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Home My WebLink About214-014Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/22/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221122-1 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# SRU 213-15 50133206520000 215100 6/24/2022 Yellowjacket PERF KBU 33-06X 50133205290000 203183 6/26/2022 Yellowjacket PERF BCU 7A 50133202840100 214060 6/28/2022 Yellowjacket GPT-PERF END 3-17F 50029219460600 203216 7/2/2022 Yellowjacket PERF-RETAINER KBU 32-08 50133206240000 214014 7/12/2022 Yellowjacket PERF BCU 7A 50133202840100 214060 7/15/2022 Yellowjacket GPT-PERF SRU 213-15 50133206520000 215100 7/19/2022 Yellowjacket GPT-PLUG MPU I-17 50029232120000 204098 7/19/2022 Yellowjacket TUBING CUT CLU 05RD 50133204740100 215160 7/21/2022 Yellowjacket PLUG CLU 10 50133205530000 205106 7/21/2022 Yellowjacket RCT-JET CUT SRU 213-15 50133206520000 215100 7/22/2022 Yellowjacket PERF Please include current contact information if different from above. By Meredith Guhl at 8:52 am, Nov 23, 2022 T37295 T37295 T37295 T37296 T37297 T37297 T37298 T37299 T37300 T37301 T37302 KBU 32-08 50133206240000 214014 7/12/2022 Yellowjacket PERF Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.23 09:08:15 -09'00' By Anne Prysunka at 11:51 am, Jul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WZ&KZd/KEd/> ^ĂŶĚƐdŽƉ;DͿƚŵ;DͿdŽƉ;dsͿƚŵ ;dsͿ&d ĂƚĞ ^ƚĂƚƵƐ Dϲϲ͕ϵϯϯ͛ϲ͕ϵϰϭ͛ϱ͕ϴϭϳ͛ϱ͕ϴϮϰ͛ϴ͛ϬϵͬϮϮͬϭϵKƉĞŶ Dϰϳ͕ϮϲϬ͛ϳ͕ϮϴϬ͛ϲ͕Ϭϳϴ͛ϲ͕Ϭϵϰ͛ϮϬ͛ϬϵͬϬϰͬϭϰKƉĞŶ >Ϯϳ͕ϴϯϭ͛ϳ͕ϴϯϲ͛ϲ͕ϱϰϭ͛ϲ͕ϱϰϱ͛ϱ͛ϬϵͬϮϮͬϭϵKƉĞŶ >Ϯϳ͕ϴϲϯ͛ϳ͕ϴϲϴ͛ϲ͕ϱϲϳ͛ϲ͕ϱϳϭ͛ϱ͛ϬϵͬϮϮͬϭϵKƉĞŶ >ϯϴ͕Ϭϳϳ͛ϴ͕ϬϴϮ͛ϲ͕ϳϰϮ͛ϲ͕ϳϰϲ͛ϱ͛ϬϵͬϮϮͬϭϵKƉĞŶ >ϯϴ͕ϭϯϲ͛ϴ͕ϭϲϮ͛ϲ͕ϳϵϬ͛ϲ͕ϴϭϭ͛Ϯϲ͛ϬϵͬϬϰͬϭϰKƉĞŶ >ϰϴ͕ϮϵϬ͛ϴ͕ϯϬϬ͛ϲ͕ϵϬϬ͛ϲ͕ϵϭϬ͛ϭϬ͛ϬϴͬϬϭͬϭϰKƉĞŶ >ϰϴ͕ϯϯϬ͛ϴ͕ϯϱϱ͛ϲ͕ϴϲϭ͛ϲ͕ϴϴϵ͛Ϯϱ͛ϭϬͬϭϰͬϭϵKƉĞŶ >ϰϴ͕ϯϲϲ͛ϴ͕ϯϵϭ͛ϲ͕ϵϳϲ͛ϳ͕ϬϬϭ͛Ϯϱ͛ϭϬͬϭϰͬϭϵKƉĞŶ >ϱϴ͕ϱϭϰ͛ϴ͕ϱϮϰ͛ϳ͕ϭϬϬ͛ϳ͕ϭϭϬ͛ϭϬ͛ϬϳͬϯϬͬϭϰKƉĞŶ dǇŽŶĞŬϳϯͲϭϴ͕ϴϰϴ͛ϴ͕ϴϱϴ͛ϳ͕ϯϲϮ͛ϳ͕ϯϳϬ͛ϭϬ͛ϬϳͬϮϴͬϭϰKƉĞŶ dǇŽŶĞŬϳϱͲϴϵ͕ϮϬϮ͛ϵ͕ϮϭϮ͛ϳ͕ϲϰϳ͛ϳ͕ϲϱϱ͛ϭϬ͛ϬϳͬϮϳͬϭϰKƉĞŶ dǇŽŶĞŬϳϲͲϳϵ͕ϯϰϯ͛ϵ͕ϯϲϲ͛ϳ͕ϳϲϮ͛ϳ͕ϳϴϭ͛ϮϯΖϬϲͬϭϵͬϭϰKƉĞŶ dǇŽŶĞŬϳϴͲϮϵ͕ϱϬϬΖϵ͕ϱϭϬΖϳ͕ϴϵϭ͛ϳ͕ϴϵϵ͛ϭϬΖϬϲͬϬϳͬϭϰ/ƐŽůĂƚĞĚ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚďǇDϬϲͲϮϵͲϮϮ WZKWK^ <ĞŶĂŝ'ĂƐ&ŝĞůĚ tĞůů͗<hϯϮͲϬϴ >ĂƐƚŽŵƉůĞƚĞĚ͗ϴͬϬϭͬϮϬϭϰ Wd͗ϮϭϰͲϬϭϰ ^/E'd/> ^ŝǌĞdǇƉĞtƚͬ'ƌĂĚĞͬŽŶŶ/dŽƉƚŵ ϭϲΗŽŶĚƵĐƚŽƌEͬ^ƵƌĨϭϯϱΖ ϭϬͲϯͬϰ͟^ƵƌĨĂĐĞϰϱ͘ϱͬ>ͲϴϬͬdϵ͘ϵϱϬ^ƵƌĨϭ͕ϰϳϴΖ ϳͲϱͬϴΗ/ŶƚĞƌŵĞĚŝĂƚĞϮϵ͘ϳͬ>ͲϴϬͬdϲ͘ϴϳϱ^ƵƌĨϲ͕ϰϬϱΖ ϱΗWƌŽĚƵĐƚŝŽŶϭϴͬ>ͲϴϬͬtͬͲ,dϰ͘Ϯϳϲϱ͕ϴϰϵ͛ϵ͕ϳϰϲ͛ dh/E'd/> ϱΗdƵďŝŶŐϭϴͬ>ͲϴϬͬtͬͲ,dϰ͘Ϯϳϲ^ƵƌĨϱ͕ϴϰϵ͛ :t>Zzd/> EŽĞƉƚŚ/ƚĞŵ ϭϱ͕ϴϰϵ͛ϱ͟^ǁĞůůWĂĐŬĞƌ Ϯϳ͕ϯϯϬ͛ϱ͛WƵƉ ϯϴ͕ϬϮϴ͛ϱ͛WƵƉ ϰϵ͕ϰϳϱ͛/WǁͬϮϳ͛ŽĨĐĞŵĞŶƚ;dKϵ͕ϰϰϴ͛Ϳ KWE,K>ͬDEdd/> ϭϬͲϯͬϰ͟ϭϲϬ>͛ƐŽĨĐĞŵĞŶƚŝŶϭϯ͘ϱ͟,ŽůĞ͘ZĞƚƵƌŶƐƚŽ^ƵƌĨĂĐĞ ϳͲϱͬϴΗϮϲϭ>͛ƐŽĨĐĞŵĞŶƚŝŶϵͲϳͬϴ͟,ŽůĞ͘ZĞƚƵƌŶƐƚŽ^ƵƌĨĂĐĞ ϱ͟ϭϭϰ>͛ƐŽĨĐĞŵĞŶƚŝŶϲͲϯͬϰ͟,ŽůĞ͘dKϰ͕ϲϬϬ͛ĂůĐƵůĂƚĞĚ WZ&KZd/KEd/> ^ĂŶĚƐdŽƉ;DͿƚŵ;DͿdŽƉ;dsͿƚŵ ;dsͿ&d ĂƚĞ^ƚĂƚƵƐ Dϲϲ͕ϵϯϯ͛ϲ͕ϵϰϭ͛ϱ͕ϴϭϳ͛ϱ͕ϴϮϰ͛ϴ͛ϬϵͬϮϮͬϭϵKƉĞŶ Dϰϳ͕ϮϲϬ͛ϳ͕ϮϴϬ͛ϲ͕Ϭϳϴ͛ϲ͕Ϭϵϰ͛ϮϬ͛ϬϵͬϬϰͬϭϰKƉĞŶ >ϭцϳ͕ϰϯϵΖцϳ͕ϰϱϵ͛цϲ͕ϮϮϯ͛цϲ͕Ϯϯϵ͛ϮϬ͛dWƌŽƉŽƐĞĚ >ϭцϳ͕ϱϭϴΖцϳ͕ϱϯϲΖцϲ͕Ϯϴϳ͛цϲ͕ϯϬϭ͛ϭϴ͛dWƌŽƉŽƐĞĚ >ϭцϳ͕ϲϭϱΖцϳ͕ϲϮϱ͛цϲ͕ϯϲϱ͛цϲ͕ϯϳϯ͛ϭϬ͛dWƌŽƉŽƐĞĚ >ϭ&hƉƌцϳ͕ϲϱϯΖцϳ͕ϲϲϯΖцϲ͕ϯϵϲ͛цϲ͕ϰϬϰ͛ϭϬ͛dWƌŽƉŽƐĞĚ >Ϯϳ͕ϴϯϭ͛ϳ͕ϴϯϲ͛ϲ͕ϱϰϭ͛ϲ͕ϱϰϱ͛ϱ͛ϬϵͬϮϮͬϭϵKƉĞŶ >Ϯцϳ͕ϴϰϰΖцϳ͕ϴϲϭΖцϲ͕ϱϱϭΖцϲ͕ϱϲϱΖϭϳΖdWƌŽƉŽƐĞĚ >Ϯϳ͕ϴϲϯ͛ϳ͕ϴϲϴ͛ϲ͕ϱϲϳ͛ϲ͕ϱϳϭ͛ϱ͛ϬϵͬϮϮͬϭϵKƉĞŶ >Ϯцϳ͕ϴϳϴΖцϳ͕ϵϭϴΖцϲ͕ϱϳϵΖцϲ͕ϲϭϮΖϰϬ͛dWƌŽƉŽƐĞĚ >Ϯцϳ͕ϵϲϳΖцϳ͕ϵϳϲΖцϲ͕ϲϱϮ͛цϲ͕ϲϱϵ͛ϵ͛dWƌŽƉŽƐĞĚ >ϯцϴ͕ϬϲϰΖцϴ͕ϬϳϮΖцϲ͕ϳϯϭ͛цϲ͕ϳϯϳ͛ϴ͛dWƌŽƉŽƐĞĚ >ϯϴ͕Ϭϳϳ͛ϴ͕ϬϴϮ͛ϲ͕ϳϰϮ͛ϲ͕ϳϰϲ͛ϱ͛ϬϵͬϮϮͬϭϵKƉĞŶ >ϯϴ͕ϭϯϲ͛ϴ͕ϭϲϮ͛ϲ͕ϳϵϬ͛ϲ͕ϴϭϭ͛Ϯϲ͛ϬϵͬϬϰͬϭϰKƉĞŶ 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Operations Abandon Plug Perforations LJ Fracture Stimulate LJ Pull Tubing Li Operations shutdown Li Performed: Suspend ❑ Perforate ❑✓ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ✓ 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑✓ Stratigraphic❑ Exploratory ❑ Service ❑ 214-014 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-133-20624-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEE A028142 & FEE A022330 Kenai Beluga Unit (KBU) 32-08 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kenai Gas Field / Upper Tyonek Gas & Beluga Gas Pool 11. Present Well Condition Summary: Total Depth measured 9,847 feet Plugs measured 9,448 feet true vertical 8,183 feet Junk measured N/A feet Effective Depth measured 9,448 feet Packer measured 5,849 feet true vertical 7,848 feet true vertical 4,940 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 135' 16" 135' 135' Surface 1,478' 10-3/4" 1,478' 1,420' 5.210psi 2,470psi Intermediate 6,405' 7-5/8" 6,405' 5,391' 6,890psi 4,790psi Production 3,897' 5" 9,746' 8,098' 10,140psi 10,500psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 5" 18# / L-80 5,849' MD 4,940' TVD Packers and SSSV (type, measured and true vertical depth) Swell Pkr 5,849' MD 4,940' TVD N/A; N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 839 8 5 69 Subsequent to operation: 0 1469 15 15 83 14. Attachments (required per 20 pac 25.070, 25.071, & 25.2113) 15. Well Class after work: Daily Report of Well Operations Q Exploratory❑ Development ❑✓ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas L�tj WDSPL LJ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-458 Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Manager Contact Email: tkramerGilhilcoro cora yOperations Authorized Signature: ��fj� 6 Q /!/r e: = Contact Phone: 777-8420 Form 10-404 Revised 4/2017 l�'�� /�( lDMS-16AOV 18 2019 Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name Ri ETE- API Number Well Permit Number Start Date End Date KBU 32-08 Lig ne 50-133-20624-00-00 214-014 10/14/19 10/14/19 Daily Operations: 10/14/2019 - Monday PTW and JSA. Warrior system was blowing fuses when check firing. Trouble shoot panel and find wiring shorted. Brought some cables and wiring from shop and fixed. Rig up lubricator PT to 250 psi low and 3,500 psi high. Well flowing 871K at 69 psi. RIH w/ 2-7/8" x 25' Razor HC, 6 spf, 60 deg phase and tie into OHL. Ran correlation log and send to town. Get ok to pert from 8.366' to 8,391_Spotted and fired gun with well flowing 825K at 71 psi. After 5 min - 925K at 74 psi. 10 min - 1.1 mcf at 81 psi and 15 min - 1.225 mcf at 82 psi. POOH and line stopped at 91'. Closed BOP's on line and pull line out of grease tube. Clamped and pulled line out to where we saw a flat. spot on line that wouldn't go thru grease tubes. We cut and stripped line and tools out of hole. All shots fired and bull nose off gun was caked with dry/moist mud in it. Be- headed line. RIH w/ 2-7/8" x 25' Razor HC, 6 spf, 60 deg phase and tie into OHL. Ran correlation log and send to town. Told to add 2' to correlation log. Added 2'. Spotted and fired gun from 8.330' to 8.355' with well flowing 1.08 mcf at 75.4 psi. After 5 min - 1.4 mcf at 94.7. 10 min - 1.8 mcf at 103.3 psi and 15 min - 1.98 mcf at 104.6 psi. At 20 min - 1.8 mcf at 101 psi. POOH. All shots fired and moist mud was caked in bull nose but gun wasn't wet. Rig down off well. Leave equipment here and pick it up on the was to Kalotsa in the morning. 16" 10.3/4" 7-5/8" LLC RKB: MSL= 22' 2 M36 MR48 L82C LB2C 4 :Tymek78-2 5„ V-1* 4 TO=9,847(MD) /8,183'(TVD) PBTD=9,448(MD) /7,848' (ND) SCHEMATIC CASING DETAIL Kenai Gas Field Well: KBU 32-08 Last Completed: 8/01/2014 PTD: 214-014 Size Type Wt/Grade/Conn ID 5,849' 5" Swell Packer 16" Conductor N/A 3 8,028' 10.3/4" Surface 45.5 /L-80/BTC 9.950 MB48 A5,84919,746' 7-5/8" Intermediate 29.7/L-80/BTC 6.875 09/04/14 5" Production 18/L-80/DWC/C-HT 4.276 6,545' TUBING DETAIL 5" Tubing I 18/L-80/DWC/C-HT 1 4.276 Surf 5,849' JEWELRY DETAIL No Depth Item 1 5,849' 5" Swell Packer 2 7,334 5' Pup 3 8,028' S' Pup 4 9,475' CIBP w/ 27' of cement (TOC 9,448') PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) (TVD) F7 Date Status MB6 6,933' 6,941' 5,817' 5,824' 8' 09/22/19 Open MB48 7,260' 7,280' 6,078' 6,094' 20' 09/04/14 Open L82C 7,831' 7,836' 6,541' 6,545' S' 09/22/19 Open L132C 7,863' 7,868' 6,567' 6,571' 5' 09/22/19 Open L63A 8,077' 8,082' 6,742' 6,746' S' 09/22/19 Open LB3B 81136' 8,162' 6,790' 6,811' 26' 09/04/14 Open LB4A 8,290' 81300' 61900' 6,910' 10' 08/01/14 Open L84C 8,330' 8,355' 6,86: 6,889' 25'1 10/14/19 Open L84C 8,366' 8,391' 6,976 7,001' 25' 10/14/19 Open L85A 8,514' 8,524' 7,100' 7,110' 30' 1 07/30/14 Open Tyonek 73-1 8,848' 8,858' 7,362' 7,370' 10' 07/28/14 Open Tyonek 75-8 91202' 9,212' 7,647' 7,655' 10' 07/27/14 Open Tyonek 76-7 9,343' 9,366' 7,762' 7,781' 23' 06/19/14 Open Tyonek 78-2 9,500' 9,510' 7,891' 7,899' 10' 06/07/14 Isolated OPEN HOLE/ CEMENT DETAIL Updated by DMA 11-01-19 160BBL's of cement in 13.5" Hole. Returns to Surface 2616BL's of cement in 9-7/8" Hole. Returns to Surface El 5" 114BBL's of cement in 6-3/4" Hole. TOC 4,600 Calculated Updated by DMA 11-01-19 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Kenai Gas Field, Upper Tyonek Gas Pool, KBU 32-08 Permit to Drill Number: 214-014 Sundry Number: 319-458 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a o g c c. a l a s ka. g o v Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Je Price Chair DATED this q day of October, 2019. -Mms��'4CT 10 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS nn n 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: Nitrogen ❑� 2. Operator Name: Hilcorp Alaska, LLC 4. Current Well Class: 5. Permit to Drill Number: Exploratory ❑ Development Q - Stratigraphic ❑ Service ❑ 214-014 - 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, Alaska 99503 50-133-20624-00-00 . 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 510A ' Will planned perforations require a spacing exception? Yes[—] No Kenai Beluga Unit (K8U) 32-08 9. Property Designation (Lease Number): 10. Field/Pool(s): FEE A028142'& FEE A022330 Kenai Gas Field: Beluga / Upper Tyonek Gas Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,847' $`738r5/> 9,448' 7,848' 2,380 psi 9,475' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 135' 16" 135' 135' Surface 1,478' 10-3/4" 1,478' 1,420' 5,210psi 2,470psi Intermediate 6,405 7-5/8" 6,405' 51391' 6,890psi 4,790psi Production 3,897' 5" 9,746' 8,098' 10,140psi 10,500psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 5" 18# / L-80 5,849' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Swell Pkr; N/A 5,849'MD/4,940'TVD; N/A 12. Attachments: Proposal Summary Wellbore schematic L47j 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Strati ns hic 9 p ❑ Development [] Service ❑ 14. Estimated Date for ✓ 15. Well Status after proposed work: Commencing Operations: October 18, 2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Christina Twogood Authorized Name: Be York 777-8345 Contact Email: ctwogood(a)hilcoro.com Authorized Title: Operations Manager Contact Phone: 907-777-8443 � 1 Authorized Signature: " Date: % �� vt COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: tt��I 1BDMS �� 4CT 10 2019 Post Initial Injection MIT Req'd? Yes E] No ❑ Spacing Exception Required? Yes El No ©/ Subsequent Form Required: !�—.. APPROVED BY O n Approved by: COMMISSIONER THE COMMISSION I I Date: (�an'--' gyp• � �Y t0� J'+1 JnN �,� Submit Form and '710-403 evi e 1 01 Approved applica t It r the date of approval. Attachment in Duplicate H Hilwrp Alaska, LLi Well Prognosis Well: KBU 32-08 Date: 10/18/2019 Well Name: KBU 32-08 API Number: 50-133-20624-00-00 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: 10/18/2019 Rig: E -Line Reg. Approval Req'd? 10-403 Sundry Number: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-044 First Call Engineer: Christina Twogood (907) 777-8443 (0) (907) 378-7323 (C) Second Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (C) Current BHP: -3,079 psi @ 7,001' TVD (Based on 2014 RFT data) Max. Expected BHP: ^3,059 psi @ 7,001' TVD (Based on normal gradient of 0.437 psi/ft) Max. Potential Surface Pressure: -2,380 psi @ 7,001' TVD (Based on current BHP and gas gradient to surface (0.10 psi/ft)) Brief Well Summa ppp��...�� O 4 / to,0 KBU 32-08 was drilled and completed in March 2014 targeting the Upper Tyonek and Beluga formations as a 5" monobore completion. In July five zones were fracture stimulated: In September 2014 two zones were perforated. In September 2019 (3) Lower Beluga sands and (1) idle Beluga sand was perforated. The purpose of this work/sundry is to add perforations in the LB -4C and the LB -2D sands in the Lower Beluga zone. Notes Regarding Wellbore Condition • Last tag at 8,493' RKB on 9/23/2019, fluid level was at 8,300' • RA markers are at 7,330' MD and 8,028' MD per the 3/15/2014 Casing and Cementing Report Safety Concerns • Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. • Considertank placement based on wind direction and current weather forecast (venting nitrogen during thisjob). • Ensure all crews are aware of stop job authority. E -Line Procedure 1. MIRU E -Line and pressure control equipment. PT lubricator to 250 psi low/ 3,000 psi high. 2. RIH with GPT tool and find fluid level. For applicable perfs, if fluid level is over the depth to shoot the new perfs, discuss using Nitrogen with the Operations Engineer. 3. If needed, RU Nitrogen Truck and pressure up on well to push water back into formation. Use GPT Tool to confirm fluid leve .. 4. RU perfguns. ff 1lilcara Alaska, LL 5. RIH and perforate the following intervals: Well Prognosis Well: KBU 32-08 Date: 10/18/2019 Zone Sand Top (MD) Btm (MD) Top (ND) Btm (ND) Amt Lower Beluga LB_2D +7,887' +7,917' +6,500' +6,530' 30' Lower Beluga LB_4C +8,330' +8,355' +6,861' ±6,889' 25' Lower Beluga LB 4C +8,366' +8,391' +6,976' ±7,001' 25' a. Shut in well 5 minutes before perforating. b. Proposed perfs shown on the proposed schematic in red font. c. Final Perfs tie-ins sheet will be provided in the field for exact perf intervals. d. Use Gamma/CCL to correlate. e. Spacing allowance is based on Conservation Order 510A. f. Record tubing pressures before and after each perforating run. g. Record 5, 10 and 15 minute pressures after firing guns. 6. POOH and RD E -Line. 7. Turn well over to production. E -Line Procedure (Contingency) 1. If these zones produce sand and/or water and need to be isolated. 2. MIRU E -Line, PT lubricator to 250 psi Low/ 3,000 psi High. 3. RIH and set 5" CIBP (or tubing patch) and dump 25' of cement on top of the plug. Attachments 1. Current Well Schematic 2. Proposed Well Schematic 3. Standard Well Procedure— N2 Operations 4 1 16" 103/4" 7-5/8" RIB: M5L=22' 02 Tyonek73-1 Tyaek 758 TOC @9,4411Tymek 75 y4 Ty -08- 5„ .. TD=9,847'(MD) /8,183'(TVD) PBTD=9,448'(W) /7,848' (ND) SCHEMATIC CASING DETAIL Kenai Gas Field Well: KBU 32-08 Last Completed: 8/01/2014 PTD: 214-014 SizeAIntermedlate Depth Wt/Grade/Conn ID Top Btm 16" 7,330' WA 3 Surf 135' 10-3/4" 9,475' 45.5/L-80/BTC 9.950 Surf 1,478' 7-5/8" 6,078' 29.7/L-80/BTC 6.875 Surf 6,405' 5" 7,831' 18/L-80/DWC/C-HT 1 4.276 5,849' 9,746' TUBING DETAIL 5" Tubing 18/L-SO/DWC/C-HT 1 4.276 1 Surf 1 5,849' JEWELRY DETAIL No Depth Item 1 5,849' 1 S" Swell Packer 2 7,330' S' Pup 3 8,028' S' Pup 4 9,475' CIBP w/ 27' of cement (TOC 9,448') PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) rn (ND) FT Date Status M86 6,933' 6,941' 5,817' 5,824' 8 09/22/19 Open MB413 7,260' 7,284 6,078' 6,094' 20 09/04/14 Open LB2C 7,831' 7,836' 6,541' 6,545' S 09/22/19 Open L32C 7,863' 7,868' 6,567' 6,571' S 09/22/19 Open LB3A 8,077' 8,082' 6,742' 6,746' S 09/22/19 Open LB313 8,136' 8,162' 6,790' 6,811' 26 09/04/14 Open L84A 8,290' 8,300' I 6,900' 1 6,910' 1 10' 1 08/01/14 1 Open L85A 8,514' 8,524' 7,100' 7,114 1 10' 1 07/30/14 1 Open Tyonek 73-1 8,848' 8,858' 7,362' 7,370' 10' 07/28/14 Open Tyonek75-8 9,202' 9,212' 7,647' 7,655' 30' 07/27/14 Open Tyonek 76-7 9,343' 9,366' 7,762' 7,781' 1 23' 06/19/14 Open Tyonek 78-2 9,500' 9,510' 7,891' 7,899' 1 10' 06/07/14 1 Isolated OPEN HOLE / CEMENT DETAIL 103/4" 160BBUS of cement in 13.5" Hole. Returns to Surface 7-5/8" 261BBL's of cement in 9-7/8" Hole. Returns to Surface 5" 13486L's of cement in 6-3/4"Hole. TOC 4,600' Calculated Updated by DMA 09-27-19 PROPOSED Kenai Gas Field Well: 32-08 SCHEMATIC Last Completed: 8/01/2014 corp Alaska. LLC PTD: 214-014 16" 7-5/8 RKB: MSL =2Y 3 LBSA LB3B LB4A / UB4C / Tyonek 73-1 Tycrek 758 TOC@9'448' Tyonek 76.7 4 Tyonek 78-2 5" TD=9,847(MD) /8,183'(ND) PBTD=9,448'(NID) /7,848' (TVD) CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 16" Conductor N/A 3 Surf 135' 10-3/4" Surface 45.5/L-80/BTC 9.950 Surf 1,478' 7-5/8" Intermediate 29.7/L-80/BTC 6.875 Surf 6,405' 5" Production 18/L-80/DWC/C-HT 4.276 5,849' 9,746' TUBING DETAIL 5" Tubing 18/L-80/DWC/C-HT 1 4.276 1 Surf 1 5,849' JEWELRY DETAIL No Depth Item 1 5,849' 5" Swell Packer 2 7,330' S' Pup 3 8,028' 5' Pup 4 9,475' CIBP w/ 27' of cement (TOC 9,448') PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) (TVD) (TVD) FT Date Status MB6 6,933' 6,941' 5,817' 8' 09/22/19 Open M84B 7,260' 1 7,28(Y 1 6,078' 1 6,094' 1 20' 09/04/14 Open LB2C 7,831' 1 7,836' 6,541' 6,545' S' 09/22/19 Open L82C 7,863' 1 7,868' 1 6,567' 6,571' S' 09/22/19 Open LB20 ±7,887_t_±7,917' +6,500' +6,530' 30' TBD Proposed LB3A 8,077' 8,082' 6,742' 6,746' S' 09/22/19 Open LB38 8,136' 8,162' 6,790' 6,811' 26' 09/04/14 Open LB4A 8,290' 8,300' 6,900' 6,910' 10' 08/01/14 Open • LB4C +8,330' +8,355' +6,861' +6,889' 25' TBD Proposed LB4C +8,366' +_8,391' +6,976' +7,001' 25' TBD proposed 8,514' 8,524' 7,100' 7 7,110' 10' 07/30/14 1 -- Open Tyonek 73-1 8,848' 8,858' 7,362' 7,374 30' 07/28/14 Open Tyonek 75-8 9,202' 9,212' 7,647' 7,655' 10' 07/27/14 Open Tyonek 76-7 9,343' 9,366' 7,762' 7,781' 23' 06/19/14 Open Tyonek 78-2 9,500' 9,510' 7,891' 7,899' 10' 06/07/14 Isolated OPEN HOLE/ CEMENT DETAIL 10-3/4" 160BBL's of cement In 13.5" Hole. Returns to Surface 7-5/8" 261BBL's of cement in 9-7/8" Hole. Returns to Surface 5" 114BBL's of cement in 6-3/4" Hole. TOC 4,60(Y Calculated Updated by CMT 10-4-19 STANDARD WELL PROCEDURE HilforpAlaska, LLC NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre -job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4 -gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL vl Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS OCT j 4i -:n �11iv 1. Operations Abandon LJ Plug PerforationsET Fracture Stimulate Li Pull Tulbing0 Operations shutdown Ll Performed: Suspend ❑ Perforate ❑� Other Stimulate ❑ Alter Casing Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Displace Nitrogen❑✓ 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑✓ Exploratory ❑ 214-014 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6. API Number: AK 99503 50-133-20624-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEE A028142 & FEE A022330 Kenai Beluga Unit (KBU) 32-08 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kenai Gas Field / Upper Tyonek Gas & Beluga Gas Pool 11. Present Well Condition Summary: Total Depth measured 9,847 feet Plugs measured 9,448 feet true vertical 8,138 feet Junk measured N/A feet Effective Depth measured 9,448 feet Packer measured 5,849 feet true vertical 7,848 feet true vertical 4,940 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 135' 16" 135' 135' Surface 1,478' 10-3/4" 1,478' 1,420' 5,210psi 2,470psi Intermediate 6,405' 7-5/8" 6,405' 5,391' 6,890psi 4,790psi Production 3,897' 5" 9,746' 8,098' 10,140psi 10,500psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 5" 18# / L-80 5,849' MD 4,940' TVD Packers and SSSV (type, measured and true vertical depth) Swell Pkr 5,849' MD 4,940' TVD N/A; N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 10 585 11 5 76 Subsequent to operation: 1 0 840 9 5 70 14. Attachments (required per 20 AAc 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations El Exploratory❑ Development p ❑ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. WeII Status after work: Oil 71 Gas WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-397 Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer0hilcoro.com Authorized Signature: 7` Date: 11, 0 (A 1.0 } ok Contact Phone: 777-8420 Form 10-404 Revised 4/201 a /��r -/ /e , Y. j OCT 0 7 2019 fC S / RBDMS Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date KBU 32-08 Rig 401 50-133-20624-00-00 1 214-014 9/22/19 9/22/19 Daily Operations: - 09/22/2019-Sunday PTW and JSA. Rig up lubricator. PT to 250 psi low and 3,500 psi high. Well flowing 613K at 64 psi. RIH w/GPT, 3-1/4" GR and tie into OHL. Tag at 8,493' and solid fluid level at 8,300'. Run correlation log and send to town to see how far off we were. POOH. We needed to shift log up 2 '. RIH w/ 2-7/8" x 5' Razor HC, 6 spf, 60 deg phase and tie into GPT log. Run correlation log and send to town. Get ok to pert from 8077' to 8082' with well flowing 607.3K at 68 psi. Spotted and fired gun. After 5 min - 635.9K at 68 psi, 10 min - 615.1K at 68 psi and 15 min - 515.4K at 67 psi. POOH. All shots fired and gun was soapy like wet. RIH w/ 2-7/8" x 5' Razor HC, 6 spf, 60 deg phase and tie into GPT log. Run correlation log and send to town. Get ok to pert from 7_863' to ' with well flowing 666.2K at 68.8 psi. Spotted and fired gun. After 5 min - 728.2K at 71 psi, 10 min - 750.4K at 72 psi and 15 min - 667.3K at 72 psi. POOH. All shots fired and gun was soapy like wet. RIH w/ 2-7/8" x 5' Razor HC, 6 spf, 60 deg phase and tie into GPT log. Run correlation log and send to town. Get ok to perf from 7,831' t� ith well flowing 746.5K at 70 psi. Spotted and fired gun. After 5 min - 754.2K at 70 psi, 10 min - 714.3K at 69 psi and 15 min - 616.3K at 68 psi. POOH. All shots fired and gun was soapy like wet. RIH w/ 2-7/8" x 8' Razor HC, 6 spf, 60 deg phase and tie into GPT log. Run correlation log and send to town. Get ok to perf from 6,933' to 6,941' with well flowing 756K at 68 psi. Spotted and fired gun. After 5 min - 770K at 68.4 psi, 10 min - 700K at 66.3 psi and 15 min - 749K at 68.9 psi. POOH. All shots fired and gun was soapy like wet. Rig down lubricator and turn well over to field. H ITncmn nista.lcr, 16" 7-5/9- RKB: MSL = 22' 2 M36 MM8 LB2C LB2C 3 LB3A LB3B LB4A LB54 Tyaek 734 Tyonek 758 4 5„ Tyaek78 TO=9,847'(MD) /8,183'(ND) PBTD=9,448'(MD) /7,848' (TND) SCHEMATIC CASING DETAIL Kenai Gas Field Well: KBU 32-08 Last Completed: 8/01/2014 PTD: 214-014 Size Type Wt/ Grade/ Conn ID Top Btm 16" Conductor N/A 3 Surf 135' 30-3/4" Surface 45.5/L-80/BTC 9.950 Surf 3,478' 7-5/8" Intermediate 29.7/L-80/BTC 6.875 Surf 6,405' 5" Production 18 / L-80 / DWC/C-HT 4.276 5,849' 9,746' I UBING UL [AIL 5" Tubing 18/L-80/DWC/C-HT 4.276 Surf 5,849' JEWELRY DETAIL No Depth Item 1 5,849' 5" Swell Packer 2 7,330' S' Pup 3 8,028' S' Pup 4 9,475' CIBP w/ 27' of cement (TOC 9,448') PERFORATION nFTAII Sands Top (MD) Btm (MD) Top (TVD) Btm TVD) FT MB6 6,933' 6,941' 5,817' 5,824' 8 MB4B 7,260' 7,280' 6,078' 6,094' 20 i09/22/19 P(OpeUn LB2C 7,831' 7,836' 6,541' 6,545' 5 L32C 7,863' 7,868' 6,567' 6,571' 5 LB3A 8,077' 8,082' 6,742' 6,746' S LB3B 81136' 8,162' 6,790' 6,811' 26 09/04/14 Open LB4A 8,290' 8,300' 6,900 6,910' 10 08/01/14 Open LB5A 8,514' 8,524' 7,100' 7,110' 10' 07/30/14 Open Tyonek 73-1 8,848' 8,858' 7,362' 7,370' 10' 07/28/14 Open Tyonek 75-8 9,202' 9,212' 7,647' 7,655' 10' 07/27/14 Open Tyonek 76-7 9,343' 9,366' 7,762' 7,781' 23' 06/19/14 Open Tyonek 78-2 9,500' 9,510' 7,891' 7,899' 10' 06/07/14 Isolated OPEN HOLE/ CEMENT DETAIL 10-3/4" 160BBL's of cement in 13.5" Hole. Returns to Surface 7-5/8" 1 261BBUs of cement in 9-7/8" Hole. Returns to Surface 5" 1 114BBL's of cement in 6-3/4" Hole. TOC 4,600' Calculated Updated by DMA 09-27-19 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, Inc. 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Kenai Gas Field, Beluga/Upper Tyonek Gas Pool, KBU 32-08 Permit to Drill Number: 214-014 Sundry Number: 319-397 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaslka.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this fday of September, 2019. �BDMS.L4�(IZEP 0 5 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ASU ; 2 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 _, n f-. ,4` ("`• 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Aerations shutdown❑ Suspend ❑ Perforate ❑� ' Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Nitrogen ❑� 2. Operator Name: Hilcorp Alaska, LLC 4. Current Well Class: Permit 5. Pit to Drill Number: D. s P/« G Exploratory ❑ Development Q - Stratigraphic ❑ Service ❑ 214-014 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, Alaska 99503 50-133-20624-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 510A • Will planned perforations require a spacing exception? YeED No ❑✓ Kenai Beluga Unit (KBU) 32-08 9. Property Designation (Lease Number): 10. Field/Pool(s): FEE A02814i & FEE A022331 • Kenai Gas Field: Beluga / Upper Tyonek Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,847' - 8,138' 9,448' 7,848' 2,579' 9,475' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 135' 16" 135' 135' Surface 1,478' 10-3/4" 1,478' 1,420' 5,210psi 2,470psi Intermediate 6,405' 7-5/8" 6,405' 5,391' 6,890psi 4,790psi Production 3,897' 5" 9,746' 8,098' 10,140psi 10,500psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 5" 18# / L-80 5,849' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Swell Pkr; N/A 5,849'MD/4,940'TVD; N/A 12. Attachments: Proposal Summary El 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: Septembepe2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑Q WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Christina Twogood Authorized Name: Bo York Contact Email: ctwocood(c�hilcoro.com Authorized Title: Operations Manager Contact Phone: 907-777-8443 a Authorized Signature: i ) 7 Date: ! A, 161 1 COMMISSION L1§E ONLY Conditions of approval: otify Commission so that a representative may witness Sundry Number: I r /_^I /✓\ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RDDMSI�SEP 0 51019 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: / — "(64 APPROVED ld /IQ Approved by: COMMISSIONER THEHECOMMISSION Date: "0- 3�-ed 11 � ~��a �I� � Submit Form and rm 1a4oa evised 11/2015 Approved application is al 1 t s a of approval.�a/„/_ Attachments Duplicate T J%'� / ,i " �J 0 50 B 1lilcora Alaska. LLC RKS. M51.=2Y 16" 10.3/4" 7-5/8" i,., .1 1 i 3. ID Top 2 it Conductor i S' Pup Surf 135' L MB4B 45.5 /L-80 / BTC 3 l LB3B 7-5/8" LB44 29.7 / L-80 / BTC IRV Surf 6,406' w Tyandc 73-7 18 / L-80 / DWC/C-H7 Tyonek 758 29,448 Tyamek 76-7 * ~ 4 M Tytack 78-2 5" vis 7,100' TD =9,746(fvD) /8,O96'(TVD) PBTD=9,35r(MD)17,768' IND) SCHEMATIC DETAIL Kenai Gas Field Well: KBU 32-08 Last Completed: 8/01/2014 PTD: 214-014 Size Type Wt/ Grade/ Conn ID Top Btm 16" Conductor N/A S' Pup Surf 135' 10-3/4" Surface 45.5 /L-80 / BTC 9.950 Surf 1,478' 7-5/8" Intermediate 29.7 / L-80 / BTC 6.875 Surf 6,406' 5" Production 18 / L-80 / DWC/C-H7 4.276 5,849' 9,746' TUBING DETAIL 5" Tubing I18/L-80/DWUC-HT 4.276 Surf 5,849' JEWELRY DETAIL No Depth Item 1 5,849' S" Swell Packer 2 7,330' S' Pup 3 8,028' S' Pup 4 9,475' CIBP OPEN HOLE/ CEMENT DETAIL 30-3/4" 16086L's of cement In 13.5" Hole. Returns to Surface 7-5/8" 2638BL's of cement In 9-7/8" Hole. Returns to Surface 5" 114BBCsof cement In 6-3/4" Hole. TOC 4,600'Calculated PERFORATION DETAIL Sands Top (MD) Btm(MD) Top(TVD) (Np) FT Date Status M848 1 7,261' 7,280' 6,078' 6,094' 1 20 09/04/14 Open L83B 8,136' 8,162' 6,790' 6,811' 26 09/04/14 Open LB4A 8,290' 8,300' 6,900' 6,911' 10' 08/01/14 Open LB5A 8,514' 8,524' 7,100' 7,110' 10' 07/30/14 Open Tyonek 73-1 8,848' 8,858' 7,362' 7,370' 10' 07/28/14 Open Tyonek 758 9,202' 9,212' 7,647' 7,655' 10' 07/27/14 Open Tyonek 76-7 9,343' 9,366' 7,762' 7,781' 23' 06/19/14 Open Tyonek 78-2 9,500' 9,510' 7,891' 7,899' 10' 06/07/14 Isdated Updated by DMA 09/22/14 ff Hileorp .Alaska. LLC 16" 10-3/4" 7-5/8" 2 M36 MMB LB2C LB2C i LBBA LB3B LB4A TCC g 9448 lyo'teK ISE TOek 76-7 4 Tyonek 7&2 S" :tat TO=9,746(MD) /8,099(TVD) PB7D=9,35r(MD) /7,768' (TVD) PROPOSED SCHEMATIC CASING DFTAII Kenai Gas Field Well: KBU 32-08 Last Completed: 8/01/2014 PTD: 214-014 Size Type Wt/Grade/ Conn ID Top Btm 16" Conductor N/A S' Pu Surf 135' 10-3/4" Surface 45.5 /L-80/ BTC 9.950 Surf 1,478' ±6,941' Intermediate 29.7/L-80/B7C 6.875 Surf 6,406' 5" Production 18/L-80/DWC/C-HT 4.276 5,849' 9,746' I Ut11NG ULTAIL 5"1 Tubing I 18/L-80/DWC/C•HT 1 4.276 Surf 5,849' JEWELRY DETAIL No Depth Item 1 5,849' S" Swell Packer 2 7,330' S' Pup 3 8,028' S' Pu 4 9,475' CIBP OPEN HOLE / CEMENT DETAIL 10-3/4" 160BBL's of cement in 13.5" Hole. Returns to Surface 7-5/8" 261BBL's of cement in 9-7/8" Hole. Returns to Surface 5" 3148BL's of cement in 6-3/4" Hole. TOC 4,600' Calculated PERFORATION nFTAll Sands Top (MD) Btm (MD) Top (TVD) rn FT Date Status (TVD) MB6 ±6,933' ±6,941' ±5,817' ±5,824' ±8 Proposed TBD MB4B 7,260' 7,280' 6,078' 6,094' 20 09/04/14 Open L62C ±7,831' ±7,836' ±6,541' ±6,545' ±5 Proposed TBD LB2C ±7,863' 1:7,868' ±6,567' ±6,571' ±5 Proposed TBD L83A ±8,077' ±8,082' ±6,742' ±6,746' ±5 Proposed TBD LB3B 8,136' 8,162' 6,790' 6,811' 26 09/04/14 Open LB4A 8,290' 8,300' 6,900' 6,910' 10, 08/01/14 Open LBSA 8,514' 8,524' 7,100' 7,110' 10' 07/30/14 Open T onek 73-1 8,848' 8,858' 7,362' 7,370' 10' 07/28/14 O n T onek75-8 9,202' 9,212' 7,647 7,655' 10' 07/27/14 Open Tyonek 75-8 ±9,205' ±9,211' ±7,649' ±7,654' ±6 Proposed TBD Tyonek 76.7 9,343' 9,366' 7,762' 7,781' 23' 06/19/14 Open Tyonek 78-2 9,500' 9,510' 7,891' 7,899' 10' 06/07/14 Isolated Updated by DMA 08-28-19 ff flilwrp Alaska, LG Well Prognosis Well: KBU 32-08 Date: 08/28/2019 Well Name: KBU 32-08 API Number: 50-133-20624-00-00 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: 9j9-/2019 to ) Rig: E -Line Reg. Approval Req'd? 10-403 Sundry Number: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-044 First Call Engineer: Christina Twogood (907) 777-8443 (0) (907) 378-7323 (C) Second Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (C) Current BHP: Max. Expected BHP: Max. Potential Surface Pressure: Brief Well Summary "'1,800 psi @ 6,078' TVD "'3,345 psi @ 7,654' TVD "'2,579 psi @ 7,654' TVD (Based on actual reservoir conditions) (Based on normal gradient of 0.437 Psi/ft) (Based on expected BHP and gas gradient to surface (0.10 psi/ft)) KBU 32-08 was drilled and completed in March 2014 targeting the Upper Tyonek and Beluga formations as a 5" monobore completion. In July 2015 five zones were fracture stimulated. In September 2014 two zones were perforated. The purpose of this work/sundry is to add perforations in the Upper Tyonek, Lower Beluga (three intervals) and Middle Beluga sands. Notes Regarding Wellbore Condition • Last tag at 9,145' RKB on 7/26/2014 w/ a 2.5" DD Bailer, tagged fill (frac sand) • RA markers are at 7,330' MD and 8,028' MD per the 3/15/2014 Casing and Cementing Report Safety Concerns Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. Consider tank placement based on wind direction and current weather forecast (venting nitrogen during this job). • Ensure all crews are aware of stop job authority. E -Line Procedure I. MIRU E -Line and pressure control equipment. PT lubricator to 250 psi low / 3,000 psi high. 2. RIH with GPT tool and find fluid level. For applicable perfs, if fluid level is over the depth to shoot the new perfs, discuss using Nitrogen with the Operations Engineer. 3. If needed, RU Nitrogen Truck and pressure up on well to push water back into formation. Use GPT Tool to confirm fluid level. 4. RU 2-7/8" 6 SPF 602 phasing perfguns. Well Prognosis Well: KBU 32-08 Date: 08/28/2019 flilcorp Alaeks, LLi 5. RIH and perforate the following intervals: Zone Iand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Middle Beluga MB 6 6,933' 6,941' 5,817' 5,824' 8' Lower Beluga LB_2C 7,831' 7,836' 6,541' 6,545' S' Lower Beluga LB_2C 7,863' 7,868' 6,567' 6,571' S' Lower Beluga LB_3A 8,077' 8,082' 6,742' 6,746' S' Upper Tyonek 75-8 9,205' 9,211' 7,649' 7,654' 1 6' a. Shut in well 5 minutes before perforating. b. Proposed perfs shown on the proposed schematic in red font. c. Final Perfs tie-ins sheet will be provided in the field for exact perf intervals. d. Use Gamma/CCL to correlate e. Spacing allowance is based on Conservation Order 510A. f. Record tubing pressures before and after each perforating run. g. Record 5, 10 and 15 minute pressures after firing guns. 6. POOH and RD E -Line. 7. Turn well over to production. E -Line Procedure (Contingency) 1. If these zones produce sand and/or water and need to be isolated. 2. MIRU E -Line, PT lubricator to 250 psi Low/ 3,000 psi High. 3. RIH and set 5" CIBP (or tubing patch) and dump 25' of cement on top of the plug. Attachments I. Current Well Schematic 2. Proposed Well Schematic • • • Wallace, Chris D (DOA) From: Drew Anderson <ananderson@hilcorp.com> Sent: Friday, September 04, 2015 1:39 PM To: Schwartz, Guy L (DOA); Campbell, Peter C (DEC); 'Ethan Schutt (eschutt@ciri.com)'; Wallace, Chris D (DOA) Cc: Gretchen Stoddard; Chad Helgeson Subject: PTD# 2,14-404-KBU 32-08 Post-Frac Water Well Results Attachments: KBU 32-08 Sample Results.xlsm D 02 14 014)-0 All, Please see the attached water well sample results. One water well was sampled to represent post-fracturing conditions near KBU 32-08 in accordance with the sampling plan provided in the approved sundry application. Below is a summary of the notifications required by 20 AAC 25.283(a)(4) based on the sample results: • The water well near KBU 32-08 contained a detectable concentration of DRO. The detectable concentration of DRO is well below the 18 AAC 75 Table C Groundwater Cleanup level. Please note that ADEC checklists have not yet been completed and a data quality analysis has not been performed for this sample. Please contact me if you have any questions or concerns. Thank you, Drew �,��(® P G o Z016 Drew Anderson, PE PMP I Environmental Specialist SL 11 Hilcorp Alaska, LLC ananderson@hilcorp.corn P(907)777-84881F(907)777-85601M(907)382-0987 1 • • • Orn• Ln ,1, ,—I c CO `� N 0 0 mf° 0 I I I I I p l I I I I I I I I I I E5 ~ oo n r�-i 0 •C Y ^ z H O O u1 u1 yD _ ,-� N o 0O +-' ++ +-, O O O o N N N Ln r'' O _ O O O ,--I O N 1 N I M O C C C Ni Ni Ni u 0 ,--I O M Ni O O ° O O O m m O vi a) v 00 0 0 •0 _ O O O 0 0 In o0 - so - M M O O M m m g'' \ CO as as � r-i z 0 0 0 2 O O m co.Q Lo N O N Y Y Y N z 0 z z N z • N O z N QS ma) O M ‘--1M C Ln M 0 > ,-1 I I I I I I I p l l l I I 1 1 1 1 1 1m m 0 N. 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ISI O 4-+ — 7 a) N N N N N N N N N N N Y Y Y 111 U 2 Lf) LI) Ln LI) Ln Ifs 1f1 LI) Lf) LI) Lf) V) V) iii 4 II II II N v lin O V o\p U C I I ISI Z 7 2 E n • Hilcorp Alaska, LLC SCANNED AUG 0 4 2096 Water Well Sampling Program After-Action Report Post-Hydraulic Fracturing KBU 32-08 PTD #214-014 Prepared by Jacobs Engineering Group, Inc. 4300 B Street, Suite 600 Anchorage, Alaska 99503 COM-J07-05DK5006-J22-0003 September 2015 • • After-Action Report Water Well Sampling Program how IA•ka.1.1.1 1.0 INTRODUCTION This report describes the project approach and methods used to conduct drinking water sampling activities at a well in the Kenai Gas Field outside of Kenai, Alaska. Post- hydraulic fracturing water sampling was conducted at water wells within 0.5-mile of well KBU 32-08 on 8 July 2015 in accordance with 20 AAC 25.283(4) (final regulations as of April 2015), site-specific work plan, and the Standard Operating Procedure, Hydraulic Fracturing Water Well Sampling, July 2014 (SOP). Jacobs Engineering Group Inc. (Jacobs)executed the work under contract to Hilcorp Alaska, LLC (Hilcorp). 2.0 FIELD ACTIVITIES Water sampling activities were conducted by one qualified sampler on 8 July 2015 at well pad 41-18 of the Kenai Gas Field. One primary water sample was collected from the water well on the pad. Prior to sample collection, the water from the well was purged until water quality parameters stabilized or 15 minutes had passed, whichever came first. The sample was then collected directly from the well spigot. A completed sample form is presented in Attachment 1. All samples were sent to ALS Laboratory in Kelso, Washington and analyzed for the parameters listed in the SOP. The completed chain-of-custody is presented in Attachment 2. 3.0 DATA QUALITY ASSESSMENT The Data Quality Assessment evaluates the overall quality and usability of data from the 2015 drinking water sampling activities at the Kenai Gas Field. Attachment 2 contains the chain-of-custody and Attachment 3 contains the analytical data table. A completeness check of the electronic data was performed to verify that the data packages and electronic files included all information requested. A data quality review using the method and laboratory requirements was conducted on all analytical data. The review included an evaluation of chain-of-custody and sample receipt records, laboratory case narratives, and laboratory data, including analytical methodology, sample holding times, laboratory blanks, reporting limits, surrogate recoveries, laboratory control sample (LCS) recoveries, matrix spike (MS) and matrix spike duplicate (MSD) recoveries, and precision. Analytical data quality objectives were considered met when the quality of the sample data met precision, accuracy, representativeness, completeness, comparability, and sensitivity requirements. The overall quality of the data was acceptable as qualified. Flagged data are considered usable but estimated. The following data qualifiers are applicable to the 2015 Kenai Gas Field drinking water activities: "J"—The analyte was positively identified, but the associated result was less than the limit of quantitation but greater than or equal to the detection limit. "J"— Result is estimated value and biased low due to quality control. The overall quality of project data was acceptable, and no data were rejected. Page 1 JACOBS "Use or disclosure of data contained in this sheet is restricted" • • After-Action Report Ip 164.Ill Water Well Sampling Program 4.0 RESULTS Water sample results from the baseline sampling conducted in July 2014 and the post- fracturing sampling conducted in July 2015, as well as the applicable U.S. Environmental Protection Agency (EPA) maximum contaminant levels (EPA 2009), are presented in Attachment 3. 5.0 REFERENCES EPA(U.S. Environmental Protection Agency). 2009 (May). National Primary Drinking Water Regulations. EPA 816-F-09-004. Page 2 JACOBS "Use or disclosure of data contained in this sheet is restricted" • Kenai Gas Field, Pad 41-18 24-7X X41-18X14-8 #1-17X• r 32-08 43-07Y 24-07 SB00401118AACA1 001 - 33-07 24-7RD 41-18 11-17 • 13-08 r. 12-17 • Section 18, T4N, R11 W, S.M.,AK Legend * AOGCC Oil and Gas Well(BH Location) Drinking Water Well USGS .Tyonek 1 inch=150 feet g Project Location All Locations Are Approximate 0 75 150 225 300 NlkisM Feet •sai.mxar •Kenai aot a NAD 1983 StatePlane Alaska 4 FIPS 5004 Feet .sibl Gulch inch HILCORP ESTIMATED WATER WELL ASSESSMENT sl Nlnll<Mk KBU 32-08 NIKISKI -KENAI,ALASKA � A^<I'°t Nlkoleevsk •int DATE'. PROJECT MANAGER FIGURE NO. ° IliI,orp 41a.ka.I.IA: 27 AUG 2015 E. MCDONALD 1 • ATTACHMENT 1 WATER SAMPLING DATA SHEET • • II Water Sampling Data Sheet iva..wr 11.1.4.1 LI. }h t.-CW Site Nam@ &gpj Well ID Project Number Y- •11-)C Qa.941-I`5 , 2-0$ 05D Stc)to Weather Conditions Date Sampler Initial V, --may cr-a -7/SI/5 C -1 Tank Information (Drinkin Water) Tank Volume laallonsi Faucet/Snlaot Flow Rate(aaVrnin1 Estimated Puree Time(minutest WeIVTank Purging Information Start Time Fish ruts _ Eau• r= 3• • l yrf,X13 ZU ) -3 13� Faucet pigot ist *111,1114111N Other color gX& Sheen Pursed Dry -ptnina Pur 1 le Cloudy Brown C) Moderate Yes Yes SI utti Met Other. Faint Strong ( ) 'o Horiba Multi Meter L Purging reached: Stabilltyx Tim' Purge water was: Treated Stor Discharged Note: Volume Acceptable Range to Demonstrate Stability Tine (Oatltxrs or Ulers) *0.2°C *3% t 10%or 02 mg/l. *0.1 *10 mV *10%or 31 NW (HH:mm) (wNchwsris greater) Change Total Temperature Conductivity DO pH ORP Turbhlity (•C) (MS/cm) (Pig-) (aid units (mV) (NTU) 3; 2141: C roles.- (C i- (o 3-O O �, 03 '"-'7, I4- 3 i ()) .'i- ; 2`o' 2 �3co g, , 1 3 1' 'b fI , • /, r 31r 1 0e /4- 33;Z9 1 .5c. 'owl_ 1 14- ( r I -7, (02. 2:7, , O a Z3 � � Co `� 13:31 .5� 1.544,. (a, 1 )4,0 146. 6-1 •x)'71- 24.E Oil L 13 .33 Loc. 12,6e, 6, 1 55 ts,t0g 7eL3 _l .. .5 I3 ', 5 1.56 )4 Co- 33 it , 11174 `7,g`7 20,2- dI ( Suggested Notation: =not measured "✓"=stable "+"=rising "--=falling "•"=all parameters stable Page 1 i • Water Sampling Data Sheet ESP t�.►.+„ Sample Collection Information Start'Time ni h Tim Dae 13',I-0 14',6-7/7/9)/1 y Spigot Exist 42r1 Other SAMPLE ID: g_i50 32_ Og QC: Dup MS/MSD Container/Preservative Analysis Requested Notes 3-VOA glass,HCL GRO 2-1 Liter,HCL DRO 3-VOA glass Dissolved methane,ethane,propane 1 -250 mL HDPE TDS 2- 1 Liter,HCL TPH 1-60 mL HDPE iodide 1 -60 mL HOPE fluoride 1 -60 mL HDPE Bromide 1 -60 mL HDPE chloride 1-60 mL HDPE,H2504 NO2/NO3 as N 1-250 mL HDPE,H2SO4 phosphorous 1-250 mL HDPE,HNO3 strontium-90 1 -250 mL HOPE alkalinity 1 -250 mL HDPE alkalinity,bicarbonate 1-250 mL HDPE hydroxide 1-250 mL HDPE,HNO3 200.7 metals (b,ca,fe,li,k,na) 1 -250 mL HDPE,HNO3 200.8 metals (as,ba,cd,cr,mg,mn,se,si) 3-VOA glass,HCL BTEX 2-1 Liter PAH 1 -60 mL HOPE sulfate 1 -60 mL HDPE pH 1-250 mL HOPE,HNO3 Radium 226 1 -250 mL HDPE,HNO3 Radium 228 1 -60 mL HDPE Specific conductance 1 -120 sterile plastic iron related 1 •120 sterile plastic sulfate reducing 1-120 sterile plastic slime forming x ¢0 .,L VOA L k4 C s t4 C L —tb`r61(. 6 x 40 L Vo-a ,01 SGL - 111-)DI > G Ra n.t6- .-ice. I x Sao L Pat,/ w/i4 2.504 — No i /MO 3 ) Ptto`-a? -4-0S 9- x900.--,L , ��N� �a N C-L 25, Z Mu --D 1� z X /000 M L, { y co>~►D�7> � ) b,c A-Q( *-r-6 ) 11-1/t fix,ice, � I S> P ) 6� , C i> f I ) 754 3 ' /oo ,M L- i -&c 1 c,.l� Na 1 2 —p�AC1-624 k &l.-f P-‘4, R i , •-D- )5 IN_pek- .) 1 x I Lr Pbf,Y -- 260,-7, 200 g P-> 22g l x l L- r�d.y — Q-A- 2.2-0 aer A w/146L — 0,U -c-As6. f2-0 , 'P14 • • ATTACHMENT 2 SAMPLE CHAIN-OF-CUSTODY • W .2 ti a 7. z e Pt R c • F pp pp ...`z.._-_), = O E"" M dO R O - O F,-; O O O M M M ze tZ g m F. c S il K1 O F •- „ •o ,- w N a Xw 4 a d x a u X a c • q r 06 Cq o Q y,,.:7•1 i' 1 g v t.p' LJ _ u "o ro a E O N O r� F O lL AS g o t c ��Qo QQ 74 g. 0,o F c ca a a' v C1 a' z ai a z M IN V W N vim! Wim,„ v -N a N V 0 g •N a N E m O j N N N T.o osi O qen Q Q d 6 F r Ls m m a R a .... 1111 $1.i i 'id CV " 0 Z Z 0 x x 0 '� U M U U a IR o C Xi U 0 a U U U d• U U d U Q U ° g' df g 4. °v 2 °a °v 4 v °v a °v 0 a a O cor‘t (0 r o E E E E E E c E EE .__1 E `J :7`4 O ' o N cCX T 1 `o cW w !+] Lt] LL3 W W ti H v, v` N .a r= e o 1-, x e0 x a. aS - 2 x E .a ao oo a 00 00 • 3 V 3 t,* a U I a ue A riA s 7 x V1 -. N - — -. .... - M ,t- VD N V M ,D .0 o. .. E ‘1 c2 2 2 2 2 2 2 2 2 2 2 2 2 g 8 .5, W W W W Le .1J W ILL W W W W W 9 "' g V t Ti -� ka �'1 NP a 4111 . ti $ 4%\l' �. dJ 00 C0 00 oo oo00ODooN N.$ P; 01 c1 ai of -I o1 01 °'u1 01 01 Oi ❑ ❑ N N N N N N N N N N F4 a � . 7 M M M M M M M M M M O� m '�( X 1 g 3 a a a a - a a a a a a E- H scI �, U 44 id. 0 0,. p., m• t �pV N 0 M c0 00 00 ' 00 W W 00 8 O a 6 7_ 13 pO O O O O O O O O O O Q ��(('' 7 [� 0. N NI NI N) NI NI NI N) NI NI '0 a. S M M M M . en en en en M M I I �a�qq t�aip tai paq • a paq cap paq �aq �aq Cn g+ a a °L aG Y A7 PG ?C Y F H „�„ U SC �{ } ` N M i • • V" z P a F `_ g o 0 0 0 0 g g 2 G x g $ - 2 c 7t�' U ,. E u'o v .: QO ,r N V (;J ._.... ri ,T, `,ii- .dr V Fin E •N a C. L. �, N vi g',1 Pn I q C N ri .... ¢ V1"' o d ' rim h o 'a :' "' u rl N N Al N E T - - o `v v b ti ng g t w 1 I ` F K 3 3 3 3 3 3 3 3 B 8 L 7 AO W G A G G G 0 Oa _04 0 $y�4 pL, iZ a �+ >_ C3 U ryi O O O M s Ip. V cn m x m x C• •a�i a V `t c�� z CJ U C.i J = �3 tg d o z Zr 4 4 %.1 t�p4 M a `N U 5 E E E E � ,02 J Q j t^ O `f1 g° o o C a a. a a F co ,Z V ,g � x z = °x x a U Ian a 0 E.E. 4 N VF Q w w w w w w i J a ti I s e_ .,..,.. . 1 es ...... i 8 iz. __ einii c4:r) , € kii\\ o0a •04, v U N 14:.a 8QN 2. a a a a a i I I �� b� bI bI �i s'i �i \I �° may+ o v v v v v a v v q .. . ,.. 0. al B N N 0a pM N a N �NN 8g -8 2 u k X X X ?C iaG U t ,oi poi v'i wi +or 'aF `off mi �i s . . o a v a - v a ,i i x (p1 pq cq o� oq pp�� p� �q m V ad aG X �4 aG X • -.� a t\ ^ ti . . i i ATTACHMENT 3 ANALYTICAL DATA TABLE • • L al O d'pa U1 `1 > N C M O (n O f9 ^ N p0 I I I I I p I I I I I I 1 1 1 1 1 1 m o oo C Q Q r-1 \ Y 0 .0 Y N. C Z i— 0 'CD II-3' � _ in --O > 4-, 4-, 4-, O O O O N N N Lf1 `i O _ O O O ,--1 p N N I m p > N C C C N N ,-1 p 0 CO nl O 000000 DLn 0 _� < vl IA in 03 so .Q -0 cnt-I cm-I 0 O O 0 Cr in M °c.' N o0 m i--I \ •-leE Q Q Q r-1 .-i Z 1-1 Z O z Z Z N Z O LC) N Z N. m Y Y 'i O O N O t0 0 L a O 1f1 _Th co m COCsoN 'n 0 ° I I I I I I I p I I I I I I I I I I I I m n cQ Ct art � Y 0 Y N .- Z E w ~ 0 ca L .o ba O co A: (5Lal 1 1 _00 M _ Cr- 7.7 01 M d' m _ C p M i 1 >f0� 4-+ +-, +-, O O O M-1 '� O I� m c 00 O O O LD O O • E �p NI M > N C C C ,-i u p O p• I •• l0 O O p •p O p 0 (5 t� m O N c Q Q VI li) lD tD chi O O 0 ^ p O v) 5 m \ c Q Q Q r�-1 g-I Z 0 r�1 `- Z 0 N Z m 0o O 0 N m 3 C Y n .0 Z O co' O N OiD Q 0 O co' °0- m L ate+ C f0 0) N E t �4-,Q. (0 v 0 D .L �O J u r Q- D 0) co 0 I I I I I I I I I V1 1n 00 I I i I I I I I s < fa E o co in Co J N E J J J U If. E E E J J J J J J J J J \ J J J J J J J C \ \ \ 00 b0 C0 00 b0 on \ \ \ Q 00 00 bD 0A 00 00 00 2 12i u_ u_u_ E E E E E E n a a 2 E EEEEEE U U U 2 N (9 (0 0) CO CZS _ M_ 'C 0) O m m CO L 0J U I 0 > 00 ++ +' U co 00 M 0 eau U co co O� 0 CC lD 00 4.-, 0) 0 H 0) 0�0 m 00 U 0cc 0 NN ~ rizN to C E ,� j C 00 C CO (0 an 0 i i cs .2 Ejrav VI U cc LL +-, 2 2 vi V ++ C d C N a+ C CO U V) u co7 o f w Y m m o -o O _ N CC to N < U I— I— I— cc cc \ \ \ \ 0 ° ° m 0.-3 oo 0 o mo 0 0 0 N 0 < N N N N N _c 03 03 cip M N M N (N N d- 0 0 m 0 C O u) 0 0 0 0 0 0 Q) cn N H N N N N N N N N YQ Q a1 N l0 0 0 0 0 0 0 U U U 2 Q 2 Q 2 Q 2 Q 1 CO CO CO N N N N 2 2 2 • • c1 LN DJ 0 41- r0 0 0 1 0 0 0 0 0 0 0 M O > N 0 0 0 0 COza. N J 1 1 1 1 1 1 1 1 I I I I I I 1 0000 — 1 1 1 1 1 1 1 Q .-i \ - Q O O O O O 'c Y ^ C 0 0 0 0 0 H 0 Z Z Z Z g O LM 1.11 in a) ci N e-1 0 .-i _ -, CO 00 CO l0 00 in N ul N Ill N 7• :T ^ F ET 000 ,-IoN' 0000000 01 0.) .-, c0 rrO O o O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 M N N N J 0 0 0 0 0 0 0 0 0 ' 6 o O O q q 6 O o 0 0 0 0 0 0 0 0 0 0 O ul 00 C Q If) lD o N 01 O ill M 010000 - 0000000 m Y N C N N to N 0 r-1 O Z M N r-1 O 0 m 0 0 0 0 z 0 0 0 0 0 0 0 Y .-1 01 O to O Z N O Z z 0 O O Z O O O OZZZZZZZZZZZZ O O o O L r1 aJ N M LiI M 1. ++ .1 N 0 c M o 3 0 0 0 0 0 f0 N OD J I I I I I I 1 I 1 1 1 1 I 1 10 0 0 0 O I I I I 1 1 I C0 O N C Q 0 0 0 0 O_ .--I ci Y O o 0 0 Si L ^ .L 0 0 0 0 0 E a, ~ p Z Z Z Z Z as12.0 113O til: CO L ; N N in 0. M a) _ _ O In O O _ _ _ , N M ul m o lD N o0 ul 0 03 In r70 N N O 0 0 0 0 Fri m m -. lD O 8 N N ct N o .--1 O 8 D o (8 o O M .-i 0 0 0 0 0000 (7\78 .a ri I M O 5 0 0 0 0 0 0 O O N 0888888800808 u m NN R0 66660600 °. 60. 00 0 0 0 0 0 0 0 0 0 0 0 0 8 0 o r\ C Q o0 0 0 0 0 0 0 0. 000 - 000 0 o —y• co co Y L O oo 0 0 .1. Z Z -: ,-1 Z Z Z • 00000000z0 ° 0 • Q 0 o 0 Z 00 O O 0 Z Z Z Z 0 Z Z Z Z Z 41 r O O a+ C 63 61 a s O co =' Q � nt0 1.1-3 � oNoo I 0 0 `� � I I 0 000 ,.-i I I I I I 1 1 In co J to Vf J J J J J . . . . . . . . J J J J J J J J J J J J J J DEEEEEEEEEEEEE E EEEEEEEEEEEEE C a) O a) c v L , C C aJ C a 0 C C aJ a1 ✓ v E E a, v a, Z ~ w w 03 vi c NJ c a, a, a' j c as L rC0 w CO CO ' 'i 3 .E CD E .E -6• 'c ( a) w ` N al N aJ -C L cc00 +J a p .Q a = la ,p„ 'L E 0 00 C 0 O O +- T 7 Q L C !0 7 L r0 "6 O c aJ 0 p O L O C X x r0 IZ .0 N t p N lO . m V . � N m U LL � O 2 0_ m _c O 1— t, C C dA rp �+ O U U Z NO w Q U Q C a p ON a) a < ai CO v at L COCO m m Z O r, 00 00 00 00 00 00 0 0 0 0 0 (...4 M N N N N N N N N N N N N -C o 0 0 0 0 0 0 0 0 0 0 0 4 M u1 4 4 4 4 4 u1 1n u1 tri u1 ul ul aa) O o 0 0 0 0 0 0 0 0 0 0 .-i to l0 N N N N N N N N N N N N 2 N N N N N N N N M M M M M M m u1 ul In tf1 tl1 u1 in ul Lt-, in In In • • L l"I a 01 l"I > O O O C M J co NNJ 0 j 1 1 1 1 1 1 1 I . . O I m in 00 C Q O O Y 0 •� Y N c ❑ ❑ Z I— Z Z L �0) N N N N e--I N N N M .7 OI m r�-I t5 0 0 0 0 0 0 0 0 0 0 0 0 M00000000000 ci N0 NN OD -, 0 0 0 0 0 0 0 0 0 0 d ❑ \ - Q 0 0 0 0 0 0 0 0 0 0 ❑ 0 Y N C ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ r-1 ❑ Z o0 0 Z Z Z Z Z Z Z Z O Z m r, a) o r1 rn O V) ,--1ca 0 O O • OD I I I I I I I l O pp I Em0 CQ drN O O - I? .--1 '- Y ^ L 0 ❑ ❑ C ~ O O Z Z O c O u OD e CU L a) I-- "O d r L OD f6 a N l0 V1 m l0 V) l0 r1 01 0 coO M i--I 0 0 0 0 0 0 0 0 0 0 0 V cu U ml o OD v] 0 0 o O o 0 0 0 co (NI E o n C Q 0 0 0 0 0 0 0 0 0 0 0 v1 ❑ `--1 Y 0 0 0 0 0 0 0 0 0 0 L 3 C Y Y N C C 0000000 0 C — 0 Z Z Z Z Z Z Z Z o Z Z ro Co L M ++ L c a Coa +, £ Ca as o O v L v ❑ •X O J OD co C +' a Ci a *-' U I I I I I I I I I I I I +(0- Q E o n CO O 2 co x co Els C Vl CO '�-I0 N 0 (a N a, a-+ VC C ) 0 Co 1.,1 J J J J J J J J J J J ~ +, 0 ;4"' \ \ \ L., \ \ \ \ \ \ \ Z 0 CT E OD OD OD OD OD OD OD OD OD OD OD ❑ 0 DEEEEEEEEEEE 4-. a o E +, aa a) E v C C C J O a a v _ o C t two a A a �t .f 0c aJ ++ 4-, i C a C 4, Ln Ln La C O a C +� a i C (0 C (0 (0 a Q ° in 113 C L M C v Co Cl CL C 'a 'O E ` N c a a w O O COCu M (o O Y U .i a d O t a co s NJ C LL L a Ca Cl.) - a-, N ro O O Q E. 'a 3 .E Co m U E E •0 a) a E + a a �a C N E ao u (o -� Ln N Li)N 1 -6 O- 1n 0 N N N N N N N N N. � N � � X = O � E N yam•, L!1 Ll1 Ln 111 In 111 111 Vl c-1 r-I c-I O O E 'Q II O a N N N N N N N N Y Y Y L E U 7 2 V1 V) Ln V) V1 V) V) 111 V) Ci V) iii , II II II 3 N N cc Ln OU O II z E a -, -, • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg151 1 l4 DATE: 6/8/14 P. I. Supervisor FROM: Bob Noble SUBJECT: Plug Perforations Petroleum Inspector KBU 32-08, PTD 2140140 Sundry 314-345 Kenai Gas Field 6/8/14 I arrive at the Kenai Gas Field, Kenai Beluga Unit 32-08 to witness the setting and tagging of plug that isolates perforations. When I arrived I met with Hilcorp Rep. Mr. James Ostroot. I looked at their procedure and we when over what they were going to be doing. Pollard E-line was rigged up and was going to set the plug. I witnessed them set the 'plug at 9,475 ft RKB. The perfs in the well were at 9500 ft to 9510 ft RKB. Pollard E-line - pulled out of the hole and rigged down their equipment. Baker-Hughes then rigged up their pump to the well to pressure test the plug. The test went as follows: Pre T/I/O=0/0/0 psi Initial T/I/O- 5200/340/0 psi 15 min. T/I/O= 5190/400/0 psi 30 min. T/I/O/= 5190/420/0 psi ' I did not witness this but I was told they were going to dump bail 27 feet of cement on - top of the plug. Pollard was in the process of mixing cement when I left the location. Attachments: none SCANNED MAF 8 ni- 2014-0608_Plug_Verification_KBU_32-08 bn.docx 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. 4 4 - of 14.. Well History File Identifier Organizing (done) Two-sided ❑ Rescan Needed RESC OVERSIZED: NOTES: C_ lbrz.. Colo Items: ❑ Maps: ` v" "7,�,�- rayscale Items: s. C � et-el a ' ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: arlibb Date: / a. IS /s/ ad a Project Proofing BY: alp Date: OF ca, 5- /s/ b ° Scanning Preparation IR/ x 30 =a 4.O + / c - = TOTAL PAGES d 5 (Count does not imp nclude cover sheet) BY: Maria Date: if a /s/ Production Scanning Stage 1 Page Count from Scanned File: as 3 (Count does include coy sheet) Page Count Matches Number in Scanning Preparation: YES NO 1 BY: (SEW Date: t9 i/5— /s/ iivi r Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: ® NO TOTAL PAGES: Digital version appended by: Meredith-1\-N-6Michal Date: 9/&!i S-- /s/ 1 Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: age 1 Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc c o o O N - J • co oZ _ 0 O E m ° • • en E EMM E 41 4--o U I o) U �?_ p Rp p ppHp > N > p H p > QHp Cop coY mg v Y 2 0 > 2 F- a > 2 'o=tn T F- F- F- F- 2 F- F- F- 2 F- I- F- •>- • •o a) 1 a) ai in < < U U < < . U0 Z Z E E 00 CO F- F- CO CO > CO CO F- F- CO CO F- F- CO CO 7 CO OW 00 CO CO CO ao cd a0 co co co co ao ao ao ao ao co Er. co :? 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Q C Tii LL LL N co co M co co co C) C) coNCNO M co co M co co CC') 07p O p p > > p > > > > p p p p p O p l/) . 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Q o co0 C III C '', C G w 0) .2� U I J .m m . 0 c U a o a a m i, E 0. £ E 2 O 2 E m m E E O a 0 0 a 0 0 0 c 0 0 Wallace, Chris D (DOA) From: Drew Anderson <ananderson@hilcorp.com> Sent: Wednesday, October 22, 2014 3:47 PM To: Schwartz, Guy L (DOA); Campbell, Peter C (DEC); Wallace, Chris D (DOA) Cc: Paul Chan; Chad Helgeson Subject: PTD# 2 KBU 32-08 Water Well Sampling Report Attachments: image003.png; KBU 32-08 AAR.PDF All, eT D d \ �--O \r 0 Please see the attached After Action Report for the pre-fracturing water well sampling that was performed near well KBU 32-08. This report satisfies the requirement to provide all analytical results and sample locations to the commission and to ADEC. As with the previous report,today we at are 97 days after sample collection. I apologize again for the delay in reporting. Please let me know if you require any additional information. Thank you, Drew Drew Anderson, PE PMP I Environmental Coordinator fHilcorp Alaska, LLC anandersonv hilcorp.com P(907)777-8488 F(907)777-8560 I M(907)382-0987 1 Hilcorp Alaska, LLC Water Well Sampling Program After-Action Report K B U 32-08 PTD #214-014 Prepared by Jacobs Engineering Group, Inc. 4300 B Street, Suite 600 Anchorage, Alaska 99503 COM-J 07-05 D K 5006-J 22-0001 October 2014 11 After-Action Report ri,lm.PAlaska.1.1.1Water Well Sampling Program 1.0 INTRODUCTION This report describes the project approach and methods used to conduct drinking water sampling activities at a well in the Kenai Gas Field outside of Kenai, Alaska. Baseline water sampling was conducted at water wells within 0.5-mile of well KBU 32-08 on 17 July 2014 in accordance with 20 AAC 25.283(4) (draft regulations as of 18 July 2014), site-specific work plan, and the Standard Operating Procedure, Hydraulic Fracturing Water Well Sampling, July 2014 (SOP). Jacobs Engineering Group Inc. (Jacobs) executed the work under contract to Hilcorp Alaska, LLC (Hilcorp). 2.0 FIELD ACTIVITIES Water sampling activities were conducted by two qualified samplers on 17 July 2014 at well pad 41-18 of the Kenai Gas Field. One primary water sample was collected from the water well on the pad. Prior to sample collection, the water from the well was purged until water quality parameters stabilized or 15 minutes had passed, whichever came first. The sample was then collected directly from the well spigot. A completed sample form is presented in Attachment 1. All samples were sent to ALS Laboratory in Kelso, Washington and analyzed for the parameters listed in the SOP. The completed chain-of-custody is presented in Attachment 2. 3.0 RESULTS Water sample results and applicable U.S. Environmental Protection Agency (EPA) maximum contaminant levels (EPA 2009) are presented in Attachment 3. 4.0 REFERENCES EPA (U.S. Environmental Protection Agency). 2009 (May). National Primary Drinking Water Regulations. EPA 816-F-09-004. Page 1 JACOBS "Use or disclosure of data contained in this sheet is restricted" • s, ; i I Kenai Gas Field, Pad 41-18 411* 104 24-7X X41-18X 14-8 111-17X a #32-0el" : IL r 3-07Y 24-07 SB00401118AACA1 001 ,► 3$i-07 24-7RD 41-18 11-17 r * • 12-17 * e s ,Sec o „,1 :, TSN, R11 W S�M , A Legend , yE AOGCC Oil and Gas Well(BH Location) Drinking Water Well USGS .lvonek 1 inch=150 feet g Project Location All Locations Are Approximate 0 75 150 225 300 iNikiaae:naiki ' Feet sal,7 K m �dnlna NAD 1983 StatePlane Alaska 4 FIPS 5004 Feet Naailol GWm Gulch; HILCORP ESTIMATED WATER WELL ASSESSMENT �111c�k KBU 32-08 • NIKISKI-KENAI,ALASKA Mclro�Nikolaevsk • DATE. PROJECT MANAGER. FIGURE NO !Meorp IaRka.1.1.0 29 SEP 2014 J. MCVAY 1 ATTACHMENT 1 WATER SAMPLING DATA SHEET 11 Water Sampling Data Sheet ri,k^rN%hank".r r.,: Site Name Eyerit Well ID Protect Number PA-9 4 I — IS k-131)32_b$ 051)X-SDDC., Weather Conditions pate Sampler Initials 6+0--1-1-Lf C Vy —7/1 -7/i+ Al)/ 741 Tank Information (Drinkin Water) Tank Volume(gallons) Faucet/Spigot Flow Rate(gal/min) Estimated Purge Time(minutes) WeIVTank Purging Information Start Time Finish Time ,Equi ment Used for Pur 122-14i l4I' Faucet Spigo Existing Pump Bucket Other Color O r Sheen Purged Dry ,....ti_..:1:,-_eurin. Pur.',.0 r.