The URL can be used to link to this page

Home My WebLink About213-0791. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Sweep Annulus 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: Redoubt Shoal 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 15,050 14,949 Casing Collapse Structural N/A Conductor Surface 2260 Intermediate 4760 Production 4790 Liner 6390 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 sporhola@glacieroil.com 907-331-8228 Production & Wells Engineer Redoubt Unit 1A Redoubt Shoal Undefined Oil 12,502 14,953 12,426 2,799 N/A 12/15/2025 15,038'8,529' 3 1/2" & 2-3/8" 12,493' N/A & N/A N/A & N/A 12,246' Perforation Depth MD (ft): 6,986' 14,110'-14,872' 5,544' 5 1/2" 11,753'-12,362' 11,616'7-5/8" 200' 36" 13 3/8" 9 5/8"6,986' 1,831' MD N/A 6870 50201,803' 5,988' 1,831' Length Size Proposed Pools: 200' 200' L-80 & L-80 TVD Burst 6,048' & 11,954' 6890 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 381203 & 378114 213-079 188 W. Northern Lights Blvd. SUITE 510, ANCHORAGE, AK 99503 50-733-20497-01-00 COOK INLET ENERGY LLC 20 AAC 25.055 AOGCC USE ONLY 7740 Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Stan Porhola Subsequent Form Required: 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 Perforate Reppair Well Exploratory Stratigraphic Development Service BOP Test Mechanical Integrity Test No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-730 By Grace Christianson at 7:34 am, Dec 02, 2025 TS 12/2/25 10-404 DSR-12/3/25BJM 12/4/25 12/4/25 188 West Northern Lights Blvd, Suite 510, Anchorage, AK 99503 Main (907) 334-6745 | Fax (907) 334-6735 December 1st, 2025 Jessie Chmielowski, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry Application Cook Inlet Energy, LLC: Redoubt Unit 1A API: 50-733-20497-01-00 Dear Commissioner, Cook Inlet Energy, LLC, hereby submits a Sundry Application for RU-01A, PTD: 213-079, requesting to sweep oil out of the annulus with produced water to lower the sustained casing pressure. If you have any questions, please contact me at (907) 433-3820. Sincerely, Stan Porhola Production & Wells Engineer Cook Inlet Energy, LLC (a Glacier Oil & Gas owned company) 188 W Northern Lights Blvd, Suite 510 Anchorage, AK 99503 Attachments 1. RU-1A: 10-403 2. RU-1A: Annular sweep procedure 3. RU-1A: Current Wellbore Diagram 188 West Northern Lights Blvd, Suite 510, Anchorage, AK 99503 Main (907) 334-6745 | Fax (907) 334-6735 WELL NAME Redoubt Unit 1A Requirements of 20 AAC 25.005(f) Well Summary Current Status: The well is not producing (failed ESP) and has been shut-in since July 2024 Current pressures: WHP = 415 psi; IAP = 462 psi Last Casing Test = 2,400 psi 7/27/2013 Last annular sweep = None Scope of Work: Sweep oil from annulus by pumping down the tubing; taking returns from the annulus. Shut-in well and confirm well is static (lower sustained casing pressure). General Well Information: Reservoir Pressure / TVD: 0.32 psi/ft (BHP Gradient as of 2021) 3,956 psi @ 12,362 TVD (14,872 MD) MASP: 3,956 psi - (TVD x Pressure Gradient of 0.10 psi/ft) 3,956 psi (12,362 ft X 0.10 psi/ft) = 2,720 psi Wellhead Type/Pressure Rating: 13 5/8 5K GE MB-205 Wellhead 3 1/8 5K Tree Well Type/Location: Oil Well (Failed ESP); Leg #3, Slot #19 Osprey Platform Estimated Start Date: December 15, 2025 Well Status: No-Flow Test Witnessed 06/11/2017 Program 1. Confirm alignment of flowline valves and test lines up to tree to 1,500 psi for 5 min. a. Well tubing and annulus already plumbed into facility piping. 2. Pump produced water down tubing taking returns up the annulus. a. Tubing capacity = 77 bbl; Annulus capacity = 501 bbl (578 bbl total) 188 West Northern Lights Blvd, Suite 510, Anchorage, AK 99503 Main (907) 334-6745 | Fax (907) 334-6735 b. Plan to pump up to 1.5 x capacity = 1.5 x 578 = 867 bbl c. Maximum anticipated pump pressure = 1,500 psi. 3. Take returns to test meter and sample for oil cut until samples show 100% water. 4. Upon 100% water or full planned displacement volume, cease water displacement. 5. Monitor tubing and annulus pressures (T/I/O). Return well to shut-in status. RU-01A Current Wellbore Schematic Version: Final 5/4/2020 Tubing hanger - ACME 3.725" MCA top connection / 3 1/2" EUE 8rd btm connection - ID 2.950" 36" 150# A-36 200' MD ID - 34.00" Welded 200' TVD 13 3/8" 68# L-80 1,831' MD ID - 12.25" BTC 1,803' TVD 3 1/2" 9.3# L-80 EUE 8rd Tubing - ID 2.992" XO - 2 3/8" x 3 1/2" - ID 1.995" @ 6,048 MD / 5,236' TVD 9 5/8" 47# L-80 6,986' MD ID - 8.50" BTC 5,988' TVD Dual 1/4" Stainless Flat Pack Lines ESP #1 Flat Cable 2 3/8" 4.7# L-80 EUE 8rd Tubing - ID 1.995" Cross collar clamp on every 3-1/2" jt (190) Cross collar clamp on every 2-3/8" jt (185) Half cannon clamp on every 2-3/8" mid-jt (190) ESP Assembly Top @ 11,954' MD / 9,996' TVD ELECTRIC SUBMERSIBLE PUMP - 146' Perforations (& 2017 Reperfs)Baker Centrilift MD TVD Reperf Type Discharge Unit Assembly 14,110'-14,113' 11,753'-11,756' TCP Pump Assembly 14,113'-14,122' 11,756'-11,763' TCP/StimGun Intake / Gas Separator 14,122'-14,126' 11,763'-11,766' TCP Seal Assembly - Upper / Lower Seals 14,126'-14,141' 11,766'-11,778' TCP/StimGun Motor 14,141'-14,154' 11,778'-11,789' TCP Sensor 14,171'-14,187' 11,803'-11,816' TCP Anode 14,187'-14,199' 11,816'-11,825' TCP/StimGun ESP Assembly Bottom @ 12,100' MD / 10,115' TVD 14,199'-14,206' 11,825'-11,831' TCP 14,206'-14,226' 11,831'-11,847' TCP/StimGun Window 14,226'-14,230' 11,847'-11,851' TCP 7 5/8" 29.7# L-80 12,246' MD 14,261'-14,263' 11,876'-11,877' TCP ID - 6.75" BTC 10,231' TVD 14,263'-14,273' 11,877'-11,885' TCP/StimGun 14,273'-14,303' 11,885'-11,909' TCP 14,373'-14,454 11,964'-12,029' TCP 14,454'-14,463' 12,029'-12,036' TCP/StimGun 14,463'-14,570' 12,036'-12,122' TCP 14,581-14,588' 12,131'-12,137' TCP 14,604'-14,653' 12,149'-12,188' TCP 14,653'-14,662' 12,188'-12,195' TCP/StimGun 14,662'-14,721' 12,195'-12,243' TCP 14,726'-14,746' 12,247'-12,263' TCP 14,758'-14,786' 12,272'-12,294' TCP 14,812'-14,836' 12,315'-12,334' -Fish - 4' StimGun - no fishing neck 14,852'-14,872' 12,346'-12,362' - 5 1/2" 17# L-80 15,038' MD ID - 4.767" Hydril 521 12,493' TVD PBTD: 14953' MD / 12426' TVD 6 3/4" Hole Note: 5/4/2020 - Well killed for Cold Stack; 820 bbls of produced water pumped down the IA, 184 bbls returned 17-1/2" hole TOL @ 6,509' MD / 5,605' TVD (9 5/8" x 5 1/2") TOL @ 6,702' MD / 5,760' TVD (7 5/8" X 9 5/8") 12-1/4" hole 8 1/2" Hole 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: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 15,050 feet N/A feet true vertical 12,502 feet 14,949 feet Effective Depth measured 14,953 feet None feet true vertical 12,426 feet None feet Perforation depth Measured depth 14,110 - 14,872 feet True Vertical depth 11,753 - 12,362 feet Tubing (size, grade, measured and true vertical depth) Tapered 3-1/2" L-80 0 - 6,048' (MD) 0 - 5,236' (TVD) 2-3/8" L-80 6,048 - 11,954' (MD) 5,236 - 9,996' (TVD) Packers and SSSV (type, measured and true vertical depth) No Packer SSSV - None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 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: Stan Porhola Contact Email:sporhola@glacieroil.com Authorized Title: Production & Wells Engineer Contact Phone: 907-331-8228 324-358 Sr Pet Eng: 6390 psi Sr Pet Geo: Sr Res Eng: WINJ WAG 2.2 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 221 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureGas-Mcf MD 200' 14,110'-14,872' MD Size 200' 1803' 5020 psi 6870 psi6,986' 0 7 5/8" 7740 psi -- 4790 psi -- 6890 psi -- 0 00 8 396471 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 213-079 50-733-20497-01-00 None 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL 381203 and ADL 378114 REDOUBT SHOAL, UNDEFINED OIL COOK INLET ENERGY LLC 3. Address: 188 W. Northern Lights Blvd. SUITE 510, ANCHORAGE, AK 99503 REDOUBT UNIT #1A Plugs Junk measured Mutual Solvent (15 bbl) and 15% HCL acid (30 bbl) displaced with produced water (125 bbl). Final tubing pressure = 717 psi. Length 200' 1,831' 6,986' 1831'Conductor Surface Intermediate 36" 13 3/8" 9 5/8" measured TVD Production Liner 5,544' -- 8,529' Casing Structural 11,616' -- 5 1/2" 12,246' -- 15,038' 12,493' 5,988' Burst -- Collapse -- 2260 psi 4760 psi p k ft t Fra O s 213 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 10:47 am, Aug 09, 2024 RU-1A Daily Operations Summary API: 50-733-20497-01-00 Permit #: 213-079 Sundry #: 324-358 Date Activity 22 July 2024 23 July 2024 26 July 2024 SI ESP. RU AODD injection pump. Test hoses to 100 psi test ok. Open well, on vacuum. Pump 15 bbl of mutual solvent. Pump 1 bbl of diesel. Pump 30 bbl of 15% HCl acid. Pump 1 bbl of diesel. Test hardline to 1,000 psi for 5 min test ok. Displace w/ 80 bbl of produced water. Max injection pressure of 927 psi. SI and allow acid to soak for 3 hours. Hesitation squeeze acid and displace w/ 45 bbl of produced water. Max injection pressure of 806 psi. SI and allow acid to soak for 5 hours. Well on vacuum. Turn on ESP. Place well on production. Minimal improvement on well performance. ESP Died. Two phases compromised. Well offline. Date: RKB Rig 35: 44.0'Version: Pump Installed: 12/08/2017 Pump Died: 7/26/2024 PTD: API: Tubing hanger - ACME 3.725" MCA top connection / 3 1/2" EUE 8rd btm connection - ID 2.950" 36" 150# A-36 200' MD ID - 34.00" Welded 200' TVD 13 3/8" 68# L-80 1,831' MD ID - 12.25" BTC 1,803' TVD 3 1/2" 9.3# L-80 EUE 8rd Tubing - ID 2.992" XO - 2 3/8" x 3 1/2" - ID 1.995" @ 6,048 MD / 5,236' TVD 9 5/8" 47# L-80 6,986' MD ID - 8.50" BTC 5,988' TVD Dual 1/4" Stainless Flat Pack Lines ESP #1 Flat Cable 2 3/8" 4.7# L-80 EUE 8rd Tubing - ID 1.995" Cross collar clamp on every 3-1/2" jt (190) Cross collar clamp on every 2-3/8" jt (185) Half cannon clamp on every 2-3/8" mid-jt (190) ESP Assembly Top @ 11,954' MD / 9,996' TVD ELECTRIC SUBMERSIBLE PUMP - 146' Perforations (& 2017 Reperfs)Baker Centrilift MD TVD Reperf Type Discharge Unit Assembly 14,110'-14,113' 11,753'-11,756' TCP Pump Assembly 14,113'-14,122' 11,756'-11,763' TCP/StimGun Intake / Gas Separator 14,122'-14,126' 11,763'-11,766' TCP Seal Assembly - Upper / Lower Seals 14,126'-14,141' 11,766'-11,778' TCP/StimGun Motor 14,141'-14,154' 11,778'-11,789' TCP Sensor 14,171'-14,187' 11,803'-11,816' TCP Anode 14,187'-14,199' 11,816'-11,825' TCP/StimGun ESP Assembly Bottom @ 12,100' MD / 10,115' TVD 14,199'-14,206' 11,825'-11,831' TCP 14,206'-14,226' 11,831'-11,847' TCP/StimGun Window 14,226'-14,230' 11,847'-11,851' TCP 7 5/8" 29.7# L-80 12,246' MD 14,261'-14,263' 11,876'-11,877' TCP ID - 6.75" BTC 10,231' TVD 14,263'-14,273' 11,877'-11,885' TCP/StimGun 14,273'-14,303' 11,885'-11,909' TCP 14,373'-14,454 11,964'-12,029' TCP 14,454'-14,463' 12,029'-12,036' TCP/StimGun 14,463'-14,570' 12,036'-12,122' TCP 14,581-14,588' 12,131'-12,137' TCP 14,604'-14,653' 12,149'-12,188' TCP 14,653'-14,662' 12,188'-12,195' TCP/StimGun 14,662'-14,721' 12,195'-12,243' TCP 14,726'-14,746' 12,247'-12,263' TCP 14,758'-14,786' 12,272'-12,294' TCP 14,812'-14,836' 12,315'-12,334' -Fish - 4' StimGun - no fishing neck 14,852'-14,872' 12,346'-12,362' - 5 1/2" 17# L-80 15,038' MD ID - 4.767" Hydril 521 12,493' TVD PBTD: 14953' MD / 12426' TVD 26-Jul-24 Final 213-079 50-733-20497-01 RU-01A Current Wellbore Schematic 6 3/4" Hole Note: 5/4/2020 - Well killed for Cold Stack; 820 bbls of produced water pumped down the IA, 184 bbls returned 17-1/2" hole TOL @ 6,509' MD / 5,605' TVD (9 5/8" x 5 1/2") TOL @ 6,702' MD / 5,760' TVD (7 5/8" X 9 5/8") 12-1/4" hole 8 1/2" Hole 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 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): 15050 14949 Casing Collapse Structural Conductor 2260 Surface 4760 Intermediate 4790 Production Liner 6390 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: Production & Wells Engineer 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 7/5/2024 15,038'8,529' 2-3/8" & 3-1/2" 12,493' N/A Perforation Depth MD (ft): 12,246' 14110-14872 5-1/2" 11753-12362 Perforation Depth TVD (ft): 200' 36" 13-3/8" 9-5/8" 1,831' 7-5/8"5,544' 6,986' MD 6890 5020 6870 1,803' 5,988' 11,616' 1,831' 6,986' Length Size Proposed Pools: 200' 200' L80 & L80 TVD Burst 11,954'/6,048' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 381203, ADL 378114 213-079 188 W. Northern Lights Blvd, Ste 510 Anchorage, AK 99503 50-733-20497-01-00 Cook Inlet Energy, LLC Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 7740 Tubing Grade: 12502 14953 12426 Subsequent Form Required: 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. Stan Porhola sporhola@glacieroil.com 907-331-8228 Redoubt Unit 1A Redoubt Shoal, Undefined OilRedoubt Shoal N/A2,799 Tubing MD (ft): N/A m n P s 2 6 5 6 t t N 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 7:47 am, Jun 20, 2024 Stan Porhola Digitally signed by Stan Porhola DN: cn=Stan Porhola, o, ou=Glacier Oil & Gas, email=sporhola@glacieroil.com, c=US Date: 2024.06.19 16:33:14 -08'00' 324-358 CDW 06/20/2024 A.Dewhurst 21JUN24 DSR-6/21/24BJM 6/26/24 10-404 *&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.06.27 11:57:56 -08'00'06/27/24 RBDMS JSB 062824 1 June 19th, 2024 Jessie Chmielowski, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry Application Cook Inlet Energy, LLC:Redoubt Unit 1A API: 50-733-20497-01-00 Dear Commissioner, Cook Inlet Energy, LLC, hereby submits a Sundry Application for RU-01A, PTD: 213-079, requesting to perform an acid stimulation of the perforations below the producing ESP. If you have any questions, please contact me at (907) 433-3820. Sincerely, Stan Porhola Production & Wells Engineer Cook Inlet Energy, LLC (a Glacier Oil & Gas owned company) 188 W Northern Lights Blvd, Suite 510 Anchorage, AK 99503 Stan Porhola Digitally signed by Stan Porhola DN: cn=Stan Porhola, o, ou=Glacier Oil & Gas, email=sporhola@glacieroil.com, c=US Date: 2024.06.19 16:33:38 -08'00' 2 WELL NAME – RU-01A Requirements of 20 AAC 25.005 (f) Well Summary Current Status: ESP Producing Oil Well Scope of Work: x Perform HCL acid stimulation of perforations. General Well Information: Reservoir Pressure / TVD: 0.32 psi/ft 3,956 psi @ 14,872’ MD (12,362’ TVD) MASP: Reservoir Pressure – (Gas Gradient X TVD) (0.32 psi/ft X 12,362’ TVD) – (0.1 psi/ft X 12,362’) = 3,956 psi – 1236 psi = 2,720 psi Wellhead Type/Pressure Rating: 13 5/8” 5M Wellhead - 3 1/2” 5M tree BOP Configuration: Well Tree (5M Rated) Well Type: Oil Well (ESP Completion) Estimated Start Date: July 5, 2024 Waivers Requested: None Well Status: No-Flow Test Witnessed 06/11/2017 Stimulation Procedure Pre-Stimulation 1. Conduct pre-job safety meeting with all personnel on location. o Review upcoming work and discuss safety first. o Review SDS sheets for HCL acid and mutual solvent. 2. Stage ISO containers of 15% HCL and mutual solvent. 3. Stage containment materials for all hose and piping connections. 4. Maintain log during upcoming acid injection operation utilizing previous acid job template. 3 Reservoir Stimulation 1. Prep well for HCL treatment. SI ESP. 2. Rig Up Air-Operated Double Diaphragm (AODD) Injection Pump to RU-01A and perform pre- job safety meeting. 3. Pressure test hoses, connections, etc to 100 psi. o Maximum anticipated treating pressure is 100 psi. o Check valve to be used downstream of AODD Injection Pump. 4. Open tubing and annulus and confirm surface pressures (Tbg & IA). 5. Deliver 15 bbl of Mutual Solvent using AODD injection pump. o Do not exceed 0.5 BPM injection rate. 6. Deliver 1 bbl of Diesel using AODD injection pump. o Do not exceed 0.5 BPM injection rate. 7. Deliver 30 bbl of 15% HCL using AODD injection pump. o Do not exceed 0.5 BPM injection rate. 8. Deliver 1 bbl of Diesel using AODD injection pump. o Do not exceed 0.5 BPM injection rate. 9. Line up PW down tubing and prep for system flush. o RU hardline from RU-D1 injection piping as produced water source. 10. Pressure test hardline to 1,000 psi for 5 min. 11. Deliver 80 BBL of PW down tubing for initial hesitation. o Verify high-pressure shutdown has been set to 1,000 psi. o Maximum treating pressure anticipated to be 750 psi. o Do not exceed 1.0 BPM injection rate. 12. Shut in for 2 hour soak and monitor well. 13. Deliver 45 BBL of PW down tubing. o Verify high-pressure shutdown has been set to 1,000 psi. o Maximum treating pressure anticipated to be 750 psi. o Do not exceed 1.0 BPM injection rate. 14. Shut in for 2 hour soak and monitor surface pressures (Tbg & IA). 15. Rig down equipment. 16. Open tubing and annulus. 17. Turn on ESP and place well on production. Date: RKB Rig 35: 44.0'Version: Pump Installed: 12/08/2017 PTD: API: Tubing hanger - ACME 3.725" MCA top connection / 3 1/2" EUE 8rd btm connection - ID 2.950" 36" 150# A-36 200' MD ID - 34.00" Welded 200' TVD 13 3/8" 68# L-80 1,831' MD ID - 12.25" BTC 1,803' TVD 3 1/2" 9.3# L-80 EUE 8rd Tubing - ID 2.992" XO - 2 3/8" x 3 1/2" - ID 1.995" @ 6,048 MD / 5,236' TVD 9 5/8" 47# L-80 6,986' MD ID - 8.50" BTC 5,988' TVD Dual 1/4" Stainless Flat Pack Lines ESP #1 Flat Cable 2 3/8" 4.7# L-80 EUE 8rd Tubing - ID 1.995" Cross collar clamp on every 3-1/2" jt (190) Cross collar clamp on every 2-3/8" jt (185) Half cannon clamp on every 2-3/8" mid-jt (190) ESP Assembly Top @ 11,954' MD / 9,996' TVD ELECTRIC SUBMERSIBLE PUMP - 146' Perforations (& 2017 Reperfs)Baker Centrilift MD TVD Reperf Type Discharge Unit Assembly 14,110'-14,113' 11,753'-11,756' TCP Pump Assembly 14,113'-14,122' 11,756'-11,763' TCP/StimGun Intake / Gas Separator 14,122'-14,126' 11,763'-11,766' TCP Seal Assembly - Upper / Lower Seals 14,126'-14,141' 11,766'-11,778' TCP/StimGun Motor 14,141'-14,154' 11,778'-11,789' TCP Sensor 14,171'-14,187' 11,803'-11,816' TCP Anode 14,187'-14,199' 11,816'-11,825' TCP/StimGun ESP Assembly Bottom @ 12,100' MD / 10,115' TVD 14,199'-14,206' 11,825'-11,831' TCP 14,206'-14,226' 11,831'-11,847' TCP/StimGun Window 14,226'-14,230' 11,847'-11,851' TCP 7 5/8" 29.7# L-80 12,246' MD 14,261'-14,263' 11,876'-11,877' TCP ID - 6.75" BTC 10,231' TVD 14,263'-14,273' 11,877'-11,885' TCP/StimGun 14,273'-14,303' 11,885'-11,909' TCP 14,373'-14,454 11,964'-12,029' TCP 14,454'-14,463' 12,029'-12,036' TCP/StimGun 14,463'-14,570' 12,036'-12,122' TCP 14,581-14,588' 12,131'-12,137' TCP 14,604'-14,653' 12,149'-12,188' TCP 14,653'-14,662' 12,188'-12,195' TCP/StimGun 14,662'-14,721' 12,195'-12,243' TCP 14,726'-14,746' 12,247'-12,263' TCP 14,758'-14,786' 12,272'-12,294' TCP 14,812'-14,836' 12,315'-12,334' -Fish - 4' StimGun - no fishing neck 14,852'-14,872' 12,346'-12,362' - 5 1/2" 17# L-80 15,038' MD ID - 4.767" Hydril 521 12,493' TVD PBTD: 14953' MD / 12426' TVD TD: 15050' MD / 12502' TVD 4-May-20 Final 213-079 50-733-20497-01 RU-01A Current Wellbore Schematic 6 3/4" Hole Note: 5/4/2020 - Well killed for Cold Stack; 820 bbls of produced water pumped down the IA, 184 bbls returned 17-1/2" hole TOL @ 6,509' MD / 5,605' TVD (9 5/8" x 5 1/2") TOL @ 6,702' MD / 5,760' TVD (7 5/8" X 9 5/8") 12-1/4" hole 8 1/2" Hole 60o 9-5/8" 13-3/8" 7-5/8" 5-1/2" Est fluid level ~ 5,000' MD 60o 60o STATE OF ALASKA '.. i vED ALA.OIL AND GAS CONSERVATION COMMIS N REPORT OF SUNDRY WELL OPERATIONS iiiy 2018 1.Operations Abandon U Plug Perforations U Fracture Stimulate l Pull Tubing Li Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other StimulatLj Alter Casing ❑ • ►o ed Program E Plug for Redrill ❑ Perforate New Pool ❑ Repair Weu Re-enter Susp Well ❑ °they a r Atick Treatment 0 2.Operator COOK INLET ENERGY,LLC 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development ❑✓ Exploratory ❑ 213-079 3.Address: 601 W 5TH AVE SUITE 310,ANCHORAGE,AK, Stratigraphic ❑ Service ❑ 6.API Number: 99501 50-733-20497-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 381203,ADL 374002 REDOUBT UNIT#1A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A REDOUBT SHOAL,Undefined Oil 11.Present Well Condition Summary: Total Depth measured 15050 feet Plugs measured N/A feet true vertical 12502 feet Junk measured 14949' feet Effective Depth measured 14953 feet Packer measured n/a feet true vertical 12426 feet true vertical n/a feet Casing Length Size MD TVD Burst Collapse Structural 200' 36" 200' 200' N/A N/A Conductor 1831' 13 3/8" 1831' 1803' 5020 psi 2260 psi Surface 6986' 9 5/8" 6986' 5988' 6870 psi 4760 psi Intermediate 5544' 7 5/8" 12246' 11616' 6890 psi 4790 psi Production Liner 8529' 5 1/2" 15038' 12493' 7740 psi 6390 psi Perforation depth Measured depth 14110-14872 feet True Vertical depth 11753-12362 feet Tubing(size,grade,measured and true vertical depth) 2-3/8"&3-1/2" L-80&L-80 11954'MD/6048'MD 9996'TVD/5236'TVD Packers and SSSV(type,measured and true vertical depth) No Packer No SSSV 12.Stimulation or cement squeeze summary: PP�� Intervals treated(measured): SC 6J '' °'i Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 260 57 484 385 376 Subsequent to operation: 268 55 22 385 376 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 171 Exploratory ❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 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: 317-588 Authorized Name: Stephen Ratcliff Contact Name: Stephen Ratcliff Authorized Title: Drilling Manager Contact Email: sratcliff@glacieroil.com Authorized Signature: )\,--- \f Date: 4/2/2018 Contact Phone: 907-433-3808 Form 10-404 Revised 4/2017y4_, RBDN S APR 0 5 2018 Submit Original Only _ c- t . 110 • GLACIER RECEIVED April 2nd, 2018 Mr. Hollis S. French, Chair APR 0 If 2018 Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 CC Anchorage, Alaska 99501 ) t�✓✓ Re: Report of Sundry Cook Inlet Energy, LLC: RU-01A Permit to Drill NO: 213-079 API No: 50-733-20497-01-00 Dear Mr. French, Cook Inlet Energy (CIE) hereby submits a Report of Sundry Well Operations for RU-01A. The work performed was covered under Approved Sundry 317-588 for conducting a water block treatment. If you have any questions, please contact me at (907)433-3816. Sincerely, Stephen Ratcliff Drilling Manager Cook Inlet Energy, LLC (a Glacier Oil & Gas Corp. owned company) 601 W. 5th Avenue STE 310 Anchorage, AK 99501 GLACIER RU-01A Daily Operations Summary API: 50-733-20497-01-00 Permit #: 213-079 Rig: Osprey Rig 35 Date and Footage Drilled as of 24:00 hours. Activity 14 January 2018 Receive products and personnel at platform. Build Water block treatment as per program. Bleed off tubing and annulus to 0 psi. Inject 50 bbls treatment pill, followed by 25 bbls of diverter, followed by 50 bbls of treatment pill, followed by 80 bbls of produced water. 15 January 2018 Finish injection down tubing and begin produced water injection down annulus to fluid pack. Fill annulus as needed until 170 bbls reached. Let treatment soak. Restart ESP. RU-01A Final Wellbore Schematic Version: Final • 12/13/2017 ` Tubing hanger-ACME 3.725"MCA top connection/ GLACIER 3 1/2"EUE 8rd btm connection-ID 2.950" 36" 150#A-36 MD ID-34.00" Welded 200200''ND [L V" a 17 1/2"Hole 13 3/8" 68#L-80 1,831'MD ID-12.25" BTC 1,803'TVD 31/2"9.3#L-80 EUE 8rd Tubing-ID 2.992" • ' 44 XO-23/8"x31/2"-ID1.995"@6,048MD/5,236'TVD • TOL @ 6,509'MD/5,605'TVD(9 5/8"x 5 1/2") ::,.. 2 3/8"4.7#L-80 EUE 8rd Tubing-ID 1.995" TOL©6,702'MD/5,760'TVD(7 5/8"X 95/8") 9 5/8" 47#L-80 6,986'MD 12 1/4"Hole ID-8.50" BTC 5,988'TVD 4 Dual 1/4"Stainless Flat Pack Lines ESP#1 Flat Cable Cross collar clamp on every 3-1/2"jt(190) ESP Assembly Top @ 11,954'MD/9,996'TVD Cross collar clamp on every 2-3/8"jt(185) Half cannon clamp on every 2-3/8"mid jt(190) ELECTRIC SUBMERSIBLE PUMP-146' Baker Centrilift " Discharge Unit Assembly Il•1 cV..a Pump Assembly Intake/Gas Separator 8 1/2"Hole Seal Assembly-Upper/Lower Seals k - Motor Sensor Anode • 11,011 , 0 ESP Assembly Bottom @ 12,100'MD/10,115'TVD Perforations(&2017 Reperfs) ‘i MD TVD Reperf Type 14,110'-14,113' 11,753'-11,756'/ TCP , ' Window 14,113'-14,122' 11,756-11,763' TCP/StimGun 7 5/8" 29.7#L-80 12,246'MD 14,122'-14,126' 11,763'-11,766' TCP - ID-6.75" BTC 10,231'TVD 14,126-14,141' 11,766-11,778' TCP/StimGun ' 14,141'-14,154' 11,778'-11,789' TCP 14,171'-14,187' 11,803'-11,816' TCP 14,187'-14,199' 11,816-11,825' TCP/StimGun , 14,199'-14,206' 11,825'-11,831' TCP 14,206'-14,226' 11,831'-11,847' TCP/StimGun 14,226-14,230' 11,847'-11,851' TCP 14,261'-14,263' 11,876-11,877' TCP 14,263'-14,273' 11,877'-11,885' TCP/StimGun ' 14,273'-14,303' 11,886-11,909' TCP c 14,373-14,454 11,964'-12,029' TCP _ 14,454'-14,463' 12,029'-12,036' TCP/StimGun S E 14,463-14,570' 12,036-12,122' TCP - c 14,581-14,588' 12,131'-12,137' TOP • C 14,604'-14,653' 12,149'-12,188' TCP 14,653'-14,662' 12,188'-12,195' TCP/StimGun - o • 14,662'-14,721' 12,195'-12,243'_ TCP ■ C 14,726-14,746' 12,247'-12,263' TCP - - c 14,758'-14,786' 12,272'-12,294' TCP in r 14,812'-14,836' 12,315'-12,334' - Fish-4'StimGun-no fishing neck C 14,852'-14,872' 12,346'-12,362' - 5 1/2" 17#L-80 15,038'MD 6 3/4"Hole F :y (f-r-----"- ID-4.767" Hydril 521 12,493'TVD PBTD:14953'MD/12426'TVD STATE OF ALASKA RECEIVED AASKA OIL AND GAS CONSERVATION COM SION s G REPORT OF SUNDRY WELL OPERATIONS JAN 1 £ 2®18 1.Operations Abandon U Plug Perforations U Fracture StimulatLI Pull Tubing I d Operations shutdown (J Performed: Suspend ❑ Perforate El Other StimulatL Alter Casing ❑ A �g7 d Program ❑ Plug for Redrill CI Perforate New Pool CI Repair Wel Re-enter Susp Well CIOt ubinq/ESP ❑✓ 2.Operator COOK INLET ENERGY,LLC 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development ElExploratory ❑ 213-079 3.Address: 601 W 5TH AVE SUITE 310,ANCHORAGE,AK, Stratigraphic ❑ Service ❑ 6.API Number: 99501 50-733-20497-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 381203,ADL 374002 REDOUBT UNIT#1A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A REDOUBT SHOAL,Undefined Oil 11.Present Well Condition Summary: Total Depth measured 15050 feet Plugs measured N/A feet true vertical 12502 feet Junk measured 14949' feet Effective Depth measured 14953 feet Packer measured n/a feet true vertical 12426 feet true vertical n/a feet Casing Length Size MD TVD Burst Collapse Structural 200' 36" 200' 200' N/A N/A Conductor 1831' 13 3/8" 1831' 1803' 5020 psi 2260 psi Surface 6986' 9 5/8" 6986' 5988' 6870 psi 4760 psi Intermediate 5544' 7 5/8" 12246' 11616' 6890 psi 4790 psi Production Liner 8529' 5 1/2" 15038' 12493' 7740 psi 6390 psi Perforation depth Measured depth 14110-14872 feet True Vertical depth 11753-12362 feet Tubing(size,grade,measured and true vertical depth) 2-3/8"&3-1/2" L-80&L-80 11954'MD/6048'MD 9996'TVD/5236'TVD Packers and SSSV(type,measured and true vertical depth) No Packer No SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): CANNED JAN 2 3X018 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 318 88 55 27 310 Subsequent to operation: 260 57 484 385 376 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑., Exploratory ❑ Development 0 Service El Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 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: 317-294 0-17-56-9>-7 Authorized Name: Stephen Ratcliff Contact Name: Stephen Ratcliff Authorized Title: Drilling Manager Contact Email: sratcliff@glacieroil.com Authorized Signature: �J —` Date: 1/15/2018 Contact Phone: 907-433-3808 /-/ Si -I ve, Form 10-404 Revised 4/2017 RBDI S t L .1,1j1 1 v cu w n^ Submit Original Only v • • RECEIVED GLACIER .1� ,N IP'018 January 15th, 2018 Ms. Cathy Foerster, Chair AOGCC Alaska Oil and Gas Conservation Commission 333 West 7th Ave.,Suite 100 Anchorage,Alaska 99501 Re: Report of Sundry Cook Inlet Energy, LLC: RU-01A Permit to Drill NO: 213-079 API No: 50-733-20497-01-00 Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a Report of Sundry Well Operations for RU-01A. The work performed was covered under Approved Sundries 317-294 and 317-509 for pulling the ESP completion and running a new ESP completion. If you have any questions, please contact me at (907)433-3816. Sincerely, Stephen Ratcliff Drilling Manager Cook Inlet Energy, LLC (a Glacier Oil &Gas Corp. owned company) 601 W. 5th Avenue STE 310 Anchorage, AK 99501 10-404 • • GLACIER RU-01A Daily Operations Summary API: 50-733-20497-01-00 Permit #: 213-079 Rig: Osprey Rig 35 Date Activity 26 November 2017 Rig start up on RU-01A. 27 November 2017 Rig up. 28 November 2017 Rig up. ND tree. Begin NU BOPE. 29 November 2017 Continue NU BOPE.Shell test BOPE.Test BOPE 250psi low/3500psi hjgh__ Test witnessed by AOGCC Rep, Lou Laubenstein. Make up landing joint. RU to pull ESP. Unseat and LD tubing hanger. POH with tubing and ESP Assembly. 30 November 2017 Continue POH with tubing and ESP Assembly. 01 December 2017 Continue POH with tubing and ESP Assembj_. LD ESP Assembly.All clamps recovered. RU Slickline. RIH w/8.34" GR&junk basket to 6530' MD, POH. RIH w/4.5" GR &junk basket to 14002' MD, POH. RD Slickline. 02 December 2017 Rig Maintenance. 03 December 2017 Prep tubing. Rig maintenance. 04 December 2017 Tally tubing.Test BOPE 250 psi low/3500 psi high.Test witness waived by AOGCC Rep,Jim Regg. Continue rig maintenance. 05 December 2017 Prep for running ESP. RIH with Centrilift ESP on 2-3/8" 4.7# EUE 8rd L80 tubing to 1015' MD.Test ESP cable. 06 December 2017 Troubleshoot ESP cable. POH with ESP. Redress ESP. RIH with ESP on 2-3/8" 4.7# EUE 8rd L80 tubing to 3977' MD. 07 December 2017 Continue RIH with ESP on 2-3/8"tubing to 6051' MD.Crossover to 3-1/2" 9.3# EUE 8rd L80 tubing and continue RIH to 10706' MD. 08 December 2017 Continue RIH with ESP on 3-1/2" tubing. MU landing joint and hanger. Land hanger, lay down landing joint. Bottom of ESP at 12100.61' MD. RD ESP running equipment. ND BOPE. 09 December 2017 Continue ND BOPE. Rig down and winterize. 0 RU-01A Current Wellbore Schematic Version: Final • 12/13/2017 l _ Tubing hanger-ACME 3.725"MCA top connection/ GLACIER 3 1/2"EUE 8rd btm connection-ID 2.950" 36" 150#A-36 200'MD \1\ [L ID-34.00" Welded 200'TVD 17 1/2"Hole 13 3/8" 68#L-80 1,831'MD ID-12.25" BTC 1,803'TVD I 3 1/2"9.3#L-80 EUE 8rd Tubing-ID 2.992" i 's 41 XO-2 3/8"x 3 1/2"-ID 1.995"@ 6,048 MD/5,236'ND TOL @ 6,509'MD/5,605'TVD(9 5/8"x 5 1/2") 2 3/8"4.7#L-80 EUE 8rd Tubing-ID 1.995" TOL @ 6,702'MD/5,760'TVD(7 5/8"X 9 5/8") 9 5/8" 47#L-80 6,986'MD 12 1/4"Hole ID-8.50" BTC 5,988'ND Al Dual 1/4"Stainless Flat Pack Lines ESP#1 Flat Cable Cross collar clamp on every 3-1/2"jt(190) ESP Assembly Top @ 11,954'MD/9,996'ND Cross collar clamp on every 2-3/8"jt(185) Half cannon clamp on every 2-3/8"mid jt(190) ELECTRIC SUBMERSIBLE PUMP-146' Baker Centrilift Discharge Unit Assembly , Pump Assembly • Intake/Gas Separator 8 1/2"Hole Seal Assembly-Upper/Lower Seals Motor Sensor Anode ESP Assembly Bottom @ 12,100'MD/10,115'ND Perforations(&2017 Reperfs) MD TVD Reperf Type 14,110'•14,113' 11,753'-11,756' TCP / 166Window 14,113'-14,122' 11,756'-11,763' TCP/StimGun 7 5/8" 29.7#L-80 12,246'MD 14,122'-14,126' 11,763'-11,766' TCP ID-6.75" BTC 10,231'ND 14,126'-14,141' 11,766'-11,778' TCP/StimGun 14,141'-14,154' 11,778'-11,789' TCP 14,171'-14,187' 11,803'-11,816' TCP 14,187'-14,199' 11,816'-11,825' TCP/StimGun 14,199'-14,206' 11,825'-11,831' TCP 14,206'-14,226' 11,831'-11,847' TCP/StimGun 14,226'•14,230' 11,847'-11,851' TCP 14,261'-14,263' 11,876'-11,877' TCP 14,263'-14,273' 11,877'-11,885' TCP/StimGun 14,273'-14,303' 11,885'-11,909' TCP - - C 14,373'-14,454 11,964'-12,029' TCP 14,454'-14,463' 12,029'•12,036' TCP/StimGun si L 14,463'-14,570' 12,036'-12,122' TCP - 14,581-14,588' 12,131'•12,137' TCP - >_ 14,604'-14,653' 12,149'-12,188' TCP ii C - C 14,653'-14,662' 12,188'•12,195' TCP/StimGun - o 14,662'-14,721' 12,195'-12,243' TCP fi IE 14,726'-14,746' 12,247'-12,263' TCP - c 14,758'•14,786' 12,272'-12,294' TCP in 1C 14,812'•14,836' 12,316-12,334' me c Fish-4'StimGun-no fishing neck on 14,852'-14,872' 12,346'•12,362' - ra c 5 1/2" 17#L-80 15,038'MD 6 3/4"Hole ID-4.767" Hydril 521 12,493'ND PBTD:14953'MD/12426'ND OF TtJ 4,i, I%, sA THE STATE Alaska Oil and Gas 41, of Conservation Commission ..011h. LAsKA. 333 West Seventh Avenue - Anchorage, Alaska 99501-3572 lOPITh; GOVERNOR BILL WALKER g ®F T . Main: 907.279.1433 ALASY' Fax: 907.276.7542 www.aogcc.alaska.gov Stephen Ratcliff Drilling ManagersNNED ,1AN. 2 9 Cook Inlet Energy, LLC 601 W. 5th Ave., Suite 310 Anchorage, AK 99501 Re: Redoubt Shoal Field, Undefined Oil Pool, RU 1A Permit to Drill Number: 213-079 Sundry Number: 317-588 Dear Mr. Ratcliff: 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, tWr\„ Hollis S. French Chair DATED this i5 day of December, 2017. RCED:13 l." :5 , e 2517 RECEIVED STATE OF ALASKA DEC 1 3 1.017 ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Water Block Treatment n 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: COOK INLET ENERGY,LLC Exploratory ❑ Development ❑✓ 213-079 3.Address: El6.API Number: Stratigraphic ❑ Service 601 W 5TH AVE SUITE 310,ANCHORAGE,AK,99501 50-733-20497-01-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A ' Will planned perforations require a spacing exception? Yes ❑ No ❑✓ d REDOUBT UNIT#1A 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 381203,ADL 378114 REDOUBT SHOAL,UNDEFINED OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 15,050'• 12,502'' 14,953: ` 12,426' 2799 NONE 14949' Casing Length Size MD TVD Burst Collapse Structural 200' 36" 200' 200' Conductor 1831' 13 3/8" 1831' 1803' 5020 PSI 2260 PSI Surface 6986' 9 5/8" 6986' 5988' 6870 PSI 4760 PSI Intermediate 5544' 7 5/8" 12246' 11616' 6890 PSI 4790 PSI Production __ __ Liner 8529' 5 1/2" 15038' 12493' 7740 PSI 6390 PSI Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 14110'-14872' • 11753'-12362' 2-3/8"&3-1/2" L80&L80 11954'MD/6048'MD Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): NONE NONE 12.Attachments: Proposal Summary U Wellbore schematic U 13.Well Class after proposed work: Detailed Operations Program El BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑✓ ' Service El 14.Estimated Date for 15.Well Status after proposed work: CommencingASAP Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: f z.-/3-17 GAS ❑ WAG El GSTOR ❑ SPLUG ❑ Commission Representative: 63 S GINJ El Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is tru�and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stephen Ratcliff Contact Name: Stephen Ratcliff Authorized Title: Drilling Manager Contact Email: sratcliff@glacieroil.com Contact Phone: 907-433-3808 Authorized Signature: ..g2„..,/s..---- `+-_1 V--Date: 12/13/2017 \\\ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3n . 3 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ElLocation Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes EI No 111 R31717.5 W��: �`� I Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: /V / t 4-1 earf----Ns._ APPROVED BY I Z I t S It Approved by: COMMISSIONER TCO ISSION Date: A sPg /MI)17- ��r ORIGINE- �L 4,a-15,-17 (�( /( , Submit Form and ( hA( s Form 10-403 Revised 4/2017 pproved application is valid for 12 months from the date of appro I. Attachments in Duplicate 'V . < • • RECEIVED GLACIER DEC 1 3 2017 December 13th, 2017 AOGCC Mr. Hollis French, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry: RU-01A— Water Block Treatment Cook Inlet Energy: 50-733-20497-01-00, PTD: 213-079 Dear Mr. French, Cook Inlet Energy, LLC, hereby applies for a Sundry for Redoubt Unit #1A well located on ADL 381203 & 378114, in the Redoubt Unit, requesting to conduct a Water Block treatment across the perforated intervals. • - • I '• • • he "nolo . " • : - '_ _ _e •• • • . If you have any questions, please contact me at (907) 433-3808. Sincerely, Stephen Ratcliff Drilling Manager Cook Inlet Energy, LLC (a Glacier Oil &Gas wholly owned company) 601 W. 5th Avenue, Suite 310 Anchorage,AK 99501 1 ORIGINAL . < • • GLACIER 1. WELL NAME—RU-01A Requirements of 20 AAC 25.005(f) Well Summary Current Status: The well is currently producing. Scope of Work: • Shut down ESP pump. • Mix and pump 110 gals (2.6 bbls) treatment pill down tubing. • Displace with produced water. • Pump produced water down annulus. • Allow pill to treat formation. • Release well to production. General Well Information: Reservoir Pressure/TVD: 0.32 psi/ft 4,000 psi @ 14,872' MD (12,362'TVD) MASP: Reservoir Pressure— (Gas Gradient X TVD) (0.32 psi/ft X 12,362' TVD)—(0.1 psi/ft X 12,362') = 3,955 psi — 1236 psi = 2,799 psi Wellhead Type/Pressure Rating: 13 5/8" 5M Wellhead - 3 1/2" 5M tree BOPE: N/A Well Type: Oil Well Estimated Start Date: ASAP Waivers Requested: E - . . _ . -. .' : ! 2 • • GLACIER Program 1) Rig up production lines to swab and annular valves. 2) Pump 110 gallons (2.6 bbls) treatment down tubing. 3) Open annulus valve. 4) Chase treatment down tubing with 75 bbls of produced water. Pump at 1 bpm until fluid level is reached ("'51 bbls) then slow rate to1/2 bpm. a. This should put 100% of treatment out the pump intake. b. Note that the tubing will continue to attempt to drain due to being out of balance with annulus. 5) Shut-in Tubing, but monitor surface pressure. 6) Immediately start pumping produced water down annulus at 2-3 bpm until full. a. Annulus empty volume at start should be 368 bbls—24 bbls =+/- 343 bbls b. Watch annulus pressure very carefully, do not allow pressure on the annulus to increase more than 100 psi —200 psi. 7) Stop pumping once annulus is full of produced water. 8) Monitor intake pressure. Refill annulus every time the pressure drops 100 psi (14 bbls) 9) The treatment will reach mid perfs after 57.5 bbls of losses. This will most likely take over 24 hrs. 3 • RU-01A Final Wellbore Schematic S Version: Final 12/13/2017 J Tubing hanger-ACME 3.725"MCA top connection/ GLACIER [l 3 1/2"EUE 8rd btm connection-ID 2.950" 36" 150#A-36 200'MD 0 ID-34.00" Welded 200'TVD {---,-- 171/2"Hole 1 13 3/8" 68#L-80 _ 1,831'MD ID-12.25" BTC 1,803'TVD 31/2"9.3#L-80 EUE 8rd Tubing-ID 2.992" 1 44 XO-23/8"x31/2"-ID 1.995"@6,048MD/5,236'TVD TOL @ 6,509'MD/5,605'TVD(9 5/8"x 5 1/2") 2 3/8"4.7#L-80 EUE 8rd Tubing-ID 1.995" TOL @ 6,702'MD/5,760'TVD(7 5/8"X 9 5/8") 9 5/8" 47#L-80 6,986'MD 12 1/4"Hole ID-8.50" BTC 5,988'TVD 4 Dual 1/4"Stainless Flat Pack Lines ESP#1 Flat Cable Cross collar clamp on every 3-1/2"jt(190) ESP Assembly Top @ 11,954'MD/9,996'TVD Cross collar clamp on every 2-3/8"jt(185) Half cannon clamp on every 2-3/8"mid-jt(190) ELECTRIC SUBMERSIBLE PUMP-146' Baker Centrilift Discharge Unit Assembly Pump Assembly Intake/Gas Separator 8 1/2"Hole - - Seal Assembly-Upper/Lower Seals Motor Sensor Anode c - ILY ll ESP Assembly Bottom @ 12,100'MD/10,115'TVD Perforations(&2017 Reperfs) I MD TVD ReperfType 14,110'-14,113' 11,753-11,756' TCP / ' Window 14,113'-14,122' 11,756'-11,763' TCP/StimGun ' 7 5/8" 29.7#L-80 12,246'MD 14,122'-14,126' 11,763-11,766' TCP ID-6.75" BTC 10,231'ND 14,126-14,141' 11,766'-11,778' TCP/StimGun 14,141'-14,154' 11,778'-11,789' TCP 14,171'-14,187' 11,803'-11,816' TCP 14,187'-14,199' 11,816-11,825' TCP/StimGun 14,196-14,206' 11,625'-11,831' TCP 14,206'-14,226' 11,831'-11,847' TCP/StimGun 14,226-14,230' 11,847'-11,851' TCP 14,261'-14,263' 11,876-11,877' TCP 14,263'-14,273' 11,877'-11,885' TCP/StimGun ' 14,273-14,303' 11,885'-11,909' TCP C 14,373-14,454 11,964'-12,029' TCP -_ Q 14,454'-14,463' 12,026-12,036' TCP/StimGun e;i E 14,463-14,570' 12,036-12,122' TCP -- @ 14,581-14,588' 12,131'-12,137' TCP ti 14,604'-14,653' 12,149'-12,188' TCP 14,653-14,662'_12,186-12,195' TCP/StimGun .,.- p 14,662'-14,721' 12,196-12,243' TCP ! jG 14,726'-14,746' 12,247'-12,263' TCP _. C' - C 14,758'-14,786' 12,272'-12,294' TCP r L.y 14,812'-14,836' _12,315'-12,334' - - 6 Fish-4'StimGun-no fishing neck 14,852'-14,872' 12,346'-12,362' - ii. 5 1/2" 17#L-80 15,038'MD 6 3/4"Hole r -y " ID-4.767" Hydril 521 12,493'ND PBTD:14953'MD/12426'ND • • Product Data BAKER Baker Petrolite WAW5206 Mutual Solvent DESCRIPTION: FEATURES AND BENEFITS: WAW5206 mutual solvent is a proprietary blend of Feature: specialty additives that has been designed for use in •Water-wets the formation acid for the reduction or removal of emulsion or Benefit: water blocks.WAW5206 will also aid in the •Stimulates production/improves injectivity removal of sludge and deposits in the near wellbore Feature region. This product is miscible in produced water, •Readily miscible in produced water and flood waters and other brines,and thus is an other brines excellent formation wetting agent to be applied Benefit: ahead of formation matrix scale squeeze treatments. •Excellent for use ahead of matrix squeeze APPLICATION: treatments In producing wells,WAW5206 mutual solvent is Feature: typically used at a concentration of 5%by volume in 'Aids in the removal of acid blocks or acid. The treatment volume should be calculated to emulsion blocks allow for penetration of about 3 feet into the Benefit: reservoir. The acid solution should be squeezed •Useful in the remediation of common away slowly and displaced beyond the perforations formation damage into the producing zone. When using WAW5206 as MATERIAL COMPATIBILITY: a wetting agent in a preflush,the product should be added to the preflush fluid at a 5%concentration. Suitable: This mixture should be agitated thoroughly to insure Metals: admiralty brass,aluminum,copper, homogeneity.Pump the preflush mixture to enter the mild steel,304 stainless steel, producing zone slowly and follow with the desired 316 stainless steel scale inhibitor squeeze treatment. Plastics: HD polyethylene,HD polypropylene, polyurethane TYPICAL PROPERTIES: Elastomers: BUNA N,EP,TEFLON,VITON Specific Gravity @ 60°F(16°C) 0.914 Not Suitable: Specific Weight @ 60°F(16°C) 7.61 lbs/gal Metals: Flash Point, SFCC 150°F(66°C) Plastics: PLEXIGLAS,PVC,fiberglass Pour Point -40°F(-40°C) Elastomers: neoprene,HYPALON, Ionic character Anionic SAFETY AND HANDLING: Before handling, storage or use,see the Material Safety Data Sheet(MSDS)for details. Baker Petrolite 24 Hour Emergency Hotline: 1-800-424-9300(CHEMTREC)U.S.A. 1-613-996-6666(CANUTEC)Canada Baker Petrolite Customer Care Hotline: 1-800-872-1916(8 a.m.to 5 p.m.CST) Disclaimer of Liability:Baker Petrolite Corporation(BPC)warrants to purchaser,but no third parties or others,the specifications for the product shall fall within a generally recognized range for typical physical properties established by BPC when the product departs BPC's point of origin and that any services shall only be performed in accordance with applicable written work documents.BPC MAKES NO OTHER WARRANTY OR GUARANTEE OF ANY KIND,EXPRESS OR IMPLIED,INCWDING NO IMPLIED WARRANTY OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE,REGARDING ANY SERVICES PERFORMED OR PRODUCT SUPPLIED.BPC will give purchaser the benefit of BPC's best judgement in making interpretations of data,but does not guarantee the accuracy or correctness of such interpretations.BPC's recommendations contained herein are advisory only and without representations as to the results.BPC shall not be liable for any indirect,special, punitive,exemplary or consequential damages or losses from any cause whatsoever including but not limited to its negligence. BPPD2275 (09/98) %,OF 711-_ • 5 ��(//yam''m, THE STATE Alaska Oil and Gas � � : of T ASKA Conservation Commission 5 } 2 �� 333 West Seventh Avenue iz '� w ' ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 _ Main: 907.279.1433 OA., ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Stephen Ratcliff Sr. Drilling Engineer Cook Inlet Energy, LLC 601 W 5th Ave., Suite 310 SCANNED N 0 V 1 3 2017) Anchorage, AK 99501 Re: Redoubt Shoal Field, Undefined Oil Pool, RU-#1A Permit to Drill Number: 213-079 Sundry Number: 317-509 Dear Mr. Ratliff: 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, tarr -- Hollis S. French -r Chair J DATED this 6 day of November, 2017. RBD , S t- r"°, - 9 2017 • 0 RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION OCT 3 0 2017 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 j�O(C C 1.Type of Request: Abandon CI Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ ^`✓ perations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑✓ , Change Approved Program 2 Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing El Other: Run ESP n • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: COOK INLET ENERGY,LLC Exploratory ❑ Development Q• 213-079 " 3.Address: ❑ 6.API Number: Stratigraphic ElService 601 W 5TH AVE SUITE 310,ANCHORAGE,AK,99501 50-733-20497-01-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No ❑., / REDOUBT UNIT#1A 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 381203,ADL 378114 • REDOUBT SHOAL,UNDEFINED OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 15,050' • 12,502' . 14,953' • 12,426'• 2799 NONE 14949' Casing Length Size MD TVD Burst Collapse Structural 200' 36" 200' 200' Conductor 1831' 13 3/8" 1831' 1803' 5020 PSI 2260 PSI Surface 6986' 9 5/8" 6986' 5988' 6870 PSI 4760 PSI Intermediate 5544' 7 5/8" 12246' 11616' 6890 PSI 4790 PSI Production __ Liner 8529' 5 1/2" 15038' 12493' 7740 PSI 6390 PSI Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 14110'-14872' - 11753'-12362' 2-7/8"&3-1/2" L80&L80 13050'MD/6049'MD Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): NONE NONE 12.Attachments: Proposal Summary L] Wellbore schematic L] 13.Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 2, Service ❑ 14.Estimated Date for 15.Well Status after proposed work: ASAP Commencing Operations: OIL ❑., ' WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ 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. Authorized Name: Stephen Ratcliff Contact Name: Stephen Ratcliff Authorized Title: Sr.Drilling Engineer Contact Email: sratcliff@glacieroil.com (� Contact Phone: 907-433-9738 Authorized Signature: .A.___-c. ...--\ Date: 10/27/2017 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 5)1 44 I Plug Integrity ❑ BOP Test Ua Mechanical Integrity Test ❑ Location Clearance El Other: ieK1 lot, -S t"- /61 ' t" ' * 3 S /0,-, /go I° kst- A c V -(-.0-s reeGCA.. a ,-.°L.,-/-{:, c Post Initial Injection MIT Req'd? Yes ❑ No El Spacing Exception Required? Yes ❑ No EX Subsequent Form Required: /6-- 0 `l RBD S t ty3 - '' 2017 APPROVED BY Approved by: t./00.(1/.---\" . ^ L`J v COMMISSIONER THE COMMISSION Date: b 4, il iv-2-47- Submitrwirlim Form and 47i\ Form 10-403 Revised 4/2017 Approved application is valid f 1 m h ro h ttl klpproval. Attachments in Duplicate • RECEIVE, OCT 302017 GLACIER AOGCC RECEIVED October 27th, 2017 OCT 3 0 2017 Mr. Hollis French, Chair AOGCC Alaska Oil and Gas Conservation Commission 333 West 7th Ave. Suite 100 Anchorage, Alaska 99501 RE: Sundry: RU-01A— Change Approved Program Cook Inlet Energy: 50-733-20497-01-00, PTD: 213-0794i9 \ g1^-ec 1L � Dear Mr. French, �,(,, Cook Inlet Energy, LLC, hereby submits an Application for Sundry Approval for Redoubt Unit 01A, PTD: 213-079, requesting permission to Change the Approved Program, as described in Sundry 317- 294, by setting the new ESP completion at a depth higher in the 5-1/2" liner. l 3z ` . 12 ,fou ' 0.0 GSr'62 The sub-surface safety valve, vent valve, and production packer are omitted from the planned completion. An AOGCC witnessed "no flow" test was passed on 6/11/17 for RU-01A. Due to the ESP swap being the only scope of work, a waiver is requested for a subsequent no-flow test. An extension is also requested to the 5-day production limit for the surface safety valve test to 30-days. .,' a t 5 .�. —'- wa_zo.,..q f- 5✓s fc,sr c �j�,. 5'� - If you have any questions, please contact me at 907.433.3808. /,_ ft-SJ? Sincerely, 4 ` x"" \ Stephen Ratcliff Sr. Drilling Engineer Cook Inlet Energy, LLC (a Glacier Oil &Gas wholly owned company) 601 W. 5th Avenue STE 310 Anchorage, AK 99501 1 • • • GLACIER 1. WELL NAME—RU-01A Requirements of 20 AAC 25.005(f) Well Summary Current Status: The well is currently producing. Scope of Work: • Rig up Rig 35 & NU BOPE • Pull ESP completion and tubing. • RIH with new ESP assembly on tubing. / • Turn well over to production. General Well Information: Reservoir Pressure/TVD: 0.32 psi/ft 4,000 psi @ 14,872' MD (12,362'ND) MASP: Reservoir Pressure—(Gas Gradient X ND) (0.32 psi/ft X 12,362'TVD)—(0.1 psi/ft X 12,362') = 3,955 psi—1236 psi = 2,799 psi Wellhead Type/Pressure Rating: 13 5/8" 5M Wellhead -3 1/2" 5M tree BOPE: 13 5/8" 5M—Pipe Rams/ Blind Rams/Annular Well Type: Oil Well Estimated Start Date: ASAP Waivers Requested: Extension for production limit from 5-days to 30-days. CIE Drilling Manager CIE Sr. Drilling Engineer CIE Production Manager Conrad Perry Stephen Ratcliff David Pascal (907) 727-7404 (907) 433-3808 (907) 433-3822 cperry@glacieroil.com sratcliff@glacieroil.com dpascal@glacieroil.com 2 • • GLACIER Program Pre-Rig 1. Conduct pre-job safety meeting with all personnel on location. o Review upcoming work and discuss safety first. 2. Lock out safety systems 3. Prep for Rig and Workover operations. 4. Ensure that well is dead. Rig Workover 1. Kill well with produced water. 2. Move Rig 35 onto RU-05B. 3. Check for pressure and note pressure in tubing and in annulus. 4. RID lines from tree and annulus to production if not done prior to rig move. 5. Check for flow, ensure well is dead and shut in well. 6. Place back pressure valve in wellhead. 7. Notify AOGCC 48 hours in advance of start of operations and upcoming BOP test. 8. N/D Production Tree. 9. N/U and Test 13 5/8" BOPE with 2 7/8" x 5" VBR rams with blinds in middle. 10. Test BOPE on 2 7/8" and 3 1/2"to 250 psi low/3500 psi high and chart. 11. Rig up ESP spoolers and hardware. 12. Remove back pressure valve. 13. P/U Landing Joint and make up to 3 1/2" Tubing Hanger. 14. Back out Lock Down screws in Tubing Hanger. 15. Pull & L/D 3 1/2" Landing Joint and Tubing Hanger. 16. Check for Flow and confirm well is dead. 17. POH and stand back 3-1/2" tubing. 18. Continue to POH and lay down: a. 2-7/8"Tubing b. ESP BHA 19. Prep to pick up ESP Completion equipment, spoolers, and tools. 20. Rig up Summit for ESP Completions. a. Hold PJSM for ESP Run. b. Test and confirm that all equipment is on location and ready to RIH. c. NOTE: COMPLETION ESP/TUBING WILL NOT BE ROTATED. 21. Pick up the ESP completion assembly as directed. a. NOTE: Setting depth of ESP BHA at 12,950_ ' IIID (Confirm with GLA Engineer prior to RIH). Do not enter the 5-1/2" liner.12,95p b. Pump should be set in less than 1 degree/100' dogleg. (Top of Pump Assy tentatively set for 12,800' MD). 3 • • GLACIER c. NOTE: Will not run any 2-7/8" tubing. d. NOTE: the 3/8" flat pack chemical injection line is to be run to the anode on the bottom of the ESP assembly. e. 3/8" Nova Valves to be installed at top of pump assembly. f. The Packer, SSSV, and Vent Valve will NOT be ran with this completion. g. Blank off vent line and SSSV line. h. Cannon clamps at every collar and a mid-clamp on every joint. 22. RIH with ESP completion on 3-1/2" tubing. Test cable every 500'. 23. Monitor trip tank for proper hole filling. Splice cable as needed. At TD, confirm pipe tally. 24. MU landing joint and set string in slips. 25. Dress hanger and control lines. Land hanger, run in screws, test hanger to 5000 psi. a. Make sure the two extra ports in hanger are plugged. 26. Observe well dead. Lay down landing joint and install BPV. 27. Nipple down riser and BOPE. 28. Install and test production tree. 29. Turn over well to production. 30. Release Rig. 4 " • RU-01A Current Wellbore Schematic1110 Version: C6/7/2017urrent < - Tubing hanger-ACME 3.725"MCA top connection/ GLACIER JI l 3 1/2"EUE 8rd btm connection-ID 2.950" 36" 150#A-36 200'MD ID-34.00" Welded 200'TVD k-'- 17 1/2"Hole , 13 3/8" 68#L-80 1,831'MD ID-12.25" BTC 1,803'TVD ESP#1 Round Cable ' 3 1/2"9.3#L-80 EUE Tubing-ID 2.992" F/6,000'MD to surface i XO-2 7/8"x 3 1/2"-ID 2.441"@ 6,049'MD/5,236'TVD TOL @ 6,509'MD/5,605'TVD(9 5/8"x 5 1/2") - 2 7/8"6.5#L-80 EUE Tubing-ID 2.441" @ 13,420'MD-6,000'MD/11,174'TVD-5,197'TVD TOL @ 6,702'MD/5,760'TVD(7 5/8"X 9 5/8") 9 5/8" 47#L-80 6,986'MD 12 1/4"Hole , ID-8.50" BTC 5,988'TVD 4-- Dual 3/8"Stainless Flat Pack Lines Window 7 5/8" 29.7#L-80 12,246'MD 8 1/2"Hole , ' ID-6.75" BTC 10,231'TVD ESP Assembly Top @ 13,050'MD/10,874'ND ELECTRIC SUBMERSIBLE PUMP-151' ESP#2 Flat Pack Cable _ Perforations(&2017 Reperfs) Discharge Unit Assembly MD TVD Reperf Type a Pump Assembly(3) 14,110'-14,113' 11,753'-11,756' TCP Intake/Gas Separator 14,113'-14,122' 11,756'-11,763' TCP/StimGun Seal Assembly-Upper/Lower Seals 14,122'-14,126' 11,763'-11,766' TCP Motor(2)/Motor Gauge Unit 14,126'-14,141' 11,766'-11,778' TCP/StimGun ';1 Sensor 14,141'-14,154' 11,778'-11,789' TCP q Anode - 14,171'-14,187' 11,803'-11,816' TCP �{1 Chemical Injection Check Valve 14,187'-14,199' 11,816'-11,825' TCP/StimGun It�Villll 14,195-14,206' 11,825'-11,831' TCP 14,206'-14,226' 11,831'-11,847' TCP/StimGun 11 14,226'-14,230' 11,847'-11,851' TCP ESP Assembly Bottom @ 13,201'MD/10,994'ND 14,261'-14,263' 11,875-11,877' TCP 14,263'-14,273' 11,877'-11,885' TCP/StimGun 1:4 14,273'-14,303' 11,885'-11,909' TCP 11= 14,373'-14,454 11,964'-12,029' TCP - 6 14,454'-14,463' 12,025-12,036' TCP/StimGun 'le E 14,463'-14,570' 12,036'-12,122' TCP - = - 14,581-14,588' 12,131'-12,137' TCP Si 14,604'-14,653' 12,149'-12,188' TCP _� i=14,653'-14,662' 12,188'-12,195' TCP/StimGun _ _ 14,662'-14,721' 12,195-12,243' TCP isi C 14,726'-14,746' 12,247'-12,263' TCP ilil 1= 14,758'-14,786' 12,272'-12,294' TCP G PE IC 14,812'-14,836' 12,315-12,334' - ma !lgE Fish-4'StimGun-no fishing neck 14,852'-14,872' 12,345-12,362' - a 5 1/2" 17#L-80 15,038'MD 6 3/4"Hole ID-4.767" Hydril 521 12,493'ND PBTD:14953'MD/12426'TVD + • RU-01A Proposed Wellbore Schematic . Version: Proposed 10/26/2017 < - Tubing hanger-ACME 3.725"MCA top connection/ GLACIER i [IL 3 1/2"EUE 8rd btm connection-ID 2.950" 36" 150#A-36 200'MD 1 ID-34.00" Welded 200'TVD kx. 17 1/2"Hole ¢', i 13 3/8" 68#L-80 1,831'MD ESP#1 Round Cable .;i ID-12.25" BTC 1,803'TVD V : st 43, 1 a. 3 1/2"9.3#L-80 EUE Tubing-ID 2.992' "-.. F/6,000'MD to surface 4" t i 4 A XO-2 7/8"x 3 1/2"-ID 2.441"@ 6,049'MD/5,236'TVD r. k`i TOL @ 6,509'MD/5,605'ND(9 5/8"x 5 1/2") 2 7/8"6.5#L-80 EUE Tubing-ID 2.441" w @ 11,950'MD-6,000'MD/10,115'ND-5,197'ND TOL @ 6,702'MD/5,760'ND(7 5/8"X 9 5/8") °'� 9 5/8" 47#L-80 6,986'MD 12 1/4"Hole AI kik ID-8.50" BTC 5,988'ND Dual 1/4"Stainless Flat Pack Lines ::'I ESP Assembly Top @ 11,950'MD/10,115'ND ELECTRIC SUBMERSIBLE PUMP-151' ESP#2 Flat Pack Cable Discharge Unit Assembly Fri Pump Assembly(3) Intake/Gas Separator 8 1/2"Hole Seal Assembly-Upper/Lower Seals Motor(2)/Motor Gauge Unit Sensor Anode -,iii Chemical Injection Check Valve `1 ESP Assembly Bottom @ 12,100'MD/10,115'ND ' ( 1 Perforations(&2017 Reperfs) MD TVD ReperfType 14,110'-14,113' 11,753'-11,756' TCP 4 ;.,+ ' Window 14,112-14,122' 11,756'-11,763' TCP/StimGun 7 5/8" 29.7#L-80 12,246'MD 14,122-14,126' 11,763-11,766' TCP ID-6.75" BTC 10,231'ND 14,126'-14,141' 11,765-11,778' TCP/StimGun 14,141'-14,154' 11,775-11,789' TCP , 14,171'-14,187' 11,803-11,816' TCP . 14,187'-14,199' 11,815-11,825' TCP/StimGun 14,199'-14,206' 11,825'-11,831' TCP 14,206'-14,226' 11,831'-11,847' TCP/StimGun 14,226'-14,230' 11,847'-11,851' TCP 14,261'-14,263' 11,876'-11,877' TCP 14,263'-14,273' 11,877'-11,885' TCP/StimGun ', 14,273-14,303' 11,885'-11,909' TCP -. 14,373-14,454 11,964'-12,029' TCP _ - 14,454'-14,463' 12,025-12,036' TCP/StimGun M ;:,+ 14,463'-14570' 12,036'-12,122' TCP --- -- 14,581-14,588' 12,131'-12,137' TCP "� 14,604'-14,653' 12,149'-12,188' TCP ._ _ 14,653-14,662' 12,185-12,195' TCP/StimGun „, 14,662'-14,721' 12,195-12,243' TCP we ! 14,726'-14,746' 12,247'-12,263' TCP "' "' 14,758'-14,786' 12,272'-12,294' TCP r u, 14,812'-14,836' 12,315-12,334' - Fish-4'StimGun-no fishing neck 14,852'-14,872' 12,346'-12,362' - 7 +t7 5 1/2" 17#L-80 15,038'MD 6 3/4"Hole .- iii ID-4.767" Hydril 521 12,493'ND PBTD:14953'MD/12426'ND • S CIE Rig 35 Redoubt Unit 13 5/8" 10,000 PSI BOP STACK 5000 psi Annular 10,000 psi 4" pipe rams Double Gate 4" outlets 10,000 psi DSA 113" Both sides Blind Rams Double Gate 3" Kill line Mud3" Choke line 2 2 Cross _ 2 1 1= HCR Valve 10,000 psi 2=Gate Valve 4" Pipe Rams Single Gate �4 } 13 5/8" 5M 4. Wellhead 13 3/8" Surface Casing 1 9 5/8" Intermediate Casing • OFT • • (04,\\\�'1%y am THE STATE Alaska Oil and Gas ofA LA SKA Conservation Commission 333 West Seventh Avenue 1. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 \ w� Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Conrad Perry 1 3 2Q l l Sr. Vice President SCO •J U L 1 Cook Inlet Energy, LLC 601 W. 5th Ave., Ste. 310 Anchorage,AK 99501 Re: Redoubt Shoal Field,Undefined Oil Pool, RU 1A Permit to Drill Number: 213-079 Sundry Number: 317-294 Dear Mr. Perry: 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, .1 ' p9041.4„...„, Cathy '. Foerster Chair, Commissioner DATED this Ziay of June, 2017. RBDMS t,L- JUN 2 8 2017 • • RECEIVED STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION jUN 2 2 2017 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGCC 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑✓ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: likorWelgO n 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: re:e--Ai;,zi,, COOK INLET ENERGY,LLC Exploratory ❑ Development ❑ 1213-079 • ESP 3.Address: Stratigraphic ❑ Service 6.API Number: 601 W 5TH AVE SUITE 310,ANCHORAGE,AK,99501 ❑ 50-733-20497-01-00 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No ❑., REDOUBT UNIT#1A • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 381203,ADL 378114 ' REDOUBT SHOAL,UNDEFINED OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 15,050' 12,502' 14,953' • 12,426' ' 2799 NONE 14949' Casing Length Size MD TVD Burst Collapse Structural 200' 36" 200' 200' Conductor 1831' 13 3/8" 1831' 1803' 5020 PSI 2260 PSI Surface 6986' 9 5/8" 6986' 5988' 6870 PSI 4760 PSI Intermediate 5544' 7 5/8" 12246' 11616' 6890 PSI 4790 PSI Production __ __ _- _ Liner 8529' 5 1/2" 15038' 12493' 7740 PSI 6390 PSI Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 14110'-14872' - 11753'-12362' 2-7/8"&3-1/2" L80&L80 13050'MD/6049'MD Packers and SSSV Type: NONE Packers and SSSV MD(ft)and TVD(ft): NONE 12.Attachments: Proposal Summary U Wellbore schematic [✓j 13.Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch El Exploratory ❑ Stratigraphic ❑ Development❑✓ , Service ❑ 14.Estimated Date for 15.Well Status after proposed work: ASAP Commencing Operations: OIL ❑✓ • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG El 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. Authorized Name: Conrad Perry Contact Name: Stephen Ratcliff Authorized Title: Sr - Prei. ' Contact Email: Sratcliff@glacieroiI.com Contact Phone: 907-433-9738 Authorized Signature: / Date: 6/22/2017 COMMISSION USE ONLY Conditions of approval: Notify C, mission so at a representative may witness Sundry Number: 31-7-25f1{ Plug Integrity ❑ o 3s-co BOP Test V Mechanical Integrity Test ❑ Location Clearance ❑ -1V � / Ii' i Other: - 3JC OS.,: 7c'f / .s )e- il ik},-; - F.-4f,, . 7-.7, f 1.,..:".....:, .1 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No vi Subsequent Form Required: /0 —L%C't RBDMS 1/V JUN 2 8 2017 APPROVED BY Approved by: / COMMISSIONER THE COMMISSION Date: G.. 2,7../ -2 �Ka Gl / l c- t Submit Form and Form 10-403 4/2017 ORTGTNAL ilid for 12 months from the date of op/lova. Attachments in Duplicate • • RECEIVED GLACIER JUN 2 2 2017 June 22, 2017 AOGGC Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry: RU-01A— Application to Pull and Run ESP Completion Cook Inlet Energy: 50-733-20497-01-00, PTD: 213-079 Dear Ms. Foerster, Cook Inlet Energy, LLC, hereby submits an Application for Sundry Approval for Redoubt Unit 01A, PTD: 213-079, requesting permission to pull the current ESP completion and run a new ESP r completion. Monitoring systems currently indicate the pump assembly is not operating correctly and a failure is being predicted. If you have any questions, please contact me at 907.433.3808. Sincerely, Conrad Perr '71 Sr. Vice President Cook Inlet Energy, LLC (a Glacier Oil & Gas wholly owned company) 601 W. 5th Avenue STE 310 Anchorage, AK 99501 1 •. < • GLACIER 1. WELL NAME— RU-01A Requirements of 20 AAC 25.005(f) Well Summary Current Status: The well is currently producing. Scope of Work: • Rig up Rig 35 & NU BOPE • Pull ESP completion and tubing. • RIH with new ESP assembly on tubing. • Turn well over to production. General Well Information: Reservoir Pressure/TVD: 0.32 psi/ft 4,000 psi @ 14,872' MD (12,362'TVD) MASP: Reservoir Pressure — (Gas Gradient X TVD) (0.32 psi/ft X 12,362' TVD)— (0.1 psi/ft X 12,362') = 3,955 psi — 1236 psi = 2,799 psi Wellhead Type/Pressure Rating: 13 5/8" 5M Wellhead - 3 1/2" 5M tree BOPE: 13 5/8" 5M —Pipe Rams/ Blind Rams/Annular Well Type: Oil Well Estimated Start Date: ASAP Waivers Requested: No flow test to omit vent valve, production packer and SSSV. fCIEExtension for production limit from 5-days to 30-days. Of(— CIE Drilling Manager CIE Sr. Drilling Engineer CIE Production Manager Conrad Perry Stephen Ratcliff David Kumar (907) 727-7404 (907) 433-3808 (907) 433-3822 cperry@glacieroil.com sratcliff@glacieroil.com dkumar@glacieroil.com 2 • • GLACIER Program Pre-Rig 1. Conduct pre-job safety meeting with all personnel on location. o Review upcoming work and discuss safety first. 2. Lock out safety systems and power oil 3. Prep for Rig and Workover operations. 4. Ensure that well is dead. Rig Workover General Note: There is 2 7/8" and 3-1/2" tubing currently in the well. General Note: Full opening Safety Valve will be on rig floor at all times with appropriate crossovers for all pipe being run below rotary table. 1. Move rig onto RU-01A. 2. Check for pressure and note pressure in tubing and in annulus. 3. R/U lines from tree and annulus to production if not done prior to rig move. 4. Check for flow and shut in well. 5. Place back pressure valve in wellhead. • 6. Notify AOGCC 48 hours in advance of start of operations and upcoming BOP test. 7. N/D Production Tree. 8. N/U and Test 13 5/8" BOPE with 2 7/8" x 5" VBR rams with blinds in middle. 9. Test BOPE on 2 7/8" and 3 1/2"to 250 psi low/3500 psi high and chart. 10. Rig up ESP spoolers and hardware. 11. Remove back pressure valve. 12. P/U Landing Joint and make up to 3-1/2" Tubing Hanger. 13. Back out Lock Down screws in Tubing Hanger. 14. Kill well with 8.5 ppg produced water+ KCI, circulate wellbore volume. o Track fluid volume to identify losses if they occur. ■ Have salt pill prepared if losses are identified. 15. Pull & L/D 3-1/2" Landing Joint and Tubing Hanger. 16. Check for Flow and confirm well is dead. 17. POH and L/D the following: o 3-1/2" Tubing o 2-7/8" Tubing 3 • GLACIER o ESP BHA 18. Change out failed ESP equipment. 19. Pick up the ESP completion assembly as directed. o NOTE: Setting depth of ESP BHA at 13,201' MD (Confirm with GLA Engineer prior to RIH). o Pump should be set in less than 1 degree/100' dogleg. (Top of Pump Assy tentatively set for+/- 13,050' MD). o NOTE: the 3/8" flat pack chemical injection line is to be run to the anode on the bottom of the ESP assembly. o 3/8" Nova Valves to be installed at top of pump assembly. 20. RIH with ESP completion on 3-1/2" 9.3# L80 EUE & 2-7/8" 6.5# L80 EUE tubing. o Test cable every 1000'. o Crossover from 3-1/2" to 2-7/8" tubing at+/- 6,000'. 21. Monitor trip tank for proper hole filling. Splice cable as needed. At TD, confirm pipe tally, MU landing joint and set string in slips. 22. Dress hanger and control lines. Land hanger, run in screws, test hanger to 5000 psi. 23. Observe well dead. Lay down landing joint and install BPV. 24. Nipple down riser and BOPE. 25. Install and test production tree to 5,000 psi. Turn over well to production. 26. Release Rig. 4 • RU-01A Current Wellbore SchematicIP Version: Current 6/7/2017 Tubing hanger-ACME 3.725"MCA top connection/ GLACIER Al - l 3 1/2"EUE 8rd btm connection-ID 2.950" 36" 150#A-36 200'MD ID-34.00" Welded 200'TVD ,f I 17 1/2"Hole x i . _ 13 3/8" 68#L-80 1,831'MD ID-12.25" BTC 1,803'TVD I. n 4 "kr 3 1/2"9.3#L-80 EUE Tubing-ID 2.992" - F/6,000'MD to surface XO-27/8"x31/2"-ID 2.441"@6,049'MD/5,236'ND ti' II.vTOL @ 6,509'MD/5,605'TVD(9 5/8"x 5 1/2") ` r,. -+ 2 7/8"6.5#L-80 EUE Tubing-ID 2.441" w @ 13,420'MD-6,000'MD/11,174'TVD-5,197'TVD TOL @ 6,702'MD/5,760'TVD(7 5/8"X 9 5/8") • 9 5/8" 47#L-80 6,986'MD • 12 1/4"Hole I �� ID-8.50" BTC 5,988'TVD i 1 L, Dual 3/8"Stainless Flat Pack Lines I! Window i 7 5/8" 29.7#L-80 12,246'MD , I 8 1/2"Hole I ' Ii;: ID-6.75" BTC 10,231'TVD 1 ',A •f ESP Assembly Top @ 13,050'MD/10,874'TVD 'i `i ELECTRIC SUBMERSIBLE PUMP-151' ESP#1 Flat Pack Cable Perforations(&2017 Reperfs) Discharge Unit Assembly MD TVD Reperf Type } Pump Assembly(3) 14,110'-14,113' 11,753'-11,756' TCP -- - Intake/Gas Separator , 14,113'-14,122' 11,756'-11,763' TCP/StimGun '" "� Seal Assembly-Upper/Lower Seals 14,122'-14,126' 11,763'-11,766' TCP +* !- Motor(2)/Motor Gauge Unit 14,126'-14,141' 11,766'-11,778' TCP/StimGun "gid .' Sensor 14,141'-14,154' 11,778'-11,789' TCP . . C- Anode 14,171'-14,187' 11,803'-11,816' TCP Chemical Injection Check Valve 14,187'-14,199' 11,816'-11,825' TCP/StimGun f e*- 14,199'-14,206' 11,825'-11,831' TCP I. 14,206'-14,226' 11,831'-11,847' TCP/StimGun Pr ' 14,226'-14,230' 11,847'-11,851' TCP s, 1. " k, ESP Assembly Bottom @ 13,201'MD/10,994'TVD 14,26;'-;4,26:i ,mu ;677' TG 14,263'-14,273' 11,877'-11,885' TCP/StimGun 14,273'-14,303' 11,885'-11,909' TCP Tight spots(4.50"-4.60")in casing encountered @ 13171', 14,373'-14,454 11,964'-12,029' TCP 13257',and 13430'MD(2017 WO) 14,454'-14,463' 12,029'-12,036' TCP/StimGun S 14,463'-14,570' 12,036'-12,122' TCP 14,581-14,588' 12,131'-12,137' TCPTT 14,604'-14,653' 12,149'-12,188' TCP 14,653'-14,662' 12,188'-12,195' TCP/StimGun _ 14,662'-14,721' 12,195'-12,243' TCP II! 14,726'-14,746' 12,247'-12,263' TCP 14,758'-14,786' 12,272'-12,294' TCP 14,812'-14,836' 12,315'-12,334' - Fish-4'StimGun-no fishing neck 14,852'-14,872' 12,346'-12,362' - '- 05 1/2" 17#L-80 15,038'MD 6 3/4"Hole I R ID-4.767" Hydril 521 12,493'ND• PBTD:14953'MD/12426'TVD RU-01A Planned Wellbore Schematic Version: Planned . < • IP 6/22/2017 Tubing hanger-ACME 3.725"MCA top connection/ " 6 f.-AC E RlJ 7 i 3 1/2"EUE 8rd btm connection-ID 2.950" 36" 150#A-36 200'MD ID-34.00" Welded 200'TVD ,5' j, 17 1/2"Hole •. IF ',.:[ 13 3/8" 68#L-80 1,831'MD ID-12.25" BTC 1,803'TVD 3 1/2"9.3#L-80 EUE Tubing-ID 2.992" F/6,000'MD to surface 4 XO-2 7/8"x 3 1/2"-ID 2.441"@ 6,049'MD/5,236'TVD TOL @ 6,509'MD/5,605'TVD(9 5/8"x 5 1/2") - 2 7/8"6.5#L-80 EUE Tubing-ID 2.441" @ 13,420'MD-6,000'MD/11,174'TVD-5,197'TVD TOL @ 6,702'MD/5,760'TVD(7 5/8"X 9 5/8") 9 5/8" 47#L-80 6,986'MD 12 1/4"Hole I ID-8.50" BTC _ 5,988'TVD Dual 3/8"Stainless Flat Pack Lines Window 7 5/8" 29.7#L-80 12,246'MD 8 1/2"Hole , ID-6.75" BTC 10,231'TVD ESP Assembly Top @ 13,050'MD/10,874'TVD ELECTRIC SUBMERSIBLE PUMP-151' 1 ESP#1 Flat Pack Cable Perforations(&2017 Reperfs) it Discharge Unit Assembly MD TVD Reperf Type 1. Pump Assembly(3) 14,110'-14,113' 11,753'-11,756' TCP "t Intake/Gas Separator 14,113'-14,122' 11,756'-11,763' TCP/StimGun Seal Assembly-Upper/Lower Seals 14,122'-14,126' 11,763'-11,766' TCP Motor(2)/Motor Gauge Unit 14,126'-14,141' 11,766'-11,778' TCP/StimGun Sensor 14,141'-14,154' 11,775-11,789' TCP Anode 14,171'-14,187' 11,803'-11,816' TCP Chemical Injection Check Valve 14,187'-14,199' 11,816'-11,825' TCP/StimGun 14,199'-14,206' 11,825-11,831' TCP . . 14,205-14,226' 11,831'-11,847' TCP/StimGun 14,226'-14,230' 11,847'-11,851' TCP _ ESP Assembly Bottom @ 13,201'MD/10,994'ND 14,261'-14,263' 11,876'-11,877' TCP r in 14,263'-14,273' 11,877'-11,885' TCP/StimGun 14,273'-14,303' 11,885-11,909' TCP - Tight spots(4.50"-4.60")in casing encountered @ 13171', 14,373'-14,454 11,964'-12,029' TCP M 13257',and 13430'MD(2017 WO) 14,454'-14,463' 12,029'-12,036' TCP/StimGun g,1 14,463'-14,570' 12,036'-12,122' TCP 14,581-14,588' 12,131'-12,137' TCP 14,604'-14,653' 12,149'-12,188' TCP moil 14,653'-14,662' 12,188'-12,195' TCP/StimGun ail C 14,662'-14,721' 12,195-12,243' TCP 14,726'-14,746' 12,247'-12,263' TCP - 14,758'-14,786' 12,272'-12,294' TCP -. ' 14,812'-14,836' 12,315'-12,334' - "`" Fish-4'StimGun-no fishing neck MI / 14,852'-14,872' 12,346'-12,362' - NM 5 1/2" 17#L-80 15,038'MD 6 3/4"Hole ID-4.767" Hydril 521 12,493'TVD PBTD:14953'MD/12426'TVD OF rAr ► THE STATE Alaska Oil andGas • • I/� �A o ®® ®® cc TTA Conservation Commission 333 West Seventh Avenue ^� GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Ce Main: 907.279.1433 A ;5Y. Fax: 907.276.7542 www.aogcc.alaska.gov June 15, 2017 Mr. David Kumar Production Manager Cook Inlet Energy 601 W. 5th Avenue, Suite 310 Anchorage, AK 99501 RE: No-Flow Verification SCANNED J ti N 2 3 2017 Redoubt Unit 1 A PTD 2130790 Dear Mr. Kumar: On June 11, 2017 an Alaska Oil and Gasn Co servation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Redoubt Unit 1A located on the Osprey platform in Cook Inlet. The well is operated by Cook Inlet Energy (CIE). The AOGCC Inspector confirmed that the proper test equipment—as outlined in AOGCC Industry Guidance Bulletin 10-004—was rigged up on Redoubt Unit 1A prior to the test. The well performance was monitored for three hours. Observed gas rates at the end of three separate flow checks preceded by 1-hour pressure build up periods were less than the allowed 900 standard cubic feet per hour for a passing no-flow test. There was no liquid flow to surface during the no-flow test. Redoubt Unit 1 A may be produced without a subsurface safety valve. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Redoubt Unit 1 A demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no-flow test. Please retain a copy of this letter at the Osprey platfomr. Sincerely, James :. Regg (f Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM ION • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon LJ Plug Perforations U Fracture Stimulate H Pull TubingU H 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: Run Tubinq/ESP ❑✓ 2.Operator COOK INLET ENERGY,LLC 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development ❑✓ Exploratory ❑ 213-079 3.Address: 601 W 5TH AVE SUITE 310,ANCHORAGE,AK, Stratigraphic ❑ Service El 6.API Number: 99501 50-733-20497-01-00 7.Property Designation(Lease Number): k," 8.Well Name and Number: ADL 381203, 7-4002. REDOUBT UNIT#1A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A REDOUBT SHOAL,Undefined Oil 11.Present Well Condition Summary: Total Depth measured 15050 feet Plugs measured N/A RECEIVED true vertical 12502 feet Junk measured 14949' feet JUN 14 2017 Effective Depth measured 14953 feet Packer measured n/a feet true vertical 12426 feet true vertical n/a feet® C Casing Length Size MD TVD Burst �'2 Collapse Structural 200' 36" 200' 200' N/A N/A Conductor 1831' 13 3/8" 1831' 1803' 5020 psi 2260 psi Surface 6986' 9 5/8" 6986' 5988' 6870 psi 4760 psi Intermediate 5544' 7 5/8" 12246' 11616' 6890 psi 4790 psi Production Liner 8529' 5 1/2" 15038' 12493' 7740 psi 6390 psi Perforation depth Measured depth 14110-14872 feet SCANNED JUN True Vertical depth 11753-12362 feet Tubing(size,grade,measured and true vertical depth) 2-7/8"&3-1/2" L-80&L-80 13050'MD/6049'MD 10874'TVD/5236'TVD Packers and SSSV(type,measured and true vertical depth) No Packer No SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 318 88 55 27 310 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations CI Exploratory ❑ Development 2 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data El GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG El 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: 316-543/317-011 /317-052/317-156 Authorized Name: Stephen Ratcliff Contact Name:Stephen Ratcliff Authorized Title: Sr.Drilling Enineer Contact Email: sratcliff@glacieroil.com Authorized Signature: 5.....1.--CD----\\ Date: '113 I 1i Contact Phone: 907-433-3808 Form 10-404 Revised 4/2017Submit Original Only RBDMS `jr,ii 1 5 2017 • • • GLACIER RECEIVED JUN 14 2017 June 13th, 2017 Ms. Cathy Foerster, Chair AGC Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage,Alaska 99501 Re: Report of Sundry Cook Inlet Energy, LLC: RU-01A Permit to Drill NO:213-079 API No: 50-733-20497-01-00 Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a Report of Sundry Well Operations for RU-01A. The work performed was covered under Approved Sundries 316-537- rpulli.n the ESPcompletion_and v/ setting a temporary completion utilizing a packer and kill string. The continuation of work was covered under Approved Sundries 317-052 & 317-156 for perforating and running an ESP completion. If you have any questions, please contact me at (907)433-3808. Sincerely, Stephen Ratcliff Sr. Drilling Engineer Cook Inlet Energy, LLC (a Glacier Oil & Gas Corp. owned company) 601 W. 5th Avenue STE 310 Anchorage,AK 99501 10-404 • • GLACIER RU-01A Daily Operations Summary API: 50-733-20497-01-00 Permit #: 213-079 Rig: Osprey Rig 35 Date and Footage Drilled as of 24:00 hours. Activity 10 January 2017 Kill well with produced water. 11 January 2017 Finish killing well with produced water. 13 January 2017 Prep to skid rig. Install BPV, ND tree. 14 January 2017 NU BOPE. Pressure test BOPE to 250_2i low, 3500 psi high (Annular 250 psi low/2500 psi high). 15 January 2017 Continue testing BOPE. op() 16 January 2017 Continue testing BOPE. 17 January 2017 Continue testing BOPE. 18 January 2017 Finish testing BOPE. Pull BPV. MU landing joint, pull hanger and PU to release twin seal packer at 2023' MD—no good. Bullhead fluid down tubing, unable to circulate. Work pipe to release packer, bullhead fluid—release unsuccessful. 19 January 2017 Continue to work pipe to release packer—unsuccessful. RU Slickline and RIH with 2.34" gauge cutter to 315', POH, RD. RU Eline. 20 January 2017 RIH with 1 9/16" gun to 2170'. Perf tubing from 2007'-2008' and 2019'- 2020', 6spf. Tubing/annulus equalized. Work pipe to release packer— successful. Circulate 250 bbls. Packers dragging. Undress hanger, lay down landing joint. POH with completion. 