H ileo p r%I ,ka,LLC 30.0 Spider Plot (NAD 27) (Governmental Sections) _ - Legend 02,724/ 4...3,11. ..�. ,11.- --T-- .... PP+.2CTON 311H' • Paidon 47 SHL }' 1 * r Paxton 47 rPH 1 Paxton 7 MIL] "' Pae�araA7 BHL 1 • D103g,Gc" -. 1 1 0: er Surface Hole Location 1 • 1 • r Other Bottom Location LmcaI iiii...Wel Paths 1 • 1 KPB Parcel; 1 . 1 01 arilvas LAritt B.SJiK 3y ! A.DL35924 1 I 1 i r 1 ' ° 1 • { 4 • r 1 t 1,-.:\'BH` 1 • •Inr +1 1 kL� 1 a \, ADL3843V2 , • r° x 1 . 1. 1 1. 1 1. Ay / 0061505 A L / li, S001S014W AANINILCIlIK UNIT ir` , % J rr .. ti e f 11 •1 tai T i1 .,�i r•4k• 5 ` °5 . 1t. 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ASBU1 ii, , ..- 1',...' ) .,,---: ,.....' //' I f illi 1 .' PAXTON 47 WELL 4 ' . S-EttALT 1‘ , /Wan ASP ZOKE 4 t/J I 1 = N 21304MM' t ' • " ... 4'. i''..,...Z. / E 206309 1 wis op ELEC.6TE.'88,55 1$Wfir,iwzmiNENT s sp AT,MOO INT 51tTF NY " PC1 \ i , , .4"..,../ tp La ar mir srmiectsra mo,-, Ti.6 Ft TVA TIM Or 5113 I%38,3'Orrrr A.\ 4,IMA'S 5,23 N ,S. imcm>ms.eAsts or 110121034,1,111 COC/113PIATIM ME ALASKASTATL NAM LON i5I1V3Z 74Fr w 1 Ott)it!ZONE&MO,2,x53 DE.Ef 41444Eb Nee M NM 040$%LA,KA FREW k .,.' EL V 1411 W NOVO* / CMS BASE 1.TAT4)'40'LICA NO M1494.TAW PIO DE,rilr AhO'GAM No ..." -,-CTIONt 1.3 Tr%R14*.AR ,. 41..Wkr Of SER.dED.4.04E E..M17 ON kla SEtFC47),r Aum ....., :45 iff EEL,MY FTC - Nu 04:1747 TO PM 513 il 335MAT,Tiln C 13&113L1,12.1 MM.341 re mr-. \. /,,.. r, 7).4oftmtAsT Comets,NEL 13 CotiNbionn ne norm to MOM CA8!C .1,'''V'8 1 SUFI mee ISE TO me TO EXaT**3 kW NEONON i-ONstm WE.1.10105PeD 14 .48,8"!"1,., .1'''' 411.4 PROTRACTOD SECTION CORNEA.04.1.163 NOT k.LSE) °.,...,) •,,,, ..._ ,,:.,,,,,. ' .k0e2NPRoC4v)0ERSIK74.4 a 1.184K13 TO COAX il T l„...c.......fc3till.atkr.fm.a.....sv ...8 - l''P,-47 -8. 5 '''' PAXTON #7 WELL AS-BUILT SURFACE LOCATION NOTES (NAD27) LOCATION:SECTION/3, TOWNSHIP 1 SOUTH, 1 ._----- ----, ENGINEERING-TESTING RANGE 14 WEST,SEWARD MERIDIAN ALASKA A SURVEYING.MAPPING '4$ OOX,LRE / SOLFX3TNA.AX PPOOR & JOB NO. 143098 I 111pot It AlJtALAL LH, REV.0 'Asir vOIGE gic01,283-42.18 FAX:0:57)283-3265 DWG. cifflogenalne WWW.MCLANECG.CONI 143MB AS-BUILT Dae.August 08,2014 FIGURE: 1 Page 49 Version 1 July, 2014 • • Paxton#7 Drilling & Completion Procedure Hilem•p Alaska,LLt: 32.0 Offset MW vs TVD Chart Paxton#7 Offset Wells 0 , t i I S kiN 1000 111111,114."11.:1. ' j — Paxton#1 Paxton#2 2000 ""��� FaklsCreek#3 — 1M , Falls Creek#4 3000 '111111111111 Fra aces#1 1 g_‘". —Susan Dinnne8 4{)00 .�l " Falls reek#5 , 1 ip 5000 3 6000 ,; il — k a 7000 9000 10000 1 1 11000 12000 13000 / 14 - — 8 9 10 11 12 13 14 15 Mud Weight(PPG) Page 50 Version 1 July,2014 • 0 Paxton#7 Drilling & Completion Procedure 111ki i)AIa.Aa.LLC 33.0 Drill Pipe Specification Sheet SIZE: 4 1l2" r jWEIGUT; 16.6 LES/FT GR � �� ADE: 3-135 Th R SEINIG S RAE: 11(31,5') IJRILL,PIPE SPECS CONNECTION: CD$40 TUBE NEW 1.....M PREMIUM IN MM IN MMI OD' 4.500 1 14.3' 4365 110,9, WALL THICKNESS 0.337 8.6 0.270 6 8' ID 3.826 97.2 3.826 97.2'; FT-LBS NiK FT-LBS N-M , T0R5 0NAL STRENGTH 55,453 75.200 43.451 58 903:, 8036 TORSIONAL STRENGTH 44.362 60.200 34.761 47.100 Las DAN LBS DAN TENSILE 5 ENGTI-I 595.004 265.3 468.297 205800 PSI KPA PSI KPA INTERNAL PRESSURE CAPAC 17,693 121.985 16,176 111,530, COLLAPSE CAPAC 16.769 115.615 10.959 75.561 INx MM; INx MMZ CR055 SECTIONAL AREA BO' 4.407 2544 3.469 2235, CROSS 5ECT1ONAL AREA OD 15.904 10261 14.966 9655' CROSS 5ECT1ONAL AREA ID 11.497 7417 11,497 7417 IN' MM3 IND MMa' SECTION MODULUS 4.271 69995 3.347 54845' _ POLAR SECTION MODULUS 8.543 139989 6.694 _ 10996901 TOOL JOINT _ _ i 1 �. ,[V�va►. ,� t�i�uiui� P61 KPA I PSI KPA YIELD STRENGTH 130,000 696.318' 130.000 896 318 IN MM IN MM OD 5.2500 133.4 5.1198 130.4/ ID 2.6875 68.3 2 6875 68.3° RN LENGTH 11.0 279.4 11.0 279.4' BOX LENG11.1 14.0 355.6 14.0 355.6 FT-LBB NM FT-LBS NM TORSIONAL STRENGINI 35,400 48.004 34.700 47A 00 MAX MAKE-UP TORQUE 22.500 30.500 i 21.400 29.0004 RECOMMENDED MAKE-LIP TOROUE (21.200✓ 28.8001 20,800 25.2001 MiN MAKE-UP TORQUE L19.600 26.600 19.300 26200 LBS DAN 1,BS DAN TENSILE 5TRENGIN 824,400 367.600 804.900 358.90_: TOCOL.DINT/DRILL PIPE TORSIONAL RATIO 0.64 0.83 DRILL.PIPE ASSEMBLY WITH CONNECTION 1,85/Fr KG/M ADJUSTED WEIGHT 17.87 26.E+4 FT M APPROXIMATE LENGTH 31.50 9.60 GAL/FT maim FLUI D DISPLACEMENT 0.273 0.003394 FLUID CAPACITY 0.577 0.007169 IN MM DRI"TSIZE 2.5625 6w Page 51 Version 1 July, 2014 • II Paxton #7 Drilling & Completion Procedure iiileorp Ala,ka.1,11: ' ' ., — --------' -- - - COMBINED LOAD CURVE FOR 4 1/2"3-135 16.6 LBS/FT DRILL PIPE WITH CDS4O CONNECTIONS BEC-,000 EX,C,G0 IDC.,0 Aftl,,aft, i *Itt4 , *t*** a 1 Z. ac,c,000 3 D2,C,C10 i r 2 . i , ,.... / / .,,..,. ti, z , . Applied Torquelft-lbsi ••••**NEW TUBE CO!,101,1E0 LOAD ••••PREMIUM TUBE COMBINED LOAD ••••••,•MAKE-UF"TORQUE SHOU_DER 5 EPERATION *****-PIN YIELD ••••••••BOX YIELD Page 52 Version 1 July, 2014 • ` RECEIVED AUG 25 2014 AOGCC Hilcorp Energy Company Ninilchik Unit Paxton Paxton #7 Paxton #7 Plan: Paxton #7 wp5.0 Standard Proposal Report 25 August, 2014 HALLIBURTON i : Sperry Drilling Services • • o0 y O O O - co a - N - H 0 - O N O O N m r co 0.-.1r N m . CO0{pp p{pp O)a) 2 N F d + + 0 0 . 0 J 0 00 000a,-N0M 0 0 C NV) d00 V MO>000 _ f- ! 00 >0000NCif70 1O y`) O>3 M000() ~ O to o ro 0-0. > S8828.88 `n I oY u) o LJ OO 0900 H _ . -_1 p Q VirIo a 1- #it a 0 O N EV 0(0000000 V X d00o0oOo m o J .. co 0 re > N N 000(+i)O tDON 0 O_ —O fim a as o d > o_ co op ��pp La J C 0 O > NN C)OOONCO01,- _r J N{Np p O M,, ,N�Np�Np�Np{Np�7p V OWO N M aCC wNNNNNNN �-/`'. I- _0 » O N r m NNNNNNN - 1WO .22 K 0 a 'n a s J 288'M 0 0 0100 I ~ _ O Q Z66-66,---:ca N #I - 0 00 N 1-00 W w w y a 4 R 0 CO y' 0 000000 7(D ~ I X O trOD M 00 0 0 Z Z N N N N N N N 0 0 0. - Lo ZO OMr O NNNNNNN p) d N E00 W .00.-0)000 ml 0.- E00 - O 000 V) WOOgq�000D u It O LLNO + t`o XCO 00 _O W 0 C M a - .4- C +O 0 CO 0 N000 M CO M COOa - M 2000D MNO 3 MO 070CO —0 O ZO - v O O +0 - fO o 0 M N M 0 0 U o o n n P O O 0 Oi o CD Cp o o - co 00n.-,-V co - 0 CO . p..7 N7-Nm 0 • w W _ m 00000NM00 0 C`7 Mo 1-n n -� CO d (O W N NCO V OOCaO.-0 - N .Z.-0.- NV1O1-NM - 0 0 MO O O 0 QOONOOiaa)a, CO - M Cl) 0 OWN 0 M 0066666 - CO1O1O NO CO E 1O J U M M M MM — - � 0 Z 0 O a O`U 0000000. - O _U E 0 LE C0070001� —N ,_ U) p001� no.g 001Ooi000]N _ N 0 J 000 E Ea 0 1�I-M H woo E w Q p 00000 O N n O MW o .�U W W �DO'oot01wo0 - o O NN.T0W0O ? w vOpppai-d LONL $� o - N y y U .0.0 �`n�rn� m_NMvu)1or - >ooM = O `0 5 � '-m 2t�R ` o mwrnwE 0 m >01-o m 3 000 >OMO U zoo HOMO m,o w OM= 000 -@ar0 —0 QDV = _- re re aaaE 3„.1§: C G C G —o z aaC1 O O O - 1° ww +. Q. W U U O .= x k k 3 - co Y Mt CL /� �� LL• K a'a'O • C —o ■ 1r wam p Vi _ • _:? omoU ' O k O - Q. d a o 3 01 C o > U 2 M = - 0 L 0 J o -0 J i - - L I N I I I I I I I I I I I I I I 1 7 I I I I I I I I I HIIIIIII I I I I I I I I I I I I I I I I I I I I I I I I I I I N O O 0 0 O o 0 o O 0 0 0 O O O O O O CD 0 0 0 0 0 0 CO 0 0 N 0 00 N 0 0 0 0 N N M M V V (U!/usn 000L) (Adan Ieai1ian anal • HALLIBURTON Project: Ninilchik Unit WELL DETAILS: Paxton#7 Sperry Drilling Services Site: Paxton Ground Level: 149.00 �I Well: Paxton #7 +1,P-S +E/-W Northing Easting Ietittude Longitude Slot Wellbore: Paxton #7 0.00 0.00 2230463.00 206222.00 60.09565365 -15L60957882 Plan: Paxton#7 wp5.0 REFERENCE INFORMATION Co-ordinate(N/E)Reference:Well Paxton#7,True North Vertical(TVD)Reference:Plan Paxton 7 Q 170.00usft Measured Depth Reference: Plan Paxton 7 91 170.00usft _ Calculation Method:Minimum Curvature Paxton#7 wp5.0 6000— _ IPax#7_TD4 T3I IPax#7_Tu4 T2 5 1/2" 5500-- Paxton#3 Surveys SOq. C 3250 3000 5000- - 2750 4500— 2500 IPax#7_B1g50 T21 4000— 2250 3500- - c – 3000— 2000 9 5/8" 0 2500— r o _ 359° 1750 2000- - 1500— 000- 1500— CASING DETAILS 1,00 u '/ 3l TVD TVDSS MD Name Size – n r' 80.00 -90.00 80.00 16 16" Vet 1875.67 1705.67 3600.00 9-5/8 9 5/8" 1000— 3500.00 3330.00 7098.07 5-1/2 5 1/2" 1251 500— l000 T M Azimuths to True North – Alia.16" Magnetic North:16.57° 0— 1 Magnetic Field Strength:55199.9snT Dip Angle:73.11° Date:9/11/2014 Model:BGGM2013 -500— I I I I I I I I 1 1 1 1 1 1 1 t 1 1 1 I I I I I -1000 -500 0 500 1000 1500 2000 2500 3000 3500 II. West(-)/East(+)(750 usft/in) 1.1 I Wog)o r i) 0 • Halliburton HALLIBURTDN Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Paxton#7 Company: Hilcorp Energy Company TVD Reference: Plan Paxton 7©170.00usft Project: Ninilchik Unit MD Reference: Plan Paxton 7 @ 170.00usft Site: Paxton North Reference: True Well: Paxton#7 Survey Calculation Method: Minimum Curvature Wellbore: Paxton#7 Design: Paxton#7 wp5.0 Project Ninilchik 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 Site Paxton Site Position: Northing: 2,230,587.12 usft Latitude: 60.09599940 From: Map Easting: 206,316.53usft Longitude: -151.60907766 Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -1.39 ° Well Paxton#7 Well Position +N/-S 0.00 usft Northing: 2,230,463.00 usft Latitude: 60.09565365 +El-W 0.00 usft Easting: 206,222.00 usft Longitude: -151.60957882 Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 149.00 usft Wellbore Paxton#7 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°l ("1 (nT) BGGM2013 9/11/2014 16.57 73.11 55,200 Design Paxton#7 wp5.0 Audit Notes: Version: Phase: PLAN Tie On Depth: 21.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 21.00 0.00 0.00 358.89 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +El-W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) (1100usft) (°/100usft) (°/100usft) (°) 21.00 0.00 0.00 21.00 -149.00 0.00 0.00 0.00 0.00 0.00 0.00 261.00 0.00 0.00 261.00 91.00 0.00 0.00 0.00 0.00 0.00 0.00 441.00 5.40 358.98 440.73 270.73 8.47 -0.15 3.00 3.00 0.00 358.98 591.00 12.90 358.98 588.72 418.72 32.31 -0.58 5.00 5.00 0.00 0.00 1,592.64 73.00 358.89 1,288.73 1,118.73 683.80 -13.04 6.00 6.00 -0.01 -0.10 5,085.42 73.00 358.89 2,310.00 2,140.00 4,023.30 -78.00 0.00 0.00 0.00 0.00 7,098.07 32.75 358.89 3,500.00 3,330.00 5,594.87 -108.57 2.00 -2.00 0.00 180.00 8/25/2014 5:36:33PM Page 2 COMPASS 5000.1 Build 70 • • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Paxton#7 Company: Hilcorp Energy Company TVD Reference: Plan Paxton 7 @ 170.00usft Project: Ninilchik Unit MD Reference: Plan Paxton 7 @ 170.00usft Site: Paxton North Reference: True Well: Paxton#7 Survey Calculation Method: Minimum Curvature Wellbore: Paxton#7 Design: Paxton#7 wp5.