-•— r Cloudy Brown o : Moderate Yes Multi Meter Hach Turbidimeter 0 er: Faint Strong WO 1 No Horiba Multi Meter Purging reached: Stability Max Time Purge water was: Treated Stored Discharged Note: Volume Acceptable Range to Demonstrate Stabilfty Time (Gallons or litere) t 0.2'C ±396 > 10%a 0.2 myL *0.1 ±10 mV *1096 or t1 NTU (HH:mm) _ (whichever is greater) . Change Total Temperature Conductivity DO pH OSP Turbidityty 2 (°C) (µS/cm) mg' (aid/' uscb / —(tn�V) 7 6 NTU) .2D ( (o 3c L - 5, t 1 `1D j Ir 2 G `(�J [i , 12',vi Cocom. (3 - 7, 33 L k 7 '7.W Ce 1 7 4 o t'b t, S 0 12-.32_ Co&A„ 15& 5 .3s ?A'S 1 Z,3(o 5, (; O,i 0.-77 17 :3.5 /4,/n. 20 . 5, 77 14--7 r7, 62 C.09 36,Z 0, 53 L2,3$ '5c„tt, 254t. S,3S /4—i 7, 25 5 ,a (0 3 2, 3 0 ,2`1 Suggested Notation: —"=not measured "✓"=stable "+"=rising ""=falling •"=all parameters stable Page 1 Water Sampling Data Sheet °"rp%InAa:"A Sample Collection Information Start Time Finish Time/Date ; ipment Used for Sam C) 1 2', 5 S/7/7//f Faucet Spigo Existing Pump Bucket Other SAMPLE ID: iL-E,U 3Z—OS QC: Dup MS/MSD Container/Preservative Analysis Requested Notes 3-VOA glass,HCL GRO 2-1 Liter,HCL DRO 3-VOA glass Dissolved methane,ethane,propane 1 -250 mL HDPE TDS 2-1 Liter,HCL TPH 1 -60 mL HDPE iodide 1 -60 mL HDPE fluoride 1 -60 mL HDPE Bromide 1 -60 mL HDPE chloride 1 -60 mL HDPE,H2SO4 NO2/NO3 as N 1 -250 mL HDPE,H2SO4 phosphorous 1 -250 mL HDPE,HNO3 strontlum-90 1 -250 mL HDPE alkalinity 1 -250 mL HDPE alkalinity,bicarbonate 1 -250 mL HDPE hydroxide 1 -250 mL HDPE,HNO3 200.7 metals (b,ca,fe,II,k,na) 200.8 metals 1 250 mL HDPE,HNO3 (as,ba,cd,cr,mg,mn,se,si) 3-VOA glass,HCL BTEX 2-1 Liter PAH 1 -60 mL HDPE sulfate 1 -60 mL HDPE pH 1-250 mL HDPE,HNO3 Radium 226 1 -250 mL HDPE,HNO3 Radium 228 1 -60 mL HDPE Specific conductance 1 -120 sterile plastic Iron related 1 -120 sterile plastic sulfate reducing 1 -120 sterile plastic slime forming 3x40ML vol i/mC,1+Cc - 6r67r Co X4131,-.L VDA-J/t.lCt -. -i - vii (942.4 ,wtr 6- ��r-►t E, ff�v4A*�E 1 X 500v-.L ??Ly .)/14.2_50+ —NOL/NO3 ) P+w4Pt> -u5 4 u 50t).4,.L ►�c-,�z. id/N,k, sot 4-LL - S 23.2 Phi/ ZX/DUD — CD.„0 A-L-v f i C -Iz✓D mi-C I i"N2-O'(l DG ) fl) ) 9µ,r. , d � ,�, `504- 3-A /00 ML- `%9..4 L w/T 7 % O3 - ACS t.l r ) I f1-0)-`� 1 x I 901.-`1 — ZOO:7 `zoo, g 64c-- ,.s I 226 Ix / L- Ppw - rt-a-c, 2? / L 901--1 - s-,-2 t y r, /0 4-X I t, X55 IA) 14-cl — a? c'. -c-,6-, DR-0 jTVt4 2 ATTACHMENT 2 SAMPLE CHAIN-OF-CUSTODY w Ns y � A.J �., t0 z. c �`•. ? 0 N.,...,_ a 4 _ 7 - j _ %+ C C L N. . 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O O O O O O 0 O O OO M do I I I , O ODOOp66^ Q Lo o-) .6en 6NJ 0 m ,--1 MW O O O r p 0 O a) 0 o� tN c-i •L O tf1N 0 m M ,-i a1 O tf0 0 lD zZ Ni z O O O kD OZo ,-i O z 0 O O 6 O 6 O E a) fa `.1 fa a) • I- 00 ri to "' a N. I- +° OI 1D (m o N L0 O 0rsJ 0.0 O m ^p y O o IIIIIIiIIIIIIIIIIIII N O Q t11 Q m E 2 Y , Y n .1:- Z Z o as •- 0 H d L 0 a .6, L v (a L gyp c E p 1- U is) 00 t11 1 I I I I I 1 1 I I ON p ( a 1 O O c-I cf I I E v) N �O O O O O O Qt to -0 (0 L to O f6 J U 4. = a E U V) J J J . . . . . J . . . . . J J J J J J J J J -, \ \ \ V) \ \ \ \ \ \ \ \ \ \ \ \ \ \ - \ \ \ \ \ C U V U 0 OA 00 00 OA 00 00 0.0 00 00 CIO 0A 0.0 00 00 00 OA CO 00 0.0 01) D Q a n z EEEEEEEEEEEEEEEEEEEE 2 n N a) a) 0A 4--, Tu 0J 0 o p I— C E N v Si E E N ~ (gyp N N °; c E E .' D c E •`-' E E .g Cr E a) o E E v E n "7., a`°i Lu o c c - v O = c m E '� (a c o •- a) (.7 = mo ifs 0 Y acA ;a N o '- (0 -o ° 0 OA a ° = o '(0 C 0) -0 U U J (0 O V) Q m (0 (0 a) m u LT v) U (Y OL 0) (1 .+: D_ U U 2 i N z c0 I c 0 C 0 U i .-1 r-I < N N N N N N N N 00 00 00 co co 00 0 0 0 0 0 -Cop 0 M O w o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 4 au a) cc 0 N LD O O O O O O O O O O O O O O O O O O ,1 c V) a) ,-iN N N N N N N N N N N N N N M m m m M m a) N m in M O 0 m r- 0 0 0 0 O m C Ln (n o O N O o o 0 o 0 E m p 01 ^ Q 1 1 0 0 0 0 0 1 I 1 1 1 1 1 1 1 1 1 1 1 1 I p 1 1 1 a oo Y 0 0 0 0 0 IL Y ^ � 0 0 0 0 0 Z 0 Z Z Z Z L a) ^ (V m Ln m o LD Ln co ^ in N lD LD in m LD Ln L0 CO 0 } O N (V (V O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 <--1 co 0 (yl •--1 ra O O o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 .--1 {, i-• in m o 0 0 0 0 0 0 088800000000000 . . NI m N N J O o o o o o o o o 0 o o o o o o o o o a) a) (» m 0 ^ Q o 0000 - 0080000000000006 .52, . a r, , o Ln 299222d9920 0 0 0 0 0 0 0 0 0 WD Q Q m Y ^ Z m 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Z o Y 0 O Z Z Z Z O Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z O O E w i . L.. 0 f6 a) co ,--1 Ln L (0 0 �D m r a +, 10 m 0 c p m ^ 0 ^ teQ I I I I i l l l l l l l l l 1 1 1 1 1 1 1 •a i m , \ Y tor, c E C Y .--1 Y 'C co •- 0 N cu .L cu 0 3 d L., T O ((3 L y a) O o .L J Ln j £ E N 0 a 0 2 0 1O O o o I I I I I I I 0. .c to -Q (0 as L gj M Ln O (C J U a+ Q J J I/1 J J J J J J J J J J . . . . . . . . J J J J J J EE woo 00 00 U0 OCA 00 1010 OCA tC0 b0 tow 00 00 OCA hC0 t10 0 00 ti0 U0 U0 U0 E E E E E E E E E E E E E E E E E E E E E E E E LL LL 00 C a) U) a) (9 °° v c (a .L OL f0 a) C CL) C (1) a) v •L a) �' v c -C a, T v +., z H v C v v v v c C ` C v v v a aci a p CO m (0 N C N v C C Y L a) ? CD a) c0 C +--• = C U L a) U m dA a C a) a) _C Y U 4-, �- o a) C a-. N }, C O C u N a ? (0 T f0 C 1- m N N E t v X X o ro (Qo C r° o �_ = -C ,_ = N c >, v '' E o 9- 00 = a o l— v c c N - °p -c U (d o LL -1 v a 0 U) o 0 z p E U a) Q N C O r.1 L .-( OC L.L. a) t W Q U c m , NI , C LL OC C- U U C a1 < C C �_ a) OL E m a) N a) - �_ m m m -6 C — N Z I— 1— cc tr tr Q Q o N CO N N N N N N N N N N N N N N N N N N N . o"1 N m m �,,, m Ln 4 4 .4 4 4 Ln Ln Ln Ln Ln Lfl Ln Ln Ln Ln Ln 111 Ln Ln Ln O� 0� cc cc a) in lD N N N N N N N N N N N N N N N N N N N N Y Y Ln N m m in to in Ln Ln Ln Lr) Ln to to in in to Ln LC) in to in in in Q Q GU U ra (a 2 2 M { 0 rH Cn \ 0 $ / 0 0 0 § m m o ¥ a o 0 a m E N. / \ m / / 1 1 1 1 g o / a » 0 0 Cr » .s 0 0 0 2 0 / z z \ } k « ? / m 0 / 0 0 0 0 0 g 0 o o e e e@ E _ u o = \ m N. \ s < - \ \ 3 2 0 ® § E \ 2 r \ % 0 0 ^ ^ •_ 0 u z z ¥ $ E co \ 2 0 13.0 / i_ F- m as 0 ) 0as E ql % N- - Li) I I I I 1 1 1 1 e 2 0 \ \ •, ® . 1- c # ® E _ 2 � » •� ro 2 J 7 0 t 44.4 L 0 0 a » \ M a) 0 ./ 0 e as c a E \ a % \ / � � � � � � � � � \ E \ 'A E 2 C 0. = z \ n 3 0 o ¥ -J ..1-7. i 2 c - z \ \ i E E E 0.0 E CIA E ƒ 0 L..) a 7 E g 3 LL L \ \ I- U 0 \ 0 ro w m G \ - $ CIJ © @ m 2 / \ \ m » 3 7 / 5 o 'U 7 % a U a) { a I > _ _ 0.. \ $ 2 » f 2 t E = 2 \ % o CL : / § \ -C � \ ± { ® § \ ® E t ° % \ -o \ T. . I o E 2 •» » ® _ \ _ _ _ zr) ( o a) z 2 c S \ 0 © > E 0 cc co \ = \ I - / \ ƒ o , % % % / CO \ al ƒ - / � / j E •/ \ \ j % \ % \ \ \ [ E u cc \ \ I \ J J J > > > > % „ " " I 2 2 f z z m > } I / 2 0 c z -- 2 Eo_ 2 / —, STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMML..AON j 0 2 2014 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Lf Repair Well L] Plug Perforations ❑ Perforate U OtherCICC Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program 0 Operat.Shutdown 0 Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development ❑✓ Exploratory ❑ 214-014 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20624-00 7.Property Designation(Lease Number): 8.Well Name and Number: FEE A028142&FEE A022330 Kenai Beluga Unit(KBU)32-08 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kenai Gas Field/Upper Tyonek Gas&Beluga Gas Pool 11.Present Well Condition Summary: Total Depth measured 9,847 feet Plugs measured 9,475 feet true vertical 8,138 feet Junk measured feet Effective Depth measured 9,448 feet Packer measured 5,849 feet true vertical 7,848 feet true vertical 4,940 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 135' 16" 135' 135' Surface 1,478' 10-3/4" 1,478' 1,420' 5,210psi 2,470psi Intermediate 6,405' 7-5/8" 6,405' 5,391' 6,890psi 4,790psi Production 3,897' 5" 9,746' 8,098' 10,140psi 10,500psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 5" 18#/L-80 5,849'MD 4,940'TVD Packers and SSSV(type,measured and true vertical depth) Swell Pkr 5,849'MD 4,940'ND N/A;N/A 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 1,082 55 0 171 Subsequent to operation: 0 1,234 55 0 147 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas Q WDSPL❑ GSTOR ❑ WINJ 0 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: 314-486 Contact Paul Chan Email pchanahilcorp.com ::::m Paul ChanTitle :::i::::b0n5 Engineer Phone Date / 01 Z / 1 tr PRBC AVIS OCT - 2 2.01C._ Form 10-404 Revised 10/2012 74 J Ay (/ 4r Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date KBU 32-08 50-133-20624-00-00 214-014 9/4/14 9/4/14 Daily Operations: 09/03/2014-Wednesday No activity to report. 09/04/2014-Thursday PTW and JSA. Mobe to location. Spot equipment. Arm gun. Rig up lubricator and pressure test to 250 psi low and 3,500 psi high. Well flowing 1 million at 164 psi. RIH w/2-7/8" x 26' Connex HC, 6 spf, 60 deg phase and tie into SLB RST log. Run correlation log and send to town. Get ok. Spot shot from 8,136' to 8,162'. Well flowing 1 million at 164 psi. Fired shot. After 5 min well was flowing 1.1 million at 167 psi. POOH, RIH w/2-7/8" x 20' Connex HC, 6 spf, 60 deg phase and tie into SLB RST log. Run correlation log and send to town. Get ok. Spot shot from 7,260' to 7,280'. Well flowing 1.1 million at 220 psi. Fired shot. Well being monitored in office. Pick up 150', let well stablize and go tag bottom at 9,358'. POOH, Rig down lub and turn well over to field. 09/05/2014- Friday No activity to report. 09/06/2014-Saturday No activity to report. 09/07/2014-Sunday No activity to report. 09/08/2014- Monday No activity to report. 09/09/2014-Tuesday No activity to report. Kenai Gas Field Well: KBU 32-08 14 SCHEMATIC Last Completed: 8/01/2014 Ililcorp Alaska,LLC PTD: 214-014 CASING DETAIL RKB:MSL=22' Size Type Wt/Grade/Conn ID Top Btm A i , 't 16" Conductor N/A Surf 135' % 10-3/4" Surface 45.5/L-80/BTC 9.950 Surf 1,478' 7-5/8" Intermediate 29.7/L-80/BTC 6.875 Surf 6,406' " 5" Production 18/L-80/DWC/C-HT 4.276 5,849' 9,746' 16' r r' M7 TUBING DETAIL 5" Tubing 18/L-80/DWC/C-HT 4.276 Surf 5,849' t r 4 JEWELRY DETAIL n 10-3/4" 'd t ► No Depth Item L) 1 5,849' 5"Swell Packer 2 7,330' 5'Pup ;i 3 8,028' 5'Pup M 4 9,475' CIBP M '' OPEN HOLE/CEMENT DETAIL M 10-3/4" 160BBL's of cement in 13.5"Hole.Returns to Surface 7-5/8" 261BBL's of cement in 9-7/8"Hole.Returns to Surface J 5" 114BBL's of cement in 6-3/4"Hole. TOC 4,600'Calculated L4 PERFORATION DETAIL Ti li r Sands Top(MD) Btm(MD) Top(TVD) (TVD) FT Date Status i ` MB4B 7,260' 7,280' 6,078' 6,094' 20 09/04/14 Open i r LB3B 8,136' 8,162' 6,790' 6,811' 26 09/04/14 Open ;+ Lr. LB4A 8,290' 8,300' 6,900' 6,910' 10' 08/01/14 _ Open !.kt. LBSA 8,514' 8,524' 7,100' 7,110' 10' 07/30/14 _ Open ;'z % Tyonek 73-1 8,848' 8,858' 7,362' 7,370' 10' 07/28/14 Open Tyonek 75-8 9,202' 9,212' 7,647' 7,655' 10' 07/27/14 Open to el,-- Tyonek 76-7 9,343' 9,366' 7,762' 7,781' 23' 06/19/14 Open '= Tyonek 78-2 9,500' 9,510' 7,891' 7,899' 10' 06/07/14 Isolated 4,1 ., 7-5/8" ja ak f ;4 1 , A 10 ►a 12 3 d it D4, 1 tie46 4. -7- 43 V LB3B 1' it L84A 1 VP LBSA =Tyonek 73-1 v Tyonek 758 TOC©9,448'..`\et ��Tyonek 767 1. a 4 sh r� Tyonek 78-2 ♦c 5" .+4• r+ 1 TD=9,746'(ND)/8,098'(TVD) PBTD=9,351'(MD)/7,768'(TVD) Updated by DMA 09/22/14 Colombie, Jody J (DOA) From: Foerster, Catherine P (DOA) Sent: Wednesday, September 10, 2014 9:22 AM To: Schwartz, Guy L (DOA); Wallace, Chris D (DOA); Colombie, Jody J (DOA) Subject: FW: KBU 32-08 Water Well Sampling Results Attachments: KBU 32-08 Water Well Results.xlsx PID ZI`r- °IK From: Drew Anderson [mailto:ananderson@hilcorp.com] Sent: Wednesday, August 27, 2014 3:17 PM To: Foerster, Catherine P (DOA); Campbell, Peter C (DEC); 'Ethan Schutt (eschutt@ciri.com)' Cc: Paul Chan; Chad Helgeson Subject: KBU 32-08 Water Well Sampling Results All, Please see the attached water well sample results. One water well was sampled to represent pre-fracturing conditions near KBU 32-08 in accordance with the sampling plan provided in the approved sundry application. Due to laboratory capacity issues, we have not received results for Propane or Ethane for either sample. We will forward the results for Propane and Ethane when we receive them. Below is a summary of the notifications required by 20 AAC 25.283(a)(4) based on the sample results: • The water well near KBU 32-08 contained a detectable concentration of toluene and an estimated concentration of DRO near the laboratory detection limits. The estimated concentration of DRO and detectable concentration of toluene are well below 18 AAC 75 Table C Groundwater Cleanup Levels. Please note that ADEC checklists have not yet been completed and a data quality analysis has not yet been performed for this sample. Please contact me if you have any questions or concerns. Thank you, Drew Drew Anderson, PE PMP I Environmental Coordinator UHilcorp Alaska, LLC ananderson@hilcorp.com P(907)777-8488 I F(907)777-8560 I M(907)382-0987 1 Project: Hilcorp Hydraulic Fracturing Support ALS SDG: K1407335 Sample Date Collected Method Component KBU 32_08 7/17/2014 120.1 Conductivity at 25 Degrees Celsius KBU 32_08 7/17/2014 200.7 Boron, Total KBU 32_08 7/17/2014 200.7 Calcium, Total KBU 32_08 7/17/2014 200.7 Iron, Total KBU 32_08 7/17/2014 200.7 Lithium,Total KBU 32_08 7/17/2014 200.7 Magnesium,Total KBU 32_08 7/17/2014 200.7 Potassium,Total KBU 32_08 7/17/2014 200.7 Silicon,Total KBU 32_08 7/17/2014 200.7 Sodium, Total KBU 32_08 7/17/2014 200.8 Arsenic,Total KBU 32_08 7/17/2014 200.8 Barium,Total KBU 32_08 7/17/2014 200.8 Cadmium,Total KBU 32_08 7/17/2014 200.8 Chromium,Total KBU 32_08 7/17/2014 200.8 Manganese,Total KBU 32_08 7/17/2014 200.8 Selenium,Total KBU 32_08 7/17/2014 300 Bromide KBU 32_08 7/17/2014 300 Chloride KBU 32_08 7/17/2014 300 Fluoride KBU 32_08 7/17/2014 300 Sulfate KBU 32_08 7/17/2014 314 Iodide KBU 32_08 7/17/2014 353.2 Nitrate+Nitrite as Nitrogen KBU 32_08 7/17/2014 365.3 Phosphorus,Total KBU 32_08 7/17/2014 524.2 Benzene KBU 32_08 7/17/2014 524.2 Toluene KBU 32_08 7/17/2014 524.2 Ethylbenzene KBU 32_08 7/17/2014 524.2 m,p-Xylenes KBU 32_08 7/17/2014 524.2 o-Xylene KBU 32_08 7/17/2014 525.2 Acenaphthylene KBU 32_08 7/17/2014 525.2 Acenaphthene KBU 32_08 7/17/2014 525.2 Fluorene KBU 32_08 7/17/2014 525.2 Phenanthrene KBU 32_08 7/17/2014 525.2 Anthracene KBU 32_08 7/17/2014 525.2 Fluoranthene KBU 32_08 7/17/2014 525.2 Pyrene KBU 32_08 7/17/2014 525.2 Benz(a)anthracene KBU 32_08 7/17/2014 525.2 Chrysene KBU 32_08 7/17/2014 525.2 Benzo(b)fluoranthene KBU 32_08 7/17/2014 525.2 Benzo(k)fluoranthene KBU 32_08 7/17/2014 525.2 Benzo(a)pyrene KBU 32_08 7/17/2014 525.2 Indeno(1,2,3-cd)pyrene KBU 32_08 7/17/2014 525.2 Dibenz(a,h)anthracene KBU 32_08 7/17/2014 525.2 Benzo(g,h,i)perylene KBU 32_08 7/17/2014 903.1 Radium-226 KBU 32_08 7/17/2014 904 Radium-228 KBU 32_08 7/17/2014 905 Strontium-90 KBU 32_08 7/17/2014 1664A Oil and Grease, Total (HEM) KBU 32_08 7/17/2014 AK101 C6 - C10 GRO KBU 32_08 7/17/2014 AK102 C10 -C25 DRO KBU 32_08 7/17/2014 Hach SRB-BART Iron Related Bacteria KBU 32_08 7/17/2014 Hach SRB-BART Slime Forming Bacteria KBU 32_08 7/17/2014 Hach SRB-BART Sulfate Reducing Bacteria KBU 32_08 7/17/2014 RSK 175 Methane KBU 32_08 7/17/2014 SM 2320B Alkalinity,Total as CaCO3 KBU 32_08 7/17/2014 SM 2320B Bicarbonate as CaCO3 _KBU 32_08 7/17/2014 SM 2320B Hydroxide as CaCO3 KBU 32_08 7/17/2014 SM 2540 C Solids, Total Dissolved KBU 32_08 7/17/2014 SM 4500-H+ B pH Result LOD Units 228 uMHOS/cm 35.4 10 ug/L 25800 2 ug/L 209 10 ug/L 5.7 J 10 ug/L 6730 0.6 ug/L 3600 200 ug/L 17600 50 ug/L 9190 40 ug/L 6.3 0.1 ug/L 50.3 0.03 ug/L ND 0.01 ug/L 0.08 J 0.05 ug/L 164 0.012 ug/L ND 1 ug/L ND 0.04 mg/L 2.03 0.06 mg/L 0.19 J 0.04 mg/L ND 0.04 mg/L ND mg/L ND 0.02 mg/L 0.315 0.008 mg/L ND 0.08 ug/L 0.06 J 0.2 ug/L ND 0.08 ug/L ND 0.16 ug/L ND 0.08 ug/L ND ug/L ND ug/L ND ug/L ND ug/L ND ug/L ND ug/L ND ug/L ND ug/L ND ug/L ND ug/L ND ug/L ND ug/L ND ug/L ND ug/L ND ug/L 0.15 LT pCI/L ND pCI/L ND pCI/L ND 4 mg/L ND 25 ug/L 16 J 20 ug/L Absent CFU/mL Absent CFU/mL Absent CFU/mL 490 ug/L 116 2 mg/L 116 2 mg/L ND 2 mg/L 148 mg/L 8.02 pH UNITS 47, 1%j%SA THE STATE ska OE and G c r--r "i c •'•# ; ,�r. 1e-' _:= 333 West Seventh Avenue " GOJ'R;\'oR SFAN PAR ELL. Anchoiage, Alaska 99501-3572 QF '\Ac;n 907.279 14-3 i,J 9 Paul Chan Senior Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Kenai Gas Field, Upper Tyonek Gas and Beluga Gas Pools, Kenai Beluga Unit 32-08 Sundry Number: 314-486 Dear Mr. Chan: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 7c2P- 9)/6- - Cathy P Foerster Chair DATED this 3 day of September, 2014. Encl. RECEIVED • STATE OF ALASKA 119-(14 ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 2 7 2014 • 4)/\/\ APPLICATION FOR SUNDRY APPROVALS AOG�G 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redd! ❑ Perforate New Pool p Repair Well❑ Change Approved Program ❑ Suspend D Plug Perforations ❑ Perforale 2. Pull Tubing❑ Time Extension 0 Operations Shutdown D Re-enter Susp.Well ❑ Stimulate ❑ Alter Casing❑ Other. ❑ 2.Operator Name: 4.Current Wel pass: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development D• 214-014. 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-133-20624-00-00 • 7.If perforating: di) 5-A--) Jr, S.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? WA-- ; L('' e. Will planned perforations require a spacing exception? Yes 0 No ❑., Kent Beluga Unit 32-06 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): FEEA028142&FEEA022330 Kenai Gas Field/Upper Tyonek Gas&Beluga Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9,847' • 8,138 • 9,448' 7,848' 9,351'(Cement on CIBP) N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 135' 16' 135' 135' Surface 1,478' 10-3/4" 1,478' 1,420' 5,210psi 2,470psi Intermediate 6,405' 7-5/8" 6,405' 5,391' 6,890psi 4,790psi Production 3,897' 5" 9,746' 8,098' 10,140psi 10,500psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See attached schematic See attached schematic 5" 18#/L-80 5,849' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Swell Packer;N/A 5,849'(MD)and 4,940(TVD);N/A 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: , Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0 Service ❑ 14.Estimated Date for / 15.Well Status after proposed work: Commencing9/4/2014 Operations: Oil ❑ Gas ❑✓ • WDSPL ❑ Suspended 0 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Paul Chan Email pchan u.hilcorD.com Printed N. e ,I C an Title Senior Operations Engineer Signature Phone 777-8333 Date U(2.7(f Cy COMMISSION USE ONLY I Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 kLk- '--1/4. lQ Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes 0 No Subsequent Form Required: /6 -&j by APPROVED BY /� Approved by: ,_ p COMMISSIONER THE COMMISSION Date: 4 -3 - �' ly Submit Formand Form 10-403 vi oAp p lt NIlo 2 months from the date of ap�val� ! Kaenin e REICMS /�DCt . Well Prognosis Well: KBU 32-08 AFE: 1421941 Hilcorp Alaska,LL Well Name: KBU 32-08 API Number: 50-133-20624-00-00 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: 9/3/2014 Rig: N/A Reg.Approval Req'd? 10-403 Sundry Number: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-044 First Call Engineer: Paul Chan (907) 777-8333 (0) (907) 345-3161 (H) (907)444-2881 (C) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (C) Estimated Bottom Hole Pressure: — 3,587 psi at 7,970 ft TVD (based on 0.45 psi/ft gradient) Max.Anticipated Surface Pressure: —2,989psi (0.075 psi/ft gas gradient) Brief Well Summary: KBU 32-08 was drilled in March 2014 and five zones were fracture stimulated July 2014. The gas rate is too low to keep the 5" casing unloaded so additional zones will be added to increase rate. A velocity string will be run subsequent to the ad perfs to keep the critical velocity over the water unloading rate. A separate 10-403 sundry will be submitted for the velocity string. Objective: • Add perforations in the Tyonek and Beluga sands. Summary Procedure: E-Line Procedure 1. MIRU e-line and pressure control equipment. PT lubricator to 250 psi low/3,500 psi high. 2. RA markers are at 7,330'and 8,028' MD as per the Casing and Cementing Report dated 3/15/2014. Send log in to Paul Chan and Sarah Rittenhouse. 3. Perforate the sands with 2-7/8" 6 SPF 60 deg phased GEODynamics Connex gun. Depths are from the Schlumberger RST/GR/CCL log dated 2 June 2014. Send the correlation pass to Paul Chan and Sarah Rittenhouse for confirmation. Proposed Perforated Intervals Sands Top (MD) Btm (MD) FT Tyonek LB3B 8,121' 8,147' 26 ' Beluga MB4B 7,246' 7,266' 20 4. POOH. 5. Flow well through test separator and record water and gas rates 6. If any of the Tyonek or Beluga sands are not commercial,then the zone will be covered with a tubing/casing patch if there are productive intervals below 7. RD e-line. 8. Turn well over to production. Attachments: As-built Well Schematic and Proposed Well Schematic Kenai Gas Field Well: KBU 32-08 • + SCHEMATIC Last Completed: 6/19/2014 HuicorP Alaska,LLC PTD: 214-014 CASING DETAIL RKB:MSL=22' Size Type Wt/Grade/Conn ID Top Btm 16" Conductor N/A Surf 135' 10-3/4" Surface 45.5/L-80/BTC 9.950 Surf 1,478' • 7-5/8" Intermediate 6.875 Surf 6,406' 5" Production• 182/91-78/01-/-81)0W/C8/TCC-HT 4.276 5,849' 9,746' 16" TUBING DETAIL 5" Tubing 18/L-80/DWC/C-HT 4.276 Surf 5,849' JEWELRY DETAIL 10-3/4" No Depth Item 1 5,849' 5"Swell Packer 2 7,330' 5'Pup _ 3 8,028' 5'Pup 4 9,475' CIBP OPEN HOLE/CEMENT DETAIL 10-3/4" 160BBL's of cement in 13.5"Hole.Returns to Surface 7-5/8" 261BBL's of cement in 9-7/8"Hole.Returns to Surface 5" 11488L's of cement in 6-3/4"Hole. TOC 4,600'Calculated PERFORATION DETAIL Btm Sands Top(MD) Btm(MD) Top(ND) (TVD) FT Date Status LB4A 8,290' 8,300' 6,900' 6,910' 10' 08/01/14 Open LB5A 8,514' 8,524' 7,100' 7,110' 10' 07/30/14 Open Tyonek 73-1 8,848' 8,858' 7,362' 7,370' 10' 07/28/14 Open Tyonek 75-8 9,202' 9,212' 7,647' 7,655' 10' 07/27/14 Open Tyonek 76-7 9,343' 9,366' 7,762' 7,781' 23' 06/19/14 Open Tyonek 78-2 9,500' 9,510' 7,891' 7,899' 10' 06/07/14 Isolated • St 1 7-5/8" a • O2 33 • LB4A LB5A Tyonek 731 Tyonek 75-8 =Tyonek 76-7 -41 `:4 4 Tyonek 78-2 TD x,746'( )/8,098'(TVD) PBTD=9,351'(MD)/7,768'(ND) Updated by DMA 08-20-14 Kenai Gas Field rH Well: KBU 32-08 PROPOSED Last Completed: 8/01/2014 ua(•„r„Alaska,i.i.c PTD: 214-014 CASING DETAIL RKB:Ma=22' Size Type Wt/Grade/Conn ID Top Btm 16" Conductor N/A Surf 135' 10-3/4" Surface 45.5/L-80/BTC 9.950 Surf 1,478' 7-5/8" Intermediate 29.7/L-80/BTC 6.875 Surf 6,406' 16" 5" Production 18/L-80/DWC/C-HT 4.276 5,849' 9,746' TUBING DETAIL 5" Tubing 18/L-80/DWC/C-HT 4.276 Surf 5,849' JEWELRY DETAIL • 103/4" No Depth Item % 1 5,849' 5"Swell Packer 2 7,330' 5'Pup 3 8,028' 5'Pup 4 9,475' CIBP OPEN HOLE/CEMENT DETAIL 10-3/4" 160BBL's of cement in 13.5"Hole.Returns to Surface 7-5/8" 261BBL's of cement in 9-7/8"Hole.Returns to Surface 5" 114BBL's of cement in 6-3/4"Hole. TOC 4,600'Calculated PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) (Np) FT Date Status MB4B ±7,246' ±7,266' ±6,067' ±6,083' ±20 TBD Proposed LB3B ±8,121' ±8,147' ±6,777' ±6,799' ±26 TBD Proposed LB4A 8,290' 8,300' 6,900' 6,910' 10' 08/01/14 Open LB5A 8,514' 8,524' 7,100' 7,110' 10' 07/30/14 Open Tyonek 73-1 8,848' 8,858' 7,362' 7,370' 10' 07/28/14 Open Tyonek 75-8 9,202' 9,212' 7,647' 7,655' 10' 07/27/14 Open Tyonek 76-7 9,343' 9,366' 7,762' 7,781' 23' 06/19/14 Open Tyonek 78-2 9,500' 9,510' 7,891' 7,899' 10' 06/07/14 Isolated 8 1 7-5/8" A v P s: ]2 '' Meas a 3 L83[ LB4A =.---,LBSA Tyonek 73-1 Tyonek 75-8 TOC @ 9,448 _Tyonek 76.7 T Tyonek 78-2 ti '' 5" •a " 'i TD=9,746'(MD)/8,098'(TVD) PBTD=9,351'(MD)/7,768'(TVD) Updated by DMA 08-27-14 REDEWED STATE OF ALASKA ALA. OIL AND GAS CONSERVATION COMMIT N AUG 2 6 2014 • REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon U Repair Well U Plug Perforations U Perforate [J Other Li Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑, Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development Q Exploratory ❑ 214-014 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20624-00 7.Property Designation(Lease Number): 8.Well Name and Number: FEE A028142&FEE A022330 Kenai Beluga Unit(KBU)32-08 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kenai Gas Field/Upper Tyonek Gas&Beluga Gas Pool 11.Present Well Condition Summary: Total Depth measured 9,847 feet Plugs measured 9,475 feet true vertical 8,138 feet Junk measured feet Effective Depth measured 9,448 feet Packer measured 5,849 feet true vertical 7,848 feet true vertical 4,940 feet Casing Length Size MD ND Burst Collapse Structural Conductor 135' 16" 135' 135' Surface 1,478' 10-3/4" 1,478' 1,420' 5,210psi 2,470psi Intermediate 6,405' 7-5/8" 6,405' 5,391' 6,890psi 4,790psi Production 3,897' 5" 9,746' 8,098' 10,140psi 10,500psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 5" 18#/L-80 5,849'MD 4,940'ND Packers and SSSV(type,measured and true vertical depth) Swell Pkr 5,849'MD 4,940'ND N/A;N/A 12.Stimulation or cement squeeze summary: Fracfocus data entered and attached Intervals treated(measured): 9,343'-9,366';9,202'-9,212';8,848'-8,858';8,514'-8,524';8,290'-8,300' Treatment descriptions including volumes used and final pressure: See attached treatment reports. 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: 0 1,063 89 0 148 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development E Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas Q WDSPL❑ 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: 314-383 i Contact Pau •- Email pchantcDhilcoro.com Printed Name Paul Chan Title Senior Operations Engineer Signature ��1 Phone 907-777-8333 Date a I 2.c// c / C1 - )_1 4_1 RBGMS AUG 2 8 201 Form 10-404 Revised 10/2012 ,* Submit Original Only • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date KBU 32-08 50-133-20624-00-00 214-014 7/18/14 8/4/14 Daily Operations: 07/18/2014- Friday Held JSA with Halliburton. Open well with 20psi SICP. RIH at 80fpm, pumping .25bpm. Made weight checks every 1000'. Tagged plug at 9,030' CTM. PU off plug and increased rate to 2.6bpm. Set down on plug and started milling. Plug milled up in 2 hrs. RIH and tagged Bottom at 9,787' CTM, Circulated bottoms up and 2.5bpm. With returns clean, POOH at 80fpm. ND BOP's, LD riser, injector head and NU tree cap. 07/19/2014-Saturday Held JSA with Halliburton. RU flowback iron to well. MU CT iron from pump to well. Test iron to 6,000psi. Test ok. Performed DFIT test, Sent test in for review. RU flowback iron off well head. Finshed mixing work tanks with 6% KCL. Heated work tanks to 95 deg. 07/20/2014-Sunday Held JSA with Halliburton. Loaded proppant into sand king, Prep frac equipment for 1st stage frac. NU Goathead and MU 3" Frac Iron, Tested iron to 9,500psi.-Test Ok. MU 2" 1502 iron from CT pump to annular. 07/21/2014- Monday Held JSA with Halliburton Crews . 7:50a-Open the well with 1,080 psi at the wellhead. 7:52a-Start pumping, initial injection at 3,700 psi and 3 bpm. 7:59a-Dry gel unit unable to mix gel, S/D, ISIP= 3,311 psi. 8:10a-Resume pumping, 15 cP. 8:14a- Minifrac volume pumped, S/D, ISIP = 3,355 psi, 221 bbl total, 85 bbl after initial S/D. 10:13a-Begin pumping frac treatment. 10:14a-Shut down to measure ISIP, ISIP = 3,490 psi. 10:37a-Final S/D, ISIP = 3,374 psi. 10:46a-Open at 1-1.5 bpm for forced closure. Issue with plugged up sand seperator. 13:00-Shut-in well and rig up coiled tubing, (flow rate down to 5 gpm). Maximum treating pressure: 4,760 psi. Maximum treating rate: 32.3 bpm. Average treating pressure: 4,137 psi. Maximum treating rate: 30.4 bpm. Proppant placed: 66,000 lb curable resin-coated sand,TLTR: 802 bbl. RU CT, NU BOP's, Riser and Injector Head. Hook up flowback iron from CT flow cross to Ck manifold. Started pump and filled CT and BOP's, broke circulation and Body tested 250-4,500psi-Test ok. RIH, 90fpm pumping .25bpm to 3,000'. Cut water and started N2 at 400 scf/m,jetted dry. Unloaded 83 bbls (43bbls from CT), Well did not flow. RIH to 6,000' and jetted dry, unloaded 41 bbls to tank. Well would not flow. RIH and Tagged lightly at 8,400', increased N2 to 700scf/m and .75bpm. Washed down to tagged bottom at 9,390'ctm. Circulated Bottoms up, returns showed light sand. Jetted well dry and cut N2. No gas. WellHead Psi 150-500psi. Circulating Psi 1,500-2,300psi. POOH, ND CT Injector head, riser, Bop's and flowcross. NU tree cap and Secured well. SIFB. 07/22/2014-Tuesday Held JSA with Halliburton. SIFB, shot fluid level 2,450', SICP 1,225', Open well to choke and bled down to Opsi in 20 mins. No fluid recovered. Could not determine fluid level after bleeding the well down. Received order from Anchorage to blow down the well with CT. RU CT, NU 10k valve to isolate from frac. NU Cross, Bop's, riser and injector head. Loaded CT and shell tested 250-4,500psi-Test ok. Blew water out of CT to flowback tank. 07/23/2014-Wednesday Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date KBU 32-08 50-133-20624-00-00 214-014 7/18/14 8/4/14 Daily Operations: Held JSA with Halliburton. POOH and secured well. SIFB. Monitored fluid up on well. Opsi. Received orders from Anchorage to plug back stg 1 and perf stg 2. Stood back CT Injector head and riser.; MIRU EL, NU Bop's and lubricator. Tested to 3,500psi -test ok. MU 3.97" CBP and CCL/GR. RIH at 100fpm per Halliburton Tool Hand. Set down at 8,921'. Pulled 3,600psi to free tool. POOH. L/D and inspected plug. Found sand inside the plug body. MU 4" GR/JB and RIH. Tag up at 8,916'. Had to worked tool for 15 mins to free. Tried working down with no luck. POOH. RD EL . Waited on SL Unit to arrive. Plan to work bailer and GR thru tight spot. 07/24/2014-Thursday Waited on SL to arrive. Held JSA with Pollard SL. MIRU SL and tested lub to 3,500psi-Test ok. RIH w/4" GR and Tag @ 8,905' slm, Worked up/down for 30 mins. Did not make any hole. POOH, MU 2.87" GR and RIH, Tagged at 8,905'slm, worked up/down with no progress. POOH, MU 2.5" OD x 5" drivedown bailer and RIH, Tagged @ 8,905' slm. Worked bailer and POOH. Bailer 3/4 full of sand. Made 4 more bailer runs and recovered 3-4' of sand. RDMO SL. RU CT and prep to BOP Test. Tested BOP's, performed drawdown test. Tested rams, blinds and body to 250-4,500psi and charted for 5 mins-Test ok. Witness waived by Jim Regg, AOGCC. MU BHA,4" Bit, 2 bpm motor, and cir sub. Pull,tested to 20k. RIH at report time. 07/25/2014- Friday Held JSA. RIH w/CT started .75bpm and N2 at 400scf,Tagged fill 8,780'. Washed down 9,295'ctm. Send 10bbl sweep and PU 10' waiting on sweep to exit CT. Stopped pumping N2 and increased rate to 2.5bpm. Returns at 2bbls per min/heavy sand. Continue cir until returns cleaned up. POOH pumping to 2.5bpm. Stood back CT riser and injector head. RU EL and tested lub to 3,500psi-test ok. RIH w/4" GR/JB and tagged solid at 9,138'elm. Worked tool down to 9,146' elm and could not make anymore hole. RU CT Pump and started pump and well pressured up to 8,500psi. Tried surging well with no luck. POOH and RD EL. MIRU SL, made 6 bailer runs and made 8' (9,146-9,152'). 07/26/2014-Saturday Held JSA with Halliburton SL Operations. Made 2 2-1/2" bailer runs and tagged 9,105'slm. No sand recovered. RDMO SL, Waited on crane operator. RU CT riser and injector head, performed body test 250-4500psi-test ok. RIH w 2-7/8" reverse jet nozzel, stopped every 2,000' and circulated at 2bpm. Tag fill at 9,068'. Wash down to 9,150'. Short trip to 9,066'while washing. Continue to wash down 200' at a time. Short trip after each 200'gain. Ultimately wash to 9,366'-CT measurement. Tag top of cement. Pick up off bottom and circulate bottoms up at 2.5 bpm. Not seeing much sand after bottoms up. Increase rate to 3 bpm. Although it was strung out we were getting a good bit of sand after bottoms up at 3 bpm. Fluid pretty clean. Start POOH @ 60 ft/min. Pump 10 bbls sweep every 2,000' while POOH. With CT at 500' shut down pump. POOH and rack Injector head/riser. Rig up slickline. RIH w/4.00" OD gauge ring and junk basket. RIH and tag bottom at 9,450' slickline depth. POOH and rig down slickline. Rig up e-line. Pressure test lubricator to 3,500 psi. 07/27/2014-Sunday • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date KBU 32-08 50-133-20624-00-00 214-014 7/18/14 8/4/14 Daily Operations: Held JSA. MIRU EL,Test lub to 3,500psi-test ok. RIH w/ 3.97" CBP and GR/CCL to 9,320'. Correlated back up to 9,150'. With tools on depth we set plug at 9,270'. POOH. PU 2-7/8" x 10' 6spf perf gun and RIH. Tag CBP lightly at 9,270'. Correlated up to 9,100'. With tools on depth fire guns and perf 9,202-9,212'. POOH. RD EL and secured well for frac. RU Frac iron and prep to frac,Tested to 9,500psi -test ok. With CT pump pressured up on backside to 1,500psi and held. Frac stage 9,Job log: 18:20-Pressure test to 9,465 psi. Good test. 18:30-Backside pressured up to 1,465 psi. 18:35-Open the well with 272 psi at the wellhead. 18:39-Start pumping; breakdown at 3,800 psi and 3.5 bpm. 18:49-Wellbore displaced, shut down to allow wellbore water to leak off. 19:29-Pump minifrac; ISIP=3,117 psi. 20:40-Begin pumping frac treatment. 21:04-Shut down frac and perform forced closure by flowing. Job highlights: Maximum treating pressure: 3,583 psi. Maximum treating rate: 26.2 bpm. Average treating pressure: 4,301 psi. Maximum treating rate: 25.5 bpm. Proppant placed: 54,000 lb curable resin- coated sand. Load to recover: 662 bbl. Well was flowed back/bled to 0 at 1 bpm for forced closure. Well pressure 0. Shut in well. Rig up slickline. Well pressure built to 700 psi. RIH w/4.00"gauge ring and junk basket. Tagged at 8,805' slickline depth. POOH. Rig down slickline. Open well. Pressure built to 700 psi. Bleed well off very slowly to O. Well pressure 0. Shut well in. Allow to build. Well pressure at 650 psi. Bleed to zero slowly. Shut well in. Rig up CT. 07/28/2014- Monday Held JSA with Halliburton. MU 2-7/8" reverse jet nozzle, RU CT riser and injector head, Body test 250-4500psi -Test ok. RIH w/CT, started pump .25bpm at 2,000'. Broke circulation to flowback tank and continued RIH. Tag fill at 8,871'ctm, Increased rate to 3bpm. Washed down to 9,137'. PU and pumped a 10 bbl sweep, circulated sweep around with heavy sand returns. Pumped sweep and waited for sweep to exit the coil. Started POOH pumping 2bpm. After the sweep hit surface, the returns were clean. Bumped up and SI well. Stood back CT riser and injector head. MIRU EL, Tested lub to 3,500psi-test ok. TIH w/4.00" GR/JB and tag at 9,199'. POOH. Rig up plug. RIH. Send correlation log to town for evaluation. Set plug at 9,100'. POOH. OOH. Rig up perf gun. RIH. Perforate at 8,848-8,858'. Perfs were correlated to previous log run to set plug. POOH. OOH. All shots fired. Rig down e-line, wait on frac crew. Frac crew rig up/prepare for frac job. 07/29/2014-Tuesday RU for mini-frac/frac. Hold pre-job tool box talk. Discuss emergency procedures and muster area. Discuss job assignments and job. Pump 164 bbls linear 20 PPG gel at 25 bpm. ISIP 2,320 psi. Watch for 45 minutes. Pump 23 bbls at 25 bpm. ISSIP 2,185 psi. Wait for 45 minutes. Calculate leak-off. Pump zone 3 frac job. Flow back well at 1 bpm for forced clossure. Well flowed back 35-40 bbls. and died in approx 45 minutes. Call out Eline to tag fill. RU Eline. NU lubricator. PT lubricator- 500/3,500 psi. Test good. RIH w/4" GR and junk basket. Tag up at 7,894'. Test tag two more times. POOH. Recover severely over-crosslinked gel and sand. Call out coil. RD Eline. RU coil. ND E12 connection. PU injector. MU lubricator. 07/30/2014-Wednesday • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date KBU 32-08 50-133-20624-00-00 214-014 7/18/14 8/4/14 Daily Operations: RU Halliburton Eline. PT lubricator 500/3,500 psi. Test good. RIH(1) w/4" GR and junk basket to 8,858'. All clear to set plug. Pull 500' correlation pass. POOH. RIH(2) w/5" Halliburton Fastdrill BP. Correlate to Schlumberger log and R/A tags. Set plug at 8,772'. Good indication that plug set. POOH. Arm guns. RIH(3)w/ 10' of 3-3/8"guns. Correlate to above logs. Perforate 8,514-8,524' 6 SPF. POOH. RD Eline. Prepare to frac Beluga LB5A. PTest pumps and lines 1,000/9,550 psi. Test good. Pressure annulus to 1,550 psi. Load casing w/20 ppg gel. Pumping 150 bbls at 25 bpm. !SIP 2,893 psi. Pump 24 bbl mini-frac at 20 bpm. Start frac. Samples indicate no cross-link. Shut down. Pump zone LB5A frac as planned at 20 bpm. Begin forced closure at end of frac, flowing 1 bpm to flowback tank. RU Pollard slickline w/4.00" OD gauge ring to tag fill. Tag at 8,511'. Deep enough to procedure. RD Pollard. RU Coil to perform weekly BOP Test. 07/31/2014-Thursday Tested CT BOPE. Performed drawdown test. Tested rams, blinds and body to 250-4,500psi and charted for 5mins-Test good. Witness waived by AOGCC rep Mr.Jim Regg. RU Halliburton Eline. PTest lubricator. Leaking. Replace ring gasket. Re- test lubricator 500/3,500 psi. Test good, RIH(1) w/4" GR/junk basket. Set down at 8,372'. Make three attempts to get deeper. POOH. OOH. Sand grains in junk basket. MU 5" FasDrill BP. ARM. RIH(2) w/5" FasDrill. Tools stall out at 3,350'. Make several attempts to get deeper. POOH. OOH. BP has gel slime and sand grains clinging to it. RIH(3) w/4" GR/junk basket. Tool passes 3,350'. Fell to 8,373'. Tag hard. POOH. OOH. Recover sand and gel in junk basket. RIH w/plug. Hung up at+/- 3,300'. Made several attempts to pass through but unsuccessful. POOH. E-line OOH and rigged down. JSA for rigging up and running coil tubing. Rig up and pressure test CT injector/BOP. RIH w/CT. Stop RIH at 3,100'. Bring pumps on line at 3 bpm. Wash down to 4,000'. Pumped sweep, after sweep exited coil back reamed to 3,000' and washed back to 4,000'. Never saw anything in returns or the sweep. After pumping bottoms up and recovering the sweep RIH. Looked like we lost a little weight as we passed through 4,000'. Pump sweep. RIH to 4,500'. Back ream to 3,500'. RIH to 5,000'. Wait on bottoms up. Again, Nothing in the returns. RIH to tag bottom. Nothing definitive until we sat down hard at 8,400'. The weight came back almost immediately. Picked up to 8,300'. Pumping at 3 bpm 4,360 psi. Pumped sweep circulate until hole clean. Sweep back at surface at 0415 hrs. Quite a bit of sand in sweep. Circulate until clean. Returns pretty clean. Still a trace of sand. POOH while still pumping at 3 bpm. Send sweep at 6,000'. Stop at 5,000' and allow sweep to exit coil. Chase sweep out of the hole while pumping at 3 bpm. Wash and back ream from 3,000-4,000'-3,000'. Pull up to 500'. Shut down pump. Continue POOH and rig down. CT rig down at 0700 hrs. 08/01/2014- Friday Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date KBU 32-08 50-133-20624-00-00 214-014 7/18/14 8/4/14 Daily Operations: Wait for Halliburton Eline crew. (Houred out last night.) Move Eline truck back out of the way. Lay herculite liner for fluid tanks. Spot two R for R tanks for cleanout fluid and 30 ppg gel sweep. RU Eline. Carry lubricator to WH. PT lubricator 500/3,500 psi. Test good. RIH(1) w/4" GR/junk basket. Engineer decides to run FasDrill BP instead of junk basket. POOH. PU 5" Halliburton FasDrill BP. RIH (2) w/5" FasDrill BP. Slide thru 3,200-3,400' zone to 8,452'. Run correlation pass up to 7,980'. Correlate to R/A marker at 8,032'. Run back in hole to 8,450'. CCL to mid pkr element is 24.5'. PUH to CCL depth of 8,385.7'. Set FasDrill BP@ 8,410'. Lost 400#. Rocked unit when charge fired. POOH. OOH. LD firing head. PU 10' of 3-3/8" perf guns loaded 6 SPF. Carry lubricator to WH. RIH(3) to 8,400'. Pull correlation past to 7,980'. Correlate to R/A marker at 8,032'. PUH. Perforate LB4A zone at 8,290'-8,300'. POOH. OOH. RD Halliburton Eline unit and BOP's. JSA for frac job. Pump mini frac. ISIP 2,204. Evaluate data. Bring pumps on line at 25 bpm for main frac. Lost prime on the pumps. Shut down. Re-prime pumps. Bring pumps back on line at 2215 hrs. Pump frac job. Flush lines. Shut down pumps. Isolate pumps. Open well to flow well back at 1 bpm. Well dead. Zero pressure. Shut in well. JSA for CT. Rig up CT w/4"J Z bit and motor. Pressure test Surface equipment to 4,500 psi. RIH w/CT. Tag up at 7,300' CT depth. Wash 200' at 2.65 bpm. Pump sweep. Back ream 200'. RIH and wash 200'. Back ream 200'. RIH and wash to plug. Tag plug at 8,310' CT depth. Pump 10bbls sweep. Pick up off plug. Circulate bottoms up. Recovered a large volume of sand overall. 0800 hrs: RIH. Tag plug. Begin milling with 1,000 lbs down at 2.65 bpm. Drilled up plug in 21 minutes. RIH. Tagged up at 7,380'. 08/02/2014-Saturday Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date KBU 32-08 50-133-20624-00-00 214-014 7/18/14 8/4/14 Daily Operations: 0800 hrs: RIH. Tag plug. Begin milling with 1,000 lbs down at 2.65 bpm. Drilled up plug in 21 minutes. RIH. Tagged up at 7,380'. 08:45 Milling at 8,389'. 2.6 BPM CTP 4,966 psi. 08:50 8,390' Stall motor very hard sand. 09:05 8,390.2' Milling 2.6 BPM CTP 5,100 very hard. PUH wt check 34.5 K. 09:35 8,484' Milling 2.6 BPM ctp 3,880 psi. v , 5 09:40 PUH 50' wt check 34.5 clean. N` t'L 09:45 8,435' Milling back down. Spud hard spot a couple times. 09:55 8,647' Milling RIH. 10:05 8,755' 2.5 BPM Milled thru plug#2. 10:40 8,990'. Milling just above plug#3. 10:42 Tag plug#3. 10:50 Break thru plug. 11:10 9,086' Milling 2.5 BPM CTP 4,000 psi. Sweep at surface. Heavy sand. 11:40 9,158' Milling on 4th plug 2.6 BPM WHP 149 CTP 5,017. 11:55 9,160' Break thru 4th plug. RIH. 12:05 Tag hard cement of PBTD at 9,351'ctm. (Prior tag on first coil run was 9,366' ctm. Mill had traces of cement on this first tag. ) Launch sweep and continue pumping bottoms up to clean out well. 12:35 Have pumped 93 bbls of bottoms up. 12:55 Pumped 200 bbls. POOH. OOH. LD motor and 4.0"JZ bit. MU jetting nozzle. Cooling down N2 pump. Displace KCL out of coil. Recover coil volume-43 bbls'. RIH. TIME DEPTH N2 WHP CTP 16:35 850' 1,000 493 1,079 17:10 3,000' 1,000 690 1,365 17:15 3,650' 1,000 515 1,331 17:45 6,000' 1,000 431 1,587 Parked Good returns 17:50 6,000' 1,000 491 1,540 RIH to 9000' 18:45 9,000' 1,000 331 1,723 Parked Good returns 19:00 9,000' 1,000 POOH. Pump 1,431 bbls of KCL. Pumped 201,000 scf N2. Recovered approx 230 bbls. 08/03/2014-Sunday Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date KBU 32-08 50-133-20624-00-00 214-014 7/18/14 8/4/14 Daily Operations: Frac crew RD 3" frac lines/backside iron and missle. SITP 1,600 psi. RU to flow well to flare stack. Flow well. Well blows down to near 300 psi. Cool down N2 pump. RIH with jetting nozzle pumping N2 min rate to 6,000'. Increase N2 rate to 1,000 scf/min. Park at 6,000'. WHP 91 psi CTP 1,180 psi. 1105 Returns to surface. Returns increasing to 1 BPM. 1145 6,000' Parked. Returns dry up. Recovered 31 bbls. RIH to 9,250'. 1200 7,500' RIH returns approx 1/2 BPM. 1220 9,250' Parked WHP 381 CTP 1,539. 1240 9,250' Parked returns increase to 1-2 BPM. Parked at 9,250'. Returns 3/4 to 1 BPM. Recovered 82 bbls. Open both sides of choke. 1305 WHP 467 psi CTP 1,263 psi. Returns about 1 BPM. 1350 WHP 290 psi CTP 1,073 psi. Returns about 1 BPM. 1400 9,250' Parked. Recovered 95 bbls of fluid. Returns mostly N2. Less that 1/4 BPM. Pumped 200,000 scf N2. 1415 Receive orders to POOH. Pulling out of hole. Coil at 500'. Cut N2, Continue POOH. 1540 OOH. Continue bleeding down N2. Pull coil up into the lubricator at close swab. Pumped 292,000 N2. Recovered 124 bbls of fluid. Well flowing less than 50 psi. Meter detects LEL. Close well in. 1530 SITP 200 psi. Input reports. Change out. 08/04/2014- Monday SITP 2,200 psi. Flow well to flare stack. Blow down well. Shut in well with less than 200 psi. Open well. RIH with coil and jetting nozzle. Begin cooling down N2 unit. 1030 start N2 at 500 scf/min. 1117 At 5,000' CTP 474 psi WHP 79 psi. 1122 Increase N2 to 1,000 scf CTP 610 psi WHP 76 psi. 1133 Fluid returns to surface. 1152 RIH to 9,300'. Continue RIH. Tag fill @ 9,281' CTP . 1322 psi WHP 227 psi. 1339 Parked 9,277' Recovered 44 bbls of fluid Pumped 156,000 scf N2. 1350 Parked 9,277' Recovered 55 bbls. returns .4 BPM. 14:20 Parked 9,277' Recovered 60 bbls. PUH to 8,000'. Continue to gas lift well pumping 1000 scf/min N2 CTP 1,108 psi WHP 291 psi. Pumped 266,000 scf N2. 1515 Recovered 67 bbls. Returns .3 BPM. 1542 Recovered 72 bbls. Returns .2 BPM. 1620 Recovered 76 bbls. CTP 1,229 psi WHP 322 psi Running low on N2. 1640 RIH to 9,280' Pumping N2 @ 1000 scf/min. 1645 Returns dry. Fine spray and a few drops. Recovered no measureable fluid in 25 minutes. 1620 POOH with coil while pumping N2 @ 1,000 scf/min. OOH. Pumped 452,792 scf N2. Recovered 76 bbls fluid. RD coil. 08/05/2014-Tuesday • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date KBU 32-08 50-133-20624-00-00 214-014 7/18/14 8/4/14 Daily Operations: Flowing well to sales. 300 to 700 mscf/d. Call out coil crew. Continue flowing well to sales. Hold PJSM. Start equipment. Drop 4 soap sticks down "goat head". Change coil stripper pack off. RIH to 8,000'. Continue flowing well to sales. Continue flowing well to sales. Start pumping N2 at min rate for 3 min, then shut down for 10 min. Continue flowing well to sales. Productions monitoring gas and water rates.Vessel full. Dumped at 2000 hrs. Calculated 6 bph returns. Still 6 bph returns. Shut down N2. RIH 60 ft/min pumping N@ at 1,000 scf/min. Tag bottom w/running speed of 10 ft/min at 9,290'. Pick up to 9,250'. Wait for N2 to exit coil + 30 min. POOH at 80 ft/min. pumping N2 at 600 scf/min. 1,525 ct psi/560 psi wellhead psi. Increased rate to 700 scf/min with no discernible diff. Reduce rate to 600 scf/min and continued to POOH at 80 ft/min. CT in lubricator. 95,000 scf total pumped. Close swab valve on tree. Open flow to sand separator and flowback tank. Received an initial return of N2 and then gas. Called production to sniff. Positive for gas. Turn well over to production. Flow well to production. 08/06/2014-Wednesday Drop 4 soap sticks down frac head. Vac out hoses and RD fluid hoses. ND coil BOP's. ND "goat head". Break out 2" surface test iron. Move out gas buster, sweep tank, and flow back tank. Move out coil equipment. Kenai Gas Field Well: KBU 32-08 sli SCHEMATIC Last Completed: 8/01/2014 liilcorp Alaska,LLC PTD: 214-014 CASING DETAIL RKB:MSL=22' Size Type Wt/Grade/Conn ID Top Btm 16" Conductor N/A _ Surf 135' 10 3/4" Surface 45.5/L-80/BTC 9.950 Surf 1,478' 7 5/8" Intermediate 29.7/L-80/BTC 6.875 Surf 6,406' 16" 5" Production 18/L-80/DWC/C-HT 4.276 5,849' 9,746' TUBING DETAIL 5" Tubing 18/L-80/DWC/C-HT 4.276 Surf 5,849' ) ' JEWELRY DETAIL 10-3/4" ' No Depth Item 1 5,849' 5"Swell Packer 2 7,330' 5'Pup 3 8,028' 5'Pup 4 9,475' CIBP OPEN HOLE/CEMENT DETAIL 10-3/4" 160BBL's of cement in 13.5"Hole.Returns to Surface 7-5/8" 261BBL's of cement in 9-7/8"Hole.Returns to Surface 5" 114BBL's of cement in 6-3/4"Hole. TOC 4,600 Calculated 4 PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) (N�) FT Date Status LB4A 8,290' 8,300' 6,900' 6,910' 10' 08/01/14 Open LB5A 8,514' 8,524' 7,100' 7,110' 10' 07/30/14 Open Tyonek 73-1 8,848' 8,858' 7,362' 7,370' 10' 07/28/14 Open I* Tyonek 75-8.' 9,202' 9,212' 7,647' 7,655' 10' 07/27/14 Open Tyonek 76-7 9,343' 9,366' 7,762' 7,781' 23' 06/19/14 Open s, Tyonek 78-2 9,500' 9,510' 7,891' 7,899' 10' 06/07/14 Isolated O 1 7-5/8" b 2 33 LB4A _.LB5A Tyonek 73-1 Tyonek 758 TOC @ 9,448` =Tyonek 767 ,-. .i 4 T Tycnek 78-2 ti e 5 1 • TD=9,746'(MD)/8,098'(1VD) PBTD=9,351'(MD)/7,768'(TVD) Updated by DMA 08-20-14 u) C a) E o E 0 V', o .0 m 0 ii VT 0 0 )( N Q C V• 0 0 N V N I-el N- 00 CO CO (00 0) (N (0 V 0 N 0) 0) CO CO O a) C • U0) CO 0) NN N (0 D M O 0 CO O o 0 O O O 0 C) •Q -05 @o V O O O O O O o O O E(ti -0 --0) 0 - EQ)j = UL _ c = a 0 0 0 0 0 0 0 0 0 0 O V O O o 0 0 0 0 0 0 0 0 0 0 0 * 0 0 0 0 0 0 0 0 0 0 0 0 Q I C o 0 0 0 0 00 00 00 O LIS o 0 0 0 0 0 0 0 0 0 0 0 (� 'u 1-� X E a) j ad ad o o ui N o0 0 0 o o tri � C.) 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F-J W co F--C p Z C C Q o_O I cn Interval Summary Kenai Beluga Unit 32-08 Tyonek 76-7-Interval 1 Interval Summary Date: 7/21/2014 Start Time: 7:52:00 AM End Time: 10:38:00 AM Initial Rate(Breakdown): 3.1 bpm Initial Pressure(Breakdown): 3701 psi Max Rate: 32.3 bpm Max Pressure: 4760 psi Max Pressure(SLF): 4522 psi Average Rate: 30.4 bpm Average Pressure: 4137 psi Average Missile Pressure 4174 psi Average Missile HHP: 3110 hhp Average Visc: 14 cP Average Temp: 74 F Average pH: 8.3 ISIP: 3311 psi Initial Fracture Gradient: 0.876 psi/(i 5 min: 3123 psi 10 min: 3049 psi 15 min: 2990 psi ISDP: 3375 psi Final Fracture Gradient: 0.884 psi/ft 5 min: 2958 psi 10 min: 2956 psi 15 min: 2586 psi Proppant Summary 20/40 CRC LT Pumped 64,500 lbs Calculated Proppant Pumped* : 64,500 lbs Proppant in Formation: 64,500 lbs Fluid Summary(by fluid description) 20#Delta 140 Volume 17,931 gal 427 bbls 20#Waterfrac G Volume 15,755 gal 375 bbls Fluid Summary(by stage description) Pad Volume: 3,320 gal 79 bbls Spacer Volume: 9,765 gal 233 bbls Proppant Laden Fluid Volume: 14,139 gal 337 bbls Flush Volume: 6,462 gal 154 bbls Treatment Volume: 33,686 gal 802 bbls Total Fluid Volume: 33,686 gal 802 bbls Interval Status: Completed Comments: Had to come offline due to ADP not working correctly. Resumed pumping on the main Engineer: Johann Baltrusch frac. Sand concentration was reading low throughout the zone. Went over on volume to Treater: James Moore get the correct amount of proppant in. Will adjust sand calibration numbers before next Supervisor: frac. Flushed well to per customer. Marcos Adan `Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes. Customer Rep: Wade Hudgens Hilcorp - Kenai Beluga Unit 32-08 Interval Summary 4 „I m 'u 1 n ry n ry 0 ,9 ... :.9._. ,,, . , o m m n o c o 0 0 0 0 0 3.';'' b 8 8 8 8 8 8 8 8 8 8 8 8 ° m Ag 5 ” pO 0 2 ,, c88 0 o m 8 4 A 4 0 8888888888 3 a 66 0 0 o ry n n n n n n n 3 ` .7.;- $ `o F8 8 8 0 8 8 0 8 8 8 8 8 8 8 m o m e w m o k',.' eV n N ry n n n N m �+ E0 a 8 8 8 8 8 8 8 8 = o e. m e H w v s e o 0 o . o t00 0 0008000000 .c a0m °+ e ^ , 0 0 o o E n E 5 m o a I i _ o 0 o g g 8 > > , ov (4 a, = '.°, ' 0 n m v; oe :° n B E 8 E 8 w To > 2 2 > > > .� w m n - o22o ,, nNS 0 8 8 8 8 8 0 8 o Q22Tg Q °,° c n .� o,o ., n ., ,$ I ov ~ a d 2 i 0, 8 e aZ5 Ti. o` ,°', m 0 *4 r r r2 w ti m ^ if y > t & a .0 0 x 9 e r >° r. C a a 0 0.0o m Ln m C - C m M 0 O T Oi m O — ° ,8w ,° m8 & o O V to c 3 o E EBB o50 = � A a „° f f d O O p p O p p -rt!: i Y 111 n a V E_ O O O 0 0 0 0 0 0 0 0 0 V m Y 0 0.. v , O m 0 ^ 0 0 0 O O m F O~ G ^ ^ ,c � c .c n E � 8 ry n o o, 0 f er - 8 S3` a m N o $o ry - c'a m ., n m m mo m n n M m n v 0 0 n ,o c c u a; 2 o o ^ Ic *2rii& O o ry m v ,n 2 ,n a O c G a ^ vn� ''..'69. 8 ^ AlLgi F \W _ I; N w OW tttttttt ¢ K 5 C O DDO V V U VCC ¢ ¢U V U I.. .5. G O n n ry n ryry ry n O 0 0 m w v Eg 7_ 72 :27727272m ,E . i J O C O O :-..°'„ w w ` m v A _ a a a22 O �o a . _ N 1 m ni 8 o. nan c n'. E e 2 2 2 2 2 2 a - •'J zx � awdawwww C 0 0 0 0 0 0 _ m< .+ 0 ' R e a °m I om - 2 c � " I � Aon a 3 al 0 , , , — . . . . v , . . . 2$ $ ' F wM3 oN 0 3 LL mo f o88 2 $ 22 S , 8 1 :4 ,° n n n o — co ' • — i o. T. C °- _ - - C zv " N d c m > j J t — .2 8 d ' -8 0- t . U99£6-£Y6 7 a3 . a L_OO E G'9L„auoi wo $ 8 _ , ,11' 1.fualu1 w — z in O 00 O N U (N — — r- — —O CO CO d N 0 1 , I , I , I , I , I , I . I , I , I 0 030 O O O O 0 0 0 0 0 r- 0) CO r CO M N I- O 14 QU 0v (0 77 1 o l I W moi 0) To o p) O L 0 w a 2 a) N U (I) ID. -'-+ e 0 O aO N Cl- fin, O ,r (0 CoNva _ ,r, N a-+ N 1 L, co O V L -, M d %V OE N N Qmo ai a, Oto c 0 4) oD •C O N 0 M Co 9 O J o I N CO C To gj co a v Leo CL co , U a ai °-U -J 49 NC I Y 00 d to, ao mix aC N rn N 'a — Mme_ ...7. Y N a 2 t = r N L V n O , U , 6--,--6--- --6 U1 , 6 , a I CS Ib c5 O a n 0 0 0 0 0 0 0 0 0 0 m a0O00 MN co CO00 C N— a) Y 2- 0 O U 2 m U N 00 . d . 00 qO N O I , I , I , I I . I , I , I , I , I , I COO C 0 0 N 0 O " � M OON O Ov O.- 1 1 , 1 , 1 . 1 . 1 . 1 . 1 1 d.N 4ea1UCo) �N n In M —O el O IA m —O O O _ N ti o .-- a 472 (73a 0 H o ^ —.. 4_N en Om co) : � _ N 0 : 010Uv el� � a c �0 0 �„� t., -oma N E' t' a n M coz 0 0 0 0 0 0 0 0 0 0 o a, M < 00 0 0 0 0 0kr) � 0 0 0 C0 Y 2- o O u 2 Interval Summary Kenai Beluga Unit 32-08 Tyonek 75-8-Interval 2 Interval Summary Date: 7/27/2014 Start Time: 6:39:00 PM End Time: 9:03:00 PM Initial Rate(Breakdown): 3798.0 bpm Initial Pressure(Breakdown): 6.3 psi Max Rate: 26.2 bpm Max Pressure: 4301 psi Max Pressure(SLF): 4301 psi Average Rate: 25.5 bpm Average Pressure: 3583 psi Average Missile Pressure 3583 psi Average Missile HHP: 2239 hhp Average Visc: 15 cP Average Temp: 81 F Average pH: 8.4 ISIP: 2918 psi Initial Fracture Gradient: 0.832 psi/ft 5 min: 2575 psi 10 min: 2308 psi 15 min: 2076 psi Initial Perforations Open: 17 ISIP: 3117 psi Initial Fracture Gradient: 0.858 psi/ft 5 min: 2626 psi 10 min: 2413 psi 15 min: 2249 psi ISDP: 3238 psi Final Fracture Gradient: 0.874 psi/ft 5 min: 2978 psi 10 min: 2819 psi 15 min: 2658 psi Proppant Summary 20/40 CRC LT Pumped 54,000 lbs Calculated Proppant Pumped*: 54,000 lbs Proppant in Formation: 54,000 lbs Fluid Summary(by fluid description) 20#WaterFrac G Volume 14,589 gal 347 bbls 20#Delta Frac 140 Volume 12,666 gal 302 bbls Fluid Summary(by stage description) Acid Volume: 0 gal 0 bbls Pad Volume: 3,329 gal 79 bbls Spacer Volume: 0 gal 0 bbls Proppant Laden Fluid Volume: 9,337 gal 222 bbls Flush Volume: 6,704 gal 160 bbls Total Fluid Volume: 27,255 gal 649 bbls Interval Status: Completed Comments: Ran job at 25 bpm per customer. Extended pad to see good crosslink on surface. Engineer: Johann Baltrusch Sand ran out 50 sacks early;will charge off the slips. Treater: James Moore Supervisor: Marcos Adan *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes. Customer Rep: Wade Hudgens Hilcorp - Kenai Beluga Unit 32-08 Interval Summary 4 , M °1 vmi m m 9i 9i 9i u a n c no o c o 0 0 o d m 8 8 888888888 s � m � �or, ;1 ,1 rl ry o as 8 8 8 8 8 8 8 8 8 8 8 8O 8 o a? N 0 O m 0 0 0 0 N N N N o a b N n � of V in m v,m N ARI-i i 8 8 8 N 8 8 8 8 0 5 N 4 4 n ti E 8 8 p 8o 8o po pO m -1' Z -!A O O_8 8 8 8 O a9 X 8 .e4 1 < S ‹ CS p p COGC8pp8pp I h m ?-1 ,. i n 5 m aw t oa E> E s via § § m § 2 § ` 8 8 c 5 074 , 8 r3 i3 >pg o o 22%8 Yo be o • g14 0 i - a ✓ E ."a' '''jc r . nnNm . N oi ,a i r V O a m `a 3 a N i . L Q t o Ea n n NrvN ,, v'. `� `o° 325 . . 1 E d pe 8 N c c N C O I L h h0 2 8 m m Q 55�2 c 8'''o u E a• N m m ? m . N 10 n . 8 6 § o p - a a g3 m Q 1.0 o E 2 E ,Et. ER v f o 211 t i t a m m c e '^ 0 § o n m 3 E $ $ N1 2 .= n E v F Y y N a n > m `a � gi p - a0 a • N t3 -i K 1 m 2222222222222 n 1 nm n, cu n «- Nocarc - o 3 .+ mu6 A!''' n --= n E:.n i. a` a g o a s a > zr r 7'7'4 2 s $ r r r r r r r r .-,,-„-i, 5 3 u gg c l s E E E et g 8 ? ? ? ? - _ tt. Ae 2 a Qa R rr cL LL - n & E E_ E - 3 5 > > 3 5 z 5 t- W r ti `o_ w u w w w w u i _ -'40, 4= m -- U•C n L a 9 2 3 3 2 9 3 5 L N q _ r r ° 0 889 v '^ stn888 % 8888 3 a` ' a A 8888 N 0' o n ' o' o' o' 0 < E M `o'�o a a n d d a d n _ _ d Ft a c _ _ a C 9Sga3SgS3 � - ma =° D z aoe - - LL LLLLLL « - Am M 2 ,.r .° « A 2 A 2 2 3 3 9 « S � a D o _ i LL a 3" - 3 000000000 3'L" LL - N w mo n n $N 8 8 o ry ry $ 8 8 N o m LL G - - .i '::at :: _ C Z n '47m N s o " a 3E >> z r 8 1!9LZ6'90(6 @7 3 0 ` a N o Q E 2 95L 9auo,(y LL 88 u E w O " Z ien,ayui W c c U in O O0 CO d' N O U N <- CO CO V- N O 1 I _ 1 1 1 I I _ 1 I , I , I , I , 1 m 0 O O O O U) V- CO N O I I I , I , I Q 0 O I M2 CO I C)) c.,,.'--i_ N N to a� O I 1 CD ii _ O L L .- 6 N o II ` VJ +. 0 c -I Hca O a� Q O NIo o NI- co -d CV O N N i -8 N Y i N M O C) L 3 M CL N }' CO U) O -i _ CB E N c) a)2QmC I I- 0o °' c N O CD . CD CV O Ni U co •- O o C) CV < M __ O Y r- cn C Q D c6 J c6 Cn < rn Q = N U O m N^C _ 3 O O U CO Q OO J C coSC-) _ . .� — N CU c O N 2 Y op CL`.0.. �r O as Q C N Q I Q , CCs +-CL - C I-U)m • a) co (t3' 1 1 1 I I I I I 1 0o 0 D O O O O O O O O O O O - O O O O O O O O O O 7 0 m QO O O O O O O O O O V O CS ? - ) 0) I— CId) O V- CO') N C C Cu CZ L 8 U O co CO N C) U N CO CO Nr N C) I , I , I , I , I , I , I , I , I , I , I m 0 O C) C) CD LO M N N- O I , I , l t I , < U V V M M N N O V. N N N N N N Ch N V V V' CO CO co ' in O co O N CO CA r r co) N� N (V N !