21 January 2017 Continue POH with completion. 22 January 2017 Continue POH with completion. Disassemble ESP pump. MU 3.5" 9.3# L80 EUE shoe track and RIH with 3.5" 12.95#P110 PH6 tubing to 14901' MD.... Land hanger,test void to 5000 psi—good. 23 January 2017 ND BOPE. NU Dry hole tree. Prep to skid rig. Rig Release from RU-01A. Move for batch operations. • GLACIER 05 May 2017 Skid Rig over RU-01A. 06 May 2017 Circulate well with produced water.Set BPV. ND dry hole tree, NU BOPE. Test BOPE 250 psi low/3500 psi high (annular 250 psi low/2500 psi high). Test witnessed by AOGCC rep, Brian Bixby. 07 May 2017 Finish BOPE test. Pull BPV. Pull hanger and POH with 3-1/2" 12.95#PH6 tubing, observed tight spot at 13257', worked free. POH with tubing to 4828' MD. �{ 08 May 2017 Finish POH with 3-1/2" tubing and LD.TIH with 4" drill pipe. POH and LD 4" drill pipe. Prep to PU workstring. 09 May 2017 MU milling BHA and RIH on 2-7/8"workstring and 5"drill pipe.Tag at 13176' MD. Attempt to work string mill through tight spot—unable to pass. CBU and POH to 13070'. 10 May 2017 Finish POH. Redress string mill down to 4.600" and RIH. Work through tight spots as needed. CBU. RIH below perfs and circulate. 11 May 2017 POH to 14106', CBU,flow check—good. POH to 13428', pulled tight. Work/ream tight spot. POH to 10900',TIH to 13900'. CBU, pump 30 bbls hi- vis pill, and circulate. Flow check—good. POH and LD BHA. PU TCP Guns. 12 May 2017 Continue PU TCP Guns.TIH with TCP Guns on 2-7/8"workstring to 14786' (btm perfs)—14110' (top perfs). Set packer. RU Eline and verify RA marker placement. Shut annular and pressure up to 2000 psi. Guns fired at 1575 psi. Hold pressure on annulus and monitor. Unseat packer. Circulate, monitor losses. POH. 13 May 2017 Continue POH and LD 2-7/8 &5" workstring. LD spent TCP guns (no misfires). PU and RIH with 2-7/8" & 3-1/2"tubing. 14 May 2017 Continue PU and RIH with 3-1/2" tubing. POH and rack back tubing. LD 5" drill pipe. RU BOPE test equipment.Test BOPE 250 psi low/3500 psi high (annular 250 psi low/2500 psi high)—good.Test waived witnessed by AOGCC rep,Jim Regg. RU Eline. 15 May 2017 RIH with StimGun #1 (14113'—14122' MD)-misfire. POH and fix issue. RIH with StimGun#1 and correlate,fire, POH with spent guns. RIH with StimGun #2 (14126'—14141' MD) and correlate, fire—lost weight indicating guns dropped. POH and confirm 15'gun section pulled from rope socket. RIH with StimGun #3 (14187'—14199' MD) and correlate, fire, POH with spent guns. RIH with StimGun #4 (14206'—14216' MD) and correlate,fire, POH with spent guns. RIH with StimGun#5 (14216'—14226' MD) and correlate, fire— POH to find 10' StimGun had dropped. RD Eline and RU Slickline to fish. GLACIER 16 May 2017 RU Slickline. RIH with overshot and recover both StimGun fish. RD Slickline. RU Eline. RIH with StimGun#6 (14263'—14273' MD) and correlate,fire— POH with spent guns. RIH with StimGun#7 (14454'—14463' MD) and correlate,fire—POH with spent guns. RIH with StimGun#8 (14653'—14662' MD) and correlate,fire—POH with partial spent gun. 4.5' of StimGun left in hole. MU 4.65" GR and RIH to 13180'WLM—unable to pass, POH. MU 4.50" GR and RIH. 17 May 2017 Continue TIH with GR and tag 14825', POH. RD Eline. RU ESP Running equipment. MU ESP pump and motor assembly. c`' . 18 May 2017 TIH with ESP assembly on 2-7/8" 6.5# L80 EUE tubing to 7156' MD. Changeover to 3-1/2"tubing equipment. 19 May 2017 Continue running completion on 3-1/2" 9.3# L80 EUE tubing. Land tubing hanger at 13201' MD. ND BOPE. 20 May 2017 Continue ND BOPE. NU Tree and test. Release well to production. Prep to skid rig to RU-07B. • • RU-01A Current Wellbore Schematic Version: Current ID 6/7/2017 GLACIER i Tubing hanger-ACME 3.725"MCA top connection/ l 3 1/2"EUE trd btm connection-ID 2.950" 36" 150#A-36 200'MD ID-34.00" Welded 200'TVD I[ 17 1/2"Hole 1 ' 13 3/8" 68#L-80 1,831'MD ID-12.25" BTC 1,803'ND y Q Y+^ 3 1/2"9.3#L-80 EUE Tubing-ID 2.992" 11; F/6,000'MD to surface A ( XO-27/8"x31/2"-ID 2.441"@ 6,049'MD/5,236'TVD TOL @ 6,509'MD/5,605'TVD(9 5/8"x 5 1/2") 154 2 7/8"6.5#L-80 EUE Tubing-ID 2.441" @ 13,420'MD-6,000'MD/11,174'TVD-5,197'TVD TOL @ 6,702'MD/5,760'TVD(7 5/8"X 9 5/8") 9 5/8" 47#L-80 6,986'MD 12 1/4"Hole ID-8.50" BTC 5,988'TVD Dual 3/8"Stainless Flat Pack Lines P Window 7 5/8" 29.7#L-80 12,246'MD 8 1/2"Hole I ID-6.75" BTC 10,231'TVD , I. i'. !d L t. ... 7,i ESP Assembly Top @ 13,050'MD/10,874'TVD 1 #., ELECTRIC SUBMERSIBLE PUMP-151' 0., 1 I ,4 ESP#1 Flat Pack Cable Perforations(8 2017 Reperfs) • j Discharge Unit Assembly MD TVD ReperfType_ ,� h. Pump Assembly(3) 14,110'-14,113' 11,753'-11,756' TCP ' Intake/Gas Separator 14,113'-14,122' 11,756'-11,763' TCP/StimGun • "A i 4 Seal Assembly-Upper/Lower Seals 14,122'-14,126' 11,763'-11,766' TCP T g` Motor(2)/Motor Gauge Unit 14,126'-14,141' 11,766-11,778' TCP/StimGun • tZ Sensor 14,141'-14,154' 11,776-11,789' TCP Anode 14,171'-14,187' 11,803'-11,816' TCP ' Chemical Injection Check Valve 14,187'-14,199' 11,816-11,825' TCP/StimGun • 4'••14,199'-14,206' 11,825'-t 1,831' TCP 'kIP °C 14,206'-14,226' 11,831'•11,847' TCP/StimGun 14,226-14,230' fi 11,847'-11,851' TCP • A A . ESP Assembly Bottom @ 13,201'MD/10,994'TVD 14,261'-14,263' 11,876-11,877' TCP Sr; 14,266-14,273' 11,877'-11,885' TCP/StimGun • t',eIt .. 14,276-14,303' 11,886-11,909' TCP Tight spots(4.50"-4.60")in casing encountered @ 13171', 14,373'-14,454 11,964'-12,029' TCP 13257',and 13430'MD(2017 WO) 14,454'-14,463' 12,029'-12,036' TCP/StimGun • .i 14,466-14,570' 12,036'-12,122' TCP - 14,581-14,588' 12,131'-12,137' TCP 14,604'-14,653' 12,149'-12,188' TCP 14,653'-14,662' 12,188'-12,195' TCP/StimGun • m 14,662'-14,721' 12,195'-12,243' TCP ] ,• A' on 14,726'-14,746' 12,247'-12,263' TCP id 14,758'-14,786' 12,272'-12,294' TCP + MU 14,812'-14,836' 12,316-12,334' - • •. Fish-4'StimGun-no fishing neck OM 14,852'-14,872' 12,346-12,362' - e V " 5 1/2" _ 17#L-80 15,038'MD 6 3/4"Hole r f11 ID-4.767" Hydril 521 12,493'TVD PBTD:14953'MD/12426'TVD • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 1Z611 6/l 3/0 DATE: 06/12/17 P. I. Supervisor FROM: Adam Earl SUBJECT: No Flow Test Petroleum Inspector RU 1A PTD 2130790 Osprey Platform Glacier Oil & Gas June 11, 2017: I arrived at the heliport at 9am to meet Dan Clark, Glacier Oil & Gas (Cook Inlet Energy) production superintendent. There were 2 no-flow tests scheduled for today: RU 1A and RU 5B (separate report). We flew out to Osprey Platform where Operator Sully Sullivan met us and we walked down and went over the job set-up. The well's inner annulus (IA) and tubing were for both wells were connected to a manifold with separate, '/2-inch lines and isolations valves to enable RU 1A and RU 5B to be tested independently but at the same time. Test equipment also included a no-flow meter as well as a digital test pressure gauge. The following table shows test details for RU 1A: Time Pressures' Flow Rate2 Remarks (psi) Gas - scf/hr Liquid - gal/hr 10:25 0/0/5 none Well shut in - 10:55 1.3/1.3/5 - none Well shut in 11:25 1.6/1.6/5 90 none bleed through meter 11:55 1.7/1.9/5 • none Well shut in 12:25 1.9/2.2/5 150 none bleed through meter - 12:55 2/2.4/5 none Well shut in - 13:25 2.4/2.7/5 210 ✓ none Bleed through meter for 3min; 210 to 150 scf per hour 1 Pressures are T/IA/OA 2 No-Flow meter measured standard cubic feet per minute (SCFM); converted to SCF per hour The no-flow test of RU 1A went good and seemed to me to be a passing test. There was no fluid to surface. Calibration certificates and photos of test equipment were ./" provided by the operator— copies attached. Attachments: Calibration certificates (Crystal gauge; no-flow meter) • Photos (2) SCANNED JUL. ." ,t1 2017-0611_No-FlowRU-1 A_ae.docx Page 1 of 4 • • No Flow Test- Redoubt Unit 1A (PTD 2130790) Photos by AOGCC Inspector A. Earl 6/11/2017 o/zf Calibration Certificate Certificate Number.2016000338 400 'c Customer: Osprey IISCO LAB Mile 26.5 Kenai Spur HWY 300 Airport Way Niklskl,AK 99635,USA Konai,AK 991)11,USA 1(907)203 4230 PO Number 2601 Asset Number 1000610 SO Number 10A3578 DesaiptIon Technician Cody V iiianis Temperature 22.751 Manufacturer Crystal Pressure Humidity 15 Model Number XP2i WO Results Pass - Seiler Number 1500/7 Received In Toleranr'c Service Date Service Dale:11/22/2016 '' Duot)nlo 11/22/201/ Refewnce Standards used in this calibration are traceable to the National Institute of Standards and Technology of the United States(NIST)or other NMI. All calculations made using Fluke COMPASS Software for Full calculation mode This report may not be reproduced.except in full,unless pormissior for the publication of an approved abstract is obtained in writing from the organization issuing this report.. Description Service Dale Due Date Assoc Number P3100 Dead Weight Tester 7/21/2016 7/21/2017 1000434 Laboratory Enviroment Monitor 7212016 7/21/2017 1000435 m k � ' § r a 2 :k "s z xr° V-40: 2017-0611_No-Flow_RU-1 A_ae.docx Page 2 of 4 • • S KING INSTRUMENT COMPANY 12700 Pala Drive,Garden Grove,CA 92841 TEL#(714)891-0008 FAX#(714)891-0023 CALIBRATION CERTIFICATE CERT. NO. 593311607 Submitted for calibration by: SAVANT ALASKA LLC FLOWMETER SPECIFICATIONS Manufacturer: BROOKS INSTRUMENT Type: Variable Area(Rotameter) Model#: MT3810A13A1 RAAS1 Float Material : N/A Serial#: 0111060466126001 Float Type : N/A Tag#: N/A CALIBRATION INFORMATION Calibration Date : 18-Jul-16 ✓ Calibration Fluid : Air Recalibration Date : 18-Jul-17 Calibration Fluid Sp.Gr. : 1.0 Rated Accuracy(%F. .) : +1-5% Calibration Fluid Viscosity: 0.01812 cP Pass I Fail: ' Passed Calibration Fluid Temp. : 70°F Signature: _ Calibration Fluid Pressure: 14.7 PSIA ' •.• • able, Lab Tech Indicated Flowrate-Scfm GAS-Dens.21.p0s6IMW-125°F MW-125°F& As Found/As Left 5 PSIG 25.00 24.12582 20.00 19.40280 16.00 15.30096 10.00 9.54031 • 2.50 2.35701 Calibration Equipment Id: KICSYSSV01 Rocallbratlon Date: 20-Jan-2017 Calibration Procedure: ISA:RP 16.6 Approved BY: C4,/ i,(t '°. King Instrument Company calibration services comply with MIL-STD 45662A an ANSI ► L Z540-1=1994 and ; traceable to the National Institute of Standards and Technology. The collective uncertainty of the equipment used in this calibration does not exceed 25%of the certified instrument under test Any reproduction or representation of this data exce• in full tpot incl ._ : compliance with the above mentioned sta •- Form F851 Rev.A , 2017-0611_No-FlowRU-1 A_ae.docx Page 3 of 4 � . • • d 0 i..)-4 .4 — _ .E N •0 i1 . 0 Q x 1 9 ill A'4,:: ',. CT a) 2 o I. 40 vp „, „L, 0 CD 11. .:=3 ' - er)i„„ c•-, . = CD i U../ III ..'. +`.:, up C. ' i i '3-4 Hca.. a) " I. d' w .1) iF. er ♦ y U ct ' ',/,/ 11. / � � dl o o 7 TS m Z °� 31v o W bb z4. ts- O 3 � N o cu ami N co co a i = 1 ,'. - ''''.. - I:- :i._._./ , 1. o • cd • '..,• -5. g L N U o 11 i -`-,t1 15 g, %,OF � • • ‘,41°-,\ I//77,s, • THE STATE Alaska Oil and Gas of® LA S KA Conservation Commission 333 West Seventh Avenue . GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 O . , � ? Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Stephen Ratcliff Sr. Drilling Engineer 4,041"4. 1V. ik e `� Cook Inlet Energy, LLC 601 W. 5th Ave., Ste. 310 Anchorage,AK 99501 Re: Redoubt Shoal Field, Undefined Oil Pool, RU 1 A Permit to Drill Number: 213-079 Sundry Number: 317-156 Dear Mr. Ratcliff: 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, Daniel T. Seamount, Jr. Commissioner DATED thi day of April, 2017. RDDIJ1S LL- MAY - 3 2017 0 I RECEIVED STATE OF ALASKA APR 1 8 ?017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate Q ' Other Stimulate ❑ Pull Tubing 0 /change Approved Program Q Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Run ESP, n 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: COOK INLET ENERGY,LLC Exploratory ❑ Development 11 213-079 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 601 W 5TH AVE SUITE 310,ANCHORAGE,AK,99501 50-733-20497-01-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? ' 20 AAC 25.055 Will planned perforations require a spacing exception? Yes ❑ No 2 1 REDOUBT UNIT#1A 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 381203,ADL 378114 • REDOUBT SHOAL, UNDEFINED OIL• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): ✓ Plugs(MD): Junk(MD): 15,050' • 12,502' , 14,953', 12,426' 2799 NONE NONE Casing Length Size MD TVD Burst Collapse Structural 200' 36" 200' 200' -- -- Conductor 1831' 13 3/8" 1831' 1803' 5020 PSI 2260 PSI Surface 6986' 9 5/8" 6986' 5988' 6870 PSI 4760 PSI Intermediate 5544' 7 5/8" 12246' 11616' 6890 PSI 4790 PSI Production __ __ Liner 8529' 5 1/2" 15038' 12493' 7740 PSI 6390 PSI Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 14110'-14872' r 11753'-12362' 3 1/2"12.95# P110 14901'MD Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): None None 12.Attachments: Proposal Summary Q Wellbore schematic Q X13.Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development❑✓ ti Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 1-May-17 Commencing Operations: OIL ❑✓ ' WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ 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. Authorized Name: Stephen Ratcliff Contact Name: Stephen Ratcliff Authorized Title: Sr.Drilling Engineer Contact Email: sratcliff@glacieroil.com Contact Phone: 907-433-3808 Authorized Signature: \\ Date: 4/18/2017 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 ❑ 4A5C.$T L 1_ 1l.4 Other: k J 5 CO /05-L 6 c.r /...- - f' O._ ( ' /t_-S F-- ,,,,i t-t-0-..... . ctid- -3 07 13-- . Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: r j) —y OL( r - 3 20'7 RE3D8S P,P4 }iI APPROVED BY , Approved by' / COMMISSIONER THE COMMISSION Date: 25 /(7 & " /F!/17 `�( r �,(��L( 2' —/7 Submit Form and c � � Form 10-403 Revised 4/2017 p r d *Land valid for 12 months fror the date of approval. Attachments in Duplicate • • RECEIVED GLACIER APR l Zii April 18th, 2017 AOGCC Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry: RU-01A— Application to Pull Completion Cook Inlet Energy: 50-733-20497-01-00, PTD: 213-079 Dear Ms. Foerster, Cook Inlet Energy, LLC, hereby submits an Application for Sundry to Change the Approved Program as described in Sundry 317-052, for Redoubt Unit 01A, PTD: 213-079, requesting to reperforate with TCP guns and possibly Stim Guns prior to running the ESP completion./ It is also requested that a no flow test be performed to omit the vent valve, production packer, and sub-surface safety valve from the completion. An extension of 30 days is requested in place of the 5-day production limit prior to executing the test as well. to ��, � 1) rezt �" If you have any questions, please contact me at 907.433.3808. m_2-'1_/7 Sincerely, Stephen Ratcliff Sr. Drilling& Completions Engineer Cook Inlet Energy, LLC (a Glacier Oil & Gas wholly owned company) 601 W. 5th Avenue STE 310 Anchorage, AK 99501 1 • I GLACIER 1. WELL NAME— RU-01A Requirements of 20 AAC 25.005(f) Well Summary Current Status: The well is currently shut-in and has 3-1/2" tubing set at 14901' MD. Scope of Work: • Rig up Rig 35 & NU BOPE • Pull tubing. • RIH with TCP guns and re-perforate. • RIH with StimGuns and re-perforate. • RIH with ESP Completion. • N/D BOPE. • Turn well over to production. General Well Information: Reservoir Pressure/TVD: 0.32 psi/ft 4,000 psi @ 14,872' MD (12,362' TVD) MASP: Reservoir Pressure—(Gas Gradient X TVD) (0.32 psi/ft X 12,362' TVD) — (0.1 psi/ft X 12,362') = 3,955 psi — 1236 psi = 2,799 psi Wellhead Type/Pressure Rating: 13 5/8" 5M Wellhead - 3 1/2" 5M tree BOPE: 13 5/8" 10M —Pipe Rams/ Blind Rams/Annular Well Type: Oil Well Estimated Start Date: May 1, 2017 Waivers Requested: No flow Test to omit vent valve, production packer and SSSV. Extension for production limit from 5-days to 30-days. CIE Drilling Manager CIE Sr. Drilling Engineer CIE Production Manager Conrad Perry Stephen Ratcliff David Kumar (907) 727-7404 (907) 433-3808 (907) 433-3822 cperry@glacieroil.com sratcliff@glacieroil.com dkumar@glacieroil.com 2 • • GLACIER Program Rig Workover (i 01' 3 General Note: Prior to this work, the 3-1/2" 12.95# P110 frac string was RIH and set at 14901' MD. V General Note: Full opening Safety Valve will be on rig floor at all times with appropriate crossovers for all pipe being run below rotary table. 1. Move rig onto RU-01A. 2. Confirm that back pressure valve is installed in wellhead. 3. Notify AOGCC 48 hours in advance of start of operations and upcoming BOP test. 4. N/D Dry Hole Tree. 5. N/U and Test 13 5/8" BOPE with 2 7/8" x 5" VBR rams with blinds in middle. 6. Test BOPE on 2 7/8" and 31/2" to 250 psi low/3500 psi high and chart. ^- 7. Remove back pressure valve. 8. P/U Landing Joint and make up to 3-1/2" Tubing Hanger. Clr`' e P 9. Back out Lock Down screws in Tubing Hanger. K� 10. Pull & L/D 3-1/2" Landing Joint and Tubing Hanger. 11. Check for Flow and confirm well is dead. 12. POH and L/D 3-1/2"tubing. 13. PU TCP guns (6 spf, 60 deg phase). 14. RIH and perforate new intervals and reperforate existing perforations. o Observe and report pressure increase, if any, after each interval is perforated. o Confirm final intervals with GLA Engineer prior to RIH. Proposed Intervals to Perforate and Reperforate: New Reperf PERF INTERVAL PERF INTERVAL Interval Interval (MD FT) (TVD FT) X 14110'—14154' 11753'—11789' X 14171'—14230' 11803'—11851' X 14261'—14303' 11876'—11909' X 14373'—14570' 11964'—12122' X 14581'—14588' 12131'—12137' X 14604'- 14610' 12149'—12154' X 14610'—14721' 12154'—12243' X 14726'—14746' 12247'—12263 X 14758'—14786' 12272'—12294' 3 • • GLACIER 15. POH and LD TCP guns. 16. RU Eline. 17. PU and MU Stim Guns. o Confirm intervals with GLA Engineer prior to RIH. 18. RIH and reperf with StimGuns across perforation intervals. o Final intervals will be confirmed prior to RIH. 19. RD Eline. 20. Prep to pick up ESP Completion equipment, spoolers, and tools. 21. Rig up Summit for ESP Completions. o Hold PJSM for ESP Run. o Test and confirm that all equipment is on location and ready to RIH. o NOTE: COMPLETION ESP/TUBING WILL NOT BE ROTATED. 22. Pick up the ESP completion assembly as directed. o NOTE: Setting depth of ESP BHA at 13,550' MD (Confirm with GLA Engineer prior to RIH). o Pump should be set in less than 1 degree/100' dogleg. (Top of Pump Assy tentatively set for+/- 13,425' MD). o NOTE: the 3/8" flat pack chemical injection line is to be run to the anode on the bottom of the ESP assembly. o 3/8" Nova Valves to be installed at top of pump assembly. 23. RIH with ESP completion on 3-1/2" 9.3# L80 EUE & 2-7/8" 6.5# L80 EUE tubing. o Test cable every 1000'. o Crossover from 3-1/2" to 2-7/8" tubing at +/- 6,000'. 24. Monitor trip tank for proper hole filling. Splice cable as needed. At TD, confirm pipe tally, MU landing joint and set string in slips. 25. Dress hanger and control lines. Land hanger, run in screws, test hanger to 5000 psi. 26. Observe well dead. Lay down landing joint and install BPV. 27. Nipple down riser and BOPE. 28. Install and test production tree to 5,000 psi. Turn over well to production. 29. Release Rig. 4 • RU-01A Proposed Wellbore Schematic Version: Planned • 4/18/2017 _I Tubing hanger-ACME 3.725"MCA top connection/ GLACIER 31/2"EUE 8rd btm connection-ID 2.950" 36" 150#A-36 200'MD ID-34.00" Welded 200'TVD r, II, v- /'osii s:.18 1/2"Hole 13 3/8" 68#L-80 1,831'MD ID-12.25" BTC 1,803'TVD t 4 31/2"9.3#L-80 EUE Tubing-ID 2.992" "" F/6,000'MD to surface 4 -+ XO-27/8"x31/2"-ID 2.441"@6,000'MD/5,197'TVD TOL @ 6,509'MD/5,605'ND(9 5/8"x 5 1/2") r„, 2 7/8"6.5#L-80 EUE Tubing-ID 2.441" @ 13,420'MD-6,000'MD/11,174'TVD-5,197'TVD TOL @ 6,702'MD/6,803'ND(7 5/8"X 9 5/8") ■ ,:- 9 5/8" 47#L-80 6,986'MD 121/4"Hole IS. ID-8.50" BTC 5,988'TVD Dual 3/8"Stainless Flat Pack Lines 7 5/8" 29.74 L-80 12,246'MD 8 1/2"Hole ID-6.75" BTC 10,231'ND /� ESP Assembly Top @ 13,425'MD/11,174'TVD t` c✓/"'�/�'_/ g ELECTRIC SUBMERSIBLE PUMP-200' ESP#1 Flat Pack Cable /_La Discharge Unit Assembly C. l�`'p r R i Pump Assembly(3) 4, ci '' s Intake/Gas Separator !/ Seal Assembly-Upper/Lower Seals Motor(2)/Motor Gauge Unit l l Sensor / Anode 1 r Chemical Injection Check Valve r ' 1 ESP Assembly Bottom @ 13,550'MD/11,281'TVD New Perforations&Reperfs .. MD TVD Feet _ 14,115-14,154' 11,753'-11,789' 48 reperf 14,171'-14,230' 11,803'-11,851' 59 reperf _ 14,261'-14,303' 11,876'-11,909' 42 reperf c 14,373%14,570' 11,964%12,122' 197 reperf_ = 14,581-14,588' 12,131'-12,137' 7 reperf 1 IE 14,604'-14,610' 12145-12154' new Mal C 14,610'-14,721' 12,154'-12,243' 111 reperf ii IC 14,725-14,746' 12,247'-12,263' 20 rept 14,755-14,786' 12,272'-12,294' 38 reperf - c 14,812'-14,836' 12,315-12,334' 24 1 14,852'-14,872' 12,346'-12,362' 60 w Total Perforations 612 al c 5 1/2" 179 L-80 15,038'MD 6 3/4"Hole ID-4.767" Hydril 521 12,493'ND 4111 S RU-01A-Current Wellbore Schematic Date: 30-Jan-17 Version: 1.0 Tubing hanger-ACME 3.725"MCA top connection/ [:1 GLACIER 3 1/2"12.95#P-110 PH6 btm connection 36" 150#A-36 200'MD ID-34.00" Welded 200'TVD r 18 1/2"Hole + 13 318" 68#L-80 1,831'MD ID-12.25" BTC 1,803'TVD 4 , I, 3 1/2"12.95#P-110 PH6 Tubing-ID 2.625"@ 14,901'MD TOL @ 6,509'MD/5,605'TVD(9 5/8"x 5 1/2") TOL @ 6,702'MD/6,803'TVD(7 5/8"X 9 5/8") 9 5/8" _ 47#L-80 6,986'MD 12 1/4"Hole ID-8.50" BTC 5,988'TVD 7 5/8" 29.7#L-80 12,246'MD 8 1/2"Hole ID-6.75" BTC 10,231'TVD TOC(2013 CBL)@ 12,900'MD e " e 3 Current Perforations - I MD TVD Feet Ca G V!!! 14,116-14,154' 11,753'-11,789' 48 14,171-14,230' 11,803'-11,851' 59 dC 14,261-14,303' 11,876'-11,909' 42 Q fGa 14,373'-14,570'-11,964'-12,122' 197 14,581-14,588' 12,131'-12,137' 7 C7t p 14,616-14,721' 12,154'-12,243' 111 Q o 14,726-14,746' 12,247'-12,263' 20 E 14,756-14,786' 12,272'-12,294' 38 Q C 14,812'-14,836' 12,315'-12,334' 24 Dr C 14,852'-14,872'12,346'-12,362' 60 Total Perforations 606 mor 5 1/2" 17#L-80 15,038'MD 6 314"Hole ID-4.767" Hydril 521 12,493'TVD • STATE OF ALASKAII RECEIVEDMAR 3 0 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS �� 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑✓ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate 0 Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Pe it to Drill Number: COOK INLET ENERGY,LLC Exploratory ❑ Development 213-079 3.Address: Stratigraphic ❑ Service ❑ API Number: 601 W 5TH AVE SUITE 310,ANCHORAGE,AK,99501 50-733-20497-01-00 7.If perforating: -t),413 8. ell Name and Number: What Regulation or Conservation Order governs well spacing in this pool? cn... a 20 AAC 25.055 Will planned perforations require a spacing exception? Yes2 No REDOUBT UNIT#1A 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 381203,ADL 378114 • RE P•UBT SHOAL,Undefined Oil 11. PRESENT WELL CONDITION SUMMAR Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MP- • i): 12100 psi Plugs(MD): Junk(MD): 15,050'. 12,502' ` 14,953' • 12,426'• 'Iodeled 8167 psi) NONE NONE Casing Length Size MD TVD Burst Collapse Structural 200' 36" 200' P 200' Conductor 1831' 13 3/8" 1831' 1803' 5020 PSI 2260 PSI Surface 6986' 9 5/8" 6986' 5988' 6870 PSI 4760 PSI Intermediate 5544' 7 5/8" 1224: 11616' 6890 PSI 4790 PSI Production -- -- - -- -- -- Liner 8529' 5 1/2" 1`4]!''� i 12493' 7740 PSI 6390 PSI Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 14110'-14872' i 11753'-12362' 3 1/2" 2 -• \ P110 14901'MD Packers and SSSV Type: N/A �' hacker nd SSSV MD(ft)and TVD(ft): N/A 12.Attachments: Proposal Summary U Wellbore schem-;c ✓ ell Class after proposed work: Detailed Operations Program Q BOP Sketch 0 8 Exploratory ❑ Stratigraphic❑ Development❑✓ ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 20-Ap 1 OIL 2 • WINJ El WDSPL ❑ Suspended CICommencing Operations: 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the . •.-dure approved herein will not be deviated from without prior written ap'royal. Contact Stephen Ratcliff Email sratcliff@glacieroil.com Printed Name Title Stephen Ratcliff Sr.Drilling Engineer Signature Phone Date —\. 907-433-3808 3/30/2017 COMMISSION USE ONLY Conditions of approval: Notify Commission s. that a representative may witness Sundry Number: 311- \32 Plug Integrity ❑ BOP Te ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: SCANNED MAY 0 2011: RBDNIS LL 'nY - 12017 Post Initial Injection MIT Req'd? es ❑ No Spacing Exception Required? es ❑ No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Submit Form and 0RL Form 10-403 Revised 11/2015 I�ip''.JtA valid for 12 mont from the date of approval. Attachments in Duplicate �w +/+/z,,7if (24/ • • GLACIER March 30th, 2017 RECEIVED MAR 302017 Ms. Cathy Foerster, Chair G�� Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage,Alaska 99501 RE: Sundry Application for Hydraulic Fracturing Cook Inlet Energy, LLC: RU-01A Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a Sundry Request to perform a hydraulic fracture for RU-01A, located on ADL 381203 and 378114 (TD), in the Redoubt Unit. Please find attached for review of the Commission the 10-403 Form,Hydraulic Frac Procedures, Post Frac Clean Up Program, Fracture Parameters, Geological Information, and Proposed Well Schematics, as required by 20 AAC 25.005, 20 AAC 25.280, and 20 AAC 25.283. Additional information includes MASP Calculations, Frac Layout,and Surface Equipment Diagrams. Rig 35, on the Osprey Platform,will be used to complete this work,commencing approximately May 15th, 2017. If you have any questions,please contact me at(907) 433-3808. Sincerely, ') Stephen Ratcliff Senior Drilling Engineer Cook Inlet Energy(a Glacier Oil &Gas owned company) 601 W. 5th Avenue, Suite 310 Anchorage,AK 99501 Stephen.Ratcliff@CookInlet.net 0: 907.433.3808 C: 907.433.9738 F: 907.334.6735 1 • GLACIER Well To Hydraulically Fracture - RU-01A Requirements of 20 AAC 25.283(a) Well Summary Current Status: RU-01A Well is currently shut-in with the ESP completion pulled and the 3-1/2" frac string run in the well. Scope of Work: • Cement frac string- approved under Sundry 316-543. • Mobilize and rig up for 5 stage hydraulic fracturing operation. • Rig up and Test all surface equipment and frac string to 110% of Max Surface Treating Pressure. • Perf first stage. • Complete Data Frac to confirm breakdown. • Pump +/- 60,000 # frac in first stage. • Continue Hydraulic Fracturing Operation for remaining stages. • RU Coil Tubing Unit and clean out equipment. • Clean out well with CTU. • Run Completion Equipment, per Program - Completion Sundry to follow. • Turn well over to Production. General Well Information: Reservoir Pressure MD/TVD: 5,281 psi @ 14,664' MD / 12,197'TVD MASTP: 12,100 psi (modelled: 8,951 psi) Wellhead Type/Pressure Rating: Vetco Grey- 5M -Wellhead Assembly Vecto Grey- 15M - 4-1/16" Frac Tree BOP Configuration: Coil BOP during CTU operations. Well Type: Producer Estimated Start Date: May 15th, 2017 GLA Drilling Manager GLA Sr. Drilling Engineer GLA Production Manager Conrad Perry Stephen Ratcliff David Kumar (907) 727-7404 (907) 433-3808 (907) 433-3822 cperry@glacieroil.com sratcliff@glacieroil.com dkumar@glacieroil.com 2 GLACIER 1. Notice of Operations Requirements of 20 AAC 25.283(a)(1) An affidavit stating that all owners, landowners, surface owners, and operators within a one- half mile radius of the current/proposed wellbore trajectory have been provided with a notice of operations. (A) Upon request, a complete copy of the application is available. (B) Operator Contact Information is on file with the AOGCC. 2. Location Summary Requirements of 20 AAC25.283(a)(2) (A) Well Location • General Location Kenai Peninsula Borough,Alaska • Osprey Platform Center Leg 3 - Slot#19 • Sea Bottom Elevation 45' to Mudline • RKB 89' above MSL X-Coordinate Y-Coordinate il FNL/FSL FWL/FEL Sec/T/R Surface Location 200626.556' 2449941.112' 1918'FSL 315'FEL 14/7N/14W Bottom Hole Location 207093.64' 2440304.46' 352'FSL ; 2139'FWL 18/7N/13W (B) Water Wells located within a one-half mile radius of the well's surface location: X-Coordinate Y-Coordinate FNL/FSL FEL/FWL Sec/T/R Not Applicable (C) Offset Wells within a one-half mile radius of the wellbore fracturing interval: Surface Surface I Surface Well TD Well TD Well TD FNL/FSL FWL/FEL BHSec/T/R FNL/FSL FWL/FEL BH Sec/T/R RU-01 1918'FSL 315'FEL 14/7N/14W 77'FSL 2240'FEL 24/7N/14W RU-02A 1819'FSL 320'FEL 14/7N/14W 2450'FSL 1780'FEL 19/7N/13W RU-06 1909'FSL 318'FEL 14/7N/14W 1137'FNL 1518'FEL 19/7N/13W RU-07 1967'FSL 223'FEL 14/7N/14W 2037'FNL 2024'FEL 19/7N/13W RU-07B 1967'FSL 223'FEL 14/7N/14W 1323'FNL 2218'FEL 19/7N/13W Redoubt Bay Unit 1 1598'FNL 3390'FWL 13/7N/14W 3546'FNL 2740'FWL 18/7N/13W Redoubt Shoal ST 1 701'FSL 1628'FWL 13/7N/14W 861'FNL 904'FWL 19/7N/13W Redoubt Shoal Unit 701'FSL 1628'FWL 13/7N/14W 866'FNL 2192'FWL 19/7N/13W No.2 RU-02A and RU-07B are producers. RU-06 is a water injector. RU-01, RU-07, Redoubt Bay Unit 1, Redoubt Shoal ST1 and Redoubt Shoal Unit No 2 are abandoned. See Attachment 1: Plat/As-Staked Design See Attachment 2: Equipment Layout 3 GLACIER 3. Identification of Freshwater Aquifers Requirements of 20 AAC 25.283(a)(3) Identification of any freshwater aquifer,within a one-half mile radius of the wellbore trajectory: Geological Name of Freshwater Aquifer: Not Applicable Measured Depth of Freshwater Aquifer: Not Applicable True Vertical Depth of Freshwater Aquifer: Not Applicable There are no freshwater aquifers within a one-half mile radius of the proposed wellbore trajectory. 4. Water Sampling Baseline Plan Requirements of 20 AAC 25.283(a)(4) Water sampling and collection of baseline water data is needed before fracturing for all water wells within a one-half mile radius of the proposed wellbore. Water Sampling Plan - Not Applicable 5. Casing and Cementing Information Requirements of 20 AAC 25.283(a)(5) RU-01A Size Wt Grade Top Bottom Burst Collapse Drive Pipe 36" 0 200' Surface Casing 13 3/8" 68# L80 0 1831' 5020 psi 2260 psi Intermediate Casing 9 5/8" 47# L80 0 6986' 6870 psi 4760 psi Liner 7 5/8" 29.7# L80 6702' 12246' 6890 psi 4790 psi (window) Production Liner 5 1/z" 17# L80 6509' 15038' 7740 psi 6390 psi • Surface casing was set at 1831' MD and cemented through an inner string and pumped 322 bbls of 12.5 ppg Class G lead and 157 bbls of 15.8 ppg Class G tail cement. Cement was displaced with 29.7 bbls of water based mud. Cement returns at surface at 295 bbls pumped. • Intermediate casing was set at 6986' MD and cemented with 33 bbls of 12.5 ppg Class G lead cement and 47 bbls of 15.8 ppg Class G tail cement. Cement was displaced with 503 bbls mud,with full returns throughout. Plug did not bump, floats held. The casing was tested to 3000 psi. • The 7 5/8" liner was set from 6712' - 13990' MD. It was cemented with 65 bbls of cement. The liner top packer and 9-5/8" casing was tested to 4000 psi. 4 i S GLACIER • During sidetrack RU-01A-A window was milled in the 7 5/8" liner from 12261' - 12270' MD. A 5 1/2" liner was set from 6509' - 15038' MD and cemented with 65 bbls of 15.8 ppg Class G cement, displaced with 262 bbls of OBM. Full returns and reciprocation throughout cementing and plug bumped.A CBL showed TOC at 12830' MD. See Attachment 3: Frac String Cement Program The 3-1/2" Frac String will be cemented in place. The operation is described in Approved Sundry 316-543. A CBL will be provided once available. 6. Casing and Cementing Assessment Requirements of 20 AAC 25.283(a)(6) An assessment of each casing and cementing operation has been performed with supporting information, including cement evaluation logs and the following has been determined: (A) Casing is cemented: (i) Below the base of the lowest freshwater aquifer. (ii) In accordance with 20 AAC 25.030 (B) Hydrocarbon zones penetrated by the wellbore are isolated. A Cement Bond Log for the 3-1/2" frac string will be submitted to the state by the GLA Engineer upon running the log. Cement Bond Logs are on file with the AOGCC for RU-01, RU-01A, RU-02A, RU-06, RU-07B, and all logs have been evaluated and determined that there is no expectation of no cement or poor cement in the zones that are within the half mile radius. See CBL's on file if further analysis is needed. • RU-01 original wellbore set the 5 1/2" liner from 13741' - 15323' MD and cemented with 90 bbls of cement and displaced with 186 bbls of mud. Liner was rotated during cement job. Plug was bumped. Unable to set hanger and safety released. Cement was tagged at 14435' and drilled out. Casing was tested to 4000 psi. In preparation for the RU-01A sidetrack, a 7-5/8" cement retainer was set at 12505' MD. Unable to squeeze into the perfs, spotted 9 bbls (200') of 15.8 ppg of Class G cement on top of retainer. Tested plug, 7-5/8" csg&9-5/8"casing to 1500 psi.A CIBP was unintentionally set at 12383' MD and a second CIBP was set at 12310' MD for the whipstock. 7. Pressure Test Information Requirements of 20 AAC 25.283(a)(7) The wellbore and frac string will be pressure tested as follows: 5 • GLACIER Surface Equipment and Pumps: 12,100 psi Frac String: 12,100 psi Frac Zone Wellbore: 12,100 psi Annular Pressure Held: 2,000 psi Inner Annulus Pop-Off: 2,500 psi 8. Pressure Ratings and Schematics Requirements of 20 AAC 25.283(a)(8) Wellbore: 15,000 psi Frac String: 15,000 psi Wellhead: 5,000 psi (Isolated) Frac Tree: 15,000 psi Surface Equipment: 15,000 psi See Attachment 5: Frac String Schematic See Attachment 6: Proposed Wellbore Completion Schematic See Attachment 7: Wellhead Schematic See Attachment 8: Frac Tree Schematic 9. Fracturing and Confining Zone Data Requirements of 20 AAC 25.283(a)(9) (A) Lithological Description of Zone: Conglomeratic Sandstone (B) Geological Name of Zone: Hemlock Total Number of Stages 5 (C) Depth of Zone: Zone 1 Zone 1 - Measured Depth 14,654' - 14,664' Zone 1 - True Vertical Depth 12,189' - 12,197' Zone 2 Zone 2 - Measured Depth 14,540' - 14,550' Zone 2 - True Vertical Depth 12,098' - 12,106' Zone 3 Zone 3 - Measured Depth 14,440' - 14,450' Zone 3 -True Vertical Depth 12,018' - 12,026' Zone 4 Zone 4 - Measured Depth 14,210' - 14,220' Zone 4 - True Vertical Depth 11,835' - 11,843' Zone 5 Zone 5 - Measured Depth 14,132' - 14,142' Zone 5 - True Vertical Depth 11,771' - 11,779' 6 S • GLACIER (D) Thickness of Zone: Zone 1 Zone 1 - Measured Depth 10' Zone 1 - True Vertical Depth 8' Zone 2 Zone 2 - Measured Depth 10' Zone 2 - True Vertical Depth 8' Zone 3 Zone 3 - Measured Depth 10' Zone 3 - True Vertical Depth 8' Zone 4 Zone 4 - Measured Depth 10' Zone 4 - True Vertical Depth 8' Zone 5 Zone 5 - Measured Depth 10' Zone 5 - True Vertical Depth 8' (E) Estimated Fracture Pressure 9,500 psi 10. Offset Well Report Requirements of 20 AAC 25.283(a)(10) Within a one-half mile radius of the wellbore trajectory, a report on the mechanical condition of each offset well that will transect the confining zone has been evaluated. The offset wells within a one-half mile radius, RU-01, RU-02A, RU-06, RU-07, RU-07B, will not interfere with containment of the hydraulic fracturing fluid of the proposed wellbore trajectory. See section 2 (C) above for location and orientation of offset wells. It has been analyzed and determined that there will not be communication between the frac interval on the RU-01A wellbore and the offset wells. • RU-02A-A window was milled in the 9 5/8" casing from 8517' - 8540' MD.A 7" liner was set from 8147' - 15360' MD and cemented with 93.6 bbls of 13.5 ppg Class G cement. Plug bumped and floats held. Set liner top packer and tested annulus to 2500 psi.A CBL showed TOC at 13050' MD. This well is currently on production. • RU-06 - The 13-3/8" surface casing was set at 3840' MD and cemented with 572 bbls of 12.5 ppg lead cement and 171 bbls of 15.2 ppg tail cement. Full returns through cement job and plug was bumped. ES cementer was opened and cement was pumped, plug bumped. Casing was tested to 3000 psi. The 9-5/8" intermediate casing was set at 15085' MD and cemented with a total of 229 bbls of cement and plug bumped. Casing was tested to 3000 psi. The 7-5/8" liner was set from 14779' - 16100' MD and cemented with 97.5 bbls of 15.7 ppg cement while reciprocating. Displaced with OBM and plug did not bump. Liner was tested to 3000 psi. A USIT confirms varying cement quality along the liner. This well is currently being utilized for water injection. • RU-07 - The 13-3/8" surface casing was set at 3528' MD and cemented with1750 sx of 12.5 ppg lead cement and 950 sx of 15.8 ppg tail cement. The casing was tested above 7 • . GLACIER the float collar to 3000 psi. The 9-5/8" intermediate casing was set at X' MD and cemented with 450 sx of 12.5 ppg Class G lead cement and 300 sx of 15.0 ppg Class G tail cement, plug did not bump. The casing was tested to 3000 psi.A 7" liner was set from 13708' - 15950' MD and cemented with 210 bbls of 15.8 ppg Class G cement, plug bumped. Tested casing/liner to 3000 psi.A CBL identified TOC at 14100' MD (dated 12/18/03). In preparation for a sidetrack, a CBL confirmed cement from 11860' - 13708' MD (top of 7" liner). A 7" cement retainer was set at 15050' MD and 46 bbls of 15.8 ppg Class G cement was left on top. Cement/Casing was tested to 1500 psi. TOC was tagged at 13786' MD. A bridge plug was set at 12618' MD for the whipstock. • RU-07B-A window was milled in the 9-5/8" casing from 12539' - 12553' MD.A 41/2" liner was set from 12356' - 14849' MD and cemented with 105.8 bbls of 15.3 ppg Class G cement.A CBL shows cement from 14540' to the top of the liner hanger at 12356' MD. This well is currently producing. • Redoubt Bay Unit 1 - The 30" casing was set at 233' MD. The 20" casing was set at 874' MD and cemented with 1000 sx of Class G cement. Casing was tested to 500 psi. The 13-3/8" surface casing was set at 3519' MD and cemented with 1714 sx of Class G lead cement and 224 sx of Class G tail cement. Plug bumped and float held. Good cement returns to surface. Casing tested to 2500 psi. The 9-5/8" casing was set at 12186' MD and cemented with 1500 sx of Class G cement. Plug bumped and floats held. The casing was tested to 5000 psi.A 7" liner was set from 11795' - 13840' MD and cemented with 1000 sx of Class G cement, bumped plug. Tested 9-5/8" casing and liner lap to 3000 psi. The well was P&A'd with a 7" cement retainer set at 13455',with 150 sx Class G cement squeezed below. Set a 7" cement retainer at 11945',with 50 cuft squeezed below and 300' of cement left on top. A 9-5/8" cement retainer was set at 3505' MD with 250 sx of cement squeezed below and 50 sx left on top.A bridge plug was set at 920'with 420 ft of cement left on top. The wellhead was cut 20' below mudline. Due to the age of this well (1976), there isn't record of a CBL/USIT being used. • Redoubt Shoal ST 1 - The 20" casing was set at 636' MD and cemented with 1000 sx of cement. The 13-3/8" surface casing was set at 2037' MD and cemented with 1800 sx of cement. The 9-5/8" casing was set at 10943' MD and cemented with 900 sx of cement. The 7" liner was set from 10615' - 13741' MD and cemented with 640 sx of cement.A cement retainer was set at 13710' MD with 150 sx of cement spotted on top. A 100 sx cement plug was spotted from 10480' - 10900' MD.A retainer was set at 1806' MD.Additionally, 100 sx of cement was placed from 225' - 500' MD. The well was suspended and capped at the mudline. • Redoubt Shoal Unit No 2 -A window was milled in the 9-5/8" casing from 8900' - 8946' MD.A 7" liner was set from 8688' - 13001' and cemented with 480 sx of cement. A 5" liner was set from 12712' - 14057' MD and cemented with 140 sx of cement.A 5" bridge plug was set at 13106'with 25 sx spotted on top.A 7" bridge plug was set at 11525'with 25 sx spotted on top.A 9-5/8" bridge plug was set at 7825'with 50 sx of cement spotted on top and a 9-5/8" bridge plug was set at 2037'with 50 sx left on top. Additionally, 80 sx of cement was placed from 180' - 400' MD. The well was capped at the mudline. (Considered abandoned in 1993). 8 • . GLACIER 11. Geological Data Report Requirements of 20 AAC 25.283(a)(11) Within a one-half mile radius of the wellbore trajectory, a review and analysis of the location and orientation of all known and suspected geological faults and fractures,that will transect the confining zone, has been evaluated. The offset faults within a one-half mile radius will not interfere with containment of the hydraulic fracturing fluid of the proposed wellbore trajectory. 12. Drilling Hazards Requirements of 20 AAC 25.283 There were no losses encountered during drilling of the Hemlock in past wells or RU-01A. 13. Proposed Hydraulic Fracturing Program Requirements of 20 AAC 25.283(a)(12) (A) Estimated Total Volumes Planned 31,000 Gallons per Stage (B) Base Fluid and Additives Name YF125F1exD Purpose Gelling Agent, Crosslinker, Buffer, Stabilizer, and Gel Breaker Concentration Frac Fluid: YF125F1exD 27,000 Gallons 25.0 lb/mgal Pad &Frac Fluid 20/40 CarboBond Lite 59,500 lbs per stage Flush Fluid: WF125 4,400 Gallons 25.0 lb/mgal Flush Rate 20 BPM Max (C) Max Concentration of Chemical Ingredient 8% (D) Estimated Weight/Volume of Proppant 59,500 lbs / 13,229 gallons (E) Max Anticipated Treating Pressure 8,167 psi (F) Proposed Fracture Total Frac Height 82 ft Length - 1 Wing 340 ft Average Frac Width 0.110 inches Method of Determination SLB - Frac Cade Pre-Frac-This is a continuation of the workover operation of RU-01A: 1) Confirm the following has been completed prior to commencing operations: a) Confirm AOGCC has approved Hydraulic Frac Sundry prior to start of operations. b) Confirm that casing and liner lap has passed a 2,500 psi pressure test. c) Confirm 3 1/2" frac string is RIH,landed,cemented, and BPV in place. 9 • GLACIER 2) Hold pre-job safety meeting for hydraulic fracture operations. 3) Plan to N/U for Frac Operations as follows: i) 4-1/16" 15K Gate Valve#1 - Manual (Bottom of Frac Tree) ii) 4-1/16" 15K Gate Valve #2 - Hydraulic Actuated iii) 4-1/16" Frac Tee& (1) Wing Valve with 3" 1502 Unions on side iv) 4-1/16" 15K Gate Valve #2 - Manual v) Goat Head- 11K Manual Valve with 1502 Connections vi) 4-1/16" 15K Gate Valve#2 - Manual with 3" 1502 Union on top 4) Hold Pre Job Safety Meeting. a) Review all potential hazards with trapped pressure and risk with high pressure testing. b) Make certain that all personnel and crew members understand the hazards and where to be located. c) Confirm that all crew members are secured in a safe place while pressure testing. 5) Pull BPV. 6) Rig up necessary surface equipment and lines. 7) Rig Up Schlumberger Equipment for Hydraulic Fracture. 8) Rig up to Frac Tree and prepare for pressure test of frac string. 9) Pressure test all surface pumping equipment and lines to 12,100 psi for 10 minutes. a) Do not Pressure test frac string and liner during surface pressure test. 10)Rig Up pumping equipment for holding annular pressure while testing and performing frac. a) Note-We will hold a constant 2,000 psi on annulus. b) Set Annular Safety Pop-Off Valves to 2,500 psi. c) Take Bleed Off Line to diffuser tank or Trip Tank. 11)Ensure well is open. 12)Establish minimal rate to load hole if hole is not full. 13)Pressure Test Frac String to 12,100 psi for 10 minutes and chart. a) Note- Internal Yield on 3.5", 12.95#, P-110 is 15,000 psi. b) Note-After surface pressure test,plan to set Nitrogen Pop-Off Valves at 11,000 psi. c) Plan to hold 2,000 psi on the annulus during pressure test and frac. 14)Bleed off pressure in frac string. 15)Bleed off annulus pressure. 16)R/D Frac lines and prep for E-line. 17)Rig up wireline equipment and pressure test. a) Frac will be a Plug and Perf System. b) Will plan to perforate each zone individually before hydraulically fracturing each stage. 18)Prepare for Frac Operations a) Verify that the pump safety kick outs are set at 11,000 psi before moving into frac operations. Procedure Data-Frac-Zone 1 19)Hold&document pre job safety meeting. 20)Review entire rig up procedure,with applicable personnel, and ensure everyone fully understands work objectives and appropriate safety practices. 21)Ensure well is open. 22)Pickup 10'wireline perf guns. 23)RIH with perf guns to Zone 1 a) Confirm with GLA Engineer on actual interval. b ExIected Perf Interval: 1 Lower Hemlock 14654'MD 14664'MD 12189'TVD 12197'TVD 10 • • GLACIER 24)Correlate guns on depth. 25)Fire guns, per service company procedure. 26)POH with wireline and L/D perf guns. 27)N/D lubricator and wireline. 28)Hold&document pre job safety meeting. 29)Review entire rig up procedure,with applicable personnel, and ensure everyone fully understands work objectives and appropriate safety practices. 30)R/U Frac Lines and Pressure Test,per SLB Procedure. 31)Establish minimal rate to load hole if hole is not full. a) Note- Max Pump Rate of 20 BPM. 32)Consult with GLA Engineer and follow most recent Stimulation Procedure. 33)Pressure up on Annulus to 2,000 psi and hold. 34)Inject at matrix rate to ensure perfs are open,if able. 35)Wait for Pressure to stabilize. 36)Step up rate while watching for breakdown pressure until frac rate is established. 37)Hold steady rate until pressure stabilizes for at least 1/z to 1 min. 38)Hard shutdown,monitor leak-off until well is dead or pressure stops declining and stabilizes. a) Pressure data is critical for Pressure Transient Analysis. b) Confirm with GLA Engineer before bleeding off pressure. 39)Displace with 200 bbls of Linear Gel. 40)Shut Down and Monitor Pressure. 41)Send data to engineer for analysis. a) If a breakdown was present then proceed with actual frac after conferring with GLA Engineering. Procedure-Lower Hemlock Frac-Zone 1 42)Hold&document pre job safety meeting 43)Confirm that all necessary materials are on location and accounted for. 44)Ensure well is open and 3,000 psi is held on the backside. 45)Follow Schlumberger Pump Schedule and Procedure for pumping frac. a) Note- Prior to pumping, confirm with GLA management on latest pump schedule. b) Note- Max Pump Rate of 20 BPM. 46)Pump all chemicals. a) Bring each frac pump up to rate with cross-linked fluid. b) Flush will be called when proppant concentration drops by 2.0 ppa. c) Once Flush volume has been pumped, close in the well and allow cross-linked fluid to break. d) If pressure is released before the cross-linked gel has broken, proppant may be carried into the wellbore. 47)Complete pump schedule and shut down. a) If a pre-mature screen out occurs,pumps will shut down at 11,000 psi. i) Note-This will be revised after 1st Data Frac. b) Nitrogen Safety Pop Off Valves are set to relieve pressure at 11,000 psi. c) If no screen out then move to next stage. i) If a screen out occurs,confer with GLA Engineering on clean out procedure with Coil Tubing. 48)Bleed off annulus and tubing pressure. 49)Prepare to move to Zone 2 Frac. 11 • • GLACIER Procedure-Middle Hemlock Bottom Frac-Zone 2 50)Hold&document pre job safety meeting for Stage 2 Frac. 51)Plan for Data Frac prior to Pumping stage 2 Frac (See data Frac Procedure Above). 52)R/U wireline,lubricator, and pressure test. 53)Ensure well is open. 54)If no prior screen out then dummy run may not be needed. 55)P/U 15K Frac Plug and running tool on E-line. 56)RIH with Frac Plug to 5'above last perforation interval. 57)Set Frac Plug,per Schlumberger Procedure. 58)POH and L/D Running Tool. 59)Pickup 10'wireline perf guns. 60)RIH with perf guns to Zone 2. a) Confirm with GLA Engineer on actual interval. b) Expected Perf Interval: 2 Middle Hemlock Bottom 14540'MD 14550'MD 12098'TVD 12106'TVD 61)Correlate guns on depth. a) Confirm with GLA Engineer prior to setting guns. 62)Fire guns,per service company procedure. 63)POH with wireline and L/D perf guns. 64)R/D lubricator,wireline,and prep for pumping frac. 65)R/U Frac Lines and Pressure Test,per SLB Procedure. 66)Consult with GLA representative and follow most recent GLA Stimulation Procedure. 67)Pressure up on Annulus to 2,000 psi and hold. 68)Inject at matrix rate to ensure perfs are open,if able. 69)Wait for Pressure to stabilize. 70)Follow Schlumberger Pump Schedule and Procedure for pumping frac. a) Note- Prior to pumping, confirm with GLA management on latest pump schedule. b) Note- Max Pump Rate of 20 BPM. 71)Pump all chemicals. a) Bring each frac pump up to rate with cross-linked fluid. b) Flush will be called when proppant concentration drops by 2.0 ppa. c) Once Flush volume has been pumped, close in the well and allow cross-linked fluid to break. d) If pressure is released before the cross-linked gel has broken, proppant may be carried into the wellbore. 72)Complete pump schedule and shut down. a) If a pre-mature screen out occurs, pumps will shut down at 11,000 psi. b) Nitrogen Safety Pop Off Valves are set to relieve pressure at 11,000 psi. c) If no screen out then move to next stage. i) If a screen out occurs,confer with GLA Engineering on clean out procedure with Coil Tubing. 73)Bleed off annulus and tubing pressure. 74)Prepare to move to Zone 3 for Stage 3 Frac. Procedure-Middle Hemlock Top Frac-Zone 3 75)Hold&document pre job safety meeting for Stage 3 Frac. 76)Plan for Data Frac prior to Pumping stage 3 Frac (See data Frac Procedure Above). 77)R/U wireline, lubricator, and pressure test. 78)Ensure well is open. 12 • . GLACIER 79)If no prior screen out then dummy run may not be needed. 80)P/U 15K Frac Plug and running tool on E-line. 81)RIH with Frac Plug to 5'above last perforation interval. 82)Set Frac Plug, per Schlumberger Procedure. 83)POH and L/D Running Tool. 84)Pickup 10'wireline perf guns. a) Confirm with GLA Engineer on actual interval. b) Expected Perf Interval: 3I Middle Hemlock Top � 14440'MD — 14450'MD _I 12018'ND 12026'TVD 85)Correlate guns on depth. a) Confirm with GLA Engineer prior to setting guns. 86)Fire guns,per service company procedure. 87)POH with wireline and L/D perf guns. 88)R/D lubricator,wireline, and prepare for pumping frac. 89)R/U Frac Lines and Pressure Test, per SLB Procedure. 90)Consult with GLA representative and follow most recent GLA Stimulation Procedure. 91)Pressure up on Annulus to 2,000 psi and hold. 92)Inject at matrix rate to ensure perfs are open,if able. 93)Wait for Pressure to stabilize. 94)Follow Schlumberger Pump Schedule and Procedure for pumping frac. a) Note- Prior to pumping, confirm with GLA management on latest pump schedule. 95)Pump all chemicals. a) Bring each frac pump up to rate with cross-linked fluid. b) Flush will be called when proppant concentration drops by 2.0 ppa. c) Once Flush volume has been pumped,close in the well and allow cross-linked fluid to break. d) If pressure is released before the cross-linked gel has broken, proppant may be carried into the wellbore. 96)Complete pump schedule and shut down. a) If a pre-mature screen out occurs,pumps will shut down at 11,000 psi. b) Nitrogen Safety Pop Off Valves are set to relieve pressure at 11,000 psi. c) If no screen out then prep for milling and cleanout operations. i) If a screen out occurs,confer with GLA Engineering on clean out procedure with Coil Tubing. 97)Bleed off annulus and tubing pressure. 98)Prepare to move to Zone 4 for Stage 4 Frac. Procedure-Upper Hemlock Bottom Frac-Zone 4 99) Hold&document pre job safety meeting for Stage 4 Frac. 100) Plan for Data Frac prior to Pumping stage 4 Frac (See data Frac Procedure Above). 101) R/U wireline, lubricator,and pressure test. 102) Ensure well is open. 103) If no prior screen out then dummy run may not be needed. 104) P/U 15K Frac Plug and running tool on E-line. 105) RIH with Frac Plug to 5'above last perforation interval. 106) Set Frac Plug, per Schlumberger Procedure. 107) POH and L/D Running Tool. 108) Pickup 10'wireline perf guns. a) Confirm with GLA Engineer on actual interval. b) Expected Perf Interval: 13 • • GLACIER 4 Upper Hemlock Bottom 14210'MD 14220'MD 11835'TVD 11843'TVD 109) Correlate guns on depth. a) Confirm with GLA Engineer prior to setting guns. 110) Fire guns,per service company procedure. 111) POH with wireline and L/D perf guns. 112) R/D lubricator,wireline,and prepare for pumping frac. 113) R/U Frac Lines and Pressure Test,per SLB Procedure. 114) Consult with GLA representative and follow most recent GLA Stimulation Procedure. 115) Pressure up on Annulus to 2,000 psi and hold. 116) Inject at matrix rate to ensure perfs are open,if able. 117) Wait for Pressure to stabilize. 118) Follow Schlumberger Pump Schedule and Procedure for pumping frac. a) Note- Prior to pumping, confirm with GLA management on latest pump schedule. 119) Pump all chemicals. a) Bring each frac pump up to rate with cross-linked fluid. b) Flush will be called when proppant concentration drops by 2.0 ppa. c) Once Flush volume has been pumped, close in the well and allow cross-linked fluid to break. d) If pressure is released before the cross-linked gel has broken, proppant may be carried into the wellbore. 120) Complete pump schedule and shut down. a) If a pre-mature screen out occurs,pumps will shut down at 11,000 psi. b) Nitrogen Safety Pop Off Valves are set to relieve pressure at 11,000 psi. c) If no screen out then prep for milling and cleanout operations. i) If a screen out occurs,confer with GLA Engineering on clean out procedure with Coil Tubing. 121) Bleed off annulus and tubing pressure. 122) Prepare to move to Zone 5 for Stage 5 Frac. Procedure-Upper Hemlock Top Frac-Zone 5 123) Hold&document pre job safety meeting for Stage 5 Frac. 124) Plan for Data Frac prior to Pumping stage 5 Frac (See data Frac Procedure Above). 125) R/U wireline,lubricator,and pressure test. 126) Ensure well is open. 127) If no prior screen out then dummy run may not be needed. 128) P/U 15K Frac Plug and running tool on E-line. 129) RIH with Frac Plug to 5'above last perforation interval. 130) Set Frac Plug,per Schlumberger Procedure. 131) POH and L/D Running Tool. 132) Pickup 10'wireline perf guns. a) Confirm with GLA Engineer on actual interval. b) Ex ected Perf Interval: 5 Upper Hemlock Top 14132'MD 14142'MD 11771'TVD 11779'TVD 133) Correlate guns on depth. a) Confirm with GLA Engineer prior to setting guns. 134) Fire guns, per service company procedure. 135) POH with wireline and L/D perf guns. 136) R/D lubricator,wireline,and prepare for pumping frac. 137) R/U Frac Lines and Pressure Test,per SLB Procedure. 138) Consult with GLA representative and follow most recent GLA Stimulation Procedure. 14 • GLACIER 139) Pressure up on Annulus to 2,000 psi and hold. 140) Inject at matrix rate to ensure perfs are open,if able. 141) Wait for Pressure to stabilize. 142) Follow Schlumberger Pump Schedule and Procedure for pumping frac. a) Note- Prior to pumping, confirm with GLA management on latest pump schedule. 143) Pump all chemicals. a) Bring each frac pump up to rate with cross-linked fluid. b) Flush will be called when proppant concentration drops by 2.0 ppa. c) Once Flush volume has been pumped, close in the well and allow cross-linked fluid to break. d) If pressure is released before the cross-linked gel has broken, proppant may be carried into the wellbore. 144) Complete pump schedule and shut down. a) If a pre-mature screen out occurs,pumps will shut down at 11,000 psi. b) Nitrogen Safety Pop Off Valves are set to relieve pressure at 11,000 psi. c) If no screen out then prep for milling and cleanout operations. i) If a screen out occurs,confer with GLA Engineering on clean out procedure with Coil Tubing. 145) Bleed off annulus and tubing pressure. 146) Prep for coil cleanout and milling operations. Procedure-Post Frac Clean Out 147) Hold&document Pre-Job Safety Meeting. a) Confirm that BOPE Test is still valid or schedule BOPE Test with AOGCC. 148) Review entire rig down procedure to ensure everyone fully understands work objectives and appropriate safety practices. 149) Caution for potential hazards and trapped pressures. 150) Shut in well at frac tree by closing 4-1/16" 15K Actuated Gate Valve. 151) Rig Down Schlumberger Equipment and clear the rig floor. 152) R/D Wireline Equipment and Lubricator. a) Frac tree will remain in place 153) N/U Coil Tubing BOPE to 4-1/16" 15K Flange. a) Notify AOGCC 48 hours ahead of upcoming CTU BOPE Test. 154) Test CT BOPE,per Service Company Procedure. a) Open manual valve on frac tree after CT BOPE is installed and tested. 155) Rig up CTU and prepare to RIH to Mill Plugs and Clean Out Well. a) Make sure equipment is rigged up for reverse circulating. 156) Nitrogen lift will be utilized directly after Coil Cleanout. 157) Pickup Clean out BHA, Motor,and Mill. 158) RIH on coil tubing to liner top at+/- 11,000'. a) RIH and watch running speeds in anticipation for fill. 159) Continue RIH and report fill depth on daily report if encountered. 160) Clean out each stage from heel to toe of well. a) Report any issues or fill on report. b) Document on report if losses are encountered. 161) Circulate well clean with kill weight fluid and prepare to POH. 162) Confirm that well is dead. 163) POH and L/D clean out BHA. 164) Confirm Pressure on tubing and annulus is zero. 165) Install BPV. 15 ! ! GLACIER 166) Shut in 4-1/16" 15K Gate Valve below frac tee. 167) N/D Coil Tubing BOPE. 168) N/D Frac Tree. 169) Move to Completion Sundry. 14. Proposed Post Frac Clean-Up Program Requirements of20 AAC 25.283(a)(13) Schlumberger Coil Tubing will be on location with a 19,000' - 1.75" CT string for any clean out needs. Uses/Unused hydraulic fracturing fluid will be disposed down the RU-D1 - Class 1 Disposal Well. Procedure-Screen Out(Per Schlumberger) 1) R/U 1.75" Coil Tubing, PT BOPE to 4,500 psi HI 250 Low for 5 min. 2) M/U jet nozzle for washing down operations. Stab on well, PT lubricator and flowlines to 250/4,500 psi. 3) RIH at 20 ft/min near the jewelry and tubing restriction. Increase the running speed to 60 ft/min if the tubing is clear and perform pull test for every 1000 ft. 4) While RIH,pump KCL down tubing and take returns to tank. Monitor returns for sand and tank levels in returns tank 5) Verify with Company Rep potential sand depth in the hole.Start RIH to about 500 ft or pre- determined sand depth, RIH slowly to perform dry tag top of sand.A dry tag as a first run is advised to verify where fill will be encountered. 6) Once top of fill determined,pull CT 20 ft,and line up to performed conventional fill cleanout circulation at maximum rate. a) During Operation conduct frequent WT checks and increase frequency if losses occur. 7) Wash down to desired TD depth. 8) Once reached TD, circulate 2 annulus volumes. Monitor return tank levels and return volume. Discuss returns with the Company Rep. 9) POH coil 500 ft from TD. Stop circulating.Wait 30 minutes. RIH with coil pumping and tag bottom. If tag is above desired TD depth (review results with Company rep),then repeat steps 6-8 until fill remains below this depth. 10) POH with coil.Unstab coil from well. 11) Blowdown the string with N2. RD Coil. 12) Turn well over to Operations. 15. Hydraulic Fracturing Requirements of 20 AAC 25.283(b) Hydraulic fracturing done through the production or intermediate casing will have a pre-casing test to 110 percent of maximum anticipated pressure differential. If the casing fails the pressure test, casing will be repaired prior to starting the frac or a frac string will be utilized. Requirements of 20 AAC25.283(c) 16 • • GLACIER Hydraulic fracturing done through a fracturing string must be: (1) Stung in to a liner or run on a packer set at a measured depth of not less than 100 feet below the cement top of the production casing or intermediate casing (2) Tested to 110 percent of maximum anticipated pressure differential CIE will perform the hydraulic fracture through a frac string. Requirements of 20 AAC 25.283(d) A pressure relief valve will be installed on the treating line between the pump and the wellhead to limit line pressure to the test pressure determined under (a)(12)(E) of this section. The well will be equipped with a remotely controlled shut-in device. Inner annulus pressure relief valve will be set to pop-off at 2,500 psi. Surface lines are protected with pop-off valves set at 11,000 psi. Shut down surface pressure from the pumps is set at 11,000 psi. Requirements of 20 AAC 25.283(e) The placement of all hydraulic fracturing fluids will be contained to the approved formations during the hydraulic fracturing operations. Requirements of 20 AAC 25.283(f) Surface casing pressures shall be monitored with a gauge and pressure relief device while frac operations are in progress. (and) The annular space between the fracturing string and the intermediate or production casing will be continually monitored. The pressure in the annulus will not exceed the pressure rating of the lowest rated component that would be exposed to pressure if the frac string failed. Requirements of 20 AAC 25.283(g) During fracturing operations, all annulus pressures will be continuously monitored and recorded. IF at any time during hydraulic fracturing operations, annular pressure increases by more than 500 psig above anticipated increases, CIE shall perform the following: (1) Notify the commission as soon as possible, but not later than 24 hours after the incident (2) Implement corrective action and/or increased surveillance (3) Submit a Report of Sundry Well Operations (Form 10-404) not later than 15 days after the incident 17 • • GLACIER Requirements of 20 AAC 25.283(h) A Report of Sundry Well Operations (Form 10-404) will be completed and submitted to the commission no later than 30 days after completion of the hydraulic fracturing operations. Attachments Attachment 1: Plat/As-Staked Design Attachment 2: Equipment Layout Attachment 3: Cement Program Attachment 4: Cement Bond Log (already on file at AOGCC) Attachment 5: Frac String Schematic Attachment 6: Proposed Wellbore Completion Schematic Attachment 7: Wellhead Schematic Attachment 8: Frac Tree Schematic Attachment 9: FracCade Stim Proposal Attachment 10: Trajectory and Spider Plot Attachment 11: Affidavit Providing Notice of Operations Attachment 12: Geologic Frac Summary TITLE NAME SIGNATURE DATE APPROVED Engineer- Originator Engineer- Review Superintendent Drilling Manager 18 MILLER MG -35 -Schema • MeihJa... «. N. - IIWM IU OF akakl' !ib I � : rkMr ulaszoA11 . . Iri /1"1" 1P4a r ' f a. • : + i:: C 1, j k i' 1 .."' Zt \ 11.1../alfILIPIPAIIIPi...7/1 ` M SIF 4, r r w r r I. W • y ...��_,._ -'-.it�.Ya r ...s�tr�v sem.^+•. ew Hsw td �C Ani t •... i ° p� • _ .... ' .. F.L. DRILLING RIG ARRANIGIV NI FAST SIDE *poet Btu , ...__. VOjiiiiinegimiata litiKI E t S > s .k•" 1 ..ate Ag', ' SECN 14 T7N R1 SMA _.--47---- .-_-11111N 0 300 450 600 O RE PLATF•RM NORTH - GRID SCALE 1 inch =300 ft. See Deta. + 322' FEL y. 269' FEL-- 7 WELL SLOT #8 WELL SLOT #22 #12 WELL SLOT PT.NO.21 WELL RU-7 a c #9 ,( CENTER LEG 3 e WELL SLOT ` LAT:60°41'43.698"N #10 LON: 151°40'14.573"W #11 WELL SLOT �` _ N:2449936.607' WELL SLOT V E:200623.926' OSPREY PLATFORM ASP ZONE 4 NAD 27 EL VEA BOTTOM:-45'MLLW DETAIL 1"=20' #17 WELL RU D-1 PT.NO.6 #18 CENTER LEG 2 0 WELL RU-2 LAT:60°41'44.155"N O #19 LON: 151°40' 13.520"W V WELL RU-1 N:2449981.637' 4/10 E:200677.509' AI #14 ASP ZONE 4 NAD 27 JWELL RU-4 ELEV SEA BOTTOM:-45'MLLW v) L'-#15 o #20 WELL RU-3 rn rn #16 WELL RU-5 See Tabular Sheet for Well Slot Coordinates a) 1.BASIS OF HORIZONTAL AND VERTICAL ```��O F��'1, J_ CONTROL WAS DETERMINED BY AN OPUS �. P'��!•• •A/ 1., ,� C SOLUTION FROM CORS BASE STATIONS Oar"AC23 PID DM748"&"AC51 PID DD1812"& '� "KENS PID DJ3029"ALASKA STATE PLANE g� . *,�, 0 NAD 83 ZONE 4 EPOCH 2010 HORIZONTAL4 / a) DATUM AND NAVD88 VERTICAL DATUM - UTILIZING GEOID12A. '"� „. - 2)SECTION LNE OFFSETS DETERMINED / M. SCOTT McLANE . c ow FROM PROTRACTED SECTION CORNER 4; VALUES. lI '; _ 4928-S z- 3)MLLW ELEVATIONS WERE DERIVED Sept 15,201A •� FROM NOAH NAUTICAL CHARTS. .I, c`'c: )NP- 40 NOTES t'vt S,+-+Lwl I LII Ie /11 OSPREY PLATFORM COOK INLET, ALASKA ENGINEERING-TESTING WELL LOCATIONS NAD27 SURVEYING-MAPPING MC' w J. P.O.BOX 468 CLIENT: �v SOLDOTNA,AK.99669 COOK INLET ENERGY, LLC VOICE:(907)283-4218 601 W. 5TH AVENUE SUITE 310 FAX:(907)283-3265 _ Cook Inlet Energy ANCHORAGE,AK 99501 WWW.MCLANECG.COM Consulting Inc PROJECT NO. DRAWN BY: DATE: LOCATION: 133075 PROTRACTED SECTION 14 msm Sept 15,2015 TOWNSHIP 7 NORTH, RANGE 14 WEST SEWARD MERIDIAN,ALASKA Glacier Oil and Gas BAIT RO Location: Cook Inlet,Alaska(Offshore) Slot: Leg#3,Slot 19(RU1&1A) G L AG 1 E R Field: Redoubt Shoal Well: Redoubt Unit#1A HUGHES Facility: Osprey Platform Wellbore: RU1A s�HiA„nc„_,00 Easting(ft) 6000 6250 6500 6750 7000 7250 7500 7750 8000 8250 8500 8750 9000 9250 I I I I I I I I I 1 I I I I 0 —' 0 -250 • —-250 750 —-750 -1000— —-1000 —-1250 1500— —-1500 17J0 —-1750 m —-2000 O L m' 0 Z -2250 —-2250 -2500— .. —-2500 -mo —-2750 N N - -3000,— g.—_________________415° Rus P tai 40 —-3000 —-3250 RU6 3500 --3500 -3750— -3750 -4000— ” RU7 S77 --4000 YR 4250 I 1 �29 i I 1 1 1 1 1 1 I 1 1 1 L_m-4250 6000 6250 0500 6750 7000 7250 7500 7750 8000 8250 8500 8750 9000 9250 Easting(ft) • 0 r 8 N .�Q C +� 6.. c Pn 1114 ua4M § § i o"= X91000 8L (1 ). & (,9'8 X,Z1)ollS I ? 51 co o' 1^ * = 00 6 x Y 00- iJ ��.++SI p e-1 O � 5 � 0 '"� � ai � x m I l O � kI I 13 G O 7 �y b 4eLip � � ® * 4. 4 4 k eh .q 14 IVL. ,8x91 $ Xo8sqe 1 000001o4.111:#71311: OsB ft I °1.6, Ea, 3e.11/gel PrW 8#)laid it � I x ISI If 1.41 I I I 11Dii IV II C ce v g II 1 t ill jiliP z IQ I 3 1 0 i o• Is aH� > b u IS < a 43 � x15 ti N __ U. �+ b. L. F; 2 a 2 or O 43 .2 K IIS uaynn g l ® sgI000'8L Ln N , (,9'8 x,ZT)CMS LLrl 3 � U. "II 000'0b �2T x,OZ)iapuais OOd - 1 L1 ____L...."__ it- 1 � 10 m :o °' it1 co f At 4 X11000'99 X (,8 x,OE)dwell �I ' I Sg1000'99 (,8 x,0E)dw fid e I , g I I I i I i ._. i v i I I SqI 00r GZ6'8 x,SZ'LZ)dwnd yevi no E.- a. HEM SIV If • • .�F I String: 3.5-in Tubing Well Name: RU-01B Company: Glacier Oil & Gas Field: REDOUBT SHOAL Contact: Mr. Stephen Ratcliff Well Location: Cook Inlet,Alaska (Offshore) Well Number(API): Osprey Platform Proposal Number: 3 Date: 11/16/2016 Made By: Rianne Campbell Service from District: Kenai,AKA District Phone: Objective: Cement Tubing into place to Isolate Perforations. Acceptance Criteria: Pump per design (Volume, Density, Rate) Disclaimer Notice Schlumberger submits this document with the benefit of its judgment experience.and good oilfield practices. This information is provided in accordance with generally accepted industry practice,relying on facts or information provided by others,limitations,computer Schlumberger models,measurements,assumptions and inferences that are not infallible. Calculations are estimates based on provided information.All proposals,recommendations,on predictions are opinions only. NO WARRANTY IS GIVEN CONCERNING ACCURACY OR COMPLETENESS OF DATA,INFORMATION PRESENTED,EFFECTNENESS Of MATERIAL,PRODUCTS OR SUPPLIES,RECOMMENDATIONS MADE,OR RESULTS OF THE SERVICES RENDERED. Freedom fon infringement of any intellectual property rghts of Schlumberger or others is not to be inferred and no intellectual property rights are granted hereby. r ! .4w 6.--7,41;.. Well Data Summary The cementing program incorporates the following data All depths take the rig floor as reference RigType Offshore Mud Line Depth 345.0 ft Fluids Return to Water Depth 185.0 ft Mud Return Depth 79.0 ft BHST 204 degF Section MD 15038.0 ft Section TVD 12492.9 ft Tubulars and Casing Hardware MD OD Joint Weight ID Grade Collapse Burst Thread ft in ft lb/ft in psi psi Prey Casing 6509.0 9 5/8 40.0 _ 47.0 8.681 L-80 4750 6870 API 15038.0 51/2 40.0 17.0 4.892 L-80 6290 7740 API Casing 15038.0 3 1/2 40.0 9.3 2 9/10 L-80 10538 10160 KS Bear Landing Collar 14958.0 Serial number : Float Shoe MG Saft s ft mg mg _ „a« Inclination(deg) Horizontal Departure(ft) 0 10 20 30 40 50 0 2000 4000 6000 8'J'i; 0 0 Q —Incimaton(deg) —Hoc ontai Departure fn K Fr 1 `..:g in Ca ( v \ 6569 ft _ C w i. _g Sand i 0 I � � poTi y CL U 8 00 8 8 0 c 8 172881( i ,31,2 a Casing, e I 5 i;2 in Casing c, 136101 Open Holej o 1 ,i_ caw mait� j _ l.i 8 153-81 8 2 of 12 Schlumberger • • Open Hole Total Volume 0.00 bbl Minimum Diameter 6.750 in Maximum Diameter 6.750 in Mean Diameter 0.000 in Mean Annular Excess 20.00% Mean Equivalent Diameter 0.000 in MD m 345 ft ~09^ 122o ^ . / | ! [13610 f 1495»^ "m38^ .- Formation Frac Pore Top Bottom Bottom Frac Bottom Pore Bottom Res. MD MD TVD Top ED ED Top ED ED Lithology Fluid Name ft ft ft lb/gal lb/gal lb/gal lb/gal 345.0 15038.0 12492.0 4.58 14.46 4.58 0.89 Sandstone Sand Temperature Relative Name Top MD Bottom MD Bottom TVD Temperature Gradient Gradient Sea Current M ft ft degF dagF/10Oft degF/1O0h ft/min Surface 0.0 0.0 0.0 80 0.00 0.00 SeaLevel 0.8 160.0 160.0 80 '0.02 '0.02 10.13 3 of 12 Schlumberger . • ,.. : " Temperature Relative Name Top MD Bottom MD Bottom TVD Temperature Gradient Gradient Sea Current ft ft ft degF degF/100ft degF/100ft ft/min SeaBed 160.0 345.0 345.0 73 -2.15 -4.00 10.13 Rock 345.0 14950.0 12423.7 203 0.99 1.08 0.00 BHST 14950.0 15038.0 12492.9 204 0.99 1.20 0.00 Rock 15038.0 15640.0 13092.3 210 0.99 1.00 0.00 Geothermal Profile(degF) 60 80 100 12: 140 160 180 200 22: 0 © ., -- Geothermal ten (def Cs CD CV 0 0 N N.0 - `O o NN. o 0 a> opo `\ S N © o ,N CD N 0 0 0 Po 0 4 of 12 Schlumberger • • r=` Fluid Placement Surface Densities are computed at P=1 atm and T=Surface Temperature(80 degF) Fluid Placement in Annulus Fluid Name Top MD Bottom MD Length Volume Surface Density ft ft ft bbl lb/gal Sea Water 79.0 12288.2 12209.2 459.78 8.60 SPACER 12288.2 13610.0 1321.8 15.00 11.50 16.5ppg Class G 13610.0 15038.0 1428.0 16.20 16.50 Fluid Placement in Pipe Fluid Name Top MD Bottom MD Length Volume Surface Density ft ft ft bbl lb/gal Sea Water 0.0 14958.0 14958.0 122.20 8.60 16.5ppg Class G 14958.0 15038.0 80.0 0.65 16.50 MD '„°-S5ft R Immo _... .._. i cci 6509$ . Sea'.'iyter Ia i �a �, 17288 - I 1%1011 1c 5ppa ass-, 1195811 I{` I =cr 150381 5 of 12 Schlumberger • • A` 0 .44 1011.* Pumping Schedule Pumping Schedule Pump Injection Cumulated Fluid Name Duration Volume Rate Temperature Comment Time hr:mn bbl bbl/min degF hr:mn SPACER 00:03 15.00 6.00 68 00:03 Plug 00:10 00:13 16.5ppg Class G 00:03 16.86 6.00 68 00:15 Top Plug 00:10 00:25 Sea Water : 00:17 122.20 > Sea Water 00:17 117.10 7.00 68 00:42 > Sea Water 00:01 5.10 7.00 68 00:43 Maximum Required Hydraulic Horsepower(HHP) 689.7 hhp(at 00:43 hr:mn) 6 of 12 Scblumberger • • co I I —Pump rate(bbirrniM Return Rate(bbYrnm) O 00:00 00:10 00:20 00.30 00:40 Time(hrmn) —Pump pressure(pd) —Cement head pressure(psi) v / /17 1 8N ` 00:00 00:10 00:20 00:30 00:40 Time(hymn) —t?o4roen tote pressure ED(bigot) Pore Pressure At Bottom Hole Frac Pressure At Bottom Hole T _Stair pressure at bottom ED pWgal) ED WO ED(Nat, 2s co 00:00 00:10 00:20 00:30 00:40 Time(hrmn) 7 of 12 Schlumberger • • Well Security Well Security Status Description Min Differential At Depth At Time Pressure ft hr:mn psi N/A Fracturing 0 0.0 00:00 N/A Production/Influx 0 0.0 00:00 Success Burst 6261 79.0 00:43 Success Collapse 9001 15038.0 00:43 N/A Dead-End Collapse 0 0.0 00:00 N/A Dynamic u-tubing in Dead-End 0 0.0 00:00 N/A Balanced u-tubing in Dead-End 0 0.0 00:00 0 2 - 6 8 10 12 14 0 —Mat Annular Pressure ED i b;al —Mm Annular Pressure ED t, _ 00 N 0 0 O tg o 0 v Q m 80 91 0 Og r O 0 O o 8 of 12 Schlumberger • i ,,,,�r� Temperature Outputs Temperature Summary Table Static Temperature.at TOC 191 degF Static Temperature at BH 204 degF Simulated HCT at TOC 188 degF Simulated HCT at BH 191 degF Max First SK Temperature 192 degF Max Last SK Temperature 191 degF At time 00:41 hr:mn At time 00:43 hr:mn T at Bottom Hole(degF) coo Sea Water/SPACER Interface Temp(degF) SPACER i 16.5ppg Class G Interface Temp(degF) _16.5ppg Class G 1 Sea Water Interface Temp(degF) �s r Qv 0 c.i 0 0 ctp 0000 0010 0020 00:30 00:40 Time(hr:mn) degF 60 80 100 120 140 160 180 200 220 o — o —Geothermal temp.(degF) —T m annulus at time(degF, 0 0 T in pipe at time(degF) 0 0 _ a t -o 00 ,*,yam QSg 9 of 12 Schlumberger • • . Centralization Centralizers Commercial Alias Manufacturer Name Type Config Csg OD Min OD Max OD Count in in in SPIRAGLIDER HD-4 Hannover Not Set rigid Not Set 4 1/2 6.252 6.252 0 1/2-4-SPI RAL650 SpiraGlider HD-5 0-4- Hannover SpiraGlider HD rigid Spiral 5 6.252 6.252 0 Spiral650 SpiraGlider SC-3 1/2- Hannover SpiraGlider SC rigid Spiral 3 1/2 4.126 4.126 8 4-Spiral437 Pattern Placement Bottom MD Joints Centralizer Alias Pattern Min STO Depth ft ft 14050.0 351.25 - 0 0.00 147.6 15038.0 24.70 SpiraGlider SC-3 1/2-4-Spira1437 1/3 0.00 14051.8 MC Cft _ 345 R _ - Sea Vi,Er 0 20 40 60 80 lC 0 Standoff b+*eentraieets Standoff at central¢ets g t 6609 A __,.._ I - p8 . _. _.,..i. Sea ;rater N � ppop &'.�.c l O = 12288k :_ _ SPACER } 13610R 111 - 116 Spiv Class Gt 11 ;16 5Pag Mass G 1ISee .'ater 14958* 16038•- .Ill' Computation time:Cement Turns 00:40 10 of 12 Schlumberger I WELLCLEAN* III Average Fluid Concentrations Average fluid concentration in annulus Average fluid concentration in pipe Average Concentration(%) Average Concentration(%) 0 20 40 60 80 100 c> 0 23 43 53 83 100 120 r o ' L —Sea Water in ann.(%i -Sea Water in pipe i%, —SPACER in ann.