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Home My WebLink About213-1071. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 15750 N/A Casing Collapse Structural Conductor 2260 Surface 4760 Intermediate 4790 Production Liner 6390 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Production & Wells Engineer Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 7/6/2024 15,740'4,703' 2-7/8" & 3-1/2" 11,037' N/A Perforation Depth MD (ft): 12,928' 14786'-15386' 5-1/2" 11952'-12366' Perforation Depth TVD (ft): 200' 36" 13-3/8" 9-5/8" 3,190' 7-5/8"1,638' 11,500' MD 6890 5020 6870 2,940' 10,065' 10,862' 3,190' 11,500' Length Size Proposed Pools: 200' 200' L80 & L80 TVD Burst 10,950'/9,528' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 381203, ADL 374002 213-107 188 W. Northern Lights Blvd, Ste 510 Anchorage, AK 99503 50-733-20513-02-00 Cook Inlet Energy, LLC Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 7740 Tubing Grade: 12661 15653 12579 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Stan Porhola sporhola@glacieroil.com 907-331-8228 Redoubt Unit 5B Redoubt Shoal, Undefined OilRedoubt Shoal N/A2,764 Tubing MD (ft): N/A m n P s 2 6 5 6 t t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 7:55 am, Jun 20, 2024 Stan Porhola Digitally signed by Stan Porhola DN: cn=Stan Porhola, o, ou=Glacier Oil & Gas, email=sporhola@glacieroil.com, c=US Date: 2024.06.19 16:36:47 -08'00' 324-359 CDW 06/20/2024 BJM 6/26/24 DSR-6/21/24A.Dewhurst 24JUN24 10-404 *&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.06.27 11:58:46 -08'00'06/27/24 RBDMS JSB 062824 1 June 19th, 2024 Jessie Chmielowski, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry Application Cook Inlet Energy, LLC:Redoubt Unit 5B API: 50-733-20513-02-00 Dear Commissioner, Cook Inlet Energy, LLC, hereby submits a Sundry Application for RU-05B, PTD: 213-107, requesting to perform an acid stimulation of the perforations below the producing ESP. If you have any questions, please contact me at (907) 433-3820. Sincerely, Stan Porhola Production & Wells Engineer Cook Inlet Energy, LLC (a Glacier Oil & Gas owned company) 188 W Northern Lights Blvd, Suite 510 Anchorage, AK 99503 Stan Porhola Digitally signed by Stan Porhola DN: cn=Stan Porhola, o, ou=Glacier Oil & Gas, email=sporhola@glacieroil.com, c=US Date: 2024.06.19 16:37:40 -08'00' 2 WELL NAME – RU-05B Requirements of 20 AAC 25.005 (f) Well Summary Current Status: ESP Producing Oil Well Scope of Work: x Perform HCL acid stimulation of perforations. General Well Information: Reservoir Pressure / TVD: 0.32 psi/ft 4,000 psi @ 15,386’ MD (12,366’ TVD) MASP: Reservoir Pressure – (Gas Gradient X TVD) (0.32 psi/ft X 12,366’ TVD) – (0.1 psi/ft X 12,366’) = 4,000 psi – 1236 psi = 2,764 psi Wellhead Type/Pressure Rating: 13 5/8” 5M Wellhead - 3 1/2” 5M tree BOP Configuration: Well Tree (5M Rated) Well Type: Oil Well (ESP Completion) Estimated Start Date: July 6, 2024 Waivers Requested: None Well Status: No-Flow Test Witnessed 10/20/2023 Stimulation Procedure Pre-Stimulation 1. Conduct pre-job safety meeting with all personnel on location. o Review upcoming work and discuss safety first. o Review SDS sheets for HCL acid and mutual solvent. 2. Stage ISO containers of 15% HCL and mutual solvent. 3. Stage containment materials for all hose and piping connections. 4. Maintain log during upcoming acid injection operation utilizing previous acid job template. 3 Reservoir Stimulation 1. Prep well for HCl treatment. SI ESP. 2. Rig Up Air-Operated Double Diaphragm (AODD) Injection Pump to RU-01A and perform pre- job safety meeting. 3. Pressure test hoses, connections, etc to 100 psi. o Maximum anticipated treating pressure is 100 psi. o Check valve to be used downstream of AODD Injection Pump. 4. Open tubing and annulus and confirm surface pressures (Tbg & IA). 5. Deliver 7.5 bbl of Mutual Solvent using AODD injection pump. o Do not exceed 0.5 BPM injection rate. 6. Deliver 1 bbl of Diesel using AODD injection pump. o Do not exceed 0.5 BPM injection rate. 7. Deliver 15 bbl of 15% HCL using AODD injection pump. o Do not exceed 0.5 BPM injection rate. 8. Deliver 1 bbl of Diesel using AODD injection pump. o Do not exceed 0.5 BPM injection rate. 9. Line up PW down tubing and prep for system flush. o RU hardline from RU-D1 injection piping as produced water source. 10. Pressure test hardline to 1,000 psi for 5 min. 11. Deliver 95 BBL of PW down tubing for initial hesitation. o Verify high-pressure shutdown has been set to 1,000 psi. o Maximum treating pressure anticipated to be 750 psi. o Do not exceed 1.0 BPM injection rate. 12. Shut in for 2 hour soak and monitor well. 13. Deliver 85 BBL of PW down tubing. o Verify high-pressure shutdown has been set to 1,000 psi. o Maximum treating pressure anticipated to be 750 psi. o Do not exceed 1.0 BPM injection rate. 14. Shut in for 2 hour soak and monitor surface pressures (Tbg & IA). 15. Rig down equipment. 16. Open tubing and annulus. 17. Turn on ESP and place well on production. Date: RKB Rig 35: 44.0'Version: RKB Rig Team Snubbing 102: 31.0' (2023)PTD: API: Tubing Hanger - ACME 3.725" MCA top connection / 3 1/2" RTS-6 btm connection - ID 2.682" 36" 150# A-36 215' MD ID - 35" A-36 215' TVD 13 3/8" 68# L-80 3,190' MD ID - 12.25" BTC 2,940' TVD X/O - 3 1/2" x 2 7/8" Tubing @ 9,528' MD / 8,352' TVD ESP Pump Assembly TOL @ 11,037' MD (9 5/8" x 5 1/2") Top of Discharge Head @ 10,950' MD / 9,581' TVD Bottom of ESP Assembly @ 11,112' MD / 9,725' TVD TOL @ 11,290' MD (9 5/8" x 7 5/8") 9 5/8" 47# L-80 11,500' MD ID - 8.50" BTC 10,065' TVD Window 7 5/8" 29.7# L-80 12,928' MD ID - 6.75" BTC 10,862' TVD MD TVD Reperf Type 14,786-14,799 11,952-11,959 TCP 14,799-14,809 11,959-11,965 TCP/StimGun TOC @ 13,710' MD (CBL 9/17/2013) 14,809-14,811 11,965-11,966 TCP 14,811-14,821 11,966-11,972 TCP/StimGun 14,821-14,848 11,972-11989 TCP 14,860-14,865 11,995-11,999 TCP 14,865'-14,880' 11,999-12,009 TCP/StimGun 14,880-14,934 12,009-12,042 TCP Note: 14,956-14,958 12,057-12,058 TCP WL Tagged 3.7" OD Tapered GR at 14,613' MD 14,958-14,968 12,058-12,065 TCP/StimGun 14,968-14,972 12,065-12,068 TCP 14,972-14,987 12,068-12.078 TCP/StimGun 14,987-14,994 12.078-12082 TCP 15,007-15,018 12,091-12,098 TCP Fish - 4' StimGun (possibly still live) 15,116-15,140 12,166-12,183 ---Cement Retainer @ 15114' MD 15,171-15,184 12,206-12,215 --- 15,265-15,272 12,274-12,280 --- 15,304-15,326 12,303-12320 ---Fish - ESP Assembly (+/-133ft) - Top @ 15260' MD 15,356-15,362 12,343-12,347 --- 15,378-15,386 12,360-12,366 --- 5 1/2 17# L-80 15,740' MD ID - 4.767" BTC 12,653' TVD PBTD @ 15653' MD 2 7/8" 6.3# L80 8RD EUE Tubing - ID 2.441" f/10,950' - 9,530' MD RU-05B: Current Completion Schematic Final 3 1/2" 9.3# L80 8RD Tubing - ID 2.441" f/9,528' MD to surface 6 3/4" Hole 18 1/2" Hole Perforations (& 2017 Reperfs) Retainer @ 15,114' 12 1/4" Hole 8 1/2" Hole Note: 5/5/2020 Well kill for Cold Stack; 283 bbls produced water pumped down tubing, no returns. 8-Aug-23 213-107 50-733-20513-02 gg 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 15,740 feet 15,114 feet true vertical 12,653 feet 15,110-15,114 feet Effective Depth measured 15,653 feet None feet true vertical 12,579 feet None feet Perforation depth Measured depth 14,786 - 15,386 feet True Vertical depth 11,952 - 12,366 feet Tubing (size, grade, measured and true vertical depth) Tapered 3-1/2" L-80 0 - 9,936' (MD) 0 - 8702' (TVD) 2-7/8" L-80 9,936 - 14,410' (MD) 8702 - 11,726' (TVD) Packers and SSSV (type, measured and true vertical depth) No Packer SSSV - None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date:Contact Name:Stan Porhola Contact Email:sporhola@glacieroil.com Authorized Title: Production & Wells Engineer Contact Phone: 907-331-8228 10065' Burst -- Collapse -- 2260 psi 4760 psi measured TVD Production Liner 1638' -- 4703' Casing Structural 10862' -- 5 1/2" 12928' -- 15740' 11037' Plugs Junk measured MaxStim Fusion acid (30 bbl) mixed with produced water (150 bbl). Final tubing pressure = 1,763 psi. Length 200' 3190' 11500' 3190'Conductor Surface Intermediate 36" 13 3/8" 9 5/8" None 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL 381203 and ADL 374002 REDOUBT SHOAL, UNDEFINED OIL COOK INLET ENERGY LLC 3. Address: 188 W. Northern Lights Blvd. SUITE 510, ANCHORAGE, AK 99503 REDOUBT UNIT #5B STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 213-107 50-733-20513-02-00 431 7 5/8" 7740 psi -- 4790 psi -- 6890 psi -- 399 16915 0 3040 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureGas-Mcf MD 200' 14,786'-15,018' MD Size 200' 2940' 5020 psi 6870 psi11500' 323-581 Sr Pet Eng: 6390 psi Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 64 303 Development Service GINJ SUSP SPLUG Gas Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Stan Porhola Digitally signed by Stan Porhola DN: cn=Stan Porhola, o, ou=Glacier Oil & Gas, email=sporhola@glacieroil.com, c=US Date: 2024.05.28 16:19:56 -08'00' By Grace Christianson at 4:32 pm, May 28, 2024 RBDMS JSB 053024 DSR-5/29/24 May 28, 2024 Ms. Jessie Chmielowski, Chair, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, AK 99501-3752 RE: Sundry # 323-581: RU-05B – ĐŝĚ^ƟŵƵůĂƚĞ ƉƉůŝĐĂƟŽŶ ŽŽŬ/ŶůĞƚŶĞƌŐǇ: 50-733-20513-02-00 ĞĂƌDƐ͘ŚŵŝĞůŽǁƐŬŝ͕ ŽŽŬ/ŶůĞƚŶĞƌŐǇŚĞƌĞďǇƐƵďŵŝƚƐĂƌĞƉŽƌƚŽĨSƵŶĚƌǇǁĞůůŽƉĞƌĂƟŽŶƐĨŽƌŵϭϬ-ϰϬϰĨŽƌRU-05B͕ PTD: 213-107͕W/͗ϱϬ-733-20513-02-ϬϬ͕^ƵŶĚƌǇEƵŵďĞƌ͗ϯϮϯ-581͘dŚĞǁĞůůŝƐlocated on CIE lease #381203 and 374002, in the Redoubt Shoal ϐ. ŶĐůŽƐĞĚƉůĞĂƐĞĮŶĚ͗ ϭ͘ ZĞƉŽƌƚ ŽĨ^ƵŶĚƌǇtĞůůKƉĞƌĂƟŽŶƐ ;K'&ŽƌŵϭϬ-404) Ϯ͘ ŽŵƉůĞƟŽŶ^ĐŚĞŵĂƟĐ ϯ͘ ĂŝůǇ^ƵŵŵĂƌŝĞƐ ϰ͘ EŽ-ŇŽǁdĞƐƚZĞĐŽƌĚ /ĨǇŽƵŚĂǀĞĂŶǇƋƵĞƐƟŽŶƐ͕ƉůĞĂƐĞĐŽŶƚĂĐƚŵĞĂƚϵϬϳ͘331͘8228͘ ZĞŐĂƌĚƐ͕ ^ƚĂŶWŽƌŚŽůĂ WƌŽĚƵĐƟŽŶĂŶĚtĞůůƐ ŶŐŝŶĞĞƌ 'ůĂĐŝĞƌKŝůĂŶĚ'ĂƐŽƌƉŽƌĂƟŽŶ ϭϴϴt͘EŽƌƚŚĞƌŶ>ŝŐŚƚƐůǀĚ͕͘^ƵŝƚĞϱϭϬ ŶĐŚŽƌĂŐĞ͕<ϵϵϱϬϯ K- ;ϵϬϳͿϰϯϯ-3820 Stan Porhola Digitally signed by Stan Porhola DN: cn=Stan Porhola, o, ou=Glacier Oil & Gas, email=sporhola@glacieroil.com, c=US Date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aily Operations Summary API: 50-733-20513-02-00 Permit #: 213-107 Sundry #: 323-581 Date Activity 29 December 2023 Fill tank w/ 150 bbl of produced water and 30 bbl of MaxStim Fusion acid and blend (180 bbl of stimulation fluid). RU injection pump. Test lines to 5,000 psi. Begin pumping 180 bbl of acid blend. Tight formation limiting pump. 30 December 2023 31 December 2023 01 January 2024 Continue pumping acid against tight formation. Continue pumping acid against tight formation. Displace acid w/ 125 bbl of produced water. 02 January 2024 Complete displacement. SI well. Soak for 48 hours. 03 January 2024 Well remains SI for 48 hour soak. 04 January 2024 Displace tubing w/ 95 bbl of produced water. 05 January 2024 06 January 2024 Complete displacement. SI well. Soak for 48 hours. Well remains SI for 48 hour soak. 07 January 2024 Turn on ESP. Place well on production. 05 March 2024 Notify AOGCC 48 hours in advance of No-Flow test. Turn off ESP. SI well. 08 March 2024 AOGCC inspector Austin McLeod on location. Perform No-Flow test. Start: T/I/O = 0.05/0/30; End: T/I/O = 0.94/0/30. Duration = 125 min. No-flow passed. Turn on ESP. Place well on production. Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov March 28, 2024 David Pascal Chief Operating Officer Cook Inlet Energy, LLC 188 W Northern Lights Blvd, Suite 510 Anchorage, AK 99503 RE: No-Flow Verification Redoubt Unit 5B PTD 2131070 Dear Mr. Pascal: On March 8, 2024, an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Redoubt Unit 5B on the Osprey Platform. The test procedure employed was the fluid flow rate method outlined in 20 AAC 25.265(l)(1) and Guidance Bulletin 21-001. Gas flow was unmeasurable and there was no liquid flow at surface during the No-Flow Test. Redoubt Unit 5B may be produced without a subsurface safety valve. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Redoubt 5B demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no-flow test. The AOGCC Inspector allowed this no-flow test to proceed despite the following inconsistencies with the Guidance Bulletin 21-001, a copy of which was provided to Cook Inlet Energy’s representative on March 5, 2024: - Well pressures were bled longer than established in the guidance bulletin. - There was no documentation supporting the calibration of the flow meter used for the test. Please review the Guidance Bulletin with appropriate staff in advance of future no-flow tests to prevent potential delays. A copy of this letter must be maintained at the Osprey Platform. Sincerely, James B. Regg Petroleum Inspection Supervisor ecc: P. Brooks AOGCC Inspectors James B. Regg Digitally signed by James B. Regg Date: 2024.03.28 14:10:16 -08'00' 2024-0308_No-Flow_RU-5B_am Page 1 of 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 3/9/2024 P. I. Supervisor FROM: Austin McLeod SUBJECT: No Flow Test Petroleum Inspector Redoubt Unit #5B Cook Inlet Energy, LLC PTD 2131070; Sundry 323-581 3/8/2024: I traveled to the Osprey platform and met with Lance Anderson (CIE) to witness a No-Flow Test on the packerless ESP completion after stimulation work had been completed on 1/2/2024. CIE had been bleeding off pressure from RU #5B since 15:00 on 3/5/2024 and the well was still open to atmosphere when I arrived at 10:30. This is ~ 20.5 hours longer than allowed to bleed the well down prior to the No-Flow Test per Guidance Bulletin 21-001. I verified the platform’s injectors were online and moving fluid. RU #6 was injecting ~ 665 barrels water per day (bwpd) and RU #3 was injecting ~ 3300 bwpd. The flow meter in use was “standard cubic feet per minute” instead of the typical Armor Flo “standard cubic feet per hour” we see when doing No-Flow Tests. An Armor Flo meter was on the platform but not current in calibration. Flow meter in use did have a calibration sticker but no supporting documentation. The meter was installed in the proper direction of flow. Per schematic and operator there were no plugs and/or flow control devices in the wellbore but a few “fish” left in the hole during a workover in August 2023. The inner annulus and tubing were in communication throughout the test via jumper hose. The above noted Sundry number is for the most recent well work. The well was shut in and pressures monitored every 15 minutes for one hour, then opened to flow through the meter. They did this same sequence twice. The well appeared dead as the needle on the meter never moved and I visually checked the end of the hose and slightly felt wellbore gas on the first check. On the second hour I could not feel anything but could barely see gas fumes when looking at it in the right lighting. No liquids were observed during the test. This was a poorly managed No-Flow Test and it was apparent they did not look at the Guidance Bulletin even after sent to them days before the test.           2024-0308_No-Flow_RU-5B_am Page 2 of 3 The following table shows test details: Time Pressures1 Flow Rate2 Remarks (psi) Gas – scf/hr Liquid – gal/hr 10:52 0.05 / 0 / 30 Well S/I 11:07 0.13 / 0 / 30 11:22 0.27 / 0 / 30 11:37 0.40 / 0 / 30 11:52 0.67 / 0 / 30 0 0 Open to meter after pressures taken. Needle didn’t move. Could feel and see slight flow at end of hose. 11:57 0.67 / 0 / 30 Well S/I 12:12 0.75 / 0 / 30 12:27 0.80 / 0 / 30 12:42 0.81 / 0 / 30 12:57 0.94 / 0 / 30 0 0 Open to meter after pressures taken. Needle didn’t move. No feel. Could see slight “fumes”. 13:00 0.70 / 0 / 30 Stop test 1 Pressures are T/IA/OA 2 Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr Attachments: Meter pictures (2) 2024-0308_No-Flow_RU-5B_am Page 3 of 3 No-Flow Test – Redoubt Unit 5B (PTD 2131070) Photos by AOGCC Inspector A. 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HUJ\//& 5('28%781,7% $$& )RUP5HYLVHG$SSURYHGDSSOLFDWLRQYDOLGIRUPRQWKVIURPGDWHRIDSSURYDO6XEPLW3')WRDRJFFSHUPLWWLQJ#DODVNDJRY Zach Tomco Digitally signed by Zach Tomco DN: cn=Zach Tomco, o=Cook Inlet Energy, ou=Cook Inlet Energy, email=ztomco@glacieroil.com, c=US Date: 2023.10.23 13:52:54 -08'00' 323-581 By Grace Christianson at 2:30 pm, Oct 23, 2023 BJM 11/10/23 DSR-10/24/23SFD 10/24/2023 Obsolete Form SFD 10-404 *&:JLC 11/14/2023 Brett W. Huber, Sr.Digitally signed by Brett W. 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Conduct pre-job safety meeting with all personnel on location o Review upcoming work and discuss safety first 2. Stage containment materials for all hose and piping connections 3. Fill T-106 with 150 bbl of PW water 4. Fill T-106 with (6) totes of MaxStim Fusion 5. Recycle fluid in T-106 with Transfer Pump to adequately mix 6. Maintain log during upcoming acid injection operation utilizing previous acid job template. Reservoir Stimulation 1. Prep well for MaxStim treatment 2. Rig Up High Pressure Injection Pump to RU-05 and perform pre-job safety meeting 3. Pressure test hoses, connections, etc to 5000 psi o Maximum anticipated treating pressure is 1000 psi 4. Verify PIT-07-3C5 PSH has been set to 1500 psig. 5. Open tubing and annulus and confirm circulation 6. Deliver 200 bbl of MaxStim Fusion/PW mixture o Do not exceed 0.33 BPM 7. Record flowrate from High Pressure Injection Pump meter. 8. Line up PW down tubing and prep for system flush and hesitation squeeze. 9. Deliver 125 BBL of PW down tubing o Do not exceed 0.33 BPM injection rate o MaxStim Fusion/Water mixture will now be in contact with perfs o Soak for 2 days 10. Line up PW down tubing and prep to bullhead into formation 11. Deliver 75 bbl of PW down tubing o Do not exceed 0.33 BPM injection rate 12. Shut-in tubing and annulus, monitor surface pressure 13. Divert PW back to injection o Stimulation fluids can be processed at KPF 14. Rig down equipment 15. Allow MaxStim Fusion to soak for 2 days, then Put On Production MP D - O G A - 2 0 0 0 - 0 1 RU - 0 5 B MA X S T I M fl u i d w i l l b e st o r e d h e r e . MP D - O G A - 2 0 0 7 - 0 1 HI G H P R E S S U R E IN J P U M P CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. You don't often get email from ztomco@glacieroil.com. Learn why this is important From:Rixse, Melvin G (OGC) To:Zach Tomco Cc:McLellan, Bryan J (OGC) Subject:20230731 1637 APPROVAL to forego casing pressure test RDOUBT Unit #5B PTD 213-107 Date:Monday, July 31, 2023 4:40:59 PM Attachments:image002.png image003.png Zach, Glacier is approved to forego the IC pressure test on this well, as evidence was found from April 2017 (6 years ago) that a passing pressure test was performed to 1,225 psi. (See below.) Note: This well is to have a ‘no-flow’ test within 30 days of POP. A failing ‘no-flow’ test would alter this approval for continuing production. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Bryan McLellan From: Zach Tomco <ztomco@glacieroil.com> Sent: Monday, July 31, 2023 4:16 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: PTD 213-107 Mel, Glacier would like to forego the casing pressure test on the RU-05B Sundry #323-278. The attached drilling report shows the cement packer was tested at 1,225 psi @ 15114’ MD on 4/23/2017. RU-05B is a no flow well that was subsequently perforated after the cement packer was installed; this is reflected on the well schematic. Could you please review and approve changing this Sundry to forego the casing pressure test? Regards, Zach Tomco Facilities Engineer Office: (907) 433-3803 Cell: (907) 715-1244 Glacier Oil & Gas 1 Regg, James B (OGC) From:Regg, James B (OGC) Sent:Thursday, July 13, 2023 2:42 PM To:David Pascal Cc:Stephen Ratcliff; McLellan, Bryan J (OGC) Subject:RE: No Flow Extension Request for RU and WMRU AOGCC approves a temporary waiver of subsurface safety valve (SSSV) requirements for the following wells, allowing them to produce uninterrupted aŌer installaƟon of their respecƟve compleƟon to ensure the new ESP is operaƟng properly: W McArthur River Unit 2B (PTD 2140390) Sword 1(PTD 2130800) Redoubt Unit 2A(PTD 2121720) Redoubt Unit 5B(PTD 2131070) Redoubt Unit 7B(PTD 2141910) ANoͲFlow Test on each well must be performed not later than 60 days aŌer ESP installaƟon.All wells must maintain an AOGCCͲcompliant surface safety valve system.These wells must be visually checked at least twice each day to conĮrm mechanical integrity. Jim Regg Supervisor, Inspections AOGCC 333 W. 7 th Ave, Suite 100 Anchorage, AK 99501 907Ͳ793Ͳ1236 From:David Pascal <dpascal@glacieroil.com> Sent:Wednesday, July 12, 2023 10:33 AM To:Regg, James B (OGC) <jim.regg@alaska.gov> Cc:Stephen Ratcliff <sratcliff@glacieroil.com> Subject:No Flow Extension Request for RU and WMRU Jim, Thank you for taking my call today. As menƟoned on the phone we had an infant mortality incident on WMRUͲ2B. We were not able to restart the ESP aŌer we shut it down for the second noͲŇow test on July 8th. IniƟal indicaƟons lead us to believe that we have lost a phase.AŌer talking to the manufacture and some of our consultants it is recommended that we keep these ESP’s running as long as we can without interrupƟons during its early life. In light of this incident, we are requesƟng the Commission to extend the window to perform the noͲŇow tesƟng on rest of the WMRU and RU wells to 60Ͳday window from the current 7/14Ͳday window. We just established Sword to operaƟng frequency last night aŌer installing a new ESP and will be moving over to Osprey to replace ESP’s on RUͲ2A, 5B, 7B in the next few weeks. As discussed, these wells have been previously established to be noͲŇow wells (previous cerƟĮcaƟons aƩached) and the last recorded pressures indicate gradients that are incapable of supporƟng free Ňow (tableaƩached below). These readings were taken just before we restarted the RU and WMRU assets aŌer being shutͲin from May 2020 to Sep 2021 via wireline unless menƟoned. We are humbly requesƟng the Commission to extend the window for noͲŇow tesƟng on these upcoming workovers. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 5HGRXEW8QLW% 37' Redoubt Unit 5B(PTD 2131070) 2 Thank you for paying aƩenƟon to this maƩer.Please reach out if there are any quesƟons. Regards David Pascal Chief Operating Officer |Glacier Oil and Gas Corporation 188 W. Northern Lights Blvd. Suite 510 907Ͳ433Ͳ3822 (Direct)| 907Ͳ903Ͳ4164 (Mobile) 907Ͳ334Ͳ6745 (Main)|907Ͳ334Ͳ6735 (Fax) Email:dpascal@glacieroil.com Well Name Type Date Pressure (psi) MD (ft) TVD (ft) Gradient (psi/ft)Formation Comments RU-1A Producer - ESP 9/13/21 3,263 10,000 8,420 0.39 Hemlock Shut-in since May 2020- Sep2021 RU-2A Producer - ESP 9/27/21 4,548 14,177 12,011 0.38 Hemlock Shut-in since May 2020- Sep2021. Taken from ESP intermittent data RU-5B Producer - ESP 9/15/21 4,594 14,432 11,740 0.39 Hemlock Shut-in since May 2020- Sep2021 RU-7B Producer - ESP 9/12/21 3,812 12,085 10,075 0.38 Hemlock Shut-in since May 2020- Sep2021 WMRU- 2B Producer - ESP 9/25/21 3,254 12,111 8,457 0.38 Hemlock Shut in since Feb 2020 WMRU- 5 Producer - ESP 10/25/21 3,252 12,163 8,450 0.38 Hemlock Shut-in since May 2020- Sep2021. Taken from ESP Data WMRU- 6 Producer - ESP 10/25/21 2,870 11,440 7,357 0.39 Hemlock Shut-in since May 2020- Sep2021. Taken from ESP Data Sword-1 Producer - ESP 9/25/21 3,298 16,300 8,620 0.38 Hemlock/Tyonek Shut-in since Dec 2020 RU-5B Producer - Shut-in since May 2020-9/15/21 4,594 0.3911,74014,432 HemlockESP Sep2021 By Grace Christianson at 2:11 pm, Oct 05, 2023 Version: Final Tubing Hanger - ACME 3.725" MCA top connection / 3 1/2" RTS-6 btm connection - ID 2.682" 36" 150# A-36 215' MD ID - 35" A-36 215' TVD 13 3/8" 68# L-80 3,190' MD ID - 12.25" BTC 2,940' TVD X/O - 3 1/2" x 2 7/8" Tubing @ 9,936' MD / 8,701' TVD TOL @ 11,037' MD (9 5/8" x 5 1/2") TOL @ 11,290' MD (9 5/8" x 7 5/8") 9 5/8" 47# L-80 11,500' MD ID - 8.50" BTC 10,065' TVD Window 7 5/8" 29.7# L-80 12,928' MD ID - 6.75" BTC 10,862' TVD MD TVD Reperf Type 14,786-14,799 11,952-11,959 TCP 14,799-14,809 11,959-11,965 TCP/StimGun TOC @ 13,710' MD (CBL 9/17/2013) 14,809-14,811 11,965-11,966 TCP 14,811-14,821 11,966-11,972 TCP/StimGun ESP Pump Assembly 14,821-14,848 11,972-11989 TCP Top of Discharge Head @ 14,410' MD / 11,726' TVD 14,860-14,865 11,995-11,999 TCP 14,865'-14,880' 11,999-12,009 TCP/StimGun 14,880-14,934 12,009-12,042 TCP 14,956-14,958 12,057-12,058 TCP Bottom of ESP Assembly @ 14,555' MD / 11,816' TVD 14,958-14,968 12,058-12,065 TCP/StimGun 14,968-14,972 12,065-12,068 TCP 14,972-14,987 12,068-12.078 TCP/StimGun 14,987-14,994 12.078-12082 TCP 15,007-15,018 12,091-12,098 TCP Fish - 4' StimGun (possibly still live) 15,116-15,140 12,166-12,183 ---Cement Retainer @ 15114' MD 15,171-15,184 12,206-12,215 --- 15,265-15,272 12,274-12,280 --- 15,304-15,326 12,303-12320 ---Fish - ESP Assembly (+/-133ft) - Top @ 15260' MD 15,356-15,362 12,343-12,347 --- 15,378-15,386 12,360-12,366 --- 5 1/2 17# L-80 15,740' MD ID - 4.767" BTC 12,653' TVD PBTD @ 15653' MD 2 7/8" 6.3# L80 8RD EUE Tubing - ID 2.441" f/14,410' - 9,936' MD RU-05B: Current Completion Schematic 5/5/2020 3 1/2" 9.3# L80 8RD Tubing - ID 2.441" f/9,936' MD to surface 6 3/4" Hole 18 1/2" Hole Perforations (& 2017 Reperfs) Retainer @ 15,114' 12 1/4" Hole 8 1/2" Hole Note: 5/5/2020 Well kill for Cold Stack; 283 bbls produced water pumped down tubing, no returns. Temp:°F Wind Speed:Weather:Road Cond:Lease Cond: KB-THF:ftKB-Ground:44.01 ftKB:44.01 ft Day 1 Rig Name:Rig Release: Licence #: Rig Number:Personnel On Location: Safety SITP:0 psi SICP:0 psi Last BOP Press Test:Last BOP Drill: H2S:No %Last Safety Meeting:Last Rig Inspection: Time Log Time From Time To Hours Code Comments Total: Wellbores Wellbore KOP MD (ft)KOP TVD (ft)TD MD (ft)TD TVD (ft) Main Wellbore 17,118.24 Load Fluids Fluid Type Pumped (bbl)Cum (bbl)Rec. (bbl)Cum (bbl)To Rec (bbl)Balance (bbl)Weight (lb/gal)Temp (°F) Casing Type OD (in)ID (in)Weight (lb/ft)Grade Depth MD (ft) Perforations Wellbore Formation Top MD (ft)Bottom MD (ft)Shot Density (shots/ft)Phasing (°) Other In Hole Wellbore Item Run Date OD (in)Top (ft)Btm (ft)Length (ft) Operations Operations at Start: 24 Hr Summary: 24 Hr Forecast: Remarks: KB-RT:ft www.resourceenergysolutions.com Generated Oct 04, 2023 16:46 Page 1 of 1 Daily Completion Well Name: Country: RU-05B United States State:Alaska Activity: Well Number: 50-733-20513-02-00 API: RU-05B ESP Completion Date:Jul 28, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Tom Boyd (inacti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Paul Smith (i 9075290737206-914-7247Wes JeardoeSupervisor: Temp:55 °F Wind Speed:Calm Weather:Overcast Road Cond:Lease Cond:Good KB-THF:ftKB-Ground:44.01 ftKB:44.01 ft Day 2 Rig Name:Rig Release: Licence #: Rig Number:Personnel On Location:26 Safety SITP:0 psi SICP:0 psi Last BOP Press Test:Last BOP Drill: H2S:No %Last Safety Meeting:Last Rig Inspection: Wellbores Wellbore KOP MD (ft)KOP TVD (ft)TD MD (ft)TD TVD (ft) Main Wellbore 17,118.24 Load Fluids Fluid Type Pumped (bbl)Cum (bbl)Rec. (bbl)Cum (bbl)To Rec (bbl)Balance (bbl)Weight (lb/gal)Temp (°F) Casing Type OD (in)ID (in)Weight (lb/ft)Grade Depth MD (ft) Perforations Wellbore Formation Top MD (ft)Bottom MD (ft)Shot Density (shots/ft)Phasing (°) Other In Hole Wellbore Item Run Date OD (in)Top (ft)Btm (ft)Length (ft) Operations Operations at Start:POH laying down 3 1/2" ESP completion. 24 Hr Summary:Pull tree from RU 05B, set on riser and BOPs, set snubbing unit from deck to well, Rig up snubbing unit, Test BOPE, pull hanger to floor, 165 up weight, lay down landing joint and hanger. 24 Hr Forecast:Pull to tie cap string and e line to Summit spooler, tie into spools, POH laying down 3 1/2" ESP completion. Remarks:BOP test notification was sent in to AOGCC on 7 27 23 at 10:00 hrs. Jim Regg waived states right of witness for BOP test on RU 05B,7 28 23 at 9:30 hrs. Hanger seals and threads looked to be in good condition. KB-RT:ft www.resourceenergysolutions.com Generated Oct 04, 2023 16:46 Page 1 of 2 Daily Completion Well Name: Country: RU-05B United States State:Alaska Activity: Well Number: 50-733-20513-02-00 API: RU-05B ESP Completion Date:Jul 29, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Tom Boyd (inacti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Paul Smith (i 9075290737206-914-7247Wes JeardoeSupervisor: Time Log Time From Time To Hours Code Comments 00:00 02:00 2.00 BOPS-Install / Remove / Pressure Test Set BPV, pull production tree and plug cap string and e-line penetrator, inspect hanger threads, good, install blanking nipple, Set riser and BOP on well head. 02:00 03:00 1.00 Move Equipment / Service Rig Attach crane to TSI unit and release guys from deck. pick up, set on RU-05A (wt. = 62K jack unit and work window together). 03:00 06:00 3.00 Rig Up / Rig Out / Repair Service Rig Make up jacking unit flanges to BOP, set guy lines, release crane, rigging up TSI snubbing unit for well work. Making up BOP flange and Koomey lines. 