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +EI-W Northing Easting DLS Vert Section (usft) (°) (0) (usft) usft (usft) (usft) (usft) (usft) -149.00 21.00 0.00 0.00 21.00 -149.00 0.00 0.00 2,230,463.00 206,222.00 0.00 0.00 80.00 0.00 0.00 80.00 -90.00 0.00 0.00 2,230,463.00 206,222.00 0.00 0.00 16" 100.00 0.00 0.00 100.00 -70.00 0.00 0.00 2,230,463.00 206,222.00 0.00 0.00 200.00 0.00 0.00 200.00 30.00 0.00 0.00 2,230,463.00 206,222.00 0.00 0.00 261.00 0.00 0.00 261.00 91.00 0.00 0.00 2,230,463.00 206,222.00 0.00 0.00 Start Dir 3°1100':261'MD,261'TVD 300.00 1.17 358.98 300.00 130.00 0.40 -0.01 2,230,463.40 206,222.00 3.00 0.40 400.00 4.17 358.98 399.88 229.88 5.06 -0.09 2,230,468.06 206,222.03 3.00 5.06 441.00 5.40 358.98 440.73 270.73 8.47 -0.15 2,230,471.48 206,222.06 3.00 8.48 Start Dir 5°/100':441'MD,440.73'TVD 500.00 8.35 358.98 499.30 329.30 15.54 -0.28 2,230,478.54 206,222.10 5.00 15.54 591.00 12.90 358.98 588.72 418.72 32.31 -0.58 2,230,495.31 206,222.21 5.00 32.31 Start Dir 6°/100':591'MD,588.72'TVD 600.00 13.44 358.98 597.48 427.48 34.36 -0.61 2,230,497.36 206,222.23 6.00 34.36 700.00 19.44 358.94 693.35 523.35 62.64 -1.13 2,230,525.65 206,222.40 6.00 62.65 800.00 25.44 358.93 785.74 615.74 100.79 -1.84 2,230,563.80 206,222.62 6.00 100.80 900.00 31.44 358.92 873.63 703.63 148.38 -2.73 2,230,611.40 206,222.88 6.00 148.41 1,000.00 37.44 358.91 956.06 786.06 204.90 -3.80 2,230,667.93 206,223.19 6.00 204.94 1,100.00 43.44 358.90 1,032.14 862.14 269.72 -5.04 2,230,732.77 206,223.53 6.00 269.77 1,200.00 49.44 358.90 1,101.02 931.02 342.14 -6.43 2,230,805.20 206,223.90 6.00 342.20 1,300.00 55.44 358.89 1,161.95 991.95 421.36 -7.96 2,230,884.43 206,224.31 6.00 421.44 1,400.00 61.44 358.89 1,214.26 1,044.26 506.52 -9.60 2,230,969.60 206,224.73 6.00 506.61 1,500.00 67.44 358.89 1,257.39 1,087.39 596.67 -11.35 2,231,059.77 206,225.18 6.00 596.78 1,592.64 73.00 358.89 1,288.73 1,118.73 683.80 -13.04 2,231,146.91 206,225.61 6.00 683.92 End Dir :1592.64'MD,1288.73'TVD 1,600.00 73.00 358.89 1,290.88 1,120.88 690.83 -13.18 2,231,153.95 206,225.65 0.00 690.96 1,700.00 73.00 358.89 1,320.12 1,150.12 786.44 -15.04 2,231,249.58 206,226.12 0.00 786.59 1,800.00 73.00 358.89 1,349.36 1,179.36 882.06 -16.90 2,231,345.20 206,226.58 0.00 882.22 1,900.00 73.00 358.89 1,378.60 1,208.60 977.67 -18.76 2,231,440.83 206,227.05 0.00 977.85 2,000.00 73.00 358.89 1,407.84 1,237.84 1,073.28 -20.62 2,231,536.46 206,227.52 0.00 1,073.48 2,100.00 73.00 358.89 1,437.08 1,267.08 1,168.89 -22.48 2,231,632.09 206,227.99 0.00 1,169.11 2,200.00 73.00 358.89 1,466.32 1,296.32 1,264.50 -24.34 2,231,727.72 206,228.46 0.00 1,264.74 2,300.00 73.00 358.89 1,495.56 1,325.56 1,360.11 -26.20 2,231,823.35 206,228.93 0.00 1,360.37 2,400.00 73.00 358.89 1,524.80 1,354.80 1,455.73 -28.06 2,231,918.98 206,229.40 0.00 1,456.00 2,500.00 73.00 358.89 1,554.04 1,384.04 1,551.34 -29.92 2,232,014.60 206,229.87 0.00 1,551.63 2,600.00 73.00 358.89 1,583.27 1,413.27 1,646.95 -31.78 2,232,110.23 206,230.34 0.00 1,647.26 2,700.00 73.00 358.89 1,612.51 1,442.51 1,742.56 -33.64 2,232,205.86 206,230.81 0.00 1,742.89 2,800.00 73.00 358.89 1,641.75 1,471.75 1,838.17 -35.50 2,232,301.49 206,231.28 0.00 1,838.52 2,900.00 73.00 358.89 1,670.99 1,500.99 1,933.78 -37.36 2,232,397.12 206,231.75 0.00 1,934.15 3,000.00 73.00 358.89 1,700.23 1,530.23 2,029.40 -39.22 2,232,492.75 206,232.22 0.00 2,029.78 3,100.00 73.00 358.89 1,729.47 1,559.47 2,125.01 -41.08 2,232,588.37 206,232.68 0.00 2,125.40 3,200.00 73.00 358.89 1,758.71 1,588.71 2,220.62 -42.94 2,232,684.00 206,233.15 0.00 2,221.03 3,300.00 73.00 358.89 1,787.95 1,617.95 2,316.23 -44.80 2,232,779.63 206,233.62 0.00 2,316.66 3,400.00 73.00 358.89 1,817.19 1,647.19 2,411.84 -46.66 2,232,875.26 206,234.09 0.00 2,412.29 8/25/2014 5:36:33PM Page 3 COMPASS 5000.1 Build 70 • • Halliburton HALLIBURTOI'.1 Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Paxton#7 Company: Hilcorp Energy Company TVD Reference: Plan Paxton 7 @ 170.00usft Project: Ninilchik Unit MD Reference: Plan Paxton 7 @ 170.00usft Site: Paxton North Reference: True Well: Paxton#7 Survey Calculation Method: Minimum Curvature Wellbore: Paxton#7 Design: Paxton#7 wp5.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (0) (°) (usft) usft (usft) (usft) (usft) (usft) 1,676.43 3,500.00 73.00 358.89 1,846.43 1,676.43 2,507.45 -48.51 2,232,970.89 206,234.56 0.00 2,507.92 3,600.00 73.00 358.89 1,875.67 1,705.67 2,603.07 -50.37 2,233,066.52 206,235.03 0.00 2,603.55 9 5/8" 3,700.00 73.00 358.89 1,904.91 1,734.91 2,698.68 -52.23 2,233,162.14 206,235.50 0.00 2,699.18 3,800.00 73.00 358.89 1,934.15 1,764.15 2,794.29 -54.09 2,233,257.77 206,235.97 0.00 2,794.81 3,900.00 73.00 358.89 1,963.39 1,793.39 2,889.90 -55.95 2,233,353.40 206,236.44 0.00 2,890.44 4,000.00 73.00 358.89 1,992.63 1,822.63 2,985.51 -57.81 2,233,449.03 206,236.91 0.00 2,986.07 4,100.00 73.00 358.89 2,021.87 1,851.87 3,081.12 -59.67 2,233,544.66 206,237.38 0.00 3,081.70 4,200.00 73.00 358.89 2,051.11 1,881.11 3,176.74 -61.53 2,233,640.29 206,237.85 0.00 3,177.33 4,300.00 73.00 358.89 2,080.35 1,910.35 3,272.35 -63.39 2,233,735.92 206,238.31 0.00 3,272.96 4,400.00 73.00 358.89 2,109.59 1,939.59 3,367.96 -65.25 2,233,831.54 206,238.78 0.00 3,368.59 4,500.00 73.00 358.89 2,138.83 1,968.83 3,463.57 -67.11 2,233,927.17 206,239.25 0.00 3,464.22 4,600.00 73.00 358.89 2,168.07 1,998.07 3,559.18 -68.97 2,234,022.80 206,239.72 0.00 3,559.85 4,700.00 73.00 358.89 2,197.31 2,027.31 3,654.79 -70.83 2,234,118.43 206,240.19 0.00 3,655.48 4,800.00 73.00 358.89 2,226.54 2,056.54 3,750.41 -72.69 2,234,214.06 206,240.66 0.00 3,751.11 4,900.00 73.00 358.89 2,255.78 2,085.78 3,846.02 -74.55 2,234,309.69 206,241.13 0.00 3,846.74 5,000.00 73.00 358.89 2,285.02 2,115.02 3,941.63 -76.41 2,234,405.31 206,241.60 0.00 3,942.37 5,085.42 73.00 358.89 2,310.00 2,140.00 4,023.30 -78.00 2,234,487.00 206,242.00 0.00 4,024.06 Start Dir 2°/100':5085.4T MD,2310'TVD 5,100.00 72.71 358.89 2,314.30 2,144.30 4,037.23 -78.27 2,234,500.93 206,242.07 2.00 4,037.99 5,200.00 70.71 358.89 2,345.68 2,175.68 4,132.15 -80.12 2,234,595.87 206,242.53 2.00 4,132.93 5,300.00 68.71 358.89 2,380.37 2,210.37 4,225.92 -81.94 2,234,689.66 206,242.99 2.00 4,226.72 5,400.00 66.71 358.89 2,418.30 2,248.30 4,318.43 -83.74 2,234,782.18 206,243.45 2.00 4,319.24 5,500.00 64.71 358.89 2,459.44 2,289.44 4,409.55 -85.51 2,234,873.32 206,243.90 2.00 4,410.38 5,600.00 62.71 358.89 2,503.73 2,333.73 4,499.18 -87.25 2,234,962.97 206,244.34 2.00 4,500.03 5,700.00 60.71 358.89 2,551.13 2,381.13 4,587.22 -88.97 2,235,051.01 206,244.77 2.00 4,588.08 5,800.00 58.71 358.89 2,601.57 2,431.57 4,673.54 -90.65 2,235,137.35 206,245.19 2.00 4,674.42 5,900.00 56.71 358.89 2,654.99 2,484.99 4,758.05 -92.29 2,235,221.88 206,245.61 2.00 4,758.95 6,000.00 54.71 358.89 2,711.33 2,541.33 4,840.65 -93.90 2,235,304.49 206,246.01 2.00 4,841.56 6,100.00 52.71 358.89 2,770.52 2,600.52 4,921.23 -95.46 2,235,385.09 206,246.41 2.00 4,922.16 6,200.00 50.71 358.89 2,832.48 2,662.48 4,999.70 -96.99 2,235,463.57 206,246.79 2.00 5,000.64 6,300.00 48.71 358.89 2,897.15 2,727.15 5,075.95 -98.47 2,235,539.84 206,247.17 2.00 5,076.91 6,400.00 46.71 358.89 2,964.44 2,794.44 5,149.91 -99.91 2,235,613.80 206,247.53 2.00 5,150.88 6,500.00 44.71 358.89 3,034.27 2,864.27 5,221.47 -101.30 2,235,685.38 206,247.88 2.00 5,222.45 6,600.00 42.71 358.89 3,106.55 2,936.55 5,290.55 -102.65 2,235,754.47 206,248.22 2.00 5,291.54 6,700.00 40.71 358.89 3,181.20 3,011.20 5,357.06 -103.94 2,235,821.00 206,248.55 2.00 5,358.07 6,800.00 38.71 358.89 3,258.13 3,088.13 5,420.94 -105.18 2,235,884.88 206,248.86 2.00 5,421.96 6,900.00 36.71 358.89 3,337.24 3,167.24 5,482.08 -106.37 2,235,946.04 206,249.16 2.00 5,483.12 7,000.00 34.71 358.89 3,418.44 3,248.44 5,540.43 -107.51 2,236,004.40 206,249.45 2.00 5,541.48 7,098.07 32.75 358.89 3,500.00 3,330.00 5,594.87 -108.57 2,236,058.85 206,249.71 2.00 5,595.92 Total Depth:7098.07'MD,3500'TVD-5 1/2" 8/25/2014 5:36:33PM Page 4 COMPASS 5000.1 Build 70 S • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Paxton#7 Company: Hilcorp Energy Company TVD Reference: Plan Paxton 7 @ 170.00usft Project: Ninilchik Unit MD Reference: Plan Paxton 7 @ 170.00usft Site: Paxton North Reference: True Well: Paxton#7 Survey Calculation Method: Minimum Curvature Wellbore: Paxton#7 Design: Paxton#7 wp5.0 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) Pax#7_BIg50 T2 0.00 0.00 2,093.00 4,023.30 -78.00 2,234,487.00 206,242.00 -plan misses target center by 207.52usft at 5021.97usft MD(2291.45 TVD,3962.64 N,-76.82 E) -Point Pax#7_B1g50 T2 Adjusted 0.00 0.00 2,310.00 4,023.30 -78.00 2,234,487.00 206,242.00 -plan hits target center -Point Pax#7_TD4 T2 0.00 0.00 3,500.00 5,514.05 57.74 2,235,974.00 206,414.00 -plan misses target center by 179.08usft at 7051.41 usft MD(3460.96 TVD,5569.32 N,-108.07 E) -Point Pax#7_TD4 T3 0.00 0.00 3,500.00 5,510.25 -98.22 2,235,974.00 206,258.00 -plan misses target center by 71.48usft at 7050.98usft MD(3460.61 TVD,5569.08 N,-108.07 E) -Point Plan @ 2140.00(Paxton#7 Paxton#7 Paxton#7 wi 0.00 0.00 2,140.00 4,049.81 10.34 2,234,511.35 206,330.96 -plan misses target center by 191.65usft at 5059.41 usft MD(2302.40 TVD,3998.44 N,-77.52 E) -Circle(radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (') (") 7,098.07 3,500.00 5 1/2" 5-1/2 6 3,600.00 1,875.67 9 5/8" 9-5/8 12-1/4 80.00 80.00 16" 16 16 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 261.00 261.00 0.00 0.00 Start Dir 3°/100':261'MD,261'TVD 441.00 440.73 8.47 -0.15 Start Dir 5°/100':441'MD,440.73'TVD 591.00 588.72 32.31 -0.58 Start Dir 6°/100':591'MD,588.72'TVD 1,592.64 1,288.73 683.80 -13.04 End Dir :1592.64'MD,1288.73'TVD 5,085.42 2,310.00 4,023.30 -78.00 Start Dir 2°/100':5085.42'MD,2310'TVD 7,098.07 3,500.00 5,594.87 -108.57 Total Depth:7098.07'MD,3500'TVD 8/25/2014 5:36:33PM Page 5 COMPASS 5000.1 Build 70 0 • Z1 m EnL CD a a Mo _ Q I.umW Q J = a N 0 E C I- m N c N O U A c N a w m §s a v d c N o v m o 11 w M N O _a O C N • {O W d M x O 03 O ° R O y O L LO a) • + CI rn a o s 3 ? m N O II 1111111 CU O d a ..° y to L U 3• ' c t Now ` c W Q U 3 V• D_ N N 3 c• N 3a) LL W L. 0 = c 0 r-- ui-C # O O a) U d A� o N .o C N O ` a W " Q C W O '+ E . r- 11) i V �- 'K v p CO 0,._0 2 c K N T d J Q C a g N a 1- Q -6 m o Om CC13 0 a i c ^ ° 'E O o L Fs- � N.. V a, . O_ O OOi LL (� N O 'r *k *k k L N c 'w .. o N o 0 S C C C C CU • a 0 E rn ai = U o t' c a In Ill ID c ■ 'C < x X x — -, aa, 2i) C coi E • a ° c c as as tz co UJ V < .• ` — `° `° o t nr m I Z a a d M U KBO mm (7 > N (n 11111 C0 • • E x 0 o zO W a A. in Q N N N N N N N N N N N N N N N N N V D m m O CO m m a CO o m O a CO CO a (a CL a a a a a a a a a a a a a a a a '_' C 0 13 N E O C C C C C O 7 110. 7-95 .11. 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Q ' o M ii �� N i CV CV OA o ; ., _ L 't7 i cr 2 O as 1 .> o 0) CD 4-1 Lo vt CL - N ~ U O N CO C O O I 0 : awl N ti I I I I I I I L_i i i I i i i i i ( i I I I i I I i I i i i i i I Ili i i i O M Q V O N O r 0 LO N 0 UC O 113 xi r O N M N O _ a (u!/09'Z)JoToed uoijeiedeg < U • HALLIBtJRTOIV Project: Ninilchik Unit WELL DETAILS: Paxton#7 Sperry Drilling Services Site: Paxton Ground Level: 149.00 Well: Paxton #7 +N/-S +EI-W Northing Easting Latittude Longitude Slot Wellbore: Paxton #7 0.00 0.00 2230463.00 206222.00 60.09565365 -151.60957882 Plan: Paxton#7 wp5.0 REFERENCE INFORMATION Co-ordinate(N/E)Reference:Well Paxton#7,True North Vertical(TVD)Reference:Plan Paxton 7 @ 170.00usft Measured Depth Reference: Plan Paxton 7 @ 170.00usft Calculation Method:Minimum Curvature Paxton#7 wp5.0 6000— _ I Pax#7_TD4 T3I I Pax#7_TD4 T2/ I I � I 51/2" ,' i - Paxton#3 Suave s i 'SOq 5500— IY – 3250 3000 5000- 2750 4500— 2500 I Pax#7_B1g50 T2I 4000— - 2250 3500— 0 3000— 2000 9 5/8" 2500— 359° 1750 2000- 1500— CASING DETAILS 1.00 TVD TVDSS MD Name Size 80.00 -90.00 80.00 16 16" 1875.67 1705.67 3600.00 9-5/8 9 5/8" 1000— 3500.00 3330.00 7098.07 5-1/2 5 1/2" 1251 500— _ -1000 T 4� M Azimuths to True North �►16" Magnetic North:16.57° 0— ' Magnetic Field Strength:55199.9snT Dip Angle:73.11° _ Date:9/11/2014 Model:BGGM2013 500— I I I I -1 1 1 1 1 1 1 1 I 1 1 1 1 -1000 -500 0 500 1000 1500 2000 2500 3000 3500 nn West(-)/East(+)(750 usft/in) fl I-Hilcorp • • -m -- o m _0 o - CD Q _ N - 0 C) —O LO m - r 00 m MM - n w 1- C - O m Oj UU 0000.