(%) —SPACER in pipe t% 16.Sppg Class G a ann. 16.6ppg Class G in pipe. I s v 0 :et L v <I> CO 7 to N CC COIDM co Q � I S CD 11 of 12 Schlumberger • • I • 44.4111°.' #46,010111 Final Fluid Concentrations MO Oft _ 3,5 ft au , S.P.a Vales- 14400_ 14800_ 6509 ft -I IT-- ; 14800 1 i I 15000_ 1228(11 I - soacER ii Fluids Concentrations Sea Water prkkoi_. _ II SPACER 116.5ppg gum G1 2116 5ppg Class_91 16 5ppg Class G f sea wm. 1 14958 ft 15038 ft 12 of 12 Schlumberger • RU-01A-Current Wellbore Schematic • Date: 30-Jan-17 Version: 1.0 Tubing hanger-ACME 3.725'MCA top connection/ GLACIER 3 1/2"12.95#P-110 PH6 btm connection 36" 150#A-36 200'MD ID-34.00" Welded 200'TVD 18 1/2"Hole 13 3/8" 68#L-80 1,831'MD ID-12.25" BTC 1,803'TVD 1 3 1/2"12.954 P-110 PH6 Tubing-ID 2.625"@ 14,901'MD TOL @ 6,509'MD/5,605'TVD(9 5/8"x 5 1/2") TOL @ 6,702'MD/6,803'TVD(7 5/8"X 9 5/8") 9 5/8" 47#L-80 6,986'MD 12 1/4"Hole ID-8.50" BTC 5,988'TVD 7 5/8" 29.7#L-80 12,246'MD 8 112"Hole ID-6.75" BTC 10,231'TVD TOC(2013 CBL)@ 12,900'MD • 5 1/2" 17#L-80 15,038'MD 6 3/4"Hole ID-4.767" Hydril 521 12,493'TVD • RU-01A-Frac Wellbore Schematic Date: 2-Mar-17 • Version: 3.1 Tubing hanger-ACME 3.725"MCA top connection/ GLACIER 3 1/2"12.95#P-110 PH6 btm connection 36" 150#A-36 200'MD ID-34.00" Welded 200'TVD 18 112"Hole 13 3/8" 684 L-80 1,831'MD ID-12.25" BTC 1,803'TVD 4 3 1/2"12.95#P-110 PH6 Tubing-ID 2.625"@ 14,943'MD TOL @ 6,509'MD/5,605'TVD(9 5/8"x 5 1/2") TOL @ 6,702'MD/6,803'TVD(7 5/8"X 9 5/8") ■ 9 5/8" _ 47#L-80 6,986'MD 12 1/4"Hole ID-8.50" BTC 5,988'TVD 7 5/8" 29.7#L-80 12,246'MD 8 1/2"Hole l ID-6.75" BTC 10,231'TVD TOO(2013 CBL)@ 12,900'MD Planned Top of cement©+/-13,610'MD (Top of Old perfs @ 14,110'MD) •` i l Planned Frac Zones t Top MD Btm MD •Top TVD Btm TVD 1 •= 14132 14142 11771 11779 _ 14210 14220 11835 11843 14440 14450 12018 12026 14540 14550 12098 12106 "+� s 14654 14664 12189 12197 '- 5 1/2" 17#L-80 15,038'MD 6 3/4"Hole �' �' ' ID-4.767" Hydril 521 12,493'TVD • RU-01A-Proposed ESP Wellbore Schematic• Date: 1-Mar-17 < r . Version: 3.1 Tubing hanger-ACME 3.725"MCA top connection3:1 GLACIER I 3 1/2"EUE 8rd btm connection-ID 2.950" 36" 150#A-36 200'MD ID-34.00" Welded 200'TVD _ 3-1/2"SSSV-ID 2.992"@ 300'MD/300'TVD r I ,�!IIIII 1"Vent Valve w/1/4"seamless steel line 18 1/2"Hole - Trident Packer @ 500'MD 13 3/8" 68#L-80 1,831'MD ID-12.25" BTC 1,803'TVD 3 1/2"9.3#L-80 EUE Tubing-ID 2.992" F/6,000'MD to surface XO-27/8"x31/2"-ID 2.441"@6,000'MD/5,197'TVD 1 27/8"6.5#L-80 EUE Tubing-ID 2.441" @ 13,420'MD-6,000'MD/11,174'TVD-5,197'TVD TOL @ 6,509'MD/5,605'TVD(9 5/8"x 5 1/2") TOL @ 6,702'MD/6,803'TVD(7 5/8"X 9 5/8") I [ 9 5/8" 47#L-80 _ 6,986'MD 12 114"Hole ID-8.50" BTC 5,988'TVD D3Stainless Pack 7 5/8" _ 29.7#L-80 12,246'MD 8 1/2"Hole IDual-6/8".75" BTCFlat Lines 10,231'TVD TOC(2013 CBL)@ 12,900'MD ESP Assembly Top @ 13,420'MD/11,174'TVD ELECTRIC SUBMERSIBLE PUMP-200' ESP#1 Flat Pack Cable — _- Discharge Unit Assembly Pump Assembly(3) Intake/Gas Separator Seal Assembly-Upper/Lower Seals Motor(2)/Motor Gauge Unit Sensor Anode Chemical Injection Check Valve 'I 1 ESP Assembly Bottom @ 13,550'MD/11,281'TVD , ' (Original Planned ESP @ 13,600'MD/11,322'TVD) Planned Top of cement @+1-13,610'MD (Top of Old perfs @ 14,110'MD) Top of 3 1/2"tubing stub-ID 2.992"@ 13,550'MD/11,281'TVD II I ■■I Planned Frac Zones -_.— _ Top MD Btm MD Top TVD Btm TVD IIA II 14132 14142 11771 11779 14210 14220 11835 11843 'I L' 14440 14450 12018 12026 14540 14550 12098 12106 �. - —'- 14654 14664 12189 12197 5 1/2" 17#L-80 15,038'MD 6 3/4"Hole r- A ID-4.767" Hydril 521 12,493'TVD • Si GE Oil & Gas I , ase on 6 21 MirmII 0 00 I' • ISfOOO :I li �O�p III' C 1. r ./ man a es w� 196 7 Uji i ' U.S1 id .4* 1.1 ,858'SM 28.0 ■- 4 " ,1111.81:1' q1i41i 4t •. �� , aSM -/t6"5M -".:j 1.1 ,` I 1.1 2].2 to t !I 1 ,,,, ,,.., ii, .. 2-1//67511 MO 46 1 MI ,.. 1_- li 11 I 1 . AI , All a a9 3-1/211,469 PFT Cable ALL DIMENSIONS ARE APPROXIMATE This drawing is the property of GE Oil&Gas Pressure Control LP and is considered confidential.Unless otherwise approved in writing. COOK INLET ENERGY neither it nor its contents may be used,copied,transmitted or reproduced except for the sole purpose of GE Oil&Gas Pressure Control LP. OSPREY PLATFORM R R U-01 A DRAWN CR 03OCT16 13-3/8" x 9-5/811 x 3-1/2" 5M Multibowl Wellhead Assembly With MB-205 Tubing Head and Tubing APP RF KN 030CT16 FOR REFERENCE ONLY Hanger and Adapter Flange DRAWING NO. HP160203 s GE Oil &• 4110 SIXmox po %l, 4v10.ISM r,a1-0.r` v�oxol;j t l>°P.m I.,' '.,'4,•••',.SW I.I I I I I I I I I I‘44'.., .1/t,•1,M [ -1 a1.1• ,Ire&�t1n 4v10.teM u. "n 41/10.ISM k, \.,- 111111111.11 1•1 iltaosix,MI rISMaepa 1302 ween urvn 4-1/16.ISM i Mien , SI I1 ,070�r 41W15M ,;1111 wi'. i I i 13-60• L 0 1 6 _..,J " . - II 8.SPA tasM ...- .&5• r — 1.1 (( 0..l 27z 4 4.11D'4.1 SI �' 'I..114.„-. ■■ ✓tc SM 3.1 mi: I Ill 1 IT if as cewn 13ae•cs+a 0-6/....12 41/2•Tully ALL DIMENSION-i ARE APPROXIMATE This drawing N elsproperly of GE 011&Gas Pressure Control LP and Is considered ponfldendelunless otherwise approved In wrens,. COOK INLET ENEEGY neither ft nor Its contents may be used,copied,trenemltted or reproduced except for the sole p3rpose of OE OI&Gas Pressure Control LP, 13.3/8"x 9-5/8"x 4-1/2"5M MB-205 Multibowl Wellhead DRAWN CR 09FEB17 APPRV KN 09FEB17 Assembly,With MB-205 Tubing Head,Tubing Hanger and FOR REFERENCE ONLY A.I....S,..CI,...,.,. lA/;tt.A 111Ctt 1C&A C...-....1".......-. DRAWING NO. HP170019 1 • • Cook Inlet Energy COOK INLET BASIN REDOUBT SHOAL RU-1 A 50733204970100 Sperry Drilling Services Definitive Survey Report 17 September, 2013 HALLIBURTON °ice , m Sperry Drilling Services • Halliburton Company S Definitive Survey Report Company: Cook Inlet Energy Local Co-ordinate Reference: Well Redoubt Unit#1 Project: COOK INLET BASIN TVD Reference: Redoubt Unit#1A(Rig 35)@ 89.10ft(89.1 KB+40' Site: REDOUBT SHOAL MD Reference: Redoubt Unit#1A(Rig 35)@ 89.10ft(89.1 KB+40' Well: Redoubt Unit#1 North Reference: Grid Wellbore: RU-1 A Survey Calculation Method: Minimum Curvature Design: RU-1 A Database: .16 prd Project COOK INLET BASIN 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 Well Redoubt Unit#1 Well Position +NI-S 0.00 ft Northing: 746,743.54 m Latitude: 60°41'43.743 N +EI-W 0.00 ft Easting: 61,151.10 m Longitude: 151°40'14.523 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Water Depth: 40.00 ft Wellbore RU-1 A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2013 6/28/2013 17.10 73.56 55,440 Design RU-1 A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 12,207.05 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) 129.10 0.00 0.00 95.00 Survey Program Date 9/17/2013 From To Survey II (ft) (ft) Survey(Wellbore) Tool Name Description Start Date 163.86 1,829.10 RU#1 MWD#1 (RU#1) MWD Fixed:v2:standard declination 08/30/2012 1,830.10 6,985.10 RU#1 MWD#1 (RU#1) MWD Fixed:v2:standard declination 08/30/2012 6,985.10 12,207.05 RU#1 MWD#1 (RU#1) MWD Fixed:v2:standard declination 08/30/2012 12,263.00 12,566.01 MWD_Interp Azi+Sag(RU-1 A) MWD_Interp Azi+sag Fixed:v2:std dec with interpolated azimuth+sa 07/02/2013 12,660.34 15,011.23 MWD+SC+sag(RU-1 A) MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 07/19/2013 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 129.10 0.00 0.00 129.10 40.00 0.00 0.00 746,743.54 61,151.10 0.00 0.00 UNDEFINED 163.86 0.21 103.43 163.86 74.76 -0.01 0.06 746,743.54 61,151.12 0.60 0.06 MWD(1) 193.94 0.62 103.43 193.94 104.84 -0.07 0.27 746,743.52 61,151.18 1.36 0.28 MWD(1) 282.86 0.51 103.43 282.85 193.75 -0.27 1.13 746,743.46 61,151.44 0.12 1.15 MWD(1) 373.42 0.50 103.43 373.41 284.31 -0.45 1.90 746,743.41 61,151.68 0.01 1.94 MWD(1) 463.82 0.97 103.43 463.80 374.70 -0.72 3.03 746,743.32 61,152.02 0.52 3.08 MWD(1) 553.79 3.11 119.90 553.71 464.61 -2.12 5.89 746,742.90 61,152.89 2.44 6.05 MWD(1) 644.78 4.53 114.67 644.50 555.40 -4.85 11.29 746,742.07 61,154.54 1.61 11.67 MWD(1) 734.83 5.19 105.21 734.22 645.12 -7.40 18.46 746,741.29 61,156.72 1.15 19.03 MWD(1) 824.80 5.68 104.49 823.79 734.69 -9.58 26.69 746,740.62 61,159.23 0.55 27.43 MWD(1) 9/17/2013 11:18:45AM Page 2 COMPASS 2003.16 Build 73 • Halliburton Company • Definitive Survey Report Company: Cook Inlet Energy Local Co-ordinate Reference: Well Redoubt Unit#1 Project: COOK INLET BASIN TVD Reference: Redoubt Unit#1A(Rig 35)@ 89.10ft(89.1KB+40' Site: REDOUBT SHOAL MD Reference: Redoubt Unit#1A(Rig 35)@ 89.10ft(89.1KB+40' Well: Redoubt Unit#1 North Reference: Grid Wellbore: RU-1 A Survey Calculation Method: Minimum Curvature Design: RU-1 A Database: .16 prd Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 914.73 5.73 104.98 913.27 824.17 -11.86 35.34 746,739.93 61,161.87 0.08 36.24 MWD(1) 1,004.70 6.86 107.75 1,002.70 913.60 -14.66 44.79 746,739.08 61,164.75 1.30 45.90 MWD(1) 1,092.50 9.28 107.48 1,089.63 1,000.53 -18.38 56.54 746,737.94 61,168.33 2.76 57.93 MWD(1) 1,190.25 10.36 105.68 1,185.94 1,096.84 -23.12 72.52 746,736.50 61,173.20 1.15 74.26 MWD(1) 1,284.97 11.92 106.57 1,278.87 1,189.77 -28.22 90.10 746,734.94 61,178.56 1.66 92.22 MWD(1) 1,381.39 12.17 105.61 1,373.17 1,284.07 -33.79 109.43 746,733.25 61,184.45 0.33 111.96 MWD(1) 1,476.21 13.48 104.74 1,465.62 1,376.52 -39.29 129.75 746,731.57 61,190.64 1.40 132.68 MWD(1) 1,570.15 16.38 106.09 1,556.38 1,467.28 -45.75 153.07 746,729.60 61,197.75 3.11 156.47 MWD(1) 1,665.48 19.17 107.35 1,647.15 1,558.05 -54.14 180.93 746,727.04 61,206.24 2.95 184.96 MWD(1) 1,761.84 19.78 106.80 1,738.00 1,648.90 -63.58 211.64 746,724.17 61,215.60 0.66 216.37 MWD(1) 1,857.49 20.04 107.87 1,827.93 1,738.83 -73.28 242.73 746,721.21 61,225.08 0.47 248.19 MWD(2) 1,955.04 22.47 108.85 1,918.84 1,829.74 -84.44 276.28 746,717.81 61,235.31 2.52 282.59 MWD(2) 2,049.80 25.44 109.68 2,005.43 1,916.33 -97.14 312.59 746,713.94 61,246.38 3.15 319.87 MWD(2) 2,144.63 28.51 110.36 2,089.93 2,000.83 -111.88 353.00 746,709.44 61,258.69 3.25 361.41 MWD(2) 2,240.36 31.55 110.92 2,172.80 2,083.70 -128.78 397.82 746,704.29 61,272.35 3.19 407.53 MWD(2) 2,336.00 33.62 108.58 2,253.39 2,164.29 -146.15 446.30 746,699.00 61,287.13 2.53 457.34 MWD(2) 2,430.49 35.40 104.52 2,331.26 2,242.16 -161.35 497.60 746,694.37 61,302.77 3.08 509.77 MWD(2) 2,523.21 36.01 103.58 2,406.55 2,317.45 -174.48 550.09 746,690.36 61,318.77 0.88 563.21 MWD(2) 2,616.67 36.06 102.00 2,482.13 2,393.03 -186.65 603.71 746,686.65 61,335.11 1.00 617.68 MWD(2) 2,712.20 36.25 100.52 2,559.26 2,470.16 -197.65 658.98 746,683.30 61,351.95 0.94 673.70 MWD(2) 2,808.39 36.43 100.09 2,636.74 2,547.64 -207.85 715.06 746,680.19 61,369.05 0.32 730.45 MWD(2) 2,906.52 36.56 99.85 2,715.63 2,626.53 -217.96 772.54 746,677.11 61,386.57 0.20 788.60 MWD(2) 3,000.39 36.54 101.38 2,791.04 2,701.94 -228.25 827.48 746,673.97 61,403.31 0.97 844.23 MWD(2) 3,099.56 36.71 101.42 2,870.63 2,781.53 -239.95 885.48 746,670.41 61,420.99 0.17 903.02 MWD(2) 3,192.23 36.84 100.50 2,944.86 2,855.76 -250.49 939.94 746,667.19 61,437.59 0.61 958.20 MWD(2) 3,288.27 36.49 102.59 3,021.90 2,932.80 -261.96 996.12 746,663.70 61,454.72 1.35 1,015.17 MWD(2) 3,385.17 36.41 103.18 3,099.85 3,010.75 -274.80 1,052.24 746,659.78 61,471.82 0.37 1,072.19 MWD(2) 3,478.26 36.45 103.61 3,174.74 3,085.64 -287.61 1,106.02 746,655.88 61,488.21 0.28 1,126.88 MWD(2) 3,573.68 36.49 102.97 3,251.48 3,162.38 -300.65 1,161.22 746,651.91 61,505.04 0.40 1,183.00 MWD(2) 3,670.04 36.58 102.94 3,328.90 3,239.80 -313.51 1,217.12 746,647.99 61,522.08 0.10 1,239.82 MWD(2) 3,766.23 36.50 103.24 3,406.19 3,317.09 -326.48 1,272.91 746,644.03 61,539.08 0.20 1,296.52 MWD(2) 3,861.96 36.29 102.42 3,483.24 3,394.14 -339.09 1,328.29 746,640.19 61,555.96 0.55 1,352.79 MWD(2) 3,957.44 36.19 102.10 3,560.25 3,471.15 -351.08 1,383.44 746,636.54 61,572.77 0.22 1,408.78 MWD(2) 4,051.33 36.63 101.31 3,635.82 3,546.72 -362.38 1,438.01 746,633.09 61,589.40 0.68 1,464.13 MWD(2) 4,147.70 36.43 103.19 3,713.26 3,624.16 -374.55 1,494.07 746,629.38 61,606.49 1.18 1,521.03 MWD(2) 4,243.71 36.82 104.39 3,790.31 3,701.21 -388.20 1,549.69 746,625.22 61,623.44 0.85 1,577.63 MWD(2) 4,339.42 37.05 104.94 3,866.81 3,777.71 -402.76 1,605.33 746,620.78 61,640.40 0.42 1,634.32 MWD(2) 4,433.24 36.66 105.63 3,941.88 3,852.78 -417.60 1,659.61 746,616.26 61,656.95 0.61 1,689.69 MWD(2) 4,531.31 36.87 110.77 4,020.47 3,931.37 -435.92 1,715.33 746,610.67 61,673.93 3.14 1,746.79 MWD(2) 4,627.70 36.69 111.03 4,097.67 4,008.57 -456.51 1,769.24 746,604.40 61,690.36 0.25 1,802.30 MWD(2) 9/17/2013 11:18:45AM Page 3 COMPASS 2003.16 Build 73 • Halliburton Company • Definitive Survey Report Company: Cook Inlet Energy Local Co-ordinate Reference: Well Redoubt Unit#1 Project: COOK INLET BASIN TVD Reference: Redoubt Unit#1A(Rig 35)@ 89.10ft(89.1 KB+40' Site: REDOUBT SHOAL MD Reference: Redoubt Unit#1A(Rig 35)@ 89.10ft(89.1KB+40' Well: Redoubt Unit#1 North Reference: Grid Wellbore: RU-1 A Survey Calculation Method: Minimum Curvature Design: RU-1 A Database: .16 prd Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,723.74 36.46 109.83 4,174.80 4,085.70 -476.49 1,822.87 746,598.31 61,706.71 0.78 1,857.46 MWD(2) 4,820.36 36.39 110.12 4,252.54 4,163.44 -496.09 1,876.79 746,592.34 61,723.14 0.19 1,912.88 MWD(2) 4,916.42 36.21 108.84 4,329.96 4,240.86 -515.05 1,930.40 746,586.56 61,739.48 0.81 1,967.94 MWD(2) 5,011.27 36.09 110.44 4,406.55 4,317.45 -533.85 1,983.09 746,580.83 61,755.54 1.00 2,022.07 MWD(2) 5,107.38 35.90 110.02 4,484.31 4,395.21 -553.39 2,036.09 746,574.87 61,771.70 0.32 2,076.57 MWD(2) 5,202.09 36.87 109.03 4,560.56 4,471.46 -572.16 2,089.04 746,569.15 61,787.84 1.20 2,130.96 MWD(2) 5,298.66 37.27 107.95 4,637.61 4,548.51 -590.62 2,144.25 746,563.52 61,804.66 0.79 2,187.56 MWD(2) 5,394.68 37.49 107.82 4,713.91 4,624.81 -608.52 2,199.72 746,558.07 61,821.57 0.24 2,244.39 MWD(2) 5,488.57 37.50 107.86 4,788.40 4,699.30 -626.03 2,254.13 746,552.73 61,838.16 0.03 2,300.11 MWD(2) 5,583.79 37.36 108.04 4,864.02 4,774.92 -643.86 2,309.18 746,547.29 61,854.94 0.19 2,356.51 MWD(2) 5,682.44 37.12 107.39 4,942.55 4,853.45 -662.03 2,366.05 746,541.76 61,872.27 0.47 2,414.75 MWD(2) 5,778.34 36.70 107.60 5,019.23 4,930.13 -679.34 2,420.98 746,536.48 61,889.01 0.46 2,470.98 MWD(2) 5,873.09 36.50 107.47 5,095.30 5,006.20 -696.36 2,474.85 746,531.29 61,905.43 0.23 2,526.12 MWD(2) 5,969.88 36.75 106.88 5,172.98 5,083.88 -713.41 2,530.01 746,526.10 61,922.25 0.45 2,582.56 MWD(2) 6,065.16 36.63 106.88 5,249.38 5,160.28 -729.94 2,584.49 746,521.06 61,938.85 0.13 2,638.27 MWD(2) 6,163.48 36.68 105.62 5,328.26 5,239.16 -746.37 2,640.84 746,516.05 61,956.03 0.77 2,695.84 MWD(2) 6,258.55 36.72 105.77 5,404.49 5,315.39 -761.74 2,695.54 746,511.37 61,972.70 0.10 2,751.67 MWD(2) 6,353.25 36.64 105.58 5,480.43 5,391.33 -777.02 2,750.00 746,506.71 61,989.30 0.15 2,807.26 MWD(2) 6,448.92 36.81 105.86 5,557.11 5,468.01 -792.52 2,805.07 746,501.98 62,006.08 0.25 2,863.47 MWD(2) 6,543.97 36.74 106.20 5,633.25 5,544.15 -808.23 2,859.76 746,497.19 62,022.75 0.23 2,919.32 MWD(2) 6,637.59 36.73 106.63 5,708.28 5,619.18 -824.06 2,913.47 746,492.37 62,039.13 0.27 2,974.21 MWD(2) 6,739.10 36.60 106.75 5,789.70 5,700.60 -841.47 2,971.54 746,487.07 62,056.82 0.15 3,033.57 MWD(2) 6,834.80 36.32 106.11 5,866.67 5,777.57 -857.55 3,026.08 746,482.16 62,073.45 0.49 3,089.31 MWD(2) 6,928.01 36.35 106.31 5,941.76 5,852.66 -872.97 3,079.11 746,477.46 62,089.61 0.13 3,143.48 MWD(2) 7,030.44 36.62 105.78 6,024.11 5,935.01 -889.80 3,137.65 746,472.33 62,107.45 0.41 3,203.26 MWD(3) 7,126.14 36.84 106.28 6,100.81 6,011.71 -905.61 3,192.65 746,467.51 62,124.22 0.39 3,259.43 MWD(3) 7,221.78 36.40 107.29 6,177.58 6,088.48 -922.08 3,247.27 746,462.49 62,140.87 0.78 3,315.28 MWD(3) 7,317.93 36.39 106.36 6,254.97 6,165.87 -938.59 3,301.88 746,457.46 62,157.51 0.57 3,371.12 MWD(3) 7,413.61 36.15 106.69 6,332.11 6,243.01 -954.69 3,356.15 746,452.55 62,174.05 0.32 3,426.58 MWD(3) 7,510.13 35.97 107.15 6,410.14 6,321.04 -971.23 3,410.50 746,447.51 62,190.62 0.34 3,482.17 MWD(3) 7,604.70 35.77 107.22 6,486.77 6,397.67 -987.60 3,463.44 746,442.52 62,206.76 0.22 3,536.34 MWD(3) 7,699.73 35.62 107.03 6,563.95 6,474.85 -1,003.92 3,516.43 746,437.55 62,222.91 0.20 3,590.55 MWD(3) 7,795.74 35.35 107.63 6,642.13 6,553.03 -1,020.52 3,569.63 746,432.49 62,239.12 0.46 3,644.99 MWD(3) 7,892.37 35.20 106.51 6,721.02 6,631.92 -1,036.91 3,622.97 746,427.49 62,255.38 0.69 3,699.56 MWD(3) 7,988.10 34.62 107.14 6,799.52 6,710.42 -1,052.76 3,675.41 746,422.66 62,271.37 0.71 3,753.18 MWD(3) 8,017.77 34.60 106.80 6,823.94 6,734.84 -1,057.68 3,691.53 746,421.16 62,276.28 0.65 3,769.67 MWD(3) 8,113.81 34.67 107.20 6,902.96 6,813.86 -1,073.64 3,743.73 746,416.30 62,292.19 0.25 3,823.06 MWD(3) 8,209.91 34.94 107.32 6,981.87 6,892.77 -1,089.91 3,796.11 746,411.34 62,308.15 0.29 3,876.66 MWD(3) 8,302.05 34.65 107.64 7,057.53 6,968.43 -1,105.71 3,846.26 746,406.52 62,323.44 0.37 3,928.00 MWD(3) 8,398.43 36.43 106.56 7,135.96 7,046.86 -1,122.17 3,899.81 746,401.51 62,339.76 1.96 3,982.77 MWD(3) 9/17/2013 11:18:45AM Page 4 COMPASS 2003.16 Build 73 Halliburton Company S Definitive Survey Report Company: Cook Inlet Energy Local Co-ordinate Reference: Well Redoubt Unit#1 Project: COOK INLET BASIN TVD Reference: Redoubt Unit#1A(Rig 35)@ 89.10ft(89.1KB+40 Site: REDOUBT SHOAL MD Reference: Redoubt Unit#1A(Rig 35)@ 89.10ft(89.1 KB+40' Well: Redoubt Unit#1 North Reference: Grid Wellbore: RU-1 A Survey Calculation Method: Minimum Curvature Design: RU-1 A Database: .16 prd Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 8,494.88 36.68 106.81 7,213.43 7,124.33 -1,138.66 3,954.84 746,396.48 62,356.53 0.30 4,039.03 MWD(3) 8,591.52 36.75 107.12 7,290.90 7,201.80 -1,155.52 4,010.10 746,391.34 62,373.38 0.20 4,095.55 MWD(3) 8,687.37 36.70 106.94 7,367.73 7,278.63 -1,172.31 4,064.90 746,386.23 62,390.08 0.12 4,151.60 MWD(3) 8,782.68 36.47 107.04 7,444.26 7,355.16 -1,188.90 4,119.23 746,381.17 62,406.64 0.25 4,207.17 MWD(3) 8,880.44 36.07 107.91 7,523.08 7,433.98 -1,206.27 4,174.39 746,375.87 62,423.45 0.67 4,263.64 MWD(3) 8,974.98 37.25 107.81 7,598.92 7,509.82 -1,223.58 4,228.12 746,370.60 62,439.83 1.25 4,318.67 MWD(3) 9,070.64 36.98 108.10 7,675.20 7,586.10 -1,241.37 4,283.03 746,365.17 62,456.57 0.34 4,374.92 MWD(3) 9,175.99 36.92 108.05 7,759.39 7,670.29 -1,261.02 4,343.23 746,359.18 62,474.92 0.06 4,436.61 MWD(3) 9,262.85 37.15 107.97 7,828.73 7,739.63 -1,277.20 4,392.98 746,354.25 62,490.08 0.27 4,487.58 MWD(3) 9,358.72 37.42 106.33 7,905.01 7,815.91 -1,294.32 4,448.47 746,349.04 62,506.99 1.07 4,544.35 MWD(3) 9,454.32 36.95 106.69 7,981.17 7,892.07 -1,310.74 4,503.87 746,344.03 62,523.88 0.54 4,600.97 MWD(3) 9,549.51 36.23 108.25 8,057.60 7,968.50 -1,327.76 4,557.99 746,338.84 62,540.38 1.24 4,656.37 MWD(3) 9,645.31 36.43 106.96 8,134.78 8,045.68 -1,344.93 4,612.09 746,333.61 62,556.86 0.82 4,711.75 MWD(3) 9,740.66 36.29 106.44 8,211.57 8,122.47 -1,361.17 4,666.23 746,328.66 62,573.37 0.36 4,767.11 MWD(3) 9,819.64 35.70 106.53 8,275.47 8,186.37 -1,374.34 4,710.74 746,324.64 62,586.93 0.75 4,812.60 MWD(3) 9,915.60 37.40 105.66 8,352.55 8,263.45 -1,390.18 4,765.65 746,319.82 62,603.67 1.85 4,868.67 MWD(3) 10,010.96 37.39 105.48 8,428.31 8,339.21 -1,405.72 4,821.43 746,315.08 62,620.67 0.12 4,925.60 MWD(3) 10,105.30 36.99 104.91 8,503.47 8,414.37 -1,420.67 4,876.46 746,310.52 62,637.45 0.56 4,981.73 MWD(3) 10,200.58 36.97 103.74 8,579.58 8,490.48 -1,434.85 4,931.99 746,306.20 62,654.37 0.74 5,038.28 MWD(3) 10,296.99 36.29 104.98 8,656.95 8,567.85 -1,449.11 4,987.72 746,301.85 62,671.36 1.04 5,095.04 MWD(3) 10,392.93 36.91 106.86 8,733.98 8,644.88 -1,464.80 5,042.72 746,297.07 62,688.12 1.34 5,151.20 MWD(3) 10,486.16 35.94 107.74 8,808.99 8,719.89 -1,481.26 5,095.57 746,292.06 62,704.23 1.18 5,205.28 MWD(3) 10,581.07 35.54 107.96 8,886.03 8,796.93 -1,498.25 5,148.34 746,286.88 62,720.31 0.44 5,259.33 MWD(3) 10,774.76 35.37 107.71 9,043.80 8,954.70 -1,532.67 5,255.29 746,276.39 62,752.91 0.12 5,368.87 MWD(3) 10,869.18 35.47 108.97 9,120.75 9,031.65 -1,549.88 5,307.23 746,271.14 62,768.74 0.78 5,422.12 MWD(3) 10,965.73 35.49 109.13 9,199.37 9,110.27 -1,568.17 5,360.20 746,265.56 62,784.89 0.10 5,476.48 MWD(3) 11,063.36 35.53 106.90 9,278.85 9,189.75 -1,585.71 5,414.12 746,260.22 62,801.32 1.33 5,531.72 MWD(3) 11,157.03 35.67 107.78 9,355.01 9,265.91 -1,601.96 5,466.17 746,255.27 62,817.19 0.57 5,584.99 MWD(3) 11,252.47 36.00 108.49 9,432.38 9,343.28 -1,619.35 5,519.27 746,249.96 62,833.37 0.56 5,639.40 MWD(3) 11,348.10 37.10 105.27 9,509.21 9,420.11 -1,635.87 5,573.75 746,244.93 62,849.98 2.31 5,695.12 MWD(3) 11,443.78 36.93 106.08 9,585.61 9,496.51 -1,651.43 5,629.21 746,240.19 62,866.88 0.54 5,751.72 MWD(3) 11,536.97 37.34 105.86 9,659.90 9,570.80 -1,666.91 5,683.30 746,235.47 62,883.37 0.46 5,806.95 MWD(3) 11,633.70 37.06 105.99 9,736.95 9,647.85 -1,682.95 5,739.54 746,230.58 62,900.51 0.30 5,864.38 MWD(3) 11,728.96 35.89 106.03 9,813.55 9,724.45 -1,698.57 5,793.97 746,225.82 62,917.10 1.23 5,919.96 MWD(3) 11,825.13 35.51 103.91 9,891.65 9,802.55 -1,713.07 5,848.18 746,221.40 62,933.62 1.35 5,975.23 MWD(3) 11,921.90 35.95 104.36 9,970.21 9,881.11 -1,726.87 5,902.98 746,217.19 62,950.33 0.53 6,031.02 MWD(3) 12,017.91 35.30 105.91 10,048.25 9,959.15 -1,741.46 5,956.96 746,212.75 62,966.78 1.16 6,086.07 MWD(3) 12,113.68 34.74 103.84 10,126.68 10,037.58 -1,755.58 6,010.07 746,208.44 62,982.97 1.37 6,140.20 MWD(3) 12,207.05 36.46 102.24 10,202.60 10,113.50 -1,767.82 6,063.01 746,204.71 62,999.11 2.09 6,194.02 MWD(3) 12,263.00 37.10 103.10 10,247.41 10,158.31 -1,775.17 6,095.70 746,202.47 63,009.07 1.47 6,227.22 MWD_Interp Azi+sag(4) 9/17/2013 11:18:45AM Page 5 COMPASS 2003.16 Build 73 • Halliburton Company • Definitive Survey Report Company: Cook Inlet Energy Local Co-ordinate Reference: Well Redoubt Unit#1 Project: COOK INLET BASIN TVD Reference: Redoubt Unit#1A(Rig 35)@ 89.10ft(89.1 KB+40' Site: REDOUBT SHOAL MD Reference: Redoubt Unit#1A(Rig 35)@ 89.10ft(89.1 KB+40' Well: Redoubt Unit#1 North Reference: Grid Wellbore: RU-1 A Survey Calculation Method: Minimum Curvature Design: RU-1 A Database: .16 prd Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (0/10(Y) (ft) Survey Tool Name 12,330.35 37.42 101.33 10,301.02 10,211.92 -1,783.80 6,135.55 746,199.84 63,021.21 1.66 6,267.67 MWD_InterpAzi+sag(4) 12,377.28 37.31 100.10 10,338.32 10,249.22 -1,789.09 6,163.53 746,198.23 63,029.74 1.61 6,296.01 MWD_Interp Azi+sag(4) 12,435.11 36.72 98.59 10,384.50 10,295.40 -1,794.75 6,197.88 746,196.50 63,040.21 1.87 6,330.72 MWD_Interp Azi+sag(4) 12,473.34 36.46 97.58 10,415.19 10,326.09 -1,797.96 6,220.44 746,195.53 63,047.09 1.72 6,353.47 MWD_Interp Azi+sag(4) 12,566.01 37.32 95.16 10,489.31 10,400.21 -1,804.11 6,275.72 746,193.65 63,063.94 1.82 6,409.07 MWD_Interp Azi+sag(4) 12,660.34 38.50 94.55 10,563.74 10,474.64 -1,809.02 6,333.47 746,192.16 63,081.54 1.31 6,467.03 MWD+SC+sag(5) 12,754.77 40.28 94.28 10,636.71 10,547.61 -1,813.63 6,393.21 746,190.75 63,099.75 1.89 6,526.95 MWD+SC+sag(5) 12,851.49 39.39 94.32 10,710.98 10,621.88 -1,818.27 6,454.99 746,189.33 63,118.58 0.92 6,588.90 MWD+SC+sag(5) 12,945.91 36.74 95.68 10,785.31 10,696.21 -1,823.32 6,512.98 746,187.79 63,136.26 2.94 6,647.11 MWD+SC+sag(5) 13,040.26 34.55 95.34 10,861.98 10,772.88 -1,828.61 6,567.71 746,186.18 63,152.94 2.33 6,702.09 MWD+SC+sag(5) 13,131.75 34.94 95.60 10,937.16 10,848.06 -1,833.58 6,619.61 746,184.67 63,168.76 0.46 6,754.23 MWD+SC+sag(5) 13,226.97 35.39 95.10 11,015.00 10,925.90 -1,838.69 6,674.21 746,183.11 63,185.40 0.56 6,809.07 MWD+SC+sag(5) 13,322.52 34.04 93.60 11,093.54 11,004.44 -1,842.83 6,728.46 746,181.85 63,201.94 1.67 6,863.47 MWD+SC+sag(5) 13,416.95 34.10 92.19 11,171.77 11,082.67 -1,845.50 6,781.29 746,181.03 63,218.04 0.84 6,916.33 MWD+SC+sag(5) 13,510.51 34.20 91.53 11,249.19 11,160.09 -1,847.20 6,833.79 746,180.52 63,234.04 0.41 6,968.78 MWD+SC+sag(5) 13,605.11 33.82 91.53 11,327.61 11,238.51 -1,848.62 6,886.68 746,180.08 63,250.16 0.40 7,021.59 MWD+SC+sag(5) 13,699.07 32.29 92.17 11,406.36 11,317.26 -1,850.27 6,937.90 746,179.58 63,265.77 1.67 7,072.76 MWD+SC+sag(5) 13,793.55 31.23 92.44 11,486.69 11,397.59 -1,852.26 6,987.59 746,178.97 63,280.92 1.13 7,122.44 MWD+SC+sag(5) 13,888.61 31.73 92.74 11,567.76 11,478.66 -1,854.51 7,037.18 746,178.29 63,296.03 0.55 7,172.03 MWD+SC+sag(5) 13,963.01 32.69 96.58 11,630.72 11,541.62 -1,857.75 7,076.69 746,177.30 63,308.07 3.04 7,211.67 MWD+SC+sag(5) 14,003.90 32.71 95.37 11,665.13 11,576.03 -1,860.05 7,098.66 746,176.60 63,314.77 1.60 7,233.76 MWD+SC+sag(5) 14,102.01 34.54 96.69 11,746.82 11,657.72 -1,865.77 7,152.68 746,174.86 63,331.24 2.01 7,288.07 MWD+SC+sag(5) 14,195.18 36.30 95.71 11,822.74 11,733.64 -1,871.59 7,206.36 746,173.08 63,347.60 1.98 7,342.05 MWD+SC+sag(5) 14,287.74 37.05 93.58 11,896.98 11,807.88 -1,876.06 7,261.45 746,171.72 63,364.39 1.60 7,397.33 MWD+SC+sag(5) 14,382.05 37.38 91.24 11,972.09 11,882.99 -1,878.45 7,318.43 746,170.99 63,381.76 1.54 7,454.30 MWD+SC+sag(5) 14,474.00 36.83 86.75 12,045.44 11,956.34 -1,877.49 7,373.86 746,171.28 63,398.65 3.01 7,509.44 MWD+SC+sag(5) 14,572.25 37.17 78.35 12,123.96 12,034.86 -1,869.82 7,432.37 746,173.62 63,416.49 5.15 7,567.05 MWD+SC+sag(5) 14,665.24 36.54 72.79 12,198.38 12,109.28 -1,855.96 7,486.34 746,177.85 63,432.94 3.65 7,619.61 MWD+SC+sag(5) 14,759.72 38.07 68.43 12,273.54 12,184.44 -1,836.92 7,540.31 746,183.65 63,449.39 3.23 7,671.72 MWD+SC+sag(5) 14,855.16 37.86 64.27 12,348.80 12,259.70 -1,813.38 7,594.07 746,190.82 63,465.77 2.69 7,723.22 MWD+SC+sag(5) 14,949.59 37.88 60.19 12,423.36 12,334.26 -1,786.39 7,645.33 746,199.05 63,481.40 2.65 7,771.94 MWD+SC+sag(5) 15,011.23 38.31 58.37 12,471.87 12,382.77 -1,766.96 7,678.02 746,204.97 63,491.36 1.95 7,802.81 MWD+SC+sag(5) 15,050.00 38.31 58.37 12,502.29 12,413.19 -1,754.36 7,698.49 746,208.82 63,497.60 0.00 7,822.09 PROJECTED to TD 9/17/2013 11:18:45AM Page 6 COMPASS 2003.16 Build 73 • I Scblumberger FracCADE* STIMULATION PROPOSAL Operator : Glacier O&G Well : RU-01A Field : Redoubt Formation : Upper Hemlock Top Well Location : Osprey Platform County a State : Alaska Country : United States m Prepared for : Anna Belanger Service Point : Prudhoe Bay Proposal No. Business Phone : 907 2731788 Date Prepared : 31 Dec 2016 FAX No. : 907 561 8317 Prepared by : Gunther Rutzinger Phone : 907 223 9527 E-Mail Address : grutzinger@slb.com Mark of Schlumberger Disclaimer Notice: This information is presented in good faith,but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service.The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment.The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model,the assumptions and such input data.The information presented is Schlumberger's best estimate of the actual results that may he achieved and should be used for comparison purposes rather than absolute values.The quality of input data,and hence results,may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well,the reservoir,the field and conditions affecting them.If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue.Actual charges may vary depending upon time,equipment,and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. • ! Client : Glacier O&Gcwlnkrgcr Well : RU-01A Formation : Upper Hemlock Top District : Prudhoe Bay Country : United States Loadcase : 5 RU-01A Upper Hemlock Top Contents Section 1: Wellbore Configuration 3 Section 2: Zone Data 4 Section 3: Propped Fracture Schedule 7 Section 4: Propped Fracture Simulation Results 10 Section 5: Propped Fracture Simulation 11 Section 6: Treatment Fluid Data 14 Section 7: Proppant Data 15 Section 8: Hole Survey 16 2 • • Well Client : RU-01A: Glacier O&G U0180&GCIlluGIe1 Formation : Upper Hemlock Top "t u District : Prudhoe Bay Country : United States Loadcase : 5 RU-01A Upper Hemlock Top Section 1: Wellbore Configuration 0 Bottom Hole Temperature 190 degF Deviated Hole YES Treat Down TUBING Well Type Vertical Well Location OffShore 3762 - Tubing Data OD Weight ID Depth (in) (lb/ft) (in) (ft) 3.500 12.7 2.750 12589.0 Casing Data 7525 - OD Weight ID Depth (in) (lb/ft) (in) (ft) 9.625 47.0 8.681 12589.0 3.500 12.7 2.750 15050.0 Perforation Data Top Top Bottom Bottom Shot Number Diameter 11288 - MD ND MD TVD Density (ft) (ft) (ft) (ft) (shot/ft) (in) - - 14132.0 11771.4 14142.0 11779.6 6.00 60 0.32 Offshore 15050 Ocean Depth 50.0 Ocean Bed Temperature 39 Ocean Surface Current Velocity 50.63 r a n r d - a r 3 • • Client : Glacier O&G Schlumberger Well : RU-01A Formation : Upper Hemlock Top District : Prudhoe Bay Country : United States Loadcase : 5 RU-01A Upper Hemlock Top Section 2: Zone Data Formation Mechanical Properties Zone Name Top TVD Zone Frac Insitu Young's Poisson's Toughness (ft) Height Grad. Stress Modulus Ratio (psi.ino.5) (ft) (psi/ft) (psi) (psi) Hemlock Coal 11695.4 4.2 0.965 11288 2.000E+6 0.30 1000 SHALE 11699.6 3.3 1.069 12509 2.540E+6 0.33 1000 SHALE 11702.9 4.2 1.041 12185 2.370E+6 0.39 1000 SHALE 11707.1 3.3 1.148 13442 3.780E+6 0.33 1000 COAL 11710.4 5.8 1.006 11784 1.600E+6 0.45 1000 SHALE 11716.2 5.0 0.799 9363 1.850E+6 0.37 1000 DIRTY-SANDSTONE 11721.2 3.3 0.940 11019 1.730E+6 0.25 700 COAL 11724.5 4.1 0.857 10050 1.340E+6 0.36 1000 DIRTY-SANDSTONE 11728.6 5.8 0.828 9714 2.510E+6 0.27 700 DIRTY-SANDSTONE 11734.4 6.6 0.787 9238 2.020E+6 0.28 700 DIRTY-SANDSTONE 11741.0 14.0 0.817 9598 2.690E+6 0.23 700 Upper Hemlock 11755.0 8.2 0.798 9384 3.050E+6 0.24 700 DIRTY-SANDSTONE 11763.2 10.2 0.774 9109 3.560E+6 0.23 700 CLEAN-SANDSTONE 11773.5 2.9 0.828 9750 4.790E+6 0.20 1200 DIRTY-SANDSTONE 11776.3 13.0 0.907 10687 3.300E+6 0.25 700 SILTSTONE 11789.4 4.9 0.802 9457 4.840E+6 0.26 1000 m DIRTY-SANDSTONE 11794.3 4.1 0.830 9791 4.100E+6 0.23 700 DIRTY-SANDSTONE 11798.3 8.1 0.781 9218 2.580E+6 0.25 700 DIRTY-SANDSTONE 11806.4 6.5 0.796 9401 3.560E+6 0.21 700 DIRTY-SANDSTONE 11812.9 12.1 0.815 9632 3.530E+6 0.22 700 DIRTY-SANDSTONE 11825.0 4.0 0.737 8717 3.810E+6 0.24 700 CLEAN-SANDSTONE 11829.0 3.2 0.831 9831 3.940E+6 0.19 1200 DIRTY-SANDSTONE 11832.3 10.5 0.789 9340 3.620E+6 0.24 700 DIRTY-SANDSTONE 11842.7 15.3 0.916 10855 3.770E+6 0.21 700 SILTSTONE 11858.0 15.2 0.975 11569 2.760E+6 0.28 1000 SHALE 11873.2 5.6 0.811 9631 3.430E+6 0.30 1000 DIRTY-SANDSTONE 11878.8 11.2 0.916 10886 4.240E+6 0.22 700 SILTSTONE 11890.0 8.8 0.822 9777 3.940E+6 0.27 1000 DIRTY-SANDSTONE 11898.8 4.0 0.903 10746 5.750E+6 0.18 700 SILTSTONE 11902.8 2.4 0.835 9940 4.360E+6 0.27 1000 DIRTY-SANDSTONE 11905.2 3.2 0.890 10597 3.050E+6 0.30 700 Silt Zone 11908.4 9.6 0.844 10055 2.400E+6 0.34 1000 SHALE 11917.9 10.4 0.910 10850 2.770E+6 0.28 100 SILTSTONE 11928.3 18.3 0.824 9836 3.040E+6 0.28 1000 DIRTY-SANDSTONE 11946.6 11.9 0.862 10303 3.440E+6 0.24 700 DIRTY-SANDSTONE 11958.5 8.7 0.802 9594 3.490E+6 0.24 700 DIRTY-SANDSTONE 11967.3 3.2 0.702 8402 4.160E+6 0.22 700 Middle Hemlock 11970.5 4.0 0.850 10177 4.640E+6 0.16 1200 DIRTY-SANDSTONE 11974.4 8.0 0.939 11248 5.450E+6 0.20 700 4 S • Client : Glacier O&G Schlumberger Well : RU-01A Formation : Upper Hemlock Top District : Prudhoe Bay Country : United States Loadcase : 5 RU-01A Upper Hemlock Top SILTSTONE 11982.4 6.4 0.834 9996 2.640E+6 0.30 1000 DIRTY-SANDSTONE 11988.8 2.4 0.914 10959 3.210E+6 0.23 700 SILTSTONE 11991.1 2.4 0.857 10277 3.820E+6 0.27 1000 DIRTY-SANDSTONE 11993.5 4.0 0.995 11936 4.080E+6 0.25 700 SHALE 11997.5 11.2 0.891 10695 2.540E+6 0.33 1000 SILTSTONE 12008.7 5.6 0.709 8516 3.470E+6 0.25 1000 CLEAN-SANDSTONE 12014.3 26.4 0.761 9153 4.790E+6 0.15 1200 CLEAN-SANDSTONE 12040.6 27.2 0.816 9836 5.180E+6 0.17 1200 DIRTY-SANDSTONE 12067.8 4.0 0.948 11442 4.790E+6 0.21 700 SHALE 12071.8 3.1 0.787 9502 5.230E+6 0.26 1000 DIRTY-SANDSTONE 12075.0 4.3 0.587 7088 5.510E+6 0.19 700 Formation Transmissibility Properties Zone Name Top TVD Net Perm Porosity Res. Gas Oil Sat. Water (ft) Height Imdl 1%I Pressure Sat. 1%I Sat. (ft) (psi) (%) (%) Hemlock Coal 11695.4 1.3 0.100 10.0 3820 15.0 65.0 20.0 SHALE 11699.6 0.3 0.001 5.0 3821 15.0 65.0 20.0 SHALE 11702.9 0.4 0.001 5.0 3823 15.0 65.0 20.0 SHALE 11707.1 0.3 0.001 5.0 3825 15.0 65.0 20.0 COAL 11710.4 2.9 2.000 15.0 3826 15.0 65.0 20.0 SHALE 11716.2 0.5 0.001 5.0 3829 15.0 65.0 20.0 DIRTY-SANDSTONE 11721.2 2.6 2.000 15.0 3831 15.0 65.0 20.0 COAL 11724.5 2.1 2.000 15.0 3832 15.0 65.0 20.0 DIRTY-SANDSTONE 11728.6 4.6 2.000 15.0 3834 15.0 65.0 20.0 DIRTY-SANDSTONE 11734.4 5.3 2.000 15.0 3837 15.0 65.0 20.0 DIRTY-SANDSTONE 11741.0 11.2 2.000 15.0 3841 15.0 65.0 20.0 Upper Hemlock 11755.0 6.6 2.000 15.0 3846 15.0 65.0 20.0 DIRTY-SANDSTONE 11763.2 8.2 2.000 15.0 3850 15.0 65.0 20.0 CLEAN-SANDSTONE 11773.5 2.9 10.000 18.0 3853 15.0 65.0 20.0 DIRTY-SANDSTONE 11776.3 10.4 2.000 15.0 3854 15.0 65.0 20.0 SILTSTONE 11789.4 1.5 0.100 10.0 3856 15.0 65.0 20.0 DIRTY-SANDSTONE 11794.3 3.3 2.000 15.0 3857 15.0 65.0 20.0 DIRTY-SANDSTONE 11798.3 6.5 2.000 15.0 3863 15.0 65.0 20.0 DIRTY-SANDSTONE 11806.4 5.2 2.000 15.0 3869 15.0 65.0 20.0 DIRTY-SANDSTONE 11812.9 9.7 2.000 15.0 3873 15.0 65.0 20.0 DIRTY-SANDSTONE 11825.0 3.2 2.000 15.0 3877 15.0 65.0 20.0 CLEAN-SANDSTONE 11829.0 3.2 10.000 18.0 3878 15.0 65.0 20.0 DIRTY-SANDSTONE 11832.3 8.4 2.000 15.0 3881 15.0 65.0 20.0 DIRTY-SANDSTONE 11842.7 12.2 2.000 15.0 3887 15.0 65.0 20.0 SILTSTONE 11858.0 4.6 0.100 10.0 3894 15.0 65.0 20.0 SHALE 11873.2 0.6 0.001 5.0 3899 15.0 65.0 20.0 DIRTY-SANDSTONE 11878.8 9.0 2.000 15.0 3903 15.0 65.0 20.0 SILTSTONE 11890.0 2.6 0.100 10.0 3908 15.0 65.0 20.0 DIRTY-SANDSTONE 11898.8 3.2 2.000 15.0 3912 15.0 65.0 20.0 5 • Client : Glacier O&G Schlumberger Well : RU-01A Formation : Upper Hemlock Top District : Prudhoe Bay country : United States Loadcase : 5 RU-01A Upper Hemlock Top SILTSTONE 11902.8 0.7 0.100 10.0 3914 15.0 65.0 20.0 DIRTY-SANDSTONE 11905.2 2.6 2.000 15.0 3916 15.0 65.0 20.0 Silt Zone 11908.4 2.9 0.100 10.0 3918 15.0 65.0 20.0 SHALE 11917.9 1.0 0.001 5.0 3921 15.0 65.0 20.0 SILTSTONE 11928.3 5.5 0.100 10.0 3928 15.0 65.0 20.0 DIRTY-SANDSTONE 11946.6 9.5 2.000 15.0 3935 15.0 65.0 20.0 DIRTY-SANDSTONE 11958.5 7.0 2.000 15.0 3940 15.0 65.0 20.0 DIRTY-SANDSTONE 11967.3 2.6 2.000 15.0 3943 15.0 65.0 20.0 Middle Hemlock 11970.5 4.0 10.000 18.0 3944 15.0 65.0 20.0 DIRTY-SANDSTONE 11974.4 6.4 2.000 15.0 3947 15.0 65.0 20.0 SILTSTONE 11982.4 1.9 0.100 10.0 3951 15.0 65.0 20.0 DIRTY-SANDSTONE 11988.8 1.9 2.000 15.0 3953 15.0 65.0 20.0 SILTSTONE 11991.1 0.7 0.100 10.0 3954 15.0 65.0 20.0 DIRTY-SANDSTONE 11993.5 3.2 2.000 15.0 3955 15.0 65.0 20.0 SHALE 11997.5 1.1 0.001 5.0 3959 15.0 65.0 20.0 SILTSTONE 12008.7 1.7 0.100 10.0 3963 15.0 65.0 20.0 CLEAN-SANDSTONE 12014.3 26.4 10.000 18.0 3970 15.0 65.0 20.0 CLEAN-SANDSTONE 12040.6 27.2 10.000 18.0 3982 15.0 65.0 20.0 DIRTY-SANDSTONE 12067.8 3.2 2.000 15.0 3990 15.0 65.0 20.0 SHALE 12071.8 0.3 0.001 5.0 3991 15.0 65.0 20.0 DIRTY-SANDSTONE 12075.0 3.4 2.000 15.0 3993 15.0 65.0 20.0 0 7 C. ro 6 • • Client : Glacier O&G Scll!inh ler Well : RU-01A Formation : Upper Hemlock Top District : Prudhoe Bay Country : United States Loadcase : 5 RU-01A Upper Hemlock Top Section 3: Propped Fracture Schedule Pumping Schedule The following is the Pumping Schedule to achieve a propped fracture half-length(Xi)of 375.1 ft with an average conductivity(Kfw)of 1183 md.ft. Job Description Step Pump Fluid Name Step Fluid Gel Prop. Prop. Name Rate Volume Conc. Type and Mesh Conc. (bbl/min) (gal) (lb/mgal) (PPA) PAD 20.0 YF127FIexD 8400 27.0 0.00 1.0 PPA 20.0 YF127FIexD 1606 27.0 20/40 CarboBond Lite 1.00 _ 2.0 PPA 20.0 YF127FIexD 1539 27.0 20/40 CarboBond Lite 2.00 3.0 PPA _ 20.0 YF127FIexD 1477 _ 27.0 20/40 CarboBond Lite 3.00 4.0 PPA 20.0 YF127FIexD 1419 27.0 20/40 CarboBond Lite 4.00 5.0 PPA 20.0 YF127FIexD 1366 27.0 20/40 CarboBond Lite 5.00 6.0 PPA _ 20.0 YF127FIexD 1317 27.0 20/40 CarboBond Lite 6.00 7.0 PPA 20.0 YF127FIexD 1271 27.0 20/40 CarboBond Lite 7.00 8.0 PPA 20.0 YF127FIexD 1229 27.0 20/40 CarboBond Lite 8.00 Flush 20.0 WF127 4234 27.0 0.00 Fluid Totals 19625 gal of YF127FIexD 4234 gal of WF127 Proppant Totals 48300 lb of 20/40 CarboBond Lite Pad Percentages %PAD Clean 42.8 %PAD Dirty 38.5 Job Execution MI Step Step Cum.Fluid Step Cum. Step Cum. Avg. Step Cum. Name Fluid Volume Slurry Slurry Prop Prop. Surface Time Time Volume (gall Volume Volume (lb) (lb) Pressure (min) (min) (gal) (bbl) (bbl) (psi) PAD 8400 8400 200.0 200.0 0 0 8825 10.0 10.0 1.0 PPA 1606 10006 40.0 240.0 1606 1606 8825 2.0 12.0 2.0 PPA 1539 11545 40.0 280.0 _ 3077 4684 8802 2.0 14.0 3.0 PPA 1477 13022 40.0 320.0 4430 9114 8886 2.0 16.0_ 4.0 PPA 1419 14441 40.0 360.0 5677 14791 8934 2.0 18.0 5.0 PPA 1366 15807 40.0 400.0 6832 21623 8850 2.0 20.0 6.0 PPA 1317 17124 40.0 440.0 7903 29526 8634 2.0 22.0 7.0 PPA 1271 18396 40.0 480.0 8900 38426 8454 2.0 24.0 8.0 PPA 1229 19625 40.0 520.0 9830 48255 8336 2.0 26.0 7 0 • Client : Glacier O&G Schlumberger Well : RU-01A Formation : Upper Hemlock Top District : Prudhoe Bay Country : United States Loadcase : 5 RU-01A Upper Hemlock Top Job Execution Step Step Cum.Fluid Step Cum. Step Cum. Avg. Step Cum. Name Fluid Volume Slurry Slurry Prop Prop. Surface Time Time Volume (gal) Volume Volume (lb) (lb) Pressure (min) (min) (gal) (bbl) (bbl) _ (psi) Flush 4234 23859 100.8 620.8 0 48255 8460 5.0 31.0 8 0 0 Client : Glacier O&G Schlumberger Well : RU-01A �j (��j Formation : Upper Hemlock Top District : Prudhoe Bay Country : United States Loadcase : 5 RU-01A Upper Hemlock Top Pumping Schedule Totals Summary for This Stage: Average Pump Rate 20.0 bbl/min Volume Weighted Average Rate 20.0 bbl/min Total Fluid Volume 568 bbl Total Proppant Mass 48300 lb Total Slurry Volume 620.8 bbl Total Pump Time 31.0 min Fluid Based Totals for This Stage Average Volume Total Total Total Total Fluid Pump Weighted Fluid Proppant Slurry Pump Rate Average Rate Volume Mass Volume Time (bbl/min) (bbl/min) (gal) (lb) (bbl) (min) YF127FIexD 20.0 20.0 19625 48255 520.0 26.0 WF127 20.0 20.0 4234 0 100.8 5.0 Proppant Based Totals for This Stage Average Volume Total Total Total Total Proppant Pump Weighted Fluid Proppant Slurry Pump Rate Average Rate Volume Mass Volume Time (bbl/min) (bbl/min) (gall (Ib) (bbl) (min) 20/40 CarboBond Lite 20.0 20.0 11225 48255 320.0 16.0 9 • • Client Glacier O&G Schlumberger Well : RU-01A Formation : Upper Hemlock Top District : Prudhoe Bay Country : United States Loadcase : 5 RU-01A Upper Hemlock Top Section 4: Propped Fracture Simulation Results (1) ACL Fracture Profile and Proppant Concentration Plot FracCADE" Glacier O&G RU-01 hRU-0ectA2016 llyper Hemlock Top ACL Fracture Profile and Proppant Concentration D 11650 11700- - - - - - <0.016/112 MI o.o-o.z 1b1t2 0.2-0 4 11,02 c r 04-061b02 Ib02 0.8-1.0 11,02 £ 11750- - - 1.0-1.211✓12 1.2-1 415,02 y 14-1.715,02 5 L.- .-.: - >1.7 16102 11800- - - - - - 4 Fractures 1 Initiation MD=14128258 11850 - .i 6000 9000 12000 -0.15 F-0'10 -005 -0 005 0.10 0.15 0 100 200 300 400 500 Strew-pa ACL Wolt at Wellbore-in Fracture Haliiength-fl (2) Treating Plot Bottomhole Pressure — Surface Pressure — Total Ins.Rate —f-- EOJ 12000 I __ _ -20 11000— -18 ��.. 10000 r 'ifi • '14 9000 -12 A 8000 10 0 - - ff 3 7000 '8 ' -6 6000 -4 5000 > -2 4000 I r I 0 0 10 20 30 40 50 Treatment Time-min 10 • 0 Well Client : RU-01A: 0&G Schlurger Formation : Upper Hemlock Top District : Prudhoe Bay Country : United States Loadcase : 5 RU-01A Upper Hemlock Top Section 5: Propped Fracture Simulation The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-D Vertical model.Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Initial Fracture Top TVD 11763.3 ft Initial Fracture Bottom TVD 11773.5 ft Propped Fracture Half-Length 375.1 ft EOJ Hyd Height at Well 71.3 ft Average Propped Width 0.123 in Average Gel Concentration 465.2 lb/mgal Average Gel Fluid Retained Factor 0.50 Net Pressure 1325 psi Efficiency 0.339 Effective Conductivity 849 md.ft Effective Fcd 1.1 Max Surface Pressure 8951 psi Simulation Results by Fracture Segment From To Prop.Conc. Propped Propped Frac. Frac. Fracture (ft) (ft) at End of Width Height Prop. Gel Conc. Conductivity Pumping (in) (ft) Conc. (Ib/mgal) (md.ft) (PPA) (Ib/ft2) 0.0 93.8 9.3 0.155 49.9 1.37 348.8 1525 93.8 187.5 7.7 0.136 52.8 1.17 397.8 1313 187.5 281.3 7.6 0.130 49.3 1.14 392.1 1259 281.3 375.1 4.0 0.074 41.1 0.65 703.5 716 Proppant packed at 375 ft after 26 bbl in step 5 11 • • Client : Glacier O&G Sehlumburger Well : RU-01A Formation : Upper Hemlock Top District : Prudhoe Bay Country : United States Loadcase : 5 RU-01A Upper Hemlock Top Fracture Geometry Data Per Zone for Production Prediction Zone Name Top MD Top Gross Net Fracture Fracture Fracture (ft) TVD Height Height Width Length Conductivity (ft) (ft) (in) (ft) (md.ft) Hemlock Coal 14040.0 11695.4 4.2 1.3 0.000 .0 0 SHALE 14045.0 11699.6 3.3 .3 0.000 .0 0 SHALE 14049.0 11702.9 4.2 .4 0.000 .0 0 SHALE 14054.0 11707.1 3.3 .3 0.000 .0 0 COAL 14058.0 11710.4 5.8 2.9 0.001 10.8 10 SHALE 14065.0 11716.2 5.0 .5 0.002 52.5 19 DIRTY-SANDSTONE 14071.0 11721.2 3.3 2.6 0.009 156.1 86 COAL 14075.0 11724.5 4.1 2.1 0.033 316.0 319 DIRTY-SANDSTONE 14080.0 11728.6 5.8 4.6 0.085 359.1 819 DIRTY-SANDSTONE 14087.0 11734.4 6.6 5.3 0.141 365.8 1365 DIRTY-SANDSTONE 14095.0 11741.0 14.0 11.2 0.163 374.7 1571 Upper Hemlock 14112.0 11755.0 8.2 6.6 0.187 375.1 1803 DIRTY-SANDSTONE 14122.0 11763.2 10.2 8.2 0.168 375.1 1626 CLEAN-SANDSTONE 14134.5 11773.5 2.9 2.9 0.080 374.3 768 DIRTY-SANDSTONE 14138.0 11776.3 13.0 10.4 0.027 245.8 257 SILTSTONE 14154.0 11789.4 4.9 1.5 0.000 .0 0 DIRTY-SANDSTONE 14160.0 11794.3 4.1 3.3 0.000 .0 0 DIRTY-SANDSTONE 14165.0 11798.3 8.1 6.5 0.000 .0 0 DIRTY-SANDSTONE 14175.0 11806.4 6.5 5.2 0.000 .0 0 DIRTY-SANDSTONE 14183.0 11812.9 12.1 9.7 0.000 .0 0 DIRTY-SANDSTONE 14198.0 11825.0 4.0 3.2 0.000 .0 0 CLEAN-SANDSTONE 14203.0 11829.0 3.2 3.2 0.000 .0 0 DIRTY-SANDSTONE 14207.0 11832.3 10.5 8.4 0.000 .0 0 DIRTY-SANDSTONE 14220.0 11842.7 15.3 12.2 0.000 .0 0 SILTSTONE 14239.0 11858.0 15.2 4.6 0.000 .0 0 SHALE 14258.0 11873.2 5.6 .6 0.000 .0 0 DIRTY-SANDSTONE 14265.0 11878.8 11.2 9.0 0.000 .0 0 SILTSTONE 14279.0 11890.0 8.8 2.6 0.000 .0 0 DIRTY-SANDSTONE 14290.0 11898.8 4.0 3.2 0.000 .0 0 SILTSTONE 14295.0 11902.8 2.4 .7 0.000 .0 0 DIRTY-SANDSTONE 14298.0 11905.2 3.2 2.6 0.000 .0 0 Silt Zone 14302.0 11908.4 9.6 2.9 0.000 .0 0 SHALE 14314.0 11917.9 10.4 1.0 0.000 .0 0 SILTSTONE 14327.0 11928.3 18.3 5.5 0.000 .0 0 DIRTY-SANDSTONE 14350.0 11946.6 11.9 9.5 0.000 .0 0 DIRTY-SANDSTONE 14365.0 11958.5 8.7 7.0 0.000 .0 0 DIRTY-SANDSTONE 14376.0 11967.3 3.2 2.6 0.000 .0 0 Middle Hemlock 14380.0 11970.5 4.0 4.0 0.000 .0 0 DIRTY-SANDSTONE 14385.0 11974.4 8.0 6.4 0.000 .0 0 SILTSTONE 14395.0 11982.4 6.4 1.9 0.000 .0 0 12 0 • Client : Glacier Q Well : RU-01A 0&G � I�111m�� jn G1 Formation : Upper Hemlock Top District : Prudhoe Bay Country : United States Load case : 5 RU-01A Upper Hemlock Top DIRTY-SANDSTONE 14403.0 11988.8 2.4 1.9 0.000 .0 0 SILTSTONE 14406.0 11991.1 2.4 .7 0.000 .0 0 DIRTY-SANDSTONE 14409.0 11993.5 4.0 3.2 0.000 .0 0 SHALE 14414.0 11997.5 11.2 1.1 0.000 .0 0 SILTSTONE 14428.0 12008.7 5.6 1.7 0.000 .0 0 CLEAN-SANDSTONE 14435.0 12014.3 26.4 26.4 0.000 .0 0 CLEAN-SANDSTONE 14468.0 12040.6 27.2 27.2 0.000 .0 0 DIRTY-SANDSTONE 14502.0 12067.8 4.0 3.2 0.000 .0 0 SHALE 14507.0 12071.8 3.1 .3 0.000 .0 0 DIRTY-SANDSTONE 14510.9 12075.0 4.3 3.4 0.000 .0 0 Exposure Time Prediction by Step Step Name Fluid Name Pump Fluid Perforation Exposure at Exposure Rate Volume Injection BHST of aboveWatch (bbl/min) (gal) Temp. 190 degF Temp.of (degF) (min) 185 degF (min) PAD YF127FIexD 20.0 8400 181 3.6 3.6 1.0 PPA YF127FIexD 20.0 1606 181 7.3 7.3 2.0 PPA YF127FIexD 20.0 1539 167 7.3 7.3 3.0 PPA YF127FIexD 20.0 1477 151 5.2 5.2 4.0 PPA YF127FIexD 20.0 1419 141 0.0 0.0 5.0 PPA YF127FIexD 20.0 1366 132 0.0 0.0 6.0 PPA YF127FIexD 20.0 1317 124 0.0 0.0 7.0 PPA YF127FIexD 20.0 1271 117 0.0 0.0 8.0 PPA YF127FIexD 20.0 1229 113 0.0 0.0 Flush WF127 20.0 4234 13 S 41, Client : Glacier O&G Seli verger Well : RU-01A Formation : Upper Hemlock Top District : Prudhoe Bay country : United States Loadcase : 5 RU-01A Upper Hemlock Top Section 6: Treatment Fluid Data Fluid data is given at 3.066 md. Fluid Name 3% KCI Brine YF127FIexD WF127 Friction Rate Low(bbl/min) 1.9 1.0 1.0 Pressure Low(psi/1000ft) 10.0 26.9 5.3 Rate Pivot(bbl/min) 10.0 20.0 20.0 Pressure Pivot(psi/1000ft) 221.5 220.0 200.0 Rate High(bbl/min) 21.9 65.1 35.8 Pressure High(psi/1000ft) 1000.0 1000.0 1000.0 Fluid Loss CW (ft/min0.5) 1.0E+0 3.4E-3 4.6E-3 Spurt(gal/100ft2) 0.0 2.0 1.8 Ct (ft/min0.5) 3.0E-2 3.4E-3 4.3E-3 Rheology Temperature(degF) 190 190 190 Time(hr) 0.0 0.0 0.0 n Behavior Index(N') 1.00 0.53 0.80 "6 c Consist.Index(K')(Ibf.s^n/ft2) 6.84E-6 2.07E-2 7.00E-4 B cs Viscosity @ Shear Rate(cP) 0.328 80.489 12.000 .� Shear Rate(1/s) 170 170 170 ai -u 14 • Client : Glacier O&G Schlumberger Well : RU-01A Formation : Upper Hemlock Top District : Prudhoe Bay Country : United States Loadcase : 5 RU-01A Upper Hemlock Top Section 7: Proppant Data Proppant Permeability is calculated based on the following parameters: BH Static Temperature: 190 degF Stress on Proppant: 8109 psi Propped Fracture Conc.: 1.00 lb/ft2 Average Young's Modulus: 3.565E+06 psi Proppant Data Proppant Name Specific Mean Pack Permeability Gravity Diameter Porosity (md) lin) (%) Jordan Unimin 20/40 2.65 0.022 35.4 27069 CarboLite 20/40 2.74 0.029 42.9 147136 20/40 CarboBond Lite 2.61 0.016 43.3 231651 Proppant Permeability Plot Proppant Permeability Stress on Proppant 200000 - I 180000 160000 140000 120000 _ Jordan Unimin 20/40 100000 ---�-- CarboLite 20/40 _ --"�— 20/40 CarboBond Lite Prop Stress 80000. 60000 40000' 20000 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 Closure Stress(psi) 15 • • WellClien : RU-01A: Schlumberger Formation : Upper Hemlock Top District : Prudhoe Bay country : United States Loadcase : 5 RU-01A Upper Hemlock Top Section 8: Hole Survey Deviated Hole YES MD/TVD Calculation Relationship Unknown Hole Survey MD TVD Deviation Deviation Azimuth Azimuth Dogleg (ft) (ft) Angle Build Rate Angle Build Rate Severity (deg) (deg/100ft) (deg) (deg/100ft) (deg/100ft) 0.0 0.0 0.0 0.0 0.0 0.0 0.0 119.1 119.1 0.0 0.0 0.0 0.0 0.0 129.1 129.1 0.0 0.0 0.0 0.0 0.0 163.9 163.9 0.2 0.6 103.4 297.6 0.6 193.9 193.9 0.6 1.4 103.4 0.0 1.4 282.9 282.9 0.5 -0.1 103.4 0.0 0.0 373.4 373.4 0.5 -0.0 103.4 0.0 0.0 463.8 463.8 1.0 0.5 103.4 0.0 0.5 553.8 553.7 3.1 2.4 119.9 18.3 2.4 644.8 644.5 4.5 1.6 114.7 -5.7 1.6 734.8 734.2 5.2 0.7 105.2 -10.5 1.2 824.8 823.8 5.7 0.5 104.5 -0.8 0.5 914.7 913.3 5.7 0.1 105.0 0.5 0.1 1004.7 1002.7 6.9 1.3 107.8 3.1 1.3 1092.5 1089.6 9.3 2.8 107.5 -0.3 2.8 1190.3 1185.9 10.4 1.1 105.7 -1.8 1.1 1285.0 1278.9 11.9 1.6 106.6 0.9 1.7 1381.4 1373.2 12.2 0.3 105.6 -1.0 0.3 1476.2 1465.6 13.5 1.4 104.7 -0.9 1.4 1570.2 1556.4 16.4 3.1 106.1 1.4 3.1 1665.5 1647.2 19.2 2.9 107.3 1.3 3.0 1761.8 1738.0 19.8 0.6 106.8 -0.6 0.7 1830.1 1802.2 20.0 0.3 107.6 1.1 0.5 1857.5 1827.9 20.0 0.3 107.9 1.1 0.5 1955.0 1918.8 22.5 2.5 108.8 1.0 2.5 2049.8 2005.4 25.4 3.1 109.7 0.9 3.2 2144.6 2089.9 28.5 3.2 110.4 0.7 3.3 2240.4 2172.8 31.5 3.2 110.9 0.6 3.2 2336.0 2253.4 33.6 2.2 108.6 -2.4 2.5 2430.5 2331.2 35.4 1.9 104.5 -4.3 3.1 2523.2 2406.5 36.0 0.7 103.6 -1.0 0.9 2616.7 2482.1 36.1 0.1 102.0 -1.7 1.0 2712.2 2559.3 36.3 0.2 100.5 -1.5 0.9 2808.4 2636.7 36.4 0.2 100.1 -0.4 0.3 2906.5 2715.6 36.6 0.1 99.8 -0.2 0.2 3000.4 2791.0 36.5 -0.0 101.4 1.6 1.0 16 • • Client : Glacier O&G Schlumberger Well : RU-01A Formation : Upper Hemlock Top District : Prudhoe Bay country : United States Loadcase : 5 RU-01A Upper Hemlock Top Hole Survey MD TVD Deviation Deviation Azimuth Azimuth Dogleg (ft) (ft) Angle Build Rate Angle Build Rate Severity (deg) (deg/100ft) (deg) (deg/100ft) (deg/100ft) 3099.6 2870.6 36.7 0.2 101.4 0.0 0.0 3192.2 2944.9 36.8 0.1 100.5 -1.0 0.6 3288.3 3021.9 36.5 -0.4 102.6 2.2 1.3 3385.2 3099.8 36.4 -0.1 103.2 0.6 0.4 3478.3 3174.7 36.5 0.0 103.6 0.5 0.3 3573.7 3251.5 36.5 0.0 103.0 -0.7 0.4 3670.0 3328.9 36.6 0.1 102.9 -0.0 0.0 3766.2 3406.2 36.5 -0.1 103.2 0.3 0.2 3862.0 3483.2 36.3 -0.2 102.4 -0.9 0.6 3957.4 3560.3 36.2 -0.1 102.1 -0.3 0.2 4051.3 3635.8 36.6 0.5 101.3 -0.8 0.7 4147.7 3713.3 36.4 -0.2 103.2 2.0 1.2 4243.7 3790.3 36.8 0.4 104.4 1.2 0.8 4339.4 3866.8 37.0 0.2 104.9 0.6 0.4 4433.2 3941.9 36.7 -0.4 105.6 0.7 0.6 4531.3 4020.4 36.9 0.2 110.8 5.2 3.1 4627.7 4097.7 36.7 -0.2 111.0 0.3 0.2 4723.7 4174.8 36.5 -0.2 109.8 -1.2 0.8 4820.4 4252.5 36.4 -0.1 110.1 0.3 0.2 4916.4 4330.0 36.2 -0.2 108.8 -1.3 0.8 5011.3 4406.6 36.1 -0.1 110.4 1.7 1.0 5107.4 4484.3 35.9 -0.2 110.0 -0.4 0.3 5202.1 4560.6 36.9 1.0 109.0 -1.0 1.2 5298.7 4637.6 37.3 0.4 107.9 -1.1 0.8 5394.7 4713.9 37.5 0.2 107.8 -0.1 0.2 5488.6 4788.4 37.5 0.0 107.9 0.0 0.0 5583.8 4864.0 37.4 -0.1 108.0 0.2 0.2 5682.4 4942.6 37.1 -0.2 107.4 -0.7 0.5 5778.3 5019.2 36.7 -0.4 107.6 0.2 0.5 5873.1 5095.3 36.5 -0.2 107.5 -0.1 0.2 5969.9 5173.0 36.8 0.3 106.9 -0.6 0.4 6065.2 5249.4 36.6 -0.1 106.9 0.0 0.0 6163.5 5328.3 36.7 0.1 105.6 -1.3 0.8 6258.5 5404.5 36.7 0.0 105.8 0.2 0.0 6353.3 5480.4 36.6 -0.1 105.6 -0.2 0.1 6448.9 5557.1 36.8 0.2 105.9 0.3 0.2 6544.0 5633.3 36.7 -0.1 106.2 0.4 0.2 6637.6 5708.3 36.7 -0.0 106.6 0.5 0.3 6739.1 5789.7 36.6 -0.1 106.8 0.1 0.0 6834.8 5866.7 36.3 -0.3 106.1 -0.7 0.5 6928.0 5941.8 36.3 0.0 106.3 0.2 0.1 17 • • Client : Glacier O&G Schlumberger Well : RU-01A Formation : Upper Hemlock Top District : Prudhoe Bay country : United States Loadcase : 5 RU-01A Upper Hemlock Top Hole Survey MD TVD Deviation Deviation Azimuth Azimuth Dogleg (ft) (ft) Angle Build Rate Angle Build Rate Severity (deg) (deg/100ft) (deg) (deg/100ft) (deg/100ft) 6985.1 5987.7 36.5 0.3 106.0 -0.5 0.4 7030.4 6024.1 36.6 0.3 105.8 -0.5 0.4 7126.1 6100.8 36.8 0.2 106.3 0.5 0.4 7221.8 6177.6 36.4 -0.5 107.3 1.1 0.8 7317.9 6255.0 36.4 -0.0 106.4 -1.0 0.6 7413.5 6332.0 36.2 -0.3 106.7 0.3 0.3 7510.1 6410.1 36.0 -0.2 107.2 0.5 0.3 7604.7 6486.8 35.8 -0.2 107.2 0.1 0.2 7699.7 6564.0 35.6 -0.2 107.0 -0.2 0.2 7795.7 6642.1 35.3 -0.3 107.6 0.6 0.5 7892.4 6721.0 35.2 -0.2 106.5 -1.2 0.7 7988.1 6799.5 34.6 -0.6 107.1 0.7 0.7 8017.8 6823.9 34.6 -0.1 106.8 -1.1 0.7 8113.8 6903.0 34.7 0.1 107.2 0.4 0.2 8209.9 6981.9 34.9 0.3 107.3 0.1 0.3 8302.0 7057.5 34.7 -0.3 107.6 0.3 0.4 8398.4 7136.0 36.4 1.8 106.6 -1.1 2.0 8494.9 7213.4 36.7 0.3 106.8 0.3 0.3 8591.5 7290.9 36.8 0.1 107.1 0.3 0.2 8687.4 7367.7 36.7 -0.1 106.9 -0.2 0.1 8782.7 7444.3 36.5 -0.2 107.0 0.1 0.2 8880.4 7523.1 36.1 -0.4 107.9 0.9 0.7 8975.0 7598.9 37.3 1.2 107.8 -0.1 1.2 9070.6 7675.2 37.0 -0.3 108.1 0.3 0.3 9176.0 7759.4 36.9 -0.1 108.1 -0.0 0.0 9262.8 7828.7 37.2 0.3 108.0 -0.1 0.3 9358.7 7905.0 37.4 0.3 106.3 -1.7 1.1 9454.3 7981.2 37.0 -0.5 106.7 0.4 0.5 9549.5 8057.6 36.2 -0.8 108.3 1.6 1.2 9645.3 8134.8 36.4 0.2 107.0 -1.3 0.8 9740.7 8211.6 36.3 -0.1 106.4 -0.5 0.4 9819.6 8275.5 35.7 -0.7 106.5 0.1 0.8 9915.6 8352.6 37.4 1.8 105.7 -0.9 1.9 10011.0 8428.3 37.4 -0.0 105.5 -0.2 0.1 10105.3 8503.5 37.0 -0.4 104.9 -0.6 0.6 10200.6 8579.6 37.0 -0.0 103.7 -1.2 0.7 10297.0 8657.0 36.3 -0.7 105.0 1.3 1.0 10392.9 8734.0 36.9 0.6 106.9 2.0 1.3 10486.2 8809.0 35.9 -1.0 107.7 0.9 1.2 10581.1 8886.0 35.5 -0.4 108.0 0.2 0.4 10774.8 9043.8 35.4 -0.1 107.7 -0.1 0.0 18 • • Client Glacier O&G Schlumberger Well : RU-01A Formation : Upper Hemlock Top District : Prudhoe Bay Country : United States Loadcase : 5 RU-01A Upper Hemlock Top Hole Survey MD TVD Deviation Deviation Azimuth Azimuth Dogleg (ft) (ft) Angle Build Rate Angle Build Rate Severity (deg) (deg/100ft) (deg) (deg/100ft) (deg/100ft) 10869.2 9120.7 35.5 0.1 109.0 1.3 0.8 10965.7 9199.4 35.5 0.0 109.1 0.2 0.0 11063.4 9278.8 35.5 0.0 106.9 -2.3 1.3 11157.0 9355.0 35.7 0.1 107.8 0.9 0.6 11252.5 9432.4 _ 36.0 0.3 108.5 0.7 0.6 11348.1 9509.2 _ 37.1 1.2 105.3 -3.4 2.3 11443.1 9585.1 _ 36.9 -0.2 106.1 0.9 0.5 11537.0 9659.9 37.3 0.4 105.9 -0.2 0.5 11633.7 9737.0 37.1 -0.3 106.0 0.1 0.3 11729.0 9813.6 _ 35.9 -1.2 106.0 0.0 1.2 11825.1 9891.6 35.5 -0.4 103.9 -2.2 1.3 11921.9 9970.2 36.0 0.5 104.4 0.5 0.5 12017.9 10048.3 35.3 -0.7 105.9 1.6 1.2 12113.7 10126.7 34.7 -0.6 103.8 -2.2 1.4 12207.0 10202.6 _ 36.5 1.8 102.2 -1.7 2.1 12263.0 10247.4 _ 37.1 1.1 103.1 1.5 1.5 12330.3 10301.0 37.4 0.5 101.3 -2.6 1.7 12377.3 10338.3 37.3 -0.2 100.1 -2.6 1.6 12435.1 10384.5 36.7 -1.0 98.6 -2.6 1.9 12473.3 10415.2 _ 36.5 -0.7 97.6 -2.6 1.7 12566.0 10489.3 37.3 0.9 95.2 -2.6 1.8 12660.3 10563.7 38.5 1.3 94.6 -0.6 1.3 12754.8 10636.7 40.3 1.9 94.3 -0.3 1.9 12851.5 10711.0 39.4 -0.9 94.3 0.0 0.9 12945.9 10785.3 36.7 -2.8 95.7 1.4 2.9 13040.3 10862.0 34.5 -2.3 95.3 -0.4 2.3 13131.8 10937.2 34.9 0.4 95.6 0.3 0.5 13227.0 11015.0 35.4 0.5 95.1 -0.5 0.6 13322.5 11093.5 _ 34.0 -1.4 93.6 -1.6 1.7 13417.0 11171.8 34.1 0.1 92.2 -1.5 0.8 13510.5 11249.2 _ 34.2 0.1 91.5 -0.7 0.4 13605.1 11327.6 33.8 -0.4 91.5 0.0 0.4 13699.1 11406.4 32.3 -1.6 92.2 0.7 1.7 13793.5 11486.7 31.2 -1.1 92.4 0.3 1.1 13888.6 11567.8 31.7 0.5 92.7 0.3 0.6 13963.0 11630.7 _ 32.7 1.3 96.6 5.2 3.0 14003.9 11665.1 32.7 0.0 95.4 -3.0 1.6 14102.0 11746.8 34.5 1.9 96.7 1.3 2.0 14195.2 11822.7 36.3 1.9 95.7 -1.1 2.0 14287.7 11897.0 _ 37.0 0.8 93.6 -2.3 1.6 14382.0 11972.1 37.4 0.3 91.2 -2.5 1.5 19 • • Wellt : RU-01A 0G Sch10Mberger Formation : Upper Hemlock Top District : Prudhoe Bay country : United States Loadcase : 5 RU-01A Upper Hemlock Top Hole Survey MD TVD Deviation Deviation Azimuth Azimuth Dogleg (ft) (ft) Angle Build Rate Angle Build Rate Severity (deg) (deg/100ft) (deg) (deg/100ft) (deg/100ft) 14474.0 12045.4 36.8 -0.6 86.8 -4.9 3.0 14572.2 12123.9 37.2 0.3 78.3 -8.5 5.2 14665.2 12198.4 36.5 -0.7 72.8 -6.0 3.6 14759.7 12273.5 38.1 1.6 68.4 -4.6 3.2 14855.2 12348.8 37.9 -0.2 64.3 -4.4 2.7 14949.6 12423.3 37.9 0.0 60.2 -4.3 2.7 15011.2 12471.9 38.3 0.7 58.4 -3.0 2.0 15038.0 12492.9 38.3 0.0 58.4 0.0 0.0 15050.0 12502.3 38.3 0.0 58.4 0.0 0.0 20 r • Client: Cook Inlet Energy Schiunderger Wein RU-01A Basin/Field: Redoubt Unit State: Alaska County/Parish: Kenai Peninsula Borough Case: Disclosure Type: Pre-Job Well Completed: 5/5/2017 Date Prepared: 3/13/2017 1:20 PM Report ID: RPT-48089 Fluid Name&Volume Additive Additive Description Concentration VoILI. F103Surfactant 1 Gal/1000 Gal 182.0 Gal J218 1 Breaker 1.2 Lb/1000 Gal 216.0 Lb J450 Stabilizing Agent 0.8 Gal/1000 Gal 136.0 Gal J475 Breaker 4.1 Lb/1000 Gal 745.0 Lb _ J604 _ Crosslinker 1.7 Gal/1000 Gal 312.0 Gal YF127FIexD:WF127 180,096 Gal 1891 Guar Slurry 6.4 Gal/1000 Gal 1,150.0 Gal M002 Additive 1.2 Lb/1000 Gal 220.0 Lb M117 Clay Control Agent 250 Lb/1000 Gal 45,024.0 Lb M275 Bactericide 0.5 Lb/1000 Gal 90.0 Lb 5526-2040 - Propping Agent varied concentrations 245,900.0 Lb W054 i Demulsifier 1 Gal/1000 Gal 182.0 Gal The total volume listed in the tables above represents the summation of water and additives. Water is supplied by client. CAS Number Chemical Name - Water(Including Mix Water Supplied by Client)* -83 % 64-19-7 Acetic acid(impurity) <0.0001 % 67-56-1 Methanol <0.1 % 67-63-0 - Propan-2-o1 <0.1 % 91-20-3 Naphthalene(impurity) <0.001 % _ 95-63-6 1,2,4 Trimethylbenzene(impurity) <0.0001 % 102-71-6 2,2',2"-nitrilotriethanol <0.1 % 107-21-1 Ethylene Glycol <0.1 % 110-17-8 _ Fumaric acid <0.01 % 111-76-2 2-butoxyethanol <0.1 % 112-42-5 1-undecanol <0.01 % 122-18-9 Benzyldimethylammonium chloride <0.0001 % 127-08-2 Acetic acid,potassium salt _ <0.001 % 139-07-1 Benzyllauryldimethylammonium chloride <0.01 % 139-08-2 Dimethylbenzylmyristylammonium chloride <0.001 % 143-18-0 Potassium oleate <0.001 % 1303-96-4 Sodium Tetraborate Decahydrate <0.01 % 1310-73-2 Sodium hydroxide <0.1 % 1319-33-1 Boronatrocalcite <0.1 % 2682-20-4 _ 2-methyl-2h-isothiazol-3-one <0.0001 % 7447-40-7 Potassium chloride "'2 % 7631-86-9 Silicon Dioxide <0.001 % 7647-14-5 Sodium chloride <0.1 % 7727-54-0 Diammonium peroxidisulphate <0.1 % 7786-30-3 Magnesium chloride <0.001 % 9000-30-0 Guar gum <1 % 9002-84-0 poly(tetrafluoroethylene) <0.001 % 9003-11-6 Methyl oxirane polymer with oxirane <0.01 % 10377-60-3 Magnesium nitrate <0.001 % 14464-46-1 Cristobalite <0.0001 % 14807-96-6 Magnesium silicate hydrate(talc) _ <0.001 % 14808-60-7 Quartz,Crystalline silica <0.0001 % 25038-72-6 Vinylidene chloride/methylacrylate copolymer <0.01 % 25322-68-3 Poly(oxy-1,2-ethanediyl),a-hydro-w-hydroxy-Ethane-1,2-diol,ethoxylated <0.01 % 26062-79-3 Ammonium,diallyldimethyl-,chloride,polymers <0.001 % 26172-55-4 5-chloro-2-methyl-2h-isothiazolol-3-one <0.001 % 30846-35-6 Ethoxylated propoxylated 4-nonylphenol-formaldehyde resin <0.01 % 34398-01-1 Alcohol,C11 linear,ethoxylated <0.1 % _ 64742-47-8 Distillates,petroleum,hydrotreated light <1 % 64742-94-5 Heavy aromatic naphtha <0.01 % 66402-68-4 - Ceramic materials and wares,chemicals -14% 0 Schlumberger 2017.Used by Cook Inlet Energy by permission. Page:1/2 • • Client: Cook Inlet Energy Scblinberger Well: Redoub Basin/Field: Redoubt Unit State: Alaska County/Parish: Kenai Peninsula Borough Case: Disclosure Type: Pre-Job Well Completed: 5/5/2017 Date Prepared: 3/13/2017 1:20 PM Report ID: RPT-48089 CAS Number Chemical Name Mass Fraction 68131-39-5 _ C12-15 alcohol ethyoxylated <0.01 % 68153-30-0 Amine treated smectite clay <0.01 % 78330-19-5 Alcohol,C7-9-iso,C8,ethoxylated <0.01 % 78330-20-8 Alcohol,C9 11-iso,CSO,ethoxylated <0.01 % 78330-21-9 Alcohol,C11-14,ethoxylated <0.01 % 91053-39-3 Diatomaceous earth,calcined <0.01 % 125005-87-0 Diutan gum <0.001 % 595585-15-2 Diutan <0.001 % Total 100% .Mix water is supplied by the client.Schlumberger has performed no analysis of the water and cannot provide a breakdown of components that may hove been added to the water by third-parties. The evaluation of attached document is performed based on the composition of the identified products to the extent that such compositional information was known to GRC-Chemicals as of the dote of the document was produced.Any new updates will not be reflected in this document. O Schlumberger 2017.Used by Cook Inlet Energy by permission. Page:2/2 o • SPS-343 Stimuiation Pump Skid High-Pressure Pumping System, Radiator C olod ,rj i fi ::T�i .d +`a ' _ _ —.- ,,,..,i J'Aftil . 'Sib ' 'I Alai, ;mgt. ' - i h The SPS-343 Stimulation Pumper Applications Equipment is a skid-mounted fracturing service pumpkig unitdesigned for caterpilar 35128 twelve high-horsepower o Pumps up to 20,000 psi or up to 0 The trkilex pump delvers 25 BPM,depending on fkid-end cylinder deck engine rated at fracturing fluids to the well at high sae. 2250 BHP ra 1900 rpm. pressure and rate. o Electronic controlled engine o Alison 8981 O(4 transmisekm The unit can be delivered withgives maintenence ad trouble- with ems'gear locked out. shooting kiforrnation. any of the Dowell - 'opr style ® 8' stroke HD-2000 Power-end fluid-ends, depending on the rate o Provides a remote control panel, with available fluid-end sizes and pressure requirements in the which may be located up to 120 3.75', 4.5', 5", 5.5", 6.5', or users market. It rs equipped with feet triway*um fracturing woo. o.to'orarrrerrer. a remote caned alowina control of the fracturing job from up to 120 kaon insalciiiii ui ee pieces © .3-pieceUNV ;c."-/-1oesEg ea feet sway. The panel allows pear offshore.for easy transportation on and skid and crash frames. selection, throttle control, and o Radiator cooling for maximum emergency shutdown to be versatility. performed. 'A Mark of Schlumberger 6121200G e . , • SPS-343 Stimulatk i Pump Skid General Specifications Part Number 100305352 Deck Engine Caterpillar 35128-2250 BHP Q 1900 RPM Deck Transmission Allison 59810M,7 gears Ambient Rating -5 DegC to 48 DegC Dimensions; Length Overall 27 ft.-3 in.[8.30 m] Haight 18 ft-6 m.[5.63 m] Width 8 ft.-11 in.[2.70 m] Total WeIght 73,194 Ibm(33,200 kg] Engine skid(W x L x H) 8-fl-11 in.[2.70m]x 15-ft-9 in.[4.80m]x 11-ft-6 In.[3.50m) Engine skid weigtd 35,715 Ibm[16200 kg] Pump skid(Wx L x H) 8 ft.-11 in.[2.70 m]x 10-ft.-2-in.[3.09rn]x 11-ft.-6 in.[3.50m Pump skid weight 25.353 Ibm[11,500 kg] Radiator skid(da x L x H) 811-11 in.[2.70 m]x 15 ft.-9 kr.[4.80 m]x 7 ft[2.14 m] Radiator d welotit 12,125 Ibm(5500 kg] Deck Load 12.5 PSI(from the two Iongit I-beams only) Fuel tanks Two,each 160 Gal Unities : Air for starling 100 psi Fuel 107 GaUmin(maximum) Triplex Pump Model HD-2000 Type 8 inch stroke Reciprocating Triplex(Gear Ratio-8.353:1) Hydraulic Horsepower 2000 HHP Fluid End EOPI(4.5°) Maximum Pressure 15,000 PSI Maximum Rate 11.4 SPM Fluid-Ends Available FOPI(3.755,EOPI(4.55,HOPI(55,IOPI(5.57,UOPI(6.57, 1,10Pi(6.755 A Mark of Schlumberger • • SPS-343 S rnu a 9.n Pump kltd Homapinver P♦iaasa-ND-i= ENGINE:8B1 -TIRANSIMISSIOit SIt1lI-FLUE END:4-112" 17500 200100 00 Melon tat Iand �, 0Mat=15,010PlIfbrg00End --. ;. -,-,t, I neallingeN. Sul Maw 1St NOM Isterla 160mor12500 ^'-- \ a mar IcovescALUKIN Mamr.1130 N. y I Pump Mescal 1400.1200Engln0 Maar.0.74 no 7 '--' BM •0.01023110-49Q' al RAMAN IRE •r aiw011.11.301 MEPINAL aF/r1RAT0 •iilltrNW 1711101 Wirt 7500 i Y` � -arxrumem „_ •iWcati/ns 5000 I 2.00 400 4.00 500 5.00 7.00 0.00 000 1000 11.00 12.00 Mb ouPal 4 A Mark of Schlumberger 512/1001: �j�'� .a 1 '141' • • � r. 388B14 POD Bleeder Skid Note:The gmtagripe m ynot be y apmuswee of c mom p oa n be ars to mantras epeslecetiotts. APPLICATIONS Blends end punas upto 3_bbi/miin fracturing:luny (.-3 11.1011. Controls said to Squid ratio precisely with E: • 1,' ,designated values , Runs in fug automated mode with setpoints provided by operator or host t,; 4 • system J"j' L ' .. Commu nicunes with fracCAT°for remote 'F control 11. ,II ,, FtErims MO-bhp asset engire e POD"(Pmgrwarnable Optimum Denary) : compsoer control system Mechanically-driven vo lex noir . ▪ Distributed diol hardware for automated operation with mama'backup n DfV1/2.7-3 cardfod crash frame • Integrated Dry Add feeder with interchangeable feed screws o PropNET°fiber feedar • Suction flowmeter on process fined fiord MUM 58S414 lititaubsdon PODBMtdrrNdil o Radbalgivs dersiihmatarfa ProPPant The SBS-614 Stimulation POD Blender Skid is a skid-mounted fracturing service densities Wobble eeperatelyr blender which is capable of bkndatg and pumping up to 35 bblimin of fracturing totw to red are am utatalnp netrt tee Ike .The POD(Programmable Opfaaum Density)comptder precisely cruets the ntaeeeae feeotfiestA6dnftsaaesrigoe solidtDliquid ratio atd gnatedvaluesduoughouttheentirejob inbathnis and ma&Verge roderaint deneemneter SCIFIEMQ stair stp modes. from MU The blender consists of a 5.56-m3fnki [35-bbl/min) vortex Ritter and does not need an averaging tub.Additionally,an auger is not required to add the proppant because gravity works for the mixer,not against it.The maximum discharge pressure is 103 psi[63 bar). A computer-controlled integral gate meters the amount of sand added to Ithe slurry from the sand hopper.The skid niter hydraulics are powered by I a 400-bhp diesel engine. `Mark of Schlumberger Otter company,product,arta service names eie the properties of their respective owners. Copyright 02015 Schlumberger.Ag rights reserved. •t • SS-6i4 tiol000 POD blonder General Specifications Engine Detroit Diesel'Series I106893M104 400 bhp atZ100 rpm Fuel Consumption 20.8 galUS/h 78 Lfi Hydraulics Parker'PAVC variable displacement load-sensing system Slid EN 10925 carbon steel frame conetrocdon Skid(combined) LengW 2254 in 5,798 mm Width 72 in 1998 ram (digis0) 1021t $503 ram Heigh(operational,handrails 1321 3,353 mm installed) WebbiDirVi 24,200 Bim 11,000 kg Amdilary Hydraulics 18 gelUS/min et 137.9 bar 88.14 Linn 01 2,0103 psi Friel Capacity 80 IOUS 227 L Vortex Mbar Sand Gate Type integral Madinah Discharge Pressure 100 psi 6i bar Maximum Send Rata 9,000 Wein 4,003 kgfiain Maidnsas Murry Rate 35 bbllinin 5,504 LMn InietConMstlon Bin wE;O'1I6296 Winged-Male Sub(11 Oudot Consultors 4-in MECO Fi8208 Female Sub(3) Additive System Dry Add(1) (1.019 to 1750*Idn 540 to 21,700uar1e/siin PropNET fiber Feeder(1) 10 to 200 Gm/min 4.5 a 90.7 kglai► Other Gauges Available Dual-scab er user-configurable between metric end imperial mite,e.g.,Yekogawa•#owmeter Control System Distributed microprocessor-conenlled astern Cooing System Stannard radiaor11) Skid Cer89sd offshore sidd designed to DMV 27-3 AmblentRMiag 23 to 118 degF -5q 48 degC CarMise6ans Gab Frame Cerdbcation DNV 27-3 Engine Emission GNBaetions US EPA Non-Road Tier 2 EURO Non-Road Stage II IMO MARPOL 73118 Amax Vi •Merle of Schlumberger Other compeer,product,end Service names ere the properties of their respective ownersr r Copyright0 2015 Schlumberger.An rights reserved. V1.0 12 Mar 2015 .1 7,4—t I r -�`n • • Cook Inlet Energy COOK INLET BASIN REDOUBT SHOAL RU-1 A 50733204970100 Sperry Drilling Services Definitive Survey Report 17 September, 2013 HALLIBURTON Sperry Drilling Services Halliburton Company • Definitive Survey Report Company: Cook Inlet Energy Local Co-ordinate Reference: Well Redoubt Unit#1 Project: COOK INLET BASIN TVD Reference: Redoubt Unit#1ARi ( g 35)@ 89.10ft(89.1 K6+40' Site: REDOUBT SHOAL MD Reference: Redoubt Unit#1A(Rig 35)@ 89.10ft(89.1KB+40' Well: Redoubt Unit#1 North Reference: Grid Wellbore: RU-1 A Survey Calculation Method: Minimum Curvature Design: RU-1 A Database: .16 prd Project COOK INLET BASIN 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 Well Redoubt Unit#1 Well Position +N/-S 0.00 ft Northing: 746,743.54 m Latitude: 60°41'43.743 N +EI-W 0.00 ft Easting: 61,151.10 m Longitude: 151°40'14.523 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Water Depth: 40.00ft Wellbore RU-1 A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2013 6/28/2013 17.10 73.56 55,440 Design RU-1 A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 12,207.05 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) 129.10 0.00 0.00 95.00 Survey Program Date 9/17/2013 From To Survey (ft) (ft) Survey(Wellbore) Tool Name Description Start Date 163.86 1,829.10 RU#1 MWD#1 (RU#1) MWD Fixed:v2:standard declination 08/30/2012 1,830.10 6,985.10 RU#1 MWD#1 (RU#1) MWD Fixed:v2:standard declination 08/30/2012 6,985.10 12,207.05 RU#1 MWD#1 (RU#1) MWD Fixed:v2:standard declination 08/30/2012 12,263.00 12,566.01 MWD_Interp Azi+Sag(RU-1 A) MWD_Interp Azi+sag Fixed:v2:std dec with interpolated azimuth+sa 07/02/2013 12,660.34 15,011.23 MWD+SC+sag(RU-1 A) MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 07/19/2013 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 129.10 0.00 0.00 129.10 40.00 0.00 0.00 746,743.54 61,151.10 0.00 0.00 UNDEFINED 163.86 0.21 103.43 163.86 74.76 -0.01 0.06 746,743.54 61,151.12 0.60 0.06 MWD(1) 193.94 0.62 103.43 193.94 104.84 -0.07 0.27 746,743.52 61,151.18 1.36 0.28 MWD(1) 282.86 0.51 103.43 282.85 193.75 -0.27 1.13 746,743.46 61,151.44 0.12 1.15 MWD(1) 373.42 0.50 103.43 373.41 284.31 -0.45 1.90 746,743.41 61,151.68 0.01 1.94 MWD(1) 463.82 0.97 103.43 463.80 374.70 -0.72 3.03 746,743.32 61,152.02 0.52 3.08 MWD(1) 553.79 3.11 119.90 553.71 464.61 -2.12 5.89 746,742.90 61,152.89 2.44 6.05 MWD(1) 644.78 4.53 114.67 644.50 555.40 -4.85 11.29 746,742.07 61,154.54 1.61 11.67 MWD(1) 734.83 5.19 105.21 734.22 645.12 -7.40 18.46 746,741.29 61,156.72 1.15 19.03 MWD(1) 824.80 5.68 104.49 823.79 734.69 -9.58 26.69 746,740.62 61,159.23 0.55 27.43 MWD(1) 9/17/2013 11:18:45AM Page 2 COMPASS 2003.16 Build 73 0 Halliburton Company • Definitive Survey Report Company: Cook Inlet Energy Local Co-ordinate Reference: Well Redoubt Unit#1 Project: COOK INLET BASIN TVD Reference: Redoubt Unit#1A(Rig 35)@ 89.10ft(89.1KB+40' Site: REDOUBT SHOAL MD Reference: Redoubt Unit#1A(Rig 35)@ 89.10ft(89.1KB+40' Well: Redoubt Unit#1 North Reference: Grid Wellbore: RU-1 A Survey Calculation Method: Minimum Curvature Design: RU-1 A Database: .16 prd Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°I100') (ft) Survey Tool Name 914.73 5.73 104.98 913.27 824.17 -11.86 35.34 746,739.93 61,161.87 0.08 36.24 MWD(1) 1,004.70 6.86 107.75 1,002.70 913.60 -14.66 44.79 746,739.08 61,164.75 1.30 45.90 MWD(1) 1,092.50 9.28 107.48 1,089.63 1,000.53 -18.38 56.54 746,737.94 61,168.33 2.76 57.93 MWD(1) ' 1,190.25 10.36 105.68 1,185.94 1,096.84 -23.12 72.52 746,736.50 61,173.20 1.15 74.26 MWD(1) 1,284.97 11.92 106.57 1,278.87 1,189.77 -28.22 90.10 746,734.94 61,178.56 1.66 92.22 MWD(1) 1,381.39 12.17 105.61 1,373.17 1,284.07 -33.79 109.43 746,733.25 61,184.45 0.33 111.96 MWD(1) 1,476.21 13.48 104.74 1,465.62 1,376.52 -39.29 129.75 746,731.57 61,190.64 1.40 132.68 MWD(1) 1,570.15 16.38 106.09 1,556.38 1,467.28 -45.75 153.07 746,729.60 61,197.75 3.11 156.47 MWD(1) 1,665.48 19.17 107.35 1,647.15 1,558.05 -54.14 180.93 746,727.04 61,206.24 2.95 184.96 MWD(1) 1,761.84 19.78 106.80 1,738.00 1,648.90 -63.58 211.64 746,724.17 61,215.60 0.66 216.37 MWD(1) 1,857.49 20.04 107.87 1,827.93 1,738.83 -73.28 242.73 746,721.21 61,225.08 0.47 248.19 MWD(2) 1,955.04 22.47 108.85 1,918.84 1,829.74 -84.44 276.28 746,717.81 61,235.31 2.52 282.59 MWD(2) 2,049.80 25.44 109.68 2,005.43 1,916.33 -97.14 312.59 746,713.94 61,246.38 3.15 319.87 MWD(2) 2,144.63 28.51 110.36 2,089.93 2,000.83 -111.88 353.00 746,709.44 61,258.69 3.25 361.41 MWD(2) 2,240.36 31.55 110.92 2,172.80 2,083.70 -128.78 397.82 746,704.29 61,272.35 3.19 407.53 MWD(2) 2,336.00 33.62 108.58 2,253.39 2,164.29 -146.15 446.30 746,699.00 61,287.13 2.53 457.34 MWD(2) 2,430.49 35.40 104.52 2,331.26 2,242.16 -161.35 497.60 746,694.37 61,302.77 3.08 509.77 MWD(2) 2,523.21 36.01 103.58 2,406.55 2,317.45 -174.48 550.09 746,690.36 61,318.77 0.88 563.21 MWD(2) 2,616.67 36.06 102.00 2,482.13 2,393.03 -186.65 603.71 746,686.65 61,335.11 1.00 617.68 MWD(2) 2,712.20 36.25 100.52 2,559.26 2,470.16 -197.65 658.98 746,683.30 61,351.95 0.94 673.70 MWD(2) 2,808.39 36.43 100.09 2,636.74 2,547.64 -207.85 715.06 746,680.19 61,369.05 0.32 730.45 MWD(2) 2,906.52 36.56 99.85 2,715.63 2,626.53 -217.96 772.54 746,677.11 61,386.57 0.20 788.60 MWD(2) 3,000.39 36.54 101.38 2,791.04 2,701.94 -228.25 827.48 746,673.97 61,403.31 0.97 844.23 MWD(2) 3,099.56 36.71 101.42 2,870.63 2,781.53 -239.95 885.48 746,670.41 61,420.99 0.17 903.02 MWD(2) 3,192.23 36.84 100.50 2,944.86 2,855.76 -250.49 939.94 746,667.19 61,437.59 0.61 958.20 MWD(2) 3,288.27 36.49 102.59 3,021.90 2,932.80 -261.96 996.12 746,663.70 61,454.72 1.35 1,015.17 MWD(2) I 3,385.17 36.41 103.18 3,099.85 3,010.75 -274.80 1,052.24 746,659.78 61,471.82 0.37 1,072.19 MWD(2) 3,478.26 36.45 103.61 3,174.74 3,085.64 -287.61 1,106.02 746,655.88 61,488.21 0.28 1,126.88 MWD(2) 3,573.68 36.49 102.97 3,251.48 3,162.38 -300.65 1,161.22 746,651.91 61,505.04 0.40 1,183.00 MWD(2) I 3,670.04 36.58 102.94 3,328.90 3,239.80 -313.51 1,217.12 746,647.99 61,522.08 0.10 1,239.82 MWD(2) 3,766.23 36.50 103.24 3,406.19 3,317.09 -326.48 1,272.91 746,644.03 61,539.08 0.20 1,296.52 MWD(2) 1 3,861.96 36.29 102.42 3,483.24 3,394.14 -339.09 1,328.29 746,640.19 61,555.96 0.55 1,352.79 MWD(2) 3,957.44 36.19 102.10 3,560.25 3,471.15 -351.08 1,383.44 746,636.54 61,572.77 0.22 1,408.78 MWD(2) 4,051.33 36.63 101.31 3,635.82 3,546.72 -362.38 1,438.01 746,633.09 61,589.40 0.68 1,464.13 MWD(2) 4,147.70 36.43 103.19 3,713.26 3,624.16 -374.55 1,494.07 746,629.38 61,606.49 1.18 1,521.03 MWD(2) 4,243.71 36.82 104.39 3,790.31 3,701.21 -388.20 1,549.69 746,625.22 61,623.44 0.85 1,577.63 MWD(2) 4,339.42 37.05 104.94 3,866.81 3,777.71 -402.76 1,605.33 746,620.78 61,640.40 0.42 1,634.32 MWD(2) 4,433.24 36.66 105.63 3,941.88 3,852.78 -417.60 1,659.61 746,616.26 61,656.95 0.61 1,689.69 MWD(2) 4,531.31 36.87 110.77 4,020.47 3,931.37 -435.92 1,715.33 746,610.67 61,673.93 3.14 1,746.79 MWD(2) 4,627.70 36.69 111.03 4,097.67 4,008.57 -456.51 1,769.24 746,604.40 61,690.36 0.25 1,802.30 MWD(2) 9/17/2013 11:18:45AM Page 3 COMPASS 2003.16 Build 73 • Halliburton Company S Definitive Survey Report Company: Cook Inlet Energy Local Co-ordinate Reference: Well Redoubt Unit#1 Project: COOK INLET BASIN TVD Reference: Redoubt Unit#1A(Rig 35)@ 89.10ft(89.1KB+40' Site: REDOUBT SHOAL MD Reference: Redoubt Unit#1A(Rig 35)@ 89.10ft(89.1KB+40' Well: Redoubt Unit#1 North Reference: Grid Wellbore: RU-1 A Survey Calculation Method: Minimum Curvature Design: RU-1 A Database: .16 prd Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,723.74 36.46 109.83 4,174.80 4,085.70 -476.49 1,822.87 746,598.31 61,706.71 0.78 1,857.46 MWD(2) 4,820.36 36.39 110.12 4,252.54 4,163.44 -496.09 1,876.79 746,592.34 61,723.14 0.19 1,912.88 MWD(2) 4,916.42 36.21 108.84 4,329.96 4,240.86 -515.05 1,930.40 746,586.56 61,739.48 0.81 1,967.94 MWD(2) 5,011.27 36.09 110.44 4,406.55 4,317.45 -533.85 1,983.09 746,580.83 61,755.54 1.00 2,022.07 MWD(2) 5,107.38 35.90 110.02 4,484.31 4,395.21 -553.39 2,036.09 746,574.87 61,771.70 0.32 2,076.57 MWD(2) 5,202.09 36.87 109.03 4,560.56 4,471.46 -572.16 2,089.04 746,569.15 61,787.84 1.20 2,130.96 MWD(2) 5,298.66 37.27 107.95 4,637.61 4,548.51 -590.62 2,144.25 746,563.52 61,804.66 0.79 2,187.56 MWD(2) 5,394.68 37.49 107.82 4,713.91 4,624.81 -608.52 2,199.72 746,558.07 61,821.57 0.24 2,244.39 MWD(2) 5,488.57 37.50 107.86 4,788.40 4,699.30 -626.03 2,254.13 746,552.73 61,838.16 0.03 2,300.11 MWD(2) 5,583.79 37.36 108.04 4,864.02 4,774.92 -643.86 2,309.18 746,547.29 61,854.94 0.19 2,356.51 MWD(2) 5,682.44 37.12 107.39 4,942.55 4,853.45 -662.03 2,366.05 746,541.76 61,872.27 0.47 2,414.75 MWD(2) 5,778.34 36.70 107.60 5,019.23 4,930.13 -679.34 2,420.98 746,536.48 61,889.01 0.46 2,470.98 MWD(2) 5,873.09 36.50 107.47 5,095.30 5,006.20 -696.36 2,474.85 746,531.29 61,905.43 0.23 2,526.12 MWD(2) 5,969.88 36.75 106.88 5,172.98 5,083.88 -713.41 2,530.01 746,526.10 61,922.25 0.45 2,582.56 MWD(2) 6,065.16 36.63 106.88 5,249.38 5,160.28 -729.94 2,584.49 746,521.06 61,938.85 0.13 2,638.27 MWD(2) 6,163.48 36.68 105.62 5,328.26 5,239.16 -746.37 2,640.84 746,516.05 61,956.03 0.77 2,695.84 MWD(2) 6,258.55 36.72 105.77 5,404.49 5,315.39 -761.74 2,695.54 746,511.37 61,972.70 0.10 2,751.67 MWD(2) 6,353.25 36.64 105.58 5,480.43 5,391.33 -777.02 2,750.00 746,506.71 61,989.30 0.15 2,807.26 MWD(2) 6,448.92 36.81 105.86 5,557.11 5,468.01 -792.52 2,805.07 746,501.98 62,006.08 0.25 2,863.47 MWD(2) 6,543.97 36.74 106.20 5,633.25 5,544.15 -808.23 2,859.76 746,497.19 62,022.75 0.23 2,919.32 MWD(2) 6,637.59 36.73 106.63 5,708.28 5,619.18 -824.06 2,913.47 746,492.37 62,039.13 0.27 2,974.21 MWD(2) 6,739.10 36.60 106.75 5,789.70 5,700.60 -841.47 2,971.54 746,487.07 62,056.82 0.15 3,033.57 MWD(2) 6,834.80 36.32 106.11 5,866.67 5,777.57 -857.55 3,026.08 746,482.16 62,073.45 0.49 3,089.31 MWD(2) 6,928.01 36.35 106.31 5,941.76 5,852.66 -872.97 3,079.11 746,477.46 62,089.61 0.13 3,143.48 MWD(2) 7,030.44 36.62 105.78 6,024.11 5,935.01 -889.80 3,137.65 746,472.33 62,107.45 0.41 3,203.26 MWD(3) 7,126.14 36.84 106.28 6,100.81 6,011.71 -905.61 3,192.65 746,467.51 62,124.22 0.39 3,259.43 MWD(3) 7,221.78 36.40 107.29 6,177.58 6,088.48 -922.08 3,247.27 746,462.49 62,140.87 0.78 3,315.28 MWD(3) 7,317.93 36.39 106.36 6,254.97 6,165.87 -938.59 3,301.88 746,457.46 62,157.51 0.57 3,371.12 MWD(3) 7,413.61 36.15 106.69 6,332.11 6,243.01 -954.69 3,356.15 746,452.55 62,174.05 0.32 3,426.58 MWD(3) 7,510.13 35.97 107.15 6,410.14 6,321.04 -971.23 3,410.50 746,447.51 62,190.62 0.34 3,482.17 MWD(3) 7,604.70 35.77 107.22 6,486.77 6,397.67 -987.60 3,463.44 746,442.52 62,206.76 0.22 3,536.34 MWD(3) 7,699.73 35.62 107.03 6,563.95 6,474.85 -1,003.92 3,516.43 746,437.55 62,222.91 0.20 3,590.55 MWD(3) 7,795.74 35.35 107.63 6,642.13 6,553.03 -1,020.52 3,569.63 746,432.49 62,239.12 0.46 3,644.99 MWD(3) 7,892.37 35.20 106.51 6,721.02 6,631.92 -1,036.91 3,622.97 746,427.49 62,255.38 0.69 3,699.56 MWD(3) 7,988.10 34.62 107.14 6,799.52 6,710.42 -1,052.76 3,675.41 746,422.66 62,271.37 0.71 3,753.18 MWD(3) 8,017.77 34.60 106.80 6,823.94 6,734.84 -1,057.68 3,691.53 746,421.16 62,276.28 0.65 3,769.67 MWD(3) 8,113.81 34.67 107.20 6,902.96 6,813.86 -1,073.64 3,743.73 746,416.30 62,292.19 0.25 3,823.06 MWD(3) 8,209.91 34.94 107.32 6,981.87 6,892.77 -1,089.91 3,796.11 746,411.34 62,308.15 0.29 3,876.66 MWD(3) 8,302.05 34.65 107.64 7,057.53 6,968.43 -1,105.71 3,846.26 746,406.52 62,323.44 0.37 3,928.00 MWD(3) 8,398.43 36.43 106.56 7,135.96 7,046.86 -1,122.17 3,899.81 746,401.51 62,339.76 1.96 3,982.77 MWD(3) 9/17/2013 11:18:45AM Page 4 COMPASS 2003.16 Build 73 • Halliburton Company 111 Definitive Survey Report Company: Cook Inlet Energy Local Co-ordinate Reference: Well Redoubt Unit#1 Project: COOK INLET BASIN TVD Reference: Redoubt Unit#1A(Rig 35)@ 89.10ft(89.1KB+40' Site: REDOUBT SHOAL MD Reference: Redoubt Unit#1A(Rig 35)@ 89.10ft(89.1KB+40' Well: Redoubt Unit#1 North Reference: Grid Wellbore: RU-1 A Survey Calculation Method: Minimum Curvature Design: RU-1 A Database: .16 prd Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) ( ) (°) (ft) (ft) (ft) (ft) (ft) (ft) 0100') (ft) Survey Tool Name 8,494.88 36.68 106.81 7,213.43 7,124.33 -1,138.66 3,954.84 746,396.48 62,356.53 0.30 4,039.03 MWD(3) 8,591.52 36.75 107.12 7,290.90 7,201.80 -1,155.52 4,010.10 746,391.34 62,373.38 0.20 4,095.55 MWD(3) 8,687.37 36.70 106.94 7,367.73 7,278.63 -1,172.31 4,064.90 746,386.23 62,390.08 0.12 4,151.60 MWD(3) 8,782.68 36.47 107.04 7,444.26 7,355.16 -1,188.90 4,119.23 746,381.17 62,406.64 0.25 4,207.17 MWD(3) 8,880.44 36.07 107.91 7,523.08 7,433.98 -1,206.27 4,174.39 746,375.87 62,423.45 0.67 4,263.64 MWD(3) 8,974.98 37.25 107.81 7,598.92 7,509.82 -1,223.58 4,228.12 746,370.60 62,439.83 1.25 4,318.67 MWD(3) 9,070.64 36.98 108.10 7,675.20 7,586.10 -1,241.37 4,283.03 746,365.17 62,456.57 0.34 4,374.92 MWD(3) 9,175.99 36.92 108.05 7,759.39 7,670.29 -1,261.02 4,343.23 746,359.18 62,474.92 0.06 4,436.61 MWD(3) 9,262.85 37.15 107.97 7,828.73 7,739.63 -1,277.20 4,392.98 746,354.25 62,490.08 0.27 4,487.58 MWD(3) 9,358.72 37.42 106.33 7,905.01 7,815.91 -1,294.32 4,448.47 746,349.04 62,506.99 1.07 4,544.35 MWD(3) 9,454.32 36.95 106.69 7,981.17 7,892.07 -1,310.74 4,503.87 746,344.03 62,523.88 0.54 4,600.97 MWD(3) 9,549.51 36.23 108.25 8,057.60 7,968.50 -1,327.76 4,557.99 746,338.84 62,540.38 1.24 4,656.37 MWD(3) 9,645.31 36.43 106.96 8,134.78 8,045.68 -1,344.93 4,612.09 746,333.61 62,556.86 0.82 4,711.75 MWD(3) 9,740.66 36.29 106.44 8,211.57 8,122.47 -1,361.17 4,666.23 746,328.66 62,573.37 0.36 4,767.11 MWD(3) 9,819.64 35.70 106.53 8,275.47 8,186.37 -1,374.34 4,710.74 746,324.64 62,586.93 0.75 4,812.60 MWD(3) 9,915.60 37.40 105.66 8,352.55 8,263.45 -1,390.18 4,765.65 746,319.82 62,603.67 1.85 4,868.67 MWD(3) 10,010.96 37.39 105.48 8,428.31 8,339.21 -1,405.72 4,821.43 746,315.08 62,620.67 0.12 4,925.60 MWD(3) 10,105.30 36.99 104.91 8,503.47 8,414.37 -1,420.67 4,876.46 746,310.52 62,637.45 0.56 4,981.73 MWD(3) 10,200.58 36.97 103.74 8,579.58 8,490.48 -1,434.85 4,931.99 746,306.20 62,654.37 0.74 5,038.28 MWD(3) 10,296.99 36.29 104.98 8,656.95 8,567.85 -1,449.11 4,987.72 746,301.85 62,671.36 1.04 5,095.04 MWD(3) 10,392.93 36.91 106.86 8,733.98 8,644.88 -1,464.80 5,042.72 746,297.07 62,688.12 1.34 5,151.20 MWD(3) 10,486.16 35.94 107.74 8,808.99 8,719.89 -1,481.26 5,095.57 746,292.06 62,704.23 1.18 5,205.28 MWD(3) 10,581.07 35.54 107.96 8,886.03 8,796.93 -1,498.25 5,148.34 746,286.88 62,720.31 0.44 5,259.33 MWD(3) 10,774.76 35.37 107.71 9,043.80 8,954.70 -1,532.67 5,255.29 746,276.39 62,752.91 0.12 5,368.87 MWD(3) 10,869.18 35.47 108.97 9,120.75 9,031.65 -1,549.88 5,307.23 746,271.14 62,768.74 0.78 5,422.12 MWD(3) 10,965.73 35.49 109.13 9,199.37 9,110.27 -1,568.17 5,360.20 746,265.56 62,784.89 0.10 5,476.48 MWD(3) 11,063.36 35.53 106.90 9,278.85 9,189.75 -1,585.71 5,414.12 746,260.22 62,801.32 1.33 5,531.72 MWD(3) 11,157.03 35.67 107.78 9,355.01 9,265.91 -1,601.96 5,466.17 746,255.27 62,817.19 0.57 5,584.99 MWD(3) 11,252.47 36.00 108.49 9,432.38 9,343.28 -1,619.35 5,519.27 746,249.96 62,833.37 0.56 5,639.40 MWD(3) 11,348.10 37.10 105.27 9,509.21 9,420.11 -1,635.87 5,573.75 746,244.93 62,849.98 2.31 5,695.12 MWD(3) 11,443.78 36.93 106.08 9,585.61 9,496.51 -1,651.43 5,629.21 746,240.19 62,866.88 0.54 5,751.72 MWD(3) 11,536.97 37.34 105.86 9,659.90 9,570.80 -1,666.91 5,683.30 746,235.47 62,883.37 0.46 5,806.95 MWD(3) 11,633.70 37.06 105.99 9,736.95 9,647.85 -1,682.95 5,739.54 746,230.58 62,900.51 0.30 5,864.38 MWD(3) 11,728.96 35.89 106.03 9,813.55 9,724.45 -1,698.57 5,793.97 746,225.82 62,917.10 1.23 5,919.96 MWD(3) 11,825.13 35.51 103.91 9,891.65 9,802.55 -1,713.07 5,848.18 746,221.40 62,933.62 1.35 5,975.23 MWD(3) 11,921.90 35.95 104.36 9,970.21 9,881.11 -1,726.87 5,902.98 746,217.19 62,950.33 0.53 6,031.02 MWD(3) 12,017.91 35.30 105.91 10,048.25 9,959.15 -1,741.46 5,956.96 746,212.75 62,966.78 1.16 6,086.07 MWD(3) 12,113.68 34.74 103.84 10,126.68 10,037.58 -1,755.58 6,010.07 746,208.44 62,982.97 1.37 6,140.20 MWD(3) 12,207.05 36.46 102.24 10,202.60 10,113.50 -1,767.82 6,063.01 746,204.71 62,999.11 2.09 6,194.02 MWD(3) 12,263.00 37.10 103.10 10,247.41 10,158.31 -1,775.17 6,095.70 746,202.47 63,009.07 1.47 6,227.22 MWD_InterpAzi+sag(4) 9/17/2013 11:18:45AM Page 5 COMPASS 2003.16 Build 73 Halliburton Company S Definitive Survey Report Company: Cook Inlet Energy Local Co-ordinate Reference: Well Redoubt Unit#1 Project: COOK INLET BASIN TVD Reference: Redoubt Unit#1ARi ( g 35)@ 89.10ft(89.1 K6+40' Site: REDOUBT SHOAL MD Reference: Redoubt Unit#1A(Rig 35)@ 89.10ft(89.1 KB+40' Well: Redoubt Unit#1 North Reference: Grid Wellbore: RU-1 A Survey Calculation Method: Minimum Curvature Design: RU-1 A Database: .16 prd 'Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 12,330.35 37.42 101.33 10,301.02 10,211.92 -1,783.80 6,135.55 746,199.84 63,021.21 1.66 6,267.67 MWD_Interp Azi+sag(4) 12,377.28 37.31 100.10 10,338.32 10,249.22 -1,789.09 6,163.53 746,198.23 63,029.74 1.61 6,296.01 MWD_InterpAzi+sag(4) 12,435.11 36.72 98.59 10,384.50 10,295.40 -1,794.75 6,197.88 746,196.50 63,040.21 1.87 6,330.72 MWD_Interp Azi+sag(4) 12,473.34 36.46 97.58 10,415.19 10,326.09 -1,797.96 6,220.44 746,195.53 63,047.09 1.72 6,353.47 MWD_Interp Azi+sag(4) 12,566.01 37.32 95.16 10,489.31 10,400.21 -1,804.11 6,275.72 746,193.65 63,063.94 1.82 6,409.07 MWD_Interp Azi+sag(4) 12,660.34 38.50 94.55 10,563.74 10,474.64 -1,809.02 6,333.47 746,192.16 63,081.54 1.31 6,467.03 MWD+SC+sag(5) 12,754.77 40.28 94.28 10,636.71 10,547.61 -1,813.63 6,393.21 746,190.75 63,099.75 1.89 6,526.95 MWD+SC+sag(5) 12,851.49 39.39 94.32 10,710.98 10,621.88 -1,818.27 6,454.99 746,189.33 63,118.58 0.92 6,588.90 MWD+SC+sag(5) 12,945.91 36.74 95.68 10,785.31 10,696.21 -1,823.32 6,512.98 746,187.79 63,136.26 2.94 6,647.11 MWD+SC+sag(5) 13,040.26 34.55 95.34 10,861.98 10,772.88 -1,828.61 6,567.71 746,186.18 63,152.94 2.33 6,702.09 MWD+SC+sag(5) 13,131.75 34.94 95.60 10,937.16 10,848.06 -1,833.58 6,619.61 746,184.67 63,168.76 0.46 6,754.23 MWD+SC+sag(5) 13,226.97 35.39 95.10 11,015.00 10,925.90 -1,838.69 6,674.21 746,183.11 63,185.40 0.56 6,809.07 MWD+SC+sag(5) 13,322.52 34.04 93.60 11,093.54 11,004.44 -1,842.83 6,728.46 746,181.85 63,201.94 1.67 6,863.47 MWD+SC+sag(5) 13,416.95 34.10 92.19 11,171.77 11,082.67 -1,845.50 6,781.29 746,181.03 63,218.04 0.84 6,916.33 MWD+SC+sag(5) 13,510.51 34.20 91.53 11,249.19 11,160.09 -1,847.20 6,833.79 746,180.52 63,234.04 0.41 6,968.78 MWD+SC+sag(5) 13,605.11 33.82 91.53 11,327.61 11,238.51 -1,848.62 6,886.68 746,180.08 63,250.16 0.40 7,021.59 MWD+SC+sag(5) 13,699.07 32.29 92.17 11,406.36 11,317.26 -1,850.27 6,937.90 746,179.58 63,265.77 1.67 7,072.76 MWD+SC+sag(5) 13,793.55 31.23 92.44 11,486.69 11,397.59 -1,852.26 6,987.59 746,178.97 63,280.92 1.13 7,122.44 MWD+SC+sag(5) 13,888.61 31.73 92.74 11,567.76 11,478.66 -1,854.51 7,037.18 746,178.29 63,296.03 0.55 7,172.03 MWD+SC+sag(5) 13,963.01 32.69 96.58 11,630.72 11,541.62 -1,857.75 7,076.69 746,177.30 63,308.07 3.04 7,211.67 MWD+SC+sag(5) 14,003.90 32.71 95.37 11,665.13 11,576.03 -1,860.05 7,098.66 746,176.60 63,314.77 1.60 7,233.76 MWD+SC+sag(5) 14,102.01 34.54 96.69 11,746.82 11,657.72 -1,865.77 7,152.68 746,174.86 63,331.24 2.01 7,288.07 MWD+SC+sag(5) 14,195.18 36.30 95.71 11,822.74 11,733.64 -1,871.59 7,206.36 746,173.08 63,347.60 1.98 7,342.05 MWD+SC+sag(5) 14,287.74 37.05 93.58 11,896.98 11,807.88 -1,876.06 7,261.45 746,171.72 63,364.39 1.60 7,397.33 MWD+SC+sag(5) 14,382.05 37.38 91.24 11,972.09 11,882.99 -1,878.45 7,318.43 746,170.99 63,381.76 1.54 7,454.30 MWD+SC+sag(5) 14,474.00 36.83 86.75 12,045.44 11,956.34 -1,877.49 7,373.86 746,171.28 63,398.65 3.01 7,509.44 MWD+SC+sag(5) 14,572.25 37.17 78.35 12,123.96 12,034.86 -1,869.82 7,432.37 746,173.62 63,416.49 5.15 7,567.05 MWD+SC+sag(5) 14,665.24 36.54 72.79 12,198.38 12,109.28 -1,855.96 7,486.34 746,177.85 63,432.94 3.65 7,619.61 MWD+SC+sag(5) 14,759.72 38.07 68.43 12,273.54 12,184.44 -1,836.92 7,540.31 746,183.65 63,449.39 3.23 7,671.72 MWD+SC+sag(5) 14,855.16 37.86 64.27 12,348.80 12,259.70 -1,813.38 7,594.07 746,190.82 63,465.77 2.69 7,723.22 MWD+SC+sag(5) 14,949.59 37.88 60.19 12,423.36 12,334.26 -1,786.39 7,645.33 746,199.05 63,481.40 2.65 7,771.94 MWD+SC+sag(5) 15,011.23 38.31 58.37 12,471.87 12,382.77 -1,766.96 7,678.02 746,204.97 63,491.36 1.95 7,802.81 MWD+SC+sag(5) 15,050.00 38.31 58.37 12,502.29 12,413.19 -1,754.36 7,698.49 746,208.82 63,497.60 0.00 7,822.09 PROJECTED to TD 9/17/2013 11:18:45AM Page 6 COMPASS 2003.16 Build 73 ! • RU 1A Sundry Application,Geology 91 API° 15 '. 