-C-:::, N 0 IC) V C C) I .-C-T) CO iMI I *k ----, i__ C) ,_ Hi N W Nm -I QO .— .— .- .— .- .— a C CO •- o _ • • 0. Cl) n. a Cl) a tN a) - O co gr) ao c'..3 a d N _J c0 in O (NO N rn O Ncn Q Y i _ 4-. N N N N N N N M O C) c 7 M � mcn ; IMI � IM MIS as N w V co M N N- N LC) la QOOU O ~ N N N N N N i E as CA O CA O CO COja N V' If) N M Ocei a"' cla N e- e- 1- e- N N .. N )ft-4 I Q a v co co to oo J co Q: O <n _0 Q a. a. Q CS) Q co M ft (L) U N-' ("Nin CNIC .-. N •- M M 0_ ch o w m U ca N'Q C..) lIL O N I I 0- I I Q- I I a- J C Nuc �� CL o O- CL CT) 2Y f1 Q Cr),CD r N N co CO Qc L d {N ---- 01 ISI I") L� O O O its N M M M M M 0- .1= - f�') L d=2 L v E Ft co co I I I I I"� o p cM 0 0 0 0 0 0 0 0 0 0 0 = O O O O O O O O O O a) - 0 0 0 0 0 0 0 0 0 0 U CO C) 0) CO N- CO 1C) CO N re C 4) Y Q L 0 U 2 N U O 00 .O N O N ---- .--I ---I 00 s.O N O I 1 , 1 , I 1 I 1 I 1 I , 1 I S I O (4 O O O O O O O O O O 00 l� ‘.O v) M N •--, Ov I I I I I Oo d; a1UU o� f ..,) M z \ [ ci., O M E .0 O N o a 15N a� cu in cu G N +a C O a) 0 , �c a) .00 4. o ^ �� N • Q„ C C 01cl c,0 O U a 0 ,—, = acU CA pi at i 0.., tt C4 p,,, o e =y � co Cl T., i.i M m 1 1 1 I 1 ' 1 I 1ca 0.0 O 0 0 0 0 0 0 O O 0 0 n O O O O O O O O O o 3 v O CO, 000 ON O� 'OV OM N —O CO .—I '(a C a) Q O U Interval Summary Kenai Beluga Unit 32-08 Tyonek 73-1-Interval 3 Interval Summary Date: 7/29/2014 Start Time: 8:34:00 AM End Time: 10:29:00 AM Initial Rate(Breakdown): 3.1 bpm Initial Pressure(Breakdown): 3459 psi Max Rate: 25.8 bpm Max Pressure: 4302 psi Max Pressure(SLF): 3576 psi Average Rate: 24.5 bpm Average Pressure: 2772 psi Average Missile Pressure 2686 psi Average Missile HHP: 1613 hhp Average Visc: 12 cP Average Temp: 77 F Average pH: 8.5 Displacement ISIP: 2320 psi Initial Fracture Gradient: 0.765 psi/ft 5 min: 1307 psi 10 min: 865 psi 15 min: 628 psi Minifrac ISIP: 2235 psi Initial Fracture Gradient: 0.754 psi/ft 5 min: 1287 psi 10 min: 912 psi 15 min: 722 psi Final ISDP: 2595 psi Final Fracture Gradient: 0.802 psi/ft 5 min: 2188 psi 10 min: 1790 psi 15 min: 1605 psi Proppant Summary 20/40 CRC LT Pumped 114,000 lbs Calculated Proppant Pumped' : 114,000 lbs Proppant in Formation: 114,000 lbs Fluid Summary(by fluid description) 20#WaterFrac G Volume 13,594 gal 324 bbls 20#Delta Frac 140 Volume 17,614 gal 419 bbls Fluid Summary(by stage description) Displacement Volume: 6,497 gal 155 bbls Mini Frac Volume: 1,003 gal 24 bbls Pad Volume: 3,251 gal 77 bbls Proppant Laden Fluid Volume: 14,363 gal 342 bbls Flush Volume: 6,094 gal 145 bbls Treatment Volume: 31,208 gal 743 bbls Total Fluid Volume: 31,208 gal 743 bbls Interval Status: Completed Comments: 1st sand stage was 1-7 ppg ramp(avg 4 ppg)then stepped up from 4-7 ppg.Upped gel Engineer: Drew Mocgk concentration in later stages to increase viscosity per customer.Job pumped to Treater: Robert Rosario completion with no major issues. Supervisor: Larry Roberts 'Val,es for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes. Customer Rep: Jeremy Mardambek Hilcorp - Kenai Beluga Unit 32-08 Interval Summary 6 Ln � E, � � � 1 " '" ' ., III , -42- - _ ,..--. 88 $ .4 _1 $ 8 $ .4 a .o d qQ .. .. 1.14 ":1 % oiry ry % IQ 0 e o 882! 8288 3 N 6 NnNNr `,41ry 3c .m° .°1c 'n H.ai q g g g o N o 113 ,6 0 N �, 1111 ` am m i 0 0 0 0 $ t a m m 0 0 '^ e 32 Q .= N N N N a a el N 1 .O Op 8t E 8 AO L O S 8 0 0 `.!1 :1 :8 O 8 0 i',---a4 ry m O 2'52eim O a o - E > E E ° a €2 % ry N 0 > _ o d o ., m= r m m m _ - J u al -O o2, .N. ry m n ,y m d E E E E p _ _ _m o a 0 0 i ° ry o 0 8 - 1p m� 2 J m a-- 7.° 7%, RAW n g e- .XIV..N .c Z o a > o Z E F ry n n m m o St ro u _ 2 > o a m t T. 8 n a oN a o hA vl0 d a m ''9 '' 0 o t DcE na ryoe o �Uu o $ m mQ ~ O Fm Q7. 2sn e .N ,,, o ._ > c niN .+ N a O a m u o E IT o > Eo 0 0 0 'E 2 2 E c \Ua w E .c2- - _ ,..- m g Y , , , t 7, ,o ,,,,, -r m A 0 N Al t3 0 N ° a n E m \ n m 0n r, N N N N annryn n . 1oNaFcu a . '= 000 ,w 2 `o a 8 8 8 8 8 o 'e n u g o n 2 W F a t o. E as vai o • r Val a _ >° ,r r r - m e 0 n.� u u u u u 01 0- - E, -"'a o 0 0 0 0 0 7, u u -LI y o E a EE ° . LL - a c - 2 N CO a p W18 ; , 2192. 2 t - 2 ,,i. ,: -1, g2 CO t . N tHgn a o o E }' c s u F a a a a a a a a a g _ ° u e E e e R F. ? o ... v Y .moi z n 't c c .. E _ m ^' .n uo u LL LL u LL . O '° « « 'o m m m m m « G m m �G Qu a Er " 0 3 '^ '" 0 0 0 0 0 0 3 '" LL m uai 0 $ `1 N N ry ry ry ry a J — C Em E . N CO a n .a n CO m " V. tLL� g r -' o "VI 'ivSe - xm - ET, ussaa-vm0 i•EL Wok!. LL o E W _ £lee+alul W U F c s rn U N N .O tn O I 1 1 1 1 I 1 1 1 1 I 1 1 1 1 1 1 1 1 I I 1 1 1 1 C) OM N - O 0= < U U �'?N r-I N e-n 01 N N r� In vas; 0 ..-10,I '-i rn I r, - •o ,^11 O as S-.-9. Q AgiA III � O a) ,-, t H 1111 ' i 0 R j it N QJ ra C M Q — 0 ti O N O M 1- O i N M go O O Z co a s aa) O m rt ~ �`t cK v O , �! oE uy N C CCO _ IO O O� CCo 0 0 0 C 0 U 3ro V� 7r M N , Y Cl O U 0 r) O kr) 0 U N '--., ^.1 O 1 1 1 1 1 1 1 1 I_I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 02 O OC O O O 0 1 I 1 I 1 I 1 I 1 l 0', 0 Q U _MN N M M O O h In M M OQ c d; Ync.1N M 00 00 CT O\ O O ^' O O O O --- Ch — N N •L um 00 '� " .-. .--1 N r .. r II II 7 5 ° =a � � 6 ? ._-- 0 0 O o O ¢J7,1 o i) oM w 0 0 w vi cu a � aC 0W y U .. • 2 2 2 t. In a - P. in 4, rn P. N .8 ,-.Q" 0 0. P� P.. 5 ON N F., ,4 .0 ah O 0 F�-1 V1 I�-1 C/) 1�-1 c4 .:. M 0_ A M 00 :11!! C_ H 4.1W i a)Vl .+ - yi M O - N M n � - -cl , , ,..,SE.. 0 _. 0 ri. C .. ti Cr) 0 t O N N N 00 O 0 _. .. M N '-' N .-. 1 U 0,0 O o 43 N II r N II a 0 N '" a� a� N N ,- s 5 a -) gggggg 0 0 w is 0 is 0 0 N --F - -O y i FA ti 0 (a) m a`1) a`1) a a))ra a) a) a) V.w- 0 o a a a a" a w a a, ----------- --- w amico] - i; = 4 .4 -0 4 4 N A, P. / Cq r/ n CA /] O m hi .N tin 1-1 rr �' I 00 N H C/1 I 0 i 0 ^-. v I 1 ' I ' ' CO Q o 0 0 0 0 O U 3co c t) M N N I? i O U Interval Summary Kenai Beluga Unit 32-08 LB5A -Interval 4 Interval Summary Date: 7/30/2014 Start Time: 9:07:00 PM End Time: 11:46:00 PM Initial Rate(Breakdown): 3.0 bpm Initial Pressure(Breakdown): 3256 psi Max Rate: 28.0 bpm Max Pressure: 5478 psi Max Pressure(SLF): 4497 psi Average Rate: 21.0 bpm Average Pressure: 3508 psi Average Missile Pressure 3526 psi Average Missile HHP: 1815 hhp Average Visc: 13 cP Average Temp: 78 F Average pH: 8.4 ISIP: 2893 psi Initial Fracture Gradient: 0.857 psi/ft 5 min: 2558 psi 10 min: 2249 psi 15 min: 1998 psi ISIP: 3016 psi Initial Fracture Gradient: 0.874 psi/ft 5 min: 2640 psi 10 min: 2421 psi 15 min: 2231 psi ISDP: 3187 psi Final Fracture Gradient: 0.898 psi/ft 5 min: 2775 psi 10 min: 2648 psi 15 min: 2515 psi Proppant Summary 20/40 CRC LT Pumped 102,000 lbs Calculated Proppant Pumped* : 102,000 lbs Proppant in Formation: 102,000 lbs Fluid Summary(by fluid description) 20#WaterFrac G Volume 6,995 gal 167 bbls 20#Delta Frac 140 Volume 17,342 gal 413 bbls 6%KCI Water Volume 6,068 gal 144 bbls Fluid Summary(by stage description) Displacement Volume: 5,921 gal 141 bbls Mini Frac Volume: 1,074 gal 26 bbls Pad Volume: 5,091 gal 121 bbls Proppant Laden Fluid Volume: 12,251 gal 292 bbls Flush Volume: 6,068 gal 144 bbls Treatment Volume: 30,405 gal 724 bbls Total Fluid Volume: 30,405 gal 724 bbls Interval Status: Completed Hilcorp - Kenai Beluga Unit 32-08 Interval Summary 6 Ln � � � � mo m Q ° m :8 8 888888 LLaNe ' '' p O O `° ' 880888 m m '' ,,,so I 00 ' '' 3 a o n AXXXXX 3 ' a .. m, ''' ' '''" a „ a 88 ,. 8 $ 88 ,%' g-°-* N um „ m Ill v >5 x o , r H a v N a a' v,a' v a Q e III 0 o Mg t a'o 8 8008 .'00 . ° ^ cm Y`1” r r a ry N s " "s c ° §Fo ,WRm jtn §o o 5i - c 2 n M n m EEE wEA 0 - ? `o u « ° o 7 0 0 m m o 0 0 2 .137.1 -“ 10 s e J ,^ 8 m 01 10.1 O Y, J kg= b F N M -, v. , Z o° " a Z i8 O 2 a N ti V ti N U' n 3. 1 > O a a, t E . ;§ n n y u j F \4 = N � � M o m ^ D o E = . c > c m a a o - O ~ •- m m ~ al ,.`..`. 5 N m m1 El 87' _ o ae m a o o 5 m a gg a m '^ o u $ N o vNmi o $' 8n �1 N o a !; N. . . . . ti, OF. U a v O � `o 8 Ar. M 2 E 2 S o S c. a ac -42 uFt . tt n m � VEm � O OAo ,O � dPa , . E~ i ,',Le-_ m p r 2 aF O ° y mry o c una Z p° W- n« N N n N N N N a0 � mN tit Sia .'EA . . . . ]! ! um y C N n El n o c E au'a 88888 o n c p a u v 2 N co i a a j N QQQ 1 • • a a > . F , F t- 5 ii A o a c 4 u u u u u - n - n u u u u u _ _ - - m a o RM.-1 _ � I 2 a 0 22222 Sg - a ri n « « a E E E_ v m m -,,, ,, ,, m ,, F W_ _ . F o 00 0` an o ° ` vwww _ m gE0 r n c = Q39333 ,201 ;77, ' ' ' ' tA CV E ,Noo nn ao aa` — cm aaa 0 0o « T.,- cam aa .0-e AAAA T.� xt GQ LL Q ?� H H o o o "' LL = m u I coM i s�r w a ¢ KE m M = _ u a " � Y 6 y - i ,, ',÷,, ',÷E - 14 MSS-bISS� = �+ o 7 E W , O' O VSel W o c b lenla�u� LI '^ U rn V N ON �--i O— V7 O I , , , I , i i i I I . , 1 , I I al F 1- m N O O 1 , I 1 U v O^' 0 M N gM \O c3 5 ti) - N ) N .T.,2 h U 8 F ' u ��c).. "(:''''' N ii O N Qr - o A alU O IN G1 MMN yO_ Cv Cl o a 40 ao a N N VIV) Q Q 4 NM I ._ LI. cd W U � � .� O •- � N v .0 c ','i'i n°3 ro E^ NM o D O O O O O O 1 C C O r dj m C pp O O O p O – co 00-- 8 S O OO �O m O O c Y Q L 0 U O U N N - O— p co N O 1 1 ' I I U Oo N ^ ILO M c S :En~ CA M P .D M /- N cO .�.. U c., - - . , .1 I'f „., O-N 0 0. 0 Cin G:1 U W O N N O NO NLO -I-, ,--• 1 en O A-I U # -�qQQ N E V OM H N Nro ” c ) ., 0, ccn o Q ¢ NO O N N N — 0 ¢ tn in' r--, as a p M fill o0 - J� to nmmnr —mi ¢ +, '. 0 Ni = NI ) v s: U D co E I ' 1 I I I 1 I I I I I 1 ` T� 1 Nr- 3 m o S g S o o g o o m O 01 00 `O c} M N .--i C Y Q O U Treating Slurry Treatment Treatment Stage Event Time Description Comment Pressure Rate Clean Slurry Number Number Volume Volume psi bpm gal gal 1 ####### Stage 1 Displacemen 325 0 4 0 21:01:04 Start Start Avg Trt 324 0 5 0 Averaging 4 Other-Well was on a suck. Pulled 20 21:02:07 Other in 29 bbls 278 0 5 0 when we opened the well 21 21:02:40 Open Well Open Well 266 0 5 0 Break 22 21:07:06 Break Formation=3 934 1.5 5 7 Formation 256 psi, 3 born ISIP=2893 23 21:14:06 ISIP psi' 2953 0 4698 5113 FG=0.857 osi/ft 2 21:17:18 Stage 2 Shut-In 2665 0 4698 5113 Shut-In Shut-In Pressure @ 24 21:19:08 Pressure @ 5 5 2556 0 4698 5113 Minutes Minutes=255 8 osi Shut-In Shut-In Pressure @ 25 21:25:06 Pressure @ 10 10 2193 0 4698 5113 Minutes Minutes=224 9 osi Shut-In Shut-In Pressure @ 26 21:28:15 Pressure @ 15 15 2037 0 4698 5113 Minutes Minutes=199 8 osi Fluid 3 21:50:38 Stage 3 Efficiency 3186 10.8 4698 5138 Test 4 21:51:40 Stage 4 Shut-In 3281 0 5770 6128 ISIP=3016 27 21:51:41 ISIP FG=0.874 3193 0 5774 6128 osi/ft Shut-In Shut-In Pressure @ 28 22:13:23 Pressure @ 5 5 2053 0 5774 6128 Minutes Minutes=264 0 DSI Shut-In Shut-In Pressure @ 29 22:15:56 Pressure @ 15 15 1998 0 5774 6128 Minutes Minutes=223 1 osi Shut-In Shut-In Pressure @ 30 22:20:20 Pressure @ 10 10 1917 0 5774 6128 Minutes Minutes=242 1 osi 5 22:39:14 Stage 5 Pad 1914 0.1 5774 6128 Hilcorp -Kenai Beluga Unit 32-08 Other- Shut down due to 31 22:42:33 Other not getting 4377 20.5 8361 8925 crosslink. Getting good visc and pH. Moving hoses so injection port for BC- 140 reaches both sides of missile. Injection port was by hose that 32 22:46:35 Other got closed 2835 0 8440 8963 off when we dropped rate,so only one side of missile was seeing crosslink. Moving injection point so it will work 1.0-7.0 6 23:20:00 Stage 6 #/gal CRC- 4491 17.7 10861 11068 LT 7 23:22:26 Stage 7 2.0 #/gal 4368 20.4 12560 12929 CRC-LT 8 23:24:51 Stage 8 3.0 #/gal 3942 20.8 14100 15011 CRC-LT 9 23:28:57 Stage 9 4.0 #/gal 3350 20.8 16649 18595 CRC-LT 10 23:35:25 Stage 10 5.0 #/gal 3119 20.9 20658 24271 CRC-LT 11 23:39:09 Stage 11 Flush 3002 18.1 23112 27561 ISDP=3187 33 23:46:31 ISIP FFG=0.898 3249 0 29180 33803 osi/ft 12 23:46:34 Stage 12 Shut-In 3203 0 29180 33803 Shut-In Shut-In Pressure @ 34 23:51:23 Pressure @ 5 5 2776 0 29180 33803 Minutes Minutes=277 5 osi Shut-In Shut-In Pressure @ 35 23:54:52 Pressure @ 10 10 2681 0 29180 33803 Minutes Minutes=264 8 DSI Shut-In Shut-In Pressure @ 36 23:58:46 Pressure© 15 15 2585 0 29180 33803 Minutes Minutes=251 5 osi ####### End Averaging End Avg Trt 1138 0 30812 36188 37 0:56:43 End Job Ending Job 1138 0 30812 36188 Hilcorp -Kenai Beluga Unit 32-08 Interval Summary Kenai Beluga Unit 32-08 LB4A -Interval 5 — Interval Summary Date: 8/1/2014 Start Time: 8:30:00 PM End Time: 10:38:00 PM Initial Rate(Breakdown): 2.5 bpm Initial Pressure(Breakdown): 3413 psi Max Rate: 25.8 bpm Max Pressure: 4039 psi Max Pressure(SLF): 3448 psi Average Rate: 23.4 bpm Average Pressure: 2616 psi Average Missile Pressure 2528 psi Average Missile HHP: 1450 hhp Average Visc: 13.5 cP Average Temp: 70 F Average pH: 8.5 Displacement ISIP: 2204 psi Initial Fracture Gradient: 0.769 psi/ft 5 min: 1184 psi 10 min: 755 psi 15 min: 562 psi Minifrac ISIP: 2188 psi Initial Fracture Gradient: 0.767 psi/ft 5 min: 1276 psi 10 min: 823 psi 15 min: 621 psi Final ISDP: 2429 psi Final Fracture Gradient: 0.801 psi/ft 5 min: 2166 psi 10 min: 1935 psi 15 min: 1641 psi Proppant Summary 20/40 CRC LT Pumped 100,500 lbs Calculated Proppant Pumped* : 100,500 lbs Proppant in Formation: 100,500 lbs Fluid Summary(by fluid description) 20#WaterFrac G Volume 6,956 gal 166 bbls 20#Delta Frac 140 Volume 16,342 gal 389 bbls 6%KCI Water Volume 5,816 gal 138 bbls Fluid Summary(by stage description) Displacement Volume: 5,909 gal 141 bbls Mini Frac Volume: 1,047 gal 25 bbls Pad Volume: 2,014 gal 48 bbls Proppant Laden Fluid Volume: 14,328 gal 341 bbls Flush Volume: 5,816 gal 138 bbls Treatment Volume: 29,114 gal 693 bbls Total Fluid Volume: 29,114 gal 693 bbls Interval Status: Completed Hilcorp - Kenai Beluga Unit 32-08 Interval Summary 6 — to LL.._. g g 888888 a 6 O O m o I11 o w t0 0 088 $ 08 :1 -1.- 4,A m 4 .o 100 3 " N g « g ry ry a e e R �_ a _ rm Ill d o u ry ry ry ry n n u m m '11 a p n g g eF a a ,- ,W, •_21. ,7,,, ;. ,1,14 ▪ 0 08 ! i^8 888008 m. o me;2 :..* P- s WiNA igl li aN m_- m R o > > W 8 2 0 S !7 p N ' :21 ;11 v m .. _ c E E = E w ZJ22 > ';.' > g .f 2>p > > > w O _ _ _m o c .t.'r. f m m °� d o 22 Q p 8 ` .• g G 8 0 0 — - m o a 88 =941 §u v c Q _ 2 0f Q m r ri. ,^y m m a I o a Z 0 a z u - a O-2 V ° .R ni o m 'c° 1-.; 8 y j ^ c ., rn v a m m w = oo • E z $ Y M. .,7, a o M m m ', c C m m m ''Z' o 'O c oo ao co ✓ p m O b .Fn ^ FO ry V 1>O m - ..4 '0 ‘,. ..z,,, ,, ,, N d 0 V , w 8 Ohm Q 0 3 of a FE' S i F. a h ? i a u E e R 8 $ o 8 o o o . 0 U t e. t `J o s ` m o„ ..i^ m ry o M u „� ~' o u F 4.'13 o 3 ,.2' .,2, g,„0 0 m o ,�•' c w a F 0 t3 °1 o r_ n o �a r ry ry n ry r ry ry ry ry ry n a m m m p' i H �V 1 .'2 ry w n a C 0 0 p ° `o n 8 8 $ 0 n o 5i a 6 V` O I� 00 Oi ..i N p E QQ `0 n F EF .-77F W 8 1- F F- H H 8 G. 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' if1 al = 1 sa To N �v �' N H rn N L o IP" M V] C/1 N Q Q �j q , N M cn cd (7) � N 0 .., It o 1 m N 0. •. m U j-O i- ti D N co M A as rtiO E^ 4:: .........._T y0 = _3 ' I I 1 'M I I 1 I I I I m y v o O O O O O O O O O d3 m 8 8 8 8 8 8 8 8 8 - co OO� 00 N '0 m N — c a) Q L Q U 0 U N N -O — tn O 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 pa O 7 O O O O I , I , I , I U ¢ o'r M N I ch N;; 03 � y kn gkn G 2O rn o I c: co C1� UCA N + I -4,004140111j11 N I. Na �� N p hi ; el iii M N N M M I" Q r 03 8 ¢ :w h N O • 8 al0 2 IIMIIIa 0 `°i �� m �a _ 4 a I cn cam .5 r - �■ O N 14 .Iii 0 A a3 E- I N Oto O O O I I O C O m ¢ 8 8 0 C 8 8 C S C 8co Y O_ i O U Treating Slurry Treatmen Treatmen Stage Event Descripti Comment Pressure Rate t Clean t Slurry Time Number Number on Volume Volume psi bpm gal gal rime Prime 2 ####### Pumps Pumps 124 0 18235 18184 Pre-Job Pre-Job 3 20:10:41 Safety Safety 286 0 18565 22028 Meeting Meeting 1 20:29:35 Stage 1 Dtsplaceme 303 0 0 0 20:29:36 Start Start Avg 303 0 0 0 Averaging Trt 5 4 20:30:06 Open Well Open Well 254 0 0 0 Break 5 20:32:29 Break Formation= 3412 2.5 184 174 Formation 3413 psi, 2.5 bpm ISIP=2204 6 20:38:41 ISIP psi' 2204 0 5897 6168 FG=0.769 Dsi/ft Shut-In Shut-In Pressure @ 7 20:43:48 Pressure @ 5 1184 0 5909 6168 5 Minutes Minutes=11 84 Dsi Shut-In Shut-In Pressure @ 8 20:48:51 Pressure @ 10 755 0 5909 6168 10 Minutes Minutes=75 5 psi Shut-In Shut-In Pressure @ 9 20:53:50 Pressure @ 15 562 0 5909 6168 15 Minutes Minutes=56 2 DSi 2 20:58:32 Stage 2 Shut-In 445 0 5909 6168 Fluid 3 21:00:40 Stage 3 Efficiency 521 0 5951 6169 Test ISIP=2788 10 21:01:47 ISIP psi' 2188 0 6934 7210 FG=0.767 Psi/ft 4 21:01:57 Stage 4 Shut-In 2192 0 6956 7210 Shut-In Shut-In Pressure @ 11 21:05:44 Pressure @ 5 1276 0 6956 7210 5 Minutes Minutes=12 76 Psi Shut-In Shut-In Pressure @ 12 21:10:44 Pressure @ 10 823 0 6956 7210 10 Minutes Minutes=82 3 Dsi Shut-In Shut-In Pressure @ 13 21:15:43 Pressure @ 15 621 0 6956 7210 15 Minutes Minutes=62 1 psi Hilcorp - Kenai Beluga Unit 32-08 . 5 21:34:14 Stage 5 Pad 333 0 6956 7211 1.0-7.0 6 21:36:24 Stage 6 #/gal CRC- 3341 25.3 8970 9349 LT 7 21:37:12 Stage 7 7.0 #/gal 3426 25.2 9657 10194 CRC-LT Shutting 14 21:38:36 Other down to 2787 11.9 10421 11254 troubleshoo t rate issue Running through pumps 15 21:44:06 Other making 1659 0 11612 12764 sure we have prime Going through 16 22:05:27 Other pumps to 649 0 11612 12767 check rates through primeup 8 22:16:29 Stage 8 8.0 #/gal 3183 23.7 13721 15175 CRC-LT 9 22:18:53 Stage 9 9.0 #/gal 3119 23.6 15396 17544 CRC-LT 10 22:25:41 Stage 10 10.0 #/gal 2225 22.6 19746 24240 CRC-LT 11 22:31:05 Stage 11 Flush 2186 23.6 23298 29518 12 22:37:59 Stage 12 Shut-In 2412 0 29114 35520 ISIP=2429 17 22:38:01 ISIP psi' 2396 0 29114 35520 FG=0.801 psi/ft Shut-In Shut-In Pressure @ 18 22:43:29 Pressure @ 5 2164 0 29114 35520 5 Minutes Minutes=21 66 osi Shut-In Shut-In Pressure @ 19 22:48:34 Pressure @ 10 1935 0 29114 35520 10 Minutes Minutes=19 35 osi Shut-In Shut-In Pressure @ 20 22:53:33 Pressure @ 15 1641 0 29727 35520 15 Minutes Minutes=16 41 osi End ####### Averaging End Avg Trt 125 0 50982 35520 5 21 0:57:34 End Job Ending Job 125 0 50982 35520 Hilcorp - Kenai Beluga Unit 32-08 La ,n Ellison Hilcorp Alaska, LL, GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8339 HariwpAlaska.HA, Fax: 907 777-8510 E-mail: Jellison@hilcorp.com 0 0 U, DATE 08/19//2014 •i 0�� G4.1 an To: Alaska Oil & Gas Conservation Commission ` o Makana Bender °t a Natural Resource Technician c G1 333 W 7th Ave Ste 100 0 L Anchorage, AK c c 99501 02 M a DATA TRANSMITTA Transmitted herewith are cuttings from KBU 32-08 WELL SAMPLE INTERVAL KBU 32-08 6418'-7580' KBU 32-08 7580'-8860' KBU 32-08 8860'-9847' Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transr EGE .8510 Received By: Date: AUG 2 0 2014 A'A 1a K. Singh AOGCC La, n Ellison Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 DATA LOGGED Tele: 907 777-8339 i i Ififr,rr�r Alae+kw-1.f.4. Fax: 907 777-8510 M.K.BENDER e' IV E-mail: lellison@hilcorp.com AUG 12 2014 DATE 08/11/14 AOGer. To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTA KBU 32-08 CBL log data Prints: RST GR CCL SCMT GR CCL// CD 1 : 2 ,Co "1w ='`es Currently on the Disc (7) Hilcorp_BCU_32-08_Run2B_RST_Correlati... 6/9/2014 5:51 PM LAS File 472 KB Hilcorp_BCU_32-08_Run2B_RST_Correlati... 6/9/2014 5:51 PM LAS File 64 KB Hilcorp_BCU 32-08_Run2B_RST_Main_DL... 6/9/2014 5:56 PM DLIS File 59,051 KB Hilcorp_BCU_32-08_Run2B_RST_Print.pdf 6/9/2014 5:51 PM Adobe Acrobat D... 811 KB Hilcorp_BCU_32-08_Run2B_RST_RPT_DLI,.. 6/9/2014 5:53 PM DLIS File 7,638 KB Hilcorp_BCU 32-08_Run2B_RST_Sigma_... 6/912014 5:52 PM LAS File 2,868 KB Hilcorp_BCU 32-08_Run2B_RST_Sigma_R... 6/9/2014 5:51 PM LAS File 368 KB '224C1'224C1,<6CD 2: � < es Currently on the Disc (5) Hilcorp_BCU32-08_Run2A_SCMT_DLIS_... 6/9/2014 6:05 PM DLIS File 98,233 KB Hilcorp_BCU 32-08_Run2A_SCMT_DLIS_... 6/9/2014 5:52 PM DLIS File 4,505 KB Hilcorp_BC102-08_Run2A_SCMT_LAS_... 6/ ;2014 5:51 PM LAS File 1,840 KB Hilcorp_BCU32-08_Run2A_SCMT_LAS_R... 6/9/2014 5:50 PM LAS File 92 KB Hilcorp_BCU_32-08_Run2A_SCMT_Print_... 6/9/2014 5:54 PM Adobe Acrobat D... 9,980 KB Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 ..4?o [ Received By�Y /3gpate: c6 1 1 Hilcorp Alaska, LLC Post Office Box 244027 Anchorage,AK 99524-4027 RECEIVED3800 Centerpoint Drive Suite JUL 1 5 2014 Anchorage,AK 99503 Phone: 907/777-8300 Fax: 907/777.-8301 July 15, 2014 A0 3C0 Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage,Alaska 99501 Re: KBU 32-08 Form 10-407 Dear Commissioner: Please find enclosed the Well Completion Form 10-407 for the KBU 32-08. Please do not hesitate to contact me should you have any questions or need additional information. Sincerely, HILCORP ALASKA, LLC i / anise Barrett Drilling Technician RECEIVED ' STATE OF ALASKA JUL 15 2014 - ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND 1a.Well Status: Oil ❑ Gas ❑✓ - SPLUG ❑ Other ❑ Abandoned ❑ Suspended El 1 b.Well Class: 20nac25.105 zonnc25.110 Development ❑ • Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 5.Dat Comp Susp.,or 12.Permit to Drill Number: Hilcorp Alaska,LLC Aband.: 6/19/2014 • - 214-014 /3r4 34/o" 3.Address: 6.Date Spudded: 13.API Number: 3800 Centerpoint Drive,STE 1400.Anchorage AK 99503 2/18/2014 • • 50-133-20624-00-00 - 4a. Location of Well(Governmental Section): 7.Date.,TD Reached:M6 1 4t9 14.Well Name and Number: Surface: 552'FNL,427'FEL Sec 18,T4N,R11 W,SM,AK 341/2014 KBU 32-08 ' Top of Productive Horizon: 8.KB(ft above MSL): 85.6'• 15.Field/Pool(s): 2030'FNL,2464'FEL,Sec 8,T4N,R11 W,SM,AK GL(ft above MSL): 66.64'. Kenai Total Depth: 9.Plug Back Depth(MD+TVD): Upper Tyonek Gas Pool 1815'FNL,2281'FEL,Sec 8,T4N,RI 1W,SM,AK • 9,746'MD/8,098TVD - Beluga Gas Pool - 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 275386.82 - y-2356184.89 - Zone- 4 - 9,847'MD/8,183"TVD • • FEE A028142,FEEA022330 TPI: x- 278733.17 y-2359798.7 Zone- 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 278919.16 y-2360010.42 Zone- 4 NA NA 18. Directional Survey: Yes ❑ • No ❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) NA (ftM L) NA 21.Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 4' .22.Re-drill/Lateral Top Window MD/TVD: Flogs: BAT DGR EWR-Phase4 ALD CTN mudlogs:Formation.LWD Combo,Drilling Dynamics.Gas Ratio CBL_ NA 23. CASING. LINER AND CEMENTING RECORD ( fS ) WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASINGFT GRADE TOP BOTTOM - TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 109 X-56 Surface 135' Surface 135' Driven Driven 10-3/4" 45.5 L-80 Surface 1,478' Surface 1,420' 13-1/2" 160bbl 7-5/8" 29.7 L-80 Surface 6,405' Surface 5,391' 9-7/8" 261 bbl 5" 18 L-80 Surface 9,745.56' Surface 8.098' 6-3/4" 114bbI 24.Open to production or injection? Yes a No ❑ 25. TUBING RECORD If Yes, list each interval open(MD+TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 5" 5849'MD 5.849'MD/4.940'TVD Sands Top(MD/TVD) Btm(MD/TVD) Size SPF Phase Tyonek 76-7 9,343'/7,762' 9 3.6'/7.7$1• , 2-7/8" 6 60deg 26. ACID,FRACTURE,CEMENT SQUEEZE, ETC. , i-' th i Was hydraulic fracturing used during completion? Yes ❑ No C DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED _aaiLl I [T 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): Well not producing None- no production of this time Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 6/19/2014 N/A Test Period -►N/A N/A N/A N/A N/A Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (torr): Press. 24-Hour Rate --O• N/A N/A N/A N/A 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No E • Sidewall Cores Acquired? Yes ❑ No❑✓ • 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. `' i/4.. .7`i /S� S 7 31 /� Form 10 407 Revised 10/2012 % �� CONTINUED ON REVERSE SU ,qrm-rgl Oj 1 6 2 c! l� LL tVly Tit 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes - No . If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if needed, Permafrost-Top N/A N/A and submit detailed test information per 20 AAC 25.071. Permafrost-Base N/A N/A Sterling A8 4,281 3,686 Sterling Pool 6 5,356 4,545 Upper Beluga 5,555 4,703 Middle Beluga 6,399 5,386 Lower Beluga 7,286 6,100 Upper Tyonek 8,662 7,213 Tyonek 72-8 8,752 7,285 Tyonek 73-1 8,806 7,328 Tyonek 75-8 9,161 7,613 Tyonek 76-7 9,276 7,707 Formation at total depth: Tyonek UP4D 9,847 8,183 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Luke Keller Email: IkellerPhilcorp.com Printed Name: Luke Keller Title: Drilling Engineer Signature: Phone: 907-777-8395 Date: 7/15/2014 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 b: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion), so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 Kenai Gas Field Well: KBU 32-08 ,, 1E4SCHEMATIC Last Completed: 6/19/2014 Hilcorp Alaska,LLC PTD: 214-014 CASING DETAIL RKB:85.6'/GL:66.64'ANL KS-THF:18.96' Size Type Wt/Grade/Conn ID Top Btm ' 16" Conductor N/A Surf 135' 10-3/4" Surface 45.5/L-80/BTC 9.950 Surf 1,478' 7-5/8" Intermediate 29.7/L-80/BTC 6.875 Surf 6,406' 16" t ::1S" Production 18/L-80/DWC/C-HT 4.276 5,849' 9,746' TUBING DETAIL ! 5" Tubing 18/L-80/DWC/C-HT 4.276 Surf 5,849' JEWELRY DETAIL 10-3/4"i _7 No Depth Item N 1' 1 5,849' 5"Swell Packer i. 1 2 7,330' 5'Pup w/RA Tag ,, 3 8,028' 5'Pup w/RA Tag 4 4 9,475' CIBP I. OPEN HOLE/CEMENT DETAIL ', 10-3/4" 16OBBL's of cement in 13.5"Hole.Returns to Surface 7-5/8" 261BBL's of cement in 9-7/8"Hole.Returns to Surface , g 5" 114BBL's of cement in 6-3/4"Hole. TOC 4,600 Calculated '' PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(ND) Btm FT Date Status w (ND) ti Tyonek 76-7 9,343' 9,366' 7,762' 7,781' 23' 6/19/14 Open : g Tyonek 78-2 9,500' 9,510' 7,891' 7,899' 10' 6/7/14 Isolated L_, ife_uf v,., 5-ce,voit-7 3P-1 31 /o.ylc( 4 1 's F j 1 1 7-5/8" ' i 1" i. 2 er 'f. I.'i .1 1 3 kw kl tx r' 4a TOF @ 9,443' >F. w,' 0 F TOC @ 9448' t! Tyonek 76-7 iot Tyonek 78-2 5" 74; TD=9,847'(MD)/8,183(TVD) PBTD=9,448'(MD)/7,848.( ) Updated by: TDF 7/08/14 rn O c ' }, c O $ c Y �c a) 'c . - a) O 3 co-' c a co C C_ a a . c ° fa L (n L :.+. 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N M J U v M M M Q' c 0 ..c1- 40 Nr •a - ZS O O O O J N N N core co co I Q _ U) u) C �O c CO CO a) -a _0 V) 0) E C O z CO Oco Q � LE) V y U O O 0 0 0 ti.) m T + � (nN o � � a) @��_ 0 = rte ° •� ° a) v ,z ai 13- ,_ a) cL ,- 0o c`nu aoi cc - � _ � < . - Y Ec) L� 3 >, o - Din .- � � �2 6 = m _O ca ca J L o Q o Qc cE m 3L0 coci) 0 - CO a) ami CO L !a' 00 v 72 k I , co (/) •- d u6i o a °° o ca " al Q o o 0 0 a) T o ° U o ° U @��- -1-- coE 0- a'2• Z o O 0- o OIL to O fl a O o c N Q p No 0_OO c N N •S 0 Q _ . .0- CO = _0 c Lo CO c) C O >,T (n O 2 O 0 = CO ti oN- O OI- + to a) mma � LO Om , .0g6 .c :E, cO) -' - Y 0 . Qo4- m co a) L rn 0 •x @-a - § °_,) -0 E T O T U O O $ a) _ �. Y CZ 3W (0 o 0 C m :N O co M O a) LL !z O _C O .� co >� fQ _ c0 C 0 O c E ocsI- rn E c cn Q J '� 0 c0 c6 0 N O °) E � -O 5E .° O o__ O COco O'° -0 U Z U c O a) Z co C co O to 4 co L O T ,O d' LL.I p n N Ln 't O N , -0 0_•L C . -p .- 4 co O C/) 1 c N C E a) 0 c "J o a) d N B E - � - I- ° o .= t c = O O c c 0. II C3 . • O O cO O O) a) Y co N N p L O c L (n O p o QUO Q) m Lc) d C •( c 3 a) co o co L E c 0 .E E to �/ Z., > � E30a) mcma) 0 a�ai ° a) a�i -00-co o L (0 co '3 1- a)) O m o .fl`U U E a) ° c cco ° 0 ;n co CD�+ gyriE `—' � °ts � � ZO ° .•o _ N >, Cl) duow OJv) m aoD _0 cUE E oop M N •.,-, C .-, Va • _ • J O c1-••- •.., LOpaO 0 - , -o ca ,N o n aU ) COU p Ch E I a) N O p E > O -Fa = -c c to _ i 03 (� Q m .N E m 3 U al 0) a) N rn L ••� c_a " 1.0 o_ OL a) 0 '- Q a) p .c c ti OL > EUS = (1) r.... _ o_ OO) N 2 1 .0-a .- N cN`I. U N E 0 T Q L a) .` ° T al C N L D J -0 O -O L C O p (B _O L I- �_ 0 0 Q C a) (n O p O •L w u) p OL Y 7) U -° 0 L. E ° Q a) N 2 4- ~ > -° Q -O = O L cnn N O L J o , C + isoYco as 2 $2 co Lo M Q O E N N 2 Q N m x -0 N ct c § T T c) o 0 0 2 0 0 O 451.0 J _; LL co nco_ U p0 a aa) Qo � ,o a`�i � = v _I -2 E Qo 0a) a., 41:,) ccuOCU _ CO LO W w c C _ E -0 * 0 3 CoL° o Y M LL o CCSC� co W Yam , mZUCS7 N '3 OM = Y a) Ej W a0 i N E• a C g E v cv a) o o m 0 0 0 co Cl) m N o_ Q- Q O o r .r ai ° N c CO O � •a v) cn 03 Dct O o vOi W m '- >, N i m c 017, ° 0LiJ Wm rn Q - tJ C p O 0 a Qo N Y 6 rnMOcT- a) OI- ccU co o ° i0 co a) - w N o �' ° o I� c o cn T Q L Q cc O_>. 0 cn O a) r Q•� - a) �' cn O O O (0 0 0 N 0_ 0 7 O O U II Y 0 o to Ln LL Q� U v� a) ns ~ .� E� ° • Loo • - o-co D � Q` O a) CU O O E c > 73= 6 0 a) u) = ILD ,., = a) c) 0 31- wcI' T � 70 co •= c g ac) Q c a) T O a) U v - ° Y Y a = m m co E c M o cfl ° p co m co CO >0 Q) c 0_c 0_ ca -0 c 2 op ii Lo a) cnIZWc Q ° LSC = E ° '5 c - -E-. -c v tn �' CL QU aa) 2 ° md o2 0 32 a0_cooiii N- m •c o N L O O co L O O o 0 1 �C coO (.1 N CO w (On CO -° a:$ LC) O CO L cn to 90 N N D tZ >- IL c_ — N m c I` O v Y v to a) a) a) 1..6T COj N T .a u) Y 0 a. rn M o 0 coo N TO 00 W J O N C73c J c c co T x IL LU a) a) co O - C6 Y Y Y N i.n N t- cn N Pi 4iii N O 2 E m m 0 co E 0 co ,i- •q- ca ji ,, Z Q p ca E2 0 C N N C IL- = cn � � Co CO 0 1 coU CIII -) C 0 d .1- 111 V' r 0 0 J N N Ce CO CO r co C co O u) t c tr) � o M U _0 O - ° E --- o - cpM Y E _ W o aco 1, : cCOD9 . 0 p a3 .-U3 vco w v mD CO C / V) 03 ° a) (a CO Q a) (6 ct C NO `- 0) CO CO C a) 06 U � -c L 'v, O .o CD > a) O� p E r m a) O ca • C Q co U O Q U � ia �- � � Y U Em = Ucn 0 o L o CMO Lo a O D M (a - 2 _ L M Y C ca a) a) N I- _U M E M V ca n _. 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Y m N `- O-•ra = a) ,- Lo N a) N E V @ Lo ' a_ C) Q co Q O _ u) ML RI = N O O O Ma) I- > co C a) • )a00 0 - a ' coCl 0 a) -0 O LS fE � CEY rn N ° 0- MvaCa co NYU 5' tiO W "O + -0 ,...•,‘ "OULM - Cfl OvCT) a )C? 07 - m `- pN O oN .. .- n > ' E0E0Q 2cup . vo0)o 't 2 as Q.rn , 0_ ('m o -el) m 3 ) o oo h _ a) ° M Y I— .� o — U Y Q N O N > U .a .Q a) a) N N t 0 as 'H Q Q a) o c 0 a9 = " O tom ` • U a.. 2 N a) L 0 Cf) u) in H (a tun 0_coO U O U a) O C) L = N 0 O2 O O 03 c> m 0 O N ccs MO 'C3 N O M L ccn N N u) N = Q. >- co C N m 0) c o v Y 1--- cn a) a) 10 N N- CO Y0 a CD M o o — c 'c co o o Lu a) a) co o " a) Y Y Y N to N .- (n N "a *k ai N O 2 E a) as ca E U co v cu Ii Q a caD ZOZaC R, 21 co 0 CI NC HJU cO ° . O U >v `Y Q a) v ca o O 0 N J 2 O C Ce c� 'a C) X C In — a) Lo Y :-. `� C O - v-O � r U E C 1.c a) a) a .. 0 ( O 0-LU © '- 2 Cfl -a a)) D _c N p (a 0 >O c— a jcUo� O CO O s - Lo 1- Z U = C0') QL4- m O -a0) -0O a) 0) o ._, ZI- .a N } O -0 92 C E a) IT)c 0 ca .> a) o U o rn'O N O C Q C O c c) o0 - O 4) � o U V (0 0 E (a -O L N OO co O co o_ N o a) j — O O a)O N 0) a) N to c U E © E O _ct O = — F- c � oa c a) a) Q.0- u Cfl J ocQ-V •cEULCoctado a.,aocY UY _ La =o 'E a o o E aci a rn= L c } co cm 0 'V o CCD .CO - d •E a) N oO c0 O E . sEO c ca c o co 0) U • C O X r - + .. 0 N V aO -aco -a u 5 N Lac N I's o � 3 >+ i u)o '0o o aC 5a) cE a) �oo EdU2 . m p _o U O 0 c0 o co _8 •- _c ) >O O N 0) d ocipc ) = 3 .- aC m " 0_pacLQ N Ca) a • 0 .Io c a) U = E • _ 0 p s m ,_,co EQo 73 o 00 a vo = oo U 0Eoo = = C0 ooo0 . mN. co t - d co )Q0 Q U aU •7; Qao •- E 0)(N O o - O N c 2 am " U a N N Y c.1 .0 pL — Y as u) a 'Ca) co • II0N -0 '- �y0O OCb 00 Na v O COOC E Q (a> -a ,— • O Q-@ O_CD .0 U > LLO N U) 7 (N pa) Do C/3 Q1)1 U) 0 M t > EV @ E Q c Li -m (f) i- x= EOtj oi '- O = 0 a o (a 0a)co avo (0 C p c v• ; U N . - UL -J a) U 3 C N to a O r a) W t O U c c a) a) i fa = t. C ca m r a) «� C) Q t J O 0 a) c (a V' N c 0 rn > 'c O Y — a) • - I- r a U E a) C o o_ o U co c � a) O Cp[0 t, •c v c •- o cn 0 .- ca Q E w e s > 2 .) v , D O 2 E a) X C� "O 2 O O a) E � � N 'c . am0 . . moo - 0 :30 °o � o j = o aai • 003 C Q L L O m O U° +_ -cos N N E _ ▪N = D 0 OU L a LU .O• o .Q C L .0 N • LL O m C C N O a):- y o . -a co co r p_ O'Q .p cn .0 I-- Q- a M •0 O J O O — C O O co s0 C O II N j U) a Lo N >i " O C) LU E Y IL ( >, co "E CI- Cl. G. . N L O a) Q a)-a to i- = O ca 0 .Q 'O O LT Q. Q O 73 E U N a) a) m r O m O U }, U O O +� (n C Y Y i J U a) (� m �, co m .0c0 Q'3 N .� .E E m o m Q.o O -a o > c c comma ,_ •--'g a) o U) rn CO o m o m a0i a >, m y VU a . fn _. 0 a) r C_ a O a) 3 0) c v o ONtl -0 Up W -0 0 C • to o oz, ° c(1'o (9 °. 0 0 > ' 9 E •c cco 0 . 2 co a) a) -`o °�) ■— .- .r ca 0 _ c.-o a) _o a) a) c a O_ cn a U p 0 _0 0 C � v •� a) m Qw Qo sZ c tco = 0 0 io N .S E ▪L M Q U c) 4 E a) E .- cn a) O .0 C Vi a—`ni u- o p .c . m _.« Q 1E .E a) a) a Yo iv E -a = E co 3 c c sZ J • a) o E cn V U �u• 73.c— o � `n � ci) aciI c`oE E0 .0 � v°O c° � o o � .0 .Q p L a) a) O a) U a) a) U U O z 0 r o o co a) 0- o I .- v O L a) ° O n J cE - _a N 0U cco � -a COs}' 0 0 a) _0 O N coo 7) • a .3 _c o_ E rno 30 •S oM a = 2 aa)i Q- a) a) U O • 3 p sz CL a) C rn N- OU a) a-' = O L Q O c C _ 0_ coN a) 3coso a E a) c •— ca m U1- cn � w E `n 4 p• o O " 'c c o a) = -' a) UJ ti a ao 0 CU o - •ca 0 v 'o � -2m•_ m Q opo �c) ....COa) C cY.) (0 c m m 2 _ co •3 _ O � co s o • N :•-' 'rn � X o a c r o- � � o cL. O >,• L 02 c OoviM co = dOc d 0. E > 0 cn .c UU)) U)) c . Q a) c„,2 E rn U 2 m '- a`� 17 ff E o O O C 'a 0) ca ca O .fl C a) a) - a) m c 0 -a Q_- - ca O a L c N N Q a) a.0 O_ 0_ O a) a) .L _ . ca c ` O O V 0-o p y -a U 0 "c E ca cn a o c0 ~ '- o L � o � � O U L I— �o C 2 a) .s - 0 a 0 0 0 - N c Q co (a Z a)= o Q"f .� I- a) N •E- Q Y 'a -a () d L �, O O c _a — C Q — N 1- I — pOrLEvQ) ocm ' - N .Qa1 � � C c - = a) NoQ ca a) 0 cd - a) • - 0 •rm mrnL3 3cca05 .N5oT N U) U "a a) o i0 N CO 0 9— ` .,), O O_h o a) E T `8 Z U ca > o Y -.' O a Y 7 m C - 7 N if) a O L C". C C) o Q 'c ca -0N . - U C al -a c) r . O ar •c co Oa0 Cl 0 LL cooQcc00) = U .0 ac () 3 '0r � .Sm dU) r co 2 � c 0 0) aN 0 OO co L O LU O O D Y CO O H co a) CO -0 Ca (o O CO Z N N 2 N N m d. >- J co N 'E co Y co w a) m 0 d O cvI 0 c)co ' 2— • - CD tu.••• cN° - N o C •Q U) C C inr X LL YY Y co c`ONI LU (N r 4) "6 a ' ' *k a ' O .d,, E it _ Z 0 N N Ca r d O Q L O O a 4.0 --- = N N gl N �' O Q �O O '� O r r' "---• M U J U Q C o m .s- .1..Ca rCO CD r J 0 N N ++ r N Q. r ,- re re M M •- (n , o Y @ E - 0 O N Q N U CA Q r O _a _o r Cl_ +: Q _ r (0 O 0 72 O LCL ti 0-r C m CA U -C ° 'O N C 00 N Y V Q O .= .° m e a.- 0 0 O a) U 0) 00 U C i M a)Z O Y U = CO (0 :«- Y O -a 0 7 v7 cn - 0 Co C N )- O` co u) 0- C O N C O A (0 co (0 NI" a EST O a 0 V•C C co (B Q o Cr) Q 0) 0 Ks) a 7 7 0 N O O ON = Q C N I C a) a) 0 0 O O > a) +C O _0 E CO ti Q 00 (0 co m Q _c O �N Q (U M N p E U U a) E U) (.c) C O B E U N = Q N C (0 Q...j Q a--, ,•• \L "O 0- CO — O 6 O C (A C) V U N O -0 'V () t_ f• O C • 1E 4- O � C ED_ -10 C) 3Y a -§ O .1- .N .0 r (0 -- E (0 ca L .0 O r U N d' 0 2 ._ O a 'O O46 L (6 g O E C ' O 0 O O a) � Q) O CO a) C) a0 OU O U "' O CA cn O 7 U , oma) ` L = coo (n Oo C 0 cc) (n -0 00 +.. 0 - .-• a)' I- NUr M O '+-. NO N E O .0 Emco ,_ (a a 3 CLaN C 00 2 © > � � a r Crl CL @° o 6 c � � 3 0 °c° o U � U a aai Q 0 rn ° � c) c a) - 1- rn, C = 5 a`) co ea c 0 cv u � c .� coQMo3 U2QaCN OBO .E.-)__ O E ilia) c-:-.1 Q-p m _UcC m O 0 0 0UV m O 0 om Qa m70(n oNEUti a)•,7.,- t � Q0 m - ai Toy - oa °' _ �� a� aU oaO 0) ,--.° E V N • E C 0 0 CO s-11' - co O •O Q C (n = OU 0 E2 0 U � U • •- aa © (v evm W E - U c ` o Q- y '- O0 �O rn-C r t co E o U CO` E C 'U N@ O a N O U O a) m N N a r m ° a) o ° c) 3 @�c = U) >o -vi 0/ fp U) ii Q.. N (0 '- �l i ` O• O `� O N O E N O O E N 3 A V•U (A U +- N +-' r 3 O > U C i o o _0 • -2 = O rn" 5 a co >, 2 N 'v O o N c C }' = o ui co m V o Qom_ c2 c cm cC'�� a -a ca) _ ao oCr O o c - ca U • () U coo c = Q c) co _� co Li_ry NO O• AU a) a0 = r 0 _ U QN Oco ` a aJ▪ NO E4dNco ,�lO OU Q-c V �_aZ O 2 O E C (n E (B U •C co V(!') C L- () . In a'.' L. a) O Q (0 O � -p O LOC) r Uj O O H ,- (`p 0_°) 0.v'O a) Q Q O = Q U 0 CO (6 N 4- Cr) E O O O `- O O O a > Q N C R. — 4) N N = N O Z C _. a (n QOM = O > V U J .- L L c) (n E O E O v`- •- -C 0 a) 0 r C O .` (D 'V Q O (a-3 C Q C J a W c`oo vi a (s 3 .x C Q a) 2 0 3 o > L m Q rn• N `) O N I )-cc 3 aU) 0 rn o aa)) 0 0 J � _ .. E (n :ow c� (o 'U) C :11 a) M O-0 cts - Eda) = .- a) Y C aa) 0. :Z = Y N C a) c a, .0 Q m �. O N I� M O .TU >Q> O • C •UNOO _crte-.. („) 0,76 0 0 (a U ‘- _c .T Cl) U) U > �o N j N a N W Lo U = Q (Q C M U) M O C O CO (U O U CO j = < 0 0 -O QaC OO . LLB Nco a p aOa0� CL O a a X Y 0) ‘- 0011) O Q M r 00 O Q. _C o)OX 2 N N E c9 co 0 0) Q O o ° 0 (0o U) 4' L. E5W u) I-t o � co __ N- o a Emir — m c 5 ' � � � � ' C � � m@r3 � a � a�i � � 3 � ° V o= - o f c E rn a) a) 'CI) C -o °) O -1-1° 0-- a) c Y 0 - o • c o0 -0 , = = N c m•g g O N 0 m E• ° cn ami m U Srl co jI fl 3 a 3 c 4-O L `� V rn N j� Q Ln O 0 V V c 0 0 >> C N CL c N a•O a U N 0)9 O I- = O N C 0 Q > o :c_ = }' : E• a3 0- E a E m - o O E 0 (0 E c roi C E O C c_ CI) C -a C C ,_ 7 2 L M 7 O O O -0 D L — 0 E C°,� a -0O 'D QN O_CU 3 = 0v- U) rd N V' ULia. L -.N Q O O OL O M L -1 J O ) O O N w (A v o N 00 E E a Ca LO O COM 0 as CD E 2 N = a C N m eeo E N- o v Y . ( .� .N a) Lj N r 00 r -O N a) Y 0 - 0) M o o J • .FS � (V ap M (N r C T) r o Ox 11. Y Y_ C C 00 Y Y Y c(\1 LU N s u) 2 N -6 *k N N p ,a), E a) as -0.. a) E U ca ' v 03 Z LL z Q 03 N 0 0 O 0 1 >s O Q .O O N cc) p Q U it U v a M M C ° m v 0CD 0 N ON J . M "i' 0. r 1-- Et - Ct � M M c • co — m o > c t co 0_ of co co U) �° ca C4 cm } �0 ° a D ° ca m t o U > ui Q o N a) = z � O a) c O O = c Q) ui co_ •Q c r-, off$ 00 N. c m Y -O F.col. O .- M -0- co Oo Oo ©© CO N Q. c0 N C ai N o v O N O c . ° O 0 c O4 c) �•O c - Y N > co co N N O Q Q O a) U co © x w co •- c O co co `o E • c°i E co Y O v 4-= 4' c 0 E O CO '60 43 ° o 3 E ns o N s• (n - � Q a) U a cz c > 2 • c ca m •- — Nm = N (1) c N = • )=1 N a) O u) .§ 0• cu � aa) = c c O o _ Q a) E _ m N Q C a) •° O° c a) (o co ti n_ -) c °_8 a8 N 0 co n CO Ii 0 0) 0 ;2 _ 75 ` 'Y L. O M L Q" a) ° L a) co Cl) USM ca c 4-0 as LO d Q 0 as co co I- N CO E o _ m o L O E a (n �� - y > - COO N �m J O '� c cp Cl. co ° 0 Q E E -:--' co 0) 0 0 -O a) c 7 O c O = Cl) _c a_ ._ V L N o L 0 • u)a) Q. • co c cl .5U O ° co C moo Lo O ° O O c U c N M - a) 5 in'o a) co 3 aa) c m O :c co vcs N ©_ G) op_ 3 coct ° ° 'c 3 � mm co /1 p -- > w O O = LF J O J C OQC io 00 0 co c 0 c0 c. .p� �~ N •N O O ° V o o •> W = U o 0 a_ rnn U b v) Q o ) ao ( a) corn 7:3--f.- _ W p).E § a) cU E NMO o c 0 20 = QC E o 0ti rn >, >, a) O O •L rnE � °•-1 a) 2a -0 CD d- � ac m Cl) ME E -a > a) OQc NOaNoC CtS pOd as 2 N — E " 0 • Q N cii C O N 7 w- ICC 0_ CD Q C2 0f -) � 4 .c L ptco L c`Jj CL L' c O • c + c u) ai a) E a) = . in 'N c L — o m O C -) c 0 0 .— .- ° = c O j •0 4- = CO ui .J Co C co j j- Q V > 00 a) 5 ° Q- O co co °-o >,> U CC N U "a O O �O O O Q 5- d. J0 .N .5 - .o co 2 � a) = QO LU 2 — •L° � "O c 0_ 0 Nco = a) 0 a) EM u•) co - O � _cE o_ -2tnmQUm -a � U= QUD 0) 0 2 N O co L J O O O O N m O NE 00 -p CU in O CO o �, � N4 N 11 c N m fl. co N •c 00 d' Y fn a) Q (o a) t[i N co a N .0 m � N o o • -i c c x tL .. Y Y Y N Lo c.1 U) ai v ai ' ik ai ai LO a) E5 coo 0 cc E o v ca ii \ Z Q Q co coo u o co -0 Z >, N 0 1 C -IL.-o QU U 5- Q -,7--0 RSC o m C4 0 O 0 N J r.� Q W r coc a) '0 V) 5` C. 5 c � c �' u).._ :'--' C: "0 D 7 - co coo a) 0 0 as •C c c E c a c a) n- c0 a� a) c0 L 0 .- 'c -o c a) E Q a) 0 (n x E -0 o = a) O uO O O' O- c c0 O) 0 .0 a) rnN2 O).� C - N EOJ < o_ � : �0 O � M •� as ai •- ° O co a 0 3 7) a) U ©0 0 - C_ a) J 0 o `n N rn 3 0 , Q- x as D O D c 'E 3 cn :-_0 - 0 -1 � a) 0_ o _ `- m o � � oi1 .E N O- i_ u) (0 -0 O 0 -0 cn a) c ai c c 0 O ff�`` a) (0 J 0 .1T) Lr) C ,- D O • E O vN. 3 li L 2 J (0 0- O _C 0 CO 0 4 Q cn CAU O '- 0)-,' •• E _O U O _ O O a) L (0 a) - ma) co E � � Y0 � 000- , -c .- en E Q U O (0 C m C 2 r Q- , N -p Q C .. 7 2 t0[) a) a O V a) CO H O N O O U) c > g N c U (n .c E Iz U © 0 0 C).J E• o = O c c o .N O c N a O 2 -0ao o E a) ao0 o_in o F- �• W CMO - roti Q0N • c CU aEi � a 0 - cON � .E EU • � ooU U c0 t° � O . -0 c (Li 0 = 4- d 0 V c •- Y x O O O a u) ` t s a) -0 c a0 as a) - O L. • U co U a) ✓�.L c Y C (n a C }i - O" C CO (O/) C C .0 "� U C= .� O L c 0 0 o co u) Q = o .. N N .-, _ ca U vi C a) m '0 D 0 E m 0) 7 CID 0 CIS Om V O ? O CO "0 "- (L o f 00 CA C U C C r- A) 0 - m Y 0 C V) ..- (n 0 0 (0 C Ce U (0 () 0_ (0 (0 O . p_ � N 0` Q) 0 c u) E c as -o CAS • _c ` � _0 I- > @ a) CL O_ O -0 co as i) TD . V) a) N - 0 u) a) I- ''' c O 0 0 _0 N 7 1- co la -0 E a) (7 3) to 3N- E ' © o_ u) O -cr' • c 3 a) C (0 a) .. 0 E V) CU a) C CA a) '� O 0- L U C U co C U - Y - 0 3 U E = = E c0 CU In- `o c I� YU _� 0dU UY �o = Om (n N 0 -0J Q E c0 a -0N CA0O 0, a) CA O 0 m C N C To Lr) p o U E a) a t .0 o IL ,(4E N- E = c o 0 U L 3 E �. E c0 3 o `0 T rn -OI u0i C m m a o) , eL c c -o L- 0 0 -0 c • N '� c O Cl- a) 3 a o o = - a) - E = c - U U 3 cu �,m o C0 c0 I o -a O H E O c � � Q � J .x a. E. �v J > E -w •- "0 �` C E CA 20 -0 (130 .5_Y 1 .= ,- (1.) o M N C V N O C co p rn Cn 0. o) m e E m a) CO N 0_= O O 0. U 1-- d O 0 U = 0 V O co O U }' " I- C E N ,a Q E U aN Q� LO 3 N O O O c o O N U .� O v •° C U 7 (� 0 °o o U Q o U c • a) U) E U c EO ° U an O C O CA a) N > CCO ' - 1- V c`IO = D o O 0 O O O - CO a TD I- m c0CD N 3 m a c E O o 0 0 a C CO J (0 ._0 ~ CO a) (�0 0 U co O c O --C • E O m U � U o E _ MOOE_ = E � a) o ° � z (a o (a rn O c U I o (u'0 vii M 13 ° c) o ca ` m Q - O c ~ U = ° .-c 2 E C (1) _0 O c - a) 73 1- v • C > C) o) o c ' C N `' O E CO Cs.z -0 c) •c u) d (Q L o (O CA Ip 6" 0) a) o 0. a) E) .c - O m .- Q d -c co c L0 or)-0 0 U c (n - 0 0 c0 4= . -0 .0 EI- 0- a) °- c _0 `n O t_ U c00 2 us D L 0 d = c- O •,- = m a) u) (o a) u) o0 CLw D v c C 3 (1) c o ami ui el_ ( c wn a 7 a) (0 O - as ) 3 o_ U J a) Y 0 CO to a) 0 J a) a) = J II ,+ Q 92 O 0 ((12 '-` N -0 - a) 7 Qin = a) v co -o — c E - v J - mO U c -oY > cn - 0 N O u) (0 u) U CA C_ CAO CT N 10 u) c0 0 o = � � � 3 � � t C '- - = C � a) c Yv, m U C cn c c0 Q Q.o E E o Q co CL _ LE ami ( o o CU a oNc. ." (I) co 0 M o a) a) CU _ .c E 1= 3 o_m5 zJ2 v -0m and E ° U2OdU 2 m O Uo N mO co N n d O � CO -0 c0 OME V2 `1 CI 11:M C N m uJ c r-- o d. Y r` u) a) � � a) (ti N .- CO � � YU d CO CO o o J N O CO CD O c CO .- x ii W a) a) co O ,- v co Y Y Y N 10 N (./) ai v aiai ai `o 2, E )c o Ui0 E U (0 d• (0 ii: Z a p 0 2 Z O Q Z o o in 21 = O U OQ2 ,- C MJUO 0 N 20 CL - cc c� r ai 0 o _ . o O N 2 >O .0 o= 0 �* °) E co 0 0 0_' N O> N ccnO c " ONC N a) O C O a) co � . 0) 0 `) a) O m p - � fl CLv _ � � � .0U cfl a � Y c o 4- co 0 0 0 o 0 O > Q- U C v- U CO O x a) C O -. c La) CL (0 c) 0W C • O N O C Q- E 0 O O QO (o 0 a) co m O o O C a) U C O d ci) 'O 0) O (0 C (0 C O O N C a) LU O E �L W O 0a) (n O a) O J 7:30 a) a) U rL p a) -0 E > ` N C L.L N E +� @ J > -o a) O U C N a) E N a) (o a) cn u p a) cn cn CO C C Q' 7 3 v7 73 O b o O c o o U 4t ? +O+ N C m. 7 CO o C Q 00 W a) 0 2 0 co O a E �c = a) o0. d >O (1.) amia z C O J d. N F A/ > -6 I- c0 .c = c 0w LL a) ca 0 (0 > ) 5 co Q � C H }- 2 - U m o a0i a� 2 _ Cl) E CO (n C (9 OC C JO . a - - •> p oQ (/) a n c " C U OO 0 = c ' H� nE Q — o Q-o s Co a) U• -,0 DCF- C o U O• E (0u O 1- la � 2 co ici c 73(O CO .-. 0U H a) 6 a3 C D L d O - as co O < `•R -0 0 = O co Y O � Q� � a � E = 0 00 0 C N O rnN U) H 13o C > (0 a) 4- 0M a) 2 o a) O CO 0 `i Q QU D 0• 0 c0 a) o `0 Y 02 ) EZ � • Y (0 a) 3 p � � 0 ° rnRS -cCm� o aal cnC� -- •- • .0) t_ U 0 C C ._ � o N a0) ° 0 cn 0 0 0) m M U Ccn 0u- 20 2 EE //-te�l� a) U E a) O C 2 a) p c V U o = 0 3 0. cn D a) cZ coU .4 'Oo = (n N W Q a coV) m '3- O � o a) � ca E � a) o CtS U H co • (o o) o • — a) co = o Z'ot a) 4_-_ c U 2 u) 0 CU Q p O 0 U a) D O _C = a) Q o U O C 00-_o moo)_ co >- C W +-. 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' c 71)- -, C C m (N — LL w e Cl) m g Y Y N & 9 & ® & J ƒ \ \z / z /0 $ / 7 \/o p o o ! � k \ /\ Hilcorp Energy Company Kenai Gas Field KGF 41-18 Pad KBU 32-08 501332062400 Sperry► Drilling Definitive Survey Report 15 July, 2014 I fh !I HALLJBURTON Sperry Qriiiin9 HALLI BURTON CASING DETAILS Hilcorp Tom TVDSS MD Name Size • Sperry Drilling 1419.52 1334.28 1478.00 10-3/4 10 3/4" 5391.33 5306.09 6406.00 7-5/8 7 5/8" 8097.59 8012.35 9746.00 5 5" -500— REFERENCE INFORMATION Co-ordinate(N/E)Reference: Well KBU 32-08,True North Vertical(ND)Reference: KBU 32-08 @ 85.24usft(Saxon 147) 0— Measured Depth Reference: KBU 32-08 @ 85.24usft(Saxon 147) Calculation Method: Minimum Curvature 500— Project: Kenai Gas Field Site: KGF 41-18 PadV Well: KBU 32-08 Wellbore: KBU 32-08 1000— KBU 32-08 10 3/4" Hilcorp Energy Company 1500— Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Closest Approach 3D Error Surface: Elliptical Conic Warning Method: Error Ratio 2000- 2500- 3000— C - i HALLIBURTON CASING DETAILS r Corp TVD JSS MD Name Size j 1419.52 1334.28 1478.00 10-3/4 10 3/4" Sperry Drilling 5391.33 5306.09 6406.00 7-5/8 7 5/8" 8097.59 8012.35 9746.00 5 5" REFERENCE INFORMATION Project: Kenai Gas Field COMPANY DETAILS: Hilcorp Energy Company Co-ordinate(N/E)Reference: Well KBU 32-08,True North Site: KGF41-18 Pad Calculation Method: Minimum Curvature Vertical(TVD)Reference: KBU 32-08©85.24usft(Saxon 147) Well: KBU 32-08 Error System: ISCWSA Measured Depth Reference: KBU 32-08 ll 85.24usft(Saxon 147) Wellbore: KBU 32-08 Scan Method: Closest Approach 3D 4800— Calculation Method: Minimum Curvature KBU 32-08 Error Surface: Elliptical Conic Warning Method: Error Ratio 4500— KBU 32-08 WP5.3 4200— . 95%con£ 5" 3900— KBU 32-08 KBU 32-08 BHL TOT--_ 3600- - 3300— KBU 32-08 WP5.2 3000- 2700- 7 5/8" - 2400— = 8 2100— 0 _ 3 1800— 0 - v1 - 1500- 1200— _ 500-1200— 900- 600— 10 3/4" 300— , 0- -300— -600 I I I I III SI i I I II Ir -600 -300 0 300 600 900 1200 1500 1800 2100 2400 2700 3000 3300 3600 3900 West(-)/East(+)(600 usft/in) Halliburton IiALL16URTON 5pe,,,v or;,,;,, Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well KBU 32-08 Project: Kenai Gas Field TVD Reference: KBU 32-08©85.24usft(Saxon 147) • Site: KGF 41-18 Pad MD Reference: KBU 32-08 @ 85.24usft(Saxon 147) Well: KBU 32-08 North Reference: True Wellbore: KBU 32-08 Survey Calculation Method: Minimum Curvature Design: KBU 32-08 Database: Sperry EDM-NORTH US+CANADA Project Kenai Gas Field Map System: US State Plane 1927(Exact solution) • System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) • Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor • Well KBU 32-08 Well Position +N/-S 0.00 usft Northing: 2,356,184.89 usft Latitude: 60.4436008 +E/-W 0.00 usft Easting: 275,386.82 usft Longitude: -151.2437339 Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 66.64 usft Wellbore KBU 32-08 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2013 2/28/2014 16.96 73.43 55,376 Design KBU 32-08 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 18.60 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 18.96 0.00 0.00 41.64 Survey Program Date 7/15/2014 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 144.16 1,514.00 KBU 32-08(KBU 32-08) MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 02/19/2014 1,514.00 6,418.00 KBU 32-08(KBU 32-08) MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 02/19/2014 6,418.00 9,806.46 KBU 32-08(KBU 32-08) MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 02/19/2014 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (5) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 18.60 0.00 0.00 18.60 -66.64 0.00 0.00 2,356,184.89 275,386.82 0.00 0.00 UNDEFINED 144.16 0.29 100.16 144.16 58.92 -0.06 0.31 2,356,184.83 275,387.13 0.23 0.17 MWD+SC+sag(1) 207.35 0.65 112.65 207.35 122.11 -0.22 0.80 2,356,184.65 275,387.62 0.59 0.37 MWD+SC+sag(1) 268.95 0.59 131.60 268.94 183.70 -0.57 1.36 2,356,184.30 275,388.17 0.35 0.48 MWD+SC+sag(1) 332.85 1.01 121.33 332.84 247.60 -1.08 2.09 2,356,183.77 275,388.89 0.69 0.58 MWD+SC+sag(1) 396.09 0.48 99.15 396.07 310.83 -1.41 2.83 2,356,183.43 275,389.62 0.94 0.82 MWD+SC+sag(1) 454.74 1.12 70.98 454.72 369.48 -1.26 3.61 2,356,183.56 275,390.41 1.25 1.45 MWD+SC+sag(1) 515.00 1.63 62.42 514.96 429.72 -0.67 4.93 2,356,184.12 275,391.73 0.91 2.77 MWD+SC+sag(1) 576.59 2.27 42.10 576.51 491.27 0.64 6.52 2,356,185.40 275,393.35 1.51 4.81 MWD+SC+sag(1) 638.75 3.72 41.96 638.59 553.35 3.05 8.69 2,356,187.77 275,395.57 2.33 8.06 MWD+SC+sag(1) 700.00 4.74 39.13 699.67 614.43 6.49 11.62 2,356,191.16 275,398.56 1.70 12.57 MWD+SC+sag(1) 761.59 6.36 43.52 760.97 675.73 10.94 15.58 2,356,195.53 275,402.60 2.72 18.52 MWD+SC+sag(1) 7/15/2014 12:18:48PM Page 3 COMPASS 5000.1 Build 70 NALLIBURTON Halliburton Sperry C,„,,,;,,, Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well KBU 32-08 Project: Kenai Gas Field TVD Reference: KBU 32-08 @ 85.24usft(Saxon 147) Site: KGF 41-18 Pad MD Reference: KBU 32-08 @ 85.24usft(Saxon 147) Well: KBU 32-08 North Reference: True Wellbore: KBU 32-08 Survey Calculation Method: Minimum Curvature Design: KBU 32-08 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 822.70 9.08 41.50 821.52 736.28 17.01 21.10 2,356,201 49 275,408.24 4.47 26.73 MWD+SC+sag(1) 887.85 12.56 39.34 885.50 800.26 26.34 29.00 2,356,210.67 275,416.31 5.38 38.95 MWD+SC+sag(1) 949.48 15.83 38.67 945.24 860.00 38.09 38.50 2,356,222.24 275,426.03 5.31 54.05 MWD+SC+sag(1) 1,011.34 18.56 38.80 1,004.33 919.09 52.35 49.95 2,356,236.28 275,437.74 4.41 72.31 MWD+SC+sag(1) 1,072.43 20.77 40.12 1,061.85 976.61 68.21 63.02 2,356,251.90 275,451.11 3.69 92.85 MWD+SC+sag(1) 1,132.13 22.94 41.83 1,117.26 1,032.02 84.98 77.60 2,356,268.38 275,466.01 3.79 115.07 MWD+SC+sag(1) 1,194.53 24.85 40.08 1,174.31 1,089.07 104.07 94.16 2,356,287.16 275,482.92 3.26 140.34 MWD+SC+sag(1) 1,255.85 27.09 40.99 1,229.44 1,144.20 124.47 111.61 2,356,307.23 275,500.76 3.71 167.18 MWD+SC+sag(1) 1,316.35 29.28 41,36 1,282.76 1,197.52 145.98 130.43 2,356,328.37 275,519.98 3.63 195.76 MWD+SC+sag(1) 1,381.04 31.51 40,83 1,338.55 1,253.31 170.65 151.94 2,356,352.63 275,541.94 3.47 228.48 MWD+SC+sag(1) 1,442.92 33.78 41,34 1,390.66 1,305.42 195.80 173.87 2,356,377.36 275,564.35 3.70 261.86 MWD+SC+sag(1) 1,473.65 35.28 40.74 1,415.97 1,330.73 208.94 185.31 2,356,390.28 275,576.03 5.01 279.28 MWD+SC+sag(1) 1,536.32 35.95 40.82 1,466.92 1,381.68 236.57 209.15 2,356,417.46 275,600.39 1.07 315.77 MWD+SC+sag(2) 1,600.00 34.90 41.31 1,518.81 1,433.57 264.40 233.39 2,356,444.83 275,625.15 1.71 352.68 MWD+SC+sag(2) 1,662.57 34.69 41.11 1,570.19 1,484.95 291.26 256.92 2,356,471.24 275,649.18 0.38 388.38 MWD+SC+sag(2) 1,724.29 34.84 43.49 1,620.90 1,535.66 317.29 280.60 2,356,496.81 275,673.35 2.21 423.56 MWD+SC+sag(2) 1,786.69 36.01 44.30 1,671.74 1,586.50 343.35 305.68 2,356,522.39 275,698.91 2.02 459.70 MWD+SC+sag(2) 1,848.96 38.18 43.10 1,721.41 1,636.17 370.51 331.62 2,356,549.05 275,725.36 3.67 497.23 MWD+SC+sag(2) 1,910.80 38.39 41.82 1,769.95 1,684.71 398.77 357.48 2,356,576.83 275,751.75 1.33 535.54 MWD+SC+sag(2) 1,972.29 37.49 42.55 1,818.45 1,733.21 426.79 382.86 2,356,604.35 275,777.66 1.64 573.35 MWD+SC+sag(2) 2,032.85 36.92 41.60 1,866.68 1,781.44 453.97 407.40 2,356,631.06 275,802.71 1.34 609.96 MWD+SC+sag(2) 2,093.70 36.76 42.46 1,915.38 1,830.14 481.07 431.83 2,356,657.70 275,827.64 0.89 646.45 MWD+SC+sag(2) 2,158.79 36.27 41.55 1,967.69 1,882.45 509.84 457.75 2,356,685.98 275,854.09 1.12 685.18 MWD+SC+sag(2) 2,220.87 35.44 42.32 2,018.01 1,932.77 536.90 482.05 2,356,712.57 275,878.90 1.52 721.54 MWD+SC+sag(2) 2,283.16 36.38 41.58 2,068.46 1,983.22 564.07 506.47 2,356,739.27 275,903.83 1.66 758.07 MWD+SC+sag(2) 2,344.85 36.00 42.23 2,118.25 2,033.01 591.18 530.79 2,356,765.92 275,928.66 0.88 794.49 MWD+SC+sag(2) 2,405.12 34.99 42.09 2,167.32 2,082.08 617.12 554.28 2,356,791.41 275,952.63 1.68 829.49 MWD+SC+sag(2) 2,468.99 35.51 42.28 2,219.48 2,134.24 644.43 579.04 2,356,818.25 275,977.90 0.83 866.35 MWD+SC+sag(2) 2,532.71 35.17 42.08 2,271.45 2,186.21 671.74 603.79 2,356,845.09 276,003.16 0.56 903.20 MWD+SC+sag(2) 2,593.61 36.06 42.34 2,320.96 2,235.72 698.01 627.61 2,356,870.90 276,027.47 1.48 938.66 MWD+SC+sag(2) 2,652.39 36.56 42.50 2,368.33 2,283.09 723.71 651.09 2,356,896.14 276,051.43 0.87 973.47 MWD+SC+sag(2) 2,717.56 37.52 41.87 2,420.35 2,335.11 752.80 677.45 2,356,924.73 276,078.34 1.58 1,012.72 MWD+SC+sag(2) 2,779.57 38.06 41.44 2,469.35 2,384.11 781.19 702.71 2,356,952.64 276,104.12 0.97 1,050.72 MWD+SC+sag(2) 2,839.00 37.53 40.68 2,516.31 2,431.07 808.65 726.63 2,356,979.64 276,128.56 1.19 1,087.14 MWD+SC+sag(2) 2,904.92 37.18 40.47 2,568.71 2,483.47 839.03 752.65 2,357,009.52 276,155.14 0.57 1,127.13 MWD+SC+sag(2) 2,967.38 36.76 41.40 2,618.62 2,533.38 867.40 777.25 2,357,037.43 276,180.28 1.12 1,164.69 MWD+SC+sag(2) 3,027.31 36.19 41.42 2,666.81 2,581.57 894.12 800.82 2,357,063.70 276,204.35 0.95 1,200.31 MWD+SC+sag(2) 3,090.50 35.89 40.75 2,717.90 2,632.66 922.15 825.25 2,357,091.25 276,229.30 0.78 1,237.49 MWD+SC+sag(2) 3,151.46 35.67 41.04 2,767.36 2,682.12 949.09 848.59 2,357,117.75 276,253.14 0.46 1,273.13 MWD+SC+sag(2) 3,214.48 36.64 41.09 2,818.24 2,733.00 977.12 873.01 2,357,145.31 276,278.09 1.54 1,310.31 MWD+SC+sag(2) 7/15/2014 12.18:48PM Page 4 COMPASS 5000.1 Build 70 MHalliburton ALLIBURTON „°,,,.w�,r,,,;� Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well KBU 32-08 Project: Kenai Gas Field TVD Reference: KBU 32-08 @ 85.24usft(Saxon 147) Site: KGF 41-18 Pad MD Reference: KBU 32-08 @ 85.24usft(Saxon 147) Well: KBU 32-08 North Reference: True Wellbore: KBU 32-08 Survey Calculation Method: Minimum Curvature Design: KBU 32-08 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,276.58 36.97 42.04 2,867.96 2,782.72 1,004.95 897.69 2,357,172.67 276,303.29 1.06 1,347.51 MWD+SC+sag(2) 3,338.74 36.76 41.45 2,917.70 2,832.46 1,032.78 922.52 2,357,200.02 276,328.64 0.66 1,384.80 MWD+SC+sag(2) 3,400.35 36.50 42.14 2,967.14 2,881.90 1,060.18 947.02 2,357,226.96 276,353.65 0.79 1,421.56 MWD+5C+sag(2) 3,462.99 36.34 41.55 3,017.54 2,932.30 1,087.89 971.83 2,357,254.19 276,378.98 0.61 1,458.75 MWD+SC+sag(2) 3,524.98 36.13 41.88 3,067.54 2,982.30 1,115.24 996.21 2,357,281.07 276,403.87 0.46 1,495.39 MWD+SC+sag(2) 3,587.67 35.79 42.38 3,118.29 3,033.05 1,142.54 1,020.91 2,357,307.90 276,429.08 0.72 1,532.20 MWD+SC+sag(2) 3,646.28 35.65 41.92 3,165.87 3,080.63 1,167.91 1,043.87 2,357,332.83 276,452.51 0.52 1,566.42 MWD+SC+sag(2) 3,709.50 35.19 42.27 3,217.39 3,132.15 1,195.10 1,068.43 2,357,359.55 276,477.58 0.80 1,603.05 MWD+SC+sag(2) 3,772.33 35.33 41.89 3,268.69 3,183.45 1,222.02 1,092.74 2,357,386.01 276,502.39 0.41 1,639.32 MWD+SC+sag(2) 3,831.39 35.27 41.73 3,316.90 3,231.66 1,247.46 1,115.49 2,357,411.01 276,525.62 0.19 1,673.45 MWD+SC+sag(2) 3,893.07 34.85 42.29 3,367.38 3,282.14 1,273.78 1,139.20 2,357,436.88 276,549.82 0.86 1,708.88 MWD+SC+sag(2) 3,956.31 34,45 42.17 3,419.41 3,334.17 1,300.41 1,163.37 2,357,463.04 276,574.49 0.64 1,744.84 MWD+SC+sag(2) 4,018.59 34.45 41.58 3,470.77 3,385.53 1,326.64 1,186.89 2,357,488.83 276,598.49 0.54 1,780.07 MWD+SC+sag(2) 4,080.26 34.24 41.44 3,521.68 3,436.44 1,352.69 1,209.94 2,357,514.44 276,622.04 0.36 1,814.86 MWD+SC+sag(2) 4,143.20 34.75 41.58 3,573.56 3,488.32 1,379.38 1,233.57 2,357,540.68 276,646.16 0.82 1,850.50 MWD+SC+sag(2) 4,203.29 34.61 42.05 3,622.97 3,537.73 1,404.87 1,256.36 2,357,565.72 276,669.43 0.50 1,884.69 MWD+SC+sag(2) 4,267.31 34.95 42.40 3,675.55 3,590.31 1,431.91 1,280.91 2,357,592.30 276,694.48 0.62 1,921.21 MWD+SC+sag(2) 4,324.50 36.05 42.73 3,722.11 3,636.87 1,456.37 1,303.37 2,357,616.33 276,717.40 1.95 1,954.42 MWD+SC+sag(2) 4,389.33 36.75 42.88 3,774.29 3,689.05 1,484.59 1,329.51 2,357,644.05 276,744.07 1.09 1,992.88 MWD+SC+sag(2) 4,450.44 36.94 42.89 3,823.20 3,737.96 1,511.44 1,354.45 2,357,670.42 276,769.51 0.31 2,029.52 MWD+SC+sag(2) 4,512.33 36.64 42.79 3,872.76 3,787.52 1,538.62 1,379.65 2,357,697.12 276,795.22 0.49 2,066.57 MWD+SC+sag(2) 4,573.05 37.17 41.90 3,921.31 3,836.07 1,565.57 1,404.21 2,357,723.60 276,820.28 1.24 2,103.03 MWD+SC+sag(2) 4,635.52 37.22 41.36 3,971.08 3,885.84 1,593.80 1,429.30 2,357,751.35 276,845.90 0.53 2,140.80 MWD+SC+sag(2) 4,698.10 37.00 41.35 4,020.98 3,935.74 1,622.14 1,454.25 2,357,779.21 276,871.37 0.35 2,178.55 MWD+SC+sag(2) 4,760.72 36.59 41.23 4,071.13 3,985.89 1,650.32 1,479.00 2,357,806.92 276,896.65 0.66 2,216.06 MVVD+SC+sag(2) 4,822.25 37.30 41.74 4,120.30 4,035.06 1,678.02 1,503.49 2,357,834.16 276,921.67 1.26 2,253.04 MWD+SC+sag(2) 4,882.84 36.98 42.17 4,168.60 4,083.36 1,705.23 1,527.95 2,357,860.89 276,946.63 0.68 2,289.62 MWD+SC+sag(2) 4,942.42 36.68 42.21 4,216.29 4,131.05 1,731.69 1,551.94 2,357,886.90 276,971.11 0.51 2,325.33 MWD+SC+sag(2) 5,009.09 36.78 41.70 4,269.73 4,184.49 1,761.34 1,578.59 2,357,916.04 276,998.32 0.48 2,365.20 MWD+SC+sag(2) 5,071.06 37.03 40.98 4,319.28 4,234.04 1,789.28 1,603.17 2,357,943.51 277,023.42 0.81 2,402.42 MWD+SC+sag(2) 