-N0M 08 C TT mOO V co 0 0 co - I,- 7,3 00 >OOa) jCo.1-u1 MpOND ,- > HM2 V N F _ 0000)p 0 - O m(p 0 0 0'0 M LO O C 0.-R'=1n�U(p) ti266666OO I- - O o WM 0 n r ~ M 0- 1-800,0 K 'm0 #* - / # O 0 N o 0 010000000 lV X _ ........ a o O a , m m DOOM n OON O a as WQ 00 (p JC100 > p0 �p�p C)O OO N(00r - \\\ III 0 'C y N 22N a' o C 3 j NCV(V N 0 N Oi \ wSJ OW(ON M ~O Q.D 0 ** LLINN,�N(p,(N(ppp(N(pp(N(pN cr III h O > (N r .O XOX 8888888 N NNN(O8NN �•\ U) 0 3 N N H o (nas aoo oo 1 - cooammopo NI E, Q t(+)(b�u)(or� 1 - CO - Hoo W rcOf,vm,-vo H 1 _ Z(0.j YOo 0 Z0000'-v 6 1 O 'CO 00 00o 0 0Mo 0 NNNNNNN Q a _ N F > p 3 N E00 w ?oo�(0no0(rn mI 1-... - > mop rn W6606O66 at - o 0 LL(NO + -r-0 (0 0 0 W• a M C- \ - C o 00010001---v-001,-.-oo \ a 0 0 V M O M N \ - W zoopd(\i(da)g \ (n + MMN f000 0 O 28 o +0 (n O O M N M O O - NoorNr00 - 0O'.-0 •x000 M VMr-..-,-V((9 F.7 N V.-(M - 0 CO N M _ - CO (I) 0 0 0 M N M O (h N(OOM6,60 O6+-0 m 214) NVONOW 0 fns NM O MO _ 0000)0)0) W OM O)0) •-• < 00 OONOO N 0 6666666u) - mopQ m M 00000 Es-0- m L MMMMM O - Ta Z 66Cj o-`+'Up 1 Y 0 . —0 C 000000 COOVWOOr-Uqq..VOOnr Lo - cm ,_(1)ppor Ea Q �nM ....- _1 - NNR _000 0 W MOM 0 0 p) E 0 0 [100001.N1,- 0 0 0 0)0 V 0 - 0 m c_qUWW .---+-c.106 NNn0 Z VVMMCOM -- ON[1,0000W 'Ot'Oiliij O 0LU M EL LNL 0008 N FNM V N0N - U (0Dmomfm >90o C t 0 0) 3(p M 2 t O t C - 0 1p W(nW C O U 2 La- 'r- 001.-.0 I C J j >000 0 ZOO - 1-o no 600 moo _ __m , t@Um —0 0 NN Z o Z st O H gs0 C _ g '�ml > > I,. r,. - O mm(_Cac Y *k O - 0 aa� O O O oo + w w �t += k k k 3 `° w T� g zaaa1. m`m 4t 0 = W01103 � CD: � do F zol •10 k 0 - 11.-v,0 U 0 - _ �m i 0 rn oCr ' 0 s —0 L - o J 0 ++fixfi I I I I I I I I I i I I I I l I I I I I I I I II I 1 1 1 1 1 I I I 1 I I I I 1 I I I I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 i 1 1 1 0 I Y) 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 (n 0 u) Ut) 0 0 LO 0 (0 0 (() N N M M V V (uiijsn QQQ )4Tdea leai;aaA anal • • Davies, Stephen F (DOA) From: Luke Keller <Ikeller@hilcorp.com> Sent: Monday, August 25, 2014 2:44 PM To: Davies, Stephen F (DOA) Subject: Paxton#7 Directional Info Attachments: Paxton #7 wp5 Proposal Report.pdf; Paxton #7 wp5.0 - GIS Format.txt; Paxton#7 wp5.0.txt Steve, See attached info per your request. Let me know if I can do anything else to assist during your approval process. Thanks! Luke Keller Drilling Engineer Hilcorp Alaska, LLC 907-777-8395 1 • • Davies, Stephen F (DOA) From: Luke Keller <Ikeller@hilcorp.com> Sent: Monday, August 25, 2014 11:17 AM To: Davies, Stephen F (DOA) Subject: RE: Paxton 7 (PTD #2141300): Need Additional Planned Directional Survey Data Attachments: Alaska Sperry -Paxton#7 wp5 Anti-Collision Summary.pdf; Paxton#7 wp5.0 - GIS Format.txt; Paxton #7 wp5.0 Plan view.pdf; Paxton #7 wp5.0 Vertical view.pdf; Paxton #7 wp5.0.txt Steve, See attached directional info for Paxton #7. There are .txt files attached that our folks prefer for uploading into different programs. Would you prefer the data in excel format? From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Monday, August 25, 2014 10:39 AM To: Luke Keller Subject: Paxton 7 (PTD #2141300): Need Additional Planned Directional Survey Data Luke, I'm reviewing Hilcorp's Paxton 7 Permiit to Drill application. A copy of the planned directional survey was not submitted with the application, only map- and profile-view diagrams. Could you please email me a copy of the planned survey? Also, if Hilcorp could also provide these data in spreadsheet format, that will help speed my review of the application. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 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. 1 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. s ! TRANSMITTAL LETTER CHECKLIST WELL NAME: (e0( '/2=v"'" 7 PTD: ?-^/4// t3C / Development Service _ Exploratory _ Stratigraphic Test _ Non-Conrcntional FIELD: r1.J /C. U I is .. POOL: Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are Well Logging also required for this well: 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 5/2013 40 ! 0 0 O N co oa CD a U a) O a), c N O • Q Q 6� V, N a co y c, o'o o, vi n O - m c -co, 'rn_c co , a co C o -6 .C, a 000. a O co E U ai 2 u) V.. O)• 0) Eif 0 0 a) O 00) N 0. L• _ p, .p. 0 0_ CD -O p, -0. — N @' rnCD ° E 3 m E �.cts c, �. 3 U) ) =. 0, • c LL. o c — C' p, a N LL S �� p. �� in o co Y. o tca t oi. j) y, �. U co 0 CV Z O E' t0 U O t, 3, w W N. 3 a a) c 0' O) To �; m ._ o, N, p, of a 4 y. c c m y. a�ai 0 a' 2 0' a) y N — ca a 4 0 'Lo 0, m ° ° x a co co Li ci cc H -0 C W, m. 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Paxton #7 Ninilchik Unit Kenai Peninsula Borough, Alaska September 25, 2014 – October 4, 2014 Provided by: Approved by: Dave Buthman Compiled by: Ralph Winkelman H a r r y B l e y s Distribution Date: November 13, 2014 Paxton #7 2 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ................................................................................................3 1.1 Equipment Summary ......................................................................................................................3 1.2 Crew................................................................................................................................................3 2 GENERAL WELL DETAILS...................................................................................................................4 2.1 Well Objectives...............................................................................................................................4 2.2 Hole Data........................................................................................................................................4 2.3 Daily Activity Summary...................................................................................................................5 3 GEOLOGICAL DATA.............................................................................................................................7 3.1 Lithostratigraphy .............................................................................................................................7 3.2 Lithology Details..............................................................................................................................7 3.3 Sampling Program........................................................................................................................12 4 DRILLING DATA..................................................................................................................................13 4.1 Surveys.........................................................................................................................................13 4.2 Bit Record.....................................................................................................................................16 4.3 Mud Record ..................................................................................................................................17 4.4 Drilling Progress Chart..................................................................................................................18 5 DAILY REPORTS ................................................................................................................................19 Enclosures 2” / 100’ Formation Log (MD/TVD) 5” / 100’ Formation Log (MD/TVD) 2” / 100’ LWD Combo Log (MD/TVD) 2” / 100’ Drilling Dynamics Log (MD/TVD) 2” / 100’ Gas Ratio Log (MD/TVD) Final Data CD Paxton #7 3 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type /Position Total Downtime Comments Computers – Surface Logging (5) Rigwatch Server, Rigwatch Remote DML, LWD WITS, Rigwatch Remote 0 hours Ditch gas QGM gas trap; Flame ionization total gas & chromatography. 0 hours Hook Load / Weight on bit WITS from Pason 0 hours Mud Flow In Derived from Strokes/Minute and Pump Output 0 hours Mud Flow Out WITS from Pason 0 hours Pit Volumes, Pit Gain/Loss WITS from Pason 0 hours Pump Pressure WITS from Pason 0 hours Pump Stroke Counters (2) WITS from Pason 0 hours Rate of Penetration Calculated from Pason 0 hours RPM WITS from Pason 0 hours Torque WITS from Pason 0 hours WITS To/ From Pason Rigwatch Remote (HP Compaq) 0 hours 1.2 Crew Mud Logging Unit Type: Arctic Mud Logging Unit Number: ML057 Logging Geologists Years1 Days2 Sample Catchers Years Days2 Ralph Winkelman 23 17 Jim Adams 2 7 Harry Bleys 14 9/24 Dickey Hudgins 4 10 Eli Callan .5 10/6 *1 Years experience as Mudlogger *2 Days at wellsite between rig up and rig down of logging unit. Paxton #7 4 2 GENERAL WELL DETAILS 2.1 Well Objectives Paxton #7 is a twin to the Paxton 3 Beluga 50 gas sandstone. The base plan is an S-turn wellbore with a shallow kickoff at 251’ MD, building to a maximum inclination of 73 deg, then dropping back to 32 degrees by TD. Operator: HILCORP ALASKA, LLC Well Name: Paxton #7 Field: Kenai Beluga Unit County: Kenai Peninsula Borough State: Alaska Company Representatives: Doug Yessak, Kevin McDowell Location: Surface Coordinates 3016’ FEL, 855’ FNL, Sec 13, T1S, R14W, SM, AK Ground ( Pad ) Elevation 148.35’ NGV29 Rotary Table Elevation 166.85’ AMSL Classification: Development - Gas API #: 50-133-20643-00-00 Permit #: 214-130 Rig Name/Type: Saxon 147 / Land / Double Spud Date September 25, 2014 Total Depth Date: October 4, 2014 Total Depth 4695’ Primary Targets Beluga 50, 60 Primary Target Depths 4524’ MD, 2140’ TVD/ 4987’ MD, 2476’ TVD Total Depth Formation: Beluga Completion Status: Cased LWD-MWD Services. Halliburton/ Sperry Drilling Services Directional Drilling Halliburton/ Sperry Drilling Services Wireline Logging Services Well not wire-lined. Drilling Fluids Service M.I. Swaco 2.2 Hole Data Max Depth Shoe Depth Hole Section MD (ft) TVD (ft) TD Formation MW ppg Dev oinc Csg Dia MD (ft) TVD (ft) FIT ppg 12 ¼” 1945’ 1376.66’ Sterling 9.5 75.25 9 5/8” 1936’ 1374.37’ 12.0 8 ½” 4695’ 2193.41’ Beluga 10.4 72.8 5 ½” 3542’ 1849.401 Paxton #7 5 2.3 Daily Activity Summary 9/23/2014: Winkelman arrives on locations and rigs up unit. Rig continues rig up. 9/24/2014: rig up diverter, mix mud. 9/25/2014: rigged up and tested diverter. Run in hole and tagged at 129 ft. @ 22:30, spud well. Rig accepted at 06:00 on 9/25/2014 9/26/2014: rotary drilling and sliding to build angle 9/27/2014: performed a wiper trip from 1571 to surface. Found a tight spot at 1309 ft. And pumped the rest of the way to surface. Tripped back in hole and continued to drill ahead. Drilled until 1904 ft. Stopped and circulated bottoms up to check formation. At present waiting on lag to bring cuttings up. 9/28/2014: due to tightness of hole we pumped out to 1415 ft and pulled out on elevators to 502'. Using elevators we tripped back in hole to 1888 ft. We washed down to 1945 ft and circulated bottoms up recieving105 units of gas. A high viscous sweep was pumped with an increase of 5o% cuttings, yet was on time per calculations. Pulled out of hole on elevators and began laying down bottom hole assembly. Rigged up casing crew to run 9.625 " casing. 