10 1 1A 6 7 71 /13W 9 22 27 All wells within 1/2 mile radius of RU-1A. Zone open to Production/ API AOGCC Well Name Well Type Status Injection 50733204970100 REDOUBT UNIT 1A Producer Shut-In Hemlock(upper,middle,lower) REDOUBT SHOAL 50733200400100 UNIT 2 Producer P&A Hemlock REDOUBT SHOAL ST 50733200400000 1 Wildcat P&A 50733204970000 REDOUBT UNIT 1 Producer P&A Hemlock 50733205190000 REDOUBT UNIT 6 Producer Injector Hemlock(upper,middle,lower) 50733205260000 REDOUBT UNIT 7 Producer P&A Hemlock 50733205010100 REDOUBT UNIT 2A Producer Producing Hemlock(upper,middle,lower) 50733202700000 REDOUBT BAY UNIT 1 Wildcat P&A Planned 50733205260100 REDOUBT UNIT 7B Producer Producing Hemlock(Upper,Middle,Lower) 0 • Well Head Location:Section 14,T. 7 N., R. 14 W., S.M., 1,918 feet from the south line and 315'from the east line. The RU 1A Well will have a bottom hole location within Section 18,T. 7 N., R. 13 W., 352'from the south line and 2,139' feet from the west line. The top of the productive zone is anticipated to fall roughly 235'from the south line and 1,600'from the west line of Section 18:/CIE is planning to produce from zones within Section 18,T. 7 N., R. 13 W., S.M. Fluids from this production activity may additionally migrate from Section 19,T.7 N., R. 13 W.,S.M. /ss.. - VI 4 f 4 +,r u, / � { ,,� r „ , , , 1 ,' '' \\ ,-. ,4410.:i; i lllllh�. 1,fitir.„.., , , ,,,, . : , 241 '' ,. .. ,....___, ,„„ k ;#, ---f!D4,4—sior..# / .... 0- - .,, 7\� �� p 4... , /, 7.,3w i // , . I, 7.— 'LOO \� ft.„,„,, E i --M ,^4 e i RI, o0 il: / ) 1 f e 1;:i 4, I/7777 / a / r-- Faults and Fractures in'mile radius of RU-1A with all Redoubt field wells. Structural Geology: The RU-1A well is a sidetrack of the original RU-1 wellbore and was designed to penetrate the crest of the anticline structure in the central fault block. It is interpreted to be in the down drop block of a NW- SE striking normal fault. The well is situated in the hanging wall of a West thrusting reverse fault bounding the Western edge of the field. Structural dips should be flat to dipping Southwest at low dip angle. This operation will be done in the existing wellbore of RU 1A. No faults will be intersected by any wellbore within the estimated fracture wings of^'325-475' horizontally or vertically. The Oligocene Upper and Middle members of the Hemlock formation are the primary reservoir targets of this fracture stimulation and can be broken into 4 intervals: Upper, Clay/Silt Zone, Middle and Lower • • Hemlock. The Miocene lower Tyonek formation overlays the Oligocene Hemlock reservoir,which overlays the Eocene West Foreland Formation. There is a ^'78'thick carbonaceous shale at the top Hemlock reservoir at 11,670-11,734'TVD, 14,027- 14,105' MD.There is also a shale barrier below the Lower Hemlock at 14,806' MD, 12,296'TVD. Fracture modeling suggests that the expected fracture height is on the order of—67-100 with fracture wings lengths of^'325-475. The gross Upper, Silt, and Middle Hemlock interval in RU 1A is 550'feet thick. Mechanical properties have been modeled using Schlumberger's FracCADE program for shales and Hemlock Formation pressure gradients with depth. The Hemlock formation clean sandstone is estimated to have a fracture gradient in sandstones of 0.722-.828 psi/ft. and in situ stress from 8726- 9750 psi, a modeled shale fracture gradient of 0.799-0.829 psi/ft.and in situ stress of 9363-10193 psi in the shale. \ ' \ ill I // i „ \ \ - i al ' / (,. tio ' , \ ' :.,, I , Ill / / ------' 1 f, '- . 111170 alpBF F 4 i.;„.0k _� An WAilliat, ) 0 t11,'•�,��r 1hip) ! - l4., / '• �� I t -, Iry ii I iv : / ot „.. ttop/- 4 \44 ;S1 .•- ys 1g' s / l t /. lif V . T• / ///44' Fracture wing radius of 475' shown with blue circle around the RU-1A proposed location throughout the hemlock formation with the top at 14,110' MD, 11,753'TVD. Edge of fracture wings are 1000' +from nearest major faults. Minor green fault is just outside of fracture radius. RU 4 is not within the fracture wing radius as it is shallower in the section at this location. • • RU 1A Well Log: Well Nome Redoubt Unn tt1A GL 0 Net State;Province Alaska 6 ALMS! ,. 2 R09PC 200 60 ALDPLC 0 I INI (0FMM) t%) 0 DGRCC 150 2 R27PC 200 60 TNPS 0 1 GAP!. (0$ 1) 1%) MD R311PC 200 -..... (0141M) 1 1200 o00 s,7 I--- '"-+_-=._ -._ i:( l : ,....- ,31(11 r, J.- -''' ,,. -e- ,a2(, It. va I o _.. ___ u'tOr. -_ - 1 f.. Mrd�s hook _ Upper and Middle Hemlock ' I 14400 I u60,, - _..... 0 _____o Y ,:_____ 00 'b i 1 o ct 1-1-0i, _ Lower Hemlock — W st Fo and C4.al xn l 14=— •- -� LKO . • <_ W n Folend (6w4 I ^ f j i 1 1 I • • EXHIBIT A— LANDOWNERS, OWNERS AND OPERATORS Landowner Owner Operator As defined in As defined in As defined in AS 31.05.170 7 AS 31.05.170 10 20 AAC 25.990 46 Le al Descri tion State of Alaska Cook Inlet Cook Inlet ADL 381203 Energy, LLC Energy, LLC T.7N.,R.14W.,SEWARD MERIDIAN,ALASKA SECTION 13,PROTRACTED,ALL,640 ACRES; SECTION 14,PROTRACTED,ALL,640 ACRES; SECTION 23,PROTRACTED,ALL,640 ACRES; SECTION 24,PROTRACTED,ALL,640 ACRES; SECTION 25,PROTRACTED,ALL,640 ACRES; SECTION 26,PROTRACTED,ALL,640 ACRES. THIS TRACT CONTAINS 3,840 ACRES MORE OR LESS. State of Alaska Cook Inlet Cook Inlet Energy, LLC Energy, LLC ADL 374002 T.7N.,R.13W.,SEWARD MERIDIAN,ALASKA SECTION 19,PROTRACTED,ALL,615 ACRES; SECTION 20,PROTRACTED,ALL,640 ACRES; SECTION 21,PROTRACTED,ALL,640 ACRES; SECTION 28,PROTRACTED,ALL,640 ACRES; SECTION 29,PROTRACTED,ALL,640 ACRES; SECTION 30,PROTRACTED,ALL,617 ACRES; SECTION 31,PROTRACTED,ALL,619 ACRES; SECTION 32,PROTRACTED,ALL,640 ACRES; SECTION 33,PROTRACTED,ALL,640 ACRES. THIS TRACT CONTAINS 5691 ACRES MORE OR LESS. Contact Information: State of Alaska CERTIFIED MAIL 7015 1730 0000 6827 2106 Department of Natural Resources Alaska Division of Oil and Gas 550 W 7th Avenue, Suite 1100 Anchorage, AK 99503 907-269-8800 Cook Inlet Energy, LLC CERTIFIED MAIL 7015 1730 0000 6827 2113 601 W. 5th Avenue, Suite 310 Anchorage, AK 99501 907-334-6745 EXHIBIT B - WELLS WITHIN 'A MILE RADIUS OF PROPOSED OPERATION T. 7 N., R. 14 W., S.M. T. 7 N., R. 13 W., S.M. %Z mil 1A 7 9 20 7N/13W • • EXHIBIT C - NOTICE OF OPERATIONS GLACIER March 21,2017 CERTIFIED MAIL Landowners,Owners and Operators See Distribution List West Foreland Area Cook Inlet Basin,Alaska Re: Notice of Operations under 20 AAC 25.283 of Cook Inlet Energy. LLC's Sundry Application for a Fracture Stimulation for the RU 1 A Well Dear Landowner,Owner and/or Operator, Cook Inlet Energy,LLC,a Glacier Oil and Gas company(GLA)is applying for a Sundry Application under 20 AAC 25.283 to perform a fracture stimulation of the RU 1 A well.This Notice is being sent by certified mail to meet the notification requirements under 20 AAC 25.283(a)(I)(A)and 20 AAC 25.283(a)(1)(B). The complete application is available for review upon request.If you wish to review the application,please contact Tim Jones,Senior Landman,at the following: Tim Jones Senior Landman Glacier Oil and Gas Corp. 601 W.5th Avenue,Suite 310 Anchorage,AK 99501 Direct:907-433-3811 tjonesgglacieroil.com GLA,through a search of the public record,has identified you as a Landowner,Owner or Operator(as defined in AOGCC regulations)within '/2 mile of the proposed RU IA well trajectory and fracture stimulation. Please contact me should you require additional information. S4in T. Jones Seni 'Landman Distribution List:Alaska Division of Oil and Gas Cook Inlet Energy,LLC 601 W 5th Ave,Suite 310,Anchorage,AK 99501 EbRU lA Well Fracture Stimulation March 21,2017 EXHIBIT D Affidavit State of Alaska, Third Judicial District Personally appeared before me, Timothy Jones, who, being duly sworn according to law, deposes and says: 1. I, Timothy Jones, am a Senior Landman for Cook Inlet Energy, LLC and a Registered Professional Landman#84167. 2. The Landowners, Owners and Operators, as defined in relevant state statutes and regulations, identified in Exhibit A are correct to the best of my knowledge. 3. The well location in Exhibit B was taken from Cook Inlet Energy, LLC's Permit to Drill submitted to AOGCC. 4. The Notice in Exhibit C was sent to the Landowners, Owners and Operators identified in Exhibit A by certified mail. Further the affiant .ayeth naught. . 3 v 17 Timothy Jones!' Date RPL#84167 UNITED STATES OF AMERICA § § STATE OF ALASKA § Subscribed and sworn to before me on the �i day of March,2017. •`W ;� \ OFFICIAL SEALal '4/47 oper ti i Notary Public TAW_ Pubic•State of Alaska `1,„,,"•, MExpires " My commission expires: 6 • Schwartz, Guy L (DOA) From: Stephen Ratcliff <sratcliff@glacieroil.com> Sent: Monday,April 24, 2017 4:26 PM To: Schwartz, Guy L(DOA) Cc: Amanda Dial; Conrad Perry; Leland Tate; Stephen Ratcliff Subject: Frac Sundries - RU-01A, RU-03A, RU-05B Guy, Per our discussion, please move forward on the approval process for RU-03A Frac Sundry. We will, however,withdraw the Frac sundry requests for RU-05B and RU-01A at this time. Thanks and let me know if you have any questions. Regards, Stephen Ratcliff Glacier Oil and Gas Corporation 601 W.5th Avenue,Suite 310 Anchorage,AK 99501 O-(907)433-3808 C-(907)433-9738 1 • VOF TitI s THE STATE Alaska Oil and Gas of�L A SKA. Conservation Commission kit i,fz = =- 333 West Seventh Avenue r GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Stephen Ratcliff Sr. Drilling and Completion Engineer , 0 22.01.L Cook Inlet Energy, LLC 5t45 601 W. 5th Ave., Ste. 310 Anchorage, AK 99501 Re: Redoubt Shoal Field,Undefined Oil Pool, RU 1 A Permit to Drill Number: 213-079 Sundry Number: 317-052 Dear Mr. Ratcliff: 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 oerster Chair DATED this�J day of February, 2017. RBDN1S U , FF - 7 2017 liRECEIVED • STATE OF ALASKA • JAN 3 0 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 0,-TA6G 20 AAC 25.280 3 � 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate El Other Stimulate ❑ Pull Tubing 2 Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Run ESC] 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: COOK INLET ENERGY,LLC Exploratory ❑ Development 0. 213-079 • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 601 W 5TH AVE SUITE 310,ANCHORAGE,AK,99501 50-733-20497-01-00 , 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No ❑✓ 1 REDOUBT UNIT#1A ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 381203,ADL 378114 : REDOUBT SHOAL,UNDEFINED OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 15,050' ' 12,502' • 14,953'. 12,426'. 2799 NONE NONE Casing Length Size MD TVD Burst Collapse Structural 200' 36" 200' 200' Conductor 1831' 13 3/8" 1831' 1803' 5020 PSI 2260 PSI Surface 6986' 9 5/8" 6986' 5988' 6870 PSI 4760 PSI Intermediate 5544' 7 5/8" 12246' 11616' 6890 PSI 4790 PSI Production __ __ __ Liner 8529' 5 1/2" 15038' 12493' 7740 PSI 6390 PSI Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 14110'-14872' . 11753'-12362' 3 1/2"12.95# P110 14901'MD Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Pith N/A SSSV V° A' N/A 12.Attachments: Proposal Summary Q Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑., BOP Sketch Lj Exploratory LI Stratigraphic❑ Development❑✓ ' Service ❑ 14.Estimated Date fo 0 15.Well Status after proposed work: 15-Feb-17 Commencing Operations: OIL 2• WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ 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 Stephen Ratcliff Email sratcliff@glacieroil.com Printed Name Title Stephen Ratcliff Sr.Drilling&Completion Engineer Signature <'2„.3c.-- Phone Date L"—\\ 907-433-3808 30 -11.") - 24,11 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 1-7— Q Plug Integrity ❑ BOP Test Mechanical Integrity Test El Location Clearance ❑ I-$S c 2_1-q-4. Other: 3cO(:: rn5 6(.-;f" '7,_:s ( Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No V Subsequent Form Required: )0 -1-161-1 RBDMS LL +F - 7 2017 APPROVED BY Approved by: ‘,LIVetili° 9A,cdomosit,....____ COMMISSIONER THE COMMISSION Date:Z -3 -1 7 Submit Form and Form 10-403 Revised 11/2015 0 a ti valid for 12 months from the date of approval. Attachments in Duplicate • • RECEIVED • GLACIER JAN 3 0 2017 January 30th, 2017 AOGCC Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry: RU-01A— Application to Pull Completion Cook Inlet Energy: 50-733-20497-01-00, PTD: 213-079 Dear Ms. Foerster, Cook Inlet Energy, LLC, hereby submits an Application for Sundry Approval for Redoubt Unit 01A, PTD: 213-079, requesting to run the ESP completion. If you have any questions, please contact me at 907.433.3808. Sincerely, Stephen Ratcliff Sr. Drilling & Completions Engineer Cook Inlet Energy, LLC (a Glacier Oil & Gas wholly owned company) 601 W. 5th Avenue STE 310 Anchorage, AK 99501 1 Afr • • GLACIER 1. WELL NAME– RU-01A Requirements of 20 AAC 25.005(f) Well Summary Current Status: The well is shut-in due to a failed ESP. I Scope of Work: • Rig up Rig 35 & NU BOPE • Pull tubing. --� £c . ya o S.—J.3 3/7–cati • RIH with ESP Completion. • N/D BOPE. • Turn well over to production. General Well Information: Reservoir Pressure/TVD: 0.32 psi/ft 4,000 psi @ 14,872' MD (12,362'TVD) MASP: Reservoir Pressure– (Gas Gradient X TVD) (0.32 psi/ft X 12,362' TyQ 4 ..J psi/ft X 12,362') = 3,955 psi– 1236 psi 2,799 psi Wellhead Type/Pressure Rating: 13 5/8" 5M Wellhead - 3 1/2" 5M tree BOPE: 13 5/8" 10M – Pipe Rams/ Blind Rams/Annular Well Type: Oil Well Estimated Start Date: February 15, 2017 Waivers Requested: None CIE Drilling Manager CIE Sr. Drilling Engineer CIE Production Manager Conrad Perry Stephen Ratcliff David Kumar (907) 727-7404 (907) 433-3808 (907) 433-3822 cperry@glacieroil.com sratcliff@glacieroil.com dkumar@glacieroil.com 2 • • GLACIER Program Rig Workover Si`ctoe'3 3'7-o[1 General Note: Prior to this work, the 3-1/2" 12.95# P110 frac string was RIH and set at 14901' MD. General Note: Full opening Safety Valve will be on rig floor at all times with appropriate crossovers for all pipe being run below rotary table. 1. Move rig onto RU-01A. 2. Check for pressure and note pressure in tubing and in annulus. 3. Place back pressure valve in wellhead. 4. Notify AOGCC 48 hours in advance of start of operations and upcoming BOP test. 5. N/D Dry Hole Tree. 6. N/U and Test 13 5/8" BOPE with 2 7/8" x 5" VBR rams with blinds in middle. 7. Test BOPE on 2 7/8" and 31/2"to 250 psi low/3500 psi high and chart. 8. Remove back pressure valve. 9. P/U Landing Joint and make up to 3-1/2" Tubing Hanger. 10. Back out Lock Down screws in Tubing Hanger. wa'r't . 11. Pull & L/D 3-1/2" Landing Joint and Tubing Hanger. 12. Check for Flow and confirm well is dead. 13. POH and L/D 3-1/2" tubing. 14. Prep to pick up ESP Completion equipment, spoolers, and tools. 15. Rig up Summit for ESP Completions. o Hold PJSM for ESP Run. o Test and confirm that all equipment is on location and ready to RIH. o NOTE: COMPLETION ESP/TUBING WILL NOT BE ROTATED. 16. Pick up the ESP completion assembly as directed. o NOTE: Setting depth of ESP BHA at 13,550' MD (Confirm with GLA Engineer prior to RIH). o Pump should be set in less than 1 degree/100' dogleg. (Top of Pump Assy tentatively set for+/- 13,425' MD). o NOTE: the 3/8" flat pack chemical injection line is to be run to the anode on the bottom of the ESP assembly. o 3/8" Nova Valves to be installed at top of pump assembly. 3 • • GLACIER 17. RIH with ESP completion on 3-1/2" 9.3# L80 EUE & 2-7/8" 6.5# 180 EUE tubing. o Test cable every 1000'. o Crossover from 3-1/2" to 2-7/8"tubing at+/- 6,000'. 18. Install ESP packer, vent valve and SSSV assembly. Test cable every 1000'. o 3/8" control lines run independently from vent valve to surface and SSSV to surface. 19. Set Packer at 500' MD. 20. Monitor trip tank for proper hole filling. Splice cable as needed. At TD, confirm pipe tally, MU landing joint and set string in slips. 21. Dress hanger and control lines. Land hanger, run in screws, test hanger to 5000 psi. 22. Test Annulus above packer to 2000 psi. 23. Observe well dead. Lay down landing joint and install BPV. 24. Nipple down riser and BOPE. 25. Install and test production tree to 5,000 psi. Turn over well to production. 26. Release Rig. 4 • RU-01A-Current Wellbore Schematic Date: 30-Jan-17 Version: 1.0 Tubing hanger-ACME 3.725"MCA top connection/ GLACIER 3 1/2"12.95#P-110 PH6 btm connection 36" 150#A-36 200'MD ID-34.00" Welded 200'TVD 18 1/2"Hole w 13 3/8" 68#L-80 1,831'MD ID-12.25" BTC 1,803'TVD 4 3 1/2"12.95#P-110 PH6 Tubing-ID 2.625"@ 14,901'MD TOL @ 6,509'MD/5,605'TVD(9 5/8"x 5 1/2") TOL @ 6,702'MD/6,803'TVD(7 5/8"X 9 5/8") 9 5/8" 47#L-80 6,986'MD 12 1/4"Hole ID-8.50" BTC 5,988'TVD 7 5/8" 29.7#L-80 12,246'MD 8 1/2"Hole ID-6.75" BTC 10,231'TVD TOC(2013 CBL)@ 12,900'MD '— I • 5 1/2" 17#L-80 15,038'MD 6 314"Hole ID-4.767" Hydril 521 12,493'TVD S RU-01A Proposed Wellbore Schematic Version:1 Planned /30/2017 • < I Tubing hanger-ACME 3.725"MCA top connection/ G LACIER 1 3 1/2"EUE 8rd btm connection-ID 2.950" 36" 150#A-36 200'MD F_ .; ID-34.00" Welded 200'TVD I- - 3-1/2"SSSV-ID 2.992"@ 300'MD/300'TVD 1"Vent Valve w/1/4"seamless steel line 18 1/2"Hole I ' Trident Packer @ 500'MD 13 3/8" 68#L-80 1,831'MD ID-12.25" BTC 1,803'TVD 4 3 1/2"9.3#L-80 EUE Tubing-ID 2.992" - F/6,000'MD to surface 4 XO-27/8"x31/2"-ID 2.441"@6,000'MD/5,197'TVD TOL @ 6,509'MD/5,605'TVD(9 5/8"x 5 1/2") 1111 _ 2 7/8"6.5#L-80 EUE Tubing-ID 2.441" @ 13,420'MD-6,000'MD/11,174'TVD-5,197'TVD TOL @ 6,702'MD/6,803'TVD(7 5/8"X 9 5/8") ■ . 9 5/8" 47#L-80 6,986'MD 12 1/4"Hole 4 Ilk ID-8.50" BTC 5,988'TVD Dual 3/8"Stainless Flat Pack Lines 7 5/8" 29.7#L-80 12,246'MD 8 1/2"Hole ID-6.75" BTC 10,231'TVD ESP Assembly Top @ 13,420'MD/11,174'TVD r' ELECTRIC SUBMERSIBLE PUMP-200' '- _r ESP#1 Flat Pack Cable Discharge Unit Assembly Pump Assembly(3) Intake/Gas Separator Seal Assembly-Upper/Lower Seals Ji!". Motor(2)/Motor Gauge Unit Sensor Anode IChemical Injection Check Valve 1 j ESP Assembly Bottom @ 13,550'MD/11,28 i'T vD Perforations ", I'. MD TVD Feet - vs 14,110'-14,154' 11,753-11,789' 48 ' 14,171'-14,230' 11,803-11,851' 59 .II 1 14,261'-14,303' 11,876'-11,909' 42 .411ll ICC 14,373-14,570' 11,964'-12,122' 197 IC7C 14,581-14,588' 12,131'-12,137' 7 1 11` 14,610'-14,721' 12,154'-12,243' 111 7575. 14,726'-14,746' 12,247'-12,263' 20 ' 11 14,758'-14,786' 12,272'-12,294' 38 77X 14,812'-14,836' 12,315'-12,334' 24 '_ X, 14,852'-14,872' 12,346'-12,362' 60 , Total Perforations 606 7rs, >r= 5 1/2" 17#L-80 15,038'MD 6 3/4"Hole I ' I ID-4.767" Hydril 521 12,493'TVD 5{- 1A- rrb 2 ti3-mc Regg, James B (DOA) From: Regg,James B (DOA) Sent: Thursday,January 19, 2017 11:10 AMc2/1 11(111/ To: 'Osprey Drilling' Cc: Brooks, Phoebe L (DOA) Subject: RE: Glacier 35 Attachments: BOP Inlet35 1-18-17 revised.xlsx; 1-18-16 BOPE Test Summary(aogcc comments).docx Revised test report is attached. I count 9 failures from the Summary provided earlier(attached; annotated). MASP was blank; should be 2799 Changed the Remarks to list the 9 failures since there are multiple FP's in the miscellaneous cells Changed reference to "Blind shear" in Test Report Remarks to "Blind Ram". Jim Regg Supervisor, Inspections AOGCC %We V1. J QI 10!' 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 orjim.regg@alaska.gov. From: Osprey Drilling [mailto:ospreydrilling@glacieroil.com] Sent:Thursday,January 19, 2017 3:35 AM To: Regg,James B (DOA) <jim.regg@alaska.gov> Subject: Glacier 35 Mr. Regg Here is the BOP test report. DSM Osprey Platform Joshua Guy Lenward Toussant 907-776-7167 work ospreydrilling@glacieroil.com 1 • • STATE OF ALASKA 1 P OIL AND GAS CONSERVATION COMMISSION ',M4 BOPE Test Report Submit to: jim.reggealaska.gov AOGCC.Inspectors aC�.alaska.gov phoebe.brooksCaialaska.gov Contractor: Inlet Drilling Rig No.: 35 DATE: 1/18/17 Rig Rep.: Daniel Sainz Rig Phone: (907)776-7173 Operator: Glacier Oil&Gas Op. Phone: (907)776-7167 Rep.: Joshua Guy/Len Toussant E-Mail ospreydrilling@glacieroil.com Well Name: RU-01A PTD# 2130790 Sundry# 317-011 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Test Pressure(psi): Rams: 250/3500 Annular: 250/2500 Valves: 250/3500 MASP: 2799 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen. P Well Sign P Upper Kelly 1 P Housekeeping P Rig P Lower Kelly 1 P PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P Misc. NA Inside BOP 1 P FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13 5/8 P Pit Level Indicators P P #1 Rams 1 2 7/8"X 5" FP Flow Indicator P P #2 Rams 1 Blind FP Meth Gas Detector P P #3 Rams 1 2 7/8"X 5" FP H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln.Valves 1 4 1/16" P Inside Reel valves 0 NA HCR Valves 2 4 1/16", 3 1/16" P Kill Line Valves 2 3 1/16", 2 1/16" P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 3 See remarks FP Time/Pressure Test Result System Pressure(psi) 3000 P CHOKE MANIFOLD: Pressure After Closure(psi) 1850 P Quantity Test Result 200 psi Attained(sec) 28 P No.Valves 12 P Full Pressure Attained(sec) 122 P Manual Chokes 1 P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles#&psi(Avg.): 6 @ 2000 P CH Misc 1 FP ACC Misc 2 FP Test Results Number of Failures: 9 Test Time: 81.0 Hours Repair or replacement of equipment will be made within 0 days. Notify the AOGCC of repairs with written confirmation to:AOGCC.Inspectors@alaska.gov Remarks: All test performed on 2 7/8&3 1/2 test joints. 9 Failures: #1 -Kill Line DSA leak; retorque; pass. #2-Choke Manifold frozen;thaw; pass. #3-Lower BOP flange leak; retorque; pass. #4-Choke Line frozen;thaw; pass. #5-Upper VBR; replace bonnet seals; pass. #6-Lower VBR; replace door&bonnet seals; pass. #7-Blind rams; replaced bonnet seals; pass. #8-Accumulator 4-way control valve leak; repair; pass. #9-Accumulator Manifold Pressure; adjust; pass. AOGCC Inspection 24 hr Notice Yes Date/Time 1-11-2017 Waived By Lou Grimaldi Test Start Date/Time: 1/14/2017 19:00 (date) (time) Witness Test Finish Date/Time: 1/18/2017 4:00 Form 10-424(Revised 11/2015) BOP Inlet35 1-18-17 revised.xlsx .G • 130 vt_- 'S4- t kkay 0- 1-14-2017 19:00 Test annular to 250/2500 PSI. with 3 1/2"test joint. Test upper VBR rams, choke manifold valves 1-12, and choke and kill HCR with 3 1/2 test joint to 250/3500 PSI. Had one failure on kill line DSA. Choke manifold valves 3, 5, and test line were froze.Thaw out with steam heaters. Continue testing; chasing leak between upper pipe rams, HCR's, and manual choke and kill valves. Isolate each component except the upper pipe rams and got same bleed off. Pull test joint and test against blind rams with similar leak off. Froze test lines again. Break down and thaw out.Attempt to test FOSV, but had similar bleed off. Suspected issue with test equipment. Perform multiple tests until located dampener out of adjustment for test chart.Thaw frozen test lines and rig up forced air heater along feed line. 1-15-2017 11:30 Restart BOP Test.Test lower VBR rams with 3.5" to 250/3,500 psi. Found leak at lower BOP flange and ram bonnet. Retorque all riser connections and lower pipe ram bonnets. Retest lower pipe rams, door still leaking. Replace leaking bonnet seal. Flush and refill BOPE. Discovered choke line frozen. Add more tarping around choke manifold. Unable to thaw choke line externally. Break out choke line and thaw ice plug with internal steam. Nipple up choke line. Refill stack. Flush and fill lines. Using 3.5" test joint,test annular to 250/2500 PSI.Test upper VBR, Choke manifold valves# 1-12, Choke & Kill HCR's, Choke & Kill manual valves, dart valve, FOSV, and blind rams to 250/3500 PSI.Attempt to test top drive safety valves. Unable to test them by themselves. Pressure increasing due to water freezing in test line. With 2 7/8" test joint,test annular to 250/2500 PSI. Attempt to test upper VBR pipe rams. Unable to pressure up. Attempt to test lower VBR pipe rams. Unable to pressure up. FAIL#4. Perform accumulator performance test. Change test assembly for 2 7/8" pipe with Vetco test donut to center pipe in stack. No success with either rams. Install new 3rd party VBR in lower rams, and Cameron VBR in upper rams along with new top seals and bonnet gaskets. Attempt to test upper rams. Driller's side upper bonnet and both blind ram bonnets leaked. Retighten and retest with no success. FAIL#5. Open driller's side upper bonnet and both blind bonnets. Clean bonnets. Wait for daylight to get more bonnet seals. Receive and install new bonnet seals. With 2 7/8",test upper VBR to 250/3,500 psi. Attempt to test lower VBR. Unable to pressure up. Pressure test Blind rams to 250/3,500 psi. Remove 3rd party VBR elements and replace with Cameron elements. With 2 7/8", test lower VBR to 250/3,500 psi. Slow leak on high test. Inspect BOP and accumulator and found manifold pressure down to 800 psi. Bled off test. Small drip on 4 way bop control valve as well as manifold pressure not correctly reset to 1,500 psi. after ram change. Retest lower VBR rams to 250/3,500 psi. Good test. With 3.5",test lower VBR pipe rams, upper VBR pipe rams, lower manual top drive safety valve, and upper hydraulic top drive safety valve to 250/3,500 psi. 1-18-2017 04:00 Test complete. FAILURES(per J. Regg,AOGCC): 1. Kill Line DSA(leak) 6. Upper VBR (rams; bonnet seals) 2. Choke Manifold (frozen) 7. Blind Rams(bonnet seals) 3. Lower BOP Flange (leak) 8. Accumulator 4-way Control Valve (leak) 4. Lower VBR (rams; bonnet seals) 9. Accumulator Manifold Pressure (low) 5. Choke Line (frozen) • • • yor Tg gw��\�yy,�s THE STATE Alaska Oil and Gas F O Conservation Commission . - fALASI�:A Sllt� 333 West Seventh Avenue kie""'' c GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 n, Main: 907.279.1433 OF S�.• Fax: 907.276.7542 www.aogcc.alaska.gov Stephen Ratcliff Sr. Drilling Engineer cw �'1 Cook Inlet Energy, LLC SCW�E� VIAR 601 W. 5th Ave., Suite 310 Anchorage, AK 99501 Re: Redoubt Shoal Field, Undefined Pool, Redoubt Unit 1A Permit to Drill Number: 213-079 Sundry Number: 317-011 Dear Mr. Ratcliff: 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, ale Cathy P. Foerster Chair DATED this /3 day of January, 2017. RBDMS / Omi, L y 1017 ECE1VED • STATE OF ALASKA • JAN 11 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION di f51 APPLICATION FOR SUNDRY APPROVALS 4 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q Change Approved Program V Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Run Tbq,RBP0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: COOK INLET ENERGY,LLC Exploratory ❑ Development 2 . 213-079 ' 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 601 W 5TH AVE SUITE 310,ANCHORAGE,AK,99501 50-733-20497-01-00, 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No ❑., REDOUBT UNIT#1A 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 381203,ADL 378114 . REDOUBT SHOAL, UNDEFINED OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 15,050' ' 12,502' s 14,953' % 12,426'• 2799 NONE NONE Casing Length Size MD TVD Burst Collapse Structural 200' 36" 200' 200' Conductor 1831' 13 3/8" 1831' 1803' 5020 PSI 2260 PSI Surface 6986' 9 5/8" 6986' 5988' 6870 PSI 4760 PSI Intermediate 5544' 7 5/8" 12246' 11616' 6890 PSI 4790 PSI Production __ __ __ __ __ -- Liner 8529' 5 1/2" 15038' 12493' 7740 PSI 6390 PSI Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 14110'-14872' r 11753'-12362' 2 7/8"6.7# L80 12429' Packers and SSSV Type: Baker Twin Seal Packer Packers and SSSV MD(ft)and TVD(ft): 'Packer @ 2023'MD/1981'TVD Baker TE5 2 7/8"SSSV SSSV @�9 'MD/TVD /7/41)12.Attachments: Proposal Summary 0 Wellbore schematic ❑� 13.Well Class after proposed work: 3� Detailed Operations Program E BOP Sketch ❑✓ Exploratory ❑ Stratigraphic❑ Development❑✓ ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: ASAP Commencing Operations: OIL ❑✓ ' WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ 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 Stephen Ratcliff Email sratcliff@glacieroil.com Printed Name Title Stephen Ratcliff Sr.Drilling&Completion Engineer Signature �- Phone Date ._SL,---. .—.A 907-433-3808 1/11/2017 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 \ -7 - c3 Plug Integrity ❑ BOP Test LTJ MechanicalIntegrityTest ❑ Location Clearance ❑ Other: /.-3 SCJL7 /Os Z. St) —re.---s r— Post Initial Injection MIT Req d? Yes ❑ No 111m �Bp�S Spacing Exception Required? Yes ❑ No Zr Subsequent Form Required: /0 1i O41 JANL 5 201 APPROVED BY Approved by // �(/`-- COMMISSIONER THE COMMISSION Date: /—/3 �/7 10 A `t i /� Submit Form and Form 10-403'evised 11/20 5 Approved application is v01 RittislIAate of approval. Attachments in Duplicate . < • • GLACIER January 11th, 2017 RECEIVED JAN I1 2017 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission AOG C 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry: RU-01A— Application to Pull Completion Cook Inlet Energy: 50-733-20497-01-00, PTD: 213-079 Dear Ms. Foerster, Cook Inlet Energy, LLC, hereby submits an Application for Sundry Approval for Redoubt Unit 01A, PTD: 213-079, requesting permission to change the approved program under Sundry 316-543. The current ESP completion will be pulled, a retrievable bridge plug will be set and a 3-1/2" tubing will be utilized. / If you have any questions, please contact me at 907.433.3808. Sincerely, Com`( Stephen Ratcliff Sr. Drilling& Completions Engineer Cook Inlet Energy, LLC (a Glacier Oil & Gas wholly owned company) 601 W. 5th Avenue STE 310 Anchorage, AK 99501 1 . < • GLACIER 1. WELL NAME— RU-01A Requirements of 20 AAC 25.005(f) Well Summary Current Status: The well is shut-in due to a failed ESP. v Scope of Work: • Rig up Rig 35 & NU BOPE • Pull ESP completion and tubing. • RIH with Retrievable Bridge Plug and set at 6800' MD. • RIH with 3-1/2" Tubing. • N/D BOPE & Secure well. General Well Information: Reservoir Pressure/TVD: 0.32 psi/ft 4,000 psi @ 14,872' MD (12,362' TVD) MASP: Reservoir Pressure— (Gas Gradient X TVD) (0.32 psi/ft X 12,362' TVD) — (0.1 psi/ft X 12,362') = 3,955 psi — 1236 psi = 2,799 psi Wellhead Type/Pressure Rating: 13 5/8" 5M Wellhead - 3 1/2" 5M tree BOPE: 13 5/8'PlJ—Pipe Rams/ Blind Rams/Annular Well Type: Oil Well Estimated Start Date: ASAP Waivers Requested: None CIE Drilling Manager CIE Sr. Drilling Engineer CIE Production Manager Conrad Perry Stephen Ratcliff David Kumar (907) 727-7404 (907) 433-3808 (907) 433-3822 cperry@glacieroil.com sratcliff@glacieroil.com dkumar@glacieroil.com 2 • • GLACIER Program Pre-Rig 1. Conduct pre-job safety meeting with all personnel on location. o Review upcoming work and discuss safety first. 2. Lock out safety systems and power oil 3. Confirm that the SSSV is open. 4. Prep for Rig and Workover operations. 5. Ensure that well is dead. Rig Workover General Note:There is 2 7/8"tubing currently in the well. General Note: Full opening Safety Valve will be on rig floor at all times with appropriate crossovers for all pipe being run below rotary table. 1. Move rig onto RU-01A. 2. Check for pressure and note pressure in tubing and in annulus. 41e o Note: The Twin seal packer has a vent line from 2023' MD. 3. R/U lines from tree and annulus to production if not done prior to rig move. 4. Check for flow and shut in well. — K;1( Wet! as A-‘0.2-11 , 5. Place back pressure valve in wellhead. /..47-/7 6. Notify AOGCC 48 hours in advance of start of operations and upcoming BOP test. 7. N/D Production Tree. aP 8. N/U and Test 13 5/8" BOPE with 2 7/8" x 5" VBR rams with blinds in middle. ,(,0 r 9. Test BOPE on 2 7/8" and 31/2" to 250 psi low/3500 psi high and chart. 10. Rig up ESP spoolers and hardware. 11. Remove back pressure valve. (1 M 12. P/U Landing Joint and make up to 2-7/8" Tubing Hanger. 13. Back out Lock Down screws in Tubing Hanger. 14. Pick up with straight pull to release packer at 2023' MD. o Max Pull not to Exceed 115,000 lbs • W/O Weight of Blocks 15. Kill well with 8.7 ppg produced water+ KCI, circulate wellbore volume. o Be prepared for circulating gas buildup below packer. o Track fluid volume to identify losses if they occur. 3 • • GLACIER • Have salt pill prepared if losses are identified. 16. Pull & LID 2-7/8" Landing Joint and Tubing Hanger. 17. Check for Flow and confirm well is dead. 18. POH and L/D the following: o 2-7/8" Tubing e iHl o sssv o Twin Seal Packer with vent valve itAk o 2-7/8"Tubing o ESP BHA 19. Rig up E-line. 20. RIH and set Retrievable Bridge Plug at 6800' MD. 21. Pressure test RBP to 1500 psi to ensure set. e� �� -� f 22. Rig down E-line. 1� e 23. P/U 3-1/2" 12.95# P110 PH-6 Tubing. S 24. RIH to 300' MD. 25. M/U Landing Joint and set tubing string in slips. 26. Land tubing hanger and test seals to 5,000 psi through test port. 27. L/D Landing Joint. l4-t-r 1 28. Set Back Pressure Valve o Observe that well is dead. 29. Nipple down BOPE. 30. Nipple up tree and test to 5,000 psi. 31. Secure well. 4 • RU-01A Final ESP Completion-As Ran • Version: Final Cook Inlet Energy August 13,2013 J I 36" 150#A-36 200'MD 1` ID-34.00" Welded 200'TVD Baker TE5 2-7/8"SSSV @ 320'MD/320'TVD . _ 7 [w _ ) b" 13 3/8" 68#L-80 1,831'MD 181/2"Hole - .,, ID-12.25" BTC 1,803'TVD 1 V Weatherford t Valve M 11111110 fir 9-5/8"Baker Twin Seal Packer cker @ 2,023'MD/1,981'TVD `rl t L 2-7/8"XN Nipple @ 2,122'MD/2,070'TVD r TOL @ 6,509'MD - - 9 5/8"x 5 1/2"Liner Hanger TOL @ 6,712'MD . . 75/8"X 9 5/8"Liner Hanger 9 5/8" 47#L-80 6,986'MD 12 1/4"Hole ,, ` ID-8.50" BTC 5,988'ND 2-7/8"6.5#L-80 EUE Tubing 7 5/8" 29.7#L-80 12,246'MD 8 1/2"Hole ID-6.75" BTC 10,231'TVD ' 2 7/8"6.5#L-80 EUE Tubing I. Baker Centrilift ESP Assembly Top of Discharge Head @ 13,469'MD E ESP Cable F/13,470'-Surface e • L II Ilalll ESP Pump Assembly @ 13,479'MD ESP Motor Assembly @ 13,611'MD Perforations MD TVD Feet ICz 14,110'-14,154' 11,753'-11,789' 48 '3= 14,171'-14,230' 11,803'-11,851' 59 33 E 14,261'-14,303' 11,876'-11,909' 42 .� Q ix 14,373'-14,570' 11,964'-12,122' 197 � 14,581-14,588' 12,131'-12,137' 7 14,610'-14,721' 12,154'-12,243' 111 ' 1Q ?S 7Q 14,726'-14,746' 12,247'-12,263' 20 14,758'-14,786' 12,272'-12,294' 38 7Z 14,812'-14,836' 12,315'-12,334' 24 f'(C7t. 14,852'-14,872' 12,346'-12,362' 60 LC.'. Total Perforations 606 a tx r l ll- 5 1/2" 176 L-80 15,038'MD 6 3/4"Hole ID-4.767" Hydril 521 12,493'TVD RU-01A Proposed Wellbore Schematic • Version: Planned 41110 1/11/2017 GLACIER 36" 150#A-36 200'MD ID-34.00" Welded 200'TVD 31/2"12.954 P-110 PH6 Tubing-ID 2.625"t/300'MD 13 3/8" 68#L-80 _ 1,831'MD 18 1/2"Hole ID-12.25" BTC 1,803'TVD h ;z 2-7/8"6.5#L-80 EUE Tubing TOL @ 6,509'MD - 9 5/8"x 5 1/2"Liner Hanger 7 5-1/2"Retrievable Bridge Plug @ 6,800'MD TOL @ 6,712'MD 7 5/8"X 9 5/8"Liner Hanger 9 5/8" _ 47#L-80 6,986'MD 12 1/4"Hole ID-8.50" BTC 5,988'TVD 7 5/8" 29.7#L-80 12,246'MD 8 1/2"Hole ID-6.75" BTC 10,231'TVD ;y Perforations MD TVD Feet g 14,110'-14,154 11,753'-11,789 48 14,171'-14,230 11,803'-11,851 59 14,261'-14,30311,876'-11,909 42 =� = c 14,373'-14,570 11,964'-12,122 197 14,581-14,588'12,131'-12,137 7 L 14,610'-14,72112,154'-12,243 111 = �. � c 14,726'-14,74612,247'-12,263 20 14,758'-14,786 12,272'-12,294 38 xs 14,812'-14,836 12,315'-12,334 24 = _ 14,852'-14.872 12,346'-12,362 60 ] L Total Perforations 606 -_ c 5 1/2" 17#L-80 15,038'MD 6 3/4"Hole ID-4.767" Hydril 521 12,493'TVD • OF Tey • • gwy �� 7-4 THE STATE Alaska Oil and Gas ofALAsKA Conservation Commission 333 West Seventh Avenue C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 pF S�Q, Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Stephen Ratcliff Sr. Drilling Engineer WANED FEB 2 $2 0.17J Cook Inlet Energy, LLC 601 West 5th Avenue, Suite 310 Anchorage, AK 99501 Re: Redoubt Shoal Unit, Undefined Oil Pool, Redoubt Unit#1A Permit to Drill Number: 213-079 Sundry Number: 316-543 Dear Mr. Ratcliff: 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, PLS Cathy . Foerster Chair S{'- DATED this 3i day of October, 2016. RBDMS IA/ NOV - 1 2016 • • RECEIVED • STATE OF ALASKA OCT 20 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION ars ,o h t/ /4, APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations 11}0 Fracture Stimulate ❑ Re6_J7�ppair Well CIOperations shutdown 111 Suspend t Perforate ❑ Other Stimulate ❑ Pull Tubing ❑✓ Change Approved Progr m❑ Plug for Redrill LI Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Run Tu Ind] 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: COOK INLET ENERGY,LLC Exploratory ❑ Development 0 213-079 ' 3.Address: Stratigraphic ElService El 6.API Number: 601 W 5TH AVE SUITE 310,ANCHORAGE,AK,99501 50-733-20497-01-00. 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA- Will tjkWill planned perforations require a spacing exception? Yes ❑ No 2' 91b REDOUBT UNIT#1A • 9.Property Designation(Lease Number): 10.Field/Pool(s): `moi ADL 381203,ADL 378114 • REDOUBT SHOAL (A&I J-yam\ 0/L• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 15,050' - -12,502' ' 14,953' • 12,426' 2799 NONE NONE Casing Length Size MD TVD Burst Collapse Structural 200' 36" 200' 200' Conductor 1831' 13 3/8" 1831' 1803' 5020 PSI 2260 PSI Surface 6986' 9 5/8" 6986' 5988' 6870 PSI 4760 PSI Intermediate 5544' 7 5/8" 12246' 11616' 6890 PSI 4790 PSI Production Liner 8529' 5 1/2" 15038' 12493' 7740 PSI 6390 PSI Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 14110'-14872' • 11753'-12362' 2 7/8"6.7# L80 12429' 0 Packers and SSSV Type: Baker Twin Seal Packer Packers and SSSV MD(ft)and TVD(ft): Packer @ 2023'MD/1981'TVD Baker TE5 2 7/8"SSSV SSSV @ 300'MD/TVD 12.Attachments: Proposal Summary L] Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch ❑., Exploratory ❑ Stratigraphic❑ Development❑✓ Service ❑ 14.Estimated Date for 15.Well S tus after proposed work: 1-Dec-16 Commencing Operations: OIL * WINJ ❑ WDSPL ❑ Suspended I ] 16.Verbal Approval: Date: GAS ❑ WAG ❑ 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 Stephen Ratcliff Email sratcliff@glacieroil.com Printed Name Title Stephen Ratcliff Sr.Drilling&Completion Engineer Signature ��O�hone Date 907-433-3808 10/20/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number:\IR -61-1 Plug Integrity ❑ BOP Test /✓Mechanical- Integrity�' Test ❑ Location Clearance ❑ \ Other: A. 350:) ,e, „ ,jtVf ' 7r` \ �nli �jw�Aul 1--S-6 C. f'i .) 7� t T 7 Lx r4.4414-t--.- ( '$.�•"�C.� ,J i I'+'l.L✓141- 's-+,.., Post Initial Injection MIT Req'd? Yes 0 No Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: /0., - 0 41 , i ► tom, RBDMS VV NOV - 1 2016 APPROVED BY Approved by:aCOMMISSIONER THE COMMISSION Date:f O . 3/--kr �"'✓f f � Submit Fo and Form 10-403 Revised 11/2015R1f61 tilt iLalid for 12 m0 SA0917 date of approval. Attachments in Duplicate . GLACIER October 20, 2016 RECEIVED Ms. Cathy Foerster, Chair OCT 20 2Oib Alaska Oil and Gas Conservation Commission AOGCC 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry: RU-01A— Application to Pull Completion Cook Inlet Energy: 50-733-20497-01-00, PTD: 213-079 Dear Ms. Foerster, Cook Inlet Energy, LLC, hereby submits an Application for Sundry Approval for Redoubt Unit 01A, PTD: 213-079, requesting permission to pull the current ESP completion and run and cement 3-1/2" tubing in preparation for future stimulation activities. If you have any questions, please contact me at 907.433.3808. Sincerely, \\ Stephen Ratcliff Sr. Drilling& Completions Engineer Cook Inlet Energy, LLC (a Glacier Oil & Gas wholly owned company) 601 W. 5th Avenue STE 310 Anchorage, AK 99501 1 • RU-01A Current Wellbore Schematic • Version: Final August 13,2013 Cook Inlet Energy _I 36" 150#A-36 200'MD ID-34.00" Welded 200'TVD iw t Baker TE5 2-7/8"SSSV @ 320'MD/320'TVD I s 13 3/8" 68#L-80 1,831'MD 18 1/2"Hole ID-12.25" BTC 1,803'TVD Weatherford 1"Vent Valve 1/80 9-5/8"Baker Twin Seal Packer @ 2,023'MD/1,981' TVD a - 2-7/8"XN Nipple @ 2,122' MD/2,070'TVD TOL @ 6,509'MD 9 5/8"x 5 1/2"Liner Hanger TOL @ 6,712'MD ,. . 7 5/8"X 9 5/8"Liner Hanger d " 9 5/8" 47#L-80 6,986'MD 12 1/4"Hole iik1 Ilk ID-8.50" BTC 5,988'TVD 11 2-7/8"6.5#L-80 EUE Tubing 1,,1 7 5/8" 29.7#L-80 12,246'MD 8 1/2"Hole j ID-6.75" BTC 10,231'TVD T y 2 7/8"6.5#L-80 EUE Tubing " I; Baker Centrilift ESP Assembly Top of Discharge Head @ 13,469'MD ESP Cable F/13,470'-Surface • ''l 1( _ ESP Pump Assembly @ 13,479'MD ESP Motor Assembly @ 13,611'MD Perforations MD TVD Feet a 14,110'-14,15411,753'-11,789' 48 ',a 14,171'-14,23011,803'-11,851' 59 II t' .14,261.-14,303 11,876.-11,909 42 a Q. a Q 14,373'-14,570 11,964'-12,122 197 14,581-14,588 12,131'-12,137 7 In L Q 14,610'-14,72112,154'-12,243 111 a a 14,726'-14,74612,247'-12,263 20 -f1 rT 14,758'-14,78612,272'-12,294' 38 1J 11 a a 14,812-14,836 12,315'-12,334' 24 a. 14,857-14,872 12,346'-12,362 60 ,]j II TotalPerforations 606 a �, 5 1/2" 17#L-80 15,038'MD 6 3/4"Hole I ID-4.767" Hydril 521 12,493'TVD RU-01A-Proposed Interim Schematic • Date: 12-Oct-16 • Version: 2.0 • Tubing hanger-3 1/2"EUE 8rd btm-ID 2.950" GLACIER 36" 150#A-36 200'MD ID-34.00" Welded 200'TVD 18 1/2"Hole , 13 318" 68#L-80 1,831'MD ID-12.25" BTC 1,803'TVD Frac Stung 3 1/2"12.954 P-110 PH6 Tubing-ID 2.625"@ 14945' MD 9 5/8"x 5 1/2"Liner Hanger @ 6509'MD/5605'TVD I; 7 5/8"X 9 5/8"Liner Hanger @ 6702'MD/6803'TVD 9 5/8" 47#L-80 _ 6,986'MD 12 114"Hole ` ID-8.50" BTC 5,988'TVD 7 5/8" 29.7#L-80 12,246'MD 8 1/2"Hole ID-6.75" BTC 10,231'TVD TOC(2013 CBL)@ 12900'MD 17 1 (372-- ) p)( Top of Cement @+/-13,330'MD V Old Perforations MD TVD Feet >o 14,110'-14.872' 11,753-12,362' 606 ,I .o i o 5 1/2" 17#L-80 15,038'MD 6 3/4"Hole ID-4.767" Hydril 521 12,493'TVD • GLACIER 1. WELL NAME— RU-01A Requirements of 20 AAC 25.005(f) Well Summary Current Status: The well is shut-in due to a failed ESP. Scope of Work: • Rig up Rig 37 & NU BOPE • Pull ESP completion and tubing. • RIH with 3-1/2" Tubing and cement. • N/D BOPE & Secure well. General Well Information: Reservoir Pressure/TVD: 0.32 psi/ft 4,000 psi @ 14,872' MD (12,362' TVD) MASP: Reservoir Pressure— (Gas Gradient X TVD) (0.32 psi/ft X 12,362' TVD)— (0.1 psi/ft X 12,362') = 3,955 psi — 1236 psi = 2,799 psi Wellhead Type/Pressure Rating: 13 5/8" 5M Wellhead - 3 1/2" 5M tree BOPE: 13 5/8",5M—Pipe Rams/ Blind Rams/Annular Well Type: Oil Well Estimated Start Date: December 1, 2016 Waivers Requested: None CIE Drilling Manager CIE Sr. Drilling Engineer CIE Production Manager Conrad Perry Stephen Ratcliff David Kumar (907) 727-7404 (907) 433-3808 (907) 433-3822 cperry@glacieroil.com sratcliff@glacieroil.com dkumar@glacieroil.com 2 . < • • GLACIER Program Pre-Rig 1. Conduct pre-job safety meeting with all personnel on location. o Review upcoming work and discuss safety first. 2. Lock out safety systems and power oil 3. Confirm that the SSSV is open. 4. Prep for Rig and Workover operations. 5. Ensure that well is dead. Rig Workover General Note: There is 2 7/8" tubing currently in the well. General Note: Full opening Safety Valve will be on rig floor at all times with appropriate crossovers for all pipe being run below rotary table. 1. Move rig onto RU-01A. 2. Check for pressure and note pressure in tubing and in annulus. o Note: The Twin seal packer has a vent line from 2023' MD. 3. R/U lines from tree and annulus to production if not done prior to rig move. 4. Check for flow and shut in well. 5. Place back pressure valve in wellhead. 6. Notify AOGCC 48 hours in advance of start of operations and upcoming BOP test. 7. N/D Production Tree. 8. N/U and Test 13 5/8" BOPE with 2 7/8" x 5" VBR rams with blinds in middle. 9. Test BOPE on 2 7/8" and 3 1/2" to 250 psi low/350si high and chart. 10. Rig up ESP spoolers and hardware. 11. Remove back pressure valve. 12. P/U Landing Joint and make up to 2-7/8" Tubing Hanger. 13. Back out Lock Down screws in Tubing Hanger. 14. Pick up with straight pull to release packer at 2023' MD. o Max Pull not to Exceed 115,000 lbs ■ W/O Weight of Blocks 15. Kill well with 8.7 ppg produced water+ KCI, circulate wellbore volume. o Be prepared for circulating gas buildup below packer. o Track fluid volume to identify losses if they occur. ■ Have salt pill prepared if losses are identified. 3 . < • GLACIER 16. Pull & L/D 2-7/8" Landing Joint and Tubing Hanger. 17. Check for Flow and confirm well is dead. 18. POH and LID the following: o 2-7/8"Tubing o SSSV o Twin Seal Packer with vent valve o 2-7/8"Tubing o ESP BHA 19. P/U 3-1/2" 12.95# P110 PH-6 Tubing. 20. RIH to 14,945' MD. 21. RU Cementing equipment and test lines to 4800 psi. 22. Pump 15bbls of 11.5ppg Spacer, followed by 20 bbls of 16.5ppg Class G cement and displace with 122 bbls of 8.6ppg sea water. 'I 23. M/U Landing Joint and set tubing string in slips. 3x S 24. Land tubing hanger and test seals to 5,000 psi through test port. �i 25. L/D Landing Joint. 47, 35"6n P 26. RD Cementing equipment. 27. Set Back Pressure Valve 154 o Observe that well is dead. • Qi 28. Nipple down BOPE. 29. Nipple up tree and test to 5,000 psi. 30. Secure well. o ' 011 Separate Application for Sundry will be submitted for Stimulation Operations. " C3L Lc.scQiL 1_506 P s ` (3 u 4 i i GLACIER a. IiaF A IV CI >I r \FArg '11' r T . maw; Fra f , r. rA Lk OVACK 1aa IAD WI et FrliaI I MAI ': 1AT IT 130 FT r tlItt. y .4Ts 44 I 4 4 ,I ! NiiFi 6C'`- '1r Ira 1 ft fie+ ' Res'4s" --4�_meastilgl o _ f_ �_ ?2[.xi .is, rni ) I DRILLING RIG ARR.�NGE' [NT EAST SIDE APPR54.0L DAC L)'''' V H i iS , ilNKIIMI. Orr 1.,...t.../.1_1/1-' 175 R}Y Lr 1G 'QIP uir_ 6 • • GLACIER REDOUBT UNIT#7 WELLHEAD SCHEMATIC I--24.3r I .II. 1!. ...1L 3-1/8 5000 ICS a 80.68' '' '' • .H. SN w 3-1/8 5000 .1�. Ptw!I� r rn 16.63" pp (n ry !N 13-5/6 5000 68X 'q fi ql AUCNYCNl P64 SHOWN 90'OUT Of POSITION 26.00' l 11 �� 2-1/16 5000 W/4R 13-5/8 5000 68% �� 7 IIII ` ,1 2-1/16 5000 W/V8 24.75- it 1 11. 11 .1-a+-11.I1 Mu-, I pill111 �I 36'OD CASING 13-3/8"OD CASINO 3-1/7 OD TURIN i 9-5/8" 00,CASINC ALL DMIENS10145 ARE APPROX. 7 • • GLACIER • 7132012 5.2'.-12 164 BOP Schematic Gey Wail:P Pi "R16 Floor KB Boynton boa: 6r2812042 U 1 Af000r a dRpracec from'Ria Floor' 1 n III mau un (Imp cifM.u..ar P i "\Hydril Ic. 1 — --1. 13.618"61(Annular • 13.1dB'1ei./Mall I - Ir' __._ 1RP..e, ! I ...._._^, • rr a Ran. — ; 1 • dam' • • 1 Ain . mama 13 6f8".10k Hydrl ...m gam.Rana. - 9 !i «:ea MW ant : 1 ii .11 ---• MI etx tau.I i w • • 1 • 11 1247'lOk/1001 _ .c-rQd'Rsns r :...._:.....,,H. . af4'Dp ram r — — *&' 13 5131"10 k"t 13411*SK alma.spew ,aFA's,x1: 23Q 'cmrtar Lcsk9owry Daiwa °�°"'� •41, I I 1 1 • 8 • • •Schwartz, Guy L (DOA) From: Stephen Ratcliff <sratcliff@glacieroil.com> Sent: Monday, October 24,2016 4:17 PM To: Schwartz, Guy L(DOA);Stephen Ratcliff Cc: Amanda Dial Subject: Re: RU 1A pre frac RWO(PTD 213-079) Guy, No issue with running the CBL to identify the TOC. We can also test the backside to confirm that we have no communication. We will hold pressre on the backside during the frac so I would want to test this anyways. We will also run an ESP assembly after the frac. Note that it is our plan to include a packer,vent valve,and SSSV in the ESP completion. RU-01A and RU-05B will both be the same. Regards, Stephen Ratcliff Senior Drilling&Completions Engineer/Superintendent Glacier Oil and Gas Corporation 601 W.5th Avenue,Suite 310 Anchorage,AK 99501 0-(907)433-3808 C-(907)433-9738 From:"Schwartz,Guy L(DOA)"<guy.schwartz@alaska.gov> Date: Monday,October 24,2016 at 4:10 PM To:Stephen Ratcliff<sratcliff@glacieroil.com> Subject: RU 1A pre frac RWO(PTD 213-079) Stephen, In this RWO to run tubing and cement I have a couple of questions. 1.What is the final completion strategy after the frac stimulation? 2.Since this will be essentially a cement packer completion you will need to pressure test the new IA(3 122"x casing) and run a CBL to verify the TOC. 3.Your procedure does not include circulating or Bull heading KWF before pulling the tubing hanger and unseating vent packer. The vent should be open as long as there is hydraulic pressure to system allowing circulation past it. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 1 CONFIDENTIALITYNOTICE:This e-mail messancluding 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 Mr 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). 2 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable b direct inspection of the file. - 07/ Well History File Identifier Organizing(done) ❑ Two-sided III IIIII II IIII II III ❑ Rescan Needed II 1111111ff 111111 RE AN DIGITAL DATA OVERSIZED (Scannable) C or Items: ❑ Diskettes, No. ❑ Maps: Greyscale Items: ❑ Other, No/Type: V Other Items Scannable by Lw µ02,o ^ _ - a Large Scanner -r LUNG ❑ Poor Quality Originals: Gras RA-no N2Sc ^ h1AY►�I L: OVERSIZED (N Scannable) vy ❑ Other: Lb G-S ❑ Logs of various kinds: NOTES: El Other:: , BY: Maria j Date: 3 ' ! /s/ Project Proofing I I II111IIIIII 11111 BY: ACM Date: 3 / j I Is! U • Scanning Preparation (P x 30 = :0 + D..s = TOTAL PAGES ca ds (Count does not include cover sheet) BY: Maria Date: 3 1 Is/ Production Scanning I 111111 IIII II III Stage 1 Page Count from Scanned File: qo Co (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: taii:P Date: 3/1 1 L{. /s/ Y I 1 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III 111111 IIIII 11 III ReScanned 11111111111111 IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked 1111111111111111111 12/22/2011 Well History File Cover Paqe.doc O M 9 a- -�- N'71 o a o; n ai a N O o C N .T o Z c a) a) a) M 0 '2 E rn E 0) E rn d Z a 0 0 N E N E N E p Q1 a) a w w E a) E a) E N N O O 0 CO cet L°t7 = o U o w w M 2 1- 2 I- N N� Cl) r r N N Ln Lf) W d' a .- N N LO to Z Z > > Q Q Q Q Q Q 01 p1 N QI Q Q Q Q Q Q Q a co c 0 0 0 0 0 0 1° L. o O o O O o 0 0 Q c D O> j D D 2 2 0 3 3 3 3 3 > j D O CL Ce CC CL X X d d _I CC CL Q' CL CL CC CC Et to w w w w w w 3 3 o w w w w w w w w -J C , 0 f0 U U U U U U > > 8 0 0 0 0 0 0 0 0 0 o 0 m W ai ai ai ai ai ai ai o ai o ai ai ai ai ai ai ai ai ai "O , 0 0 W W LE w it it W J W J LL fa W W W tL W it it w N o n. cC 0 0 L) L) 0 0 0 o 0 o c)x 0 c0 0 L) c0 o o 0 O O N E 'c W -c c c c c c c .c c - c m 'E c c c c c c c J ici O) O O m O O O O O O o = 2 7 O_ O O O O O O O O J co V U QI 0 0 0 0 0 0 0 .n o:a 0 0 0 0 0 0 0 0 N a) a) a) a) a) a) a) a� N Ca N N a) a) a) a) a) a) a) a) • aE EE W O W w w w w w w x W 2 W e W w w w w w w w O W -p co M M M M M M M co co M M M M M M M M C Z U O O 0 0 0 0 0 0 F. _ O 0 0 0 0 0 0 0 W ce .? CV N N N N N N N N N N N N N N N N N W I- LL @ V O O O O O O O O O O co O O co co co O O a3 a) Ce w 05 Z ii) O) O) 0) O O O O) O O O) O) O O O O) W 0 2 U 0 Q 0 0 Z o a "° Q o o y R N J Q O o w acl o ZI ` t N C N N N N O a a) N E E v:,U p 0 m w J C o < cc cd a. as a)v Q o � J2 CD G F- LLI N CV Z _ LA ii CO O Q J fn m a) W v+ 0 0 0 < w o g a 1 u)) Q C Z Qa• 0 rn U E _1 J co 0 t° U Z � g co m as co co co as co co co co m m co m m as m TB N N N a3 co co co co co a) co N co co co co co co co ca 0 E E ° 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N Z .O-. a3 CO Of a3 a3 N a3 a3 as m m m a3 m as a3 CO u) co _o) _o) _O _m O) O) O) 0) _m _m _m O _r) O) O) O) G 0 Z O .+ ` 0 0 0 0 0 0 0 0 0 0 00000000 O) '- o ` : y d to U) L() LI) U) to U) U) to U) � LO LO U) U) LI) 1!) O i— a) = V „SE M M M co M M M M co M M M M M M M M N 2 Z 0 w W O Z M co = M M M M M M M M co N N N N N M CL Q O H C A Q w 6. • o LL � V � E la .2 W 0 9 C 0 a) U w O CL Z rn 20 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 m H J 0 :° a o. d a) Cr 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O. 00 13 � 0I w w w w w w w w w w w w w w w w w w IZ O M 9 0 N N.cr) O W .N ,'�– ..- a N N Z OQ Q Q O) O' w O J O H V (%) U a a w v — W QI <I 0 -�I w < 0 r) V 0. V a -o a 2 (,) (,) H Z o = b > p 0d p d p O p j p j ° > > Ito $ 3 3 Z Z Z U v r" M I- 1- M I- M F M 1- M I- J W a a a a a O O 3 d O r r N N (f) N N In In Q a) a) 66 a)U) N a) m < Z F Z Q Q ¢ Q Q Q Q Q ¢ Q Q Q — E E E a E< E E N N a O m (a ma (a mo cam W I W I W I W 1 O O O O O n, c co C a) c O 0 -a > > > > > > > > O > D > v (I) a a co Ce a IY CL a CC CC CL CC H I I 0 0 0 0 W W W W W W w W W W W W m a) M N MJ J F- H F- F- J U U U U U U U U U U U U 0 W-N u) a co_ w_ (n -=i u) Q Q Q • ai ai ai ai ai ai ai ai ai ai ai ai 0 2 w N N W LL LL –LL a m m-, coo o o a I . I a) I a I `– it it it it it it it i it W it it w aC7 0 c 0O 0O) 0 e-1 0NI LL< LL< LL< w< U) v v c) c) v v c) v c) 0 W .0 Z .0 Z 2 NI .0 E_J NI .0(. 0(7 .0 u 1 .0 xk .9 J O O O O O O O O O O O O O' O' 2m 2m 2-1 2-1 2m O ED O a 2w I— J w g; 15 g UI ti a1 I l l l l a) a) a) a) a) a) a) a) a) a) a) a) r) a) I a) I a)< a)< a)a a)< awawawN w w w w w w w w w w W w w � W2 W w u..1,-.- iii,-- Ili,- wU wU wU wU CL OW O co co co () co co co () co co co M co M M co co C) M M co co CL Z w o 0 0 0 0 0 0 0 0 0 0 0 0 o ,-- 0 0 ,-- ,-- 0 0 0 N N N N N N N N N N N N N N N N N N N N N N W W 0 0 0 0 0 0 0 0 0 0 0 0 r- n r` N- � r` r- r- r- re J O O) O a) a) O Q) O O a) O) O) Q) al 63 al - O) O) - O) Z W o -J V o O Z o N- 0 QE V) O (00 (00 ((0 (00 V M O (O co ,- ,- .N-- CV ^^ Q. Om co) o c co r- n CC) M C r O O N .CV 4- n N 0 r. N C 0 .� co (0 0 CO CV E U a 0 o J r )N CO < CO I- r M Q O C F- C N v.4--- In ap ''�^ m a) V/ M O• 0 al Q w fr 0 r a) Q O a Z E N m 0 C m cnz OS CO CO CO CO CO CO Ca CO CO CO CO N CO CO (a CO CO (O CO co co ca a) N as co (a co co CO (a CO CO ca all (6 V CO CO co ca co CO as as (a ca CD 0 0 0 0 0 0 0 0 0 0 0 0 ai 0 0 0 0 0 0 0 0 0 0 N O) O) CO CO CO CO O) O) CO CO CO O) 2 CO O) () CO CO CO CO CO O) N A-- .� .Q) .m a .o o .a a a O) o) m Of a O) O) O) O) m C O 0 0 0 0 O in 0 0 0 0 0 O O O 0 0 0 0 b 0 0 0 O) (n (n u) CO u) to (n u) v) (n () (n u) a0 co co co co co co CO a) co M co co co M co co co co co 0 M M M M M co M M M M M M M M co co co co co co co co co co M M M M M M F) M cn M M M M M co co co co co co co co co e- . + N N N N N N N N N N N N N N N N N N N N .` 0 \ 2r O in 0 O U U U U U U U U U U U U U U U 0 0 0 0 0 0 0 0 0 4U' 0 `m• 0 O O 0 O O 0 0 0 0 0 0 0 p 0 0 O 0 0 0 0 0 0 O Q a 2w w w w w w w w w w w w J w w w w w w w w w w M O 9 P o r 47. .- a O E E h o) `,.' al . o z a E a (h1 a r�1 (I) a o .� o (V a V I V 0 J V 0 J co MI _MI v M U a W a .- a w D a w D g u) g ri C7 (� C� 0 w a $ g to a Z a m 0 Z °I I- Z °1 x.c re ai CC o. c D < < ; O Z Q p Fw- Z NI Z 0 - Z 0 N iu N d N N n °I °I °I F z 0 a •d) < C� J C� a D a D E 1 E I E I E° w w w a if, 1 a < D1 .5. 0 < 0 a D d a d y0 aa)0 aa)?0 N001 Q Q ¢ 0 Q M M M Q Z Q MI r)1 <I MI r)1 QI LL.Q W Q LL.Q li QHq QI < < D J DD OD DD D�1 3v) D-J D-1 D D� D-1 D (Do (Do 0o NW D D D Do O . 0) 2rn cc rn .. [YZ cc cc D, ce N cc cc 2, cc N (JI 1 al-i ) .1 N� cc ct cc 1YJI N a)N a)N N D y 0) a)O a)O a) a)O 0)O a) CO CO CO W (I) 0 a) a)m it. (Ni g LL.gl LL.g it ca,1 LL.N LL. u.�I LL.r-I u u NI u NI W 0 UI 0 UI 0 UI 0 0 LL.. it LL. LL.UI v) (?1— 0 1— 0 1— 0 1 .0 1 0 3 0 .0 U 0 0 .9 0 c) 0 1— 0 1— 0 1- 0 1 c) 0 1- O m cU) 'c U) 'c U) cJ cJ c cD cD c cD cD c cU) 'c U) 'c(/) 'EC c c c cU) J iis oQ 0< 2‹ 0m om o 0J 0J o 0J 0J o oQ oQ oQ 20 o 0 0 2‹ J U U 01 U U a d d d U U U I— U U) 1 1 ° 1 5 I 5 1 0 1 0 1 ° l 0 0 1 5 1 5 I 1 0 U 5 1 Ce 0 a) a)< a)< a)< m Q 0 Q a) a)Q a)Q a) a)Q a)< d 0< a)< a)Q 0)Q a) a) 0) a)Q C w.- w � w.- w.- w.- w w.- w.- w w.- w.- w w.- w.- w.- w,- w w w wN- U W 5 M_ _M M_ M M_ M_ _') _') M_ M M M M _") CO_ CO_ CO co M M_ CL W• U O O O O O O O O O O co O O O O O O O O O N N N N N N N N N N N N N N N N N N N N W W h h h h h h h h h h h h h h h h h h h h Ce Z W 0 U 0 o Z _ ! N ° N N Tr NY -4r co ■I a m 0. M O N ° M c M • r ° N ° O c. O Q1 a V N a-, 0 0 o . r, < a H a of GN V CO 7 O m 0 CO 7 O 0 ra Q 0 UJ CC c O r 0 Q C 0. z E C3 ID of rts z co co co a) m m CO 03 03 m CO a) CO CO CO CO 03 CO CO m • N CO 0) 00 CO CO CO W N CO co f0 co (0 co (a co 0) fC N N O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N a) 0) (6 (a co co co co CO CO CO (0 CO (5 N N (a CO (0 CO O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 01 O W 2 W aD 2 DO W W O W 2 O 2 W W cc:0 W W W O CO M CO M M M CO CO CO M M CO M M M M M M M M M M M M CO CO (h CO M M M M M M CO M M M M M e N N N N N N N N N N N N N N N N N N N N N F.` O p 'n Cj o O to .I U 0 0 0 0 U U 0 U U 0 U U 0 0 0 U U U U V E 0 m 0 a 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 a 2 w w w w w w w w w w w w w w w w w w w w Q w-- O N O p. 4. ■ C` ',�_ Oj a N O y y O Z w C N X • a N 6) 'O > N N N M 0 M MI ° X Z °) rn U m y rn c0 J a) Z ° wp w E E O d O p Q Q W p p m >p >p O p O W W a > a > • pj .c Lo p p U > a� I— ~ a� rn > > 1- f� N c c >- e- e- N N to W d e- N N to l{7 O Z I O ° O O Lc-.- C Q Q Q Q Q Q 01 I 3 QI Q1 Q Q Q Q Q Q F M 1 I m '� 'LI a) o o o a Z Z c y a p m o 0 0 0 0 0 `o `o j o O O o 0 0 0 0 Q j O O LL p p Q Q > j > j 0 0 0 > > > > > > > > Q fl a J fY CL CL CL fY LY CL Ce Do y y CO c W W W W W W 3 3 p W W W W W W W W O X JI W W m ii ii W fY 0 0 U U U U > > > U U U U 0 0 U U Ce aim ui fY a i m w i a i a i a w a a a o 0 ai 0 642 a w i a a u u u s-- EL)! Ed U 0 00 w W U W U Lt. LL W W W U J LE—1 lL N IL LL lL IL LL U W W c, U 1— U 1 .0 I U Q U U v v U U U U U U U p c o P I P P P P P P P P U w 'c V 'c fl c d ,c W c c c c c c c c c c c t c t c m c c c c c c c c 4,2 J O Q 00 O 0 0 2 0 0 0 0 0 0 0 0 0 0 0 O o O o o O O O O O O o I— _1 0 ~ ~ I U 6(" U I u 1 UI U Q N N N v U U u u u v u�6 N f u N U U U U U U U U N Q N Q N< N d 0 W e W e W e W o W W W W W W W W W W W m W m W E w w w w w w w w rt 0 Z U M M M_ _M M M M M M M M M M M M f _M M M M M M M M M Y.� W 0 O O O 0 0 0 0 O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N N N N N N N N N N N N N N N N N N N N N N N N N W W N. n r- r` N- N- N- r- N- r` N- N- N- N- N- N- r- N- N- N- N- N- N- N- N- Ce Z rn rn rn -em- rn co rn co rn rn rn co rn 0) 0) "c-o' CB CO 0) 0) 0) 0) O) O) 0) W o -J 0 coy o Z 145 0 J a _ i co O � ' CL el 5 � o 0 N N CV CV 0 ai E t„) N o O 0 G I < co a. I— E. O 21 N CO m O) m y CO M O co Q O CL c I- 6) Q O n z c 0 d 0 E m z as m m 0s m CO Of CO Of CO 6s CO m m 03 CO as 0s m as m 03 03 CO Of 3 N N CO CO CO Al CO f6 CO CO CO CO CO CO CO CO CO CO N CO CO CO CO CO CO CO lo N N co co co as N co (6 co co Of N as co co co co co co as co N N (O CO O o p p p p p p p p p p p p p O p p p 0 0 0 0 0 0 0 0 O) ao ao co co co co Co co co CO 0 CO Co Co Co CO CO 0 CO co ao CO CO Co Co n M co co co co co co co co co co co co co co co co M co co co M M M M O M M M M M M M M M M M M M Co M M co M M M M M M M M CO M M M M e l m e l m mi..) M M M e l m M M M M M M co M M M e- N N N N N CNN N N N N N N N N N N N N N N N N N N N •` O p i O cc, U « 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 U U U U U U g OQ d 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 0 O. W W w W w LU W W W W W W W W W W W W W W LU W W W W O M O O w Z Z N O) CI o Z ❑ } } } AO N y- 4- w.. W N 6 II- Da ❑ Q ❑ 0 ❑ Q ❑ Q ❑ Q ❑ 0 a (O 'O in 2 _ 2 2 2 1- 2 2 ° _ N N to to � ,— N N tf) IC) < to O Q Z Q Q Q Q Q Q Q Q Q Q Q Q ! L t ° (-�_fp 4. 0 0 0 0 0 0 0 0 0 0 0 0 0 ~ i 0 a m Q D D D 0 0 > 0 0 0 0 7 0 a Z d 2 2 CY CL CL IY CL W EC CC Lt et CL CC E F❑- 0 0 m W W W W W W W W W W W W 200 0 0 J J 0 0 0 0 U 0 U O 0 0 0 0 F- =O • N a) a) N N a) a) a) a) Cl.) al a) a) ❑ W W LL LL W lL U. W LL W LL LL LL W U () U v U U _U _U _U _U U U U d Z to 0 E O 7 'c 'c 'C 'C 'C 'C C C C C C C C rn w J � 0 0 0 0 0 0 0 0 0 0 0 0 0 � E (A��] 6 I_ J (I) U U U U U U U U U U U U U 0 ° N a) a) a) a) a) a) o a) a) a) a) a) a) M Li O N IX W W W W W W W W W W W W W N o w W O M M M M M M M M M M M M M C�,. 1 to O-1 Om w U io 0 0 0 0 0 0 0 0 0 0 0 0 E Y E iv 2 p N N N N N N N N N N N N N (p E 44 ❑ W W I� z (1 a) oc Z 0 0) 0) 0) 0) 0) 0) C3) CS) 0) 0 0) 0) a I M W E O p) t/7 N W °o J o O. V V O y _CO J E co Z 8 ' o • to a? (n CL Q 2 O O N to O J Q C O 0 J °' N O O N c U U/i co C d C r _O 0 N N 1 n I O/ % N p 1 « .c V p U a) w m o J } } 0 E v to Q O O ° 0. ,:r as U c E H a of R E MG z d N E W .r as H C t rn i m >' . 1 2 m a) N C to 0 Q W • . u u c a) Z E v o >. O £ 0 m 0 m O co 0 (C (a CO @ CO CO CO CO CO N CO CO CO N M M a) N N a) CO CO (a CO CO CO N CO CO CO CO •p I1 • 0 ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ N '' I Q N o Lr)0 N 0 CO CO CO CO (0 t 6 (a (a N (6 co co =O i+RI 0�` ``/ CO. (O ❑ 0 0 0 0 0 0 0 0 0 0 0 0 0 ) E 0) co Co ao CO CO U) 0 w o 0 0 o rb rb ,� W O } rs co M M M M M M M M M M M M M M C lJJ O. O ix O M M M M M M M M M M M M M N M M M M M M M M M M M M t j N m W '6 O I- N N N N N N N N N N N N N N N a ° o o N = ° a co o a l U E o p a) 0 0 c to o co Z Q o 4 o w P. tn y U U U U U U U 0 0 , o 2 < •� 0 J a) .2. U r 0 v E o 0 O o —O F CO d ° ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ rn it o a) ; o a) O. 2 w W w w w w w w w w w W w J g. c.) a 0 0 0 C e- N 9 T Is. N Ot O a a N Z O M U O Z 1 , F ci Q J_ r l U = iY -J ra R V j o IX >: a Q w CL w mow/ w I 1:t J Z w O J V 0 o 11 Z o Q y 7 J O. r0 1 aM 0 u c 20 ° 1 Oa a ' 1 � ✓ O CJ o r J as ak < I a I a M 5 o G N m Z co i ma) 0 a Q • C o a 1 ) Q a Z° o �1 0 E Ile z 3 0 H 1 N 1, 1 Cl El• In o E I I E, U I . STATE OF ALASKA AL, A OIL AND GAS CONSERVATION COh, _SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil El, Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20MC 25.105 20MC 25.110 Development 0 • Exploratory ❑ GINJ ❑ WNJ ❑ WAG❑ WDSPL ❑ No.of Completions: __ Service ❑ Stratigraphic Test ❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number: COOK INLET ENERGY,LLC Aband.: 8/14/2013 . 213-079 3.Address: 6.Date Spudded: 13.API Number. 601 W 5TH AVE SUITE 310,ANCHORAGE,ALASKA 99501 7/9/2013 • 50-733-20497-01-00 ' 4a. Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 1918'FSL 315;FEL,SEC 14 T7N R14W,SM 7/23/2013 REDOUBT UNIT#1A Top of Productive Horizon: 8.KB(ft above MSL): 90' , 15.Field/Pool(s): 235'FSL 1600'FWL Sec 18 T 7N R 13 W GL(ft above MSL): N/A REDOUBT SHOAL . Total Depth: 352'FSL 2139'FWL Sec 18 T 7 N R 13 W 9.Plug Back Depth(MD+TVD): 14,953'MD/12,426'TVD 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 200630.58 y- 2449941.2 Zone- 4. 15,050'MD/12,5027-VD ' ADL 381203,ADL 378114 • TPI: x- 207787.58 y- 2448075.2 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 208329.07 y- 2448186.84 Zone-4 320'MD/3209VD N/A 18. Directional Survey: Yes El No ❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) 45' (ft MSL) N/A 21. Logs Obtained(List all logs her and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: VCBL,CAST-M,CASE,ACE,GR, 12,246'MD/10,231'TVD • 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MQ SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM • HOLE SIZE CEMENTING RECORD PULLED 36" 150# A-36 0' 200' 0' 200' N/A .N/A 13 3/8" ' 68# L80 0' 1,831' 0' 1,803' 17 1/2" none 9 5/8" 47# L80 0 6,986' 0' 5,988' 12 1/4" none 7 5/8" 29.7 L80 6,702' L,.)2.,2-qt +a.3:9981 S'7G a 11,616' 8.5" 65 bbls.(315 sacks)Class G+0.2% ��5t CD32+0.6%R3+0.5%EC1+1% 5 1/2" 17 L80 6,509' J 12,493' 63/4" FL63 el 15Z ppg. Yield 1.16 cu 11/sks/Water 4.91 gps 7�� /0't Y? 24.Open to production or injection' YLs No ❑ i i,.,-.._: 25i TUBING RECORD If Yes,list each interval open(MD+TVD of Top and Bottom; �$�I!-1,11 „ SIZE DEPTH SET(MD) PACKER SET(MDIrVD) Perforation Size and Number): `2 7/8"L80 6.7# 12,425 2,023'MD/1,981'TVD Measure Depth: 14,110'-14,154'=48'; 14,171'-14,230'=59';'14261'•-' 14,303'=42';14,373'-14,570'=197'; 14,581-14,588'=7'; 14,610'- 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 14,721•=111'; 14,726'-14,746=20'; 14,758'-14,786=38; 14,812'- Was hydraulic fracturing used during completion? Yes ❑ No Ei 14,836•=24'; 14,852-14,8720' DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL TVD:11,753'-11,789': 11,803'-11,851': 11,876'-11,909': 11,964'-12,122': CEMENTING DETAILS I RECEIVE° 12,131'-12,137': 12,154'-12,243': 12,247'-12,263': 12,272'-12,294': 12,315'. 12,334': 12,346-12,362' 7 °_.. 