5,127.51 36.62 41.13 4,364.47 4,279.23 1,814.80 1,625.39 2,357,968.59 277,046.12 0.74 2,436.25 MWD+SC+sag(2) 5,195.04 37.03 40.75 4,418.52 4,333.28 1,845.37 1,651.91 2,357,998.66 277,073.21 0.69 2,476.72 MWD+SC+sag(2) 5,256.48 37.79 39.66 4,467.32 4,382.08 1,873.88 1,676.01 2,358,026.71 277,097.84 1.64 2,514.03 MWD+SC+sag(2) 5,318.82 38.21 38.96 4,516.45 4,431.21 1,903.58 1,700.32 2,358,055.94 277,122.71 0.97 2,552.38 MWD+SC+sag(2) 5,381.82 37.96 38.73 4,566.04 4,480.80 1,933.84 1,724.69 2,358,085.74 277,147.65 0.46 2,591.20 MWD+SC+sag(2) 5,436.80 37.72 38.90 4,609.46 4,524.22 1,960.12 1,745.83 2,358,111.61 277,169.28 0.48 2,624.88 MWD+SC+sag(2) 5,504.91 37.37 39.02 4,663.46 4,578.22 1,992.40 1,771.93 2,358,143.39 277,195.98 0.52 2,666.34 MWD+SC+sag(2) 5,565.43 36.96 39.72 4,711.69 4,626.45 2,020.66 1,795.12 2,358,171.21 277,219.70 0.97 2,702.87 MWD+SC+sag(2) 5,627.68 36.92 39.73 4,761.44 4,676.20 2,049.43 1,819.03 2,358,199.52 277,244.15 0.06 2,740.26 MWD+SC+sag(2) 5,687.48 36.11 41.25 4,809.50 4,724.26 2,076.50 1,842.13 2,358,226.14 277,267.75 2.03 2,775.84 MWD+SC+sag(2) 7/15/2014 12:18:48PM Page 5 COMPASS 5000.1 Build 70 Halliburton HALLIBURTON Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well KBU 32-08 Project: Kenai Gas Field TVD Reference: KBU 32-08 @ 85.24usft(Saxon 147) Site: KGF 41-18 Pad MD Reference: KBU 32-08©85.24usft(Saxon 147) Well: KBU 32-08 North Reference: True Wellbore: KBU 32-08 Survey Calculation Method: Minimum Curvature Design: KBU 32-08 Database: Sperry EDM-NORTH US+CANADA - - I Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 5,748.21 35.86 41.40 4,858.64 4,773.40 2,103.29 1,865.69 2,358,252.49 277,291.82 0.44 2,811.52 MWD+SC+sag(2) 5,808.99 35.74 41.64 4,907.94 4,822.70 2,129.91 1,889.26 2,358,278.66 277,315.88 0.30 2,847.07 MWD+SC+sag(2) 5,873.20 35.61 42.01 4,960.10 4,874.86 2,157.82 1,914.23 2,358,306.09 277,341.37 0.39 2,884.52 MWD+SC+sag(2) 5,933.51 35.48 41.81 5,009.17 4,923.93 2,183.91 1,937.65 2,358,331.73 277,365.28 0.29 2,919.58 MWD+SC+sag(2) 5,998.46 35.49 41.89 5,062.06 4,976.82 2,211.99 1,962.81 2,358,359.33 277,390.96 0.07 2,957.28 MWD+SC+sag(2) 6,059.98 36.03 42.31 5,111.98 5,026.74 2,238.67 1,986.91 2,358,385.55 277,415.56 0.96 2,993.23 MWD+SC+sag(2) 6,123.76 36.61 43.12 5,163.37 5,078.13 2,266.42 2,012.54 2,358,412.81 277,441.71 1.18 3,031.00 MWD+SC+sag(2) 6,188.12 36.40 43.32 5,215.10 5,129.86 2,294.32 2,038.76 2,358,440.21 277,468.45 0.38 3,069.27 MWD+SC+sag(2) 6,248.77 36.29 43.35 5,263.95 5,178.71 2,320.47 2,063.42 2,358,465.88 277,493.60 0.18 3,105.20 MWD+SC+sag(2) 6,299.81 35.97 43.38 5,305.18 5,219.94 2,342.35 2,084.09 2,358,487.37 277,514.67 0.63 3,135.28 MWD+SC+sag(2) 6,371.94 35.71 43.36 5,363.65 5,278.41 2,373.05 2,113.09 2,358,517.51 277,544.25 0.36 3,177.50 MWD+SC+sag(2) 6,418.40 35.49 43.09 5,401.43 5,316.19 2,392.75 2,131.61 2,358,536.87 277,563.14 0.58 3,204.53 MWD+SC+sag(3) 6,482.81 35.69 42.98 5,453.81 5,368.57 2,420.15 2,157.19 2,358,563.78 277,589.23 0.33 3,242.01 MWD+SC+sag(3) 6,542.86 35.70 42.81 5,502.57 5,417.33 2,445.82 2,181.04 2,358,588.99 277,613.56 0.17 3,277.04 MWD+SC+sag(3) 6,605.48 35.55 41.74 5,553.48 5,468.24 2,472.81 2,205.58 2,358,615.51 277,638.60 1.02 3,313.51 MWD+SC+sag(3) 6,668.96 35.89 41.94 5,605.01 5,519.77 2,500.42 2,230.30 2,358,642.65 277,663.84 0.57 3,350.57 MWD+SC+sag(3) 6,729.79 36.06 40.90 5,654.24 5,569.00 2,527.22 2,253.94 2,358,668.99 277,687.98 1.04 3,386.30 MWD+SC+sag(3) 6,791.46 36.51 40.76 5,703.95 5,618.71 2,554.83 2,277.80 2,358,696.15 277,712.36 0.74 3,422.79 MWD+SC+sag(3) 6,853.24 36.80 41.59 5,753.52 5,668.28 2,582.59 2,302.08 2,358,723.44 277,737.16 0.93 3,459.67 MWD+SC+sag(3) 6,915.28 37.08 41.33 5,803.10 5,717.86 2,610.53 2,326.77 2,358,750.91 277,762.37 0.52 3,496.96 MWD+SC+sag(3) 6,977.29 36.89 42.05 5,852.64 5,767.40 2,638.39 2,351.58 2,358,778.30 277,787.70 0.76 3,534.26 MWD+SC+sag(3) 7,039.01 36.93 42.39 5,901.99 5,816.75 2,665.84 2,376.49 2,358,805.27 277,813.12 0.34 3,571.33 MWD+SC+sag(3) 7,101.70 37.03 42.15 5,952.07 5,866.83 2,693.75 2,401.85 2,358,832.69 277,839.00 0.28 3,609.03 MWD+SC+sag(3) 7,164.62 37.06 42.11 6,002.29 5,917.05 2,721.86 2,427.28 2,358,860.31 277,864.96 0.06 3,646.94 MWD+SC+sag(3) 7,227.09 37.01 41.58 6,052.15 5,966.91 2,749.89 2,452.38 2,358,887.86 277,890.58 0.52 3,684.56 MWD+SC+sag(3) 7,287.68 37.03 41.27 6,100.53 6,015.29 2,777.24 2,476.52 2,358,914.76 277,915.23 0.31 3,721.04 MWD+SC+sag(3) 7,350.19 36.13 41.89 6,150.73 6,065.49 2,805.11 2,501.24 2,358,942.15 277,940.47 1.56 3,758.30 MVVD+SC+sag(3) 7,413.14 36.01 41.72 6,201.61 6,116.37 2,832.74 2,525.94 2,358,969.31 277,965.69 0.25 3,795.36 MWD+SC+sag(3) 7,473.97 35.90 41.73 6,250.85 6,165.61 2,859.39 2,549.72 2,358,995.51 277,989.96 0.18 3,831.08 MWD+SC+sag(3) 7,536.38 35.80 41.68 6,301.44 6,216.20 2,886.68 2,574.03 2,359,022.33 278,014.79 0.17 3,867.63 MWD+SC+sag(3) 7,599.17 35.74 41.63 6,352.38 6,267.14 2,914.10 2,598.43 2,359,049.29 278,039.70 0.11 3,904.33 M1M3+SC+sag(3) 7,660.54 35.82 42.32 6,402.17 6,316.93 2,940.78 2,622.42 2,359,075.50 278,064.19 0.67 3,940.21 MWD+SC+sag(3) 7,723.31 35.66 42.37 6,453.12 6,367.88 2,967.88 2,647.12 2,359,102.13 278,089.40 0.26 3,976.87 MWD+SC+sag(3) 7,784.60 35.35 42.39 6,503.01 6,417.77 2,994.17 2,671.11 2,359,127.96 278,113.88 0.51 4,012.46 MWD+SC+sag(3) 7,846.95 35.26 41.78 6,553.90 6,468.66 3,020.91 2,695.27 2,359,154.24 278,138.53 0.58 4,048.50 MWD+SC+sag(3) 7,909.05 35.34 41.84 6,604.58 6,519.34 3,047.66 2,719.19 2,359,180.53 278,162.95 0.14 4,084.38 MWD+SC+sag(3) 7,970.20 35.34 41.65 6,654.46 6,569.22 3,074.05 2,742.74 2,359,206.47 278,187.00 0.18 4,119.75 MWD+SC+sag(3) 8,029.41 35.36 41.67 6,702.75 6,617.51 3,099.65 2,765.51 2,359,231.63 278,210.25 0.04 4,154.01 MWD+SC+sag(3) 8,094.41 35.38 41.77 6,755.76 6,670.52 3,127.73 2,790.55 2,359,259.24 278,235.81 0.09 4,191.63 MWD+SC+sag(3) 8,155.41 35.64 41.83 6,805.41 6,720.17 3,154.14 2,814.17 2,359,285.20 278,259.92 0.43 4,227.07 MWD+SC+sag(3) 7/15/2014 12:18:48PM Page 6 COMPASS 5000.1 Build 70 HHalliburton ALLIBURTON , $pa,.ry(=Willing Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well KBU 32-08 Project: Kenai Gas Field TVD Reference: KBU 32-08 @ 85.24usft(Saxon 147) Site: KGF 41-18 Pad MD Reference: KBU 32-08 @ 85.24usft(Saxon 147) Well: KBU 32-08 North Reference: True Wellbore: KBU 32-08 Survey Calculation Method: Minimum Curvature Design: KBU 32-08 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,220.00 35.82 41.97 6,857.84 6,772.60 3,182.22 2,839.36 2,359,312.79 278,285.63 0.31 4,264.78 MWD+SC+sag(3) 8,280.11 35.62 42.07 6,906.65 6,821.41 3,208.29 2,862.85 2,359,338.41 278,309.61 0.35 4,299.88 MWD+SC+sag(3) 8,341.33 35.45 42.12 6,956.47 6,871.23 3,234.69 2,886.70 2,359,364.36 278,333.96 0.28 4,335.46 MWD+SC+sag(3) 8,401.67 36.37 43.19 7,005.34 6,920.10 3,260.71 2,910.68 2,359,389.93 278,358.43 1.85 4,370.84 MWD+SC+sag(3) 8,466.70 37.35 42.69 7,057.37 6,972.13 3,289.27 2,937.25 2,359,417.98 278,385.53 1.58 4,409.84 MWD+SC+sag(3) 8,528.66 37.04 42.13 7,106.72 7,021.48 3,316.93 2,962.52 2,359,445.15 278,411.31 0.74 4,447.29 MWD+SC+sag(3) 8,590.80 37.53 42.31 7,156.16 7,070.92 3,344.80 2,987.81 2,359,472.54 278,437.13 0.81 4,484.93 MWD+SC+sag(3) 8,652.33 37.31 41.77 7,205.03 7,119.79 3,372.57 3,012.85 2,359,499.83 278,462.68 0.64 4,522.32 MWD+SC+sag(3) 8,714.17 36.93 41.45 7,254.34 7,169.10 3,400.47 3,037.63 2,359,527.26 278,487.99 0.69 4,559.64 MWD+SC+sag(3) 8,776.36 36.58 41.31 7,304.17 7,218.93 3,428.40 3,062.23 2,359,554.71 278,513.11 0.58 4,596.85 MWD+SC+sag(3) 8,838.67 36.91 41.30 7,354.10 7,268.86 3,456.40 3,086.84 2,359,582.24 278,538.24 0.53 4,634.13 MWD+SC+sag(3) 8,899.88 36.68 40.80 7,403.11 7,317.87 3,484.05 3,110.91 2,359,609.43 278,562.83 0.62 4,670.79 MWD+SC+sag(3) 8,962.50 36.48 41.29 7,453.40 7,368.16 3,512.19 3,135.42 2,359,637.10 278,587.86 0.57 4,708.11 MWD+SC+sag(3) 9,023.77 36.31 41.03 7,502.72 7,417.48 3,539.56 3,159.35 2,359,664.02 278,612.30 0.37 4,744.46 MWD+SC+sag(3) 9,085.72 36.13 40.76 7,552.70 7,467.46 3,567.23 3,183.31 2,359,691.23 278,636.78 0.39 4,781.06 MWD+SC+sag(3) 9,149.28 35.80 40.98 7,604.14 7,518.90 3,595.46 3,207.74 2,359,718.99 278,661.74 0.56 4,818.39 MWD+SC+sag(3) 9,210.56 35.68 40.87 7,653.88 7,568.64 3,622.51 3,231.18 2,359,745.59 278,685.69 0.22 4,854.18 MWD+SC+sag(3) 9,272.61 35.56 40.61 7,704.32 7,619.08 3,649.89 3,254.77 2,359,772.52 278,709.79 0.31 4,890.31 MWD+SC+sag(3) 9,333.16 35.31 40.76 7,753.65 7,668.41 3,676.51 3,277.65 2,359,798.70 278,733.17 0.44 4,925.41 MWD+SC+sag(3) 9,397.25 34.79 40.58 7,806.12 7,720.88 3,704.42 3,301.64 2,359,826.16 278,757.68 0.83 4,962.21 MWD+SC+sag(3) 9,459.78 34.34 40.34 7,857.61 7,772.37 3,731.42 3,324.66 2,359,852.71 278,781.20 0.75 4,997.68 MWD+SC+sag(3) 9,521.92 33.70 40.32 7,909.12 7,823.88 3,757.92 3,347.16 2,359,878.78 278,804.20 1.03 5,032.44 MWD+SC+sag(3) 9,583.92 32.94 40.00 7,960.93 7,875.69 3,783.95 3,369.13 2,359,904.39 278,826.65 1.26 5,066.48 MWD+SC+sag(3) 9,645.20 32.48 40.02 8,012.49 7,927.25 3,809.31 3,390.42 2,359,929.34 278,848.41 0.75 5,099.58 MWD+SC+sag(3) 9,707.85 32.41 40.06 8,065.36 7,980.12 3,835.04 3,412.04 2,359,954.66 278,870.52 0.12 5,133.18 MWD+SC+sag(3) 9,769.67 32.23 40.07 8,117.60 8,032.36 3,860.34 3,433.31 2,359,979.55 278,892.27 0.29 5,166.22 MWD+SC+sag(3) 9,806.46 31.89 39.96 8,148.78 8,063.54 3,875.29 3,445.87 2,359,994.26 278,905.10 0.94 5,185.74 MWD+SC+sag(3) • 9,847.00 31.89 39.96 8,183.20 • 8,097.96 3,891.71 3,459.62 2,360,010.42 278,919.16 0.00 5,207.15 PROJECTED to TD Checked By: Cary Taylor _-2,,.»� - Approved By: Date: 0C(//Z /KpP 7/15/2014 12.18:48PM Page 7 COMPASS 5000.1 Build 70 KBU 32-08 Days Vs Depth 0 1000 KBU 32-08 ACTUAL KBU 32-08 PLAN 2000 3000 4000 5000 r CU 6000 z f4 7000 8000 9000 \k, 10000 11000 12000 0 5 10 15 20 25 30 35 40 Days KBU 32-08 MW Vs Depth 0 500 1000 1500 2000 2500 3000 3500 4000 MW vs Depth 4500 -KBU 32-08 PLAN t aa, 5000 s- 5500 co m 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 8 9 10 11 12 13 14 Mud Density(ppg) • Hilcorp Energy Company CASING &CEMENTING REPORT Lease&Well No. Kenai Beluga Unit, KBU 32-08 Date 21-Feb-14 County Kenai State Alaska Supv. ,r Farrell CASING RECORD SAf( � TD 1514.00 Shoe Depth: 1478.00 PBTD: Drilled Out Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top Shoe 10 3/4 45.5 L-80 BTC WOT 1.96 1,478.00 1,476.04 2 10 3/4 45.5 L-80 BTC 81.93 1,476.04 1,394.11 Float Clr 10 3/4 45.5 L-80 BTC WOT 1.42 1,394.11 1,392.69 33 10 3/4 45.5 L-80 BTC 1,341.01 1,392.69 51.68 PUP 10 3/4 45.5 L-80 BTC 18.88 51.68 32.80 PUP 10 3/4 45.5 _ L-80 BTC 8.00 32.80 24.80 PUP 10 3/4 45.5 L-80 BTC 2.15 24.80 22.65 Hanger 0.65 22.65 22.00 RKB 22.00 22.00 0.00 Totals Csg Wt.On Hook: 75,000 Type Float Collar: WOT 403 No.Hrs to Run: 8 Csg Wt.On Slips: 57,000 Type of Shoe: Bull Nose Casing Crew: WOT Fluid Description: 9.8 ppg Spud Mud Liner hanger Info(Make/Model): Liner top Packer?: Yes _No Liner hanger test pressure: Centralizer Placement: 1 per joint of shoe track,then every other joint to 130 ft.Total of 18 centralizers run. CEMENTING REPORT Preflush(Spacer) Type: Mud Clean Density(ppg) 8.6 Volume pumped(BBLs) 25 Lead Slurry Type: Type 1 Yield: 2.13 Density(ppg) 12.5 Volume pumped(BBLs/sx) 101 /264 Mixing I Pumping Rate(bpm): 4.3 Tail Slurry Type: Type 1 Yield: 1.25 t Density(ppg) 15.2 Volume pumped(BBLs/sx) 58.77/264 Mixing/Pumping Rate(bpm): 3.6 I- Post Flush(Spacer) co Type: Density(ppg) Rate(bpm): Volume: CC I Displacement: Type: Mud Density(ppg) 9.6 Rate(bpm): 5.5 Volume(actual/calculated): 132/135.6 FCP(psi): 961 Pump used for disp: Baker Plug Bumped? X Yes No Bump press 1461 Casing Rotated? Yes X No Reciprocated? Yes X No 100 %Returns during job Cement returns to surface? X Yes _No Spacer returns? X Yes No Vol to Surf: 22 bbls Cement Cement In Place At: 17:12 Date: 2/21/2014 Estimated TOC: Surface Method Used To Determine TOC: Returns to surface Preflush(Spacer) Type: Density(ppg) Volume pumped(BBLs) Lead Slurry Type: Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): Tail Slurry w Type: a Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): 1- o) Post Flush(Spacer) 0 z Type: Density(ppg) Rate(bpm): Volume: 0 w Displacement: u) Type: Density(ppg) Rate(bpm): Volume(actual/calculated): FCP(psi): Pump used for disp: Plug Bumped? Yes No Bump press Casing Rotated? Yes No Reciprocated? _Yes _No %Returns during job Cement returns to surface? Yes No Spacer returns?_Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Post Job Calculations: Calculated Cmt Vol @ 0%excess: 108 bbls Total Volume cmt Pumped: 101 (lead)+59(tail)=160 bbls Cmt returned to surface: 22 bbls Calculated cement left in wellbore: 160-22=138 bbls OH volume Calculated: 90 bbls OH volume actual: 120 bbls Actual%Washout: (120/90)-1 =33% • Hilcorp Energy Company CASING &CEMENTING REPORT Lease&Well No. KBU 32-08 Date 3-Mar-14 County kenai State Alaska Supv. FARRELL/YESSAK CASING RECORD TD 6418.00 Shoe Depth: 6405.00 PBTD: Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top SHOE 7 5/8 29.7 L-80 IBT wft 3.00 6,405.29 6,402.29 2 7 5/8 29.7 L-80 IBT 82.22 6,402.29 6,320.07 FLT CLR 7 5/8 29.7 L-80 IBT wft 1.35 6,320.07 6,318.72 152 7 5/8 29.7 L-80 IBT 6,266.07 6,318.72 52.65 Pup 7 5/8 29.7 L-80 IBT 19.95 52.65 32.70 Pup 7 5/8 29.7 L-80 IBT 10.10 32.70 22.60 Pup 7 5/8 29.7 L-80 IBT 2.20 22.60 20.40 Hanger 0.40 20.40 20.00 RKB 20.00 20.00 0.00 Totals Csg Wt.On Hook: 177k Type Float Collar: WEATHER FORD No.Hrs to Run: 8 Csg Wt.On Slips: N/A Type of Shoe: WFT Casing Crew: tesco Fluid Description: Klay-Shield Liner hanger Info(Make/Model): CAMERON Liner top Packer?: _Yes x No Liner hanger test pressure: 5000 Centralizer Placement: 1 per joint on shoe track and then every other one to 1565.60 centralizers total. CEMENTING REPORT Preflush(Spacer) Type: Seal Bond Density(ppg) 9.8 Volume pumped(BBLs) 39 Lead Slurry Type: TYPE 1 yield 3.3 Density(ppg) 10.5 Volume pumped(BBLs) 227 Mixing/Pumping Rate(bpm): 5 Tail Slurry Type: TYPE 1 yield 1.8 161 Density(ppg) 13.5 Volume pumped(BBLs) 34 Mixing/Pumping Rate(bpm): 5 I- Post Flush(Spacer) Type: Density(ppg) Rate(bpm): Volume: ce L Displacement: Type: MUD Density(ppg) 9.8 Rate(bpm): 5 Volume(actual/calculated): 290/290 FCP(psi): 300 Pump used for disp: baker Plug Bumped? X Yes No Bump press 1000 Casing Rotated? Yes X No Reciprocated? Yes X No 100 %Returns during job Cement returns to surface? X Yes No Spacer returns? X Yes No Vol to Surf: 40 Cement In Place At: 11:47 Date: 3/3/2014 Estimated TOC: Method Used To Determine TOC: CBL ORDERED OUT Preflush(Spacer) Type: Density(ppg) Volume pumped(BBLs) Lead Slurry Type: Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): Tail Slurry w Type: Q Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): w Post Flush(Spacer) 0 Type: o Density(ppg) Rate(bpm): Volume: o0 Displacement: co Type: Density(ppg) Rate(bpm): Volume(actual/calculated): FCP(psi): Pump used for disp: Plug Bumped? Yes No Bump press Casing Rotated? Yes No Reciprocated? Yes No %Returns during job Cement returns to surface? Yes No Spacer returns? Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: h Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No. KBU 32-08 Date 15-Mar-14 County Kenai State Alaska Supv. Leslie/Lott CASING RECORD TD 9847.00 Shoe Depth: 9745.56 PBTD: 9657.00 Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top SHOE 61/4 18 L-80 DWC wft 2.40 9,745.56 9,743.16 2 5 18 L-80 DWC 84.02 9,743.16 9,659.14 FLT CLR 5 18 L-80 DWC wft _ 1.40 _ 9,659.14 9,657.74 40 joints 5 18 L-80 _ DWC 1,624.47 9,657.74 8,033.27 RA Pup 5 18 L-80 _ DWC _ 4.98 8,033.27 8,028.29 17 5 18 L-80 DWC 692.82 8,028.29 7,335.47 RA Pup 5 18 L-80 DWC 5.00 7,335.47 7,330.47 36 5 18 L-80 DWC 1,466.65 7,330.47 5,863.82 Pup 5 18 L-80 _ DWC 3.65 5,863.82 5,860.17 Swell Packer 6 X 10 18 L-80 DWC TAM _ 10.70 _ 5,860.17 5,849.47 Pup 5 18 L-80 DWC _ 4.38 5,849.47 5,845.09 Pup 5 18 _ L-80 _ DWC _ 10.03 5,845.09 5,835.06 141 Joints 5 18 L-80 _ DWC 5,811.93 5,835.06 23.13 Pup 5 18 L-80 DWC _ 4.33 23.13 18.80 Hanger 11 Sea Board 0.50 18.80 18.30 RKB _ 18.30 18.30 0.00 Totals 9,745.56 Csg Wt.On Hook: 150600 Type Float Collar: WEATHER FORD No.Hrs to Run: 16.5 Csg Wt.On Slips: N/A Type of Shoe: WFT Reamer Casing Crew: Tesco Fluid Description: Klay-Shield Liner hanger Info(Make/Model): NA Liner top Packer?: _Yes No Liner hanger test pressure: Centralizer Placement: Every Joint for first 82 Joints run CEMENTING REPORT Preflush(Spacer) Type: Seal Bond Density(ppg) 11.2 Volume pumped(BBLs) 37 Lead Slurry Type: G yield 1.180 Density(ppg) 15.7 Volume pumped(BBLs) 114 Mixing/Pumping Rate(bpm): 4.2 Tail Slurry Type: 1 Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): co Post Flush(Spacer) Type: Density(ppg) Rate(bpm): Volume: c L Displacement: Type: MUD Density(ppg) 10.7 Rate(bpm): 5.9 Volume(actual/calculated): 176/172 FCP(psi): 2350 Pump used for disp: Baker Plug Bumped? X Yes No Bump press 3720 Casing Rotated? Yes X No Reciprocated? Yes X No 100 %Returns during job YES Cement returns to surface? Yes X No Spacer returns? Yes X No Vol to Surf: 0 Cement In Place At: 18:10 Date: 3/15/2014 Estimated TOC: 4,600 Method Used To Determine TOC: Calculation C1 (--- ,^ - TO L a..t l-(5[:i, -f-, fitt„�l.Qa- A-,:-.X_ -._ 6v��+c— TO Preflush(Spacer) e Type: Density(ppg) Volume pumped(BBLs) Lead Slurry 054 Type: ?'Z`?.rS_ Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): Tail Slurry Lu Type: Tt Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): ~ Post Flush(Spacer) 0 Type: o Density(ppg) Rate(bpm): Volume: 0 w Displacement: Co Type: Density(ppg) Rate(bpm): Volume(actual/calculated): FCP(psi): Pump used for disp: Plug Bumped? Yes No Bump press Casing Rotated? Yes No Reciprocated? Yes No %Returns during job 1 Cement returns to surface? Yes No Spacer returns? Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: I N\\I%7,cs, THE STATE Al c'ka an an Ca 'tt_ 333 West Seventh Avenue i-- — Anchorage• Alaska 99501-3572 <' .," Moro 907 279 1233 als" F:,> c9C7 77, ''-' Paul Chan Senior Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Kenai Gas Field, Upper Tyonek and Beluga Gas Pools, Kenai Beluga Unit 32-08 Sundry Number: 314-383 Dear Mr. Chan: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P9 .054. _ Cathy P. F erster 4 Chair DATED this /4 a of July, 2014. Encl. , t RECEIVED STATE OF ALASKA ,JUN 2 0 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon El Plug for Redrill ❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations 0 Perforate 0 Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate(Frac)0 Alter Casing❑ Other. El 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development 0 214-014 3.Address: Stratigraphic CI Service CI6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-133-20624-00-00. 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 0 Kenai Beluga Unit 32-08 9 Property Designation(Lease Number): 10.Field/Pool(s). FEEA028142&FEEA022330 Kenai Gas Field/Upper Tyonek Gas&Beluga Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured). Junk(measured): 9,847' 8,138 9,448' 7,848' 9,448'(Cement on CIBP) N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 135' 16' 135' 135' Surface 1,478' 10-3/4" 1,478' 1,420' 5,210psi 2,470psi Intermediate 6,405' 7-5/8" 6,405' 5,391' 6,890psi 4,790psi Production 3,897' 5" 9,746' 8,098' 10,140psi 10,500psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 1 See attached schematic See attached schematic 5" 18#/L-80 5,849' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft). Swell Packer 5,849'(MD)and 4,940(TVD) 12 Attachments: Description Summary of Proposal 0 13 Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic Cl Development 0 Service ❑ 14.Estimated Date for B 15.Well Status after proposed work. o Commencing Operations: 7/2014 Oil ❑ Gas 0 WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date. WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative' N/A GSTOR s❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Paul Chan Email pchan@hilcorp.com Printed Na - P. llk n Title Senior Operations Engineer Signature AIli '„„/ Phone 777-8333 Date 6/20/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. /\i- '.- S. ?-7 Plug Integrity ❑ BOP Test Lid" Mechanical Integrity Test ❑ Location Clearance ❑ Other: �H506 >i 60F re--,51---- CG ciisINt) RBCMS JUL 15 2014) � f tw_s 5 ,4_h,-Y.,SS,oti Spacing Exception Required? Yes CA No Subsequent Form Required: Iv -LI Oy APPROVED BY ,/ Approved by: _14 COMMISSIONER THE COMMISSION Date 7- /�—f ..../1,67 © ),\\.? \�� bt m and Form 10-403(Revised 10/2012) Appro i G it�I1 L onths from the date of approval. 1 t 1 t AttachmentsSumiint ForDuplicate Post Office Box 244027 Anchorage,AK 99524-4027 Hilcorp Alaska, LLC 3800 Centerpoint Drive Suite 1400 Anchorage,AK 99503 June 19, 2014 Paul Chan Senior Operations Engineer (907)777-8333 Cathy Foerster, Chair REcE/VE1'1 YJ Alaska Oil and Gas Conservation Commission ANN ?0 2014 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 AO c rs RE: Hydraulic Fracturing Application, Kenai Unit, KBU 32-08 Dear Commissioner Foerster, Hilcorp Alaska, LLC ("Hilcorp"), as Operator of the Kenai Unit, herein submits its application to fracture stimulate KBU 32-08. For your reference, this application package was prepared utilizing the Alaska Oil and Gas Conservation Commission's pending hydraulic fracturing regulations (20 AAC 25.283 et al.) as a guide. A plat showing the location of KBU 32-08 and its relationship to adjoining properties and other wells (including one water well) located within a half-mile radius of the wellbore trajectory is depicted in Attachment 2 of the Sundry Application. • Surface Location: 552' FNL, 427' FEL, SEC. 18, T4N, R11W, SM, AK. • Bottom Hole Location: 2021' FNL, 2447 FEL, SEC. 8, T4N, R11W, SM, AK. Per AS 31.05.170(7) and (10), Hilcorp is the "owner" and "landowner" of the affected property. Cook Inlet Region, Inc. ("CIRI") is the owner of surface location of KBU 32- 08 and those portions along the well path within Sections 17 and 18, T4N, R11W, SM, Alaska. Salamatof Native Association, Inc. ("Salamatof') is the surface owner along the remainder of the well path, including the bottom-hole location within Section 8, T4N, R11W, SM, Alaska. There are no other owners, landowners, surface owners or operators within the one-half mile radius of the subject wellbore's trajectory. As a courtesy, Hilcorp has provided CIRI, Salamatof and the Bureau of Land Management (who serves as Unit Manager) notice of proposed operations via certified mail, including a copy of the attached 10-403 form. All other portions of Hilcorp's application, including confidential and non-confidential attachments, are herein filed with AOGCC.1 'Per AS 31.05.035(d),Hilcorp respectfully requests AOGCC keep confidential the engineering,geological and other information detailed in Confidential Attachments 8 and 9. Hilcorp Alaska,LLC Hydraulic Fracturing Application: KBU 32-08 June 19,2014 Page 2 of 2 Hilcorp would be pleased to schedule a technical meeting with AOGCC staff to review this application. Otherwise, please do not hesitate to contact me directly at 907-777- 8333 should you have any questions regarding this application. Sincerely, I (Cei Paul Chan, Senior Operations Engineer HILCORP ALASKA, LLC CC: (via certified mail) • Wayne M. Svejnoah, Bureau of Land Management • Ethan Schutt, Cook Inlet Region, Inc. • Penny Carty, Salamatof Native Association, Inc. Enclosures: Form 10-403 Sundry Attachments (AOGCC-only) Well Prognosis ,� Well: KBU 32-08 Iliieorp Alaska,LL Date: 07/08/2014 Well Name: Kenai Beluga Unit 32-08 API Number: 50-133-20624-00 Current Status: Cased and Cemented Leg: Estimated Start Date: July 18, 2014 Rig: N/A Reg. Approval Reqd? 10-403 Date Reg. Approval Rec: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-014 First Call Engineer: Paul Chan (907) 777-8333 (0) (907) 444-2881 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (C) AFE Number: 1421941 Estimated Bottom Hole Pressure: - 3,587 psi at 7,970 ft TVD Based on 0.45 psi/ft gradient Maximum Anticipated Surface Calculated maximum treating Pressure during Fracture Stimulation: - 5,153 psi pressure during hydraulic fracture stimulation Maximum Anticipated Surface —2,989 psi Based on 0.075 psi/ft gas gradient Pressure: Brief Well Summary Well 32-08 originates at Pad 41-18 in the Kenai Gas Field. The Kenai Gas Field has an aquifer exemption below 1300 feet and at the depths of project activities. KBU 32-08 was drilled in March 2014 and will be completed as a fracture stimulated gas producer in the Kenai Gas Field. Prior to this application for Sundry approval the well will be prepared for hydraulic fracture stimulation of multiple intervals in the Beluga and Tyonek sands. Procedure: Hilcorp's application package was prepared utilizing AOGCC's proposed hydraulic fracturing regulations(20 AAC 25.283 et. Seq.) as a guideline. Cross Reference: 20 AAC 25.283 Proposed Regulation Response Section a) 1 Cook Inlet Region, Inc. (CIRI)and Salamatof Native An affidavit showing that all owners, landowners...have been Association, Inc.(Salamatof)are the only surface owners provided notice of operations... within 1/2 mile of the project area. Hilcorp is the sole owner, operator and landowner within 1/2 mile of the project area using a traveling cylinder. No affidavit is required until the regulations become effective. As a courtesy, Hilcorp has notified both CIRI and Salamatof of proposed activities. A copy of the project application was sent via certified mail to both CIRI and Salamatof. See Attachment 1 of the certified mail receipts. Section a)2 A figure is included as Attachment 2. CIRI and Salamatof A plat showing well location and identifying any water wells do not own or operate wells within 1/2 mile of the project area. located within a one-half mile radius ... Hilcorp Alaska, LLC does operate water wells in the project area. There are no private residential surface landownership interests and there are no private residential drinking water wells within the 1/2 mile project radius definition. Section a)3 This project will occur in the Beluga formation,well within the Identification of freshwater aquifers and the geologic name depths of exempted aquifers, and far below drinking water and depth(MD and TVD)to the bottom of all freshwater aquifers. aquifers within the one-half mile radius... As stated in AOGCC Disposal Injection Order No 9, "All aquifers below 1300 feet within the Kenai Gas Field Boundary, and one-quarter(1/4)mile beyond, are exempted under 40 CFR 147.102(b)(1)(C)." Project activities will occur Well Prognosis Well: KBU 32-08 Ililrorp Alaska.LL Date: 07/08/2014 at depths where the aquifer exemption applies. Disposal Injection Order No 9 covers a different well, KU 11-17 in the general vicinity of this well, KU 32-08. 1. The Sterling Formation consists of Pliocene aged, massively bedded, predominately coarse grained, fluvial deposits and is present within the KBU 32-08 from approximately 500 feet measured depth to the Beluga Formation. This project zone is within the Beluga Formation and beneath the Sterling Formation. 2. The proposed project zone is 8234 to 9653 feet measured depth(approximately 6870 to 8119 feet vertical subsea). 3. All aquifers below 1300 feet within the Kenai Gas Field Boundary, and one-quarter(1/4)mile beyond, are exempted under 40 CFR 147.102(b)(1)(C). 4. Approximately 5570 true vertical feet of Sterling and Beluga Formation sediments separate the proposed project fracturing zone in KBU 32-08 from the base of the non-exempt aquifers in the Kenai Unit. This interval contains an aggregate thickness of more than 500 true vertical feet of impermeable confining zone lithology's. 5. 10-3/4" surface casing string is set at 1478 feet measured depth, cemented to the surface and tested. Section a)4 Proposed well activities are at a depth covered by a Whether the well is covered by a Freshwater Aquifer Freshwater Aquifer Exemption. This aquifer exemption is Exemption as per 20 AAC 25.440 described in the previous section. The aquifers below 1300 feet are exempted aquifers, and the project will occur below 6870 feet vertical subsea. Section a)4 Water wells within the project area are owned by Hilcorp. Water sampling of water wells One water well will be sampled to support project activities. A water well sampling plan is included as Attachment 3 and a sampling Standard Operating Procedure(SOP)is included as Attachment 3A. No private residential water wells are located within 1/2 mile of the project activities. Section a) 5 See Attachment 4 for the"Casing and Cement Report"for Detailed casing and cementing information. the 10-3/4" surface casing,the 7-5/8" intermediate casing, and the 5"production casing/tubing. Detailed Casing Information Size Type Wt/Grade/Conn Pipe Body Yield Collapse Pressure Internal Yield (lbs) (psi) Pressure(psi) 16" Conductor N/A N/A N/A N/A 10-3/4' Surface 45.5/L-80/BTC 1,040,000 2470 5210 7-5/8" Intermediate 29.7/L-80/ BTC 683,000 4,790 6,880 5" Production 18/L-80/DWC/C-HT 422,000 10,490 10,140 Detailed Tubing Information 5" Tubing 18/L-80/DWC/C-HT 422,000 10,490 10,140 111 Well Prognosis Well: KBU 32-08 I ikora Alaska.LI. Date: 07/08/2014 Proposed Regulation Response Section a)6 A cement bond log run March 6, 2014 in the 7-5/8"casing An assessment of each casing and cementing operation "Found top of good cement @ 1470'and good to moderate performed to construct or repair the well with sufficient bond f/1470 to Casing Shoe" supporting information, including cement evaluation logs and other evaluation logs approved by the commission, to A cement bond log run June 2, 2014 in the 5" casing/tubing demonstrate that casing is cemented below the base of the found top of cement at-4550' MD. The bond log showed lowermost freshwater aquifer and according to 20 AAC good to excellent bond above and below each proposed 25.030 and that all hydrocarbon zones penetrated by the well interval, with some intervals showing poor bond(possibly are isolated; due to being gas cut). Attachment 5: 7-5/8"and 5" Cement bond logs Proposed well activities are at a depth covered by a Freshwater Aquifer Exemption. Section a)7 A 5"casing/tubing integrity test was conducted to -5700 psi Pressure test information if available and plans to pressure (+110% over calculated maximum surface treating pressure test the casings and tubing installed in the well; of 5153 psi)on June17, 2014. See Attachment 6: 5" Casing Pressure Test Section a)8 See Attachment 7 for the pressure rating for the wellbore Accurate pressure ratings and schematics for the wellbore, and wellhead. BOPE rating: N/A. Treating head rating: wellhead, BOPE, and treating head; 10K. Section a)9 Data for the fracturing zone and confining zones including lithologic description,geological name, measured depth(MD) [CONFIDENTIAL] See Stimplan Attachment 8 and true vertical depth(TVD), measured and true vertical thickness, and estimated fracture pressures for the fracturing zone and confining zones; Section a) 10. The location, orientation, and a report on the mechanical condition of each well that may transect the confining zones and information sufficient to support a determination that such wells will not interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory; WELL PTD Location Relative to Description Mechanical Condition KBU 32-08 KDU 02(KU 21-8) 168-049 2,580'N P&A No known AnnCom Issues KBU 11-08Y 205-091 2,343'N-NW SI No known AnnCom Issues KBU 11-08Z 214-044 1,800'NW New drill well waiting on No known AnnCom Issues completion KBU 13-08 177-029 1,305'W SI No known AnnCom Issues KBU 14-08 208-048 2,091'SW Producing No known AnnCom Issues Section a) 11 The location, orientation, and geological data of known or suspected faults and fractures that may transect the confining zones, and information sufficient to supporta No faults are mapped within a'/mile radius. determination that any such faults and fractures will not interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory; Section a)12 A detailed copy of the proposed hydraulic fracturing program [CONFIDENTIAL] See Stimplan Attachment 8 for the including, but not limited to,the pumping procedure by stage fracturing program where applicable,with a chemical disclosure based on the total amounts and volumes per well including; Well Prognosis Well: KBU 32-08 Ilileorp Alaska,LL Date: 07/08/2014 Proposed Regulation Response Section a) 12(A) Interval (Mgals) The estimated total volumes planned; Stage 5 LB4A 18.4 Stage 4 LB5A 14.1 Stage 3 73-1 23.4 Stage 2 75-8 11.0 Stage 1 76-7 13.5 Section a) 12(B) See table below. The trade name, generic name, and purpose of all base fluid(s)and CONFIDENTIAL DATA: Note: The following additives to be used.The estimated or maximum rate or additives Losurf 300D,Optiflo-HTE, Optiflo II,WLC-6, concentration of each additive shall be provided in appropriate and HpH are considered confidential trade secrets and measurement units; Units—gpt(gallons per thousand gallons of Hilcorp Alaska requests extended confidentiality for fluid), ppt(pounds per thousand gallons of fluid) these additives(Losurf 300D,Optiflo-HTE, Optiflo-II, WLC-6,and HpH)submitted in a separate envelope. Trade Name Generic Name Purpose Concentration Activator-USA None Resin coated sand activator 5 gpt BA-20 Buffering Agent Buffering Agent 1 gpt BC-140 Crosslinker 3 gpt BE-6 Microbiocide Microbiocide 0.15 gpt FR-66 Light petroleum distillate Friction Reducer GBW-30 Breaker Breaker Enzyme Breaker 2 ppt HpH Breaker 1 gpt KCI KCI Shale inhibitor 6% (by weight) Losurf-300D Non-ionic surfactant Surfactant 1 gpt MO-67 Caustic Sodium Hydroxide pH control 1 gpt Optiflo-HTE Breaker 2 ppt Optiflo-II Delayed Release Breaker Encapsulated Oxidizing Breaker 2 ppt SP Breaker Sodium Persulfate Oxidizing Breaker 2 ppt WG-36 Gelling agent Guar Gum Gelling Agent 25 ppt WLC-6 Fluid Loss Additive Tallow Soap/Fatty-Acid Fluid Loss Additive 50 gpt Section a) 12(C) Please see Attachment 9(containing MSDS sheets for The chemical ingredient name and the Chemical Abstracts Service base fluid and additives used). (CAS)Registry number, as published by the Chemical Abstracts Service(a division of the American Chemical Society,see www.cas.org),for each base fluid and each additive used.The actual or maximum concentration of each chemical ingredient in each base fluid and additive used shall be provided in percent by mass. In addition,the actual or maximum concentration of each chemical ingredient in the hydraulic fracturing fluid shall be provided in percent by mass. Freeze-protect fluids pumped before and/or after hydraulic fracturing should not be included; Interval (Mlbs) Stage 5 LB4A 91.7 Section a) 12(D) Stage 4 LB5A 90.5 The estimated weight or volume of inert substances, including proppants and other substances injected; Stage 3 73-1 110.3 Stage 2 75-8 54.2 Stage 1 76-7 65.9 Well Prognosis Well: KBU 32-08 llilear',Alaska.LL 1'4 Date: 07/08/2014 Proposed Regulation Response Section a) 12(F) MD of TVD of The designed height and length of the proposed fracture(s), Interval Height(ft) Length (ft) Top(ft) Top(ft) including the calculated MD and TVD of the top of the fracture(s) LB4A 333 342 7854 6560 accompanied by a description of the methods and assumptions used to determine designed fracture height and length; The LB5A 233 621 8205 6846 fracture as modeled will be contained in the designated zones and 73-1 105 1226 8675 7223 will not grow out of the confining layers. 75-8 108 872 9066 7537 76-7 85 796 9219 7661 The Stimplan modeling results indicate that the hydraulic fracturing fluids will be contained within the designated zone and not propagate through the confining intervals above and below the designated zone. [CONFIDENTIAL] Please see Attachment 8 for Stimplan Model simulation. Section A) 15. Plan Description A detailed description of the plan for post fracture wellbore cleanup 1. RU CTU lubricator/BOPE stack. PT lubricator. and fluid recovery through to production operations. 2. Prepare to flow through test separator and flare stack. Liquid returns will be taken through the test separator to an open top tank. Gas returns will be taken to the flare stack. 3. RIH to top of sand and begin cleanout with Nitrogen/6% KCI fluid. 4. Cleanout to top of CBP. 5. Turn off 6% KCI brine and jet well dry while POOH. Take gas returns to the flare stack. 6. Once natural gas returns reach the flare stack, shut the well in in preparation for the fracture stimulating the next interval. 7. Once all zone have been fracture stimulated and cleaned up,turn well over to production operations. Section B) When hydraulic fracturing through production casing or through intermediate casing,the casing must be tested to 110%of the 5" Casing/tubing pressure tested to 5700 psi on June 17, maximum anticipated pressure differential to which the casing may 2014 (Attachment 6) be subjected. If the casing fails the pressure test it must be repaired or the operator must use a temporary casing string (fracturing string). Section C) When hydraulic fracturing through a fracturing string,the fracturing string must be stung into a liner or run on a packer set not less than 100 ft MD below the cement top of the production or intermediate N/A casing and tested to not less than 110%of the maximum anticipated pressure differential to which the fracturing string may be subjected. Section D) The fracture stimulation provider, Halliburton, has a three A pressure relief valve(s)must be installed on the treating lines level protection system designed to disengage the pumps to between pumps and wellhead to limit the line pressure to the test limit the line pressure to the test pressure in(a) 12(E). The pressure determined in (a)14(E)of this section;the well must be first level of protection"kicks out"a frac pump in a staggered equipped with a remotely controlled shut-in device unless the fashion as the treating pressure approaches the test operator requests and obtains a waiver from the commission. pressure thereby slowing the rate and pressure. The second layer of protection is a global kick out that will place all the frac pumps into neutral at the pre-determined set pressure. The third layer of protection is the DPM (Discharage Pressure Monitoring system)which is independent of the computer controls and will continue to function if the computer controls malfunction. The DPM cuts power to the engines to limit the rate and pressure(instead Well Prognosis Well: KBU 32-08 i❑!Mora Alaska,LL Date: 07/08/2014 of taking the frac pumps to neutral). Hilcorp Alaska requests a variance from the PRV requirement in lieu of the Halliburton multi-level system described above. Hilcorp Alaska also requests a waiver to the requirement for the well to be equipped with a remotely controlled shut-in device in lieu of the Halliburton multi-level system described above. Section E) The placement of all hydraulic fracturing fluids shall be confined to Only approved formations will receive fracturing fluids. the approved formations during hydraulic fracturing. Section F) • Surface casing annulus will be open to atmospheric If the surface casing annulus is not open to atmospheric pressure, pressure. then the surface casing pressures shall be monitored with a gauge • Surface casing pressure will be continuously and pressure relief device while hydraulic fracturing operations are monitored. in progress;the annular space between the fracturing string and • The 7-5/8"x 5"annulus will be continuously the intermediate or production casing must be continuously monitored. monitored;the pressure in such annular space may not exceed the • A PRVwill be placed on the 7-5/8"x 5"annulus and pressure rating of the lowest rated component that would be set below the burst/collapse pressure ratings of the exposed to pressure should the fracturing string fail. 5" and 7-5/8"casing Well Prognosis Well: KBU 32-08 Ilibrora Alaska,LL Date: 07/08/2014 9�)C e>`" Procedure o- 1. MIRU frac fleet. MIRU frac and slop tanks. MIRU CTU and associated equipment. Stump test CT BOPE. MIRU e-line combi unit. MIRU all ancillary support equipment. 2. Fill frac tanks with filtered 6%KCI brine. Heat water as needed. 3. Lay all hardlines and manifolds. Install pressure monitoring equipment on wellhead and tree. Pressure test all low pressure lines to 1500 psi. 4. Pressure test all high treating lines to 6200 psi. 5. ND tree cap. RU 10K goat head and hard line. Pressure test to 6200 psi. 6. Prepare frac fleet to perform data frac. Data frac the sand and analyze the results. Refine frac design. Fracture stimulate interval #1 wit 2 /40 mesh resin coated proppant. Do not over displace. 8. Shut well in. ND hard line and goat head. NU tree cap. A(1-t , 9. RU CTU BOPE and lubricator. PT lubricator. Cleanout frac sand and frac fluid. Flare gas and/or produce rks into production header. 10. Stand back CTU equipment. 11. RU e-line pressure control equipment. PT lubricator to 3500 psi. RIH and drift and tag. POOH. 12. Set composite bridge plug 25' below perf interval#2. POOH. 13. Perforate frac interval #2 with 6 SPF "frac guns. POOH. 14. RD pressure control equipment. ND tree cap. RU 10K goat head and hard line. Pressure test to 6200 psi. 15. Prepare frac fleet to perform data frac. Data frac the sand and analyze the results. Refine frac design. 16. Fracture stimulate interval #2 with 20/40 mesh resin coated proppant. Do not over displace. 17. Shut well in. ND hard line and goat head. NU tree cap. -/k718. RU CT BOPE and lubricator. PT lubricator. Cleanout frac sand and frac fluid. Flare gas and/or produce into production header. 19. Stand back CTU equipment. 20. RU e-line pressure control equipment. PT lubricator to 3500 psi. RIH and drift and tag. POOH. 21. Set composite bridge plug 25' below perf interval #3. POOH. 22. Perforate frac interval #3 with 6 SPF "frac guns. POOH. 23. RD pressure control equipment. ND tree cap. RU 10K goat head and hard line. Pressure test to 6200 psi. 24. Prepare frac fleet to perform data frac. Data frac the sand and analyze the results. Refine frac design. 25. Fracture stimulate interval #3 with 20/40 mesh resin coated proppant. Do not over displace. 26. Shut well in. ND hard line and goat head. NU tree cap. 27. RU CT BOPE and lubricator. PT lubricator. Cleanout frac sand and frac fluid. Flare gas and/or produce into production header. 28. Stand back CTU equipment. 29. Set composite bridge plug 25' below pert interval#4. POOH. 30. Perforate frac interval #4 with 6 SPF "frac guns. POOH. 31. RD pressure control equipment. ND tree cap. RU 10K goat head and hard line. Pressure test to 6200 psi. 32. Prepare frac fleet to perform data frac. Data frac the sand and analyze the results. Refine frac design. 33. Fracture stimulate interval #4 with 20/40 mesh resin coated proppant. Do not over displace. 34. Shut well in. ND hard line and goat head. NU tree cap. 35. RU CT BOPE and lubricator. PT lubricator. Cleanout frac sand and frac fluid. Flare gas and/or produce into production header. 36. Stand back CTU equipment. 37. Set composite bridge plug 25' below perf interval #5. POOH. Well Prognosis Well: KBU 32-08 Ililcorp Alaska,LI. Date: 07/08/2014 38. Perforate frac interval #5 with 6 SPF "frac guns. POOH. 39. RD pressure control equipment. ND tree cap. RU 10K goat head and hard line. Pressure test to 6200 psi. 40. Prepare frac fleet to perform data frac. Data frac the sand and analyze the results. Refine frac design. 41. Fracture stimulate interval #5 with 20/40 mesh resin coated proppant. Do not over displace. 42. Shut well in. ND hard line and goat head. NU tree cap. 43. RU CT BOPE and lubricator. PT lubricator. Cleanout frac sand and frac fluid. Flare gas and/or produce into production header. POOH. 44. PU motor/mill and drill out the remaining CBp.5and cleanout wellbore to PBTD. RDMO CTU 45. RDMO all remaining equipment. 46. Turn well over to operations Attachments: 1. Landowners/notifications 2. Plat 3. Water sampling program 4. Casing and cement information 5. 7-5/8" and 5" Cement bond logs 6. 5" casing pressure test 7. Wellhead and tree schematics 8. CONFIDENTIAL DATA 9. Base Fluid and Additives Kenai Gas Field 14 Nell: KBU 32-08 CURRENT Last Completed: 6/19/2014 Ililrorp Alseka,LLC PTD: 214-014 CASING DETAIL RKB:MSL=22' Size Type Wt/Grade/Conn ID Top Btm 16" Conductor N/A Surf 135' #" 10-3/4" Surface 45.5/L-80/BTC 9.950 Surf 1,478' 7-5/8" Intermediate 29.7/L-80/BTC 6.875 Surf 6,406' i 5" Production 18/L-80/DWC/C-HT 4.276 5,849' 9,746' 16' + (? TUBING DETAIL 4 4 5" Tubing 18/L-80/DWC/C-HT 4.276 Surf 5,849' tJEWELRY DETAIL 10-3/4" A I:11 No Depth Item c)3 5"$rip 1 5,849' 5"Swell PackerPacker ,,/ ` 2 7,330' 5'Pup 3 8,028' 5'Pup 4 9,475' CIBP OPEN HOLE/CEMENT DETAIL 10-3/4" 160BBL's of cement in 13.5"Hole.Returns to Surface 1 t q.,"r° 7-5/8" 261BBL's of cement in 9-7/8"Hole.Returns to Surface 1 S 4-6-n9i 5" 114BBL's of cement in 6-3/4"Hole. TOC 4,600 Calculated L OS 'S PERFORATION DETAIL Btm Sands Top(MD) Btm(MD) Top(TVD) (TVD) FT Date Status Tyonek 76-7 ±9,343' ±9,366' ±7,762' ±7,781' 23' 6/19/14 Open Tyonek 78-2 ±9,500' ±9,510' ±7,891' ±7,899' ±10' 6/7/14 Isolated t 1 7-5/8" 1 G jro G 02 .3 i'' TOC @ 9,448 Tyonek 76-7 1/1-- 7.3 1'1 �_ pr,5 ire fLt,L . .s.4 Tyonek 78-2 5" j TD=9,746'(MD)/8,098'(WD) PBTD=9,448'(MD)/x,xc'(TVD) Updated by: PC 6/19/14 Kenai Gas Field 11 Nell: KBU 32-08 PROPOSED Last Completed: 6/19/2014 Hileorp Alaska,LLC PTD: 214 014 CASING DETAIL RKB:MSL=22' Size Type Wt/Grade/Conn ID Top Btm 16" Conductor N/A Surf 135' t. �; 10-3/4" Surface 45.5/L-80/BTC 9.950 Surf 1,478' 7-5/8" Intermediate 29.7/L-80/BTC 6.875 Surf 6,406' + 5" Production 18/L-80/DWC/C-HT 4.276 5,849' 9,746' 16" r , r• TUBING DETAIL L. ; r 5" Tubing 18/L-80/DWC/C-HT 4.276 Surf 5,849' VJEWELRY DETAIL cl 10-3/4" ° No Depth Item q P 1 5,849' 5"Swell PackerPacker 2 7,330' 5'Pup F 3 8,028' 5'Pup 7 4 9,475' CIBP *, '" i. OPEN HOLE CEMENT DETAIL ,; 10-3/4" 16OBBL's of cement in 13.5"Hole.Returns to Surface 7-5/8" 261BBL's of cement in 9-7/8"Hole.Returns to Surface vx vx I 5" 114BBL's of cement in 6-3/4"Hole. TOC 4,600 Calculated PERFORATION DETAIL i141 a r Sands Top(MD) Btm(MD) Top(TVD) Btm FT Date Status (TVD) , LB4A ±8,264' ±8,284' ±6,894' ±6,910' ±20' Future Future 1, LBSA ±8,495' ±8,510' ±7,080' ±7,092' ±15' Future Future e Tyonek 73-1 ±8,807' ±8,837' ±7,329' ±7,353' ±30' Future Future et ifi,1 Tyonek 75-8 ±9,175' ±9,200' ±7,625' ±7,645' ±25' Future Future Pj Tyonek 76-7 ±9,343' ±9,366' ±7,762' ±7,781' 23' 6/19/14 Open + Tyonek 78-2 9,500' 9,510' 7,891' 7,899' 10' 6/7/14 Isolated .r..SII 7-5/8" > 4 4. is , IN ,144 el iit if' ►A r 3 4• r tt ;; r; f4 e. r M. 0. TOC @ 9,448' y Tyonek 76-7 L, 4 4 lv t Tyonek 78-2 5" $46. • TD=9,746'(MD)/8,098'(TVD) PBTD=9,488'(MD)/x,xxx'(TVD) Updated by: PC 6/19/14 Attachment 1 v U ^o r v C. E v ,;=1) v U.S. Postal Service-TM CERTIFIED MAILTM RECEIPT m m Er a (Domestic Mail Only,No Insurance Coverage Provided) ' rn� saimsmaimmonN r For delivery information visit our website at www.usps.com® m ..oma 3 i 17 �. -- ii n �0 9 A 11.Jru Postage $ /i/ 0• r o `n `1 N U Certified Feem N !_ D D Postmark N D D Return Receipt Fee D D (Endorsement Required) Here D Restricted Delivery Fee iminemomemeam (Endorsement Required) DD $ / /9 _ Total Postage&Fees D D Wayne M. Svejnoha, Branch Chief Se, anowinaig a Energy and Minerals D Por rf Bureau of Land Management r` r-- cit 222 West Seventh Avenue, #13 Anchorage, AK 99513-7504 Instructions J0.4 .3 '^ 11 ri J L a?, I�1 c,-); Q G ° v C 6., N u u o Cr w Cu v3- :,`' U C _.... C 0 z ro (..) O0) in 1:10 U.S. Postal Service T. CERTIFIED MAILTM RECEIPT i -11 --EI (Domestic Mail Only;No Insurance Coverage Provided) amm...........1 ErE; ELS For delivery information visit our website at www.usps.com, EMONNIIMMINM L-11 LI1 Mialilli Cr IT' 0 ra: iz erN i A 1 i E q F.: 1 MIIIIMIIIIIIIMININIO11111 Fri Fri 1 ru ru Postage $ / /9 ..- 1 Certified Fee 3, 3 ey . iswi......... E] D — Postmark ID 0 Return Receipt Fee Here D ED (Endorsement Required) U D Restricted Delivery Fee 1 NINIIIIIIIIIMINIIIIIIIMMEN 0 0 (Endorsement Required) ti •1111111111111111111 -1 ,-. IST Ul $ /C7 ,- 4 Total Postage&Fees , / ., / / 1111111111111111111111111 .:. CD U Salamatof Native Association, Inc. --- Sen ‘.• .. !fr.° Attn: General Manager , t- -IS P U 230 Main St or F:,61 city Kenai, AK 99611 .. 1 tstructions 1 o 1 CD 1 *4 in 1 ,... z cy, ms --'co = 1 © u E 0 co o ....., o..c •-o, 0 0 E i'4- 4 CU (.7) a.) (1) U.S. Postal Servicem, CERTIFIED MAIL. RECEIPT -0 -a (Domestic Mail Only;No Insurance Coverage Provided) ' For delivery information visit our website at www.usps.cow woo • 4 . a-" 11111111111111111111.1•1111•1111111111 M M r1.1 ru Postage $ / J3 J3 Certified Fee ED ED Postmark I=1 Return Receipt Fee Here 1=1 D (Endorsement Required) D Restricted Delivery Fee ammonms CI 0 (Endorsement Required) 1-11 1-r1 NIIIIIM11111111•11111111111111 rR r-4 Total Postage&Fees Ico E3 . [than Schutt, Senior Vice President r9 C3 CD Land Energy 0, P- Cook Inlet Region, Inc. 2525 C Street, Suite 500 InstructIons g Anchorage, AK 99503 0 0 e czt C4 '7 16-- OJ (1.1 .° 5 ‘) 0 (t3 — 0 •- 0 ?0° E WIPE..t:Ca4-' Attachment 2 — --.^. ., ,xX.,x.,xxx x X„ ` X., x., X ,YXx.,/.,X., XXX.. I ;' X x x X X )' x X X X X X X X X X \ X X X X X I� X X X X X x Y, It x x x x x" x >, ., . , x ., x xxx x Sec; x x x x x xll x xxx x x x Sec:.6, xx x.. x xx .'. ,. xx _. 4 ,xxxxxxxxxxi;fxxxxxxx ' ._"r..I..•-►.rti ri•r.:r:(� x x. > >: :< ., >. . 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I Oil and Gas Unit Boundary i 1 ' Hilcorp O&G Minerals 0 2,800 5,600 Kenai Unit Feet KBU 32-08 Alaska State Plane Zone 4, NAD27 Hilcorp Alaska,LLC Map Date:6/10/2014 Attachment 3 and 3A 7_t Hilcorp Alaska, LLC ATTACHMENT 3A Water Well Sampling Procedure Standard Operating Procedure Water Sampling Prepared by Jacobs Engineering Group, Inc. 4300 B Street, Suite 600 Anchorage, Alaska 99503 COM-J07-05DK5006-J21-0001 June 2014 Standard Operating Procedure Water Sampling 11ikorp Alnv.ka,LLC TABLE OF CONTENTS SECTION PAGE 1 SCOPE AND APPLICATION 2 1.1 SAMPLE PRESERVATION, CONTAINERS, HANDLING, AND STORAGE 2 1.2 POTENTIAL INTERFERENCES 2 2 EQUIPMENT 3 3 PROCEDURES 6 3.1 RECORDING FIELD OBSERVATIONS 6 3.2 FIELD INSTRUMENT CALIBRATION 6 3.3 PURGING 7 3.4 WATER SAMPLE COLLECTION USING EXISTING WELL PUMP 8 3.5 WATER SAMPLE COLLECTION USING A SPIGOT OR FAUCET 9 4 QUALITY CONTROL SAMPLES 10 5 HEALTH AND SAFETY 10 6 REFERENCES 10 TABLES Table 1 Well Sampling Epuipment 3 Table 2 Sample Containers 4 Table 3 Stability Criteria for Purging 7 ATTACHMENTS ATTACHMENT A Water Sampling Form Page i JACOBS Standard Operating Procedure Water Sampling Hileorp:11a+6. 1 SCOPE AND APPLICATION This Standard Operating Procedure (SOP) describes the collection of representative water samples from drinking water wells using the existing pumps and the collection of samples from typical household spigots or faucets to evaluate the aquifer water conditions prior to hydraulic fracturing operations. Post hydraulic fracturing samples may also be collected in accordance with this SOP. Alaska proposed fracturing rules (Chapter 20 of the Alaska Administrative Code [AAC] 25.283) require that water wells within a 0.5-mile radius around the wellbore trajectory be evaluated for characterization. This SOP defines a standard set of procedures applicable under typical site conditions and equipment; they may be varied as dictated by actual site conditions and equipment characteristics. Field notes shall be sufficiently specific to document adherence to these procedures or to record all relevant details of any variances. This SOP is generally consistent with the Draft Field Sampling Guidance issued by the Alaska Department of Environmental Conservation (ADEC 2010). That document may be referred to for an overview of considerations, equipment, and procedures. This SOP applies specifically to monitoring of hydraulic fracturing operations and should be used in this context. Water wells within a 0.5-mile radius of the wellbore trajectory will be considered for sampling in accordance with 20 AAC 25.283. 1.1 SAMPLE PRESERVATION, CONTAINERS, HANDLING, AND STORAGE Samples will be collected into appropriate sample containers (with preservative, if required by the analytical method) provided by the analytical laboratory. Upon collection, containers will be labeled with the sample identification string, at a minimum. Samples will be stored at 4±2 °C (if required by the analytical method). Prior to shipment, containers will be labeled with complete documentation (sample identification string, date and time of collection, sampler initials, and requested analysis). Samples will then be packaged and shipped to the analytical laboratory for analysis. 1.2 POTENTIAL INTERFERENCES Two potential issues associated with water sampling are cross-contamination and lack of representativeness due to improper well purging or stabilization. To prevent cross- contamination between wells, new collection equipment will be used. To ensure the collection of water is representative of conditions within the aquifer, purging will continue at a rate that produces only minimal drawdown until water quality parameters have stabilized as described in Section 3.3. Only then will samples be collected. Page 2 JACOBS Standard Operating Procedure Water Sampling tlikorp Alnaka,LLC 2 EQUIPMENT Water sampling equipment will include, but is not limited to, the items listed in Tables 1 and 2. Table 1 Well Sampling Equipment IActivity Type/Name Quantity Notes All Modified Level D PPE Per person Hard hat, safety glasses, nitrile gloves. All Camera 1 -- All Logbook, ballpoint pen/felt tip As needed -- marker Sampling Water sampling form 1 per well -- Sampling Sample labels As needed Information specified in this SOP shall be included. Sampling containers and packing Preservatives in sample Sampling materials As needed containers, as specified by the analytical method 1 per Engineer scale (hundredths of Sampling Tape measure sampling team a foot), preferable Sampling 5-gallon bucket 2 Use to collect well water to sample from Sampling Graduated cylinder or beaker 1 1 liter, for measurement of volume of recovered product Yellow Springs Instruments(YSI) Should include a flow-through Sampling water-quality meter(or similar) 1 cell and calibration reagents Hach portable turbidimeter(or Should include calibration Sampling 1 similar) standards Potable water and/or deionized Used for decontamination of Sampling water As needed development equipment Appropriately sized to match Sampling Tubing As needed selected pumps Page 3 JACOBS Standard Operating Procedure Water Sampling Table 2 Sample Containers Potential Containers Preservation Maximum Parameter Analytical (number, size, Method and type) Requirements Holding Time GRO AK101 (3)40 mL VOA HCI to pH less 14 days glass than 2, 4° ± 2°C 14 days to DRO AK102 (2) 1 L glass HCI to pH less extraction, 40 than 2, 4° ± 2°C days to analysis of extraction Dissolved methane, ASTM D1945/ (3)40 mL VOA HCI to pH less 14 days ethane, and RSK-175 glass than 2, 4° ± 2°C propane TDS E160.1 (1)250 mL 4° ±2°C 7 days HDPE TPH E1664 (2) 1 L glass HCI to pH less 28 days than 2, 4° ± 2°C Iodide E300.0 - Iodide (1)60 mL 4°±2°C 28 days HDPE Fluoride E300.0 (1)60 mL 4°±2°C 28 days Fluoride HDPE Bromide E300.0 (1)60 mL 4° ±2°C 28 days Bromide HDPE Chloride E300.0/SW9056 (1)60 mL 4° ±2°C 28 days -Chloride HDPE E353.1/353.21 (1)60 mL H2SO4to pH less NO2/NO3 as N E353.3 HDPE than 2, 4° ± 2°C 28 days E365.1/E365.2/ (1)250 mL H2SO4to pH less Phosphorous 28 days E365.3/E365.4 HDPE than 2, 4° ± 2°C E905.0/ASTM (1)250 mL HNO3 to pH less 6 months Strontium-90 maximum holding D5811 HDPE than 2 time Alkalinity SM2320/E310.1- (1)250 mL 4° ±2°C 14 days Alkalinity HDPE Alkalinity, SM2320/E310.1- (1)250 mL 4°±2°C 14 days bicarbonate Alkalinity CHO3 HDPE Hydroxide SM2320/E310.1 (1)250 mL 4°±2°C 14 days HDPE 200.7 metals (1)250 mL HNO3 to pH less 6 months (b, ca, fe, li, k, SW6010 HDPE than 2 maximum holding na) time Page 4 JACOBS Standard Operating Procedure Water Sampling 11&;orp Alauka,LI C Table 2 Sample Containers (continued) Potential Containers Preservation Maximum Parameter Analytical (number, size, Requirements Holding Time Method and type) 200.8 metals 6 months (as, ba, cd, Cr, SW6020 (1) 250 mL HNO3 to pH less maximum mg, mn, se, si) HDPE than 2 holding time BTEX SW8260-BTEX (3)40 mL VOA HCI to pH less 14 days glass than 2, 4° ± 2°C 7 days to PAH SW8270 SIM (2) 1 L glass 4° ±2°C extraction, 40 days to analysis of extract sulfate SW9035/SW9036/ (1)60 mL 4° ±2°C 28 days SW9038/E300.0 HDPE pH SW9040 (1)60 mL 4° ±2°C as soon as HDPE possible Radium 226 SW9315 (1)250 mL HNO3 to pH less 6 months HDPE than 2 Radium 228 SW9320 (1)250 mL HNO3 to pH less 6 months HDPE than 2 Specific E120.1 (1)60 mL 4° ±2°C 28 days conductance HDPE Iron related SM9240 (1) 120 sterile 4° ±2°C 24 hours Bacteria plastic Sulfate (1) 120 sterile reducing SM9240 plastic 4° ±2°C 24 hours Bacteria Slime forming SM9240 (1) 120 sterile 4° ±2°C 24 hours Bacteria plastic Notes: as = arsenic HNO3 = nitric acid ASTM = American Society for Testing and Materials k = potassium b = boron L = liter ba = barium li = lithium BTEX = benzene,toluene,ethylbenzene,xylenes mg = magnesium ca = calcium mL = milliliter cd = cadmium mn = manganese CH03 = bicarbonate na = sodium Cr = chromium PAH = polynuclear aromatic hydrocarbons DRO = diesel-range organic se = selenium fe = iron si = silicon GRO = gasoline-range organic TDS = total dissolved solids H2SO4 = sulfuric acid TPH = total petroleum hydrocarbon HCI = hydrogen chloride VOA = volatile organic analysis HDPE = high density polyethylene Page 5 JACOBS Standard Operating Procedure Water Sampling IIiI,orp:kl.,wa.IAA: Sample labels are necessary to prevent misidentification of samples. Each sample container will have a sample label attached to it. Where necessary, the label will be protected from water and solvents with clear tape. No sample labels or tape are to be placed on pre-tared sampling jars (volatile soil samples). Sample labels will include the following information: • Project code or number • Sampling date and time • Sample number • Sample location • Sampler's initials • Preservation • Analyses requested Sample containers will have labels that contain the same information as reported on the chain-of-custody(CoC)records. At the time of sampling, appropriate sample numbers will be recorded in the field logbook. 