9/29/2014: ran casing and rigged down casing crew. Rigged up cementing high pressure lines and tested. Pumped cement jobs and rigged down cement crews. Commenced work on stack to prepare it for new BOP’s by nippling down and up the stack to take new sized BOP’s. Cleaning pits and performing rig maintenance. 9/30/2014: Nippled down stack and nippled up with new BOP’s. Uninstalled annular double gate. Mud cross, choke, kill hydro, and manual valves. Installed flow box, bell nipple, flow line, rigged down and laid down bop pick up lines from topdrive, and unloaded and staged 5" drill pipe. Organized location, and installed choke and kill high pressure hoses. Reinstalled cds-40 saver sub for bop test. Hooked up koomy lines and secured stack. Charged koomy and rigged up cross over 5.5 rams. At present testing BOP’s. 10/1/2014: picked up 110 joint of drill pipe, and six joints of heavy weight drill pipe. Rigged up and tested casing to 2900 psi and held for thirty minutes. After test bleed off pressure. Blowed down lines and choke manifold. Cleaned and prepared the main floor for BHA. Staged tools. Directional and MWD made up BHA. Scribed motor and circulated. Downloaded MWD tools and held pre-job safety meeting on the radioactive sources. 10/2/2014: run in hole with singles, slip and cut drill line, service rig. Tag float collar at 1847 ft and drill out the float collar. Then drill cement and shoe. Drill ahead. High gas units causes mud to rise to 10.2 ppg. Gas 411 u @ 2112 ft., 339 u @ 2267 ft, 768 u @2358 ft, 1160 u @ 2403 ft. , 1236 u @ 2472 ft. , 1298 u @ 2514 ft, 1136 u @ 2609 ft. , 932 u @ 2643 ft., 675 u @ 2773 ft. , and 920 u @ 2975 ft. 10/3/2014: pump tandem sweeps and circulate hole clean. Perform short trip from 3501 to shoe. Reamed at 2959 ft. And 2850 ft. Serviced rig by greasing topdrive, crown, mud pumps, and draw works. Tripped back in hole and had 72u max as wiper trip gas. Commenced drilling ahead and had max gases at 371 u @ 3543 ft., 386 u @ 3615 ft., 637 u @ 3671 ft., 602 u @ 3767 ft., 271 u @ 3880 ft., 623 u. @ 4115 ft. 10/4/2014: circulate LCM pill. Ream out of hole. Continue to pump LCM pill and continue to ream. Work pipe and fill out. Pump fluid down drill string and work tight hole. BHA hung up. Bit depth is 3916'. Jarred 8 times. Work torque up and down. Max gases: 684 u @ 4257', 467 u @ 4304', 644 u @ 4352', 577 u @ 4461.' Paxton #7 6 10/5/2014: rig up E-line tools. Load shot and run in hole to 500 ft. Apply left hand torque to drill pipe. Continue to run in hole with E-line. Pump E-line down hole to target depth and set off charge. Work drill string. Target connection did not release. Pull out wireline and pack new charge. Put 14,500 lbs of reverse torque to drill string. Work torque down and compress drill string 40 k. Pump charge down and set off second charge. Work drill string 160 k up and 30 k down. No release. Pull out wireline and rig down tools. Make up string cock lick and re-cock jars. Make up wireline tools and FOSV. Make up third charge. Send third charge down hole. Slack off to 35 k and pump wireline down. Preparing to set off third charge at bottom of jars. Wireline depth is 3619 ft. 10/6/2014: Applied left hand torque on drill pipe. Made up a new charge and pumped it down hole and worked pipe. Regained partial returns at 08:30 of 9 bpm. Continued to monitor strokes per minute along with flow. Rigged down e-line and, circulated and worked pipe. Reduced mud weight from 9.2 to 9.0 ppg. Currently losing mud at 10 bpm from original 70 bpm to 200+ bpm from beginning of original loses. Pumped a lube around the BHA worked pipe. Rigged up wireline and attempted to free pipe. Max Gas from 08:30 partial restoration of circulation was 91 u. 10/7/2014: fire shot and successful back off. Rig down e-line and circulate hole. Perform rig Service and derrick inspection. Pull out on elevators. Brake circulation and pump high viscous sweep. Continue to pull out on elevators. Strap tally fishing BHA, and off loaded Tally and strap drill collars. Prepare drill floor for fishing tool. Reposition stands in Derrick. After pre job safety meeting make up fishing BHA. Screw in sub, circulate control Joint bumper sub with five collars, cross over intensifier. Run in five stands of heavy Weight. Inspect and re-dope connections. Cut and slip drill line and prepare to run in hole. 10/8/2014: Run in hole with new BHA and fish tool. Wash down to fish at 3559 Ft. Latch fish and pick up to 100 K and work torque down hole to connection. Start fishing operation with attempting to work fish down hole with bumper sub open. Trap torque in string and work down hole. Continuing to work fish down hole. Starting jars up operation by applying torque to string when jarring. Inspect derrick, topdrive, bop, and brake linkage. Continue to jar up. Set jars off 125 times. Continue to inspect derrick, topdrive, bop, and brake linkage. The constant jarring creates a situation where the derrick needs to be constantly inspected. Set off jars sixty times. Spot a lube pill and continue to jar up. Max gas was 12 u. 10/9/2014: Continued to fish. Decision made to cease fishing operation. Rig up E-line and run in hole. Apply left hand torque. Fire shot and lost torque. Back off pipe and pump slug and pull out of hole. At present making up clean out BHA. 10/10/2014: Pull out of hole and lay down heavy weight drill pipe. Lay down drill collars, stabilizer, and bit. Flow check well. And shut blind rams. Clean rig floor of all unneeded equipment and blow down surfaces lines. Pull wear bushing and test run hanger with Cameron rep. Change upper rams to 5.5 inch casing rams. Rig up test equipment and test upper rams. Rig down test equipment, rig down bails and elevators. Hold rig service and held pre job safety meeting for casing crew. Rigged up casing equipment. and test CRT. Make up float and test float track. At present preparing to run in with casing. Paxton #7 7 3 GEOLOGICAL DATA 3.1 Lithostratigraphy Prognosed Tops by Hilcorp Geologist and Observed Tops by Hilcorp Geologist. PROGNOSED OBSERVED FORMATION MD (ft) TVD (ft) SSTVD (ft) MD (ft) TVD (ft) SSTVD (ft) Beluga 50 4525 2140 -1970 4205’ 2048’ -1882’ Beluga 60 Na Na Na NA NA NA 3.2 Lithology Details Full service mudlogging began at 1945’ MD/ 1376’ TVD. All the sample lithology descriptions provided by Canrig began after surface casing point. The well includes Beluga formations whose lithology of largely volcanic ash-derived fluvial sediments include: tuffaceous claystone, tuffaceous siltstone, sand/sandstone, volcanic ash, coal and various other minor to trace thinly bedded lithologies. The wellbore was drilled to 4695’ MD / 2193.42’ TVD / -2026.57’ TVDSS. Tuffaceous Claystone/ Tuffaceous Siltstone (1945' - 2050') = medium light to light gray with very light brown to brownish gray secondary hues; soft to mushy; irregular shaped cuttings; silty to clayey texture; dull to earthy luster hydrophilic; moderate to very soluble; slight to moderately expansive; poor adhesiveness; poor to fair cohesiveness; non calcareous. Tuffaceous Claystone/ Tuffaceous Siltstone (2050' - 2100') = medium light to light gray with medium gray secondary hues; soft; sticky at times; irregular shaped cuttings; silty to clayey texture dull to earthy luster; moderate to very soluble and expansive; hydrophilic; poor to fair cohesiveness; fair adhesiveness; non calcareous; trace dark brown to black carbonaceous material/ coal. Coal/ Carbonaceous Shale (2100'-2160') = black with brownish black secondary hues; very firm to hard; brittle; blocky to platy; massive; planar fracture dominant; earthy luster; smooth to slightly gritty texture; sub bituminous; grading to carbonaceous shale/ material; trace outgassing bubbles observed; thin coal beds in dominantly claystone/ siltstone formation. Tuffaceous Claystone/ Tuffaceous Siltstone (2160'-2220') = medium light gray to light gray with light bluish gray secondary hues; soft to slightly firm; irregular to shapeless cuttings; sticky; silty to clayey texture; dull luster; poor cohesiveness; fair adhesiveness; hydrophilic; moderate to very soluble; slight to moderately expansive; non calcareous; continued trace dark brown to black carbonaceous material/ coal; present as very thin beds. Paxton #7 8 Sand (2220' - 2280') = medium light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, medium to dark gray, black and dark greenish gray; very fine upper to trace very coarse upper, dominantly fine upper to lower; angular to subangular; unconsolidated; fair to good sorting; dominantly non calcareous. Tuffaceous Claystone/ Tuffaceous Siltstone (2280' - 2340') = medium light to light gray with light bluish gray secondary hues; soft to slightly firm; sticky; irregular to shapeless, globular cuttings with trace pdc bit action shaped firmer pieces; silty to clayey texture; dull to earthy to slightly waxy luster; hydrophilic; moderate to very soluble and expansive; poor to fair cohesiveness; fair adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions; trace thin coal beds/ carbonaceous shale beds. Sand (2340' - 2410') = medium to medium light gray overall with individual liths dominantly medium to dark gray, clear to translucent quartz and volcanic glass, black and light to medium to dark greenish gray; very fine lower to coarse upper, dominantly fine lower to upper; angular to subangular; unconsolidated; fair to good sorting; non calcareous. Coal/ Carbonaceous Shale (2410'-2460') = black with brownish black secondary hues; very firm to hard; brittle; flaky to platy; massive; planar fracture dominant; earthy luster; smooth to slightly gritty texture; sub bituminous; grading to carbonaceous shale/ material; trace to vigorous and prolonged outgassing bubbles observed; sub bituminous to bituminous; coal occasionally grading to carbonaceous shale/ material. Sand (2460' - 2540') = medium to medium dark gray overall with a strong salt and pepper appearance, individual grains dominantly medium to dark gray to greenish gray, black, clear to translucent quartz and volcanic glass, trace light gray and light greenish gray; very fine lower to coarse lower, dominantly fine lower to medium lower; angular to subangular; dominantly unconsolidated with trace sandstone; hard; medium dark gray; fine to medium grain; calcareous cement; poor to fair sorting. Tuffaceous Claystone/ Tuffaceous Siltstone (2540'-2600') = medium light gray to light gray with light bluish gray secondary hues; soft to slightly firm; irregular to shapeless cuttings; sticky; silty to clayey texture; dull luster; poor cohesiveness; fair adhesiveness; hydrophilic; moderate to very soluble; slight to moderately expansive; non calcareous; clay easily washed away during sample processing. Sand ( 2600' - 2660' ) = light gray to medium gray with traces of sandstone; lower medium to upper coarse grain size; loose unconsolidated sands with tuffaceous siltstone and tuffaceous claystone interbedded along with trace coals fallen from above; stringers of coal are thinly structured and bedded with rarely a notice in samples; subangular to subrounded grains; dominantly quartz; low to fair sphericity; visible etching on larger quartz grains; evidence of tuffaceous claystone of a moderate adhesive to cohesive