1 EP l Liii,7 27. PRODUCTION TEST . O OCCC Date First Production: Method of Operation(Flowing,gas lift,etc.): 8/23/2013 FLOWING Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 8/23/2013 3/12/1900 Test Period +2253 BOPD 45 BWPD OPEN 205 cu ft/bbl Flow Tubing Casing Press: Calculated Oil-Bbl: / Gas-MCF: Water-Bbl: Oil Gravity-API(corr): 500 PSI 23 PSI 24-Hour Rate 774 BOPD v 15 BWPD 26.4 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 RBDMS SEP 3 0 2013 /4" Form 10-407 Revised 10/2012 CONTINUED ON REVERSE {0.2 V-1 S Submit original only ? 1°12-6113 G 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ; [Yes [1)a If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if needed, Permafrost-Top and submit detailed test information per 20 AAC 25.071. Permafrost-Base UPPER HEMLOCK 14,110' 11,753' MIDDLE HEMLOCK 14,373' 11,965' LOWER HEMLOCK 14,610' 12,154' WEST FORELAND 14,900' 12,398' OIL SHOWS(HEMLOCK) 14,110-14,872 11,753'-12,363' Interval perforations 14110-14154;14171-14230;14261-14303;14373- 14570;14581-14588; 14610-14721; 14726-14746; 14758-14796; 14812- 14836; 14852-14872 Well Completed on ESP Pump FARO:771 BO and 11 BW Formation at total depth: LOWER HEMLOCK 31. List of Attachments: Wellbore schematic,daily drilling summaries,logs,surveys,cutting sample data, 10-407 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: COURTNEY RUST 433-3809 Email: COURTNEY.RUST @COOKINLET.NET Printed Name: CON PE Y Title: DRILLING MANAGER Signature: % — �'�� Phone: 907-433-3816 Date: 9/5/2013 INSTRUCTIONS General: This form is designed for s 'milling 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 lb: Classification of Service wells: Gas Injection,Water Injection,Water-Altemating-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 ND 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 _ Cook Inlet Energy_ RECEIVED SEP 1 7 203 AOGCC September 16, 2013 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage,Alaska 99501 Re: Well Completion Report Cook Inlet Energy, LLC: Redoubt Unit#1A API 50-733-20497-01-00/ PTD 213-079 Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits the Well Completion Report and form 10-407 for the Redoubt Unit#1A well located on CIE lease#381203 off the Osprey Platform. Enclosed please find: 1. Well Completion report (AOGCC Form 10-407) with attachments 2. Summary of Daily Drilling Operations 3. List of Formations and other geologic markers encountered and depths 4. List of Depth and Formation names for oil and gas shows 5. Paper copy of Wellbore Directional Survey 6. Copies of final mudlog and report enclosed in report 2 CD. 7. Digital version of all logs run in LAS format and directional survey in ASCII format 8. Paper copies of all logs run and reproducible file in pdf and tiff format 9. Dry cuttings to AOGCC If you have any questions, please contact me at(907)-433-3816. Sincerely, °A-) Conrad Perry Drilling Manager Cook Inlet Energy, LLC Redoubt Uni.. ■ Completion Diagram Aug-13 7 Baker 2 7/8"SSSV @ 320'MD/320'TVD 36",150#,A-36,Welded Conductor @ 200'MD/200'TV Baker Hughes Twin Seal i @ 9 5/8"Packer @2,023'MD/1,981'TVD !N 13-3/8",68#,L-80,BTC @ 1,831'MD/1,803'TVD 2 7/8"XN Nipple 2122'MD/2,070'TVD P , 5 1/2"TOL @ 6,509'MD( "r1/1> :,..7 9 51B.sx 5 1/2"Liner Flange y 75/8"TOL @6,712'MD/5,702'TVD liE 9-5/8",47#,L-80,BTC @6,986'MD/5,988'TVD II Ili d7 5/8"Window @ 12,246'P/10,231'ND d I i Centrilift ESP Assembly Top of Discharge Head @13,469'Bottom @ 13,600'MD > 2 7/8"L80 6.7#EUE Tubing Perforations MD: Perforations ND:14,110'-14,154'=48' 11,753'-11,789':14,171'-14,230'=59' 11,803'-11,851': 14,261'-14,303'=42' 11,876'-11,909': 14,373'-14,570'=197' 11,964'-12,122': 14,581-14,588'=7' 12,131'-12,137': ra Q- 14,610'-14,721'=111' 12,154'-12,243': �i 14,726'-14,746'=20' 12,247'-12,263': 14,758'44,786'=38' 12,272'-12,294': 14,812'44,836'=24' 12,315'-12,334': e 7 15 1/2"17#L80 BTC-M @ 15,038'MD/12,493'TVD 6 3/4"Hole TD @ 15,050'MD/12,502'TVD RU-1A Daily Drilling Summary 6/20/13 Cleaned cellar,bled pressure down on RU 1 6/21/13 Prep production tree,bled pressure to"0". Well dead. Set Back pressure valve,nipple down production tree to RU BOPs. Pulled RU-1 production tree and set dart valve(Vetco). Start to NU BOPs. Set up riser,pulled beaver slide, stack the variable pipe rams,mud cross,blind rams,and moved hydril into place. Disassemble pump 2. Finished stacking BOP. 6/22/13 Continue rig up 6/23/13 Continue rip up,begin testing BOPs,retrieve dart valve. C/O bail and elevators. Rigged up Weatherford and set Mousehole. Made up landing joint and screwed into Hanger. Held PJSM. Pulled Hanger to floor(150K to unseat hanger). POH with 3 1/2" tubing,cleaning both tubing and EST cable. (+/-435 ft.)R/U to circulate well. Circulated tubing volume @ 1 1/2 bpm,Pump Pressure=3300 psi. R/U to circulate well. Circulated tubing volume @ 1 1/2 bpm,Pump Pressure=3300 psi. Continue to POH to Joint#380(+/-260'). 6/24/13 C/O Crew shift and continue to pull out of hole f/12,210'-t/9530'. Splice and c/o spools on the ESP. Continue to POH and lay down f/9530' -t/7585'. Continue to POH f/7,585' -t/7,084'. Checked for flow and monitor well.R/D circulating equipment. Continue to POH f/7,084'-t/ 5,806', cleaning cable at same time. 7/0 6/25/13 2.2/ Continue to pull out of hole f/5,806-t/5,190. POH F/5,190'T/4,845'. C/O Flat pack spool& undo splice, Test ESP cable(Test Good). POH F/4,845'T/862'. Load out boat W/3 1/2" tubing, cable spools &C/O flat pack spool,(2)ISO Tanks&(1)cuttings box. Clean rig floor. Continue to POH f/862'-t/98'. Cut ESP cable and reeled same onto spool. Took off remaining clamps&bands. Checked ESP and control lines. 6/26/13 Continue POH. R/D ESP equipment. Clean Rig floor. Strap&caliper milling tools,Bumper sub &Jars. RIH(SLM)to 6,811'DPM w/6-3/4"junk mill& 8-1/4" polishing mill tagged 7-5/8" TOL @ 6,707'DPM. (Note: saw 6-3/4"junk mill momentarily take 5K weight at 7-5/8" TOL, then fell through,worked mill through TOL 2X more w/o taking weight before cont. RIH to tag TOL w/polishing mill). Checked DP SO&PU weights, established circ. and began polishing 7- 5/8" TOL w/2K weight&40 RPM's. 6/27/13 Finished polishing 7-5/8" TOL w/up to 4K weight& 80 RPM's,circ. 2x BU--got some pieces of ESP cable Flat-pack debris back,built slug. Pull(2)stds T/6,631'(above 7-5/8" TOL)to slip &cut drill line. Hang off blocks&TD, Slip&Cut 110'drill line. Pump slug to POH W/Liner top polish mill. POH F/6,631'to BHA. Break down BHA#1 --polishing mill showed good 45° +/-angle wear on bottom of blades. M/U BHA#2 for wiper trip T/ 12,600'. RIH w/62 stands 4" DP from derrick to 5,901'. MU 9-5/8" casing scraper,boot basket&jars assembly in string. Cont. RIH w/4" DP from derrick(77 stands total)to 7,316'. Off-load 200 joints 4" 14#S-135 P-Tech 39 DP from workboat to pipe rack. Measure/rabbit w/2.3125" drift/PU/MU/RIH w/4" DP from pipe rack to 10,836'. 6/28/13 Cont. measure/rabbit w/2.3125" drift/PU/MU/RIH w/4" DP from pipe rack to 12,516'(9- 5/8" casing scraper @ 6,655')when started to take weight. Check pipe figures;PU=220K& SO = 170K w/o pumps(off);MU top drive&line up mud pumps. Estab. circ.and attempt to wash deeper w/ 10K WOB,but no success--have clean PU=205K& SO= 170K w/pumps (on). Circ. BU 2X at 375 GPM. Pump slug to POH w/9-5/8" casing scraper assembly and 6-3/4"junk mill--found mill damaged: 1 blade had horizontal crack& 1 blade had beveled edge wear. RU Halliburton Electric WL; hang sheaves in derrick,MU 7" CAST-M logging tool;calibrate tool @ 1470'; RIH to 6,685'. Log up at 14 fpm w/CAST-M tool from 6,685'to 5,850'. 6/29/13 Log up at 14 fpm w/7" CAST-M tool from 5,850'to surface. Cont. house keeping,rig audit, assist crane in loading out boat. L/D 7" CAST-M sonic logging tools,P/U 7-5/8" CBL tools, swap out tools,made it to 500'and tools quit working. Run in hole W/CBL t/ 12,600', found cmt stringers @ 6,900',good cmt @ 8,500'&@ 12,500'down,grease choke manifold, HCR valve, manual choke. &Kill valves, Clean BOP's&cellar while making logging run. Pulled wear bushing. MU/set test plug&4" test joint w/side entry sub,TIW type safety(floor)valve& Inside BOP(Gray)valve, fill BOP stack w/water. Test BOPE: test annular preventer on 4" pipe to 250 psi low&2,500 psi high; test upper&lower VBR pipe rams on 4" pipe, TIW type safety ("floor")&Inside BOP("Gray"/"dart")valves,choke manifold valves, standpipe(kill)valve, upper&lower kelly valves, inside(manual)choke line valve,HCR valve,inside&outside kill line valves to 250 psi low&5,000 psi high;pulled 4" test joint and tested blind rams to 250 psi low&5,000 psi high. Perform Koomey accumulator test. Pump water out of BOP stack. Pulled test plug from well head;reset 9" I.D. wear bushing in wellhead.MU 7-5/8" Halliburton EZSV cement retainer(6.12"running O.D.), setting tool&3-1/2" IF pin X 4" P-Tech 39 box X.O. and begin RIH. 6/30/13 RIH w/7-5/8" Halliburton EZ-SVB cement retainer on 4" DP,tag up @ 12,519'. Set EZ-SVB Cement retainer @ 12,505'. RU&test backside to 1,500 psi,bleed backside off to 1,000 psi and hold, attempt to inject into perfs,pressure up to 3,500 psi&could not pump into. RU&test backside to 1,500 psi,bleed backside off to 1,000 psi and hold,attempt to inject into perfs, pressure up to 3,500 psi&could not pump into. RU Baker pressure pumping services to set 200' - 9.14 bbls balanced cement plug on top of EZ-SVB cement retainer. BJ repaired leaking surge can valve and repacked mix water pump. Held pre job safety meeting. Test cement line. Mix 45 sks class "G" cement w/adds. @ 15.8 ppg/ 1.15 yield,pump&displace(spot)200'cement plug from 12,505'to 12,305'. RD cement line from side entry sub and break off top single DP,pull 6 stands DP(wet)up to 11,909'. Pump 10 bbls. mud down DP to clear Halliburton EZSV setting tool.RU and reverse circ. out 2X BU from 11,909' --saw no cement in returns.Begin POH. 7/1/13 Finish POH F 9,237'T/Surface W/EZ-SVB Running tool. L/D BHA. M/U BHA#3 (Mill assembly)P/U 4 3/4" DC's &4" HWDP. M/U BHA#3 (Mill assembly)P/U 4 3/4" DC's&4" HWDP. RIH w/6-3/4"junk&watermelon mills assembly on 4" DP to 5,380'. Installing Quadco "Wildcat" automatic driller components on drawworks. Cont.RIH to 11,880'. Break circ. @ 11,880'. Wash down to 12,068'. 7/2/13 Cont. wash down to 12,180'where started to take weight. Wash&ream down cement stringers 12,180' - 12,405'(started seeing firm cement @ 12,230'). Dress down T/ 12,405'. Circ btm's up @ 12,405'. R/U T test cmt plug&7 5/8" csg&9 5/8" csg. Test on chart @ 1,500 psi for 30 min( ? Good Test). Pump slug to POH. POH F/ 12,405'T/Surface--LD 6-3/4"junk&watermelon mills. RU HES WL. RIH w/7-5/8" (6.20" OD)EZSV CIBP,run tie-in correlation log and set top @ 12,383' --had partial set,Baker 20 setting tool did not shear release,worked WL,notified office of situation and pulled out of cable head clean w/3,200 lbs. tension; POH&RD HES WL equipment. Begin PU additional 4" DP from pipe rack&RIH. 7/3/13 Finish PU additional 4" DP from pipe rack(105 joints total)&RIH T/3,298' --have 2 single joints left on pipe rack. Inject fluid F/pits @ 22 stks min W/2,700 to 2,900 psi--injected 92 bbls. POH F/3,298'&rack 35 stands in derrick.R/U Halliburton E-Line unit hang sheaves and re-head E-line cable head;M/U CIBP&RIH, set EZSV CIBP(a 12,310'; POH&R/D E-Line equipment. Work on disassembling Wichita Break for repair; check cooling disks for water leaks --found 1 leak; clean disks. 7/4/13 Routine rig maintenance&house-keeping while WO parts for Wichita Brake. Clean water jacket plates&brake pads. Remove&clean main Wichita Brake bearing&water spear. 7/5/13 Routine rig maintenance&house-keeping while WO parts for Wichita Brake. Change dies in ST- 100 Iron Roughneck. Service equipment. Drain/pump out 13-5/8" BOP stack. Pull wear bushing from well head. MU&set test plug w/4" test joint in well head; fill stack&lines w/ water. Test PVT system audio&visual alarms on rig floor. Test BOPE: test annular preventer on 4" pipe to 250 psi low&2,500 psi high;test upper&lower VBR pipe rams on 4" pipe, TIW type safety("floor")&Inside BOP("Gray" /"dart")valves,choke manifold valves, standpipe(kill) p valve,upper&lower kelly valves,inside(manual)choke line valve,HCR valve,inside&outside l kill line valves to 250 psi low&5,000 psi high;pulled 4" test joint and tested blind rams to 250 psi low&5,000 psi high. Perform Koomey accumulator test. Pump water out of BOP stack. Pulled test plug from well head;reset 9" I.D.wear bushing in well head. Clean lower deck. Repair leak in steam piping. 7/6/13 Grease choke& standpipe manifold valves;paint valve handles on choke manifold. Cont. plumbing lines for heat exchanger for mud pump rod wash water sump. Grease Choke manifold Load Patterson water jackets on Pallet for shipment back to them. Modify Drillers roof(cut hole) for Auto Driller; Build covers for Koomey lines running into sub base; Clean parts for Wichita Brake reassembly. Clean pump room. Clean&prep. Wichita Brake parts for re-installation. Begin reassembly of Wichita Brake--install air boot,clutch assembly,&main bearing. 7/7/13 Cont. reassembly of Wichita Brake. Pick up Whipstock BHA; orient MWD. RIH to 11,750'at midnight--fill pipe every 3,000' 7/8/13 RIH to 12,175'DPM&establish circ. at 348 GPM/3,950 psi. RIH to 12,275'DPM&started taking up to 15K weight. (Note: CIBP set @ 12,310'Log depth). Attempt to work whipstock 56, assembly deeper w/up to 38K weight down,but have clean PU(no significant over pull) indicating whipstock anchor(6.38" OD)not setting--(whipstock anchor slips pinned to shear at 18k down, if properly set,then should have positive over pull)appears 6 3/4" starter mill may be taking weight. Rechecked tool face orientation= 14 degrees left. POH. BHA came out without whipstock. BHA lay down MWD. RIH w/6-3/4" starter mill&watermelon mill assembly to 12,176'at midnight--fill pipe every 3,000' 7/9/13 RIH to 12,208'DPM (PU single jt. 4" DP)&establish circ. at 356 GPM/3,350 psi. RIH to 12,208'DPM(PU single jt.4" DP)&establish circ. at 356 GPM/3,350 psi.RIH to tag top of f whipstock @ 12,261'DPM&establish PU, SO,Rotating&Torque parameters. Milling out 7- --(�, , ,/ 5/8" casing window from 12,261'to 12,262'DPM. Milling out 7-5/8" casing window from I Yom"_ 12,261'to 12,267'. Circ. Bottoms up,Lay down single;Pump Dry Job; POH. BHA Lay down Mill(1/4" out of gauge) ; Pick up new Mill. RIH to 1,650'. Slip&cut 120'drill line; service top drive, crown&blocks. Cont. RIH to 4,009'at midnight. 7/10/13 RIH to 12,209'DPM&establish circ. at 356 GPM/3,300 psi&establish off-bottom parameters for PU, SO, Rotating&Torque(set limit at 12,100 ft-lbs) . RIH to tag top of whipstock @ 12,261'DPM; begin milling out 7-5/8" casing window down to 12,263'. Mill f/ 12263 to 12290 (finish Window plus 20'of new hole). Work Mill through Window to clean up from 12261'to 12280'. Pull Mill Back into Casing and Circulate Bottoms up.Perform Integrity test Formation went to 2920psi(14.7 EMW)took 17.5 bbls to recovered 15bbls back to pits. Pump Dry Job and POH SLM on trip out--LD 4-3/4" DC's.Note: Found starter mill to be 13/16"under gauge& string("watermelon")mill 5/16" under gauge. 7/11/13 Changed out saver sub on top drive. Make up BHA#7. RIH to Window. Establish circ. and lowered drill string to bottom of window @ 12,271'&took 15K weight. Rotate/reamed through 7-5/8" window to TD @ 12,290'4X,then stopped rotation and washed through window to TD 2X smooth. POH--@ 4,380'at midnight. 7/12/13 Finish POH and LD 6-3/4" starter& string("watermelon")mills. PU/MU 6-3/4"PDC bit& directional drilling BHA,program MWD, conduct shallow test. RIH to 9,308' --fill DP every 3,000'. Finish RIH to top of 7-5/8" window. MU top drive&establish circ.,oriented bit to high side&lowered PDC bit through 7-5/8" window into open hole w/pumps off OK. W/bit in open hole,re-established circ.,but had trouble getting pulsar signal for orientation(possible internal rotor in a bind/jammed),pulled up inside 7-5/8" casing and got pulsar signals OK. Worked deeper back into open hole&got pulsar signals OK. Pull up inside 7-5/8" casing. Slide drill: 12,290'- 12,299'(9') --having trouble w/mud motor stalling out(pressure jumping up 400+psi) when barely touching bottom. Drill ahead(rotary mode): 12,999' - 12,309'(10'). 7/13/13 Drill ahead(rotate) 1'to 12,310',then(slide): 12,310'- 12,315'(5'/2.5 fph) --getting intermittent tool face readings. Drill ahead(rotate): 12,315'- 12,320'(5'/5 fph); do "hard restart" on MWD to try to get good pulsar signals --still intermittent.Make DP connection. Drill ahead(slide): 12,320' - 12,334'(14'/7 fph). Drlg ahead to 12,374'. Slide f/ 12,374'. Drill ahead(slide): 12,380' - 12,394'(14'/2.6 fph). Drill ahead(rotate): 12,394' - 12,397'(3'/6 fph). 7/14/13 Drill ahead(rotate): 12,397'- 12,415'(18'/4.5 fph). Make DP connection. Take slow pump rates. Take MWD survey. Drill ahead(rotate): 12,415'— 14,477'. 7/15/13 Take MWD survey. Pull 3 stands back through 7-5/8"window smooth. Slug DP, install wiper rubber& air slips&POH up to 11,381'. Cont. POH up to 7,139'. POH. Lay down BHA. Pick up new BHA. Program&test MWD. RIH w/HWDP. Service top drive&rig. RIH to 10,532' --fill DP every 3,000'. 7/16/13 Finish RIH to top of 7-5/8"window; establish circ.,orient bit to high side,turn off pump and go through window OK. Hrs. Take slow pump rates.Wash&ream down to TD;rotate drill to 12,484'to establish new bit pattern on bottom. Drill 12,484'— 13,022'. 7/17/13 Drill ahead(rotate): 13,022' - 13,075'(53'/53 fph). Make DP conn. and attempt to take MWD survey, cycle pump several times. Drill ahead(rotate): 13,075' - 13,098'(23'/30 fph)and take MWD survey OK. Drill ahead(rotate): 13,098' - 13,170'(72'/48 fph); make DP conn. Drill ahead(rotate): 13,170' - 13,194'(22'/44 fph); Drill ahead(rotate): 13,194' - 13,265'(71'@ 47.33 fph). POH 1 stand f/13265-t/13172'. Pumped survey RIH to 13,265'pumped another survey. Continued drilling. Drilled(rotated)f/ 13265' -t/ 13575' (310'@ 14.0 hrs=22.14 fph). Slide f/ 13575' -t/13585'(10'@ 1.0 hr= 10 fph). 7/18/13 Drilled f/13585' -t/13,950' 7/19/13 Slide f/13,950' -t/13,970' (20'@ 13.33 fph). Drilling(rotate)f/13,970-t/14,002'(32'@ 16 fph). Circulate hole clean prior to POH for new BHA.Filling trip tank,build slug @ 1 ppg over original mud wt.,and pull out of hole to csg window @ 12,260' (No problems pulled on elevators). Pump slug&check well for flow. POH F/ 12,260'T/BHA. Handle BHA. Down load MWD. Continue to handling BHA#9. Pull wear bushing, set test plug,R/U test equipment&Fill stack to test BOPE. Test BOPE, Tested Annular Low 250 psi for 5 mins./High 2500 psi for 5 mins. Tested Upper and Lower Pipe Rams,Choke Manifold Valves,Kill Line HCR,Blind Rams, Upper&Lower Kelly,Dart Valve,Floor Valve,Manual Choke. Low 250 psi for 5 mins. /High 5,000 psi for 5 mins. Performed Koomey Performance Test. Rigged down testing equipment. Sucked water from BOP stack. 7/20/13 Pulled test plug, set wear bushing and continued to suck water from BOP stack. P/U BHA#9 and lay down. P/U&M/U BHA#10,M/U MTR W/ 1.22 bend&offset of 357.11,M/U bit#3. Test and upload new MWD tool. Load sources into MWD&RIH T/ 1,020'. Slip&cut 110'drill line, R/S &C/O saver sub. RIH T/ 12,252', filled pipe every 3,000'and tested MWD. Kelly Up,filled drill pipe. Orient tool and slide through window with no problem. Encountered tight spot @ 12,266'. Worked area. Washed and reamed down from 12,532'to 12, 912'. Attempted to RIH without pumping. Encountered various tight spots. Hole attempted to packoff. Made decision to wash and ream to bottom. Continue to wash from 12,912'to 13,630'. Tight spot at 13,360' Worked drill pipe until tightspot cleaned up.NOTE: Took Survey @ 12,888', 13,458'and 13,453'. 7/21/13 Continue to wash and ream from 13,360 to bottom @ 14,002'. Drill(rotate)from 14,002' to14,062'(60'@ 40 fph). Slide from 14,062'to 14,090(38'@ 12.8 fph). Drill(rotate)from 14,090'to 14,100'(10'@ 10 fph). Drill(rotate)from 14,100'to 14,450'(350'@ 19.44 fph). Took M.A.D. of 20ft. from 14,351'to 14,331 to verify tool working. The Shadow resistivity fail but the Deep and Medium resistivity working. Held BOPE Drill @ 23;00 hrs. while drilling @ 14,432'. 7/22/13 Continue to drill(rotate)from14,450'to 14,575'(125 @ 20.83 fph). Drlg(rotate)F/ 14,575'T/ 14,849'(274'@ 15.22 fph) 7/23/13 Drilling from 14,849'to 14,869 (20'A 20 fph). Pulsar on the MWD tool plugged. Circulated and backreamed drill pipe. Pulsar unplugged, Drilled from 14,869'to 14,892'(23' @ 23.0 fph). Made connection,Top Drive started leaking oil,racked std back in derrick M/U to stand previous drill in order to circulate and move drill string. Drilled from 14,892'to 14,942'(50'@ 25 fph). Drilled from 14,942'to 15,050'(108'@ 14.40 fph) Note: Reached Total Depth of 15,050'@ 13:30 hrs. 07-23-2013. Circulated 3 BU to clean hole @71 strokes per minute. POH from 15,050'to 14,140'. Worked tight spot @ stand 144 (14,350'). Worked tight spot(high torque)until it cleaned up. Continue to POH conducting M.A.D. pass to 13,953'. Worked stand due to high torque. 7/24/13 POH for Wiper trip, conducting M.A.D. pass. Working tight spots (high torque)to 13,890'. Continue to make wiper trip conducting M.A.D.pass to12435'. POH T/csg window @ 12,261'. RIH F/ 12,261'to 13570'with rig elevators. Washing and Reaming thru coal seams. Encountered tight spot @ 13510',13520',13580',13628',13660', 13666', 13680',13854'and 13909'. Continued to RIH from 13909'to 15050'. Washed and reamed thru tight spots @ 14327'& 14423'. Circulating 2 bottom up prior to POH to surface. Circulating parameters RPM 50,GPM 260 @ 3000 psi. Dropped 2.64" O.D. in 4" drill pipe. Washed and reamed from 14,987'to 14800'. Attempted to POH on elevators but drag was too excessive. 7/25/13 Continue to POH washing and reaming from 14,800'to 13,210'. Started POH utilizing elevators @ 13,210'to inside 7 5/8" casing @ 12,146'. Filling trip tank and pumping slug of 1.0 ppg over original mud wt. of 9.4 ppg. POH F/ 12,146'T/6,700'. Circ btms up @ 6,700'to clean up 7 5/8" liner top,mix and pump dry job. POH F/6,700'T/755'. Work BHA,remove source&L/D directional tools. RIH with HWDP and laid down same. Pulled wear bushing and set test plug. CIO Upper Pipe Rams from 2 7/8" x 5" to 3 1/2" x 6". 7/26/13 Finished making up Upper Pipe Rams door, Charging Koomey unit, open Blind Rams, Filling BOP Stack,change out bails and elevators to rig bails&elevators,M/U 5 1/2" test jt. Testing Upper Pipe Rams, TIW Valve, Inside Grey, Low 250 psi for 5 mins and High 3,500 psi for 5 mins. Rigged down testing equipment and suck out BOP stack.Rigged down test joint and suck out water from BOP stack,pulled test plug set wear bushing. R/U Weatherford tongs. M/U Shoe track,RIH with same. And continued to RIH with 5 1/2" liner T/4,100'.RIH w ith a total of 207 joints of 5 1/2", 17#,L-80 liner to 8544'. 7/27/13 / Made up Halliburton VersaFlex 9 5/8" x 5 1/2" liner hanger. C/O bails and elevators to accommodate 4" drill pipe and laid down Weatherford Equipment. RIH with Liner Hanger& 5 1/2" liner on 4" drill pipe. Installed air slips,RIH @ 90 sec per std Max per Halliburton rep. Continue to RIH f/ 8,638' -t112,260'. R/U to circulate @window(12,260')&circ btms up @ 3bbl /min. RIH W/5 1/2" liner F/ 12,260'T/ 15,048'working thru tight spots @ 14,755'& 14,993'. R/U cement equipment and reverse out lines. Circ btms up. Held safety meeting with all ( J S personnel(Halliburton tool reps,Mud Eng.,Baker Hughes cementers,IDA,night Co. Rep). Test Lines low 500 psi,walked all lines for leaks, increased pressure to 7500 psi for 5 mins. ,bled off pressure. Worked on lines to cement unit. Pump Sealbond spacer @ 13.5 ppg. Mixed and Pump t(41- 65 bbls. (315sacksLClass G+0.2%CD32+0.6%R3 +0.5%EC1 + 1%FL63 @ 15.8 ppg. Yield 1.16 cu ft/sks / Water 4.91 gps. Dropped Top Plug. Displaced with 5 bbls of water and 262 bbls of OBM. Final Circulating Pressure 2,000 psi.bumped plug with 2408 psi. @ 00:30 hrs. Held pressure for 5 minuets,and released same with returns of 2 1/2 bbls. 100%circulation and reciprocation throughout cementing. Pump rate for displacing cement=3 bpm 7/28/13 Continue to cement. Top of cement= 11,993'. Drill pipe in tension @ 271,000#,dropped ball. Pressured up to 5120 psi to Rupture Disc and 4100 psi expanded casing pumping @ 1 bpm. Performed pull over test 235K up to 295k(60k up). Set 50 K down wt. indicator read 75K. Pulled cone through hanger,witness 80K over pull. Released. P/U 30'to reverse out. Closed bag and reversed out(Pumped 450 strokes). Rigged down all hard line,and cement head. POH Build slug &pump same to continue POH.to surface. POH W/liner running tool. Laid down running tool, performed rig service and general house keeping. Cleaned and prepared to P/U and RIH with 2 7/8", 6.5 #/ft, EUE, 8rd Tubing M/U BHA. Rabbit tubing prior to RIH with same to 3900'. 7/29/13 Continue to P/U&RIH with 2 7/8", 6.5 3/ft,EUE, 8rd Tubing to 8,700'. C/O elevators, install clamps on bails,to continue to RIH w/2 7/8" tbg on 4" drill pipe. C/O elevators from 2 7/8" to 4". Made up X-over to RIH with 4" drill pipe. Adjusted clamps on bails. CIO elevators,back to from 2 7/8". Laid down x-over. POH f/8952'to surface. Clean up rig floor and pulled wear bushing and set test plug to test 2 7/8 x 5" VBR's. CIO VBR in the Upper Rams from 3 1/2" x 6" to 2 7/8" x 5 ". R/U and tested Upper and Lower Pipe Rams on chart with 2 7/8 Tbg Low 250 psi for 5 mins./High 5000 psi for 5 mins. Tested with 4" Test Jt.Upper Pipe Rams,Low 250 psi/High 5000 psi. R/D Test Equipment. 7/30/13 Installed wear bushing. R/U Weatherford tongs. M/U Mill, 5 1/2" Casing Scrapper&Junk Basket. RIH 2 7/8" Tubing, install X-over to RIH with 4" Drill pipe T/ 14,836'tag up on cmt stringer.Wash F/ 14,836'T/ 14,860'. POH for 2 7/8" motor and mill. f/14,860'-t/10,700'. Continue to POH f/10,700' -t/7,500'. R/U filter unit to filter produced water in the Mud pit. (R/U @ 23:00 hrs.) 7/31/13 Continue to POH with 2 7/8"tubing to top of BHA. (Priming pump to filter water. Commenced filtering fluids in Pit#7& 8. Continue to POH and L/D BHA. M/U BHA,Mill,Motor&pump out sub. R/U on RU 5 and reverse circ produced water down pipe line @ 2.25 bbl/min,well is making oil,water&gas. (RIH W/clean out assembly). 8/1/13 Tagged bottom @ 14,846'. Attempting to circulate. Rotated drill pipe 2 revolutions on bottom with 2k,P/U and pressure up to 3000 psi. Attempted twice with no success. Racked back one stand of 4" drill pipe and R/U to reverse circulate. Attempted to reverse circulate,pressured up to 3000 psi,pressure bled down to 2650 psi. and well was circulating. Circulated down drill pipe. Shut down circulation and R/D equip ror reverse circulation. RIH to Bottom and start Milling operation with full circulation Milling from 14,846-to 14,917'. Circulated hole clean. Drop ball, opened circulating sub. Circulated. 8/2/13 Bled off pressure RU-1A. Reverse circulating RU-1A hole clean of interface; 100 bbls of interface. Rig Down Lines for injecting in to RU-5; Transfer clean OBM into Upright Tank; Clean Pits. Retrieving Wear bushing to hang off 4" drill pipe. Continue to retrieve wear bushing. Retrieved wear bushing on second try. Reversed test plug in order to hang off the 4" drill pipe. R/U test equipment and filled BOP's stack with water.Attempted to Test Hydrill. Bag leaking, Function tested Bag Approx. 6 times and checking for leaks in poor condition due to rain. Lowered koomey unit pressure from 1600 psi down to 750 psi. &attempting to test each time without success. Will C/O Bag once everything is tested. Testing BOP's. Tested Upper Pipe Rams,Dart Valve, 2" Kill Valve(Standpipe),CMV's 1-10-11-12,Floor Valve, outside Kill , Choke Manifold Valves 7,8,9. Low 250 psi for 5 mins and high 5000 psi for 5 mins. 8/3/13 Continue Testing BOP's. Tested inside Kill CMV's 2-4-6,HCR,Manual Choke,Lower Pipe Rams,Upper&Lower Kelly Low 250 psi for 5mins./High 5000 psi for 5 mins,Performed Koomey performance Test,r/u to choke manifold and test blind rams,cmv 3-5 low 250 high 5000 for 5 min/High. RID Equipment above Annular to change out Element in the Hydril Annular. Continued R/D Equipment above Annular to change out Element in the Hydril Annular. Removed Hydril Cap, Old Element and replaced with New&clean. Tested Annular on 4"with Low 250 psi for 5 mins / High 3500 psi for 5 mins. R/U to test 2 7/8" Tbg. Tested Annular with 2 7/8" Low 250 psi for 5 mins. / High 2500 psi for 5 mins. Test 2 7/8" Variables in Upper Pipe Rams Low 250 psi for 5 mins. / High 5000 psi for mins. R/D Testing Equipment. Retrieved Test Plug and set Wear bushing RIH to 14,909',M/U Top Drive to circulate filtered water. Circulate Well RU-1A until water in well that is being filtered reaches<30 NTU's as per program. Cleaning cellar and reinstalling Drip pans. At Bu's pumped interface to surface which consisted of 365 NTU's. shut down pump and dumped 200 bbls. of interface that was in the pits to build more volume. 8/4/13 Isolated pit#7& 8. Filled pit#8 with drill water and mixed KCL while cleaning pit#7.NTU's in pit#8 after mixing of KCL=37, Completion fluid wt.=8.6 ppg. Once pit#7 was clean, added drill water and KCL(NTUs=33 Completion fluid wt 8.6ppg;250 bbls drill water added to system. Circulating completion fluid @ rate of 5.5 bpm or 230 gpm with pressure of 1931 psi.NTU's= Out 190. 03:00 hrs.NTU's 73 out&280 in @ 04:00 hrs,NTUs 121 out&272 in 04:30hrs NTUs 100 out&384 in @05:00hrs;NTUs 80out&360 in @05:30hrs 06:00 NTUs 70 out&215 in. Mix dry Job and POH (Final on NTUs was 186 out 178 in). POH with 4" Drill pipe and 2 7/8" Tubing. 8/5/13 Continue to POH to top of BHA. Lay down BHA#12. R/U Halliburton wire line unit. RIH with CBL Cast-M, Stop above Liner top to get on depth. Liner Top show to be @ the depth of+/- 6517'. RIH @ 6725'@ 150 fph(05:00 hrs). Run CBL,Rig down Halliburton E-Line,Pre Job safety meeting on Picking up Guns and run In hole. Rig Up Weatherford Power tong to RIH with 2 7/8" Tubing and Assembly. Made Up Champ Packer and RIH with assembly on 2 7/8" Tubing. Continue to RIH with Assembly on 2 7/8" Tubing. Filling Tubing every 10 stds. 8/6/13 Continue to RIB with TPC Guns&Champ Pkr. on 2 7/8" Tubing&4" Drill pipe. Tag top of 7Th liner with Champ Packer(Gun depth 7454')Attempted to work through POH to Champ Packer. Inspect and Lay down packer for service(rubbers rolled over) ;pull up and inspect Firing head : Service rig. RIH with TCP Guns Assembly from 942' -to 6064. Rabbit Tubing every stand. Filling Pipe every 1000'. 8/7/13 Continue to RIH with Perforation Guns and Champ Packer Assembly and rabbitJTubing every stands. Champ Packer went in 5 1/2" liner @ 6509'.with no problems. RIH with Assembly on 2 7/8". Change out elevators and slips for 4" Drill pipe. R/D Weatherford Equipment. Filled Tubing completely. Continue to RIB with Assembly on 4" Drill pipe. Replace bolts in the top drive gooseneck clamp. Run the hole to 14917'. Rig up E Line and run in to correlate depth. POH with E-line rig down. Space out Pipe. RU E-line,RIH to correlate depth of 5-1/2" Champ packer and place TCP guns on depth;POH&RD Halliburton E-line. Set packer w/ 16K down. Close upper VBR's and test packer&annulus to 1,000 psi;bleed pressure down to 510 psi. RU TIW safety valve, side entry pump-in sub, lo-torq. valve&chicksan line from DP to rig's choke manifold& gas buster and test surface line to 2,000 psi w/drop bar loaded on top of closed TIW valve. Held PJSA safety meeting on perforating. Open TIW valve to drop bar--bar took 6:20 minutes fall to fire TCP guns,perforate interval 14,110' -'14,872'w/6 SPF at 60°phasing, observed SITP for 20 mins. w/no surf.press. increase,but casing increased to 570 psi. Opened well to flow through adjustable choke in manifold for 1 hr. 10 mins. --had no liquids to surface,casing pressure increased to 610 psi,then fell to 600 psi. 8/8/13 Bled casing pressure to "0"psi, opened VBR's,unseated champ packer,took 18 bbls.brine to fill backside,DP dead. Close upper VBR's,RU&reverse circ. out brine load and 72 bbls. crude oil &water followed by 70 bbls.more brine. Opened VBR's and checked for flow--well dead. RD chicksan line,lo-torq valve, side entry pump-in sub&TIW valve. MU top drive to DP. Circ. well ("the long way")BU--hole taking 12 BPH losses while pumping. Stop circ. and check well for static loss rate--hole taking 4.6 BPH. POH to 9864'. Cut and Slip Drlg line(cut 150'). rig up and inject Crude into Platform. POH to Guns. Finish POH--LD Halliburton Champ packer&TCP gun assembly. Clean rig floor. Tie up work boat to south side of platform. 8/9/13 Monitor well for fluid losses(2.5 BPH). Begin PU/MU Schlumberger 3.75" motor&4.00" ESP assembly. Monitor well while WO delivery of centralizer for bottom of motor&ESP assembly. S serviced top drive&draw works,pulled wear bushing from well head. MU 4.5" centralizer w/ anode&chemical injection line check valves to bottom of motor&ESP assembly. Splice MLE cable to motor--test conn. &cont. PU/MU Schlumberger ESP assembly(use banding to secure cable guards&CI lines to assembly). 8/10/13 Finish PU/MU Schlumberger ESP assembly(use banding to secure cable guards&CI lines to assembly). MU 1st stand 2-7/8" 6.50#L-80 EUE production tubing to top of ESP assembly;use banding to secure cable guards&CI lines on 1st joint to above cable splice. Attempt to Secure Cable&CIL with Cannon clamp over 2 7/8 Tubing clamp OD=4.75 (5.5 liner 17#ID=4.892 & drift=4.767 8/11/13 • Cont. RIH w/ESP assembly running 2-7/8 1t tubing stands out of derrick,applying Cannon clamps over couplings every 2nd jt. to secure cable&CIL. flat pack to pipe --testing power cable continuity every 1,000'; stop w/87 stds tbg in hole(8,598') --ran out of CIL flat pack on 1st spool. Transfer/re-spool CIL flatpack from large(2nd) spool to small(1st)spool (Have 5 stands 2-7/8" tubing remaining in derrick to run,then will begin to PU single joints from pipe rack). continue in the hole to 9966'. Splice Power Cable. WO additional CIL flatpack spool from OSK. Move Pollard slick-line unit from"center bay" inside platform to outside skid-beam deck for later use. 8/12/13 Pressure test spool of CIL to 4,000 psi. Spool off CIL from wooden spool to Baker backline tension"spooler" reel--measure 3,700'in length. Cont. RIH w/ESP assembly PU 2-7/8" tubing from pipe deck, applying Cannon clamps over couplings every 2nd jt. to secure cable&CIL. flat- pack to pipe--testing power cable every 1,000'; stop @11,483'w/350 jts of tbg. in the hole. Install "XN" 2.209" min.bore landing nipple. PU/RIH w/3 more joints 2-7/8"production tubing;PU/MU Baker Twin Seal Dual packer w/vent valve. Change to long bales to facilitate using safety valve while splicing ESP cable&CIL to Baker packer.Make ESP cable&CIL flatpack splices to bottom&top of Baker packer,connect 1/4" control line to vent valve on top of packer,test all connections.PU/RIH w/36 joints 2-7/8" production tubing above packer applying Cannon clamps over couplings every 2nd jt. to secure cable&CIL. Splicing flat ESP cable to round ESP cable. 8/13/13 Finish splicing flat ESP cable to round ESP cable. RIH w/ESP assembly PU 16 jts. 2-7/8" tubing from pipe deck, applying banding to secure cable&CIL flat-pack to pipe --testing power cable continuity every 1000'; stop w/405 joints tbg in hole @13,285'. Install 3-1/2" Baker"TE-5" SCSSV w/BX 2.812" profile(2.308" drift)and control line--test line to 4,500 psi and cycle SCSSV 3X. PU/RIH w/ 8 more joints 2-7/8"production tubing(grand total 413 jts. in hole); prep. to PU/MU Vetco-GE tubing hanger. MU Vetco-GE tubing hanger, install Schlumberger ESP cable penetrator. Make plug&connect ESP cable to penetrator,test ESP cable OK; connect CIL& 1/4" control line for SCSSV&packer vent valve;place 3,500 psi on 1/4" control line (holding SCSSV&vent valve open),close control line valve above tbg. &cut off excess control line above tbg. hanger. MU 3-1/2" EUE landing joints and land tbg. hanger in tbg.head;run in lock down pins and test to 5,000 psi. RD sheaves in derrick for ESP cable&CIL flat-pack. RU Pollard slick wire line. RIH#1 w/test tool to 2,145',but not able to set tool(not sheared),POH. RIH#2 w/same result,but lost all packing. RIH#3 w/braided line brush to 2,145' --work 10X to clean nipple,POH. RIH#4 w/test tool&set in XN nipple OK;pressured up on tbg. to 2,500 psi, then bled tbg. to 1,000 psi and pressured up casing annulus to 1,500 psi, increased tbg.press. to 3,500 psi to set packer(lost 225 psi in 7 mins.),bled off tbg.press; attempt to test packer by pumping down annulus,but would not pressure up --pumping down through open packer vent valve. POH w/test tool&redressed same (packing good). RIH#5 &set tool in XN nipple; pressured up on tbg. to 3,500 psi(lost 222 psi in 8 mins.)Observed vacuum on annulus. POH w/ test tool. Pumped 4.4 bbls.brine down casing annulus(200 psi)&got returns up tbg. RD Pollard wire line&stow equipment. LD 3-1/2" landing joint w/3.725" MCA pin end.Used dry rod to set 3" type "H" BPV in tbg. Hanger. Begin ND bell nipple&flow line. 8/14/13 Remove V-door("Beaver slide")&pollution pan. Begin ND 13-5/8" 10M BOP stack(remove VBR rams) --remove components(annular preventer&upper pipe rams)from cellar to pipe rack.ND BOP stack: remove blind rams,mud cross, lower pipe rams(remove VBR's)&XO spool; clean and prep. equipment going on the boat to town.Nipple up X-mas tree;pull BPV and set 2-way check; test bonnet&void to 5,000 psi; shell-test X-mas tree to 5,000 psi/hold 10 min. (Bled pressure off 1/4" control line to close SCSSV&packer vent valve). RU and pressure test Baker packer, 9-5/8" casing etc. 2,100 psi/30 mins. on MD-Totco chart. RD test equipment. Pull 2-way check valve from tbg. hanger. Begin prep. for rig move. Turn RU-1A well over to production. 9/13/2013 Redoubt Unit#1A, API#50-733-20497-01 Geologic Markers CONFIDENTIAL Name Measured Depth TVD Upper Hemlock 14,110' 11,753' Middle Hemlock 14,373' 11,965' Lower Hemlock 14,610' 12,154' West Foreland 14,900' 12,398' 9/13/2013 Redoubt Unit#1A, API#50-733-20497-01 Oil and Gas Shows CONFIDENTIAL Name Measured Depth TVD Hemlock 14,110'-14,872' 11,753'-12,363' Oil Shows Cook Inlet Energy COOK INLET BASIN REDOUBT SHOAL RU-1 A 50733204970100 Sperry Drilling Services Definitive Survey Report 17 September, 2013 HALLIBURTON Sperry Drilling Services Halliburton Company Definitive Survey Report Company: Cook Inlet Energy Local Co-ordinate Reference: Well Redoubt Unit#1 Project: COOK INLET BASIN TVD Reference: Redoubt Unit#1A(Rig 35)@ 89.10ft(89.1 KB+40' Site: REDOUBT SHOAL MD Reference: Redoubt Unit#1A(Rig 35)@ 89.10ft(89.1 KB+40' Well: Redoubt Unit#1 North Reference: Grid Wellbore: RU-1 A Survey Calculation Method: Minimum Curvature Design: RU-1 A Database: .16 prd Project COOK INLET BASIN 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 Well Redoubt Unit#1 Well Position +N/-S 0.00 ft Northing: 746,743.54 m Latitude: 60°41'43.743 N +E/-W 0.00 ft Easting: 61,151.10 m Longitude: 151°40'14.523 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Water Depth: 40.00 ft Wellbore RU-1 A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2013 6/28/2013 17.10 73.56 55,440 Design RU-1 A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 12,207.05 Vertical Section: Depth From(TVD) +N//-S +E/-W Direction (ft) ('-) (ft) (0) 129.10 0.00 0.00 95.00 Survey Program Date 9/17/2013 From To Survey (ft) (ft) Survey(Wellbore) Tool Name Description Start Date 163.86 1,829.10 RU#1 MWD#1 (RU#1) MWD Fixed:v2:standard declination 08/30/2012 1,830.10 6,985.10 RU#1 MWD#1 (RU#1) MWD Fixed:v2:standard declination 08/30/2012 6,985.10 12,207.05 RU#1 MWD#1 (RU#1) MWD Fixed:v2:standard declination 08/30/2012 12,263.00 12,566.01 MWD_Interp Azi+Sag(RU-1 A) MWD_Interp Azi+sag Fixed:v2:std dec with interpolated azimuth+sa 07/02/2013 12,660.34 15,011.23 MWD+SC+sag(RU-1 A) MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 07/19/2013 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (11001 (ft) Survey Tool Name 129.10 0.00 0.00 129.10 40.00 0.00 0.00 746,743.54 61,151.10 0.00 0.00 UNDEFINED 163.86 0.21 103.43 163.86 74.76 -0.01 0.06 746,743.54 61,151.12 0.60 0.06 MWD(1) 193.94 0.62 103.43 193.94 104.84 -0.07 0.27 746,743.52 61,151.18 1.36 0.28 MWD(1) 282.86 0.51 103.43 282.85 193.75 -0.27 1.13 746,743.46 61,151.44 0.12 1.15 MWD(1) 373.42 0.50 103.43 373.41 284.31 -0.45 1.90 746,743.41 61,151.68 0.01 1.94 MWD(1) 463.82 0.97 103.43 463.80 374.70 -0.72 3.03 746,743.32 61,152.02 0.52 3.08 MWD(1) 553.79 3.11 119.90 553.71 464.61 -2.12 5.89 746,742.90 61,152.89 2.44 6.05 MWD(1) 644.78 4.53 114.67 644.50 555.40 -4.85 11.29 746,742.07 61,154.54 1.61 11.67 MWD(1) 734.83 5.19 105.21 734.22 645.12 -7.40 18.46 746,741.29 61,156.72 1.15 19.03 MWD(1) 824.80 5.68 104.49 823.79 734.69 -9.58 26.69 746,740.62 61,159.23 0.55 27.43 MWD(1) 9/17/2013 11:18:45AM Page 2 COMPASS 2003.16 Build 73 Halliburton Company Definitive Survey Report Company: Cook Inlet Energy Local Co-ordinate Reference: Well Redoubt Unit#1 Project: COOK INLET BASIN TVD Reference: Redoubt Unit#1A(Rig 35)@ 89.10ft(89.1 KB+40' Site: REDOUBT SHOAL MD Reference: Redoubt Unit#1A(Rig 35)@ 89.10ft(89.1 KB+40' Well: Redoubt Unit#1 North Reference: Grid Wellbore: RU-1 A Survey Calculation Method: Minimum Curvature Design: RU-1 A Database: .16 prd Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (0/100') (ft) Survey Tool Name 914.73 5.73 104.98 913.27 824.17 -11.86 35.34 746,739.93 61,161.87 0.08 36.24 MWD(1) 1,004.70 6.86 107.75 1,002.70 913.60 -14.66 44.79 746,739.08 61,164.75 1.30 45.90 MWD(1) 1,092.50 9.28 107.48 1,089.63 1,000.53 -18.38 56.54 746,737.94 61,168.33 2.76 57.93 MWD(1) 1,190.25 10.36 105.68 1,185.94 1,096.84 -23.12 72.52 746,736.50 61,173.20 1.15 74.26 MWD(1) 1,284.97 11.92 106.57 1,278.87 1,189.77 -28.22 90.10 746,734.94 61,178.56 1.66 92.22 MWD(1) 1,381.39 12.17 105.61 1,373.17 1,284.07 -33.79 109.43 746,733.25 61,184.45 0.33 111.96 MWD(1) 1,476.21 13.48 104.74 1,465.62 1,376.52 -39.29 129.75 746,731.57 61,190.64 1.40 132.68 MWD(1) 1,570.15 16.38 106.09 1,556.38 1,467.28 -45.75 153.07 746,729.60 61,197.75 3.11 156.47 MWD(1) 1,665.48 19.17 107.35 1,647.15 1,558.05 -54.14 180.93 746,727.04 61,206.24 2.95 184.96 MWD(1) 1,761.84 19.78 106.80 1,738.00 1,648.90 -63.58 211.64 746,724.17 61,215.60 0.66 216.37 MWD(1) 1,857.49 20.04 107.87 1,827.93 1,738.83 -73.28 242.73 746,721.21 61,225.08 0.47 248.19 MWD(2) 1,955.04 22.47 108.85 1,918.84 1,829.74 -84.44 276.28 746,717.81 61,235.31 2.52 282.59 MWD(2) 2,049.80 25.44 109.68 2,005.43 1,916.33 -97.14 312.59 746,713.94 61,246.38 3.15 319.87 MWD(2) 2,144.63 28.51 110.36 2,089.93 2,000.83 -111.88 353.00 746,709.44 61,258.69 3.25 361.41 MWD(2) 2,240.36 31.55 110.92 2,172.80 2,083.70 -128.78 397.82 746,704.29 61,272.35 3.19 407.53 MWD(2) 2,336.00 33.62 108.58 2,253.39 2,164.29 -146.15 446.30 746,699.00 61,287.13 2.53 457.34 MWD(2) 2,430.49 35.40 104.52 2,331.26 2,242.16 -161.35 497.60 746,694.37 61,302.77 3.08 509.77 MWD(2) 2,523.21 36.01 103.58 2,406.55 2,317.45 -174.48 550.09 746,690.36 61,318.77 0.88 563.21 MWD(2) 2,616.67 36.06 102.00 2,482.13 2,393.03 -186.65 603.71 746,686.65 61,335.11 1.00 617.68 MWD(2) 2,712.20 36.25 100.52 2,559.26 2,470.16 -197.65 658.98 746,683.30 61,351.95 0.94 673.70 MWD(2) 2,808.39 36.43 100.09 2,636.74 2,547.64 -207.85 715.06 746,680.19 61,369.05 0.32 730.45 MWD(2) 2,906.52 36.56 99.85 2,715.63 2,626.53 -217.96 772.54 746,677.11 61,386.57 0.20 788.60 MWD(2) 3,000.39 36.54 101.38 2,791.04 2,701.94 -228.25 827.48 746,673.97 61,403.31 0.97 844.23 MWD(2) 3,099.56 36.71 101.42 2,870.63 2,781.53 -239.95 885.48 746,670.41 61,420.99 0.17 903.02 MWD(2) 3,192.23 36.84 100.50 2,944.86 2,855.76 -250.49 939.94 746,667.19 61,437.59 0.61 958.20 MWD(2) 3,288.27 36.49 102.59 3,021.90 2,932.80 -261.96 996.12 746,663.70 61,454.72 1.35 1,015.17 MWD(2) 3,385.17 36.41 103.18 3,099.85 3,010.75 -274.80 1,052.24 746,659.78 61,471.82 0.37 1,072.19 MWD(2) 3,478.26 36.45 103.61 3,174.74 3,085.64 -287.61 1,106.02 746,655.88 61,488.21 0.28 1,126.88 MWD(2) 3,573.68 36.49 102.97 3,251.48 3,162.38 -300.65 1,161.22 746,651.91 61,505.04 0.40 1,183.00 MWD(2) 3,670.04 36.58 102.94 3,328.90 3,239.80 -313.51 1,217.12 746,647.99 61,522.08 0.10 1,239.82 MWD(2) 3,766.23 36.50 103.24 3,406.19 3,317.09 -326.48 1,272.91 746,644.03 61,539.08 0.20 1,296.52 MWD(2) 3,861.96 36.29 102.42 3,483.24 3,394.14 -339.09 1,328.29 746,640.19 61,555.96 0.55 1,352.79 MWD(2) 3,957.44 36.19 102.10 3,560.25 3,471.15 -351.08 1,383.44 746,636.54 61,572.77 0.22 1,408.78 MWD(2) 4,051.33 36.63 101.31 3,635.82 3,546.72 -362.38 1,438.01 746,633.09 61,589.40 0.68 1,464.13 MWD(2) 4,147.70 36.43 103.19 3,713.26 3,624.16 -374.55 1,494.07 746,629.38 61,606.49 1.18 1,521.03 MWD(2) 4,243.71 36.82 104.39 3,790.31 3,701.21 -388.20 1,549.69 746,625.22 61,623.44 0.85 1,577.63 MWD(2) 4,339.42 37.05 104.94 3,866.81 3,777.71 -402.76 1,605.33 746,620.78 61,640.40 0.42 1,634.32 MWD(2) 4,433.24 36.66 105.63 3,941.88 3,852.78 -417.60 1,659.61 746,616.26 61,656.95 0.61 1,689.69 MWD(2) 4,531.31 36.87 110.77 4,020.47 3,931.37 -435.92 1,715.33 746,610.67 61,673.93 3.14 1,746.79 MWD(2) 4,627.70 36.69 111.03 4,097.67 4,008.57 -456.51 1,769.24 746,604.40 61,690.36 0.25 1,802.30 MWD(2) 9/17/2013 11:18:45AM Page 3 COMPASS 2003.16 Build 73 Halliburton Company Definitive Survey Report Company: Cook Inlet Energy Local Co-ordinate Reference: Well Redoubt Unit#1 Project: COOK INLET BASIN TVD Reference: Redoubt Unit#1A(Rig 35)@ 89.10ft(89.1 KB+40' Site: REDOUBT SHOAL MD Reference: Redoubt Unit#1A(Rig 35)@ 89.10ft(89.1 KB+40' Well: Redoubt Unit#1 North Reference: Grid Wellbore: RU-1 A Survey Calculation Method: Minimum Curvature Design: RU-1 A Database: .16 prd Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,723.74 36.46 109.83 4,174.80 4,085.70 -476.49 1,822.87 746,598.31 61,706.71 0.78 1,857.46 MWD(2) 4,820.36 36.39 110.12 4,252.54 4,163.44 -496.09 1,876.79 746,592.34 61,723.14 0.19 1,912.88 MWD(2) 4,916.42 36.21 108.84 4,329.96 4,240.86 -515.05 1,930.40 746,586.56 61,739.48 0.81 1,967.94 MWD(2) 5,011.27 36.09 110.44 4,406.55 4,317.45 -533.85 1,983.09 746,580.83 61,755.54 1.00 2,022.07 MWD(2) 5,107.38 35.90 110.02 4,484.31 4,395.21 -553.39 2,036.09 746,574.87 61,771.70 0.32 2,076.57 MWD(2) 5,202.09 36.87 109.03 4,560.56 4,471.46 -572.16 2,089.04 746,569.15 61,787.84 1.20 2,130.96 MWD(2) 5,298.66 37.27 107.95 4,637.61 4,548.51 -590.62 2,144.25 746,563.52 61,804.66 0.79 2,187.56 MWD(2) 5,394.68 37.49 107.82 4,713.91 4,624.81 -608.52 2,199.72 746,558.07 61,821.57 0.24 2,244.39 MWD(2) 5,488.57 37.50 107.86 4,788.40 4,699.30 -626.03 2,254.13 746,552.73 61,838.16 0.03 2,300.11 MWD(2) 5,583.79 37.36 108.04 4,864.02 4,774.92 -643.86 2,309.18 746,547.29 61,854.94 0.19 2,356.51 MWD(2) 5,682.44 37.12 107.39 4,942.55 4,853.45 -662.03 2,366.05 746,541.76 61,872.27 0.47 2,414.75 MWD(2) 5,778.34 36.70 107.60 5,019.23 4,930.13 -679.34 2,420.98 746,536.48 61,889.01 0.46 2,470.98 MWD(2) 5,873.09 36.50 107.47 5,095.30 5,006.20 -696.36 2,474.85 746,531.29 61,905.43 0.23 2,526.12 MWD(2) 5,969.88 36.75 106.88 5,172.98 5,083.88 -713.41 2,530.01 746,526.10 61,922.25 0.45 2,582.56 MWD(2) 6,065.16 36.63 106.88 5,249.38 5,160.28 -729.94 2,584.49 746,521.06 61,938.85 0.13 2,638.27 MWD(2) 6,163.48 36.68 105.62 5,328.26 5,239.16 -746.37 2,640.84 746,516.05 61,956.03 0.77 2,695.84 MWD(2) 6,258.55 36.72 105.77 5,404.49 5,315.39 -761.74 2,695.54 746,511.37 61,972.70 0.10 2,751.67 MWD(2) 6,353.25 36.64 105.58 5,480.43 5,391.33 -777.02 2,750.00 746,506.71 61,989.30 0.15 2,807.26 MWD(2) 6,448.92 36.81 105.86 5,557.11 5,468.01 -792.52 2,805.07 746,501.98 62,006.08 0.25 2,863.47 MWD(2) 6,543.97 36.74 106.20 5,633.25 5,544.15 -808.23 2,859.76 746,497.19 62,022.75 0.23 2,919.32 MWD(2) 6,637.59 36.73 106.63 5,708.28 5,619.18 -824.06 2,913.47 746,492.37 62,039.13 0.27 2,974.21 MWD(2) 6,739.10 36.60 106.75 5,789.70 5,700.60 -841.47 2,971.54 746,487.07 62,056.82 0.15 3,033.57 MWD(2) 6,834.80 36.32 106.11 5,866.67 5,777.57 -857.55 3,026.08 746,482.16 62,073.45 0.49 3,089.31 MWD(2) 6,928.01 36.35 106.31 5,941.76 5,852.66 -872.97 3,079.11 746,477.46 62,089.61 0.13 3,143.48 MWD(2) 7,030.44 36.62 105.78 6,024.11 5,935.01 -889.80 3,137.65 746,472.33 62,107.45 0.41 3,203.26 MWD(3) 7,126.14 36.84 106.28 6,100.81 6,011.71 -905.61 3,192.65 746,467.51 62,124.22 0.39 3,259.43 MWD(3) 7,221.78 36.40 107.29 6,177.58 6,088.48 -922.08 3,247.27 746,462.49 62,140.87 0.78 3,315.28 MWD(3) 7,317.93 36.39 106.36 6,254.97 6,165.87 -938.59 3,301.88 746,457.46 62,157.51 0.57 3,371.12 MWD(3) 7,413.61 36.15 106.69 6,332.11 6,243.01 -954.69 3,356.15 746,452.55 62,174.05 0.32 3,426.58 MWD(3) 7,510.13 35.97 107.15 6,410.14 6,321.04 -971.23 3,410.50 746,447.51 62,190.62 0.34 3,482.17 MWD(3) 7,604.70 35.77 107.22 6,486.77 6,397.67 -987.60 3,463.44 746,442.52 62,206.76 0.22 3,536.34 MWD(3) 7,699.73 35.62 107.03 6,563.95 6,474.85 -1,003.92 3,516.43 746,437.55 62,222.91 0.20 3,590.55 MWD(3) 7,795.74 35.35 107.63 6,642.13 6,553.03 -1,020.52 3,569.63 746,432.49 62,239.12 0.46 3,644.99 MWD(3) 7,892.37 35.20 106.51 6,721.02 6,631.92 -1,036.91 3,622.97 746,427.49 62,255.38 0.69 3,699.56 MWD(3) 7,988.10 34.62 107.14 6,799.52 6,710.42 -1,052.76 3,675.41 746,422.66 62,271.37 0.71 3,753.18 MWD(3) 8,017.77 34.60 106.80 6,823.94 6,734.84 -1,057.68 3,691.53 746,421.16 62,276.28 0.65 3,769.67 MWD(3) 8,113.81 34.67 107.20 6,902.96 6,813.86 -1,073.64 3,743.73 746,416.30 62,292.19 0.25 3,823.06 MWD(3) 8,209.91 34.94 107.32 6,981.87 6,892.77 -1,089.91 3,796.11 746,411.34 62,308.15 0.29 3,876.66 MWD(3) 8,302.05 34.65 107.64 7,057.53 6,968.43 -1,105.71 3,846.26 746,406.52 62,323.44 0.37 3,928.00 MWD(3) 8,398.43 36.43 106.56 7,135.96 7,046.86 -1,122.17 3,899.81 746,401.51 62,339.76 1.96 3,982.77 MWD(3) 9/17/2013 11:18:45AM Page 4 COMPASS 2003.16 Build 73 Halliburton Company Definitive Survey Report Company: Cook Inlet Energy Local Co-ordinate Reference: Well Redoubt Unit#1 Project: COOK INLET BASIN TVD Reference: Redoubt Unit#1A(Rig 35)@ 89.10ft(89.1 KB+40' Site: REDOUBT SHOAL MD Reference: Redoubt Unit#1A(Rig 35)@ 89.10ft(89.1 KB+40' Well: Redoubt Unit#1 North Reference: Grid Wellbore: RU-1 A Survey Calculation Method: Minimum Curvature Design: RU-1 A Database: .16 prd Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (1 (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,494.88 36.68 106.81 7,213.43 7,124.33 -1,138.66 3,954.84 746,396.48 62,356.53 0.30 4,039.03 MWD(3) 8,591.52 36.75 107.12 7,290.90 7,201.80 -1,155.52 4,010.10 746,391.34 62,373.38 0.20 4,095.55 MWD(3) 8,687.37 36.70 106.94 7,367.73 7,278.63 -1,172.31 4,064.90 746,386.23 62,390.08 0.12 4,151.60 MWD(3) 8,782.68 36.47 107.04 7,444.26 7,355.16 -1,188.90 4,119.23 746,381.17 62,406.64 0.25 4,207.17 MWD(3) 8,880.44 36.07 107.91 7,523.08 7,433.98 -1,206.27 4,174.39 746,375.87 62,423.45 0.67 4,263.64 MWD(3) 8,974.98 37.25 107.81 7,598.92 7,509.82 -1,223.58 4,228.12 746,370.60 62,439.83 1.25 4,318.67 MWD(3) 9,070.64 36.98 108.10 7,675.20 7,586.10 -1,241.37 4,283.03 746,365.17 62,456.57 0.34 4,374.92 MWD(3) 9,175.99 36.92 108.05 7,759.39 7,670.29 -1,261.02 4,343.23 746,359.18 62,474.92 0.06 4,436.61 MWD(3) 9,262.85 37.15 107.97 7,828.73 7,739.63 -1,277.20 4,392.98 746,354.25 62,490.08 0.27 4,487.58 MWD(3) 9,358.72 37.42 106.33 7,905.01 7,815.91 -1,294.32 4,448.47 746,349.04 62,506.99 1.07 4,544.35 MWD(3) 9,454.32 36.95 106.69 7,981.17 7,892.07 -1,310.74 4,503.87 746,344.03 62,523.88 0.54 4,600.97 MWD(3) 9,549.51 36.23 108.25 8,057.60 7,968.50 -1,327.76 4,557.99 746,338.84 62,540.38 1.24 4,656.37 MWD(3) 9,645.31 36.43 106.96 8,134.78 8,045.68 -1,344.93 4,612.09 746,333.61 62,556.86 0.82 4,711.75 MWD(3) 9,740.66 36.29 106.44 8,211.57 8,122.47 -1,361.17 4,666.23 746,328.66 62,573.37 0.36 4,767.11 MWD(3) 9,819.64 35.70 106.53 8,275.47 8,186.37 -1,374.34 4,710.74 746,324.64 62,586.93 0.75 4,812.60 MWD(3) 9,915.60 37.40 105.66 8,352.55 8,263.45 -1,390.18 4,765.65 746,319.82 62,603.67 1.85 4,868.67 MWD(3) 10,010.96 37.39 105.48 8,428.31 8,339.21 -1,405.72 4,821.43 746,315.08 62,620.67 0.12 4,925.60 MWD(3) 10,105.30 36.99 104.91 8,503.47 8,414.37 -1,420.67 4,876.46 746,310.52 62,637.45 0.56 4,981.73 MWD(3) 10,200.58 36.97 103.74 8,579.58 8,490.48 -1,434.85 4,931.99 746,306.20 62,654.37 0.74 5,038.28 MWD(3) 10,296.99 36.29 104.98 8,656.95 8,567.85 -1,449.11 4,987.72 746,301.85 62,671.36 1.04 5,095.04 MWD(3) 10,392.93 36.91 106.86 8,733.98 8,644.88 -1,464.80 5,042.72 746,297.07 62,688.12 1.34 5,151.20 MWD(3) 10,486.16 35.94 107.74 8,808.99 8,719.89 -1,481.26 5,095.57 746,292.06 62,704.23 1.18 5,205.28 MWD(3) 10,581.07 35.54 107.96 8,886.03 8,796.93 -1,498.25 5,148.34 746,286.88 62,720.31 0.44 5,259.33 MWD(3) 10,774.76 35.37 107.71 9,043.80 8,954.70 -1,532.67 5,255.29 746,276.39 62,752.91 0.12 5,368.87 MWD(3) 10,869.18 35.47 108.97 9,120.75 9,031.65 -1,549.88 5,307.23 746,271.14 62,768.74 0.78 5,422.12 MWD(3) 10,965.73 35.49 109.13 9,199.37 9,110.27 -1,568.17 5,360.20 746,265.56 62,784.89 0.10 5,476.48 MWD(3) 11,063.36 35.53 106.90 9,278.85 9,189.75 -1,585.71 5,414.12 746,260.22 62,801.32 1.33 5,531.72 MWD(3) 11,157.03 35.67 107.78 9,355.01 9,265.91 -1,601.96 5,466.17 746,255.27 62,817.19 0.57 5,584.99 MWD(3) 11,252.47 36.00 108.49 9,432.38 9,343.28 -1,619.35 5,519.27 746,249.96 62,833.37 0.56 5,639.40 MWD(3) 11,348.10 37.10 105.27 9,509.21 9,420.11 -1,635.87 5,573.75 746,244.93 62,849.98 2.31 5,695.12 MWD(3) 11,443.78 36.93 106.08 9,585.61 9,496.51 -1,651.43 5,629.21 746,240.19 62,866.88 0.54 5,751.72 MWD(3) 11,536.97 37.34 105.86 9,659.90 9,570.80 -1,666.91 5,683.30 746,235.47 62,883.37 0.46 5,806.95 MWD(3) 11,633.70 37.06 105.99 9,736.95 9,647.85 -1,682.95 5,739.54 746,230.58 62,900.51 0.30 5,864.38 MWD(3) 11,728.96 35.89 106.03 9,813.55 9,724.45 -1,698.57 5,793.97 746,225.82 62,917.10 1.23 5,919.96 MWD(3) 11,825.13 35.51 103.91 9,891.65 9,802.55 -1,713.07 5,848.18 746,221.40 62,933.62 1.35 5,975.23 MWD(3) 11,921.90 35.95 104.36 9,970.21 9,881.11 -1,726.87 5,902.98 746,217.19 62,950.33 0.53 6,031.02 MWD(3) 12,017.91 35.30 105.91 10,048.25 9,959.15 -1,741.46 5,956.96 746,212.75 62,966.78 1.16 6,086.07 MWD(3) 12,113.68 34.74 103.84 10,126.68 10,037.58 -1,755.58 6,010.07 746,208.44 62,982.97 1.37 6,140.20 MWD(3) 12,207.05 36.46 102.24 10,202.60 10,113.50 -1,767.82 6,063.01 746,204.71 62,999.11 2.09 6,194.02 MWD(3) 12,263.00 37.10 103.10 10,247.41 10,158.31 -1,775.17 6,095.70 746,202.47 63,009.07 1.47 6,227.22 MWD_Interp Azi+sag(4) 9/17/2013 11:18:45AM Page 5 COMPASS 2003.16 Build 73 • Halliburton Company Definitive Survey Report Company: Cook Inlet Energy Local Co-ordinate Reference: Well Redoubt Unit#1 Project: COOK INLET BASIN TVD Reference: Redoubt Unit#1A(Rig 35)@ 89.10ft(89.1 KB+40' Site: REDOUBT SHOAL MD Reference: Redoubt Unit#1A(Rig 35)@ 89.10ft(89.1 KB+40' Well: Redoubt Unit#1 North Reference: Grid Wellbore: RU-1 A Survey Calculation Method: Minimum Curvature Design: RU-1 A Database: .16 prd Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (1 (1 (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 12,330.35 37.42 101.33 10,301.02 10,211.92 -1,783.80 6,135.55 746,199.84 63,021.21 1.66 6,267.67 MWD_Interp Azi+sag(4) 12,377.28 37.31 100.10 10,338.32 10,249.22 -1,789.09 6,163.53 746,198.23 63,029.74 1.61 6,296.01 MWD_Interp Azi+sag(4) 12,435.11 36.72 98.59 10,384.50 10,295.40 -1,794.75 6,197.88 746,196.50 63,040.21 1.87 6,330.72 MWD_Interp Azi+sag(4) 12,473.34 36.46 97.58 10,415.19 10,326.09 -1,797.96 6,220.44 746,195.53 63,047.09 1.72 6,353.47 MWD_Interp Azi+sag(4) 12,566.01 37.32 95.16 10,489.31 10,400.21 -1,804.11 6,275.72 746,193.65 63,063.94 1.82 6,409.07 MWD_Interp Azi+sag(4) 12,660.34 38.50 94.55 10,563.74 10,474.64 -1,809.02 6,333.47 746,192.16 63,081.54 1.31 6,467.03 MWD+SC+sag(5) 12,754.77 40.28 94.28 10,636.71 10,547.61 -1,813.63 6,393.21 746,190.75 63,099.75 1.89 6,526.95 MWD+SC+sag(5) 12,851.49 39.39 94.32 10,710.98 10,621.88 -1,818.27 6,454.99 746,189.33 63,118.58 0.92 6,588.90 MWD+SC+sag(5) 12,945.91 36.74 95.68 10,785.31 10,696.21 -1,823.32 6,512.98 746,187.79 63,136.26 2.94 6,647.11 MWD+SC+sag(5) 13,040.26 34.55 95.34 10,861.98 10,772.88 -1,828.61 6,567.71 746,186.18 63,152.94 2.33 6,702.09 MWD+SC+sag(5) 13,131.75 34.94 95.60 10,937.16 10,848.06 -1,833.58 6,619.61 746,184.67 63,168.76 0.46 6,754.23 MWD+SC+sag(5) 13,226.97 35.39 95.10 11,015.00 10,925.90 -1,838.69 6,674.21 746,183.11 63,185.40 0.56 6,809.07 MWD+SC+sag(5) 13,322.52 34.04 93.60 11,093.54 11,004.44 -1,842.83 6,728.46 746,181.85 63,201.94 1.67 6,863.47 MWD+SC+sag(5) 13,416.95 34.10 92.19 11,171.77 11,082.67 -1,845.50 6,781.29 746,181.03 63,218.04 0.84 6,916.33 MWD+SC+sag(5) 13,510.51 34.20 91.53 11,249.19 11,160.09 -1,847.20 6,833.79 746,180.52 63,234.04 0.41 6,968.78 MWD+SC+sag(5) 13,605.11 33.82 91.53 11,327.61 11,238.51 -1,848.62 6,886.68 746,180.08 63,250.16 0.40 7,021.59 MWD+SC+sag(5) 13,699.07 32.29 92.17 11,406.36 11,317.26 -1,850.27 6,937.90 746,179.58 63,265.77 1.67 7,072.76 MWD+SC+sag(5) 13,793.55 31.23 92.44 11,486.69 11,397.59 -1,852.26 6,987.59 746,178.97 63,280.92 1.13 7,122.44 MWD+SC+sag(5) 13,888.61 31.73 92.74 11,567.76 11,478.66 -1,854.51 7,037.18 746,178.29 63,296.03 0.55 7,172.03 MWD+SC+sag(5) 13,963.01 32.69 96.58 11,630.72 11,541.62 -1,857.75 7,076.69 746,177.30 63,308.07 3.04 7,211.67 MWD+SC+sag(5) 14,003.90 32.71 95.37 11,665.13 11,576.03 -1,860.05 7,098.66 746,176.60 63,314.77 1.60 7,233.76 MWD+SC+sag(5) 14,102.01 34.54 96.69 11,746.82 11,657.72 -1,865.77 7,152.68 746,174.86 63,331.24 2.01 7,288.07 MWD+SC+sag(5) 14,195.18 36.30 95.71 11,822.74 11,733.64 -1,871.59 7,206.36 746,173.08 63,347.60 1.98 7,342.05 MWD+SC+sag(5) 14,287.74 37.05 93.58 11,896.98 11,807.88 -1,876.06 7,261.45 746,171.72 63,364.39 1.60 7,397.33 MWD+SC+sag(5) 14,382.05 37.38 91.24 11,972.09 11,882.99 -1,878.45 7,318.43 746,170.99 63,381.76 1.54 7,454.30 MWD+SC+sag(5) 14,474.00 36.83 86.75 12,045.44 11,956.34 -1,877.49 7,373.86 746,171.28 63,398.65 3.01 7,509.44 MWD+SC+sag(5) 14,572.25 37.17 78.35 12,123.96 12,034.86 -1,869.82 7,432.37 746,173.62 63,416.49 5.15 7,567.05 MWD+SC+sag(5) 14,665.24 36.54 72.79 12,198.38 12,109.28 -1,855.96 7,486.34 746,177.85 63,432.94 3.65 7,619.61 MWD+SC+sag(5) 14,759.72 38.07 68.43 12,273.54 12,184.44 -1,836.92 7,540.31 746,183.65 63,449.39 3.23 7,671.72 MWD+SC+sag(5) 14,855.16 37.86 64.27 12,348.80 12,259.70 -1,813.38 7,594.07 746,190.82 63,465.77 2.69 7,723.22 MWD+SC+sag(5) 14,949.59 37.88 60.19 12,423.36 12,334.26 -1,786.39 7,645.33 746,199.05 63,481.40 2.65 7,771.94 MWD+SC+sag(5) 15,011.23 38.31 58.37 12,471.87 12,382.77 -1,766.96 7,678.02 746,204.97 63,491.36 1.95 7,802.81 MWD+SC+sag(5) 15,050.00 38.31 58.37 12,502.29 12,413.19 -1,754.36 7,698.49 746,208.82 63,497.60 0.00 7,822.09 PROJECTED to TD 9/17/2013 11:18:45AM Page 6 COMPASS 2003.16 Build 73 Cook Inlet Energy, RECEIVED COO gyp LLC qr.p 172013 601 W. 5th Avenue, Suite 310 Anchorage, Alaska 99501 ,Qr'IC'r' Phone: (907) 334-6745 Fax: (907) 334-6735 e;t�o,oG3D . �{— 7 4 MKBENDER 2� v ( J DATA TRANSMITTAL Date: September 17, 2013 To: Howard Okland From: Barbara Kruk AOGCC Cook Inlet Energy, LLC 333 W. 7th Ave, Suite 100 601 W. 5th Avenue, Suite 310 Anchorage, AK 99501 Anchorage, AK 99501 Phone: (907) 279-1433 Phone: (907)433 - 3802 FAX: (907) 334 -6735 TRANSMITTAL DESCRIPTION Well Data for Redoubt Unit#1A, API#50-733-20497-01 In accordance with Alaska Regulations 20 AAC25.537(b),we request that confidentiality be extended to all of the following information. Item No. Qty Description 1 1 Well Completion report(AOGCC form 10-407), with attachments. 2 1 Copy of daily drilling reports or a summary report of daily drilling. (11 pages) 3 1 List of formations and other geologic markers encountered, and their depths MD and TVD 4 1 List of depth and formation name for oil and gas shows 5 1 Paper copy of directional survey (6 pages) 6 1 Paper copy of final mudlog and report enclosed in report 1 CD (257MB; 54 files) 1 File Listing for 1 CD enclosed in Canrig Well Report(3 pages) 7 1 Digital version of well logs in LAS format and digital version of directional surveys in ascii. 8 - Paper copy of all Logs run (14 paper copies) - No sepia provided pdf&tiff format files on CD Bottom Log Top Log Log Date Run# Interval Interval Description 8.1 1 08/05/13 1 14,810' 6,500' RU-1A Cast-M, CBL-M(Field Print) 8.2 1 08/05/13 1 14,923' 6,063' RU-1A ACE Depth Corrected 8.3 1 08/07/13 1 14,021' 13,640' RU-1A GR-CCL TCP Correlation Log 8.4 1 07/02/13 1 12,450' 12,075' RU-1A Bridge Plug Setting Record 8.5 1 07/02/13 1 12,326' 12,149' RU-1A Bridge Plug Setting Record 8.6 1 06/29/13 1 12,670' 6,765 RU-1A Cement Bond Log 8.7 1 06/29/13 1 6,680' 70' RU-1A CAST-M 8.8 1 06/29/13 1 6,680' 25' RU-1A CAST-M, Casing Inspection 8.9 1 7/2-7/23/13 8,9,10 15,050' 12,290' RU-1A Triple Combo Log 1"-MD 8.10 1 7/2-7/23/13 8,9,10 15,050' 12,290' RU-1A Triple Combo Log 2"-MD Transmittals CIE AOGCC.xlsx/AOGCC 9 17 13 RU1A Cook Inlet Energy, LLC 601 W. 5th Avenue, Suite 310 Anchorage, Alaska 99501 Phone: (907) 334-6745 Fax: (907) 334-6735 DATA TRANSMITTAL Date: September 17, 2013 Bottom Log Top Log Log Date Run# Interval Interval Description 8.11 1 7/2-7/23/13 8,9,10 15,050' 12,290' RU-1A Triple Combo Log 5"-MD 8.12 1 7/2-7/23/13 8,9,10 15,050' 12,290' RU-1A Triple Combo Log 1"-ND 8.13 1 7/2-7/23/13 8,9,10 15,050' 12,290' RU-1A Triple Combo Log 2"-ND 8.14 1 7/2-7/23/13 8,9,10 15,050' 12,290' RU-1A Triple Combo Log 5"-ND 9 Dry Cuttings 1 Box 1 of 3- Dry Cuttings samples depth 12,290' - 13,770' @ 30' 1 Box 2 of 3 - Dry Cuttings samples depth 13,770' - 14,160' @ 30'; 14,170- 14,540 @ 10' 1 Box 3 of 3 - Dry Cuttings samples depth 14,540' - 15,040' @ 10' 10 1 CD - For Items 7 &8.9-8.14 (Directional &Triple Combo Log data) (59.1 MB, 37 files) 1 Printout for Above Listed CD-(2 pages); Format: LAS,ASCII, PDF,TIFF, CGM, EMF 1 CD - For Items 8.1 -8.3 (Logs) (529MB; 11 files) Format: DLIS, LAS, PDF, TIFF 1 Printout for Above Listed CD-(1 -page) 1 CD- For Items 8.4-8.8 (Logs) (417MB; 22 files) Format: DLIS, LAS, PDF, TIFF 1 Printout for Above Listed CD-(1 page) Please sign below to acknowledge receipt. Received By: /7 /_ Date: 9 ` t I 1l Returned to Cook Inlet Energy, LLC Date Accepted By: Transmittals CIE AOGCC.xlsx/AOGCC 9 17 13 RU1A RECEIVED SEP 10 2013 AOGCC DATA LOGGED WELL LOG TRANSMITTAL •qi lra2013 ` q .M K BENDER / To: State of Alaska September 3, 20133`� Alaska Oil and Gas Conservation Commission Attn.: Makana Bender 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501-3539 RE: LWD Formation Evaluation Logs: RU-01A AK-MW-0900489677 RU-01A 50-733-20497-01-00 1", 2",&5" MD Triple Combo Logs: 1 Color Log each scale p g g 1", 2",&5"TVD Triple Combo Logs: 1 Color Log each scale Digital Log Images, LAS Data, & LIS Data w/verification file 1 CD ROM PLEASE ACKNOWLEDGE RECEIPT BY RETURNING A SIGNED AND DATED COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Buster Bryant/Ben Schulze 6900 Arctic Blvd. Anchorage,Alaska 99518 Office: 907-273-3539/907-273-3536 Fax: 907-273-3535 Buster.BryantPhalliburton.com Benjamin.Schulze(ahalliburton.com Date: 16 H Signed: Schwartz, Guy L (DOA) From: Courtney Rust <courtney.rust @cookinlet.net> Sent: Thursday,July 25, 2013 10:12 AM To: Schwartz, Guy L(DOA) Cc: Regg,James B(DOA) Subject: RU1A 213-079 RU1A Daily Summaries PTD: 213-079 7/19/2013 Slide f/13,950' -t/13,970' (20' @ 13.33 fph) Drilling(rotate)f/13,970-t/14,002' (32' @ 16 fph) Circulate hole clean prior to POOH for new BHA. Filling trip tank, build slug @ 1 ppg over original mud wt., and pull out of hole to csg window @ 12,260' ( No problems pulled on elevators ). Pump slug&check well for flow. POOH F/ 12,260'T/ BHA. Handle BHA Down load MWD Continue to handling BHA#9. Pull wear bushing, set test plug, R/U test equipment& Fill stack to test BOPE. Test BOPE,Tested Annular Low 250 psi for 5 mins. / High 2500 psi for 5 mins. Tested Upper and Lower Pipe Rams, Choke Manifold Valves, Kill Line HCR, Blind Rams, Upper& Lower Kelly, Dart Valve, Floor Valve, Manual Choke. Low 250 psi for 5 mins./ High 5,000 psi for 5 mins. Performed Koomey Performance Test. Rigged down testing equipment. Sucked water fron BOP stack. 7/20/2013 Pulled test plug, set wearbushing and continued to suck water from BOP stack. Injecting while P/U BHA#9 and L/D same from derrick. P/U & M/U BHA#10, M/U MTR W/ 1.22 bend &offset of 357.11, M/U bit#3. Test and upload new MWD tool. Load sources into MWD &TIH T/ 1,020'. Slip &cut 110' drill line, R/S &C/O saver sub. TIH T/ 12,252',filled pipe every 3,000' and tested MWD. Kelly Up, filled drillpipe. Orient tool and slide through window with no problem. Encounted tight spot @ 12,266'. Worked area. 1 Washed and reamed down from 12,532'to 12, 912'. Attempted to TIH witnout pumping. Encounted various tight spots. Hole attempted to packoff. Made decision to wash and ream to bottom. Continue to wash from 12,912'to 13,630'.Tight spot at 13,360' Worked drillpipe until tightspot cleaned up. NOTE:Took Survey • 12,888',13,458'and 13,453'. 7/21/2013 Continue to wash and ream from 13,360 to bottom @ 14,002'. Drill (rotate)from 14,002' to14,062' (60' @ 40 fph). Note:Auto driller not working Slide from 14,062'to 14,090 (38' @ 12.8 fph) Drill (rotate)from 14,090' to 14,100' (10' @ 10 fph). Drill (rotate)from 14,100' to 14,450' (350' @ 19.44 fph). Took M.A.D. of 20ft. from 14,351' to 14,331 to verify tool working. The Shadow resistivity fail but the Deep and Medium resistivity working. Held BOPE Drill @ 23;00 hrs. while drilling @ 14,432'. In attendants was Night Toolpusher-Jess Evans, Driller- Billy Jepson and crew. 7/22/2013 Continue to drill (rotate)from14,450'to 14,575' (125 @ 20.83 fph) DrIg(rotate) F/ 14,575'T/ 14,849' (274' @ 15.22 fph) 7/23/2013 Drilling from 14,849'to 14,869 (20' @ 20 fph) Pulsar on the MWD tool plugged. Circulated and backreamed drillipipe. Pulsar unplugged, Drilled from 14,869'to 14,892' (23' @ 23.0 fph). Made connection,Top Drive started leaking oil, racked std back in derrick M/U to stand previous drill in order to circulate and move drill string. Drilled from 14,892'to 14,942' (50' @ 25 fph) Drilled from 14,942'to 15,050' (108' @ 14.40 fph) Note:Reached Total Depth of 15,050'@ 13:30 hrs. 07-23-2013 Circulated 3 BU to clean hole @71 strokes per minuet POOH from 15,050'to 14,140'. Worked tight spot @ stand 144(14,350'). Worked tight spot (high torque) until it cleaned up. Continue to POOH conducting M.A.D. pass to 13,953'. Worked stand due to high torque. 7/24/2013 POOH for Wiper trip, conducting M.A.D. pass. Working tight spots (high torque)to 13,890'. 2 , Continue to make wiper trip conducting M.A.D. pass to12435'. POOH T/csg window @ 12,261' TIH F/ 12,261'to 13570 'with rig elevators. Washing and Reaming thru coal seams. Encountered tight spot @ 13510',13520',13580',13628',13660', 13666', 13680',13854' and 13909'. Change of rig power from shore power to rig generators Continued to TIH from 13909'to 15050'. Washed and reamed thru tight spots @ 14327' & 14423'. Circulating 2 bottom up prior to POOH to surface.as per instruction of Supt.John Nicholson. Circulating parameters RPM 50, GPM 260 @ 3000 psi. Dropped 2.64" O.D. in 4" drillpipe. Washed and reamed from 14,987'to 14800'. Attempted to POOH on elevators but drag was too excessive. Courtney Rust Cook Inlet Energy Drilling Engineer Office-907-433-3809 cell-907-350-0091 3 • Schwartz, Guy L (DOA) From: courtney Rust <courtney.rust @cookinlet.net> Sent Friday,August 02, 2013 11:03 AM To: Schwartz, Guy L(DOA) Cc: Regg,James B(DOA) Subject RUlA 213-079(7-26 to 8-1) RU1A Daily Summaries PTD: 213-079 7/26/2013 Finished making up Upper Pipe Rams door, Charging Koomey unit, open Blind Rams, Filling BOP Stack, changeg out k elevators, M/U 5 1/2"test jt. Testing Upper Pipe Rams,TIW Valve, Inside Grey, Low 250 psi for 5 mins and High 3,500 psi for 5 mins. Rigged down BOP stack. Rigged down test joint and suck out water from BOP stack, pulled test plug set wearbushing. R/U Weatherford tongs M/U Shoe track,TIH with same.and continued to RIH with 5 1/2" liner T/4,100' RIH with a total of 207 joints of 5 1/2", 17#, L-80 liner to 8544' 7/27/2013 Made up Halliburton VersaFlex 9 5/8"x 5 1/2" liner hanger. C/O bails and elevators to accommodate 4" drillpipe and laid down Weatherford Equipment. RIH with Liner Hanger&5 1/2" liner on 4" drillpipe. Installed air slips, RIH @ 90 sec per std Max per Halliburton rep. c R/U to circulate @window (12,260') &circ btms up @ 3bbl/min. TIH WI 5 1/2" liner F/ 12,260'T/15,048' working thru tight spots @ 14,755' & 14,993'. R/U cement equipment and reverse out lines. Circ btms up. Held safety meeting with all personnel (Halliburton tool reps, Mud Eng., Baker Hughes cementers, IDA, night Co. Rep all lines for leaks, increased pressure to 7500 psi for 5 mins. , bled off pressure. Worked on lines to cement unit. Pum Mixed and Pump 65 bbls. (315 sacks) Class G+0.2%CD32+0.6%R3+0.5%EC1 +1%FL63 O.15.8 ppd. Yield 1.16 cu ft/sks / Water 4.91 dos Dropped Top Plug. Displaced with 5 bbls of water and 262 bbls of OBM. Final Circulating Pressure 2.000 psi. bumped ply 07-28-2013. Held pressure for 5 minuets, and released same with returns of 221/2 bbls. 100%circulation and reciproc Pump rate for displacing cement=3 bpm 7/28/2013 Continue to cement. Top of cement = 11,993'. Drillpipe in tension @ 271,000#, dropped ball. Pressured up to 5120 psi to Ruptur Disc and 4100 psi expanded casinf test 235K up to 295k(60k up). Set 50 K daown wt indicator read 75K. Pulled cone through hanger,witness 80K overp out. Closed bag and reversed out (Pumped 450 strokes). Rigged down all hard line, and cement head. POOH Build slug& pump same to continue POOH.to surface. POOH W/liner running tool. Laid down running tool, performed rig service and general house keeping. R/U to inject Held safety meeting on injection of fluid. Injected a total of 409 bbls @ 1.5 BPM with 3200 psi. Cleaned and prepared to P/U and RIH with 2 7/8", 6.5#/ft, EUE, 8rd Tubing 1 M/U BHA. Rabbit tubing prior to RIH with same to 3900' 7/29/2013 Continue to P/U & RIH with 2 7/8", 6.5 3/ft, EUE,8rd Tubing to 8,700' C/O elevators, install clamps on bails,to continue to RIH w/2 7/8"tbg on 4" drillpipe. C/O elevators from 2 7/8"to 4" drillpipe. Adjusted clamps on bails. C/O elevators, back to from 2 7/8". Laid down x-over POOH f/8952'to surface. Clean up rig floor and pulled wearbushing and set test plug to test 2 7/8 x 5" VBR's. C/O VBR in the Upper Rams from 3 1/2" x 6"to 2 7/8" x 5 " R/U and tested Upper and Lower Pipe Rams on chart with 2 7/8 Tbg Low 250 psi for 5 mins./ High 5000 psi for 5 min Pipe Rams, Low 250 psi/High 5000 psi. R/D Test Equipment. 7/30/2013 Installed wearbushing. R/U Weatherford tongs. M/U Mill, 5 1/2" Casing Scrapper&Junk Basket. RIH 2 7/8"Tubing, install X-over to RIH with 4" Drillpipe T/ 14,836'tag up on cmt stringer. Wash F/ 14,836'T/ 14,860' POOH for 2 7/8" motor and mill.f/14,860'-t/10,700' Changed from shore power to Rig#35 power. Continue to POOH f/10,700' -t/7,500'. R/U filter unit to filter produced water in the Mud pit. (R/U @ 23:00 hrs.) 7/31/2013 Continue to POOH with 2 7/8"tubing to top of BHA. (Priming pump to filter water. Commenced filtering fluids in Pit 4 Continue to POOH and L/D BHA. Cleaned up rig floor, continue filtering water in pit#7-8 NTU's=60, been filtering water in pit#7-8 since 01:00 hrs. M/U BHA, Mill, Motor& pump out sub. R/U on RU 5 and reverse circ produced water down pipe line @ 2.25 bbl/min, well is making oil,water&gas. (TIH W Well RU-5 close well and bled pressure to 26 psi and decreased to 16 psi after 7 hours of shut-in. Attempted to circulate pressure in creased to 3000 psi released pressure and attempted to circulate using same tech 8/1/2013 Tagged bottom @ 14,846'. Attempting to circulate. Rotated drillpipe 2 revolutions on bottom with 2k, P/U and press with no success Racked back one stand of 4" drillpipe and R/U to reverse circulate. Attempted to reverse circulate, pressured up to 3000 psi, pressure bled down to 2650 psi. and well was circulating. c Shut down circulation and RID equip ror reverse circulation. RIH to Bottom and start Milling operation with full circul Milling from 14,846-to 14,917'. Circulated hole clean. Drop ball,opened circulating sub. Circulated. Circulating while pulling pump assy out of RU-5. Pulled Standing Valve to surface, bled pressure (29 psi to "0" psi). Held safety meeting on retrieving standing valve fr. Tagged &worked through @ 13,165', 13,270', and 13,314' WLM Worked gauge ring various time without passing 13 R/D Pollard to R/U to displace within reverse circulation RU-5 Held PJSM on reversing from RU-1A and displacing Ru-5 with reverse circulation. R/U to displace.RU-5 . 2 Displacing RU-5 with OBM from Ru-1A 3 OF To THE STATE Oil , Alaska coil and Gas _ -_ fALAS� , onservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue O Anchorage, Alaska 99501-3572 AL AS'' Main: 907.279.1433 Fax: 907.276.7542 Conrad Perry Drilling Manager Cook Inlet Energy, LLC 601 W. 5th Ave. Anchorage, AK 99501 Re: Redoubt Shoal Field, Redoubt Shoal Undefined Oil Pool, Redoubt Unit#1A Cook Inlet Energy, LLC Permit No: 213-079 Surface Location: 1918' FSL, 315' FEL, SEC. 14,T7N, R14W, SM Bottomhole Location: 185' FSL, 2340' FWL, SEC. 18,T7N, R13W, SM Dear Mr. Perry: Enclosed is the approved application for permit to drill the above referenced exploration well. Future Permit to Drill applications must be submitted on updated form 10-401 (revised 10/2012). This permit to drill does not exempt you from obtaining additional permits or approvals 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 Commission reserves the right to withdraw the permit in the event it was erroneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission 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 Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy P. oerster sI— Chair DATED this day of June,2013. STATE OF ALASKA AL A OIL AND GAS CONSERVATION COME ON 1 U'I,I' 1 1 2013 PERMIT TO DRILL Q�,/ ,+� 20 AAC 25.005 f r i Qa U G C la.Type of Work: lb.Proposed Well Class: Development-Oil 0 Service- Winj ❑ Single Zone [✓j lc.Specify if well is proposed for: Drill ❑ Redrill IO Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Re-entry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 112 Single Well ❑ 96 11.Well Name and Number: COOK INLET ENERGY,LLC Bond No. 3.9gg+940cMl lZ g7jREDOUBT UNIT#1A 3 Address: 6.Proposed Depth: 12.Field/Pool(s): 601 W.5TH AVE.,SUITE 310,ANCHORAGE,AK 99501 MD: 15,377 • TVD: .12,7.7.5 REDOUBT UNIT SHOAL UNDEFINED 4a. Location of Well(Governmental Section): - 7.Property Designation(Lease Number): Surface: 1918'FSL,315'FEL,Sec. 14,T7N,R14W,SM • ADL 381203,ADL 378114 4 Top of Productive Horizo 1°25-FSE 52 , See 3 N,4 8.Land Use Permit: 13.Approximate Spud Date: 1Oy ' FSL. /?4S AAA. Six_ /8i7AJA131AJ,143 n/a 6/21/2013 Total Depth:1 ' 17.I� 9.Acres in Property: ?1�3 14.Distance to Nearest Property: $S `FSI- .