06:00 09:30 3.50 Rig Up / Rig Out / Repair Service Rig Continue to rig up stairs and pick up line and tongs . Pressure up closing unit . Make up landing joint with vaults test dart on 2 7/8" pipe . Transfer source water out of return tank on pump to rig tank and fill return tank with fresh water. 09:30 13:00 3.50 BOPS-Install / Remove / Pressure Test R/U to test BOPE Per sundry and rig procedure. Make up 2 7/8" test joint with Vault test dart and install in stack and tighten in hanger. Fill stack and surface lines and choke with fresh water . Fix two leaks on Coflex hose flanges. Perform shell pressure test to low 300 psi and 3,000 psi. No test, bleed off keep bumping up to 3k and bleeding air from system. Chase leaks in surface equipment. Open needle valve at choke to bleed out air and close and open safety valve to bleed out air and close . Test low 300 psi. good test, test high 3,000 psi. good shell test. 13:00 19:00 6.00 BOPS-Install / Remove / Pressure Test Test BOPE Per Sundry and rig procedure. *Tested rams and annular with 3 1/2" and 2 7/8" test joints, 250 low 3,000 high, annular tested 250 psi low 2,500 psi high. Remove test jt. remove dart and swap running tool. Install lifting cross over to lift string with hanger. Lay down test joint rig down test tools. Perform Koomey draw down test. *BOP test witness waived by Jim Regg 7/28/23 09:25 am. 19:00 24:00 5.00 Run / Pull / Test Downhole Pump BOLDS, Pull BPV, well on vac. Pick up and make up 3 1/2" PH6 landing joint, engage hanger, work pick up weight to 165K indicated weight, Pick up weight 165K. pull hanger to floor, cut cable and cut and plug cap strings, remove hanger at window install landing joint pull to basket. Clear deck of landing and test joints. Change XO on FOSV to 3 1/2" EUE. Total: 24.00 www.resourceenergysolutions.com Generated Oct 04, 2023 16:46 Page 2 of 2 Daily Completion Well Name: Country: RU-05B United States State:Alaska Activity: Well Number: 50-733-20513-02-00 API: RU-05B ESP Completion Date:Jul 29, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Tom Boyd (inacti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Paul Smith (i 9075290737206-914-7247Wes JeardoeSupervisor: Temp:54 °F Wind Speed:Up to 19 km/h Weather:Partly Cloudy Road Cond:Lease Cond:Good KB-THF:ftKB-Ground:44.01 ftKB:44.01 ft Day 3 Rig Name:Rig Release: Licence #: Rig Number:Personnel On Location:27 Safety SITP:0 psi SICP:0 psi Last BOP Press Test:Last BOP Drill: H2S:No %Last Safety Meeting:Last Rig Inspection: Time Log Time From Time To Hours Code Comments 00:00 06:00 6.00 Run / Pull / Test Downhole Pump Pull cable to spooler and tie in cap and electric cable. Pipe pulling hard to the side. of rig. Use come-along to pull pipe over far enough to set slips. Observe light scale inside of pipe. Pumped 20 bbl. to annulus to clean outside of the pipe. POH to #30. 06:00 18:00 12.00 Run / Pull / Test Downhole Pump Continue POH laying down 3/1/2" ESP completion from #30 to jt. #130. Note: At joint 99 pipe not as bent as from surface. 18:00 24:00 6.00 Run / Pull / Test Downhole Pump Continue POH laying down 3 1/2" ESP completion. from jt. #130 to jt #191 Simops, Bundle and move 142 jts. 3 1/2" EUE pipe from drill deck and place in storage areas for load out to boat. Total: 24.00 Wellbores Wellbore KOP MD (ft)KOP TVD (ft)TD MD (ft)TD TVD (ft) Main Wellbore 17,118.24 Load Fluids Fluid Type Pumped (bbl)Cum (bbl)Rec. (bbl)Cum (bbl)To Rec (bbl)Balance (bbl)Weight (lb/gal)Temp (°F) Casing Type OD (in)ID (in)Weight (lb/ft)Grade Depth MD (ft) Perforations Wellbore Formation Top MD (ft)Bottom MD (ft)Shot Density (shots/ft)Phasing (°) Other In Hole Wellbore Item Run Date OD (in)Top (ft)Btm (ft)Length (ft) Operations Operations at Start:Laying down 3 1/2" ESP completion. 24 Hr Summary:POH laying down 146 joints 3 1/2" ESP completion. 24 Hr Forecast:Continue POH to 2 7/8" ESP, change snubbing slips and floor valve XO continue POH with ESP completion. Remarks:Adding 15 bbl. produced water to well from rig tank every 30 jts for hole fill and pipe cleaning. Note: At joint 99 pipe was not as bent as previous joints were from surface. KB-RT:ft www.resourceenergysolutions.com Generated Oct 04, 2023 16:46 Page 1 of 1 Daily Completion Well Name: Country: RU-05B United States State:Alaska Activity: Well Number: 50-733-20513-02-00 API: RU-05B ESP Completion Date:Jul 30, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Tom Boyd (inacti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Paul Smith (i 9075290737206-914-7247Wes JeardoeSupervisor: Temp:53 °F Wind Speed:Up to 19 km/h Weather:Clear Road Cond:Lease Cond:Good KB-THF:ftKB-Ground:44.01 ftKB:44.01 ft Day 4 Rig Name:Rig Release: Licence #: Rig Number:Personnel On Location:27 Safety SITP:0 psi SICP:0 psi Last BOP Press Test:Last BOP Drill: H2S:No %Last Safety Meeting:Last Rig Inspection: Time Log Time From Time To Hours Code Comments 00:00 04:30 4.50 Run / Pull / Test Downhole Pump POH laying down 3 1/2" ESP completion f/ jt# 191 t/ #228 04:30 08:00 3.50 Run / Pull / Test Downhole Pump Change ESP spools. Simops, Pump15 bbl. down tubing and 20 bbl. down annulus for hole cleaning. 08:00 12:00 4.00 Run / Pull / Test Downhole Pump Continue POH laying down 3 1/2" ESP completion f/ jt# 228 t/ jt #256 (String weight 70000lbs) Pump 5 bbls every 30 jts. 12:00 18:00 6.00 Run / Pull / Test Downhole Pump POH laying down 3 1/2" / 2 78" ESP completion f/ #256 t/ #346 18:00 20:00 2.00 Run / Pull / Test Downhole Pump Bundle and move 103 jts 3 1/2" and 27 jts 2 7/8" pipe from drill deck to storage on decks. 20:00 24:00 4.00 Run / Pull / Test Downhole Pump Continue POH laying down 2 7/8" ESP completion f/ #346 t/ #393. Total: 24.00 Wellbores Wellbore KOP MD (ft)KOP TVD (ft)TD MD (ft)TD TVD (ft) Main Wellbore 17,118.24 Load Fluids Fluid Type Pumped (bbl)Cum (bbl)Rec. (bbl)Cum (bbl)To Rec (bbl)Balance (bbl)Weight (lb/gal)Temp (°F) Casing Type OD (in)ID (in)Weight (lb/ft)Grade Depth MD (ft) Perforations Wellbore Formation Top MD (ft)Bottom MD (ft)Shot Density (shots/ft)Phasing (°) Other In Hole Wellbore Item Run Date OD (in)Top (ft)Btm (ft)Length (ft) Operations Operations at Start:Laying down ESP pump assembly. 24 Hr Summary:POH laying down ESP completion. Change ESP spools @ jt #228 continue laying down ESP completion. pumping as needed for pipe cleaning. 24 Hr Forecast:Continue POH with ESP completion, inspect and lay down motor and pump assembly. Load completion string onto boat, rig up wire line. Remarks: KB-RT:ft www.resourceenergysolutions.com Generated Oct 04, 2023 16:46 Page 1 of 1 Daily Completion Well Name: Country: RU-05B United States State:Alaska Activity: Well Number: 50-733-20513-02-00 API: RU-05B ESP Completion Date:Jul 31, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Tom Boyd (inacti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Paul Smith (i 9075290737206-914-7247Wes JeardoeSupervisor: Temp:55 °F Wind Speed:Up to 19 km/h Weather:Clear Road Cond:Lease Cond:Good KB-THF:ftKB-Ground:44.01 ftKB:44.01 ft Day 5 Rig Name:Rig Release: Licence #: Rig Number:Personnel On Location:27 Safety SITP:0 psi SICP:0 psi Last BOP Press Test:Last BOP Drill: H2S:No %Last Safety Meeting:Last Rig Inspection: Time Log Time From Time To Hours Code Comments 00:00 06:00 6.00 Run / Pull / Test Downhole Pump PJSM. Lay down 2 7/8 completion f jt 393 to ESP motor assembly Perforated joint tally # 453. 06:00 10:00 4.00 Run / Pull / Test Downhole Pump PJSM. Break and lay down ESP pump / motor assembly. Spool up ESP cables. Pipe directly above discharge head was relatively clean. Pump and motors had heavy build up of sludge and white chalky build up. All clamps recovered, 161) 3-1/2" and 123) 2-7/8" cross collar clamps. inc motor and protectolizer clamps. 10:00 15:30 5.50 Rig Up / Rig Out / Repair Service Rig Close Blinds. Clean / clear Rig and deck. Prep pipe and equipment for boat load out. 15:30 16:30 1.00 Install or Change Wellhead PJSM. makeup landing jt. Install wear bushing R/D landing jt. 16:30 20:00 3.50 Move Equipment / Service Rig Organize Deck, and ready loads for off load, general house keeping and Rig maintenance, 20:00 24:00 4.00 Move Equipment / Service Rig PJSM. Off Load and Onload equipment for work Boat #1 Endeavor (Note only 7 bundles of used tubing made this boat due to tide) Total: 24.00 Wellbores Wellbore KOP MD (ft)KOP TVD (ft)TD MD (ft)TD TVD (ft) Main Wellbore 17,118.24 Load Fluids Fluid Type Pumped (bbl)Cum (bbl)Rec. (bbl)Cum (bbl)To Rec (bbl)Balance (bbl)Weight (lb/gal)Temp (°F) Casing Type OD (in)ID (in)Weight (lb/ft)Grade Depth MD (ft) Perforations Wellbore Formation Top MD (ft)Bottom MD (ft)Shot Density (shots/ft)Phasing (°) Other In Hole Wellbore Item Run Date OD (in)Top (ft)Btm (ft)Length (ft) Operations Operations at Start:Continue Deck organizing for off load and on load boat run #2, Change out swap valves from RU2 to RU5 24 Hr Summary:PJSM on all stages of operations, POOH with ESP tubing and Motor assembly, Break and lay down motor assembly, Clear deck and ready equipment for boat on/off load, pickup landing Makeup and install wear ring, Offload and onload equipment to/from boat, 24 Hr Forecast:Continue to arrange deck for on load and off load of equipment for boat run #2, Rig up Lubricator and make a gauge ring run with slick line, Rig up lines for disposal of crude oil in rig pit, Change out tree valves from RU2 to RU5 tree Remarks: KB-RT:ft www.resourceenergysolutions.com Generated Oct 04, 2023 16:46 Page 1 of 1 Daily Completion Well Name: Country: RU-05B United States State:Alaska Activity: Well Number: 50-733-20513-02-00 API: RU-05B ESP Completion Date:Aug 1, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Tom Boyd (inacti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Paul Smith (i 9075290737206-914-7247Wes JeardoeSupervisor: Temp:53 °F Wind Speed:Up to 19 km/h Weather:Fog Road Cond:Lease Cond:Good KB-THF:ftKB-Ground:44.01 ftKB:44.01 ft Day 6 Rig Name:Rig Release: Licence #: Rig Number:Personnel On Location:23 Safety SITP:0 psi SICP:0 psi Last BOP Press Test:Last BOP Drill: H2S:No %Last Safety Meeting:Last Rig Inspection: Time Log Time From Time To Hours Code Comments 00:00 03:00 3.00 Install or Change Wellhead Remove wing and swab from RU-02A tree and install tree cap on top of master valve = dry hole tree. Note: RU-02A tree has been tested and will be used on RU-05B. 03:00 06:00 3.00 Flushby Cleanout Deck management for crane off load. Flush out and rinse rig tank. Hold PJSM and hand over with daylight crew 06:00 12:00 6.00 Move Equipment / Service Rig Off Load Boat of EUE tubulars. Back-load with used tubing, ESP motors and related equipment 12:00 18:00 6.00 Move Equipment / Service Rig Continue to work deck and boat. Work with Summit to remove spoolers in prep for Wireline rig up. Number and rabbit EUE tubing in prep for ESP completion. 18:00 24:00 6.00 Move Equipment / Service Rig Build Lubricator, spot E-line unit, stack and drift tubing Total: 24.00 Wellbores Wellbore KOP MD (ft)KOP TVD (ft)TD MD (ft)TD TVD (ft) Main Wellbore 17,118.24 Load Fluids Fluid Type Pumped (bbl)Cum (bbl)Rec. (bbl)Cum (bbl)To Rec (bbl)Balance (bbl)Weight (lb/gal)Temp (°F) Casing Type OD (in)ID (in)Weight (lb/ft)Grade Depth MD (ft) Perforations Wellbore Formation Top MD (ft)Bottom MD (ft)Shot Density (shots/ft)Phasing (°) Other In Hole Wellbore Item Run Date OD (in)Top (ft)Btm (ft)Length (ft) Operations Operations at Start:PJSM continue Rig and Deck cleanup and general house keeping Ready equipment for wire line run 24 Hr Summary:PJSM. JSAs for operations being performed. Clean oil from Pit, organize deck, off load/on load Endeavor, stack tubing and drift same. Make up spacer lubricator into BOPs. Clean/clear deck. Set BPV in RU 02A. Re rig hoses back to produced water in well bay. 24 Hr Forecast:Make gauge ring run on E line, and pulse neutron run .TBD by wire line runs Remarks: KB-RT:ft www.resourceenergysolutions.com Generated Oct 04, 2023 16:46 Page 1 of 1 Daily Completion Well Name: Country: RU-05B United States State:Alaska Activity: Well Number: 50-733-20513-02-00 API: RU-05B ESP Completion Date:Aug 2, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Tom Boyd (inacti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Paul Smith (i 9075290737206-914-7247Wes JeardoeSupervisor: Temp:54 °F Wind Speed:Up to 29 km/h Weather:Fog Road Cond:Lease Cond:Good KB-THF:ftKB-Ground:44.01 ftKB:44.01 ft Day 7 Rig Name:Rig Release: Licence #: Rig Number:Personnel On Location:26 Safety SITP:0 psi SICP:0 psi Last BOP Press Test:Last BOP Drill: H2S:No %Last Safety Meeting:Last Rig Inspection: Time Log Time From Time To Hours Code Comments 00:00 01:00 1.00 Rig Up / Rig Out / Repair Service Rig R/U and dry fit installation of 4 1/2" OD riser for wireline work 01:00 05:30 4.50 Rig Up / Rig Out / Repair Service Rig Perform 500 hr service on Power Pack. House keeping and general maintenance. 05:30 06:00 0.50 Safety Meeting Continue to wait on E-line crew rest. 06:00 10:00 4.00 Rig Up / Rig Out / Repair Service Rig Investigation of crane incident.. inspect boom, lines and grease basket for damage(okay) Grease crane sheaves, strap 1st row of tubing. 10:00 18:30 8.50 Wireline Operations PJSM Rig up E-line unit and related equipment make up lubricator, spot crane and rig up wire and sheaves. Make dry run for alignment and make up E-line tools. curtailed operations Due to Helicopter flights bringing in Groceries 18:30 24:00 5.50 Wireline Operations Rig up E-line unit and related equipment. Make up 4.70" OD gauged ring and RIH. Set down with GR at 11060' WLM multiple times. POOH. M/U 4.60" OD gauge ring and RIH. Total: 24.00 Wellbores Wellbore KOP MD (ft)KOP TVD (ft)TD MD (ft)TD TVD (ft) Main Wellbore 17,118.24 Load Fluids Fluid Type Pumped (bbl)Cum (bbl)Rec. (bbl)Cum (bbl)To Rec (bbl)Balance (bbl)Weight (lb/gal)Temp (°F) Casing Type OD (in)ID (in)Weight (lb/ft)Grade Depth MD (ft) Perforations Wellbore Formation Top MD (ft)Bottom MD (ft)Shot Density (shots/ft)Phasing (°) Other In Hole Wellbore Item Run Date OD (in)Top (ft)Btm (ft)Length (ft) Operations Operations at Start:Rigged up to run in hole with 3.75 OD gauge ring. Wire liners timed out at present. 24 Hr Summary:PJSM on any tasks or change of work scope. Install Dry hole lubricator. Perform 500 hour maintenance on power pack. Investigation of crane Boom incident. Rig up E line unit and related equipment. Make up 4.70" OD gauged ring and RIH. Set down with GR at 11060' WLM multiple times. POOH. M/U 4.60" OD gauge ring and RIH. 24 Hr Forecast:TBD by success or Failure of Gauge Ring Run 1. Smaller Gauge Ring Run (3.75) 2. Neutron Run 3. Scraper Run 4. Perf Gun Run $ Early BOP test Remarks:AOGCC inspection notification sent in on 8/3/23 at 15:45, for test at 22:00 hrs on 8/5/23. KB-RT:ft www.resourceenergysolutions.com Generated Oct 04, 2023 16:46 Page 1 of 1 Daily Completion Well Name: Country: RU-05B United States State:Alaska Activity: Well Number: 50-733-20513-02-00 API: RU-05B ESP Completion Date:Aug 3, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Tom Boyd (inacti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Paul Smith (i 9075290737206-914-7247Wes JeardoeSupervisor: Temp:55 °F Wind Speed:Up to 19 km/h Weather:Overcast Road Cond:Lease Cond:Good KB-THF:ftKB-Ground:44.01 ftKB:44.01 ft Day 8 Rig Name:Rig Release: Licence #: Rig Number:Personnel On Location:26 Safety SITP:0 psi SICP:0 psi Last BOP Press Test:Last BOP Drill: H2S:No %Last Safety Meeting:Last Rig Inspection: Time Log Time From Time To Hours Code Comments 00:00 01:00 1.00 Wireline Operations PJSM RIH with 4.60" gauge ring. Tag solid at 11060' WLM 01:00 02:30 1.50 Wireline Operations PJSM. POOH from 11060' to surface. Junk basket clean. No marks on gauge ring. 02:30 03:00 0.50 Wireline Operations PJSM. Rig Down E-liners E-line personnel timed out for rest. 03:00 06:00 3.00 Waiting Wait on wire liners for efficient rest. Call town and procure needed tapered gauge ring 06:00 06:30 0.50 Safety Meeting Crew change Safety hand over, operational meeting and plan forward 06:30 10:30 4.00 Move Equipment / Service Rig Continue to wait on e-line crew from rest (TSI performing general maintenance and house keeping) 10:30 12:00 1.50 Wireline Operations PJSM Remove flat face gauge ring and junk basket. M/U 3.75" OD tapered gauge ring. 12:00 18:00 6.00 Wireline Operations PJSM. RIH with 3.75" OD tapered gauge ring to 14569' WLM. POOH. No debris or marks on gauge ring. 18:00 19:00 1.00 Wireline Operations PJSM. Change out 3.75" OD tapered gauge ring to a tapered 4.50" OD gauge ring. 19:00 21:30 2.50 Wireline Operations PJSM. RIH with 4.5" OD tapered gauge ring. Tag hard at same depth of 14,569' WLM. 21:30 23:00 1.50 Wireline Operations POOH from 14,569' to surface. Observe some paraffin type substance on gauge ring, possibly from dragging, but no marks. 23:00 24:00 1.00 Wireline Operations PJSM. Rig Down wire line and Related equipment Total: 24.00 Wellbores Wellbore KOP MD (ft)KOP TVD (ft)TD MD (ft)TD TVD (ft) Main Wellbore 17,118.24 Load Fluids Fluid Type Pumped (bbl)Cum (bbl)Rec. (bbl)Cum (bbl)To Rec (bbl)Balance (bbl)Weight (lb/gal)Temp (°F) Casing Type OD (in)ID (in)Weight (lb/ft)Grade Depth MD (ft) Perforations Wellbore Formation Top MD (ft)Bottom MD (ft)Shot Density (shots/ft)Phasing (°) Other In Hole Wellbore Item Run Date OD (in)Top (ft)Btm (ft)Length (ft) Operations Operations at Start:Test BOPs 24 Hr Summary:Make gauge ring runs 4.60" OD. Set down and No go at 11,060' WLM. Wire liners crew timed out for bed rest. Numerous discussion with Anchorage support team. Decide to run 3.75" OD tapered gauge ring. RIH and set down and no go at 14569' WLM. POOH. RIH with 4.5" OD tapered gauge ring. Set down at same depth of 14,569'. POOH and Rig down E line equipment. 24 Hr Forecast:BOP Test. Make up and RIH with 5.5 casing scrapper assembly on 2 7/8 and 3 1/2 production TBG. clean out well as necessary Remarks:AOGCC waived states right of witness to the BOP test. KB-RT:ft www.resourceenergysolutions.com Generated Oct 04, 2023 16:46 Page 1 of 1 Daily Completion Well Name: Country: RU-05B United States State:Alaska Activity: Well Number: 50-733-20513-02-00 API: RU-05B ESP Completion Date:Aug 4, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Tom Boyd (inacti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Paul Smith (i 9075290737206-914-7247Wes JeardoeSupervisor: Temp:57 °F Wind Speed:Up to 19 km/h Weather:Overcast Road Cond:Lease Cond:Good KB-THF:ftKB-Ground:44.01 ftKB:44.01 ft Day 9 Rig Name:Rig Release: Licence #: Rig Number:Personnel On Location:30 Safety SITP:0 psi SICP:0 psi Last BOP Press Test:Last BOP Drill: H2S:No %Last Safety Meeting:Last Rig Inspection: Time Log Time From Time To Hours Code Comments 00:00 02:30 2.50 Rig Up / Rig Out / Repair Service Rig PJSM for Rig down and move out E-Line equipment 02:30 03:00 0.50 Install or Change Wellhead PJSM. Pull out wear ring. Make up and set test plug with Vault rep. 03:00 05:30 2.50 Move Equipment / Service Rig R/U test equipment for BOP test. Fill stack and choke manifold with fresh water. Bleed air from system. 05:30 06:00 0.50 Safety Meeting PJSM on Testing BOPS 06:00 13:30 7.50 BOPS-Install / Remove / Pressure Test Weekly BOPE pressure test. Test Annular, VBR's Blind rams, Choke manifold and floor valves, to 250 psi low, 3000 psi high, 5 min each, charted. AOGCC Jim Regg waived states right of witness. 13:30 17:30 4.00 Rig Up / Rig Out / Repair Service Rig Rig up equipment for RIH with Tubing 17:30 18:00 0.50 Safety Meeting PJSM on new Plan Forward to RIH with ESP completion. 18:00 19:00 1.00 Move Equipment / Service Rig Move out Equipment and Tubulars 19:00 24:00 5.00 Run / Pull / Test Downhole Pump M/U ESP BHA. Install clamps on ESP Pumps. Stage necessary tools in work platforms. M/U ESP pumps to motors. Total: 24.00 Wellbores Wellbore KOP MD (ft)KOP TVD (ft)TD MD (ft)TD TVD (ft) Main Wellbore 17,118.24 Load Fluids Fluid Type Pumped (bbl)Cum (bbl)Rec. (bbl)Cum (bbl)To Rec (bbl)Balance (bbl)Weight (lb/gal)Temp (°F) Casing Type OD (in)ID (in)Weight (lb/ft)Grade Depth MD (ft) Perforations Wellbore Formation Top MD (ft)Bottom MD (ft)Shot Density (shots/ft)Phasing (°) Other In Hole Wellbore Item Run Date OD (in)Top (ft)Btm (ft)Length (ft) Operations Operations at Start:Picking up Summit ESP motors 24 Hr Summary:PJSM on all change of work scopes, Rig down Wire line equipment, Pull wear Ring, Make up Test Equipment, Test BOPs, Rig down BOP test equipment, Rig up Summit spoolers, install clamps on ESP pumps, pick up Summits ESP pump and make up to motors to section #3 24 Hr Forecast:RIH with ESP 2 7/8 3 1/2 completion Remarks: KB-RT:ft www.resourceenergysolutions.com Generated Oct 04, 2023 16:46 Page 1 of 1 Daily Completion Well Name: Country: RU-05B United States State:Alaska Activity: Well Number: 50-733-20513-02-00 API: RU-05B ESP Completion Date:Aug 5, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Tom Boyd (inacti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Paul Smith (i 9075290737206-914-7247Wes JeardoeSupervisor: Temp:56 °F Wind Speed:Up to 19 km/h Weather:Rain Road Cond:Lease Cond:Good KB-THF:ftKB-Ground:44.01 ftKB:44.01 ft Day 10 Rig Name:Rig Release: Licence #: Rig Number:Personnel On Location:34 Safety SITP:0 psi SICP:0 psi Last BOP Press Test:Last BOP Drill: H2S:No %Last Safety Meeting:Last Rig Inspection: Time Log Time From Time To Hours Code Comments 00:00 06:00 6.00 Run / Pull / Test Downhole Pump PJSM make up ESP motor and pumps. Hook up stainless lines and power cable check conductivity 06:00 18:00 12.00 Run / Pull / Test Downhole Pump PJSM. Perform daily inspections. Make up XO on motor RIH with 2-7/8" EUE 6.5# L80 completion tubing torque to 2250 ft/lb. Install cross collar clamps on every joint. Check conductivity every 1000'. Makeup cross over to 3-1/2" EUE on top of joint 45. 18:00 24:00 6.00 Run / Pull / Test Downhole Pump PJSM Crew change. Continue RIH with 3-1/2" EUE 9.3# L80 completion tubing. Load, strap and rabbit pipe on racks as needed. Check conductivity every 1000 ft. Install clamp on every connection. Torque 3 1/2" EUE tubing to 3030 ft/lbs. Total: 24.00 Wellbores Wellbore KOP MD (ft)KOP TVD (ft)TD MD (ft)TD TVD (ft) Main Wellbore 17,118.24 Load Fluids Fluid Type Pumped (bbl)Cum (bbl)Rec. (bbl)Cum (bbl)To Rec (bbl)Balance (bbl)Weight (lb/gal)Temp (°F) Casing Type OD (in)ID (in)Weight (lb/ft)Grade Depth MD (ft) Perforations Wellbore Formation Top MD (ft)Bottom MD (ft)Shot Density (shots/ft)Phasing (°) Other In Hole Wellbore Item Run Date OD (in)Top (ft)Btm (ft)Length (ft) Operations Operations at Start:RIH with ESP completion. 06:00 depth at 5292' MD. Re load pipe Racks as necessary. 24 Hr Summary:PJSM with all scopes of work. M/U ESP Motor/Pumps, RIH with 2 7/8" EUE Tubing and ESP Power cable clamping as to procedure. Check conductivity every 1000ft, At 45 Jts ran, cross over to 3 1/2" EUE tubing. RIH clamp as to procedure checking conductivity every 1000' MD. 24:00 depth 3860' MD 24 Hr Forecast:Continue to RIH with ESP completion as to procedure Remarks: KB-RT:ft www.resourceenergysolutions.com Generated Oct 04, 2023 16:46 Page 1 of 1 Daily Completion Well Name: Country: RU-05B United States State:Alaska Activity: Well Number: 50-733-20513-02-00 API: RU-05B ESP Completion Date:Aug 6, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Tom Boyd (inacti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Paul Smith (i 9075290737206-914-7247Wes JeardoeSupervisor: Temp:53 °F Wind Speed:Up to 19 km/h Weather:Overcast Road Cond:Lease Cond:Good KB-THF:ftKB-Ground:44.01 ftKB:44.01 ft Day 11 Rig Name:Rig Release: Licence #: Rig Number:Personnel On Location:31 Safety SITP:0 psi SICP:0 psi Last BOP Press Test:Last BOP Drill: H2S:No %Last Safety Meeting:Last Rig Inspection: Wellbores Wellbore KOP MD (ft)KOP TVD (ft)TD MD (ft)TD TVD (ft) Main Wellbore 17,118.24 Load Fluids Fluid Type Pumped (bbl)Cum (bbl)Rec. (bbl)Cum (bbl)To Rec (bbl)Balance (bbl)Weight (lb/gal)Temp (°F) Casing Type OD (in)ID (in)Weight (lb/ft)Grade Depth MD (ft) Perforations Wellbore Formation Top MD (ft)Bottom MD (ft)Shot Density (shots/ft)Phasing (°) Other In Hole Wellbore Item Run Date OD (in)Top (ft)Btm (ft)Length (ft) Operations Operations at Start:RIH with 3.5 TBG 06:00 Depth 24 Hr Summary:PJSM on all change of operations, RIH with 3.5" Tubing. Load, strap and Rabbit pipe as needed. Swap spool splice injection line and test same. Continue to RIH. Swap spool and make cable splice with Dwiggin oversight. Test same. Continue to RIH loading strapping and rabbiting tubing as necessary. 24 Hr Forecast:Continue to RIH, make up hanger splice in to hanger and land out same Remarks: KB-RT:ft www.resourceenergysolutions.com Generated Oct 04, 2023 16:47 Page 1 of 2 Daily Completion Well Name: Country: RU-05B United States State:Alaska Activity: Well Number: 50-733-20513-02-00 API: RU-05B ESP Completion Date:Aug 7, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Tom Boyd (inacti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Paul Smith (i 9075290737206-914-7247Wes JeardoeSupervisor: Time Log Time From Time To Hours Code Comments 00:00 03:30 3.50 Run / Pull / Test Downhole Pump RIH with 3.5" L-80 pipe 3050ft/lbs torque, from joint #116 to JNT #173. Testing Summit conductivity every 1000 ft 03:30 05:30 2.00 Move Equipment / Service Rig Move 3.5" L-80 tibing from upper deck to lower deck. Place in tiers, drift and tally. 05:30 06:00 0.50 Safety Meeting Held PJSM and hand over with night shift 06:00 12:00 6.00 Run / Pull / Test Downhole Pump Do daily inspections on slips , Tongs , And over head lifting equipment . Transfer 3 1/2 clamps to the work window with crane . Continue in the hole from joint 153. Summit testing conductivity every 1000 feet to joint 181. Observe 7 jts of 3.5" bent tubing on rack. Replace and drift 7 new joints and adjust tally. 181,187,189,192,197,200,207 . Continue in hole to joint 208 . Drift and tally joints 209 thru 260. 12:00 14:00 2.00 Run / Pull / Test Downhole Pump Continue to run in hole with 3 1/2 tubing from joint 209 to joint 232 14:00 15:30 1.50 Run / Pull / Test Downhole Pump Change out Summits Small cap line spool and test good. 15:30 17:30 2.00 Run / Pull / Test Downhole Pump Continue in hole with 3 1/2 tubing and ESP cables from joint 232 to 243 STOP . Summit to do splice on big reel 17:30 18:00 0.50 Safety Meeting Help summit swap empty spool Hold daily safety meeting with all services / Crew hand over meeting 18:00 20:30 2.50 Run / Pull / Test Downhole Pump Make Cable splice for Summit ESP. 20:30 24:00 3.50 Run / Pull / Test Downhole Pump RIH from JNT # 243 to JNT # 280 Checking cable continuity every 1000ft Total: 24.00 www.resourceenergysolutions.com Generated Oct 04, 2023 16:47 Page 2 of 2 Daily Completion Well Name: Country: RU-05B United States State:Alaska Activity: Well Number: 50-733-20513-02-00 API: RU-05B ESP Completion Date:Aug 7, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Tom Boyd (inacti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Paul Smith (i 9075290737206-914-7247Wes JeardoeSupervisor: Temp:54 °F Wind Speed:Up to 19 km/h Weather:Rain Road Cond:Lease Cond: KB-THF:ftKB-Ground:44.01 ftKB:44.01 ft Day 12 Rig Name:Rig Release: Licence #: Rig Number:Personnel On Location:31 Safety SITP:0 psi SICP:0 psi Last BOP Press Test:Last BOP Drill: H2S:No %Last Safety Meeting:Last Rig Inspection: Wellbores Wellbore KOP MD (ft)KOP TVD (ft)TD MD (ft)TD TVD (ft) Main Wellbore 17,118.24 Load Fluids Fluid Type Pumped (bbl)Cum (bbl)Rec. (bbl)Cum (bbl)To Rec (bbl)Balance (bbl)Weight (lb/gal)Temp (°F) Casing Type OD (in)ID (in)Weight (lb/ft)Grade Depth MD (ft) Perforations Wellbore Formation Top MD (ft)Bottom MD (ft)Shot Density (shots/ft)Phasing (°) Other In Hole Wellbore Item Run Date OD (in)Top (ft)Btm (ft)Length (ft) Operations Operations at Start:RIG down Rig, Nipple up Tree and prep for tree test Ready loads for boat 24 Hr Summary:RIH with 3.5 TBG. Test conductivity every 1000'. Tag early at 11135' MD, PJSM, Discuss with Anchorage on plan forward. POOH with 5 jt for space out. Up wt 150K RIH and make up hanger. Terminate ESP cable and cap tube lines. Make up landing jt. Land hanger. ESP assy depth = 1112.47' MD. Check conductivity, run in lock downs, test hanger to 5000 psi for 15 minutes good. Break down landing jt, install BPV. Ready loads for boat. Start tear down of RIG and BOPs 24 Hr Forecast:Tear down rig, prep for boat load out, Nipple Down BOPs, nipple up tree test same, off load and load boat, skid Drilling Rig Remarks: KB-RT:ft www.resourceenergysolutions.com Generated Oct 04, 2023 16:47 Page 1 of 2 Daily Completion Well Name: Country: RU-05B United States State:Alaska Activity: Well Number: 50-733-20513-02-00 API: RU-05B ESP Completion Date:Aug 8, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Tom Boyd (inacti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Paul Smith (i 9075290737206-914-7247Wes JeardoeSupervisor: Time Log Time From Time To Hours Code Comments 00:00 06:00 6.00 Run / Pull / Test Downhole Pump Continue to RIH from JNT # 281 to JNT # 341. 