strength. Tuffaceous Claystone/ Tuffaceous Siltstone (2660 - 2755’) = medium gray to dark gray color with soft to crunchy tenacity; hydrated tuffaceous claystone is soft and moderately cohesive and adhesive; rounded cuttings to formless shape with silky smooth texture with tuffaceous claystone and gritty texture with tuffaceous siltstone; both have volcanic tuff, ash and devitrified glass in evidence; both thin to thick structure with trace sands. Tuffaceous Claystone/ Tuffaceous Siltstone ( 2755' - 2810' ) = medium gray to medium dark gray color; hydrated tuffaceous claystone is soft to slightly crumbly in tenacity with irregular fracture and rounded cuttings for both; smooth claystone to gritty siltstone; structure is thin to thick with interbedded traces of loose unconsolidated sands and coal clasts. Paxton #7 9 Tuffaceous Claystone/ Tuffaceous Siltstone (2810' - 2895' ) = soft to crumbly with hydrated claystone has soft consistency; lumpy to rounded clast; tuffaceous siltstone is firmer with crumbly to crunchy tenacity; irregular fracture like tuffaceous claystone; rounded squat cuttings; claystone is smooth with siltstone is gritty with both having volcanic ash and tuff with devitrified glass seen throughout; loose unconsolidated sands with traces of coal and carbonaceous shale clasts; few coals are loosely compacted and heavily fracture with evidence of degassing. Tuffaceous Claystone/ Tuffaceous Siltstone ( 2895' - 2975' ) = medium gray to medium dark gray to dark gray color; soft consistency with tuffaceous claystone; crumbly tenacity with tuffaceous siltstone; irregular fracture for both with slumped cuttings with hydrated tuffaceous claystone; rounded squat blocky cuttings for siltstones; smooth texture for claystone and gritty texture for tuffaceous siltstone; thick to thin structure for both; traces thin stringers of coal with trace of carbonaceous shales and thinly bedded loose unconsolidated sands. Sand ( 29750' - 3015' ) = light gray to medium gray color; loose unconsolidated sands of lower medium to upper coarse grains; low sphericity; sub angular to sub rounded; evidence of surface etching with some conchoidal cratering; poorly sorted; trace coals. Tuffaceous Claystone/ Tuffaceous Siltstone ( 3015' - 3090' ) = medium gray to medium dark gray to dark gray color; hydrated claystone has soft consistency with irregular fracture and slumped cuttings; smooth texture and thick structure; tuffaceous siltstone is crumbly tenacity with irregular fracture and rounded blocky cuttings; gritty texture; thick structure and dull earthy luster; traces of loose unconsolidated sands of lower medium to lower coarse grain size and irregular shards of trace coal are interbedded. Sands ( 3090' - 3180' ) = light gray to medium gray color; well sorted with upper fine to upper medium grains with trace sandstone clasts; dominantly quartz grains sub angular to sub rounded with low to fair sphericity; sandstone clasts are moderately indurated; not easily sheared; grain supported with a matrix cement that is slightly reactive to hcl; dark carbonaceous materials is seen as trace with local country greenstone possibly chlorites; tuffaceous claystone and tuffaceous siltstone is interbedded with the loose unconsolidated sands and sandstones. Tuffaceous Claystone/ Tuffaceous Siltstone (3180' - 3250’) = medium gray to medium dark gray color; soft for consistency with malleable tenacity and irregular fracture; rounded slumped cuttings with hydrated tuffaceous claystone; tuffaceous siltstone is firm with crumbly tenacity and irregular fracture to rounded blocky cuttings; claystone are smooth and thickly bedded; tuffaceous siltstones are gritty with thick basal structure; over all dull earthy luster. Tuffaceous Siltstone (3250’ - 3320’) = medium gray to medium dark gray color; crumbly to crunchy tenacity; irregular fracture with trace black carbonaceous material interbedded through out; trace loose unconsolidated sands; tuffaceous siltstone is composed of volcanic ash and tuff with evidence of devitrified glass causing a slight shiny luster; tuffaceous claystone is entrained with the siltstone; moderate cohesive and adhesive properties; thick basal structure. Sand (3320’ - 3390’) = light gray to medium gray color; upper fine to upper medium grain size with trace lower coarse grain size; poorly to fair sorted; sub angular to sub rounded grains; low to fair sphericity; black carbonaceous material interbedded with sands; sands a mixture of quartz and tuffaceous claystone and tuffaceous siltstones; quartz grains are clear translucent to light green color; trace sandstone; dominantly grain supported sandstones; with low visual porosity. Tuffaceous Claystone/ Tuffaceous Siltstone (3390’ - 3460’) = medium gray to medium dark gray color; soft malleable consistency and tenacity for tuffaceous claystone; tuffaceous claystone becomes soft due to bit action and the content of your safe; smooth texture; irregular fracture with soft slumped cuttings: smooth texture with gritty texture with tuffaceous siltstone; both due to devitrified glass have a slight shiny luster; overall a thick structure. Paxton #7 10 Tuffaceous Claystone (3455’ - 3500’) = medium gray to medium dark gray color; soft consistency and tenacity; irregular fracture and slumped cuttings; smooth texture; dull earthy to slight shiny luster; thick basal structure. Tuffaceous Claystone/ Tuffaceous Siltstone (3500' - 3560') = medium to medium light gray with light bluish gray secondary hues; very soft; mushy to clumpy; shapeless, amorphous cuttings; silty to clayey texture; dull to greasy luster; hydrophilic; very soluble and moderately expansive; poor cohesiveness; fair to good adhesiveness; non calcareous; trace black, very fine lithic coal fragments. Sand (3560' - 3630') = medium light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, medium to dark gray; very fine lower to fine upper, dominantly very fine upper to fine lower; angular to subrounded, dominantly subangular; unconsolidated; fair to good sorting; non calcareous; sand present in trace amounts interbedded in clay formation. Coal/ Carbonaceous Shale (3630'-3660') = black with brownish black secondary hues very firm and hard to malleable and crumbly; planar fracture dominant; platy to flaky and scaly; resinous to earthy luster; smooth texture; sub bituminous to bituminous; weak trace visible outgassing bubbles detected; coal present as very thin bed in dominantly claystone/ siltstone formation. Tuffaceous Claystone/ Tuffaceous Siltstone (3660' - 3740') = medium to medium light gray with light bluish gray secondary hues; very soft; mushy to clumpy; shapeless, amorphous cuttings; silty to clayey texture; dull to greasy luster; hydrophilic; very soluble and moderately expansive; poor cohesiveness; fair to good adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions. Sand (3740' - 3800') = medium to medium light gray with salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass light to medium gray, dark gray and black very fine upper to fine upper; angular to subangular; unconsolidated; very well sorted; non calcareous; sand is easily supported/ suspended in clay formation; very soft and easily washed away in sample preparation. Tuffaceous Claystone/ Tuffaceous Siltstone (3800' - 3880') = medium light to light gray with light brownish gray secondary hues; soft to mushy, trace firm; shapeless, globular cuttings with trace firmer fragments showing pdc bit action scooped appearance; silty to clayey texture; dull to slightly waxy luster; hydrophilic; very soluble; moderately expansive; poor cohesiveness; fair to good adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions; clay acts as supporting matrix for loose sand grains. Sand (3880' - 3940') = medium gray overall with a strong salt and pepper appearance, individual grains dominantly medium to dark gray, black, clear to translucent quartz and volcanic glass; very fine upper to trace very coarse lower, dominantly medium upper to lower; angular to subangular; fair to good sorting; unconsolidated; non calcareous; loose sand grains supported by clay formation. Tuffaceous Claystone (3880 - 3985’) = medium gray to dark gray with slight black hues; soft malleable consistency; malleable tenacity; irregular fracture; slumped hydrated claystone cuttings; smooth texture with a dull earthy to slight shiny luster due to devitrified glass in the volcanic ash and tuff matrix; trace black carbonaceous material with fine to lower medium grain sized siltstone and trace sandstone clasts; moderate cohesiveness to strong bonded adhesiveness. Sand ( 3985' - 4060' ) = translucent clear to dirty grayish white to a light green color; dominantly quartz of a upper fine to lower medium with trace lower coarse grain size; angular to sub angular to sub rounded grains with low to fair sphericity and fair sorting; sands are disaggregate loose interbedded with claystones, and trace black carbonaceous materials; trace sandstone clasts in a grain supported loosely cemented matrix; reactive to hcl; loose high visual porosity; trace coal clast are visibly degassing. Paxton #7 11 Tuffaceous Claystone (4060' - 4120') = medium gray to medium dark gray to dark gray with black hues; soft consistency with malleable tenacity; hydrated claystone has irregular fracture with slumped rounded cuttings; smooth texture with dull earthy to slight luster; tuffaceous claystone is composed of volcanic ash, tuff and devitrified glass; streaks of black are from carbonaceous materials entrained with in the claystone; Tuffaceous Claystone/ Tuffaceous Siltstone (4120’ - 4190’) = medium gray to dark gray color with black hues; soft consistency; irregular cuttings; smooth texture and dull earthy to slight luster; overall tuffaceous claystone and tuffaceous siltstone have a thick basal structure; tuffaceous siltstone is gritty with a similar shiny luster due to devitrified glass in it's volcanic ash and tuff matrix; loose unconsolidated sands are entrained with the tuffaceous claystones. Tuffaceous Claystone ( 4190' - 4250' ) = medium gray to dark gray with black hues; soft consistency; malleable tenacity; irregular fracture; slumped rounded cuttings; smooth texture with slight shiny luster; overall basal structure is thick. Sand (4250’ - 4320’) = dominantly translucent quartz; well sorted; angular to sub rounded; with upper fine to upper medium grain size; surface etching; unconsolidated sands interbedded with tuffaceous claystone and tuffaceous siltstone and small stringers of coal; overall light gray with black carbon materials entrained; the rare coal clasts are seen degassing; low to fair sphericity; textural maturity is young to middle aged and worked; occasional green chlorite seen in sands. Tuffaceous Claystone/ Tuffaceous Siltstone (4320’ - 4385’) = medium gray to a very dark gray with strong black hues to a lighter dark gray with green hues; hydrated clays have a soft consistency; irregular fracture; tuffaceous siltstones are firmer with crumbly tenacity and irregular fracture; blocky rounded cuttings; tuffaceous claystones are smooth whereas tuffaceous siltstones are very gritty; overall thick basal structure; dull to shiny luster. Sand (4385' - 4470' ) = overall