�Yo' FW L. S&L.. V 8 77.:&) A 13 tit.) 4I 687 9c/5" 4113113 180' IADL 374002 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: , 90 feet 15.Distance to Nearest Well Open Surface: x-208522 y- 2448039 Zone- GL Elevation above MSL: feet to Same Pool: 2180 16.Deviated wells: Kickoff depth: 12,500'- feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: k/0.5910.-134-degrees Downhole: 3-g7(, 538 {411 ,0-, Surface: 4599 PSI• 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) 6 3/4 5 1/2 17 L80 BTC-M 8,846 6,612 5,550 15,377 . 12,775 372 Sacks Class G 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): 15,323' 12,742' NONE 15,237' 12,668' tubing fish @ 12,227' Casing Length Size Cement Volume MD TVD Conductor/Structural 200' 36' N/A 200' 200' Surface 181' 13-3/8" 2686 cu ft 1,831' 1,803' Intermediate 6,986' 9-5/8" 448 cu ft 6,986' 5,988' Production 7,278' 7-5/8" 364 cu ft 13,990' 11,616' Liner 1,852' 5-1/2" 504 cu ft 15,323' 12,742' Perforation Depth MD(ft): 14,182'-14,910' Perforation Depth TVD(ft): 11,770'-12,382' 20. Attachments: Property Plat ❑ BOP Sketch 0 Drilling Program 0 Time v.Depth Plot el Shallow Hazard Analysis Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements El 21. Verbal Approval: Commission Representative: Date 30-May-13 22. I hereby certify that the foregoing is true and correct. Contact Courtney Rust 433-3809 courtney.rust @cookinlet.net Printed Name Conrad Perry Title Drilling Manager Signature Phone 907-433-3816 Date 6'�//3 Commission Use Only Permit to Drill API N ber: Permit Approval. See cover letter for other Number: 021 3O 7 1 50- 7-33— AO 49 7— 01 - 0 Date: q .1 � 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: [r Other: _, 50 00 S` /o( eS Samples req'd: Yes❑ Non Mud log req'd: Yes ❑ No[/] H2S measures: Yes❑ Non' Directional svy req'd: Yes 12-No❑ ZS-66 rS v �•1. . .t_7 — s n '—! h`01 PrAti : 71 ykS R14)a J ' PPROVED BY THE COMMISSION �DATE: l COMMISSIONER ORIGINAL 94)1 f(7::f7/-..„. 4�1 I Form 10-401(Revised 7/2009) This permit is valid for 24 months from the date of approval(20 AAC 25.005(9)) Submit in Duplicate G Rtf.,114 vzD 11 2013 AOGCC June 11, 2013 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage,Alaska 99501 Re:Application for Permit to Drill Cook Inlet Energy, LLC: Redoubt Unit#1A Dear Ms. Foerster, Cook Inlet Energy(CIE) hereby submits an amendment to the Permit to Drill application due to a change in the bottom hole location. Attached are completed Form 10-401 and new directional plan for the well. Rig#35 will be used to complete this work over commencing approximately June 21st, 2013 If you have any questions,please contact me at(907)-433-3816. Sincerely, 0_,77 Conrad Perry Drilling Manager Cook Inlet Energy, LLC SIAILOFALASKA ALPGKA OIL AND GAS CONSERVATION COMMIQSION PERMIT TO DRILL ��rsf� l'/�(el��5 20 AAC 25.005 la.Type of Work: lb.Proposed Well Class: Development-Oil 151 Service- Winj U Single Zone ❑ 1c.Specify if wel is proposed for: Drill ❑ Redrill el Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas > Gas Hydrates ❑ Re-entry p Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Shale Gas ❑_ 2.Operator Name: 5. Bond: Blanket 0 Single Well ❑ 11.Well N• e and Number: COOK INLET ENERGY,LLC Bond No. Rug..0004946 C.. I a La?-° REDOU UNIT#1A _ 3.Address: 6.Proposed Depth: 12.77.s-, 12.Fi- ./Pool(s): 601 W.5TH AVE.,SUITE 310,ANCHORAGE,AK 99501 MD: 15,458' ND: 12,769- RED/QSUBT UNIT SHOAL UNDEFINED 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): 90 / Surface: 1918'FSL,315'FEL,Sec.14,T7N,R14W,SM ADL 381203,ADL 378114 t 3 yoo Top of Productive Horizoi 1650'FNL 180'FSL 187N 13W 2 3 8.Land Use Permit: 13.Approximate Spud Date: FWi. C4I/`I l /a 6/1/2013 Total Depth:2350'FWL 200'FSL vs 7N 13 W 9.Acres in Property: ?ii-g) 'i3 14.Distance to Nearest Property: (y ISI Zcc 61 11 /5(3,5 180' IADL 374002 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: • 90 feet 15.Distance to Nearest Well Open Surface: x-208522 y- 2448039 Zone- IA GL Elevation above MSL: / feet to Same Pool: 2180 16.Deviated wells: Kickoff depth: 12,500' feet 17.Maximum Anticipated Preses 3 psig(see 20 AAC 25.035) Maximum Hole Angie: 40.84 degrees Downhole: S SR, 5748- G Surface: 4599 PSI 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD ND D ND (including stage data) 6 3/4 5 1/2 17 L80 BTC-M 8,846 6,612 5,550 , 5,458 12,500 F / MHr 3 0 2013 19. PRESENT WELL CONDITION SUMMARY(To be completed for Red'?and Re-Entry Operations) A (3CC Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effect.&pth MD(ft): Effect.Depth ND(ft): Junk(measured): 15,323' 12,742' NONE 15,237' 12,668' tubing fish @ 12,227' Casing Length Size Cement Volume MD ND Conductor/Structural 200' 36' N/A 200' 200' Surface 181' 13-3/8" 2686 cu ft 1,831' 1,803' Intermediate 6,986' 9-5/8" / 448 cu ft 6,986' 5,988' Production 7,278' 7-5/8" / 364 cu ft 13,990' 11,616' Liner 1,852' 5-1/2" 504 cu ft 15,323' 12,742' Perforation Depth MD(ft): 14,182'-14,910' Perforation Depth ND(ft): 11,770'-12,382' 20. Attachments: Property Plat ❑ BOP Sketch 0 Drilling Program IN Time v.Depth Plot 0 Shallow Hazard Analysis El Diverter Sketch El Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements El 21. Verbal Approval: Commission Representative: /` Date 30-May-13 22. I hereby certify that the foregoing is true and correct. / Contact Courtney Rust 433-3809 courtnev.rustt cookinleLnet Printed Name Conrad Perry Title Drilling Manager / Signature e..--t" / Phone 907-433-3816 Date c---3e7 —/ 3 Commission Use Only s Permit to Drill API Number: Permit Approval See cover letter for other Number: v21 3 0 7 9 50-"?33- o 4 ? -01 - 00 Date: requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales:5 Other: / Samples req'd: Yes❑ No[t� Mud log req'd: Yes El)10[e H2S measures: Yes❑ No ( Directional svy req'd: Yes 12'No❑ /, APPROVED BY THE COMMISSION DATE: , , ,COMMISSIONER Form 10-401(Revised 7/2009) This permit Is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit in Duplicate DUPLICATE 7/43 Siokrsk, chi /3 RE IV D -x 30203 AOGCC May 30th, 2013 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave.,Suite 100 Anchorage,Alaska 99501 Re:Application for Permit to Drill Cook Inlet Energy, LLC: Redoubt Unit#1A Dear Ms. Foerster, Cook Inlet Energy(CIE) hereby submits a Permit to Drill application to sidetrack the Redoubt Unit#1 well located on CIE lease#381203 off the/Osprey Platform.A separate sundry application was submitted to cover the abandonment of RU-1. This PTD application requests permission to sidetrack just above the productive zone (and fish) in 7 5/8" casing and drill a replacement well to RU-1. Attached are completed Form 10-401, outline pro: edures,current and proposed wellbore schematics, Directional Plan/Close Approach calculations, MASP calculations, Rig Drawing, and a BOP configuration diagram. Rig#35 will/be used to complete this work over commencing approximately June 21st, 2013 `�-°' If you have any questions,please contact me at (907)-433-3816. Sincerely, Conrad Perry Drilling Manager Cook Inlet Energy, LLC 10-401 May 30th, 2013 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage,Alaska 99501 Re: Application for Permit to Drill Cook Inlet Energy, LLC: Redoubt Unit#1A Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a Permit to Drill application to sidetrack the Redoubt Unit#1 well located on CIE lease#381203 off the Osprey Platform.A separate sundry application was submitted to cover the abandonment of RU-1. This PTD 3�3-2 51 application requests permission to sidetrack just above the productive zone (and fish) in 7 5/8" casing and drill a replacement well to RU-1. Attached are completed Form 10-401, outline procedures, current and proposed wellbore schematics, Directional Plan/Close Approach calculations, MASP calculations, Rig Drawing, and a BOP configuration diagram. Rig#35 will be used to complete this work over commencing approximately June 21st, 2013 If you have any questions, please contact me at(907)-433-3816. Sincerely, Conrad Perry Drilling Manager Cook Inlet Energy, LLC 10-401 Table of Contents Rig#35 Schematic 3 Current Completion 4 RU-1 Well After Abandonment 5 RU-1A Proposed Completion 6 Re-drill 7 Pre-Rig 7 Rig Operations 7 Sidetrack Drilling Procedure 7 Drilling 6 3/"" Hole Section 9 Special Drilling Instructions: 9 Run and Cement 5 1/2"Liner 10 Perforation and ESP Completion 11 Directional Plan 1 BOP Sketch 1 Wellhead Schematic 2 Geo-Mechanical Plot 3 Casing Program 4 Drilling Fluid Program 5 Cement Program 12 Logging Plan 17 Mud Logging Plan 17 Solids Control and Equipment 17 Drilling Waste Storage 17 Bit Proposal 18 III Rig #35 Schematic s.. 'A 10 ti 0 Sik 14 I .AIL. bytikw ' '' ilillIIIIIIIIIII 1 1 ow. Fci 1 r ..-:, $111 Ciii 1:01#0 t 4 III II kal<WC mr,ty 1'4 O K F$rifiCK r, , 147 FT I X n OW 1 ( l'. ilo'l ,r4 .r1F1674 i / i I 4 I f r a AM! ite 1,4 ifirAilir i 10 4p, A1111121 4 It: WAWA II. 11 11. 't. IllrA1111111101 il . , ,i .1 11=utturt .......... if ci 1 %rr Hicti CURL j I = ,IMINELNIIIMOI WI.' \•41:1:41 9 iiraiar ".11 lir IIRSTROCER i 7., 111 7: ''SIM 414E ' 1111111111111-Nth— -- -- -,-•.MIN -IN Maliliiill•'''' MI MIN WI'F.41 ''6*'".'''IMMO a MUM MIN 11.11MIIIIIII ill 01111 RAM, OW BM I= .----4-4/- *PIM 5 1/2 fl OSPREY 1 1 Ii II ,..---- ,.....x.....) DRILLING RIG ARRANGEMENT — EAST SIDE M..11:1Th:V:z...e N:P;5-7,AFT"Pal ri vooDu rr t Tuntun a APPROvAL DwG 1.15 7.111,4:."::'NCI TM.L9E, ■ RilLi....)lk Mil* I iii rtnrifili vr It VIVI 1 ' WM) e t OSPREY 1R1LIDIO RIG 01.7....M. sr Ow ant WI, , Win* 1"' .. .... Current Completion Current Completion Redoubt Unit#1 11/28/2012 36".1508,A-36,Welded Conductor 200'MD200'TVD •Ak £ 13-3/8",680,L-80,ETC 1.831'MD/1,8037VD ,, TUBING DETAIL 2 each 3 12"9.3#P-110 Pup 224 jts 3 12"9.3#P-110 Tubing 173 jts 3 12"9.3#L-80 Tubing 132.71'ESP Assembly with splice TOL e 6,712'MD '" pups 9-5/8".478,L-80,BTC 6,986'MD/5,988'TVD r` s 666JJJ��' " Centrilift ESP assembly @ 12,067'MD/10,090'TVD TOF:13,249'MD A Centnlift ESP assembly@ 13,581'MD Perforations 14,182'-14,214' LLC valve set in Baker FA packer @ 13,662'MD 14,238'-14,254' `'` 14,256_14,272' TOL @ 13,741'MD 14,28J-14,298' 14,320-14,344' __i. 7-5/8",29.7#,L-80,Hydnl 521 @ 13,990'MD/11,616'TVD 14,348'-14,364' 14,440-14,455' 14,462-14478' -_ 14,482-14,620' 14,630-14,656' Perforations 14,664-14,772' - - 14,784-14,850' 14,856-14,880' 14,890-14,910' 1 5-1/2",17#,L-80,Hydri1521 @ 15,323'MD/12,7421VD 3 3/8" 6 SPF RU-1 Well After Abandonment Current Completion Redoubt Unit#1 11/28/2012 _ L36",1506,A-3G,Welded Conductor 200'MD2001VD 13-38",68#,L-80,BTC 1,831'MD/1,803'TVD TOL @ 6,712'MD 1 1 9-5/8",47#,L-80,BTC @ 6,966'MD/5,988'TVD •-I i y Cement Retainer @ 12,600'MD 7lpa A TOP:13,249'MD • Centrilift ESP assembly@ 13,581'MD • Perforations 0 14,187-14,214 7 L LC valve set in Baker FA packer 13,662'MD 14,236-14,254' 14,256-14,272' TOL @ 13,741'MD 14,280'-14,298' 14,320'-14,344' I 7-58",2976,L-80,Hydril 521 @ 13,990'MD/11,616'TVD 14,346-14,364' 14,44d-14,455' 14,462-14,478' = 14,482-14,620' 14,63d-14,656 = - Perforations 14,664-14,772' = 14,784-14,850' 14,856-14,880' 14,890-14,910' 5-1/2",17#,L-80,Hydril 521 @ 15,323'MD/12,742'TVD 3 3/8" 6 SPF RU-1A Proposed Completion Proposed Completion Redoubt Unit#1A. 6/28r2013 Tubing 3SS,.r 200 iti --- -- - 36'.150s,n-36,Vaetded Conductor 20011CA200"TVD air 1:-20.B',684 L-80,ETC srli 1.831tt0tt,80?7VC Packer and SSSV vent verve @ V f` y ;', S 112"70i @ 6,512 WE +r. 7S.8'TOL @6712 MAD + ;;, 0a d s-.96',s,m,L-AZ,s-c OE,seeut;.e,serrV 27+8'P1-F665#L60 ■ TOC 11,500'MD 3 1 ESP assentt;@ 12.560 IC 7 5/8"Window @ 12,500' = — 5 12"171E L80 BTC-M @ 15,458'MD/12,775'TVD i RU 1A Siderack Procedure 5/28/2013 Re-drill Pre-Rig This is a follow-on procedure from RU-1 abandonment. The rig will be in place with BOPs tested. Rig Operations Sidetrack Drilling Procedure es+ SOPS/ 112' e J` 1. Review bond log to ensure there is sufficient cement in whipstock area. If not, and good cement is not within a reasonably close area, a circulation squeeze procedure will be written. 2. M/U the following 7-5/8" Select Oil Tools Bottom Trip Whipstock System: i. 7-5/8" Bottom trip anchor w/4-1/2" IF box ii. 7-5/8"Select whipstock w/4-1/2" IF pin iii. Starter window mill w/4-1/2" Reg pin up(shear screw set for 50,000 lbs.) iv. Full gauge upper watermelon mill w/4-1/2" reg box down x 4 1/2"XH box v. XO 4" HWDP x 4 1/2"XH pin vi. 1 joint 4" HWDP vii. 4-3/4" bumper sub viii. 4-3/4" MWD survey tool w/3-1/2" IF box X pin ix. UBHO wireline orientation sub w/3-1/2" box X pin x. 9 ea 4 3/4"drill collars w/3-1/2" IF box X pin xi. 18 ea 4" HWDP w/3-1/2"IF box X pin xii. 4" Drill pipe to surface 3. Attach the anchor/whipstock assembly to the milling assembly via the 50k whipstock shear bolt. Then align the UBHO sub and MWD (scribe as required) with the whipstock face. This should be witnessed by the Cook Inlet Energy drilling supervisor, Olgnoonik tool hand, directional driller and MWD engineer. (The UBHO orientation sub will only be used as a backup if there is an MWD failure.) 4. RIH with whipstock assembly, taking great care while running it through the BOP stack and wellhead. Run the assembly at 90 to 120 seconds per stand. Ensure the string is fully stopped when setting the rotary slips while RIH. These precautions are necessary to avoid any weakening of the whipstock shear mechanism or pre- setting of the packer. 5. With the bottom of assembly 40' above the bridge plug at +12,500', establish up and down weights, with and without circulation. Do not create any sudden movements that might weaken the whipstock shear mechanism. 6. Survey the whipstock face with the MWD tool and orient the whipstock as per directional driller recommendations. Take a minimum of three surveys, then reciprocate the assembly and verify the whipstock face has not rotated. Re- orient and survey as necessary. 7. Once orientation and depth have been verified, set down on the bridge plug with 18- 20 k lbs to shear the slip mechanism and set the bottom trip anchor. Verify the bottom trip anchor has set by picking up a maximum of 5K lbs over the string pick up weight. 8. Ensure mud is formulated as specified in the mud program. Install ditch magnets to capture milled casing cuttings. 9. With the bottom trip anchor set and the work string hanging in neutral at the whipstock, slack off 50 k lbs to shear the whipstock bolt. 10. Pick up to neutral, break circulation and establish rotation at 50-60 rpm. Lower 147 the milling assembly and commence milling with 2-4k lbs WOB and 50-60 rpm for Kb P the first foot or two. Gradually increase the rpm to 100-135 as needed and use a maximum 8-10k lbs WOB while milling. Maintain a minimum annular velocity of 150'/min and a minimum mud yield point of 40 to ensure carrying capacity for metal fry cuttings removal. 11. Continue milling until the upper watermelon mill is out in the open hole (after approximately 29' of milling). Pump a viscous sweep and circulate bottoms up. 12. Circulate and condition mud for FIT. Perform FIT to minimum of 10.3 ppg EMW. 13. POH. Check the OD of the upper watermelon mill. If it is more than 1/8" under gauge, a second reaming trip will be required. 3I3- 2S1 (vovr-) V Drilling 6 3/4"" Hole Section Objective: Drill 6 3/4" sidetrack hole and run and cement 5.5" production liner. Planned Depth 15,458' MD, 12,775'TVD Section Length 2,958' Planned KOP 12,500' Drilling Parameters: Flow Rate 300-450 gal/m RPM 60-160 rpm WOB 5-35 k lb Expected ROP 10-50 ft/hr Bit Details: 6 3/4" FXD84D Mud System: Oil base mud. See attached mud program II 14. M/U 6 3/4" bit and steerable motor with 1.2 degree bent housing. 15. RIH. Directionally drill a 6 3/4" hole as specified in the directional program. Note formation tops are in directional program. Proper hole cleaning is the major factor in successfully drilling this hole section. Maintain tangent angle and directionally drill 6%' hole from the 7-5/8"casing window to TD per the directional program. Use mud loggers to allow monitoring of progress through the section. 16. Flow check all drilling breaks. Avoid circulating in the same spot for extended periods of time to avoid excessive washout at one depth. Add lubricants as required to reduce torque and drag. Special Drilling Instructions: a) Entire hole section will be triple combo'd. Use PWD service. b) Always bring pumps on slowly. c) Minimize wiper trips. Should have reason for wiper trip eg. Increasing drag on connections,torque, sticky etc. d) Pump and rotating out of hole on all trips at maximum allowed by directional driller if not able to pull cleanly. e) Minimize surge and swab pressures- even in casing! f) Pre-treat mud with both sized calcium carbonate and black products to seal micro fractures in coals. g) Circulate a minimum of two bottoms up prior to POH at the same rate the well was being drilled. h) Minimize or eliminate sweeps except at trips out of hole. Mud rheology should be sufficient to carry all drill solids out of the hole. Sweeps, especially weighted sweeps, put undue pressure surges on the coals. i) Packoffs are deadly to hole stability. Immediately go down if pressure increases while pumping out of hole. 17. The 51/2" liner setting point will be identified by the Cook Inlet Energy geologist using mud logging information. At section TD, condition hole minimum of 4 bottoms up and POH. Run and Cement 5 1/2" Liner 18. Install and test 51/2" Casing rams --1?,/— .f 5o° 19. M/U and run 5 1/2", 18#, L80, BTCM liner on 4" drill pipe as follows: a. Liner will be brought back into the 9 5/8" casing in order to scab over the 7 5/8" liner entirely. b. Perform all measurements and equipment checks before running the liner. c. Ensure liner hanger is located 200' above 7-5/8" Liner top. • d. 1 joint 5 1/2" liner w/float collar made up on pin end of joint#2 e. 1 joint 5 1/2" liner landing collar made up on the pin end of joint#3.Also equipped w/1-7/16" ball seat and catcher sub pinned for±2,500 psi shear. f. +8900'of 5 1/2",17#, BTC M L80 Liner g. Baker 9-5/8"x 5 1/2" liner hanger pinned for 1,500 psi(±15%) h. Baker 9-5/8"x 5 1/2" liner top packer w/C-2 running tool profile and Type II tie-back sleeve, i. drill pipe wiper plug and liner wiper plug. j. Baker-Lock all float equipment and the bottom 4 joints of liner. Solid body Centralizers will be run on every joint through Hemlock then every 4th jt unless there is hydrocarbon potential in lower Tyonek. 20. RIH w/ liner hanger assembly. . 21. Run 10 stds of HWDP and circulate one drill pipe volume. Continue RIH with liner on _ DP to 7 5/8" window. Break circulation every 4000'. Break circulation at window. Obtain pick-up and slack-off values. Liner speed to be run with a calculated ECD less than when drilling! - 22. Continue to RIH to TD with liner on drill pipe. Tag bottom with liner. Top of the liner is planned at 6700' MD. 23. P/U a sufficient distance to allow a safe and convenient make-up operation of the cementing head and test lines to 500/5,000 psi. Circulate and condition the hole for cementing while reciprocating the liner. Maximize flow rate while cleaning hole. Do not exceed the liner hanger setting pressure. 24. The top of cement is planned for 11,500'MD. While reciprocating the liner again with a calculated ECD less than what it was during drilling, pump cement as �b � follows, carefully monitoring torque and flow rate while rotating: • Verify DP indicator is activated • Pump 40 bbls of 13.5ppg weighted spacer • Follow weighted spacer 69 bb Is (including 30%excess in open hole) of class G cement mixed as: Class G cement at 15.8 ppg+additives+fresh (See detailed cement program for 7" liner) • Follow the cement with the DP wiper dart and displace with drilling mud. • Slow pump down 5 bbls short of the DP wiper dart landing on the landing collar. • Bump plug w/500 psi • Limit over-displacement to 3 bbls (80' shoe track) 25. Once liner wiper plug bumps, hold the pressure for 2 minutes. Do not exceed 500psi over the final pumping pressure. 26. Set liner hanger by pressuring up to 1,800 psi down the drill string. The liner hanger will be set at this point. 5/0 liner weight plus 10,000 lbs to ensure liner hanger is set. Bleed off pressure and P/U to neutral weight at the liner hanger. Rotate 12 turns to the right to release the running tool. P/U to ensure tool is released. Note: Do not P/U enough to disengage sleeve pack-off from tie back sleeve. 27. Bleed pressure to 500 psi and slowly P/U to clear packoff from liner tie-back sleeve. 28. Clear the rotating dog sub from tie-back sleeve. Set down 45,000# at the tool, rotating if necessary. 29. Pull up 1 stand and reverse out cement at maximum rate while reciprocating and rotating drill pipe. 30. POH 31. RIH with 4 3/4" bit and 5 1/2" casing scraper and scrape the liner to TD. CBU. Test cast g and liner to 2000 psi. NOTE: Do not test casing until WOC for 24 hours! 32. Rig up and run Halliburton Cast-M cement bond log. CJ3L_. Perforation and ESP Completion 33. Rig up to run in hole with TCP guns. The perforating program will be issued by CIE geologist based on logs. 34. Pick up perf guns and RIH on Champ packer and drill pipe. Set packer and obtain 1500 psi underbalance. Fire guns. Circulate well dead. POH. 35. Test and inspect new ESP and new Phoenix tool before running in hole. 36. Pick up new ESP completion and RIH. Test cable every 1000'. 37. Install ESP packer, vent valve and SSSV assembly. (this is new to previous completions). 38. Monitor trip tank for proper hole filling. Splice cable as needed. At TD, confirm pipe tally, MU landing joint and set string in slips. 39. Dress hanger and control lines. Land hanger, run in screws, test hanger to 5000 psi. 40. Rig up slickline. Run Test tool to XN nipple below packer. Pressure up on tubing to Baker recommendations setting packer. Recover Test Tool. 41. Test Annulus to 2000 psi. 42. Open sliding sleeve. Circulate annulus and tubing to 8.8 ppg packer fluid. Close sleeve and rig down slickline. 43. Observe well dead. Lay down landing joint and install BPV. 44. Nipple down riser and BOPE. 45. Install and test production tree. Turn over well to production. 46. Release Rig RECEPIED !U N 1 1 2013 AOGCC Cook Inlet Energy COOK INLET BASIN REDOUBT SHOAL Redoubt Unit #1 RU-1 A Plan: RU-1A Wp5.0a Standard Proposal Report 11 June, 2013 HALLIBURTON Sperry Drilling Services HALLIBURTON Project:COOK INLET BASIN SECTION DETAILS Site: REDOUBT SHOAL Sec MD Inc Azi TVD ON/-S +E/-W DLeg TFace VSec Target Well Redoubt Unit#1 1 12500.00 38.10 102.79 1043499 -1850.99 6279.96 0.00 0.00 699.77 2 12520.00 40.55 101.42 1045046 -1653.54 6292.35 1100 -20.00 -700.55 Sperry Drilling Wellbore: RU-1 A 3 13300.00 40.55 101.42 1104115 -1754.02 8789.39 0.00 0.00 -725.99 RU-1A Wp5.0a 4 15377.77 27.27 71.98 12775.00 -1740.32 7918.53 1.00 -140.84 -545.00 RU-1A BHL Tgt Vera Cook Inlet Energy REFERENCE INFORMATION COMPANY DETAILS: Cook Inlet Energy Co-ordinate(N/E)Reference: Well Redoubt Unit et,True North Calculation Method:Minimum Curvature Vertical(TVD)Reference: Plan:RedoubtUnitht 090.0011(Flan:RedoubtUnit81) Error System:ISCWSA Measured Depth Reference: Plan:RedoubtUn6el Q 900011(Plan:RedoubtUnit#1) Scan Method Closest Approach 3D Calculation Method: Minimum Curvature Error Surface'Elliptical Conic ------ Warning Method:Error Ratio SURVEY PROGRAM Date:2013-06-11700:00:00 Validated:Yes Version: Depth From Depth To Survey/Plen Tool CASING DETAILS 184.76 12500.00 RU#1(RUlt1) MWD • 12500.00 13350.00 RU-1AWp5.0a(RU-1 A) MWD_Interp AZi TVD MD Name Size 1335000 15377.77 RU-1A Wp5.0a(RU-1 A) MWD+SAG 200,00 200.00 Case2 38 1773.95 1800.00 Case3 13-3/8 8000.00 7000.19 Case4 9-5/8 -12W- 12775.00 15377.77 5 1/2" 5-12 WELL DETAILS:Redoubt Unit#1 -1320- Water Depth: 40.00 +WS +E/-W Northing Easting La6ttude Longitude Slot Start Dir 13°/100':12500 MD,10434.99'TVD:20°LT TF 0.00 0.00 2449941.20 200530.58 50.895485 -151.670578 -1440- - End Dir :12520'MD,10450.46'TVD Total Depth:15377.77'MD,12775'TVD RU-1A BHL Tgt Verb 1 - - '! 80°A nee-./ Start Dir 10/100':13300'MD,11043.15'TVD j 5 l/2" -1680- I • 1 .5 _ '- RU-IA Wp5.0a g - RU-IA Hardline zn,-1920- RU#1 .:--2040- 3 b rn - -2160- -2280- -2400- -2520- -2640- rlirirlirii� iiii� ii 6120 6240 6360 6480 6600 6720 6840 6960 7080 7200 7320 7440 7560 7680 7800 7920 8040 8160 8280 8400 8520 8640 8760 8880 9000 West(-)East(+)(300 Win) • • HALL'BURTON Project: COOK INLET BASIN WELL DETAILS:Redoubt Unit#1 Site: REDOUBT SHOAL water Depth: 40.00 Well Redoubt Unit#1 +N/S +E/-W Northing Easting Latitude Longitude Slot Sperry Orillin' Wellbore: RU-1 A o.00 0.00 2449941.20 200630.58 60.695485 -151.870678 RU-IA Wp5.0a SURVEY PROGRAM _ _Cook Inlet Energy Date:2013-06-11700:0000 Validated:Yes Version: Depth From Depth To Survey/Plan Tool 184.76 12500.00 RU Y1(RU*1) MWD _ 12500.00 13350.00 RU-1A Wp5.0a(RU-1 A) MWD IMerp Pzi 13350.00 15377.77 RU-1A Wp5.0a(RU-1 A) MWD+SAG 10000- SECTION DETAILS 10250- Sec MD Inc Azi TVD +N/-S +E/-W ()Leg TFace VSec Target - Start Dir 13°/100':12500'MD,10434.99'TVD:20°LT TF 1 12500.00 38.10 102.7910434.99-1850.99 6279.98 0.00 0.00 -099.77 2 12520.00 40.55 101.4210450.48-1853.64 6292.35 13.00 -20.00 -700.55 - _ 3 13300.00 40.55 101.4211043.15-1754.02 0788.38 0.00 0.00 -725.99 4 15377.77 27.27 71.9812775.00-1740.32 7916.53 1.00-14088400 140.64 -545.00 RU-1A BHL Tgt Vera 10500- 10750- End Dir`12520'MD,10450.46'TVD REFERENCE INFORMATION Co-ordinate(N/E)Reference:Well Redoubt Unit%1,True North _ Vertical(TVD)Reference:Plan:RedoubtUnitrl ft 90.00n(Plan:RedoubtUnt/t1) Measured Depth Reference:Plan:RedoubtUnit4H 90.00ft(Plan:RedoubtUnt8l) 511000- Calculation Method:Minimum Curvature 6 Start Dir 1°/100':13300'MD,11043.15TVD - CASING DETALS 11250- TVD MD Name Size 200.00 200.00 Case2 36 _ 1773.95 1800.00 Case3 13-3/8 8000.00 275.00 15377.77 5 1/7' 5-1/2 611500- 2 Cook Inlet Energy 11750- Calculation Method:Minimum Curvature Error System:ISCWSA Scan Method:Closest Approach 3D Error Surface:Elliptical Conic Warning Method:Error Ratio 12000- 12250- 12500- _ Total Depth:15377.77'MD,12775'TVD 51/2" --- 12750- RUM- RU-1A BHL Tgt Vert 13000- RU-1A Wp5.0a viii i1 iii1i1 ii � irii -1750 -1500 -1250 -1000 -750 -500 -250 0 250 500 750 1000 1250 1500 1750 Vertical Section at 8.54°(500 ft/in) • III Halliburton Company HALLIBURTON Standard Proposal Report Database: .Sperry 16 PROD Local Co-ordinate Reference: Well Redoubt Unit#1 Company: Cook Inlet Energy TVD Reference: Plan:RedoubtUnit#1 @ 90.00ft(Plan:RedoubtU Project: COOK INLET BASIN MD Reference: Plan:RedoubtUnit#1 @ 90.00ft(Plan:RedoubtU Site: REDOUBT SHOAL North Reference: True Well: Redoubt Unit#1 Survey Calculation Method: Minimum Curvature Wellbore: RU-1 A Design: RU-1A Wp5.0a Project COOK INLET BASIN 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 Site REDOUBT SHOAL Site Position: Northing: 2,449,990.00ft Latitude: 60.695618 From: Map Easting: 200,627.00ft Longitude: -151.670705 Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: -1.46° Well Redoubt Unit#1 Well Position +N/-S 0.00 ft Northing: 2,449,941.20 ft Latitude: 60.695485 +E/-W 0.00 ft Easting: 200,630.58 ft Longitude: -151.670678 Position Uncertainty 0.00 ft Wellhead Elevation: ft Water Depth: 40.00 ft Wellbore RU-1 A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°I (nT) BGGM2012 4/12/2013 17.15 73.57 55,427 Design RU-1A Wp5.0a Audit Notes: Version: Phase: PROTOTYPE Tie On Depth: 12,500.00 Vertical Section: Depth From(TVD) +W-S +E/-W Direction (ft) (ft) (ft) 1°) 130.00 0.00 0.00 8.54 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (ft) (°1 (°) (ft) ft (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 12,500.00 38.10 102.79 10,434.99 10,344.99 -1,650.99 6,279.96 0.00 0.00 0.00 0.00 12,520.00 40.55 101.42 10,450.46 10,360.46 -1,653.64 6,292.35 13.00 12.26 -6.84 -20.00 13,300.00 40.55 101.42 11,043.15 10,953.15 -1,754.02 6,789.39 0.00 0.00 0.00 0.00 15,377.77 27.27 71.98 12,775.00 12,685.00 -1,740.32 7,916.53 1.00 -0.64 -1.42 -140.64 V 6/11/2013 2:05:39PM Page 2 COMPASS 2003.16 Build 73 Halliburton Company HALLIBURTON Standard Proposal Report Database: .Sperry 16 PROD Local Co-ordinate Reference: Well Redoubt Unit#1 Company: Cook Inlet Energy TVD Reference: Plan:RedoubtUnit#1 @ 90.00ft(Plan:RedoubtU Project: COOK INLET BASIN MD Reference: Plan:RedoubtUnit#1 @ 90.00ft(Plan:RedoubtU Site: REDOUBT SHOAL North Reference: True Well: Redoubt Unit#1 Survey Calculation Method: Minimum Curvature Wellbore: RU-1 A Design: RU-1A Wp5.0a Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (0) (0) (ft) ft (ft) (ft) (ft) (ft) 10,344.99 12,500.00 38.10 102.79 10,434.99 10,344.99 -1,650.99 6,279.96 2,448,131.07 206,866.53 0.00 -699.77 Start Dir 13°/100':12500'MD,10434.99'TVD:20°LT TF 12,520.00 40.55 101.42 10,450.46 10,360.46 -1,653.64 6,292.35 2,448,128.10 206,878.85 13.00 -700.55 End Dir :12520'MD,10450.46'TVD 12,600.00 40.55 101.42 10,511.25 10,421.25 -1,663.93 6,343.33 2,448,116.51 206,929.55 0.00 -703.16 12,700.00 40.55 101.42 10,587.23 10,497.24 -1,676.80 6,407.05 2,448,102.03 206,992.93 0.00 -706.42 12,800.00 40.55 101.42 10,663.22 10,573.22 -1,689.67 6,470.78 2,448,087.54 207,056.30 0.00 -709.68 12,900.00 40.55 101.42 10,739.21 10,649.21 -1,702.54 6,534.50 2,448,073.05 207,119.67 0.00 -712.94 13,000.00 40.55 101.42 10,815.19 10,725.19 -1,715.41 6,598.22 2,448,058.57 207,183.05 0.00 -716.20 13,100.00 40.55 101.42 10,891.18 10,801.18 -1,728.28 6,661.94 2,448,044.08 207,246.42 0.00 -719.47 13,200.00 40.55 101.42 10,967.16 10,877.16 -1,741.15 6,725.67 2,448,029.60 207,309.80 0.00 -722.73 13,300.00 40.55 101.42 11,043.15 10,953.15 -1,754.02 6,789.39 2,448,015.11 207,373.17 0.00 -725.99 Start Dir 1°/100':13300'MD,11043.157VD 13,400.00 39.78 100.43 11,119.57 11,029.57 -1,766.24 6,852.71 2,448,001.28 207,436.17 1.00 -728.67 13,500.00 39.02 99.40 11,196.85 11,106.85 -1,777.17 6,915.23 2,447,988.77 207,498.39 1.00 -730.19 13,600.00 38.27 98.34 11,274.95 11,184.95 -1,786.81 6,976.93 2,447,977.57 207,559.82 1.00 -730.55 13,700.00 37.52 97.25 11,353.87 11,263.87 -1,795.14 7,037.78 2,447,967.69 207,620.44 1.00 -729.76 13,800.00 36.79 96.12 11,433.56 11,343.56 -1,802.18 7,097.77 2,447,959.13 207,680.23 1.00 -727.80 13,900.00 36.07 94.95 11,514.02 11,424.02 -1,807.91 7,156.87 2,447,951.90 207,739.17 1.00 -724.69 14,000.00 35.36 93.74 11,595.21 11,505.21 -1,812.33 7,215.08 2,447,946.00 207,797.25 1.00 -720.41 14,100.00 34.67 92.48 11,677.11 11,587.11 -1,815.45 7,272.37 2,447,941.42 207,854.44 1.00 -714.99 14,200.00 33.98 91.18 11,759.70 11,669.70 -1,817.26 7,328.73 2,447,938.18 207,910.73 1.00 -708.40 14,300.00 33.32 89.84 11,842.94 11,752.94 -1,817.76 7,384.14 2,447,936.27 207,966.11 1.00 -700.67 14,400.00 32.66 88.45 11,926.82 11,836.82 -1,816.95 7,438.57 2,447,935.70 208,020.55 1.00 -691.78 14,500.00 32.02 87.00 12,011.31 11,921.31 -1,814.83 7,492.03 2,447,936.45 208,074.04 1.00 -681.75 14,600.00 31.40 85.51 12,096.38 12,006.38 -1,811.41 7,544.48 2,447,938.54 208,126.56 1.00 -670.57 14,700.00 30.80 83.96 12,182.01 12,092.01 -1,806.68 7,595.91 2,447,941.97 208,178.10 1.00 -658.25 14,800.00 30.22 82.36 12,268.16 12,178.16 -1,800.64 7,646.31 2,447,946.72 208,228.64 1.00 -644.79 14,900.00 29.65 80.70 12,354.82 12,264.82 -1,793.30 7,695.67 2,447,952.80 208,278.16 1.00 -630.20 15,000.00 29.11 78.99 12,441.96 12,351.96 -1,784.66 7,743.95 2,447,960.21 208,326.65 1.00 -614.48 15,100.00 28.59 77.22 12,529.55 12,439.55 -1,774.72 7,791.17 2,447,968.95 208,374.10 1.00 -597.64 15,200.00 28.09 75.38 12,617.57 12,527.57 -1,763.48 7,837.28 2,447,979.01 208,420.49 1.00 -579.68 15,300.00 27.62 73.49 12,705.98 12,615.98 -1,750.95 7,882.30 2,447,990.39 208,465.81 1.00 -560.60 15,377.77 27.27 71.98 12,775.00 12,685.00 -1,740.32 7,916.53 2,448,000.15 208,500.30 1.00 -545.00 Total Depth:15377.77'MD,12775'TVD-5 1/2"-RU-1A BHL Tgt Ver6 6/11/2013 2:05:39PM Page 3 COMPASS 2003.16 Build 73 Halliburton Company HALL I B U R TO N Standard Proposal Report Database: .Sperry 16 PROD Local Co-ordinate Reference: Well Redoubt Unit#1 Company: Cook Inlet Energy TVD Reference: Plan:RedoubtUnit#1 @ 90.00ft(Plan:RedoubtU Project: COOK INLET BASIN MD Reference: Plan:RedoubtUnit#1 @ 90.00ft(Plan:RedoubtU Site: REDOUBT SHOAL North Reference: True Well: Redoubt Unit#1 Survey Calculation Method: Minimum Curvature Wellbore: RU-1 A Design: RU-1A Wp5.0a Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) RU-1A Hardline 0.00 12,775.00 -1,840.32 7,916.53 2,447,900.18 208,497.76 -plan misses target center by 99.00ft at 15364.10ft MD(12762.85 TVD,-1742.25 N,7910.56 E) RU-1A BHL Tgt Ver6 0.00 12,775.00 -1,740.32 7,916.53 2,448,000.15 208,500.30 -plan hits target center -Circle(radius 150.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 7,000.19 6,000.00 Case4 9-5/8 12-1/4 200.00 200.00 Case2 36 36 15,377.77 12,775.00 5 1/2" 5-1/2 6-3/4 1,800.00 1,773.95 Case3 13-3/8 17-1/2 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 12,500.00 10,434.99 -1,650.99 6,279.96 Start Dir 13°/100':12500'MD,10434.99'TVD:20°LT TF 12,520.00 10,450.46 -1,653.64 6,292.35 End Dir : 12520'MD,10450.46'TVD 13,300.00 11,043.15 -1,754.02 6,789.39 Start Dir 1°/100':13300'MD,11043.15'TVD 15,377.77 12,775.00 -1,740.32 7,916.53 Total Depth:15377.77'MD,12775'TVD 6/11/2013 2:05:39PM Page 4 COMPASS 2003.16 Build 73 Cook Inlet Energy COOK INLET BASIN REDOUBT SHOAL Redoubt Unit#1 RU-1 A RU-1A Wp5.0a o'perry Drilling Services Clearance Summary Anticollision Report 11 June, 2013 Closest Approach 3D Proximity Scan on Current Survey Data(Highside Reference) Reference Design: REDOUBT SHOAL-Redoubt Unit#1-RU-1 A-RU-1A Wp5.0a Well Coordinates: 2,449,941.20 N,200,630.58 E (60°41'43.74"N,151°40'14.44"W) Datum Height: Plan:RedoubtUnit#1 @ 90.00ft(Plan:RedoubtUnit#1) Scan Range: 12,500.00 to 15,377.77 ft.Measured Depth. Scan Radius is 1,724.78 ft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Version: 2003.16 Build: 73 Scan Type: GLOBAL FILTER APPLIED:All wellpaths within 200'+1000000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services Cook Inlet Energy HALLIBURTON COOK INLET BASIN Anticollision Report for Redoubt Unit#1 - RU-1A Wp5.0a Closest Approach 3D Proximity Scan on Current Survey Data(Highside Reference) Reference Design: REDOUBT SHOAL-Redoubt Unit#1-RU-1 A-RU-1A Wp5.0a Scan Range: 12,500.00 to 15,377.77 ft.Measured Depth. Scan Radius is 1,724.78 ft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (ft) (ft) (f) (ft) ft COOK INLET BASIN REDOUBT SHOAL ST 1-REDOUBT SHOAL ST 1-F 12,905.24 1,015.28 12,905.24 195.19 11,895.74 1.238 Centre Distance Pass- REDOUBT SHOAL ST 1-REDOUBT SHOAL ST 1-F 13,075.00 1,019.67 13,075.00 189.86 12,033.77 1.229 Ellipse Separation Pass- REDOUBT SHOAL ST 1-REDOUBT SHOAL ST 1-F 13,150.00 1,024.49 13,150.00 190.28 12,093.62 1.228 Clearance Factor Pass- REDOUBT SHOAL UNIT 2-REDOUBT SHOAL UNIT 12,909.95 1,014.25 12,909.95 193.69 11,900.44 1.236 Centre Distance Pass- REDOUBT SHOAL UNIT 2-REDOUBT SHOAL UNIT 13,075.00 1,018.41 13,075.00 188.34 12,034.63 1.227 Ellipse Separation Pass- REDOUBT SHOAL UNIT 2-REDOUBT SHOAL UNIT 13,150.00 1,023.14 13,150.00 188.60 12,094.50 1.226 Clearance Factor Pass- REDOUBT SHOAL Redoubt Unit#1-RU#1-RU#1 / cAL - - Redoubt Unit#1-RU#1-RU#1 (/ - - - Redoubt Unit#6-RU#6-RU#6 12,500.00 1,364.34 12,500.00 1,194.33 12,415.76 8.025 Centre Distance Pass- Redoubt Unit#6-RU#6-RU#6 13,425.00 1,364.93 13,425.00 1,168.83 13,391.31 6.961 Ellipse Separation Pass- Redoubt Unit#6-RU#6-RU#6 13,825.00 1,388.44 13,825.00 1,185.50 13,767.10 6.842 Clearance Factor Pass- Redoubt Unit#6-RU#6 PB1-RU#6 PB1 13,441.00 1,363.74 13,441.00 1,168.00 13,431.04 6.967 Centre Distance Pass- Redoubt Unit#6-RU#6 PB1-RU#6 PB1 13,475.00 1,363.93 13,475.00 1,167.80 13,459.00 6.954 Ellipse Separation Pass- Redoubt Unit#6-RU#6 PB1-RU#6 PB1 13,625.00 1,369.07 13,625.00 1,171.39 13,591.32 6.926 Clearance Factor Pass- Redoubt Unit#7-RU#7PB1-RU#7PB1 12,500.00 1,530.43 12,500.00 1,259.11 11,348.48 5.641 Clearance Factor Pass- Survey tool grogram From To Survey/Plan Survey Tool (ft) (n) 164.76 12,500.00 MWD 12,500.00 13,350.00 RU-1A Wp5.0a MWD_InterpAzi 13,350.00 15,377.77 RU-1A Wp5.0a MWD+SAG 11 June,2013- 14:08 Page 2015 COMPASS Cook Inlet Energy HALLIBURTON COOK INLET BASIN Anticollision Report for Redoubt Unit#1 - RU-1A Wp5.0a Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor=Distance Between Profiles/(Distance Between Profiles-Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 11 June.2013- 14:08 Page 3 of 5 COMPASS • • Cook Inlet Energy HALLIBURTON COOK INLET BASIN Anticollision Report for Redoubt Unit#1 -RU-1A Wp5.0a Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to Plan RedoubtUnit#1 c t 90.00ft(Plan:RedoubtUnit#1). Northing and Easting are relative to Redoubt Unit#1. Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04. Central Meridian is-150.00°,Grid Convergence at Surface is: -1.46°. Ladder Pict LEGEND 1500— t 1E00 LAT SHOAL STI,REDOUBT SHOAL STI.REDOU 87 SHOAL t7 EDOLrT SHOALUNR 2,REDOUBT SHO ALUNR 2.REDO U8T SHOP -h- Redoub Unt M1,RUMI,RUM1V8 • ___.J. �F�edoub Unt 03,RUM3,RUO3 V8 O 1 —X— Redoub Unit#4,RUM4,RUM4 V21 Redoub Unit#4,RUN4P BI,RUN4PB1 V44 Q 1000— Redoub Un2M4,RUM4 P132,RUM4 P82 V17 O Redoub Unt 04,RUN4A,RUN4AV8 In Q) $ Redoub Unt06,RU5B,RU-513 WP02\A -�-- Redoub Unit5,RUN5,RUM5 V15 Q7 Redoub UniNS,RUMS A,RUM5 AV4 O 500 $- Redoub Uni N6,RUM8,RUN°V20 _e_- Redoub Unt88,RUMS PB1,RUNG PB1 V19 —9— Redoub Unt M7,RUM7P8I,RUM7PB1 V23 Q) J -Jet.�R edoub Unt2,Red ou bt Unit2,Redoubt Unit2 V! U -0- Redoub Unt2,Redoubt Unit2A,Redoubt Unit2AW $• R U01,i yrofte led lit,Gyro/fele drift V7 0 - - Q-e U-IAWP5.0a 0 3000 6000 9000 12000 15000 Measured Depth(3000 ftlin) //June,2013- 14:08 Page 4 075 COMPASS • Cook Inlet Energy HALLIBURTON COOK INLET BASIN Anticollision Report for Redoubt Unit#1 - RU-1A Wp5.Oa Clearance Factor Plot: Measured Depth versus Separation(Clearance)Factor L E G E N D• 875—- ...-..__ ._ _ (1 R D.UBT SHOAL ST 1,REDOUBT SHOAL ST 1,RE000BT SHOAL ST 750J___ : D.UBT SHOAL UNIT 2,REDOUBT SH OAL UNIT 2,REOOUBT SHOAL S - ■.■ I I -,R d.ubt Unita 1,RUN I,RUN1 VB o _ ;2.:;o41"i R d.ubt UnitN 3,RUN3,RUN3'..8 off— _ r, R d.ubtUntB4,R UN4,RUN4V21 R d.ubt Unt N4,RUN4 PBI,RUN4PB1 W4 05 - - R d.ubt Unt#4,RUN4PB2,R U04 B2 V17 U- _ c SAD -- R d.ubtUnitB4,RUN4A RUN4AMS 0 - - R d ubt Unit#S,RU SB,RU-5B WPB2 W 05 - Red.ubtUnitt15.RUN5,RUN5 VI5 a - Oj 3.75--- )( --Red.ubtUnt/15,RUNSA,RUNSAW 1 - Red.ubt Uni[N6,RUN6,RUNB V20 _ JJ Red.ubtUntB6,RUN6 P BI,RUNG P B1 V19 =3)— - -'- ------------------'---------- � .yew daw-- ubt UnitB7,RUN7PBI,RUN7P B1 V23 _ .St') �ltiF-CA d ubt Unit 2,Redoubt Unt 2,Redoubt Unit2 V7 -- Cbp01110tF--1D d ubtUnit2,Redou bt Unit 2ARedoubt Un62AVD 1 —. - - I"°•'�+'•'` _ -I 11,G}roAekdliR,Gylo/rekdriR V7 I - -AWp5 Da 0.60 r , 11 0 I^ D 3750 500 0.13 79:0 8750 10000 oI 100 13750 15000 Measured Depth(2500 tAn) 11 June,2013- 14:08 Page 5 of 5 COMPASS P/Q3 ,rr_std //1/1-5 / . % —,-: g 1 1 III 111P I -0. pg;!P II // gib. g Mil . -' HR511 - , ; rx I Igt GI Q. L- ' ec _ _—-K 11_ , fi -..,... g , , _-w r fRC-1P r - FIPM1:1; II i 12 ,., , ,ii ,,,,____;_,, AE3f- l'El - --;_.' -- 1 iC a 1 1 ./ ! — P gli 1 s; 7P R147,- 1 lkil i 1 Ilii z D' g o -- 8 1 /01 -' C x ARki : .; t5111 LNRI _ p: ' — -.. - :11 -- 4C *- glig l'404 ' ., . :4. I- IC''' cc, 8 '•-• _ ii, t'''''4 S '' -8 7P ftzlicc3 — _ _17_0 circt c,cc _ _ --P ct p. - 1.4 2 ILtsR1 A to g _ 1 a g _L-I 0 Lc = 2 , a i _ s , - I s A, _ cz N .. , 1 i i ". II ' L.19q ,-1 0 8 `., , C5* I LLI r4 ' ■1I EC t A \ , 1,k _.., . . ct _ = 3 0 % — CD P1 = -L X -. ,ft. -•iI I 8 - 4...•U _ /-J —8 ' ..I ,.. CDt 11I1141111111111111111111 11111111 i 11/1111I. , .. i. . .. 10. . .. 1. . .. 1. 61 Of to f si INA, V It, e ' •1■1 a A, = I LO --- Meld OW(+1,1W4O'llTk'S ?) ii Sy,a, (eIII)►3 ii , ?? 1 h / 1§§ in a g22 0 pi��,.., �Lt i raw ' 4,2 n i. F' c �$88S ", ? I 1 '' / 8. 0 x g 3d � d XF r —ry 6 °A° mo �� , ss � 4^$ - Q ' ARV!" 2 F EFI F rcarc aa'�N _o Z k ■11;1 W'o"t �$$r °�u'"i,� il —. il ad Fj OQsM � S i - N r'r s� o In - q� 266�Sgry v C [; WI - T a gg ,I-ryn.r yy 'N._ it, _n N h' �r n 1 ■ _ Ir . 11 i1 Q F` -J 111 CO It n , I-- •- yl o ar 3 - c S_ 4-• g VI fii U CC CC Cr % 1$ a / ::i g' 4 r It CZ 0 h - , P _ rp Z • -g 0 W _ S _a 3 G c dl /. "1..f. - Q J C �QQZ _ IW I I I I 1 I I I I I I I I I 1 1 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 I I I I I I I I I I I I I I I I I I I I 1 I C G 1yO� 1po O O O G O O G G r�gr an PI a. O m Rr O reJ G O 47y E M M V (Will 0661 uaerT xudn 1'J /214,3 / / HaXiburton Company /-1ALLIBURTON S ndard Proposal Report Database: Sperry 16 PROD Local Co-ordinate Reference: Wei Redoubt Unit#1 Company: Cook inlet Energy TVD Reference: Plan RedeitibtUnral 0 80.00ft(Plan RedcuititU Project COOK INLET BASIN MD Reference: Plan RedoubtUnit#1 0.0011:Plan RedceitAU Site: Redoubt North Reference: Grid Well: Redoubt Unit#1 Survey Calculation Olean& Minimum Curwatare Welibore: RU-1 St Design: RU-1A Wp4.0 Project COOK NLET BASIN Map System US State Plane 1827.'Exact solution; System Datum: Mean Sea Leve Geo Datum: NAD 1827(NADCON'CON'US: Using Well Reference Point Map Zone: Atka Zone 04 -"- Site Re.-,..,o.,Pi Site Position: Northing: 2.410.990 00'1 Latitude: 60.5;6618 From: Man Basting: 21:0.527.00/ Longitude: •151 570705 Position Uncertainty: 0 00 ft Slot Radius: 0 Grid Convervence: Well Redoubt Unrt#1 Well Position 4141-S 0 00 ft North ing- 2 440.941.2:At Latitude: 60 685485: +EI-414 000 ft Eas•ting 200.531:158 ft Longitude: -151 573578 Position Uncertainty 0,00 ft Wellhead Elevation: ft Water Depth 40.00 ft Wellbone RU--' St I / I , Magnetics Model Name Sample Dab/ Declination Dip Angle RAI Iftienidh II I fa) BGG4C012 4.. 22012 17 ' 73.57 56,422 Design RU-14 Wo4.0 Audit Notes: Version: Phase: pi.,,, -e 0- ElsDr.r •:,....,X 00 Vertical Section: Depth From rnm) +N'-S +-Ei-W Direction tft) llve) IfT1 In 120 00 000 2,00 10f 47 -7- Plan Sections Measured / Vertical WO Dogleg Build Turn Depth Inclination Azimulle Depth System +W-S +61-W Rate Rate Rate Tool Face rin n r (ft) ft PI Ift1 rileOfti (*MOON r/1001t) fl / , •2.5111.00 38.10 104.24 10434- 10.344 gg -1.810.13 5.235 85 :.0( ::0 a Do Dm 1E520.00 40 55 102 87 10 450 46 10.393.44 -1,013.10 5 248 27 '2 00 12 25 -694 -20 DO 14.121.00 .L055 102.87 11 66623 11.511623 -244417 7:52:7 200 0 2,0 0 00 ox 15.456 21 27 17 102.87 12,775.00 12.885-50 -2.210.132 7$8743 ' 00 -. DO 0 DO -1 90.07J , , / / St,t„,„,,„,j`J c/ii)Q0i3 Halliburton mpany HALLIBURTON Standard Pro sal Report Database: Sperry 16 PROD Local Co-ordinate Reference: Wei Redoubt Unit#1 Company: Cook Inlet Energy TVD(deference: Ran RedoubtUnl#1 C64 9 .00R(Ran:RedoubtU'; Protect COOK INLET BASIN MD Reference: Plan RedoubtUnt#1 @ 9I13.00ft(Plan RedoubtU Site: Redoubt North Reference: rind Well: Redoubt Unit#1 Survey Calculation Method: Mnrnum Curvature Weltbare: RU-1 St Design: RU-1A Wp40 / Planned Surrey / Measured Vertical Map Map Depth inclination Azimuth Depth TVDss +Nl-S +f1-W Northing Easting D1S Vert Section Ift1 CI n tftI ft Itt) It►) Ift) Oft) 10,344.99 82.500 00 38.10 1134 24 10,434 99 10 344 P9 -1,810 13 6235.95 2,448 131 07 206,886 53 0.00 8.492,55 Start Dir 137100':12500'MD,10434..991VD:20°LT TF 12,520.00 40.55 102 87 10,450 48 10 30046 -1 813 10 5,248.27 2.448 128_10 206,878 85 13.00 6.505.51 End De :12520'MD,10450.46"TVD 12,600.00 40.55 102 87 10,511.25 10 42125 -1 824 69 6,296.97 2,44811051 206,929 55 000 6.557.47 12,700 00 40.55 102.87 10,587.23 10 49724 -1,839 17 5.302 35 2,448.107'133 205,992 93 0.00 6,02241 12,800.00 40.55 102.87 10,06322 10 57322 -1133 66 6,425 72 2,448.08754 207,056 30 000 6 687.35 12,9370.00 40.55 102 67 10,739.21 80 64921 -1.808 15 5,488 D9 2,448,07305 207,119 67 0.00 6 75229 13,000 00 40.55 102 87 10,815 19 10 725 19 -1 682 63 6,552 47 2,448 05857 207 183 05 0.00 8 817.24 13,100 00 40.55 102 87 10,891 18 10 801.18 -1,887 12 6.615 84 .844.08 207.246 42 0.00 8 682.15 •3,200 00 40.55 102 87 10,967 16 10 677.10 -1,9l l 60 6,67922 4410.02000 207.309 80 0.00 6.947.12 '5,300 DD 40.55 10287 11043 15 10 953.15 -1,926.DA 5,742.59 z448 015 11 207,373 17 0.00 7,012.05 13,47200 40.55 102.87 11,11013 11 02913 -8,940 57 6,89607 2448,000 83 207 136 55 0.00 7,077.01 13,50:100 40.55 10287 11,198 12 11 10512 -1,965 06 5,869 2447,900.14 207,498 92 0.00 7 141.95 13,000 00 41.55 102 87 11271 11 11 181.11 -1.868 54 6.932. 244707106 207,563 30 0.00 7 206.9 13,700.00 40.55 102.87 11.347.09 11 25709 -'284 03 6,808.09 2447,967.17 207026 67 0.00 7271 33 13,E+0:.00 40.55 102.87 11,423.08 11 33308 4,998 51 7,059.47 2.447.042 09 207.6990 06 000 7 338.73 13,''.32 00 40.55 102.87 11,409 08 11 409 06 -2013 00 7,122.84 2447978211 207,753.42 0.00 7 401.72 14,032 00 41.55 102 87 11,575 055 11 48305 -2,027�,18e22 2447013 71 207,816 80 000 7 458.08 14,100.00 41.55 102.87 11,851.03 11 56103 -2,441.07 7.2.50 2447009.23 207.880 17 0.00 7 531 02 14,120.00 40.55 102 87 11,6662' 11,57623 -2944 794227 2.447.00033 207 892 85 0.00 7 544 55 Start Dr 11100':14120'MD,1160023'WD 14,202.00 39 75 102 87 ",727 38 11,6377 38 2055 3e 7,31255 2,447,884 84 227,943 13 1.00 7 596'2 14,302.00 38.75 102.87 11.804 82 11,714 82 45 7,37423 2,447,870 74 205,004 81 1.00 7 65932 14,444.00 3775 102-87 11,883.35 11,7935 25 7.43458 2,4475556 95 2.5066 16 1.00 7,721 10 14,50100 3675 10287 11,062.95 11,87.2.05 -209774 7,493.58 2,447,84346 205.12416 1.00 7-78163 14,800.00 35 75 102 877 12,043.60 11,953 -211091 +,55122 2,447.830 29 275,18.80 1.00 7 840 70 14,703.00 3475 102 87 12,12525 12,035 2,12377 7,60748 2,447.81743 205,235.06 1.00 7.898 35 14,533.00 3375 102117 12,207.92 12,1 .92 2,13031 7,662 35 2447,804 89 205,292.93 1.00 7 854 57 14,993.00 32 75 102 87 52,291.55 12 201 55 2,148.53 7,715.79 2.447,792 67 205,346 37 1.10 8 009 34 15,000.00 31 75 102.67 '2,376 13 12.288 13 2.160 42 7.76;.81 2,447,780 76 203,385.38 1.00 8 062 64 15,100.00 3075 102 87 '2.46'62 12.371 62 2,171 98 7,815.38 2,447,76922 205445.96 1.0e7 8 11446 15,200.00 29 75 102.87 '2,543.00 12,458 00 -2,183.20 7.887.49 2,447.758 00 215,493.07 1.00 8 164 79 15,300.112 28 75 102.87 '2.63525 12,54825 2194 D9 7,915 12 2,447,747 11 205,545.70 1.00 8.213 60 15,400.02 2775 102.67 *2723.34 12,633.34 -2,204 64 7,96'.26 2,447,730.58 205,59.84 1.00 8260 88 15 458.21 27-17 102.87 '277500 12.683 013 2710 62 7,987.43 21147.730.58 205,615 01 1.40 8.287 69 Total Depth:1545022 MD,12775'TVD-RU-1A B.0.TO Rev 5 15,45821 27.17 102 87 '2,77500 12,685 013 2 210 52 7,987.43 2,447.730.50 208,615.01 530,329.84 8.287.02 / -Su1kA4tAlcO Halli urton Company HALLIBURTON Stapdard Proposal Report 6aballeace: Sperry 16 PROD Local Co-ordinate Reference: Wei Redoubt Unit#1 Deopenfir Cook Inlet Energy TVD Reference: Plan RedoubtUni#1 la 90.00ft(Plan:RedoubtU Project COOK INLET BASIN MD Reference Plan RecioubtUnT#1 i 90.00R(Plan:Reck luibtU Site: Redoubt North Reference: Grid Well: Redoubt Unit#1 Survey Calculation Method: Mnenurn Curvature We!bore: RU-1 St De ' ; RU-1A Wp4.0 ".',4111111•MINIIIIIIIIIIIIN■IMM`- - I T argets I Target Name = -hithriss target Dip Angle Dip Dir TVD t-NJ-S t-E-W Northing Eating 1 -Shape r) r) (ftl ift) Ifil (61 ffrl RI..IA..:,..IL eg Rev 5 3".0.0: 12 775 1:10 -2:"D 62 7 g27 43 244773C88 239,619.01 1 -plan titt Mt-get calm -Circle 1.--°'us 15a" , I Ileasured Vertical / Casing Ikle Depth Depth , Diameter Clammier MI fit) Name ' n (1 1 800.02 1,773.85 Case3 13-3:9 17-1:2 ¶5458.22 12,775 00 7-5E' 7-5.8 8-1,2 200.0: 23100 Case2 36 36 7 DD0.'''9 6,01 00 Cased. 14-5.8 12-1A ---r- Flaw Pextritagews : Illeaused *rival Loud Coortinates / Depth Dip& ',US +EJ-W 111) CR) lig (g) / Comment 12,53:4 00 10 434.9P -1,8'0.1) 6 235 95 Start Der 13•,,100:12500'W.),1043A PO-fVD.20.LT TF 12,5Z.100 10 450.45 -1,8'310 6 24817 End Dr :1M2Cr MD.10450 44 WC 14,tM 00 11 000.23 -2,044.87 7 28217 Stan Dr 1'7100':14120"MD,116e6 23-ND '15,458.21 12774.' -2,210.82 7 P97 42 Total'Depth'154SIL='1,40,12775'I'M 3,15,,x4,j,46 c,/it) I / 1 16 /f a E / W P: E w °o $ U d r a r , A.6 f° i'' Z.1 0- 0_ 0- 0_ 0_ 0. D_ 0_ 0. 0. 0_ 0_ a. E 2 a 2 aLL1 1 n m c A' n t a th rt v WU h OwC33 ow ° owOo .S Q ` G G m m m m V W LL i ) Y. gi mp 888 •F ® 8. 8. EV p t 2 r..!. v A A h M �M Q = m o ..o ill `-c4 rV- .-- Nv r y O .A- q't .. g $ Lti- H v a g8ut'S $ i ',1 .7; . ggg E ,.,{7 § n r n $ ;5� r Q C et ? a 5 o d o rt 4a eCS �5 3 Q fi el ri CI 0i eii .n .r 7-1. of cci of C4 p W ; ; P ; Hi N Q rLe� u i d N W f cir+y�l r •a. n ? g O O O O O 4 n 1 fn L'' Sc''. Z 2 "iSE P$, $, a8 $ n8Ei $ it p� IOIbD_IL) qq � f ca kk C x a 3: y Q ri o'i ei!,i iii ci ^ ' T rii ri ^ e4 re cr y 0 c 0 h i 1 K I- r I ° D O O 2 A ala $gw. m I c3, cc c'3c �" E, xxxx `n Lr co6Le) I- I- 1- mmm - 1Gp cu z mmm a a a m a Z ci,9 mam a w "08 CI CI CI g g a � ' 4"40'h �, , , , r. a a a Ti Q1 I— §-Q o� �+� a � � � -J ' gg ggN fl m ‹ J .11; 1 E ? '- - - >- 3 5 5 5 » » 4 a A Y Sm $ $l IS 23223 3233 g g g g g a n ` 4 $ $ $ $ $ $ $ 2 $ I U0! NN ill Sly41111 cJit)i3 a 1 6 ce gw g 25 R 1 0 0 Orl-T o, Q 0, a O pot fagot C � � p YS Q �C o a b C) 4 ccaP„ j ,/////3 g 1 t ' i m i w o m o IJJ r 0 R" 7 '� c 9 9 �°3 _ a R. 8 Q Z fA If o J.. _.- y W m r SR > 5 lj w m m a o m - C W m o c `' 1. 3 , a to 5 an d a CC Q a. w ea iIt CC .. .' a_ a 6 K , 1 W n i 7 D N b a a CC t > > cc a 2 a a arc a- a. ce a a cc z Q a Ni w e a 7' ,m 10 .� ro i 1 w 0, C C + u j t t .c � z q a a CC CC EL a a a' oac R R is = c = = R a M 4t 4 t a R rata i K a it a a 7 .- 7777777 7777 = 77P% a. 5 .., .c. a a 4 n . a a . a .0 b O 0 �0�y. O O 4 O O O d D G O 9 C O lyl S 9 C 9 S O '�1 9 E 9 O 9 9 to . o W u.• l' u a o u d -a r Cr o a m V a =C a re rr el' Cr rr rY n- o- .Ic rr r r n Cr* r rr CC C ii 4 4 *+ ff4 ., ,� f + � * i + 8 1 1 I 1 I I I 1 I O I I v O I 1 I :. 1 I I ;. r 01 1 '1 4 I C ,� sl /I 4, ' E i 1 CD II I 1 O Ni j_ �, I I O a. E m 1 1 a I-z 1 1 1 1 1 [} 4t CZ MI 1 0 ! I w ID 1 O as .0 .c o I O �, 1 1 I r , ____ _ - - -- ,-- --- ------ --- - I .Q laa O 1 J z °- 1 I ■ O 1 co . 1 1 c *� I I O O Q O J us O 1 0 o In (uiluno } uageaedeg eaaueD oleiaueo I Q > I.) (i fkis 515 0l'13 it 1 '..= g a r i 1.-' .. 0 G. m 8 W a s a Cl IM Ill I- m � n 0- m E -1 py CD d C q¢- 4 d g .Cy , 5/C,;� (ems. J Q O 4 c 7 S S > > v m 5 w 7 $ m is 2 Let d d x i : w. s j n ." _ 1 s cc. 6'g Da n ra c' 7 7 7 m tym ¢ ¢ a, _. m ,_ S ' = a - a d d s q, re n m tCY n ,; ti .7 V Q m aCY ,6 O aO M1 D 4. a 4 n a s a l ac ac a a K a a C aO M L4 N g i } t F i g K qip AI = a = .w z c r — c t c = = Q CD 0 ' •'__�E�;� ■nwa■ix iii _ii,....r ,1111 - - _,��n� �! 1101111 1� 11♦ii1111 11 1• - 11M11111/1011/1� W 1111... rsitam o • � , •••■••■■■.■ . ■ ■■■ �■ ■ @ • ••.••■•a•• . .•• • MI�..■gi.-_ • , ...••■.■■..■�■ •• . .■ �■ • • �■�■■■■■■■C •■■■■■.•■•�■ ■. - mm.�....,... .........m .... 1 .. ..■■..■ 1111■■ ■■■■.■�■ 1111 _._ c) 8 ■:011111111 11111111111111u11 __ .1111■_■■ ■C 1111■1NIMMOInal" .�.■■. ..�. 1111.. 1111 v �■ ■ ■�■ ... a �C 1111111 ■C■■■ i 111 I. 2 , ME.•■■■■■■! �� 1111 �� - o 1 . si 1i 1i1 11i Ie eII♦I i u ■ _. .■ ■ . ■ ■. _ - 1 , s It ANNE NI■ 111 ili i1emi11 -- a .,..... .� 1111 .. 1111111111111111-: .11.2.C. 1■.S■■1 .••• Iloilo IS g ■ME1.C..=■■ ■■■�.■■ ..0 ■■111 �■■■■ _ 0 ■� ■■.■■■�.�■....1111■11.11 �.... � .■■. .......••�.■..■■..■..•••.•■. __ 1UI•1 IIe11111:1:�11=IIIIU HI1=U1 :1 w■••■∎.■.......■r.r■■�■■��•.��. .. _ 63 2 uI IO1111i11111■OI♦III111i111O1�♦1 e1 ieiuiiiiiii001iiliiili _'iilii 0 .�■.■.■�■■■■■■■..�■■■■■...■ _ N ■..■..■..■.■■■■■■■..�■■■...... P. c I ............::::_......... - ill 3 c a :::�:i■:�:::::::ii::::::::: 1111. - m .0 101aisiuinii11iseiii11iiii ' mi _ J U . 1111.■..■..._■■■■■■■..■...■■■■■■■■.■m i11 - ■_._.e■__1111■11•__.■.■....._. Q ' 1 (u If o5'i)JCVej uoimede5 I a o BOP Sketch 7312012 5-28-12 1CoL BOP Schematic G-eir "Rig Floor" Will:RUM KB Elevation Date: 5/26/2012 L I Measure distances from"Rio Floor P n, wl it]mrtnl DOD p 51- Ilop of Annular ♦ ( , 7 Hydril ` 'Center Hydrll - 'i1 13.5/8"5k Annular L_ - � 13-ti t0k*aril - y/N I •rim ar.....aa 4-DP rmw .o......t `� Contcr 1 Rams• :—�as� _�a� 13 6'e"10k H}dnl mom '�. —! H Blind Rams '-�=. •I i I B'!h I:nnrar q IInd9 l=! aaaaaaaaal III t':2'.I.L1!' a0. to •■ 'I 11 ill I f ►:' rI III '' II: H`F -III - Kill I till ---P • r:rlt»<•1 a,. ul nRl 11136 T u I Imo' 1313-611"10k Hydrll y • e�,�1 . 4"DP rams Cents!.4"Rams • . 13 58"10 k"x 13-590'5K adaptor spool 13 E..S'5kX135f8"Sic tils_r n m n went..oo e t Ground level e -I- e 41I i rR Tel a (____ C4nterloekdoxvt Ocroena H' 1 Wellhead Schematic • Y T—iim t !mitt'3-1/ GEC K.'25C. JIM W/Pan n� LI c'L IIi. '? w!aa-1/a vox va;�w IV.tic--. R 5-1J eon vo ma ___ fir, - 152^if RAT MIGLI WPM *• -111fill`" 3-,/1I 5000 J 1645 .•. u [ I ■t ...Mr:_13•S1g EEO 66t =:..11 7 rr ;111101--:1-111 r o•Mary hht0 25136 NF1 PM ■ u•_• • -I f7 OD PM-5 3LAD ill -11_ W '"', as(■. _.I�rr r�r� rai- ..JI _.r• 'r.._ 13.6/E ma 4EAS ••, \ 1 2_i/IE Arno w■II ,_111w. 1A.'�l�,. 24,,75 1{ " i. A•=:J� 1.644` 7 =� I « ti.3.57'tt 1.. 1111 p ii i i AN ,11111' -1.4-Alir OD t42,73 a-,,er CO 7.1132• '-'`,—Ch,IE'co CASIO ALL pMQ,sons Net*PA70C —, SYSTEM EMIR/DWG V Qgra 1;i-sjP X 4-5/$ x 7-1p 11 5.11b tAS0 VULT@CAL A55Y PRODUCER WELL ■ .,i� ■ra wsavMCr w*eu tvl•MOW, -_- w.,�, I % Geo-Mechanical Plot Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (deaF'.: (de.nFldt tt) 0.0 0.0 80 0.0 90.0 90.0 80 -0.0 160.0 159.9 77 -1.8 15226.0 12345.4 190 0.9 # degF 75 100 125 150 175 200 1 .rr.. TTrubill3t Finis _ I il� ��11111 I 11111 l . �.{ IIIII __ .111 } 'uII t 11.1 , _ I ___-- 111111. Temp. Profile 1t. 119 min Casing Program Casing Program Connection API rating Mud Wt Wt# Hole size Casing sizes(in) MD(ft) TVD(ft) (lb/ft) (Ib/ft) Grade (in) Burst Collapse tension „ Type OD(in) (psi) (psi) (kips) 5 1/2" 15,458 12,775 I 9.1 17 L80 TBA 4 1/7 6 1/8 10140 10500 377 Well Information Max Pore (psi)I 5876.5 I Gas Gradient(psi/ft) 0.1 I Eqv Mud Weight(ppg) I 14 NOTE:Pore Pressure calculated based on West Forelands 1 RFT Data,.46 psi/ft Maximum Anticipated Surface Pressure setting Setting MAWP(Max Allowable Working Pressure MASP(Max Anticpated Surface Casing Size Death((lid) Depth(tvd) (psi)) Pressure( i)) 5 1/2" 15,458 12775 5000 4599 MAWP=.80(Casing Burst)or limiting wellhead pressure Maximum Allowable Surface Casing Pressure MASCP= (0.8 x Casing Burst)-(Mud wt- Backup Fluid Wt.)x.052 x TVD Backup Fluid Wt= .433/.052 = 8.3 5 1/2" MASCP= 5000 psi Note:Limited by 5000#wellhead Well Control and Casing Design Calculations Casing Size: 5 1/2" Setting Depth: 15,458 MD 12,775 TVD 1.Collapse @ (Mud weight x.052 x depth(tvd))-(gas gradient x depth tvd) = (9.5*.052*12,775)-(.01*12,775) 4767.63 psi Safety factor 2.2 • 2.Burst @ surfa Equivalent Mud Weight= 10 ppg *Note:EMW based on offset welldata with pore pressure gradients ranging from.39-.45psi/ft a.Frac Press@ shoe (Equiv Mud Weight+0.5 ppg)X.052 X Depth(tvd)-(.1 psi/ft x Depth(tvd)) b.Surface = (10+.05)*(.052*12,775)-(.1*12,775) 5697.65 psi pressure Max Pore Pressure-Gas Gradient x next Casing Depth (lesser of a or = (5876.5-.1*12,775) 4599 psi b) 4599 psi Safety factor 2.2 3.Tensile Loads no buoyancy, hung in air= (Depth(md)x Weight/Ft) a.Tension Force = (8846*17) 150382 lb Safety factor 2.5 G 13/Z013 Cook Inlet Energy HALLIBURTON RU-1A Garold Osprey Platform DRILLING FLUIDS PROGRAM Well Name: RU-1A Sidetrack Version#1.0 June 3,2013 Prepared for Courtney Rust Cook Inlet Energy Prepared by Chris Okland Technical Professional 6900 Arctic Blvd. Anchorage,AK.99518 907-275-2612 Christopher.Okland(i,Halliburton.com 1 HALLIBURTON Cook Inlet Energy RU-1A L Rro ct re P Y s Platform Program Briefing Enclosed is our recommended procedure for Drilling Fluid Services in the referenced well. The information in this proposal includes well data,calculations,material requirements,and cost estimates. This proposal is based on information from our field personnel,customer information and previous services in the area. If you require any additional information or additional designs,please feel free to contact myself or our field representatives. Prepared and Submitted by: Chris Okland Technical Professional Reviewed by: Chris Mackinnon Operations Leader Customer Approval: Operations Drilling Engineer Table of Contents 2 HALLIBURTDN Cook Inlet Energy RU-1A Elamic; Osprey Platform 1.0 Program Briefing 1.0.1 Well Data 1.0.2 Reservoir Data 1.0.3 Deviation Data 1.0.4 Potential Problems and Solutions 1.0.5 Baroid Project Support team 2.0 Well Design 2.0.1 Casing Design 2.0.2 Drilling Fluid Properties 2.0.3 Drilling Fluid Objectives 3.0 Interval Discussion Intermediate Interval 3.0.1 Intermediate Interval Depths 3.0.2 Intermediate Interval Goals 3.0.3 Primary Products 3.0.4 Mud Maintenance and Discussion Completion Interval 3.1.1 Completion Interval Depths 3.1.2 Completion Interval Goals 3.1.3 Primary Products 3.1.4 Mud Maintenance and Discussion 4.0 Well Volumes/Cost 4.0.1 Surface Interval Cost 4.0.2 Intermediate Interval Cost 4.0.3 Total Well Cost 5.0 Appendixes 5.0.1 DFG Hydraulics With more well information these can be provided. 5.0.2 LCM Decision Tree 3 HALLIBURTON Cook Inlet Energy RU-1A Garold Osprey Platform 1.0 Program Briefing Move rig over well.Function test all spill containment with fresh water(this well will be using oil based mud). Flood drill floor checking for leaks. Open well and check for flow. Note: bullheading will be ineffective with an LLC in the hole. If well is dead,install BPV, N/D tree,N/U BOPE with 2 7/8" x 5"VBR. Test BOPE to 5,000 psi on both 3 1/2"and 4". Pull BPV. Rig up REDA and control line spoolers. M/U landing joint to tubing hanger,back out lock-down screws and pull hanger to drill floor. Check for flow. Ensure the well is dead and POH with the tubing(current install shows 224 joints 3 /" P-110 and 173 joints 3 '/2"L-80 (see attached current completion detail), checking for NORM while POH. L/D tubing,cable, and completion jewelry and send to shore. MU 8 1/2" mill and 9 5/8" Scrapper. RIH picking up 4" drill pipe to top of 7 5/8" liner @ 6702'MD. Circulate well clean. POH. R/U Halliburton and run CAST-M sonic casing inspection log in 9 5/8" casing to surface.Run Cast M cement bond tool in 7 5/8" from 12,844'to 12,000'. Check 7 5/8" casing for good cement around window area at 12,500'. MU a 7 5/8"test tool,RIH and set it at 12,600'. Pressure test the 7 5/8"and 9 5/8"casing to 1500 psi for 30 min(dependent on casing inspection results), record on chart. While still in position,attempt to establish injection rate down 7 5/8" casing. Max pressure is 3500 psi. Place 1000 psi on back side during injection test. Record rate and pressure. POH. The LLC may prevent pumping into perforations. AOGCC must be notified 24 hours in advance of plugging the perforations. M/U a cement retainer for 7-5/8",29.7#casing,RIH picking up remainder of 4"drill pipe and set retainer at 12,600' (-65'above top of fish at 13,465'). If injection rate was established in previous step: put 1000 psi on annulus. Establish injection into the perforations below the retainer,recording three rates and injection pressures.Un-sting from retainer. Note: Holding pressure on the annulus is a precaution. There have been problems on the Osprey with pressure going up hole behind pipe collapsing the casing. Mix and pump 50 bbls of fresh water followed by 77 bbls of cement as follows: Cement to consist of 342 sx Class G Slurry Wt. 15.8 ppg, Slurry Yield 1.15 cf/sk Displace cement to the stinger. Sting into the retainer and squeeze 74 bbls of cement below the retainer and into the perfs. Un-sting from the retainer and place the last 3 bbls of cement on top of the retainer. Pull up 2 stands and reverse out at high rate. If no injection rate is established: Unsting out of retainer. Balance 200' linear plug from top of retainer. Pick up 5 stands and reverse clean at high rate. POH.Pick up 6 3/4"mill and 6 3/4"string mill and run in hole to top of cement. Polish top of cement to correct depth for setting whipstock.Report condition of cement on morning report. Pressure test cement plug,7-5/8"liner and 9-5/8"casing to 1,500 psi for 30 minutes. This pressure test should be witnessed by AOGCC inspector. Circulate and condition fluid. POH and proceed with sidetrack procedure to drill Redoubt Unit#1A. 1.0.1 Well Data Operator Cook Inlet Energy Well No. RU-1A Field/Block Osprey Platform Location Alaska/U.S.A Well Type Sidetrack Max.Well Deviation 40 deg 4 HALLIBURTON Cook Inlet Energy RU-1A c,,,; Osprey Platform Maximum Expected Mud Density 10.7 ppg Estimated Days 30 Days Anticipated BHST at Total Depth of well 195°Fahrenheit 1.0.2 Reservoir Data Primary Target#1 Hemlock Primary Target#1 Depth 15,571' MD Estimated Mud Weight for Target#1 10.7 ppg 1.0.3 Deviation Data 1.0.4 Potential Problems and Solutions Ppg.Mud Exp. Potential Depth Mud Type weight Fracture Drilling Baroid Solutions Gradient Hazard • Maintain Baracarb/Barablok to 12,500'— Loss Loss seal off coals and to bridge 15,571 MOBM 10 7 ppg NA circulation/ formation MD Pack off 1.0.5 Baroid Project Support Team Baroid Support Team Title Name Cell Number Office Number Email address Technical Professional Chris Okland (907)315-4641 (907)275-2612 Christopher.Okland@Halliburton.com Operations Leader Chris (907)227-5045 (907)275-2617 Chri.Mackinnon@Halliburton.com Mackinnon Lead Mud Eng. Lead Mud Eng. Stock-point Manager 2.0 Well Design 2.0.1 Casing Design Hole Size Casing Fluid Tops Bottom Frac Grad Size Density 6-3/4" 5 1/2" 12,500' MD 15,571' MD 9.3-10.7 PPG N/A 5 HALL1BURTON Cook Inlet Energy RU-1A earoid Osprey Platform 2.0.2 Drilling Fluid Properties Intermediate Hole MD Mud PV VP HTHP WPS Weight 12,500 to 9.3- 50-80 270 8-15 18-25 <6 15,571' 10.7 300K An 75/25 OWR, MOBM mud will be used in this section. This MOBM will reconditioned mud from another job,make sure to pilot test any changes made to condition this mud. The weight will be increased to 9.3prior to millin casin.and could go up to a 10.7 ppg by TD. Baracarb and barite will be used for the initial weight up. The WPS will begin at 240K --and—FIJI-117e raised to 300K. Bridging agents/asphaltines will be maintained to help stabilize the coals. 2.0.3 Drilling Fluid Objectives • Maintain product concentrations below the maximum allowable concentration of any product • Monitor all drilling fluids/cuttings discharges • Zero fluid related HSE incidents • Achieve wellbore stability • Achieve good hole cleaning considering hole angle, geometry and anticipated ROP rates • Lost circulation mitigation/control • Achieve good Zonal Isolation as per plan • Achieve minimal formation damage • Minimize fluids related NPT • Optimize LCM particulate to strengthen coal seams Critical Fluid Issues: • Eliminate/control losses in the under pressured zones. • Maintain a low ECD in the production zone to reduce risk of lost returns. • Maintain a stable wellbore through coal seams by reducing ECD's, surge, and swab. • Reduce drilling wastes with the inhibited drilling fluid system. • Follow NPDES regulations 6 HALLIBURTON Cook Inlet Energy RU-1A earosd Osprey Platform Intermediate Interval 3.0.1 Intermediate Interval Depths: 12,500'—15,571' MD 3.0.2 Intermediate Interval Goals • Well Control • Provide Borehole Stability • Prevent balling on drilling assembly • Efficient hole cleaning • Prevent differentially stuck pipe 3.0.3 Primary Products PRODUCTS Product Description Product Function LVT 200 Mineral Oil Base Oil INVERMUL NT Tall Oil and Polyaminated Fatty Acid Emulsifier EZ MUL NT Polyaminated Fatty Acid Emulsifier GELTONE V Organophilic Clay Viscosifier Lime Calcium Hydroxide Alkalinity DURATONE HT Organophilic Lignite Filtrate Control BARABLOK Powdered Hydrocarbon Resin Filtrate Control Calcium Chloride Calcium Chloride Salinity BAROID 41 Ground Barium Sulfate Weight Material STEELSEAL Resilient Graphite LCM BARACARB 5 Ground marble LCM/Bridging agent 3.0.4 Mud Maintenance and Discussion Mud Type: 9.3-10.7 ppg MOBM MD Mud Funnel Plastic Yield OWR ES HTHP WPS LGS Weight Viscosity Viscosity Point (a;200deg 270- 12,500 to 9.3-10.7 50-80 20-35 18-25 75/25 400-800 <6 6.0 15,571' 300K 7 HALLIBURTON Cook Inlet Energy RU-1A Osprey Platform System Formulation: LVT 200 - 0.662 bbl/bbl Water - 0.172 bbl/bbl INVERMUL NT - 4 ppb EZ MUL NT - 4 ppb GELTONE V - 6-10 ppb Lime - 7 ppb DURATONE HT - 2 ppb Calcium chloride - 21 ppb Baracarb 5 - 40 ppb BAROID 41 - to a 9.3 ppg(+/-100ppb) BARABLOK - 2 ppb Special Mixing Instructions: • Mix in order as listed Intermediate Interval (6-3/4" hole, 5 1/2" liner to 15,571' MD) Mud Type: ENVIROMUL 1.Mud weight: Maintain the density at 9.3 ppg. Increase weight as needed up to a 10.7. Maximize solids control at all times to minimize low-gravity solids buildup. 2.Rheology: Maintain a YP between 18 and 25. Pump high viscosity and high weight (2 ppg over)/high viscosity sweeps throughout the interval as needed gauging effectiveness and adjusting as needed, particularly prior to POH for casing. Yield point and flowrate will be the primary mechanisms for achieving hole cleaning in this vertical wellbore. 3.Other issues: The use of good drilling practices to minimize excessive swab and surge pressure should be employed to minimize the chances for losses and differential sticking. COAL DRILLING The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The hole stability risks when drilling coal seams are often high, and the fluid design and drilling operations have been optimized to combine reduced risk with reduced costs. 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 and LCM particulates to further stabilize coal seams. • Emphasize good hole cleaning through hydraulics,ROP and system rheology. In the event that sloughing coal is encountered,consider spotting a 30 ppb(15 ppb BAROTROL and 15 ppb LCM—5 ppb total of BARACARBs (5,25 and/or 50),5 ppb total of STEELSEALs(50,100,and/or 400),5 ppb BAROFIBRE 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(based on ECD values using the DFG software). 8 HALLIBURTON Cook Inlet Energy RU-1A ea! Osprey Platform Operations Summary: Approximately 1600 bbl of mud will be needed to fill the hole and pits. This is used MOBM and will need to be reconditioned,pilot test all additions prior to adding. Adjust the OWR of the MOBM to 80/20. Additional emulsifier and lime additions can be anticipated.Weight the fluid to 9.3 ppg. Prior to drilling out, displace the well to the ENVIROMUL system designated for this interval of the well. Pump the following spacers ahead of the oil mud: Spacer Formulations: • Pump 25 bbl of water or brine treated to a>40 YP with BARAZAN D+. • 25 bbl of the MOBM treated with GELTONE to a YP>40. • Follow with the ENVIROMUL mud system. Displacement procedure: • Monitor pump strokes to obtain correct displacement. • Maintain maximum pump rates. • Have the bit on bottom as the oil mud exits the bit. • Reciprocate the drill string by one joint every 15 minutes • Rotate the pipe as rapidly as allowed during the actual displacement. • Do not shut down during the displacement. • Use an E.S. meter at the flow line to determine when the fluid is water free enough to start taking the returns back into the system. An ES of 200-400 should be sufficient to indicate when displacement is complete.A retort should also be run at this time to confirm fluid quality. • Clean possum belly and any troughs which were used to transport water base fluid. Maintenance: Maintain the mud as clean as possible while drilling. Also while drilling additions of 10 ppb BARACARBs (5, 25, and/or 50) and 6 ppb total STEELSEALs (50,100, and/or 400) of these bridging agents will strengthen the "weak" zones and coal stability. 1. Additions of GELTONE V and/or RM-63 will maintain/modify the system rheology to a YP between 12 and 25 to provide effective hole cleaning while controlling ECD and surge/swab pressures. Run the rheology checks at 120°F to TD. 2. OMC 2 and OMC 42 will be available to condition(thin)the mud as required;however,caution should be used when using these oil mud thinners (particularly the OMC-2)to avoid over-thinning the system. 3. Drill this interval with a tight DURATONE HT and BARABLOK filtration mechanism(<6 cc/30 min @ 200°F). 4. The electrical stability of the mud should be run in the 400-800 volt range with 1NVERMUL and EZ MUL as the primary emulsifiers. 5. Maintain the water phase salinity in the 240,000 mg/1 range with sack calcium chloride,increasing to 270,000 then 300,000. This level of salinity will provide an effective mechanism for good wellbore stabilization. 6. The excess lime content will be maintained at a minimum of 3 ppb to provide an effective reserve alkalinity source and to improve the emulsion stability of the mud system. 7. The initial oil water ratio will be 80:20.While drilling,maintain volume with additions of LVT. 9 HALLIBURTON Cook Inlet Energy RU-1A Garold Osprey Platform 8. If weight up beyond 9.3 is required we will incorporate Barite and Baracarbs. This will help seal micro fractures and stabilize the coals. 9. String in BARACARB 5 through the hopper while any coals are being drilled. Approximately 4 sacks per hour should suffice. 10. Thin the mud system with OMC 2/42 and LVT to a—15 YP prior to POH for casing run.This will reduce the potential for losses while establishing circulation with the liner on bottom. Suggested Drilling Parameters Pump rate and drill string rotation should be optimized through the real-time use of the DFG software for the actual ROP while drilling. The table below highlights the maximum ROP recommendations above which hole cleaning will become an issue in this interval. Maximum Acceptable ROP in fph at Specified GPM and RPM GPM—* 500 600 700 60 rpm 62 82 102 80 rpm 118 144 175 100 rpm 146 173 208 Pump rate is the most critical factor in cleaning this vertical wellbore. Maximize rpms at all times. ROPs above these levels or with no rotation(sliding)or low rpm will require an increased frequency of the following remedial hole cleaning practices: • extended periods of circulation(with maximum pipe rpm,targeting> 100 rpm) • hole cleaning sweeps(change flow regime of base mud by using fibers,density or rheology for carrying capacity) • connection practices-employing extended gpm,rpm and back reaming during the connection Completion 3.1.1 Completion Interval Depths: 6612' MD-15,571' MD 3.1.2 Completion Interval Goals • Not exceeding the maximum allowable concentration of any product • Monitoring all discharges • Zero fluid related HSE incidents • Maintain an acceptable clarity of the brine • Lost circulation mitigation/control • Achieve minimal formation damage 3.1.3 Primary Products PRODUCTS Product Description Product Function ALDACIDE G Glutaraldehyde solution Microbiocide NaC1 Sodium Chloride weight 10 HALLIBURTON Cook Inlet Energy RU-1A EiRru;ci Osprey Platform System Formulation: 8.8 ppg KCL Product Concentration Water .958 bbl KCL 33.0 lb/bbl ALDACIDE G 0.25 lb/bbl 3.2.4 Discussion Completion Mud Type: 8.8 ppg NaCl brine treated w/ALDACIDE G 1.Brine weight: Maintain an 8.8 ppg NaC1 concentration A wash train will be pumped before the completion brine the consists of the following: 50 bbls Hi vis MOBM,50 bbls of LVT, 50 bbls Hi vis brine with BaraKlean followed by completion brine until clean. Completion plans have not been finalized. The above brine weight and composition will be altered as to final completion plans. Depending on length of time the brine will be in the wellbore,sweeps,corrosion inhibitors,etc may be required. 