72,000 lbs. Tag up with 15ft stick up from basket hand rail. Checking ESP continuity every 1000ft Hold daily safety meeting with all services/ Hand over meeting with night shift. 06:00 18:00 12.00 Rig Up / Rig Out / Repair Service Rig Pull joints 341,340,339,338,337( String weight 150000 lbs. Summit tested ESP cables, good. Add 3) 4 foot pups under joint 337. RIH joint 337 to work window and install air slips. Remove landing joints from above 337 and install tubing hanger . Install 3 1/2 ph6 landing joint and 6 foot pup with safety valve with cross over to tubing hanger. Take string weight out of air slips and remove air slips . Put hanger at working height for Summit in work window. Summit tying in to tubing hanger with ESP cables . NOTE cleaning up work deck and bundling tubing . Putting away tools while Summit working with tubing hanger. Traveling heavy slips over camed when attempting to land hanger. Fix TSI slips RIH Land hanger with vault hand . Help vault tech run in lock down screws. RIH Clean up tools and help Summit clean tools out of work window while Vault tech test hanger seals. Hanger seals tested good. ESP landed at 11112.47' MD 18:00 24:00 6.00 Rig Up / Rig Out / Repair Service Rig Rig Down upper basket, tongs tarps, and all equipment from the window. R/D window stairs. Swing Iron skid to lower deck and Rig out hard iron. Clean up lower deck of cross overs. Rig down co-flex hoses and BOP hoses. Move window stump skid into position in order to stab jack when rigging down. Lift rig tank to drain/clean out. Pack up accumulator lines. Move to corner of lower deck. Scope down Gin Pole. Install Snubbing unit lifting joint and secure with slips. Total: 24.00 www.resourceenergysolutions.com Generated Oct 04, 2023 16:47 Page 2 of 2 Daily Completion Well Name: Country: RU-05B United States State:Alaska Activity: Well Number: 50-733-20513-02-00 API: RU-05B ESP Completion Date:Aug 8, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Tom Boyd (inacti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Paul Smith (i 9075290737206-914-7247Wes JeardoeSupervisor: Temp:55 °F Wind Speed:Up to 19 km/h Weather:Rain Road Cond:Lease Cond:Good KB-THF:ftKB-Ground:44.01 ftKB:44.01 ft Day 13 Rig Name:Rig Release: Licence #: Rig Number:Personnel On Location:31 Safety SITP:0 psi SICP:0 psi Last BOP Press Test:Last BOP Drill: H2S:No %Last Safety Meeting:Last Rig Inspection: Time Log Time From Time To Hours Code Comments 00:00 01:30 1.50 Rig Up / Rig Out / Repair Service Rig Attach crane to HWO unit and remove guy lines. Remove HWO and work window off of well. Stab complete unit onto stand/stump and guy off. Unhook crane. 01:30 03:30 2.00 BOPS-Install / Remove / Pressure Test Break down BOP's, install on BOP stand and move to storage area on upper deck. Remove riser spool and lay down to storage area. 03:30 05:30 2.00 Install or Change Wellhead Install Well Head Tree. Remove BPV and install 2 way check 05:30 06:00 0.50 Safety Meeting Daily safety meeting with all services / Crew hand over meeting with nights 06:00 12:00 6.00 Move Equipment / Service Rig Install wing valves. Test tree to 5000 psi 15 min. Good test. Turn well over to production at 12:00 hrs 8/9/23 12:00 17:30 5.50 Rig Up / Rig Out / Repair Service Rig Continue to get loads ready for boat and make room for equipment offload to platform. 17:30 24:00 6.50 Rig Up / Rig Out / Repair Service Rig Unload boat onto platform . Unload HCL totes, drums, and TSI Carrier from Endeavor to Osprey. Load boat with TSI accumulator unit, Choke manifold, Pump skid, Pit/tank, Summit equipment, AK E-line perf gun box, etc. Stab HWO/Snubbing unit onto lay down stand and lay over. Remove hoses and lift HWO back off of stand and lay horizontally on deck in preparation to load onto Endeavor. Total: 24.00 Wellbores Wellbore KOP MD (ft)KOP TVD (ft)TD MD (ft)TD TVD (ft) Main Wellbore 17,118.24 Load Fluids Fluid Type Pumped (bbl)Cum (bbl)Rec. (bbl)Cum (bbl)To Rec (bbl)Balance (bbl)Weight (lb/gal)Temp (°F) Casing Type OD (in)ID (in)Weight (lb/ft)Grade Depth MD (ft) Perforations Wellbore Formation Top MD (ft)Bottom MD (ft)Shot Density (shots/ft)Phasing (°) Other In Hole Wellbore Item Run Date OD (in)Top (ft)Btm (ft)Length (ft) Operations Operations at Start:Ready Drill Rig for Skid Ready loads for offload 24 Hr Summary:PTSMs x2 Rig down snubbing unit and window. Nipple down BOPs, Nipple up Tree, Ready loads for off load, on/off load work boat Stab HWO onto stand lay over same 24 Hr Forecast:Wait on work boat to return, organize deck for space, install skid rams ready drill Rig for skid Remarks:Turn well over to production at 12:00 hrs 8/9/23 KB-RT:ft www.resourceenergysolutions.com Generated Oct 04, 2023 16:47 Page 1 of 1 Daily Completion Well Name: Country: RU-05B United States State:Alaska Activity: Well Number: 50-733-20513-02-00 API: RU-05B ESP Completion Date:Aug 9, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Tom Boyd (inacti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Paul Smith (i 9075290737206-914-7247Wes JeardoeSupervisor: Temp:°F Wind Speed:Weather:Road Cond:Lease Cond: KB-THF:ftKB-Ground:44.01 ftKB:44.01 ft Day 14 Rig Name:Rig Release: Licence #: Rig Number:Personnel On Location: Safety SITP:0 psi SICP:0 psi Last BOP Press Test:Last BOP Drill: H2S:No %Last Safety Meeting:Last Rig Inspection: Time Log Time From Time To Hours Code Comments Total: Wellbores Wellbore KOP MD (ft)KOP TVD (ft)TD MD (ft)TD TVD (ft) Main Wellbore 17,118.24 Load Fluids Fluid Type Pumped (bbl)Cum (bbl)Rec. (bbl)Cum (bbl)To Rec (bbl)Balance (bbl)Weight (lb/gal)Temp (°F) Casing Type OD (in)ID (in)Weight (lb/ft)Grade Depth MD (ft) Perforations Wellbore Formation Top MD (ft)Bottom MD (ft)Shot Density (shots/ft)Phasing (°) Other In Hole Wellbore Item Run Date OD (in)Top (ft)Btm (ft)Length (ft) Operations Operations at Start: 24 Hr Summary: 24 Hr Forecast: Remarks: KB-RT:ft www.resourceenergysolutions.com Generated Oct 04, 2023 16:47 Page 1 of 1 Daily Completion Well Name: Country: RU-05B United States State:Alaska Activity: Well Number: 50-733-20513-02-00 API: RU-05B ESP Completion Date:Aug 14, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Tom Boyd (inacti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Paul Smith (i 9075290737206-914-7247Wes JeardoeSupervisor: Temp:°F Wind Speed:Weather:Road Cond:Lease Cond: KB-THF:ftKB-Ground:44.01 ftKB:44.01 ft Day 15 Rig Name:Rig Release: Licence #: Rig Number:Personnel On Location: Safety SITP:0 psi SICP:0 psi Last BOP Press Test:Last BOP Drill: H2S:No %Last Safety Meeting:Last Rig Inspection: Time Log Time From Time To Hours Code Comments Total: Wellbores Wellbore KOP MD (ft)KOP TVD (ft)TD MD (ft)TD TVD (ft) Main Wellbore 17,118.24 Load Fluids Fluid Type Pumped (bbl)Cum (bbl)Rec. (bbl)Cum (bbl)To Rec (bbl)Balance (bbl)Weight (lb/gal)Temp (°F) Casing Type OD (in)ID (in)Weight (lb/ft)Grade Depth MD (ft) Perforations Wellbore Formation Top MD (ft)Bottom MD (ft)Shot Density (shots/ft)Phasing (°) Other In Hole Wellbore Item Run Date OD (in)Top (ft)Btm (ft)Length (ft) Operations Operations at Start: 24 Hr Summary: 24 Hr Forecast: Remarks: KB-RT:ft www.resourceenergysolutions.com Generated Oct 04, 2023 16:47 Page 1 of 1 Daily Completion Well Name: Country: RU-05B United States State:Alaska Activity: Well Number: 50-733-20513-02-00 API: RU-05B ESP Completion Date:Aug 16, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Tom Boyd (inacti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Paul Smith (i 9075290737206-914-7247Wes JeardoeSupervisor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y Grace Christianson at 9:20 am, May 11, 2023 323-278 Zach Tomco Digitally signed by Zach Tomco DN: cn=Zach Tomco, o=Cook Inlet Energy, ou=Cook Inlet Energy, email=ztomco@glacieroil.com, c=US Date: 2023.05.11 08:42:56 -08'00' BJM 7/26/23 20 AAC 25.055 SFD 10-404 No Flow Test must be performed no more than 60 days after installation of new ESP completion. DSR-5/12/23 , UNDEFINED OIL SFD SFD 6/8/2023 BOP test to 3000 psi. Set test packer or plug at >14,000' MD and pressure test casing/liner to 1500 psi. X GCW 07/26/2023JLC 7/26/2023 07/26/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.07.26 19:44:53 -06'00' RBDMS JSB 072823 DĂǇϭϭƚŚ͕ϮϬϮϯ ŽŵŵŝƐƐŝŽŶĞƌ:ĞƐƐŝĞŚŵŝĞůŽǁƐŬŝ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ ϯϯϯtĞƐƚϳƚŚǀĞŶƵĞ͕^ƵŝƚĞϭϬϬ ŶĐŚŽƌĂŐĞ͕ůĂƐŬĂϵϵϱϬϭ Z͗ ƉƉůŝĐĂƚŝŽŶĨŽƌ^ƵŶĚƌǇ ŽŽŬ/ŶůĞƚŶĞƌŐǇ͕>>͕Ă'ůĂĐŝĞƌKŝůĂŶĚ'ĂƐŽŵƉĂŶǇ;'>Ϳ͗ZĞĚŽƵďƚhŶŝƚηϱ ZhͲϬϱWĞƌŵŝƚƚŽƌŝůů͗ϮϭϯͲϭϬϳ W/EŽ͗͘ϱϬͲϳϯϯͲϮϬϱϭϯͲϬϮͲϬϬ ĞĂƌŽŵŵŝƐƐŝŽŶĞƌ͕ ŽŽŬ/ŶůĞƚŶĞƌŐǇŚĞƌĞďǇƐƵďŵŝƚƐĂƐƵŶĚƌǇĂƉƉůŝĐĂƚŝŽŶĨŽƌZĞĚŽƵďƚhŶŝƚϬϱ͕Wd͗ϮϭϯͲϭϬϳ͕ ƌĞƋƵĞƐƚŝŶŐƉĞƌŵŝƐƐŝŽŶƚŽĂĐŝĚƐƚŝŵƵůĂƚĞ͕ƉƵůůƚŚĞ^WĐŽŵƉůĞƚŝŽ Ŷ͕ƌĞͲƉĞƌĨŽƌĂƚĞ͕ĂĚĚŶĞǁ ƉĞƌĨŽƌĂƚŝŽŶƐ͕ĂŶĚƌƵŶĂŶĞǁ^WŽŵƉůĞƚŝŽŶ͘ dŚĞĂĐŝĚƐƚŝŵƵůĂƚŝŽŶǁŽƵůĚŽĐĐƵƌďĞĨŽƌĞƚŚĞƌŝŐƐŚŽǁĞĚƵƉŽŶƐŝ ƚĞ͘dŚĞƉĞƌĨŽƌĂƚŝŽŶŽƉĞƌĂƚŝŽŶŝƐ ĞǆƉĞĐƚĞĚƚŽƚĂŬĞƉůĂĐĞƉƌŝŽƌƚŽƚŚĞƌĞͲĐŽŵƉůĞƚŝŽŶŽƉĞƌĂƚŝŽŶ͘ /ƚŝƐĂůƐŽƌĞƋƵĞƐƚĞĚƚŚĂƚĂŶŽĨůŽǁƚĞƐƚǁŝůůďĞƉĞƌĨŽƌŵĞĚƚŽŽŵŝƚƚŚĞǀĞŶƚǀĂůǀĞ͕ƉƌŽĚƵĐƚŝŽŶƉĂĐŬĞƌ͕ ĂŶĚƐƵďƐƵƌĨĂĐĞƐĂĨĞƚǇǀĂůǀĞǁŝƚŚŝŶϯϬĚĂǇƐ͕ĂƐĐŽŶƐŝƐƚĞŶƚǁŝƚŚƚŚĞĐƵƌƌĞŶƚĐŽŵƉůĞƚŝŽŶ͘ /ĨǇŽƵŚĂǀĞĂŶǇƋƵĞƐƚŝŽŶƐ͕ƉůĞĂƐĞĐŽŶƚĂĐƚŵĞĂƚ;ϵϬϳͿϳϭϱͲϭϮϰϰ͘ ^ŝŶĐĞƌĞůǇ͕ ĂĐŚĂƌǇdŽŵĐŽ &ĂĐŝůŝƚŝĞƐŶŐŝŶĞĞƌ ŽŽŬ/ŶůĞƚŶĞƌŐǇ͕>>;Ă'ůĂĐŝĞƌKŝůΘ'ĂƐǁŚŽůůǇŽǁŶĞĚĐŽŵƉĂŶǇͿ ϭϴϴt͘EŽƌƚŚĞƌŶ>ŝŐŚƚƐůǀĚ͕^dϱϭϬ ŶĐŚŽƌĂŐĞ͕<ϵϵϱϬϯ ϭ͘t>>EDʹZhͲϬϱ ZĞƋƵŝƌĞŵĞŶƚƐŽĨϮϬϮϱ͘ϬϬϱ;ĨͿ tĞůů^ƵŵŵĂƌǇ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗ dŚĞǁĞůůŝƐƐŚƵƚŝŶǁŝƚŚĂĨĂŝůĞĚ^WĐŽŵƉůĞƚŝŽŶ͘ ǆŝƐƚŝŶŐWĞƌĨŽƌĂƚŝŽŶƐ D;ĨƚͿ ds;ĨƚͿ ϭϰ͕ϳϴϲ ϭϰ͕ϳϵϵ ϭϭ͕ϵϱϮ ϭϭ͕ϵϱϵ ϭϰ͕ϳϵϵ ϭϰ͕ϴϬϵ ϭϭ͕ϵϱϵ ϭϭ͕ϵϲϱ ϭϰ͕ϴϬϵ ϭϰ͕ϴϭϭ ϭϭ͕ϵϲϱ ϭϭ͕ϵϲϲ ϭϰ͕ϴϭϭ ϭϰ͕ϴϮϭ ϭϭ͕ϵϲϲ ϭϭ͕ϵϳϮ ϭϰ͕ϴϮϭ ϭϰ͕ϴϰϴ ϭϭ͕ϵϳϮ ϭϭϵϴϵ ϭϰ͕ϴϲϬ ϭϰ͕ϴϲϱ ϭϭ͕ϵϵϱ ϭϭ͕ϵϵϵ ϭϰ͕ϴϲϱ ϭϰ͕ϴϴϬ ϭϭ͕ϵϵϵ ϭϮ͕ϬϬϵ ϭϰ͕ϴϴϬ ϭϰ͕ϵϯϰ ϭϮ͕ϬϬϵ ϭϮ͕ϬϰϮ ϭϰ͕ϵϱϲ ϭϰ͕ϵϱϴ ϭϮ͕Ϭϱϳ ϭϮ͕Ϭϱϴ ϭϰ͕ϵϱϴ ϭϰ͕ϵϲϴ ϭϮ͕Ϭϱϴ ϭϮ͕Ϭϲϱ ϭϰ͕ϵϲϴ ϭϰ͕ϵϳϮ ϭϮ͕Ϭϲϱ ϭϮ͕Ϭϲϴ ϭϰ͕ϵϳϮ ϭϰ͕ϵϴϳ ϭϮ͕Ϭϲϴ ϭϮ͘Ϭϳϴ ϭϰ͕ϵϴϳ ϭϰ͕ϵϵϰ ϭϮ͘Ϭϳϴ ϭϮϬϴϮ ϭϱ͕ϬϬϳ ϭϱ͕Ϭϭϴ ϭϮ͕Ϭϵϭ ϭϮ͕Ϭϵϴ ZĞƚĂŝŶĞƌΛϭϱ͕ϭϭϰΖ ϭϱ͕ϭϭϲ ϭϱ͕ϭϰϬ ϭϮ͕ϭϲϲ ϭϮ͕ϭϴϯ ϭϱ͕ϭϳϭ ϭϱ͕ϭϴϰ ϭϮ͕ϮϬϲ ϭϮ͕Ϯϭϱ ϭϱ͕Ϯϲϱ ϭϱ͕ϮϳϮ ϭϮ͕Ϯϳϰ ϭϮ͕ϮϴϬ ϭϱ͕ϯϬϰ ϭϱ͕ϯϮϲ ϭϮ͕ϯϬϯ ϭϮϯϮϬ ϭϱ͕ϯϱϲ ϭϱ͕ϯϲϮ ϭϮ͕ϯϰϯ ϭϮ͕ϯϰϳ ϭϱ͕ϯϳϴ ϭϱ͕ϯϴϲ ϭϮ͕ϯϲϬ ϭϮ͕ϯϲϲ ZhϱZĞͲWĞƌĨƐ D;ĨƚͿ ds;ĨƚͿ ϭϰϴϬϬ ϭϰϴϰϴϭϭϵϲϬ ϭϭϵϴϵ ϭϰϴϲϬ ϭϰϵϯϰϭϭϵϵϳ ϭϮϬϰϯ ϭϰϵϲϴ ϭϰϵϵϰϭϮϬϲϲ ϭϮϬϴϯ ϭϱϬϬϳ ϭϱϬϭϴϭϮϬϵϭ ϭϮϬϵϵ ZhϱWĞƌĨĚĚƐ D;ĨƚͿ ds;ĨƚͿ ϭϰϴϰϴ ϭϰϴϲϬϭϭϵϴϵ ϭϭϵϵϳ ϭϰϵϯϰ ϭϰϵϰϱϭϮϬϰϯ ϭϮϬϱϬ ϭϰϵϵϰ ϭϱϬϬϳϭϮϬϴϯ ϭϮϬϵϭ ϭϱϬϭϴ ϭϱϬϮϴϭϮϬϵϵ ϭϮϭϬϱ ^ĐŽƉĞŽĨtŽƌŬ͗ x<ŝůůǁĞůů xĐŝĚ^ƚŝŵƵůĂƚĞǁĞůůďŽƌĞƉƌŝŽƌƚŽĂƌƌŝǀĂůŽĨƌŝŐ xZŝŐƵƉdĞĂŵ^ŶƵďďŝŶŐ;d͘^ͿZŝŐ xWƵůů^WĐŽŵƉůĞƚŝŽŶĂŶĚƚƵďŝŶŐ xWͬhǁŽƌŬƐƚƌŝŶŐĂŶĚŵĂŬĞĐůĞĂŶŽƵƚƌƵŶ xZ/,ǁŝƚŚƉĞƌĨŐƵŶƐĂŶĚƉĞƌĨŽƌĂƚĞƐĞůĞĐƚĞĚǌŽŶĞƐ xWͬh^WŽŵƉůĞƚŝŽŶĂŶĚZ/,ƚŽнͬͲϭϰ͕ϱϱϱ͛D xEͬKWΘEͬhWƌŽĚƵĐƚŝŽŶdƌĞĞ xdƵƌŶŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶĂŶĚĨůŽǁǁĞůů 'ĞŶĞƌĂůtĞůů/ŶĨŽƌŵĂƚŝŽŶ͗ ZĞƐĞƌǀŽŝƌWƌĞƐƐƵƌĞͬds͗ Ϭ͘ϯϮƉƐŝͬĨƚ ϰ͕ϬϬϬƉƐŝΛϭϱ͕ϯϴϲ͛D;ϭϮ͕ϯϲϲ͛dsͿ D^W͗ ZĞƐĞƌǀŽŝƌWƌĞƐƐƵƌĞʹ;'ĂƐ'ƌĂĚŝĞŶƚydsͿ ;Ϭ͘ϯϮƉƐŝͬĨƚyϭϮ͕ϯϲϲ͛dsͿʹ;Ϭ͘ϭƉƐŝͬĨƚyϭϮ͕ϯϲϲ͛dsͿ сϰ͕ϬϬϬƉƐŝʹϭϮϯϲƉƐŝсϮ͕ϳϲϰƉƐŝ tĞůůŚĞĂĚdǇƉĞͬWƌĞƐƐƵƌĞZĂƚŝŶŐ͗ ϭϯϱͬϴ͟ϱDtĞůůŚĞĂĚͲϯϭͬϮ͟ϱDƚƌĞĞ KW͗ϭϯϱͬϴ͟ϯDʹWŝƉĞZĂŵƐͬůŝŶĚZĂŵƐͬŶŶƵůĂƌ tĞůůdǇƉĞ͗KŝůtĞůů ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗ :ƵŶĞϮϱ͕ϮϬϮϯ tĂŝǀĞƌƐZĞƋƵĞƐƚĞĚ͗ ŶŽͲĨůŽǁƚĞƐƚďĞƉĞƌĨŽƌŵĞĚƚŽŽŵŝƚƚŚĞǀĞŶƚǀĂůǀĞ͕ƉƌŽĚƵĐƚŝŽŶ ƉĂĐŬĞƌ͕ ĂŶĚ ƐƵďͲƐƵƌĨĂĐĞ ƐĂĨĞƚǇ ǀĂůǀĞ ĨƌŽŵ ƚŚĞ ĐŽŵƉůĞƚŝŽŶ ǁŝƚŚŝŶϯϬĚĂǇƐ͘ WƌŽŐƌĂŵ WƌĞͲZŝŐ ϭ͘ŽŶĚƵĐƚƉƌĞͲũŽďƐĂĨĞƚǇŵĞĞƚŝŶŐǁŝƚŚĂůůƉĞƌƐŽŶŶĞůŽŶůŽĐĂƚŝŽŶ oZĞǀŝĞǁƵƉĐŽŵŝŶŐǁŽƌŬĂŶĚĚŝƐĐƵƐƐƐĂĨĞƚǇĨŝƌƐƚ Ϯ͘^ƚĂŐĞ/^KŽĨϭϱй,ůͬŵƵƚƵĂůƐŽůǀĞŶƚ ϯ͘^ƚĂŐĞĐŽŶƚĂŝŶŵĞŶƚŵĂƚĞƌŝĂůƐĨŽƌĂůůŚŽƐĞĂŶĚƉŝƉŝŶŐĐŽŶŶĞĐƚŝŽŶƐ ϰ͘DĂŝŶƚĂŝŶůŽŐĚƵƌŝŶŐƵƉĐŽŵŝŶŐĂĐŝĚŝŶũĞĐƚŝŽŶŽƉĞƌĂƚŝŽŶƵƚŝůŝǌŝŶŐ ƉƌĞǀŝŽƵƐĂĐŝĚũŽďƚĞŵƉůĂƚĞ͘ ĐŝĚ/ŶũĞĐƚŝŽŶ ϭ͘WƌĞƉǁĞůůĨŽƌĂĐŝĚƚƌĞĂƚŵĞŶƚŽĨ^W Ϯ͘ZŝŐhƉWƌŽĚƵĐĞĚtĂƚĞƌĨƌŽŵZhͲϭƚŽZhͲϬϱĂŶĚƉĞƌĨŽƌŵƉƌĞͲũŽďƐĂĨĞƚǇŵĞĞƚŝŶŐ ϯ͘WƌĞƐƐƵƌĞƚĞƐƚŚŽƐĞƐ͕ĐŽŶŶĞĐƚŝŽŶƐ͕ĞƚĐƚŽϭϬϬϬƉƐŝ oDĂǆŝŵƵŵĂŶƚŝĐŝƉĂƚĞĚƚƌĞĂƚŝŶŐƉƌĞƐƐƵƌĞŝƐϭϬϬϬƉƐŝ ϰ͘tĂůŬZhͲϭĐŚŽŬĞƵƉƵŶƚŝůϱϬϬďƉĚŝƐǀŝĞǁĞĚĨƌŽŵZhͲϭ&ůŽǁdƌĂŶƐŵŝƚƚĞƌ oϱ͘ϱďĞĂŶƐĞƚƉŽŝŶƚŝƐĐĂůĐƵůĂƚĞĚƚŽŽďƚĂŝŶƚŚŝƐĨůŽǁƌĂƚĞ ϱ͘sĞƌŝĨǇW/dͲϬϳͲϯϮW^,ŚĂƐďĞĞŶƐĞƚƚŽϭϱϬϬƉƐŝŐ͘ ϲ͘KƉĞŶƚƵďŝŶŐĂŶĚĂŶŶƵůƵƐĂŶĚĐŽŶĨŝƌŵĐŝƌĐƵůĂƚŝŽŶ ϳ͘&ůƵŝĚƉĂĐŬƚŚĞǁĞůůĂŶĚĚŝƐƉůĂĐĞƚƵďŝŶŐǀŽůƵŵĞƵƐŝŶŐƉƌŽĚƵĐĞĚǁĂƚĞƌ oŽŶŽƚĞǆĐĞĞĚϮWD oŽŶƚŝŶƵŽƵƐůǇŵŽŶŝƚŽƌĂŶŶƵůĂƌƉƌĞƐƐƵƌĞƚŚƌŽƵŐŚƚŚĞƌĞŵĂŝŶĚĞƌŽĨƚŚŝƐŽƉĞƌĂƚŝŽŶ͘ ůĞĞĚƚŚĞƌŵĂůĞǆĐƵƌƐŝŽŶƐͬŽǀĞƌƉƌĞƐƐƵƌĞĂƐŶĞĞĚĞĚ͘ ϴ͘ZĞĐŽƌĚĨůŽǁƌĂƚĞĨƌŽŵZhͲϭ&/d͘ ϵ͘^ŚƵƚŝŶĂŶĚǁĂŝƚĂƉĞƌŝŽĚŽĨŽŶĞŚŽƵƌ ϭϬ͘tŚŝůĞŵŽŶŝƚŽƌŝŶŐͬƌĞĐŽƌĚŝŶŐǁĞůůŚĞĂĚƉƌĞƐƐƵƌĞĂŶĚǁĂƚĞƌǀŽůƵŵĞůŝŶĞƵƉWtĚŽǁŶƚƵďŝŶŐ ĂŶĚŶŽƚĞǀŽůƵŵĞŶĞĐĞƐƐĂƌǇƚŽƐĞĞĂƐƉŝŬĞŝŶƉƌĞƐƐƵƌĞ͘ o^ƚĞƉƐϳĂŶĚϴŽĐĐƵƌƚŽĚĞƚĞƌŵŝŶĞŚŽǁŵƵĐŚůŝƋƵŝĚƚŚĞǁĞůů͞ĚƌŝŶŬƐ͟ďĞĨŽƌĞƚŚĞŚŝŐŚͲ ƉƌĞƐƐƵƌĞůŝŵŝƚƐŽĨƚŚĞKĂƌĞƌĞĂĐŚĞĚ͘ odŚŝƐǁŝůůďĞƵƐĞĚƚŽĞǀĂůƵĂƚĞŚŽǁůŽŶŐƚŚĞƉƌŽĐĞĚƵƌĞǁŝůůƚĂŬĞ ϭϭ͘>ŝŶĞͲƵƉϮďďůŽĨĚŝĞƐĞůƚŽŝƌKƉĞƌĂƚĞĚŽƵďůĞŝĂƉŚƌĂŐŵ;KͿƉƵŵƉĂŶĚƉƵŵƉĚŽǁŶƚŚĞ ƚƵďŝŶŐ oŽŶŽƚĞǆĐĞĞĚϮWDŝŶũĞĐƚŝŽŶƌĂƚĞ dƵƌŶŽĨĨK ϭϯ͘>ŝŶĞͲƵƉĂĐŝĚƚŽKĂŶĚƉƵŵƉĚŽǁŶƚŚĞƚƵďŝŶŐ oϭ/^K;Εϭϭϵ>ͿŽĨϭϱй,ůͬŵƵƚƵĂůƐŽůǀĞŶƚ oŽŶŽƚĞǆĐĞĞĚϮWDŝŶũĞĐƚŝŽŶƌĂƚĞ Acid job will not be performed per Z. Tomco 7/26/23 email. No Flow Test required within 60 days following installation of new ESP. See attached email from J. Regg. -bjm ϭϰ͘dƵƌŶŽĨĨK ϭϱ͘>ŝŶĞͲƵƉϮďďůŽĨĚŝĞƐĞůƚŽKĂŶĚƉƵŵƉĚŽǁŶƚŚĞƚƵďŝŶŐ oŽŶŽƚĞǆĐĞĞĚϮWDŝŶũĞĐƚŝŽŶƌĂƚĞ ϭϲ͘>ŝŶĞƵƉWtƚŽƚƵďŝŶŐĂŶĚƉƌĞƉĨŽƌƐǇƐƚĞŵĨůƵƐŚĂŶĚŚĞƐŝƚĂƚŝŽŶƐƋƵĞĞǌĞ ϭϳ͘ĞůŝǀĞƌϭϭϳ>ŽĨƉƌŽĚƵĐĞĚǁĂƚĞƌĚŽǁŶƚƵďŝŶŐ͘ oDŽŶŝƚŽƌĂŶĚƌĞĐŽƌĚƉƵŵƉƉƌĞƐƐƵƌĞĂŶĚĨůŽǁƚŚƌŽƵŐŚŽƵƚŽƉĞƌĂƚŝŽŶ ŽŵƉĂƌĞƚŽ:ƵŶĞϮϬϮϮ^ĐŚůƵŵďĞƌŐĞƌZĞƉŽƌƚ oŽŶŽƚĞǆĐĞĞĚ͘ϯϰWD;dŚŝƐŝƐƚŚĞƌĂƚĞůŝŵŝƚĨŽƌƚŚĞZhͲϭ&/dͿ oĐŝĚǁŝůůŶŽǁďĞŝŶĐŽŶƚĂĐƚǁŝƚŚƚŚĞƉĞƌĨƐ͘ ϭϴ͘^ŚƵƚͲŝŶƚƵďŝŶŐĂŶĚĂŶŶƵůƵƐ͕ŵŽŶŝƚŽƌƐƵƌĨĂĐĞƉƌĞƐƐƵƌĞ ϭϵ͘ŝǀĞƌƚWtďĂĐŬƚŽŝŶũĞĐƚŝŽŶ oĐŝĚŝŶƚƵďŝŶŐǁŝůůďĞĚŝůƵƚĞĚǁŝƚŚƉƌŽĚƵĐĞĚĨůƵŝĚƐ oĐŝĚũŽďĨůƵŝĚƐĐĂŶďĞƉƌŽĐĞƐƐĞĚĂƚ<W& ϮϬ͘ZŝŐĚŽǁŶĂĐŝĚũŽďĞƋƵŝƉŵĞŶƚ WƌĞͲZŝŐ ϭ͘ZŝŐƵƉWƌŽĚƵĐĞĚtĂƚĞƌǀŝĂZhͲϭĨůŽǁƉĂƚŚ Ϯ͘ZŝŐƵƉͲ>ŝŶĞĂŶĚƚĞƐƚůƵďƌŝĐĂƚŽƌƚŽϯ͕ϬϬϬƉƐŝ ϯ͘Z/,ǁŝƚŚƚƵďŝŶŐƉƵŶĐŚƚŽϭϰ͕ϯϬϬ͛ĂŶĚƉĞƌĨŽƌĂƚĞƚƵďŝŶŐĂďŽǀĞ^W, ϰ͘<ŝůůǁĞůůǁŝƚŚϴ͘ϱƉƉŐƉƌŽĚƵĐĞĚǁĂƚĞƌ ϱ͘ŶƐƵƌĞƚŚĂƚǁĞůůŝƐĚĞĂĚ ZŝŐtŽƌŬŽǀĞƌ ϭ͘DŽǀĞdĞĂŵ^ŶƵďďŝŶŐZŝŐŽŶƚŽZhͲϬϱ͘ Ϯ͘ŚĞĐŬĨŽƌƉƌĞƐƐƵƌĞĂŶĚŶŽƚĞƉƌĞƐƐƵƌĞŝŶƚƵďŝŶŐĂŶĚŝŶĂŶŶƵůƵƐ͘ ϯ͘ZͬůŝŶĞƐĨƌŽŵƚƌĞĞĂŶĚĂŶŶƵůƵƐƚŽƉƌŽĚƵĐƚŝŽŶŝĨŶŽƚĚŽŶĞƉƌŝŽƌ ƚŽƌŝŐŵŽǀĞ͘ ϰ͘ŚĞĐŬĨŽƌĨůŽǁ͕ĞŶƐƵƌĞǁĞůůŝƐĚĞĂĚĂŶĚƐŚƵƚŝŶǁĞůů͘ ϱ͘WůĂĐĞďĂĐŬƉƌĞƐƐƵƌĞǀĂůǀĞŝŶǁĞůůŚĞĂĚ͘ ϲ͘EŽƚŝĨǇK'ϰϴŚŽƵƌƐŝŶĂĚǀĂŶĐĞŽĨƐƚĂƌƚŽĨŽƉĞƌĂƚŝŽŶƐĂŶĚƵƉĐŽŵŝŶŐKWƚĞƐƚ͘ ϳ͘EͬWƌŽĚƵĐƚŝŽŶdƌĞĞ͘ ϴ͘EͬhĂŶĚdĞƐƚϭϯϱͬϴ͟KWǁŝƚŚϮϳͬϴ͟ǆϱ͟sZƌĂŵƐǁŝƚŚďůŝŶĚƐŝŶŵŝĚĚůĞ͘ ϵ͘dĞƐƚKWŽŶϯЪ͟ƚŽϮϱϬƉƐŝůŽǁͬϯϬϬϬƉƐŝŚŝŐŚĂŶĚĐŚĂƌƚ͘ ϭϬ͘ZŝŐƵƉ^WƐƉŽŽůĞƌƐĂŶĚŚĂƌĚǁĂƌĞ͘ ϭϭ͘ZĞŵŽǀĞďĂĐŬƉƌĞƐƐƵƌĞǀĂůǀĞ͘ ϭϮ͘Wͬh>ĂŶĚŝŶŐ:ŽŝŶƚĂŶĚŵĂŬĞƵƉƚŽϯϭͬϮ͟dƵďŝŶŐ,ĂŶŐĞƌ͘ Ă͘DĂǆƉƵůůŶŽƚƚŽĞǆĐĞĞĚϭϲϱ͕ϬϬϬǁŝƚŚŽƵƚŵĂŶĂŐĞŵĞŶƚĂƉƉƌŽǀĂů ŝ͘ϴϬйzŝĞůĚŽĨϯͲϭͬϮ͟ϵ͘ϯη>ͲϴϬ ŝŝ͘tͬKtĞŝŐŚƚŽĨůŽĐŬƐ ϭϯ͘ĂĐŬŽƵƚ>ŽĐŬŽǁŶƐĐƌĞǁƐŝŶdƵďŝŶŐ,ĂŶŐĞƌ͘ Ensure hydrocarbons are displaced from both tubing and IA before pulling tubing. -bjm ϭϰ͘WƵůůΘ>ͬϯϭͬϮ͟>ĂŶĚŝŶŐ:ŽŝŶƚĂŶĚdƵďŝŶŐ,ĂŶŐĞƌ͘ ϭϱ͘ŚĞĐŬĨŽƌ&ůŽǁĂŶĚĐŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚ͘ ϭϲ͘WK,ĂŶĚ>ͬƚŚĞĨŽůůŽǁŝŶŐ͗ Ă͘ϯϭͬϮ͟>ĂŶĚŝŶŐ:ŽŝŶƚ ď͘dƵďŝŶŐ,ĂŶŐĞƌ Đ͘ϯϭͬϮ͟dƵďŝŶŐ Ě͘^WĂďůĞ Ğ͘^WŚĞŵŝĐĂů/ŶũĞĐƚŝŽŶ>ŝŶĞƐ Ĩ͘^W, ϭϳ͘EŽƚĞĂŶǇŝƐƐƵĞƐǁŝƚŚĞƋƵŝƉŵĞŶƚĂŶĚƉƌĞƉĨŽƌŐĂƵŐĞƌƵŶ ϭϴ͘ZͬhWŽůůĂƌĚ^ůŝĐŬůŝŶĞĂŶĚdĞƐƚ>ƵďƌŝĐĂƚŽƌ ϭϵ͘DĂŬĞ'ĂƵŐĞZŝŶŐZƵŶ Ă͘EŽƚĞĂŶǇƚĂŐͲƵƉŽƌƚŝŐŚƚŝŶƚĞƌǀĂůƐ ϮϬ͘ZͬWŽůůĂƌĚ^ůŝĐŬůŝŶĞ Ϯϭ͘WͬhϯͲϭͬϮ͟tŽƌŬƐƚƌŝŶŐĂŶĚĂƐŝŶŐ^ĐƌĂƉĞƌƐ ϮϮ͘Z/,ǁŝƚŚƐĐƌĂƉĞƌƐƚŽϭϰ͕ϲϬϬ͛D Ă͘EŽƚĞĂŶǇƚĂŐͲƵƉŽƌƚŝŐŚƚŝŶƚĞƌǀĂůƐ Ϯϯ͘ŝƌĐƵůĂƚĞďŽƚƚŽŵƐƵƉϰƚŝŵĞƐĂŶĚƉƌĞƉƚŽWK, Ϯϰ͘>ͬtŽƌŬ^ƚƌŝŶŐĂŶĚƉƌĞƉĨŽƌƉĞƌĨŽƌĂƚŝŶŐƌƵŶ Ϯϱ͘ZŝŐƵƉͲ>ŝŶĞhŶŝƚΘWͬh'ƵŶƐ Ϯϲ͘ZĞͲWĞƌĨŽƌĂƚĞĂŶĚĂĚĚŶĞǁƉĞƌĨŽƌĂƚŝŽŶƐƚŽƐĞůĞĐƚĞĚǌŽŶĞƐǀŝĂͲ>ŝŶĞ͗ dŽƚĂůWĞƌĨŽƌĂƚŝŽŶƐ D;ĨƚͿ ds;ĨƚͿ ϭϰϴϬϬ ϭϰϵϰϱϭϭϵϲϬϭϮϬϱϬ ϭϰϵϲϴ ϭϱϬϮϴϭϮϬϲϲ ϭϮϭϬϱ Ϯϳ͘DŽŶŝƚŽƌƚƌŝƉƚĂŶŬĨŽƌƉƌŽƉĞƌŚŽůĞĨŝůůŝŶŐ͘ Ϯϴ͘WƌĞƉƚŽƉŝĐŬƵƉ^WŽŵƉůĞƚŝŽŶĞƋƵŝƉŵĞŶƚ͕ƐƉŽŽůĞƌƐ͕ĂŶĚƚŽŽůƐ͘ Ϯϵ͘ZŝŐƵƉ^ƵŵŵŝƚĨŽƌ^WŽŵƉůĞƚŝŽŶƐ͘ Ă͘,ŽůĚW:^DĨŽƌ^WZƵŶ͘ ď͘dĞƐƚĂŶĚĐŽŶĨŝƌŵƚŚĂƚĂůůĞƋƵŝƉŵĞŶƚŝƐŽŶůŽĐĂƚŝŽŶĂŶĚƌĞĂĚǇƚŽ Z/,͘ Đ͘EKd͗KDW>d/KE^Wͬdh/E't/>>EKdZKdd͘ ϯϬ͘WŝĐŬƵƉƚŚĞ^WĐŽŵƉůĞƚŝŽŶĂƐƐĞŵďůǇĂƐĚŝƌĞĐƚĞĚ͘ Ă͘EKd͗^ĞƚƚŝŶŐĚĞƉƚŚŽĨ^W,ĂƚнͬͲϭϰ͕ϱϱϱ͛D;ŽŶĨŝƌŵǁŝƚŚ'>ŶŐŝŶĞĞƌ ƉƌŝŽƌƚŽZ/,Ϳ͘ ď͘WƵŵƉƐŚŽƵůĚďĞƐĞƚŝŶůĞƐƐƚŚĂŶϭĚĞŐƌĞĞͬϭϬϬ͛ĚŽŐůĞŐ͘;dŽƉŽĨWƵŵƉƐƐǇ ƚĞŶƚĂƚŝǀĞůǇƐĞƚĨŽƌϭϰ͕ϰϭϬ͛DͿ͘ Đ͘EKd͗ƚŚĞϯͬϴ͟ĨůĂƚƉĂĐŬĐŚĞŵŝĐĂůŝŶũĞĐƚŝŽŶůŝŶĞŝƐƚŽďĞƌƵŶƚŽƚŚĞĂŶŽĚĞŽŶƚŚĞ 23.a. Set test packer or plug at >14,000' MD and pressure test casing/liner to 1500 psi. For purposes of determining test pressure, MPSP is calculated using oil gradient, not gas gradient, resulting in MPSP = 0 psi, verified by passing NFT. -bjm ďŽƚƚŽŵŽĨƚŚĞ^WĂƐƐĞŵďůǇ͘ Ě͘ϯͬϴ͟EŽǀĂsĂůǀĞƐƚŽďĞŝŶƐƚĂůůĞĚĂƚƚŽƉŽĨƉƵŵƉĂƐƐĞŵďůǇ͘ Ğ͘dŚĞWĂĐŬĞƌ͕^^^s͕ĂŶĚsĞŶƚsĂůǀĞǁŝůůEKdďĞƌƵŶǁŝƚŚƚŚŝƐĐŽŵƉůĞƚŝŽŶ͘ Ĩ͘ůĂŶŬŽĨĨǀĞŶƚůŝŶĞĂŶĚ^^^sůŝŶĞ͘ Ő͘ĂŶŶŽŶĐůĂŵƉƐĂƚĞǀĞƌǇĐŽůůĂƌ͘ ϯϭ͘Z/,ǁŝƚŚ^WĐŽŵƉůĞƚŝŽŶ͘dĞƐƚĐĂďůĞĞǀĞƌǇϱϬϬ͛͘^ƉůŝĐĞĐĂďůĞĂƐŶĞĞĚĞĚ͘ ϯϮ͘ƚd͕ĐŽŶĨŝƌŵƉŝƉĞƚĂůůǇ͘ ϯϯ͘DhůĂŶĚŝŶŐũŽŝŶƚƚŽŚĂŶŐĞƌĂŶĚƐĞƚƐƚƌŝŶŐŝŶƐůŝƉƐ͘ ϯϰ͘ƌĞƐƐŚĂŶŐĞƌĂŶĚĐŽŶƚƌŽůůŝŶĞƐ͘>ĂŶĚŚĂŶŐĞƌ͕ƌƵŶŝŶƐĐƌĞǁƐ͕ƚĞƐƚŚĂŶŐĞƌƚŽϱϬϬϬƉƐŝ͘ Ă͘DĂŬĞƐƵƌĞƚŚĞƚǁŽĞǆƚƌĂƉŽƌƚƐŝŶŚĂŶŐĞƌĂƌĞƉůƵŐŐĞĚ͘ ϯϱ͘KďƐĞƌǀĞǁĞůůĚĞĂĚ͘>ĂǇĚŽǁŶůĂŶĚŝŶŐũŽŝŶƚĂŶĚŝŶƐƚĂůůWs͘ ϯϲ͘EŝƉƉůĞĚŽǁŶƌŝƐĞƌĂŶĚKW͘ ϯϳ͘/ŶƐƚĂůůĂŶĚƚĞƐƚƉƌŽĚƵĐƚŝŽŶƚƌĞĞ͘WƵůůWs͘dƵƌŶŽǀĞƌǁĞůůƚŽƉƌŽĚƵĐƚŝŽŶ͘ ϯϴ͘ZĞůĞĂƐĞZŝŐ͘ Version: Final Tubing Hanger - ACME 3.725" MCA top connection / 3 1/2" RTS-6 btm connection - ID 2.682" 36" 150# A-36 215' MD ID - 35" A-36 215' TVD 13 3/8" 68# L-80 3,190' MD ID - 12.25" BTC 2,940' TVD X/O - 3 1/2" x 2 7/8" Tubing @ 9,936' MD / 8,701' TVD TOL @ 11,037' MD (9 5/8" x 5 1/2") TOL @ 11,290' MD (9 5/8" x 7 5/8") 9 5/8" 47# L-80 11,500' MD ID - 8.50" BTC 10,065' TVD Window 7 5/8" 29.7# L-80 12,928' MD ID - 6.75" BTC 10,862' TVD MD TVD Reperf Type 14,786-14,799 11,952-11,959 TCP 14,799-14,809 11,959-11,965 TCP/StimGun TOC @ 13,710' MD (CBL 9/17/2013) 14,809-14,811 11,965-11,966 TCP 14,811-14,821 11,966-11,972 TCP/StimGun ESP Pump Assembly 14,821-14,848 11,972-11989 TCP Top of Discharge Head @ 14,410' MD / 11,726' TVD 14,860-14,865 11,995-11,999 TCP 14,865'-14,880' 11,999-12,009 TCP/StimGun 14,880-14,934 12,009-12,042 TCP 14,956-14,958 12,057-12,058 TCP Bottom of ESP Assembly @ 14,555' MD / 11,816' TVD 14,958-14,968 12,058-12,065 TCP/StimGun 14,968-14,972 12,065-12,068 TCP 14,972-14,987 12,068-12.078 TCP/StimGun 14,987-14,994 12.078-12082 TCP 15,007-15,018 12,091-12,098 TCP Fish - 4' StimGun (possibly still live) 15,116-15,140 12,166-12,183 ---Cement Retainer @ 15114' MD 15,171-15,184 12,206-12,215 --- 15,265-15,272 12,274-12,280 --- 15,304-15,326 12,303-12320 ---Fish - ESP Assembly (+/-133ft) - Top @ 15260' MD 15,356-15,362 12,343-12,347 --- 15,378-15,386 12,360-12,366 --- 5 1/2 17# L-80 15,740' MD ID - 4.767" BTC 12,653' TVD PBTD @ 15653' MD 2 7/8" 6.3# L80 8RD EUE Tubing - ID 2.441" f/14,410' - 9,936' MD RU-05B: Current Completion Schematic 5/5/2020 3 1/2" 9.3# L80 8RD Tubing - ID 2.441" f/9,936' MD to surface 6 3/4" Hole 18 1/2" Hole Perforations (& 2017 Reperfs) Retainer @ 15,114' 12 1/4" Hole 8 1/2" Hole Note: 5/5/2020 Well kill for Cold Stack; 283 bbls produced water pumped down tubing, no returns. See updates to choke manifold in attached email from Z. Tomco 7/21/23. Note that the email refers to RU 2A, but applies to RU 5B also. -bjm CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Zach Tomco Cc:Regg, James B (OGC) Subject:RE: RU-02A Sundry Modification Date:Friday, July 21, 2023 2:54:44 PM Attachments:image003.png External Sender: Proceed with Caution Zach, The proposed changes to the choke manifold are acceptable. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Zach Tomco <ztomco@glacieroil.com> Sent: Friday, July 21, 2023 12:51 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RU-02A Sundry Modification Bryan, Glacier requests a Sundry modification for the choke manifold associated with the RU-02A Sundry (attached). This Sundry was submitted in May 2023 with the same choke manifold used for the WMRU-02B and SWORD-01 workovers. During our program, AOGCC inspectors communicated preference for future workovers with different chokes. The primary reason was the choke manifold used in Trading Bay workovers was a process choke that controlled flow, but allowed pressure to leak by. Team Snubbing International (TSI) took this feedback and procured a new choke manifold that is currently planned for use with the RU-02A workover. During procurement, system upgrades were made. Photos of this manifold system have been attached. Differences between the proposed and currently approved choke manifolds are summarized below: Mechanical Rating: Proposed choke manifold is rated for 10k, previously approved choke manifold is rated for 5k Cross Overs: Proposed choke manifold includes 2 DSAs to cross over from 10k to the 5k coflex hoses used for process connection Internals: Proposed choke manifold includes “closed chokes” with metal to metal seats that are designed to hold pressure Design: Proposed choke manifold includes a HCR, where the previously approved choke manifold includes (2) manual chokes Sizing: All proposed choke manifold valves are 4-1/16” vs the previously the approved choke manifold valves which are 3-1/8” We would like to use the new choke manifold during our upcoming BOP test this weekend. Could you please review and feedback if these changes are acceptable for use? Regards, Zach Tomco Facilities Engineer Office: (907) 433-3803 Cell: (907) 715-1244 Glacier Oil & Gas CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:David Pascal Cc:Stephen Ratcliff; McLellan, Bryan J (OGC) Subject:RE: No Flow Extension Request for RU and WMRU Date:Thursday, July 13, 2023 2:42:03 PM AOGCC approves a temporary waiver of subsurface safety valve (SSSV) requirements for the following wells, allowing them to produce uninterrupted after installation of their respective completion to ensure the new ESP is operating properly: W McArthur River Unit 2B (PTD 2140390) Sword 1 (PTD 2130800) Redoubt Unit 2A (PTD 2121720) Redoubt Unit 5B (PTD 2131070) Redoubt Unit 7B (PTD 2141910) A No-Flow Test on each well must be performed not later than 60 days after ESP installation. All wells must maintain an AOGCC-compliant surface safety valve system. These wells must be visually checked at least twice each day to confirm mechanical integrity. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: David Pascal <dpascal@glacieroil.com> Sent: Wednesday, July 12, 2023 10:33 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Stephen Ratcliff <sratcliff@glacieroil.com> Subject: No Flow Extension Request for RU and WMRU Jim, Thank you for taking my call today. As mentioned on the phone we had an infant mortality incident on WMRU-2B. We were not able to restart the ESP after we shut it down for the second no-flow test on July 8th. Initial indications lead us to believe that we have lost a phase. After talking to the manufacture and some of our consultants it is recommended that we keep these ESP’s running as long as we can without interruptions during its early life. In light of this incident, we are requesting the Commission to extend the window to perform the no-flow testing on rest of the WMRU and RU wells to 60-day window from the current 7/14-day window. We just established Sword to operating frequency last night after installing a new ESP and will be moving over to Osprey to replace ESP’s on RU-2A, 5B, 7B in the next few weeks. As discussed, these wells have been previously established to be no-flow wells (previous certifications attached) and the last recorded pressures indicate gradients that are incapable of supporting free flow (table attached below). These readings were taken just before we restarted the RU and WMRU assets after being shut-in from May 2020 to Sep 2021 via wireline unless mentioned. We are humbly requesting the Commission to extend the window for no- flow testing on these upcoming workovers. Thank you for paying attention to this matter. Please reach out if there are any questions. Regards David Pascal Chief Operating Officer | Glacier Oil and Gas Corporation 188 W. Northern Lights Blvd. Suite 510 907-433-3822 (Direct)| 907-903-4164 (Mobile) 907-334-6745 (Main) | 907-334-6735 (Fax) Email:dpascal@glacieroil.com Well Name Type Date Pressure (psi)MD (ft)TVD (ft) Gradient (psi/ft)Formation Comments RU-1A Producer - ESP 9/13/21 3,263 10,000 8,420 0.39 Hemlock Shut-in since May 2020- Sep2021 RU-2A Producer - ESP 9/27/21 4,548 14,177 12,011 0.38 Hemlock Shut-in since May 2020- Sep2021. Taken from ESP intermittent data RU-5B Producer - ESP 9/15/21 4,594 14,432 11,740 0.39 Hemlock Shut-in since May 2020- Sep2021 RU-7B Producer - ESP 9/12/21 3,812 12,085 10,075 0.38 Hemlock Shut-in since May 2020- Sep2021 WMRU- 2B Producer - ESP 9/25/21 3,254 12,111 8,457 0.38 Hemlock Shut in since Feb 2020 WMRU- 5 Producer - ESP 10/25/21 3,252 12,163 8,450 0.38 Hemlock Shut-in since May 2020- Sep2021. Taken from ESP Data WMRU- 6 Producer - ESP 10/25/21 2,870 11,440 7,357 0.39 Hemlock Shut-in since May 2020- Sep2021. Taken from ESP Data Sword- 1 Producer - ESP 9/25/21 3,298 16,300 8,620 0.38 Hemlock/Tyonek Shut-in since Dec 2020 VOF77.1 • • •„i,_I//j�sA THE STATE Alaska Oil and Gas of TTASKA Conservation Commission li , 333 West Seventh Avenue � � GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 O .0 ,00, ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Stephen Ratcliff t Sr. Drilling Engineer SCONE° NOV 1 32017 Cook Inlet Energy, LLC 601 W 5th Ave., Suite 310 Anchorage, AK 99501 Re: Redoubt Shoal Field, Undefined Oil Pool, RU-5B Permit to Drill Number: 213-107 Sundry Number: 317-511 Dear Mr. Ratliff: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Cook Inlet Energy's (CIE)request to waiver the "No- flow"test after the workover is Approved. This well (RU 5B) recently passed a "No-Flow" test in June of 2017 and no new zones will be added as part of the wellwork scope. • CIE's request to extend the 5 day limit(to 30 days) for testing the SVS (Safety Valve System) is DENIED. CIE gave no compelling reason for the extension to 30 days in their application. 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, Hollis S. French Chair DATED this b day of November, 2017. RBDi S Lv - 9 2017 LVED • 1111 • STATE OF ALASKA � OCT 302017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS A®GCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑✓ Change Approved Program❑ cio Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Run ESP r]_ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: COOK INLET ENERGY,LLC Exploratory ❑ Development ❑✓ 213-107 3.Address: ❑ 6.API Number: Stratigraphic ❑ Service 601 W 5TH AVE SUITE 310,ANCHORAGE,AK,99501 50-733-20513-02-00 " 7.If perforating: RIS 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?4 .4A-C.-4.STC,12 .12 Will planned perforations require a spacing exception? Yes ❑ No ❑✓ ✓ REDOUBT UNIT#5B ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 381203,ADL 374002 REDOUBT SHOAL,UNDEFINED OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 15,750'MD , 12,661' . 15,653' . 12,579' ‘ 2764 psi NONE NONE Casing Length Size MD TVD Burst Collapse Structural 200' 36" 200' 200' - - Conductor 3190' 13 3/8" 3190' 2940' 5020 PSI 2260 PSI Surface 11500' 9 5/8" 11500' 10065' 6870 PSI 4760 PSI Intermediate 1638' 7 5/8" 12928' 10862' 6890 PSI 4790 PSI Production __ Liner 4703' 5 1/2" 15740' 11037' 7740 PSI 6390 PSI Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 14786'-15386' . 11952'-12366' 3 1/2"12.95#&2-7/8"6.3# L80&L80 9935'&14406' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): none none 12.Attachments: Proposal Summary U Wellbore schematic U 13.Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development❑✓ , Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 30-Nov-17 Commencing Operations: OIL ❑✓ . WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stephen Ratcliff Contact Name: Stephen Ratcliff Authorized Title: Sr.Drilling Engineer Contact Email: sratcliff@glacieroil.com Contact Phone: 907-433-3808 Authorized Signature: --C-Thk—' Date: 10/27/2017 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ,,/ (/ M � Plug Integrity ❑ BOP Test i Mechanical Integrity Test ❑ Location Clearance ❑ Other: if 300tj t3, i36 ,0 7:"--__ 9 Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDTIS L g 2017[ � Spacing Exception Required? Yes ❑ No I/ Subsequent Form Required: ,13 `'/O`f t:00(1. ......_, APPROVED BY 111-4 Approved by: COMMISSIONERnAL COMMISSION Date: 1 i (o /00 (,11 l R L //.