3 PROCEDURES 3.1 RECORDING FIELD OBSERVATIONS The Water Sampling Form (Attachment 1) provides spaces for all routinely collected information during the sampling process for water wells. Additionally, blank space on the second page may be used for any non-routine observations. The logbook should be used to record all calibration information including calibration checks. It should also contain a running list of wells sampled, needing to note only starting and ending times; all other sampling information for monitoring wells will be recorded on the well specific sampling form. For sampling from household spigots or faucets, all information will be recorded in the logbook. 3.2 FIELD INSTRUMENT CALIBRATION Field instruments will be calibrated in accordance with the manufacturer's recommended procedures for each instrument. Operation and maintenance manuals will be available in the field for reference. Calibrations will be evaluated at the beginning of each day prior to use. If any reading is outside +1- 5% from the expected calibration standard, the equipment will be re-calibrated. Page 6 JACOBS Standard Operating Procedure Water Sampling Hilm.rp Alaeta,LU: 3.3 PURGING Purging will be conducted in order to evacuate water from within the water supply line and plumbing. The objective is to collect representative aquifer samples using existing pumps which requires a consistent approach applied to variable infrastructure. Cold water will be allowed to flow at the standard rate produced by the pump. Purging procedures are described in Section 3.4. Criteria for low-flow sampling are described below and will be used when existing pumps can adequately provide low-flow control at the valve: • Flow rates typically range from 0.1 to 1.0 liters per minute (0.03 to 0.3 gallons per minute), but higher rates are consistent with low-flow guidelines • Water quality parameters will be measured and recorded as tabulated in Table 3. Purging will continue until water quality parameter stabilization is reached or 15 minutes have passed, whichever comes first. Water quality parameter stabilization is reached when three changes between successive readings at approximately 2 minute intervals are less than the amounts in Table 3. Turbidity readings consistently below 10 nephelometric turbidity units (NTU) are considered to represent stabilization. Table 3 Stability Criteria for Purging Typical Value Parameter Units Recording Stability Criterion Range for Precision Stability Criterion p H — 0.01 ±0.1 5 to 8 Temperature °C 0.01 ±0.2 0.1 to 15 Conductivity pS/cm 1 ±3% 80 to 1,000 Turbidity NTU 0.1 ± 10%or±1 NTU 0.3 to >900 Oxidation Reduction Potential mV 1 ±10 -120 to 350 (ORP) ±10%or 0.2 mg/L Dissolved Oxygen mg/L 0.1 (whichever is 0 to 12 (DO) greater) Notes: °C=degrees Celsius pS/cm=microsiemens per centimeter NTU=nephelometric turbidity units mV=millivolts mg/L=milligrams per liter Stability criteria from ADEC Draft Field Sampling Guidance(ADEC 2010). Page 7 JACOBS- 14 Standard Operating Procedure Water Sampling .-%I.L..l,,: 3.4 WATER SAMPLE COLLECTION USING EXISTING WELL PUMP Sampling will use the existing pump system for the water well. Samples will be collected using the following steps: • Use plastic sheeting on the ground surrounding the well as necessary to provide a clean working area and minimize contact between sampling equipment and potentially contaminated soil. • Begin purging water into a container. Adjust the flow rate so that drawdown does not exceed 0.3 feet. The flow rate can be slowly increased or decreased as needed. • After turbidity lessens (purge water begins clear up considerably), connect the flow- through cell to measure stabilization parameters. Continue to purge until stabilization criteria are met (Section 3.3) or 15 minutes. Remove the supply line from the flow- through cell and place such that purge water is captured in a container. • Don new nitrile gloves prior to handling sample bottles. • When flow is adequately slow, collect samples directly into sample containers. When the flow rate is too great, pump water to be sampled into a new container (i.e. 5-gallon bucket). • Collect samples from the container using an unpreserved sample jar or disposable bailer, then transfer to the appropriate containers (with preservatives if required by the analytical methods). For consistency, samples should be collected in the following order (if applicable): • Volatile organic compounds(VOC)(including BTEX and dissolved methane,ethane, and propane) • Gasoline-range organics (GRO) • Diesel-range organics (DRO) • Polynuclear aromatic hydrocarbons (PAH) • Metals • Other parameters • The 40-mL vials for VOCs/GRO must be filled slowly to prevent splashing and entrainment of air bubbles. Reduce the pumping rate, if necessary to control the flow rate. Care will be taken to avoid touching the mouth of the discharge line, the top of the sample bottle, the inside of the cap, or the Teflon septum. A septum that falls out of the cap onto the ground cannot be used. The bottle will be filled completely so that a convex meniscus forms. The cap will then be secured and the bottle inverted, tapped firmly, and checked for the presence of air bubbles. Analytical results are compromised if air is trapped in the sample container. Page 8 JACOBS Standard Operating Procedure Water Sampling Hfkorp Almke,LLt: • Measure the total depth of the well. Record measurements and sample bottles on the water sampling form. 3.5 WATER SAMPLE COLLECTION USING A SPIGOT OR FAUCET Drinking water will only be sampled from a home if the homeowner has given permission to do so. Prior to sampling, determine the size of the home's pressure tank and faucet flow rate. Using these numbers, determine approximately how long it will take to empty the pressure tank and home piping system. Samples will be collected using the following steps: • If sampling from the faucet, remove the screen, hoses, or aerators as these devices can put air in the water that will regroup into bubbles. • Disinfect the faucet or spigot by dipping the end in a cap full of bleach before running the water. This is optional. • Begin purging the water into the sink or out of the spigot. Run water for the predetermined amount of time it will take to empty the pressure tank and piping. This may take approximately 15 to 20 minutes. • Place the appropriate sample containers (with preservatives if required by the analytical methods) directly under the tap or spigot that is being sampled and slowly turn on the cold water to a gentle stream until the sample container is full. For consistency, samples should be collected in the following order(if applicable): • VOCs (including BTEX and dissolved methane, ethane, and propane) • GRO • DRO • PAH • Metals • Other parameters • The 40-mL vials for VOCs/GRO must be filled slowly to prevent splashing and entrainment of air bubbles. Care will be taken to avoid touching the mouth of the discharge line, the top of the sample bottle, the inside of the cap, or the Teflon septum.A septum that falls out of the cap onto the ground cannot be used. The bottle will be filled completely so that a convex meniscus forms. The cap will then be secured and the bottle inverted, tapped firmly, and checked for the presence of air bubbles. Analytical results are compromised if air is trapped in the sample container. Record any measurements and sample bottles on the water sampling form. Page 9 JACOBS Standard Operating Procedure Water Sampling Ilikarp Alaska.6t.0 4 QUALITY CONTROL SAMPLES Applicable EPA or ADEC-approved sample custody and collection protocols and analytical methods will be used (EPA 2008, ADEC 2010). Drinking water sampling protocol recommend the following quality control (QC) samples, which may be collected: • One field duplicate QC sample for every 20 or fewer primary samples. • One matrix spike and matrix spike duplicate (MS/MSD) sample for each sample shipment/laboratory batch, or at a frequency of one per 20 samples per matrix. The MS/MSD samples will be denoted on the CoC. • Trip blanks for each batch of 20 samples or one per cooler for VOCs and GRO analyses. QC samples for the hydraulic fracturing support will be collected at the above frequencies on an annual campaign basis over several sampling events. This frequency offers an evaluation of field collection measures in accordance with this SOP and complies with the intent of the guidance protocols. 5 HEALTH AND SAFETY Procedures for working with potentially hazardous materials as well as the relevant Safety Data Sheets (SDS) for each chemical that will be used at the site are included in the plan. Personnel using this SOP must be trained on the information contained in the SDSs, engineering controls, and the personal protective equipment (PPE) outlined in the plan. Sample collection equipment and gloves may contact sample preservatives. Therefore, disposable equipment will be placed in plastic bags and removed with personnel. These consumables will be disposed as general trash at a municipal landfill or transfer station. 6 REFERENCES ADEC (Alaska Department of Environmental Conservation). 2010 (May). Draft Field Sampling Guidance. EPA(U.S. Environmental Protection Agency). 2008 (November). Sampling Guidance for Unknown Contaminants in Drinking Water. EPA-817-R-08-003. Page 10 JACOBS ATTACHMENT A Water Sampling Form H Water Sampling Data Sheet H"Iaorr Alaska,Ili, Site Name Event Well ID Project Number Weather Conditions Date Sampler Initials Tank Information (Drinking Water) Tank Volume(gallons) Faucet/Spiciot Flow Rate(gal/min) Estimated Purge Time(minutes) Well/Tank Purging Information Start Time Finish Time Equipment Used for Purging Faucet Spigot Existing Pump Bucket Other Color Odor Sheen Purged Dry Meter Used During Purging Clear Cloudy Brown None Moderate Yes Yes YSI Multi Meter Hach Turbidimeter Other: Faint Strong No No Horiba Multi Meter Purging reached: Stability Max Time Purge water was: Treated Stored Discharged Note: Volume Acceptable Range to Demonstrate Stability Time (Gallons or Liters) ±0.2°C ±3% ±10%or 0.2 mg/L ±0.1 ±10 mV ±10%or±1 NTU (H H:m m) (whichever is greater) Change Total Temperature Conductivity DO pH ORP Turbidity (CC) (iS/cm) (mg/L) (std units) (mV) (NTU) Suggested Notation: " "=not measured "✓"=stable "+"=rising "-"=falling "*"=all parameters stable Page 1 Water Sampling Data Sheet aAn,q,:Umka.1,1,C Sample Collection Information Start Time Finish Time/Date Equipment Used for Sampling Faucet Spigot Existing Pump Bucket Other SAMPLE ID: QC: Dup MS/MSD Container/Preservative Analysis Requested Notes 3-VOA glass,HCL GRO 2-1 Liter,HCL DRO 3 VOA glass Dissolved methane,ethane,and propane 1 -250 mL HDPE TDS 2-1 Liter,HCL TPH 1 -60 mL HDPE iodide 1 -60 mL HDPE fluoride 1 -60 mL HDPE Bromide 1 -60 mL HDPE chloride 1 -60 mL HDPE,H2504 NO2/NO3 as N 1-250 mL HDPE,H2SO4 phosphorous 1 -250 mL HDPE,HNO3 strontium-90 1-250 mL HDPE alkalinity 1 -250 mL HDPE alkalinity,bicarbonate 1 -250 mL HDPE hydroxide 1 -250 mL HDPE,HNO3 200.7 metals (b,ca,fe,li,k,na) 1 -250 mL HDPE,HNO3 200.8 metals (as,ba,cd,cr,mg,mn,se,si) 3-VOA glass,HCL BTEX 2-1 Liter PAH 1 -60 mL HDPE sulfate 1 -60 mL HDPE pH 1 -250 mL HDPE,HNO3 Radium 226 1 -250 mL HDPE,HNO3 Radium 228 1 -60 mL HDPE Specific conductance 1 -120 sterile plastic iron related 1 -120 sterile plastic sulfate reducing 1 -120 sterile plastic slime forming Attachment 4 Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No. Kenai Beluga Unit, KBU 32-08 Date 21-Feb-14 County Kenai State Alaska Supv. Farrell CASING RECORD TD 1514.00 Shoe Depth: 1478.00 PBTD: Drilled Out Casing (Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top Shoe 10 3/4 45.5 L-80 BTC WOT 1.96 1,478.00 1,476.04 2 10 3/4 45.5 L-80 BTC 81.93 1,476.04 1,394.11 Float CIr 10 3/4 45.5 L-80 BTC WOT 1.42 1,394.11 1,392.69 33 10 3/4 45.5 L-80 BTC 1,341.01 1,392.69 51.68 PUP 10 3/4 45.5 L-80 BTC 18.88 51.68 32.80 PUP 10 3/4 45.5 L-80 BTC 8.00 32.80 24.80 PUP 10 3/4 45.5 L-80 BTC 2.15 24.80 22.65 Hanger 0.65 22.65 22.00 RKB 22.00 22.00 0.00 Totals Csg Wt. On Hook 75,000 Type Float Collar: WOT 403 No. Hrs to Run: 8 Csg Wt. On Slips: 57,000 Type of Shoe: Bull Nose Casing Crew: WOT Fluid Description: 9.8 ppg Spud Mud Liner hanger Info(Make/Model): Liner top Packer?: Yes No Liner hanger test pressure: Centralizer Placement: 1 per joint of shoe track then every other joint to 130 ft.Total of 18 centralizers run. CEMENTING REPORT Preflush(Spacer) Type: Mud Clean Density(ppg) 8.6 Volume pumped (BBLs) 25 Lead Slurry Type: Type 1 Yield: 2.13 Density(ppg) 12.5 Volume pumped (BBLs/sx) 101 /264 Mixing/Pumping Rate(bpm): 4.3 Tail Slurry Lir Type: Type 1 Yield: 1.25 Q Density(ppg) 15.2 Volume pumped (BBLs/sx) 58.77/264 Mixing/Pumping Rate(bpm): 3.6 u~i Post Flush(Spacer) co Type: Density(ppg) Rate(bpm): Volume: 1 Displacement: Type Mud Density(ppg) 9.6 Rate(bpm): 5.5 Volume(actual/calculated): 132/135.6 FCP(psi): 961 Pump used for disp: Baker Plug Bumped? X Yes No Bump press 1461 Casing Rotated? Yes X No Reciprocated? X No 100 %Returns during job Cement retums to surface? X Yes No Spacer returns' X Yes No Vol to Surf: 22 bbls Cement Cement In Place At: 17:12 Date: 2/21/2014 Estimated TOC: Surface Method Used To Determine TOC: Returns to surface Preflush(Spacer) Type: Density(ppg) Volume pumped (BBLs) Lead Slurry Type: Density(ppg) Volume pumped (BBLs) Mixing/Pumping Rate(bpm): Tail Slurry Lir Type: o < Density(ppg) Volume pumped (BBLs) Mixing/Pumping Rate(bpm): v) Post Flush(Spacer) 0 o Type: Density(ppg) Rate(bpm): Volume: w Displacement: o Type Density(ppg) Rate(bpm): Volume(actual/calculated): FCP(psi): Pump used for disp: Plug Bumped? Yes No Bump press Casing Rotated? Yes No Reciprocated? Yes No %Returns during job Cement retumsto surface? Yes No Spacer returns? Yes No Vol to Surf: Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No. KBU 32-08 Date 3-Mar-14 County kenai State Alaska Supv. FARRELL/YESSAK CASING RECORD TD 6418.00 Shoe Depth: 6405.00 PBTD: Casing(Or Liner)Detail Setting Depths No. of Jts. Size Wt. Grade THD Make Length Bottom Top SHOE 7 5/8 29.7 L-80 IBT wft 3.00 6,405.29 6,402.29 2 7 5/8 29.7 L-80 IBT 82.22 6,402.29 6,320.07 FLT CLR 7 5/8 29.7 L-80 IBT wft 1.35 6,320.07 _ 6,318.72 152 7 5/8 29.7 L-80 IBT 6,266.07 6,318.72 52.65 Pup 7 5/8 29.7 L-80 IBT 19.95 52.65 32.70 Pup 7 5/8 29.7 L-80 IBT 10.10 32.70 22.60 Pup 7 5/8 29.7 L-80 IBT 2.20 22.60 20.40 Hanger 0.40 20.40 _ 20.00 RKB 20.00 20.00 0.00 Tota l s Csg Wt.On Hook 177k Type Float Collar: WEATHER FORD No. Hrsto Run: 8 Csg Wt.On Slips: N/A Type of Shoe: WFT Casing Crew: tesco Fluid Description: Klay-Shield Liner hanger Info(Make/Model): CAMERON Liner top Packer?: _Yes x No Liner hanger test pressure: 5000 Centralizer Placement: 1 per joint on shoe track and then every other one to 1565.60 centralizers total. CEMENTING REPORT Preflush(Spacer) Type: Seal Bond Density(ppg) 9.8 Volume pumped(BBLs) 39 Lead Slurry Type: TYPE 1 yield 3.3 Density(ppg) 10.5 Volume pumped (BBLs) 227 Mixing/Pumping Rate(bpm): 5 Tail Slurry w Type: TYPE 1 yield 1.8 a Density(ppg) 13.5 Volume pumped (BBLs) 34 Mixing/Pumping Rate(bpm): 5 16 Post Flush(Spacer) 0 Type: Density(ppg) Rate(bpm): Volume: LL Displacement: Type MUD Density(ppg) 9.8 Rate(bpm): 5 Volume(actual/calculated): 290/290 FCP(psi): 300 Pump used for disp: baker Plug Bumped? X Yes No Bump press 1000 Casing Rotated? Yes X No Reciprocated? Yes X No 100 %Returns during job Cement retumsto surface? X Yes No Spacer returns X Yes No Vol to Surf: 40 Cement In Place At: 11:47 Date: 3/3/2014 Estimated TOC: Method Used To Determine TOC: CBL ORDERED OUT Preflush(Spacer) Type: Density(ppg) Volume pumped (BBLs) Lead Slurry Type: Density(ppg) Volume pumped (BBLs) Mixing/Pumping Rate(bpm): Tail Slurry w Type: a Density(ppg) Volume pumped (BBLs) Mixing/Pumping Rate(bpm): Post Flush(Spacer) 0 0 Type: Density(ppg) Rate(bpm): Volume: w Displacement: `" Type Density(ppg) Rate(bpm): Volume(actual/calculated): FCP(psi): Pump used for disp: Plug Bumped? Yes No Bump press Casing Rotated? Yes No Reciprocated? Yes No %Returns during job Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No. _ KBU 32-08 Date 15-Mar-14 County Kenai State Alaska Supv. Leslie/Lott CASING RECORD TD 9847.00 Shoe Depth: 9745.56 PBTD: 9657.00 Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top SHOE 61/4 18 L-80 DWC wft 2.40 9,745.56 9,743.16 2 5 18 L-80 DWC 84.02 9,743.16 9,659.14 FLTCLR 5 18 L-80 DWC wft 1.40 9,659.14 9,657.74 40 joints 5 18 L-80 DWC 1,624.47 9,657.74 8,033.27 RA Pup 5 18 L-80 DWC 4.98 8,033.27 8,028.29 17 5 18 L-80 DWC 692.82 8,028.29 7,335.47 RA Pup 5 18 L-80 DWC 5.00 7,335.47 7,330.47 36 5 18 L-80 DWC 1,466.65 7,330.47 5,863.82 Pup 5 18 L-80 DWC 3.65 5,863.82 5,860.17 Swell Packer 6 X 10 18 L-80 DWC TAM 10.70 5,860.17 5,849.47 Pup 5 18 L-80 DWC 4.38 5,849.47 5,845.09 Pup 5 18 L-80 DWC 10.03 5,845.09 5,835.06 141 Joints 5 18 L-80 DWC 5,811.93 5,835.06 23.13 Pup 5 18 L-80 DWC 4.33 23.13 18.80 Hanger 11 Sea Board 0.50 18.80 18.30 RKB 18.30 18.30 0.00 Totals 9,745.56 Csg Wt. On Hook: 150600 Type Float Collar: WEATHER FORD No. Hrs to Run: 16.5 Csg Wt. On Slips: N/A Type of Shoe: WFT Reamer Casing Crew: Tesco Fluid Description: Klay-Shield Liner hanger Info(Make/Model): NA Liner top Packer?: _Yes_No Liner hanger test pressure: Centralizer Placement: Every Joint for first 82 Joints run CEMENTING REPORT Preflush(Spacer) Type: Seal Bond Density (ppg) 11.2 Volume pumped(BBLs) 37 Lead Slurry Type: G yield 1.180 Density (ppg) 15.7 Volume pumped(BBLs) 114 Mixing/Pumping Rate(bpm): 4.2 Tail Slurry Type: Lu 0 Density (ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): Post Flush(Spacer) w Type: Density (ppg) Rate(bpm): Volume: cc LL Displacement: Type: MUD Density (ppg) 10.7 Rate(bpm): 5.9 Volume(actual/calculated): 176/172 FCP(psi): 2350 Pump used for disp: Baker Plug Bumped? X Yes No Bump press 3720 Casing Rotated? Yes X No Reciprocated? Yes X No 100 %Returns during job YES Cement returns to surface? Yes X No Spacer returns? Yes X No Vol to Surf: 0 Cement In Place At: 18:10 Date: 3/15/2014 Estimated TOC: 4,600 Method Used To Determine TOC: Calculation Preflush(Spacer) Type: Density (ppg) Volume pumped(BBLs) Lead Slurry Type: Density (ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): Tail Slurry U1 Type: a Density (ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): 1- 0 Post Flush(Spacer) z Type: 0 Density (ppg) Rate(bpm): Volume: w Displacement: w Type: Density (ppg) Rate(bpm): Volume(actual/calculated): FCP(psi): Pump used for disp: Plug Bumped? Yes No Bump press Attachment 5 Attachment 6 * E 13) R. O Pressure - psi asn C) coo .....a — N W -P., CT! OD 170 0„ CD O CD O O O CD_, �i n> O q CD O O CD CD �e ..... . . CD CD O CD O O CD O O CT W CD N .s n ''''•"I CD CV CD N' * CIh b 77 m Cn Di m i'jCn m _ m N D 0 cn CO w --1 0 ! CCD ..,.,, z I D- cWn- v _ 3 N o h ; , co Ce) Z ' y 1 i 7:21 IP rn n CD C N rn - Ei. cn Q G70-1 CO Cn Cp -O CA coCO v C7 M , O y O N co Do CoyO CD -13O 0 -A W _a N Con 5 O O , , , r , W CTor ) c!„ . W NCD CD , O CD N CD O O CD CD O 1112 CIM Iql -Ttp!aM 13 CD Attachment 7 11 Kenai was Field KBU 32-08 Current 06/04/2014 Itikorp.earka,Ill: Kenai Gas Field Tubing hanger,SMB-22 KBU 32-08 ported,11 X 5"18#DWC/C 16x103/4x75/8x5 csg btm x 5.875-4 stub acme LH box top,5"type H BPV prep,4.261 bore,DD material Tree cap,Otis,5 1/8 5M FE X 9'A Otis Quick Union > 0 Crossover spool, 51/85MFEX - s -. 5 1/810M FE 5 Valve,Swab,CIW-FC, �10 C.. .j. 1\g`� �y `Se�� 51/810M FE,HWO, kit,. 44\4% + ec' caJtioS EE trim OQ Cel D \,e44\4% c� ye tac�,Z,a,„sec Ja G �� ti\tib S`7 aoe¢6 "�' � �y ''''''\''' e, 07 w 04 427""4 comma /. Q Cross,stdd,5 1/8 10M X tab \OO i 31/1610M � ls, , 1 741m. 1 Valve,Upper Master, * 0 CIW-FC,5 1/810M FE,HWO, Q 1(}O EE trim 0 0 OG rigloillr Valve,Master,Cactus, 5 1/8 10M FE,HWO, 0 \O EE trim '0S40,.-.) IVO 1 Adapter,Seaboard-EN, 115M stdd x 5 1/810M top, WI 7"PP bottom lissi ME Multibowl Wellhead,SMB-22, '! 11 rill 115M X16''A3M,w/ At 4-21/16 5M SSO 'ilussmik _ C. •' iw —lFi' min G ., f• N- Nil ' k TO !; @( . !i 3o .:• ; - C : : r Attachment 8 CONFIDENTIAL DATA r (,,,A ,,,T,(_ t,e, 00 MC 25.25 3 C6) M t s /iJi5 Attachment 9 30 PAL ,25. Ze33 Ck-) Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday,July 10, 2014 3:04 PM To: 'Paul Chan' Cc: Chad Helgeson;Stan Porhola Subject RE: KBU 32-08 Sundry Application Paul, I will add these steps (set CBP ,test casing and drill-out) to the sundry procedure. Thanks for the HAL BOP schematic. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Paul Chan [mailto:pchanCa)hilcorp.com] Sent Thursday, July 10, 2014 2:04 PM To: Schwartz, Guy L(DOA) Cc: Chad Helgeson; Stan Porhola Subject: KBU 32-08 Sundry Application Guy In order to pressure test the casing to 9600 psi,a composite bridge plug will be set at^'9100' MD. The well will then be loaded with 6%KCI brine. The 7-5/8"x 5"annulus will be pressure tested to 3000 psi for 30 charted minutes and the 5"casing pressure tested to 9600 psi for 30 charted minutes. After the pressure testing has been completed, Halliburton coiled tubing will drill out the CBP in preparation for the first frac. The Halliburton BOPE will be tested to 250 psi low/4500 psi high. I have attached the generic schematic for the Halliburton CT BOPE. Thanks Paul than Operations Engineer p g South Kenai Asset Hilcorp Alaska LLC (907)777—8333 (w) 1 24 API RECOMMENDED PRACTICE 16ST Coiled Tubing . '`� Stripper PR Type u i_y Well Control Component Blind ` SheaI.r. _ .....-x?...- Slip ° ea Kill Line Inlet Pipe °� -7117 Shear-blind Pipe I t°"`— J 1j° -±a.Z::: "I ®° Alternate Assembly I - - — a_ Pipe Slip Dual Combination Ram Stack {{ Shear-blind • f (Combination Ram) BHA with Flow Check Assembly Figure 9—Well Control Stack Components for PC-Conditions(7501 psig to 12,500 psig)—for Returns Taken Through the Tree or Wellhead Below the Well Control Stack c) PC-2—All connections from the tree to the uppermost required ram component in the well control stack configuration should be flanged or hubbed with a minimum pressure rating of 5000 psig. Flanged or other connection types used above the uppermost ram component shall have a minimum pressure rating of 5000 psig. Where surface wellhead and tree construction prevents use of a flange or hub connection, an installation plan for use of other end connectors shall be available and reviewed. For tree construction with a threaded connection only, the threaded connection shall meet the minimum pressure rating of 5000 psig and should be restricted to the connection between the tree and well control stack. d) PC-3—All connections from the tree to the uppermost required ram component in the well control stack configuration shall be flanged or hubbed with a minimum pressure rating of 10,000 psig- Flanged or other connection types used above the uppermost ram component shall have a minimum pressure rating of 10,000 psig. e) PC-4—All connections from the tree to the stripper assembly in the well control stack configuration shall be flanged or hubbed with a minimum pressure rating of 15,000 psig. 4.2.7.4 Other types of connections may be used above the uppermost ram component provided they are in accordance with API 6A and/or API 16A. Copyright Anu0can Petroleum Inseeoe Provided by IHS under license oA h API LlcenseeoHepgaxtonl4197550100,User-Courntle,Perry No reproduction or networking permitted without license from IHS Not for Resale.05/104010 06'09:12 MDT Schwartz, Guy L (DOA) From: Paul Chan <pchan@hilcorp.com> Sent: Thursday,July 10, 2014 9:12 AM To: Schwartz, Guy L(DOA);Wallace, Chris D (DOA) Subject: RE: Sundry 314-383 Well Beluga Unit 32-08 (PTD 214-014) Frac application Attachments: KBU 32-08 Frac Sundry Attachment 3A- SOP Revised 7-8-14.pdf; 32-08 WO Sundry Frac FINAL Rev 1 2014-07-10.pdf Guy/Chris We have updated the information as noted below in red. In addition we will be pressure testing the 5" production casing to 9600 psi in case we have higher than expected well bore tortuosity. We will forward those results after completion of the test. The expected start date is now July 18, 2014. Thanks Paul Chan Operations Engineer South Kenai Asset Hilcorp Alaska LLC (907) 777—8333 (w) (907)444—2881 (c) (907) 345—3161 (h) From: Schwartz, Guy L(DOA) [mailto:guv.schwartz@alaska.gov] Sent: Thursday, July 03, 2014 10:55 AM To: Wallace, Chris D (DOA); Paul Chan Subject: RE: Sundry 314-383 Well Beluga Unit 32-08 (PTD 214-014) Frac application Paul, I just got back from vacation and had a few more comments on the frac procedure: 1) I didn't see where the 5" casing or 5 x 7 5/8" annulus is being pressure tested before the frac ( or verified that is was tested) . The 5" x 7-5/8" annulus was pressure tested to 2000 psi on June 7, 2014. The 5" x 7-5/8" annulus will be pressure tested to 3000 psi prior to executing the first fracture stimulation and we will forward those results after the test. 2) In section F the PRV for the 5" x 7 5/8" annulus is mentioned but not the set pressure. Do you know what this will be? Assume you are testing the IA to 2500 psi although it could go higher if need be. The 5" x 7-5/8" annulus PRV will be set to 2500 psi. 3) Is your plan to keep the 10 3/"x 7 5/8" annulus open to atmosphere? . I believe there was cement pumped to surface in the 7 5/8" but not sure .. the CBL seems to indicate this. The 10-3/"x 7-5/8" annulus will be lined out to an open top tank. The 7-5/8" casing was cemented to surface(with cement returns noted on the report). 4) Not clear if you are flow testing the first zone for a long period of time to clean up or waiting until both zones are frac'd and then do a combined flow test/cleanup. The procedure is not clearly written. I have re-done the procedure (attached). 1 Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),Mate of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Wallace, Chris D (DOA) Sent: Tuesday, June 24, 2014 10:14 AM To: pchan@hilcorp.com Cc: Schwartz, Guy L(DOA) Subject: Sundry 314-383 Well Beluga Unit 32-08 (PTD 214-014) Frac application Paul, We are reviewing the received Sundry Application and I have a clarification or two and a few formatting ideas for your template on the next application. 1. Please clarify the units expressed in Section a) 12 (B) as we are thinking(gpt)gallon per thousand gallon of total hydraulic fracturing fluid volume (liquids only no proppant?), and (ppt) is pounds per thousand pounds of total hydraulic fracturing fluid (liquids only no proppant?). ..orrect. on c e units of gpc dila ppt as scatea auo4, 2. Please update the tables for Section a) 12 (E) "%of Yield Pressure"on the included stimulation(Attachment 8). Updated table (attached). Please note that the chnwn differential pre«{irAc h d r calculation error. 3. Please update the tables for Section a) 12 (F) "Height and Length" based on the included stimulation (Attachment 8). The TVD and MD mentioned in the regulations is to identify the fracture growth not the perforation depth—with the goal to have the Operator review and ensure the fracture is modeled to be within the desired zone and not fracture into a confining layer of across a well/fault etc. Potentially a statement from the Operator in Section a) 12 (F)to restate that"the fractures, as modeled, show that the hydraulic fracturing fluid will be contained within the designated zone and not propagate through the confining zones." Similar intent as Section E). Jpdated table (att?rherl' nd response to a) 12 (F). 4. The plan description should be numbered Section A) 13.And not Section A) 15. Again we renumbered from draft to draft. Nill update on the next sundry application 5. Section D should say"the test pressure determined in (a) 12 (E)" rather than (a) 14(E)as we re-numbered this from the draft regs to the final proposed regulations. Will update on the next sundry application 6. Attachment 3 Water plan—please confirm that in addition to the identified dissolved methane,the testing will include results for dissolved ethane and dissolved propane as per draft regs 25.283 a)4) RSK 175? Corrected and attached (KBU 32-08 Frac Sundry Attachment 3A -SOP Revised 7-8-14 7. Attachment 3 Attachment A the water sampling form—the printing of the first letter in each some of the table cells are missing and the form is printing as 2 pages?? Corrected and attached (KBU 32-08 Frac Sundry Attachment 3A-SOP Revised 7-8-14) The cover letter and in several places within the sundry and program steps—you request confidentiality of Section 8 and 9. Section 9 contains all chemicals even though only 5 of the chemicals are listed as confidential in Section a) 12) C). Please review and let me know what exactly it is you request/claim confidentiality on. The latest regulations detail in Section (k)that confidential trade secret information shall be separately filed in an envelope clearly marked confidential along with a list of the documents which are nondisclosable in accordance with 2 AAC 96.325 (a)(2)(privilege log). As these regulations are not final it is not a requirement- but it could be good to establish this for your current and future Sundries Hilcorp Alaska respectfully withdraws the request for confidentiality of attachment 9. Hilcorp Alaska is 2 requesting extended confidentiality for,__ Jocuments in Attachment 8(already subs,..—ed). The fluid additives will be submitted in a separate envelope marked "Extended Confidentiality"shortly(they are not included in this email). Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallacealaska.gov. 3 • oF '� . ri ` �w�-A1`//y- `9� "I STATE E r.„'_ �. c FIS Y w -'1-:-'---::-?, _ _ /- = - _ 4_ _ - 333 West Se Jcni'n A,e!,uc /F CGOVERNoR St AN PARi�L,I i Anchorage, Alaska 99501-35;2 \ 74 ”) ' Vn�., cn7 '779 1/?'' Paul Chan Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Kenai Gas Field, Upper Tyonek Gas & Beluga Gas Pools, Kenai Beluga Unit 32-08 Sundry Number: 314-345 Dear Mr. Chan: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 01.6. ,4t..„,st Cathy P. erster Chair DATED this J day of June, 2014. Encl. • 1E 4 STATE OF ALASKA �EIV �� ` ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 3 0 ?n f APPLICATION FOR SUNDRY APPROVALS it),:, , „��j/ 20 AAC 25.280 A G ' O 1.Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well❑ Change Appro 'Pf"Cm ❑ Suspend ❑ Plug Perforations Q Perforate Q Pull Tubing E Time Extension ❑ Operations Shutdown ❑ Re-enter Susp.Well ❑ Stimulate ❑ Alter Casing E Other Complete l 2.Operator Name: '4.Current Well Class. 5.Permit to Drill Number AP •44.7 � rpt Hilcorp Alaska,LLC Exploratory E Development E 214-014 ' 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-133-20624-00-00 �� z.r,1 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 E Kenai Beluga Unit 32-08 9.Property Designation(Lease Number): 10.Field/Pool(s): FEEA028142& FEEA022330 Kenai Gas Field/Upper Tyonek Gas&Beluga Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 9,847' 8,138 9,656' 8,022 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 135' 16' 135' 135' Surface 1,478' 10-3/4” 1,478' 1,420' 5,210psi 2,470psi Intermediate 6,406' 7-5/8" 6,405' 5,391' 6,890psi 4,790psi Production 3,897' 5" 9,746' 8,098' 10,140psi 10,500psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A 5" 18#/L-80 5,849' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Swell Packer 5,849'(MD)and 4,940(TVD) 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development Q Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 6/5/2014 Oil ❑ Gas E WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ 7L. Abandoned ❑ Commission Representative: N/A GSTOR 4 Z sISPLUG ❑ 17.I hereby certify that the forego' i true and correct to the best of my knowledge. Contact Paul Chan Email pchanahilcorp.com Printed Nam Paul Chan Title Operations Engineer Signature Phone 777-8333 Date 5/30/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: \ _ CA ffiL Plug Integrity ❑ BOP Test 2 M�echaani�cal Integrity Test ❑ Location Clearance ❑ Other: *- 1.1-.5-0 G psi &)/ 1 t.- 5 i / RBDM e,.'. UN 0 6 2014 Spacing Exception Required? Yes ❑ No [d Subsequent Form Required: 1 )" y 0 7 APPROVED BY Approved by: .),?l� COMMISSIONER THE COMMISSION Date: —3 -/ V Submit Form and Form 10-403(Revised 70,112)6.,-3� Appro e i I I f 1 months from the date of approval. Attachvents in Duplicate ., , ii 411 Well Prognosis Well: KBU 32-08 AFE: 1421941 Hilcorp Alaska,LL, Well Name: KBU32-08 API Number: 50-133-20624-00-00 Current Status: New Gas Well Leg: N/A Estimated Start Date: 5/72014 Rig: N/A Reg.Approval Req'd? 10-403 Sundry Number: Regulatory Contact: Tom Fouts 777-8398 (0) Permit to Drill Number: 214-019 First Call Engineer: Paul Chan (907)777-8333 (0) (907) 345-3161 (H) (907)444-2881 (C) Second Call Engineer: Mike Dunn (907) 777-8382 (0) (907) 351-4191 (M) Measured Bottom Hole Pressure: –3,587psi at 7,970' TVD Max. Anticipated Surface Pressure: –2,725psi (Estimated maximum pump pressure during leak off test) Max. Anticipated Surface Pressure: –5,000psi (Final casing pressure test) Max.Anticipated Surface Pressure: –2,989psi (0.075 psi gas gradient) Brief Well Summary: KBU 32-08 was drilled and completed March 2014. Justification: • Perform extended leak off test in the Tyonek 78-2 water sand to determine reservoir properties of permeability and leakoff coefficient. • Blow well down with N2 and perforate the Tyonek 76-7 gas sand. Flow test the 76-7 gas sand. Summary Procedure: 1. Notify Jeremy Mardambek 24 hours in advance of the timing for the extended LOT. 2. RU 500 bbl tank and fill with 6% K I hri►e. RU pump truck and hard line to wellhead. PT lines to 5,500psi. Note: 5" 18#/ft L-80 Casing/ 100% Burst= 10,140psi/80%Burst=8,112psi. M l 1 IN 3. Pressure test casing to 3,500psi for 30 charted minutes after pressure has stabilized. Bleed off--- pressure. r—_). r,c ,,...r 1,,..,••••-r all L h_,-,--e--6-;--,- f- f2-sl- 4. RU e-line and pressure control equipment. T lubricator to 250psi low/3,500psi high 5. PU perf gun with pressure/temperature sub. Set sub to record pressure and temperatures every 2 seconds. 6. Perforate the Tyonek 78-2 water sand with 3-3/8" 6 SPF 60 deg phased gun. Depths are from the Halliburton Quad Composite LWD log. The depths will be adjusted once the cased hole CBL log has been run and correlated to the composite log. Send the correlation pass to Paul Chan and Sarah Rittenhouse for confirmation. Proposed Perforated Intervals(Open Hole Log Depths) ,IN Sands Top (MD) Btm (MD) FT Tyonek 78-2 9,500 9,510 10 7. Start pumping at 1.0 BPM to start the leak off test. Plot rate vs pressure and note breakover on LOT. 8. Once the pressure break has occurred, keep rate constant for 2 minutes or until the pressure has stabilized (within 50 psi of the same value for 30 seconds) 9. Increase the rate by 1.0 BPM to 2.0 BPM and keep rate constant for 2 minutes or until the pressure has stabilized (within 50 psi of the same value for 30 seconds) 411) Well Prognosis Well: KBU 32-08 AFE: 1421941 Hikorp Alaska,LL) 10. Increase the rate by 1.0 BPM to 3.0 BPM and keep rate constant for 2 minutes or until the pressure has stabilized (within 50 psi of the same value for 30 seconds) 11. Increase the rate by 1.0 BPM to 4.0 BPM and keep rate constant for—100 minutes. Estimated final pump pressure of 2,725psi @ 4 BPM. 12. Shut down pump and record the fall off with the 2 second data acquisition for two hours. 13. POOH with P/T sub and perf gun. ,--, AAA" i<.< « .. ) 14. Notify AOGCC 24 hours prior to setting plug at http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html 15. PU CIBP and set within 50'of the top perforation of the Tyonek 78-2 sand. POOH. 16. Close swab valve. 17. Pressure test CIBP to 5,000psi for 30 charted minutes after pressure has stabilized. 18. RDMO pump truck 19. Dump bail 25'of cement on top of plug 20. POOH. RD a-line. 21. RU CTU, nitrogen, and flow back tank. Notify AOGCC 24 hours prior to testing at http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html. 22. PT BOPE to 250psi low/4,500psi high' 23. Blow well dry down to±9,812'PBTD with nitrogen. Leave well with SITP of^'2,500psi. POOH. 24. RDMO CTU. 25. RU a-line and PT lubricator to 250psi low/3,500psi high. 26. Perforate the Tyonek 76-7 sands with 2-7/8" 6 SPF 60 deg phased GEODynamics Connex gun. Depths are from the Halliburton Quad Composite LWD log. The depths and interval will be adjusted once the cased hole CBL log has been run and correlated to the composite log. Send the correlation pass to Paul Chan and Sarah Rittenhouse for confirmation. Proposed Perforated Intervals(Open Hole Log Depths) Sands Top (MD) Btm (MD) FT Tyonek 76-7 9,275 9,351 82 27. POOH. RD e-line. 28. Turn well over to Operations. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic Kenai Gas Field Well: KBU 32-08 • SCHEMATIC Last Completed: FUTURE IIaeorp Alaska,LLC PTD: 214-014 CASING DETAIL RKB:MSL=22' Size Type Wt/Grade/Conn ID Top Btm 16" Conductor N/A Surf 135' 10-3/4' Surface 45.5/L-80/BTC 9.950 Surf 1,478' 7-5/8" Intermediate 29.7/L-80/BTC 6.875 Surf 6,406' 16" 5" Production 18/L-80/DWC/C-HT 4.226 5,849' 9,746' TUBING DETAIL 5" Tubing 18/L-80/DWC/C-HT 4.226 Surf 5,849' JEWELRY DETAIL 10-3/4" No Depth Item 1 5,849' 5"Swell PackerPacker 2 7,330' 5'Pup 3 8,028' 5'Pup OPEN HOLE/CEMENT DETAIL 10-3/4"" 160BBL's of cement in 13.5"Hole.Returns to Surface 7-5/8" 261BBL's of cement in 9-7/8"Hole.Returns to Surface 5" 114BBL's of cement in 6-3/4"Hole. TOC 4,600 Calculated r 8 , 7-5/8„ , , ` r 0 2 ' • 5 fa l TD=9,746'(MD)/8,098'(TVD) PBTD=9,656'(MD)/8,022'(TVD) Updated by: TDF 5/30/14 lbKenai Gas Field Well: KBU 32-08 • PROPOSED Last Completed: FUTURE Hileorp Alaska,LLC PTD: 214-014 CASING DETAIL RKB:MSL=22' Size Type Wt/Grade/Conn ID Top Btm 16" Conductor N/A Surf 135' ' ^ 10-3/4' Surface 45.5/L-80/BTC 9.950 Surf 1,478' 7-5/8" Intermediate 29.7/L-80/BTC 6.875 Surf 6,406' 16" 5" Production 18/L-80/DWC/C-HT 4.226 5,849' 9,746' TUBING DETAIL 5" Tubing 18/L-80/DWC/C-HT 4.226 Surf 5,849' JEWELRY DETAIL 10-3/4";41 .' No Depth Item 1 5,849' 5"Swell PackerPacker 2 7,330' 5'Pup 3 8,028' 5'Pup OPEN HOLE/CEMENT DETAIL 10-3/4"" 160BBL's of cement in 13.5"Hole.Returns to Surface 7-5/8" 261BBL's of cement in 9-7/8"Hole.Returns to Surface 5" 114BBL's of cement in 6-3/4"Hole. TOC 4,600 Calculated C i3L- PERFORATION DETAIL Btm Sands Top(MD) Btm(MD) Top(TVD) (TVD) FT Date Status Tyonek 76-7 ±9,275' ±9,351' ±7,709' ±7,768' ±82' Future Future Tyonek 78-2 ±9,500' ±9,510' ±7,891' ±7,899' ±10' Future Future • 8 � 7-5/8" _A 0 2 113 w: Tycnek 76-7 .=Tycnek 78-2 (U/4--r 2 5" • TD=9,746'(MD)/8,098'(TVD) PBTD=9,656'(MD)/8,022'(TVD) Updated by: TDF 5/30/14 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, June 02, 2014 2:45 PM To: 'Paul Chan' Cc: Davies, Stephen F (DOA); Mike Dunn Subject: RE: KBU 32-08 Perf and Pump-in test (PTD 214-014) Paul, Go ahead and include MIT—IA in step three. I missed the pump truck rig-up the first time I read it... my fault. Thanks for the clarifications.... Let me know how the CBL looks. If question able contact me before moving ahead with LOT/injection test. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz4alaska.gov). From: Paul Chan [mailto:pchan@hilcorp.com] Sent: Monday, June 02, 2014 2:35 PM To: Schwartz, Guy L (DOA) Cc: Davies, Stephen F (DOA); Mike Dunn Subject: RE: KBU 32-08 Perf and Pump-in test (PTD 214-014) Guy We are running the SCMT CBL log today. We will be using 6%KCI brine. We have not tested the IA yet as we are planning on doing that during the extended LOT. I did not include the IA test in the program. Can we amend step#3 to also include the IA test? We are planning to tie into the wellhead valve and PT the lines to 5500 psi as per step#2. Estimated max pump pressure is 2725 psi @ 4 BPM. We are estimating^'450 bbls of fluid for the extended LOT. Thanks Paul Chan 1 •,Operations Engineer " South Kenai Asset Hilcorp Alaska LLC (907)777—8333 (w) (907)444—2881 (c) (907) 345—3161(h) From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@ alaska.gov] Sent: Monday, June 02, 2014 9:31 AM To: Paul Chan Cc: Davies, Stephen F (DOA) Subject: KBU 32-08 Perf and Pump-in test(PTD 214-014) Paul, Do you have the CBL results yet? Has the IA been pressure tested.. .if so please send me the documentation. Also, as far as the pump-in test...a few questions: 1. What fluid are you pumping? 2. E-line will stay rigged up with Press/temp tool during test .. Assume you are rigging up through their pump-in sub to do the pumping test?There is no mention of the pumping unit rig-up and testing of hardline. 3. What is your expected max pressure at surface during the test? 4. What is your expected total volume to pump? It looks like less than 1000 bbls based on what I read in the procedure. FYI ...when you are plugging back perfs we don't need a inspector notification. That is only for a final abandonment of the wellbore. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guv.schwartz@alaska.gov). 2 L....don Ellison Hilcorp Alaska, Lam_ GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8339 2.4{1.:2-1 Hilknrp Alaska.t.t.t Fax: 907 777-8510 DATA LOGGED .5r /2014 E-mail: Jellison@hilcorp.com .MK BENDER DATE 05/01/14 To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTA KBU 32-08 Mud log data Prints: Final Well Report Formation Log MD 2" Formation Log TVD 2" LWD Combo Log MD 2" LWD Combo Log TVD 2" Drilling Dynamics MD 2" Drilling Dynamics TVD 2" Gas Ratio Log MD 2" Gas Ratio Log TVD 2" CD : Final Well Data Daily Reports 4/6/2014 3:00 PM File folder DML DATA 4/6/2014 3:00 PM File folder Final Well Report 4/6/2014 3:00 PM File folder tit, LAS Data 4/6/2014 3:00 PM File folder Log PDFs 4/6/2014 3:00 PM File folder Log Tiffs 4/6/2014 3:00 PM File folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: 2\4k -0 k44 .don Ellison Hilcorp Alaska, L. GeoTech 3800 Centerpoint Drive, Suite 100 LtZ�CJ Anchorage, AK 99503 Tele: 907 777-8339 42Z Hilrnrp.Alaoka.1.ii• Fax: 907 777-8510 DATA LOGGED E-mail: Jellison@hilcorp.com S i 5/2014 M K BENDER DATE 05/01/14 To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTA KBU 32-08 E log data Prints: BAT DGR EWR-Phase4 ALD CTN MD BAT DGR EWR-Phase4 ALD CTN TVD DGR EWR-Phase4 ALD CTN TVD ROP DGR EWR-Phase4 ALD CTN MD CD 1 : Final Well Data CGM 4.111/2014 9:20 AM File folder DLIS+LAS 4/11/2014 9:20 AM File folder EMF 4/11/2014 9:20 AM File folder 'I. PDF 4/11/2014 9:21 AM File folder TIFF 4/11/2014 9:21 AM File folder CD 2: Directional survey Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: _� Date: �`�\� I1/7%�, 1 HE 61Ai t. �-.-2_;7;.!:_%. - U --L _— -- 333 VJesi Sevenlh Avenue '' i;, �i <;C>VFRNOR SEAN PARNE1 f Anchorage, Alaska 99501-3372 —71�1,`< w fair' 90/ 279 X33 Luke Keller Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Kenai Field, Upper Tyonek and Beluga Gas Pools, KBU 32-08 Hilcorp Alaska, LLC Permit No: 214-014 Surface Location: 552' FNL, 427' FEL, SEC. 18, T4N, R11 W, SM, AK Bottomhole Location: 2021' FNL, 2447' FEL, SEC. 8, T4N, R11 W, SM, AK Dear Mr. Keller: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, P4t4,(4,___ Cathy P Foerster Chair DATED thisAay of February, 2014. STATE OF ALASKA RECEIVED • � 4i1( A ,KA OIL AND GAS CONSERVATION COM. ;ION FEB 0 4 2014 fl,,,,.. vrshiA PERMIT TO DRILL 20 AAC 25.005 la.Type of Work. 1 b.Proposed Well Class: Development-Oil ❑ Service- Winj ❑ Single Zone Q lc.Speci i for: Drill ❑., • Lateral ❑ Stratigraphic Test 0 Development-Gas ❑.r • Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates 0 Redrill❑ Reentry 0 Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal 0 Shale Gas 0 2 Operator Name. 5. Bond: Blanket Q Single Well ❑ 11.Well Name and Number. Hilcorp Alaska,LLC Bond No. 022035244• Kenai Beluga Unit(KBU)32-08 • 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 380 Centerpoint Drive Suite 100,Anchorage,AK 99503 MD: 9,350. TVD. 7,853' Upper Tyonek Gas Pool • 4a. Location of Well(Governmental Section). 7.Property Designation(Lease Number): Beluga Gas Pool . Surface: •552'FNL,427'FEL Sec 18,T4N,R11 W,SM,AK ' FEEA028142 i1.--6Z-t1 V 2.2. A) Az.•'t/y Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1961'FSL,1670'FWL,Sec 8,T4N,R11 W,SM,AK N/A(Kenai Unit Tract 26) 3/2/2014 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2021'FNL,2447'FEL,Sec 8,T4N,R11 W,SM,AK 2494(lease FEEA028142) 6628'FWL Sec.7,TO4N,R11 W,SM 4b.Location of Well(State Base Plane Coordinates-NAD 27)• 10.KB Elevation above MSL: 85 feet • 15.Distance to Nearest Well Open Surface: X=275386.82 • Y=2356184.89 • Zone-4 GL Elevation above MSL: 67 feet 1 to Same Pool: 2475' r 16.Deviated wells: Kickoff depth: 300 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 35 6 degrees Downhole: 4084 psi Surface: 2199 psi 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) Conductor 16" 109 X-56 Weld 80 ft surf surf 80' 80' Driven 13 1/2" 10 3/4" 45 5 L-80 Buttress 1550 ft surf surf 1,550' 1,500' 938 ft3 9 7/8" 7 5/8" 29.7 L-80 BTC 6400 ft surf surf 6,400' 5,455.57' 933 ft3 6 3/4" 5" 18 L-80 DWC/HT 9350 ft surf surf 9,350' 7,853' 734 ft3 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft). Plugs(measured): Effect.Depth MD(ft): Effect.Depth ND(ft)• Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): 20 Attachments: Property Plat 0 BOP Sketch ❑ Drilling Program ❑ Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Janise Barrett Email jbarrett@hilcorp.com Printed Name Luke Ke ler Title Drilling Engineer d/L.Signature Phone (907)777-8395 Date 2,- y-2014 Commission Use Only Permit to Drill c�/� API Number J2 Permit Approval. 1,u I See cover letter for other Number: �t/ ! t✓� 50-! )5 Z{%�,L'--/-(1J eC ) Date: (� � I requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed urethan gas hydrates,or gas contained in shales:1i Other: 41.. 350O rs,. L?o P —Th---5-1— Samples req'd: Yes❑ No / Mud log req'd:Yes❑ og S �H /� HZS measures: Yes❑ Nog Directional svy req'd:Yes No impar c- %\ " 1/ Spacing exception req'd: Yes❑ No t[� Inclination-only svy req'd:Yes❑ No - Ped---P ///7) -f ` epi " - APPROVED BY C Approved by: COMMISSIONER THE COMMISSION Date. Z .? T ei l GANAoLhe /T/ . ! / /9 Submit Form and ��Form 10-401(Revised 10/20P4:12r7- This pe r li date of approval(20 AAC 25.005(8)) Attachments in Duplicate ,; .11 Hilcorp Alaska, LLC P.O. Box 244027 Luke Keller Anchorage, AK 99524-4027 Drilling Engineer Tel 907 777 8395 Hilcorp Email Ikeller@hilcorp.com Energy Company 01/09/2014 " ECEIV E.D FEB 04 2014 Commissioner AOGGC Alaska Oil &Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: Kenai Beluga Unit(KBU) 32-08 Surface Revision Dear Commissioner, Enclosed for review and approval is a change to 10-401 Permit to Drill Application for the Kenai Beluga Unit (KBU) 32-08 Development Gas well. The following changes have been made to the program and are listed below: The surface location has moved to 552' FNL, 427' FEL Sec 18, T4N, R11W, SM, AK, X=275386.82, Y=2356184.89 and the top of the productive horizon has moved to 1961' FSL, 1670' FWL, Sec 8, T4N, R11W, SM, AK. The target total depth location has not changed and remains the same as specified in the original 10-401 Permit to drill Application. Drilling operations are expected to commence approximately March 2nd, 2014. .- If you have any questions, please don't hesitate to contact myself at 777-8395 or Paul Mazzolini at 777-8369. Sincerely, / //IL Luke Keller Drilling Engineer Hilcorp Alaska, LLC Page 1 of 1 • SECTION LINE NOT TO SCALE (NTS) 2"ALUMINUM CAP. ft N:2356501.847 E:275006.250 0 `CAUTION` T'"'"'"' '3HIGH PRESSURE <> 95-1-1617 -s_ �O LATERAL GAS • m !...•\''(:),,_\\t" PIPELINE TO 41-7 SECTION 18, T4N, R111/V1 S.M., AK 1937N 2356721.432 • E 275826.873 • 1 552' FNL(NTS) i.\\ KBU 21-18 • NORTH KBU 24-7X N KBU 41-18X N KBU 14-8 N 2356295.750 2356284.455 E 2356284.892 E N 2356284.867 E 275450.200 275220.644 275279.955 E 275339.989 '11111111,,111111111111I � -...i KBU 11-17X O \ -0 V El N 2356287.728 to E 275399.569 KBU 32-08 \AS UILT SURFACE LOCATION NAD 27 ASP Z4 427' FEL(NTS) --'--_- N: 2356184.890 V: E:275386.820 - F- 2"ALUMINUM z"ALUMINUM CAP --------- Q Q LAT: 60°26'36.963"N z _---- LON: 151°14'37.442"W _ILLI . -r---- 0 ELEV: 66.644' (MSL) KBU 43-07Y Q 427' FEL ® E275387.2099 KBU 33-7 44Q \` 552' FNL 0 I Ela / , I- o o z . 7 ... A :D. KBU 24-7 EDGE OF PAD z A W J KU 41-18 0 A 0 z , C A /-EDGE OF PAD Il ' 2_,p I KU 13-8 lW),.,„1 EQUIP. V 0 BLDG. W PRODUCTION O® FACILITIES METE' O KU 12-17 :LDG. KENAI GAS FIELD 1 PAD 41-18 c F. AL,9s/,i sl � ..' ••7 ,I *: 49-"a * , GRIND&INJECT BUILDING 1.BASIS OF COORDINATES IS U.S.C.&G.S.TRI STATION AUDRY IN A.S.P. / c / ZONE 4. (NAD 27)AVERAGE CONVERGENCE OF POINTS SHOWN:01°5'58" / "14:01744/2I ZP_. 00 U 2.AUDRY GEODETIC POSITION PER NGS: / c0 • M. SCOTT McLANE.. i X=269866.75559"Y LONG:, 045.4216'37.445'W 3)BASIS OF VERTICAL DATUM IS MEAN SEA LEVEL(LOCAL DATUM). /, i, 4928-S _ 4)NORTHEAST CORNER SEC.18 COORDINATES DETERMINED FROM DIRECT % •.. E . 0/31/14•' • SCALE SURVEY TIE TO THE TO EXISTING BLM SECTION CORNER RECOVERED AND ,I1 ESSIONA1-V �� 0 I 100 I 200 NOT THE PROTRACTED SECTION CORNER VALUES. I'1`"‘C‘` I FEET I PROJECT HILLCORP ALASKA, LLC DATE:REVIS1O01/31/14 (Ad\' Consulting Inc KBU WELL 32-08 ON KGF PAD 41-18 DRAWN BY: ICB �I1I�cLANG., AS BUILT SURFACE LOCATION SCALE: 1'=100' �/ NAD 27 • PROJECT NO. 143001 ENGINEERING/MAPPING I SURVEYING/TESTING BOOK NO. 13-20 P.O.BOX 468 SOLVOICE:(907)283-42118DOFAX:(907)283-3265 LOCATION SHEET EMAIL:SAMCLANE@MCLANECG.COM Ililcorp Alaska, LLC S18 T4N R11 W SEWARD MERIDIAN,ALASKA 1 OF 1 /Z KBU 21 2,�51#L• '< j A028055 A05 ,� xS005 11 W Itriicr‘DL000588 Kenai Gas Field Pad'No"34=3� \ w• ,� g( ADL000588 .\.. � ',.`..KU:34=3213HL ...... ..I..nnn . . ` ..rnnnt ::' 21=t6: ' U:416 HL N. I <5U:21e26:BHL�..,, .22i-6.X:B4* Sec. 6 II KEU03:(K1k21-5):Bt1t, r KBU:22=0.6:B.t i1 .. t KBU:4.2=6X:Bl i + N. KBU 21 21:BHLA J KBU:42-BH• .y KV:1340681ek p 8U:135:BHi•,�r /� �. BU�a 06:BHL::t:.::tSU:43\ H "�y r✓ r! `� Sec-4: : .� KBl331... BHL 1 ... Kenai Gas-F.ield7Pad No. 33-01 t.. .....1:..1..... .. \ •jK. 45:BH �� 2"D6 HLti \..tt ::::`t,. .i��ZII...t:Bt . . i 1U t:: :• .:::KBJKU 21 :�L 14t1-4444:-Batik KBU 21-25 BHL- • • "• •- kw 1 / KBE,12�- 1,BFfLr 0' :13.14. 1 .0 b4�06 :Bi-li_ ADL000593 ~IS u, te�8rr .•, �.. 3-cc- t1:: .... i 1 6.1593 Kenai Gas"F.ielcI4c1 No: 14;06 FE'.:,• E•.8'142::K naiGasiFeid�Pacl�No-41:-07 --, , •028047.. ,` %.---• • l.- .N.:-. ...� -- �}UggHL�-::.�., .: :. : ;..: A028047: KBU 1:=• BHL+ • + . . 11,08:1 , KU:31:-.111X:131:4/ I ,. • ADL390821 I•••••E4l.u:Al �-: FEEA028142 Knit 81..0A:0:424/FpB 1L • KENAI UNIT / TU:3 .•ZSHL. :t...i Elzaffl . ...................3:::: oU 1 . i sHE{ S 9 KE 04--b:BF 1.... W:3=0:t "P\ 1 I r Sec. .9 43-12 BHL• :::KBU:23r1V:BRA.....I. 4:...: H�' l : Sec:tf KBU 32-08 IP111 S004N012W KBu:q;19BHL1 KBli:34-7.1fi tiLi �...KBEI:14 0 H , S004N011W K is 24-07 BHL' -....,,� KU( 1:(K94:1-)0) .:&11:24=0:7.1 BIN .1: : :. '. ------- A028143 "4 ` . '::13-178 61{0 32-0IL KBU 21-22 31 I�- . .•i,,_ ��' i,,* A028143 Kenai G:as Fief d, `No 41-18 xl t 1 ��DL000594 :21:188HLr ADL-000594ettai • I .tEl KU:12..1TBH • FEE:ADL' 460 Sec. .16 :::: , Legend FEEADL22330 ......FE ASB. :22330 KU:44-18BHL• Hilcorp O&G Minerals ' t • KBU 32-08 SHL X KBU 32-08 TPH i4 + KBU 32-08 BHL • Other Surface Well Locations KU:4.1-13 BM.: AD L32 ��iI - __—_• Other Bottom Hole Locations M '� -AD032 I, Well Paths Well Pad ! ,- , 1 I Oil and Gas Unit Boundary II 0 2,600 5,200 Kenai Unit Feet KBU 32-08 Alaska State Plane Zone 4, NAD27 Hilcorp Alaska.LLC. Map Date:2/3/2014 STATE OF ALASKA RECEIVED AL :A OIL AND GAS CONSERVATION COMM DN JAN 1 PERMIT TO DRILL 2014 20 AAC 25.005 . - 1a.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑ Service- Winj ❑ Single Zone ✓❑ . lc.Specify if well is proposed for: Drill ❑✓ • Lateral ❑ Stratigraphic Test ❑ Development-Gas Q Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q Single Well ❑ / 11.Well Name and Number: Hilcorp Alaska,LLC Bond No. 022035244 ' Kenai Beluga Unit(KBU)32-08 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 380 Centerpoint Drive Suite 100,Anchorage,AK 99503 MD: 9,350 TVD: 7,853' ' Upper Tyonek Gas Pool 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Beluga Gas Pool Surface: 436'FNL,361'FEL,Sec 18,T4N,R11W,SM,AK A028142 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1943'FSL, 1645'FWL,Sec 8,T4N,R11 W,SM,AK N/A(Kenai Unit Tract 26) 3/2/2014 - Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2021'FNL,2447'FEL,Sec 8,T4N,R11 W,SM,AK 2494(lease A028142) -3,645'FWL Sec.9,TO4N,R11 W,SM 4b.Location of Well(State Base Plane Coordinates-NAD 27): - 10.KB Elevation above MSL: 85 feet. 15.Distance to Nearest Well Open Surface: X=275450.2 ' Y=2356295.7- Zone-4 - GL Elevation above MSL: 67 feet, to Same Pool: 2475' 16.Deviated wells: Kickoff depth: 300 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 35.6 degrees - Downhole: 4084 psi Surface: 2199 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) Conductor 16" 109 X-56 Weld 80 ft surf/ surf 80' 80' Driven 13 1/2" 10 3/4" 45.5 L-80 Buttress 1550 ft suff surf 1,550' 1,500' 166.9 BBLS 9 7/8" 7 5/8" 29.7 L-80 BTC 6400 ft urf surf 6,400' 5,455.57' 166.1 BBLS 6 3/4" 5" 18 L-80 DWC/HT 9350 ft surf surf 9,350' 7,853' 130.7 BBLS 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Silk> Cement Volume MD TVD Conductor/Structural 1 Surface Qf Intermediate r Production Liner f cf , Perforation Depth MD(ft): ( 1 Perforation Depth TVD(ft): 4. 