4.0.1 Interval I Volumes Interval: 12,500' — 15,571' MD 6 3/4"" Hole Section I.D. Depth BBLS Pit Volume 1000.0 9-5/8"Casing Volume 8.861 6986 512 7-5/8"Casing Volume 6.696 12500 260 Open Hole 6.75 15,571 136 Dilution 400 Total Volume 2911 **Completion plans are not finalized. II 11 HALLIBURTON Cook Inlet Energy RU-IA @ roid Osprey Platform Losses Lost Circulation Decision Tree fl MOBM Mud Systems • 4' 4' 4 Partial Seepage 20.60 bbllhr Severe Total 5.20 bbllhr Static Static 60.200 bbllhr Static >200 bbllhr Static f' Treat Active System Treat Active System + with 5 sx/hr Baracarb with 10 sx/hr Baracarb 60-150 bbl/hr Static 150-200 bbl/hr Static Drill Across Fault 5/25 50 i Drill Across Fault Drill Across Fault i + Contact the Engineer �ynami on call to determine if Losses<15 Yes Dynamic 100 ppb LCMIMud Pill: Contact the Losses<15 Yes 20 ppb Baroseal f additional LCM bbllhr I I Engineer on call to bbllhr + 20 ppb Baracarb 50 treatments are to be 30 ppb Barocarb 5 determine if made or to proceed to Drill Ahead Drill Ahead 20 ppb SteelSeal additional LCM mud cap drilling No 10 ppb Baracarb 150 treatments are to p g V No be made or to Increase Treatment to 50 ppb LCMIMud Pill: proceed to mud 10 sx/hr Baracarb 5/25 Contact the cap drilling V 20 bbls Base mud Engineer on call to 10 ppb Baracarb 5 determine if 20 ppb Baracarb25 additional LCM Dynamic 20 ppb Baracarb 50 treatments are to Losses<15 Yes be made or to bbl/hr proceed to mud cap drilling Drill Ahead No v 20 ppb LCMIMud Pill: Dynamic Losses<20 Yes 20 bbls base mud bbllhr 10 ppb Baracarb 25 Drill Ahead 10 ppb Baracarb 50 No i 1)Drilling Engineer must approve any steps past PARTIAL Contact the Engineer losses. on call to determine if 2)Drill across fault or loss zone 1.5-2.0 times the length of the Dynamic throw before spotting any high stop-loss pills additional LCM 3)PBL sub should be run in BHA to spot pills if'Partial Loss'cases or Losses<15 Yes treatments are to be ) p of p bbl/hr I above are anticipated prior to drilling to allow the spotting of LCM made or to proceed to pills. mud cap dulling 4) LCM pill volume=300'-600'column based upon actual hole Drill Ahead diameter. No 5)PRIOR TO ANY LCM PILL,APPROPRIATE DISCUSSIONS AT i THE RIG MUST BE MADE TO MINIMIZE THE POTENTIAL FOR Proceed to'Partial PLUGGING THE DRILL STRING. Losses'Pill 12 sk,.ci (/3) 13 Drilling Fluid Program HALLIBURTON Cook Inlet Energy RU-1A Baroid Osprey Platform a. tea; Maximum Expected Mud Density 10.7 ppg Estimated Days 30 Days Anticipated BHST at Total Depth of well 195'Fahrenheit 1.0.2 Reservoir Data Primary Target#1 Hemlock Primary Target#1 Depth 15,571' MD Estimated Mud Weight for Target#1 10.7 ppg 1.0.3 Deviation Data 1.0.4 Potential Problems and Solutions Exp. Potential Depth Mud Type PWag htd Fracture Drilling Baroid Solutions Gradient Hazard • Maintain Baracarb/Barablok to 12,500'— Loss Loss seal off coals and to bridge 15,571 MOBM 10.7 pp NA circulation! formation MD Pack off 1.0.5 Baroid Project Support Team Baroid Support Team Title Name Cell Number Office Number Email address Technical Professional Chris Okland (907)3154641 (907)275-2612 Christopher.Okland1,Halliburton.com Operations Leader Chris (907)227-5045 (907)275-2617 Chri.Mackinnon @Halliburton.com Mackinnon Lead Mud Eng. Lead Mud Eng. Stock-point Manager 2.0 Well Desien 2.0.1 Casing Desimn Hole Size Casing Tops Bottom Uetmsity Frac Grad 6-314" 5112" 12,900' MD 15,571' MD 9.3-10.7PPG N/A 5 HAL.L.IBURTON Cook Inlet Energy RU-1A Barad Osprey Platform 2112 Drilling Fluid Properties Intermediate Hole MD Mud PV YP HTHP WPS Weight 12,500 to 9.3- 50-60 8_15 18-25 <6 270 15,571' 10.7 300K An 75/25 OWR,MOBM mud will be used in this section.This MOBM will reconditioned mud from another job,make sure to pilot test any changes made to condition this mud. The weight will be increased to 9.3 prior to milling casing and could go up to a 10.7 ppg by TD. Baracarb and barite will be used for the initial weight up.The WPS will begin at 240K and then be raised to 300K. Bridging agentslasphaltines will be maintained to help stabilize the coals. 2.0.3 DrillingFluid Objectives • Maintain product concentrations belowthe maximum allowable concentration of any product • Monitor all drilling fluids/cuttings discharges • Zero fluid related HSE incidents • Achieve wellbore stability • Achieve good hole cleaning considering hole angle,geometry and anticipated ROP rates • Lost circulation mitigation/control • Achieve good Zonal Isolation as per plan • Achieve minimal formation damage • Minimize fluids related NPT • Optimize LCM particulate to strengthen coal seams Critical Fluid Issues: • Eliminate/control losses in the under pressured zones. • Maintain a low ECD in the production zone to reduce risk of lost returns. • Maintain a stable wellbore through coal seams by reducing ECD's,surge,and swab. • Reduce drilling wastes with the inhibited drilling fluid system. • Follow NPDES regulations 6 HALLIBURTON Cook Inlet Energy RU-1A Baroid Osprey Platform Intermediate Interval 3.0.1 Intermediate Interval Depths 12500'—15571' MD 3.0.2 Intermediate Interval Goals • Well Control • Provide Borehole Stability • Prevent balling on drilling assembly • Efficient hole cleaning • Prevent differentially stuck pipe 3.0.3 Primary Products PRODUCTS Product Description Product.Function LVT 200 Mineral Oil Base Oil INVERMUL NT Tall Oil and Polyaminated Fatty Acid Emulsifier EZ MUL NT Polyaminated Fatty Acid Emulsifier GELTONE V Organophilic Clay Viscosifier Lime Calcium Hydroxide Alkalinity DURATONE HT Organophilic Lignite Filtrate Control BARABLOK Powdered Hydrocarbon Resin Filtrate Control Calcium Chloride Calcium Chloride Salinity BAROID 41 Ground Barium Sulfate Weight Material STEELSEAL Resilient Graphite LCM BARACARB 5 Ground marble LCM/Bridging agent 3.0.4 Mud Maintenance an d Discussion Mud Tyne:93-10.7 ppg MOBM Mnd Funnel Plastic Yield BTHP Wps LGS MD Waght Viscosity Viscosity Point �VR ES; @20Udeg % 2IU- 11555�1to 9.3-10.7 50-80 20-35 18-25 75/25 400-800 <6 300K `6.0 7 HALLIBURTON Cook Inlet Energy RU-1A Barak/ Osprey Platform System Formulation: LVT 200 - 0.662 bbl/bbl Water - 0.172 bbl/bbl INVERMUL NT - 4 ppb EZMULNT - 4ppb GELTONEV - 6-10 ppb Lime - 7 ppb DURAT ONE HT - 2 ppb Calcium chloride - 21 ppb Baracarb 5 - 40 ppb BAROID 41 - to a 9.3 ppg(+/-100ppb) BARABLOK - 2 ppb Special Mixing Instructions: • Mix in order as listed Intermediate Interval (6-3/4"hole. 5 112"liner to 15,571'MD) Mud Tvoe: ENVIROMUL 1.Mud weight: Maintain the density at 9.3 ppg. Increase weight as needed up to a 10.7. Maximize solids control at all times to minimize low-gravity solids buildup. 2.Rheology: Maintain a YP between 18 and 25. Pump high viscosity and high weight (2 ppg over)/high viscosity sweeps throughout the interval as needed gauging effectiveness and adjusting as needed, particularly prior to POH for casing. Yield point and flowrate will be the primary mechanisms for achieving hole cleaning in this vertical wellbore. 3. Other issues: The use of good drilling practices to minimize excessive swab and surge pressure should be employed to minimize the chances for losses and differential sticking. COAL DRILLING The following lessons were learned from extensive experience drilling coal seams in Cook Inlet.The hole stability risks when drilling coal seams are often high, and the fluid design and drilling operations have been optimized to combine reduced risk with reduced costs. 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 awhipping effect which can disturb coal sections. • Use asphalt-type additives and LCM particulates to further stabilize coal seams. • Emphasize good hole cleaning through hydraulics,ROP and system rheology. In the event that sloughing coal is encountered, consider spotting a 30 ppb(15 ppb BAROTROL and 15 ppb LCM—5 ppb total of BARACARBs(5,25 and/or 50), 5 ppb total of STEELSEALs(50,1 00,and/or 400),5 ppb BAROFIBRE 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(based on ECD values using the DFG software). 8 HALLIBURTON Cook Inlet Energy RU-1A Ba-vicr Osprey Platform Operations Summary Approximately 1600 bbl of mud will be needed to fill the hole and pits. This is used MOBM and will need to be reconditioned,pilot test all additions prior to adding.Adjust the OWR of the MOBM to 80/20. Additional emulsifier and lime additions can be anticipated.Weight the fluid to 9.3 ppg. Prior to drilling out, displace the well to the ENVIROMUL system designated for this interval of the well Pump the following spacers ahead of the oil mud: Spacer Formulations: • Pump 25 bbl of water or brine treated to a>40 YP with BARAZAN D+. • 25 bbl of the MOBM treated with GELTONE to aYP>40. • Follow with the ENVIROMUL mud system. Displacement procedure: • Monitor pump strokes to obtain correct displacement. • Maintain maximum pump rates. • Have the bit on bottom as the oil mud exits the bit. • Reciprocate the drill string by one j oint every 1 5 minutes • Rotate the pipe as rapidly as allowed during the actual displacement. • Do not shut down during the displacement. • Use an E.S. meter at the flow line to determine when the fluid is water free enough to start taking the returns back into the system. An ES of 200400 should be sufficient to indicate when displacement is complete.Aretort should also be run at this time to confirm fluid quality. • Clean possumbelly and any troughs which were used to transport water base fluid. Maintenance: Maintain the mud as clean as possible while drilling. Also while drilling additions of 10 ppb BARACARBs(5, 25, and/or 50) and 6 ppb total STEELSEALs (50,100, and/or 400) of these bridging agents will strengthen the"weak"zones and coal stability. 1. Additions of GELTONE V and/or RM-63 will maintain/modify the system rheology to a YP between 12 and 25 to provide effective hole cleaning while controlling ECD and surge/swab pressures. Run the rheology checks at 12t1°F to TD. 2. OMC 2 and OMC 42 will be available to condition(thin)the mud as required;however,caution should be used when using these oil mud thinners(particularly the OMC-2)to avoid over-thinning the system. 3. Drill this interval with atight DURATONE HT and BARABLOK filtration mechanism(<6 cc/30 min @200°F). 4. The electrical stability of the mud should be run in the 400-800 volt range with INVERM UL and EZ MUL as the primary emulsifiers. 5. Maintain the water phase salinity in the 240,000 mg/1 range with sack calcium chloride,increasing to 270,000 then 300,000. This level of salinity will provide an effective mechanism for good wellbore stabilization. 6. The excess lime content will be maintained at aminimum of 3 ppb to provide an effective reserve alkalinity source and to improve the emulsion stability of the mud system. 7. The initial oil water ratio will be 80:20.While drilling,maintain volume with additions of LVT. 9 HALLIBURTON Cook Inlet Energy RU-1A Baroid Osprey Platform 8. If weight up beyond 9.3 is required we will incorporate Barite and Baracarbs. This will help seal micro fractures and stabilize the coals. 9. String in BARACARB 5 through the hopper while any coals are being drilled. Approximately 4 sacks per hour should suffice. 10. Thin the mud system with OMC 2/42 and LVT to a—15 YP pri or to POH for casing run.This will reduce the potential for losses while establishing circulation with the liner on bottom. Suggested Drilling Parameters Pump rate and drill string rotation should be optimized through the real-time use of the DFG software for the actual ROP while drilling. The table below highlights the maximum ROP recommendations above which hole cleaning will become an issue in this interval. Maximum Acceptable ROP in f hat Specified GPM and RPM GPM 500 600 700 60 rpm 62 82 102 80 rpm 118 144 175 100 rpm 146 173 208 Pump rate is the most critical factor in cleaning this vertical wellbore. Maximize rpms at all times. ROPs above these levels or with no rotation(sliding)or low rpm will require an increased frequency of the following remedial hole cleaning practices: • extended periods of circulation(with maximum pipe rpm,targeting?100 rpm) • hole cleaning sweeps(change flow regime ofbase mud by using fibers,density or theology for carrying capacity) • connection practices-employing extended gpm,rpm and back reaming during the connection Completion 3.1.1 Completion Interval Depths: 6612'MD-15.571'MD 3.1.2 Completion Interval Goals • Not exceeding the maximum allowable concentration of any product • Monitoring all discharges • Zero fluid related HSE incidents • Maintain an acceptable clarity of the brine • Lost circulation mitigation/control • Achieve minimal formation damage 3.L3 Primary Products PRODUCTS .Product Description Product Function ALDACIDE G Glutaraldehyde solution Microbioci de NaC1 Sodium Chloride weight 10 HALLIBURTON Cook Inlet Ena•ej RU-1A Baruid Osprey Platform System Formulation: 8.8 ppg KCL Product Concentration Water .958 bbl KCL 33 0 lb/bbl ALDACIDE G 0.25 lb/bbl 3.2.4 Discussion Completion Mud Type: 8.8 ppg NaC1 brine treated wl ALDACIDE G 1. Brine weight: Maintain an 8.8 ppg NaC1 concentration Awash train will be pumped before the completi on brine the consists o fthe following:50 bbls Hi vis M OEM,50 bbls of LVT,50 bbls Hi vis brine with BaraKlean followed by completion brine until clean. Completion plans have not been finalized. The above brine wei ght and composition will be altered as to final completion plans Depending on length of time the brine will be in the wellbore, sweeps,corrosion inhibitors, etc may be required. 4.0.1 Interlul I Volumes Interval: 12,500'—15,571' MD 6 314""Hole Section ID. Depth BBLS Pit Volume 1000.0 9-5/8"Casing Volume 8.861 6986 512 7-5/8"Casing Volume 6.696 12500 260 Open Hole 6.75 15,571 136 Dilution 400 Total Volume 1 2911 ""Completion plans are not finalized. 11 Cement Program Oparl ar Marne COON HLET Et*ER Y LLC *1 *.Q Na *t fteD ET t BAITER Job Description. Abar+eon Pert HUGHES Date: flay 17,21313 .y x Pff06Qeat NO: 1Gc:11EA56.16, JOB AT A GLANCE C 46109 SItiolVi.4gM !S m, £G mom 7 SAM, 23.7 twit Pillnkb YID Canna r C.D. 1-3.42r.I.D1 11.6 Trial him Wily Itigrbed 1,+37 gals Sam 01644 G 372140116 Densty 15.6 ppg Yield 1.16 chlsacit ills Operator Nark: COOK MET ENERGY LLC siLr WW1 Name: REDOUBT UNIT v1 Job D..er1p4Ms: Abandon Par% 11E5, Dale May 17.M113 Pr 5536 FLUID SPECII=IC.ATPONS PLUG VOLUME VOLUME NO CLt f T F ACTOA AMOUNT AND TYPE Of CEMENT 1 4.31 t 1.16 ■ 372 mein Cow Gt•Cement•0.D26 Imam Sc ta>I Free+0.4%bum R-+0.97E bIRIC EC-1 +0.5%M.ac FL 63+02%11■!1w CO-32+1 9misoGlsue FPS 4 434%14001 Vd*' CEMENT PNOPERTEA �L11G M0.1 Slurry Wegrt i pg i is.AO Slurry Yre+a atosar3;, 1.16 Amount or Mri WSW Oki s04 Ar'Cunt a'Mix Fhir7 time; 4,115 COMPRESSIVE STRENGTH 4$nes a tae'F Its4 x:1' eLlAraSIMIEM PLUG PLUG TOP 0OTTON 126D:1 to 1346611 !11h 6.675 man ID Casing �.�l1GMe oairrg anc rain ,are eoria :l aniV w1ll acre Eased cr,asmo .eta canSton perr3^ig laooralt+ry basg n.cos+ Page 2 r.+—ar+r 'Vw r^64 M I l0.A!' MIM'1 °pontos Now CO t l&ET ENERGY LLC re Ws*biilwM: R D�f�t T UNIT#1 ER ,wb Dosestplost ADOCINOrtiOrlitappg HLS nits' 111i10 JOB AT A GstAt1 . Devitt i 12.775 t Daph(W) 15,57111 IioN Stu, 6.75 h LinerSIz+s*esSQht 5 Mr. 17 E*W Pump Ala Poe s 0.0. Older 01 15 F Ca ing S ti' ,*OD. (4.142' .I_D 1 1 i Total Mil 1h aisr Recgutrwi 1,638 gals Wokrisea paw Soar 8<c d S pacsr t.L bb* Covisity 1! it p4' Slurry Class 0 Ti11i 133 iiai Density t6..8 ppg YFt��O t.is cr.sac"i DtIpia.c neo Dtspli.sewonit F luw 274 MS ii . ...�e Yr W.wimp maw 4111,11110684' 1/e Ga- 'r,n x er 111111WWW,b40 Kin ,rFr4- Operator Name: COOK INLET ENERGY LLC Well Name: REDOUBT win-#1 41 - . Job Description: 5 1t2' Liner I15.eppg } Dale: May 17,2013 Propoeal No: 10011605538 WELL DATA ANNULAR GEOMETRY A.NNL?LAR LO. Mf+ 0E1~T t1[iYj ESU O TRUE VERTICAL E E-35 Cl.,511I+G k 712 E,712 E E75 CASl`IG 2 12.540 E 750 HO_E ° E.?1 12,175 SUSPENDED PIPES DIAMETER [1q} WEIGHT DEFTHi Q.D. I.D. [bat) MEASURED TRUE VERTICAL E EJU 4.851 17 '8,57' 12,774. Drill,Pipe 4.8 Qin)OD, 3.24(In)M E.E 12 It 15.7 ltxeiVt[let Liner 5.5 pm)OD, 4.111321914)ID. 17 15.491 It 1108.ri ead Dilpthr lo Top or Lime( 5,512 11 FIofLen0lop Collar eet•' ,5,491 't Mu°Deretty 10.33 pp; Eet Static Temp. 195 F Eel. Circ.Tomb. 171 'F VOLUME CALCULATIONS 1,.70E r x 3.0923 cltit wi+tth 0% axone 93 cr 3,07' r x +].4838 c1?1t volt 10% excess 292 rx x 0.1305 c1?tt wrtth D% ex - 1D c?Ortslaie pipe TOTAL SLURRY VOLUME - 385 or 0i6 • 372- S1. c l 14313 7G aaLS JI.AMI-I;r r,r zae n a-w Pap 5 E*! awe mare u w bon14 YOU men era Le se Operator Nano: COOK INLET ENERGY LLC MO UMW REO0UDT LONIIT 01 BAKER JOS OMCripbon S V'2'LINN (1S.Sppg i HUGHES Dab: May 17,2D 13 Proposal No, 1 FLUID SPECIFICATIONS INehrted Spacrr IC DM Spar some spacer•75 gaN SzS-2 +2S1*WW1 Barn* •Sapcitm 13$ppc vOLUNIE VOIIJOE FLUID C1447 FACTOR ANOLINT U TYPE OF CORM +t} 3E E ; , 1€ =333 wall Class G Commrt+0.1305 itNews,=Re PRfit+D.d%Dwoc A 3+&5%NOVO EC-1 +D e% Clew FL-S3+0. tea C0,32+ t gtisitiG san FP#&4 43.6016 FMOR,WNW t 273 5 DON Dispacriont Fltict CEMENT PROPERT13 SLURRY NO 1 !"Weight Ippg: 15.6C■ sure'new tCfiiace 1 1 p Mnouort at Arco War Kos' e : Annorrrt CC Ftuid rgp61 4.S.3 COMPRES,frIVE STRENGTrs 5 ors Qt8S`Fa(; 5C 6 Rlrs et 185-F mpg Aden QM",goll 36:1 A +ot Wang Ur'r0++tiwau' 's it.OVIPPISMIC ar10 r :hang*04140 Cr,41041"al it DIMON IMoratOry twang. ple0 moo wsntomirrrat ripsom Logging Plan Open-hole Triple Combo Logging services(Gamma Ray,Neutron,Density and Resistivity) from 7 5/8" window to TD. Mud Logging Plan Mud loggers will catch 30'ditch samples and maintain a wet and dry cut. Samples to be sent to state as required by regulations. Solids Control and Equipment Item Equipment Specifications Shakers 2-4 panel (2'x4')shale shakers Desander 3 cone desander Desilter 20 cone desilter Mud Cleaner 4 panel (2'x4') mud cleaner Centrifuge Halliburton Drilling Waste Storage Drilling wastes will be either granular solids (cuttings), or liquids (drilling mud or water). Cuttings will be stored in cuttings boxes for shipment to the West MacArther grind and inject plant. Liquids will be stored in tanks and either disposed of in the Osprey disposal well or sent to the West MacArther facility. Bit Proposal Bit Summary Interval MD Size Recommended Estimated (ft) (in) Type WOB-RPM ROP ft-hr 12,500- 14,513 63/4" FX65D 20-250 50 14,513 - 15,571 63/4" FX74D 20- 250 20 r Bettis, Patricia K (DOA) From: Courtney Rust[courtney.rust @cookinlet.net] Sent: Wednesday, June 12, 2013 3:40 PM To: Bettis, Patricia K(DOA) Subject: RE: Revised Permit to Drill Application: Redoubt Unit 1A Attachments: RU1A 10-401 PTD FORM New BHL.xls Patricia, Please find a new 10-401 form attached. Here are the actual coordinates: Surface: 1918'FSL, 315'FEL,Sec. 14,T7N, R14W,SM Top of Productive 104'FSL 1765'FWL Sec 18 T7NR13W Horizon: Total 185'FSL 2340'FWL Sec 18 Depth: T7N13W From: Bettis, Patricia K (DOA) [mailto:patricia.bettisOalaska.gov] Sent: Wednesday, June 12, 2013 3:14 PM To: Courtney Rust Subject: RE: Revised Permit to Drill Application: Redoubt Unit 1A Courtney, An email would be fine. Thank you From: Courtney Rust [mailto:courtney.rust@cookinlet.net] Sent: Wednesday, June 12, 2013 3:14 PM To: Bettis, Patricia K (DOA) Subject: RE: Revised Permit to Drill Application: Redoubt Unit 1A Patricia, It appears that our Sword Well coordinates were inadvertently entered instead of Ru1A. I am reviewing the directional plan right now, would you like the information emailed or would you like a new 10-401 submitted? Thanks! From: Bettis, Patricia K(DOA) [mailto:patricia.bettisOalaska.gov] Sent: Wednesday, June 12, 2013 12:23 PM To: Courtney Rust Subject: Revised Permit to Drill Application: Redoubt Unit 1A Good afternoon Courtney, 1 On the application, Box 4a,the Top off Productive Horizon is given as 1924 FSL and 520 FEL Section 3,Township 8 North, Range 14 West; whereas,Total Depth is given as 1980 FNL and 560 FWL, Section 2,Township 7 North, Range 14 West. Would you please verify this information as Section 2 and 3 are not near the Osprey platform and it should be Township 7 North, Ranges 14W and 13 W. I also question the footage from the section lines. Thanks, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 Bettis, Patricia K (DOA) From: Bettis, Patricia K(DOA) Sent: Wednesday, June 12, 2013 12:23 PM To: 'Courtney Rust' Subject: Revised Permit to Drill Application: Redoubt Unit 1A Good afternoon Courtney, On the application, Box 4a,the Top off Productive Horizon is given as 1924 FSL and 520 FEL Section 3,Township 8 North, Range 14 West; whereas,Total Depth is given as 1980 FNL and 560 FWL, Section 2,Township 7 North, Range 14 West. Would you please verify this information as Section 2 and 3 are not near the Osprey platform and it should be Township 7 North, Ranges 14W and 13 W. I also question the footage from the section lines. Thanks, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 Bettis, Patricia K (DOA) From: Conrad Perry[conrad.perry@cookinlet.net] Sent: Friday, June 07, 2013 2:35 PM To: Bettis, Patricia K(DOA) Cc: 'David Hall'; courtney.rust @cookinlet.net; 'Greg Kirkland' Subject: RU-1A- Spacing Exception Patricia, We agree with the AOGCC that it will fall within the NW1/4 of Section 19 and are evaluating directional options to correct this. Please hold on to the PTD application until we get this resolved. Thank-you for the heads up. conrad Drilling Manager Cook Inlet Energy, LLC 601 W. 5th Avenue STE 310 Anchorage, AK 99501 (907)433-3816—Office (907)727-7404-Cell (907) 344-0584- Home (907) 260-5356-Cabin conrad.perry@cookinlet.net 1 Bettis, Patricia K (DOA) From: Bettis, Patricia K(DOA) Sent: Friday, June 07, 2013 10:21 AM To: 'Courtney Rust' Subject: Permit to Drill Application: Redoubt Unit 1A Good morning Courtney, Per 20 AAC 25.055(a)(3), in an undefined oil pool only one well may be drilled and completed within a governmental quarter section. According to AOGCC's records,the proposed Redoubt Unit 1A will be the third well completed in the NW1/4 of Section 19. So, unless AOGCC's records are wrong, a spacing exception will be required. Please advise whether this is correct and let me know if you have any questions. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 Bettis, Patricia K (DOA) From: Courtney Rust[courtney.rust @cookinlet.net] Sent: Friday, June 07, 2013 8:29 AM To: Bettis, Patricia K(DOA) Subject: Re: Permit to Drill: Redoubt Unit 1A That is correct. Apparently the latest plan does move the well into that location and we missed it. Courtney Rust On Jun 6, 2013, at 4:50 PM, "Bettis, Patricia K(DOA)" <patricia.bettis @ alaska.gov>wrote: Good afternoon Courtney, In plotting the borehole survey for the proposed well, it appears that RU 1A will TD in Section 19, Township7 North, Range 14 West, not Section 18. Would you please verify. Thanks, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis @alaska.gov. 1 ti Bettis, Patricia K (DOA) From: Conrad Perry[conrad.perry@cookinlet.net] Sent: Thursday, June 06, 2013 2:22 PM To: Bettis, Patricia K(DOA) Cc: courtney.rust@cookinlet.net Subject: RE: Redoubt Unit 1A Attachments: NAM 606 Forrest Final Report.pdf Sorry Patricia, we have been in pre-spuds the last two days. This is the fluid analysis for the original RU-1 well. It shows zero h2S. Conrad From: Bettis, Patricia K (DOA) [mailto:patricia.bettis©alaska.gov] Sent: Thursday, June 6, 2013 1:57 PM To: Conrad Perry Subject: FW: Redoubt Unit 1A Good afternoon Conrad, Could you provide the answer to this question? Thanks, Patricia From: Bettis, Patricia K (DOA) Sent: Thursday, June 06, 2013 10:41 AM To: 'Courtney Rust' Subject: Redoubt Unit 1A Good morning Courtney, The permit to drill application did not address the potential for H2S. Please advise and provide the basis, e.g.fluid sample. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis @alaska.gov. 1 111 Oilphlase Fluid Analysis on Bottomhole Samples Forest Oil Corporation, Rebout Shoal Oil Well: Rebout Unit 1 Final Report Prepared For Keneth W. Griffin Forest Oil Corporation Standard Conditions Used: Pressure: 14.696 psia Temperature: 60°F Prepared By: Nikhil Joshi Reviewed By: Joseph Thomas Oilphase Houston A Schlumberger Company 2315 Schlumberger Street, Building 15 Houston, Texas, 77023 (713) 921-9500 Date: March 2001 Report NAM 606 Client: Forest Oil Corp. Block: Redoubt Shoal Oil L . Well: Redoubt Unit 1 Sand: Oil phase Table 4: Reservoir Fluid Composition (Sample 1.03) (Sample 1.03; SSB 3131-QA; 13,600 ft MD) Components Flashed Liquid Flashed Gas Monophasic Fluid Mole % Mole % Mole% Nitrogen 0.00 6.07 2.20 Carbon Dioxide 0.00 0.04 0.02 Hydrogen Sulfide 0.00 0.00 0.00 Methane 0.01 62.27 22.56 Ethane 0.05 7.20 2.64 Propane 0.76 1 1 .37 4.60 I - Butane 0.68 3.24 1.61 N - Butane 1.56 5.20 2.88 1 - Pentane 1.41 1.58 1.47 N - Pentane 1.87 1.40 1.70 pseudo C6H 14 3.17 0.88 2.34 pseudo C7H16 5.76 0.60 3.89 pseudo C8H 18 8.00 0.14 5.15 pseudo C9H20 6.52 0.01 4.16 pseudo C10H22 5.19 0.00 3.31 pseudo Cl 1 H24 4.68 0.00 2.99 pseudo Cl2H26 4.12 0.00 2.63 pseudo C13H28 4.14 0.00 2.64 pseudo Cl4H30 3.28 0.00 2.09 pseudo C15H32 3.50 0.00 2.23 pseudo C l 6H34 2.81 1.79 pseudo C 17H36 2.26 1 .44 pseudo Cl 8H38 2.80 1.78 pseudo C 19H40 2.91 1.85 pseudo C20H42 2.37 1.51 pseudo C21 H44 1.94 1 .24 pseudo C22H46 1.82 1.16 ;pseudo C23H48 1 .32 0.84 pseudo C24H50 1.63 1.04 pseudo C25H52 1.11 0.71 pseudo C26H54 1.14 0.73 pseudo C27H56 1.1 2 0.72 pseudo C28H58 1.00 0.64 pseudo C29H60 0.98 0.63 C30+ 20.08 12.81 Total 100 100 100 MW 254.79 27.42 172.43 MW C30+ 559.98 559.98 Mole Ratio 0.6377 0.3623 8 Schlomberger PVT Report NAM 606 Bettis, Patricia K (DOA) From: Courtney Rust[courtney.rust @cookinlet.net] Sent: Monday, June 03, 2013 10:49 AM To: Bettis, Patricia K(DOA) Subject: RE: Permit to Drill Application: Redoubt Unit#1A Patricia, 5876 PSI is the maximum. From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Monday, June 03, 2013 10:31 AM To: Courtney Rust Subject: RE: Permit to Drill Application: Redoubt Unit #1A Thank you Courtney. Can you verify as to whether the maximum anticipated downhole pressure for Redoubt Unit#1A is 5738 psi or 5876 psi? Thank you, Patricia From: Courtney Rust [mailto:courtney.rust@cookinlet.net] Sent: Monday, June 03, 2013 9:38 AM To: Bettis, Patricia K (DOA) Subject: RE: Permit to Drill Application: Redoubt Unit #1A Patricia, Here is the final version of the Halliburton mud program for the RU1A well. Thanks! Courtney From: Bettis, Patricia K (DOA) [mailto:patricia.bettis©alaska.gov] Sent: Friday, May 31, 2013 2:28 PM To: courtney.rust@cookinlet.net Subject: Permit to Drill Application: Redoubt Unit #1A Good afternoon Courtney, I started the review of the application. The Drilling Fluid Program submitted as part of the application is a "Draft". Please submit via e-mail a copy of the final Halliburton Drilling Fluid Program. Also would you verify whether the maximum anticipated downhole pressure is 5738 psi or 5876 psi. Thank you, Patricia 1 w Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907)793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettisPalaska.gov. 2 TRANSMITTAL LETTER CHECKLIST WELL NAME: aFoc,,�>( Un i f IA PTD: ,2J.3 0?9 ✓ Development Service _Exploratory _Stratigraphic Test Non-Conventional FIELD: /{k.do j 1 -Shock.) POOL: /\F-c10 •SAcx1/4-1) 66cJF rh A&I tD d 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. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no Dry Ditch Sample wherersamples 0are first caught aand 10' sample intervals permafrost hough 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 Commission 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 Well Logging logs are also required for this well: Requirements ATAN.-f- IL.J s m � J36 ,s,13, roam 04.u4.1 to/cola, Revised 5/2013 co To 3 N a) a) o N 0- To N ° c a 0 > 13 E of c Q co c 0 > o c En co aa)) o co 3 m (n U a) . w To CI) O O co n U En -ci N U) a m a c6 L L O ° ` m a 0) a L N a w co O a) N 0 7 a '3 ° n 0 2 E a c o E 0 -0 a = ° 0 H a a _o (6 c a) N a) ° a co No 0 3 E o O a 15- — ,- a) M O v c a — .5 m > of CL N- a) C 3 N 7 • L a. M a 7 L C U) ° _ L •c U> w ° 0 N w a = @ N a c — Q a`) c a) O 3 o a) o oaai a) o 2 -° o -° c a) a a) a) a) a o o — = y, a -o TD CL o 0 o c -`NO Co o c `o N 3, Cl) a N L -O a a) o N 2 N 'w N 'N • c O c c a) E -O L .cn w Q a -0 >. F , N co ca o a) c -e N a) O) a ° c N uJ O L J o a N o m Q 3 0 o a N o o c Ea M T E >. N N 0 'f0 ca a O i o co 5 Q o p a m o 0° .- L 2 ac E a W • 1D O ° a Ti ° o o m o 0 c °4 d ° N ° ro c a) Z M CO Z O a N 7 .O "76 > 0) Z .u) m a. aa)) (6 N E a F 0 w o 3 3 'N a = a) m a ao m m -o 0 o `O CO Q 0 = A a) N N N f E L co N L N a) ° .. Z 3 7 N 0 c a) 0 0 U 0) m m a) p o o O° m ao m U — va m >o `n o a m En w ' Q V = a a E 5 o a)Ca CO Q 0 a 3 C a) m '76 13 a) a >• ° N °O a ) O a N Q . N T a) @ N O O L t 0 7 a) OQ O) a) O N, a). U N D H .0 0 N 0 0- °- V) (6 .0 a N L X `)' - O.co aEa C) co m o `O N U 3 T = E ca V N a ° N z M Q _c Cl) 3 0 )n d c c 3 o O O a pp _ N .X Cl M O a) N 0 aai °w ° o L aal H 7 M o 0 o 0) Q N aai °x a) Q w Q CC C CC U cm c m O co d CO 2 C 2 I 1Y w a_ 7 0 L1.1 a 0 a) rX Cl) N Cl) N Cl) N N N N N N Cl) Cl) Cl) Cl) N Cl) N N N CO N � O Q a) a) o o a) a) a) a) a) a) a) a) < < < Q < < < < a) a) a) a) a) < a) a) a) a) a) o < a). a) < Q. Q. �0 a >- >-Z >- z Z >- >- >- >- >- >- >- >- Z z Z Z Z Z Z Z >- >- >• >- Z >- >- >- >- >- z z >- >- Z z z u) w -->--, 0 N o U 0 ` 0 — \.nJJJ F. E 3 E a) O U U j •c a)\ N 0 0 0,` ° u_ T T N c ` N _ o c .) U N. a) Ti) E 3 J_ ° O M C U op O o c a) 0 0 - _ ° a) E a) o _1 Z N i U N N Q CO O E o w as o .- )o a t a j c LL j a) 1—° >, -• c 7 0) O Q a N N N CO Z 4 a) 0- L a .� Q N N c a) 07 V w a3 N r ' d !O !CI th - c °E o ° Iii '4-- i; I a o CO ' L 0) U .N N C 3 ,_ °,,.; O) L cn j � O LO < 7 N N m co~ E E a 0 c E 6 o a>) O M c o ` CO -° o °) atS N d N c c ° -c n c c N . c a) c m L_ a s m o o $ a o °) n o o Q o ° m �j 'n ° a) ° o ai d ° I . ° > m a) 0 J _a 0 a) 0 ••- c c p - o C 0 a) a) C N N Q CO. a3 N O O) 0 O C w ° ° o -0 0 0 o c a) — Z o E 7 3 a) o L m 3 w a) E r U @ 7 a m m m o o a) L £ -0 a) 0 7o E 0 o ` a) N co c` .N L a0 ° N o a 3 ° .c ° T 3 c E TD w Q a c N N .m a) a m 3 3 a) a) a) .. o ° c 3 c o ° ° °) N ° 3 m 3 m co °) ° w U O z 2 c .- -0 -0 > a s 8 >O N .E O C O a) o o c O' N "°0 N N a O 0) 5 a d N a) d a s) a) 0 0 ° ° , a) o E o E L .o o N c w 0 a a a) a) a) . N 7 7 0- C 7 U 8 d ° a) a) - a a) a) -p 2 2 0) O U) _ 7 c O 0 ~ cLj N N O O co .) a ccr) Enn 0 L —, '0 N O) 0- c9 (a ca ° O) CO 0 N O) T .0 O 2 a N ° N O ° LL @ N C .5 a a 22 co N T N a) a) a) 3 C -0 0) c C) Q 6 a) c ca = 7 a C " O U p O° a) a) T a a) a) J _ Il Z fa -co a a a o ' E N L -0 '0 a L o • N N a a O .� as L 3 F a N c U 0 L C (6 c E a) 0 ca O L c c = U n3 — 0 O (a C a) CO a) ° s) o n) ss s) 2 o 3 7 > o 0 0 0 o a) a) = o a s) = c ns n o o c O c o 0 0 0 0 0 o Y o o N o c ° o 0 0 = ° s) `o ss r 0 a E '3 N 'c .0 o 0 a U) O . ° 7 0 0 0 .5 .5 s s a o 7 d ° '70 CO U > > 3 - a c a o - w w Y Y o co a E a m i J U m a) E a) a) a) M a a a a`) a) m ° 3 m 0 0 a 2 2 2 m -o o a `o _ 0 0 L ° a a°) a`) co •a5) a), o, a) VcaJ ° � � � (n . 00aa0Qa`. z 0 �n000oQ - Q4- ommO � N2 a ° U) U) O 0 W a O N CO ''t. LC) O r Co 0) O N M V U) CO N- CO O) O N M V LU CO r CO W T. E ,- N CO V )!') CO N. CO 0) C cm N N N N N N N N N N 2 c`') M M M C) M M M M U. M M M c N C G O c _ ( — N '.' N o 0 W O w c0 c c0 c0 N .E J N N Cl) e 0 1c c ° ` .-a a w c a 0 a) a s U Q Q W Q 0 Q Well History File AP NIX InfounHation of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. RECEIVED SEP 17 '1u,,) AOGCC Cook Inlet Energy_ z` �� 2333 t , 4 r -... ,, ...-„, - .. ....7! .-1 .., '''''',.,4',. '' ' T ifr : r it i C 7 xT , 1 k � t itoo -- - ***-4ANIC;ca. .1 "'I' "':I ' . It.... lj V- ,,, a 110 le �._ , L ' ! ,.fry /...„ ..., _ _ , 0,_ Cook Inlet Energy RU-1A REDOUBT SHOALS Section 14 — T7N - R14W Upper Cook Inlet, Alaska FINAL WELL REPORT Steve Pike—Senior Logging Geologist Omar Hinostroza-Logging Geologist Trey Thrailkill -Logging Geologist Dylan Muller— Logging Geologist Cook Inlet Energy_ Cook Inlet Energy RU-1A CANRIG I)en.i.ixr.Ta ri\Ui(..) 1.7 u. TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT AND CREW 3 1.1 EQUIPMENT SUMMARY 3 1.2 PERSONNEL 3 2 GENERAL WELL DETAILS 4 2.1 OBJECTIVES 4 2.2 WELL RESUME 4 2.3 HOLE DATA 5 3 GEOLOGICAL DATA 6 3.1 FORMATION /ZONE MARKER TOPS 6 3.2 ZONE SUMMARIES 7 3.2.1 HEMLOCK COAL 7 3.2.2 WEST FORELAND 10 3.3 WELL LITHOLOGY 11 3.4 SAMPLING PROGRAM AND DISTRIBUTION 17 4 DRILLING DATA 18 4.1 DAILY ACTIVITY SUMMARY 18 4.2 SURVEY DATA 20 4.3 MUD RECORD 26 4.4 BIT RECORD 27 5 DAILY REPORTS 28 Enclosures: 2"/ 100' Formation Log (MD and TVD 2"/ 100' LWD Combo Log (MD and TVD) 2"/ 100' Gas Ratio Log (MD and TVD) 2"/ 100' Drilling Dynamics Log (MD and TVD) Final Well Data on CD 2 CANRIG Cook Inlet Energy_ Cook Inlet Energy RU-1A 1 MUDLOGGING EQUIPMENT AND CREW 1 .1 EQUIPMENT SUMMARY Parameter Equipment Type And Position Total Comments Downtime Electric Driven QGM Gas Trap Mounted In Possum Belly; FID Total Occasional Downtime Due Ditch Gas Hydrocarbon Analyzer And 0* to Loss of Rig Power Minor Data Losses Chromatograph Rate of Penetration (ROP) Primary Draw works Belt Driven 0 Encoder On Drum Shaft(Quadco) Pump stroke counter Externally Mounted Magnetic 0 Proximity Sensor(Quadco) Hook load/Weight on bit(WOB) Hydraulic Pressure Transducer 0 (Quadco) Drill string torque Varco Analog Feed 0 Top drive rotary(RPM) Varco Analog Feed 0 Standpipe Pressure Solid State Pressure Transducer 0 Casing Pressure Solid State Pressure Transducer 0 Mud flow in/out(MFI/MFO) MFI: Derived From SPM 0 MFO: Flow Paddle(Quadco) Pit volumes Radar Pit Probes 0 Driller's work station Explosion Proof Touch Screen 0 Quadco Company Man's work station Quadco 0 Tool pusher's work station Quadco 0 Mud Engineer's work station Quadco 0 Pits work station Quadco 0 MWD/LWD WITS Feed WITS 0 1.2 PERSONNEL Unit Number: ML04 Mudloggers Years Days Technician Days Sample Catchers Days Steve Pike 12 22 Omar Hinostroza 16 Dylan Muller 3 18 Trey Thrailkill 18 Omar Hinostroza 5 3 3 CANING • Cook Inlet Energy_ Cook Inlet Energy RU-1A 2 GENERAL WELL DETAILS 2.1 OBJECTIVES Osprey RU-1A is a development oil well planned to side track off of the original RU-1 well utilizing the existing casing program down to 12,271' MD. RU-2A will kick off from the 7 5/8"casing at 12,271' and drill a 6 3/4"hole section from 12,272'to 15,050' MD.The well will be completed with 5 1/2" production tubing and an ESP completion. 2.2 WELL RESUME Operator: Cook Inlet Energy Well Name: RU-1A Field and Pool: Redoubt Shoals Unit-Hemlock State: County. Alaska Kenai Borough Company Representatives: Carlos Cretsinger, Keith Carter, Don Faulkner, Warren Johnson Location: SEC. 14, T7N, R14W Elevation: KB 89.10' Classification: Development Oil API#: 50-733-20497-01-00 PERMIT# 2130790 AFE#: 131004 Rig Name / Type: Osprey Rig #1 Primary Target: Hemlock Oil Spud Date :-> Finish Date :-> 7/10/13—*7/26/13*Released before 5.5"tubing was run _Total Depth: 15,050' Total Depth Formation: West Foreland Mudlogging Company CANRIG DRILLING TECHNOLOGY, LTD MWD Company: Halliburton Tools Run: MWD: Survey, Gamma, Resis, Neu Por, Neu Den Directional Drilling: Halliburton Drilling Fluids Company: HALLIBURTON/BAROID 4 CANRIG . Cook Inlet Energy_ Cook Inlet Energy RU-1A 2.3 HOLE DATA Maximum Depth Mud Shoe Depth Hole T.D. Deviation Casing F.I.T. Section MD TVD Formation Weight (°inc) MD TVD 6.75" 15050' 12502' West 9.3 38.31° 5 1/2" Foreland 5 CANRIG Cook Inlet Energy_ Cook Inlet Energy RU-1A 3 GEOLOGICAL DATA 3.1 FORMATION / ZONE MARKER TOPS FORMATION ACTUAL MD(ft) TVD(ft) SSTVD(ft) RU 3 GAS SAND 13354 11120 11031 HEMLOCK COAL 14060 11712 11623 UPR HEMLOCK 14110 11753 11664 SILT ZONE 14303 11909 11820 MIDDLE HEMLOCK 14373 11965 11876 LWR HEMLOCK 14610 12154 12065 WF COAL 14802 12303 12214 WEST FORELAND 14900 12398 12309 6 CANRIG Cook Inlet Energy_ Cook Inlet Energy RU-1A 3.2 ZONE SUMMARIES RU 3 GAS SAND: 13354' MD, 11120'TVD, 110431' SSTVD Drill Rate(ft/hr) Total Gas(units) Maximum Minimum Average Maximum Minimum Average 98 0.5 33 94 13 25 Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 13450 94 11421 6 - - - - - Tuffaceous siltstone, dark gray to medium dark gray with some medium gray; mostly stiff to slightly clumpy; brittle; irregular to amorphous fracture; massive cuttings habit, with some PDC grooved; mostly earthy to slightly dull luster;very silty texture with some grading to clayey and slightly gritty;thicker beds of tuffaceous siltstones interbedded with thin beds of tuffaceous claystones and very fine grained friable tuffaceous sandstones and loose grain quartz sand; abundant laminations of fine coals and carbonaceous materials. Sand, clear to translucent, with white, milky white, light to medium gray hues; mostly quartz grain sand matrix throughout; upper fine grain sand to upper medium; poorly sorted; very well rounded to subrounded with some subangular to well angular; moderate to high sphericity; thinner beds of loose quartz sand interbedded with thicker beds of tuffaceous siltstones; OBM fluorescence; no other petroleum indicators were observed. Sand/tuffaceous sandstone, predominantly clear to translucent, with light grayish brown hues; mostly quartz sand matrix with abundant light and dark colored lithic fragments throughout; upper fine grain to upper medium grain sand; fair to well sorted; very angular to subangular with some very rounded; moderate to high sphericity; thinner beds of loose quartz sand and fine "grained, very friable tuffaceous sandstones interbedded with thick beds of tuffaceous siltstones; laminations of carbonaceous material, tuff and very thin coals throughout sample; OBM fluorescence. 3.2.1 HEMLOCK COAL HEMLOCK COAL: 14060' MD, 11712 TVD, 11623 SSTVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum _ Minimum Average 88 7 34 39 16 25 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 14061 39 3703 36 24 - - - - 7 CANRIG Cook Inlet Energy_ Cook Inlet Energy RU-1A Sand/sandstone/tuffaceous sandstone, mostly translucent to clear, with some light gray, white, and light brownish gray hues; mostly quartz sand matrix with abundant light and dark colored lithic fragments throughout; upper fine grain to upper medium grain sand; fair to well sorted; very angular to subangular with some subrounded; moderate to high sphericity; thicker beds of loose quartz sand and fine grained, very friable tuffaceous sandstones and sandstones, interbedded with tuffaceous siltstones; laminations of carbonaceous material,tuff and very thin coals throughout sample. UPPER HEMLOCK: 14110' MD, 11753'TVD, 11664'SSTVD Drill Rate (ft/hr) Total Gas(units) Maximum Minimum Average Maximum Minimum Average 106 2 40 50 17 30 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 14122 50 4747 57 36 - - - - Tuffaceous siltstone, medium light gray to medium dark gray to light olive gray with scattered off white (interbedded ash); moderate to poorly consolidated with less compaction in the ashy silts; slightly adhesive; pdc bit grooved fracture and habit with soft sediment deformation in greater clay/ash matrix; earthy to some greasy luster; silty to ashy text; gradational beds of tuffaceous silt; composed of 80% silt, 10%clay, 10%ash and various detrital material;thin coal beds. Sand/sandstone,very light gray to medium gray with white clear and translucent; quartz sand matrix with dark and light colored lithic fragments; upper fine to upper medium grain size; moderately sorted; subrounded to rounded with some very angular to subangular; moderate to high sphericity; moderate sorting; polished to pitted texture; both grain and matrix supported of ash/tuff; pore fills and loosely attached; 80% quartz with minor chert; fair porosity with poor permeability; OBM fluorescence; no other petroleum indicators were observed. SILT ZONE: 14303' MD, 11909'TVD, 11820' SSTVD Drill Rate (ft/hr) Total Gas(units) Maximum Minimum Average Maximum Minimum Average 87 1 34 28 15 19 Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 14304 28 3799 142 44 10 7 - - Sandstone/sand, clear to translucent, white, yellowish gray, pinkish gray and light bluish gray hues; upper fine grain to upper coarse; fair to poorly sorted; very angular to subangular, with some very well rounded; high sphericity; mostly uncemented sand interbedded with grain supported fine grained, very friable sandstones and conglomerate sandstones interbedded with tuffaceous siltstones; OBM fluorescence; no other petroleum indicators were observed. 8 CANRIG Cook Inlet Energy_ Cook Inlet Energy RU-1A MIDDLE HEMLOCK: 14373' MD, 11965' TVD, 11876' SSTVD Drill Rate (ft/hr) Total Gas(units) Maximum Minimum Average Maximum Minimum Average 63 1 22 29 13 27 Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 14416 29 3891 211 43 8 4 - - Tuffaceous siltstone, medium dark gray to dark gray with some medium gray; stiff to mostly clumpy; very brittle; mostly amorphous to irregular fracture; pdc grooved to massive cuttings habit; mostly earthy to dull luster; very silty texture with some grading to gritty and clayey;thinner beds of tuffaceous siltstones interbedded with thicker beds of loose uncemented quartz sand with thin lenses of very friable fine grained quartz sandstone, and conglomerate; obm fluorescence; no other petroleum indicators were observed. LOWER HEMLOCK: 14610' MD, 12154'TVD, 12,065' SSTVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 69 1 26 28 17 22 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 14751 28 3180 269 24 - - - - Sand/sandstone/conglomerate sand/conglomerate, clear to translucent, white, light gray, light bluish gray and pinkish gray hues; lower medium to upper coarse grains; very angular to subangular; low to high sphericity; predominantly grain supported sandstone with some slightly matrix supported; mostly quartz sand matrix with 10% chert, and 10% clastics and tuff; OBM fluorescence throughout sample; no other petroleum indicators were observed. Tuffaceous siltstone, olive grey to olive black, dark grey and grayish black; brittle to crumbly tenacity; blocky and slightly planar fracture; massive to platy cuttings habit; metallic to earthy luster; silty texture; thin bed structure; often interbedded with sandstones and interbedded with unconsolidated sand grains; highly calcareous; cuttings very small due to slow ROP. 9 CANRIG Cook Inlet Energy_ Cook Inlet Energy RU-1A 3.2.2 WEST FORELAND WEST FORLAND COAL: 14802' MD, 12303'TVD, 12214' SSTVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 67 5 23 37 13 21 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 14880 37 4417 189 31 - - - - Sand/sandstone/conglomerate sand, olive grey to dark medium grey; upper fine to upper very coarse grains and some up to 2mm; finer grains moderate to high sphericity and well rounded to subangular, larger grains low to moderate sphericity and very angular to subangular; sandstones predominantly grain supported and some matrix supported,well cemented; moderately calcareous. WEST FORELAND: 14900' MD, 12398'TVD, 12309'SSTVD Drill Rate(ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 60 1 23 42 17 21 Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 15026 42 4967 128 32 - - - - Tuffaceous siltstone, medium dark gray to dark gray with some medium gray; stiff to mostly clumpy; very brittle; mostly amorphous to irregular fracture; pdc grooved to massive cuttings habit; mostly earthy to dull luster; very silty texture with some grading to gritty and ashy; thinner beds of tuffaceous siltstones interbedded with loose uncemented quartz sand, and very fine grained, very friable sandstones, with lesser amounts of tuffaceous claystones; abundant laminations of tuff, detrital carbonaceous material and very thin coals; OBM fluorescence. 10 CANRIG Cook Inlet Energy_ Cook Inlet Energy RU-1A 3.3 WELL LITHOLOGY SAND(12315-12380)= PREDOMINANTLY CLEAR TO TRANSLUCENT WITH SOME LIGHT GRAY VERY PALE ORANGE PINKISH GRAY YELLOWISH GRAY AND WHITE; MOSTLY QUARTZ SAND MATRIX WITH ABUNDANT DARK COLORED LITHIC FRAGMENTS; LOWER FINE GRAIN TO UPPER MEDIUM GRAIN; VERY WELL SORTED;WELL ROUNDED TO VERY ANGULAR; MODERATE TO HIGH SPHERICITY;THICKER BEDS OF LOOSE GRAIN QUARTZ SAND INTERBEDDED WITH THICKER BEDS OF TUFFACEOUS SILTSTONES AND VERY THIN BEDS OF TUFFACEOUS CLAYSTONES. TUFFACEOUS SILTSTONE(12405-12455)=MEDIUM LIGHT GRAY WITH DARK GRAY; MOSTLY SOFT TO SLIGHTLY STIFF; BRITTLE; IRREGULAR FRACTURE;AMORPHOUS CUTTINGS HABIT WITH SOME SLIGHTLY BLOCKY; EARTHY TO DULL LUSTER; MOSTLY SILTY WITH SOME SLIGHTLY GRITTY IN PLACES; THINNER BEDS OF TUFFACEOUS SILTSTONES INTERBEDDED WITH THICKER BEDS OF LOOSE UNCEMENTED QUARTZ SAND. SAND(12500-12580)= MOSTLY CLEAR TO TRANSLUCENT WITH SOME LIGHT GRAY TO MEDIUM GRAY; PREDOMINANTLY QUARTZ SAND MATRIX WITH ABUNDANT DARK COLORED LITHIC FRAGMENTS THROUGHOUT; LOWER FINE GRAIN SAND TO UPPER MEDIUM GRAIN; FAIR TO WELL SORTED;VERY ROUNDED TO SUBROUNDED WITH SOME VERY ANGULAR TO SUBANGULAR; HIGH SPHERICITY; SOME QUARTZ GRAINS APPEARED TO BE SLIGHTLY FROSTED IN PLACES; THINNER BEDS OF LOOSE UNCEMENTED QUARTZ SAND INTERBEDDED WITH THICKER BEDS OF TUFFACEOUS SILTSTONES AND CLAYSTONES; OBM FLUORESCENCE; NO OTHER PETROLEUM INDICATORS WERE OBSERVED. COAL(12585-12598)= BLACK; FIRM; EARTHY TO RESINOUS LUSTER; MATTE TEXTURE; PDC GROUND UP HACKLY CUTTINGS; COMPOSED OF BITUMINOUS TO LIGNITIC COAL; NO VISIBLE OFF GASSING WAS OBSERVED. TUFFACEOUS SILTSTONE(12615-12675)=DARK GRAY TO MEDIUM GRAY WITH SOME LIGHT GRAY; MUSHY TO CLUMPY; CRUMBLY TO VERY BRITTLE; MOSTLY IRREGULAR FRACTURE; MASSIVE CUTTINGS HABIT;VERY SILTY TO SOMEWHAT CLAYEY TEXTURE; THICKER BEDS OF TUFFACEOUS SILTSTONES INTERBEDDED WITH LOOSE UNCEMENTED QUARTZ SAND WITH LESSER AMOUNTS OF VERY FRIABLE CALCAREOUS SANDSTONES AND TUFFACEOUS CLAYSTONES; OBM FLUORESCENCE. SAND/SANDSTONE(12680-12765)=LIGHT GRAY TO MEDIUM GRAY TRANSLUCENT TO CLEAR WITH SOME WHITE HUES; MOSTLY QUARTZ GRAIN SAND WITH ABUNDANT DARK COLORED LITHIC FRAGMENTS; LOWER FINE GRAIN SAND TO UPPER MEDIUM GRAIN;WELL SORTED THROUGHOUT;WELL ROUNDED TO SUBROUNDED WITH SOME VERY ANGULAR TO SUBANGULAR; MODERATE TO HIGH SPHERICITY; MOSTLY LOOSE UNCEMENTED QUARTZ SAND WITH VERY THIN LENSES OF VERY FRIABLE FINE GRAINED CALCAREOUS CEMENTED SANDSTONES INTERBEDDED WITH TUFFACEOUS SILTSTONES GRADING DOWNWARD TO TUFFACEOUS CLAYSTONES IN PLACES; OBM FLUORESCENCE; NO OTHER PETROLEUM INDICATORS WERE OBSERVED. TUFFACEOUS SILTSTONE(12770 -12835)= MEDIUM DARK GRAY TO DARK GRAY WITH SOME MEDIUM GRAY; POORLY INDURATED; SLIGHTLY STIFF;VERY BRITTLE; IRREGULAR TO AMORPHOUS FRACTURE; PDC GROOVED TO MASSIVE CUTTINGS HABIT; PREDOMINANTLY GREASY TO SLIGHTLY DULL LUSTER; SILTY TEXTURE WITH SOME GRADING TO CLAYEY AND 11 CANRIG Cook Inlet Energy_ Cook Inlet Energy RU-1A SLIGHTLY GRITTY; THICK BEDS OF TUFFACEOUS SILTSTONES INTERBEDDED WITH THINS BEDS OF TUFFACEOUS CLAYTONES;ABUNDANT LAMINATIONS OF CARBONACEOUS MATERIALS WITH VERY THIN COALS. SAND/SANDSTONE(12840-12910)=DARK GREY AND SLIGHTLY OLIVE BLACK INDIVIDUAL GRAINS WHITE CLEAR TRANSLUCENT ROSE AND BUFF; MOSTLY MEDIUM GRAINS WITH OCCASIONAL LOWER VERY COARSE AND LOWER FINE GRAINS MODERATE TO POOR SORTING; HIGH TO MODERATE SPHERICITY;VERY ANGULAR TO SUBROUNDED; SANDSTONES VERY TO SLIGHTLY FRIABLE AND VERY ARGILLACEOUS WITH ABUNDANT FINE CARBONACEOUS MATERIAL AND INTERBEDDED WITH DARKER OLIVE BLACK SILTSTONES; VERY CALCAREOUS. TUFFACEOUS SILTSTONE(12915-12980)=OLIVE BLACK TO DARK GREY; POORLY INDURATED; VERY SOFT OCCASIONALLY SLIGHTLY FIRM; CRUMBLY AND SLIGHTLY SECTILE TENACITY; BLOCKY TO EARTHY FRACTURE; WAXY AND SLIGHTLY GREASY TO EARTHY LUSTER; SILTY AND SOMETIMES GRITTY TEXTURE; THICK BED CLAYSTONE WITH ABUNDANT THIN BED CLAYSTONE INTERBEDDED AND ABUNDANT INCLUSIONS OF CARBONACEOUS MATERIAL .5MM-1MM AND LOOSE SAND GRAINS;VERY CALCAREOUS. SANDSTONE/SAND(13005-13070)=GREENISH BLACK TO GRAYISH BLACK; INDIVIDUAL GRAINS WHITE TRANSLUCENT BUFF; UPPER FINE TO UPPER VERY FINE GRAINS WITH OCCASIONAL UPPER COARSE INCREASING GRAIN SIZE WITH DEPTH; WELL SORTED; MODERATE TO SUB-SPHERICAL;WELL ROUNDED TO SUB-ANGULAR; SANDSTONE VERY FRIABLE TO SLIGHTLY FIRM; SANDSTONE GRAIN SUPPORTED NON CALCAREOUS CEMENT; DOMINANTLY QUARTZ WITH ABUNDANT LITHIC FRAGMENTS AND CARBONACEOUS MATERIAL SMALLER THAN .5MM. COAL(13076-13099)= BLACK; BRITTLE TO FIRM; BLOCKY AND SOMETIMES CONCHOIDAL FRACTURE; GREASY TO MATTE LUSTER; SMOOTH TO GRITTY TEXTURE; NO VISIBLE OFF GASSING;THIN BEDS OF CARBONACEOUS SHALE/SILTSTONE INTERBEDDED. TUFFACEOUS SILTSTONE(13125-13205)= LIGHT GRAY TO MEDIUM LIGHT GRAY WITH SOME MEDIUM GRAY; MOSTLY STIFF TO SLIGHTLY CLUMPY; BRITTLE; IRREGULAR TO AMORPHOUS FRACTURE; PDC GROOVED TO MASSIVE CUTTINGS HABIT; MOSTLY VERY DULL TO SLIGHTLY GREASY LUSTER;VERY SILTY TEXTURE WITH SOME GRADING TO CLAYEY AND SLIGHTLY GRITTY; THINNER BEDS OF TUFFACEOUS SILTSTONES INTERBEDDED WITH THIN BEDS OF TUFFACEOUS CLAYTONES AND ASH INTERBEDDED WITH LOOSE QUARTZ SAND;ABUNDANT LAMINATIONS OF VERY THIN COALS ALTERNATING WITH THICKER BEDS OF COAL AND CARBONACEOUS MATERIALS. SAND/SANDSTONE(13210-13290)=MOSTLY CLEAR TO TRANSLUCENT WITH SOME GRAY; PREDOMINANTLY QUARTZ SAND MATRIX WITH ABUNDANT LIGHT AND DARK COLORED LITHIC FRAGMENTS THROUGHOUT THE SAMPLE; UPPER FINE GRAIN TO UPPER MEDIUM GRAIN SAND; FAIR TO WELL SORTED;VERY WELL ROUNDED TO SUBROUNDED WITH SOME VERY ANGULAR; MODERATE TO HIGH SPHERICITY; THICKER BEDS OF LOOSE QUARTZ SAND AND VERY FINE GRAINED AND VERY FRIABLE SANDSTONES INTERBEDDED WITH POORLY INDURATED TUFFACEOUS SILTSTONES WITH INCREASING AMOUNTS OF ASH THROUGHOUT; OBM FLUORESCENCE; NO OTHER PETROLEUM INDICATORS WERE OBSERVED. TUFFACEOUS SILTSTONE(13295 - 13375)= DARK GRAY TO MEDIUM DARK GRAY WITH SOME MEDIUM GRAY; MOSTLY STIFF TO SLIGHTLY CLUMPY; BRITTLE; IRREGULAR TO AMORPHOUS FRACTURE; MASSIVE CUTTINGS HABIT WITH SOME PDC GROOVED; MOSTLY EARTHY TO 12 CANRIG Cook Inlet Energy_ Cook Inlet Energy RU-1A SLIGHTLY DULL LUSTER; VERY SILTY TEXTURE WITH SOME GRADING TO CLAYEY AND SLIGHTLY GRITTY;THICKER BEDS OF TUFFACEOUS SILTSTONES INTERBEDDED WITH THIN BEDS OF TUFFACEOUS CLAYTONES AND VERY FINE GRAINED FRIABLE TUFFACEOUS SANDSTONES AND LOOSE GRAIN QUARTZ SAND;ABUNDANT LAMINATIONS OF FINE COALS AND CARBONACEOUS MATERIALS. SAND/TUFFACEOUS SANDSTONE(13380-13455)=CLEAR WITH LIGHT BROWNISH GRAY HUES; PREDOMINANTLY QUARTZ SAND MATRIX WITH ABUNDANT LIGHT AND DARK COLORED LITHIC FRAGMENTS THROUGHOUT THE SAMPLE; UPPER FINE GRAIN TO UPPER MEDIUM GRAIN SAND; FAIR TO WELL SORTED;VERY WELL ROUNDED TO SUBROUNDED WITH SOME VERY ANGULAR; MODERATE TO HIGH SPHERICITY; THINNER BEDS OF LOOSE QUARTZ SAND AND VERY FINE GRAINED FRIABLE TUFFACEOUS SANDSTONES INTERBEDDED WITH THICK BEDS OF TUFFACEOUS SILTSTONES AND TUFFACEOUS CLAYSTONES; OBM FLUORESCENCE; NO OTHER PETROLEUM INDICATORS WERE OBSERVED. TUFFACEOUS SILTSTONE(13460-13525)=MEDIUM DARK GRAY TO DARK GRAY WITH SOME MEDIUM GRAY; MOSTLY CLUMPY TO SLIGHTLY STIFF;VERY BRITTLE; IRREGULAR TO AMORPHOUS FRACTURE; PDC GROOVED TO MASSIVE CUTTINGS HABIT; PREDOMINANTLY DULL TO SLIGHTLY GREASY LUSTER;VERY SILTY TEXTURE WITH SOME GRADING TO CLAYEY AND SLIGHTLY GRITTY; THICK BEDS OF TUFFACEOUS SILTSTONES INTERBEDDED WITH THINS BEDS OF TUFFACEOUS CLAYTONES;ABUNDANT LAMINATIONS OF CARBONACEOUS MATERIALS WITH VERY THIN COALS. SAND (13530-13595)=CLEAR TO TRANSLUCENT WITH WHITE MILKY WHITE LIGHT TO MEDIUM GRAY HUES; MOSTLY QUARTZ GRAIN SAND MATRIX THROUGHOUT; UPPER FINE GRAIN SAND TO UPPER MEDIUM; POORLY SORTED;VERY WELL ROUNDED TO SUBROUNDED WITH SOME SUBANGULAR TO WELL ANGULAR; MODERATE TO HIGH SPHERICITY; THINNER BEDS OF LOOSE QUARTZ SAND INTERBEDDED WITH THICKER BEDS OF TUFFACEOUS SILTSTONES; OBM FLUORESCENCE; NO OTHER PETROLEUM INDICATORS WERE OBSERVED. TUFFACEOUS SILTSTONE(13620-13685)=DARK GRAY TO MEDIUM DARK GRAY WITH SOME MEDIUM GRAY; MOSTLY STIFF TO SLIGHTLY CLAYEY; BRITTLE;AMORPHOUS TO IRREGULAR FRACTURE; MOSTLY MASSIVE CUTTINGS HABIT WITH PDC GROOVED; MOSTLY EARTHY TO SLIGHTLY DULL LUSTER;VERY SILTY TEXTURE WITH SOME GRADING TO CLAYEY AND SLIGHTLY GRITTY; THICK BEDS OF TUFFACEOUS SILTSTONES INTERBEDDED WITH THIN BEDS OF TUFFACEOUS CLAYTONES AND VERY FINE GRAINED FRIABLE TUFFACEOUS SANDSTONES AND LOOSE QUARTZ. SANDITUFFACEOUS SANDSTONE(13690 -13775)= PREDOMINANTLY CLEAR TO TRANSLUCENT WITH LIGHT GRAYISH BROWN HUES; MOSTLY QUARTZ SAND MATRIX WITH ABUNDANT LIGHT AND DARK COLORED LITHIC FRAGMENTS THROUGHOUT; UPPER FINE GRAIN TO UPPER MEDIUM GRAIN SAND; FAIR TO WELL SORTED;VERY ANGULAR TO SUBANGULAR WITH SOME VERY ROUNDED; MODERATE TO HIGH SPHERICITY; THINNER BEDS OF LOOSE QUARTZ SAND AND FINE GRAINED VERY FRIABLE TUFFACEOUS SANDSTONES INTERBEDDED WITH THICK BEDS OF TUFFACEOUS SILTSTONES; LAMINATIONS OF CARBONACEOUS MATERIAL TUFF AND VERY THIN COALS THROUGHOUT SAMPLE; OBM FLUORESCENCE. TUFFACEOUS SILTSTONE(13780-13850)= MEDIUM LIGHT GRAY TO MEDIUM DARK GRAY TO LIGHT GRAY WITH SCATTERED OFF WHITE POORLY CONSOLIDATED THROUGHOUT; MOSTLY IRREGULAR TO SLIGHTLY SPLINTERY FRACTURE; PDC GROOVED CUTTINGS HABIT WITH SOFT SEDIMENT DEFORMATION IN CLAY/ASH MATRIX; EARTHY TO GREASY LUSTER; PREDOMINANTLY SILTY TO ASHY TEXTURE; PREDOMINANTLY THICKER BEDS GRADATIONAL 13 CANRIG Cook Inlet Energy_ Cook Inlet Energy RU-1A OF TUFFACEOUS SILT; COMPOSED OF 80% SILT 10% CLAY 10%ASH AND VARIOUS DETRITAL MATERIAL;ABUNDANT LAMINATIONS OF VERY FINE COALS. SAND/SANDSTONE(13875-13940)=GRAYISH BLACK TO OLIVE BLACK; UPPER VERY COARSE TO LOWER FINE GRAINS; POORLY SORTED;WELL ROUNDED TO SUBANGULAR AND OCCASIONALLY VERY ANGULAR; HIGH TO LOW SPHERICITY; SANDSTONES MATRIX SUPPORTED HIGHLY CALCAREOUS CEMENT; DOMINANTLY QUARTZ GRAINS WITH ABUNDANT LITHIC CLASTS TUFF AND INTERBEDDED WITH TUFFACEOUS SILTSTONE AND CARBONACEOUS SHALES; INTERBEDDED LAYERS SOMETIMES VERY ARGILLACEOUS. TUFFACEOUS SILTSTONE(13945-13995)=OLIVE BLACK TO DARK GREY; POORLY TO MODERATELY INDURATED; BLOCKY TO EARTHY FRACTURE; EARTHY AND SLIGHTLY SPARKLY LUSTER; GRITTY TO ABRASIVE TEXTURE; THIN TO THICK BED STRUCTURE;ABUNDANT BEDDED LOOSE SAND GRAINS AND CARBONACEOUS MATERIAL; OCCASIONALLY VERY CALCAREOUS. SAND/SANDSTONE/TUFFACEOUS SANDSTONE(14040-14125)= MOSTLY TRANSLUCENT TO CLEAR WITH SOME LIGHT GRAY WHITE AND LIGHT BROWNISH GRAY HUES; MOSTLY QUARTZ SAND MATRIX WITH ABUNDANT LIGHT AND DARK COLORED LITHIC FRAGMENTS THROUGHOUT; UPPER FINE GRAIN TO UPPER MEDIUM GRAIN SAND; FAIR TO WELL SORTED; VERY ANGULAR TO SUBANGULAR WITH SOME SUBROUNDED; MODERATE TO HIGH SPHERICITY; THICKER BEDS OF LOOSE QUARTZ SAND AND FINE GRAINED VERY FRIABLE TUFFACEOUS SANDSTONES AND SANDSTONES INTERBEDDED WITH TUFFACEOUS SILTSTONES; LAMINATIONS OF CARBONACEOUS MATERIAL TUFF AND VERY THIN COALS THROUGHOUT SAMPLE. TUFFACEOUS SILTSTONE(14130-14205)= MEDIUM LIGHT GRAY TO MEDIUM DARK GRAY TO LIGHT OLIVE GRAY WITH SCATTERED OFF WHITE (INTERBEDDED ASH); MODERATE TO POORLY CONSOLIDATED WITH LESS COMPACTION IN THE ASHY SILTS; SLIGHTLY ADHESIVE; PDC BIT GROOVED FRACTURE AND HABIT WITH SOFT SEDIMENT DEFORMATION IN GREATER CLAY/ASH MATRIX; EARTHY TO SOME GREASY LUSTER; SILTY TO ASHY TEXT; GRADATIONAL BEDS OF TUFFACEOUS SILT; COMPOSED OF 80% SILT 10% CLAY 10%ASH VARIOUS DETRITAL MATERIAL;THIN COAL BEDS. SAND/SANDSTONE(14205-14285)=VERY LIGHT GRAY TO MEDIUM GRAY WITH WHITE CLEAR AND TRANSLUCENT; QUARTZ SAND MATRIX WITH DARK AND LIGHT COLORED LITHIC FRAGMENTS; UPPER FINE TO UPPER MEDIUM GRAIN SIZE; MODERATELY SORTED; SUBROUNDED TO ROUNDED WITH SOME VERY ANGULAR TO SUBANGULAR; MODERATE TO HIGH SPHERICITY; MODERATE SORTING; POLISHED TO PITTED TEXTURE; BOTH GRAIN AND MATRIX SUPPORTED OF ASH/TUFF; PORE FILLS AND LOOSELY ATTACHED; 80%QUARTZ WITH MINOR CHERT; FAIR POROSITY WITH POOR PERMEABILITY; OBM FLUORESCENCE; NO OTHER PETROLEUM INDICATORS WERE OBSERVED. SANDSTONE/SAND(14290-14355)=CLEAR TO TRANSLUCENT WHITE YELLOWISH GRAY PINKISH GRAY AND LIGHT BLUISH GRAY HUES; UPPER FINE GRAIN TO UPPER COARSE; FAIR TO POOR SORTED;VERY ANGULAR TO SUBANGULAR WITH SOME VERY WELL ROUNDED; HIGH SPHERICITY; MOSTLY UNCEMENTED SAND INTERBEDDED WITH GRAIN SUPPORTED FINE GRAINED VERY FRIABLE SANDSTONES AND CONGLOMERATE SANDSTONES INTERBEDDED WITH TUFFACEOUS SILTSTONES; OBM FLUORESCENCE; NO OTHER PETROLEUM INDICATORS WERE OBSERVED. 14 CANRIG Cook Inlet Energy_ Cook Inlet Energy RU-1A SILTSTONE(14355-14425)=DARK GREY TO GRAYISH BLACK AND OCCASIONAL MEDIUM GREY; POOR TO MODERATE INDURATION; CRUMBLY AND BRITTLE TENACITY; BLOCKY AND SLIGHTLY PLANAR TO EARTHY FRACTURE; MASSIVE AND SLIGHTLY PLATY CUTTINGS HABIT; EARTHY TO FROSTED LUSTER; SILTY TO GRITTY TEXTURE;THIN BED INTERBEDDING WITH LIGHTER SILTSTONES AND SOME TUFFACEOUS SANDSTONES;ABUNDANT LOOSE SAND GRAINS AND FINER CARBONACEOUS MATERIAL IMBEDDED;VERY CALCAREOUS. SAND/SANDSTONE/TUFFACEOUS SANDSTONE(14360-14515)=OLIVE GREY TO DARK GREY; DOMINANTLY UPPER FINE TO LOWER MEDIUM GRAINS WITH 10% UP TO LOWER VERY COARSE; SMALLER GRAINS LOW TO MODERATE AND SOME SPHERICITY LARGER GRAINS VERY LOW TO MODERATE; GRAINS WELL ROUNDED TO SUBROUNDED LARGER GRAINS SUBANGULAR AND SOMETIMES VERY ANGULAR; SANDSTONES MATRIX SUPPORTED WELL CEMENTED;VERY CALCAREOUS; INTERBEDDED WITH SILTSTONE AND TUFFACEOUS SILTSTONE. TUFFACEOUS SILTSTONE(14520 -14590)= MEDIUM DARK GRAY TO DARK GRAY WITH SOME MEDIUM GRAY; STIFF TO MOSTLY CLUMPY;VERY BRITTLE; MOSTLY AMORPHOUS TO IRREGULAR FRACTURE; PDC GROOVED TO MASSIVE CUTTINGS HABIT; MOSTLY EARTHY TO DULL LUSTER;VERY SILTY TEXTURE WITH SOME GRADING TO GRITTY AND CLAYEY;THINNER BEDS OF TUFFACEOUS SILTSTONES INTERBEDDED WITH THICKER BEDS OF LOOSE UNCEMENTED QUARTZ SAND WITH THIN LENSES OF VERY FRIABLE FINE GRAINED QUARTZ SANDSTONE AND CONGLOMERATE; OBM FLUORESCENCE; NO OTHER PETROLEUM INDICATORS WERE OBSERVED. SAND/SANDSTONE/CONGLOMERATE SAND/CONGLOMERATE(14600-14670)=CLEAR TO TRANSLUCENT WHITE LIGHT GRAY LIGHT BLUISH GRAY AND PINKISH GRAY HUES; LOWER MEDIUM TO UPPER COARSE GRAINS; VERY ANGULAR TO SUBANGULAR; LOW TO HIGH SPHERICITY; PREDOMINANTLY GRAIN SUPPORTED SANDSTONE WITH SOME SLIGHTLY MATRIX SUPPORTED; MOSTLY QUARTZ SAND MATRIX WITH 10% CHERT AND 10% CLASTICS AND TUFF; OBM FLUORESCENCE THROUGHOUT SAMPLE; NO OTHER PETROLEUM INDICATORS WERE OBSERVED. SAND/SANDSTONE/CONGLOMERATE SAND(14675-14750)=OLIVE BLACK TO DARK GREY; UPPER FINE TO 2 MM QUARTZ GRAINS; POORLY SORTED; LARGER GRAINS MODERATELY SPHERICAL AND VERY ANGULAR WITH SOME SUBANGULAR; FINER GRAINS HIGHLY TO MODERATELY SPHERICAL AND WELL ROUNDED TO SUBROUNDED; PREDOMINANTLY QUARTZ SAND GRAINS; TRANSLUCENT PINKISH GREY AND TRACE GREENISH GREY GLAUCONITIC STAINING; SANDSTONES DOMINANTLY GRAIN SUPPORTED WITH MEDIUM TO COARSE RANGE GRAINS;VERY CALCAREOUS; 10% SILTSTONE GRAINS; NO DETECTABLE PETROLEUM INDICATORS DUE TO OBM. SILTSTONE(14760-14815)=OLIVE GREY TO OLIVE BLACK DARK GREY AND GRAYISH BLACK; BRITTLE TO CRUMBLY TENACITY; BLOCKY AND SLIGHTLY PLANAR FRACTURE; MASSIVE TO PLATY CUTTINGS HABIT; METALLIC TO EARTHY LUSTER; SILTY TEXTURE;THIN BED STRUCTURE; OFTEN INTERBEDDED WITH SANDSTONES AND IMBEDDED WITH UNCONSOLIDATED SAND GRAINS; HIGHLY CALCAREOUS; CUTTINGS VERY SMALL DUE TO SLOW ROP. SAND/SANDSTONE/CONGLOMERATE SAND(14825-14880)=OLIVE GREY TO DARK MEDIUM GREY; UPPER FINE TO UPPER VERY COARSE GRAINS AND SOME UP TO 2MM; FINER GRAINS MODERATE TO HIGH SPHERICITY AND WELL ROUNDED TO SUBANGULAR LARGER GRAINS LOW TO MODERATE SPHERICITY AND VERY ANGULAR TO SUBANGULAR; SANDSTONES 15 CANRIG Cook Inlet Energy_ Cook Inlet Energy RU-1A DOMINANTLY GRAIN SUPPORTED AND SOME MATRIX SUPPORTED WELL CEMENTED; MODERATELY CALCAREOUS. TUFFACEOUS SILTSTONE(14905-14985)= MEDIUM DARK GRAY TO DARK GRAY WITH SOME MEDIUM GRAY; STIFF TO MOSTLY CLUMPY;VERY BRITTLE; MOSTLY AMORPHOUS TO IRREGULAR FRACTURE; PDC GROOVED TO MASSIVE CUTTINGS HABIT; MOSTLY EARTHY TO DULL LUSTER;VERY SILTY TEXTURE WITH SOME GRADING TO GRITTY AND ASHY;THINNER BEDS OF TUFFACEOUS SILTSTONES INTERBEDDED WITH LOOSE UNCEMENTED QUARTZ SAND AND VERY FINE GRAINED, VERY FRIABLE SANDSTONES WITH LESSER AMOUNTS OF TUFFACEOUS CLAYSTONES;ABUNDANT LAMINATIONS OF TUFF DETRITAL CARBONACEOUS MATERIAL AND VERY THIN COALS; OBM FLUORESCENCE. SAND/SANDSTONE(14990-15050)=MOSTLY TRANSLUCENT TO CLEAR WITH SOME WHITE LIGHT GRAY AND BROWNISH GRAY HUES; PREDOMINANTLY QUARTZ SAND MATRIX WITH ABUNDANT LIGHT AND DARK COLORED LITHIC FRAGMENTS THROUGHOUT; UPPER FINE GRAIN TO UPPER MEDIUM GRAIN SAND; FAIR TO WELL SORTED;VERY ANGULAR TO SUBANGULAR WITH SOME SUBROUNDED; MODERATE TO HIGH SPHERICITY; THICKER BEDS OF LOOSE QUARTZ SAND AND FINE GRAINED AND VERY FRIABLE SANDSTONES INTERBEDDED WITH TUFFACEOUS SILTSTONES; OBM FLUORESCENCE; NO OTHER PETROLEUM INDICATORS WERE OBSERVED. 16 CANRIG Cook Inlet Energy_ Cook Inlet Energy RU-1A 3.4 SAMPLING PROGRAM AND DISTRIBUTION Set Type and Purpose Interval Frequency Distribution 12290' - 14160' 30' Cook Inlet Energy 1 Cleaned and Spun Dry 14170'- 15040' 10' Attn: Greg Kirkland 601 W.51n Ave, Suite 310 Anchorage,AK 99501 17 CANRIG Cook Inlet Energy_ Cook Inlet Energy RU-7A 4 DRILLING DATA 4.1 DAILY ACTIVITY SUMMARY July 7,2013: Continue repairing draw works July 8,2013: Finish rebuilding drawworks. P/U whipstock and milling assembly. RIH t/11,234',filling pipe/breaking circulation every 3000'. July 9,2013 Continue RIH with whipstock t/12,275'and orientate. Sat down 38k, unsure if whipstock set. Pump dry job and POOH to surface with no whipstock;TIH U11,329'with milling assembly. July 10,2013 Continue RIH with milling assembly t/12,261'and tag top of whipstock; mill window t/12,267'. Circulate BU, pump dry job and POOH. Slip/Cut 120'of drill line, P/U new milling assembly and TIH t/4,000'. July 11,2013 Continue RIH with milling assembly to 12,209'. Wash to window at 12,263'. Mill from 12,263'to 12,290' (window plus 20'new hole); circulate B/U at 12,205'. LOT MD 12,290'/TVD 10,264'@ 2920 PSI, EMW 13.89. POOH, L/D BHA t/286'. July 12,2013 Service and lubricate rig; make up and RIH with milling assembly. Wash through window, rotated through 4x and slid trough 2x to bottom; pump dry job and POOH U5740'. July 13,2013 Continue POOH to surface with milling assembly and lay down. Make up 6 3/4"drilling BHA and RIH on 4" DP to bottom;drill/slide U12,309'. July 14,2013 Continue rotating and sliding f/12,309'U12,396'. July 15,2013 Continue rotating/sliding U12,478'. Preparing to TOOH. July 16,2013 POOH U12,228'and pumped dry job. POOH U11,381 and repaired iron roughneck. Finish POOH; P/U BHA and RIH U10,532', filling pipe and testing MWD every 3000'. 18 CANRIG Cook Inlet Energy_ Cook Inlet Energy RU-1A July 17,2013 Finished RIH to bottom; Drilled from 12,478'to report depth of 13,019'. July 18,2013 Continued drilling ahead from 13,589'to 13,950'. Drilling ahead at time of report. July 19,2013 Continued drilling ahead to 14,001'. Circulated bottoms up and began tripping out for B.O.P.testing. Perform flow check and pump dry job at casing shoe. Continue POOH to surface and lay down tools. Rig up for BOP test. Test BOP. Began rigging down test equipment. July 20,2013 Continued drilling ahead to 14,001'. Circulated bottoms up and began tripping out for B.O.P.testing. Perform flow check and pump dry job at casing shoe. Continue POOH to surface and lay down tools. Rig up for BOP test.Test BOP. Began rigging down test equipment. July 21,2013 Picked up new BHA and TIH. Slip and cut drilling line. Continue TIH to bottom washing down from 12,532' to 13,630'. No new footage drilled July 22,2013 Continued washing down from 13,630'to bottom. Drilled from 14,004'to 14,450'. Drilling ahead at time of report. July 23,2013 Continued drilling ahead from 14,450'to 14,849'. Drilling ahead at time of report. July 24,2013 Continued drilling ahead from 14,849'to td at 15,050'. Circulate hole clean pump out of hole to casing shoe, log MWD mad pass. RIH to bottom. July 25,2013 Continued M.A.D. Pass t/12,435'. RIH to TD washing down tight spots. Circulated 3X B.U.then began reaming out of the hole to 14,800'. 19 CANRIG =, i O I O 0 M N 0 LO 1' CD 0 in CO M CD _7 co Oco d: C) CO Vim' LO U) N CA CO CO CO A- J :` O O r r r Q 0 0 0 CV — — 0 0 — CV — - O Ch CV 0 O N M M M CN cc; O d • .-- 0 a0 U) a0 U) (Dr" O N O N (NI N COO V co M 7 M M r N co. 1J.1 O O O '- co CO ,_ _ N M st M N ,- M CO 00 CO CO CO O O CO 0 C) 0 GOO N. + ... r- A- N N N CO CO 1- 1' U) U) CO • M CU N- M 1- M CO CA N CA Cl) ^ co f-- co O M (A N v COO M N tN - 4 C` O O co. N- N M co M O O Z = p O N O a0 co co co 4 0 N O O O M O x— N CD N LO f: M O M �. ... O O M Cf) N M 4 Ct) C� CT O N U) CO N N N M M M CCI COO To C co CO 10 U7 a) CC)LO �'• .-. O O N CO 0 CO M ,- N N 1.0 CO 'mod. co I� . 0 0 2 0 i 0 0 N . C i (A �t a0 M 00 M O U) 4 M M d' I� N CO 4,.._ aO0 > CO• ... N N M M d' CO r a0 O) ' ' _ M 1- N. r N CO U) co 4 M co O) CO U) CO Q co O 0) co D CO •,- U) N N- N CO D) CO (D M ,- 00 CA CO CA co M N co N M ('M N M CD ('M CM Ci O co W N. N. CD N- N C- co COO r IMf) M 0 a0D C\I. . CO O N M LO CO P CO C) O N M V C1) co co (A N N N N CO N N .0 ^ CO M M M M O CD N- (A CO U) CO CO I� N- 0 LO I Cp t` U) CO CD N CO N O N 7 0) 4 4 4 4 CO N CA I-- 4 co CC) co h O co co a0 0 co O co co U) E 0) 0 M M M C7 CM 4 U) 4 4 N- N U) CD U) 4 CO N-1 CO N- co Cn O O aD 4 M O 'O o 0 0 0 0 "— 0 0 0 0 0 0 0 0 0 0 O - 0 0 0 - — 0 0 0 C 0 C d p N co N U) co co — Q C) co O CDD N CO N- 0V CO N- O co co co N CL0 O CO IC O O O O O M rt 0 U) U) CO CA O — N CO CD CA O N N N CO M co M CO O cri C 0) t ^ 0 CD N N O) O M M r"". Cf) U) N- O) U) CO 1' CD 1' co M CO CA N- L- r+ O O CD 4 0 N- N- Cp a0 N- N N O) M N 1' CO '- O C. CO M co 1- N CO Q R3 N CO CD aN0 CO CD M N oo co co co NN COD CO M CC[ 0 1' 1- M co M N 0 F- 0) Q ,- N M v U) co N. a0 O ,- . ,- N C) ' tf) CD N- co O N N N N N co co 0 w fY D CO N N _j O 0)) CNM N N. N. CO M M co LO N tM N COO - 1.0 1- CO - N N 0 00 — M N N N Q O O O O O O A- O O O O O O O O O O O M O 0 0 0 O A- 0 0 G) , to co N n 0 CO N N 0) OD CO M M N 0) O) (.,) CO CO 1- N- N CO CO 0) • ^n CO N O CV 7 7 co. M CO to N- N. A- O CD M CO N CO O) O to 0) 6 to M $ 0N M O 0M + CD M N NY 0 O N N M M CO M O) 0) O O N r O O Lo O O N 0 N N M CO N ^O O O O) 0 N 0 0 CO CD V) N 0) 0) O N_ r- Z = 00 to N n to O) Ct7 j O A- ^ N- N MM - O t6 O 6 M MM O4 + ... M 0 O O N N M OM O 0) to D O C aN D 00 so O OO C, CD ^ N M N 0) N N N N O Iv V O .-.COD 000 0)) N 00) 00) O co C6D to d0' O O CO t6 N R. O N to O O to M .- CNO M• LLI T z; = r 00 0 O n n O M CD O) N 4 M N to O CO CO to M M N O O• C) V 0) O N M O CO CO O N M to CO N. O M to N- O) M to N- O) O F-' o o v,- N N N N N N N N M M M M CM C`') CM M � to to to to to CO W Q , � � O Y co M v M CO O) to v co 0) O) v to N O CO N N O 1- CO to CO O O Q ^N r- co O CO CO co r- .- N N CO N M CO CO CD O 0 to M to CD 0) 8_ V V , pi M O O) ON v N 00) 4 to N O W COO M M 00) COO v N C UC) N ai O 4 COO M M v N N N N N N M CD M M CN% M M CO M M M M M CO 1- 1- MV 4- L _ _ •' ^N 0 O CO N O) CO N- N O) 0 M M M N N M to N 5C to O M st to - CO 0 O) N V; `— M M 0 CD O O O 4- 0 0 0 00 E 'C O O N O O O O 0 0 0 0 0 0 0 0 0 0 0 0 0 7- 0 0 0 0 0 0 0 0 C o r ^to M CO O) to co co 0 O) M M N to CD 0 CO cc?,) O) t` 0 R O N to to 1� co v d' to Lo N a) Cfl v 00 O CD 0o CO sg N O 0 aD N C d O O O O O CO O D O O O O O O O O O - O O O O O O O 6 O ti N � co co co co co co co co M co M M co co co co co co co co co co co co co M co co co C i t N M INO M (COO co N - N 0O O N 00) 1- M _. N. V N CM N. CO N co O CO O COO 0 Q. N CO CO O O) N 00 to 00 co O CO N M CA C6 . N CM O CO .- N Co v N $ 000 00) 0 0 0 N M tf CD N. CO 0) O N M U CO r CO N 0 0 0 N N M Asa)Q N N N CO M M co co co co co co co co 'ct to to to to to N N y O O CO 4 co V co N N CO N co M co C[ M M CV N C COO N- CO N O O O O O O O O O O O O O O O O O O O O O O O O O O O O O d U) co N CD I- N- CD I- N CO CO CO CO N CO I- M C 0) CD OD I- CD . U) I- 0) ' U) N CO CD N C co N U) co C N C N U) . M U) O U) e- CD O O (O O CD N O M 0) C M O M M 0) U) CD N CO O C 0) M O UJ+ M M C C1� CO CCD COO N ODD CO C 0) 0) co co C N N co M V CO (M L CD CD N- N CO + N N N N N N N N N N N N N co co co co co co co M co co co co co co co co co co U) CO U) 0) C C N- CD N- C CO - U) U) h CO U) C co co N- CO CO O 0) CO O C CO U) O O N- U) O A- CD CO N OD C CD 0) Nr U) N ~C O O O C O C O U) U) Cf) 0) M CO O N N: CD O M O 0) N U) M Z - U7 O CD N N- CO CO C 0) n O U) N- N N- CO 0) C O U) CO CD N h 0) C + v N CO CO C O LO CD CD N CO CO 0) 0) O O N CO M - C U) U) CO CO CO N N N N N N N N N N N N N N CO CO co co co co co co co co co co co co OA L _ N To C co CO CO C CD N- Nt N N CO CD CD U) N- CO 0) 0) N N N O CD CO C V O —O co O CO CO C 0) CO I- O U) N O C U) 0) co CO O U) CO N CO O U N O CD W �' V N CCD N- 00) M N CO r 00)) O N C u N- co O N CO U) N- CD O N N CN CI 4-+ d d d —CO CO co CO CO N. N. N. N. N. N co OD co co co 00 O) O) O) O) O) O O O O O 7 ce N LO M OD CO CO 0) CO U) CO I CO N.- CO I,- N- U) M N N C CD O• O 0 O U) N M O) co N N N • CO N- OD U) 0) - - N- 0) O CC) 0) 0) 8_ 0 > =---0„c6 N 0) N 0) O C O OD CO C C N O CO CO N O CO CV N ..i f� CCO 0)) O O N M U) CMO ON- U) CO 6C) O O N co C VO' CD (CD N- � CCD 00) C C U) U) U) U) U) U) U) U) U) U) U) CO CD CD CD CD CD CD CD CD CD CD CD CO L _ _ • ' )CO 0 CO N- CO CO N N- CO OD N M U) CO CO 0) CO 0) U) N CO CO co N• E a)CO O CO M C CO CO CD I- U) CD CO N- - C") I- N N CO CD - N O CO U) E d CD NO CD CD Cf) U) O U) 00 CD O O CO U) CO CO CO F- N CD f- O O ▪ v 0 0 0 c 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C O lw'0 U) M N U) N- CMO COO N- co co N- N CD M M CND CO ' M O0) N. co N M N CD C) CCD C M M CD O (O CO CD CO M CD O M O CO U U U U) M C M C ' co co co co co co co co co co CO CO CO CO CO CO CO CO CO CO M(.) C) N- O) C 'Cr 0) CO CD OD U) U) N N- 0) C C CD M M co I- N U) N C C") O co. 7 C U) N O O U) co 0 7 I- 0) (O '7 N- N- M N- O 3 C. CO CO N O C'') 0) U) M O M O CM h O O CO N- CO 0 C 0) U) N 0 I- M d 0 (Of) COO N CO C 0) O O N M U) co M 0)) O N N M C U) C COD OOD U7 U) U) U) U) U) to CD to CO CO CO CD O N- N- N- N- OD OO _.. .... . .. ... ...... M N it U) O N N- N M N N N CCOO N M CO N O LO N CCOO CO N. COD N U O M CO 4 CV CO i Q O O A—1 0 0 0 0 0 0 0 0 ,— 0 0 0 0 0 0 0 , 0 0 0 0 co 1 j �.�.COO CO N. CO 0 O N. CEO CCO N CO CO M 0)) M N A- O CCO O CO N O O CO CO CO N CO CO N N 6) O h M 6 4 CO h 4 O CO — h N O O N O •• O 6) • • • W OO N O CO M M 4 V 4 4 4 co co 4 4 4 co 4 4 4 4 4 co 4 4 U co O CN CN CO co co CO 4 ,_ O co a) N CO CO CO h h 6) 6) CO 4 O C`') CO 0) N CV h V 6) co N N CO CO N CO A- O CV CA 4 CO 6) O CV h CO 4 4 6) h N. O M N N Z N d0' ..... O _O N co U 4 N 4 O ) N COO O COO N N CO CO C 4 60) 4 U O O + ._.M co co M V 4 4 4 4 4 4 4 4 4 4 d' 4 CO V CO 4 4 6 U O U CO O . co O CO C• d) h h co O U M . N co M O N M N N- CO h co N- N CUO COO A- . CO CV CD COO COO h I..LJ T t (Q co O O N CO LO ,_ CO CO 4 CO N 6a) O N- 4 co N- N O N M 4 co co M 4 ai COO ,�„I 6 w d 0 A- A- r- A- ,_ N N CV N — N CO CO CO CO co co 4 4 4 4 4 4 0 0 0 6 Cr O c N- CO CO CO O CO CO CO N N 6) co h 0 CD h h 0 N- O O CO O co O O N O 6 0 CO O 6) h N O 6) M N- O v- h to 4 O M '4 O 6) Q) 6) O h CO 8_ U , CO C) _M M N CO 4 N N N si N O CD 0 _M '— h CNf) N O N- t) M O COD 0 N_ N_ v COO Oh h N h co N- co N h N- CO N. N O O U CON U U) COD U U CON- COD COD O a) a) =▪ 3)N U O .c.7, N 8. O _ C_ `- O Q1 h M 6O 7 O 6 4- M O OO a�D O_ N- n O N- Q _h h 1 M E W h h CO O h CO h h h O O h CO CO O CO CO CO to 6 v M v CO h h h O 6) ▪ 'a 0 O O O O O O O O O,— O O O O O O O O O O O O O O O O O O O v C O S U O N CC d a) CO h 4 O N N g co m N MV N h ,z,. M O N 6) 4 M N. V _ -a 4 4 CO CO 0 M CO O h O O N h CO CO 0 CO M () h CO CO CO CO O O O O O '� ........ co co co M co co M co co co co co co co co co M co co M co co co co co co C G1 O M CO N N- CO 4 CO '4 CA O N N CO 4 CO co co a) co CO h CO CO CO L •C Cr) O 4 CD O CO O 4 Cr) O O C6 h CO O co CO co O 6) • O O) 6) O h h w 3 C)• 65 N CD h N O 4 O O N co U) O O O 6) O O_ O O O N CO 4 0 0 w C8 N M CO O 4 U co O N- co O O O h N M 4 CU) CCO N- co O O C N N M V in C COO N y G co co co co co co co co co O O O O a) a) a) a) a) 6) O � 0 0 0 0 0 0 0 0 N 1 G M U CO M v ". co M co 7 M O v co O co N. co N M co O m a) M CO CO U CO O v O cp,- O O N O O O ,- ,- O ,- N O N N O O r- 0 0 d j �„�(N CO 0 (N (N 60) CO CO co O N N O N CCOO O (N 1- CO O N O ,- O N O N- M CO . 0 O CO 4 0) U) o O 4 N- N- CO O M 0) N- CD O N N d' 0) M CD co + co CO C) O (00 N- COO COD 0) 00)) co co '- 0 N co N co co 0V OV CNf) O CO CO 0 co CO O CO O 0) 00) + Cn co O co co co co co co CO CO O Co co CO co CO Co CO CO CO O Co co CO CO CO Co CO . I .. N. N N. N M N. CO CO CO 0 ~ Lc j LO COO 4 4 N N CO r- CO N 1- Ch N- y M Cr) co co N- O co co M N f� CA 4 CD c M CO 0) M 0) O 0) 0) 1- 0 CO O 0 CD Z co LO h N co CA CO 0 CC) C. CD M CO 0) N CV N. M 0 4 LO CO CD N- N M + U) co O CC) CO Low U) U) CO 0) 0) O O O co N N M M CD LO CC) CD CO co N. O CD CC) In Cn Cn 117 Cf) LC) Cn Cn In O CO CO CO CO CO CO CO CO CD O O O CO O CO . j to 0 .-.N- 00) M CO V 0 0O) U 0 N- 4 CD OD 00 ,- CD O N- CO 0 - 0 CND N cNr) CD LO COD CO O N - wr to CA Cn O N 00 M CD Cn h CC) M 0) 4 r- 4 0) M co M co co co N Cn N dco ° M O ° O o n a D N N M M C ,4-0 d co CO O CO (OWN- n n N- CDCD CCD CD CD CD CD ,_ . (1) c > W . . i i ' . . . s . , . . . . . . 1 . . , . . , C d a .�C 5 re O Y CC) CO N N N 0 M O CO CO 4 CO 0) 8 Cn CO 0 CC) Cn N Co 4. O co. Cn co f— r- 0 co O co O O 0 .�O c,,,_ M N O 0,L0 O Co N N _ _ _ - V V + O to N 0 O CO M O N_ 0 O M O O 00D CCOO M O COD (.7) M _O OM) N- • V 0 0 Ci N N N 0�) N 00i N 0 0 O 0 0 0 0 O O O O N N O O ,- . s ,� _ _ 0 0 co 0 CV 0.CO 0) M V) CO CV M 0 CO CO O CD N CD 0) M 7 C) N- 06 N O CO 0) O 0) M CO CO N M O O CC7 N M CD M CD 6 (p II? • 10 O N O O O 0 0 0 0 0 0 O O c, O o N N N g g N N N N N 0 47 v C 0 ..� CSC co co n Co ' co M co co co co M N- ' ' v co N CD M — CO CO N. LO 0) M 0 `- N c -0 M co co M M M M co O M M M M M Ch M M M M M M 4 CO') CO O M M M M M M V C . 6. s CD 0 4 . CO 00)), n 00) 0) CO 0 LO cr) M N ,- M 0 M N. 4 0 CD N- 00)) CNn 00) CC) N ' CMO U NIX) M M N N n _M O N M M COO COO Cn _M N N CO O_ CO ...0 ' N C LO N CO O ,- N M CO st 1- CC) CO f- co 0 0 N M 1- O W 0 N N N CV CV N N N N N N N M M M d) M CO 2 Nn N cu J co c co CU) O V) O 00) CO O - CCO co COO CO 0) O Q a1 0 O r) CV cM Cn M Ci N CV a) 0) CO 1 M N- CD N- CC) M CC) 7 N 0) 0 N- R O CO N- O O M O CO N- N C) CO O LLI O N N N 7 N .— M N CO CV C) C O CO C (A CO C) N- N N + O N N M M LO CO CO N- c0 c0 N N- N- N— N- N- N- N- N- N- N- N- N. N. N. .-.(00 0) CO COO COO COO CO c00 N- M M O M O 1- Z - CO M (00 C)) (ND co U) O CO CO N CO CO 0)) 1- � 00) + C0 0) O O O 7 N N M CO IX) CO CO CO CO CO CO N- N- N- N- N- N- N- N- N- N- N- N- n N- Q) - C N CO CO 1- h 0) CO LO 0) N CD N C0 O CO CO O ...CO N N Cn h 0 Cf) O CO O O M M 0) CO LJ.J T i+ CO O CV N- O Cr) CO co N- 0i (n CO C) CO CO d o) d CC0 CC0 CC0 CC0 CC0 Cp CO CO CO N- 03 c0 c0 0MO CO N- CO N- - lL Q > 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 - d 6 .�L c NY O Y CO 0) CO N M N 1- CO 0) 1- CO CO CO N- 0) - O O ...