`3./7 Submit Form and M Form 10-403 Revised 4/2017 Approved application is valid fff�"alb '111PP7 h r000111ppp h as ate_ppp��approyyy111 I. Attachments in Duplicate • • • RECEIVED RECEIVED OCT 3 0 2O 7 GLACIER OCT 3 0 2017 AOGCC AOGCC October 27th, 2017 Mr. Hollis French, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry: RU-05B— Application to Replace ESP Completion Cook Inlet Energy: 50-733-20513-02-00, PTD: 213-107 Dear Mr. French, CIE hereby submits an Application for Sundry Approval for Redoubt Unit 05B, PTD: 213-107, requesting permission to pull the existing ESP completion and run a new ESP completion. ✓ The sub-surface safety valve, vent valve, and production packer are omitted from the planned completion.An AOGCC witnessed "no flow" test was passed on 6/11/17 for RU-05B. Due to the ESP swap being the only scope of work, a waiver is requested for a subsequent no-flow test.An extension is also requested to the 5-day production limit for the surface safety valve test to 30- days. //•3r? If you have any questions, please contact me at 90433.3808. Sincerely, \\ Stephen Ratcliff Sr. Drilling& Completions Engineer Cook Inlet Energy, LLC (a Glacier Oil &Gas wholly owned company) 601 W. 5th Avenue STE 310 Anchorage, AK 99501 1 ORIGINAL '• ' i. • • GLACIER 1. WELL NAME—RU-05B Requirements of 20 AAC 25.005(f) Well Summary Current Status: The well is currently producing. The monitoring system indicates the pump is still operating but the cable is grounded. Scope of Work: • Kill well. • Rig up Rig 35 and NU BOPE. • Pull ESP Completion and tubing. • RIH with new ESP Completion and tubing. • ND BOPE and rig down. • Put well on production. General Well Information: Reservoir Pressure/TVD: 0.32 psi/ft 4,000 psi @ 15,386' MD (12,366'TVD) MASP: Reservoir Pressure—(Gas Gradient X TVD) (0.32 psi/ft X 12,366' TVD)—(0.1 psi/ft X 12,366'TVD) =4,000 psi— 1236 psi = 2,764 psi Wellhead Type/Pressure Rating: 13 S/8" 5M Wellhead - 3 1/2" 5M tree BOPE: 13 5/8" 10M —Pipe Rams/ Blind Rams/Annular Well Type: Oil Well Estimated Start Date: November 30, 2017 Waivers Requested: Extension for the 5-day production limit to 30-days. CIE Drilling Manager CIE Sr. Drilling Engineer CIE Production Manager Conrad Perry Stephen Ratcliff David Pascal (907) 727-7404 (907) 433-3808 (907) 433-3822 cperry@glacieroil.com sratcliff@glacieroil.com dpascal@glacieroil.com 2 GLACIER Program Pre-Rig 1. Conduct pre-job safety meeting with all personnel on location. o Review upcoming work and discuss safety first. 2. Lock out safety systems and power oil 3. Prep for Rig and Workover operations. 4. Ensure that well is dead. Rig Workover 1. Kill well with produced water. 2. Move Rig 35 onto RU-05B. 3. Check for pressure and note pressure in tubing and in annulus. 4. R/D lines from tree and annulus to production if not done prior to rig move. 5. Check for flow, ensure well is dead and shut in well. 6. Place back pressure valve in wellhead. 7. Notify AOGCC 48 hours in advance of start of operations and upcoming BOP test. 8. N/D Production Tree. 9. N/U and Test 13 5/8" BOPE with 2 7/8" x 5" VBR rams with blinds in middle. 10. Test BOPE on 2 7/8" and 3 1/2"to 250 psi low/3500 psi high and chart. 11. Rig up ESP spoolers and hardware. 12. Remove back pressure valve. 13. P/U Landing Joint and make up to 3 1/2" Tubing Hanger. 14. Back out Lock Down screws in Tubing Hanger. 15. Pull & L/D 3 1/2" Landing Joint and Tubing Hanger. 16. Check for Flow and confirm well is dead. 17. POH and stand back 3-1/2" tubing 18. Continue to POH and lay down: a. 2-7/8" Tubing b. ESP BHA 19. Prep to pick up ESP Completion equipment, spoolers, and tools. 20. Rig up Summit for ESP Completions. a. Hold PJSM for ESP Run. b. Test and confirm that all equipment is on location and ready to RIH. c. NOTE: COMPLETION ESP/TUBING WILL NOT BE ROTATED. 21. Pick up the ESP completion assembly as directed. a. NOTE: Setting depth of ESP BHA at 12,950' MD (Confirm with GLA Engineer prior to RIH). Do not enter the 5-1/2" liner. b. Pump should be set in less than 1 degree/100' dogleg. (Top of Pump Assy tentatively set for 12,800' MD). 3 • < • • GLACIER c. NOTE: Will not run any 2-7/8" tubing. d. NOTE: the 3/8" flat pack chemical injection line is to be run to the anode on the bottom of the ESP assembly. e. 3/8" Nova Valves to be installed at top of pump assembly. f. The Packer, SSSV, and Vent Valve will NOT be ran with this completion. g. Blank off vent line and SSSV line. h. Cannon clamps at every collar. 22. RIH with ESP completion on 3-1/2" tubing. Test cable every 500'. 23. Monitor trip tank for proper hole filling. Splice cable as needed. At TD, confirm pipe tally. 24. MU landing joint and set string in slips. 25. Dress hanger and control lines. Land hanger, run in screws, test hanger to 5000 psi. a. Make sure the two extra ports in hanger are plugged. 26. Observe well dead. Lay down landing joint and install BPV. 27. Nipple down riser and BOPE. 28. Install and test production tree. 29. Turn over well to production. 30. Release Rig. L.-)6 S 17, - PaL.) 4.)et_c*414-12 4 • RU-05B:Current Completion Schematic * Version: Final 114 Tubing Hanger-ACME 3.725"MCA top connec5/8/201tion/ 3 1/2"RTS-6 btm connection-ID 2.682" GLACIER I I " l , .y rw 4'? , 13 3/8" 68#L-80 3,190'MD 18 1/2"Hole 0ID-12.25" BTC 2,940'ND n 'ti , } A� Sa.r i '4x `s'. 3 1/2"9.3#L80 8RD Tubing-ID 2.441"f/14,410'-9,936'MD -'.r irY• .' say 7. X/O-3 1/2"x 2 7/8"Tubing @ 9,936'MD/8,701'TVD TOL@ 11,037'MD(95/8"x51/2") rAMIlli 1 �_ ry ' j 2 7/8"6.3#L80 8RD EUE Tubing-ID 2.441"f/14,410'- TOL @ 11,290'MD(9 5/8"x 7 5/8") ;. i f 4. 9,936'MD ) 9 5/8" 47#L-80 11,500'MD 12 1/4"Hole A € ID-8.50" BTC 10,065'TVD Window 8 1/2"Hole i 7 5/8" 29.7#L-80 12,928'MD 4 !' ' ID-6.75" BTC 10,862'ND Perforations(&2017 Reperfs) _. MD TVD Reperf Type 14,786-14,799 11,952-11,959 TCP . j 14,799-14,809 11,959-11,965 TCP/StimGun j; it, TOC @ 13,710'MD(CBL 9/17/2013) 41• 14,809-14,811 11,965-11,966 TCP 14,811-14,821 11,966-11,972 TCP/StimGun , I' . ESP Pump Assembly 14,821-14,848 11,972-11989 TCP Top of Discharge Head @ 14,410'MD/11,726'MD 14,860-14,865 11,995-11,999 TCP 14,865'-14,880' 11,999-12,009 TCP/StimGun I ry. 14,880-14,934 12,009-12,042 TCP 'I r 14,956-14,958 12,057-12,058 TCP Bottom of ESP Assembly @ 14,555'MD/11,816'MD 14,958-14,968 12,058-12,065 TCP/StimGun ® _` CII - 14,968-14,972 12,065-12,068 TCP 14,972-14,987 12,068-12,078 TCP/StimGun O. -" 14,987-14,994 12.078-12082 TCP 15,007-15,018 12,091-12,098 TCPll Retainer @ 15,114' i Fish-4'StimGun(possibly still live) 15,116-15,140 12,166-12,183 -- Cement Cement Retainer @ 15114'MD 15,171-15,184 12,206-12,215 -- Ili 15,265-15,272 12,274-12,280 -- h - 15,304-15,326 12,303-12320 -- t011 -- Fish-ESP Assembly(+1-133ft)-Top @ 15260'MD 15,356-15,362 12,343-12,347 -- 0 r 15,378-15,386 12,360-12,366 -- 5 1/2 17#L-80 15,740'MD 6 3/4"Hole J ID-4.767" BTC 12,653'ND PBTD @ 15653'MD . RU-O5B:Proposed Completion Schematic • Version: Proposed 10/26/2017 GLAeiER Tubing Hanger-ACME 3.725"MCA top connection/ 3 1/2"RTS-6 btm connection-ID 2.682" . [ i 13 3/8" 68#L-80 3,190'MD ID-12.25" BTC 2,940'ND 3 1/2"9.3#L80 8RD Tubing-ID 2.441" 18 1/2"Hole i • TOL @ 11,037'MD(9 5/8"x 5 1/2") TOL @ 11,290'MD(9 5/8"x 7 5/8") k. -° RY ESP Pump Assembly Top of Discharge Head @ 10,800'MD/9,449'MD 12 1/4"Hole I Bottom of ESP Assembly @ 10,950'MD/9,491'TVD 4,4 :,,,tWindow 9 5/8" 47#L-80 11,500'MD 8 1/2"HoleID-8.50" BTC 10,065'TVD Perforations(8 2017 Reperfs) MD TVD Reperf Type 14,786-14,799 11,952-11,959 TCP ' 14,799-14,809 11,959-11,965 TCP/StimGun , 14,809-14,811 11,965-11,966 TCP 14,811-14,821 11,966-11,972 TCP/StimGun Window 14,821-14,848 11,972-11989 TCP 7 5/8" 29.7#L-80 12,928'MD 14,860-14,865 11,995-11,999 TCP ID-6.75" BTC 10,862'TVD 14,865'-14,880' 11,999-12,009 TCP/StimGun 14,880-14,934 12,009-12,042 TCP TOC @ 13,710'MD(CBL 9/17/2013) 14,956-14,958 12,057-12,058 TCP 14,958-14,968 12,058-12,065 TCP/StimGun 14,968-14,972 12,065-12,068 TCP 14,972-14,987 12,068-12,078 TCP/StimGun ' 14,987-14,994 12.078-12082 TCP 15,007-15,018 12,091-12,098 TCP 1:211 - Retainer @ 15,114' Ca 15,116-15,140 12,166-12,183 --- 'OM --. 15,171-15,184 12,206-12,215 --- oa�ff .�Qj Fish-4'StimGun(possibly still live) 15,265-15,272 12,274-12,280 --- r* 7 n Cement Retainer @ 15114'MD 15,304-15,326 12,303-12320 --- to 15,356-15,362 12,343-12,347 --- C ff 15,378-15,386 12,360-12,366 --- ii. # a Fish-ESP Assembly(+/-133ft)-Top @ 15260'MD 5 1/2 17#L-80 15,740'MD 6 3/4"Hole ID-4.767" BTC 12,653'TVD PBTD @ 15653'MD • CIE Rig 35 Redoubt Unit 13 5/8" 10,000 PSI BOP STACK 5000 psi Annular 10,000 psi 4" pipe rams Double Gate 4" outlets 10,000 psi DSA T/3" Both sides Blind Rams Double Gate 3" Kill line Mud 3" Choke line 2 2 Cross 2 1 1= HCR Valve 10,000 psi 2=Gate Valve 4" Pipe Rams Single Gate 13 5/8" 5M Wellhead 13 3/8" Surface Casing 9 5/8" Intermediate Casing OF T1tit r�;� THE STAT• ,, Alaska Oil and Gas N %- I/�tom o ALAsKA Conservation Commission it }� 333 West Seventh Avenue 1. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 (4'ALAY' SP Fax: 907.276.7542 www.aogcc.alaska.gov June 15, 2017 Mr. David Kumar Production Manager Cook Inlet Energy 601 W. 5th Avenue, Suite 310 Anchorage, AK 99501 SCANNED 2 2 nri RE: No-Flow Verification Redoubt Unit 5B PTD 2131070 Dear Mr. Kumar: On June 11, 2017 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Redoubt Unit 5B located on the Osprey platform in Cook Inlet. The well is operated by Cook Inlet Energy (CIE). The AOGCC Inspector confirmed that the proper test equipment—as outlined in AOGCC Industry Guidance Bulletin 10-004—was rigged up on Redoubt Unit 5B prior to the test. The well performance was monitored for three hours. Observed gas rates at the end of three separate flow checks preceded by 1-hour pressure build up periods were less than the allowed 900 standard cubic feet per hour for a passing no-flow test. There was no liquid flow to surface during the no-flow test. Redoubt Unit 5B may be produced without a subsurface safety valve. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Redoubt Unit 5B demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no-flow test. Please retain a copy of this letter at the Osprey platform. Sincerely, James B. Regg ( 1 Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors STATE OF ALASKA ' A•KA OIL AND GAS CONSERVATION COM,SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon LJ Plug Perforations U Fracture StimulateL Pull Tubing U Operations shutdown Li Performed: Suspend Cl Perforate ❑., Other Stimulate❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well❑ Re-enter Susp Well ❑ Other: Set Retainer,Run ESP ❑., 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: COOK INLET ENERGY,LLC Development Q Exploratory ❑ 213-107 3.Address: 601 W 5TH AVE SUITE 310,ANCHORAGE,AK, Stratigraphic ❑ Service ❑ 6.API Number: 99501 50-733-20513-02-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 381203,ADL 374002 REDOUBT UNIT#5B 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A REDOUBT SHOAL,Undefined Oil 11.Present Well Condition Summary: Total Depth measured 15750 feet Plugs measured 15114 RECEIVED true vertical 12661 feet Junk measured 15260 feet JUN 0 6 2017 Effective Depth measured 15653 feet Packer measured N/A feet true vertical 12579 feet true vertical N/A feet AOG Casing Length Size MD TVD Burst Collapse Structural 200' 30" 200' 200' N/A N/A Conductor 3190' 13 3/8" 3190' 2940' 5020 psi 2260 psi Surface 11500' 9 5/8" 11500' 10065' 6870 psi 4760 psi Intermediate 1638' 7 5/8" 12928' 10862' 6890 psi 4790 psi Production Liner 4703' 5 1/2" 15740' 11037' 7740 psi 6390 psi Perforation depth Measured depth 14786-15386 feet True Vertical depth 11952-12366 feet Tubing(size,grade,measured and true vertical depth) 3-1/2"&2-7/8" L80 &L80 14450'&10000' 11750'&8756' Packers and SSSV(type,measured and true vertical depth) None 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNEV J U ,1 G t: Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 102 39 566 71 318 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑I Exploratory ❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil D Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-5t4/317-152 Authorized Name: Stephen Ratcliff Contact Name: Stephen Ratcliff Authorized Title: Sr.Drilling Engineer Contact Email: sratcliff@glacieroil.com Authorized Signature: C Date: 6/6/2017 Contact Phone: 907-433-9738 h''"/7 7 Form 10-404 Revised 4/2017 RBDMS U . , ; e 7 ZO1I Submit Original Only f 6(st/7 • • 44 GLACIER RECEIVED June 5th, 2017 JUN 0 6 2017 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission AOGCC 333 West 7th Ave., Suite 100 Anchorage,Alaska 99501 Re: Report of Sundry Cook Inlet Energy, LLC: RU-05B Permit to Drill NO:213-107 API No:50-733-20513-02-00 Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a Report of Sundry Well Operations for RU-05B. The work performed was originally covered under Approved Sundry 316-544 to pull the original completion, and Approved Sundry 317-152 to pull the packer and kill string (interim completion), set retainer, reperf the existing zones, and run an ESP completion. If you have any questions, please contact me at(907)433-9738. Sincerely, Stephen Ratcliff Sr. Drilling Engineer Cook Inlet Energy, LLC (a Glacier Oil&Gas Corp. owned company) 601 W. 5th Avenue STE 310 Anchorage, AK 99501 10-404 4110 RU-O5B:Current Completion Schematic • Version: Final 5/8/2017 Tubing Hanger-ACME 3.725"MCA top connection/ 3 1/2"RTS-6 btm connection-ID 2.682" GLACIER -4, �4' ill 13 3/8" 68#L-80 3,190'MD 18 1/2"Hole 4 ID-12.25" BTC 2,940'TVD • 3 1/2"9.3#L80 8RD Tubing-ID 2.441"f/14,410'-9,936'MD y' rr ""* X/O-3 1/2"x 2 7/8"Tubing @ 9,936'MD/8,701'TVD TOL @ 11,037'MD(9 5/8"x 5 1/2") ?' 41.11Vr 2 7/8"6.3#L80 8RD EUE Tubing-ID 2.441"(/14,410'- TOL @ 11,290'MD(9 5/8"x 7 5/8") , ,-.4. 9,936'MD 9 5/8" 47#L-80 11,500'MD I 12 1/4"Hole 4 , ID-8.50" BTC 10,065'TVD Window 8 1/2"Hole 7 5/8" 29.78 L-80 12,928'MD A , ID-6.75" BTC 10,862'TVD Perforations(&2017 Reperfs) MD TVD Reperf Type 14,786-14,799 11,952-11,959 TCP - - 14,799-14,809 11,959-11,965 TCP/StimGun TOC @ 13,710'MD/C81.9/17/2013) 14,809-14,811 11,965-11,966 TCP 14,811-14,821 11,966-11,972 TCP/StimGun - t ESP Pump Assembly 14,821-14,848 11,972-11989 TCP Top of Discharge Head @ 14,410'MD/11,726'MD 14,860-14,865 11,995-11,999 TCP 14,865'-14,880' 11,999-12,009 TCP/StimGun >kti�I 14,880-14,934 12,009-12,042 TCP - 14,956-14,958 12,057-12,058 TCP - Bottom of ESP Assembly @ 14,555'MD/11,816'MD 14,958-14,968 12,058-12,065 TCP/StimGun O C v c 14,968-14,972 12,065-12,068 TCP p C 14,972-14,987 12,068-12,078 TCP/StimGun or c 14,987-14,994 12.078-12082 TCP 15,007-15,018 12,091-12,098 TCP Retainer @ 15,114' Oj - Fish-4'StimGu sibly still live) 15,116-15,140 12,166-12,183 --- . ement Retainer @ 15114'MD 15,171-15,184 12,206-12,215 --- O C '✓----.... --- 15,265-15,272 12,274-12,280 --- 0 C 15,304-15,326 12,303-12320 --- ol Fish-ESP Assembly(+/-133ft)-Top @ 15260'MD a C 15,356-15,362 12,343-12,347 --- C 15,378-15,386 12.360-12,366 --- 5 1/2 178 L-80 15,740'MD 6 3/4"Hole ID-4.767" BTC 12,653'TVD PBTD @ 15653'MD • • GLACIER RU-056 Daily Operations Summary API: 50-733-20513-02-00 Permit #: 213-107 Rig: Osprey Rig 35 Date and Footage Drilled as of 24:00 hours. Activity 17 April 2017 Skid rig to RU-05B. 18 April 2017 Continue to rig up. 19 April 2017 ND Dry hole tree. NU BOPE. RU test equipment and test BOPE to 250 psi low /3500 psi high (annular 250 psi low/2500 psi high).Test witnessed by AOGCC rep., Brian Bixby. 20 April 2017 Pull BPV. RU Slickline and RIH, pull prong and tubing tail plug @ 1772'. RD Slickline. Pull hanger and LD. Circulate and flow check—static. POH and LD 3.5" tubing and storm packer. MU Mill and scraper BHA and RIH. 21 April 2017 Continue RIH with Scraper BHA and tag fish (ESP) at 11070'.Chase fish to 15150'. Circulate and monitor for losses—none. Wash while pushing fish from 15150'to 15260' (top of fish depth). Circulate while monitoring losses. Losses diminished. 22 April 2017 Continue circulating monitoring for losses.Well static. POH and LD BHA. RU Eline and RIH with EZSV Retainer.Set retainer at 15100' wireline depth. RD Eline. PU Running tool and RIH. 23 April 2017 Continue RIH with Running tool to 15114' MD.Circulate and Stab into retainer. RU lines for injection. Pressure up on annulus to 1225 psi and 4050 psi on drill pipe—no injection. Unsting and confirm circulation. POH to 3485'. 24 April 2017 Continue POH with running tool and LD same. PU 228' of TCP guns and RIH on drill pipe to 15005' MD. RU Eline and TIH to correlate depth. 25 April 2017 RD Eline. Set Guns on Depth, set packer(Interval: 14790'—15018' MD) Backside pressure to 800 psi. Fire Guns. Unseat packer. Reverse circulate, monitor losses. POH with TCP guns and LD same. RU test equipment, prep to test BOPE. 26 April 2017 Test BOPE to 250 psi low/3500 psi high (annular 250 psi low/2500 psi high).AOGCC rep, Mike Quick,waived witness of test. RU Wireline. RIH with 6,..(s- — StimGun#1 and shoot interval 14799'—14809'. RIH with StimGun#2 and �� shoot interval 14811'—14821', lost 4' section of gun in hole. RIH with StimGun#3 and shoot interval 14865'—14880'. RIH with StimGun#4. GLACIER 27 April 2017 Continue RIH with StimGun#4 and shoot interval 14958'—14968'. RIH with StimGun#5 and shoot interval 14972'—14987', lost 31'StimGun in hole (pulled out of rope socket). RD Eline. RU Slickline. RIH and attempt to 6(,''� retrieve fish, POH—no fish. RIH and tagged fish again, POH—recovered fish.- 5'S ? RD Slickline. RU to run ESP. Begin making up ESP assembly. 28 April 2017 Finish making up ESP assembly. Modify cannon clamp for acceptable OD. RIH with ESP assembly on 2-7/8" 6.5# L80 EUE 8RD tubing to 2708' MD. 29 April 2017 Continue TIH with ESP assembly on 2-7/8" 6.5#L80 EUE 8RD tubing to 4618' MD. Change to 3-1/2" handling equipment. Continue TIH with ESP on 3-1/2" 9.3# L80 EUE 8RD tubing to 9796' MD. 30 April 2017 Continue TIH with ESP assembly on 3-1/2" 9.3#L80 EUE 8RD tubing to 12323' MD.Tagged tight spot, picked up and RIH to 13033'.Tested ESP cable � and found to be grounded out.POH with ESP assembly from 13033'to 7906' ji.t, MD. �5- 01 May 2017 Continue POH with ESP assembly.Test pump, motor—good test. RU slickline and RIH with 8.5" OD GR to 5-1/2" liner top at 11060'WLM, POH. RIH with 4.75" GR and tag up at 11,112'.WLM, POH. RIH with 4.66" GR and RIH to 14600' WLM, POH and RD slickline unit. Prep to run ESP assembly. 02 May 2017 Continue to prep ESP equipment. Reassemble ESP motor, seals, and pumps. RIH with ESP assembly on 2-7/8" 6.5# L80 EUE 8RD tubing to 4063' MD. 03 May 2017 Continue RIH with ESP assembly on 2-7/8" 6.5#L80 EUE 8RD and 3-1/2" 9.3# L80 EUE 8RD tubing to 13443' MD, splicing cable as necessary and testing every 1000ft. 04 May 2017 Continue RIH with ESP assembly on 2-7/8" 6.5#L80 EUE 8RD and 3-1/2" 9.3# L80 EUE 8RD tubing to 14499' MD. MU tubing hanger,orient, and land hanger with ESP set depth of 14555' MD. Pull landing joint and set BPV. ND BOPE and NU tree. 05 May 2017 Continue NU tree. Pull BPV and set TWC.Test tree to 5000 psi—good. Prep for slot move. Rig Release at 02:00. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 1- I'(i 7 DATE: 06/12/17 P. I. Supervisor FROM: Adam Earl SUBJECT: No Flow Test Petroleum Inspector RU 5B ' PTD 2131070 Osprey Platform Glacier Oil & Gas June 11, 2017: I arrived at the heliport at 9am to meet Dan Clark, Glacier Oil & Gas (Cook Inlet Energy) production superintendent. There were 2 no-flow tests scheduled for today: RU 1A and RU 5B (separate report). We flew out to Osprey Platform where Operator Sully Sullivan met us and we walked down and went over the job set-up. The well's inner annulus (IA) and tubing were for both wells were connected to a manifold with separate, %2-inch lines and isolations valves to enable RU 1A and RU 5B to be tested independently but at the same time. Test equipment also included a no-flow meter as well as a digital test pressure gauge. The following table shows test details for RU 56: Time Pressures' Flow Rate2 Remarks (psi) Gas - scf/hr Liquid - gal/hr 10:25 0/0/70 none Well shut in 10:55 1.2/1.5/70 . none Well shut in 11:25 1.3/1.9/70- 60 - none bleed through meter 11:55 1.8/2.0/70 " none Well shut in 12:25 1.9/2.4/70 . 120 - none bleed through meter 12:55 2.1/2.7/70 - none Well shut in 13:25 2.4/3.1/70 240 none Bleed through meter for 3min; 240 to 180 scf per hour 1 Pressures are T/IA/OA 2 No-Flow meter measured standard cubic feet per minute (SCFM); converted to SCF per hour The no-flow test of RU 5B went good and seemed to me to be a passing test. There was no fluid to surface. Calibration certificates and photos of test equipment were provided by the operator— copies attached. Attachments: Calibration certificates (Crystal gauge; no-flow meter) - Photos (2) SCANNED e'u i 1 4 20r: 2017-0611 No-Flow RU-5B_ae.docx Page 1 of 4 • • No Flow Test— Redoubt Unit 5B (PTD 2131070) Photos by AOGCC Inspector A. Earl 6/11/2017 2 Uize" r ei Pt P4��!�y rQ Calibration Certificate Fpp x� 1000 Ceillheitte Number.2016000338 e a Customer: Oeproy IISCO LAB Mlle 26.5 Kenel Spur IHWY 300 Airport Way NIkIskI,AK 99635,USA Konei,AK 99611,USA 1(907)283-4230 PO Number 2807 Asset Number 1000610 SO Number 10A35713 DesrxiptIon '{ fI Psi tk rut I est(.aura Technician Cody Williams Temperature 22.19 Manufacturer Crystal Pressure Humidity 15 Model Number XP2i WO Results Pass Serial Number 159077 Received In Tolerance Service Date Service Date:11/22/2016 Duo Date 11/22/201/ � Refe,ence Standards used in this calibration are Iraceablo to Iho National Instituto of Standards and 1 echnolor y of the United Stales(NIST)or other NMI. All calculations made using Fluke COMPASS Software for Full calculation mode This report may not be reproduced,except in full,unless pormissiou for the publication of an approved abstract is obtained in writing from the organization issuing this report.. DesrxlptIon SerMce Data Due Date Asset Number P3100 Dead Weight Tester 7/21/2016 7/21/2017 1000434 Laboratory Enviroment Monitor 7/21/2016 7/2112017 1000435 �r 1 Y w *xY i 4 a .. f Y .F ` 3 2017-0611 No-Flow RU-5B ae.docx Page 2 of 4 • KING INSTRUMENT COMPANY 12700 Pala Drive,Garden Grove,CA 92841 TEL#(714)891-0008 FAX#(714)891-0023 CALIBRATION CERTIFICATE CERT. NO. 593311607 Submitted for calibration by: SAVANT ALASKA LLC FLOWMETER SPECIFICATIONS Manufacturer: BROOKS INSTRUMENT Type: Variable Area(Rotameter) Model#: MT3810A13A1 RAAS1 Float Material : N/A Serial#: 0111060466126001 Float Type : N/A Tag#: N/A CALIBRATION INFORMATION Calibration Date: 18-Jul-16 - Calibration Fluid : Air Recalibration Date : 18-Jul-17 Calibration Fluid Sp.Gr.: 1.0 Rated Accuracy(%F. .): +/-5% - Calibration Fluid Viscosity: 0.01812 cP Pass 1 Fail: Passed - Calibration Fluid Temp. : 70°F Signature: ' Calibration Fluid Pressure: 14.7 PSIA 14. 2hle, Lab Tech Indicated Flowrate-Scfm GAS-Dens.21.06 MW-125°F& As Found l As Left 5 PSIG 25.00 24.12582 20.00 19.40280 16.00 15.30096 10.00 9.54031 2.50 2.35701 - Calibration Equipment Id: KICSYSSV01 Recalibration Date: 20-Jan-2017 Calibration Procedure: ISA:RP 18.6 Approved By: #&.! ANIGng Instrument Company calibration services comply with MIL-STD 45662A a SIML •ian a'= , 're traceable to the National Institute of Standards and Technology. The collective uncertainty of the equipment used in this calibration does not exceed 25%of the certified accuracy of instrument under test. Any reproduction or representation of this data,except in full,must not include - «.‘ of compliance with the above mentioned sta . Form F851 Rev r F �. 2017-0611 No-Flow RU-5B ae.docx Page 3 of 4 • • irb a, •d i 6 U �� III 0 I tip (=> \3 c..., � CI TUU W....... el �+ 0 .b CL N n y 5c, w a> cn Lu f ao N 0 a) U 0 CC ° a. • I ° k" 3 0 • R: w �{.� ov AFT dim ,p.�. w bo o C� z �" o 1 ct • o 1' S 3 `� ° a; r ► Iv' , fix= . 2 v w w 0 ° ` CL) Y c � e ii '; , f ill IP1 VOF rilt • S • y \V/7;4.s, THE STATE Alaska Oil and Gas = 7 of Conservation Commission LASKA #Mt ___- 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 oFA S Fax: 907.276.7542 www.aogcc.alaska.gov Stephen Ratcliff Sr. Drilling Engineer Cook Inlet Energy, LLC SCANNED f'PR 4)20R 601 W. 5th Ave., Ste. 310 Anchorage,AK 99501 Re: Redoubt Shoal Field, Undefined Oil Pool,RU 5B Permit to Drill Number: 213-107 Sundry Number: 317-152 Dear Mr. Ratcliff: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, (SA ...;14..4._15/1„.._ Cathy P oerster Chair DATED this 177 day of April,2017. RBDNIS """ ° 2017 S • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APR 1 3 2017 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280AOGCC 1.Type of Request: Abandon ❑ Plug Perforations 2 % Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate Q Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Set Retainer,Run ESP P 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: COOK INLET ENERGY,LLC Exploratory ❑ Development 2 . 213-107• 3.Address: Stratigraphic ElService ❑ 6.API Number: 601 W 5TH AVE SUITE 310,ANCHORAGE,AK,99501 50-733-20513-02-00 • 7.If perforating: 610 AAC,C,A.• ass-ass- j J 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? l�lt Will planned perforations require a spacing exception? Yes ❑ No 0 REDOUBT UNIT#5B 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 381203,ADL 374002 REDOUBT SHOAL,UNDEFINED OIL', 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 15,750'MD 4 12,661' + 15,653' . 12,579', 2764 psi NONE NONE Casing Length Size MD TVD Burst Collapse Structural 200' 36" 200' 200' Conductor 3190' 13 3/8" 3190' 2940' 5020 PSI 2260 PSI Surface 11500' 9 5/8" 11500' 10065' 6870 PSI 4760 PSI Intermediate 1638' 7 5/8" 12928' 10862' 6890 PSI 4790 PSI Production __ Liner 4703' 5 1/2" 15740' 11037' 7740 PSI 6390 PSI Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 14786-15386' A 11952'-12366' 3 1/2"12.95# P-110 1855'MD Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 9-5/8 x 3-1/2"Storm Packer , 1661'MD/1615'TVD 12.Attachments: Proposal Summary U Wellbore schematic U 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: 17-Apr-17 OIL ❑✓ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stephen Ratcliff Contact Name: Stephen Ratcliff Authorized Title: Sr.Drilling Engineer Contact Email: sratcliff@glacieroil.com C (� �� Contact Phone: 907-433-3808 Authorized Signature: ?�4---- ' J t_,.-.\( Date: 4/12/2017 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test / rit Mechanical Integrity Test ❑ Location Clearance CI 4-0:=-- -1/16A Other: )4... '35 X? ,p,c -7i1- 14:- N 11i_/ ff Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No ] Subsequent Form Required: /0 -- 51011 RBDMS k. APR 1 9 2017 �(� / wC 441' APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 4—1 8 / ' i'ii a y/�i/�?- y-/7-/ Submit Form and Form 10-403 Revised 4/2017 oRtetNiofit Eid for 12 month rom the date of approval. Attachments in Duplicate • • RECEIVED GLACIER APR 1 3 2011 April 13th, 2017 AOGCC Ms. Cathy Foerster, Chair `✓ V Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry: RU-05B— Application to Run ESP Completion Cook Inlet Energy: 50-733-20513-02-00, PTD: 213-107 Dear Ms. Foerster, Cook Inlet Energy, LLC, would like to cancel Approved Sundry 317-053. CIE hereby submits an Application for Sundry Approval for Redoubt Unit 05B, PTD: 213-107, requesting permission to squeeze perfs, add perfs, and run a new ESP completion. It is also requested that a no flow test be performed to omit the vent valve, production packer, and sub-surface safety valve from the oc'mpletion. An extension of 30 days is requested in place of the 5-day production limit prior to executing the test as well. If you have any questions, please contact me at 907.433.3808. Sincerely, Stephen Ratcliff Sr. Drilling & Completions Engineer Cook Inlet Energy, LLC (a Glacier Oil & Gas wholly owned company) 601 W. 5th Avenue STE 310 Anchorage, AK 99501 1 • • GLACIER 1. WELL NAME— RU-05B Requirements of 20 AAC 25.005(f) Well Summary Current Status: The well is currently shut in. The ESP completion has been pulled and a storm packer with kill string was ran. Scope of Work: • Rig up Rig 35 & NU BOPE • Pull Storm Packer and kill string. • RIH and set retainer at 15,100' MD with 270' of 2-7/8" tubing hanging below. • Pump 15 bbls cement below retainer. • RIH with TCP guns and perforate selected intervals. • RIH with StimGuns and reperforate selected intervals. • RIH with ESP completion. • N/D BOPE. • Turn well over to production. General Well Information: Reservoir Pressure/TVD: 0.32 psi/ft 4,000 psi @ 15,386' MD (12,366' TVD) MASP: Reservoir Pressure— (Gas Gradient X TVD) (0.32 psi/ft X 12,366' TVD)_,-(-0,-Lpsi/ft X 12,366'TVD) = 4,000 psi —1236 psi 2,76644 psis Wellhead Type/Pressure Rating: 13 5/8" 5M Wellhead - 3 1/2" 5M tree BOPE: 13 5/8" 10M —Pipe Rams/ Blind Rams/Annular Well Type: Oil Well Estimated Start Date: April 17, 2017 Waivers Requested: None 2 • • • GLACIER CIE Drilling Manager CIE Sr. Drilling Engineer CIE Production Manager Conrad Perry Stephen Ratcliff David Kumar (907) 727-7404 (907) 433-3808 (907) 433-3822 cperry@glacieroil.com sratcliff@glacieroil.com dkumar@glacieroil.com Program Rig Workover General Note: Full opening Safety Valve will be on rig floor at all times with appropriate crossovers for all pipe being run below rotary table. 1. Move rig onto RU-05B. 2. Check for pressure and note pressure in tubing and in annulus. 