20. Attachments: Property Plat ❑ . -\ BOP Sketch Q Drilling Program ❑ Time v.Depth Plot 0 Shallow Hazard Analysis❑ / Diverter Sketch Q Seabed Report ❑ Drilling Fluid Program El 20 AAC 25.050 requirements❑✓ 21. Verbal Approval: Commission Represents e: Date 22. I hereby certify that the foregoing is true d correct. Contact Janise Barrett Email j_b_arrett(a�hilcorp.com Printed Name Luke Keller ' Title Drilling Engineer Signature /� Phone (907)777-8395 Date I 3 ,Z /Y Commission Use Only Permit to Drill _ /U/, API Number: Permit Approval See cover letter for other Number: LJ t-� 50- /33 -2.64;z,-/-e• (-66 Date: requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: ❑ Other: Samples req'd: Yes❑ No E] Mud log req'd:Yes❑ No❑ H2S measures: Yes❑ No❑ Directional svy req'd:Yes❑ No❑ Spacing exception req'd: Yes❑ No❑ Inclination-only svy req'd:Yes❑ No❑ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Submit Form and Form 10-401 (Revised 10/2012) ThOe rR if Gd 1o1mtl[rom the date of approval(20 AAC 25.005(g)) Attachments in Duplicate Hilcorp Alaska, LLC P.O. Box 244027 Luke Keller Anchorage,AK 99524-4027 Drilling Engineer Tel 907 777 8395 Hilcorp Email Ikeller@hilcorp.com Energy Company 01/09/2014 JAN 1 3 2094 Commissioner AOGCC Alaska Oil &Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: KBU 32-08 Dear Commissioner, Enclosed for review and approval is the application for the Permit to Drill the KBU 32-08 Development Gas well. KBU 32-08 is a 9,350' MD / 7,853' TVD Beluga/Upper Tyonek development well off the 41-18 pad in the Kenai Gas Field. The KBU 32-08 will target the Mid-Lower Beluga and Upper Tyonek reserves on the eastern flank of the field. This well will offset several successful wells including KBU 41-18X, KBU 24-7X and KBU 11-17X. The base plan is a build and hold wellbore reaching a maximum inclination of 35.6 deg and a 4817' vertical separation. Drilling operations are expected to commence approximately March 2nd, 2014. The Saxon Rig # 147 will be used to drill and complete the wellbore. The well will be perforated after the rig has departed. Pursuant to 20 AAC 25.055(a)(3), a spacing exception is NOT required: 1. KBU 32-08 does not fall within 500 ft of a property line where ownership or landownership changes. Pursuant to 20 AAC 25.005 (c) &(d), the following is included: 1. Plat identifying the property on which the well will be drilled. 2. Diagram &description of blowout prevention equipment. 3. Information on drilling hazards. a. MASP calculations are attached per 20 AAC 25.005 (c)(4)(A) b. Potential target reservoirs and their predicted pore pressures are indicated in attached Drilling Program 4. Formation integrity test procedure. 5. Planned casing &cement program (Drilling Program) 6. Drilling fluid program (Drilling Program) 7. Tabulation of predicted depths with equivalent formation pressures. 8. Requirements of 20 AAC 25.025 have been met. a. Blanket state wide bond issued: 22035257 9. Copy of Drilling Program is attached. 10. General description of waste disposal. Operator does not wish to request authorization under 20 AAC 25.080 for an annular disposal operation in the well. a. Drilling waste (cuttings and water based drilling fluids) will be hauled to the Kenai Gas Field • G&I facility. At the G&I facility, cuttings will be tested, and either injected or slotted for beneficial reuse. Hilcorp Alaska, LLC Page 1 of 2 Hilcorp Alaska, LLC Kenai Beluga Unit KBU 32-08 Drilling & Completion Program Ninilchik Field Revision 0 Jan 3rd, 2014 KBU 32-08 Drilling Procedure Hilcorp Energy Company Contents 1.0 Well Summary 2 2.0 Management of Change Information 3 3.0 Tubular Program• 4 4.0 Drill Pipe Information: 4 5.0 Internal Reporting Requirements 5 6.0 Planned Wellbore Schematic 6 7.0 Drilling/Completion Summary 7 8.0 Mandatory Regulatory Compliance/Notifications 8 9.0 R/U and Preparatory Work 10 10.0 N/U 21-1/4"2M Diverter 11 11.0 Drill 13-1/2"Hole Section 14 12.0 Run 10-3/4"Surface Casing 18 13.0 Cement 10-3/4"Surface Casing 20 14.0 BOP N/U and Test 23 15.0 Drill 9-7/8"Hole Section 24 16.0 Run 7-5/8"Production Casing 29 17.0 Cement 7-5/8"Cement Procedure 31 18.0 Drill 6-3/4"Hole Section 34 19.0 Run 5"Production Long String 39 20.0 Cement 5"Production Long String 42 21.0 RDMO 44 22.0 Perf and Frac 44 23.0 BOP Schematic 45 24.0 Wellhead Schematic 46 25.0 Days Vs Depth 47 26.0 Geo-Prog 48 27.0 Anticipated Drilling Hazards 49 28.0 Saxon Rig 147 Layout 52 29.0 FIT Procedure 53 30.0 Choke Manifold Schematic 54 31.0 Casing Design Information 55 32.0 9-7/8"Hole Section MASP 56 33.0 6-3/4"Hole Section MASP 57 34.0 Directional Program(P3) 58 35.0 Directional Plan View(Plot) 61 36.0 Directional Plan View(Plot) 62 37.0 Spider Plot(NAD 27)(Governmental Sections) 63 38.0 Kenai Gas Field 41-18 Pad Plan View 64 39.0 Surface Plat(As Built)(NAD 27) 65 40.0 Offset MW vs TVD Chart 66 41.0 Drill Pipe Information 67 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 1.0 Well Summary Well Kenai Beluga Unit(KBU)32-08 • Pad&Old Well Designation KBU 32-08 is a grass roots well on the existing 41-18 pad Planned Completion Type 5"production tubing Target Reservoir(s) Tyonek/Beluga Planned Well TD,MD/TVD 9350' MD/7853' TVD PBTD,MD/TVD 9200' MD/7731' TVD Surface Location(Governmental) 436' FNL,361' FEL, Sec 18,T4N,R11 W, SM,AK Surface Location(NAD 27) X=275450.2,Y=2356295.7 Surface Location(NAD 83) Top of Productive Horizon (Governmental) 1943'FSL, 1645'FWL, Sec 8, T4N,R11 W, SM,AK TPH Location(NAD 27) X=277540.4,Y=2358514.2 TPH Location(NAD 83) BHL(Governmental) 2021'FNL,2447'FEL, Sec 8,T4N,R11 W, SM,AK BHL(NAD 27) X=278750.5,Y=2359807.4 BHL(NAD 83) AFE Number 1410108 AFE Drilling Days 25 AFE Completion Days 3 AFE Drilling Amount $5.34 MM AFE Completion Amount $0.82 MM Work String 4-1/2" 16.6# S-135 CDS-40(Rental Saxon String) KB Elevation above MSL 85 ft GL Elevation above MSL 67 ft BOP Equipment 11" 5M T3-Energy Annular BOP 11" 5M T3-Energy Double Ram 11"5M T3-Energy Single Ram Page 2 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 2.0 Management of Change Information int Hilcorp Alaska, LLC H iicorPainottpp Changes to Approved Permit to Drill Date: Subject: Changes to Approved Permit to Drill for KBU 32-08 File#: KBU 32-08 Drilling and Completion Program Any modifications to Drilling&Completion Program will be documented and approved below Changes to an approved APD will be communicated to the AOGCC. Date Procedure Change Approved Approved By By Approval: Drilling Manager Date Prepared Drilling Engineer Date Page 3 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 3.0 Tubular Program: Hole OD (in) ID (in) Drift Conn Wt Grade Conn Burst Collapse Tension (in) OD (in) (#/ft) (psi) (psi) (k-lbs) Cond 16'' 15" - - 109 X-56 Weld 13-1/2" 10-3/4" 9.95" 9.875" 11.75" 45.5 L-80 BTC 5210 2480 1040 9-7/8" 7-5/8" 6.875" 6.75" 8.5" 29.7 L-80 BTC 6890 4790 683 9-7/8" 7-5/8" 6.875" 6.75" 8.5" 29.7 P-110 HC BTC 9470 7580 769 6-3/4" 5" 4.276" 4.151" 5.563" 18 L-80 DWC/C 9910 10500 422 HT 4.0 Drill Pipe Information: Hole OD(in) ID (in) TJ ID TJ OD Wt Grade I Conn Burst Collapse Tension Section (in) (in) (#/ft) � (psi) (psi) (k-lbs) All 4.5" 3.826 2.6875" 5.25" 16.6 S-135 CDS40 17,693 16,769 468k All casing will be new, PSL 1 (100%mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on Wellez. • Report covers operations from 6am to 6am • Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area—this will not save the data entered, and will navigate to another data entry tab. • Ensure time entry adds up to 24 hours total. • Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. • Ensure to enter daily mud info,BHA info,directional surveys, depths 5.2 Afternoon Updates • Submit a short operations update each work day to ibarrett@hilcorp.com and lkeller@hilcorp.com by 3pm 5.3 Morning Updates: • Update Intranet homepage"Enter Drilling Comment"each morning before 7 am(Before 5 am on weekends and Holidays). 5.4 EHS Incident Reporting • Notify EHS field coordinator. 1. This could be one of(3) individuals as they rotate around. Know who your EHS field coordinator is at all times, don't wait until an emergency to have to call around and figure it out!!!! a. John Coston: 0: (907) 777-6726 C: (907)227-3189 b. Mark Tornai: 0: (907)283-1372 C: (907)748-3299 c. Thad Eby: 0: (907)777-8317 C: (907)602-5178 2. Spills:Kate Kaufman: 0:907-777-8329 C:907-244-8292 • Notify Drlg Manager 1. Paul Mazzolini: 0: 907-777-8369 C: 907-317-1275 • Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally 1. Send final"As-Run"Casing tally to lkeller@hilcorp.com and jbarrett@hilcorp.com 5.6 Casing and Cmt report • Send casing and cement report for each string of casing to lkeller@hilcorp.com and jbarrett@hilcorp.com Page 5 Revision 0 Jan,2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 6.0 Planned Wellbore Schematic D/^► Minitel*eUnit PROPOSED Well:K6U32-08 PTO: 000-000 API: 50-000-00000-000 CASING DETAIL • Mud tc= 1 Type Wt Grade Conn. _ Top Btm Welg,—. , 8 '4 ._ t-nor-Drover 16' ea Set 109 %-55 Wet: :6' Surf 80' • ---3,- ...:1_ c 45 -.a._ Nitres: ..=5' Surf 15:: 3.': o tiJN= - izier .-5 _ to _: L-8C ETC Surf 5-C, - . , TOC-31410' ` r(r- TUBING 5 :-::-:-•:- 18 L-50 J DWC,Ct!' 5 S-4 i 35' :: , r Drilling Info n g Hole Sect,:- :3. 13-1/2' -.-3't ::,, --1/2' 3-7/8' "•5:'3' 35:x 1-1/2' ; -1:5 a 6-8/4" 5' ::: 4-1/2' Po x Inhibited mud'pls fluid ta ii,44 No. x ip 40."�„""i 1 s' 4.276 :: ,,T -anger "1 2 5,_•�_' 4.276 5375' ::ft -'Pat;,er;:rate' Ce}. 7 e` 1 Mi r PERFORATIONS . zone Top(NI 0 gt,-{MDI Topfrvo) Btm(TVD) SPF Length Cate rq >.t;Cdk Ee1u�n 6326' 3383' :::,e•Oe+.,a 7232' 6066' Ii :eek 8889" 7195' V r,. PSTD=9200'MD/7731'11D TD=9350'11D%7853'TIT • Page 6 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 7.0 Drilling / Completion Summary KBU 32-08 is a 9,350' MD/7,853' TVD Beluga/Upper Tyonek development well off the 41-18 pad in the Kenai Gas Field. The KBU 32-08 will target the Mid-Lower Beluga and Upper Tyonek reserves on the eastern flank of the field. This well will offset several successful wells including KBU 41-18X,KBU 24-7X and KBU 11-17X. The base plan is a build and hold wellbore reaching a maximum inclination of 35.6 deg and a 4817' vertical separation. Drilling operations are expected to commence approximately March 2°a, 2014. The Saxon Rig # 147 will be used to drill and complete the wellbore. The well will be perforated after the rig has departed. The closest industrial water well to the drill wells on pad 41-18 in the Kenai Gas Field is the Kenai B-4. The hole depth is 100' with the water level at 96', and the chlorides are around 1200 ppm. Arsenic levels came in at 11.8 parts per billion,which is over the EPA limit for the naturally occurring substance. Total gas • levels from offset mud logs begin to register at depths as shallow as 175'. The closest domestic water well is the Kenai B-4 KS01, located on the eastern flank of the field,which draws its water from a depth of 268' and has chlorides around 2000 ppm. Casing for the drill wells will be placed well below the fresh water table at 1500' to isolate any useable ground water. Surface casing will be run to 1500' MD and cemented to surface to ensure protection of these resources. Cement returns to surface will confirm TOC at surface. If cmt returns to surface are not observed, a Temp log will be run between 6 — 18 hrs after CIP to determine TOC. Necessary remedial action will then be discussed with AOGCC authorities. All waste & mud generated during drilling and completion operations will be hauled to the Kenai Gas Field G&I facility for disposal /beneficial reuse depending on test results. This facility is on the same pad as the drill well. General sequence of operations: 1. MOB Saxon Rig# 147 to well site. 2. N/U 21-1/4" x 2M diverter. 3. Drill 13-1/2"hole to 1500' MD. Run and cmt 10-3/4" surface casing. 4. N/D diverter,N/U &test 11"x 5M T3-Energy BOP. 5. Drill 9-7/8" hole section to 6,400' MD. Run and cmt 7-5/8" intermediate casing. 6. Drill (and LWD log) 6-3/4"production hole section to well TD. Run RFT pressures. Run and cmt 5"production casing. 7. N/D BOP,N/U tree, RDMO. Page 7 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the below AOGCC regulations. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. • BOPs shall be tested at(2) week intervals during the drilling and completion of KBU 32-08. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. • The initial test of BOP equipment will be to 250/3000 psi & subsequent tests of the BOP equipment will be to 250/3000 psi for 5/5 min(annular to 50%rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. • If the BOP is used to shut in on the well in a well control situation, we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system" • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements" • Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. AOGCC Regulation Variance Requests: • No variance requests at this time. Page 8 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) 13-1/2" • 21-1/4"x 2M Hydril MSP diverter Function Test Only • 11"x 5M T3-Energy(Model 7082)Annular BOP • 11"x 5M T3-Energy Double Ram Initial Test:25043.000-3•521' o Blind ram in btm cavity (Annular 2500 psi) • Mud cross .1t( 9-7/8"&6-3/4" • 11"x 5M T-3 Energy Single Ram • 3-1/8"5M Choke Line Subsequent Tests: • 2-1/16"x 5M Kill line 250/3eo0 35-46' • 3-1/8"x 2-1/16"5M Choke manifold (Annular 2500 psi) • Standpipe,floor valves,etc • Primary closing unit: Control Technologies accumulator unit, 5 station, 120 gallon(12 x 11 gal bottles). • Primary closing hydraulic pressure is provided by an electrically driven triplex pump. Emergency pressure is provided by bottled nitrogen. Required AOGCC Notifications: • Well control event(BOPS utilized to shut in the well to control influx of formation fluids). • 24 hours notice prior to spud. • 24 hours notice prior to testing BOPs. • 24 hours notice prior to casing running & cement operations. • Any other notifications required in APD. Regulatory Contact Information: AOGCC Jim Regg/AOGCC Inspector/(0): 907-793-1236/Email:jim.regg@alaska.gov Guy Schwartz/Petroleum Engineer/(0): 907-793-1226/(C): 907-301-4533 /Email: guy.schwartz@alaska.gov Victoria Ferguson/Petroleum Engineer/(0): 907-793-1247/Email:Victoria.ferguson@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification/Emergency Phone: 907-793-1236(During normal Business Hours) Notification/Emergency Phone: 907-659-2714(Outside normal Business Hours) Page 9 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 9.0 R/U and Preparatory Work 9.1 Set 16" conductor at 60' below ground level. 9.2 Dig out and set impermeable cellar. 9.3 Install Seaboard slip-on 16-3/4" 3M "A" section & 20" adapter bushing. Ensure to orient wellhead so that tree will line up with flowline later. 9.4 Level pad and ensure enough room for layout of rig footprint and R/U. 9.5 Layout Herculite on pad to extend beyond footprint of rig. 9.6 R/U Saxon Rig# 147, spot service company shacks, spot& R/U company man&toolpusher offices. 9.7 After rig equipment has been spotted, R/U handi-berm containment system around footprint of rig. 9.8 Mix mud for 13-1/2"hole section. 9.9 Set test plug in wellhead prior to N/U diverter to ensure nothing can fall into the wellbore if it is accidentally dropped. 9.10 Mud loggers not required in surface hole section. I 9.11 Install 5-1/2" liners in mud pumps. • TSM 1000 mud pumps are rated at 3633 psi (85%) /333 gpm (100%) with 5-1/2" liners. Page 10 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 10.0 N/U 21-1/4" 2M Diverter 10.1 N/U 21-1/4"Hydril MSP 2M diverter System. • N/U 16-3/4" 3M x 21-1/4" 2M DSA(Hilcorp) on 16-3/4" 3M wellhead. • N/U 21-1/4"diverter"T". • Knife gate, 16" diverter line. • Ensure diverter R/U complies with AOGCC reg 20.AAC.25.035(C). 10.2 Function test diverter. Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. 10.3 Ensure to set up a clearly marked"warning zone" is established on each side and ahead of the vent line tip. "Warning Zone"must include: • A prohibition on vehicle parking • A prohibition on ignition sources or running equipment • A prohibition on staged equipment or materials • Restriction of traffic to essential foot or vehicle traffic only. 10.4 Set 15.375"ID wearbushing in wellhead. Page 11 Revision 0 Jan,2014 KBU 32-08 ititDrilling & Completion Procedure Hilcorp Enemy Company 10.5 Rig and Diverter Line Orientation on 41-18 pad KENAI GAS FIELD PAD 41-18 SITE PLAN ruuw.ur0 SECTION LINE NTS ilk 1J S 'CAUTION' / -\ MILK TO.,e NORTH _� / SCALE A ,x xw flOb,NJrM.W.• 11 .eu.,-,•x au.•s Cry MOON>X e>rwv,cr r 1 ,Il'>'."- 150ft c,.,.....c,.�vm , 'OTC ®• >.,. al en.a•. ei.* .I unsa.om 1 V KENAI GAS FIELD rwn,'y» PAD 41.18 ttre OW roz.,e r 11 30 ft eKR0awuoo ntxae r'1 111,11,/ od"eot e.oa e00ay.., .rehan..ve IRMO!MO QM! 0 ro.ater� y r./....rw ...1 tWott•TII OW sno .n.. tWY,4,419S4C M0,0 WZ 0' ! •e•,00 Z F ung0, a04 J. �� 8 SNS "lrrli1 t 14 ., a(BtJ 41.18X KBU 24-8 , s i ' ., ., E 150 ft N 2356048 220 N 7,356046 197 t�; i1 o I E 1415300.140 E 14153E0 172 . v s , X ® N & : ' `E•.1 `22 .578 E 141 > . t 7'91 a 11 0.83 #ti ' TOR V 1 AI GAS FIELD ? S. ' SAD 41-18 ,. 30 ft EDGE OF PAD--‘, 16"Diverter Line Page 12 Revision 0 Jan, 2014 KBU 32-08 HDrilling & Completion Procedure Hilcorp Energy Company 10.6 Diverter Schematic KBU 32-08 Diverter Schematic 1r V III in fill in in fel in itti 1 Annular Preventer `, Hydril?ASP .� 21-'h."2M N Knife Gate Ill iI 1111 16" Diverter line Diverter Tee,21-W x 21-W x 2M w!16"ANSI 150 outlet 4-,— _ ��,--. ISI ail Ili ISI lel 16-W3Mx21-W2MDSA :.sN�i, lI'�/IV i '$ i ice' i_ v, : : ,. „S It l O, 4 ! I, Seaboard 16-W 3M i ��' I Casing head Assy 6" Page 13 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 11.0 Drill 13-1/2" Hole Section 11.1 P/U 13-1/2" directional drilling assy: • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Bit TFA should be —0.7 in2. We need to pump at 500 to 510 gpm to clean the hole effectively. • Workstring will be 4.5" 16.6# S-135 CDS40 11.2 Hydraulics Summary: Depth- Hole Size Pump Rate Standpipe Est Openhole MW ECD TFA MD (ft) (in) (gpm) Pressure (psi) AV(fpm) (ppg) (ppg) (in2) BHA MM + MWD+25 0- 1500 13-1/2" 510 1200 77 9.0 9.2 0.70 HWDP Page 14 Revision 0 Jan, 2014 KBU 32-08 iltDrilling & Completion Procedure Hilcorp Energy Company 11.3 Primary bit will be the Smith 13-1/2" XR+ Milled Tooth Bit. These are available at Schlumberger facility in Nikiski. SMITH BITS Xp l o r e r Expan d e d A Schlumberger Company 13-1/2" XR+ Milled Tooth (342.9 MM) ID:0057813010 FEATURES IADC:115i me The sealed precision roller bearing provides a robust. reliable platform capable of ,.• t *- excellent performance in a . `i ,1 ; wide range of applications. Tight tolerance surfaces and controlled contour rollers provide significantly ' # improved bearing life and =r i y.. , allow the bit to drill at a high w ROP for extended periods of _ y time. " / . ■ The Gemini twin seal system consists of a primary seal which protects the bearing. I and a secondary seal that protects the primary seal. This dual seal system will perform reliably for extended periods of time in high RPM. heavier WOB,high mud Xplorer Expanded bits are specifically designed to drill soft formations with exceptional weight and severe dogleg ROP and reliability. With the proven Gemini Twin Seal system and the ultra durable applications. MIC2 hardmetal,these bits deliver maximum ROP and long run times in a wide range ■ Premium hardmatal material of applications. reduces wear,provides e ar4,TvailA, Specifications superior durability and ".i +. Bearing Type Sealed Precision Roller Bearing ensures that a full gauge j hole is drilled. Seal Type Gemini"Twin Seal System Bit Connection Type 6-518'API Reg. Rows Total:7 Inner.4 Gage:3 Inserts/Teeth Total:74 Inner:44 Ga!-:30 Operating Parameters Weight on Bit 10,000 To 55,000(lbs) 4,545 To 24.998(daN) 4 To 25(Tonnes) Rotary Speed(RPM) 280 To 50 Operating parameters are typical ranges.Please contact your Smith Bits representative for recommendations for your individual well. Page 15 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 11.4 4-1/2" Workstring & HWDP will come from Saxon. Jars will come from Weatherford. 11.5 13-1/2"proposed BHA: • 13-1/2"MTB (IADC 117) • A962M5640XP Mud Motor • 8-1/4"NM Pony Collar • NM Stabilizer(13-3/8" OD) • 8-1/4"Drill Collar • PowerPulse 825 NF • Bottleneck XO • 7"NMDC • 8-3/8"NM Stab • 7"NMDC • (5) 4-1/2"HWDP • 6-1/4"Dailey Jar • (21) 4-1/2"HWDP • 4-1/2"DP to surface. 11.6 No LWD tools will be run on the 13-1/2"hole section. 11.7 Begin drilling out from 16"conductor at reduced flow rates to avoid broaching the conductor. 11.8 Drill 13-1/2"hole section to 1550' MD/ 1500' TVD. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 510 gpm. This gives us an annular velocity of 77 fpm, which is borderline for effective hole cleaning. Ensure shaker screens are set up to handle this flowrate. • Utilize Inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team. Work through coal seams once drilled. • Keep swab and surge pressures low when tripping. • Make wiper trips every 500' or every couple days unless hole conditions dictate otherwise. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. Keep API fluid loss< 10. • TD the hole section in a good shale btwn 1500' & 1600' MD. • • Take MWD surveys every stand drilled(60' intervals) • Page 16 Revision 0 Jan,2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 11.9 13-1/2"hole mud program summary: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system(1)ppg above highest anticipated MW. We will start with a simple gel+FW spud mud at 8.8 ppg. MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. System Type: 8.8—9.3 ppg Pre-Hydrated Aquagel/freshwater spud mud Properties: Depths Density Viscosity Plastic Viscosity Yield Point API FL LGS 80-1500' 8.8—9.3 1 85-150 20-40 25-45 <10 <15% System Formulation: M-I Gel + FW spud mud Product Concentration Fresh Water 0.905 bbl M-I Gel Export 20 ppb M-I Wate As needed Soda Ash 0.5 ppb Caustic Soda 0.1 ppb Busan 1060 0.04ppb 11.10 At TD;pump sweeps, CBU, and pull a wiper trip back to the 16" conductor shoe. 11.11 TOH with the drilling assy, handle BHA as appropriate. Page 17 Revision 0 Jan,2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 12.0 Run 10-3/4" Surface Casing 12.1 R/U and pull 15.375" wearbushing. 12.2 R/U Weatherford 10-3/4" casing running equipment. • Ensure 10-3/4" BTC x CDS 40 XO on rig floor and M/U to FOSV. • R/U fill-up line to fill casing while running. • Ensure all casing has been drifted on the location prior to running. • Be sure to count the total # of joints on the location before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor&model info. 12.3 P/U shoe joint, visually verify no debris inside joint. 12.4 Continue M/U &thread locking shoe track assy consisting of: • (1) Shoe joint w/float shoe bucked on (thread locked). • (1) Joint with coupling thread locked. • (1) Joint with float collar bucked on pin end &thread locked. • Install (2) centralizers on shoe joint over a stop collar. 10' from each end. • Install (1) centralizer, mid tube on thread locked joint and on FC joint. • Ensure proper operation of float equipment. 12.5 Continue running 10-3/4" surface casing • Fill casing while running using fill up line on rig floor. • Use "API Modified"thread compound. Dope pin end only w/paint brush. • M/U connections to the base of the triangle stamped on the pin end. Note M/U torque values required to achieve this position. Estimated torque to reach base of triangle: 10,750 ft-lbs. • After making up several connections, use the torque required to M/U to base of triangle as the M/U torque and continue running string. • Install (1) centralizer every other joint to 300'. Do not run any centralizers above 300' in the event a top out job is needed. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 10-3/4" BTC Estimated M/U Torque Casing OD Est Torque to Reach Triangle Base 10-3/4" 10,750 ft-lbs Page 18 Revision 0 Jan,2014 KBU 32-08 Drilling& Completion Procedure Hilcorp Energy Company Tenaris Casing and Tubing Performance Data Choose pipe size,wall thickness and steel grade to view API connection options and performance data. Size 11111111111 Wall - Grade 0 Connection Unit 11111.12 Pipe Body Data GEOMETRY Nominal OD 10.750 in Wall Thickness 0.400 in API Drift Diameter 9.794 in Nominal Weight 45.50 lbs/ft Nominal ID 9.950 in Alternate Drift Diameter 9.875 in Plain End Weight 44.26 lbstft Nominal Cross Section 13.006 sq in PERFORMANCE Steel Grade L80 Minimum Yield 80,000 psi Minimum Ultimate 95,000 psi .— Body Yield Strength 1,040,000 lbs Internal Yield Pressure 5,210 psi Collapse Pressure 2,470 psi V 4J ll► — Connection Data GEOMETRY Regular OD 11.750 in Threads Per Inch 5 Make-Up Thread Turns 1 PERFORMANCE Steel Grade L80 Minimum Yield 80,000 psi Minimum Ultimate 95,000 psi Joint Strength 1,063,000 lbs Internal Pressure 5,210 psi Resistance enarisHydril PremiumaC nne—ins Print Contact Us Ver 8.6 12.6 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.7 Slow in and out of slips. 12.8 P/U casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe as close to TD as possible. Strap the landing joint while it is on the deck and mark the joint at (1) ft intervals to use as a reference when landing the hanger. 12.9 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. Page 19 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 12.10 R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 12.11 After circulating, lower string and land hanger in wellhead again. 13.0 Cement 10-3/4" Surface Casing 13.1 Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cmt unit at acceptable rates. • How to handle cmt returns at surface, regardless of how unlikely it is that this should occur. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cmt operation. • Document efficiency of all possible displacement pumps prior to cement job. 13.2 R/U cmt head (if not already done so). Ensure top and bottom plugs have been loaded correctly. 13.3 Pump 5 bbls 10 ppg spacer. Test surface cmt lines. 13.4 Pump remaining 35 bbls 10 ppg spacer. 13.5 Drop bottom plug. Mix and pump cmt per below recipe. 13.6 Cement volume based on annular volume + 50% open hole excess. Job will consist of lead & tail, TOC brought to surface. V Estimated Total Cement Volume: Section: Calculation: Vol(BBLS) Vol (ft3) LEAD: 80' x .106 bpf= 8.5 47.8 16" Conductor x 10-3/4" casing annulus: LEAD: (1000' —80') x .065 bpf x 1.5 = 89.7 504 13-1/2" OH x 10-3/4" Casing annulus: Total LEAD: 98.2 552 TAIL: (1550'-1000') x .065 bpf x 1.5 = 53.6 335 13-1/2" OH x 10-3/4" Casing annulus: TAIL: 90 x .096 bpf = 8.7 48.8 10-3/4" Shoe track: Total TAIL: 68.7 386 Page 20 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company Cement Slurry Design: Lead Slurry (1000' MD to surface) Tail Slurry (1550' to 1000' MD) System Extended Conventional Density 12 lb/gal 15.4 lb/gal Yield 2.44 ft3/sk 1.22 ft3/sk Mixed Water 14.349 gal/sk 5.507 gal/sk Mixed Fluid 14.469 gal/sk 5.507 gal/sk Code Description Concentration Code Description Concentration Type1 Cement 94 lb/sk WBWOB Type1 Cement 94 lb/sk WBWOB Additives D110 Retarder 0.12 gal/sk VBWOC D046 Anti Foam 0.2% BWOB D046 Anti Foam 0.2% BWOB D065 Dispersant 0.4% BWOB D079 Extender 2.0% BWOB S002 CaCl2 0.2% BWOB D020 Extender 2.6% BWOB S002 CaCl2 0.2% BWOB 13.7 Attempt to reciprocate casing during cement pumping if hole conditions allow. Keep the hanger elevated above the wellhead while working. If the hole gets "sticky", land the hanger on seat and continue with the cement job. 13.8 After pumping cement, drop top plug and displace cement with mud. 13.9 Ensure cement unit is used to displace cmt so that volume tracking is more accurate. Be lined up to displace with rig pumps as well, in the event there is an issue during the displacement with the rig pumps. 13.10 Displacement calculation: 1411' x .0962 bpf= 135.7 bbls 13.11 Monitor returns closely while displacing cement. Adjust pump rate if necessary. If hanger flutes become plugged, open wellhead side outlet in cellar and take returns to cellar. Be prepared to pump out fluid from cellar. Have some sx of sugar available to retard setting of cement. 13.12 Do not overdisplace by more than V2 shoe track volume. Total volume in shoe track is 8.7 bbls. 13.13 Be prepared for cement returns to surface. If cmt returns are not observed to surface, be prepared to run a temp log btwn 6— 18 hours after CIP. 13.14 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until Page 21 Revision 0 Jan, 2014 KBU 32-08 II Drilling & Completion Procedure Hilcorp Emu Company cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held. 13.15 R/D cement equipment. Flush out wellhead with FW. 13.16 Back out and L/D landing joint. Flush out wellhead with FW. 13.17 M/U pack-off running tool and pack-off to bottom of Landing joint. Set casing hanger packoff. Run in lock downs and inject plastic packing element. 13.18 Lay down landing joint and pack-off running tool. Ensure to report the following on wellez: • Pre flush type,volume(bbls)&weight(ppg) • Cement slurry type, lead or tail,volume&weight • Pump rate while mixing,bpm,note any shutdown during mixing operations with a duration • Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement,actual displacement volume,whether plug bumped&bump pressure, do floats hold • Percent mud returns during job, if intermittent note timing during pumping of job.Final circulating pressure • Note if pre flush or cement returns at surface&volume • Note time cement in place • Note calculated top of cement • Add any comments which would describe the success or problems during the cement job Send final "As-Run" casing tally& casing and cement report to lkeller@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 22 Revision 0 Jan,2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 14.0 BOP N/U and Test 14.1 N/D the conductor riser. 14.2 N/U Seaboard multibowl wellhead assy. Install packoff 10-3/4" P-seals. Test to 3000 psi. 14.3 N/U 11"x 5M T3-Energy BOP as follows: • BOP configuration from Top down: 11" x 5M T3-Energy annular BOP/11" x 5M T3-Energy Model 6011i double ram/11"x 5M mud cross/11"x 5M T3-Energy Model 6011i single ram • Double ram should be dressed with 2-7/8 x 5" VBRs in top cavity, blind ram in btm cavity. • Single ram should be dressed with 2-7/8 x 5" VBRs • N/U bell nipple, install flowline. • Install (1) manual valves & (1) HCR on kill side of mud cross. Manual valve used as inside or"master valve". • Install (1) manual valve on choke side of mud cross. Install an HCR outside of the manual valve. L•7•/7 14.4 Run 4-1/2" BOP test assay, land out test plug (if not installed previously). • Test BOP to 250L3psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. • Ensure to leave "B" section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. 14.5 R/D BOP test assy. 14.6 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.7 Mix 9 ppg 6% KC1/Kla-Shield drilling fluid for 9-7/8" hole section. 14.8 Set 10" ID wearbushing in wellhead. 14.9 Mud loggers not required in the intermediate hole section. R/U Canrig infrared mud gas detector and tie into the Pason PVT (if possible). This will allow gas units to be measured while drilling. 14.10 Rack back as much 4-1/2" DP in derrick as possible to be used while drilling the hole section. 14.11 Install 5" liners in mud pumps. • TSM 1000 mud pumps are rated at 4250 psi (85%) /275 gpm (100%)with 5" liners. Page 23 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 15.0 Drill 9-7/8" Hole Section 15.1 Prior to P/U 9-7/8" directional BHA—test casing against blind rams to 2600 psi / 30 min. 15.2 P/U 9-7/8"directional drilling assy consisting of: • 9-7/8"PDC bit(Smith MSi616) • Mud Motor(1.2deg, confirm optimum setting with DD) • Non-Mag Stab (9-3/4" OD) • NMPC • MWD (D&I) • ARC Res/GR 675 • (3)Non-Mag Flex collars • XO • (5) 4-1/2"HWDP • Dailey Jar • Well Commander Circulation sub. • (21) 4-1/2"HWDP • 4-1/2" DP to surface 15.3 Ensure BHA components have been inspected previously. 15.4 Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 15.5 Bit TFA should be—0.75 —0.80 in2. We need to pump at—450 - 500 gpm to clean the hole effectively. Have the directional driller run hydraulics calculations to confirm optimum TFA. 15.6 9-7/8"hole section mud program summary: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system(1)ppg above highest anticipated MW. MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. r System Type: 9.0—9.5 ppg 6%KC1/K1a-Shield fresh water based drilling fluid. Page 24 Revision 0 Jan,2014 • KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company Properties: Depths Density Plastic Viscosity Yield Point HTHP FL CL— LGS(%) (mg/I) 1500'-6,400' 9—9.515-30 20-30 <10 20,000— < 6% ✓ 32,000 System Formulation: M-1 Swaco "KIa-Shield" Drilling Fluid Product Concentration Water 0.905 bbl Flowzan 1 ppb (Viscosity) PolyPac Supreme UL 1 ppb (API Fluid loss) M-I Wate As needed for density(Weighting Agent) Potassium Chloride (KCL) 21.8 ppb (Inhibition) Busan 1060 0.4 ppb (Biocide) EMI-2009 6 ppb (Shale/Clay Inhibition) DF-9065 0.05 ppb (Anti-foaming agent) Asphasol Supreme 4 ppb (Shale/Coal Stabilizer) Sack Black 3 ppb(Gilsonite Shale/Coal Stabilizer) Caustic Soda 0.2 ppb (pH controller) 15.7 Hydraulics Summary: 9-7/8" Hole Section Hydraulics Summary Depth-MD Hole Size Pump Rate Standpipe Est Openhole MW ECD TFA (ft) (in) (gpm) Pressure (psi) AV(fpm) (ppg) (ppg) (in2) BHA 2000 9-7/8" 500 1300 158 9 9.1 0.75 MM + MWD+25 HWDP 4000 9-7/8" 500 1400 158 9 9.1 0.75 MM + MWD+25 HWDP 6000 9-7/8" 500 1700 158 9 9.2 0.75 MM + MWD+25 HWDP Page 25 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Enemy company 15.8 Primary bit for the 9-7/8" hole section will be the 9-7/8" Smith SHARC MSi616 PDC bit. It is available from Schlumberger facility in Nikiski. Be sure to call out an insert bit to have available as back up. SHARC SMITH BITS A Schlumberger Company 9 7/8 in MSi6I6 PDC (250.825 mm)ID:64680A0108 FEATURES • Bit design and performance have been +`. certified through the validation process presented by IDEAS simulation technology. , • The PX feature places thermally stable diamond inserts(TSP)on the gauge to maximize gauge retention r _ and extend bit life. I I ■ Bit design is available with ("t ONYX fixed cutters for improved thermal stability in r harder,more abrasive ° " formations.resulting in --. greater wear resistance. The Smith High Abrasion Resistance Configuration(SHARC)bits are designed with the durability to withstand the demands of highly abrasive formations without sacrificing ROP. Specifications Totts Cutters 69 Cutter Size 16mm(518 in) Face Cutters 124)16mm Gauge Cutters i 71 16mm Cone Cutters 19)16mm Back-Up Cutters (29)16mm Blade Count 6 Nozzles 6 Standard Series 6014 Bit Connection 6 5%'8 Reg Junk Slot Area.kit 13.122 Gauge Length:3' Protection:Options Available Length Make-Up:11.086 OveraN:16.024 Fishing Neck Diameter:7.5 Length:4.382 Operating Parameters Rotary Speed Suitable for Rotary b PDM Weight.on•84 5.000 To 30,000(Ibf) 2,272 To 13,635(daN) 2 To 14(Tonnes) Flow Rate galUs/'min 400 To 850 Hydraulic Horsepower,HSI 1 To 6 Recommended Make-up Torque 47,300 To 47,800 flubs Operating parameters are typical ranges.Please contact your Smith Bits representative for recommendations for your individual well, Page 26 Revision 0 Jan,2014 KBU 32-08 II Drilling & Completion Procedure Hilcorp Ena.c.,,,p, 15.9 TIH, Conduct shallow hole test of MWD and confirm Gamma Ray LWD functioning properly. 15.10 Continue in hole and tag TOC. Note depth tagged on AM report. 15.11 Drill out plugs and shoe track. Clean out rat hole and drill an additional 20' of new formation. 15.12 CBU and condition mud for FIT. 15.13 Conduct FIT to 12 ppg EMW. 15.14 Drill 9-7/8" hole section to 6400' MD / 5455' TVD. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 500 gpm. Ensure shaker screens are set up to handle this flowrate. • Utilize inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team, try to avoid sliding through coal seams. Work through coal seams once drilled. • Keep swab and surge pressures low when tripping. • Make wiper trips every 500' or every couple days unless hole conditions dictate otherwise. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. Keep HTHP fluid loss < 10. • Take MWD surveys every other stand drld. Surveys can be taken more frequently if deemed necessary. • Ensure to pre-treat the active system with 10 ppg Calcium carbonate. Have additional fibrous and other bridging material on location in the event lost returns is encountered. There are many stacked sands that are severely depleted that will be penetrated in the 9-7/8"hole section. Page 27 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 15.15 Casing Point selection • KBU 13-08 is the closest offset to use for correlation to pick casing point. Below is the annotated GR+ gas +resistivity log. • We want to set the 7-5/8" shoe 10 - 20' into the shale below the MBIA sand. ,/ • This will allow us to drill out from the shoe, and conduct a LOT to gather some useful fracture data for these shales at this depth. This will aid greatly in the frac design for the well. 0 . „ a i . . ._ :—.1„.„:„. l A,.; ; ; .. ,. . fj MBOA SAND ` weMabine mot rti . _.---'- HMI[ IYIr•aa^ , .. ... . M806 SAND i - ,.. �nf¢ ._ __ f J MB1A SAND �� .._-.:_. ._ - _ - ti 9 875m Cag Pt *t �..,„..,-, 5410'-54S0'tva •. �. _ ,- .. _ - .,,L �. 7 _ 4 3 MOr rfr. . + LhShw6.' LNb f ML . Q } . . to 15.16 At TD; pump sweeps, CBU, and pull a wiper trip back to the 10-3/4" shoe. 15.17 TOH with the drilling assy, handle BHA as appropriate. Page 28 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 16.0 Run 7-5/8" Production Casing 16.1 R/U and pull 10"ID wear bushing. Install and test 7-5/8"casing ram in top ram cavity. Test to 250/3000 psi. 16.2 R/U Weatherford 7-5/8" casing running equipment. • Ensure 7-5/8" BTC x CDS-40 XO on rig floor and M/U to FOSV. • R/U fill up line to fill casing while running. • Ensure all casing has been drifted on the deck prior to running. • Be sure to count the total#of joints on the deck before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor&model info. 16.3 P/U 7-5/8" 29.7#L-80 BTC shoe joint, visually verify no debris inside joint. 16.4 Continue M/U &thread locking the shoe track assy consisting of: • (1)Float shoe joint w/float shoe bucked on. Install (2)bow spring centralizers at 10' from each end over a stop collar. • (1)Baker locked joint. Install (1)centralizer mid tube over a stop collar. • (1)Float collar joint w/float collar bucked on pin end. Install (1) centralizer mid tube over a stop collar. • Ensure proper operation of float shoe and float collar. 16.5 Run 7-5/8"29.7#L-80 BTC casing. • Fill casing while running using fill up line on rig floor. • Use"API Modified"thread compound. Dope pin end only w/paint brush. • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Install centralizers over couplings on every other joint to 1550' MD. 16.6 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 16.7 Slow in and out of slips. 16.8 P/U casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe approx 10—20' above TD. Strap the landing joint while it is on the deck and mark the joint at(1) ft intervals to use as a reference when landing the hanger. Page 29 Revision 0 Jan,2014 KBU 32-08 Drilling& Completion Procedure Hilcorp Energy Company Casing and Tubing Performance Data PIPE BODY DATA GEOMETRY Outside Diameter 7.625 in Wall Thickness 0.375 in API Drift Diameter 6.750 in Nominal Weight 29.70 lbs/ft Nominal ID 6.875 in Alternative Drift Diameter n.a. Plain End Weight 29.06 lbs/ft Nominal cross section 8.541 in PERFORMANCE Steel Grade 180 Minimum Yield 80,000 psi Minimum Ultimate 95,000 psi Tension Yield 683,000 in Internal Pressure Yield 6,890 psi Collapse Pressure 4,790 psi Available Seamless Yes Available Welded No CONNECTION DATA TYPE:ETC GEOMETRY Coupling Reg OD 8.500 in Threads per in 5 Thread turns make up 1 PERFORMANCE Steel Grade 180 Coupling Min Yield 80,000 psi Coupling Min Ultimate 95,000 psi Joint Strength 721,000 lbs Internal Pressure Resistance 6,890 psi 7-5/8" BTC Estimated M/U Torque Casing OD Est Torque to Reach Triangle Base 7-5/8" 7,630 ft-lbs 16.9 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 16.10 R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat (slightly) to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 16.11 Continue circulating until required properties achieved for cmt operations. 16.12 After circulating, lower string and land hanger in wellhead again. Page 30 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hileorp Energy Company 17.0 Cement 7-5/8" Cement Procedure 17.1 Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. • How to handle cmt returns at surface, regardless of how unlikely it is that this should occur. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cmt operation. • Document efficiency of all possible displacement pumps prior to cement job. 17.2 R/U cmt head (if not already done so). Ensure flexible shut-off plug supplied by stage tool hand is loaded and ready. 17.3 Pump 5 bbls 13.5 ppg spacer. Close low torque on plug dropping head,test surface cmt lines to 4000 psi. 17.4 Pump remaining 35 bbls 13.5 ppg spacer. 17.5 Mix and pump slurry per below calculations: Section: Calculation: Vol(BBLS) Vol(ft3) LEAD: 9-7/8" OH x 7-5/8" csg: (5,900'- 3,000') x .038 bpf x 1.25 = 138 775 Total Lead: 138 bbls 775 ft3 TAIL: 500' x .038 bpf x 1.25 = 24 135 9-7/8" OH x 7-5/8" csg: TAIL: 7-5/8" Shoe Track: 90' x .046 bpf= 4.1 23 Total Tail: 28.1 bbls 158 ft3 Page 31 Revision 0 Jan, 2014 KBU 32-08 intDrilling & Completion Procedure Hilcorp Energy Company Slurry Information stage System Conventional Conventional Density 10.5 lb/gal 15.3 lb/gal Yield 1.58 ft3/sk 1.35 ft3/sk Mixed Water 8.09 gal/sk 5.912 gal/sk Mixed Fluid 8.09 gal/sk 5.962 gal/sk Expected Thickening 5:30 HR:MIN 4:00 HR:MIN Expected ISO/API Fluid Loss 13 mL in 30 min Code Description Concentration Code Description Concentration G Cement 94 Ib/sk WBWOB G Cement 94 lb/sk WBWOB D110 Retarder 0.05 gal/sk D110 Retarder 0.05 gal/sk VBWOC VBWOC Additives D046 Anti Foam 0.2%BWOB D046 Anti Foam 0.2%BWOB D020 Extender 4.0%BWOB D202 Dispersant 1.5%BWOB D065 Dispersant 0.3%BWOB D400 Gas Control Agent 0.8%BWOB D800 Retarder 0.2%BWOB D154 _ Extender 8.0%BWOB D174 Expanding Agent 1.5%BWOB 17.7 After pumping cement, drop flexible shut-off plug and displace cement with mud. Use the cement unit to displace with as volumes can be tracked much more accurately. Displacement calcs: • 6,310' x .0459 bpf= 290 bbls. • Displace with 10 ppg 6% KC1/Kla-Guard drilling fluid out of mud pits. 17.8 Monitor returns closely while displacing cement. Adjust pump rate if necessary. 17.9 Do not overdisplace by more than '/2 shoe track volume. Total volume in shoe track is 4.1 bbls 17.10 There should be no cmt returns to surface. TOC is planned to be at 3000' MD. 17.11 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. • If this is the case, monitor the pressure on the casing and do not let it exceed 500 psi over the final pump pressure. Page 32 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hilcorp EnergY Company Ensure to report the following on wellez: • Pre flush type, volume(bbls)&weight(ppg) • Cement slurry type, lead or tail,volume&weight • Pump rate while mixing, bpm,note any shutdown during mixing operations with a duration • Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement, actual displacement volume,whether plug bumped&bump pressure, do floats hold • Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure • Note if pre flush or cement returns at surface&volume • Note time cement in place • Note calculated top of cement • Add any comments which would describe the success or problems during the cement job Send final "As-Run" casing tally & casing and cement report to lkeller@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. 17.1 R/D cement equipment. Flush out wellhead with FW. 17.2 Back out and L/D landing joint, flush out wellhead with FW. 17.3 M/U pack-off running tool and pack-off to bottom of landing joint. Set casing hanger pack-off. Run in lock downs and inject plastic packing element. Test void to 250/3000 psi for 10 min. 17.4 Lay down landing joint and pack-off running tool. Page 33 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 18.0 Drill 6-3/4" Hole Section 18.1 Remove 7-5/8" casing rams from BOP. Install 2-7/8" x 5" VBRs in top cavity. BOP configuration should be (from top down): Annular/VBR/Blind/Mud cross/VBR. 18.2 Test BOPs on 4-1/2" and 5"test joints. 18.3 R/U Mud loggers for the 6-3/4"production hole section. They need to be set up to generate mud log, pixler plots, and collect (3) sets of samples every 20 ft. 18.4 Pull test plug, run and set wear bushing. 18.5 Run CBL on 7-5/8" casing. 18.6 P/U 6-3/4" directional drilling assy consisting of: • 6-3/4" PDC bit (Smith MDi613). • Mud Motor(1.18 deg, consult with DD for optimum setting) • Non-Mag Stab (6-5/8" OD) • NMPC • Impulse MWD (D&I, GR, Res) • VDN (Vision Den/Neu) • SonicScope (Sonic) • (3)Non-Mag Flex collars • XO • (5) 4-1/2" HWDP • Dailey Jar • (15) 4-1/2"HWDP • 4-1/2" DP to surface. 18.7 Ensure BHA Components have been inspected previously. Rack enough 4" DP in derrick to drill the entire open hole section without having to pick up pipe from the pipeshed. 18.8 Drift& caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 18.9 Ensure TF offset is measured accurately and entered correctly into the MWD software. 18.10 Confirm that the bit is dressed with a TFA of 0.46 sqin. Have DD run hydraulics models to ensure optimum TFA. We want to pump at 270 gpm. Page 34 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 18.11 Hydraulics Summary: 6-3/4" Hole Section Hydraulics Summary Depth- Hole Pump Rate Standpipe Est Openhole MW ECD TFA BHA MD (ft) Size (in) (gpm) Pressure (psi) AV(fpm) (ppg) (ppg) (in2) 7,000 6-3/4" 250 1400 242 10 10.3 0.46 MM + MWD+20 HWDP 8,000 6-3/4" 250 1600 242 10 10.3 ' 0.46 MM + MWD+20 HWDP 9,000 6-3/4" 250 1800 242 10 10.3 0.46 MM + MWD+20 HWDP 18.12 Motor AKO should be set at 1.18 deg to allow maximum rotation. The 6-3/4" hole is a straight tangent section and only minimal sliding will be necessary. 18.13 Primary bit will be the Smith 6-3/4" MDi613 PDC bit. Spec sheet on next page. Page 35 Revision 0 Jan, 2014 KBU 32-08 1111 Drilling & Completion Procedure Hilcorp Energy Company flinopt'nnSMITH BITS i tVI ! 1 A Schlumberger Company 9 P Y 3/4 in MD1613 3 PDC (171.45 mm) ID:6419220204 FEATURES ER:25039 IADC:M233 '° • Bit design and performance have been certified through the validation process prescnbed by IDEAS simulation technology. • CFD optimized nozzle placement for improved aw hydraulics *4 • • . Smith Bits Directional bits consistently deliver superior performance in directional applications with both push-the-bit and point-the-bit rotary steerable systems. Spedfications Total Cutters 29 Cutter Size 13mm(112 in) Face Cutters (13) 13mm Gauge Cutters (6) 13mm Cone Cutters 10 13mm Blade Count 6 Nozzles 3 Standard Serbs 60N.3 Standard Serbs 40N Bit Connection 3 112 Rem Junk Slot Area(sq in) 7.2117 Gauge Length 2" Protection Options Available Length Make-Up:8 3//16 In Overall:11 718 M Fishing Neck Diameter:4 518 M Length:2 11/16 in Operating Parameters Rotary Speed Rotary Steerable BHA Weight-on-Bit 2.500 To 19,000(Ibf) 1.136 To 8.636(daN) 1 To 9(Tonnes) Flow Rate(GPM) 200 To 500 Hydraulic Horsepower(HSI) 1 To 6 Operating parameters are typical ranges.Please contact your Smith Bits representative for recommendations for your individual well. Page 36 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 18.14 TIH to TOC. Shallow test MWD on trip in. Note depth TOC tagged at on AM report. 5?„ 18.15 Conduct casing test to 3500 psi / 30 min. 7 18.16 Drill out shoe track and additional 20' new formation. CBU and prep for FIT. 18.17 Conduct LOT per below guidelines. It may be necessary to have a cmt unit on location so that the FIT can be done appropriately. • Pump at 0.25 bpm, pump down DP and annulus at same time. • Record vol +pressure every 0.25 bbl pumped. • "Leak Off' occurs when pressure vs volume relationship becomes non-linear. • When this occurs, continue pumping for(3) more data points, then shut down pump. • Allow pressure to stabilize for 10 seconds, then begin recording shut in data. • Record pressures every minute for the first 10 minutes, then every 10 minutes for the next hour. • This data will be used to design the frac for this well. 18.18 Drill 6-3/4" hole to 9,350' MD using above motor/LWD assembly. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Utilize Inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team, try to avoid sliding through coal seams. Work through coal seams once drilled. • Keep swab and surge pressures low when tripping. • See attached mud program for hole cleaning and LCM strategies. • Ensure solids control equipment functioning properly and utilized to keep LGS to a minimum without excessive dilution. • maintain MW as necessary to hole stability. • Ensure mud engineer set up to perform HTHP fluid loss. • Maintain HTHP fluid loss <9. • Take MWD surveys every other stand drilled. Page 37 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 18.19 6-3/4"hole section mud program summary: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system (1)ppg above highest anticipated MW. MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. System Type: 10— 10.5 ppg 6% KCl/Kla-Shield fresh water based drilling fluid. Properties: Depths Density Plastic Viscosity Yield Point HTHP FL CI LGS(%) (mg/I) 6400-9350 10- 10.5/ 10- 16 15-23 <9 20,000— < 6 ✓ 32,000 System Formulation: M-1 Swaco "Kla-Shield" Drilling Fluid Product Concentration Water 0.905 bbl Flowzan 1 ppb (Viscosity) PolyPac Supreme UL 1 ppb (API Fluid loss) M-I Wate As needed for density(Weighting Agent) Potassium Chloride (KCL) 21.8 ppb(Inhibition) Busan 1060 0.4 ppb(Biocide) EMI-2009 6 ppb(Shale/Clay Inhibition) DF-9065 0.05 ppb(Anti-foaming agent) Asphasol Supreme 4 ppb (Shale/Coal Stabilizer) Sack Black 3 ppb (Gilsonite Shale/Coal Stabilizer) Caustic Soda 0.2 ppb(pH controller) 18.20 Hilcorp Geologists will follow LWD log closely to determine exact TD. • 18.21 At TD; pump sweeps, CBU, and pull a wiper trip back to the 7-5/8" shoe. 18.22 TOH with drilling assy. 18.23 R/U and attempt to run RFT log. 18.24 Make a wiper trip with drilling assy after RFTs, LDDP on trip out of hole. Page 38 Revision 0 Jan,2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 19.0 Run 5" Production Long String 19.1 R/U Weatherford 5"casing running equipment. • Ensure 5"DWC/C HT x CDS 40 crossover on rig floor and M/U to FOSV. • R/U fill up line to fill casing while running. • Ensure to R/U Tesco or Weatherford CRT so that string can be rotated if necessary while running. • Ensure all casing has been drifted on the deck prior to running. • Be sure to count the total # of joints on the deck before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor&model info. 19.2 P/U shoe joint, visually verify no debris inside joint. 19.3 Continue M/U&thread locking shoe track assy consisting of: • (1) Shoe joint w/shoe bucked on&threadlocked(coupling also thread locked). • (1)Joint with float collar bucked on pin end&threadlocked (coupling also thread locked). • (1)Joint with landing collar installed INSIDE pin end. • Solid body centralizers will be pre-installed on shoe joint&FC joint. • Install a solid body centralizer on landing collar joint. Leave centralizers free floating so that they can slide up and down the joint. • Ensure proper operation of float shoe. 19.4 Continue running 5"prod casing. • Fill casing while running using fill up line on rig floor. • Use"API Modified"thread compound. Dope pin end only w/paint brush. • Install solid body centralizers on every joint to 6,400' MD. Leave the centralizers free floating. • Ensure to install swell packer joint so that it is 500' from the 7-5/8" shoe when landed out. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 5" DWC/C HT M/U torques Casing OD Minimum Maximum Yield Torque 10,700 ft-lbs 12,100 ft-lbs 16,000 ft-lbs Page 39 Revision 0 Jan,2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company Technical Specifications Connection Type: Size(O.D.): Weight(Wall): Grade: DWCJC-HT Casing 5 in 18.00 Ibtft(0.362 in) L-80 .F.standari Material wiry L-80 Grade 80.000 Minimum Yield Strength(psi) 111111111111111111111111W USA 95.000 Minimum Ultimate Strength(psi) VAV-USA Pipe Dimensions 4:42.: `W.S n trousx1 Ay.S 150 041 5.000 Nominal Pipe BodyO.D.(in) ane 713. 9.3200 4.276 Nominal Pipe Body I.D.(in) Fax 713323: 0.362 Nominal WallThickness(in) £-maA:VAAtuSJt '''tlivana 18.00 Nominal Weight(Ibsllft) 17.95 Plain End Weight(lbslft) 5.275 Nominal Pipe BodyArea(sq in) Pipe Body Performance Properties 422.000 Minimum Pipe BodyYield Strength(lbs) 10.490 Minimum Collapse Pressure(psi) 10.140 Minimum lnternalYield Pressure(psi) 9.300 Hydrostatic Test Pressure(psi) Connection Dimensions 5.563 Connection O.D.(in) 4.276 Connection I.D.(in) 4.151 Connection Drift Diameter(in) 4.06 Make-up Loss(in) 5.275 Critical Area(5_gin) 100.0 Joint Efficiency(%) Connection Performance Properties 422.000 Joint Strength)bs) 16.750 Reference String Length(ft) 1.4 Design Factor 457.000 API Jo int Strength(lbs) 422.000 Compression Rating(lbs) 10.490 API Collapse Pressure Rating(psi) 9.910 API Internal Pressure Resistance(psi) 73.3 Maximum Uniaxial Bend Rating[degreesi 100 ft] Appptcim.ated.Field End Torque Values 10.700 Minimum Final Torque(ft-lbs) o- 12.100 Maximum Final Torque(ft-lbs) 16.000 Connection Yield Torque(ft-lbs) For detailed info rmaion on performance properties,refer to DWC Connection Data Notes on fol twin g page(s). Connection speaficabonswilhinihe oontrol col of VA1%-USA were correct as ofthedale printf.Speofcaions aresubjecttochargewittout notice.Cesar correct on s pecificaaons are dependent on the mechanical al properties of the pipe.Mechanical properties emit proprietary pipe grades o.ere obuired frau mill putligions and are subject to charge.Poperties of mill proprietary grades sio.d be confirmed wth 2 he m ill.Use's are advised to obtain current correction s peoficatiors and verify pipe mechanical properties for each application. Page 40 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 19.5 M/U casing hanger joint to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe approx 10—20' above TD. Strap the landing joint while it is on the deck and mark the joint at (1) ft intervals to use as a reference when landing the hanger. 19.6 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 19.7 R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat (slightly) to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 19.8 Displace 5" casing and entire annulus to packer fluid per below recipe. This will be the fluid left j� in the 5"x 7-5/8"annulus above the cmt. Ensure the density of the packer fluid is equal to the �( final MW needed to balance the wellbore (10— 10.5 ppg). • Water: 0.94 bbls • KCL: 21.8 ppb /r;lig • NaC123 ppb • Busan 1060: 0.4 ppb • Congor 303A: 5.0 ppb / • Soda Ash: (Add to a PH of 10.0— 11.0) • Sodium Metabisulfite: 0.5 ppb 19.9 After circulating, lower string and land hanger in wellhead again. Page 41 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 20.0 Cement 5" Production Long String 20.1 Hold a pre job safety meeting over the upcoming cmt operations. Ensure the below is covered during the meeting: • How to handle cmt returns at surface, regardless of how unlikely it is that this should occur. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cmt operation. • Document efficiency of all possible displacement pumps prior to cement job. 20.2 Attempt to reciprocate the long string during cmt operations. 20.3 Wellbore should be displaced to 1.3%by Volume Conqor 303A corrosion inhibitor. 20.4 Pump 5 bbls 12 ppg MUDPUSH II spacer. 20.5 Test surface cmt lines to 4500 psi. 20.6 Pump remaining 15 bbls 12 ppg MUDPUSH II spacer. 20.7 Mix and pump 15.3 ppg class "G" cmt per below recipe. Ensure cmt is pumped at designed weight. Job is designed to pump 100% OH excess. Section: Calculation: Vol (BBLS) Vol(ft3) 7-5/8"x 5" long string 500' x 0.022 = 11 61.8 Overlap: 6-3/4" OH x 5" Liner: (9,350—6,400') x 0.020 x 2 = 118 662 Shoe Track: 90' x 0.019 = 1.7 9.5 Total Volume: 130.7 bbls 734 ft3 Page 42 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company Slurry Information: System Conventional Density 15.3 lb/gal Yield 1.35 ft3/sk Mixed Water 5.912 gal/sk Mixed Fluid 5.962 gal/sk Expected Thickening 100 Bc at 05:57 hr:mn Expected ISO/API Fluid Loss 15 mL in 30.0 min at 175degF/ 1000 psi Code Description Concentration G Cement 94 lb/sk D198 Retarder 0.4% BWOC Additives D046 Anti Foam 0.2% BWOC D202 Dispersant 1.5% BWOC D400 Gas Control Agent 0.8% BWOC D154 Extender 8.0 % BWOC D174 Expanding Agent 1.5% BWOC 20.8 Drop top plug and displace with filtered 6% KC1. 9250 ft x .01776 = 164 bbls. 20.9 Do not overdisplace by more than 1/2 shoe track. Shoe track volume is 1.7 bbls. 20.10 Bleed pressure to zero to check float equipment. 20.11 Pressure up again to 3500 psi and hold for 30 min to test production bore. Page 43 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company Ensure to report the following on wellez: • Pre flush type,volume(bbls)&weight(ppg) • Cement slurry type, lead or tail,volume&weight • Pump rate while mixing,bpm,note any shutdown during mixing operations with a duration • Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement,actual displacement volume,whether plug bumped&bump pressure, do floats hold • Percent mud returns during job,if intermittent note timing during pumping of job.Final circulating pressure • Note if pre flush or cement returns at surface&volume • Note time cement in place • Note calculated top of cement • Add any comments which would describe the success or problems during the cement job Send final "As-Run" casing tally& casing and cement report to lkeller@hilcorp.coin. This will be included with the EOW documentation that goes to the AOGCC. 21.0 RDMO 22.1 Install back pressure valve in hanger neck. N/D BOP. 22.2 N/U tree. 22.3 RDMO Saxon Rig#147. 22.4 After rig has departed,pull BPV &run CBL to determine TOC behind 5" production casing. L_--� e-3 "x �� -/a 2S460®. .. 22.0 Perf and Frac 23.1 separate Sundry will be submi d to the AOGCC that will cover the perf& frac operations for KBU 32-08. Page 44 Revision 0 Jan,2014 KBU 32-08 titDrilling & Completion Procedure Hilcorp Energy Company 23.0 BOP Schematic IU+ur iI,u: i.i I 4 ° T3•Energy Saxon Rig 147 11"5M T-3 Energy BOP I•I til lI l I.l lil Ar T3-Energy .27g "- S 4 1•"..5nnn i. 3 �..,/Un Manual Manua! Marwal Valve Valve Valve NCR Kbl dt. ... ► r li,/il , Isl 4 -L.,-.: • .6 `I� `. Line il -4S, d „� / Iti III tii III Z. �i� . 73-Energy Model 6011i - 7l „ S, • Grade Level Illi II,III III III Spacer spool v 115MX115M Iii 1!I 111 iii Ita •.1•�1 h...II�.- Seada7rd•A10S system �I.3hr X t' ",�1 �w��II _?4I• '� 1. .;pe. . 1111111111 —I+ 'sella I. ..-�j.l 11 I'4�/�_.- •II-t 111.11.11111 II" 1.. 1.11a1. Page 45 Revision 0 Jan, 2014 KBU 32-08 HDrilling & Completion Procedure Hilcorp Energy Company 24.0 Wellhead Schematic I KBU 32-08 0 1„1 o . .Tr:. IIIIIIIIIIIIIIIIIII 3-1/16"10M I/411, VONA iO.Or ..,". / l 3-1/16'10 3.1/16"IOM / 42 Illiammill 3-1/16"16010104 11411-14 • ,•, Adapte+,SM-E-2CLN _ 11"SM x 3-112.5'101.0 VOWNANCVI.914-(-30.—.dim 1 arumtt 5Ntt x 3-1/2 Ng $ at11 1�1 x3-Inaawaox 7C► IRA prillit‘til rr �1 0 Mil: Ail Waisil CA". IIM110 �- ' 11e,X 7 rr. IF sae2-1 SW II: gm Mil lis11.x11 . 4 IPS Win► I.l OM* yW-22 0111.1111. �w� 2-1/149Y j 4 x 10-3J4 3/4 311 9 -LI �1 ._ I( s!1 ]I. * Is wipes I 2-04 31.1 10-3/4 C#3,10 7-0/11 CA 0O ,r 3-1/2 VOW••••••••••••• 1 �4'8 RD `___..3.000 psi Wertfe40 a 10,0001fsi tree assy 16x103/4x 7-5/t x 3-1/2 Ir IK rCOlf100flUt 00QNQR%; 2 Miki[t! eVti=� ,'tl.firt I . P-14873 1 Page 46 Revision 0 Jan,2014 KBU 32-08 Drilling& Completion Procedure Hilcorp Energy Company 25.0 Days Vs Depth Days Vs Depth 0 \\\\\\ KBU 32-08 —SRU 13-27 2000 4000 Z. t a v 6000 8000 10000 12000 0 5 10 15 20 25 30 35 40 Days Page 47 Revision 0 Jan, 2014 HF KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 26.0 Geo-Prog 1/7/2014 MSS Gkol o ,;(,...! [MEM= =1111111111111K8U 3248 FiLD: Kama Get Field SURFACE a'275200.* BOTTOM HOLE:zo278750.5 AFE: .•-- 4.1 r2359007.4 STATE: Alaska PROPOSED TD:i 10,007 MD IIIIIIIIIIIf API: TBD ..- 'EST.GL: 167 I 1, Drill a 10,000'MD Beluga/Upper Tyonek development well off the 41-18 pad in the Kenai Gas field. The KBU 32.08 will target the Mid-Lower Beluga and Upper Tyonek reserves on the eastern flank of the field. This well will offset several successful wells including KBU 41-18X,KBU 24-7X and KBU 11-17X, The wet locabon Is planned 25 ft down do to LKG at Kau 11.17X with close offset wets KBU 144 and,/ Geo.. Summ ./../ustficaPort KBU 1348,both of%tech ••e. • •a thro •h the entire secton ANTICIPATED FORMATION TOPS&GEOHAZAROS 1 1 1 I I 1_,..... EXPECTED FWD 12 Macau /3521ED _ fUOSEA DEPTH pL Pressurt &offing secondary gas 3,189 3,638 13550) 250 Staffing 5 2 seem-defy gas 4,4152t--- 1500 4236 4 (4,148) Upper&Alga secondary gas 5,392 4,723 -r-- 44.625) ------- • 900 /Amu,Betuga Primary Target gas 6,3265.383 (5285) 1000 * ....., Loywr Beiuga Primary Target gas 7,292 . 6.066I (5.968) 1000 Upper Twine* Primary Target gas 8,889 7,195 , -7.097 2500 Total Depth 9,800 7,853 ' 4,755 normal =Reservoir Objectives Possible Goo Hazards WM DATA COLLECTION REQUIREMENTS mod Loggng, ,.Surface C.69.To TV.20 fool samples.Swore sets i MD Data: OR-Resisavey only.Suet Cog toll) ,E4.1ne Log Data: Surf.Csg.To 10000appmx OR.ONL-I.DT.Res.Dipole Sonlc.nudear magnetic resonance.fm pressure&sampling log • t COt.ti, . " Pf,F mullion-tone frac * ....—. Char44.4. , .,.ess&Antiopated Ra 95%/'7 BOEPO ARTIFICIAL LITT EQUIPMENT 00 TUBING SIZE i 1 OTHER COMMENTS ' SOC,0e,11'r targets nctide the Upper Bela.Sv.eIng 5 2 and Stering Undefined(above 3.1891 .1- 1 ' 4 than to 1 SARAH RITTENHOUSE 1 907-7774306 301142543011 2 DAVID BUTHMAN(Alternate) l 907-7174373 t 5014544543 i — ,CONTINUOUS FAX — 907-777.8510 1 - ---+--- I NO INFORMATION CONCERNING THIS WELL IS TO BE RELEASED TO ANYONE EXCEPT THE EMPLOYEES OF HLCORP OR THEW PARTNERS. 1 , I I I I. I Page 48 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 27.0 Anticipated Drilling Hazards 13-1/2" Hole Section: Lost Circulation: / Ensure adequate amounts of LCM are available. Safe-carb 10, 20, 40, 250, & 750. Ensure G-seal, Pecan nut plug, and Mix II are also available for more severe lost returns incidents. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of Safe-carb 10 &20 to the active system at 1 —2 ppb. Hole Cleaning: Maintain rheology w/gel and gel extender. Sweep hole with gel or flowzan sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Maintain YP btwn 25 —45 to optimize hole cleaning and control ECD. Wellbore stability: Lithology through this zone is a composite of pebble conglomerate and sand in the upper intervals with intermittent clay matrix. Carbonaceous material and coal may be noted. Gravel sizes that are larger than normal can cause hole-cleaning problems. If encountered,be prepared to increase the viscosity. Excessive quantities of gravel and sand may indicate wellbore instability. Increase properties up to a YP of—50 -—60 lbs/100ft2 to combat this issue. Maintain low flow rates for the intial 200' of drilling to reduce the likelihood of washing out the conductor shoe. To help insure good cement to surface after running the casing, condition the mud to a YP of 25 —30 prior to cement operations. Do not lower the YP beyond 25 to avoid trouble with sands that may be found on this well. Have Desco DF, SAPP, and water on hand to ensure the desired rheologies can be achieved. H2S: H2S is not present in this hole section. No abnormal pressures or temperatures are present in this hole section. Page 49 Revision 0 Jan,2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 9-7/8" Hole Section: Lost Circulation: Ensure adequate amounts of LCM are available. Safe-carb 10, 20, 40, 250, & 750. Ensure G-seal, Pecan nut plug, and Mix II are also available for more severe lost returns incidents. Monitor fluid volumes to detect any early signs of lost circulation. Background concentrations of LCM (sized calcium carbonate) should be btwn 5— 10 ppb while drilling this interval. There is a high probability of lost returns through the many stacked, depleted sands in this hole section. Hole Cleaning: Maintain rheology w/flowzan. Sweep hole w/20 bbls hi-vis pills as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain YP btwn 20 - 30 to optimize hole cleaning and control ECD. Wellbore stability: Maintain 1ppb total of PolyPac Supreme UL to maintain a thin/strong wall cake and keep HTHP filtrate below 9 ml/30 min. Maintain MW as necessary using additions of Barite. Maintain 6 ppb EMI-2009 for shale/clay inhibition. Maintain 4 ppb Asphasol Supreme & 3 ppb Sack Black for Shale/Coal stabilizer. Maintain 6%KC1 in system for shale inhibition. Coal Drilling: The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The need for good planning and drilling practices is also emphasized as a key component for success. • Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. • Use asphalt-type additives to further stabilize coal seams (Asphasol Supreme, Sack Black). • Increase fluid density as required to control a"running coal". • Emphasize good hole cleaning through hydraulics, ROP and system rheology. In the event that sloughing coal is encountered, consider spotting a 30 ppb Asphasol Supreme pill across the coal seam. The pill can be safely "squeezed" into the coal by closing the bag and applying pressure not to exceed the total annular pressure loss. H2S: H2S is not present in this hole section. No abnormal temperatures are present in this hole section. Page 50 Revision 0 Jan,2014 KBU 32-08 11 Drilling & Completion Procedure HilcEnergy orp y 6-3/4" Hole Section: Lost Circulation: Ensure adequate amounts of LCM are available. Safe-carb 10, 20, 40, 250, & 750. Ensure G-seal, Pecan nut plug, and Mix II are also available for more severe lost returns incidents. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of Safe-carb 10 &20 to the active system at 1 —2 ppb. Hole Cleaning: Maintain rheology w/flowzan. Sweep hole w/20 bbls hi-vis pills as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain YP btwn 20 - 30 to optimize hole cleaning and control ECD. Wellbore stability: Maintain 1ppb total of PolyPac Supreme UL to maintain a thin/strong wall cake and keep HTHP filtrate below 9 m1/30 min. Maintain MW as necessary using additions of Barite. Maintain 6 ppb EMI-2009 for shale/clay inhibition. Maintain 4 ppb Asphasol Supreme& 3 ppb Sack Black for Shale/Coal stabilizer. Maintain 6% KC1 in system for shale inhibition. Coal Drilling: The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The need for good planning and drilling practices is also emphasized as a key component for success. • Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. • Use asphalt-type additives to further stabilize coal seams (Asphasol Supreme, Sack Black). • Increase fluid density as required to control a"running coal". • Emphasize good hole cleaning through hydraulics, ROP and system rheology. In the event that sloughing coal is encountered, consider spotting a 30 ppb Asphasol Supreme pill across the coal seam. The pill can be safely "squeezed" into the coal by closing the bag and applying pressure not to exceed the total annular pressure loss. H2S: H2S is not present in this hole section. / No abnormal temperatures are present in this hole section. / Page 51 Revision 0 Jan, 2014 KBU 32-08 HDrilling & Completion Procedure Hilcorp Energy Company 28.0 Saxon Rig 147 Layout 123'-7" 36'-0- 55'-6" 30'-0" — 2'-1- t=i IPQr-tit TANK(TOTAL VOI 496 691 SI 1 —_z. _ -- I r 1 _ • `_ III 111111111.111111 { III IIIII.IIIIIIII(,' !i 1 _I ' I �� i 1I +�+_ IIIIIIIIIIIIIIIiit II VUOyy►w r— I 1• "I �. ECM I1111111f 1; All 1 r� o i itititillll! ) ar,51 l'il INN '1111 1111 �!rnFsr_.. I __.1 w — _. •Im c 11 I - _ •- .�.:_ IIIII 1111111111.111111. ituasiss. H11111111 NMI I 11 OM PUMP it I=I li OM �7 o S .- itt�1 nnunm• — -I- _ :7--.-: ■Skil. , __Emir,1111111111111.111 111111111111111111111111111111111111111111111111111111111111111111111111111111111IIIIIII111I1111111111IlII IIIII'II►IIIIIIIIIIiiuii111111 I I +I.111111111111111111111111111111111111111111111111 ! _� ___ 1"i•IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIII1 1111111111111111111111111111111111111111111111111111111111111111111111111111111 I1111111(1mmlun'!II IIIIIIIIIIi��1 11111111111111111111111111111111Ei �- - __ ;,1:�'iim1w11y111 11111111111111111111111111111111111111111111111111II1nu1111ennunul' — III►�11111111111111I' D - ='�� Oe"'"""`° _Ili I=...---' Iliouniumonoillulliii VICKT°IV•I1iQr _, i. _t-r11 �� :.,j' ! _ 111111IIIIIIllllllilllIIl1111111181IllIIIIIIIIIIIIIIummnnlnonnn,... Ili — . III//illllllflltlllianl;'"11C' lime 1111111111111111111iiiiiiiiimii11111111111111111111111111U11111111111111111{'i1 IIIIIIt1�'I!II!IIII11 IIIII'1I11I1IIIllIIIIIIIIIIIIill,1T. mini o IIIIIIIIIIIIIIIIII1l1i1Illl(IIIIIIIIIIIIIIIIIIIIIIIIIIIilIHI111111IiIIllllil IIIIIIIIIUII►# Il i i IIIIIIDp �dvIIIIlINI11111IIIIIIIIIIII111111111 1IIIIII1111■1. D W 11511 r ( l _i mumtea; mI.IIionoi11m' I1 Ii • I°�ipm i . � 11 ! ��IIIIIIIII:IIIIIion "'r ,= = `Ilil.11illlllllillll• r' ;.8 s' ��'._ i 1� ■- ., mol mium, ...tr-... .-. -- --2'-0" 53'-0" 45'-0" 85'-0" Ivc 85'-5' 170'-4" Page 52 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 29.0 FIT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer(ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 53 Revision 0 Jan, 2014 KBU 32-08 HDrilling & Completion Procedure Hilcorp Energy Company 30.0 Choke Manifold Schematic 1 5 I e f',, t.,,,4 Ili - : •P** v P P .L % . , LI . I 1 Jogipur.,!111 Lk.:;!::.'.4,s .4 tiit. ! e yr r� �7 6 ma `! g t 3 !►�A �I.iA•� Z t� F� �i� Ai, t3 i' y i i i 1i14'1i 112 s k I1 \� .� ►.. 4 - �_ -ii� i,\, -j atm b ! .i;., .i4p P r _ 111111.1111111111 I rV P o e`, ' r r „ti; L��f o A a e. IAA ��►of w i :.. , ,r $ c .11'c 0 I F, i vow -711111117: i• 4 ..•l ;�%V IN_V' ;1-.,' :w 113 )1i°10 r MN= 14- . Ili i ,. P 41 ill ,� t L.- 4D PI -- - I I, ; , Page 54 Revision 0 Jan,2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 31.0 Casing Design Information Calculation & Casing Design Factors Kenai Beluga Unit DATE: 1-7-2014 WELL: KBU 32-08 FIELD: Kenai Gas Field DESIGN BY:Luke Keller Design Criteria: Hole Size 9.7/8" Mud Density: 9.5 ppg Hole Size 6-3/4" Mud Density: 10.5 ppg Hole Size Mud Density: Drilling Mode MASP(sec 1): 1254 psi(see attached MASP determination&calculation) MASP: 2199 psi(see attached MASP determination&calculation) Production Mode MASP(Sec 2,3,4): 3299 psi(see attached MASP determination&calculation) Collapse Calculation: Section Calculation 1,2,3 Max MW gradient external stress and the casing evacuated for the internal stress Casing Section Calculation/Specification 1 2 3 Casing OD 10-3/4' 7-518" 5' Top(MD) 0 0 0 Top(TVD) 0 0 0 Bottom(MD) 1,550 6,400 9,350 Bottom(TVD) 1,500 5,455 7.853 Length 1,550 6.400 9.350 Weight(ppf) 45.5 29.7 18 Grade L-80 L-80 L-80 Connection BTC BTC DWC/C HT Weight wto Bouyancy Factor(lbs) 70,525 190.080 168,300 Tension at Top of Section(lbs) 70.525 358,380 168,300 Min strength Tension(1000 lbs) 1040 683 457 Worst Case Safety Factor(Tension) 14.75 1.91 2.72 Collapse Pressure at bottom(Psi) 741 2,695 4,084 Collapse Resistance w/o tension(Psi) 2.480 4,790 10,500 Worst Case Safety Factor(Collapse) 3.35 1.78 2,57 MASP(psi) 1,254 3,299 3,299 Minimum Yield(psi) 5,210 ) 6.890 x 9,910 Worst case safety factor(Burst) 4.15 2.09 3.00 Page 55 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 32.0 9-7/8" Hole Section MASP Maximum Anticipated Surface Pressure Calculation 9-7/8" Hole Section Htcowp KBU 32-08 Ninilchik Unit MD TVD Planned Top: 1550 1500 Planned T0: 6400 5455 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad Sterling 3,638 250 Gas 1.3 0.069 Sterling 5.2 4,236 1500 Gas 6.8 0.354 Upper Beluga 4,72.3 900 Gas 3.7 0.191 Offset Well Mud Densities Well MW range 1 Top(TVD) Bottom(TVD) Date KBU 11.17X 9 -9.2 1,587 5,464 2009 KBU 14-08 9-9.2 1,510 5,432 2008 KBU 41-18X 9-9.2 1,500 5,391 2008 KBU 24-7X 9-9.7 1,502 5,326 2006 Assumptions: 1. Fracture gradient at 1,550'MD/ 1,500'TVO is estimated at 0.936 psi/ft based on field test data. 2. Maximum planned mud density for the 9-7/8"hole section is 9.5 ppg. 3. Calculations assume"Unknown" reservoir contains 100%gas(worst case). 4. Calculations assume worst case event is 2/3 evacuation of wellbore to gas. Remaining 1/3 volume in wellbore remains drilling fluid density. Fracture Pressure at 10-3/4" shoe considering a full column of gas from shoe to surface: 1500(ft)x 0.936(psi/ft)- 1404 psi 1404(psi)-(0.1(psi/ft)`1500(ft)j= 1254 psi MASP from pore pressure(unknown gas sand at TD,at 9.2 ppg(0.4784 psi/ft) 0 5,455(ft)x 0.4784(psi/ft)- 2610 psi �• "�6 2610(psi)- ((2/3)'0.1(psi/ft)`5,455(ft)J-((1/3)•0.494(psi/ft)`5,455(ft)J= 1348 psi • Summary: , ,r /fro' 1. MASP while drilling 9.7/8" intermediate hole is governed by fracture gradient at the 10-3/4"casing shoe Page 56 Revision 0 Jan, 2014 KBU 32-08 intDrilling & Completion Procedure Hilcorp Energy Company 33.0 6-3/4" Hole Section MASP Maximum Anticipated Surface Pressure Calculation 6-3/4"Hole Section t iitcor KBU 32-08 Cook Inlet,Alaska MD TVD Planned Top: 6,400' 5,455' Planned TD: 9,350` 7,853' Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad Middle Beluga 5,383 1000 Gas 3.6 0.186 Lower Beluga 6,066 1000 Gas 3.2 0.165 Upper Tyonek 7,195 2500 Gas 6.7 0.347 Offset Well Mud Densities Well Max Drig MW Top(TVD) Bottom(TVD) Date KBU 11-17X 10.7 5,464 7,919 2009 KBU 14-08 10.3 5,432 7,746 2008 KBU 41-18X 11.6 5,391 8,651 2008 KBU 24-7X 9.7 5,326 7,550 2006 Assumptions: 1. Fracture gradient at 6,400'MD/5,455'TVD is estimated at 0.936 psi/ft based on field test data. 2. Maximum planned mud density for the 9-7/8"hole section is 10.5 ppg. 3. Calculations assume"Upper Tyonek"reservoir contains 100%gas(worst case). 4. Calculations assume worst case event is 2/3 evacuation of wellbore to gas. Remaining 1/3 volume in wellbore remains drilling fluid density. Fracture Pressure at 7-5/8"shoe considering a full column of gas from shoe to surface: 5,455(ft)x 0.936(psi/ft)= 5106 psi 5,106(psi)-[0.1(psi/ft)'5,455(ft)]= 4561 psi Drilling Mode MASP MASP from pore pressure(2/3 wellbore evacuated to gas from Upper Tyonek) 7,853(ft)x 0.52(psi/ft)= 4084 psi iltA'f"'42'441 4,084(psi)-((0.1(psi/ft)'7,853(ft)'2/3)+(0.52(psi/ft)'7,853(ft)'1/3))= 2199 psi 14 / , Production Mode MASP MASP from pore pressure(entire wellbore evacuated to gas from Upper Tyonek): 7,853(ft)x 0.52(psi/ft)= 4084 psi vu I" 4,084(psi)- [0.1(psi/ft)'7,853(ft)]= 3299 psi -' , �! S�° rsV r -fa � L .t.19 Page 57 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 34.0 Directional Program (P3) H Hitco Schlumberger 11KBU 32-08 (P3) Proposal Geodetic Report (Def Plan) Report Date: December 23,2013•01:58 PM Survey/DLS Computation: Minimum Curvature I • Client: Haborp Energy Company Vertical Section Azimuth: 42.016°(True North) • Field: Kenai Unit Vertical Section Origin: 0.000 ft.0.000 ft Structure/Slot: KGU-Pad 41-181 KBU 32-08 new TVD Reference Datum: KB Well: Plan KBU 32-08(2) TVD Reference Elevation: 85.000 ft above MSL ' Borehole: Plan KBU 32-08 Ground Elevation: 87.000 ft above MSL ' APIs: 50133xxxxx00 Magnetic Declination: 16.931 " Survey Namo: KBU 32-08(P3) Total Gravity Field Strength: 1001.1873mgn(9.80665 Survey Date: December 23,2013 Gravity Model: GARM Tort/AHD/DDI I ERO 35.642":4817.624 ft/5 311!0.613 Total Magnetic Field 55374.006 nT Coordinate Reference NAD27 Alaska State Plane,Zone 04,US • Magnetic Dip Angle: 73.433' Location Lat/Long: N 60'26'38 00940`.W 151"14'36.04285" Declination Date: April 01,2014 Location Grid N/E Y/X: N 2356289.790lb S,E 275459.019 ftUS Magnetic Declination Model: BGGM 2013 CRS Grid Convergence -1.0816' North Reference: True North ' Grid Scale Factor: 0 99995738 Total Corr Mag North->True 0 0000" Version/Patch: 2.7.998.0 Total Corr Mag->Grid North: 16.9310' Local Coord Referenced To: Well Head Comments MO Incl Azim True TVDSS TVD VSEC NS EW TF DLS Easting Northing (ft) (1 (°) (ft) (ft) (ft) (ft) (ft) (') (1100ft) (MS) (ftUS) RTE 0.00 0.00 42.02 -85.00 0.00 0.00 0.00 0.00 42.02M NIA 275459.02 2356289.79 100.00 0.00 42.02 15.00 100.00 0.00 0.00 0.00 42.02M 0.00 275459.02 2356289.79 200.00 0.00 42 02 115 00 200.00 0 00 0.00 0.00 42.02M 0.00 275459.02 2356289.79 KOP Cry 300.00 0.00 42.02 215.00 300.00 0.00 0.00 0.00 42.02M 0.00 275459.02 2356289.79 1.5/100 400.00 1.50 42.02 314 99 399.99 1.31 0.97 0.88 42.02M 1,50 275459.91 2356290.75 Cry 2.5/100 500.00 3.00 42.02 414.91 499.91 5.23 3.89 3.50 42.02M 1.50 275462.60 2356293.61 600.00 5.50 42.02 514.63 599.63 12.65 9.39 8.46 42.02M 2.50 275467.66 2356299.02 700.00 8.00 42 02 613 92 698.92 24 40 18.13 16.33 42.02M 2.50 275475.69 2356307.60 800.00 10.50 42.02 712.62 797.62 40.47 30.07 27.09 HS 2.50 275486.67 2356319.34 900.00 13.00 42.02 810.51 895.51 60.83 45.19 40.72 HS 2.50 275500.58 2356334.21 1000.00 15.50 42.02 907.43 992.43 85 45 63.48 57.20 HS 2.50 275517 40 2356352.18 1100.00 18.00 42.02 1003.18 1088.18 114.26 84.89 76.49 HS 2.50 275537.09 2356373.22 1200.00 20.50 42.02 1097.58 1182.58 147.23 109.38 98.55 HS 2.50 275559.62 2356397.28 1300.00 23.00 42.02 1190.45 1275.45 184 28 136.91 123.36 HS 2.50 275584.93 2356424.34 1400.00 25.50 42.02 1281.62 1366.62 225.35 167.42 150.85 HS 2.50 275612.99 2356454.32 1500.00 28.00 42,02 1370 91 1455.91 270.36 200.85 180.98 HS 2.50 27564374 2356487.18 End Cry 1538.78 28.97 42.02 1405.00 1490.00 288 85 214.59 193.36 HS 2.50 275656.38 2356500.69 13-3/8" 1550.21 28.97 42.02 1415.00 1500.00 294.39 218.71 197.06 HS 0.00 275660.17 2356504.73 KOP Cry 1578.78 28.97 42 02 1440 00 1525.00 308.23 228.99 206.32 HS 0.00 275669 62 2356514.83 1.5!100 1600.00 29.29 42.02 1458.53 1543.53 318.56 236.66 213.24 HS 1.50 275676.68 2356522.37 1700.00 30.79 42.02 1545.10 1630.10 368.61 273.85 246.75 HS 1.50 275710.88 2356558.92 Cry 2.51100 1778.78 31.97 42.02 1612.36 1697.36 409 63 304.32 274.20 0,041, 1,50 275738.91 2356588.87 1800.00 32.50 42.02 1630.30 1715.30 420.95 312.73 281.78 0.041_ 2.50 275746.64 2356597.13 1900.00 35.00 42.02 1713.44 1798.44 476.50 354.00 318.96 0.031 2.50 275784.59 2356637.69 End Cry 1925.67 35.64 42 02 1734 38 1819.38 491.34 365.03 328.90 HS 2.50 275794.73 2356648 53 2000.00 35.64 42.02 1794.79 1879.79 534.66 397.21 357.89 HS 0.00 275824.33 2356680.15 2100.00 35.64 42.02 1876.06 1961.06 592,93 440.50 396.89 HS 0.00 275864.14 2356722.70 2200.00 35.64 42 02 1957.33 2042.33 651.20 483.79 435.90 HS 0 00 275903.95 2356765.25 2300.00 35.64 42.02 2038.60 2123.60 709.47 527.09 474.90 HS 0.00 275943.76 2356807.79 2400.00 35.64 42.02 2119.86 2204.86 767.74 570.38 513.90 HS 0.00 275983.57 2356850.34 2500.00 35.64 42.02 2201.13 2286.13 826.01 613.67 552.91 HS 0.00 276023.38 2356892.89 2600.00 35.64 42.02 2282.40 2367.40 884.29 656.97 591.91 HS 0.00 276063.20 2356935.44 2700.00 35.64 42 02 2363 67 2448.67 942 56 700.26 630.91 HS 0 00 276103 01 2356977.98 2800.00 35.64 42 02 2444 94 2529.94 1000 83 743.55 669.92 HS 0 00 276142.82 2357020.53 2900.00 35.64 42.02 2526.20 2611.20 1059.10 786.85 708.92 HS 0.00 276182.63 2357063.08 3000.00 35.64 42.02 2607.47 2692.47 1117.37 830.14 747.92 HS 0.00 276222.44 2357105.63 Page 58 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company Comments MO Inel Azim True TVDSS TVD VSEC NS EW TF DIS Easting Northing on r) P) (ft) (ft) (ft) on (ft) (°) ('1100ft) (ftUS) (mUS) 3100.00 35.64 42.02 2688.74 2773.74 1175,64 873.43 786.92 HS 0.00 276262.25 2357148.17 3200.00 35.64 42.02 2770.01 2855.01 1233.91 916.73 825.93 HS 0.00 276302.07 2357190.72 3300.00 35.64 42 02 2851.27 2936.27 1292 18 960.02 864.93 HS 0 00 276341.88 2357233.27 3400.00 35.64 42,02 2932.54 3017.54 1350.46 1003.31 903.93 HS 0.00 276381.69 2357275.82 3500.00 35.64 42.02 3013.81 3098.81 1408.73 1046.61 942.94 HS 0.00 276421.50 2357318.36 3600.00 35.64 42 02 3095 08 3180.08 1467 00 1089.90 981.94 HS 0 00 276461.31 2357360.91 3700.00 35.64 42.02 3176.35 3261.35 1525.27 1133.19 1020.94 HS 0.00 276501.13 2357403.46 3800.00 35.65---42.02`3257.6t 3342.61 158 .54 1176.48 1059.95 HS 0.00 276540.94 2357446.01 3900.00 35.64 42.02 3338.88 3423.88 1641.81 1219,78 1098,95 HS 0.00 276580.75 2357488,55 4000.00 35.64 42.02 3420.15 3505,15 1700.08 1263.07 1137.95 HS 0.00 276620.56 2357531.10 4100.00 35.64 42.02 3501.42 3586.42 1758.36 1306.36 1176,96 HS 0.00 276660.37 2357573.65 Storting 4175.78 35.64 42.02 3563.00 3648.00 1802 51 1339.17 1206.51 HS 0.00 276690.54 2357605.89 4200.00 35.64 42.02 3582.68 3667.68 1816.63 1349.66 1215.96 HS 0.00 276700.18 2357616.20 4300.00 35.64 42.02 3663 95 3748.95 1874.90 1392.95 1254.96 HS 0.00 276740 00 2357658.74 4400.00 35.64 42.02 3745.22 3830.22 1933 17 1436.24 1293.97 HS 0 00 276779.81 2357701 29 4500.00 35.64 42.02 3826.49 3911.49 1991.44 1479.54 1332.97 HS 0.00 276819.62 2357743.84 4600.00 35.64 42 02 3907 76 3992.78 2049 71 1522,83 1371.97 HS 0.00 276859 43 2357786.38 4700.00 35.64 42.02 3989.02 4074.02 2107.98 1566.12 1410.98 HS 0 00 276899.24 2357828.93 4800.00 35.64 42.02 4070.29 4155.29 2166.26 1609.42 1449.98 HS 0.00 276939.05 2357871.48 4900.00 35.64 42 02 4151.56 4236.56 2224 53 1652.71 1488.98 HS 0 00 276978 87 2357914.03 Sto1,n,5 7 4911.62 35.64 42.02 4161.00 4246.00 2231.30 1657.74 1493.51 HS 0.00 276983.49 2357918.97 5000.00 35.64 42.02 4232.83 4317.83 2282.80 1696.00 1527.99 HS 0.00 277018.68 2357956.57 5100.00 35.64 42.02 4314.09 4399.09 2341.07 1739.30 1566.99 HS 0 00 277058 49 2357999.12 5200.00 35.64 42.02 4395.36 4480.36 2399,34 1782.59 1605,99 HS 000 277098.30 2358041,67 5300.00 35.64 42.02 4476.63 4561.63 2457.61 1825.88 1645.00 HS 0.00 277138.11 2358084.22 5400.00 35.64 42 02 4557.90 4642.90 2515 88 1869.18 1684.00 HS 0 00 277177 92 2358126.76 Upper Beluga 5498.57 35.64 42.02 4638.00 4723.00 2573.32 1911.85 1722.44 HS 0.00 277217.17 2358168.70 5500.00 35.64 42.02 4639.16 4724.16 2574.16 1912.47 1723.00 HS 0.00 277217.74 2358169.31 5600.00 35.64 42.02 4720 43 4805.43 2632.43 1955.76 1762.01 HS 0 00 277257.55 2358211 86 5700.00 35.64 42.02 4801.70 4886.70 2690.70 1999.06 1801.01 HS 0.00 277297.36 2358254.41 5800.00 35.64 42.02 4882.97 4967.97 2748.97 2042.35 1840.01 HS 0.00 277337.17 2358296.95 5900.00 35.64 42.02 4964 24 5049.24 2807.24 2085,64 1879.01 HS 0 00 277376.98 2358339,50 Page 59 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company Comments MD Inel Aztm True TVDSS TVD VSEC NS EW TF DLS Easting Northing YU t'1 t•1 (R) Eft) (R) (ft) (ft) (•) (•11001t) oils) (Rt1S) 600000 35.64 42 02 5045 50 5130.50 2865 51 2128.94 1918.02 HS 0 00 277416 79 2358382 05 6100,00 35.64 42.02 5126.77 5211.77 2923.78 2172.23 1957.02 HS 0.00 277456.61 2358424.60 6200.00 35.64 42.02 520804 5293,04 2982 06 2215.52 199602 HS 000 277496 42 2358467 14 9.518' 6208.57 35.64 42.02 521500 5300.00 2987.05 2219.23 1999.37 HS 000 277499.83 2358470.79 6300.00 35.64 42.02 5289.31 5374.31 3040.33 2258.82 2035.03 HS 0.00 277536.23 2358509.69 6Mddto Beluga 6310.70 35.64 42 02 5298.00 5383.00 3046 56 2263,45 2039.20 HS 000 277540.49 2358514.24 6400.00 35.64 42 02 5370 57 5455,57 3098.60 2302.11 2074.03 MS 0.00 277576 04 2358552 24 6500.00 35.64 42.02 5451.84 5536.84 3156.87 2345.40 2113.03 HS 0.00 277615.85 2358594.79 6600 00 35.64 42 02 5533 11 5618.11 3215.14 2388,70 2152.04 HS 0.00 277655.66 2358637.33 6700.00 35.64 42.02 5614.38 5699.38 3273.41 2431.99 2191.04 HS 000 277695.48 2358679.88 6800.00 35.64 42.02 5695 65 5780.65 3331.68 2475.28 2230.04 HS 000 277735.29 2358722.43 6900 00 35.64 42 02 5776 91 5861.91 3389 95 2518.57 2269.05 HS 0 00 277775.10 2358764 97 7000.00 35.64 42.02 5858.18 5943.18 3448.23 2561.87 2308.05 HS 0.00 277814.91 2358807.52 7100.00 35.64 42.02 5939.45 6024.45 3506.50 2605.16 2347.05 HS 0.00 277854.72 2358850.07 Lower 8ek, a 7151.13 35,64 42.02 5981.00 6066.00 3536 29 2627.30 2367.00 HS 0.00 277875.08 2358871.82 7200.00 35.64 42.02 6020.72 6105.72 3564.77 2648.45 2386.06 HS 0.00 277894.53 2358892.62 7300.00 35.64 42.02 6101.98 6186.98 3623.04 2691.75 2425,06 HS 0.00 277934.35 2358935.16 7400.00 35.64 42 02 6183 25 6268.25 3681 31 2735.04 2464.06 HS 0.00 277974.16 2358977 71 7500.00 35.64 42.02 6264.52 6349.52 3739.58 2778.33 2503.07 HS 0.00 278013.97 2359020.26 7600.00 35.64 42.02 6345.79 6430.79 3797.85 2821.63 2542.07 HS 0.00 278053.78 2359062.81 7700 00 35.64 42.02 6427.05 6512.05 3856.13 2864.92 2581.07 HS 0.00 278093.59 2359105.35 7800.00 35.64 42.02 6508.32 6593.32 3914.40 2908.21 2620.08 HS 0.00 278133.41 2359147.90 7900.00 35.64 42 02 6589 59 6674.59 3972 67 2951.51 2659.08 HS 0.00 278173 22 2359190 45 8000.00 35.64 42 02 6670 86 6755 86 4030 94 2994.80 2698.08 HS 0.00 278213.03 2359233 00 8100.00 35.64 42.02 6752.13 6837.13 4089.21 3038.09 2737.09 HS 0.00 278252.84 2359275.54 8200.00 35.64 42 02 6833 39 6918.39 4147.48 3081.39 2776.09 HS 0 00 278292 65 235931809 8300.00 35.64 42 02 6914.66 6999.66 4205.75 3124.68 2815.09 HS 0.00 278332.46 2359360.64 8400.00 35.64 42.02 6995.93 7080.93 4264.03 3167.97 2854.10 HS 0.00 278372.28 2359403.19 8500.00 35.64 42 02 7077 20 7162.20 4322 30 3211.27 2893.10 HS 0 00 278412 09 2359445 73 Upper Tyonek 8540.36 35.64 42.02 7110.00 7195.00 4345.82 3228.74 2908.84 HS 0.00 278428.16 2359462.91 8600.00 35.64 42.02 7158.46 7243.46 4380.57 3254.56 2932.10 HS 0.00 278451.90 2359488.28 8700.00 35.64 42 02 7239.73 7324,73 4438 84 3297.85 2971,11 HS 0 00 278491.71 2359530 83 8800.00 35.64 42.02 7321.00 7406.00 4497.11 3341,15 3010.11 HS 0 00 278531.52 2359573.38 8900.00 35.64 42.02 7402 27 7487.27 4555.38 3384.44 3049.11 HS 0.00 278571.33 2359615.92 9000.00 35.64 42 02 7483 54 7568.54 4613 65 3427.73 3088.11 HS 000 278611.15 2359658 47 9100.00 35.64 42.02 7564.80 7649.80 4671.93 3471.03 3127.12 HS 0.00 278650.96 2359701.02 9200.00 35.64 42.02 7646.07 7731.07 4730.20 3514.32 3168.12 HS 0.00 278690.77 2359743.56 9300.00 35.64 42 02 7727 34 7812.34 4788.47 3557.61 3205.12 HS 0 00 278730.58 2359786.11 7D 9350.03 35.64 42.02 7768.00 7853.00 4817.62 3579.27 3224.64 0.00 278750.50 2359807.40 Survey Error Model: ISCWSA Rev 0"•3-D 950001,r Confidence 2.7955 sigma Survey Program: Description pan MD From MO To EOU Freq Hole Size Casing Diameter Survey Tool Borchol (h) (R) (8) (in) (in) Typo 0 t 1 0000 1550.212 1.100000 16.000 13.375 SLB MWD•ST0 Plan 1 1550.212 6208.566 11100.000 12.250 9625 SIB_MWD-STD Plan 1 6208.566 9350.034 11100.000 8.500 7.000 SLB MWD-STD Plan Page 60 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 35.0 Directional Plan View (Plot) Vertical Section Plane (0.00 ft N,0.00 ft E)0 42.02° Vertical Section(ft) -2500 0 2500 5000 1 I 1 t 1 I 1 I s I ii i 2500 r t i i i i 3 0 i i i i i 5000 r ii i i i i i r i i i i i ii i 1500—._....._.....b..«.»....»»..»».««...J.....««..............._...j_._. _ .«_._._.«...,_.....y........_._»._._.«....«..J......«.._.«.........,._. ..._.«.._....._..»..»...j,»..»»._..»......._._..._ • Page 61 Revision 0 Jan,2014 KBU 32-08 11 Drilling & Completion Procedure Hilcorp Energy Company 36.0 Directional Plan View (Plot) WEST (ft) EAST 0 1500 3000 4500 i 0 ,i 7 3404._. ...««........»..»»»...««...._.� ,..n..«««.».«......_»..»»»..{.»......._»»._._..................._. ««..«..........«.»». «..«. «..««.»._»..._».««....««.. �...._..,....«.........._._.. { i i ! j i 0 i z t ii 5 1500 j t f { { { { I f Page 62 Revision 0 Jan, 2014 r KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 37.0 Spider Plot (NAD 27) (Governmental) Sections)�� $C .8- ClI.�CJ iKBU $- % �' i Kenai Gas rieik�PadiVo-�4j 07 � "`1� -_.__ \` i .f7 i "C 4�` IOU 02 Bt1I. KU 31-0\715.0 t// \1 KBU 11:$040:44,,, I/ C KU 11.083 tom* A). I \ --..... , !t t I /1 liBU 42-0740 / i /K0U42-07f�J BNI•' i KTU 32.07 BML KBU 23,8 BHti BM.; /a F`i;t:32_Os MIL] KBU 13.09 B ems A028142 a° i % rabfi /° ba° � KU/43-07 Bt$.` so KBU 43-07X BHT // /i °o°°` KM.)32-os TEl i KBU 21.19 tlHL• // °o° / ADL390821 S004N011 W KENAI UNIT ,/ °° °°° , KiiU 4.08 BHL, °°� \ t / // E Kai(KU 71-10 Bt r \ t / t rs \ t / i/ S. KBU 41.18X 1�tL i // /,/,././�\ \ 8 / KU 11.17 -....„.....,,,\ ,,,,,i ,t' / ..,..„,,,,,...--* / "_______.Kenai Gas T,e10 Pad No.41-18, Legend KU 13-0x ' 111147:8)%. r \ 0 KBU 32-08 SHL � ✓ KBU 32-08 TPH r, te , ;j \ (lace FEE022330 • KBU 32.08 BHL 0 Other Surface Wen Locations 'E • Other Bottom Hole Locations Well Paths Well Pad N EM Oil and Gas Unit Boundary r 111000 2 CX(; Kenai Unit Feet KBU 32-08 Alaska Slate Pta,e Tort*4.NA027 A /l:le.rp 11.,4.,1.1 Map Date:t2t31t2013 Page 63 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 38.0 Kenai Gas Field 41-18 Pad Plan View KENAI GAS FIELD ''' PAD 41-18 SITE PLAN rutivoao.1c .. SECTION LINE NTS (..---A&'...\\---- / - N23eS.`SS 17 _ Eat4C6u o 'CAUTION' ti "t moo PRESUME LATERAL rrrow*ro ro+ta NORTH it SCALE \\ I r US,444G ormtunr \I 1 11 03 Riff NOON SASOF I FEET K13U 4 leo Kau u a N733H116Y29 N1334044 144 E 14133)0 I40 E I4r3340IT7 • KW 1, 1581)71.14 ®4tw.4 7X 1581)71.14® N 2 0443 N notgas1 in N2N,6')45 E 14,M1 7S3 f 14154:9149 E I4IS21O43 C*4DICTOR KENAI GAS FIELD 78\104'1!.22 PAD 41-18 ' ELEv CS NT ±OZX IOT $427 CORNµOG \1 : ` fib' . .7 142X16.7 Odt7M BLDG A i, EDGE Of RAD—. VEETNfs SHED a.SW4f S44tQ SU . 14 • YALUr , UNS.1W . • tb 4.X20 Cr J NW4 N23940E4124 OEN.µDO. E t4t4MOf4 4SU 33.7 ELEY:OW VNfO N23'64/773 SEE FOO E 10101 SLOG I iii4:0: 1WLL. _.\ \pyt •V REU 24411.91 N 298674451 tNJECnp1WELL 41 12.74123' tAsd EtatSlV4.15 144241 44ram247a OIDNWRSDO KU,41.14 �E 741 48 L 44-2313S717 42 vtYJ A7 X44' t/q8.\ I1415W 74 UUU///"" �•a ©��OLO CONTROl4LW. KU.131. {'t Qi 5541 SW+e 412R305114 47 CONTAC71'31t `� 4.3'44.6 KU.12.17 ENfS1aS 8a SLOG AIR COUP SLOG N2366844.4. PRCOUCTlON 4 A E 14Met.OSS FAC4lTIES gax4A4' 4EE '4 10 —UTTIRY'EATER 8nn0svam . Aarxa� �to"x2o 1 ime A11111,111111,111111,1E7tBTNo6E0 OF PAD A ENCLOSURE mom E µDO. 4444 ,Y..' 2 RNccs iv m S - OPiIND A NJECT 8IM.OJNG ' 4'A STN•ALUL\NLN LEON Ft23Bs+2STN O.. - 7 Et4t4OS774 MY 6443' SECTION 18, T4N, R11W, S.M., AK Page 64 Revision 0 Jan, 2014 KBU 32-08 14Drilling & Completion Procedure Hilcorp Energy Company 39.0 Surface Plat (As Built) (NAD 27) SECTION LINE NOT TO SCALE(NTS) :CAUTIO) r«.n I I(; F44E55Ceg T , LATERAL CA, FIOELFLET 4•' SECTION 18, T4N, R11W,'S.M.. AK ',r' \7 i . I Z UW (71 , E 235 ;+ MZ • .vx Kttq 4I.<Ax IeuuAx . 361'FEL • N 1i5844% N 239324AAlARL ZJ73912a.g a Zb4 t NORTH Etrerrc:Mn4a r_z+szes Eirsxresxze • (NTS) VI KBU 32-08 AS-BUILT SURFACE LOCATION ESN-<: 20"CONDUCTOR • Et.,... NAD27 ASP ZONE 4 1,37x"' N:2356295.748 spout Otrfoi eLDy Iiffxlg ' E:275450.195 COttrxq then; r: LATITUDE:60'26'38.066"N ? c K.Y O LONGITUDE:151'14'36.221'W Lu c''- ELEV.:67'(MSL) a• J a� T .a= 436 FNL '•Al 1trenIP nAt• 1 t... 361'FE01 L • •r H X 4a3 EDGE 9t--•. I_ Y '� 's,' r.PENCE . , d EnaG, Z „,I•Tt Z. KeuT4.r ri_rrrtONVYEEL �j's T2a•x+2x e SLOB Z ISo �POW� w rtlaU RAE: !cJ t: OONVACIOIA V V) EA()0. 1111)O %EASE PRACxdCTKW t "C' C . �x �ag�•'q`'x IACE trrs 0 �rr'" ox-TF KENAI GAS FIELD csa PAD 41-18 NEDR°T"et TANA .\ .....A�gs�fi el, "' *I 49Th /` ••* / GRID 4It+UECT ELM L x..: \ / / I/I SASNOF COCR:oLATES€S u.S ad TM STATION ALCRY tiA S' /y.�•, I ZONE 4.IW D AvtRAGE CCNVERGENOE Ci MINES SILONN.o :" I Lit.. / S AWRY OtODE tE POSEMON PER NGS / / IAT ImirrSLMb,'R-N LOWL' SSI•ltr3r 44;1Y / 'R -.U. SCOTT McLANE: x,Z4a TS Y.21E2 4S 42 3I BASIS a 4ERTtCAL DATUM IS MEAN SEA LEVEL rtOCA:DAT`.,E4+ '//•r.•`▪ 4928-5 '• — a •,a'cAs'CORNER stc le coonommts rETtr it o FROM DIRtC- r - I''tv TIE TOTNE TOE AISTPAGp.N SECOCIN MAW R It[CmQRED ANN /I '4+••-''••.•..•.••••3A 1 SCALE ,Y,ENE PRMTRN,TED SFCTpN CORNER VALL'E9 ii. E SKEW. 1` ' k HILLCORP ALASKA,LLC \ o 'y KBU WELL 32-08 ON KGF PAD 41-18 OMAN R- CO AS BUILT SURFACE LOCATION •,•- NAD 27 T .,...MOW,,MlW.W.Iii$,4•IN i,IFtes., SEAN NO MEC "O MT.4M NAOO'M4.W.i rI t.Muir.,. AI rMlr.'M.-2+ Ir n,r, SMU T ew.. 5/.31,.4'aK1WrVIC,CW IlhLnrp 11:E.1..a.USC $18 T4N R11W SEWARD MERIDIAN.ALASKA 1 1 Page 65 Revision 0 Jan, 2014 KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 40.0 Offset MW vs TVD Chart MW vs ND Offsets 0 • 1000 KBU 11-17X(2009) 2000 „KA —KU 11-17(1982) —KBU 14-08(GD-1 2008) -- 3000 KBU 13.08(1977) � —, 1 ' —KU 41-18(KUH 1) 4000 I ----41-18X(GD-12008) —1 ----KBU 24-7X(2006) 5000 , E 6000 .1* 7000 O 8000 9000 10000 11000 12000 13000 Itc 14000 I C, 15000 I 16000 8 9 10 11 12 13 14 15 Mud Weight(PPG) Page 66 Revision 0 Jan, 2014 is KBU 32-08 Drilling & Completion Procedure Hilcorp Energy Company 41.0 Drill Pipe Information ......_ SUM 4 1/2" E. COMMAND WEIGHT: 16.6 LBS/FT GRADE: S-135 MUM SHIM RANGE 11(31.5') DRILL.PIPE SPECS CONNECTION: CDS40 TUBE NEW PREMIUM a IN MM IN MM OD 4.500 114.3 4,365 110 9 WALL THICKNESS 0.337 8.6 0.270 6.8 ID 3.826 97.2 3.826 97.2 FT-LBS N-m FT-LEM N-M TORSIONAL STRENGTH 55.453 75,200 43.451 58.900 80%TORSIONAL STRENGTH 44.362 60.200 34.761 47.100 LBS DAN LBS DAN TENSILE STRENGTH 595.004 265.300 468.297 208.800 PSI KPA 1 PSI KPA INTERNAL PRESSURE CAPACITY 17.693 121,985 1 16,176 111.530 COLLAPSE CAPACITY 16.769 115 615 : 10.959 75.561 IN2 MM2 . IN2 MM2 CROSS SECTIONAL AREA BODY 4.407 2844 3.469 2238 CROSS SECTIONAL AREA OD 15.904 10261 14.966 9655 CROSS SEcTioNAL AREA ID 11.497 74 1 7 i 11.497 7417 IN2 MM2 IN2 MM2 SECTION MODULUS 4.271 69995 3.347 54845 POLAR SECTION MODULUS. 8.543 1399891: 6.694 109690 TOOL JoINT _ ---- icrEW 1 PREMIUM I PSI KPA PSI KPA YIELD STRENGTH, 130.000 896,318 i 130.000 896.318 IN MM IN MM OD, 5.2500 133.4 5.1198 130.0 ID 2.6875 68.3 2.6875 68.3 PIN LENGTH 11.0 279.4 11.0 279 4 BOXLENGTH 14.0 355.6 14.0 355 6 FTLBS N-M FT-LBS N44 TORSIONAL STRENGTH 35.400 48.000 34.700 47,100 MAX MAKEUP TORQUE 22.500 30.500 21.400 29.000 RECOMMENDED MAKEUP TORQUE 21.200 28.800 20.800 28.200 MIN MAKEUP TORQUE 19.600 26.600 19.300 26.200 LBS DAN LBS DAN TENSILE STRENGTH 824.400 367.600, 804.900 358.900 TOOL JOINT/DRILL PIPE TORSIONAL RATIO 0.64 , 0.80 DRILL PIPE ASSEMBLY WITH CONNECTION LBS/FT KG/M ADJUSTED WEIGHT 7.87 26.64 FT m APPROXIMATE LENGTH 31.50 960 GAL/FT M2/M FLUID DISPLACEMENT 0 273 0.003394 FLUID CAPACITY 0 577 0.007169 IN MM DRIFT SIZE 2.5625 65 Page 67 Revision 0 Jan, 2014 KBU 32-08 itiDrilling & Completion Procedure Hilcorp Energy Company COMBINED LOAD CURVE FOR 4 1/2"S-135 16.6 LBS/FT DRILL PIPE WITH CDS4O CONNECTIONS 9C{000 .'.: •r ..w, ma mxx«x.m*.ca•,.�...a.,, W i ; � e 5r1/i'n ' 700 OCO Gcn coC., g, eft avow i mau 3 ale 040 a 500 000 we c + sso4 * * ogrt E It')WO ! 300.00O Y • 0• 200 OCO t , Il+• w ;� aI :000(0 0 •• EL 0 C 10,000 20.000 30.000 40,000 SO'100 G0.000 Applied Torque(h•Ibs) ——NEw TUIRE COMBINED LOAD ••••PR Ft./l.AI TLUI3F.COMIII NED LOAD —MAKE-JP TORQUE SHOULDER SEPERATION —PIN YIELD —BOX YIELD • Page 68 Revision 0 Jan. 2014 Schwartz, Guy L (DOA) From: Luke Keller <Ikeller@hilcorp.com> Sent: Friday, February 07, 2014 10:11 AM To: Schwartz, Guy L (DOA) Subject: Falls Creek#5 Information Attachments: HO-32022 KBU-32-08, KENAI FIELD.PDF pp? z /Y- oiy Guy, Attached is the corrected wellhead diagram for KBU 32-08 that reflects the correct size of prod tubing (5"). Below is a map showing the location of the Kenai Gas Field and the 41-18 pad where KBU 32-08 and KBU 43-07Y will be drilled. Regarding the leak off test conducted at the 7-5/8" casing point—a minimum of 12 ppg would be required to drill ahead. We expect leak off to occur somewhere btwn 15 and 17 ppg. I'll track down a drawing and some info concerning the surface safety valve that will be installed on the tree. Let me know if you need anything else! P 41: 1(nrr ii,,x..l c.at)r b /ORV S tMirw-P(1 a' e f Photos N a r :.,, ... 41, Krnar tttrrr ,,, 4t! wig - s " a t v \ �,t" •r t' r r / ! Ve 0 . 4641011k f 41-1$ pa dIf - anon r r �' 4 41,—,• a . ` .? y t .,yam„ w • J . M • Knlilrxrr!..a Y • A re* ILt 1 Luke Keller Drilling Engineer Hilcorp Alaska, LLC 907-777-8395 2 _CORP ALASKA, LLC KENAI GAS FIELD KBU-32-08 HO-32022 © Cl 5-1/8 10M STUDDED ' + ` ADAPTER, EN 8.6 1 11 5M X 5-1/8 10M EST I � _ w/7 DBL D SEAL PREP i t -0. CASING HANGER, - ��i' J Ill t 0 1;,= SMB-22 PORTED 11 X 5 �� I �III 11 5M 17.2 w/5 H BPV PREP EST i ..hit, ,. : O■ J I 1R- 10� ,t: Is" :■ _ • ' t: 1 j - 1 - 71 1 CASING HANGER, SMB-22 i 11 5 EST 11 X 7-5/8 • ! = jLiii 2-1/16 5M W/SEAL ASSEMBLY j O •- I r1114,1k.,.•26.3 ( i I _. ' e '-i�1,■�EST 5 'L: _10-3/4 D SEAL � 1.1► - 1111 i■ I ca 2-1/16 5M CASING HANGER, SMB-22 =..I s j 0 X16-3/4 3M 16-3/4 X 10-3/4 W/PRIMARY SEALIJI ;L i O 19.0 I _ • •EST M -* "",, .10 _ ....■ 11. _,. �� L , j 2-1/16 5M 16 CASING - 10-3/4 CASING I 7-5/8 CASING -...--- j 5 CASING -•----L NOTE: DIMENSIONS SHOWN ON THIS DRAWING ARE ESTIMATES ONLY AND CAN VARY SIGNIFICANTLY Mil DEPENDING ON RAW MATERIAL LENGTHS. OIL&GAS NO GUARANTEE OF STACKUP HEIGHT IS IMPLIED. DIMENSIONS SHOWN SHOULD BE CONSIDERED 5,000 PSI WELLHEAD ASSEMBLY FOR REFERENCE PURPOSES ONLY. 16 X 10-3/4 X 7-5/8 X 5 RESTRICTED CONFIDENTIAL DOCUMENT QE.. S ONE TO MAIM AND Au OPaNA1ON WWI HMCO ARE TIE ■I` LAP 1:10 '`/16/2014 R'/ EXCLUSIVE PROPERTY OF SEABOARD INTONATIONAL INC NO NE SNSTTOTENDPON CCERM.E0O/R0OAL In ONLY. TIF LPIRECIPRECIPIENT■EIQT■KNEESKNEES.A!ND M•a° /co DRAWING NO. THAT NO ORIELO9➢IE CF TK DMSO OR THE PPORNARQI MOON Q-3138 A MOON 1111.1.BE MACE A MOO PANTYREV A 01/21/14 CHANGE FROM SP-H TO 7 DBL D/JCS m ow'a SE ow' ■C. w„ _ Davies, Stephen F (DOA) From: David Duffy[dduffy@hilcorp.com] Sent: Monday, February 03, 2014 2:32 PM To: Davies, Stephen F (DOA) Cc: Janise Barrett; Luke Keller Subject: FW: KBU 32-08: Lease Number? Steve, Sorry for the confusion. I understand the surface location has changed slightly and Hilcorp will be submitting a revision shortly. In the meanwhile, please note that Hilcorp owns the minerals along the entire wellpath of KBU 32-08 in fee. The surface location (Section 18)falls on former state lease No.ADL 22330. The bottomhole location (Section 8)falls on former federal lease number A028142. Mapmakers continues to reference the old government lease numbers. On the revised application, we'll include a map that gives reference to those portions of the Kenai Gas Field that Hilcorp owns the minerals in fee. We'll also include reference to the former government lease number—but include the phrase "fee" in front (e.g., FEEA028142 and FEE ADL2230). Here's a snapshot of the map I'm working on now(dotted area illustrate Hilcorp minerals and former lease blocks): 1 .:\ 1 gu4a3: --B141.0...,_ a •• ,K ," ..\„ ti I� 3:1' BNt`\ �.... b 448 s .r SI Sec. 6 "' . .. :hs 1 I.I:# -j•••I::" #11�4Ob +„ t{(0.64: --..,_ 1\ ate..*., Kermit i Gas Fiell449ad,No. 1'448 i \ ;I f'r ,i .. — k 1 I ,� Kenai:Gas'•F'ieId'Pad Nts:41:07.r.,.,...,--...t 71 ��:`: ,fir, ...- '•" r:'''.• ::':`: KDUt12}$3t�t K: •.:k¢ :7::8811 K1 : 7x •V 1 f KU T1=08$A13• if 1 3442=B1•]L.ti._... ._: •4 - 78-8 • pL-r :04:B1tLr '/ 3 I I . ,,�...j.....) • /! , iini 1411: :.SHL. 1 I MK;23:8 8H ,,'' I ::: r..1.-_--+r EEL II R KEW: 3408 Snit .•. r , � -8:61ik•�--r-lf> :33. $FILA C k .•.Sec. �i BU 2307 BIL A. KBU L '\KU:43-01 BHL KBJ:43=0• BNL" �� •'.13L-3:-OtTPS SOO4N 011 W KB2149BHL G f.2 \ s N. KBIT 244-X BHL„.. ti MIR KU 2.4=07 Bilk R 40.1:4111` : >-. .. - . ki'lr '^ ena: as- 4Id�Pa 1 N•.-41=18 4 —KiG - ii1-1 :18111_ . XBU ZY-48:13' •� 1t 1. sec:: 4 •AL ►• KUK2=TTBf 2. = -�� - 330 E 1 KU 44;18 8Ht, 1 row1 .., ,, i. .. 1 s,at _ v. I .........1. . . Hope this helps-give me a call with any questions. David Duffy, Landman Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, Alaska 99503 Office: 907 777-8300 Direct: 907 777-8414 Fax: 907 777-8580 2 Cell: 907 301-2629 Email: dduffv@hilcorp.com This email may contain confidential and/or privileged information and is intended for the recipient(s)only. In the event you receive this message in error, please notify me and delete the message. Does this help? From: Davies, Stephen F (DOA) [mailto:steve.davies©alaska.gov] Sent: Monday, February 03, 2014 12:28 PM To: Luke Keller; David Duffy Subject: KBU 32-08: Lease Number? David, Luke: When I type Federal lease number A 028142 into BLM's Alaska Case Retrieval Enterprise System (ACRES; available at http://sdms.ak.blm.gov/acres/abstract/get sernum), I see a "Case Status" of"Closed" with a "Case Status Date" of Dec 3, 2010. Is A028142 the proper lease number for the planned KBU 32-08 well? When I check the location of the well against the lease map in my workstation, Sections 18 and 17 of T4N, R11W appear to lie outside of lease A 028142. Is this correct? If so, what lease number(s)encompass Sections 18 and 17? Thanks, Steve Davies AOGCC 907-793-1224 3 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. `L l �I�? 1\��_i.1 1: L ITER C ECl_E,T WELL NAME: (D _a)4_--)ot i \clUllli 'il c: til tlililc'l i c,l ilii\ oI;L'I 1 i.I',II: POOH 8C1/5 -- Check Box for Appropriate Letter/ Paragraphs to iie Included in Transmittal Letter CHEC1< OPTION� TEXT> I4OR APPROVAL LETTER - MULTI The permit is for a new wellbore segment of existing well Permit L1'1 F.RAI No. . API No. 50 (If last t\\o digits Production should continue to he reported as a function of the original in API number are API number stated abo\e between 60-69) In accordance with 20 AAC 25 005(f). all records. data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are Well Lo in also required for this well: gg g Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 5/2013 a) 2 N co m 0 w a) O- co cn N_ a) 0 2 4 c a) CT 0 Ca) N N a _ o o C 3 N -0 O) N O • O c a N w (/) U c6 p a) a 2 o 2 O u) a) c6 O c0 7 0 ° a) a) m a a m o )n o 7 > L c a c _I Eo a 0 o Z o co n cn _ p@ co y n 0• a c a Q V co co E O p o Y o Y a `o) o o 0 a o a o m d 2 co 7 >• .0 c/)• C L N >• T st a) as .@ E 3 7 F o O O 0 CV t- d a 0 a.) a) •a C a) a) N O) 0 _ 0 0 Q -0 N- N U 7 - L = O c —_ _ a) 7 o CO 0 3 0 — N co O C a3 a) a co 0 N 7 Ua) 7 0 7 = > 7 0 a` a) ) O w 2 m o uo) a > -0 a ° - Y D -o N 0 N .L..� = 7 To O a in p L 0 O a) V O O O O -O a - X m U. O) o a oN a°i 0) .0 . 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(U c6 a o a 0 7 0 > > 3 0) 7 6 7 a) o) w w N 3 N CO n O 0 N J 2 E N a - - - a>) a`) Cl)` E E C - 3 a c -o '2 I- I- I- ') lir) ao) > c Cl- a o L- E 0 E a3 0 m c m V V >., o 0 c a a a 7 a a a 45 co o - 2 0 0 7 2 2 2 co a 0 a -0 0 0 0 L ° N a) a) a) a) a) 0 0 c a _I0 cn 0 0 a a U Q a Z O co O O O O < ) < ) 0 m m O - 2 a 0 co cn O V-",_,,LV aO NMV «) (0 N- CO 6) O N (1) V (C) O r W O) ON M A U) OhWO) VEO N CO C Cl) CO N. CO CA N N N N N N N N N N M M M M M M M M (Cl) M 0 I— 'V C' . a) G O c + O OS N OS O 0 ce V o CO6 N R N R N 0._ D v a) 0 0 co o y dII O N c N N ' V N N m 0 E J c o ° v 1 W o f a L CD 0. o Q o U IC a a U) c Q (7 Q U) Well History File APPENDIX Information 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. KBU 32-08 Kenai Beluga Unit Kenai Borough, Alaska Mar 6, 2014 – Mar 9, 2014 Provided by: Approved by: Sarah Rittenhouse Compiled by: Ralph Winkelman Donna New Distribution Date: 4/7/2014 KBU 32-08 2 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ...............................................................................................3 1.1 Equipment Summary....................................................................................................................3 1.2 Crew ..........................................................................................................................................3 2 GENERAL WELL DETAILS.................................................................................................................4 2.1 Well Objectives ...........................................................................................................................4 2.2 Hole Data ...................................................................................................................................5 2.3 Daily Activity Summary.................................................................................................................5 3 GEOLOGICAL DATA .........................................................................................................................7 3.1 Lithostratigraphy ..........................................................................................................................7 3.2 Lithological Details .......................................................................................................................8 3.3 Sampling Program .....................................................................................................................14 4 DRILLING DATA ..............................................................................................................................15 4.1 Surveys ....................................................................................................................................15 4.2 Bit Record ................................................................................................................................20 4.3 Mud Record ..............................................................................................................................21 4.4 Drilling Progress Chart ...............................................................................................................22 5 DAILY DRILLING REPORTS ............................................................................................................23 Enclosures 2” / 100’ Formation Log (MD/TVD) 5” / 100’ Formation Log (MD/TVD) 2” / 100’ LWD Combo Log (MD/TVD) 2” / 100’ Drilling Dynamics Log (MD/TVD) 2” / 100’ Gas Ratio Log (MD/TVD) Final Data CD KBU 32-08 3 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type /Position Total Downtime Comments Computers – Surface Logging (5) Rigwatch Server, Rigwatch Remote DML, LWD WITS, Rigwatch Remote 0 hours Ditch gas QGM gas trap; Flame ionization total gas & chromatography. Hook Load / Weight on bit WITS from Pason 0 hours Mud Flow In Derived from Strokes/Minute and Pump Output 0hours Mud Flow Out WITS from Pason 0hours Pit Volumes, Pit Gain/Loss WITS from Pason 0hours Pump Pressure WITS from Pason 0 hours Pump Stroke Counters (2) WITS from Pason 0 hours Rate of Penetration Calculated from Pason 0 hours RPM WITS from Pason 0 hours Torque WITS from Pason 0 hours WITS To/ From Pason Rigwatch Remote (HP Compaq) 0 hours 1.2 Crew Mud Logging Unit Type: Arctic Mud Logging Unit Number: ML057 Mud Loggers Years1 Days2 Sample Catchers Years Days2 Technician Days2 Ralph Winkelman 23 3/4/2014 Don Thibodeaux 37 3/4 Allen Williams 2 hrs Donna New 9 3/4 Ben Calo .5 4 *1 Years experience as Mudlogger *2 Days at well site between rig up and rig down of logging unit. KBU 32-08 4 2 GENERAL WELL DETAILS 2.1 Well Objectives KBU 32-08 is permitted as a grass roots Single Zone Development Gas well in the Kenai Beluga Gas Unit. The well is planned to be directionally drilled, with a minimum of hole or other problems, in a NE direction to 9350’MD/ 7853’TVD planned, (9847’MD/ 8183.2’ TVD actual). The KBU 32-08 will target the Mid-Lower Beluga and Upper Tyonek reserves on the eastern flank of the field. The base plan is a build and hold wellbore reaching a maximum inclination of 35.6 deg and a 4817’ vertical separation. Operator: HILCORP ALASKA, LLC Well Name: KBU 32-08 Field: Kenai Beluga Unit County: Kenai Borough State: Alaska Company Representatives: Mike Leslie, Bob Farrell, Doug Yessak Location: Surface Coordinates 552' FNL, 427' FEL, Sec 18, T4N, R11W, SM, AK Ground ( Pad ) Elevation 67’ Rotary Table Elevation 85.6’ Classification: Development - Gas API #: 50-133-20624-00-00 Permit #: 214-014 Rig Name/Type: Saxon 147/ Land/ Double Spud Date February 18, 2014 Total Depth Date: March 9, 2014 Total Depth 9847’ MD / 8183.2’ TVD Primary Targets Beluga and Tyonek Gas Pools Primary Target Depths Gas Zones: Beluga and Tyonek Total Depth Formation: Tyonek Completion Status: Run, Set and Cement 5” Liner to surface. LWD-MWD Services. Halliburton/ Sperry Drilling Services Directional Drilling Halliburton/ Sperry Drilling Services Wireline Logging Services Pollard for CBL, Schlumberger for production interval Drilling Fluids Service M.I. Swaco CANRIG Logging Geologists: Ralph Winkelman, Donna New CANRIG Sample Catchers: Ben Calo, Donald Thibodeaux KBU 32-08 5 2.2 Hole Data Maximum Depth Shoe Depth Hole Section MD (ft) TVD (ft) TD Formation Mud Weight (ppg) Dev. (oinc) Casing Diam. MD (ft) TVD (ft) FIT (ppg) 13 1/2” 1514’ 1448.9’ Sterling 9.3 35.28 10.75” 1477’ 1418.7’ 12.0 9 7/8” 6418’ 5401.1’ Beluga 9.6 35.49 7 5/8” 6348’ 5344.2’ 12.2 6 3/4” 9847’ 8183.2’ Tyonek 10.3 31.89 5” 9747’ 8098.4’ N/A 2.3 Daily Activity Summary March 4, 2014: Run in hole picking up singles and prepare to drill ahe ad. March 5, 2014: Trip to bottom and drill out; drill 20' new formation (estimated- will confirm and adjust). Perform FIT and trip to surface, lay down BHA and rig up wireline for CBL. Currently running CBL. March 6, 2014: Pick up drilling assembly and trip to bottom, perform new FIT, drill ahead. March 7, 2014: Drill ahead alternately sliding and rotating as needed to maintain planned trajectory toward target for TD. Max Gasses past 24 hours: 6858'-253u/ 6945'-513u / 6988'- 268u / 7059'- 204u/ 7108'-183u / 7178' -177u / 7251' -516u / 7354' - 165u / 7411' 150u / 7449'- 164u / 7550'-265u / 7607'-425u / 7669'-310u/ 7774'- 225u / 7870'- 809u / 7920' -386u / 7976'- 354u/ 8084' - 554/ March 8, 2014: Drilled ahead to 8506', short trip to 7463'- many tight spot s and multiple 30K over pulls, reamed through it, tripped back to bottom with no problems, resumed drilling and currently drilling ahead. Max Gasses 8286'-1304u//8361'-1406u//8383'-1515u // 8413' 291u // 8441'-351u // 8499'-423u// 8540'-481u // 8606'-728' // 8683'- 511u // 8720'-300u // 8742'- 315u // 8798' 456u 8834'- 577u // 8902' - 419u // 8970' - 380u // 9065' -597 u // --Max Connection gas 1554u at 9064' March 9, 2014: Drilled ahead to TD @ 9374', pull off bottom and circulate and condition mud. Decision made to drill on with new TD set at approximately 9850.' Completed short trip and tripped back to bottom and drilled ahead to new TD at 9847' currently circulating and conditioning for trip out to run logs. connection gasses 9621' - 1223u and 9684' - 341u. Wiper gas was 2832u @ 9374'; Max gasses 9140'- 770u // 9207'-789u // 9280'- 632u // 9300' - 495u // 9331'-330u // 9368' - 774u // 9570'- 654u // 9598'- 602u // 9707' - 173u // 9796' - 631u // 9847' first bottoms up 394u,// multiple high gasses as we circulat ed condition with the highest ~630 units and abundant readings in the 400u to 500u range. March 10, 2014: circulated condition mud cir culated b/u pulled up 2 stands off bottom cir raised MW to 10.3 POOH pumping out to 8000' cir B/U max gas 600u TOOH to 6320' cut slip drill line TIH to 9847' circulated condition mud Max gas 2100u weight up mud to 10.5 pulled 2 stands cir B/U POOH to 7770' cir B/U max gas 735u. March 11, 2014: POOH to 6500' circulated B/U max gas 756u finished POOH to BHA laid down MWD tools and BHA rigged up wireline tools ran in hole logging hole with wireline XPT logs at report time . KBU 32-08 6 March 12, 2014: Finish running wireline logs laid down directional tools P/U new BHA TIH to 1978' cir B/U max gas 1975u TIH to 4150' cir B/U max