�CO CO CO N- N .7 CO N� 0) O � 0) M LO M CO N V V > N- co CO CEO C)) CCOO v N co N v N CO N M N N- O co cr �t CO C0 CO N- CO O O N .4- .1- N N N N N t .. CO N- 1' '� CO N- 0) CO 1- 0 CC) O CO h O n N- 3C C)CO. N` CI) CO CO N- LO N r- M N- N M CO E N N (Ni CO 0 CO U) C) O CO Ni CO r- O CO CO •N O O O) O) O) O) O) 0) 0) O CO N- N- CO CO CO U) LC) C O CNS d CO N CO CO COO N- M O CO co M U)) N- co 0 co 0 co co•C CM CV N (Ni �!' M N� CO N: CO co C') •CO '- v co co co co co co co co co co co M co M M M M C dN- Cn O CO 1- LO LO N CO 0) CO O ▪ .0 „� O 0 CO O O N- O N Cn N 0 '•-• 7 Q Ili O M CO CO O CV LO N- N n N Vi O Cl) CA — O (0 d COO COO N- CO 0 CO O 0) co co N. CCO N- CO C 0) O O CV Q M M M M M - 7 1- `- 1- 1- 1- LO CC) 2 CD N d CO CO CO O O CO O C") p CO CO U) r r U) Ln r E co co r cr O U) LO N r r O co co O O co J c'') C'') U) 4 4 C') C'') - 4 C') U) U) U) LC) U) U) U) U) m , H N co O O co co 0) co co N- O CD N 0) LO LC) 0) U) CC') co o co co 1 co in CD co O co N- CO !, CD N. N co co 0 co 0 Ui CI Z O O o O O O O o O O O O O O O O O O M • 6 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Wo o 00 O O O o O O o co co o O O o p i— CA CA C3) N- N- N- C` N N- N- 4 4 V 4 C") M r p Q N CV N N N N N N N N N N N N N N N N O U) O o O O O O O O O O O L[) O O O p c') N N 4 4 4 4 4 4 C` N- N CO N- N- O p _ co CO CO co CD CD CD CD CD CO CD CD CD CO CD CD N-O • O O U) CO U) d' N r CO CO LO r CD C'7 co N- co O L O CD CO U) CD CD CD CD CO CD Lf) CD CD CD N h N- CD O Cl) C to W > 4-' 1:” V N N N N N N N N N N N N N N N N N N lL LL O O O O O O O O O O O O O O O O O O 1; J i i i i i i i i i ca. u- O Y • O °o CD In Ill CD r` as N rn o r rn rn ca) co co rn o r _ U V Cl) N N N r r r N r (NI N N N N r N LO CO CO CD N C'•) U) U) U) LO CD N- N W N N N 0 N- CD CD r O O N O O N N r N r r c--:, r r r r r r r r r r r r r r r r r r O d co N- CO CO O N- N- 0) CO CO r CO CA co CA O co >- N N N N r r r r N O U) . ' > O O O M C'') r r r r O O O r O LC) CO cr O a CO CO C'') N N N N N N N (N N N N N N N N CV N. N M O O O U) O O CY) CO O N- N r N- N- N- O M O A CO I-- ` CO CO CD CO I- N- CD CO CO - CV r r r N r O O O O O U O LO U O O O O v} M t -0• > N CO C CO C7 CO CO CO V. nr C7 CO '' t = 2 A ; A A A A O o 0 o A C7) (A O O O A CD 2 O O O O O 0) N r O CD N- C\ r O O O r O V) H CO d r r r N N) N-M N- N- O 'd) U O O l) O o U) co W N N N N N N N N N N CO CO .4- U O 0 U) r O . -5 CO CO C`') CO M CO CO CO CO CO CO CO CO CO CO M C'') CO CO CD W O O O O O O O O O O O O O O O O O O O -0 2 Q N N N (Ni N N N N CV N N N N N N N CV N N O OL • 0 CD 1 O (A O r N CO U) CO N- O Cr) N N N N A- () m C N- N- N- N- N- N- N- ti C` N- N- N- N- N- N- ti N- N- N- W - Ct CI o Q c v co▪• U2 N a < o I X m ZO q~ >> H M G X Z Q Q O co cc U cO m N. tf) CO N N >O r d c, Q ce n Cn N co NI- a- N 0 N W I— w co in W °r o LL n O co co I- CU 0 N °v a- a- a- W >, 4--J C Z N O �. - W a CV CV 'ci- as=' 3 0 Y Et O o 0o V _co H Q c CV N -) ~ c CO X Cl) co a) Z co _ oo ro fn o M NI- N W co Lo Lo u W0 LLI CO I < 0 I 0 O 2 I D I I 0 w IY W u) to u) N N N I� — y CO cfl CO m d. H O N M m Z Nr Cook Inlet Energy_ Cook Inlet Energy RU-7A 5 DAILY REPORTS 28 CANRIG Daily Report Page 1 of 1 Cook Inlet Energy ...415‘.1\111R1 117aee.r.ev.:Tw,rre.e..rcv:v 1.,-... RU-1A RU-1A REPORT FOR K.Carter/W.Johnson DATE Tn2013 DEPTH 12304' PRESENT OPERATION Rig Repair TIME 0300 YESTERDAY 12304 24 HOUR FOOTAGE 0 CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 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 MBL pH Ca+ CCI 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 Work on draw works EPOCH PERSONNEL ON BOARD 4 DAILY COST$3340 REPORT BY D.Muller file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CooklnletEnerg... 7/13/2013 Daily Report Page 1 of 1 Cook Inlet Energy #2 DAILY WELLSITE REPORT SIC RU-1A REPORT FOR Keith Carter/Warren Johnson DATE 7/8/2013 DEPTH 12304' PRESENT OPERATION pumps off TIME 0300 YESTERDAY 12304' 24 HOUR FOOTAGE 0 CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 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 9.2 VIS 135 PV 30 YP 25 FL Gels 17/22/26 CL- FC 0/2 SOL 6.0 SD 0.10 OIL 63.0/29.0 MBL pH Ca.. CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 86 @ 0145 hrs @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT 0 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Finish rebuilding drawworks.P/U whipstock and milling assembly.RIH 1/11,234',filling pipe/breaking circulation every 3000'. EPOCH PERSONNEL ON BOARD 4 DAILY COST$3340 REPORT BY D.Muller file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnergy\... 7/8/2013 Daily Report Page 1 of 1 Cook Inlet Energy Morning Report 43 DAILY WELLSITE REPORT 1�j RU-1A REPORT FOR K.Carter/W.Johnsen DATE 7/9/2013 DEPTH 12260' PRESENT OPERATION Milling window TIME 0300 YESTERDAY 12260' 24 HOUR FOOTAGE 0 CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 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 9.3 VIS 137 PV 30 YP 24 FL Gels 16/21/25 CL- FC 0/2 SOL 6.5 SD 0.10 OIL 62.5/29.0 MBL pH Ca. CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 33 @ 12260' @ 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 Continue RIH with whipstock 1/12,275'and orientate.Sat down 38k,unsure if whipstock set.Pump dry job and POOH to surface with no whipstock;TIH 5/11,329'with milling SUMMARY assembly. EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY D.Muller file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CooklnletEnergy\... 7/9/2013 Daily Report Page 1 of 1 Cook Inlet Energy , #4 DAILY WELLSITE REPORT 17a.,...I NC.Tn.-t∎v.s...,:,1-,-,. RU-1A REPORT FOR K.Carter/W.Johnson DATE 7/10/2013, DEPTH 12267' PRESENT OPERATION TIH TIME 0300 YESTERDAY 12267' 24 HOUR FOOTAGE 0 CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 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 9.4 VIS 100 PV 30 YP 24 FL Gels 16/22/25 CL- FC 0/2 SOL 5.9 SD 0.10 OIL 68.1/31.9 MBL pH Ca* CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 0 @ @ 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 Continue RIH with milling assembly 1/12,261'and tag top of whipstock;mill window t/12,267'.Circulate BU,pump dry job and POOH.Slip/Cut 120'of drillline,P/U new milling assembly SUMMARY and TIH 1/4,000'. EPOCH PERSONNEL ON BOARD 4 DAILY COST$3340 REPORT BY D.Muller file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CooklnletEnerg... 7/10/2013 Daily Report Page 1 of 1 Cook Inlet Energy ■� #5 DAILY WELLSITE REPORT �.i,V V1Fta� 1,..E.r.1 i.rc:Tw.,,I Neer.,:,f_r“. RU-1A REPORT FOR K.Carter/W.Johnson DATE Jul 11,2013 DEPTH 12289' PRESENT OPERATION TIME 0300 YESTERDAY 12267' 24 HOUR FOOTAGE 22 CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 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 249.8 @ 12284' 5.4 @ 12270' 61.5 54.9 FT/HR SURFACE TORQUE 7478 @ 12282' 5940 @ 12273' 6489.1 6662 AMPS WEIGHT ON BIT 0 @ 12289' 0 @ 12289' 0.0 0 KLBS ROTARY RPM 136 @ 12269' 126 @ 12289' 129.9 126 RPM PUMP PRESSURE 3158 @ 12268' 3052 @ 12289' 3085.3 3052 PSI 1 DRILLING MUD REPORT DEPTH MW 9.3 VIS 85 PV 23 YP 17 FL Gels 11/15/19 CL- FC 082 SOL 0.10 SD 6.5 OIL 64.0/27.0 MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 78 @ 12287' 6 @ 12274' 26.6 TRIP GAS CUTTING GAS 0 @ 12289' 0 @ 12289' 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 15194 @ 12287' 1201 @ 12274' 5133.8 CONNECTION GAS HIGH ETHANE(C-2) 0 @ 12289' 0 @ 12289' 0.0 AVG 6 PROPANE(C-3) 0 @ 12289' 0 @ 12289' 0.0 CURRENT 0 BUTANE(C-4) 0 @ 12289' 0 @ 12289' 0.0 CURRENT BACKGROUND/AVG PENTANE(C-5) 0 @ 12289' 0 @ 12289' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous siltstone/Sand PRESENT LITHOLOGY Tuffaceous siltstone/Sand DAILY ACTIVITY Continue RIH with milling assembly to 12,209'.Wash to window at 12,263'.Mill from 12,263'to 12,290'(window plus 20'new hole);circulate B/U at 12,205'.LOTMD 12,290'/ND SUMMARY 10,264'@ 2920 PSI,EMW 13.89.POOH,UD BHA 0286'. EPOCH PERSONNEL ON BOARD 4 DAILY COST$3340 REPORT BY D.Muller file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnerg... 7/11/2013 Daily Report Page 1 of 1 Cook Inlet Energy , #6 DAILY WELLSITE REPORT RU-1A REPORT FOR K.Carter/W.Johnson DATE Jul 12,2013 DEPTH 12289' PRESENT OPERATION Assembling BHA TIME 0300 YESTERDAY 12289' 24 HOUR FOOTAGE 0 CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 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 9.3 VIS 90 PV 23 YP 18 FL Gels 10/13/17 CL- FC 082 SOL 6.4 SD 0.10 OIL 64.0/27.0 MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 35 @ 1840 hrs @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG 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 Service and lubricate rig;make up and RIH with milling assembly.Wash through window,rotated through 4x and slid trough 2x to bottom;pump dry job and POOH 1/5740'. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3340 REPORT BY D.Muller file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnerg... 7/12/2013 Daily Report Page 1 of 1 Cook Inlet Energy #7 DAILY WELLSITE REPORT R. lluai.a..nrca TwK-t•rv.i.zk:v 1_,-,. RU-1A REPORT FOR K.Carter/W.Johnson DATE Jul 13,2013 DEPTH 12315' PRESENT OPERATION Drilling Ahead TIME 0300 YESTERDAY 12289' 24 HOUR FOOTAGE 26 CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 6.75 HOBS:EM65D 12075067 6013 12289 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 99.8 0 12295' 1.1 0 12314' 20.8 1.70392 FT/HR SURFACE TORQUE 6662 @ 12289' 5547 @ 12304' 2633.2 5616.00000 AMPS WEIGHT ON BIT 42 @ 12295' 13 0 12300.' 27.8 16.60000 KLBS ROTARY RPM 126 0 12289' 25 0 12303' 19.8 29.00000 RPM PUMP PRESSURE 3365 0 12314.' 2878 0, 12299' 3085.8 3357.00000 PSI DRILLING MUD REPORT DEPTH MW 9.35 VIS 85 PV 21 YP 18 FL Gels 10/13/19 CL- FC 0/2 SOL 6.4 SD 0.10 OIL 64.0/27.0 MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 43 0 12289' 2 @ 12295' 7.1 TRIP GAS CUTTING GAS 0 @ 12315' 0 @ 12315' 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 8614 0 12289' 1055 0 12293' 371.9 CONNECTION GAS HIGH ETHANE(C-2) 0 @ 12315' 0 @ 12315' 0.0 AVG 8 PROPANE(C-3) 0 0 12315' 0 @ 12315' 0.0 CURRENT 8 BUTANE(C-4) 0 @ 12315' 0 0 12315' 0.0 CURRENT BACKGROUND/AVG 0 PENTANE(C-5) 0 0 12315' 0 0 12315' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand/iltstone PRESENT LITHOLOGY 85%Sand/15%Siltstone DAILY ACTIVITY SUMMARY Continue POOH to surface with milling assembly and lay down.Make up 6 3/4"drilling BHA and RIH on 4"DP to bottom;drill/slide 912,309'. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3340 REPORT BY D.Muller file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CooklnletEnerg... 7/13/2013 Daily Report Page 1 of 1 Cook Inlet Energy DAILY WELLSITE REPORT ■ANfgIG RU-1A REPORT FOR Keith Carter DATE Jul 13,2013 DEPTH 12376' PRESENT OPERATION Drill Ahead TIME 1500 YESTERDAY 12310' 24 HOUR FOOTAGE 66' CASING INFORMATION 9 5/8"@ 6,986 7 5/8"@ 6,712' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 6.75" PDC EM65D 12075067 6x13 12,290' 86' 9.5 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 556.3 @ 12333' 0.6 @ 12371' 29.8 30.01100 FT/HR SURFACE TORQUE 10556 @ 12349' 5358 @ 12318' 4710.2 5766.00000 AMPS WEIGHT ON BIT 40 @ 12333' 3 @ 12371' 172 12.80000 KLBS ROTARY RPM 41 @ 12356' 13 @ 12349' 26.0 40.00000 RPM PUMP PRESSURE 3365 @ 12314' 2870 @ 12321' 3104.8 3070.00000 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 39 @ 12329' 5 @ 12312' 15.8 TRIP GAS NA CUTTING GAS 0 @ 12374' 0 @ 12374' 0.0 WIPER GAS NA CHROMATOGRAPHY(ppm) SURVEY NA METHANE(C-1) 7388 @ 12329' 874 @ 12374' 2766.1 CONNECTION GAS HIGH NA ETHANE(C-2) 48 @ 12330' 0 @ 12316' 13.9 AVG 16u PROPANE(C-3) 0 @ 12374' 0 @ 12374' 0.0 CURRENT 9u BUTANE(C-4) 0 @ 12374' 0 @ 12374' 0.0 CURRENT BACKGROUND/AVG 9/16 PENTANE(C-5) 0 @ 12374' 0 @ 12374' 0.0 HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,tuffaceous siltstone and tuffaceous claystone PRESENT LITHOLOGY Sand,tuffaceous siltstone and tuffaceous claystone DAILY ACTIVITY SUMMARY Drill and slide ahead from 12,330'MD to 12,376' EPOCH PERSONNEL ON BOARD 4 DAILY COST$3,340 REPORT BY Steve Pike file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CooklnletEnerg... 7/13/2013 Daily Report Page 1 of 1 Cook Inlet Energy #8 DAILY WELLSITE REPORT IR'G Isu,,.,..-Tw..>,H.>,....-v 1-,,, RU-1A REPORT FOR K.Carter/W.Johnson DATE Jul 14,2013 DEPTH 12405.00000 PRESENT OPERATION Drilling ahead TIME 0300 YESTERDAY 12315.00000 24 HOUR FOOTAGE 90 CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 6.75 HOBS,EM65D 12075067 6,03 12289' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 19.5 @ 12413.00000 0.6 @ 12371.00000 11.5 67.17719 FT/HR SURFACE TORQUE 10556 @ 12349.00000 5358 @ 12318.00000 4048.0 5445.00000 AMPS WEIGHT ON BIT 58 @ 12392.00000 3 @ 12371.00000 24.7 29.70000 KLBS ROTARY RPM 79 @ 12405.00000 1 @ 12393.00000 26.2 79.00000 RPM PUMP PRESSURE 3357 @ 12315.00000 2128 @ 12382.00000 3018.7 2945.00000 PSI DRILLING MUD REPORT DEPTH MW 9.40 VIS 70 PV 24 YP 18 FL Gels 12/16/22 CL- FC 0/2 SOL 6.2 SD 0.10 OIL 64.0/27.0 MBL pH Car- CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 39 @ 12329.00000 6 @ 12315.00000 14.2 TRIP GAS CUTTING GAS 0 @ 12405.00000 0 @ 12405.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 7388 @ 12329.00000 821 @ 12386.00000 2026.6 CONNECTION GAS HIGH ETHANE(C-2) 48 @ 12330.00000 0 @ 12316.00000 9.9 AVG PROPANE(C-3) 0 @ 12405.00000 0 @ 12405.00000 0.0 CURRENT BUTANE(C-4) 0 @ 12405.00000 0 @ 12405.00000 0.0 CURRENT BACKGROUND/AVG PENTANE(C-5) 0 @ 12405.00000 0 @ 12405.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous Sillstone,Tuffaceous Claystone,Sand,Coal PRESENT LITHOLOGY 80%Coal/15%Sand/5%Tuffaceous Siltsone/Claystone DAILY ACTIVITY SUMMARY Cuntinue rotating and sliding from 12315'to 12405' EPOCH PERSONNEL ON BOARD 4 DAILY COST$3340 REPORT BY D.Muller file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CooklnletEnerg... 7/14/2013 Daily Report Page 1 of 1 Cook Inlet Energy /� �± DAILY WELLSITE REPORT CANI1V f]uer.a.rr.r..T.a-,1-1 N.,r_,.k:v 1._7-1.. RU-1A REPORT FOR Keith Carter DATE Jul 14,2013 DEPTH 12437' PRESENT OPERATION Drill and slide ahead TIME 1500 YESTERDAY 12406' 24 HOUR FOOTAGE 31 CASING INFORMATION 9 5/8"@ 6986'75/8"@ 12269' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 6.75" PDCEM65D 12075067 6x13 12290' 147' 20.25 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 16.0 @ 12425' 0.4 @ 12413' 12.5 2.23577 FT/HR SURFACE TORQUE 7419 @ 12418' 5433 @ 12407' 4415.5 6259.00000 AMPS WEIGHT ON BIT 49 @ 12429' 19 @ 12435' 33.8 28.90000 KLBS ROTARY RPM 78 @ 12408' 2 @ 12428' 50.4 55.00000 RPM PUMP PRESSURE 3500 @ 12437 2729 @ 12430' 31052 3500.00000 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 13 @ 12413' 4 @ 12434' 10.3 TRIP GAS NA CUTTING GAS 0 @ 12437' 0 @ 12437' 0.0 WIPER GAS NA CHROMATOGRAPHY(ppm) SURVEY NA METHANE(C-1) 1402 @ 12413' 384 @ 12434' 1030.6 CONNECTION GAS HIGH NA ETHANE(C-2) 18 @ 12406' 0 @ 12431' 6.6 AVG 10u PROPANE(C-3) 0 @ 12437' 0 @ 12437' 0.0 CURRENT 5u BUTANE(C-4) 0 @ 12437' 0 @ 12437' 0.0 CURRENT BACKGROUND/AVG 5/10 PENTANE(C-5) 0 @ 12437 0 @ 12437' 0.0 HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,Tuffaceous siltstones,and tuff aceous claystones PRESENT LITHOLOGY Sand,Tuffaceous siltstones,and tuffaceous claystones DAILY ACTIVITY SUMMARY Drill and slide ahead from the midnight depth 0112406'MD to 12437'MD. EPOCH PERSONNEL ON BOARD 4 DAILY COST$3340.00 REPORT BY Steve Pike file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CooklnletEnerg... 7/14/2013 Daily Report Page 1 of 1 Cook Inlet Energy , 49 DAILY WELLSITE REPORT RU-1A REPORT FOR K.Carter/W.Johnson DATE Jul 15,2013 DEPTH 12470.00000 PRESENT OPERATION POOH TIME 0300 YESTERDAY 12405.00000 24 HOUR FOOTAGE 65 CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 3.75 HDBS:EM65D 12075067 6x13 12289 12474 185 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 36.0 @ 12425.00000 0.4 @ 12413.00000 10.6 1.94115 FT/HR SURFACE TORQUE 7782 @ 12463.00000 5433 @ 12407.00000 4864.1 5767.00000 AMPS WEIGHT ON BIT 49 @ 12429.00000 6 @ 12439.00000 25.2 23.50000 KLBS ROTARY RPM 80 @ 12448.00000 2 @ 12428.00000 55.6 28.00000 RPM PUMP PRESSURE 3703 @ 12443.00000 2729 @ 12430.00000 3254.3 2997.00000 PSI DRILLING MUD REPORT DEPTH MW 9.35 VIS 70 PV 21 YP 17 FL Gels 10/12/19 CL- FC 0/2 SOL 6.1 SD 0.10 OIL 64.0/27.0 MBL pH Cad- CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 13 @ 12413.00000 4 @ 12467.00000 8.5 TRIP GAS CUTTING GAS 0 @ 12470.00000 0 @ 12470.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 1402 @ 12413.00000 343 @ 12434.00000 609.7 CONNECTION GAS HIGH ETHANE(C-2) 30 @ 12445.00000 0 @ 12431.00000 7.1 AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 70%Tuffaceous Siltstone/30%Sand PRESENT TUFFACEOUS SILTSTONE:MEDIUM LIGHT GRAY WITH DARK GRAY;MOSTLY SOFT TO SLIGHTLY STIFF;BRITTLE;IRREGULAR FRACTURE;AMORPHOUS CUTTINGS HABIT LITHOLOGY SITH SOME SLIGHTLY BLOCKY;EARTHY DAILY ACTIVITY SUMMARY Continue rotating/sliding 012,478'.Preparing to POOH. EPOCH PERSONNEL ON BOARD 4 DAILY COST$3340 REPORT BY D.Muller file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnerg... 7/15/2013 Daily Report Page 1 of 1 Cook Inlet Energy �r� #10 DAILY WELLSITE REPORT ■t1� RU-1A REPORT FOR K.Carter/W.Johnson DATE Jul 16,2013 DEPTH 12474.00000 PRESENT OPERATION TIH TIME 0000 YESTERDAY 12470.00000 24 HOUR FOOTAGE 4 CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 6.75 HOBS:EM65D 12075067 6x13 12289 12474 185 2 6.75 BAKER HUGHES:DP505x 7034894 3x16,2x18 12474 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 7.9 @ 12473.00000 1.7 @ 12472.00000 4.0 1.91134 FT/HR SURFACE TORQUE 5937 @ 12471.00000 4721 @ 12473.00000 6994.5 5660.00000 AMPS WEIGHT ON BIT 27 @ 12474.00000 23 @ 12471.00000 31.2 27.70000 KLBS ROTARY RPM 81 @ 12472.00000 28 @ 12470.00000 77.0 75.00000 RPM PUMP PRESSURE 3365 @ 12474.00000 2812 @ 12473.00000 3799.8 3365.00000 PSI DRILLING MUD REPORT DEPTH MW 9.35 VIS 83 PV 21 YP 17 FL Gels 10/13/20 CL- FC 0/2 SOL 6.3 SD 0.10 OIL 64.0/27.0 MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 5 @ 12471.00000 4 @ 12470.00000 2.5 TRIP GAS CUTTING GAS 0 @ 12474.00000 0 @ 12474.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 897 @ 12471.00000 506 @ 12470.00000 350.9 CONNECTION GAS HIGH ETHANE(C-2) 0 @ 12474.00000 0 @ 12474.00000 0.0 AVG PROPANE(C-3) 0 @ 12474.00000 0 @ 12474.00000 0.0 CURRENT BUTANE(C-4) 0 @ 12474.00000 0 @ 12474.00000 0.0 CURRENT BACKGROUND/AVG PENTANE(C-5) 0 @ 12474.00000 0 @ 12474.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 70%Sand/30%Turtfaceous Siltstone/Clayslone PRESENT LITHOLOGY TUFFACEOUS SILTSTONE:MEDIUM LIGHT GRAY WITH DARK GRAY;MOSTLY SOFT TO SLIGHTLY STIFF;BRITTLE;IRREGULAR FRACTURE;AMORPHOUS CUTTINGS DAILY ACTIVITY SUMMARY POOH 1/12,228'and pumped dry job.POOH 1/11,381 and repaired iron roughneck.Finish POOH;P/U BHA and RIH 1/10,532',filling pipe and testing MWD every 3000'. EPOCH PERSONNEL ON BOARD 4 DAILY COST$3440 REPORT BY D.Muller file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnerg... 8/16/2013 Daily Report Page 1 of 1 Cook Inlet Energy DAILY WELLSITE REPORT ■ RIV t?nrr.r.rer.a Tri_rru.ir..i.:v I.--rr.- RU-1 A REPORT FOR Keith Carter DATE Jul 16,2013 DEPTH 12793 PRESENT OPERATION Drill and slide ahead TIME 1500 YESTERDAY 12495 24 HOUR FOOTAGE 298 CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6.75 Hughes PDC DP505X 7034894 3x16,2x18 12475' 318' 9.5 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 76.9 @ 12648' 1.2 @ 12693' 42.1 49.75198 FT/HR SURFACE TORQUE 7215 @ 12684' 5027 @ 12695' 6208.6 6342.00000 AMPS WEIGHT ON BIT 46 @ 12500' 5 @ 12748' 16.9 24.70000 KLBS ROTARY RPM 79 @ 12793' 52 @ 12695' 69.0 79.00000 RPM PUMP PRESSURE 3125 @ 12761' 2703 0 12547' 2931.2 2704.00000 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Car- CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 72 @ 12594' 9 @ 12497' 21.9 TRIP GAS 33u CUTTING GAS 0 @ 12793' 0 @ 12793' 0.0 WIPER GAS NA CHROMATOGRAPHY(ppm) SURVEY NA METHANE(C-1) 6250 @ 12594' 582 @ 12497' 1912.3 CONNECTION GAS HIGH NA ETHANE(C-2) 51 @ 12594' 0 @ 12509' 16.0 AVG 22 PROPANE(C-3) 0 @ 12793' 0 @ 12793' 0.0 CURRENT 18 BUTANE(C-4) 0 @ 12793' 0 @ 12793' 0.0 CURRENT BACKGROUND/AVG 18/22 PENTANE(C-5) 0 @ 12793' 0 @ 12793' 0.0 HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,tuffaceous sillslones,sandstone,and tuffaceous claystones with thin lenses of coal PRESENT LITHOLOGY sand,tuffaceous siltstones,sandstone,and tuffaceous claystone DAILY ACTIVITY SUMMARY Drill and slide ahead from 12495'to 12793'. EPOCH PERSONNEL ON BOARD 4 DAILY COST$3,340 REPORT BY Steve Pike file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CooklnletEnerg... 8/16/2013 Daily Report Page 1 of 1 Cook Inlet Energy �+ #11 DAILY WELLSITE REPORT c 4 f lqIG RU-1A REPORT FOR K.Carter/W.Johnson DATE Jul 17,2013 DEPTH 13010.00000 PRESENT OPERATION Drilling ahead TIME 00:00 YESTERDAY 12474.00000 24 HOUR FOOTAGE 536 CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 12945.91 36.740 95.680 10785.31 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6.75 Baker Hughes:DP505X 7034894 3x16,2x18 12474 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 285.0 @ 12982.00000 1.2 @ 12693.00000 38.1 5.05884 FT/HR SURFACE TORQUE 7483 0 12965.00000 5027 0 12695.00000 51652 0.00000 AMPS WEIGHT ON BIT 58 @ 13004.00000 5 @ 12948.00000 18.8 51.20000 KLBS ROTARY RPM 89 @ 12805.00000 1 @ 12493.00000 59.6 0.00000 RPM PUMP PRESSURE 3365 @ 12474.00000 44 0 12948.00000 2842.4 3185.00000 PSI DRILLING MUD REPORT DEPTH MW 9.4 VIS 66 PV 21 YP 79 FL Gels 12/15/21 CL- FC 0/2 SOL 5.8 SD 0.10 OIL 64.0/27.0 MBL pH Ca* CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 72 @ 12594.00000 7 @ 12490.00000 19.6 TRIP GAS 33u CUTTING GAS 0 @ 13010.00000 0 @ 13010.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 6862 @ 12841.00000 551 @ 12493.00000 1814.1 CONNECTION GAS HIGH ETHANE(C-2) 51 @ 12594.00000 0 @ 12509.00000 8.9 AVG PROPANE(C-3) 0 @ 13010.00000 0 @ 13010.00000 0.0 CURRENT 14 BUTANE(C-4) 0 @ 13010.00000 0 @ 13010.00000 0.0 CURRENT BACKGROUND/AVG-3 PENTANE(C-5) 0 0 13010.00000 0 @ 13010.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 40%Tuffaceous Siltstone/Clayslone/60%Sand/Sandstone PRESENT Tuffaceous siltstone=olive black to dark grey;poorly indurated;very soft,occasionally slightly firm;crumbly and slightly sectile tenacity;blocky to earthy fracture;waxy and slightly greasy to LITHOLOGY earthy luster;silty and sometimes gritty texture;Ihic DAILY ACTIVITY SUMMARY Finished RIH to bottom;Drilled from 12,478'to report depth of 13,019' EPOCH PERSONNEL ON BOARD 4 DAILY COST$3340 REPORT BY D.Muller file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnerg... 8/17/2013 Daily Report Page 1 of 1 Cook Inlet Energy DAILY WELLSITE REPORT RIIIV 17¢.I.o.,v.1 Tn_ct,4"1,...1v 1_7,.. RU-1A REPORT FOR Keith Carter DATE Jul 17,2013 DEPTH 13357' PRESENT OPERATION Drill and slide ahead TIME 1500 YESTERDAY 13010' 24 HOUR FOOTAGE 347' CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6.75 Hughes PDC DP505X 7034894 3016,2x18 12475' 882' 16.5 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 102.1 @ 13085' 0.9 @ 13076' 58.7 41.52824 FT/HR SURFACE TORQUE 8114 @ 13150' 6436 @ 13098' 6579.7 7258.00000 AMPS WEIGHT ON BIT 51 @ 13011' 2 @ 13350' 23.6 3.10000 KLBS ROTARY RPM 88 @ 13098' 80 @ 13022' 76.7 86.00000 RPM PUMP PRESSURE 3554 0 13172' 2870 0 13076' 3313.0 3342.00000 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 223 @ 13186' 11 @ 13020' 45.9 TRIP GAS NA CUTTING GAS 0 @ 13357' 0 @ 13357' 0.0 WIPER GAS NA CHROMATOGRAPHY(ppm) SURVEY NA METHANE(C-1) 32098 @ 13186' 1013 @ 13020' 6068.0 CONNECTION GAS HIGH NA ETHANE(C-2) 115 @ 13155' 0 @ 13294' 16.7 AVG 46u PROPANE(C-3) 11 @ 13151' 0 @ 13203' 0.8 CURRENT 15u BUTANE(C-4) 0 @ 13357' 0 @ 13357' 0.0 CURRENT BACKGROUND/AVG 15/46 PENTANE(C-5) 0 @ 13357' 0 @ 13357' 0.0 HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,Tuffaceous sandstone,tuffaceous siltstone,tuffaceous claystones,tuff PRESENT LITHOLOGY Sand,Tuffaceous sandstone,tuffaceous siltstone,tuffaceous claystones,tuff DAILY ACTIVITY SUMMARY Drill and slide ahead from midnight depth of 13010'MD to 13357'MD. EPOCH PERSONNEL ON BOARD 4 DAILY COST$3,340 REPORT BY Steve Pike file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CooklnletEnerg... 8/17/2013 Daily Report Page 1 of 1 Cook Inlet Energy DAILY WELLSITE REPORT RU-1A CANR/G REPORT FOR Keith Carter DATE Jul 18,2013 DEPTH 13829' PRESENT OPERATION Drill and Slide ahead TIME 1500 YESTERDAY 13357' 24 HOUR FOOTAGE 472' CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA III BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS TB/C PULLED 2 6.75" Hughes PDC DP505X 7034894 3x16,2x18 12475' 1354' 32.5 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 127.8 @ 13661' 0.9 @ 13796' 32.8 36.11668 FT/HR SURFACE TORQUE 10323 @ 13703' 6586 @ 13448' 6378.3 7303.00000 AMPS WEIGHT ON BIT 64 @ 13685' 2 @ 13420' 20.4 12.20000 KLBS I'I ROTARY RPM 90 @ 13812' 1 @ 13673' 73.2 85.00000 RPM PUMP PRESSURE 3527 @ 13808' 39 @ 13678' 3194.5 3355.00000 PSI DRILLING MUD REPORT DEPTH 13547' MW 9.40 VIS 68 PV 20 YP 18 FL Gels 128/15/19 CL- . FC 0/2 SOL 6.5 SD 0.10 OIL 67.0/24.0 MBL pH Ca+ 19.85 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 93 @ 13448' 13 @ 13361' 27.9 TRIP GAS NA CUTTING GAS 0 @ 13829' 0 @ 13829' 0.0 WIPER GAS NA CHROMATOGRAPHY(ppm) SURVEY NA METHANE(C-1) 11560 @ 13357' 1558 @ 13383' 3344.7 CONNECTION GAS HIGH NA ETHANE(C-2) 37 @ 13357' 0 @ 13420' 10.9 AVG 28u PROPANE(C-3) 0 @ 13829' 0 @ 13829' 0.0 CURRENT 18u BUTANE(C-4) 0 @ 13829' 0 @ 13829' 0.0 CURRENT BACKGROUND/AVG 18/28 PENTANE(C-5) 0 @ 13829' 0 @ 13829' 0.0 HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,tuffaceous siltstone,tuffaceous sandstone,tuffaceous claystone,and tuff PRESENT LITHOLOGY Sand,tuffaceous siltstone,tuffaceous sandstone,tuffaceous claystone,and tuff DAILY ACTIVITY SUMMARY Drill and slide from 13357'MD to 13829'MD. CANRIG PERSONNEL ON BOARD 4 DAILY COST$3,340 REPORT BY Steve Pike file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WE... 8/18/2013 Daily Report Page 1 of 1 Cook Inlet Energy ii #12 DAILY WELLSITE REPORT RU-1A CiMs1RIG REPORT FOR C.Cretsinger/D.Faulkner DATE Jul 19,2013 DEPTH 13950.00000 PRESENT OPERATION Drilling ahead TIME 0000 YESTERDAY 13588.00000 24 HOUR FOOTAGE 362 CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 13888.61 31.73 92.74 11567.83 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6.75 Baker Hughes:DP505X 709484 3x16,2x18 12474 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 127.8 @ 13661.00000 0.5 @ 13863.00000 31.2 15.14939 FT/HR SURFACE TORQUE 10323 0 13703.00000 6780 0 13812.00000 5339.0 0.00000 AMPS WEIGHT ON BIT 64 0 13685.00000 4 0 13885.00000 25.4 44.30000 KLBS ROTARY RPM 90 0 13812.00000 1 0 13922.00000 60.8 0.00000 RPM PUMP PRESSURE 3527 @ 13808.00000 39 @ 13678.00000 31343 3118.00000 PSI DRILLING MUD REPORT DEPTH MW 9.30 VIS 89 PV 20 YP 18 FL Gets 11/15/19 CL- FC 0/2 SOL 6.1 SD 0.10 OIL 67.0/24.0 MBL pH Can CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 45 @ 13645.00000 5 @ 13912.00000 21.2 TRIP GAS CUTTING GAS 0 @ 13950.00000 0 @ 13950.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 6761 @ 13707.00000 138 @ 13879.00000 2255.4 CONNECTION GAS HIGH ETHANE(C-2) 35 0 13707.00000 0 0 13878.00000 11.0 AVG 21 PROPANE(C-3) 0 @ 13950.00000 0 @ 13950.00000 0.0 CURRENT 17 BUTANE(C-4) 0 @ 13950.00000 0 @ 13950.00000 0.0 CURRENT BACKGROUND/AVG-4 PENTANE(C-5) 0 0 13950.00000 0 0 13950.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 70%Sand/30%Tuffaceous Siltstone/lace to 5%Tuff PRESENT Greyish black to olive black;upper very coarse to lower One grains;poorly sorted;well rounded to subangular and occasionally very angular;high to low sphericity;sandstones matrix LITHOLOGY supported,highly calcareous cement;dominantly Quartz grains with abu DAILY ACTIVITY SUMMARY Continued drilling ahead from 13,589'to 13,950'.Drilling ahead at time of report. CANRIG PERSONNEL ON BOARD 4 DAILY COST$3340 REPORT BY D.Muller file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WE... 8/19/2013 Daily Report Page 1 of 1 Cook Inlet Energy #13 DAILY WELLSITE REPORT RU-1A cANRIG REPORT FOR C Cretsinger/D.Faulkner DATE Jul 20,2013 DEPTH 14001.00000 PRESENT OPERATION BOP test TIME 0000 YESTERDAY 13950.00000 24 HOUR FOOTAGE 51 CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 13888.61 31.73 92.74 11567.83 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6.75 Baker Hughes:DP505X 709484 3x16,2x18 12474 14001 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 83.1 @ 13976.00000 0.5 @ 13985.00000 18.6 39.86798 FT/HR SURFACE TORQUE 8070 0 13996.00000 7081 @ 13967.00000 5181.7 7719.00000 AMPS WEIGHT ON BIT 61 @ 13966.00000 25 @ 13977.00000 35.7 28.80000 KLBS ROTARY RPM 89 0 13967.00000 1 @ 13953.00000 61.6 87.00000 RPM PUMP PRESSURE 3623 @ 13989.00000 3118 @ 13950.00000 3488.9 3588.00000 PSI DRILLING MUD REPORT DEPTH MW 9.30 VIS 67 PV 20 YP 18 FL Gels 11/15/19 CL- FC 0/2 SOL 6.1 SD 0.10 OIL 67.0/24.5 MBL pH Can CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 29 @ 13968.00000 12 @ 13963.00000 16.0 TRIP GAS CUTTING GAS 0 @ 14001.00000 0 @ 14001.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 2947 @ 13968.00000 1259 @ 13963.00000 1619.1 CONNECTION GAS HIGH ETHANE(C-2) 0 @ 14001.00000 0 @ 14001.00000 0.0 AVG 16 PROPANE(C-3) 0 @ 14001.00000 0 @ 14001.00000 0.0 CURRENT- BUTANE(C-4) 0 @ 14001.00000 0 @ 14001.00000 0.0 CURRENT BACKGROUND/AVG- PENTANE(C-5) 0 0 14001.00000 0 @ 14001.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 60%Sand/20%TuffaceousSiltstone/10%Tuffaceous Claystone/10%Carbonaceous Shale/trace%Tuff PRESENT Tuffaceous siltstone olive black to dark grey;poorly to moderately indurated;blocky to earthy fracture;earthy and slightly sparkly luster;gritty to abrasive texture;thin to thick bed structure; LITHOLOGY abundant imbedded loose sand grains and carbonaceous material;occasionally very calcareous. DAILY ACTIVITY Continued drilling ahead to 14,001'.Circulated bottoms up and began tripping out for B.O.P.testing.Perform flow check and pump dry job at casing shoe.Continue POOH to surface and SUMMARY lay down tools.Rig up for BOP lest.Test BOP.Began rigging down test equipment. CANRIG PERSONNEL ON BOARD 4 DAILY COST$3340 REPORT BY D.Muller file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WE... 8/20/2013 Daily Report Page 1 of 1 Cook Inlet Energy #14 DAILY WELLSITE REPORT RU-1A CANRIG REPORT FOR C.Cretsinger/D.Faulkner DATE Jul 21,2013 DEPTH 14001.00000 PRESENT OPERATION TIH TIME 0000 YESTERDAY 14001.00000 24 HOUR FOOTAGE 0 CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 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 9.40 VIS 71 PV 21 YP 18 FL Gels 11/14/18 CL- FC 0/2 SOL 7.3 SD 0.10 OIL 66.5/24.0 MBL pH Ca* CCI 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 Pumps off.No new gas INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Same PRESENT LITHOLOGY Same DAILY ACTIVITY SUMMARY Picked up new BHA and TIH.Slip and cut drilling line.Continue TIH to bottom washing down from 12,532'to 13,630'.No new footage drilled CANRIG PERSONNEL ON BOARD 4 DAILY COST$3340 REPORT BY D.Muller file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WE... 8/21/2013 Daily Report Page 1 of 1 Cook Inlet Energy DAILY WELLSITE REPORT RU-1A c1Ajr.,Jric3 REPORT FOR Carlos Cretsinger DATE Jul 21,2013 DEPTH 14290' PRESENT OPERATION Drill ahead TIME 1500 YESTERDAY 14002' 24 HOUR FOOTAGE 288' CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON N0. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 143.8 @ 14005' 0.4 @ 14027' 44.9 28.10803 FT/HR SURFACE TORQUE 8309 @ 14266' 6300 @ 14050' 6706.0 7876.00000 AMPS WEIGHT ON BIT 28 @ 14002' 0 @ 14005' 8.2 11.70000 KLBS ROTARY RPM 101 @ 14245' 1 @ 1407T 84.5 96.00000 RPM PUMP PRESSURE 3741 @ 14033' 47 @ 14005' 3418.0 3637.00000 PSI DRILLING MUD REPORT DEPTH 14004' MW 9.4 VIS 71 PV 21 YP 18 FL Gels 11/14/18 CL- FC 0/2 SOL 7.3 SD 0.10 OIL 66.5/24.0 MBL pH Ca+ 19.85 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 50 @ 14122' 15 @ 14086' 29.9 TRIP GAS NA CUTTING GAS 0 @ 14290' 0 @ 14290' 0.0 WIPER GAS NA CHROMATOGRAPHY(ppm) SURVEY NA METHANE(C-1) 6899 @ 14276' 1482 @ 14086' 3394.0 CONNECTION GAS HIGH NA ETHANE(C-2) 279 @ 14276' 15 @ 14086' 68.4 AVG 30u PROPANE(C-3) 104 @ 14276' 10 @ 14086' 33.2 CURRENT 21u BUTANE(C-4) 67 @ 14276' 0 @ 14250' 11.8 CURRENT BACKGROUND/AVG 21/30 PENTANE(C-5) 20 @ 14288' 1 @ 14267' 1.1 HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Have not seen a clean quartz conglomerate sand PRESENT LITHOLOGY Sand,sandstone,luffaceous siltstone DAILY ACTIVITY SUMMARY Drill ahead from 14002'MD to 14290'MD. CANRIG PERSONNEL ON BOARD 4 DAILY COST$3,340 REPORT BY Steve Pike file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WE... 7/12/2013 Daily Report Page 1 of 1 Cook Inlet Energy a15 DAILY WELLSITE REPORCANRIG RU-1A REPORT FOR C.Crestinger/D.Faulkner DATE Jul 22,2013 DEPTH 14450.00000 PRESENT OPERATION Drilling ahead TIME 0000 YESTERDAY 14001.00000 • 24 HOUR FOOTAGE 449 CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 14382.05 37.38 9124 11972.09 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.75 HDBS,EM65D 12143032 6x12 14001 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG • RATE OF PENETRATION 98.75 @ 14058.00000 0.4 @ 14027.00000 38.3 14.42932 FT/HR SURFACE TORQUE 8542 @ 14441.00000 6300 @ 14050.00000 6567.4 8035.00000 AMPS ' WEIGHT ON BIT 40 @ 14402.00000 0 @ 14005.00000 12.3 29.80000 KLBS ROTARY RPM 101 @ 14245.00000 1 @ 14077.00000 81.0 95.00000 RPM PUMP PRESSURE 3741 @ 14033.00000 47 0 14005.00000 3446.7 3289.00000 PSI DRILLING MUD REPORT DEPTH MW 9.40 VIS 67 PV 20 YP 19 FL Gels 11/14/18 CL- , FC 0/2 SOL 7.6 SD 0.10 OIL 67.0/23.0 MBL pH Ca* CCI MWD SUMMARY INTERVAL TO I TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 50 @ 14122.00000 9 @ 14408.00000 26.4 TRIP GAS 123 CUTTING GAS 0 @ 14450.00000 0 @ 14450.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 6899 @ 14276.00000 1127 @ 14408.00000 3175.3 CONNECTION GAS HIGH ETHANE(C-2) 328 0 14449.00000 10 0 14001.00000 95.0 AVG 26 PROPANE(C-3) 104 @ 14276.00000 0 @ 14390.00000 30.5 CURRENT 19 BUTANE(C-4) 67 @ 14276.00000 0 @ 14390.00000 10.5 CURRENT BACKGROUND/AVG-7 PENTANE(C-5) 27 @ 14350.00000 0 0 14321.00000 2.3 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 70%Sandstone/20%Siltstone 10%Sandstone/Tuffaceous Sandstone PRESENT Dark grey to greyish black and occasional medium grey;poor to moderate induration;crumbly and brittle tenacity;blocky and slightly planar to earthy fracture;massive and slightly platy cuttings LITHOLOGY habit;earthy to frosted luster;silty to gritty texture;thin bed interbedding with lighter silistones and some tuffaceous sandstones;abundant loose sand grains and finer carbonaceous material imbedded;very calcareous. DAILY ACTIVITY SUMMARY Continued washing down from 13,630'to bottom.Drilled from 14,004'to 14,450'.Drilling ahead at time of report. CANRIG PERSONNEL ON BOARD 4 DAILY COST$3340 REPORT BY D.Muller file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\IVIY DOCUMENTS\MY WE... 7/22/2013 Daily Report Page 1 of 1 Cook Inlet Energy DAILY WELLSITE REPORT RU-1A cAJJRI3 REPORT FOR Carlos Crelsinger DATE Jul 22,2013 DEPTH 14669' PRESENT OPERATION Drill ahead TIME 1500 YESTERDAY 14451' 24 HOUR FOOTAGE 218' CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS TB/C PULLED 3 6.75" PDC SBDS EM65D 12143032 6x12 14003' 667' 34 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 69.4 @ 14489' 1.0 @ 14600' 24.5 22.31247 FT/HR SURFACE TORQUE 10001 @ 14566' 7627 0 14594' 8240.9 8928.00000 AMPS WEIGHT ON BIT 31 @ 14492' 1 @ 14592' 15.0 11.30000 KLBS ROTARY RPM 99 @ 14461' 89 @ 14656' 96.6 97.00000 RPM PUMP PRESSURE 4025 @ 14669' 3157 0 14515' 3547.6 4025.00000 PSI DRILLING MUD REPORT DEPTH 14450' MW 9.4 VIS 67 PV 20 YP 19 FL Gels 11/14/18 CL- FC 0/2 SOL 7.6 SD 0.10 OIL 67.0/23.0 MBL pH Ca+ 19.85 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 28 @ 14653' 13 @ 14516' 20.7 TRIP GAS NA CUTTING GAS 0 @ 14669' 0 @ 14669' 0.0 WIPER GAS NA CHROMATOGRAPHY(ppm) SURVEY NA METHANE(C-1) 3543 @ 14620' 1658 @ 14669' 2570.2 CONNECTION GAS HIGH NA ETHANE(C-2) 234 @ 14596' 117 @ 14609' 178.3 AVG 21u PROPANE(C-3) 46 @ 14653' 18 @ 14516' 28.6 CURRENT 18u BUTANE(C-4) 12 @ 14631' 0 @ 14590' 4.5 CURRENT BACKGROUND/AVG 18/21 PENTANE(C-5) 0 @ 14669' 0 @ 14669' 0.0 HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,tuffaceous siltstone,conglomerate sand,conglomerate PRESENT LITHOLOGY Sand,tuttaceous siltstone,conglomerate sand,conglomerate DAILY ACTIVITY SUMMARY Drill ahead from 14451'MD to 14669'MD. CANRIG PERSONNEL ON BOARD 4 DAILY COST$3,340 REPORT BY Steve pike file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WE... 7/22/2013 Daily Report Page 1 of 1 Cook Inlet Energy #16 DAILY WELLSITE REPORT RU-1A CANRIG REPORT FOR C.Crestinger/D.Faulkner DATE Jul 23,2013 DEPTH 14850.00000 PRESENT OPERATION Drilling agead TIME 0000 YESTERDAY 14450.00000 24 HOUR FOOTAGE 400 CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 14759.72 38.07 68.43 12273.54 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.75 HDBS:EM65D 12143032 6X12 14001 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 69.4 @ 14489.00000 1.0 @ 14725.00000 24.3 7.72997 FT/HR SURFACE TORQUE 10001 0 14566.00000 7423 0 14724.00000 8323.0 8879.00000 AMPS WEIGHT ON BIT 33 0 14811.00000 1 0 14716.00000 15.4 33.40000 KLBS ROTARY RPM 105 0 14715.00000 56 @ 14850.00000 94.0 56.00000 RPM PUMP PRESSURE 4025 0 14669.00000 3157 @ 14515.00000 3530.4 3554.00000 PSI DRILLING MUD REPORT DEPTH MW 9.40 VIS 67 PV 25 VP 18 FL Gels 12/16/19 CL- FC 0/2 SOL 7.7 SD 0.10 OIL 67.0/23.0 MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 28 @ 14751.00000 9 @ 14768.00000 20.3 TRIP GAS CUTTING GAS 0 @ 14850.00000 0 @ 14850.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 3573 @ 14620.00000 1012 @ 14768.00000 2337,3 CONNECTION GAS HIGH ETHANE(C-2) 340 0 14816.00000 84 0 14768.00000 175.4 AVG 20 PROPANE(C-3) 58 @ 14700.00000 7 @ 14768.00000 28.3 CURRENT 20 BUTANE(C-4) 55 @ 14700.00000 0 @ 14553.00000 12.6 CURRENT BACKGROUND/AVG 0 PENTANE(C-5) 0 0 14850.00000 0 0 14850.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 80%Sand/Conglomeratic Sand/20'/Siltstone DAILY ACTIVITY SUMMARY Continued drilling ahead from 14,450'to 14,849'.Drilling ahead at time of report. • CANRIG PERSONNEL ON BOARD 4 DAILY COST$3340 REPORT BY D.Muller file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WE... 7/23/2013 Daily Report Page 1 of 1 Cook Inlet Energy P S' n17 DAILY WELLSITE REPORT CANRIG RU-1 A REPORT FOR C.Crestinger/D.Faulkner DATE Jul 23,2013 DEPTH 15050.00000 PRESENT OPERATION MWD MAD PASS TIME 14:51:04 YESTERDAY 14850.00000 24 HOUR FOOTAGE 200 CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 15050 38.31 58.37 12502.29 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.75 HDBS/EM647ZZ 12143032 6x12 14001 15050 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 60.0 @ 14923.00000 0.5 @ 14851.00000 23.8 6.98143 FT/HR SURFACE TORQUE 9348 @ 14925.00000 8147 @ 14977.00000 8771.7 8295.00000 AMPS WEIGHT ON BIT 34 @ 14851.00000 6 @ 14956.00000 13.7 13.10000 KLBS ROTARY RPM 100 @ 14931.00000 56 @ 14850.00000 96.4 93.00000 RPM PUMP PRESSURE 3739 @ 14918.00000 3078 @ 14891.00000 3573.7 3356.00000 PSI DRILLING MUD REPORT DEPTH MW 9.30 VIS 70 PV 23 YP 19 FL Gels 14/1720 CL- FC 0/2 SOL 7.7 SD 0.10 OIL 76.9/23.1 MBL pH Ca, CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 41 @ 15027.00000 15 @ 14850.00000 23.3 TRIP GAS CUTTING GAS 0 @ 15050.00000 0 @ 15050.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 4972 @ 15027.00000 1786 @ 14850.00000 2807.4 CONNECTION GAS HIGH ETHANE(C-2) 189 @ 14880.00000 47 0 14988.00000 83.4 AVG PROPANE(C-3) 31 @ 15027.00000 11 @ 14940.00000 17.3 CURRENT BUTANE(C-4) 0 @ 15050.00000 0 @ 15050.00000 0.0 CURRENT BACKGROUND/AVG PENTANE(C-5) 0 @ 15050.00000 0 @ 15050.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND/SANDSTONE/TUFFACEOUS SILTSTONE SAND/SANDSTONE MOSTLY TRANSLUCENT TO CLEAR WITH SOME WHITE LIGHT GRAY,AND BROWNISH GRAY HUES;PREDOMINANTLY QUARTZ SAND MATRIX WITH ABUNDANT PRESENT LIGHT AND DARK COLORED LITCHIC FRAGMENT THROUGHOUT;UPPER FINE GRAIN TO UPPER MEDIUM GRAIN SAND;FAIR TO WELL SORTED VERY ANGULAR TO;TO LITHOLOGY SUBANGULAR WITH SOME SUBROUNDED MODERATE TO HIGH SPHERICITY;THICKER BEDS OF LOOSE QUARTZ SAND AND FINE GRAINED,AND VERY FRIABLE SANDSTONES INTERBEDDED WITH TUFFACEOUS SILTSTONES;OBM FLUORESCENCE;NO OTHER PETROLEUM INDICATORS WERE OBSERVED. DAILY ACTIVITY SUMMARY CONTINUED DRILLING AHEAD FROM 14,849'TO TD AT 15,050'.CIRCULATE HOLE CLEAN PUMP OUT OF HOLE TO CASING SHOE,LOG MWD MAD PASS.RIH TO BTM. CANRIG PERSONNEL ON BOARD STEVE PIKE,OMAR HINOSTROZA DAILY COST$3340 REPORT BY OMAR HINOSTROZA file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\IVIY DOCUMENTS\MY WE... 7/24/2013 Daily Report Page 1 of 1 Cook Inlet Energy 18 DAILY WELLSITE REPORT RU-1A CANR/ IG REPORT FOR C.Crestinger/D.Faulkner DATE Jul 23,2013 DEPTH 15050.00000 PRESENT OPERATION Reaming TIME 14:51:04 YESTERDAY 15050.00000 24 HOUR FOOTAGE 0 CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.75 PDC SBDS EM65D 12143032 6x12 14003' 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 9.4 VIS 70 PV 23 YP 20 FL Gels 14/17/21 CL- FC 0/2 SOL 8.0 SD 0.10 OIL 77.8/22.2 MBL pH Ca+ 17.91 CCI 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 Continued M.A.D.Pass 1112,435'.RIH to TD washing down tight spots.Circulated 3X B.U.then began reaming out of hole to 14,800'.Reaming at time of report. CANRIG PERSONNEL ON BOARD STEVE PIKE,OMAR HINOSTROZA DAILY COST$3340 REPORT BY OMAR HINOSTROZA file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTSW1Y WE... 7/25/2013 Daily Report Page 1 of 1 Cook Inlet Energy DAILY WELLSITE REPORT CANR/ IG REPORT FOR Carlos Cretsinger DATE Jul 23,2013 DEPTH 15050' PRESENT OPERATION Circulate out hole TIME 1500 YESTERDAY 14850' 24 HOUR FOOTAGE 200' CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS TB/C PULLED 3 6.75" PDC SBDS EM65D 12143032 6x12 14003' 1047 53 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 60.0 @ 14923' 0.5 @ 14851' 23.8 6.98143 FT/HR SURFACE TORQUE 9348 @ 14925' 8147 @ 14977' 8771.7 8295.00000 AMPS WEIGHT ON BIT 34 @ 14851' 6 @ 14956' 13.7 13.100W KLBS ROTARY RPM 100 @ 14931' 56 @ 14850' 96.4 93.00000 RPM PUMP PRESSURE 3739 @ 14918' 3078 0 14891' 3573.7 3356.00000 PSI DRILLING MUD REPORT DEPTH 14849' MW 9.4 VIS 67 PV 25 YP 18 FL Gels 12/16/19 CL- FC 0/2 SOL 7.7 SD 0.10 OIL 67.0/23.0 MBL pH Ca+ 20.82 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 41 @ 15027.00000 15 @ 14850.00000 23.3 TRIP GAS NA CUTTING GAS 0 @ 15050.00000 0 @ 15050.00000 0.0 WIPER GAS NA CHROMATOGRAPHY(ppm) SURVEY NA METHANE(C-1) 4972 @ 15027.00000 1786 @ 14850.00000 2807.4 CONNECTION GAS HIGH NA ETHANE(C-2) 189 @ 14880.00000 47 0 14988.00000 83.4 AVG 23u PROPANE(C-3) 31 @ 15027.00000 11 @ 14940.00000 17.3 CURRENT 15u BUTANE(C-4) 0 @ 15050.00000 0 @ 15050.00000 0.0 CURRENT BACKGROUND/AVG 15/23 PENTANE(C-5) 0 00 15050.00000 0 @ 15050.00000 0.0 HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,tuffaceous siltstone,sandstone,and tuffaceous claystone PRESENT LITHOLOGY Sand,tuffaceous siltstone,sandstone,and tuffaceous claystone DAILY ACTIVITY SUMMARY Drill ahead from 14850'MD to 15050'MD.Circulate out hole. CANRIG PERSONNEL ON BOARD 4 DAILY COST$3,340 REPORT BY Steve Pike file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WE... 7/23/2013 0 0 Z r 0 C) N v r r z G) z n 0) r O O N 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. RECEIVED SEP 172013 EIV AOGGC Cook Inlet Energy_ •�r '� - ��._,; =:a. _. _ :.c Mme'?► yra• 4' ....� , • • Lam. _ _ re Low-sai 1.10„...re.:: .-_-"7- 111111r zit__ F. • Cook Inlet Energy RU-1A REDOUBT SHOALS Section 14 — T7N - R14W Upper Cook Inlet, Alaska FINAL WELL REPORT Steve Pike—Senior Logging Geologist Omar Hinostroza - Logging Geologist Trey Thrailkill -Logging Geologist Dylan Muller— Logging Geologist Cook Inl_ energY R11- 4 1 ' Contents: Daily Reports DM L_ Data July 23, 2013 Well Report LAS Files Log PDF Files iii,� - Log TIFF Files y t: Ail- f r III !9,.-.H.•f ��,Q,I.., in a I . CANRIG ;� , rula_mudlog_cd.txt volume in drive E is CIE - RU-LA Volume Serial Number is E7E1-5F0A Directory of E:\ 08/03/2013 03:11 PM <DIR> DAILY REPORTS 08/03/2013 03:11 PM <DIR> DML DATA 08/03/2013 03:11 PM <DIR> FINAL WELL REPORT 08/03/2013 03:11 PM <DIR> LAS FILE 08/03/2013 03:11 PM <DIR> LOG PDF FILES 08/03/2013 03:11 PM <DIR> LOG TIFF FILES 0 File(s) 0 bytes Directory of E:\DAILY REPORTS 08/03/2013 03:11 PM <DIR> . 08/03/2013 03:11 PM <DIR> 08/03/2013 03:11 PM <DIR> Afternoon Reports 08/03/2013 03:11 PM <DIR> Morning Reports 0 File(s) 0 bytes Directory of E:\DAILY REPORTS\Afternoon Reports 08/03/2013 03:11 PM <DIR> . 08/03/2013 03:11 PM <DIR> . . 07/13/2013 02: 52 PM 26,242 RU-L4 Afternoon Report_7-13-2013.pdf 07/14/2013 02: 52 PM 26,344 RU-L4 Afternoon Report_7-14-2013.pdf 08/16/2013 03:32 PM 26,617 RU-L4 Afternoon Report_7-16-2013.pdf 08/17/2013 02:51 PM 26, 542 RU-L4 Afternoon Report_7-17-2013.pdf 08/18/2013 02:46 PM 22,160 RU-L4 Afternoon Report_7-18-2013.pdf 07/12/2013 02: 53 PM 21,846 RU-L4 Afternoon Report_7-21-2013.pdf 07/22/2013 02:46 PM 21,938 RU-L4 Afternoon Report_7-22-2013.pdf 07/23/2013 03:37 PM 21,994 RU-L4 Afternoon Report_7-23-2013.pdf 8 File(s) 193,683 bytes Directory of E:\DAILY REPORTS\Morning Reports 08/03/2013 03:11 PM <DIR> 08/03/2013 03:11 PM <DIR> . . 07/13/2013 05:02 AM 35,972 RU-1A Morning Report #1 7-7-2013.pdf 08/16/2013 04:27 AM 27,391 RU-1A Morning Report #10 7-16-2013.pdf 08/17/2013 04:04 AM 27,492 RU-1A Morning Report #11 7-17-2013.pdf 08/19/2013 03:28 AM 23,195 RU-L4 Morning Report #12 7-19-2013.pdf 08/20/2013 03:53 AM 23,575 RU-L4 Morning Report #13 7-20-2013.pdf 08/21/2013 03:00 AM 21,435 RU-L4 Morning Report #14 7-21-2013.pdf 07/22/2013 03:17 AM 23,210 RU-L4 Morning Report #15 7-22-2013.pdf 07/23/2013 02:17 AM 22,250 RU-L4 Morning Report #16 7-23-2013.pdf 07/24/2013 04:40 AM 23,004 RU-L4 Morning Report #17 7-24-2013.pdf 07/25/2013 03:57 AM 21,701 RU-L4 Morning Report #18 7-25-2013.pdf 07/13/2013 05:12 AM 38,522 RU-L4 Morning Report #2 7-8-2013.pdf 07/09/2013 04:44 AM 25,930 Ru-L4 Morning Report #3 7-9-2013.pdf 07/10/2013 04:15 AM 25,944 RU-L4 Morning Report #4 7-10-2013.pdf 07/11/2013 04:50 AM 26,466 RU-L4 Morning Report #5 7-11-2013.pdf 07/13/2013 05:14 AM 37,213 RU-L4 Morning Report #6 7-12-2013.pdf 07/13/2013 05:15 AM 37,998 RU-L4 Morning Report #7 7-13-2013.pdf 07/14/2013 03:45 AM 26,622 RU-L4 Morning Report #8 7-14-2013.pdf 07/15/2013 04:18 AM 26,922 RU-L4 Morning Report #9 7-15-2013.pdf 18 File(s) 494,842 bytes Directory of E:\DML DATA 08/03/2013 03:11 PM <DIR> . 08/03/2013 03:11 PM <DIR> . . Page 1 rula_mudlog_cd.txt 08/03/2013 03:11 PM <DIR> RU-1A_DML Data 0 File(s) 0 bytes Directory of E:\DML DATA\RU-1A_DML Data 08/03/2013 03:11 PM <DIR> 08/03/2013 03:11 PM <DIR> . . 08/03/2013 03:06 PM 11,169,857 RU-1A.dbf 08/03/2013 03:06 PM 54,272 RU-1A.mdx 08/03/2013 03:00 PM 968 RU-1A_SCL.DBF 08/03/2013 03:00 PM 6,144 RU-1A_SCL.MDX 07/25/2013 10:46 AM 189,319 RU-1A_tvd.dbf 07/25/2013 10:46 AM 41,984 RU-1A_tvd.mdx 07/25/2013 10:46 AM 102 RU-2A.hdr 08/03/2013 02:59 PM 448 ru-la.hdr 07/25/2013 10:46 AM 21,194 ru-lar.dbf 07/25/2013 10:46 AM 16,384 ru-lar.mdx 10 File(s) 11,500,672 bytes Directory of E:\FINAL WELL REPORT 08/03/2013 03:11 PM <DIR> 08/03/2013 03:11 PM <DIR> . . 08/03/2013 01:38 PM 784,738 RU-1A Final well Report.pdf 1 File(s) 784,738 bytes Directory of E:\LAS FILE 08/03/2013 03:11 PM <DIR> 08/03/2013 03:11 PM <DIR> . . 08/03/2013 03:06 PM 1,909,095 RU-1A.las 1 File(s) 1,909,095 bytes Directory of E:\LOG PDF FILES 08/03/2013 03:11 PM <DIR> 08/03/2013 03:11 PM <DIR> . . 08/03/2013 12:47 PM 1,819,439 RU-1A_DRILLING_DYNAMICS_MD.pdf 08/03/2013 12:37 PM 1,374,119 RU-1A_DRILLING_DYNAMICS_TVD.pdf 08/03/2013 12:00 PM 1,527,011 RU-1A_FORMATION_LOG_MD.pdf 08/03/2013 12:09 PM 1,154,228 RU-1A_FORMATION_LOG_TVD.pdf 08/03/2013 02:10 PM 2,054,088 RU-1A_GAS_RATIO_LOG_MD.pdf 08/03/2013 03:04 PM 1,537,947 RU-1A_GAS_RATIO_LOG_TVD.pdf 08/03/2013 02:56 PM 1,564,341 RU-1A_LWD_COMBO LOG_MD.pdf 08/03/2013 02:53 PM 1,179,562 RU-1A_LWD_COMBO LOG_TVD.pdf 8 File(s) 12,210,735 bytes Directory of E:\LOG TIFF FILES 08/03/2013 03:11 PM <DIR> 08/03/2013 03:11 PM <DIR> . . 08/03/2013 03:08 PM 35,942,093 RU-1A_DRILLING_DYNAMICS_MD.tif 08/03/2013 03:08 PM 28,815,872 RU-1A_DRILLING_DYNAMICS_TVD.tif 08/03/2013 03:08 PM 33,930,171 RU-1A_FORMATION_LOG_MD.tif 08/03/2013 03:08 PM 24,542,816 RU-1A_FORMATION_LOG_TVD.tif 08/03/2013 03:08 PM 34,575,880 RU-1A_GAS_RATIO_LOG_MD.tif 08/03/2013 03:08 PM 27,494,850 RU-1A_GAS_RATIO_LOG_TVD.tif 08/03/2013 03:08 PM 31,806,132 RU-1A`LWD_COMBO_LOG_MD.tif 08/03/2013 03:08 PM 25,886,960 RU-1A_LWD_COMBO_LOG_TVD.tif 8 File(s) 242,994,774 bytes Total Files Listed: 54 File(s) 270,088,539 bytes Page 2 rula_mudlog_cd.txt 27 Dir(s) 0 bytes free Page 3 . . . . . . . . \ o o w b k b b 0 CD CO 0. $ $ $ § ' 7 0 § q K \ 0 t c c Q $ ( o / 0 $ cm-04 o a o k - b b b b - B w E 2 c G § $ R k 2 2 S B ■ ƒ % ƒ $ % 2 a a # % m $ e _ \ Q E 0 G G Q G G G Q G \ / a o 0 rt CO- .,-. / CI r - 2 / .0 E 0 § k A b § k 4.0 - Z $ , s - z 2 To & ■ p } \ « _1 k § 0 C. - ¢ § E m o 1 k. ' m 0 0 ■ t a / o 0 ° c 0 $ 2 . 0 C \ £ D 2 2 co § $ k 0. 2 § 8 8 g s 2 ` I \ 8 E. or t / 8 0 w , § a 0 $ 2 f z K K co o p 0) 9 0 o 2- c 0 % E 0 0 ro To % / Ce 2 # § E k 0 % Q « O m Co 0 0 0 0 0 a n n n n n n CO CO CO CO k k d d d k B R Q 0 Q E m w w � Co CO / CO CO CO e q w w ƒ k / k C C C C C C C a 2 + 2 2 2 2 2 / 2 2 . 2 k k k O 1 1 1 I I I I I I I CAST-M HALLIBURTON CBL-M (FIELD PRINT) Company Cook Inlet Energy ep Y Well Redoubt Unit #1A D Q Field Redoubt Unit Shoal Undefined Ft Borough Cook Inlet state Alaska Ill API No.: 50-733-20497-01 Sery#: 900624764 Other Services n X Location: SURFACE: 1918' FSL& 315' FEL .he o o c S-14,T-7N, R-14W t c0 U BOTTOM: S-18,T-7N, R-13W >, NONE c E — ' o co _Sec: __Twp:7N Rge: 14W Permanent Datum MSL Elevation 0 Elevation Log Measured From KB , 89.1' Ft.above perm.datum K.B. 89.1' D.F. 89.1' Drilling Measured From DF G.L. 0 Date @ Time Logged 05-AUG-2013 @ 0815_ Type Fluid in Hole WBM _ Run No. ONE Density of Fluid 8.6 PPG Depth-Driller 15050' Fluid Level FULL Depth-Logger _ 14910' Cement Top Est.Logged LOGGED _ Bottom-Logged Interval 14910' Equipment/Location 11202279 / STERLING Top-Log Interval 6500' Recorded by R.STONE Max.Recorded Temp. 207 DEGF Witnessed by K.CARTER CEMENTING DATA Surface Protection Production Liner String String _Stringy Date/Time Cemented N/A N/A N/A N/A Primary/Squeeze_ I Expected Compressive Strength - psi@ hrs psi@ hrs psi t7 hrs psi@ hrs i Cement Volume ` Cement Type/Weight / / / / Formulation Mud Type/Mud Wgt. / / / / f,�;; Borehole Record Casing&Tubing Record Run Number Bit From To Size Weight From To 36" 150 lb surface 200' 13.375" 68 lb surface 1831' 9.625" 47 lb surface 6986' _ 7.625" 29.7 lb 6705' 13990' 5.5' 17.0 lb 6509' 15050' HALLIDURTON ADVANCED CEMENT EVALUATION DEPTH CORRECTED COMPANY COOK INLET ENERGY WELL REDOUBT UNIT#1A FIELD REDOUBT UNIT SHOAL UNDEF. COUNTY COOK INLET OFFSHORE STATE AK Location: SURFACE BOTTOM S-14,T-7N, R-14W S-18,T-7N, R-13W rs Elevations: K.B.: 89.1' R.T.: 89.1' G.L.: MSL Date Processed 8/5/2013 Logs Processed CAST-M Job Number Date Logged 8/5/2013 Interval Processed 6500-14910 Type Fluid In Hole WBM 8.6PPG Processed By C.GULLETT Location REDBT Processed At ANC.FRS --- COMPUTER PROCESSED PRODUCT --- GR-CCL HALLIBURTON TCP CORRELATION LOG .• Company Cook Inlet Energy CD Y Well Redoubt Unit #1A Field Redoubt Unit Shoal Undefined Ft Borough Cook Inlet State Alaska W E a API No.: 50-733-20497-01 Sery#: 900543082 Other Services c _a Q Location: SURFACE: 1918' FSL& 315' FEL -se o o S- 14,T-7N, R-14W v v BOTTOM: S-18, T-7N, R-13W a CBL c E t- - o O u = °— -- Sec: Twp:7N _ Rge_ 14W — Permanent Datum MSL Elevation 0 Elevation Log Measured From KB . 89.1' Ft.above perm,datum K.B. 89.1' D.F. 89.1' Drilling Measured From DF G.L. 0 Date @_Time Logged 07-AUG-201 1750 Type Fluid in Hole WBM Run No. ONE Density of Fluid 8.6 PPG -------- -- -- -------------- - — Depth_Driller _ 15050' — Fluid Level FULL _ Depth-Logger 14021' Cement Top Est.Logged LOGGED Bottom:.Logged Interval _.14021' _ Equipment/Location 11202279 / STERLING Top-Log Interval SURFACE _ Recorded by R.STONE _ Max_Recorded Temp. N/A Witnessed by K.CARTER CEMENTING DATA Surface Protection Production Liner String String String Date/Time Cemented N/A N/A N/A N/A Primary/Squeeze Expected Compressive Strength psi@ hrs psi hrs psi@ hrs psi@ hrs Cement Volume - Cement Type/Weight /— — — / / / Formulation _ Mud Type/Mud Wgt. / / / / ; Borehole Record _ Casing&Tubing Record Run Number Bit From To Size Weight From To j 36" 150# surface _ 200' _, 13.375" 68# surface 1831' 1 9.625" 47# surface 6986' _ -7.625" 29.7# 6705' 13990' 5.5" 17# 6709' 15050' BRIDGE PLUG HALLIBURTON SETTING RECORD Company Cook Inlet Energy a) it o Well Redoubt Unit #1A 76 Q Field Redoubt Unit Shoal Undefined Borough Cook Inlet State Alaska w +, API No.: 50-733-20497-00 Sery#: 900543082 Other Services c Z Location: SURFACE: 1918'FSL&315' FEL Y o o -1 c S-14,T-7N, R-14W °o m m °o BOTTOM: S-18,T-7N, R-13W U ct w U a CBL c C1 = E — v o 8 ' L m Sec: 14 Twp:7N Rge: 14W Permanent Datum MSL Elevation 0 Elevation Log Measured From KB , 44' Ft.above perm.datum K.B. 44' D.F. 43' Drilling Measured From DF G.L. 0 Date @ Time Logged 02-JUL-2013 @ 17:15 Type Fluid in Hole OIL BASED Run No. ONE _Density of Fluid 9.3 PPG Depth-Driller 12516' Fluid Level FULL Depth-Logger 12600' Cement Top Est.Logged N/A Bottom-Logged Interval 12600' Equipment/Location 11202279 / STERLING Top-Log Interval SURFACE Recorded by D.SCHWARZENBERGER Max.Recorded Temp. N/A Witnessed by_ C.CRETSINGER CEMENTING DATA Surface Protection Production Liner String String String 1 Date/Time Cemented N/A N/A N/A N/A Primary/Squeeze Expected Compressive Strength _ psi@ hrs psi@ hrs psi@ hrs psi@ hrs Cement Volume Cement Type/Weight / / / / Formulation _ Mud Type/Mud Wgt. / / / / , Borehole Record Casing&Tubing Record Run Number Bit From To Size Weight From To 36 in _ 150 lb surface 200 ft 13 3/8 in 68 lb surface 1831 ft 9 5/8 in 47 lb surface 6986 ft 7 5/8 in 29.7 lb 6705 ft 13990 ft . BRIDGE PLUG HALLIBURTON SETTING RECORD Company Cook Inlet Energy Y Well Redoubt Unit #1A o a Field Redoubt Unit Shoal Undefined a Q Borough Cook Inlet State Alaska c r - cn w c c API No.: 50-733-20497-00 Sery#: 900543082 Other Services Se Location: SURFACE: 1918' FSL&315' FEL .1c o o -c S-14,T-7N, R-14W v v BOTTOM: S-18,T-7N, R-13W ccw a CBL a a - E _ -a p 0 s LL m Sec: 14 Twp:7N Rge: 14W Permanent Datum MSL Elevation 0 Elevation Log Measured From KB , 44' Ft.above perm.datum K.B. 44' D.F. 43' Drilling Measured From DF G.L. 0 Date @ Time Logged 02-JUL-2013 @ 17:15 Type Fluid in Hole OIL BASED Run No. ONE Density of Fluid 9.3 PPG Depth-Driller 12516' Fluid Level FULL Depth-Logger 12600' Cement Top Est.Logged N/A Bottom-Logged Interval 12600' Equipment/Location 11202279 / STERLING Top-Log Interval SURFACE Recorded by D.SCHWARZENBERGER Max.Recorded Temp. N/A Witnessed by C.CRETSINGER CEMENTING DATA Surface Protection Production Liner String String String Date/Time Cemented N/A N/A N/A N/A Primary/Squeeze Expected Compressive Strength psi@ hrs psi@ hrs psi@ hrs psi@ hrs Cement Volume Cement Type/Weight / / / / Formulation Mud Type/Mud Wgt. / / / / Borehole Record Casing&Tubing Record Run Number Bit From To Size _ Weight From To 36 in 150 lb surface 200 ft • 13 3/8 in 68 lb surface 1831 It 9 5/8 in 47 lb _ surface _ 6986 ft 7 5/8 in 29.7 lb 6705 ft 13990 ft _ . ..., HALLIBURTON CEMENT BOND LOG c Company Cook Inlet Energy 4(15 co Well Redoubt Unit #1A D co Field Redoubt Unit Shoal Undefined • Q • ii Borough Cook Inlet State Alaska iii D D a� API No.: 50-733-20497-00 Sery#: 900543082 Other Services c ri r E Location: SURFACE: 1918' FSL &315' FEL 0 0 S-14, T-7N, R-14W 8 ix tY U BOTTOM: S-18, T-7N, R-13W • CBL c Q 7 E — -v o 8 L m Sec:14 Twp:7N Rge: 14W Permanent Datum MSL Elevation Q Elevation Log Measured From KB , 44' Ft.above perm.datum K.B. 44' D.F. 43' Drilling Measured From DF G.L. 0 Date @ Time Logged 29-JUN-2013 @ 00:30 Type Fluid in Hole OIL BASED Run No. ONE Density of Fluid 9.3 PPG Depth-Driller 12516' Fluid Level FULL Depth-Logger 12600' Cement Top Est.Logged LOGGED Bottom-Logged Interval 12600' Equipment/Location 11202279 / STERLING Top-Log Interval SURFACE Recorded by D.SCHWARZENBERGER Max.Recorded Temp. N/A Wtnessed by C.CRETSINGER CEMENTING DATA Surface Protection Production Liner String String String Date/Time Cemented N/A N/A N/A N/A Primary/Squeeze Expected Compressive Strength psi@ hrs psi@ hrs psi@ hrs psi@ hrs Cement Volume Cement Type/Weight / / / / Formulation Mud Type/Mud Wgt. / / / / A Borehole Record Casing&Tubing Record Run Number Bit From To Size Weight From To 5 . 36 in 150 lb surface 200 ft -0 13 3/8 in 68 lb surface 1831 ft 75 9 5/8 in 47 lb surface 6986 ft v 7 5/8 in 29.7 lb 6705 ft 13990 ft v CIRCUMFERENTIAL is HALL[BURTQN ACOUSTIC SCANNING j` • TOOL (CAST-M) t p, r Company Cook Inlet Energy , cu Y Well Redoubt Unit #1A is i 6- D Q Field Redoubt Unit Shoal Undefined i . Borough Cook Inlet State Alaska 12 w -I- API No.: 50-733-20497-00 Sery#: 900543082 Other Services . Location: SURFACE: 1918'FSL&315' FEL o -0 o -° o S-14,T-7N, R-14W U iY v BOTTOM: S-18,T-7N, R-13W a CBL 0 E o — • o u m Sec: 14 Twp:7N Rge: 14W Permanent Datum MSL Elevation 0 Elevation Log Measured From KB , 44' Ft.above perm.datum K.B. 44' D.F. 43' Drilling Measured From DF G.L. 0 - Date @ Time Logged 29-JUN-2013 @ 00:30 Type Fluid in Hole OIL BASED , Run No. ONE Density of Fluid 9.3 PPG f,, Depth-Driller 12516' Fluid Level FULL - Depth-Logger 6685' Cement Top Est.Logged LOGGED '" Bottom-Logged Interval 6685' Equipment/Location 11202279 / STERLING g Top-Log Interval SURFACE Recorded by D.SCHWARZENBERGER Max.Recorded Temp. N/A Witnessed by C.CRETSINGER CEMENTING DATA Surface Protection Production Liner a String String String Date/Time Cemented _N/A N/A N/A N/A • Primary/Squeeze Expected °, Compressive Strength psi@ hrs psi© hrs psi© hrs psi@ hrs Cement Volume k' Cement Type/Weight / / / / Formulation Mud Type/Mud Wgt. / / / / Borehole Record Casing&Tubing Record Run Number Bit From To Size Weight From To _ 36 in 150 lb surface 200 ft 13 3/8 in 68 lb surface 1831 ft 9 5/8 in 47 lb surface 6986 ft 7 5/8 in 29.7 lb 6705 ft 13990 ft it' 1 I ,t HALLIBURTQN c CAST-M ,... i CASING INSPECTION t ,„ ., .., ,. i:,, ,,,, .. , , ., ... _ . COMPANY COOK INLET ENERGY , WELL REDOUBT UNIT#1A FIELD REDOUBT UNIT SHOAL UNDEFINED ■ COUNTY COOK INLET STATE ALASKA Location: il II Elevations: K.B.: 44 R.T.: 43 G.L.: 0 ki ▪ Date Processed 6/29/13 Logs Processed CAST-M !._ Job Number Date Logged 6/29/13 is Interval Processed 0'-6685' Type Fluid In Hole OIL BASED 0, Processed By C.GULLETT Location • Processed At ANC FRS -- COMPUTER PROCESSED PRODUCT — ` ._, HALLIBURTON 1 Sperry Drilling ROP Rate of Penetration DGR Dual Gamma Ray +�— EWR-Phase 4 P Yy INSITE ALD Azimuthal Lithodensity CTN Compensated Thermal Neutron TM 1 : 240 Company : Cook Inlet Energy Rig : Osprey Rig 35 Z u Well : Redoubt Unit #1A M 4 Field : Redoubt Shoal Country : USA IC b c K T API Number 50-733-20497-01-00 a v J. O Of d O Y b . -i o t� k 0 z Latitude :60°41'43.75"North Other Services T Longitude :151°40'14.44"West z o a DDSr PWD g o , 5 StatePlane X= 200,630.580 ft 0 ° ° 2 ' StatePlane Y= 2,449,941.200 ft Permanent Datum : Mean Sea Level Elevation: 0.00 ft Elev. KB Log Measured From : Drill Floor 89.10 ft Above Permanent Datum DF 89.10 ft GL Drilling Measured From : Drill Floor MD LOG WD 40.00 ft Depth Logged : 12,263.00 ft To 15,050.00 ft Unit No. : 107 Job No. :AK-XX-0900489677 Date Logged : 02-Jul-13 To 23-Jul-13 Total Depth MD : 16,060.00 ft TVD: 12,602.29 ft Plot Type : Final Spud Date : 02-Jul-13 Plot Date : 30-Aug-13 Borehole Record(MDR Borehole Record(MD) Run No. Size From To Run No. Size From To 8 6.750 in 12,290.00 ft 12.477.00 ft 9 6.750 in 12,477.00 ft 14.004.00 ft 10 6.750 in 14,004.00 ft 15,050.00 ft Casbg Record(MD) Size Weight From To 9.625 in 40.00 ibpf _ SURFACE 6,712.00 ft 7.625 in 29.00 Ibpf 6,712.00 ft 12,263.00 ft • HALLIBURTON I Sperry Drilling ROP Rate of Penetration DGR Dual Gamma Ray ted EWR-Phase 4 Pow by INSITE ALD Azimuthal Lithodensity CTN Compensated Thermal Neutron TN 1 : 600 Company : Cook Inlet Energy Rig : Osprey Rig 35 Z 3 Well : Redoubt Unit#1A En 4 Field : Redoubt Shoal d 2 W el Country : USA a E . API Number : 50-733-20497-01-00 9° ° 2 2 ya�np co w to J J K V O Z Latitude :60°41'43.75"North Other Services o Longitude :151°40'14.44"West DDSr PWD a Q StatePlane X= 200,630.580 ft J StatePlane Y= 2,449,941.200 ft Permanent Datum : Mean Sea Level Elevation: 0.00 ft Elev. KB Log Measured From : Drill Floor 89.10 ft Above Permanent Datum DF 89.10 ft GL Drilling Measured From : Drill Floor MD LOG WD 40.00 ft Depth Logged : 12,263.00 ft To 15,050.00 ft Unit No. : 107 Job No. :AK-XX-0900489677 Date Logged : 02-Jul-13 To 23-Jul-13 Total Depth MD : 16,060.00 ft TVD: 12,602.29 ft Plot Type : Final Spud Date : 02-Jul-13 Plot Date : 30-Aug-13 Run No. Borehole Record(MD' Run No. Borehole Record(MD)_ Size From To Size From To 8 6.750 in 12,290.00 ft 12.477.00 ft 9 6.750 in '2,477.00 ft '4.004.00 ft 10 6.750 in 4.004.00 ft '5.050.00 ft Cash Record(MD) Size Weight From To 9.625 in 40.00 lbpf SURFACE 6,712.00 ft 7.625 in 29.00 lbpf 6,712.00 ft 12.263.00 ft 1 1 HALLIBURTON I Sperry Drilling • ROP Rate of Penetration DGR Dual Gamma Ray EWR-Phase 4 'by fN51TE ALD Azimuthal Lithodensity CTN Compensated Thermal Neutron TM 1 : 1200 Company : Cook Inlet Energy Rig : Osprey Rig 35 r Well : Redoubt Unit#1A 0 z $ Field : Redoubt Shoal To b r d O• < W M Country : USA "" § E T API Number : 50-733-20497-01-00 O OI O z Latitude :60°41'43.75"North Other Services Longitude :151°40'14.44"West a Q DDSr PWD StatePlane X= 200,630.580 ft StatePlane Y= 2,449,941.200 ft Permanent Datum : Mean Sea Level Elevation: 0.00 ft Elev. KB Log Measured From : Drill Floor 89.10 It Above Permanent Datum DF 89.10 ft GL Drilling Measured From : Drill Floor MD LOG WD 40.00 ft Depth Logged : 12,263.00 ft To 15,050.00 ft Unit No. : 107 Job No. :AK-XX-0900489677 Date Logged : 02-Jul-13 To 23-Jul-13 Total Depth MD : 16,060.00 ft TVD: 12,602.29 ft Plot Type : Final Spud Date : 02-Jul-13 Plot Date : 30-Aug-13 Run No. Borehole Record(MD, Run No. Borehole Record(MD) Size From To Size From To 8 6.750 in 12,290.00 ft 12,477.00 ft 9 6.750 in 12,477.00 ft 14,004.00 ft 10 6.750 in 14,004.00 ft 15,050,00 ft _ Casing Record(MD) Size Weight From To 9.625 in 40.00 Ibpf SURFACE 6,712.00 ft 7.625 in 29 0 f 6.712.00 ft 12,263.00 ft HALLIBURTON I Sperry Drilling DGR Dual Gamma Ray EWR-Phase 4 her�y 'N��T ALD Azimuthal Lithodensity CTN Compensated Thermal Neutron TM 1 : 600 Company : Cook Inlet Energy Rig : Osprey Rig 35 Well : Redoubt Unit#1A Z $ Field : Redoubt Shoal M - r M Country : USA s $° a API Number : 50-733-20497-01-00 o a 0 Y >v J J K V O z Latitude :60°41'43.75"North Other Services o a Longitude :151°40'14.44"West DDSr PWD g �, a m v StatePlane X= 200,630.580 ft o StatePlane Y= 2,449,941.200 ft Permanent Datum : Mean Sea Level Elevation: 0.00 ft Elev. KB Log Measured From : Drill Floor 89.10 ft Above Permanent Datum DF 89.10 ft GL Drilling Measured From : Drill Floor TVD LOG WD 40.00 ft Depth Logged : 10,247.42 ft To 12,502.29 ft Unit No. : 107. Job No. :AK-XX-0900489677 Date Logged : 02-Jul-13 To 23-Jul-13 Total Depth MD : 16,060.00 ft WD: 12,602.29 ft Plot Type : Final Spud Date : 02-Jul-13 Plot Date : 30-Aug-13 Run No. Borehole Record(TVD. Run No. Borehole Record(TVD Size From To Size From To 8 6.750 in 10,268.93 ft 10.418.13 ft 9 6.750 in 10.418.13 ft 11.665.21 ft _ 10 6.750 in 11,665.21 ft 12,502.29 ft Casing Record(TVD) Size Weight From To 9.625 in 40.00 Ibpf _ SURFACE 5,767.95 ft 7.625 in , 29.00 IlJ pf 5.767.95 ft 10.247.42 ft . ______________.___________ _ . . ____. _ L _ . 1 3n Lo NI. 0 H N r o O I- ~r----a- a) L a. "0 Z c4 a m tiJe x o CO Y C7S a. E E0rn 0 0 0 _j 0 > i iii 8ti�c^o LW '- 0 a) N- CU o O c E- '3 Q of E a t a s Q D QM p 4 (7, �' °'o000 N W c t o3 c O o o of Of N III N o wt = H - o 2 J m Q€ ti 0.J Q g. 7 7 M o N o a LL CO ° iq . . .. . . e- � O t� s M v ° a WI In Ln O O c .. Q z o N N ooi l c Z O O V L O co II II y • .M-NN t0 �'- L1J O F°-O U')N 0 g ViSg C c E '06 ) CT co d N r °rte iI E — 2 = — c m m a0 c 4c. . =tea= W U . > U Q J J fn R . O r E�.�-N o 8 N �i-2 CC; • lima NOIIVOO1 c rc t2 � g oo,_ O N 0 'c M •- M m 0 S£SRI Muds°: Biel 2 G G w 7 o 7 S . . v o N' �(B�au a u oo ~ e 3 3 3 1 1 (uedwo� E o yccc• E ° ° 2,1 16 o No Min v6#Win 3000P921: Hem E 2 LL .. .. .. .. N 3saM own A4•3S6:buoy 0 co co co m o 0 as v M cP N3ioN..SL'£9.1. uoi eoo fy v09 :3e1 c 3 IL) I ‘..E c m _i o o icon 3Qnopaa: PIa!J m M m t J 0 0 ao rn 0 v vsn: tiw� a ° 0 0 0 f°- co HALLIBURTON ( Sperry Drilling DGR Dual Gamma Ray EWR-Phase 4 Pow �NB�T� ALD Azimuthal Lithodensity CTN Compensated Thermal Neutron 1 : 1200 Company : Cook Inlet Energy Rig : Osprey Rig 35 I d Well : Redoubt Unit#1A Z t. 4 Field : Redoubt Shoal a 2 a W Country : USA § >. API Number : 50-733-20497-01-00 a o c 10 m a D et 5 3 le' 0 0 z Latitude :60°41'43.75"North Other Services Longitude :151°40'14.44"West z o Q DDSr PWD 0 T. e - o �, v StatePlane X= 200,630.580 ft -' v StatePlane Y= 2,449,941.200 ft Permanent Datum : Mean Sea Level Elevation: 0.00 ft Elev. KB Log Measured From , : Drill Floor 89.10 ft Above Permanent Datum DF 89.10 ft GL Drilling Measured From : Drill Floor TVD LOG WD 40.00 ft Depth Logged : 10,247.42 ft To 12,502.29 ft Unit No. : 107 Job No. :AK-XX-0900489677 Date Logged : 02-Jul-13 To 23-Jul-13 Total Depth MD : 16,060.00 ft ND: 12,602.29 ft Plot Type : Final Spud Date : 02-Jul-13 Plot Date : 30-Aug-13 Run No. Borehole Record(TVD' Run No. Borehole Record(TVD Size From To Size From To 8 6.750 in 10,268.93 ft 10,418.13 ft 9 6.750 in 10.418.13 ft 11,665.21 ft 10 . 6.750 in 11,66521 ft 12.502.29 ft Casing Record((VD) Size Weight From To 9.625 in 40.00 Ibpf SURFACE 5,767.95 ft 7.625 in 29.00 Ibpf 5,767.95 ft 10.247.42 ft sza • CANRIG DRILLING TECHNOLOGr ; 301 East 92nd Avenue, Suite 2 Anchorage, AK 99515 (907) 561-2465 • (907) 561-2474 FAX TO: CooK IrIeI- rN tor y r P4ks I See ) h1rk1aA 6ot w . S '14` Avc , S 'rc 310 Ag SOS 11 �prol I4 & q q E064(03/09)•GMG Services,Inc.•713.460.8801 CANRIG DRILLING TECHNOLOGY, LTD. 301 East 92nd Avenue, Suite 2 Anchorage, AK 99515 (907) 561-2465 • (907) 561-2474 FAX TO: Ceo If■ It* E r‘ ter9y R+11% '. Gee.. & r1L \oak 601 W . 54% 114411w Qc,. - 'alO � 1� q°I S01 ! r \ or9 ' s E064(03/09)•GMG Services,Inc.•713A60.8801 ,IPI . .., . . CANRIG DRILLING TECHNOLOGY, LTD. 301 East 92nd Avenue, Suite 2 Anchorage, AK 99515 j (907) 561-2465 • (907) 561-2474 FAX TO: Coo4 I IN elrs.e1 1 i A-41°1■*, S ro.e% Kt r kk4' 60t W s 'il• Au & • S ke. - 11 0 A Nc.kur 6.1 6 i A )&, °1aS 01 E064(03/09)•GMG Services, Inc.•713.460.8801 1 C.-to Wkit.A- . , „. L ~:. I `Vitor _._ ftu-IA. Lavil - i a i' - b iI D 1 // '11.,,q13 ,, ._ ., ,,, A u --l Pt 3 P a��tr yry • ii\Sc,i L ;, 'Dr'I of, "`, 1 e rula_logs.txt volume in drive E is CIE_RU1A_Logs Volume Serial Number is OCOF-F540 Directory of E:\ 09/17/2013 11:53 AM <DIR> DIRECTIONAL 09/16/2013 05:10 PM <DIR> LOGS_RU1A 0 File(s) 0 bytes Directory of E:\DIRECTIONAL 09/17/2013 11: 53 AM <DIR> 09/17/2013 12: 54 PM <DIR> 09/16/2013 01:37 PM 26,444 Final Direction RU1A.prn 09/16/2013 11:31 AM 21,802 Final Direction RU1A.xlsx 09/17/2013 11:48 AM 11,047 RU-1 A Definitive Survey.txt 09/17/2013 11:47 AM 52,888 RU-1A definitive survey.pdf 4 File(s) 112,181 bytes Directory of E:\LOGS_RUlA 09/16/2013 05:10 PM <DIR> 09/17/2013 12:54 PM <DIR> . . 09/16/2013 05:10 PM <DIR> CGM 09/16/2013 05:10 PM <DIR> DLIS+LAS 09/16/2013 05:10 PM <DIR> EMF 09/16/2013 05:10 PM <DIR> PDF 09/16/2013 05:10 PM <DIR> TIFF 0 File(s) 0 bytes Directory of E:\LOGS_RU1A\CGM 09/16/2013 05:10 PM <DIR> 09/16/2013 05:10 PM <DIR> . . 08/30/2013 01:41 PM 701,094 CIE RU-01A 1 MD.cgm 08/30/2013 03:11 PM 616,480 CIE RU-01A 1 TVD.cgm 08/30/2013 11:19 AM 708,890 CIE RU-01A 2 MD.cgm 08/30/2013 02:54 PM 623,462 CIE RU-01A 2 TVD.cgm 08/30/2013 11:47 AM 1,028,686 CIE RU-01A 5 MD.cgm 08/30/2013 02:36 PM 847,272 CIE RU-01A 5 TVD.cgm 09/16/2013 05:10 PM <DIR> HalliburtonLogViewer 6 File(s) 4,525,884 bytes Directory of E:\LOGS_RU1A\CGM\HalliburtonLogviewer 09/16/2013 05:10 PM <DIR> 09/16/2013 05:10 PM <DIR> 02/12/2008 12:04 PM 13,908 HalliburtonLogviewPro9. 50_EnduserLicense.pdf 03/28/2008 07:00 PM 427,619 HalliburtonLogviewPro9.50_ReleaseNotes.pdf 03/26/2008 09:24 AM 9,575,424 HalliburtonLOgViewPro9501nstall .exe 03/28/2008 03:44 PM 198,493 InstallingHalliburtonLogViewPro9.50.pdf 4 File(s) 10,215,444 bytes Directory of E:\LOGS_RU1A\DLIS+LAS 09/16/2013 05:10 PM <DIR> 09/16/2013 05:10 PM <DIR> . . 08/30/2013 03:48 PM 550,020 CIE RU-01A_MERGED.dlis 08/30/2013 03:51 PM 1,077,135 CIE RU-01A_MERGED.las 08/30/2013 03:48 PM 91,771 CIE RU-01A_MERGED.ver 3 File(s) 1,718,926 bytes Directory of E:\LOGS_RU1A\EMF Page 1 rula_logs.txt 09/16/2013 05:10 PM <DIR> 09/16/2013 05:10 PM <DIR> . . 08/30/2013 01:41 PM 284,868 CIE RU-01A 1 MD.emz 08/30/2013 03:05 PM 243,146 CIE RU-01A 1 TVD.emz 08/30/2013 11:19 AM 293,967 CIE RU-01A 2 MD.emz 08/30/2013 02: 54 PM 249,633 CIE RU-01A 2 TVD.emz 08/30/2013 11:47 AM 450,101 CIE RU-01A 5 MD.emz 08/30/2013 02:36 PM 359,601 CIE RU-01A 5 TVD.emz 09/16/2013 05:10 PM <DIR> EMF Viewer 6 File(s) 1,881,316 bytes Directory of E:\LOGS_RU1A\EMF\EMF Viewer 09/16/2013 05:10 PM <DIR> 09/16/2013 05:10 PM <DIR> 06/03/2008 02:35 PM 466,944 EmfView3.exe 1 File(s) 466,944 bytes Directory of E:\LOGS_RU1A\PDF 09/16/2013 05:10 PM <DIR> 09/16/2013 05:10 PM <DIR> . . 08/30/2013 01:42 PM 290,624 CIE RU-01A 1 MD.pdf 08/30/2013 03:08 PM 218,433 CIE RU-01A 1 TVD.pdf 08/30/2013 11:21 AM 298,930 CIE RU-01A 2 MD.pdf 08/30/2013 02: 55 PM 217,076 CIE RU-01A 2 TVD.pdf 08/30/2013 11:48 AM 514,632 CIE RU-01A 5 MD.pdf 08/30/2013 02:37 PM 364,233 CIE RU-01A 5 TVD.pdf 6 File(s) 1,903,928 bytes Directory of E:\LOGS_RU1A\TIFF 09/16/2013 05:10 PM <DIR> 09/16/2013 05:10 PM <DIR> . . 08/30/2013 01:42 PM 4,807,591 CIE RU-01A 1 MD.tif 08/30/2013 03:08 PM 4,404,321 CIE RU-01A 1 TVD.tif 08/30/2013 11:20 AM 6,165,699 CIE RU-01A 2 MD.tif 08/30/2013 02:54 PM 5, 514,847 CIE RU-01A 2 TVD.tif 08/30/2013 11:47 AM 10,973,053 CIE RU-01A 5 MD.tif 08/30/2013 02:37 PM 9,275,301 CIE RU-01A 5 TVD.tif 6 File(s) 41,140,812 bytes Total Files Listed: 36 File(s) 61,965,435 bytes 27 Dir(s) 0 bytes free Page 2 �� =M,...-_ • �i' coole__ wt„ 'c'st,t Eg c L. 1 1 50-'l3 Y I � = 3 9'DASD ,k l Ru-t itQ c�r4l �T P�c_ L a, CopLuatior 11,t 1 RV —lik. L � 115b3 ■ .k.,, f ____ ,./. -,, .U 1 R �-T�7 l∎ t �-�Y✓v ` ) , ` j. ,, , . , , 1 e kul Skkki" .. TI. Fc tsarµ - 's.— rula_31ogs.txt volume in drive E is My Files Volume Serial Number is 6D5A-54C8 Directory of E:\ 08/15/2013 08:32 AM <DIR> RU-1A ACE 08/15/2013 08:32 AM <DIR> RU-1A_CAST_CBL 08/15/2013 08:31 AM <DIR> RU-1A_TCP_CORRELATION 0 File(s) 0 bytes Directory of E:\RU-1A_ACE 08/15/2013 08:32 AM <DIR> 08/15/2013 08:31 AM <DIR> . . 08/14/2013 04:01 PM 20,542,061 RU-1A ACE_05AUG13.pdf 08/14/2013 04:07 PM 102,430,882 RU-1A ACE_05AUG13_dlis.zip 08/14/2013 04:01 PM 19,218,690 RU-1A ACE_05AUG13_img.tiff 3 File(s) 142,191,633 bytes Directory of E:\RU-1A_CAST_CBL 08/15/2013 08:32 AM <DIR> 08/15/2013 08:31 AM <DIR> . . 08/15/2013 08:12 AM 56,303,536 RU-1A_CAST_CBL_05AUG13.pdf 08/15/2013 08:08 AM 96,126,489 RU-1A_CAST_CBL_05AUG13_Main.LAS 08/15/2013 08:08 AM 3,072,579 RU-1A_CAST_CBL_05AUG13_Pipe.LAS 08/15/2013 08:08 AM 3,368,514 RU-1A_CAST_CBL_05AUG13_Repeat.LAS 08/14/2013 04:50 PM 251,643,722 RU-1A_CAST_CBL_05AUG13_img.tiff 5 File(s) 410,514,840 bytes Directory of E:\RU-1A_TCP_CORRELATION 08/15/2013 08:31 AM <DIR> 08/15/2013 08:31 AM <DIR> . . 08/15/2013 08:10 AM 187,651 RU-1A_TCP_CORRELATION_07AUG13.LAS 08/15/2013 08:26 AM 944,059 RU-1A_TCP_CORRELATION_07AUG13.pdf 08/15/2013 08:25 AM 1,833,476 RU-1A_TCP_CORRELATION_07AUG13_img.tiff 3 File(s) 2,965,186 bytes Total Files Listed: 11 File(s) 555,671,659 bytes 9 Dir(s) 0 bytes free Page 1 rula_51ogs.txt Volume in drive E is My Files volume Serial Number is 3040-CBA8 Directory of E:\ 07/02/2013 11:26 AM <DIR> CASE_ANALYSIS 07/05/2013 08:39 AM <DIR> Field Prints 07/05/2013 08:23 AM <DIR> LAS Files 0 File(s) 0 bytes Directory of E:\CASE_4NALYSIS 07/02/2013 11:26 AM <DIR> 07/05/2013 08:42 AM <DIR> . . 07/02/2013 11:03 AM 135,235,673 CIE_RU#1A_FASTCASE_29JUN13_DLIS.zip 07/02/2013 11:03 AM 4,292,144 CIE_RU#1A_FASTCASE_29JUN13_img.tiff 07/02/2013 11:03 AM 4,535,304 CIE_RU#1A_FASTCASE_PAGINATED.pdf 07/02/2013 11:03 AM 2,069,437 CIE_RU#1A_FASTCASE_UNPAGINATED.pdf 4 File(s) 146,132, 558 bytes Directory of E:\Field Prints 07/05/2013 08:39 AM <DIR> 07/05/2013 08:42 AM <DIR> . . 07/02/2013 11:03 AM 21,052,073 RU-1A_CASTM_29JUN13_PAGINATED.pdf 07/02/2013 11:03 AM 21,442,058 RU-lA_CASTM_29JUN13_UNPAGINATED.pdf 07/02/2013 11:03 AM 114,616,222 RU-1A_CASTM_29JUN13_img.tiff 07/01/2013 05:11 PM 5,499,802 RU-1A_CBL_29JUN13_PAGINATED.pdf 07/01/2013 05:08 PM 5,724,593 RU-1A_CBL_29JUN13_UNPAGINATED.pdf 07/02/2013 11:12 AM 21,266,630 RU-1A_CBL_29JUN13_img.tiff 07/05/2013 08:03 AM 1,056,184 RU-1A_PLUG1_02JUL13_PAGINATED.pdf 07/05/2013 08:03 AM 1,081,333 RU-1A_PLUG1_02JUL13_UNPAGINATED.pdf 07/05/2013 08:03 AM 5,653,304 RU-1A_PLUG1_02JUL13_img.tiff 07/05/2013 08:03 AM 887,679 RU-1A_PLUG2_02JUL13_PAGINATED.pdf 07/05/2013 08:03 AM 903,251 RU-1A_PLUG2_02JUL13_UNPAGINATED.pdf 07/05/2013 08:03 AM 4,651,642 RU-1A_PLUG2_02JUL13_img.tiff 12 File(s) 203,834,771 bytes Directory of E:\LAS Files 07/05/2013 08:23 AM <DIR> 07/05/2013 08:42 AM <DIR> . . 07/02/2013 11:05 AM 66,998,044 RU-1A_CAST-M_29JUN13_Main.LAS 07/02/2013 11:05 AM 2,602,009 RU-1A_CAST-M_29JUN13_Repeat.LAS 07/05/2013 08:22 AM 7,609,539 RU-1A_CBL_29JUN13_FreePipe.LAS 07/05/2013 08:21 AM 8,348,563 RU-1A_CBL_29JUN13_Main.LAS 07/05/2013 08:19 AM 2,107,921 RU-1A_PLUG1_02JUL13.LAS 07/05/2013 08:19 AM 49,227 RU-1A_PLUG2_02JUL13.LAS 6 File(s) 87,715,303 bytes Total Files Listed: 22 File(s) 437,682,632 bytes 9 Dir(s) 0 bytes free Page 1