3. Notify AOGCC 48 hours in advance of start of operations and upcoming BOP test. 4. N/D Dry Hole Tree. 5. N/U and Test 13 5/8" BOPE with 2 7/8" x 5" VBR rams with blinds in middle. 6. Test BOPE on 2 7/8", 3-1/2" and 5" to 250 psi low/ 3500 psi high and chart. 7. Remove back pressure valve. 8. P/U Landing Joint and make up to 4 1/2" Tubing Hanger. 9. Back out Lock Down screws in Tubing Hanger. r- 10. Pickup with straight pull to release storm packer at 1661' MD. 5riot 11. Pull & L/D Landing Joint and Tubing Hanger. 12. Check for flow and confirm well is dead. 13. POH and LID 3-1/2"tubing and storm packer. 14. PU +/- 4500' of 3-1/2" PH6 tubing and +/- 270' of 2-7/8"tubing. ,,-C 15. MU mechanical setting tool to 5-1/2" cement retainer with 2-7/8"tubing hung below. o Bottom connection of the cement retainer is 2-7/8" EUE. 16. RIH with 2-7/8"tubing and retainer on 3-1/2", 4", & 5" drill pipe to 15370' (retainer at 15100'). o Fish from previous work (+/- 133 ft of ESP Completion) has not been tagged. o If fish is encountered, push to bottom with retainer/stinger, if possible. 17. Rig up and test cementing lines. 18. Pump 15 bbls of 15.8 ppg cement and displace with produced water until 6 bbls remain in the drill pipe (above retainer). 19. Set cement retainer at 15,100' MD. 3 • • GLACIER 20. Sting in with weight down, as per tool hand instructions, and squeeze 5 bbls of 15.8 ppg cement, leaving 1 bbl inside drill pipe above retainer. 21. Un-sting and circulate residual cement out. 22. POH and LD setting tool. 23. PU TCP guns (6 spf, 60 deg phase). 24. RIH and perforate new intervals and reperforate existing perforations. o Observe and report pressure increase, if any, after each interval is perforated. o Consult with Production if pressure increase is seen to determine whether to suspend perforations and take well to production. Proposed Intervals to Perforate and Reperforate: New Reperf PERF INTERVAL PERF INTERVAL Interval Interval (MD FT) (TVD FT) X 14790'—14848' 11953'—11989' X 14860'—14862' 11995'—11997' X 14862'—14880' 11997'—12009' X 14880'—14888' 12009'—12014' X 14888'—14915' 12014'—12030' 1 ) X 14915'—14922' 12030'—12035' n: X 14922'—14928' 12035'—12038' 19- X 14928'—14934' 12038'—12042' X 14956'—14965' 12057'—12063' X 14965'—14972' 12063'—12068' X 14972'—14988' 12068'—12079' X 14988'—14994' 12079'—12082' X 15007'—15008' 12091'—12092' X 15008'—15018' 12092'—12098' 25. POH and LD 3-1/2" PH6 and TCP guns. 26. RU Eline. PU and MU Stim Guns. 28. RIH and reperf with StimGuns across specified perforation intervals. Proposed Intervals for StimGuns: PERF INTERVAL PERF INTERVAL (MD FT) (TVD FT) 4 • • GLACIER 14800'-14820' 11953'-11989' 14864'-14880' 11995'-11997' 14922'-14934' 11997'-12009' 14958'-14968' 12009'-12014' 14972'-14982' 12014'-12030' 29. RD Eline. 30. Prep to pick up ESP Completion equipment, spoolers, and tools. 31. PU New 3-1/2" 9.3# L80 EUE & 2-7/8" 6.5# L80 EUE tubing. 32. Rig up Summit for ESP Completions. o Hold PJSM for ESP Run. o Test and confirm that all equipment is on location and ready to RIH. o NOTE: COMPLETION ESP/TUBING WILL NOT BE ROTATED. 33. Pick up the ESP completion assembly as directed. o NOTE: Setting depth of ESP BHA at 14,550' MD (Confirm with GLA Engineer prior to RIH). o Pump should be set in less than 1 degree/100' dogleg. (Top of Pump Assy tentatively set for+/- 14,450' MD). o NOTE: the 3/8" flat pack chemical injection line is to be run to the anode on the bottom of the ESP assembly. o 3/8" Nova Valves to be installed at top of pump assembly. 34. RIH with ESP completion on 3-1/2" 9.3# L80 EUE & 2-7/8" 6.5# L80 EUE tubing. o Test cable every 1000'. o Crossover from 3-1/2"to 2-7/8" tubing at+/- 10,000'. 35. Monitor trip tank for proper hole filling. Splice cable as needed. At TD, confirm pipe tally, MU landing joint and set string in slips. 36. Dress hanger and control lines. 37. Land hanger, run in screws, test hanger to 5000 psi. 38. Observe well is dead. Lay down landing joint and install BPV. 39. Nipple down riser and BOPE. 40. Install and test production tree to 5,000 psi. 41. Turn over well to production. 42. Release Rig. ys— if. freeref-t (i()i' 36)- 5 rRU-05B:Current Wellbore Schematic • Version: Current 1/30/2017 GLACIER Tubing Hanger-31/2"RTS-6-ID 2.682" ii.11 - _ 9-5/8"x 3-1/2"Storm Packer @ 1661'MD - - R Profile @+/-1769'MD 31/2"12.95#P-110 PH6 Tubing-ID 2.625"1/1855'MD 13 3/8" 68#L-80 3,190'MD 18 1/2"Hole ID-12.25" BTC 2,940'TVD TOL @ 11,037'MD(9 5/8"x 5 1/2") yy Fish-ESP Assembly-tag @ 11082'MD 0l IP TOL @ 11,290'MD(9 5/8"x 7 5/8") 9 5/8" 47#L-80 11,500'MD 12 1/4"Hole , _ ID-8.50" BTC 10,065'TVD Window 7 5/8" 29.7#L-80 12,928'MD 8 1/2"Hole , , ID-6.75" BTC 10,862'TVD TOC @ 13,710'MD(CBL 9/17/2013) Perforations:3-3/8"6 SPF MD TVD Feet 14,786-14,848 11,952-11,989 62 - 14,862-14,880 11,997-12,009 18 Aa cm 14,888-14,915 12,014-12,030 29 14,922-14,928 12,035-12,038 6 14,956-14,965 12,057-12,063 9 r= 14,972-14,988 12,068-12,079 16 S 15,008-15,018 12,092-12,098 10 17 15,116-15,140 12,166-12,183 24 15,171-15,184 12,206-12,215 13 15,265-15,272 12,274-12,280 7 02 m 15,304-15,326 12,303-12320 22 m m 15,356-15,362 12,343-12,347 6 I r 15,378-15,386 12,360-12,366 8 Total Perforations 230 m m 5 1/2 17#L-80 15,740'MD 6 3/4"Hole ID-4.767" BTC 12,653'TVD " • RU-05B:Proposed Completion Schematic 0 Version: V1.0 4/10/2017 Tubing Hanger-ACME 3.725"MCA top connection/ GLACIER 31/2"RTS-6 btm connection-ID 2.682" 3 1/2"9.3#L80 EUE Tubing-ID 2.992"t/330'MD J1 : 13 3/8" 68#L-80 3,190'MD 18 1/2"Hole ID-12.25" BTC 2,940'TVD , t , • X/O-3 1/2"x 2 7/8"Tubing @ 10,000'MD/8,756'TVD ,,s '_F • A 4 ' 2 7/8"6.5#L80 EUE Tubing-ID 2.441"f/14,332'-10,000' MD TOL @ 11,037'MD(9 5/8"x 5 1/2") "* IMP OM ". t TOL @ 11,290'MD(9 5/8"x 7 5/8") 141 9 5/8" 47#L-80 11,500'MD 12 1/4"Hole ID-8.50" BTC 10,065'TVD ___ ESP Pump Assembly Top of Discharge Head©14,450'MD Window '-- 7 5/8" 29.7#L-80 12,928'MD 8 1/2"Hole 4 j ' , ID-6.75" BTC 10,862'TVD Perforations:3.3/8"6 SPF / 1 _ MD TVD Feet - 14,786-14,848 11,952-11,989 62 ItIli TOC @ 13,710'MD(CBL 9/17/2013) 14,860-14,862 11,995-11,997 14,862-14,880 11,997-12,009 18 14,880-14,888 12,009-12,014 8 ' 1 ,' Bottom of ESP Assembly @ 14,550'MD 14,888-14,915 12,014-12,030 29 14,915-14,922 12,030-12,035 7 _ - 14,922-14,928 12,035-12,038 6 o C 14,928-14,934 12,038-12,042 c o c 0 c 14,956-14,965 12,057-12,063 9 o c o c 14,965-14,972 12,063-12,068 7 on C 14,972-14,988 12,068-12,079 16 o c 14,988-14,994 12,079-12,082 6 0 _ c ement Retainer @ 15100'MD 15,007-15,008 12,091-12,092 1 0 '...� w/15 bbls 15.8ppg cement squeezed below 15,008-15,018 12,092-12,098 10 v 1-1• c 15,116-15,140 12,166-12,183 24 4 C 15,171-15,184 12,206-12,215 13 0 I c CII 1 15,265-15,272 12,274-12,280 7 -- ' c 15,304-15,326 12,303-12320 22 15,356-15,362 12,343-12,347 6 . -a 15,378-15,386 12,360-12,366 8 ish-ESP Assembly(+/-133ft)@ 15520'MD Total Perforations 267 it RP'" 5 1/2 17#L-80 15,740'MD 6 3/4"Hole ji, , Ti ID-4.767" BTC 12,653'TVD PBTD @ 15653'MD • S Bettis, Patricia K (DOA) From: Bettis, Patricia K(DOA) Sent: Friday, April 14, 2017 9:13 AM To: Stephen Ratcliff Subject: RU 5B (PTD 213-107): Sundry Application Good morning Stephen, Please note that CO 712 applies only to the Spacing Exception for Redoubt Unit-7B well. This conservation order does not apply to any other well in the Redoubt Unit and as such should not be listed on Form 10-403, Box 7 for"What regulation or conservation Order governs well spacing in this pool". CO 712 applies only to RU-7B well. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Ste 100 Anchorage,AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 RECEIVED STATE OF ALASKA MAR 1 3 7011 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOG 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑✓ • Repair Well ❑ 0.erations shutdown❑ Suspend ❑ Perforate ❑., Other Stimulate ❑ Pull Tubing 11 Ch- ge Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ ''her: ❑ 2.Operator Name: 4.Current Well Class: 5. _' 1 /:',rrill Number: COOK INLET ENERGY, LLC ' Exploratory ❑ Development 0 • , ,; 213-107 3.Address: :��f 't mber: Stratigraphic ❑ Service ❑ �' 601 W 5TH AVE SUITE 310,ANCHORAGE,AK,99501 50-733-20513-02-00 • 7.If perforating: 8. -/Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CA.742--&20 AAC 25.055 Will planned perforations require a spacing exception? Yes( : No EI 1' • REDOUBT UNIT#5B ' 9.Property Designation(Lease Number): 10.Fiend/Pool(s): 77 ADL 381203,ADL 374002 A of/BT SHOAL,Undefined Oil " 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total D opth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP�y-. 12100 psi Plugs(MD): Junk(MD): 15,750'MD • 12 . 15,653' ' 12,579' • odelled 7962 psi) NONE NONE Casing Length Size MDBurst Collapse Structural 200' 36" 200' N 11,'\ .W0' Conductor 3190' 13 3/8" 3190' / 9 5020 PSI 2260 PSI Surface 11500' 9 5/8" 11500' / 10065' 6870 PSI 4760 PSI Intermediate 1638' 7 5/8" 129 :' ' 862' 6890 PSI 4790 PSI Production __ __ / -_ __ Liner 4703' 5 1/2" 1 1/40' 11037' 7740 PSI 6390 PSI Perforation Depth MD(ft): Perforation Depth TVD(ft): Tu.' g Si V Tubing Grade: Tubing MD(ft): 14786'-15386' • 11952'-12366' logi ' 31/2" P110 1885 Packers and SSSV Type: 9 5/8"x 3-1/2"Retrievable Test ' 111.' Packers and SSSV MD(ft)and TVD(ft): . Packer @ 1661'MD/1615'TVD No SSV No SSV 12.Attachments: Proposal Summary L] Wellbore sche -/c 0 13.Well Class after proposed work: Detailed Operations Program ❑., BOP Sketch SO/ Exploratory p ry ❑ Stratigraphic❑ Development 2 • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 15-Apr-17 Commencing Operations: OIL Q• WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the ,rocedure approved herein will not be deviated from without prior writte approval. Contact Stephen Ratcliff Email sratcliff@glacieroil.com Printed Name Title Stephen Ratcliff Sr.Drilling Engineer Signature Phone Date \\ 907-433-3808 3/13/2017 COMMISSION USE ONLY Conditions of approval: Notify Commis-on so that a representative may witness Sundry Number: � 31 -7- II3 mica. nteg r (C,tv Plug Integrity ❑ Be'Test Mechanical Integra Test Location Clearance ❑ Other: SCANNED MAY 02017. 9 7 Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMS Lk—t:1Ry - 4 201 Spacing Exception Required? Yes ❑ No j Subsequent Form Required: r 0 H 0 L' APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Submit Form and Form 10-403 Revised 11f2015 Approved application i I 1 t o t date of approval. Attachments in Duplicate 14‘63)17f IT' CDN 3/z1/zeta RI �IR GLACIER March 13th, 2017 RECEIVED Ms. Cathy Foerster, Chair MAR 1 3 2017 Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 AOGCC Anchorage,Alaska 99501 RE: Sundry Application for Hydraulic Fracturing Cook Inlet Energy, LLC: RU-05B Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a Sundry Request to perform a hydraulic fracture for RU-05B,located on ADL 381203 and 374002 (TD), in the Redoubt Unit. Please find attached for review of the Commission the 10-403 Form,Hydraulic Frac Procedures, Post Frac Clean Up Program, Fracture Parameters, Geological Information, and Proposed Well Schematics, as required by 20 AAC 25.005, 20 AAC 25.280, and 20 AAC 25.283. Additional information includes MASP Calculations, Frac Layout,and Surface Equipment Diagrams. Rig 35,on the Osprey Platform,will be used to complete this work,commencing approximately April 15th, 2017. If you have any questions, please contact me at(907) 433-3808. Sincerely, Stephen Ratcliff Senior Drilling Engineer Cook Inlet Energy(a Glacier Oil&Gas owned company) 601 W. 5th Avenue, Suite 310 Anchorage,AK 99501 Stephen.Ratcliff@CookInlet.net 0: 907.433.3808 C: 907.433.9738 F: 907.334.6735 1 GLACIER Well To Hydraulically Fracture - RU-05B Requirements of 20 MC 25.283(a) Well Summary Current Status: RU-05B Well is currently shut-in with the ESP completion pulled and a kill string and packer run in the well. Scope of Work: (` ( S f r"`" 3 f t • Release packer and L/D kill string. • Run Frac String and cement- approved under Sundry 316-544. • Mobilize and rig up for 3 stage hydraulic fracturing operation. • Rig up and Test all surface equipment and frac string to 110% of Max Surface Treating Pressure. • Perf first stage. • Complete Data Frac to confirm breakdown. • Pump +/- 50,000 # frac in first stage. j-3 • Continue Hydraulic Fracturing Operation for remaining stages. • RU Coil Tubing Unit and clean out equipment. • Clean out well with CTU. • Run Completion Equipment,per Program - Completion Sundry to follow. • Turn well over to Production. General Well Information: Reservoir Pressure MD/TVD: 5,278 psi @ 15,150 MD / 12,190 TVD MASTP: 12,100 psi (modelled: 7,962 psi) Wellhead Type/Pressure Rating: Vetco Grey- 5M -Wellhead Assembly Vecto Grey- 15M - 4-1/16" Frac Tree BOP Configuration: Coil BOP during CTU operations. Well Type: Producer Estimated Start Date: April 15th, 2017 GLA Drilling Manager GLA Sr. Drilling Engineer GLA Production Manager Conrad Perry Stephen Ratcliff David Kumar (907) 727-7404 (907) 433-3808 (907) 433-3822 cperry@glacieroil.com sratcliff@glacieroil.com dkumar@glacieroil.com 2 4 GLACIER 1. Notice of Operations Requirements of 20 AAC 25.283(a)(1) An affidavit stating that all owners, landowners, surface owners, and operators within a one- half mile radius of the current/proposed wellbore trajectory have been provided with a notice of operations. (A) Upon request, a complete copy of the application is available. (B) Operator Contact Information is on file with the AOGCC. 2. Location Summary Requirements of 20 AAC 25.283(a)(2) (A) Well Location • General Location Kenai Peninsula Borough,Alaska • Osprey Platform Center Leg 3 - Slot#20 • Sea Bottom Elevation 45' to Mudline • RKB 89' above MSL Surface Location X-Coordinate Y-Coordinate FNL/FSL FEL/FWL Sec/T/R 200623.424' 2449931.683' 1909'FSL 318'FEL 14/7N/14W Bottom Hole Location 207093.64' 2440304.46' 1692'FSL 674'FWL 19/7N/14W (B) Water Wells located within a one-half mile radius of the well's surface location: X-Coordinate 1Y-Coordinate FNL/FSL FEL/FWL Sec/T/R Not Applicable (C) Offset Wells within a one-half mile radius of the wellbore fracturing interval: Surface Surface Surface Well TD Well TD Well TD FNL/FSL FWL/FEL BHSec/T/R FNL/FSL FWL/FEL BH Sec/T/R RU-05 1909'FSL 318'FEL 14/7N 14W 1769'FSL 577'FEL 24/7N/14W RU-05A119-09'FSL 318'FELJ14/7N/14w 40'FSL 1361'FEL 19/7N/13W_ RU 02 1819'FSL 320'FEL 14/7N/14W 2627'FNL 1307'FEL 19/7N/13W RU 02A 1819'FSL 320'FEL 14 7N 14W 2450'FSL 1780'FEL 19/7N/13Wr • RU-02A is the producing. RU-02, RU-05, and RU-05A are abandoned. See Attachment 1: Plat/As-Staked Design See Attachment 2: Equipment Layout 3 GLAC.ER 3. Identification of Freshwater Aquifers Requirements of 20 AAC 25.283(a)(3) Identification of any freshwater aquifer,within a one-half mile radius of the wellbore trajectory: Geological Name of Freshwater Aquifer: Not Applicable Measured Depth of Freshwater Aquifer: Not Applicable True Vertical Depth of Freshwater Aquifer: Not Applicable There are no freshwater aquifers within a one-half mile radius of the proposed wellbore trajectory. 4. Water Sampling Baseline Plan Requirements of 20 AAC 25.283(a)(4) Water sampling and collection of baseline water data is needed before fracturing for all water wells within a one-half mile radius of the proposed wellbore. Water Sampling Plan - Not Applicable 5. Casing and Cementing Information Requirements of 20 AAC 25.283(a)(5) RU-05B Size I Wt i Grade To. Bottom Burst Collapse E Drive Pipe 30" 0 200' Surface Casing 13 3/8" 68# L80 0 3190' 5020 psi 2260 psi Intermediate 9 5/8" 47# L80 0 11500' 6870 psi 4760 psi Casing (Window) Liner 7 5/8" 29.7# L80 11290' 12928' 6890 psi 4790 psi (Window Production Liner 5 1/a" 17# 4 L80 11037' 1 15740' 7740 psi 6390 psi • Surface casing was ran to 3190' MD and cemented with 410 bbls of 12.5ppg lead and 180 bbls of 15.8ppg tail cement. Cement was displaced with 459 bbls of water based mud. Cement returns to surface at 435 bbls displaced. The pipe was reciprocated and landed. The plug bumped and floats checked. The ES cementer was opened with 2800 psi and pumped 440 bbls of 12.5ppg lead and 95 bbls of 15.8ppg tail cement. Cement was displaced with 255 bbls of mud. Plug bumped closing the ES cementer with 2000 psi. The casing was tested to 3000 psi. • Intermediate casing was ran to 13760' MD/11927' TVD without issue. It was cemented with 168 bbls of 12.5 ppg lead and 61.7 bbls of 15.8 ppg tail, and displaced with 1016 bbls OBM. The plug did not bump, floats held. Full returns occurred during cement job. The casing was tested to 3000 psi. A USIT shows TOC at 10560' MD (dated 8/11/02). 4 GLACIER • During Sidetrack RU-05A-A window was milled in the 9-5/8"casing from 11473' - 11492'MD. A 7-5/8"liner was ran from 11290'- 15323' MD and cemented with 45 bbls of 15.8 ppg cement with full returns. Plug was bumped and float held. Casing was tested to 3000 psi. A CBL shows TOC at 11470'MD (Dated 8/23/13). • During Sidetrack RU-05B -A window was milled in the 7 5/8" casing from 12915'- 12930' MD.A 5 1/2liner was ran from 11037' - 15740 MD and cemented with 48 bbls of 15.8 ppg Class G cement. Casing was tested to 2000 psi.A CBL showed TOC at 13705' MD (dated 9/17/13). See Attachment 3: Frac String Cement Program The 3-1/2" Frac String will be cemented in place. The operation is described in Approved Sundry 316-544. A CBL will be provided once available. 6. Casing and Cementing Assessment Requirements of 20 MC 25.283(a)(6) An assessment of each casing and cementing operation has been performed with supporting information, including cement evaluation logs and the following has been determined: (A) Casing is cemented: (i) Below the base of the lowest freshwater aquifer. (ii) In accordance with 20 AAC 25.030 (B) Hydrocarbon zones penetrated by the wellbore are isolated. A Cement Bond Log for the 3-1/2"frac string will be submitted to the state by the GLA Engineer upon running the log. Cement Bond Logs are on file with the AOGCC for RU-02, RU-02A RU-05, and RU-05A, and all logs have been evaluated and determined that there is no expectation of no cement or poor cement in the zones that are within the half mile radius. See CBL's on file if further analysis is needed. • RU-05 original wellbore from 13722' - 15438' MD was abandoned with a cement retainer set in the 9-5/8" casing at 13722'MD and 57.8 bbls(25Osx) of 15.7 ppg cement squeezed below retainer and 25 sx left on top of retainer. A bridge plug was also set at 11500'MD in preparation for a whipstock. • RU-05A-A window was milled in the 9-5/8"casing from 11473'- 11492'MD. A 7-5/8" liner was ran from 11290' - 15323' MD and cemented with 45 bbls of 15.8 ppg cement with full returns. Plug was bumped and float held. Casing was tested to 3000 psi. A CBL shows TOC at 11470' MD. A 5-1/2"liner was ran from 15118' - 16995' MD and cement with 56 bbls cement. Plug was bumped. Casing was tested to 4000 psi. EZ Drill plug set at 16575'MD.The sidetrack was abandoned with a 7 5/8"cement retainer set at 13550' 5 GLACIER MD, and 10 bbls of 15.8 ppg Class G cement on top. Casing/retainer was tested to 1500 psi.A bridge plug was also set at 12928'MD in preparation for a whipstock. 7. Pressure Test Information Requirements of 20 MC 25.283(a)(7) The wellbore and frac string will be pressure tested as follows: Surface Equipment and Pumps: 12,100 psi Frac String: )9 bc, .0-psi Frac Zone Wellbore: ccta o - 6-psi e.( _ `150 0/05 Annular Pressure Held: 2,000 psi Inner Annulus Pop-Off: 2,500 psi so� psi 8. Pressure Ratings and Schematics Requirements of 20 MC 25.283(a)(8) Wellbore: 15,000 psi Frac String: 15,000 psi Wellhead: 5,000 psi (Isolated) Frac Tree: 15,000 psi Surface Equipment: 15,000 psi See Attachment 5: Frac String Schematic See Attachment 6: Proposed Wellbore Completion Schematic See Attachment 7: Wellhead Schematic See Attachment 8: Frac Tree Schematic 9. Fracturing and Confining Zone Data Requirements of 20 MC 25.283(a)(9) (A) Lithological Description of Zone: Conglomeratic Sandstone (B) Geological Name of Zone: Hemlock Total Number of Stages 3 (C) Depth of Zone: Zone 1 , JlZone 1 - Measured Depth 15 140' - 15,150' Zone 1 -True Vertical Depth 12,183' - 12,190' '1� ✓ Zone 2 Zone 2 - Measured Depth 14,950' - 14,960' Zone 2 -True Vertical Depth 12,053' - 12,059' Zone 3 Zone 3 - Measured Depth 14,812' - 14,822' Zone 3 -True Vertical Depth 11,966' - 11,972' 6 GLACIER (D) Thickness of Zone: Zone 1 Zone 1 - Measured Depth 10' Zone 1 -True Vertical Depth 7' Zone 2 Zone 2 -Measured Depth 10' Zone 2 - True Vertical Depth 6' Zone 3 Zone 3 - Measured Depth 10' Zone 3 -True Vertical Depth 6' (E) Estimated Fracture Pressure •,400 psi 10. Offset Well Report Requirements of 20 AAC 25.283(a)(10) Within a one-half mile radius of the wellbore trajectory, a report on the mechanical condition of each offset well that will transect the confining zone has been evaluated. The offset wells within a one-half mile radius, RU-02, RU-02A, RU-05, and RU-05A, will not interfere with containment of the hydraulic fracturing fluid of the proposed wellbore trajectory. See section 2 (C) above for location and orientation of offset wells. It has been analyzed and determined that there will not be communication between the frac interval on the RU-05B wellbore and the offset wells. • RU-02 - The 13-3/8" surface casing was set at 3212' MD and cemented in 2 stages with an ES cementer at 2017'. Stage 1 pumped 223 bbls of 12.5 ppg lead and 171 bbls of 15.8 ppg tail cement. The plug bumped and floats checked. The ES cementer was opened and pumped 530 bbls of 12.5 ppg lead and 95.5 bbls of 15.8 ppg tail cement. Plug bumped closing the ES cementer. The casing was tested to 3000 psi. The 9-5/8" casing was set at 9011' MD. It was cemented with 190 bbls cement and displaced with OBM. The casing was tested to 3000 psi.A 7-5/8"liner was ran from 8759'- 14320' MD and cemented with 34 bbls of 15.8 ppg cement with full returns. Plug was bumped and float held. Set liner top packer and tested annulus to 3000 psi. Casing was tested to 4000 psi. A 5-1/2"liner was ran from 14112' - 15325' MD and cement with 49 bbls cement. Plug was bumped. Casing was tested to 4000 psi. In preparation of the sidetrack, a 7-5/8" cement retainer was set at 11759'MD.Attempted to pump through EZSV without success. Set 200' (77 cuff) of 15.8 ppg Class G cement plug on top of retainer.Tagged firm cement at 11470' MD. • RU-02A-A window was milled in the 9 5/8" casing from 8517'- 8540' MD.A 7"liner was ran from 8147'- 15360' MD and cemented with 93.6 bbls of 13.5 ppg Class G cement. Plug bumped and floats held. Set liner top packer and tested annulus to 2500 psi.A CBL showed TOC at 13050' MD. 7 GLACIER 11. Geological Data Report Requirements of 20 MC 25.283(a)(11) Within a one-half mile radius of the wellbore trajectory, a review and analysis of the location and orientation of all known and suspected geological faults and fractures,that will transect the confining zone, has been evaluated. The offset faults within a one-half mile radius will not interfere with containment of the hydraulic fracturing fluid of the proposed wellbore trajectory. 12. Drilling Hazards Requirements of 20 MC 25.283 There were no losses encountered during drilling of the Hemlock in past wells or RU-05B. 13. Proposed Hydraulic Fracturing Program Requirements of 20 MC 25.283(a)(12) (A) Estimated Total Volumes Planned 28,000 Gallons per Stage (B) Base Fluid and Additives Name YF125F1exD Purpose Gelling Agent, Crosslinker, Buffer, Stabilizer,and Gel Breaker Concentration Frac Fluid: YF125FlexD 24,000 Gallons 25.0 lb/mgal Pad&Frac Fluid 20/40 CarboBond Lite 48,300 lbs per stage Flush Fluid: WF125 4,700 Gallons 25.0 lb/mgal Flush Rate 20 BPM Max (C) Max Concentration of Chemical Ingredient 8% (D) Estimated Weight/Volume of Proppant 48,255 lbs/ 11,225 gallons (E) Max Anticipated Treating Pressure 7,962 psi (F) Proposed Fracture Total Frac Height 135 ft Length - 1 Wing 143 ft Average Frac Width 0.136 inches Method of Determination SLB - Frac Cade Pre-Frac-This is a continuation of the workover operation of RU-05B: 1) Confirm the following has been completed prior to commencing operations: a) Confirm AOGCC has approved Hydraulic Frac Sundry prior to start of operations. b) Confirm that casing and liner lap has passed a 2,500 psi pressure test. c) Confirm 3 '/z"frac string is RIH,landed,cemented,and BPV in place. 2) Hold pre-job safety meeting for hydraulic fracture operations. 8 GLACIER 3) Plan to N/U for Frac Operations as follows: i) 4-1/16" 15K Gate Valve#1-Manual (Bottom of Frac Tree) ii) 4-1/16" 15K Gate Valve#2 -Hydraulic Actuated iii) 4-1/16"Frac Tee&(1)Wing Valve with 3" 1502 Unions on side iv) 4-1/16" 15K Gate Valve#2-Manual v) Goat Head- 11K Manual Valve with 1502 Connections vi) 4-1/16" 15K Gate Valve#2-Manual with 3" 1502 Union on top 4) Hold Pre Job Safety Meeting. a) Review all potential hazards with trapped pressure and risk with high pressure testing. b) Make certain that all personnel and crew members understand the hazards and where to be located. c) Confirm that all crew members are secured in a safe place while pressure testing. 5) Pull BPV. 6) Rig up necessary surface equipment and lines. 7) Rig Up Schlumberger Equipment for Hydraulic Fracture. 8) Rig up to Frac Tree and prepare for pressure test of frac string. 9) Pressure test all surface pumping equipment and lines to 12,100 psi for 10 minutes. a) Do not Pressure test frac string and liner during surface pressure test. 10)Ri Uppumping Rig p p ng equipment for holding annular pressure while testing and performing frac. a) Note-We will hold a constant 2,000 psi on annulus. b) Set Annular Safety Pop-Off Valves to 2,500 psi. c) Take Bleed Off Line to diffuser tank or Trip Tank. 11)Ensure well is open. 12)Establish minimal rate to load hole if hole is not full. 13)Pressure Test Frac String to 12,100 psi for 10 minutes and chart. a) Note-Internal Yield on 3.5", 12.95#,P-110 is 15,000 psi. b) Note-After surface pressure test,plan to set Nitrogen Pop-Off Valves at 11,000 psi. c) Plan to hold 2,000 psi on the annulus during pressure test and frac. 14)Bleed off pressure in frac string. 15)Bleed off annulus pressure. 16)R/D Frac lines and prep for E-line. 17)Rig up wireline equipment and pressure test. a) Frac will be a Plug and Perf System. b) Will plan to perforate each zone individually before hydraulically fracturing each stage. 18)Prepare for Frac Operations a) Verify that the pump safety kick outs are set at 11,000 psi before moving into frac operations. Procedure Data-Frac-Zone 1 19)Hold&document pre job safety meeting. 20)Review entire rig up procedure,with applicable personnel,and ensure everyone fully understands work objectives and appropriate safety practices. 21)Ensure well is open. 22)Pickup 10'wireline perf guns. 23)RIH with perf guns to Zone 1 a) Confirm with GLA Engineer on actual interval. b) Expected Perf Interval: 1 Middle Hemlock 15140'MD 15150'MD 12183'TVD 12190'TVD 24)Correlate guns on depth. 9 GLACIER 25)Fire guns,per service company procedure. 26)POH with wireline and L/D perf guns. 27)N/D lubricator and wireline. 28)Hold&document pre job safety meeting. 29)Review entire rig up procedure,with applicable personnel,and ensure everyone fully understands work objectives and appropriate safety practices. 30)R/U Frac Lines and Pressure Test,per SLB Procedure. 31)Establish minimal rate to load hole if hole is not full. a) Note-Max Pump Rate of 20 BPM. 32)Consult with GLA Engineer and follow most recent Stimulation Procedure. 33)Pressure up on Annulus to 2,000 psi and hold. 34)Inject at matrix rate to ensure perfs are open,if able. 35)Wait for Pressure to stabilize. 36)Step up rate while watching for breakdown pressure until frac rate is established. 37)Hold steady rate until pressure stabilizes for at least 1/i to 1 min. 38)Hard shutdown,monitor leak-off until well is dead or pressure stops declining and stabilizes. a) Pressure data is critical for Pressure Transient Analysis. b) Confirm with GLA Engineer before bleeding off pressure. 39)Displace with 200 bbls of Linear Gel. 40)Shut Down and Monitor Pressure. 41)Send data to engineer for analysis. a) If a breakdown was present then proceed with actual frac after conferring with GLA Engineering. Procedure-Middle Hemlock Frac-Zone 1 42)Hold&document pre job safety meeting 43)Confirm that all necessary materials are on location and accounted for. 44)Ensure well is open and 2,000 psi is held on the backside. 