gas 2680u TIH to 6333' cir B/U Max gas 2768u TIH to 7882' cir B/U max gas 2696u TIH to 9669 cir B/U raise MW to 10.7 max gas 2758u. March 13, 2014: Washed ream from 9669' to 9847' back ream back to 9669' cir B/U max gas 2570u short trip 9682 to 9061' TIH to 9682' cir B/U max gas 1380u POOH back reaming to 6500' max gas 498u while pumping cir B/U max gas 12u slug pipe POOH laying down drill pipe at present depth 2097'. March 14, 2014: Continue laying down drill pipe from 2097' to 688' TIH with rest of drill pipe to 4040' cir B/U max gas 608u finished POOH laying down DP and BHA pickup CRT tool casing equipment made up Shoe track TIH with 5" production CSG to 1839' cir high gas out max 615u TIH to 3947' cir high gas out max gas 1700u TIH at report time@ 5177'. March 15, 2014: Cont RIH w/ 5” production liner to 9747’. Cement in place as per plan. Rig down Canrig. KBU 32-08 7 3 GEOLOGICAL DATA 3.1 Lithostratigraphy Prognosed and observed tops given by Hilcorp geologist Sarah Rittenhouse. Observed tops determined after evaluation of Schlumberger Quad-Combo LWD logs. PROGNOSED OBSERVED FORMATION MD (ft) TVD (ft) SSTVD (ft) MD (ft) SSTVD (ft) TVD (ft) A0 2,544 -2,213 2,280 A1 2,654 -2,303 2,370 A2 2,767 -2,392 2,459 A3 2,957 -2,543 2,610 A4 3,353 -2,862 2,929 A5 3,532 -3,006 3,073 A6 4,071 -3,447 3,514 A7 4,126 -3,493 3,560 A8_(POOL_3) 4,281 -3,619 3,686 A9_(POOL_3) 4,340 -3,668 3,735 A10_(POOL_3) 4,378 -3,698 3,765 A11_(POOL_3) 4,458 -3,762 3,829 B1_(POOL_4) 4,555 -3,840 3,907 B2_(POOL_4) 4,627 -3,897 3,964 B3_(POOL_5_1) 4,719 -3,971 4,038 B4_(POOL_5_1) 4,784 -4,023 4,090 B5_(POOL_5_2) 4,999 -4,195 4,262 C1_(POOL_6) 5,356 -4,478 4,545 C2_(POOL_6) 5,481 -4,578 4,645 UPPER_BELUGA 5,555 -4,636 4,703 MIDDLE_BELUGA 6,424 -5,339 5,406 LOWER_BELUGA 7,286 -6,033 6,100 TYONEK 8,662 -7,146 7,213 72-8 8,752 -7,218 7,285 73-1 8,810 -7,264 7,331 75-8 9,161 -7,546 7,613 76-7 9,276 -7,640 7,707 KBU 32-08 8 3.2 Lithological Details Full service mud logging began at 6418’ MD /5401’ TVD. All the sample lithology descriptions provided by Canrig began after the intermediate casing shoe track. The logged well included the Beluga and Tyonek Formations, whose lithology of largely volcanic ash-derived fluvial sediments included: tuffaceous claystone, tuffaceous siltstone, sand/sandstone, volcanic ash, coal and various other minor to trace thinly bedded lithologies. The wellbore was drilled to 9847’MD / 8183.2’ TVD / -8097.6’ TVDSS. T uffaceous Claystone (6418' - 6460') = medium light to light gray with light brownish and yellowish gray secondary hues; soft to moderately firm; irregular to shapeless cuttings; silty to clayey; gummy to sticky. T uffaceous Sandstone (6450'-6580') = medium light gray to medium dark gray; frame work transparent colorless quartz to translucent grayish quartz with up to 40% medium gray lithic fragment s; grain size predominantly lower very fine to upper medium grained, angular to occasional sub rounded; sphericit y moderate with most grains fairly equant; moderately to poorly sorted; texture gritty; poorly indurated presenting with abundant to common loose grains; poorly welded tuff matrix with no additional cementation evident; mostly matrix sup ported with occasional grain supported specimens showing point contact and long contact; associated with thinly interbedded tuffaceous siltstones and occasional v thinly bedded coals and carbonaceous shales with thin laminae of very dark carbonaceous material; both the thin coals and the carbonaceous shale show weak out gassing . T uffaceous Siltstone (6580'- 6640') = very light gray to whitish gray with occasional dark medium gray to light medium gray; earthy to dull luster rare slightly waxy; texture silty; poorly to moderately indurated with rare slightly firm specimens; considerable ash component, common to occasional very thin carbonaceous laminae commonly discontinuous and occasionally contorted; rare very thin laminae of very fine sand. Unconsolidated Sand (6640'-6740') = very light gray to medium dark gray ; presents as loose grains predominantly transparent colorless quartz to translucent white to very pale gray quartz; common dark inclusions within; grain surfaces commonly pitted; frosted; and many broken and fractured grains; very fine to lower medium grained; angular to sub rounded; sphericity poor to occasional moderate; poorly to moderately sorted; poorly indurated with little evidence of relict cementation or matrix, rare preserved specimens of very soft to extremely crumbly sand stone with a very poorly welded tuff to ash matrix; up to 50% lithic clasts; also angular to sub rounded; moderate to poorly sorted; no fluorescence, no cut. Carbonaceous Shale (6680'- 6800') = moderate yellowish brown to dusky yellowish brown, brownish black to black, common light yellowish brown; earthy to slightly waxy luster; smooth to slightly silty texture; moderately indurated to occasional well indurated, crumbly to occasionally crunchy; common thin laminae of carbonaceous material and thinly interbedded with thin well developed coals, common out gassing seen in both the carbonaceous shale and the thin coal laminae. Coal (6800' -6900') = very dark brownish black to black with common dusky yellowish brown to moderate yellowish brown rare slightly reddish brown to reddish black; very soft to occasionally firmly crunchy with occasional well developed very hard; luster waxy to slightly resinous and in the well developed specimens vitreous luster evident; slow sparse out gassing seen in both the well developed and the lesser developed specimens; blocky to planar fracture in the softer coals with common conchoidal seen in the harder cuttings; thinly interbedded with carbonaceous shale and tuffaceous siltstones which occasionally add a slightly silty texture; coals often accompanied with an increase in gas. KBU 32-08 9 T uffaceous Siltstone (6900' -6980') = very light gray to whitish gray, occasional light medium gray to light grayish brown, occasional light yellow brown; very soft to slightly crunchy specimens; very slightly silty texture; abundant tuffaceous matrix mostly poorly welded with some specimens showing nearly no evidence of welding and more ashy than tuffaceous; cuttings commonly show imbrications due to pdc bit metamorphosis; very thin discontinuous and commonly contorted laminae of carbonaceous material. T uffaceous Sandstone (6980'-7100') = very light gray to light medium gray with rare light gray, occasional whitish gray to very pale gray; upper very fine to upper medium grained; frame work transparent to translucent colorless to very pale gray quartz with an equal mix of medium grained very light gray to medium gray lithic fragments; sub angular to sub rounded with common very angular cuttings; poorly sorted to moderately sorted in occasional individual specimens; texture gritty to abrasive; soft to occasionally slightly firm crumbly; poorly indurated, poorly welded ashy tuffaceous matrix with little evidence of additional cementation; no fluorescence and no cut. Carbonaceous Shale (7100'- 7170') = very dark dusky brown to dark yellowish brown, occasional light yellowish brown to light reddish brown; rare brownish black; dull earthy luster to occasional slightly waxy luster; texture mostly smooth but occasional slightly silty and rare slightly gritty due to trace amount of sand entrained in thin laminar tuffaceous shale; common thin laminae of carbonaceous material and very thin coals often discontinuous and slightly contorted; out gassing often seen from thicker of these laminae. T uffaceous Claystone/ T uffaceous Siltstone (7170' - 7240') = light gray to very light gray with yellowish gray secondary hues; irregular with trace pdc bit action shaped cuttings; silty to clayey texture; dull, earthy to slightly waxy luster; soft to slightly firm; sticky at times; moderate to very soluble; hydrophilic; poor to fair adhesiveness; fair cohesiveness; trace dark brown to black microthin laminations and inclusions; trace thin carbonaceous shale/ coal beds; non calcareous. Sand/ Sandstone (7240' - 7300') = medium to medium dark gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, medium to dark gray, black and trace light to medium greenish gray; very fine upper to trace coarse lower, dominantly fine upper to medium lower; angular to subangular; poor to fair sorting; dominantly unconsolidated with trace very fine, calcareous cemented sandstone; dark gray; hard to brittle. T uffaceous Claystone (7300' - 7350') = medium to medium light gray with light brown secondary hues; soft to slightly firm; irregular with trace pdc bit action shaped cuttings; silty to clayey texture dull, earthy luster; hydrophilic; fair cohesiveness and adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations. Coal/ Carbonaceous Shale (7350'-7380') = black with brownish black secondary hues very firm to hard, brittle at times; finely ground to blocky cuttings; planar fracture dominant; smooth to slightly gritty texture; earthy to resinous luster very weak, trace out gassing observed. T uffaceous Claystone/ T uffaceous Siltstone (7380' - 7460') = medium light to light gray with yellowish gray secondary hues; soft and mushy to slightly firm; irregular to shapeless, amorphous cutting s; silty to clayey texture; dull to greasy to slightly waxy luster; moderate to very soluble; hydrophilic; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions; trace thin carbonaceous shale/ coal beds throughout. Sand (7460' - 7510') = medium gray overall with a weak salt and pepper appearance, individual grains dominantly medium to dark gray, black, clear to translucent quartz and volcanic glass with trace light greenish gray; very fine upper to trace very coarse lower, dominantly fine upper to medium lower; angular to subangular; poorly sorted; dominantly unconsolidated; non calcareous. KBU 32-08 10 T uffaceous Claystone/ T uffaceous Siltstone (7510' - 7590') = medium light to light gray; soft and sticky to slightly firm; irregular with trace pdc bit action shaped cuttings; silty to clayey texture dull, earthy luster; hydrophilic; poor fair cohesiveness; fair adhesiveness; soluble; moderately expansive; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions. Coal/ Carbonaceous Shale (7590'-7620') = black with browni sh black secondary hues hard to brittle; massive to blocky and platy, occasionally splintery; planar fracture dominant with trace conchoidal; earthy to resinous luster; smooth to silty to slightly gritty texture; trace resinite along bedding planes; very weak trace out gassing observed. T uffaceous Claystone/ T uffaceous Siltstone (7620' - 7690') = medium light to light gray with pinkish gray secondary hues; soft and mushy to slightly firm; irregular to shapeless, amorphous cuttings; silty to clayey texture; dull to greasy to slightly waxy luster; moderate to very soluble; hydrophilic; non calcareous; poor to fair cohesiveness and adhesiveness; trace dark brown to black microthin carbonaceous laminations and inclusions; scattered coals throughout. Carbonaceous Shale (7690'-7780') = dusky yellowish brown to moderate yellowish brown, brownish black to occasional black, occasional intervals lighter colored specimens ranging from pale brown to pale yellowish brown; moderately soft to firmly crumbly with occasional slightly firmer to nearly crunchy; luster earthy to slightly waxy, texture mostly smooth with occasional slightly silty; common thin laminae of carbonaceous material from 0.5mm thin coals to very thin laminar crusts, the thinner laminae are often contorted and discontinuous; slow sparse out gassing seen in occasional specimens; no fluorescence, no cut. Sandstone (7780'-7940') = tri-modal tuffaceous sandstone very light gray to whitish gray; upper very fine to upper fine with occasional lower medium; sub angular to sub rounded sphericity moderate and grains mostly equant; moderately well sorted with occasional specimens especially in the finer grained specimens are often well sorted; poorly to moderately well indurated presents with abundant loose grains and abundant finely divided sandstone; tuffaceous matrix with soft to crumbly matrix in the preserved, no other cementation observed; mode 2 unconsolidated sand = loose transparent to translucent colorless to whitish gray quartz, also up to 50% very light gray to medium dark gray lithic fragments appearing to be reworked sediments; trace darker irresolvable fine grains; mode 3 sandstone = light medium gray to dark medium gray and occasional light grayish brown; lower fine to upper fine grained; sub rounded to sub angular with moderately high sphericity; siliceous cementation, firmly crunchy to very firm and moderately hard; framework approx. 50% transparent to translucent colorless to very light gray quartz and approximately 50% very light gray to light medium gray lithic fragments possibly reworked sediments; no fluorescence or cut. Coal (7900'- 8020') = black to brownish black with occasional very dark dusky brown, occasional very dark reddish brown to very dark reddish black; luster sub vitreous to vitreous with common resinous to waxy; texture mostly smooth with occasional very slightly silty very thin laminae; well developed well indurated; crunchy moderately hard; common planar parting to moderately fissile; common interbedding with thin carbonaceous shale and occasional thin tuffaceous siltstone laminae; common moderately vigorous, steady out gassing from both coals and the carbonaceous shale; no cut; no fluorescence. T uffaceous Siltstone (8020'- 8140') = very light gray to medium dark gray with occasional light yellowish brown light grayish brown; luster dull to earthy; texture silty to very slightly gritty; moderately to poorly indurated; easily crunched to easily crumbled with occasionally pasty to tacky with a slight argillaceous component; thinly interbedded with coals and carbonaceous shale and occasional coals; no cut; no fluorescence observed. Carbonaceous Shale (8100'-8200) = light yellowish dusky brown to medium yellowish brown; light olive brown to light grayish brown; banding common with rare mottling of colors; luster waxy to resinous to earthy; texture predominantly smooth with occasional thin laminae of slightly silty to moderately silty tuffaceous siltstone; KBU 32-08 11 moderately indurated to soft and malleable with common crunchy to slightly firm; common thin laminae of carbonaceous material and occasional very thin laminar coals; common slow to moderately vigorous out gassing; no fluorescence and no cut. Coal (8200' -8340') = black to brownish black, very dark grayish black to very dark gray; hard to vey firmly crunchy on the best developed specimens with common easily crunched and crumbly specimen; fracture from conchoidal to very thin planar parting; well indurated to very fissile and easily slipped apart along bedding plans; cuttings habit from blocky and sub tabular to irregular elongated and occasionally irregular bladed to wedge like; texture predominantly smooth and satiny to occasional slightly waxy; very thi nly laminated structure with bedding readily distinguishable especially in the more poorly developed specimens, common out gassing seen in all modes with best developed coals showing a moderately vigorous out gassing while the lesser specimens exhibit slower but still steady out gassing ; max gas associated with this interval reached 1312 units. Sand (8340' - 8380') = medium to medium light gray with a moderate salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, light to dark gray, green to greenish gray and black; fine lower to coarse lower, dominantly medium angular to subangular; fair to good sorting; unconsolidated; non calcareous. T uffaceous Claystone/ T uffaceous Siltstone (8380' - 8460') = medium light to light gray with light brownish gray and yellowish gray secondary hues; soft and pulverulent to slightly firm; irregular to shapeless to trace pdc bit action shaped cuttings; silty to clayey texture dull to slightly waxy luster; soluble; hydrophilic; poor to fair cohesiveness; poor adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions; abundant very thin carbonaceous shale/ coal beds throughout with weak to moderate and occasionally strong out gassing . T uffaceous Siltstone (8460' - 8500') = light to medium light gray with light brownish gray secondary hues; soft and fragile; amorphous to pdc bit action shaped cuttings; silty to clayey; dull, earthy luster; non calcareous. Coal/ Carbonaceous Shale (8500'-8660') = black with brownish black and grayish black secondary hues; platy and flaky to blocky; firm and splintery to hard and brittle; planar fracture dominant with trace conchoidal and birdseye; smooth to resinous to slightly silty texture; resinous to slightly earthy luster; trace to common, weak to vigorous out gassing from larger, hard fragments; trace resinite along bedding planes; bituminous. T uffaceous Claystone/ T uffaceous Siltstone (8380' - 8460') = medium light to light gray with light brownish gray hues soft, fragile and pulverulent, to slightly firm; irregular to wedge to shapeless and trace pdc bit action shaped cuttings silty to clayey texture; dull to slightly sparkly luster; very soluble; hydrophilic poor to fair cohesiveness and adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminae; siltstone commonly grades between silty sandstone/ sandy siltstone. Coal (8620'- 8760') = black to blackish brown; dark yellowish brown to occasional dark grayish brown to very dark gray; luster satiny to vitreous and occasionally slightly resinous; texture very smooth to slightly siltier in the less developed; induration moderately hard to moderate soft with few specimens exhibiting moderate fissility; tenacity very firm to crunchy with occasional crumbly; fracture blocky to sub planar with occasional imperfect planar parting to conchoidal fracture in best developed specimens; cuttings habit mostly irregular to occasional sub blocky to sub tabular with common irregular wedge like to elongated cuttings; structure very thinly bedded with sandstones and siltstones . T uffaceous Sandstone/ Siltstone (8730'- 9100') = very pale whitish gray to light gray with occasional light medium gray, occasional light yellowish brown to medium yellowish brown; frame work transparent to translucent colorless to light gray quartz often with dark lithic inclusions within the quartz, also light gray to occasionally dark gray lithic fragments generally less than 30%; lower very fine to lower medium grained; poorly to moderately sorted; angular to sub angular with only occasional rounded grains; grains fairly equant; KBU 32-08 12 very soft to very easily friable and presents with loose grains and very small aggregates of grains ; tuffaceous cementation with a slight argillaceous component; poorly welded very pale tuff matrix; most specimens matrix supported; no cut , no fluorescence. Carbonaceous Shale (8820' -8960') = very dark brown to brownish black, occasional dark yellowish brown to very dark reddish brown, occasional grayish brown; tenacity moderately firm to crumbly with common very soft; fracture hackly to sub planar with common irregular to earthy in the softer specimens; cuttings habit sub tabular to moderately wedge like with common irregular cuttings; luster resinous to waxy and commonly dull to earthy; texture slightly silty to very smooth and wax like; structure very thinly laminated with very thin laminar short discontinuous and contorted laminae of carbonaceous material to very thin laminae of coals; common out gassing from both the coals and the carbonaceous shale; no cut; no fluorescence. Coal (8860' -8920') = black to very dark grayish black, occasional very dark reddish black to very dark reddish brown; occasional reddish crusts at planar fractures; very fir mly crunchy to nearly hard, commonly brittle; fracture blocky to planar with common sub planar to conchoidal; cuttings habit blocky to sub tabular with occasional irregular elongated specimens; common irregular cuttings that appear to be following a contorted relict structure; luster mostly vitreous to sub metallic, rare surfaces show trace of frosting; structure thinly laminated occasional minor small scale twists and contortions of bedding planes; moderate out gassing to occasionally sparse out gassing , no cut; no fluorescence. T uffaceous Sandstone (8900' - 9120') = very pale gray to whitish gray with common very light medium gray, slight yellowish gray occasionally observed; tenacity very soft to slightly firm, very easily friable; lower very fine to upper fine grained with occasional lower medium grains; mostly quartz ranging from transparent colorless to translucent white to very pale gray; many grains have dark lithic inclusions; moderately sorted to poorly sorted; sun angular to angular with occasiona l sub rounded grains; sphericity moderate; most grain surfaces unabraided with rare very slightly frosted grains; soft to slightly firm, very easily friable; cementation predominantly the loose welding of a tuffaceous matrix with a slight argillaceous comp onent; matrix is very bright white to very slightly very pale orange tuff; most specimens are matrix supported; approximately 30% light gray to very pale lithics; no fluorescence or cut. Coal (9200' - 9260') = ve ry dark blackish brown to black with common dark reddish black to dark reddish brown; tenacity very fir mly crunchy to slightly crumbly; common planar parting and readily fissile; fracture blocky to sub planar to common conchoidal; cuttings habit sub blocky to sub tabular with occasional irregular wedge like to irregular elongated specimens; luster mostly satiny to vitreous with common resinous to slightly waxy especially when scored with probe a waxy streak shows with brownish red residue; texture waxy smooth with very rare slightly silty texture due to occasional thin silt laminae within the coal; very thinly laminated structure with some specimens showing this structure well while other the laminar structure is rarely visible yielding a harder more vitreous coal. Coal (9320' - 9370') = black with brownish black secondary hues; hard to brittle flaky to platy to massive; planar fracture dominant; vitreous to slightly earthy luster; smooth to silty texture; steady out gassing observed; bituminous. Sand/ Sandstone/ Tuffaceous Sandstone (9370'-9470') = light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, medium to dark gray, black and trace light bluish green to greenish gray; very fine lower to trace very coarse upper, dominantly very fine upper to fine lower angular to subangular; moderately well sorted; very loosely consolidated with non calcareous cement; firm to fragile; very light gray ashy tuff supporting matrix common; pulverulent; light gray sandstone commonly grades between silty sandstone/ sandy siltstone; firm to fragile; poor estimated porosity and permeability. Tuffaceous Siltstone/ Tuffaceous Claystone (9470' - 9530') = light gray with light brownish gray secondary hues; soft and fragile; irregular to trace pdc bit action shaped cuttings; silty to clayey texture; dull to slightly sparkly luster moderately soluble; hydrophilic; poor to fair cohesiveness; poor adhesiveness; non calcareous; KBU 32-08 13 siltstone commonly grades between silty sandstone/sandy siltstone. Carbonaceous Shale (9530'-9620') = dusky yellowish brown to moderate yellowish brown, blackish brown to reddish brown with occasional grayish brown to light grayish brown; tenacity moderately crunchy to moderately crumbly with rare moderately soft; fracture hackly to irregular with common earthy, cuttings habit sub blocky and sub tabular to slightly irregular wedge like; luster dull to waxy with rare earthy and rare resinous; texture smooth with occasional slightly silty due to interbedding with tuffaceous siltstones and sandstones; structure thinly laminated. Tuffaceous Sandstone (9620'- 9847') = very pale whitish gray to light gray, light brownish gray to rare very pale orange and rare very pale yellow , speckled white; framework predominantly transparent to translucent colorless to very pale gray quartz and very light gray to bluish gray lithic fragments up to 20% of sample; lower very fine to upper fine with occasional lower medium grains; moderately well sorted; cuttings habit irregular blocky to irregular wedge like with occasional sub tabular to somewhat rounded; luster overall dull with slight sparkle on fresh surfaces; sub angular to sub rounded with common angular grain fragments <10%; sphericity moderate with fairly equant grains; soft to very easily friable with common slightly firm to easily crumbled, rare harder specimens especially with darker color cuttings; cementation mostly due to poorly welded nature of the tuffaceous matrix with the sand stone being matrix supported; grades to tuffaceous siltstone; occasional thin laminae of carbonaceous material often as thin crusts at partings; thinly interbedded with coals; no fluorescence; no cut. Coal (9760' -9847'@TD) = black to brownish black with occasional reddish black; very firmly crunchy to slightly hard with occasional easily crunched; mostly conchoidal fracture with occasional sub planar; cuttings habit irregular to sub blocky, common contorted platy to irregular; luster predominantly vitreous; texture very smooth; thinly laminated structure; most specimens show moderate to vigorous out gassing . KBU 32-08 14 3.3 Sampling Program The sampling program specified by the Geologist called for the collection of three sets of Washed and Dried Reference Samples beginning at 6418’ MD. The resulting set, interval, and distribution are shown below. Sets Type and Purpose Interval Frequency Distribution 1 Washed and Dried 6418’ – 9847’ 20’ Landon Ellison Hi lcorp Alaska LLC 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 2 Washed and Dried 6418’ – 9847’ 20’ Landon Ellison Hilcorp Alaska LLC 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 3 Washed and Dried 6418’ – 9847’ 20’ Landon Ellison Hilcorp Alaska LLC 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 KBU 32-08 15 4 DRILLING DATA 4.1 Surveys Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 18.60 0.00 0.00 18.60 0.00 0.00 0.00 0.00 144.16 0.29 100.16 144.16 -0.06 0.31 0.17 0.23 207.35 0.65 112.65 207.35 -0.22 0.80 0.37 0.59 268.95 0.59 131.60 268.94 -0.57 1.36 0.48 0.35 332.85 1.01 121.33 332.84 -1.08 2.09 0.59 0.69 396.09 0.48 99.15 396.07 -1.41 2.83 0.83 0.94 454.74 1.12 70.98 454.72 -1.26 3.61 1.46 1.25 515.00 1.63 62.42 514.96 -0.67 4.93 2.78 0.91 576.59 2.27 42.10 576.51 0.64 6.52 4.82 1.51 638.75 3.72 41.96 638.59 3.05 8.69 8.07 2.33 700.00 4.74 39.13 699.67 6.49 11.62 12.58 1.70 761.59 6.36 43.52 760.97 10.94 15.58 18.54 2.72 822.70 9.08 41.50 821.52 17.01 21.10 26.74 4.47 887.85 12.56 39.34 885.50 26.34 29.00 38.96 5.38 949.48 15.83 38.67 945.24 38.09 38.50 54.06 5.31 1011.34 18.56 38.80 1004.33 52.35 49.95 72.32 4.41 1072.43 20.77 40.12 1061.85 68.21 63.02 92.85 3.69 1132.13 22.94 41.83 1117.26 84.98 77.60 115.07 3.79 1194.53 24.85 40.08 1174.31 104.07 94.16 140.34 3.26 1255.85 27.09 40.99 1229.44 124.47 111.61 167.19 3.71 1316.35 29.28 41.36 1282.76 145.98 130.43 195.76 3.63 1381.04 31.51 40.83 1338.55 170.65 151.94 228.48 3.47 1442.92 33.78 41.34 1390.66 195.80 173.87 261.86 3.70 1473.65 35.28 40.74 1415.97 208.94 185.31 279.27 5.01 1536.32 35.95 40.82 1466.92 236.57 209.15 315.76 1.07 1600.00 34.90 41.31 1518.81 264.40 233.39 352.67 1.71 1662.57 34.69 41.11 1570.19 291.26 256.92 388.37 0.38 1724.29 34.84 43.49 1620.90 317.29 280.60 423.56 2.21 1786.69 36.01 44.30 1671.74 343.35 305.68 459.70 2.02 1848.96 38.18 43.10 1721.41 370.51 331.62 497.24 3.67 KBU 32-08 16 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 1910.80 38.39 41.82 1769.95 398.77 357.48 535.55 1.33 1972.29 37.49 42.55 1818.45 426.79 382.86 573.35 1.64 2032.85 36.92 41.60 1866.68 453.97 407.40 609.97 1.34 2093.70 36.76 42.46 1915.38 481.07 431.83 646.45 0.89 2158.79 36.27 41.55 1967.69 509.84 457.75 685.18 1.12 2220.87 35.44 42.32 2018.01 536.90 482.05 721.54 1.52 2283.16 36.38 41.58 2068.46 564.07 506.47 758.08 1.66 2344.85 36.00 42.23 2118.25 591.18 530.79 794.50 0.88 2405.12 34.99 42.09 2167.32 617.12 554.28 829.49 1.68 2468.99 35.51 42.28 2219.48 644.43 579.04 866.36 0.83 2532.71 35.17 42.08 2271.45 671.74 603.79 903.21 0.56 2593.61 36.06 42.34 2320.96 698.01 627.61 938.68 1.48 2652.39 36.56 42.50 2368.33 723.71 651.09 973.48 0.87 2717.56 37.52 41.87 2420.35 752.80 677.45 1012.73 1.58 2779.57 38.06 41.44 2469.35 781.19 702.71 1050.73 0.97 2839.00 37.53 40.68 2516.31 808.65 726.63 1087.15 1.19 2904.92 37.18 40.47 2568.71 839.03 752.65 1127.14 0.57 2967.38 36.76 41.40 2618.62 867.40 777.25 1164.69 1.12 3027.31 36.19 41.42 2666.81 894.12 800.82 1200.32 0.95 3090.50 35.89 40.75 2717.90 922.15 825.25 1237.50 0.78 3151.46 35.67 41.04 2767.36 949.09 848.59 1273.13 0.49 3214.48 36.64 41.09 2818.24 977.12 873.01 1310.31 1.54 3276.58 36.97 42.04 2867.96 1004.95 897.69 1347.51 1.06 3338.74 36.76 41.45 2917.70 1032.78 922.52 1384.80 0.66 3400.35 36.50 42.14 2967.14 1060.18 947.02 1421.56 0.79 3462.99 36.34 41.55 3017.54 1087.89 971.83 1458.75 0.61 3524.98 36.13 41.88 3067.54 1115.24 996.21 1495.39 0.46 3587.67 35.79 42.38 3118.29 1142.54 1020.91 1532.20 0.72 3646.28 35.65 41.92 3165.87 1167.91 1043.87 1566.42 0.52 3709.50 35.19 42.27 3217.39 1195.10 1068.43 1603.06 0.80 3772.33 35.33 41.89 3268.69 1222.02 1092.74 1639.33 0.41 3831.39 35.27 41.73 3316.90 1247.46 1115.49 1673.46 0.19 3893.07 34.85 42.29 3367.38 1273.78 1139.20 1708.89 0.86 3956.31 34.45 42.17 3419.41 1300.41 1163.37 1744.84 0.64 4018.59 34.45 41.58 3470.77 1326.64 1186.89 1780.07 0.54 4080.26 34.24 41.44 3521.68 1352.69 1209.94 1814.87 0.36 4143.20 34.75 41.58 3573.56 1379.38 1233.57 1850.51 0.82 KBU 32-08 17 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 4203.29 34.61 42.05 3622.97 1404.87 1256.36 1884.70 0.50 4267.31 34.95 42.40 3675.55 1431.91 1280.91 1921.22 0.62 4324.50 36.05 42.73 3722.11 1456.37 1303.37 1954.43 1.95 4389.33 36.75 42.88 3774.29 1484.59 1329.51 1992.89 1.09 4450.44 36.94 42.89 3823.20 1511.44 1354.45 2029.53 0.31 4512.33 36.64 42.79 3872.76 1538.62 1379.65 2066.59 0.49 4573.05 37.17 41.90 3921.32 1565.57 1404.21 2103.05 1.24 4635.52 37.22 41.36 3971.08 1593.80 1429.30 2140.81 0.53 4698.10 37.00 41.35 4020.98 1622.14 1454.25 2178.57 0.35 4760.72 36.59 41.23 4071.13 1650.32 1479.00 2216.07 0.66 4822.25 37.30 41.74 4120.30 1678.02 1503.49 2253.05 1.26 4882.84 36.98 42.17 4168.60 1705.23 1527.95 2289.64 0.68 4942.42 36.68 42.21 4216.29 1731.69 1551.94 2325.35 0.51 5009.09 36.78 41.70 4269.73 1761.34 1578.59 2365.22 0.48 5071.06 37.03 40.98 4319.28 1789.28 1603.17 2402.43 0.81 5127.51 36.62 41.13 4364.47 1814.80 1625.39 2436.26 0.74 5195.04 37.03 40.75 4418.52 1845.37 1651.91 2476.73 0.69 5256.48 37.79 39.66 4467.33 1873.88 1676.01 2514.04 1.64 5318.82 38.21 38.96 4516.45 1903.58 1700.32 2552.39 0.97 5381.82 37.96 38.73 4566.04 1933.84 1724.69 2591.20 0.46 5436.80 37.72 38.90 4609.46 1960.12 1745.83 2624.88 0.48 5504.91 37.37 39.02 4663.46 1992.40 1771.93 2666.33 0.52 5565.43 36.96 39.72 4711.69 2020.66 1795.12 2702.86 0.97 5627.68 36.92 39.73 4761.44 2049.43 1819.03 2740.25 0.06 5687.48 36.11 41.25 4809.50 2076.50 1842.13 2775.82 2.03 5748.21 35.86 41.40 4858.64 2103.29 1865.69 2811.50 0.44 5808.99 35.74 41.64 4907.94 2129.91 1889.26 2847.05 0.30 5873.20 35.61 42.01 4960.10 2157.82 1914.23 2884.50 0.39 5933.51 35.48 41.84 5009.17 2183.91 1937.65 2919.56 0.29 5998.46 35.49 41.89 5062.06 2211.99 1962.81 2957.26 0.07 6059.98 36.03 42.31 5111.98 2238.67 1986.91 2993.21 0.96 6123.76 36.61 43.12 5163.37 2266.42 2012.54 3030.98 1.18 6188.12 36.40 43.32 5215.10 2294.32 2038.75 3069.26 0.38 6248.77 36.29 43.35 5263.95 2320.47 2063.42 3105.19 0.18 6299.81 35.97 43.38 5305.18 2342.35 2084.09 3135.27 0.63 6371.94 35.71 43.36 5363.65 2373.05 2113.09 3177.49 0.36 6418.40 35.49 43.09 5401.43 2392.75 2131.61 3204.53 0.58 KBU 32-08 18 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 6482.81 35.69 42.98 5453.81 2420.15 2157.19 3242.00 0.33 6542.86 35.70 42.81 5502.58 2445.82 2181.04 3277.03 0.17 6605.48 35.55 41.74 5553.48 2472.81 2205.57 3313.51 1.02 6668.96 35.89 41.94 5605.01 2500.42 2230.30 3350.57 0.57 6729.79 36.06 40.90 5654.24 2527.21 2253.94 3386.30 1.04 6791.46 36.51 40.76 5703.95 2554.83 2277.80 3422.79 0.74 6853.24 36.80 41.59 5753.52 2582.59 2302.08 3459.67 0.93 6915.28 37.08 41.33 5803.10 2610.53 2326.77 3496.95 0.52 6977.29 36.89 42.05 5852.64 2638.39 2351.58 3534.26 0.76 7039.01 36.93 42.39 5901.99 2665.84 2376.48 3571.32 0.34 7101.70 37.03 42.15 5952.07 3693.74 2401.85 3609.03 0.28 7164.62 37.06 42.11 6002.29 2721.86 2427.28 3646.94 0.06 7227.09 37.01 41.58 6052.16 2749.89 2452.38 3684.56 0.52 7287.68 37.03 41.27 6100.53 2777.24 2476.51 3721.04 0.31 7350.19 36.13 41.89 6150.73 2805.11 2501.24 3758.29 1.56 7413.14 36.01 41.72 6201.61 2832.73 2525.94 3795.36 0.25 7473.97 35.9 41.73 6250.85 2859.39 2549.71 3831.07 0.18 7536.38 35.8 41.68 6301.44 2886.68 2574.03 3867.63 0.17 7599.17 35.74 41.63 6352.38 2914.1 2598.43 3904.33 0.11 7660.54 35.82 42.32 6402.17 2940.78 2622.42 3940.21 0.67 7723.31 35.66 42.37 6453.12 2967.88 2647.12 3976.87 0.26 7784.60 35.35 42.39 6503.01 2994.17 2671.11 4012.47 0.51 7846.95 35.26 41.78 6553.90 3020.91 2695.26 4048.50 0.58 7909.05 35.34 41.84 6604.58 3047.66 2719.19 4084.38 0.14 7970.20 35.34 41.65 6654.46 3074.05 2742.74 4119.75 0.18 8029.41 35.36 41.67 6702.76 3099.64 2765.51 4154.01 0.04 8094.41 35.38 41.77 6755.76 3127.73 2790.55 4191.64 0.09 8155.41 35.64 41.83 6805.41 3154.14 2814.16 4227.07 0.43 8220.00 35.82 41.97 6857.85 3182.22 2839.35 4264.79 0.31 8280.11 35.62 42.07 6906.65 3208.29 2862.84 4299.88 0.35 8341.33 35.45 42.12 6956.47 3234.69 2886.70 4335.46 0.28 8401.67 36.37 43.19 7005.34 3260.71 2910.68 4370.85 1.85 8466.70 37.35 42.69 7057.37 3289.27 2937.25 4409.85 1.58 8528.66 37.04 42.13 7106.73 3316.93 2962.51 4447.30 0.74 8590.80 37.53 42.31 7156.17 3344.80 2987.81 4484.94 0.81 8652.33 37.31 41.77 7205.03 3372.57 3012.85 4522.33 0.64 8714.17 36.93 41.45 7254.34 3400.47 3037.63 4559.65 0.69 KBU 32-08 19 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 8776.36 36.58 41.31 7304.17 3428.40 3062.23 4596.86 0.58 8838.67 36.91 41.30 7354.10 3456.40 3086.83 4634.14 0.53 8899.88 36.68 40.80 7403.11 3484.05 3110.91 4670.80 0.62 8962.50 36.48 41.29 7453.40 3512.19 3135.42 4708.11 0.57 9023.77 36.31 41.03 7502.72 3539.56 3159.34 4744.46 0.37 9085.72 36.13 40.76 7552.70 3567.23 3183.31 4781.06 0.39 9149.28 35.80 40.98 7604.14 3595.46 3207.73 4818.39 0.56 9210.56 35.68 40.87 7653.88 3622.50 3231.18 4854.18 0.22 9272.61 35.56 40.61 7704.32 3649.89 3254.77 4890.31 0.31 9333.16 35.31 40.76 7753.66 3676.51 3277.65 4925.41 0.44 9397.25 34.79 40.58 7806.12 3704.42 3301.64 4962.21 0.83 9459.78 34.34 40.34 7857.62 3731.41 3324.66 4997.67 0.75 9521.92 33.70 40.32 7909.12 3757.92 3347.16 5032.43 1.03 9583.92 32.94 40.00 7960.93 3783.95 3369.12 5066.47 1.26 9645.20 32.48 40.02 8012.49 3809.31 3390.41 5099.57 0.75 9707.85 32.41 40.06 8065.36 3835.04 3412.04 5133.17 0.12 9769.67 32.23 40.07 8117.60 3860.34 3433.31 5166.20 0.29 9806.46 31.89 39.96 8148.78 3875.29 3445.87 5185.72 0.94 **9847.00 31.89 39.96 8183.20 3891.71 3459.62 5207.13 0.00 **Projected KBU 32-08 20 4.2 Bit Record BIT NO. SIZE TYPE S/N JETS/ TFA IN OUT FT HRS AVE ROP Ft/HR CONDITION 4 6.75” QH1R 12301040 3X14 6418’ 6418’ 0 0 0 CLEAN OUT CSG 5 6.75” EM65D 12396253 6X10 6418’ 9847’ 3429’ 34.42 99.6 1-1-WT-G-X-I-NO -TD KBU 32-08 21 4.3 Mud Record Contractor: M.I. Swaco Date Depth (MD / TVD) MW (ppg) VIS (s/qt) PV YP Gels FL (cc) FC Sols (%) O/W Ratio Sd (%) MBT pH Cl (ml/l) Ca (ml/l) KLA-SHIELD 3/4/2014 6418/5401 9.8 72 18 21 6/8/10 7 1/1 9 2/89 .25 7.5 10.0 28000 400 3/5/2014 6418/5401 9.7 57 11 11 2/4/6 8 1/ 8 /92 .1 9.8 80000 120 3/6/2014 6802/5420 9.8 55 12 15 5/5/6 5.2 1/1 8 /92 1 9.6 79000 120 3/7/2014 8136/6790 9.8 60 19 27 11/22/28 5.2 1/1 8 1/91 .1 2 9.3 76000 120 3/8/2014 9120/7592 9.9 58 18 29 9/21/30 4.8 1/1 8 2/91 .25 3 9.1 75000 140 3/9/2014 9847/8183 10.3 60 19 29 10/22/31 4.8 1/1 9 2/89 .25 3 9.0 83000 140 3/10/2014 9847/8183 10.5 63 20 29 11/23/30 5 1/1 10 2/88 .25 3 8.8 85000 140 3/11/2014 9847/8183 10.5 69 21 28 12/24/32 4.8 1/1 10 2/88 .1 4 8.8 85000 140 3/12/2014 9847/8183 10.5 63 22 23 9/19/27 4.8 1/1 10 2/88 .1 4 8.7 86000 120 3/13/2014 9847/8183 10.7 65 27 30 9/22/30 3.8 1/1 12 2/86 .1 4 8.9 88000 120 3/14/2014 9847/8183 10.7 69 26 31 9/21/28 3.6 1/1 12 2/86 .1 4 8.8 87000 120 Abbreviations: MW = Mud Weight VIS = Funnel Viscosity PV = Plastic Viscosity YP = Yield Point Gels = Gel Strength FL = Water or Filtrate Loss FC = Filter Cake O/W = Oil to Water ratio Sols = Solids Sd = Sand content MBT = Methylene Blue Alk, Pm = Alkalinity, Mud pH = Acidity Cl = Chlorides Ca = Hardness Calcium nr = Not Recorded KBU 32-08 22 4.4 Drilling Progress Chart DAYS VERSUS DEPTH 6000 6500 7000 7500 8000 8500 9000 9500 10000 3/4/14 3/5/14 3/6/14 3/7/14 3/8/14 3/9/14 3/10/14 3/11/14 3/12/14 3/13/14 3/14/14 3/15/14 3/16/14 DE P T H ( F T ) 6-3/4"Hole KBU 32-08 KBU 32-08 23 5 DAILY DRILLING REPORTS Hilcorp Alaska, LLC Kenai Beluga Uit DAILY WELLSITE REPORT KBU 32-08 REPORT FOR Bob Farrell/ Doug Yessak DATE March 4, 2014 DEPTH 6418 PRESENT OPERATION Tripping in Hole TIME 23:59 YESTERDAY 6418 24 HOUR FOOTAGE 0 CASING INFORMATION 7 5/8" @ 6400' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4 6.75 HDBS QH1R 12301040 0.4510 6418' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 6418/5401 MW 9.8 VIS 48 PV 15 YP 20 Gels 5/9/13 FL 6 CL- 30000 FC 1/1 SOL 9 SD 0.25 OIL 2/89 MBT 7.5 pH 8.9 Ca+ 320 Alk MWD SUMMARY INTERVAL TO TOOLS NONE GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH N/A ETHANE (C-2) @ @ CONNECTION GAS AVG N/A PROPANE (C-3) @ @ CONNECTION GAS CURRENT N/A BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG N/A PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY NONE PRESENT LITHOLOGY -- DAILY ACTIVITY SUMMARY RUN IN HOLE PICKING UP SINGLES AND PREPARE TO DRILL AHEAD. CANRIG PERSONNEL ON BOARD 4= D. New, R. Winkleman, D. Thibodeax, B. Calo DAILY COST $4987.00 REPORT BY Donna New Hilcorp Alaska, LLC Kenai Beluga Unit DAILY WELLSITE REPORT KBU 32-08 REPORT FOR Bob Farrell/ Doug Yessak DATE March 5, 2014 DEPTH 6438 PRESENT OPERATION Running CBL TIME 23:59 YESTERDAY 6418 24 HOUR FOOTAGE 20 CASING INFORMATION 7 5/8" @ 6405' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0.0 @ 6438 0 @ 6438 0.0 FT/HR SURFACE TORQUE 0 @ 6438 0 @ 6438 0.0 FT-LBS WEIGHT ON BIT 0 @ 6438 0 @ 6438 0.0 KLBS ROTARY RPM 0 @ 6438 0 @ 6438 0.0 RPM PUMP PRESSURE 0 @ 6438 0 @ 6438 0.0 PSI DRILLING MUD REPORT DEPTH 6418/5401 MW 9.9 VIS 56 PV 18 YP 21 Gels 6/8/10 FL 8 CL- 30000 FC 1/na SOL 9 SD 0.25 OIL 2/89 MBT 7.5 pH 10.0 Ca+ 400 Alk 3 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 5 @ 6435 2 @ 6429 3.9 TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 357 @ 6438 357 @ 6438 17.9 CONNECTION GAS HIGH N/A ETHANE (C-2) 37 @ 6438 37 @ 6438 1.9 CONNECTION GAS AVG N/A PROPANE (C-3) 0 @ 6438 0 @ 6438 0.0 CONNECTION GAS CURRENT N/A BUTANE (C-4) 0 @ 6438 0 @ 6438 0.0 CURRENT BACKGROUND/AVG N/A PENTANE (C-5) 0 @ 6438 0 @ 6438 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga PRESENT LITHOLOGY @6438' = Cement Contamination 50%, Coal 20%, Carbonaceous Shale 20%,Tuffaceous siltstone10%. DAILY ACTIVITY SUMMARY Trip to bottom and drill out; drill 20' new formation (estimated- will confirm and adjust). Perform FIT and trip to surface, lay down BHA and rig up wireline for CBL. Currently running CBL. CANRIG PERSONNEL ON BOARD 4= D. New, R. Winkleman, D. Thibodeax, B. Calo DAILY COST $2877.00 REPORT BY Donna New Hilcorp Alaska, LLC Kenai Beluga Unit DAILY WELLSITE REPORT KBU 32-08 REPORT FOR Mike Leslie /Doug Yessek DATE Mar 06, 2014 DEPTH 6803 PRESENT OPERATION Drilling Ahead TIME 23:59 YESTERDAY 6438 24 HOUR FOOTAGE 365 CASING INFORMATION 7 5/8'@6344' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6542 35.70 42.81 5502.58 6605.48 35.55 41.74 5553.48 6668.96 35.89 41.94 5605.01 6729.79 36.06 40.90 5654.24 6791.46 36.51 40.76 5703.95 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 5 6.75 HDBS EM65D 12396253 6X10 6418 (6803) 385 4.3 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 370.1 @ 6708 2.5 @ 6710 112.8 59.22 FT/HR SURFACE TORQUE 12027 @ 6666 114 @ 6724 9139.0 0.00 FT-LBS WEIGHT ON BIT 96 @ 6522 3 @ 6523 9.1 16.13 KLBS ROTARY RPM 65 @ 6733 1 @ 6724 47.3 0.00 RPM PUMP PRESSURE 2251 @ 6638 1842 @ 6522 2032.9 2058.32 PSI DRILLING MUD REPORT DEPTH 6802/5420 MW 9.8 VIS 55 PV 12 YP 15 Gels 5/5/6 FL 5.2 CL- 79000 FC 1/1 SOL 8 SD -- OIL -/921 MBT 1 pH 9.6 Ca+ 120 Alk MWD SUMMARY INTERVAL 6418 TO CURRENT TOOLS LWD, MWD and directional GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 135 @ 6763 9 @ 6646 46.6 TRIP GAS 32 CUTTING GAS @ @ WIPER GAS -- CHROMATOGRAPHY (ppm) SURVEY -- METHANE (C-1) 26305 @ 6763 1829 @ 6710 9269.7 CONNECTION GAS HIGH 120 ETHANE (C-2) 165 @ 6568 0 @ 6489 23.9 CONNECTION GAS AVG 96 PROPANE (C-3) 0 @ 6803 0 @ 6803 0.0 CONNECTION GAS CURRENT 120 BUTANE (C-4) 0 @ 6803 0 @ 6803 0.0 CURRENT BACKGROUND/AVG 32 / 46 PENTANE (C-5) 0 @ 6803 0 @ 6803 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga PRESENT LITHOLOGY 50% TUFFACEOUS SILTSTONE; 40% TUFFACEOUS SANDSTONE; 10% CARBONACEOUS SHALE DAILY ACTIVITY SUMMARY Pick up drilling assembly and trip to bottom, perform new FIT, drill ahead. CANRIG PERSONNEL ON BOARD D. New, R. Winkleman, D. Thibodeax, B. Calo DAILY COST $2877.00 REPORT BY Donna New Hilcorp Alaska, LLC Kenai Beluga Unit DAILY WELLSITE REPORT KBU 32-08 REPORT FOR Mike Leslie /Doug Yessek DATE Mar 07, 2014 DEPTH 8137.00000 PRESENT OPERATION Drilling Ahead TIME 23:59 YESTERDAY 6803.00000 24 HOUR FOOTAGE 1334 CASING INFORMATION 7 5/8'@6344' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7846.95 35.26 41.78 6553.90 7909.05 35.34 41.84 6604.58 7970.20 35.34 41.65 6654.46 8029.41 35.36 41.67 6702.76 8094.41 35.38 41.77 6755.76 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 5 6.75 HDBS EM65D 12396253 6X10 6418 8137 1699 16.4 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 457.6 @ 7582 0.5 @ 7823 127.2 46.69 FT/HR SURFACE TORQUE 11777 @ 7744 2006 @ 7904 9870.3 10504.14 FT-LBS WEIGHT ON BIT 103 @ 7823 2 @ 7824 8.7 5.81 KLBS ROTARY RPM 67 @ 7918 3 @ 7900 58.8 62.47 RPM PUMP PRESSURE 2677 @ 8016 1923 @ 6832 2338.1 2422.02 PSI DRILLING MUD REPORT DEPTH 8138/6790 MW 9.8 VIS 60 PV 19 YP 27 Gels 11/22/28 FL 5.2 CL- 76000 FC 1/1 SOL 8 SD 0.1 OIL 1/91 MBT 2 pH 9.3 Ca+ 120 Alk 1.6 MWD SUMMARY INTERVAL 6418 TO CURRENT TOOLS LWD, MWD and directional GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 810 @ 7869 1 @ 7493 193.2 TRIP GAS 20 CUTTING GAS @ @ WIPER GAS -- CHROMATOGRAPHY (ppm) SURVEY -- METHANE (C-1) 134843 @ 8115 339 @ 7493 26599.9 CONNECTION GAS HIGH 0 ETHANE (C-2) 654 @ 7730 0 @ 6883 55.2 CONNECTION GAS AVG 9 PROPANE (C-3) 0 @ 8137 0 @ 8137 0.0 CONNECTION GAS CURRENT 0 BUTANE (C-4) 0 @ 8137 0 @ 8137 0.0 CURRENT BACKGROUND/AVG 120 /193 PENTANE (C-5) 0 @ 8137 0 @ 8137 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga PRESENT LITHOLOGY 50% TUFFACEOUS SANDSTONE; 30% TUFFACEOUS SILTSTONE; 20% CARBONACEOUS SHALE DAILY ACTIVITY SUMMARY Drill ahead alternately sliding an rotating as needed to maintain planned trajectory toward target for TD. Max Gasses past 24 hours: 6858'-253u/ 6945'-513u / 6988'- 268u / 7059'- 204u/ 7108'-183u / 7178' -177u / 7251' -516u / 7354' - 165u / 7411' 150u / 7449'- 164u / 7550'-265u / 7607'-425u / 7669'-310u/ 7774'- 225u / 7870'- 809u / 7920' -386u / 7976'- 354u/ 8084' - 554/ CANRIG PERSONNEL ON BOARD 4 = D. New, R. Winkleman, D. Thibodeax, B.Calo DAILY COST $2877.00 REPORT BY Donna New Hilcorp Alaska, LLC Kenai Beluga Unit DAILY WELLSITE REPORT KBU 32-08 REPORT FOR Mike Leslie /Doug Yessek DATE Mar 08, 2014 DEPTH 9123 PRESENT OPERATION Drilling Ahead TIME 23:59 YESTERDAY 8137 24 HOUR FOOTAGE 986 CASING INFORMATION 7 5/8'@6344' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8714.17 36.93 41.45 7254.34 8776.36 36.58 41.31 7304.17 8838.67 36.91 41.30 7354.10 8899.88 36.68 40.80 7403.11 8962.50 36.48 41.29 7453.40 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 5 6.75 HDBS EM65D 12396253 6X10 6418 9123 2705 26.9 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 469.9 @ 8632 1.6 @ 8334 118.0 49.33 FT/HR SURFACE TORQUE 11529 @ 8417 769 @ 8210 8868.3 11094.95 FT-LBS WEIGHT ON BIT 125 @ 8941 0 @ 8391 9.3 7.12 KLBS ROTARY RPM 65 @ 8171 0 @ 8346 51.5 60.06 RPM PUMP PRESSURE 2802 @ 9023 2192 @ 8196 2520.8 2577.27 PSI DRILLING MUD REPORT DEPTH 9120/7592 MW 9.9 VIS 58 PV 18 YP 29 Gels 9/21/30 FL 4.8 CL- 75000 FC 1/1 SOL 8.0 SD 0.25 OIL 2/91 MBT 3 pH 9.1 Ca+ 140 Alk 1.4 MWD SUMMARY INTERVAL 6418 TO CURRENT TOOLS LWD, MWD and Directional GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1515 @ 8383 2 @ 8419 337.6 TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 300753 @ 8383 599 @ 8419 65629.1 CONNECTION GAS HIGH 1574 ETHANE (C-2) 5 @ 8649 0 @ 8630 0.1 CONNECTION GAS AVG 205 PROPANE (C-3) 0 @ 9123 0 @ 9123 0.0 CONNECTION GAS CURRENT 1554 BUTANE (C-4) 0 @ 9123 0 @ 9123 0.0 CURRENT BACKGROUND/AVG 380 / 337 PENTANE (C-5) 0 @ 9123 0 @ 9123 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TYONEK PRESENT LITHOLOGY Tuffaceous sandstone 80% ad tuffaceous siltstone 20% with trace carbonaceous shale DAILY ACTIVITY SUMMARY Drilled ahead to 8506', short trip to 7463'- many tight spots nd multile 30K over pulls, reamed through it , tripped back to bottom with no problems, resumed drilling and currently drilling ahead. Max Gasses 8286'-1304u//8361'-1406u//8383'-1515u // 8413' 291u // 8441'-351u // 8499'-423u// 8540'-481u // 8606'-728' // 8683'- 511u // 8720'-300u // 8742'- 315u // 8798' 456u 8834'- 577u // 8902' - 419u // 8970' - 380u // 9065' -597 u // --Max Connection gas 1554u at 9064' CANRIG PERSONNEL ON BOARD 4 = D. New, R. Winkleman, D. Thibodeax, B.Calo DAILY COST $2877.00 REPORT BY Donna New Hilcorp Alaska, LLC Kenai Beluga Unit DAILY WELLSITE REPORT KBU 32-08 REPORT FOR Mike Leslie /Doug Yessek DATE Mar 09, 2014 DEPTH 9847 PRESENT OPERATION Circulating Bottoms Up TIME 23:59 YESTERDAY 9123 24 HOUR FOOTAGE 724 CASING INFORMATION 7 5/8'@6348' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9645.20 32.48 40.02 8012.49 9707.85 32.41 40.06 8065.36 9769.67 32.23 40.07 8117.60 9806.46 31.89 39.96 8148.78 9847.00 31.89 39.96 8183.20 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 5 6.75 HDBS EM65D 12396253 6X10 6418 9847 3429' 34.4 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 425.5 @ 9578 2.5 @ 9719 113.0 109.54 FT/HR SURFACE TORQUE 12850 @ 9415 10219 @ 9561 11265.5 11301.94 FT-LBS WEIGHT ON BIT 126 @ 9561 3 @ 9812 9.7 8.34 KLBS ROTARY RPM 63 @ 9375 58 @ 9181 60.5 61.15 RPM PUMP PRESSURE 2874 @ 9830 2234 @ 9339 2646.9 2734.06 PSI DRILLING MUD REPORT DEPTH 9847/8184 MW 10.3 VIS 60 PV 19 YP 29 Gels 10/22/31 FL 4.8 CL- 83000 FC 1/1 SOL 9 SD 0.25 OIL 2/89 MBT 3 pH 9.0 Ca+ 140 Alk 1.4 MWD SUMMARY INTERVAL 6418' TO 9847' TOOLS LWD, MWD and Directional GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1223 @ 9622 49 @ 9753.00000 283.2 TRIP GAS -- CUTTING GAS 0 @ 9847 0 @ 9847.00000 0.0 WIPER GAS 2832 CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 248556 @ 9622 9567 @ 9753 56545.2 CONNECTION GAS HIGH 1223 ETHANE (C-2) 1361 @ 9571 0 @ 9720 141.4 CONNECTION GAS AVG 156 PROPANE (C-3) 61 @ 9571 0 @ 9700 8.9 CONNECTION GAS CURRENT 0 BUTANE (C-4) 7 @ 9796 0 @ 9829 0.4 CURRENT BACKGROUND/AVG 494 / 283 PENTANE (C-5) 0 @ 9847 0 @ 9847 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek PRESENT LITHOLOGY @ 9847 (TD) = tuffaceous sandstone 50%; coal 40%; and carbonaceous shale 10%, DAILY ACTIVITY SUMMARY Drilled ahead to TD @ 9374', pull off bottom and circulate and condition mud. Decision made to drill on with new TD set at approximately 9850.' Completed short trip and tripped back to bottom and drilled ahead to new TD at 9847' currently circulating andconditioning for trip out to run logs. connectiona gasses 9621' - 1223u and 9684' - 341u. Wiper gas was 2832u @ 9374'; Max gasses 9140'- 770u // 9207'-789u // 9280'- 632u // 9300' - 495u // 9331'-330u // 9368' - 774u // 9570'- 654u // 9598'- 602u // 9707' - 173u // 9796' - 631u // 9847' first bottoms up 394u,// multiple high gasses as we circulatd condition with the highest ~630 units and abundant readings in the 400u to 500u range. CANRIG PERSONNEL ON BOARD D. New, R. Winkleman, D. Thibodeax, B.Calo DAILY COST $2877.00 REPORT BY Donna New Hilcorp Alaska, LLC Kenai Beluga Unit DAILY WELLSITE REPORT KBU 32-08 REPORT FOR Mike Leslie/Doug Yessek DATE Mar 10, 2014 DEPTH 9847. PRESENT OPERATION Circulate B/U TIME 23:59 YESTERDAY 9847 24 HOUR FOOTAGE 0 CASING INFORMATION 7 5?8"@6348' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9847' 31.89 39.96 8012.49 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 5 6.75 HDBS EM65D 12396253 6x10 6418 9847 3429' 34.4 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 9847 MW 10.5 VIS 63 PV 20 YP 29 Gels 11/23/30 FL 5 CL- 85000 FC 1 SOL 10 SD .25 OIL 2/88 MBT 3 pH 8.8 Ca+ 140 Alk .7 MWD SUMMARY INTERVAL 6418' TO 9847' TOOLS LWD MWDand directional GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS N/A CUTTING GAS @ @ WIPER GAS 2100 CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH N/A ETHANE (C-2) @ @ CONNECTION GAS AVG N/A PROPANE (C-3) @ @ CONNECTION GAS CURRENT N/A BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 74 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek PRESENT LITHOLOGY @ 9847' (TD)= tuffaceous sandstone 50%;coal 40% and carbonaceous shale 10% DAILY ACTIVITY SUMMARY circulated condition mud cirulated b/u pulled up 2 stands off botom cir raised MW to 10.3 POOH pumping out to 8000' cir B/U max gas 600u TOOH to 6320' cut slip drill line TIH to 9847' circulated condition mud Max gas 2100u weight up mud to 10.5 pulled 2 stnds cir B/U POOH to 7770' cir B/U max gas 735u CANRIG PERSONNEL ON BOARD D.New,R.Winkleman,D.Thibodeaux,B.Calo DAILY COST $2877.00 REPORT BY Don Thibodeaux Hilcorp Alaska, LLC Kenai Beluga Unit DAILY WELLSITE REPORT KBU 32-08 REPORT FOR Mike Leslie/Doug Yessek DATE Mar 11, 2014 DEPTH 9847 PRESENT OPERATION Running Wireline Logs TIME 23:59:52 YESTERDAY 9847 24 HOUR FOOTAGE 0 CASING INFORMATION 7 5/8"@6348' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9847 31.89 39.96 8012.49 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 5 6.75 HDBSEM65D 12396253 6x10 6418 9847 3429' 34.4 1-1WT-G DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 9847 MW 10.5 VIS 69 PV 21 YP 28 Gels 12/24/32 FL 4.8 CL- 85000 FC 1 SOL 10 SD .1 OIL 2/88 MBT 4 pH 8.8 Ca+ 140 Alk .8 MWD SUMMARY INTERVAL 6418 TO 9847' TOOLS LWD MWD and Directional GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH N/A ETHANE (C-2) @ @ CONNECTION GAS AVG N/A PROPANE (C-3) @ @ CONNECTION GAS CURRENT N/A BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek PRESENT LITHOLOGY @ 9847"(TD)=tuffaceous sandstone 50%,coal 40%, carbonaceous shale 10% DAILY ACTIVITY SUMMARY POOH to6500' circulated B/U max gas 756u finished POOH to BHA layed down MWD tools and BHA rigged up wireline tools ran in hole logging hole with wireline XPT logs at report time CANRIG PERSONNEL ON BOARD R.Winkleman,D.Thibodeaux,T.Harris,K.Wallander DAILY COST $2877.00 REPORT BY Don Thibodeaux Hilcorp Alaska, LLC Kenai Beluga Unit DAILY WELLSITE REPORT KBU 32-08 REPORT FOR Mike Leslie/Doug Yessek DATE Mar 12, 2014 DEPTH 9847 PRESENT OPERATION Circulating B/U@ 9669' TIME 23:59:52 YESTERDAY 9847 24 HOUR FOOTAGE 0 CASING INFORMATION 7 5/8"@6348' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9847 31.89 39.96 8012.49 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 5 6.75 HDBSEM65D 12396253 6x10 6418 9847 3429' 34.4 1-1WT-G RRB#5 6.75 HDBSEM65D 12396253 6x10 9847 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 9847 MW 10.5 VIS 63 PV 22 YP 23 Gels 9/19/27 FL 4.8 CL- 86000 FC 1 SOL 10 SD .1 OIL 2/88 MBT 4 pH 8.7 Ca+ 120 Alk .7 MWD SUMMARY INTERVAL 6418 TO 9847' TOOLS LWD MWD and Directional GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH N/A ETHANE (C-2) @ @ CONNECTION GAS AVG N/A PROPANE (C-3) @ @ CONNECTION GAS CURRENT N/A BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 1005 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek PRESENT LITHOLOGY @ 9847"(TD)=tuffaceous sandstone 50%,coal 40%, carbonaceous shale 10% DAILY ACTIVITY SUMMARY Finish running wireline logs layed down directional tools P/U new BHA TIH to 1978' cir B/U max gas 1975u TIH to 4150' cir B/U max gas 2680u TIH to 6333' cir B/U Max gas 2768u TIH to 7882' cir B/U max gas 2696u TIH to 9669 cir B/U raise MW to 10.7 max gas 2758u CANRIG PERSONNEL ON BOARD R.Winkleman,D.Thibodeaux, DAILY COST $2877.00 REPORT BY Don Thibodeaux Hilcorp Alaska, LLC Kenai Beluga Unit DAILY WELLSITE REPORT KBU 32-08 REPORT FOR Mike Leslie/James Lott DATE Mar 13, 2014 DEPTH 9847 PRESENT OPERATION POOH laying down DP@ 2097' TIME 23:59:52 YESTERDAY 9847 24 HOUR FOOTAGE 0 CASING INFORMATION 7 5/8"@6348' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9847 31.89 39.96 8012.49 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 5 6.75 HDBSEM65D 12396253 6x10 6418 9847 3429' 34.4 1-1WT-G RRB#5 6.75 HDBSEM65D 12396253 6x10 9847 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 9847 MW 10.7 VIS 65 PV 27 YP 30 Gels 9/22/30 FL 3.8 CL- 88000 FC 1 SOL 12 SD .1 OIL 2/86 MBT 4 pH 8.9 Ca+ 120 Alk .9 MWD SUMMARY INTERVAL 6418 TO 9847' TOOLS LWD MWD and Directional GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 2570 CUTTING GAS @ @ WIPER GAS 1380 CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH N/A ETHANE (C-2) @ @ CONNECTION GAS AVG N/A PROPANE (C-3) @ @ CONNECTION GAS CURRENT N/A BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek PRESENT LITHOLOGY @ 9847"(TD)=tuffaceous sandstone 50%,coal 40%, carbonaceous shale 10% DAILY ACTIVITY SUMMARY Washed ream from 9669' to 9847' backream back to 9669' cir B/U max gas 2570u short trip 9682 to 9061' TIH to 9682' cir B/U max gas 1380u POOH backreaming to 6500' max gas 498u while pumping cir B/U max gas 12u slug pipe POOH laying down drill pipe at present depth 2097' CANRIG PERSONNEL ON BOARD R.Winkleman,D.Thibodeaux DAILY COST $2048.50, REPORT BY Don Thibodeaux Hilcorp Alaska, LLC Kenai Beluga Unit DAILY WELLSITE REPORT KBU 32-08 REPORT FOR Mike Leslie/James Lott DATE Mar 14, 2014 DEPTH 9847 PRESENT OPERATION TIH with 5" Production CSG @5177' TIME 23:59:52 YESTERDAY 9847 24 HOUR FOOTAGE 0 CASING INFORMATION 7 5/8"@6348' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9847 31.89 39.96 8012.49 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 5 6.75 HDBSEM65D 12396253 6x10 6418 9847 3429' 34.4 1-1WT-G RRB#5 6.75 HDBSEM65D 12396253 6x10 9847 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 9847 MW 10.7 VIS 69 PV 26 YP 31 Gels 9/21/28 FL 3.6 CL- 87000 FC 1 SOL 12 SD .1 OIL 2/86 MBT 4 pH 8.8 Ca+ 120 Alk .8 MWD SUMMARY INTERVAL 6418 TO 9847' TOOLS LWD MWD and Directional GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH N/A ETHANE (C-2) @ @ CONNECTION GAS AVG N/A PROPANE (C-3) @ @ CONNECTION GAS CURRENT N/A BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 46 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek PRESENT LITHOLOGY @ 9847"(TD)=tuffaceous sandstone 50%,coal 40%, carbonaceous shale 10% DAILY ACTIVITY SUMMARY Continue laying down drill pipe from 2097' to 688' TIH with rest of drill pipe to 4040' cir B/U max gas 608u finished POOH laying down DP and BHA pickup CRT tool casing equipment made up Shoe track TIH with 5" production CSG to 1839' cir high gas out max 615u TIH to 3947' cir high gas out max gas 1700u TIH at report time@ 5177' CANRIG PERSONNEL ON BOARD R.Winkleman,D.Thibodeaux DAILY COST $2048.50, REPORT BY Don Thibodeaux