light to medium gray color; poor to fair sorted; sub angular to rounded with low to fair sphericity; trace sandstone clasts; loose unconsolidated sands are entrained with tuffaceous claystones; sand are not apparent until worked out of the soft hydrated tuffaceous claystone; black carbon materials and trace feldspars are entrained along with calcitic white marl; due to the clays strong adhesive and cohesive properties it takes time to liberate the sands; the quartz in the sand are translucent clear to grayish white with occasional green clast possibly chlorite. Tuffaceous Claystone ( 4470' - 4545' ) = dark gray to greenish dark gray with black hues; firmer to crumbly tenacity; irregular fracture; rounded blocky cuttings; smooth texture with a dull earthy luster; overall thick basal structure; loose unconsolidated sands entrained in the tuffaceous claystone; volcanic ash and tuff compose the clays matrix along with volcanic devitrified glass; tuffaceous claystone none reactive to hcl; as tuffaceous claystone dries the cohesiveness and adhesiveness reduces dramatically. Tuffaceous Claystone/ Tuffaceous Siltstone ( 4545' - 4615' ) = dark gray to greenish dark gray with black hues; crumbly to firmer; irregular fracture; rounded blocky cuttings; smooth texture for claystone and gritty texture for tuffaceous siltstone; both tuffaceous claystone and siltstone have volcanic ash and tuff matrix with volcanic devitrified glass entrained with is black carbonaceous materials and loose unconsolidated sands. Paxton #7 12 3.3 Sampling Program The sampling program specified by the Hilcorp Geologist called for the collection of two sets of Washed and Dried Reference Samples beginning at 1945’ MD. The resulting set, interval, and distribution are shown below. Sets Type and Purpose Interval Frequency Distribution A Washed and Dried Reference Samples 1940’ – 4695’ 20’ David Buthman Hilcorp Alaska LLC 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 B Washed and Dried Reference Samples 1940’ – 4695’ 20’ David Buthman Hilcorp Alaska LLC 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 Paxton #7 13 4 DRILLING DATA 4.1 Surveys Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 18.50 0.00 0.00 18.50 0.00 0.00 0.00 0.00 185.82 0.34 64.76 185.82 0.21 0.45 0.19 0.20 215.54 0.76 51.43 215.54 0.37 0.68 0.34 1.48 276.07 1.22 39.38 276.06 1.12 1.40 1.06 0.83 339.14 2.33 22.42 339.10 2.82 2.32 2.73 1.92 397.44 3.70 13.93 397.32 5.75 3.22 5.61 2.47 458.62 5.05 359.81 458.32 10.35 3.69 10.19 2.80 523.18 7.46 357.03 522.49 17.38 3.46 17.22 3.76 585.40 10.79 355.82 583.91 27.22 2.83 27.08 5.37 646.59 14.82 355.40 643.57 40.74 1.78 40.63 6.58 709.13 19.18 355.24 703.36 58.95 0.29 58.89 6.97 773.36 23.15 351.84 763.25 81.97 -2.38 82.00 6.47 835.94 26.56 351.84 820.03 108.00 -6.19 108.16 5.45 899.26 31.60 351.29 875.34 138.42 -10.79 138.75 7.97 963.27 35.30 352.45 928.75 173.35 -15.76 173.85 5.85 1027.12 37.81 353.40 980.03 211.08 -20.43 211.74 4.03 1090.59 41.08 355.55 1029.04 251.21 -24.28 251.99 5.59 1152.47 45.14 356.49 1074.21 293.39 -27.20 294.26 6.65 1215.63 50.66 357.54 1116.53 340.17 -29.63 341.10 8.82 1278.59 55.38 357.93 1154.40 390.41 -31.61 391.38 7.51 1341.03 59.78 358.43 1187.86 443.08 -33.28 444.08 7.08 1404.49 64.51 358.53 1217.50 499.15 -34.76 500.16 7.46 1467.85 67.70 358.41 1243.16 557.05 -36.31 558.08 5.03 1529.94 71.02 358.43 1265.05 615.13 -37.91 616.17 5.35 1593.05 73.61 358.79 1284.22 675.23 -39.37 676.28 4.14 1656.07 74.09 359.22 1301.75 735.76 -40.42 736.80 1.01 1720.09 74.22 359.86 1319.23 797.34 -40.91 798.35 0.98 1783.28 75.23 0.22 1335.87 858.30 -40.87 859.25 1.69 1845.39 75.63 0.46 1351.49 918.41 -40.52 919.30 0.74 1906.55 75.25 0.46 1366.87 977.61 -40.04 978.42 0.62 1937.95 75.11 0.21 1374.90 1007.96 -39.86 1008.75 0.90 2002.37 73.89 359.17 1392.11 1070.03 -40.19 1070.78 2.45 2065.55 73.94 359.12 1409.61 1130.74 -41.10 1131.47 0.11 Paxton #7 14 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 2128.48 73.03 358.34 1427.50 1191.05 -42.44 1191.79 1.88 2191.87 72.73 357.88 1446.16 1251.60 -44.44 1252.37 0.84 2255.32 72.68 357.88 1465.03 1312.14 -46.68 1312.95 0.08 2317.10 72.59 357.45 1483.47 1371.06 -49.08 1371.91 0.67 2380.86 72.51 357.07 1502.59 1431.81 -51.98 1432.74 0.59 2443.51 72.34 357.19 1521.50 1491.46 -54.97 1492.46 0.33 2507.27 72.50 357.14 1540.76 1552.17 -57.98 1553.24 0.26 2570.91 72.38 357.08 1559.96 1612.77 -61.04 1613.92 0.21 2634.26 72.28 356.94 1579.19 1673.05 -64.19 1674.27 0.27 2698.39 72.84 357.35 1598.41 1734.15 -67.24 1735.45 1.07 2761.66 72.79 357.02 1617.10 1794.53 -70.20 1795.89 0.50 2824.74 73.00 357.87 1635.65 1854.76 -72.89 1856.18 1.33 2888.87 73.35 357.60 1654.22 1916.09 -75.31 1917.57 0.68 2951.83 73.32 357.46 1672.27 1976.35 -77.91 1977.88 0.22 3015.19 73.34 357.05 1690.44 2036.98 -80.82 2038.58 0.62 3078.65 73.25 356.92 1708.68 2097.68 -84.02 2099.36 0.24 3142.23 73.12 356.51 1727.07 2158.44 -87.51 2160.21 0.65 3204.69 72.50 356.49 1745.53 2218.00 -91.15 2219.87 0.98 3268.75 71.86 358.97 1765.14 2278.93 -93.57 2280.85 3.81 3331.94 71.98 358.93 1784.75 2338.99 -94.67 2340.91 0.19 3396.01 72.00 358.50 1804.56 2399.91 -96.04 2401.82 0.65 3459.31 72.14 358.48 1824.05 2460.11 -97.63 2462.04 0.23 3520.19 72.12 358.14 1842.73 2518.03 -99.34 2519.98 0.53 3584.42 72.00 357.75 1862.51 2579.10 -101.53 2581.09 0.61 3647.83 71.87 357.70 1882.18 2639.33 -103.93 2641.37 0.22 3711.33 72.75 357.85 1901.47 2699.78 -106.27 2701.87 1.42 3774.27 72.85 357.43 1920.09 2759.86 -108.75 2761.99 0.67 3837.63 72.77 357.27 1938.81 2820.32 -111.55 2822.52 0.26 3900.83 72.75 357.04 1957.55 2880.61 -114.54 2882.88 0.36 3963.95 72.72 357.24 1976.28 2940.81 -117.55 2943.15 0.31 4027.26 72.66 356.87 1995.12 3001.17 -120.66 3003.59 0.56 4089.73 72.57 356.45 2013.78 3060.69 -124.13 3063.20 0.66 4153.00 72.53 356.56 2032.75 3120.93 -127.81 3123.55 0.19 4215.94 72.34 356.19 2051.75 3180.82 -131.60 3183.54 0.63 4279.09 72.77 356.96 2070.68 3240.95 -135.20 3243.77 1.34 4342.24 72.66 356.42 2089.45 3301.15 -138.68 3304.06 0.84 4405.56 73.01 357.65 2108.14 3361.57 -141.81 3364.56 1.93 4468.30 72.95 358.06 2126.50 3421.52 -144.05 3424.55 0.63 Paxton #7 15 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 4531.84 72.85 357.36 2145.19 3482.20 -146.48 3485.28 1.06 4595.38 72.80 357.39 2163.95 3542.84 -149.26 3545.98 0.09 *4695 2193.42 72.80 357.3+9 3637.92 -153.59 3637.92 0.0 * Projected Pa x t o n # 7 16 4. 2 B i t R e c o r d BI T NO . SI Z E TY P E S/ N JE T S / TF A IN OU T FT HR S AV E RO P Ft / H R CONDITION 1 1 2 . 2 5 ” HD B S Q H 1 G R C Mi l l T o o t h 12 4 7 4 4 4 4 3 x 1 8 , 1 2 0. 8 5 6 0 13 9 ’ 1 9 4 5 ’ 1 8 0 6 ’ 3 1 . 2 5 7 . 9 2-2-WT-A-E-IN-O-TD 2 8 . 5 ” HD B S M M 6 5 M PD C 12 4 7 4 8 1 9 6x 1 2 0. 6 6 2 7 19 4 5 ’ 4 6 9 5 ’ 2 7 5 0 ’ 2 0 . 9 1 3 1 . 6 L e f t i n h o l e Pa x t o n # 7 17 4. 3 M u d R e c o r d Co n t r a c t o r : M . I . S w a c o De p t h Da t e MD ( f t ) TV D (f t ) MW (p p g ) VI S (s / q t ) PV YP Ge l s FL (c c ) FC So l s (% ) O/ W Ra t i o Sd (% ) MB T pH Cl (ml/l) Ca (ml/l) Sp u d M u d 9/ 2 4 / 2 0 1 4 1 3 9 1 3 9 8 . 7 6 5 8 21 1 4 / 1 8 / 2 0 1 5 2 / - 1 -/ 9 9 0 2 0 1 0 . 4 1 0 0 0 0 9/ 2 5 / 2 0 1 4 2 0 4 2 0 4 8 . 8 1 3 4 2 1 42 2 3 / 3 9 / 4 5 1 4 . 6 2 / - 1 -/ 9 9 0 2 5 1 0 . 4 1 6 0 0 0 9/ 2 6 / 2 0 1 4 1 1 2 9 1 0 5 8 9 . 0 1 5 0 2 9 32 1 1 / 2 1 / 2 6 8 . 1 1 / - 2 /9 8 . 5 2 6 1 0 . 0 9 0 0 0 9/ 2 7 / 2 0 1 4 1 3 9 6 1 2 1 4 9 . 5 1 4 2 2 6 48 2 3 / 3 2 / 4 0 7 . 1 1 / - 6 /9 4 . 7 5 2 4 9 . 0 8 0 0 8 0 9/ 2 8 / 2 0 1 4 1 9 4 5 1 3 7 7 9 . 6 1 8 1 2 9 53 2 2 / 3 4 / 4 0 7 . 1 1 / - 8 /9 2 1 2 5 9 . 2 9 0 0 8 0 9/ 2 9 / 2 0 1 4 1 9 4 5 1 3 7 7 9 . 6 5 8 2 3 25 6 / 1 2 / 1 8 9 2 / - 8 / 92 . 7 5 2 0 8 . 5 5 0 0 4 0 Kl a - S h i e l d 9/ 2 9 / 2 0 1 4 1 9 4 5 1 3 7 7 1 0 . 6 5 5 1 6 30 1 2 / 1 5 / 1 9 5 . 6 1 / - 1 0 1/ 8 9 . 1 1 1 1 0 . 2 2 9 0 0 0 6 0 9/ 3 0 / 2 0 1 4 1 9 4 5 1 3 7 7 9 . 5 5 0 1 1 25 9 / 1 1 / 1 4 6 . 6 1 / - 6 /9 4 . 1 4 9 . 1 3 0 0 0 0 1 2 0 10 / 1 / 2 0 1 4 1 9 4 5 1 3 7 7 9 . 6 6 0 1 1 21 6 / 8 / 1 0 4 . 5 1 / - 7 1/ 9 2 . 1 4 9 . 9 4 0 0 0 0 1 2 0 10 / 2 / 2 0 1 4 2 7 4 0 1 6 1 1 1 0 . 2 5 8 1 5 23 5 / 8 / 1 0 4 . 4 1 / 1 9 1/ 9 0 . 1 4 1 0 . 0 4 0 0 0 0 6 0 10 / 3 / 2 0 1 4 4 1 9 5 2 0 4 6 1 0 . 4 6 2 2 2 27 7 / 1 4 / 2 1 4 . 8 1 / 1 1 1 2/ 8 7 . 1 6 1 0 . 5 4 9 0 0 0 8 0 10 / 4 / 2 0 1 4 4 6 9 5 2 1 9 3 8 . 9 3 8 1 8 2 / 3 / 4 1 0 1 / - 4 /9 6 0 4 1 0 . 0 1 1 0 0 0 1 2 0 10 / 5 / 2 0 1 4 4 6 9 5 2 1 9 3 9 . 5 4 0 1 0 18 3 / 4 / 5 7 . 4 1 / - 6 1/ 9 4 0 4 9 . 7 2 0 0 0 0 1 2 0 10 / 6 / 2 0 1 4 4 6 9 5 2 1 9 3 9 . 0 4 1 9 18 3 / 4 / 4 7 . 4 1 / - 4 2/ 9 4 0 3 9 . 5 1 8 0 0 0 1 2 0 10 / 7 / 2 0 1 4 4 6 9 5 2 1 9 3 9 . 0 4 8 1 0 19 4 / 6 / 7 7 . 5 1 / - 4 2/ 9 4 0 3 9 . 5 2 4 0 0 0 1 2 0 10 / 8 / 2 0 1 4 4 6 9 5 2 1 9 3 9 . 0 4 4 7 18 4 / 5 / 6 6 . 6 1 / - 4 4/ 9 2 0 3 9 . 5 3 1 0 0 0 1 2 0 10 / 9 / 2 0 1 4 4 6 9 5 2 1 9 3 9 . 0 4 7 7 17 4 / 5 / 6 6 . 2 1 / - 4 3/ 9 3 0 3 9 . 8 3 1 0 0 0 1 2 0 10 / 1 0 / 2 0 1 4 4 6 9 5 2 1 9 3 9 . 0 5 9 9 19 7 / 1 0 / 1 3 4 . 8 1 / - 4 3/ 9 3 0 3 9 . 8 0 3 2 0 0 0 Ab b r e v i a t i o n s : MW = M u d W e i g h t V I S = F u n n e l V i s c o s i t y PV = P l a s t i c V i s c o s i t y Y P = Y i e l d P o i n t G e l s = G e l S t r e n g t h F L = W a t e r o r F i l t r a t e Lo s s F C = F i l t e r C a k e O / W = O i l t o W a t e r r a t i o S o l s = S o l i d s S d = S a n d c o n t e n t M B T = M e t h y l e n e B l u e A l k , P m = A l k a l i n i t y , M u d pH = A c i d i t y C l = C h l o r i d e s C a = H a r d n e s s C a l c i u m n r = N o t R e c o r d e d Pa x t o n # 7 18 4. 4 D r i l l i n g P r o g r e s s C h a r t 0 50 0 10 0 0 15 0 0 20 0 0 25 0 0 30 0 0 35 0 0 40 0 0 45 0 0 50 0 0 55 0 0 60 0 0 65 0 0 70 0 0 75 0 0 9 /23 /1 4 9 /24 /14 9/25 /14 9/26/14 9/2 7/1 4 9 /28 /1 4 9 /29 /14 9/30 /14 10/1/14 10/2/14 1 0/3 /1 4 1 0 /4 /14 10/5 /14 10/6/14 10/7/1 4 1 0/8/1 4 1 0 /9 /14 10/1 0 /14 1 0/1 1 /1 4 1 0 /12 /1 4 10/13/14 D E P T H (F T ) 12 1/4" Hole 8 1/2" Hole Paxton #7 19 5 DAILY REPORTS Hilcorp Alaska, LLC Ninilchik DAILY WELLSITE REPORT Paxton #7 REPORT FOR D. Yessak/ K. McDowell DATE Sep 25, 2014 DEPTH 180.00000 PRESENT OPERATION Drilling ahead TIME 00:00:00 YESTERDAY 129.00000 24 HOUR FOOTAGE 51 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 12.25" HDBS MILLTOOTH QHCIGRC 3X18,12 139' 51' 2 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 296.3 @ 162.00000 32.9 @ 158.00000 77.9 77.03704 FT/HR SURFACE TORQUE 4363 @ 171.00000 3050 @ 160.00000 3021.0 3674.14990 AMPS WEIGHT ON BIT 6 @ 167.00000 0 @ 160.00000 2.6 5.58000 KLBS ROTARY RPM 53 @ 159.00000 9 @ 146.00000 33.0 43.99000 RPM PUMP PRESSURE 646 @ 171.00000 494 @ 160.00000 472.1 628.63000 PSI DRILLING MUD REPORT DEPTH MW 8.7 VIS 65 PV 9 YP 21 FL 14.8 Gels 14/18/20 CL- 1600 FC 2/- SOL 1 SD OIL -/99 MBT 20 pH 10.4 Ca+ Alk MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 4 @ 175.00000 0 @ 142.00000 1.7 TRIP GAS 0 CUTTING GAS 0 @ 180.00000 0 @ 180.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 0 @ 180.00000 0 @ 180.00000 0.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 180.00000 0 @ 180.00000 0.0 AVG 0 PROPANE (C-3) 0 @ 180.00000 0 @ 180.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 180.00000 0 @ 180.00000 0.0 CURRENT BACKGROUND/AVG 1.7/4 PENTANE (C-5) 0 @ 180.00000 0 @ 180.