45)Follow Schlumberger Pump Schedule and Procedure for pumping frac. a) Note-Prior to pumping,confirm with GLA management on latest pump schedule. b) Note-Max Pump Rate of 20 BPM. 46)Pump all chemicals. a) Bring each frac pump up to rate with cross-linked fluid. b) Flush will be called when proppant concentration drops by 2.0 pps. c) Once Flush volume has been pumped,close in the well and allow cross-linked fluid to break. d) If pressure is released before the cross-linked gel has broken,proppant may be carried into the wellbore. 47)Complete pump schedule and shut down. a) If a pre-mature screen out occurs,pumps will shut down at 11,000 psi. i) Note-This will be revised after 1st Data Frac. b) Nitrogen Safety Pop Off Valves are set to relieve pressure at 11,000 psi. c) If no screen out then move to next stage. i) If a screen out occurs,confer with GLA Engineering on clean out procedure with Coil Tubing. 48)Bleed off annulus and tubing pressure. 49)Prepare to move to Zone 2 Frac. Procedure-Upper Hemlock Bottom Frac-Zone 2 50)Hold&document pre job safety meeting for Stage 2 Frac. 10 GLACIER 51)Plan for Data Frac prior to Pumping stage 2 Frac(See data Frac Procedure Above). 52)R/U wireline,lubricator,and pressure test. 53)Ensure well is open. 54)If no prior screen out then dummy run may not be needed. 55)P/U 15K Frac Plug and running tool on E-line. 56)RIH with Frac Plug to 5'above last perforation interval. 57)Set Frac Plug,per Schlumberger Procedure. 58)POH and L/D Running Tool. 59)Pickup 10'wireline perf guns. 60)RIH with perf guns to Zone 2. a) Confirm with GLA Engineer on actual interval. b) Expected Perf Interval: 2 Upper Hemlock Bottom 14950'MD 14960'MD 12053'ND 12059'ND 61)Correlate guns on depth. a) Confirm with GLA Engineer prior to setting guns. 62)Fire guns,per service company procedure. 63)POH with wireline and L/D perf guns. 64)R/D lubricator,wireline,and prep for pumping frac. 65)R/U Frac Lines and Pressure Test,per SLB Procedure. 66)Consult with GLA representative and follow most recent GLA Stimulation Procedure. 67)Pressure up on Annulus to 2,000 psi and hold. 68)Inject at matrix rate to ensure perfs are open,if able. 69)Wait for Pressure to stabilize. 70)Follow Schlumberger Pump Schedule and Procedure for pumping frac. a) Note-Prior to pumping, confirm with GLA management on latest pump schedule. b) Note-Max Pump Rate of 20 BPM. 71)Pump all chemicals. a) Bring each frac pump up to rate with cross-linked fluid. b) Flush will be called when proppant concentration drops by 2.0 ppa. c) Once Flush volume has been pumped,close in the well and allow cross-linked fluid to break. d) If pressure is released before the cross-linked gel has broken,proppant may be carried into the wellbore. 72)Complete pump schedule and shut down. a) If a pre-mature screen out occurs,pumps will shut down at 11,000 psi. b) Nitrogen Safety Pop Off Valves are set to relieve pressure at 11,000 psi. c) If no screen out then move to next stage. i) If a screen out occurs,confer with GLA Engineering on clean out procedure with Coil Tubing. 73)Bleed off annulus and tubing pressure. 74)Prepare to move to Zone 3 for Stage 3 Frac. Procedure-Upper Hemlock Top Frac-Zone 3 75)Hold&document pre job safety meeting for Stage 3 Frac. 76)Plan for Data Frac prior to Pumping stage 3 Frac (See data Frac Procedure Above). 77)R/U wireline,lubricator,and pressure test. 78)Ensure well is open. 79)If no prior screen out then dummy run may not be needed. 80)P/U 15K Frac Plug and running tool on E-line. 81)RIH with Frac Plug to 5'above last perforation interval. 11 GLACIER 82)Set Frac Plug,per Schlumberger Procedure. 83)POH and L/D Running Tool. 84)Pickup 10'wireline perf guns. a) Confirm with GLA Engineer on actual interval. b) Expected Perf Interval: 3 Upper Hemlock Top 14812'MD 14822'MD 11966'ND 11972'ND 85)Correlate guns on depth. a) Confirm with GLA Engineer prior to setting guns. 86)Fire guns,per service company procedure. 87)POH with wireline and L/D perf guns. 88)R/D lubricator,wireline,and prepare for pumping frac. 89)R/U Frac Lines and Pressure Test,per SLB Procedure. 90)Consult with GLA representative and follow most recent GLA Stimulation Procedure. 91)Pressure up on Annulus to 3,000 psi and hold. 92)Inject at matrix rate to ensure perfs are open,if able. 93)Wait for Pressure to stabilize. 94)Follow Schlumberger Pump Schedule and Procedure for pumping frac. a) Note- Prior to pumping,confirm with GLA management on latest pump schedule. 95)Pump all chemicals. a) Bring each frac pump up to rate with cross-linked fluid. b) Flush will be called when proppant concentration drops by 2.0 ppa. c) Once Flush volume has been pumped,close in the well and allow cross-linked fluid to break. d) If pressure is released before the cross-linked gel has broken,proppant may be carried into the wellbore. 96)Complete pump schedule and shut down. a) If a pre-mature screen out occurs,pumps will shut down at 11,000 psi. b) Nitrogen Safety Pop Off Valves are set to relieve pressure at 11,000 psi. c) If no screen out then prep for milling and cleanout operations. i) If a screen out occurs,confer with GLA Engineering on clean out procedure with Coil Tubing. 97)Bleed off annulus and tubing pressure. 98)Prep for coil cleanout and milling operations. Procedure-Post Frac Clean Out 99)Hold&document Pre-Job Safety Meeting. a) Confirm that BOPE Test is still valid or schedule BOPE Test with AOGCC. 100) Review entire rig down procedure to ensure everyone fully understands work objectives and appropriate safety practices. 101) Caution for potential hazards and trapped pressures. 102) Shut in well at frac tree by closing 4-1/16" 15K Actuated Gate Valve. 103) Rig Down Schlumberger Equipment and clear the rig floor. 104) R/D Wireline Equipment and Lubricator. a) Frac tree will remain in place 105) N/U Coil Tubing BOPE to 4-1/16" 15K Flange. a) Notify AOGCC 48 hours ahead of upcoming CTU BOPE Test. 106) Test CT BOPE,per Service Company Procedure. a) Open manual valve on frac tree after CT BOPE is installed and tested. 107) Rig up CTU and prepare to RIH to Mill Plugs and Clean Out Well. a) Make sure equipment is rigged up for reverse circulating. 12 GLACIER 108) Nitrogen lift will be utilized directly after Coil Cleanout. 109) Pick up Clean out BHA,Motor,and Mill. 110) RIH on coil tubing to liner top at+/- 11,000'. a) RIH and watch running speeds in anticipation for fill. 111) Continue RIH and report fill depth on daily report if encountered. 112) Clean out each stage from heel to toe of well. a) Report any issues or fill on report. b) Document on report if losses are encountered. 113) Circulate well clean with kill weight fluid and prepare to POH. 114) Confirm that well is dead. 115) POH and L/D clean out BHA. 116) Confirm Pressure on tubing and annulus is zero. 117) Install BPV. 118) Shut in 4-1/16" 15K Gate Valve below frac tee. 119) N/D Coil Tubing BOPE. 120) N/D Frac Tree. 121) Move to Completion Sundry. 14. Proposed Post Frac Clean-Up Program Requirements of 20 AAC 25.283(a)(13) Schlumberger Coil Tubing will be on location with a 19,000' - 1.75" CT string for any clean out needs. Uses/Unused hydraulic fracturing fluid will be disposed down the RU-D1 - Class 1 Disposal Well. ----- Procedure-Screen Out(Per Schlumberger) 1) R/U 1.75"Coil Tubing, PT BOPE to 4,500 psi HI 250 Low for 5 min. 2) M/U jet nozzle for washing down operations.Stab on well,PT lubricator and flowlines to 250/4,500 psi. 3) RIH at 20 ft/min near the jewelry and tubing restriction.Increase the running speed to'60 ft/min if the tubing is clear and perform pull test for every 1000 ft. 4) While RIH,pump KCL down tubing and take returns to tank.Monitor returns for sand and tank levels in returns tank 5) Verify with Company Rep potential sand depth in the hole.Start RIH to about 500 ft or pre- determined sand depth, RIH slowly to perform dry tag top of sand.A dry tag as a first run is advised to verify where fill will be encountered. 6) Once top of fill determined,pull CT 20 ft,and line up to performed conventional fill cleanout circulation at maximum rate. a) During Operation conduct frequent WT checks and increase frequency if losses occur. 7) Wash down to desired TD depth. 8) Once reached TD,circulate 2 annulus volumes.Monitor return tank levels and return volume. Discuss returns with the Company Rep. 9) POH coil 500 ft from TD. Stop circulating.Wait 30 minutes. RIH with coil pumping and tag bottom. If tag is above desired TD depth (review results with Company rep),then repeat steps 6-8 until fill remains below this depth. 13 GLACIER 10) POH with coil.Unstab coil from well. 11) Blowdown the string with N2.RD Coil. 12) Turn well over to Operations. 15. Hydraulic Fracturing Requirements of 20 AAC 25.283(b) Hydraulic fracturing done through the production or intermediate casing will have a pre-casing test to 110 percent of maximum anticipated pressure differential. If the casing fails the pressure test, casing will be repaired prior to starting the frac or a frac string will be utilized. Requirements of 20 AAC 25.283(c) Hydraulic fracturing done through a fracturing string must be: (1) Stung in to a liner or run on a packer set at a measured depth of not less than 100 feet below the cement top of the production casing or intermediate casing (2) Tested to 110 percent of maximum anticipated pressure differential CIE will perform the hydraulic fracture through a frac string. Requirements of 20 AAC 25.283(d) A pressure relief valve will be installed on the treating line between the pump and the wellhead to limit line pressure to the test pressure determined under(a)(12)(E) of this section. The well will be equipped with a remotely controlled shut-in device. Inner annulus pressure relief valve will be set to pop-off at 2,500 psi. Surface lines are protected with pop-off valves set at 11,000 psi. Shut down surface pressure from the pumps is set at 11,000 psi. Requirements of 20 MC 25.283(e) The placement of all hydraulic fracturing fluids will be contained to the approved formations during the hydraulic fracturing operations. Requirements of 20 MC 25.283(f) Surface casing pressures shall be monitored with a gauge and pressure relief device while frac operations are in progress. (and) 14 GLACIER The annular space between the fracturing string and the intermediate or production casing will be continually monitored. The pressure in the annulus will not exceed the pressure rating of the lowest rated component that would be exposed to pressure if the frac string failed. Requirements of 20 AAC 25.283(g) During fracturing operations, all annulus pressures will be continuously monitored and recorded. IF at any time during hydraulic fracturing operations, annular pressure increases by more than 500 psig above anticipated increases, CIE shall perform the following: (1) Notify the commission as soon as possible,but not later than 24 hours after the incident (2) Implement corrective action and/or increased surveillance (3) Submit a Report of Sundry Well Operations (Form 10-404) not later than 15 days after the incident Requirements of 20 AAC 25.283(h) A Report of Sundry Well Operations (Form 10-404) will be completed and submitted to the commission no later than 30 days after completion of the hydraulic fracturing operations. Attachments Attachment 1: Plat/As-Staked Design Attachment 2: Equipment Layout Attachment 3: Cement Program Attachment 4: Cement Bond Log-Will be submitted when available. Attachment 5: Frac String Schematic Attachment 6: Proposed Wellbore Completion Schematic Attachment 7: Wellhead Schematic Attachment 8: Frac Tree Schematic Attachment 9: FracCade Stim Proposal Attachment 10: Trajectory and Spider Plot A tachmeiit 11; Affidavit Providing Notice of Operations Attachment 12: Geologic Frac Summary TITLE —1 NAME SIGNATURE DATE APPROVED Engineer- Originator Engineer - Review Superintendent _ Drilling Manager 15 MILLER RIG-35-Schematic . . f r_ . ..,. n •.1c gi ih: '' is at iimcs 1FA 111, . : ,.4 IA V NON WO . '.... arib it mat 4-.4 • ',' . to , ionsaiii rA . I ,.,4 , . . n ' . 1,. AL 'A. i . ell . 1010100 iLL 1 3 r a • . Al r N4 r 1 ii 1r lit.* /414 ; . .1-y • •;----- r;:::.'--..'..""t:4-''''' e. • 1 ..... ''''''-.'"*/* *KU iel ft --- - 1 ! 4.-4.,.....!L**..17170c."641• • I M'rritri I , /- % .• • i::'11 p . ' ,r, DRILLING RIG ARR /44W NI FAST SIDE , .... .: APPOM. DAG __. : WALLS s mamma litittiki. ,....,...,_... , --- wow ... ..,.. .. ..... ; ! . s k.3431 OSPRIT r0111.1% AZ keem, i ,:_,N I. 14 T7N R1 SM A ijseiSECTION 300 450 600 O RE P LAT F•R M NORTH GRID SCALE 1 inch =300 ft. See Deta. + 322 FEL li •r 269' FEL 7 WELL SLOT #8 WELL SLOT 6 #22 #12 • ' WELL SLOT PT.NO.21 WELL RU-7 a r #9 ,( CENTER LEG 3 WELL SLOT / ` LAT:60°41'43.698"N #10 VVI LON: 151°40'14.573"W #11 WELL SLOT ` N:2449936.607' WELL SLOT ..`V E:200623.926' OSPREY PLATFORM \ ASP ZONE 4 NAD 27 EL E1 S EA BOTTOM:-45'MLLW DETAIL 1"=20' WELL RU D-1 PT.NO.6 #18 CENTER LEG 2 O WELL RU-2 LAT:60°41'44.155"N #19 LON: 151°40' 13.520"W V O WELL RU-1 N:2449981.637' r. e- E:200677.509' #14 ASP ZONE 4 NAD 27 �j WELL RU-4 ELEV SEA BOTTOM:-45'MLLWLi- LL �' c #15ccoo #20 WELL RU-3 - rn #16 WELL RU-5 See Tabular Sheet for Well Slot Coordinates `N,‘N'tI% c 1.BASIS OF HORIZONTAL AND VERTICAL �s 1 CONTROL WAS DETERMINED BY AN OPUS ��• OF A4 l i,,C SOLUTION FROM CORS BASE STATIONS Mir Q..• • "AC23 PID DM748"&"AC51 PID DD1812"& "KEN5 PID DJ3029"ALASKA STATE PLANE =*:a g� •'� �I/ 0 NAD 83 ZONE 4 EPOCH 2010 HORIZONTAL / * CD DATUM AND NAVD88 VERTICAL DATUM / Atr UTILIZING GEOID12A. 2)SECTION LNE OFFSETS DETERMINED /M .SCOTT McLANE• fc ow FROM PROTRACTED SECTION CORNER II '" 4928-S f 3)MLLW ELEVATIONS WERE DERIVED ��2. '•Sept 15,2015• Via`\ FROM NOAA NAUTICAL CHARTS. .11 VALUES. fa ‘•1', I �''f a ss'sr�N- :No NOTES 11 t‘NANNN cam,.+:,.� 1 v�.vuvlI Line OSPREY PLATFORM COOK INLET, ALASKA /Irk ENGINEERING-TESTING WELL LOCATIONS NAD27 SURVEYING-MAPPING MCI w ,' CLIENT: �}�v P.O.SOLDOTNA,AK.99669 COOK INLET ENERGY, LLC VOICE:(907)283-4218 601 W. 5TH AVENUE SUITE 310 FAX:(907)283-3265 Cook Inlet Energy ANCHORAGE,AK 99501 WWW.MCLANECG.COM Consulting Inc PROJECT NO. DRAWN BY: DATE: LOCATION: 133075 PROTRACTED SECTION 14 msm Sept 15,2015 TOWNSHIP 7 NORTH, RANGE 14 WEST SEWARD MERIDIAN,ALASKA Locadpn:GkInlet,Alaska(Offshore) lacier Oil San#dlptZGSaAs �/.�: Field: Redoubt Shoal Well: Redoubt Unit#5B ER Facility: Osprey Platform Wellbore: RU-05B HUGHES GLACIE$ Plot relerexe wellpetn is RU-0561 e12O15-15750> Grid SWAIN,NA027/TM 0us04 SP.zone 4(5004).US feet TrueveOcel depths Are referenced to Rip 80.I(RT) 1=Wpllpath wee 4erinformed from a defererd geodal0 datum Meeeured depths ere referenced to Rig 80.1(RT) North Reference:Ord north Rig 80.1(RT)b leen See Level:80.1 Wet a rue distance Mean See Level to Mud Nm(At Slot Leg..Slot 20(RU6 8 50)):45 feet Deplhe ere in feel Coordinates AN in feat referenced to Slot Created by:ubicard on 201,02-28 Database:WA ANC Oen S ae,IR h=500 Easting(ft) 4500 5000 5500 6000 6500 7000 7500 I I I 1 I I -4000— —-5000 -4500..• ----62-.1.) —-4500 ill • • g61i > -8000— —4000 4500— —4500 • -7000— —-7000 \s9 r -7500— —-7500 • 1 I I I I I • 4500 6000 5500 6000 6500 7000 7500 Scale 1 Inch=500 Easting(ft) no Ayc N v C4/ �c Id pi.uayiw o fi F.-c ca x91000 8L In In A (i9'8 x,ZT)OM '' _ li u. u. ,:-01 0 0 F. * _ .3C Ii0 x ei Ca Its g " n� a � � II. x � # HOZ x.Z.B u _J .-r an se u o s91000'ZT "4N " '-iN 8 1 e il O „, I e1 G 0 -tl * -c. 0 r sit qt v deo • : - kIa§ 114 _� in CP CS de g 8 i i8x,9TI .o a qei 3ei1/gel Pnvg SQ6000'oi N 8#Pid e tool i!o� g OT#)Ptd II I I�pyu►toy t i 1 e Li I cc-ro . ....... . . 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(,9'8 X in)OHS LL ID Sg1000'Ob ,ZZ x,OZ)iaPual9 0Od P a -Y1 -8 ; l 4 S I= 0 iJ Irm oei Ito I 14y — At sqI 000'99 111. ll (,8 x,0£)dua�ad tt M aI sql 000'99 (,8 X,0£)dul ld a I 1 I t I 4 II I I I i I i I I ii (Z6qI Xo,SZ':'LZ )dwnd .ce to tio i IIeMAU B r�= kT,. b s P, ., A._ - , . ,,.. ..... „....,.....__:,„,„:..,„„„ r,- r,,,,: ,, i09,44,, ,,,,wr.,:+4,r,-, t ,,,,) rr,,,,,p.r.----,,,... 17:6 if t„ : -='.. ...,,,,,,,,,,,,,,,, ,,,2,- ,,,_ , 241,0,4 ,...., r, + -* . ,tithL # ac .4e" vikk,k7 +`� ,:fir, q Y ' nay „ ,, String: 3.5-in Tubing Well Name: RU-05B Company: Glacier Oil &Gas Field: REDOUBT SHOAL Contact: Mr. Stephen Ratcliff Well Location: Cook Inlet,Alaska (Offshore) Well Number(API): Osprey Platform Proposal Number: 3 Date: 8/18/2016 Made By: Rianne Campbell Service from District: Kenai,AKA District Phone: Objective: Cement Tubing into place to Isolate Perforations. Acceptance Criteria: Pump per design (Volume, Density, Rate) Disclaimer Notice Schlumberger submits this document with the benefit of its judgment,experience,and good oilfield practices This information cents,ided min accordance with genera t are opted l infallible practice,relying on rads or information provided by others,limitations,computer Schlumberger moculation s are sba edtioos and inferences inform Mat are All pr opo als r Calculations are estimates based on nsprovided infatuation. proposals,recommendations,or predictions are opinions only. NO WARRANTY IS GIVEN CONCERNING ACCURACY OR COMPLETENESS OF DATA,INFORMATION PRESENTED,EFFECTNENESS OF MATERIAL,PRODUCTS OR cuooi¢c nrrnnenncninnnnue nnnnc na accinlc reTue ccmnrcc racnmcaon Well Data Summary The cementing program incorporates the following data : All depths take the rig floor as reference RigType Offshore Mud Line Depth 345.0 ft Fluids Return to Water Depth 185.0 ft Mud Return Depth 79.0 ft BHST 206 degF Section MD 15740.0 ft Section TVD 12652.6 ft Tubulars and Casing Hardware MD OD Joint Weight ID Grade Collapse Burst Thread ft in ft lb/ft in psi psi Prey Casing 11037.0 9 5/8 40.0 47.0 8.681 L-80 4750 6870 API 15740.0 51/2 40.0 17.0 4.892 L-80 6290 7740 API Casing 15640.0 3 1/2 40.0 9.3 2 9/10 L-80 10538 10160 KS Bear Landing Collar 15560.0 Serial number : Float Shoe w Oft r "Via OP l irElirrtion(dem Eirmslydal Departure t t) av w: x;741 =kY.L'i Mk rt:: .. ' G G .. I i K.iniLtort lag) , I —+Iarkmziai Departure Ft) li E \ , HH . s 1 _- s -i i i c. I Y: Cr v 4 4/V11,1 - _ I I G 3¶rdi iCasing' ..- .,\ 1 I -k42; _ ' 14 ft i Aa tick. i 17 ! I 15560ft 1 1�Y I' a• �/�� 15740 ft 1 2of 12 SchIumbrnr 1 t , Open Hole Total Volume 0.00 bbl Minimum Diameter 6.750 in Maximum Diameter 6.750 in Mean Diameter 0.000 in Mean Annular Excess 20.00% Mean Equivalent Diameter 0.000 in MD Oft ft 345ft WaU^` : i t I 1 I 1103715,658 le _ , 1 164* , . 1 ', 1 , :15560A I.V.7...._,_.._ ,... 15740*Formation Frac Pore Top Bottom Bottom Frac Bottom Pore Bottom Res. MD MD TVD Top ED ED Top ED ED Lithology Fluid Name ft ft ft lb/gal lb/gal lb/gal lb/gal 345.0 15740.0 12652.6 4.59 14.27 4.59 8.97 Sandstone Sand Temperature Relative Name Top MD Bottom MD Bottom TVD Temperature Gradient Gradient Sea Current ft ft ft degF degF/100ft degF/100ft ft/min Surface 0.0 0.0 0.0 80 0.00 0.00 SeaLevel 0.0 160.0 160.0 80 -0.02 -0.02 10.13 3 of 12 Schlumharnewp x Temperature Relative Name Top MD Bottom MD Bottom TVD Temperature Gradient Gradient Sea Current ft ft ft degF degF/100ft degF/100ft ft/min SeaBed 160.0 345.0 344.9 73 -2.15 -4.00 10.13 Rock 345.0 14950.0 12053.0 199 0.99 1.08 0.00 Rock 14950.0 15038.0 12112.1 201 1.00 3.18 0.00 BHST 15038.0 15640.0 12567.7 206 1.00 1.00 0.00 G #1s+mai Profile(degF) 60 80 01: 120 140 160 1:t 20� 22:' C r i4i 0 7 C, G N. w 88 R. 8 .r. „, , \ c , 4 of 12 Schlumhnrnnr Fluid Placement Surface Densities are computed at P=1 atm and T=Surface Temperature(80 degF) Fluid Placement in Annulus Fluid Name Top MD Bottom MD Length Volume Surface Density ft ft ft bbl lb/gal Sea Water 79.0 12964.2 12885.2 693.66 8.60 SPACER 12964.2 14286.0 1321.8 15.00 11.50 16.5 ppg Class G 14286.0 15640.0 1354.0 15.37 16.50 Fluid Placement in Pipe Fluid Name Top MD Bottom MD Length Volume Surface Density ft ft ft bbl lb/gal Sea Water 0.0 15560.0 15560.0 127.12 8.60 16.5 ppg Class G 15560.0 15640.0 80.0 0,65 16.50 MD Oft _,r=. ..' Sea?'tater I 1 I I S.ea!'la`rx 11037?? 1 1 12%4ft. ,_ H SPACER I o v yyy us: Y. m ij 14285 t 16.5 frpg Oats G Sea,le,e, 155600 : 15740 0 5 of 12 Schiurnhornar :t j. Pumping Schedule Pumping Schedule Pump Injection Cumulated Fluid Name Duration Volume Rate Temperature Comment Time hr:mn bbl bbl/min degF hr:mn SPACER 00:03 15.00 6.00 68 00:03 Plug 00:10 00:13 16.5 ppg Class G 00:03 16.02 6.00 68 00:15 Top Plug 00:10 00:25 Sea Water : 00:18 127.12 > Sea Water 00:17 117.10 7.00 68 00:42 > Sea Water 00:01 10.02 7.00 68 00:43 Maximum Required Hydraulic Horsepower(HHP) 574.9 hhp(at 00:43 hr:mn) 6 of 12 Schlumhnrnnr m —Pump rale(bbV r ) Return Rabe ittrkr n co r-- o _ I I 00:00 00:10 00:20 0030 00:40 Time(flrmn) o —Pump>x (psi) —l:errtteed mane ip* §- g c, Qso o 00:00 00110 00:20 00:30 00140 Time(f►rmn) Le Et tom die prune ED(irtgat) Pae Pressure At Bottom holt —Frac Preawes At Bolton bale Statc Barri'al bottom ED(DJga3) ED(1 110) ED Ittigal) r ? co 00:00 00:10 00:20 00:30 00:40 Time(Wren) 7 of 12 SchlurnhflrnRr RR' i v.' kl+..' 1f .yes i .'~r Well Security Well Security Status Description Min Differential At Depth At Time Pressure ft hr:mn psi N/A Fracturing 0 0.0 00:00 N/A Production/Influx 0 0.0 00:00 Success Burst 6930 79.0 00:43 Success Collapse 9140 15640.0 00:43 N/A Dead-End Collapse 0 0.0 00:00 N/A Dynamic u-tubing in Dead-End 0 0.0 00:00 N/A Balanced u-tubing in Dead-End 0 0.0 00:00 Nal ,G 2 4 S E 10 12 c c — AVMS Neve ED[may deo A, f�ED tb'gat C� L\----------,_4 V CD Q co IP RN 0 to 8 of 12 SchlumhRrner k . • ~ ' s Temperature Outputs Temperature Summary Table Static Temperature.at TOC 195 degF Static Temperature at BH 206 degF Simulated HCT at TOC 192 degF Simulated HCT at BH 194 degF Max First SK Temperature 195 degF Max Last SK Temperature 194 degF At time 00:41 hr:mn At time 00:43 hr:mn C 7 at Bottom HOP{tF} Sea i+datet 1 SPACER Intettace 7e {s(degF) SPACER!1&.5 pm Class G fritert Tern;!degF) 1&.5 ppg Class G i Sea mate+ intetime Inc(fief SY5 C• 8 8 00:00 00:10 00:20 00:30 00:40 F 60 80 100 120 141 160 180 200 221.: G ',."e+irrlYtai Virlp (clef e ) 7 m annulus at tm 7 rt ptpe rime f deg!) S' C C p c C' Com; te : 9 of 12 Schlumherner . 1,.:. ..,,i::¢tia >3n,,.. yro I Centralization Centralizers Commercial Alias Manufacturer Name Type Config Csg OD Min OD Max OD Count in in in SPIRAGLIDER HD-4 Hannover Not Set rigid Not Set 41/2 6.252 6.252 0 1/2-4-SPIRAL650 SpiraGlider HD-5 0-4- Hannover SpiraGlider HD rigid Spiral 5 6.252 6.252 0 Spiral650 SpiraGlider SC-3 1/2- Hannover SpiraGlider SC rigid Spiral 31/2 4.126 4,126 12 4-Spira1437 Pattern Placement Bottom MD Joints Centralizer Alias Pattern Min STO Depth ft ft 14200.0 355.00 - 0 0.00 180.4 15640.0 36.00 SpiraGlider SC-31/2-4-Spira1437 1/3 0.00 14202.8 MO 9, Oft .1.4.1_11._._n7---.------—„-` _-- Goa •-4aterr 0 2E' 41 e: 80 100 i !t .-,.. . 1 O 7g 1 ... ._ _ _ W op ... 3 W j I . .. 11037ft_ 8 C'r V" ... 12964R 3PfiCER, • I ' 165 vws etasc 14296 R CL5 -: to Sig CfassG` 155608__. II 15740 R Computation time:Cement Turns 00:41 10of12 SchIomhRrner v 009' a r ' -s.. WELLCLEAN* III Average Fluid Concentrations Average fluid concentration in annulus Average fluid concentration in pipe Average Concentration(96) Average Concentration(%) 0 20 40 80 80 100c 0 20 40 ii0 80 100 120 -Sea Water in ann.(% —Sea Water in{eye % -SPACER in arm.(% —SPACER In p e('K? g 16.E g Class 0 in Ran_ 16.5 ppg Class G in i> 1 (%) I i i m as M 1 I 1 1 11 of 12 SchIllmhnrnp.p ottr*-a,' Final Fluid Concentrations MD DR jj 3458 Sea we., .-1 14400_ arr • 14600_ • 14800_ 15000_ Sea.Watee 15400_ 11037* 15600_ 12964* _SPACER Fluids Concentrations ..:16.5ppg Class G 142861E --' ----.._--I Sea Water SPACER 16.5 ppg Class G �a 1Malrr 1� 12 of 12 SchlumhRrnpr RU-05B:Current Wellbore Schematic Version: Current 1/30/2017 GLACIER Tubing Hanger-3 1/2"RTS-6-ID 2.682" 71 �---9-5/8"x 3-1/2"Storm Packer @ 1661'MD R Profile @+/-1769'MD s.0 3 1/2"12.95#P-110 PH6 Tubing-ID 2.625"t/1855'MD 'r 13 3/8" 68#L-80 3,190'MD 18 1/2"Hole I I ID-12.25" BTC 2,940'TVD x*!a r TOL @ 11,037'MD(9 5/8"x 5 1/2") PiiiiiFish-ESP Assembly-tag @ 11082'MD if TOL @ 11,290'MD(9 5/8"x 7 5/8") ti 9 5/8" 47#L-80 11,500'MD 12 1/4"Hole , k ID-8.50" BTC 10,065'TVD Window 7 5/8" 29.7#L-80 12,928'MD 8 1/2"Hole I , ID-6.75" BTC 10,862'TVD TOC @ 13,710'MD(CBL 9/17/2013) ' Perforations:3-3/8"6 SPF MD TVD Feet 14,786-14,848 11,952-11,989 62 14,862-14,880 11,997-12,009 18tot CiN 14,888-14,915 12,014-12,030 29 - 14,922-14,928 12,035-12,038 6 14,956-14,965 12,057-12,063 9 14,972-14,988 12,068-12,079 16 ffi tzs 15,008-15,018 12,092-12,098 10 15,116-15,140 12,166-12,183 24 15,171-15,184 12,206-12,215 13 15,265-15,272 12,274-12,280 7 1' 15,304-15,326 12,303-12320 22 1:111( 15,356-15,362 12,343-12,347 6 15,378-15,386 12,360-12,366 8 Total Perforations 230 dn+ jr 5 1/2 17#L-80 15,740'MD ` 6 3/4"Hole �u D-4.767" BTC 12,653'TVD RU-05B-Frac Wellbore Schematic Date: 10-Nov-16 Version: 3.0 GLACIER L Tubing Hanger-ACME 3.725"MCA top connection/ 3 1/2"12.95#P-110 PH6 btm connection 36" 150#A-36 200'MD ID-34.00" Welded 200'TVD 13 3/8' 68#L-80 3,190'MD 18 1/2"Hole ID-12.25" BTC 2,940'TVD 3 1/2"12.95#P-110 PH6 Tubing-ID 2.625"@ 15,645'MD I k TOL @ 11,037'MD(9 5/8"x 5 1/2") TOL @ 11,290'MD(9 5/8"x 7 5/8") 9 5/8" 47#L-80 11,500'MD 12 1/4"Hole I I ID-8.50" BTC 10,065'TVD �3r tt7i� L›�✓ �� lJ Window 7 5/8" 29.7#L-80 12,928'MD 8 1/2"Hole I ''/ ID-6.75" BTC 10,862'TVD TOC @ 13,710'MD(CBL 9/17/2013) 17.---'"'""^• — .t-- ,._ I5_.rrL' V I i Planned TOC @+/-14,286'MD (Top of old perfs @ 14,786'MD) ) z 0- Frac Zones TBD ii -.,1 5 1/2 17#L-80 15,740'MD 6 3/4"Hole I ID-4.767" BTC 12,653'TVD RU-05B-Proposed ESP Wellbore Schematic Date: 23-Feb-17 Version: 5.0 Tubing Hanger-ACME 3.725"MCA top connection/ GLACIER I 3 1/2"RTS-6 btm connection-ID 2.682" f 36" 150#A-36 200'MD ID-34.00" Welded 200'TVD i 3/8"Stainless Line --- - -- _ 3-1/2"SSSV-2.992"@ 300'MD/300'TVD 1"Vent Valve @ 500'MD/TVD sr 1T Tripoint Dual ESP Packer @ 500'MD/TVD-ID-2.992" aka^- - 3-1/2"X-Nipple-ID-2.813" _Y 18 1/2"Hole 13 318" 68#L-80 3,190'MD ID-12.25" BTC 2,940'TVD Ai y 3 1/2"9.34 L-80 EUE Tubing-ID 2.992' .4 sort 9 by"'—-- ""�`X/O-3 1/2"x 2 7/8"Tubing @+/-10,000'MD/8,756'TVD -T!i �`""'� 2 7/8"6.5#L-80 EUE Tubing-ID 2.441" TOL©11,037'MD(9 5/8"x 5 1/2") _- ---------------- ', ' TOL @ 11,290'MD(9 5/8"x 7 5/8") .t 9 5/8" 47#L-80 11,500'MD 12 1/4"Hole ID-8.50" BTC 10,065'TVD --- Dual 3/8"Stainless Flat Pack Lines Window 7 5/8" 29.7#L-80 12,928'MD 8 1/2'°Hole ID-6.75" BTC 10,862'TVD TOC @ 13,710'MD-(CBL 9/17/2013) `-----'—ESP Assembly Top©+/-14,120'MD/11,554'TVD ESP Cable to Surface--.-------- ----- - I „.- ELECTRIC SUBMERSIBLE PUMP-+/-125' ` rt s• Discharge Unit Assembly e iw Pump Assembly(3) f." 1 2 4‘,i Intake/Gas Separator Seal Assembly-Upper/Lower Seals Motor(2)/Motor Gauge Unit .# M Centralizer - 1 -• Chemical Injection Check Valve *" ' (y Anode 1 r ..„ -' `-----° `'ESP Assembly Bottom @+/-14,250'MD/11,629'TVD ', . " '--'3 1/2"Tubing Stub©+/-14,250'MD/11,629'TVD Planned TOC©+/-14,286'MD "— — -_ 1 ? 1L€ ;:` �3 1/2"12.95#P-110 PH6 Tubing-ID-2.625" (Top of Old Perfs©14,786'MD) — — R—�-- - --Upper Hemlock Perforations 14812-14822'MD/11966-11972'TVD . ""v -.--=— -- Upper Hemlock Perforations 14950-14960'MD/12053-12059'TVD ...m _ — _,Middle Hemlock Perforations 15140-15150'MD/12183-12190'TVD Ij 5 1/2 17#L-80 15,740'MD 6 3/4"Hole > w ID-4.767" BTC 12,653'TVD i® GE Oil & Gas I .... Mil NI 111111 1111 24.0' ell 60.2' 1311 MI 111r11.1 eM i�s 3-1/8.5mf+�.. tI6'sM � i � 4L ' l C .SC. eitt,!;,-Nt:. 01114 64.4' }t/6' i1• 6 • 198 7' Ilk 1.11, 1111 11111 El 13b/6'SM.— A inid. I W I' I" 2 28.0' - ++■■��I 29.0'toc 133/8'SM + �.�I EI x 2-1/16'SN. j•IF u� r■� 27.2,c O ii m nr 46.1' .-6# t-.1 K'Lr t1 11 I POI 1 '— 3o'rasmg 133/6'Casing 9-6/6'Casing 3-102'Tubing _1,1 Cable ALL DIMENSIONS ARE APPROXIMATE �+ This drawing is the property of GE Oil&Gas Pressure Control LP and is considered confidential.Unless otherwise approved in writing, COOK INLET EN E RG�/ 1 neither it nor its contents may be used,copied,transmitted or reproduced except for the sole purpose of GE Oil&Gas Pressure Control LP. OSPREY PLATFORM RU-05B 13-3/8" x 9-5/8" x 3-1/2" 5M Multibowl Wellhead DRAWN CR 050CT16 APPRV KN 050CT16 Assembly With MB-205 Tubing Head and Tubing FOR REFERENCE ONLY Hanger and Adapter Flange DRAWING NO. HP160203-2 G ` GEOiI&Gas L ,,a, Fog/"\ ' Nr....,‘, r .„ ---i:€=:. 4-1/IT ISO 4-,,,x,36, N. I 4,11113.151.1 , 1 ,; k .st ilt,,),,, 0 .Il�lyl�ll. !: iIFM r ..v,e sre / AL send. MOM L F s1r MEP o -, ti111a 4-111V NA 61661 IIAx$al'IAs •e 1'$ El - � I ila iila' k vt. 2 1/16.54A isr r ID gni KW •' Ii 1 I 1 ,urc.ro — —aae•c.p stir Tsu,s ALL DIMENSION-i ARE APPROXIMATE This drawing 1.mrproperly of GE Oil A Gas Pressure Contrci LP and Is considered confidential Unless othenvIse approved in vetting COOK INLET ENEEGY neither ft nor Its contents may be used,cowed,transmitted or reproduced except for the sole purpose or GE a&Gas Pressure Contra LP. 13.3/8"x 9-5/8"x 4-1/2"5M MB-205 Multibowl Wellhead DRAWN CR 09FE617 APPRV KN 09FEB17 Assembly,With MB-205 Tubing Head,Tubing Hanger and FOR REFERENCE ONLY Arhn}nr Clonnn \A/i4L.A_4/1 Qe AMU Cror Tr.. DRAWING NO. HP170019 Halliburton Company Definitive Survey Report Company: Cook Inlet Energy Local Co-ordinate Reference: Well Redoubt Unit#5 Project: COOK INLET BASIN TVD Reference: Osprey:N-429 @ 89.1'RKB @ 89.10ft(Osprey:N Site: REDOUBT SHOAL MD Reference: Osprey:N-429 @ 89.1'RKB @ 89.10ft(Osprey:N Well: Redoubt Unit#5 North Reference: Grid Wellbore: RU#5B Survey Calculation Method: Minimum Curvature Design: RU#5B Rig Surveys Database: .16 prd Project COOK INLET BASIN Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Well Redoubt Unit#5 Well Position +N/-S 0.00 ft Northing: 2,449,931.68 ft Latitude: 60.695458 +EI-W 0.00 ft Easting: 200,623.42 ft Longitude: -151.670717 Position Uncertainty 0.00 ft Wellhead Elevation: ft Water Depth: 40.00 ft Wellbore RU#5B Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2013 8/1/2013 17.07 73.56 55,438 Design RU#5B Rig Surveys Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 12,826.01 Vertical Section: Depth From�} (TVD) +N//-S +E/-W Direction (ft) (t) (ft) (°) 129.10 0.00 0.00 132.67 Survey Program Date 9/9/2013 From To Survey (it) (ft) Survey(Wellbore) Tool Name Description Start Date 143.10 383.10 RU#5 Gyro(RU#5) CB-GYRO-SS Camera based gyro single shots 08/30/2012 472.10 11,383.49 RU#5 MWD SAG(RU#5) MWD+SAG MWD+Sag correction 08/30/2012 11,472.10 12,826.01 RU#5A MWD SAG(RU#5A) MWD+SAG MWD+Sag correction 08/30/2012 12,915.00 13,504.39 RU#5B Rig Surveys(MWD_Interp Azi+ MWD_Interp Azi+sag Fixed:v2:std dec with interpolated azimuth+sa 08/29/2013 13,598.70 15,686.03 RU#5B Rig Surveys(MWD+SC+sag)(RI MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 09/01/2013 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (tt) (") ('") (tt) (tt) (tt) (tt) (ft) (ft) (°1100) (ft) Survey i ool Name 129.10 0.00 0.00 129.10 40.00 0.00 0.00 2,449,931.68 200,623.42 0.00 0.00 UNDEFINED 143.10 0.25 42.00 143.10 54.00 0.02 0.02 2,449,931.71 200,623.44 1.79 0.00 CB-GYRO-SS(1) 173.10 0.10 356.00 173.10 84.00 0.10 0.06 2,449,931.78 200,623.49 0.65 -0.02 CB-GYRO-SS(1) 204.10 0.25 232.00 204.10 115.00 0.08 0.01 2,449,931.77 200,623.43 1.02 -0.05 CB-GYRO-SS(1) 234.10 0.90 206.00 234.10 145.00 -0.17 -0.15 2,449,931.51 200,623.28 2.28 0.01 CB-GYRO-SS(1) 294.10 2.80 198.00 294.06 204.96 -1.99 -0.81 2,449,929.70 200,622.62 3.19 0.75 CB-GYRO-SS(1) 383.10 5.37 212.00 382.83 293.73 -7.59 -3.69 2,449,924.10 200,619.74 3.08 2.43 CB-GYRO-SS(1) 472.10 7.82 211.68 471.24 382.14 -16.27 -9.07 2,449,915.41 200,614.35 2.75 4.36 MWD+SAG(2) 562.10 9.77 211.50 560.17 471.07 -28.00 -16.28 2,449,903.69 200,607.14 2.17 7.01 MWD+SAG(2) 677.60 12.47 211.37 673.50 584.40 -47.00 -27.89 2,449,884.68 200,595.53 2.34 11.35 MWD+SAG(2) 9/23/2013 12:16:40PM Page 2 COMPASS 2003.16 Build 73 Halliburton Company Definitive Survey Report Company: Cook Inlet Energy Local Co-ordinate Reference: Well Redoubt Unit#5 Project: COOK INLET BASIN TVD Reference: Osprey:N-429 @ 89.1'RKB @ 89.10ft(Osprey:N Site: REDOUBT SHOAL MD Reference: Osprey:N-429 @ 89.1'RKB @ 89.10ft(Osprey:N Well: Redoubt Unit#5 North Reference: Grid Wellbore: RU#5B Survey Calculation Method: Minimum Curvature Design: RU#5B Rig Surveys Database: .16 prd Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 767.00 12.45 211.19 760.79 671.69 -63.49 -37.91 2,449,868.20 200,585.52 0.05 15.16 MWD+SAG(2) 855.20 11.97 207.06 847.00 757.90 -79.77 -46.99 2,449,851.92 200,576.43 1.13 19.52 MWD+SAG(2) 943.10 11.86 196.04 933.01 843.91 -96.57 -53.64 2,449,835.12 200,569.79 2.59 26.02 MWD+SAG(2) 1,035.80 11.98 183.38 1,023.73 934.63 -115.33 -56.84 2,449,816.35 200,566.59 2.82 36.38 MWD+SAG(2) 1,129.70 13.65 166.78 1,115.32 1,026.22 -135.85 -54.88 2,449,795.83 200,568.55 4.29 51.74 MWD+SAG(2) 1,223.10 16.53 152.09 1,205.52 1,116.42 -158.33 -46.13 2,449,773.35 200,577.29 5.10 73.40 MWD+SAG(2) 1,319.30 17.10 146.26 1,297.62 1,208.52 -182.19 -31.87 2,449,749.49 200,591.55 1.85 100.06 MWD+SAG(2) 1,413.40 18.91 139.41 1,387.11 1,298.01 -205.28 -14.26 2,449,726.40 200,609.16 2.96 128.66 MWD+SAG(2) 1,508.60 21.74 138.71 1,476.38 1,387.28 -230.25 7.41 2,449,701.44 200,630.84 2.98 161.52 MWD+SAG(2) 1,603.90 24.42 137.24 1,564.04 1,474.94 -257.98 32.44 2,449,673.71 200,655.86 2.88 198.71 MWD+SAG(2) 1,700.20 26.69 135.98 1,650.92 1,561.82 -288.15 60.99 2,449,643.54 200,684.41 2.42 240.15 MWD+SAG(2) 1,796.40 28.56 137.41 1,736.15 1,647.05 -320.62 91.57 2,449,611.07 200,714.99 2.06 284.64 MWD+SAG(2) 1,890.80 31.44 136.54 1,817.89 1,728.79 -355.11 123.78 2,449,576.58 200,747.20 3.09 331.70 MWD+SAG(2) 1,985.20 31.19 137.09 1,898.54 1,809.44 -390.88 157.36 2,449,540.80 200,780.78 0.40 380.64 MWD+SAG(2) 2,080.00 30.15 137.78 1,980.08 1,890.98 -426.49 190.07 2,449,505.19 200,813.49 1.16 428.83 MWD+SAG(2) 2,172.90 28.43 138.93 2,061.10 1,972.00 -460.44 220.28 2,449,471.24 200,843.70 1.95 474.05 MWD+SAG(2) 2,267.60 28.09 141.81 2,144.52 2,055.42 -494.96 248.87 2,449,436.72 200,872.30 1.48 518.48 MWD+SAG(2) 2,358.60 29.91 139.13 2,224.11 2,135.01 -528.96 276.97 2,449,402.72 200,900.39 2.46 562.18 MWD+SAG(2) 2,451.30 32.04 139.27 2,303.58 2,214.48 -565.08 308.14 2,449,366.60 200,931.56 2.30 609.57 MWD+SAG(2) 2,545.30 29.94 139.11 2,384.16 2,295.06 -601.71 339.77 2,449,329.97 200,963.19 2.24 657.66 MWD+SAG(2) 2,641.50 29.73 136.15 2,467.61 2,378.51 -637.06 372.01 2,449,294.62 200,995.43 1.55 705.33 MWD+SAG(2) 2,736.00 28.33 134.49 2,550.24 2,461.14 -669.68 404.24 2,449,262.01 201,027.66 1.71 751.13 MWD+SAG(2) 2,828.70 29.17 132.89 2,631.51 2,542.41 -700.47 436.48 2,449,231.22 201,059.91 1.23 795.71 MWD+SAG(2) 2,923.30 29.14 135.31 2,714.13 2,625.03 -732.53 469.57 2,449,199.15 201,093.00 1.25 841.77 MWD+SAG(2) 3,018.00 31.76 135.26 2,795.76 2,706.66 -766.63 503.34 2,449,165.05 201,126.76 2.77 889.71 MWD+SAG(2) 3,110.20 33.45 134.03 2,873.43 2,784.33 -801.53 538.69 2,449,130,15 201,162.11 1.97 939.36 MWD+SAG(2) 3,160.48 34.70 133.98 2,915.08 2,825.98 -821.10 558.95 2,449,110.58 201,182.38 2.49 967.52 MWD+SAG(2) 3,250.76 34.19 133.88 2,989.53 2,900.43 -856.53 595.73 2,449,075.15 201,219.15 0.57 1,018.57 MWD+SAG(2) 3,345.42 34.14 133.79 3,067.85 2,978.75 -893.35 634.07 2,449,038.34 201,257.50 0.08 1,071.72 MWD+SAG(2) 3,440.39 34.07 133.39 3,146.49 3,057.39 -930.06 672.64 2,449,001.62 201,296.07 0.25 1,124.96 MWD+SAG(2) 3,536.13 33.06 137.67 3,226.27 3,137.17 -967.80 709.72 2,448,963.89 201,333.15 2.69 1,177.80 MWD+SAG(2) 3,633.05 33.28 137.59 3,307.40 3,218.30 -1,006.97 745.46 2,448,924.71 201,368.88 0.23 1,230.63 MWD+SAG(2) 3,729.96 32.31 138.49 3,388.86 3,299.76 -1,046.00 780.56 2,448,885.68 201,403.98 1.12 1,282.89 MWD+SAG(2) 3,826.01 32.11 138.40 3,470.13 3,381.03 -1,084.31 814.52 2,448,847.37 201,437.94 0.21 1,333.83 MWD+SAG(2) 3,920.25 32.43 138.63 3,549.82 3,460.72 -1,122.01 847.85 2,448,809.68 201,471.27 0.36 1,383.88 MWD+SAG(2) 4,014.83 31.84 138.41 3,629.91 3,540.81 -1,159.70 881.17 2,448,771.99 201,504.59 0.64 1,433.93 MWD+SAG(2) 4,109.46 31.68 138.08 3,710.37 3,621.27 -1,196.86 914.34 2,448,734.83 201,537.76 0.25 1,483.50 MWD+SAG(2) 4,204.98 31.82 138.19 3,791.59 3,702.49 -1,234.29 947.88 2,448,697.39 201,571.31 0.16 1,533.54 MWD+SAG(2) 4,300.21 31.70 138.21 3,872.56 3,783.46 -1,271.66 981.29 2,448,660.03 201,604.72 0.13 1,583.43 MWD+SAG(2) 4,396.55 31.92 138.25 3,954.43 3,865.33 -1,309.53 1,015.12 2,448,622.15 201,638.55 0.23 1,633.97 MWD+SAG(2) 9/23/2013 12:16:40PM Page 3 COMPASS 2003.16 Build 73 Halliburton Company Definitive Survey Report Company: Cook Inlet Energy Local Co-ordinate Reference: Well Redoubt Unit#5 Project: COOK INLET BASIN TVD Reference: Osprey:N-429 @ 89.1'RKB @ 89.10ft(Osprey:N Site: REDOUBT SHOAL MD Reference: Osprey:N-429 @ 89.1'RKB @ 89.10ft(Osprey:N Well: Redoubt Unit#5 North Reference: Grid Wellbore: RU#5B Survey Calculation Method: Minimum Curvature Design: RU#5B Rig Surveys Database: .16 prd Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,491.38 31.82 138.47 4,034.97 3,945.87 -1,346.95 1,048.39 2,448,584.73 201,671.81 0.16 1,683.79 MWD+SAG(2) 4,586.72 32.09 138.64 4,115.86 4,026.76 -1,384.77 1,081.79 2,448,546.91 201,705.21 0.30 1,733.99 MWD+SAG(2) 4,675.57 30.99 137.93 4,191.58 4,102.48 -1,419.47 1,112.71 2,448,512.22 201,736.13 1.31 1,780.24 MWD+SAG(2) 4,770.79 30.69 138.67 4,273.34 4,184.24 -1,455.91 1,145.18 2,448,475.77 201,768.61 0.51 1,828.82 MWD+SAG(2) 4,862.34 31.01 138.65 4,351.93 4,262.83 -1,491.16 1,176.19 2,448,440.52 201,799.62 0.35 1,875.51 MWD+SAG(2) 4,957.14 31.49 139.10 4,432.98 4,343.88 -1,528.21 1,208.54 2,448,403.48 201,831.96 0.56 1,924.40 MWD+SAG(2) 5,051.86 32.01 138.45 4,513.53 4,424.43 -1,565.69 1,241.39 2,448,365.99 201,864.81 0.66 1,973.96 MWD+SAG(2) 5,147.54 31.77 138.40 4,594.76 4,505.66 -1,603.51 1,274.93 2,448,328.18 201,898.35 0.25 2,024.25 MWD+SAG(2) 5,242.95 31.39 136.62 4,676.05 4,586.95 -1,640.35 1,308.67 2,448,291.33 201,932.10 1.06 2,074.03 MWD+SAG(2) 5,339.11 32.01 136.98 4,757.86 4,668.76 -1,677.18 1,343.26 2,448,254.50 201,966.68 0.67 2,124.43 MWD+SAG(2) 5,433.72 32.54 136.94 4,837.85 4,748.75 -1,714.11 1,377.74 2,448,217.58 202,001.16 0.56 2,174.81 MWD+SAG(2) 5,526.83 31.16 137.70 4,916.94 4,827.84 -1,750.22 1,411.05 2,448,181.46 202,034.48 1.54 2,223.78 MWD+SAG(2) 5,623.49 30.25 137.67 5,000.05 4,910.95 -1,786.72 1,444.28 2,448,144.96 202,067.70 0.94 2,272.95 MWD+SAG(2) 5,714.73 30.18 137.81 5,078.89 4,989.79 -1,820.70 1,475.16 2,448,110.98 202,098.58 0.11 2,318.68 MWD+SAG(2) 5,808.74 30.27 138.15 5,160.12 5,071.02 -1,855.86 1,506.83 2,448,075.82 202,130.26 0.21 2,365.81 MWD+SAG(2) 5,900.12 30.44 138.19 5,238.98 5,149.88 -1,890.27 1,537.63 2,448,041.41 202,161.06 0.19 2,411.77 MWD+SAG(2) 5,995.96 30.54 137.81 5,321.56 5,232.46 -1,926.41 1,570.17 2,448,005.28 202,193.60 0.23 2,460.19 MWD+SAG(2) 6,091.09 30.69 136.70 5,403.43 5,314.33 -1,961.98 1,603.05 2,447,969.70 202,226.48 0.61 2,508.48 MWD+SAG(2) 6,187.66 30.85 137.00 5,486.41 5,397.31 -1,998.03 1,636.84 2,447,933.66 202,260.27 0.23 2,557.75 MWD+SAG(2) 6,281.42 31.22 136.82 5,566.75 5,477.65 -2,033.33 1,669.86 2,447,898.36 202,293.29 0.41 2,605.96 MWD+SAG(2) 6,376.95 31.31 136.91 5,648.40 5,559.30 -2,069.51 1,703.76 2,447,862.18 202,327.19 0.11 2,655.41 MWD+SAG(2) 6,469.88 31.61 137.13 5,727.67 5,638.57 -2,104.99 1,736.83 2,447,826.69 202,360.25 0.35 2,703.77 MWD+SAG(2) 6,563.42 31.93 137.89 5,807.20 5,718.10 -2,141.31 1,770.09 2,447,790.38 202,393.52 0.55 2,752.84 MWD+SAG(2) 6,671.86 31.20 138.15 5,899.59 5,810.49 -2,183.50 1,808.06 2,447,748.18 202,431.48 0.68 2,809.36 MWD+SAG(2) 6,766.31 30.81 138.42 5,980.55 5,891.45 -2,219.82 1,840.44 2,447,711.86 202,463.86 0.44 2,857.78 MWD+SAG(2) 6,861.42 30.66 137.94 6,062.30 5,973.20 -2,256.04 1,872.85 2,447,675.64 202,496.27 0.30 2,906.16 MWD+SAG(2) 6,956.88 30.33 137.56 6,144.56 6,055.46 -2,291.90 1,905.42 2,447,639.78 202,528.84 0.40 2,954.41 MWD+SAG(2) 7,052.82 29.96 137.29 6,227.52 6,138.42 -2,327.38 1,938.01 2,447,604.30 202,561.44 0.41 3,002.43 MWD+SAG(2) 7,145.72 29.54 138.01 6,308.18 6,219.08 -2,361.45 1,969.07 2,447,570.23 202,592.49 0.59 3,048.35 MWD+SAG(2) 7,237.26 30.15 136.57 6,387.58 6,298.48 -2,394.92 1,999.97 2,447,536.77 202,623.39 1.03 3,093.76 MWD+SAG(2) 7,330.36 30.45 137.41 6,467.96 6,378.86 -2,429.26 2,032.01 2,447,502.42 202,655.43 0.56 3,140.59 MWD+SAG(2) 7,422.90 30.74 138.82 6,547.62 6,458.52 -2,464.33 2,063.45 2,447,467.35 202,686.87 0.84 3,187.48 MWD+SAG(2) 7,518.25 30.63 138.32 6,629.62 6,540.52 -2,500.81 2,095.65 2,447,430.87 202,719.07 0.29 3,235.88 MWD+SAG(2) 7,613.52 30.51 140.36 6,711.65 6,622.55 -2,537.56 2,127.21 2,447,394.12 202,750.64 1.10 3,284.00 MWD+SAG(2) 7,706.46 32.45 139.11 6,790.91 6,701.81 -2,574.58 2,158.59 2,447,357.10 202,782.02 2.20 3,332.16 MWD+SAG(2) 7,802.59 32.36 137.35 6,872.07 6,782.97 -2,613.00 2,192.90 2,447,318.68 202,816.33 0.99 3,383.43 MWD+SAG(2) 7,895.17 32.53 136.54 6,950.20 6,861.10 -2,649.29 2,226.81 2,447,282.39 202,850.24 0.50 3,432.96 MWD+SAG(2) 7,990.85 32.44 134.74 7,030.91 6,941.81 -2,686.03 2,262.74 2,447,245.65 202,886.16 1.01 3,484.27 MWD+SAG(2) 8,083.79 32.63 133.86 7,109.26 7,020.16 -2,720.94 2,298.51 2,447,210.74 202,921.93 0.55 3,534.24 MWD+SAG(2) 8,179.82 32.36 133.95 7,190.26 7,101.16 -2,756.71 2,335.68 2,447,174.97 202,959.10 0.29 3,585.81 MWD+SAG(2) 9/23/2013 12:16:40PM Page 4 COMPASS 2003.16 Build 73 Halliburton Company Definitive Survey Report Company: Cook Inlet Energy Local Co-ordinate Reference: Wet Redoubt Unit#5 Project: COOK INLET BASIN TVD Reference: Osprey: N-429 @ 89.1'RKB @ 89.10ft(Osprey:N Site: REDOUBT SHOAL MD Reference: Osprey:N-429 @ 89.1'RKB @ 89.10ft(Osprey: N Well: Redoubt Unit#5 North Reference: Grid Wellbore: RU#5B Survey Calculation Method: Minimum Curvature Design: RU#5B Rig Surveys Database: .16 prd Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (0) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,277.23 32.03 133.90 7,272.69 7,183.59 -2,792.72 2,373.06 2,447,138.96 202,996.49 0.34 3,637.70 MWD+SAG(2) 8,370.51 31.66 133.30 7,351.93 7,262.83 -2,826.66 2,408.70 2,447,105.02 203,032.13 0.52 3,686.91 MWD+SAG(2) 8,464.68 32.33 134.93 7,431.80 7,342.70 -2,861.39 2,444.52 2,447,070.29 203,067.94 1.16 3,736.79 MWD+SAG(2) 8,555.86 31.83 133.80 7,509.05 7,419.95 -2,895.26 2,479.13 2,447,036.43 203,102.56 0.86 3,785.19 MWD+SAG(2) 8,651.46 31.18 133.21 7,590.56 7,501.46 -2,929.65 2,515.36 2,447,002.03 203,138.79 0.75 3,835.14 MWD+SAG(2) 8,746.29 30.66 133.20 7,671.91 7,582.81 -2,963.01 2,550.88 2,446,968.67 203,174.31 0.55 3,883.87 MWD+SAG(2) 8,838.67 30.25 135.12 7,751.55 7,662.45 -2,995.62 2,584.47 2,446,936.06 203,207.90 1.14 3,930.67 MWD+SAG(2) 8,937.44 30.16 136.45 7,836.91 7,747.81 -3,031.23 2,619.12 2,446,900.45 203,242.55 0.68 3,980.28 MWD+SAG(2) 9,030.86 29.43 136.26 7,917.98 7,828.88 -3,064.82 2,651.16 2,446,866.86 203,274.59 0.79 4,026.61 MWD+SAG(2) 9,122.15 29.03 135.85 7,997.65 7,908.55 -3,096.92 2,682.10 2,446,834.76 203,305.52 0.49 4,071.11 MWD+SAG(2) 9,214.04 28.21 135.57 8,078.31 7,989.21 -3,128.43 2,712.83 2,446,803.25 203,336.25 0.90 4,115.06 MWD+SAG(2) 9,309.33 28.99 134.68 8,161.97 8,072.87 -3,160.75 2,745.02 2,446,770.93 203,368.44 0.93 4,160.63 MWD+SAG(2) 9,403.13 29.62 135.36 8,243.77 8,154.67 -3,193.23 2,777.47 2,446,738.46 203,400.89 0.76 4,206.50 MWD+SAG(2) 9,497.69 30.01 136.09 8,325.81 8,236,71 -3,226.89 2,810.29 2,446,704.79 203,433.71 0.56 4,253.45 MWD+SAG(2) 9,591.59 31.16 136.18 8,406.65 8,317.55 -3,261.34 2,843.39 2,446,670.35 203,466.82 1.23 4,301.14 MWD+SAG(2) 9,687.78 31.16 136.06 8,488.96 8,399.86 -3,297.21 2,877.89 2,446,634.47 203,501.32 0.06 4,350.82 MWD+SAG(2) 9,779.45 31.14 135.48 8,567.41 8,478.31 -3,331.19 2,910.97 2,446,600.49 203,534.39 0.33 4,398.17 MWD+SAG(2) 9,875.68 31.05 136.64 8,649.82 8,560.72 -3,366.97 2,945.45 2,446,564.71 203,568.88 0.63 4,447.78 MWD+SAG(2) 9,969.98 30.93 136.04 8,730.66 8,641.56 -3,402.10 2,978.97 2,446,529.58 203,602.40 0.35 4,496.24 MWD+SAG(2) 10,064.23 30.70 136.95 8,811.60 8,722.50 -3,437.12 3,012.21 2,446,494.57 203,635.64 0.55 4,544.41 MWD+SAG(2) 10,157.85 31.12 136.64 8,891.92 8,802.82 -3,472.17 3,045.14 2,446,459.51 203,668.56 0.48 4,592.38 MWD+SAG(2) 10,251.59 30.16 136.46 8,972.57 8,883.47 -3,506.85 3,077.99 2,446,424.83 203,701.41 1.03 4,640.04 MWD+SAG(2) 10,346.24 29.59 136.91 9,054.65 8,965.55 -3,541.16 3,110.33 2,446,390.53 203,733.76 0.65 4,687.07 MWD+SAG(2) 10,440.66 29.54 136.99 9,136.77 9,047.67 -3,575.20 3,142.14 2,446,356.48 203,765.56 0.07 4,733.53 MWD+SAG(2) 10,533.13 29.29 136.96 9,217.32 9,128.22 -3,608.40 3,173.12 2,446,323.28 203,796.55 0.27 4,778.82 MWD+SAG(2) 10,627.18 29.47 136.74 9,299.28 9,210.18 -3,642.06 3,204.68 2,446,289.62 203,828.10 0.22 4,824.83 MWD+SAG(2) 10,721.81 29.45 136.40 9,381.67 9,292.57 -3,675.86 3,236.67 2,446,255.82 203,860.10 0.18 4,871.27 MWD+SAG(2) 10,819.12 29.26 136.74 9,466.49 9,377.39 -3,710.50 3,269.47 2,446,221.18 203,892.89 0.26 4,918.86 MWD+SAG(2) 10,913.00 28.37 137.08 9,548.74 9,459.64 -3,743.55 3,300.38 2,446,188.14 203,923.81 0.96 4,963.98 MWD+SAG(2) 11,010.19 27.63 137.09 9,634.55 9,545.45 -3,776.96 3,331.45 2,446,154.72 203,954.87 0.76 5,009.48 MWD+SAG(2) 11,104.41 27.76 137.64 9,717.98 9,628.88 -3,809.18 3,361.11 2,446,122.50 203,984.53 0.30 5,053.12 MWD+SAG(2) 11,138.66 27.91 136.81 9,748.27 9,659.17 -3,820.92 3,371.97 2,446,110.77 203,995.39 1.21 5,069.06 MWD+SAG(2) 11,197.38 28.13 137.00 9,800.10 9,711.00 -3,841.06 3,390.82 2,446,090.62 204,014.24 0.40 5,096.57 MWD+SAG(2) 11,233.43 28.32 137.06 9,831.87 9,742.77 -3,853.54 3,402.44 2,446,078.15 204,025.86 0.53 5,113.57 MWD+SAG(2) 11,289.04 28.96 137.75 9,880.67 9,791.57 -3,873.16 3,420.48 2,446,058.53 204,043.90 1.30 5,140.13 MWD+SAG(2) 11,383.49 29.19 137.71 9,963.22 9,874.12 -3,907.12 3,451.35 2,446,024.56 204,074.77 0.24 5,185.85 MWD+SAG(2) 11,472.10 28.86 138.11 10,040.70 9,951.60 -3,939.03 3,480.17 2,445,992.66 204,103.59 0.43 5,228.67 MWD+SAG(3) 11,492.45 30.90 137.92 10,058.35 9,969.25 -3,946.56 3,486.95 2,445,985.12 204,110.37 10.04 5,238.76 MWD+SAG(3) 11,579.43 36.79 137.08 10,130.56 10,041.46 -3,982.24 3,519.68 2,445,949.44 204,143.11 6.79 5,287.01 MWD+SAG(3) 11,635.91 41.70 136.54 10,174.28 10,085.18 -4,008.28 3,544.14 2,445,923.40 204,167.56 8.71 5,322.64 MWD+SAG(3) 9/23/2013 12:16:40PM Page 5 COMPASS 2003.16 Build 73 Halliburton Company Definitive Survey Report Company: Cook Inlet Energy Local Co-ordinate Reference: Well Redoubt Unit#5 Project: COOK INLET BASIN TVD Reference: Osprey:N-429 @ 89.1'RKB @ 89.10ft(Osprey:F Site: REDOUBT SHOAL MD Reference: Osprey:N-429 @ 89.1'RKB @ 89.10ft(Osprey:t Well: Redoubt Unit#5 North Reference: Grid Wellbore: RU#5B Survey Calculation Method: Minimum Curvature Design: RU#5B Rig Surveys Database: .16 prd Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,682.78 41.70 136.42 10,209.28 10,120.18 -4,030.89 3,565.61 2,445,900.79 204,189.03 0.17 5,353.75 MWD+SAG(3) 11,743.49 42.51 138.54 10,254.32 10,165.22 -4,060.89 3,593.11 2,445,870.79 204,216.53 2.69 5,394.31 MWD+SAG(3) 11,780.01 44.56 139.36 10,280.80 10,191.70 -4,079.86 3,609.62 2,445,851.82 204,233.05 5.82 5,419.31 MWD+SAG(3) 11,871.20 47.92 139.57 10,343.86 10,254.76 -4,129.91 3,652.42 2,445,801.77 204,275.84 3.69 5,484.70 MWD+SAG(3) 11,965.61 52.19 138.58 10,404.46 10,315.36 -4,184.57 3,699.84 2,445,747.11 204,323.26 4.59 5,556.61 MWD+SAG(3) 12,013.49 54.52 137.63 10,433.04 10,343.94 -4,213.16 3,725.49 2,445,718.52 204,348.92 5.12 5,594.85 MWD+SAG(3) 12,107.45 56.20 137.08 10,486.44 10,397.34 -4,270.02 3,777.86 2,445,661.66 204,401.29 1.85 5,671.90 MWD+SAG(3) 12,173.80 57.32 137.31 10,522.81 10,433.71 -4,310.73 3,815.57 2,445,620.95 204,438.99 1.71 5,727.22 MWD+SAG(3) 12,262.45 59.16 136.86 10,569.47 10,480.37 -4,365.93 3,866.89 2,445,565.75 204,490.32 2.12 5,802.36 MWD+SAG(3) 12,357.32 60.31 136.65 10,617.29 10,528.19 -4,425.62 3,923.03 2,445,506.06 204,546.46 1.23 5,884.10 MWD+SAG(3) 12,450.88 62.10 135.80 10,662.35 10,573.25 -4,484.81 3,979.76 2,445,446.87 204,603.18 2.07 5,965.92 MWD+SAG(3) 12,546.74 63.77 136.03 10,705.97 10,616.87 -4,546.13 4,039.14 2,445,385.55 204,662.57 1.76 6,051.15 MWD+SAG(3) 12,642.68 65.58 135.72 10,747.00 10,657.90 -4,608.37 4,099.52 2,445,323.31 204,722.94 1.91 6,137.73 MWD+SAG(3) 12,734.45 66.77 136.25 10,784.07 10,694.97 -4,668.75 4,157.85 2,445,262.94 204,781.27 1.40 6,221.54 MWD+SAG(3) 12,826.01 67.33 136.97 10,819.77 10,730.67 -4,730.02 4,215.76 2,445,201.67 204,839.19 0.95 6,305.65 MWD+SAG(3) 12,915.00 65.06 137.91 10,855.69 10,766.59 -4,789.98 4,270.83 2,445,141.70 204,894.26 2.73 6,386.78 MWD_Interp Azi+sag(4) 12,939.78 65.96 137.29 10,865.96 10,776.86 -4,806.63 4,286.04 2,445,125.05 204,909.46 4.29 6,409.25 MWD_Interp Azi+sag(4) 13,035.46 64.59 134.86 10,905.99 10,816.89 -4,869.23 4,346.31 2,445,062.46 204,969.74 2.72 6,495.99 MWD_Interp Azi+sag(4) 13,130.17 62.07 132.37 10,948.50 10,859.40 -4,927.61 4,407.56 2,445,004.07 205,030.99 3.55 6,580.60 MWD_Interp Azi+sag(4) 13,223.39 59.71 129.79 10,993.85 10,904.75 -4,981.14 4,468.93 2,444,950.55 205,092.35 3.50 6,662.00 MWD_Interp Azi+sag(4) 13,314.93 56.55 127.11 11,042.19 10,953.09 -5,029.49 4,529.78 2,444,902.20 205,153.20 4.25 6,739.51 MWD_Interp Azi+sag(4) 13,412.37 53.43 125.38 11,098.08 11,008.98 -5,076.68 4,594.12 2,444,855.00 205,217.54 3.52 6,818.80 MWD_Interp Azi+sag(4) 13,504.39 51.12 125.05 11,154.39 11,065.29 -5,118.65 4,653.57 2,444,813.03 205,277.00 2.53 6,890.96 MWD_Interp Azi+sag(4) 13,598.70 48.88 123.26 11,215.01 11,125.91 -5,159.22 4,713.34 2,444,772.46 205,336.76 2.78 6,962.40 MWD+SC+sag(5) 13,694.55 47.02 121.73 11,279.20 11,190.10 -5,197.47 4,773.36 2,444,734.21 205,396.78 2.27 7,032.45 MWD+SC+sag(5) 13,787.44 47.19 122.34 11,342.43 11,253.33 -5,233.57 4,831.05 2,444,698.12 205,454.47 0.51 7,099.34 MWD+SC+sag(5) 13,882.50 49.24 121.40 11,405.77 11,316.67 -5,270.98 4,891.24 2,444,660.70 205,514.67 2.28 7,168.95 MWD+SC+sag(5) 13,977.79 50.70 119.53 11,467.06 11,377.96 -5,307.96 4,954.13 2,444,623.72 205,577.56 2.15 7,240.26 MWD+SC+sag(5) 14,072.77 52.53 119.43 11,526.04 11,436.94 -5,344.60 5,018.94 2,444,587.09 205,642.37 1.93 7,312.74 MWD+SC+sag(5) 14,167.68 54.97 119.91 11,582.15 11,493.05 -5,382.48 5,085.44 2,444,549.20 205,708.86 2.60 7,387.31 MWD+SC+sag(5) 14,261.35 54.72 118.87 11,636.09 11,546.99 -5,420.07 5,152.16 2,444,511.61 205,775.59 0.95 7,461.85 MWD+SC+sag(5) 14,355.25 51.80 117.60 11,692.25 11,603.15 -5,455.68 5,218.44 2,444,476.01 205,841.87 3.29 7,534.71 MWD+SC+sag(5) 14,449.10 51.49 116.04 11,750.49 11,661.39 -5,488.88 5,284.12 2,444,442.80 205,907.54 1.34 7,605.50 MWD+SC+sag(5) 14,542.35 51.20 115.71 11,808.74 11,719.64 -5,520.66 5,349.64 2,444,411.02 205,973.06 0.42 7,675.22 MWD+SC+sag(5) 14,637.74 53.63 117.47 11,866.92 11,777.82 -5,554.51 5,417.21 2,444,377.17 206,040.64 2.94 7,747.84 MWD+SC+sag(5) 14,732.03 56.70 117.97 11,920.77 11,831.67 -5,590.51 5,485.71 2,444,341.17 206,109.14 3.28 7,822.61 MWD+SC+sag(5) 14,824.67 52.96 115.44 11,974.13 11,885.03 -5,624.57 5,553.33 2,444,307.12 206,176.75 4.61 7,895.40 MWD+SC+sag(5) 14,919.63 49.98 112.53 12,033.28 11,944.18 -5,654.79 5,621.16 2,444,276.89 206,244.58 3.95 7,965.76 MWD+SC+sag(5) 15,014.73 47.13 109.06 12,096.23 12,007.13 -5,680.13 5,687.76 2,444,251.55 206,311.18 4.06 8,031.91 MWD+SC+sag(5) 15,108.83 45.81 106.18 12,161.05 12,071.95 -5,700.80 5,752.76 2,444,230.89 206,376.19 2.62 8,093.70 MWD+SC+sag(5) 9/23/2013 12:16:40PM Page 6 COMPASS 2003.16 Build 73 Halliburton Company Definitive Survey Report Company: Cook Inlet Energy Local Co-ordinate Reference: Well Redoubt Unit#5 Project: COOK INLET BASIN TVD Reference: Osprey:N-429 @ 89.1'RKB @ 89.10ft(Osprey:N Site: REDOUBT SHOAL MD Reference: Osprey: N-429 @ 89.1'RKB @ 89.10ft(Osprey:N Well: Redoubt Unit#5 North Reference: Grid Wellbore: RU#5B Survey Calculation Method: Minimum Curvature Design: RU#5B Rig Surveys Database: .16 prd Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 15,202.96 42.82 99.01 12,228.44 12,139.34 -5,715.22 5,816.82 2,444,216.46 206,440.25 6.19 8,150.58 MWD+SC+sag(5) 15,297.04 41.47 90.92 12,298.24 12,209.14 -5,720.73 5,879.60 2,444,210.95 206,503.02 5.94 8,200.47 MWD+SC+sag(5) 15,390.46 40.03 84.86 12,369.04 12,279.94 -5,718.54 5,940.48 2,444,213.14 206,563.90 4.50 8,243.74 MWD+SC+sag(5) 15,485.57 38.72 78.26 12,442.59 12,353.49 -5,709.74 6,000.09 2,444,221.94 206,623.52 4.61 8,281.61 MWD+SC+sag(5) 15,580.20 35.10 72.16 12,518.27 12,429.17 -5,695.37 6,055.01 2,444,236.31 206,678.43 5.44 8,312.25 MWD+SC+sag(5) 15,673.98 32.24 65.90 12,596.33 12,507.23 -5,676.89 6,103.53 2,444,254.79 206,726.95 4.79 8,335.40 MWD+SC+sag(5) 15,686.03 31.39 64.87 12,606.57 12,517.47 -5,674.25 6,109.31 2,444,257.44 206,732.73 8.37 8,337.85 MWD+SC+sag(5) 15,750.00 31.39 64.87 12,661.18 12,572.08 -5,660.10 6,139.47 2,444,271.59 206,762.90 0.00 8,350.44 PROJECTED to TD 9/23/2013 12:16:40PM Page 7 COMPASS 2003.16 Build 73 Scilimbrpr FracCADE* STIMULATION PROPOSAL Operator : Glacier Oil & Gas Well : RU-05B Field : Redoubt Formation : Middle Hemlock Well Location : Osprey platform County : Kenai State : Alaska Country : United States Prepared for : Anna Belanger Service Point : Prudhoe Bay Proposal No. : Business Phone : 907 659 2434 Date Prepared : 31 Dec 2016 FAX No. : 907 659 2538 Prepared by : Gunther Rutzinger Phone : 907 273 1788 E-Mail Address : grutzinger©slb.com *Mark of Schlumberger Disclaimer Notice' This information is presented in good faith,but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service.The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment.The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model,the assumptions and such input data.The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values.The quality of input data,and hence results,may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well,the reservoir,the field and conditions affecting them.If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue.Actual charges may vary depending upon time,equipment,and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. Client : Glacier Oil &Gas Well : RU-05B I TN Formation : Middle Hemlock District : Prudhoe Bay Country : United States Loadcase : Middle Hemlock Contents Section 1: Wellbore Configuration 3 Section 2: Zone Data 4 Section 3: Propped Fracture Schedule 7 Section 4: Propped Fracture Simulation Results 10 Section 5: Propped Fracture Simulation 11 Section 6: Treatment Fluid Data 14 Section 7: Proppant Data 15 Section 8: Hole Survey 16 2 Client : Glacier Oil & Gas a Well : RU-05B a 3� brill Formation : Middle Hemlock District : Prudhoe Bay Country : United States Loadcase : Middle Hemlock Section 1: Wellbore Configuration 0 Bottom Hole Temperature 195 degF Deviated Hole YES Treat Down TUBING Well Type Vertical Well Location OffShore Tubing Data OD Weight ID Depth 5250 — (in) (lb/ft) (in) (ft) 3.500 12.7 2.750 12928.0 Casing Data OD Weight ID Depth (in) (lb/ft) (in) (ft) 7.000 23.0 6.366 12928.0 3.500 12.7 2.750 15750.0 10500 — Perforation Data Top Top Bottom Bottom Shot Number Diameter MD TVD MD TVD Density _ (ft) (ft) (ft) (ft) (shot/ft) (in) 15140.0 12182.8 15150.0 12189.9 6.00 60 0.32 Offshore 15750 Ocean Depth 50.0 Ocean Bed Temperature 39 < c , K Ocean Surface Current Velocity 50.63 3 Client : Glacier Oil & Gas Well : RU-05B klimlirpi Formation : Middle Hemlock District : Prudhoe Bay Country : United States Loadcase : Middle Hemlock Section 2: Zone Data Formation Mechanical Properties Zone Name Top TVD Zone Frac Insitu Young's Poisson's Toughness (ft) Height Grad. Stress Modulus Ratio (psi.in0.5) (ft) (psi/ft) (psi) (psi) DIRTY-SANDSTONE 11844.5 24.0 0.800 9485 4.220E+6 0.23 700 CLEAN-SANDSTONE 11868.5 4.3 0.761 9034 3.650E+6 0.27 1200 SILTSTONE 11872.8 4.7 0.835 9916 1.050E+6 0.23 1000 CLEAN-SANDSTONE 11877.5 4.7 0.772 9171 1.650E+6 0.19 1200 SHALE 11882.2 4.3 0.932 11076 1.890E+6 0.29 1000 SILTSTONE 11886.5 2.6 0.859 10212 7.250E+5 0.45 0 SHALE 11889.1 5.1 0.937 11142 3.680E+6 0.34 1000 SILTSTONE 11894.2 4.9 0.829 9862 8.520E+5 0.47 0 Hemlock Coal 11899.1 6.2 0.931 11081 2.430E+5 0.48 0 DIRTY-SANDSTONE 11905.3 9.4 0.788 9385 6.250E+5 0.43 0 SILTSTONE 11914.7 4.3 0.921 10975 6.030E+5 0.18 0 DIRTY-SANDSTONE 11919.0 1.7 0.807 9619 4.450E+5 0.43 0 SHALE 11920.7 5.1 0.936 11160 3.840E+6 0.31 1000 SILTSTONE 11925.8 4.2 0.865 10318 4.900E+6 0.15 1000 SILTSTONE 11930.0 6.1 0.920 10978 2.340E+6 0.37 1000 SHALE 11936.1 11.4 0.928 11082 4.020E+6 0.25 1000 Upper Hemlock 11947.6 3.5 0.863 10312 4.120E+6 0.32 1000 CLEAN-SANDSTONE 11951.0 38.3 0.770 9217 5.660E+6 0.17 1200 SHALE 11989.3 4.9 0.943 11308 4.310E+6 0.28 1000 SILTSTONE 11994.2 1.2 0.855 10256 3.990E+6 0.28 1000 DIRTY-SANDSTONE 11995.5 13.7 0.791 9494 4.560E+6 0.26 1200 SILTSTONE 12009.2 22.2 0.831 9989 3.840E+6 0.26 1000 DIRTY-SANDSTONE 12031.4 3.2 0.789 9494 4.790E+6 0.19 700 DIRTY-SANDSTONE 12034.6 1.9 0.822 9893 4.160E+6 0.24 700 CLEAN-SANDSTONE 12036.5 25.3 0.773 9314 4.360E+6 0.23 1200 DIRTY-SANDSTONE 12061.8 7.7 0.821 9906 4.230E+6 0.25 700 CLEAN-SANDSTONE 12069.5 343 n 771 93!9 4 AnnE+R n 9n 1200 Silt Zone 12103.8 4.2 0.798 9661 1.610E+6 0.39 700 SILTSTONE 12108.0 6.6 0.855 10355 3.900E+6 0.30 1000 DIRTY-SANDSTONE 12114.6 20.9 0.820 9943 3.970E+6 0.28 700 Middle Hemlock 12135.5 126.8 0.773 9430 4.620E+6 0.23 1200 DIRTY-SANDSTONE 12262.3 7.7 0.803 9850 3.830E+6 0.19 700 CLEAN-SANDSTONE 12270.0 7.8 0.773 9488 5.010E+6 0.21 1200 SHALE 12277.8 12.0 0.945 11608 3.970E+6 0.28 1000 CLEAN-SANDSTONE 12289.8 32.6 0.775 9537 4.730E+6 0.19 1200 SILTSTONE 12322.4 2.6 0.905 11153 2.180E+6 0.31 1000 DIRTY-SANDSTONE 12325.0 1.7 0.816 10058 1.180E+6 0.43 700 SHALE 12326.7 3.4 0.938 