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY RIGGED UP AND TESTED DIVERTER. RUN IN HOLE AND TAGGED AT 129 FT. @ 22:30. RIG ACCEPTED AT 06:00 ON 9/25/2014 CANRIG PERSONNEL ON BOARD 2 DAILY COST 2342.50 REPORT BY HARRY E. BLEYS Hilcorp Alaska, LLC Ninilchik DAILY WELLSITE REPORT Paxton #7 REPORT FOR D.Yessak/K.McDowell DATE Sep 26, 2014 DEPTH 1251.00000 PRESENT OPERATION Sliding building angle. TIME 23:54:42 YESTERDAY 180.00000 24 HOUR FOOTAGE 1071 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 899 31.60 351.29 875.34 963 35.30 352.45 928.03 1027 31.81 353.40 980.03 1091 41.08 355.55 1029.04 1152 45.14 356.49 1074.21 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 12.25" HDBS MILLTOOTH QHCIGRC 3X18,12 129' 1122' 17.93 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 297.1 @ 952.00000 1.9 @ 747.00000 85.7 21.79863 FT/HR SURFACE TORQUE 7790 @ 1162.00000 1361 @ 226.00000 1030.0 7551.25000 AMPS WEIGHT ON BIT 23 @ 1203.00000 0 @ 225.00000 10.3 19.75000 KLBS ROTARY RPM 71 @ 429.00000 1 @ 226.00000 10.7 52.84000 RPM PUMP PRESSURE 1622 @ 960.00000 610 @ 202.00000 1397.4 1561.41003 PSI DRILLING MUD REPORT DEPTH 1256' MW 8.8 VIS 136 PV 20 YP 43 FL 14.8 Gels 23/38/44 CL- 1400 FC 2/- SOL 1 SD 0 OIL /99 MBT 25 pH 10.4 Ca+ Alk MWD SUMMARY INTERVAL 180' TO 1251' TOOLS MUD MOTOR AND DIRECTIONAL MODULE GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 106 @ 1175.00000 0 @ 439.00000 19.7 TRIP GAS 0 CUTTING GAS 0 @ 1251.00000 0 @ 1251.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 21198 @ 1175.00000 124 @ 226.00000 3961.6 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 1251.00000 0 @ 1251.00000 0.0 AVG 0 PROPANE (C-3) 0 @ 1251.00000 0 @ 1251.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 1251.00000 0 @ 1251.00000 0.0 CURRENT BACKGROUND/AVG 26/20 PENTANE (C-5) 0 @ 1251.00000 0 @ 1251.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY ROTARY DRILLING AND SLIDING TO BUILD ANGLE. CANRIG PERSONNEL ON BOARD 2 DAILY COST 2342.50 REPORT BY HARRY E. BLEYS Hilcorp Alaska, LLC Ninilchik DAILY WELLSITE REPORT Paxton #7 REPORT FOR D. Yessak/K.McDowell DATE Sep 27, 2014 DEPTH 1883.00000 PRESENT OPERATION Drilling ahead. TIME 23:59:00 YESTERDAY 1251.00000 24 HOUR FOOTAGE 632' CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1529.94 71.02 358.43 1265.05 1593.05 73.61 358.79 1284.22 1656.07 74.09 359.22 1301.75 1720.09 74.22 359.86 1319.23 1783.28 75.23 0.22 1335.87 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 12.25" HDBS Milltooth QHCIGRC 3X18,12 129' 1754' 30.05 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 228.7 @ 1741.00000 1.6 @ 1696.00000 63.1 26.37279 FT/HR SURFACE TORQUE 9598 @ 1795.00000 6139 @ 1696.00000 5199.0 6872.54980 AMPS WEIGHT ON BIT 23 @ 1588.00000 1 @ 1507.00000 16.8 15.67000 KLBS ROTARY RPM 77 @ 1825.00000 12 @ 1506.00000 41.1 15.90000 RPM PUMP PRESSURE 1930 @ 1592.00000 1506 @ 1624.00000 1720.8 1762.39001 PSI DRILLING MUD REPORT DEPTH 1256' MW 8.8 VIS 136 PV 20 YP 43 FL 14.8 Gels 23/38/44 CL- 1400 FC -/2 SOL 1 SD 0 OIL /99 MBT 25 pH 10.4 Ca+ 0 Alk MWD SUMMARY INTERVAL 1251' TO 1883' TOOLS MUD MOTOR AND DIRECTIONAL MODULE GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 109 @ 1883.00000 10 @ 1589.00000 36.9 TRIP GAS 0 CUTTING GAS 0 @ 1883.00000 0 @ 1883.00000 0.0 WIPER GAS 168 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 22821 @ 1551.00000 2053 @ 1341.00000 6770.8 CONNECTION GAS HIGH 0 ETHANE (C-2) 113 @ 1883.00000 113 @ 1883.00000 0.2 AVG 0 PROPANE (C-3) 0 @ 1883.00000 0 @ 1883.00000 0.0 CURRENT 0 BUTANE (C-4) 9 @ 1714.00000 0 @ 1742.00000 0.3 CURRENT BACKGROUND/AVG 23/37 PENTANE (C-5) 0 @ 1883.00000 0 @ 1883.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY PERFORMED A WIPER TRIP FROM 1571 TO SURFACE. FOUND A TIGHT SPOT AT 1309 FT. AND PUMPED THE REST OF THE WAY TO SURFACE. TRIPPED BACK IN HOLE AND CONTINUED TO DRILL AHEAD. DRILLED UNTIL 1904 FT. STOPPED AND CIRCULATED BOTTOMS UP TO CHECK FORMATION. AT PRESENT WAITING ON LAG TO BRING CUTTINGS UP. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2342.5 REPORT BY HARRY E. BLEYS Hilcorp Alaska, LLC Ninilchik DAILY WELLSITE REPORT Paxton #7 REPORT FOR D. Yessak/K. McDowell DATE Sep 28, 2014 DEPTH 1945.00000 PRESENT OPERATION RUNNING CASING. TIME 23:59:58 YESTERDAY 1883.00000 24 HOUR FOOTAGE 62 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1845.39 75.63 0.46 1351.50 1906.55 75.25 0.46 1366.87 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 12.25" HDBS MILLTOOTH QHCIGRC 3X18,12 129' 1945' 1816' 31.2 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 112.7 @ 1885.00000 5.3 @ 1945.00000 44.6 5.33645 FT/HR SURFACE TORQUE 9967 @ 1921.00000 6872 @ 1883.00000 7180.8 0.00000 AMPS WEIGHT ON BIT 15 @ 1920.00000 7 @ 1945.00000 14.4 7.52000 KLBS ROTARY RPM 80 @ 1897.00000 15 @ 1883.00000 58.0 0.00000 RPM PUMP PRESSURE 1780 @ 1911.00000 1556 @ 1945.00000 1755.1 1556.35000 PSI DRILLING MUD REPORT DEPTH 1945' MW 9.6 VIS 180 PV 26 YP 48 FL 1 Gels 22/33/39 CL- 800 FC -/2 SOL 6 SD 0.75 OIL /94 MBT 24 pH 9.3 Ca+ 80 Alk MWD SUMMARY INTERVAL 1883' TO 1945' TOOLS MUDMOTOR, AND DIRECTIONAL MODULE GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 124 @ 1885.00000 16 @ 1910.00000 33.8 TRIP GAS 0 CUTTING GAS 0 @ 1945.00000 0 @ 1945.00000 0.0 WIPER GAS 108 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 23880 @ 1885.00000 2631 @ 1944.00000 6368.4 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 1945.00000 0 @ 1945.00000 0.0 AVG 0 PROPANE (C-3) 0 @ 1945.00000 0 @ 1945.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 1945.00000 0 @ 1945.00000 0.0 CURRENT BACKGROUND/AVG 0/34 PENTANE (C-5) 0 @ 1945.00000 0 @ 1945.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY DUE TO TIGHTNESS OF HOLE WE PUMPED OUT TO 1415 FT AND PULLED OUT ON ELEVATORS TO 502'. USING ELEVATORS WE TRIPPED BACK IN HOLE TO 1888 FT. WE WASHED DOWN TO 1945 FT AND CIRCULATED BOTTOMS UP RECIEVING105 UNITS OF GAS. A HIGH VISCOUS SWEEP WAS PUMPED WITH AN INCREASE OF 5O% CUTTINGS, YET WAS ON TIME PER CALCULATIONS. PULLED OUT OF HOLE ON ELEVATORS AND BEGAN LAYING DOWN BOTTOM HOLE ASSEMBLY. RIGGED UP CASING CREW TO RUN 9.625 " CASING. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2342.5 REPORT BY HARRY E. BLEYS Hilcorp Alaska, LLC Ninilchik DAILY WELLSITE REPORT Paxton #7 REPORT FOR D. Yessak/K. McDowell DATE Sep 29, 2014 DEPTH 1945.00000 PRESENT OPERATION Working on stack. TIME 23:59:58 YESTERDAY 1945 24 HOUR FOOTAGE 0 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1845.39 75.63 0.46 1351.50 1906.55 75.25 0.46 1366.87 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 1945' MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY RAN CASING AND RIGGED DOWN CASING CREW. RIGGED UP CEMENTING HIGH PRESSURE LINES AND TESTED. PUMPED CEMENT JOBS AND RIGGED DOWN CEMENT CREWS. COMMENCED WORK ON STACK TO PREPARE IT FOR NEW BOP'S BY NIPPLIING DOWN AND UP THE STACK TO TAK E NEW SIZED BOP'S . CLEANING PITS AND PERFORMING RIG MAINTENANCE. CANRIG PERSONNEL ON BOARD 2. DAILY COST $2342.5 REPORT BY HARRY E. BLEYS Hilcorp Alaska, LLC DAILY WELLSITE REPORT Paxton #7 REPORT FOR DATE Sep 30, 2014 DEPTH 1945.00000 PRESENT OPERATION Testing BOP's TIME 23:59:59 YESTERDAY 1945.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9.625"@ 1936' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Nippled down stack and nippled up with new BOP's. Unstalled annular double gate. mud cross, choke, kill hydro, and manual valves. Installed flow box, bell nipple, flow line, Rigged down and laid down BOP pick up lines from topdrive, and unloaded and staged 5" drill pipe. Organized location, and installed choke and kill high pressure hoses. Reinstalled CDS-40 saver sub for BOP Test. Hooked up Koomy lines and secured stack. Charged Koomy and rigged up cross over 5.5 rams. At present testing BOP's. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3465.00 REPORT BY HARRY E. BLEYS Hilcorp Alaska, LLC Ninilchik DAILY WELLSITE REPORT Paxton #7 REPORT FOR J. Lott/Doug Yessak DATE Oct 01, 2014 DEPTH 1945.00000 PRESENT OPERATION Building BOP's TIME 23:59:59 YESTERDAY 1945.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9.625"@ 1936' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" HDBS PDC MM65M 12474819 6X12 1945 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 1945' MW 9.5 VIS 50 PV 11 YP 25 FL 6.6 Gels 9/11/14 CL- 30000 FC 1/- SOL 6 SD 0.1 OIL /94 MBT 4 pH 9.1 Ca+ 120 Alk MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY PICKED UP 110 JOINT OF DRILL PIPE, AND SIX JOINTS OF HEAVY WEIGHT DRILL PIPE. RIGGED UP AND TESTED CASING TO 2900 PSI AND HELD FOR THIRTY MINUTES. AFTER TEST BLEED OFF PRESSURE. BLOWED DOWN LINES AND CHOKE MANIFOLD. CLEANED AND PREPARED THE MAIN FLOOR FOR BHA. STAGED TOOLS. DIRECTIONAL AND MWD MADE UP BHA. SCRIBED MOTOR AND CIRCULATED. DOWNLOADED MWD TOOLS AND HELD PRE-JOB SAFETY MEETING ON THE RADIOACTIVE SOURCES. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3465.00 REPORT BY HARRY E. BLEYS Hilcorp Alaska, LLC NINILCHIK DAILY WELLSITE REPORT Paxton #7 REPORT FOR D. YESSAK/K. McDowell DATE Oct 02, 2014 DEPTH 3002.00000 PRESENT OPERATION Drilling ahead. TIME 23:57:55 YESTERDAY 1945.00000 24 HOUR FOOTAGE 1057 CASING INFORMATION 9.625'@1935' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2888.87 73.35 357.60 1654.22 2951.83 73.32 357.46 1672.27 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5 HDBS PDC MM65M 12474819 6X12 1945 1057 8.516 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 907.8 @ 2935.00000 5.3 @ 1945.00000 164.0 215.79359 FT/HR SURFACE TORQUE 10247 @ 2872.00000 6865 @ 1953.00000 7856.1 8096.02979 AMPS WEIGHT ON BIT 21 @ 2679.00000 0 @ 2485.00000 8.7 6.29000 KLBS ROTARY RPM 79 @ 2388.00000 13 @ 2229.00000 53.5 71.23000 RPM PUMP PRESSURE 1930 @ 2872.00000 1185 @ 1954.00000 1633.8 1841.56006 PSI DRILLING MUD REPORT DEPTH 2297' MW 10.2 VIS 58 PV 15 YP 23 FL 4.4 Gels 5/8/10 CL- 40000 FC 1/1 SOL 7 SD 0.1 OIL 1/90 MBT 4 pH 10.0 Ca+ 60 Alk MWD SUMMARY INTERVAL 1945' TO 3002' TOOLS MUD MOTOR AND DIRECTIONAL MODULE. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1298 @ 2514.00000 2 @ 1947.00000 252.1 TRIP GAS 0 CUTTING GAS 0 @ 3002.00000 0 @ 3002.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 258408 @ 2514.00000 225 @ 1947.00000 48025.6 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 3002.00000 0 @ 3002.00000 0.0 AVG 0 PROPANE (C-3) 0 @ 3002.00000 0 @ 3002.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 3002.00000 0 @ 3002.00000 0.0 CURRENT BACKGROUND/AVG 18/252 PENTANE (C-5) 0 @ 3002.00000 0 @ 3002.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY TUFFACEOUS SILTSTONE 50%, TUFFACEOUS CLAYSTONE 40%, AND SAND 10% DAILY ACTIVITY SUMMARY RUN IN HOLE WITH SINGLES, SLIP AND CUT DRILL LINE, SERVICE RIG. TAG FLOAT COLLAR AT 1847 FT AND DRILL OUT THE FLOAT COLLAR. THAN CEMENT AND SHOE. DRILL AHEAD. HIGH GAS UNITS CAUSES MUD TO RAISE TO 10.2 ppg. GAS 411 u @ 2112 FT., 339 u @ 2267 FT, 768 u @2358 FT, 1160 u @ 2403 FT. , 1236 u @ 2472 FT. , 1298 u @ 2514 FT, 1136 u @ 2609 FT. , 932 u @ 2643 FT., 675 u @ 2773 FT. , AND 920 u @ 2975 FT. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3465.00 REPORT BY HARRY E. BLEYS Hilcorp Alaska, LLC NINILCHIK DAILY WELLSITE REPORT Paxton #7 REPORT FOR D. YESSAK/K. MCDOWELL DATE Oct 03, 2014 DEPTH 4254.00000 PRESENT OPERATION DRILLING AHEAD. TIME 23:59:00 YESTERDAY 3002.00000 24 HOUR FOOTAGE 1252 CASING INFORMATION 9.625"@1935' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4089.73 72.54 356.45 2013.78 4153.00 72.53 356.56 2032.75 4215.94 72.34 356.19 2051.75 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" HDBS PDC MM65M 12474819 6X12 1945' 2309' 18.78 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 346.2 @ 3833.00000 7.3 @ 3924.00000 146.4 111.00988 FT/HR SURFACE TORQUE 11920 @ 4225.00000 1164 @ 3697.00000 8827.9 9773.34961 AMPS WEIGHT ON BIT 21 @ 3185.00000 0 @ 3062.00000 10.2 5.71000 KLBS ROTARY RPM 79 @ 4017.00000 6 @ 3697.00000 63.0 60.86000 RPM PUMP PRESSURE 2173 @ 4243.00000 1703 @ 3248.00000 1899.9 1952.98999 PSI DRILLING MUD REPORT DEPTH 4321' MW 10.4 VIS 62 PV 22 YP 27 FL 4.8 Gels 5/8/10 CL- 44000 FC -/1 SOL 9 SD 0.1 OIL 1/90 MBT 4 pH 10.0 Ca+ 60 Alk MWD SUMMARY INTERVAL 3002' TO 4254' TOOLS MUD MOTOR AND DIRECTIONAL MODULE GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 718 @ 3392.00000 11 @ 3485.00000 159.1 TRIP GAS 0 CUTTING GAS 0 @ 4254.00000 0 @ 4254.00000 0.0 WIPER GAS 72 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 127341 @ 3671.00000 2008 @ 3485.00000 29719.7 CONNECTION GAS HIGH 0 ETHANE (C-2) 571 @ 3670.00000 10 @ 4117.00000 92.2 AVG 0 PROPANE (C-3) 191 @ 4216.00000 1 @ 4240.00000 2.6 CURRENT 0 BUTANE (C-4) 0 @ 4254.00000 0 @ 4254.00000 0.0 CURRENT BACKGROUND/AVG 414/159 PENTANE (C-5) 0 @ 4254.00000 0 @ 4254.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY BELUGA FORMATION PRESENT LITHOLOGY TUFFACEOUS CLAYSTONE 70%, SAND 20%, AND TUFFACEOUS SILTSTONE 10% DAILY ACTIVITY SUMMARY PUMP TANDEM SWEEPS AND CIRCULATE HOLE CLEAN. PERFORM SHORT TRIP FROM 3501 TO SHOE. REAMED AT 2959 FT. AND 2850 FT. SERVICED RIG BY GREASING TOPDRIVE, CROWN, MUD PUMPS, AND DRAWWORKS. TRIPPED BACK IN HOLE AND HAD 72 u MAX AS WIPER TRIP GAS. COMMENCED DRILLING AHEAD AND HAD MAX GASES AT 371 u @ 3543 FT., 386 u @ 3615 FT., 637 u @ 3671 FT., 602 u @ 3767 FT., 271 u @ 3880 FT., 623 u. @ 4115 FT. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3465.00 REPORT BY HARRY E. BLEYS Hilcorp Alaska, LLC NINILCHIK DAILY WELLSITE REPORT Paxton #7 REPORT FOR D. YESSAK/K.MCDOWELL DATE Oct 04, 2014 DEPTH 4695.00000 PRESENT OPERATION Attemping to jar to work pipe up and down TIME 23:59:54 YESTERDAY 4254.00000 24 HOUR FOOTAGE 441 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4595.38 72.80 357.39 2163.95 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" HDBS MM55M 12474819 3X12 1945' 2750' 20.9 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 332.5 @ 4470.00000 8.5 @ 4562.00000 167.2 246.47795 FT/HR SURFACE TORQUE 13316 @ 4419.00000 7340 @ 4659.00000 9451.0 9869.24000 AMPS WEIGHT ON BIT 16 @ 4387.00000 0 @ 4694.00000 9.5 0.00000 KLBS ROTARY RPM 78 @ 4292.00000 7 @ 4394.00000 59.0 60.97000 RPM PUMP PRESSURE 2260 @ 4670.00000 1777 @ 4695.00000 2046.9 1777.73000 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL 4254' TO 4695' TOOLS MUD MOTOR AND DIRECTIONAL MODULES. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 684 @ 4257.00000 0 @ 4685.00000 233.1 TRIP GAS 0 CUTTING GAS 0 @ 4695.00000 0 @ 4695.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 121576 @ 4257.00000 8668 @ 4513.00000 42300.8 CONNECTION GAS HIGH 0 ETHANE (C-2) 623 @ 4258.00000 43 @ 4513.00000 222.8 AVG 0 PROPANE (C-3) 0 @ 4695.00000 0 @ 4695.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 4695.00000 0 @ 4695.00000 0.0 CURRENT BACKGROUND/AVG 233/0.2 PENTANE (C-5) 0 @ 4695.00000 0 @ 4695.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY CIRCULATE LCM PILL. REAM OUT OF HOLE. CONTINUE TO PUMP LCM PILL AND CONTINUE TO REAM. WORK PIPE AND FILL OUT. PUMP FLUID DOWN DRILL STRING AND WORK TIGHT HOLE. BHA HUNG UP. BIT DEPTH IS 3916'. JARRED 8 TIMES. WORK TORQUE UP AND DOWN. MAX GASES: 684 u @ 4257', 467 u @ 4304', 644 u @ 4352', 577 u @ 4461' CANRIG PERSONNEL ON BOARD 4 DAILY COST $3465.00 REPORT BY HARRY E. BLEYS Hilcorp Alaska, LLC NINILCHIK DAILY WELLSITE REPORT Paxton #7 REPORT FOR D. YESSAK/K.MCDOWELL DATE Oct 05, 2014 DEPTH 4695.00000 PRESENT OPERATION PREPARING TO SET OFF THIRD CHARGE. TIME 23:59:54 YESTERDAY 4695.00000 24 HOUR FOOTAGE 0 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4595.38 72.80 357.39 2163.95 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 4695' MW 9.5 VIS 40 PV 10 YP 18 FL Gels 3/4/5 CL- 20000 FC 1/- SOL 6 SD OIL 1/94 MBT 4 pH 9.7 Ca+ 120 Alk MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY RIG UP ELINE TOOLS. LOAD SHOT AND RUN IN HOLE TO 500 FT. APPLY LEFT HAND TORQUE TO DRILL PIPE. CONTINUE TO RUN IN HOLE WITH ELINE. PUMP ELINE DOWN HOLE TO TARGET DEPTH AND SET OFF CHARGE. WORK DRILL STRING. TARGET CONNECTION DID NOT RELEASE. PULL OUT WIRELINE AND PACK NEW CHARGE. PUT 14,500 LBS OF REVERSE TORQUE TO DRILL STRING. WORK TORQUE DOWN AND COMPRESS DRILL STRING 40 K . PUMP CHARGE DOWN AND SET OFF SECOND CHARGE. WORK DRILL STRING 160 K UP AND 30 K DOWN. NO RELEASE. PULL OUT WIRELINE AND RIG DOWN TOOLS. MAKE UP STRING COCK LICK AND RE-COCK JARS. MAKE UP WIRELINE TOOLS AND FOSV. MAKEUP THIRD CHARGE. SEND THIRD CHARGE DOWN HOLE. SLACK OFF TO 35 K AND PUMP WIRELINE DOWN. PREPARING TO SET OFF THIRD CHARGE AT BOTTOM OFJARS. WIRELINE DEPTH IS 3619 FT. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3465.00 REPORT BY HARRY E. BLEYS Hilcorp Alaska, LLC NINILCHIK DAILY WELLSITE REPORT Paxton #7 REPORT FOR J. LOTT/ D. YESSAK DATE Oct 06, 2014 DEPTH 4695.00000 PRESENT OPERATION Working to free pipe. TIME 23:59:54 YESTERDAY 4695.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9.625@1936' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4595.38 72.80 357.39 2163.95 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 4695' MW 9.0 VIS 41 PV 9 YP 18 FL Gels 3/4/4 CL- 18000 FC 1/- SOL 6 SD OIL 2/94 MBT 3 pH 9.7 Ca+ 120 Alk MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Applied left hand torque on drill pipe. Made up a new charge and pumped it down hole and worked pipe. Regained partial returns at 08:30 of 9 bpm. Continued to monitor strokes per minute along with flow. Rigged down e-line and, circulated and worked pipe. Reduced mud weight from 9.2 to 9.0 ppg. Currently losing mud at 10 bpm from origonal 70 bpm to 200+ bpm from beginning of origol loses. Pumped a lube around the BHA worked pipe. Rigged up wireline and attempted to free pipe. Max Gas from 08:30 partial restoration of circulation was 91 u. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3465.00 REPORT BY HARRY E. BLEYS Hilcorp Alaska, LLC NINILCHIK DAILY WELLSITE REPORT Paxton #7 REPORT FOR J. LOTT/ D. YESSAK DATE Oct 07, 2014 DEPTH 4695.00000 PRESENT OPERATION SLOWLY BUILDING NEW FISHING BHA AND PREPARING TRIPPING IN HOLE. TIME 23:59:54 YESTERDAY 4695.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9.625@1936' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4595.38 72.80 357.39 2163.95 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 4695' MW 9.0 VIS 48 PV 10 YP 19 FL 7 Gels 4/6/7 CL- 24000 FC 1/- SOL 4 SD OIL 2/94 MBT 3 pH 9.5 Ca+ 120 Alk MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY FIRE SHOT AND SUCCESSFUL BACK OFF. RIG DOWN E-LINE AND CIRCULATE HOLE. PERFORM RIG SERVICE AND DERRICK INSPECTION. PULL OUT ON ELEVATORS. BRAKE CIRCULATION AND PUMP HIGH VISCOUS SWEEP. CONTINUE TO PULL OUT ON ELEVATORS. STRAP TALLY FISHING BHA, AMD OFF LOADED TALLY AND STRAP DRILL COLLARS. PREPARE DRILL FLOOR FOR FISHING TOOL . REPOSITION STANDS IN DERRICK. AFTER PRE JOB SAFETY MEETING MAKE UP FISHING BHA. SCREW IN SUB, CIRCULATE CONTROL JOINT BUMPER SUB WITH FIVE COLLARS, CROSS OVER INTENSIFIER. RUN IN FIVE STANDS OF HEAVY WEIGHT. INSPECT AND REDOPE CONNECTIONS. CUT AND SLIP DRILL LINE AND PREPARE TO RUN IN HOLE. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3465.00 REPORT BY HARRY E. BLEYS Hilcorp Alaska, LLC NINILCHIK DAILY WELLSITE REPORT Paxton #7 REPORT FOR J. LOTT/ D. YESSAK DATE Oct 08, 2014 DEPTH 4695.00000 PRESENT OPERATION Continuing to jar up hole. TIME 23:59:54 YESTERDAY 4695.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9.625@1936' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4595.38 72.80 357.39 2163.95 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 4695' MW 9.0 VIS 48 PV 10 YP 19 FL 7 Gels 4/6/7 CL- 24000 FC 1/- SOL 4 SD OIL 2/94 MBT 3 pH 9.5 Ca+ 120 Alk MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Run in hole with new BHA and fish tool. Wash down to fish at 3559 Ft. Latch fish and pick up to 100 K and work torque down hole to connection. Start fishing operation with attempting to work fish down hole with bumper sub open. Trap torque in string and work down hole. Continuing to work fish down hole. Starting jars up operation by applying torque to string when jaring. Inspect derrick, topdrive, bop, and brake linkage. Continue to jar up. Set jars off 125 times. Continue to inspect derrick, topdrive, bop, and brake linkage. The constant jaring creats a situation where the derrick needs to be constantly inspected. Set off jars sixty times. Spot a lube pill and continue to jar up. Max gas was 12 u. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3465.00 REPORT BY Harry E. Bleys Hilcorp Alaska, LLC Ninilchik DAILY WELLSITE REPORT Paxton #7 REPORT FOR J. Lott/S. Barber DATE Oct 09, 2014 DEPTH 4695.00000 PRESENT OPERATION Preparing to make up clean out run BHA TIME 23:59:00 YESTERDAY 4695.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9.625"@1936' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 9.0 VIS 47 PV 7 YP 17 FL 6.4 Gels 4/5/6 CL- 31000 FC -/1 SOL 4 SD OIL 3/93 MBT 3 pH 9.8 Ca+ 120 Alk MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Coninued to fish. Decision made to cease fishing operation. Rig up E-line and run in hole. Apply left hand torque. Fire shot and lost torque. Back off pipe and pump slug and pull out of hole. At present making up clean out BHA. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3465.00 REPORT BY Harry E. Bleys Hilcorp Alaska, LLC Ninilchik DAILY WELLSITE REPORT Paxton #7 REPORT FOR J. Lott/S. Barber DATE Oct 10, 2014 DEPTH 4695.00000 PRESENT OPERATION Preparing to make up clean out run BHA TIME 23:59:00 YESTERDAY 4695.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9.625"@1936' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 4695' MW 9.0 VIS 47 PV 7 YP 17 FL 6.4 Gels 4/5/6 CL- 31000 FC -/1 SOL 4 SD OIL 3/93 MBT 3 pH 9.8 Ca+ 120 Alk MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Pull out of hole and lay down heavy weight drill pipe. Lay down drill collars, stabilizer, and bit. Flow check well. and shut blind rams. Clean rig floor of all unneeded equipment and blow down surfaces lines. Pull wear bushig and test run hanger with Cameron rep. Change upper rams to 5.5 inch casing rams. Rig up test equipmet and test upper rams. Rig down test equiment. Rig down bails and elevators. Hold rig service and held pre job safety meeting for casing crew. Rigged up casing equipment. and test CRT. Make up float and test float track. Preparing to run in with casing. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2342.50 REPORT BY Harry E. Bleys