11564 3.700E+6 0.28 1000 4 Client : Glacier Oil &Gas Well : RU-05B MOW Formation : Middle Hemlock District : Prudhoe Bay Country : United States Loadcase : Middle Hemlock SILTSTONE 12330.1 9.5 0.887 10941 3.480E+6 0.26 1000 Lower Hemlock 12339.6 15.5 0.802 9903 5.170E+6 0.19 700 DIRTY-SANDSTONE 12355.1 4.3 0.821 10145 6.180E+6 0.18 700 CLEAN-SANDSTONE 12359.4 23.2 0.776 9600 5.940E+6 0.17 1200 DIRTY-SANDSTONE 12382.6 12.0 0.820 10159 4.350E+6 0.19 700 CLEAN-SANDSTONE 12394.6 6.9 0.773 9584 4.460E+6 0.23 1200 SILTSTONE 12401.5 5.2 0.829 10283 4.030E+6 0.25 1000 Formation Transmissibility Properties Zone Name Top TVD Net Perm Porosity Res. Gas Oil Sat. Water (ft) Height (md) (%) Pressure Sat. (%) Sat. (ft) (psi) (%) (%) DIRTY-SANDSTONE 11844.5 19.2 2.000 15.0 3898 10.0 65.0 25.0 CLEAN-SANDSTONE 11868.5 4.3 10.000 18.0 3904 10.0 65.0 25.0 SILTSTONE 11872.8 1.4 0.100 10.0 3906 10.0 65.0 25.0 CLEAN-SANDSTONE 11877.5 4.7 10.000 18.0 3908 10.0 65.0 25.0 SHALE 11882.2 0.4 0.001 5.0 3910 10.0 65.0 25.0 SILTSTONE 11886.5 0.8 0.100 10.0 3911 10.0 65.0 I 25.0 SHALE 11889.1 0.5 0.001 5.0 3913 10.0 65.0 25.0 SILTSTONE 11894.2 1.5 0.100 10.0 3915 10.0 65.0 25.0 Hemlock Coal 11899.1 0.6 0.001 5.0 3918 10.0 65.0 25.0 DIRTY-SANDSTONE 11905.3 7.5 2.000 15.0 3921 10.0 65.0 25.0 SILTSTONE 11914.7 1.3 0.100 10.0 3924 10.0 65.0 25.0 DIRTY-SANDSTONE 11919.0 1.4 2.000 15.0 3925 10.0 65.0 25.0 SHALE 11920.7 0.5 0.001 5.0 3927 10.0 65.0 25.0 SILTSTONE 11925.8 1.3 0.100 10.0 3929 10.0 65.0 25.0 SILTSTONE 11930.0 1.8 0.100 10.0 3931 10.0 65.0 25.0 SHALE 11936.1 1.1 0.001 5.0 3937 10.0 65.0 25.0 Upper Hemlock 11947.6 1.1 0.100 10.0 3942 10.0 65.0 25.0 CLEAN-SANDSTONE 11951.0 38.3 10.000 18.0 3948 10.0 65.0 25.0 SHALE 11989.3 0.5 0.001 5.0 3953 10.0 65.0 25.0 SILTSTONE 11994.2 0.4 0.100 10.0 3955 10.0 65.0 25.0 DIRTY-SANDSTONE 11995.5 13.7 10.000 18.0 3957 10.0 65.0 25.0 SILTSTONE 12009.2 6.7 0.100 10.0 3959 10.0 65.0 25.0 DIRTY-SANDSTONE 12031.4 2.6 2.000 15.0 3963 10.0 65.0 25.0 DIRTY-SANDSTONE 12034.6 1.5 2.000 15.0 3969 10.0 65.0 25.0 CLEAN-SANDSTONE 12036.5 25.3 10.000 18.0 3979 10.0 65.0 25.0 DIRTY-SANDSTONE 12061.8 6.2 2.000 15.0 3988 10.0 65.0 25.0 CLEAN-SANDSTONE 12069.5 34.3 10.000 18.0 3997 10.0 65.0 25.0 Silt Zone 12103.8 3.4 2.000 15.0 4005 10.0 65.0 25.0 SILTSTONE 12108.0 2.0 0.100 10.0 4008 10.0 65.0 25.0 DIRTY-SANDSTONE 12114.6 16.7 2.000 15.0 4014 10.0 65.0 25.0 Middle Hemlock 12135.5 126.8 10.000 18.0 4045 10.0 65.0 25.0 DIRTY-SANDSTONE 12262.3 6.2 2.000 15.0 4074 10.0 65.0 25.0 CLEAN-SANDSTONE 12270.0 7.8 10.000 18.0 4077 10.0 , 65.0 25.0 5 Client : Glacier Oil &Gas Well RU-05B SCIIIIIIIII Formation : Middle Hemlock District : Prudhoe Bay Country : United States Loadcase : Middle Hemlock SHALE 12277.8 1.2 0.001 5.0 4082 10.0 65.0 25.0 CLEAN-SANDSTONE 12289.8 32.6 10.000 18.0 4091 10.0 65.0 25.0 SILTSTONE 12322.4 0.8 0.100 10.0 4099 10.0 65.0 25.0 DIRTY-SANDSTONE 12325.0 1.4 2.000 15.0 4100 10.0 65.0 25.0 SHALE 12326.7 0.3 0.001 5.0 4101 10.0 65.0 25.0 SILTSTONE 12330.1 2.9 0.100 10.0 4104 10.0 65.0 25.0 Lower Hemlock 12339.6 12.4 2.000 15.0 4109 10.0 65.0 25.0 DIRTY-SANDSTONE 12355.1 3.4 2.000 15.0 4113 10.0 65.0 25.0 CLEAN-SANDSTONE 12359.4 23.2 10.000 18.0 4119 10.0 65.0 25.0 DIRTY-SANDSTONE 12382.6 9.6 2.000 15.0 4127 10.0 65.0 25.0 CLEAN-SANDSTONE 12394.6 6.9 10.000 18.0 4131 10.0 65.0 25.0 SILTSTONE 12401.5 1.6 0.100 10.0 4133 10.0 65.0 25.0 6 Client : Glacier Oil & Gas Well : RU-05B SehlUderger Formation : Middle Hemlock District : Prudhoe Bay Country : United States Loadcase : Middle Hemlock Section 3: Propped Fracture Schedule Pumping Schedule The following is the Pumping Schedule to achieve a propped fracture half-length(X1)of 143.0 ft with an average conductivity(K,w)of 2476 md.ft. Job Description Step Pump Fluid Name Step Fluid Gel Prop. Prop. Name Rate Volume Conc. Type and Mesh Conc. (bbl/min) (gal) (lb/mgal) (PPA) PAD 20.0 YF127FIexD 12600 27.0 0.00 1.0 PPA 20.0 YF127FIexD 1606 27.0 20/40 CarboBond Lite 1.00 2.0 PPA 20.0 YF127FIexD 1539 27.0 20/40 CarboBond Lite 2.00 3.0 PPA 20.0 YF127FIexD 1477 27.0 20/40 CarboBond Lite 3.00 4.0 PPA 20.0 YF127FIexD 1419 27.0 20/40 CarboBond Lite 4.00 5.0 PPA 20.0 YF127FIexD 1366 27.0 20/40 CarboBond Lite 5.00 6.0 PPA 20.0 YF127FIexD 1317 27.0 20/40 CarboBond Lite 6.00 7.0 PPA 20.0 YF127FIexD 1271 27.0 20/40 CarboBond Lite 7.00 8.0 PPA 20.0 YF127FIexD 1229 27.0 20/40 CarboBond Lite 8.00 Flush 20.0 WF127 4671 27.0 0.00 Fluid Totals 23825 gal of YF127FIexD 4671 gal of WF127 Proppant Totals 48300 lb of 20/40 CarboBond Lite Pad Percentages %PAD Clean 52.9 %PAD Dirty 48.4 Job Execution Step Step Cum.Fluid Step Cum. Step Cum. Avg. Step Cum. Name Fluid Volume Slurry Slurry Prop Prop. Surface Time Time Volume (gal) Volume Volume (Ib) (lb) Pressure (min) (min) (gal) (bbl) (bbl) (psi) PAD 12600 12600 300.0 300.0 0 0 7743 15.0 15.0 1.0 PPA 1606 14206 40.0 340.0 1606 1606 7741 2.0 17.0 2.0 PPA 1539 15745 40.0 380.0 3077 4684 7569 2.0 19.0 3.0 PPA 1477 17222 40.0 420.0 4430 9114 7306 2.0 21.0 4.0 PPA 1419 18641 40.0 460.0 5677 14791 7079 2.0 23.0 5.0 PPA 1366 20007 40.0 500.0 6832 21623 6951 2.0 25.0 6.0 PPA 1317 21324 40.0 540.0 7903 29526 6942 2.0 27.0 7.0 PPA 1271 22596 40.0 580.0 8900 38426 7041 2.0 29.0 8.0 PPA 1229 23825 40.0 620.0 9830 48255 7201 2.0 31.0 7 Client : Glacier Oil &Gas Wen : RU-05B Formation : Middle Hemlock District : Prudhoe Bay Country : United States Loadcase : Middle Hemlock Job Execution Step Step Cum.Fluid Step Cum. Step Cum. Avg. Step Cum. Name Fluid Volume Slurry Slurry Prop Prop. Surface Time Time Volume (gal) Volume Volume (Ib) (lb) Pressure (min) (min) (gal) (bbl) (bbl) (psi) Flush 4671 28496 111.2 731.2 0 48255 7670 5.6 36.6 8 Client Glacier Oil &Gas Well : RU-05B 111161111 Formation : Middle Hemlock District : Prudhoe Bay Country : United States Loadcase : Middle Hemlock Pumping Schedule Totals Summary for This Stage: Average Pump Rate 20.0 bbl/min Volume Weighted Average Rate 20.0 bbl/min Total Fluid Volume 678 bbl Total Proppant Mass 48300 lb Total Slurry Volume 731.2 bbl Total Pump Time 36.6 min Fluid Based Totals for This Stage Average Volume Total Total Total Total Fluid Pump Weighted Fluid Proppant Slurry Pump Rate Average Rate Volume Mass Volume Time (bbl/min) (bbl/min) (gal) (Pb) (bbl) (min) YF127FIexD 20.0 20.0 23825 48255 620.0 31.0 WF127 20.0 20.0 4671 0 111.2 5.6 Proppant Based Totals for This Stage Average Volume Total Total Total Total Proppant Pump Weighted Fluid Proppant Slurry Pump Rate Average Rate Volume Mass Volume Time (bbl/min) (bbl/min) (gal) (Pb) (bbl) (min) 20/40 CarboBond Lite 20.0 20.0 11225 48255 320.0 16.0 Summary for Each Treatment Average Volume Total Total Total Total Treatment Pump Weighted Fluid Proppant Slurry Pump Type Rate Average Rate Volume Mass Volume Time (bbl/min) (bbl/min) (gal) (Ib) (bbl) (min) Propped Fracture 20.0 20.0 28496 48255 731.2 36.6 Summary for Each Fluid in Each Treatment ITreatment Fluid PuW Plump eightad ci„ia c t c,.. o.. Type Rate Average Rate Volume Mass Volume Time (bbl/min) (bbl/min) (gal) (Pb) (bbl) (min) Propped Fracture YF127FIexD 20.0 20.0 23825 48255 620.0 31.0 Propped Fracture WF127 20.0 20.0 4671 0 111.2 5.6 9 Client Glacier Oil & Gas Well : RU-05B Formation : Middle Hemlock District : Prudhoe Bay Country : United States Loadcase : Middle Hemlock Section 4: Propped Fracture Simulation Results (1) ACL Fracture Profile and Proppant Concentration Plot FracCADE* Giaaiar Oil&Gas RU-0513 Middle Hemlock ACL Fracture Profile and Pro Ppanl Concentruton 31 Dec 2016 12120 • r r r .5 0.0 WU 12180- - - 0.0-0.21i>1[t2 0.2-0.4 Ibft2 0.4-0.6 16102 0.6-0.816Nt2 0.8-1.016.102 1.0-1.2 IbrFt2 1.2-1.416-102 NM 1.4-1.61Mt2 Mit >1.616/t2 12240- - - Fractures 1 In . MD=15160.76 ft • • 12300 6000 8000 10001',-0.15 -0:10 -0.05 -0 0.05 0.10 0.15 0 50 100 150 200 • Stress-pe ACL Wdth at N§Ilbora-in Fracture Half-Length-ft (2) Treating Plot Bottomhole Pressure — Surface Pressure — Total Inj.Rate —P— EOJ 11000 • 20 10000 ^ 18 -16 9000' 14 8000' a 12 N \ n u 10 7000' m 6000 6 -4 5000' -2 4000 • • • r 0 0 10 20 30 40 50 Treatment Time-min 10 Client : Glacier Oil&Gas Well : RU-05B Formation : Middle Hemlock District : Prudhoe Bay Country : United States Loadcase : Middle Hemlock Section 5: Propped Fracture Simulation The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-D Vertical model.Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Initial Fracture Top TVD 12135.5 ft Initial Fracture Bottom TVD 12262.3 ft Propped Fracture Half-Length 143.0 ft EOJ Hyd Height at Well 148.4 ft Average Propped Width 0.136 in Average Gel Concentration 836.8 lb/mgal Average Gel Fluid Retained Factor 1.00 Net Pressure 736 psi Efficiency 0.304 Effective Conductivity 2992 md.ft Effective Fcd 2.1 Max Surface Pressure 7962 psi Simulation Results by Fracture Segment From To Prop.Conc. Propped Propped Frac. Frac. Fracture (ft) (ft) at End of Width Height Prop. Gel Conc. Conductivity Pumping (in) (ft) Conc. (Ib/mgal) (md.ft) (PPA) (lb/ft2) 0.0 35.7 8.2 0.176 135.6 1.58 435.6 3209 35.7 71.5 7.8 0.161 132.1 1.45 479.7 2943 71.5 107.2 7.1 0.151 123.8 1.37 488.7 2750 107.2 143.0 3.8 0.060 97.3 0.55 1830.8 1104 11 Client : Glacier Oil & Gas Well : RU-05B Formation : Middle Hemlock District : Prudhoe Bay Country : United States Loadcase : Middle Hemlock Fracture Geometry Data Per Zone for Production Prediction Zone Name Top MD Top Gross Net Fracture Fracture Fracture Ift) TVD Height Height Width Length Conductivity (ft) (ft) (in) (ft) (md.ft) DIRTY-SANDSTONE 14600.7 11844.5 24.0 19.2 0.000 .0 0 CLEAN-SANDSTONE 14640.8 11868.5 4.3 4.3 0.000 .0 0 SILTSTONE 14648.1 11872.8 4.7 1.4 0.000 .0 0 CLEAN-SANDSTONE 14656.1 11877.5 4.7 4.7 0.000 .0 0 SHALE 14664.2 11882.2 4.3 .4 0.000 .0 0 SILTSTONE 14671.6 11886.5 2.6 .8 0.000 .0 0 SHALE 14676.1 11889.1 5.1 .5 0.000 .0 0 SILTSTONE 14685.0 11894.2 4.9 1.5 0.000 .0 0 Hemlock Coal 14693.6 11899.1 6.2 .6 0.000 .0 0 DIRTY-SANDSTONE 14704.6 11905.3 9.4 7.5 0.000 .0 0 SILTSTONE 14721.4 11914.7 4.3 1.3 0.000 .0 0 DIRTY-SANDSTONE 14729.2 11919.0 1.7 1.4 0.000 .0 0 SHALE 14732.3 11920.7 5.1 .5 0.000 .0 0 SILTSTONE 14741.6 11925.8 4.2 1.3 0.000 .0 0 SILTSTONE 14749.1 11930.0 6.1 1.8 0.000 .0 0 SHALE 14760.0 11936.1 11.4 1.1 0.000 .0 0 Upper Hemlock 14780.0 11947.6 3.5 1.1 0.000 .0 0 CLEAN-SANDSTONE 14786.0 11951.0 38.3 38.3 0.000 .0 0 SHALE 14850.0 11989.3 4.9 .5 0.000 .0 0 SILTSTONE 14858.0 11994.2 1.2 .4 0.000 .0 0 DIRTY-SANDSTONE 14860.0 11995.5 13.7 13.7 0.000 .0 0 SILTSTONE 14882.0 12009.2 22.2 6.7 0.000 .0 0 DIRTY-SANDSTONE 14917.0 12031.4 3.2 2.6 0.000 .0 0 DIRTY-SANDSTONE 14922.0 12034.6 1.9 1.5 0.000 .0 0 CLEAN-SANDSTONE 14925.0 12036.5 25.3 25.3 0.000 .0 0 DIRTY-SANDSTONE 14963.7 12061.8 7.7 6.2 0.000 .0 0 CLEAN-SANDSTONE 14975.3 12069.5 34.3 34.3 0.000 .0 0 Silt Zone 15026.2 12103.8 4.2 3.4 0.000 .0 0 SILTSTONE 15032.3 , 12108.0 6.6 20 annn n n DIRTY-SANDSTONE 15042.0 12114.6 20.9 16.7 0.031 87.5 559 Middle Hemlock 15072.3 12135.5 126.8 126.8 0.164 143.0 2992 DIRTY-SANDSTONE 15249.2 12262.3 7.7 6.2 0.044 98.5 807 CLEAN-SANDSTONE 15259.6 12270.0 7.8 7.8 0.006 22.3 113 SHALE 15270.1 12277.8 12.0 1.2 0.000 .0 0 CLEAN-SANDSTONE 15286.1 12289.8 32.6 32.6 0.000 .0 0 SILTSTONE 15329.4 12322.4 2.6 .8 0.000 .0 0 DIRTY-SANDSTONE 15332.9 12325.0 1.7 1.4 0.000 .0 0 SHALE 15335.1 12326.7 3.4 .3 0.000 .0 0 SILTSTONE 15339.6 12330.1 9.5 2.9 0.000 .0 0 Lower Hemlock 15352.2 12339.6 15.5 12.4 0.000 .0 0 12 Client : Glacier Oil& Gas St hiumberger Well : RU-05B Formation : Middle Hemlock District : Prudhoe Bay Country : United States Loadcase : Middle Hemlock DIRTY-SANDSTONE 15372.5 12355.1 4.3 3.4 0.000 .0 0 CLEAN-SANDSTONE 15378.2 12359.4 23.2 23.2 0.000 .0 0 DIRTY-SANDSTONE 15408.4 12382.6 12.0 9.6 0.000 .0 0 CLEAN-SANDSTONE 15424.0 12394.6 6.9 6.9 0.000 .0 0 SILTSTONE 15433.0 12401.5 5.2 1.6 0.000 .0 0 Exposure Time Prediction by Step Step Name Fluid Name Pump Fluid Perforation Exposure at Exposure Rate Volume Injection BHST of aboveWatch (bbl/min) (gal) Temp. 195 degF Temp.of (degF) (min) 190 degF (min) PAD YF127FIexD 20.0 12600 152 1.8 1.8 1.0 PPA YF127FIexD 20.0 1606 122 11.7 11.7 2.0 PPA YF127FIexD 20.0 1539 117 7.8 7.8 3.0 PPA YF127FIexD 20.0 1477 114 0.0 0.0 4.0 PPA YF127FIexD 20.0 1419 112 0.0 0.0 5.0 PPA YF127FIexD 20.0 1366 111 0.0 0.0 6.0 PPA YF127FIexD 20.0 1317 110 0.0 0.0 7.0 PPA YF127FIexD 20.0 1271 109 0.0 0.0 8.0 PPA YF127FIexD 20.0 1229 108 0.0 0.0 Flush WF127 20.0 4671 13 Client Glacier Oil & Gas Well : RU-05B Formation : Middle Hemlock District : Prudhoe Bay Country : United States Loadcase : Middle Hemlock Section 6: Treatment Fluid Data Fluid data is given at 10 md. Fluid Name 3% KCI brine YF127FIexD WF127 Friction Rate Low(bbl/min) 1.9 1.0 1.0 Pressure Low(psi/1000ft) 10.0 26.9 5.3 Rate Pivot(bbl/min) 10.0 20.0 20.0 Pressure Pivot(psi/1000ft) 221.5 220.0 200.0 Rate High(bbl/min) 21.9 65.1 35.8 Pressure High(psi/1000ft) 1000.0 1000.0 1000.0 Fluid Loss CW (ft/min0.5) 1.0E+0 8.7E-3 1.0E-2 Spurt(gal/100ft2) 0.0 0.0 3.4 Ct (ft/min0.5) 5.1E-2 3.4E-3 9.4E-3 Rheology Temperature(degF) 195 195 195 Time(hr) 0.0 0.0 0.0 Behavior Index(N') 1.00 0.53 0.80 Consist.Index(K')(Ibf.s^n/ft2) 6.66E-6 1.44E-2 7.00E-4 Viscosity©Shear Rate(cP) 0.319 55.966 12.000 Shear Rate(1/s) 170 170 170 14 Client : Glacier Oil & Gas l derger Well : RU-05B F Formation : Middle Hemlock District : Prudhoe Bay country : United States Loadcase : Middle Hemlock Section 7: Proppant Data Proppant Permeability is calculated based on the following parameters: BH Static Temperature: 195 degF Stress on Proppant: 8430 psi Propped Fracture Conc.: 1.00 lb/ft2 Average Young's Modulus: 4.620E+06 psi Proppant Data Proppant Name Specific Mean Pack Permeability Gravity Diameter Porosity (md) (in) (%) Jordan Unimin 20/40 2.65 0.022 35.0 23763 CarboLite 20/40 2.74 0.029 35.0 139688 20/40 CarboBond Lite 2.61 0.016 43.3 218810 Proppant Permeability Plot -- ProppanI Permeability 400000 _ Stress on Proppant • 300000 --0— Jordan Unimin 20/40 200000 r—' • Carb Lite 20/40 • 20/40 CarboBond Lit a - Prop Stress ...:100000 I � 9 1000 2000 3000 4000 5000 6000 7900 8000 9000 10000 11000 12000 Closure Stress 10011 15 Client Glacier Oil & Gas Well : RU-05B Formation : Middle Hemlock District : Prudhoe Bay Country : United States Loadcase : Middle Hemlock Section 8: Hole Survey Deviated Hole YES MD/TVD Calculation Relationship Unknown Hole Survey MD TVD Deviation Deviation Azimuth Azimuth Dogleg (ft) (ft) Angle Build Rate Angle Build Rate Severity (deg) (deg/100ft) (deg) (deg/100ft) (deg/100ft) 0.0 0.0 0.0 0.0 0.0 0.0 0.0 143.1 143.1 0.3 0.2 42.0 29.4 0.2 173.1 173.1 0.1 -0.5 356.0 -153.3 0.6 200.0 200.0 0.2 0.4 235.0 -449.8 1.0 204.1 204.1 0.3 1.0 232.0 -73.2 1.0 234.1 234.1 0.9 2.2 206.0 -86.7 2.3 294.1 294.1 2.8 3.2 198.0 -13.3 3.2 383.1 382.8 5.4 2.9 212.0 15.7 3.1 472.1 471.2 7.8 2.8 211.7 -0.4 2.8 562.1 560.2 9.8 2.2 211.5 -0.2 2.2 677.6 673.5 12.5 2.3 211.4 -0.1 2.3 767.0 760.8 12.4 -0.0 211.2 -0.2 0.0 855.2 847.0 12.0 -0.5 207.1 -4.7 1.1 943.1 933.0 11.9 -0.1 196.0 -12.5 2.6 1035.8 1023.7 12.0 0.1 183.4 -13.7 2.8 1129.7 1115.3 13.6 1.8 166.8 -17.7 4.3 1223.1 1205.5 16.5 3.1 152.1 -15.7 5.1 1319.3 1297.6 17.1 0.6 146.3 -6.1 1.8 1413.4 1387.1 18.9 1.9 139.4 -7.3 3.0 1508.6 1476.4 21.7 3.0 138.7 _ -0.7 3.0 1603.9 1564.0 24.4 2.8 137.2 -1.5 2.9 1700.2 1650.9 26.7 2.4 136.0 -1.3 2.4 1796.4 1736.1 28.6 1.9 137.4 1.5 2.1 1890.8 1817.9 31.4 3.1 136.5 -0.9 3.1 1585.2 1858.5 3i.2 -0.3 137.1 0.6 0.4 2080.0 1980.1 30.1 -1.1 137.8 0.7 1.2 2172.9 2061.1 28.4 -1.9 138.9 1.3 2.0 2267.6 2144.5 28.1 -0.4 141.8 3.0 1.5 2358.6 2224.1 29.9 2.0 139.1 -2.9 2.5 2451.3 2303.6 32.0 2.3 139.3 0.2 2.3 2545.3 2384.2 29.9 -2.2 139.1 -0.2 2.2 2641.5 2467.6 29.7 -0.2 136.1 -3.1 1.5 2736.0 2550.2 28.3 -1.5 134.5 -1.8 1.7 2828.7 2631.5 29.2 0.9 132.9 -1.7 1.2 2923.3 2714.1 29.1 -0.0 135.3 2.6 1.2 3018.0 2795.8 31.8 2.8 135.3 -0.1 2.8 16 Client : Glacier Oil & Gas Sal" Well : RU-05B Formation : Middle Hemlock District : Prudhoe Bay Country : United States Loadcase : Middle Hemlock Hole Survey MD TVD Deviation Deviation Azimuth Azimuth Dogleg (ft) (ft) Angle Build Rate Angle Build Rate Severity (deg) (deg/100ft) (deg) (deg/100ft) (deg/100ft) 3110.2 2873.4 33.5 1.8 134.0 -1.3 2.0 3160.5 2915.1 34.7 2.5 134.0 -0.1 2.5 3190.0 2939.4 34.5 -0.6 133.9 -0.1 0.6 3250.8 2989.5 34.2 -0.6 133.9 -0.1 0.6 3345.4 3067.9 34.1 -0.1 133.8 -0.1 0.0 3440.4 3146.5 34.1 -0.1 133.4 -0.4 0.2 3536.1 3226.3 33.1 -1.1 137.7 4.5 2.7 3633.1 3307.4 33.3 0.2 137.6 -0.1 0.2 3730.0 3388.9 32.3 -1.0 138.5 0.9 1.1 3826.0 3470.1 32.1 -0.2 138.4 -0.1 0.2 3920.3 3549.8 32.4 0.3 138.6 0.2 0.4 4014.8 3629.9 31.8 -0.6 138.4 -0.2 0.6 4109.5 3710.4 31.7 -0.2 138.1 -0.3 0.2 4205.0 3791.6 31.8 0.1 138.2 0.1 0.0 4300.2 3872.6 31.7 -0.1 138.2 0.0 0.0 4396.5 3954.4 31.9 0.2 138.3 0.0 0.2 4491.4 4035.0 31.8 -0.1 138.5 0.2 0.2 4586.7 4115.9 32.1 0.3 138.6 0.2 0.3 4675.6 4191.6 31.0 -1.2 137.9 -0.8 1.3 4770.8 4273.3 30.7 -0.3 138.7 0.8 0.5 4862.3 4351.9 31.0 0.3 138.6 -0.0 0.3 4957.1 4433.0 31.5 0.5 139.1 0.5 0.6 5051.9 4513.5 32.0 0.5 138.4 -0.7 0.7 5147.5 4594.8 31.8 -0.3 138.4 -0.1 0.3 5243.0 4676.0 31.4 -0.4 136.6 -1.9 1.1 5339.1 4757.9 32.0 0.6 137.0 0.4 0.7 5433.7 4837.9 32.5 0.6 136.9 -0.0 0.6 5526.8 4916.9 31.2 -1.5 137.7 0.8 1.5 5623.5 5000.1 30.3 -0.9 137.7 -0.0 0.9 C71 A 7 ret-in n nn __ JV1U.J JV.L -U.I IS/.ZS U.L U.0 5808.7 5160.1 30.3 0.1 138.1 0.4 0.2 5900.1 5239.0 30.4 0.2 138.2 0.0 0.2 5996.0 5321.6 30.5 0.1 137.8 -0.4 0.2 6091.1 5403.4 30.7 0.2 136.7 -1.2 0.6 6187.7 5486.4 30.9 0.2 137.0 0.3 0.2 6281.4 5566.7 31.2 0.4 136.8 -0.2 0.4 6377.0 5648.4 31.3 0.1 136.9 0.1 0.0 6469.9 5727.7 31.6 0.3 137.1 0.2 0.3 6563.4 5807.2 31.9 0.3 137.9 0.8 0.5 6671.9 5899.6 31.2 -0.7 138.1 0.2 0.7 6766.3 5980.6 30.8 -0.4 138.4 0.3 0.4 17 Client Glacier Oil & Gas Well : RU-05B Formation : Middle Hemlock District : Prudhoe Bay Country : United States Loadcase : Middle Hemlock Hole Survey MD TVD Deviation Deviation Azimuth Azimuth Dogleg (ft) (ft) Angle Build Rate Angle Build Rate Severity (deg) (deg/10(1ft) (deg) (deg/100ft) (deg/100ft) 6861.4 6062.3 30.7 -0.2 137.9 -0.5 0.3 6956.9 6144.6 30.3 -0.3 137.6 -0.4 0.4 7052.8 6227.5 30.0 -0.4 137.3 -0.3 0.4 7145.7 6308.2 29.5 -0.5 138.0 0.8 0.6 7237.3 6387.6 30.1 0.7 136.6 -1.6 1.0 7330.4 6468.0 30.5 0.3 137.4 0.9 0.6 7422.9 6547.6 30.7 0.3 138.8 1.5 0.8 7518.2 6629.6 30.6 -0.1 138.3 -0.5 0.3 7613.5 6711.6 30.5 -0.1 140.4 2.1 1.1 7706.5 6790.9 32.5 2.1 139.1 -1.3 2.2 7802.6 6872.1 32.4 -0.1 137.4 -1.8 1.0 7895.2 6950.1 32.7 0.3 136.5 -0.9 0.6 7990.9 7030.8 32.4 -0.2 134.7 -1.9 1.0 8083.8 7109.1 32.6 0.2 133.9 -0.9 0.5 , 8179.8 7190.1 32.4 -0.3 133.9 0.1 0.3 8277.2 7272.6 32.0 -0.3 133.9 -0.1 0.3 8370.5 7351.8 31.8 -0.3 133.3 -0.6 0.4 8464.7 7431.6 32.3 0.6 134.9 1.7 1.1 8555.9 7508.8 31.8 -0.5 133.8 -1.2 0.9 8651.5 7590.3 31.2 -0.7 133.2 -0.6 0.8 8746.3 7671.7 30.7 -0.5 133.2 -0.0 0.5 8838.7 7751.3 30.3 -0.4 135.1 2.1 1.1 8937.4 7836.7 30.2 -0.1 136.4 1.3 0.7 9030.9 7917.8 29.4 -0.8 136.3 -0.2 0.8 9122.2 7997.4 29.0 -0.4 135.9 -0.4 0.5 9214.0 8078.1 28.2 -0.9 135.6 -0.3 0.9 9309.3 8161.7 29.0 0.8 134.7 -0.9 0.9 9403.1 8243.5 29.6 0.7 135.4 0.7 0.8 9497.7 8325.6 30.0 0.4 136.1 0.8 0.6 9591 F APR d 11.1 7 7 ,oe n a 9687.8 8488.7 31.2 0.0 136.1 -0.1 0.0 9779.5 8567.2 31.1 -0.0 135.5 -0.6 0.3 9875.7 8649.6 31.0 -0.1 136.6 1.2 0.6 9970.0 8730.4 30.9 -0.1 136.0 -0.6 0.4 10064.2 8811.4 30.7 -0.2 136.9 1.0 0.6 10157.8 8891.7 31.1 0.4 136.6 -0.3 0.5 10251.6 8972.3 30.2 -1.0 136.5 -0.2 1.0 10346.2 9054.4 29.6 -0.6 136.9 0.5 0.6 10440.7 9136.5 29.5 -0.1 137.0 0.1 0.0 10533.1 9217.1 29.3 -0.3 137.0 -0.0 0.3 10627.2 9299.0 29.5 0.2 136.7 -0.2 0.2 18 Client Glacier Oil & Gas Well : RU-05B tehltitgrger Formation : Middle Hemlock District : Prudhoe Bay Country : United States Loadcase : Middle Hemlock Hole Survey MD TVD Deviation Deviation Azimuth Azimuth Dogleg (ft) (ft) Angle Build Rate Angle Build Rate Severity (deg) (deg/100ft) (deg) (deg/100ft) (deg/100ft) 10721.8 9381.4 29.5 -0.0 136.4 -0.4 0.2 10819.1 9466.3 29.3 -0.2 136.7 0.3 0.3 10913.0 9548.5 28.4 -0.9 137.1 0.4 1.0 11010.2 9634.3 27.6 -0.8 137.1 0.0 0.8 11104.4 9717.8 27.8 0.1 137.6 0.6 0.3 11138.7 9748.0 27.9 0.4 136.8 -2.4 1.2 11197.4 9799.9 28.1 0.4 137.0 0.3 0.4 11233.4 9831.6 28.3 0.5 137.1 0.2 0.5 11289.0 9880.4 29.0 1.2 137.8 1.2 1.3 11383.5 9963.0 29.2 0.2 137.7 -0.0 0.2 11472.1 10040.5 28.9 -0.4 138.1 0.5 0.4 11492.5 10058.1 30.9 10.0 137.9 -0.9 10.0 11579.4 10130.3 36.8 6.8 137.1 -1.0 6.8 11635.9 10174.1 41.7 8.7 136.5 -1.0 8.7 11682.8 10209.1 41.7 0.0 136.4 -0.3 0.2 11743.5 10254.1 42.5 1.3 138.5 3.5 2.7 11780.0 10280.6 44.6 5.6 139.4 2.2 5.8 11871.2 10343.6 47.9 3.7 139.6 0.2 3.7 11965.6 10404.2 52.2 4.5 138.6 -1.0 4.6 12013.5 10432.8 54.5 4.9 137.6 -2.0 5.1 12107.5 10486.2 56.2 1.8 137.1 -0.6 1.9 12173.8 10522.6 57.3 1.7 137.3 0.3 1.7 12262.5 10569.2 59.2 2.1 136.9 -0.5 2.1 12357.3 10617.1 60.3 1.2 136.6 -0.2 1.2 12450.9 10662.1 62.1 1.9 135.8 -0.9 2.1 12546.7 10705.7 63.8 1.7 136.0 0.2 1.8 12642.7 10746.8 65.6 1.9 135.7 -0.3 1.9 12734.5 10783.8 66.8 1.3 136.3 0.6 1.4 12826.0 10819.5 67.3 0.6 137.0 0.8 0.9 1291�...0 i marc CC+ n pal. 40.............• "J.i -c.V 137.S 1.1 2.7 12939.8 10865.7 66.0 3.6 137.3 -2.5 4.3 13035.5 10905.8 64.6 -1.4 134.9 -2.5 2.7 13130.2 10948.3 62.1 -2.7 132.4 -2.6 3.5 13223.4 10993.6 59.7 -2.5 129.8 -2.8 3.5 13314.9 11042.0 56.5 -3.5 127.1 -2.9 4.3 13412.4 11097.9 53.4 -3.2 125.4 -1.8 3.5 13504.4 11154.2 51.1 -2.5 125.1 -0.4 2.5 13598.7 11214.8 48.9 -2.4 123.3 -1.9 2.8 13694.5 11279.0 47.0 -1.9 121.7 -1.6 2.3 13787.4 11342.2 47.2 0.2 122.3 0.7 0.5 13882.5 11405.5 49.2 2.2 121.4 -1.0 2.3 19 Client Glacier Oil & Gas Well : RU-05B liklikuipr Formation : Middle Hemlock District : Prudhoe Bay Country : United States Loadcase : Middle Hemlock Hole Survey MD TVD Deviation Deviation Azimuth Azimuth Dogleg (ft) (ft) Angle Build Rate Angle Build Rate Severity (deg) (deg/100ft) (deg) (deg/100ft) (deg/100ft) 13977.8 11466.8 50.7 1.5 119.5 -2.0 2.1 14072.8 11525.8 52.5 1.9 119.4 -0.1 1.9 14167.7 11581.9 55.0 2.6 119.9 0.5 2.6 14261.3 11635.9 54.7 -0.3 118.9 -1.1 0.9 14355.2 11692.0 51.8 -3.1 117.6 -1.4 3.3 14449.1 11750.3 51.5 -0.3 116.0 -1.7 1.3 14542.3 11808.5 51.2 -0.3 115.7 -0.4 0.4 14637.7 11866.7 53.6 2.5 117.5 1.8 2.9 14732.0 11920.5 56.7 3.3 118.0 0.5 3.3 14824.7 11973.9 53.0 -4.0 115.4 -2.7 4.6 14919.6 12033.0 50.0 -3.1 112.5 -3.1 3.9 15014.7 12096.0 47.1 -3.0 109.1 -3.6 4.1 15108.8 12160.8 45.8 -1.4 106.2 -3.1 2.6 15203.0 12228.2 42.8 -3.2 99.0 -7.6 6.2 15297.0 12298.0 41.5 -1.4 90.9 -8.6 5.9 15323.0 12317.5 41.0 -1.7 89.3 -6.4 4.5 15390.5 12368.8 40.0 -1.5 84.9 -6.5 4.5 15485.6 12442.3 38.7 -1.4 78.3 -6.9 4.6 15580.2 12518.0 35.1 -3.8 72.2 -6.4 5.4 15674.0 12596.1 32.2 -3.0 65.9 -6.7 4.8 15686.0 12606.3 31.4 -7.1 64.9 -8.5 8.4 15740.0 12652.4 31.4 0.0 64.9 0.0 0.0 15750.0 12661.0 31.4 0.0 64.9 0.0 0.0 20 ``��,,, Client: Cook Inlet Energy erg Q Wei Basin RU-05B �i Redoubt Unit State: Alaska County/Parish: Kenai Peninsula Borough Case: Disclosure Type: Pre-Job Well Completed: 5/10/2017 Date Prepared: 3/13/2017 1:22 PM Report ID: RPT-48090 Fluid Name&Volume :,dditve Description Concentration F103 Surfactant 1 Gal/1000 Gal 113.0 Gal 1218 Breaker 1.2 Lb/1000 Gal 134.0 Lb J450 Stabilizing Agent 0.7 Gal/1000 Gal 84.0 Gal .1475 Breaker 4 Lb/1000 Gal 450.0 Lb .1604 i Crosslinker _ 1.7 Gal/1000 Gal 193.0 Gal YF127FIexD:WF127 112,560 Gal 1891 Guar Slurry 6.4 Gal/1000 Gal 720.0 Gal M002 Additive 1.2 Lb/1000 Gal 138.0 Lb M117 _ Clay Control Agent 250 Lb/1000 Gal 28,140.0 Lb M275 Bactericide 05 Lb/1000 Gal 54.0 Lb - - -- ----- - S526-2040 Propping Agent varied concentrations 144,900.0 Lb W054 Demulsifier 1 Gal/1000 Gal 113.0 Gal The total volume listed in the tables above represents the summation of water and additives.Water is supplied by client. CAS':; . 1,a!,v. Water(Including Mix Water Supplied by Client)* -83% 64-19-7 Acetic acid(impurity) <0.0001 % 67-56-1 Methanol <0.1 % 67-63-0 �__ Propan-2-ol _ <0.1 % 91-20-3 Naphthalene(impurity) <0.001 % 95-63-6 1,2,4 Trimethylbenzene(impurity) _ <0.0001% 102-71-6 2,2',2"-nitrilotriethanol <0.1% 107-21-1 Ethylene Glycol <0.1 % 110-17-8 Fumaric acid <0.01 % 111-76-2 2-butoxyethanol <0.1% 112-42-5 1-undecanol <0.01 % 122-18-9 Benzyldimethylammonium chloride <0.0001% _ 127-08-2 _ Acetic acid,potassium salt <0.001 % 139-07-1 Benzyllauryldimet ylammonium chloride <0.01 % 139-08-2 Dimethylbenzylmyrisylammonium chloride <0.001 % 143-18-0 Potassium oleate <0.001% 1303-96-4 Sodium Tetraborate Decahydrate <0.01% 1310-73-2 Sodium hydroxide <0.1% 1319-33-1 Boronatrocalcfe <0.1 % 2682-20-4 2-methyl-2h-isothiazol-3-one <0.0001 % 7447-40-7 Potassium chloride "P 2% 7631-86-9 Silicon Dioxide <0.001% 7647-14-5 Sodium chloride <0.1% 7727-54-0 Diammonium peroxidisulphate <0.1 % 7786-30-3 Magnesium chloride <0.001 % 9000-30-0 Guar gum <1 % 9002-84-0 poly(tetrafluoroethylene) <0.0001% 9003-11-6 Methyl oxirane polymer with oxirane <0.01% 10377-60-3 Magnesium nitrate <0.001 % 14464-46-1 Cristobalite <0.0001% 14807-96-6 Magnesium silicate hydrate(talc) <0.001 % 14808-60-7 Quartz,Crystalline silica <0.0001 % 25038-72-6 Vinylidene chloride/methylacrylate copolymer <0.01 % 25322-68-3 Poly(oxy-1,2-ethanediyl),a-hydro.w-hydroxy-Ethane-1,2-diol,ethoxylated <0.01 % 26062-79-3 l Ammonium,diallyldimethyl-,chloride,polymers <0.001 % 26172-55-4 5-chloro-2-methyl-2h-isothiazolol-3-one <0.001% 30846-35-6 Ethoxytated propoxylated 4-nonylphenol-formaldehyde resin <0.01% 34398-01-1 Alcohol,Cii linear,ethoxylated <0.1 % 64742-47-8 Distillates,petroleum,hydrotreated light <1 % _ 64742-94-5 Heavy aromatic naphtha <0.01 % 66402-68-4 Ceramic materials and wares,chemicals -13 % ©Schlumberger 2017.Used by Cook Inlet Energy by permission. Page:1/2 `� Client: Cook Inlet Energy rp Wein RU-05B Basin/Field: Redoubt Unit State: Alaska County/Parish: Kenai Peninsula Borough Case: Disclosure Type: Pre-Job Well Completed: 5/10/2017 Date Prepared: 3/13/2017 1:22 PM Report ID: RPT-48090 Chemical Name Mass Fraction 68131-39-5 C12-15 alcohol ethyoxylated <0.01 % 68153-30-0 Amine treated smectite clay <0.01 % 78330-19-5 Alcohol,C7-9-iso,C8,ethoxylated <0.01 % 78330-20-8 Alcohol,C9-11-iso,C10,ethoxylated <0.01 % 78330-21-9 Alcohol,C11-14,ethoxylated <0.01 % 91053-39-3 Diatomaceous earth,calcined <0.01 % 125005-87-0 Diutan gum <0.001 % 595585-15-2 Diutan <0.001 % JO% Mix water is supplied by the client.Schlumberger has performed no analysis of the water and cannot provide a breakdown of components that may have been added to the water by third-parties. *The evaluation of attached document is performed based on the composition of the identified products to the extent that such compositional information was known to CRC-Chemicals as of the date of the document was produced.Any new updates will not be reflected in this document ©Schlumberger 2017.Used by Cook Inlet Energy by permission. Page:2/2 SPS-343 St mutation Pump Skid F'egrn-Pressur Pumping System, Radiator Cooled .- It * ' Ir' .k7N Fe,*) .... i, , 16'""cr.i aq: ".,4::5,1 ,,;,„ J 1, ''.0., k -,,,, - ° lift '''¢ 7. t ''',/)''''' «. 'I. ' .-Pr' ! i. _ ( i w 1, ' 't x ' /, „ ...'(1 g .tom M: The SPS-343 Stimulation Pumper is a skid-mounted EquiPn sk a pumping unit designedfor ery high-horsePtrwer applk�tioraa. © 825 B�Pu pup to 20,0�on fend o liar 35128 twelve The triplex pump delivers deck engine rated at fracturing fluids to the well at high 2250 BHP 1900fpm• pressure and rate. o * ( ' mainteeenIT' ergine o dean S®81 The unit can be delivered with ung and fro wflh eight'gem locked alt. any of the Dowell - 'OPI° style 8° stroke HD-2000 Power-ted fluid-ends, depending on the rate Provides a remote tool tom, with available fluid-end sizes and pressure requirements in the Which may be locates to 120 3.75`, 4.5`, 5`, 5.5°, 6.5', a Users market. RIs equipped%vitt, lean ircrrn fir ing YitlO. tf.(D teamster. a remote panel sMowina oc�rni. the g from IIP to 1210 ecanasy na spirt rn trues pieces 3-piece DNV 2.7-1 feet away. The panel allows o 0s on and skid and crash frames. selection, throttle control, � c Radiator tooting fpr maximum emergency shutdown to be versatTfty. perfonned. A Mark of Schlumberger annocw SPS-343 Stimulation Pump Skid General Specifications Part Number 100305352 Deck Eine Caterpillar 35128-2250 BHP @ 1900 RPM Deck Transmission Allison 59810M,7 gears Ambient Raring -5 DegC to 48 DegC Dimensions: Length Overall 27 ft-3 in.[8.30 m] Height 18ft-6in.[5.63m] Mdth 8 f1-11 in.[2.70 m] Total Weight 73,194 bin[33,200 kg] Engine skid(W x L x H) 8-ft-11 in.[2.70m]x 1541-9 in.[4.80rn]x 11-ft-6 in.13.50m] Engine skid weight 35,715 Ibm[16200 kg] Pump skid(VVx L x H) 8 ft-11 in.[2.70 m]x 10-f1-2-in.[3.09rn]x 11-ft-6 in.[3.50m Pump skid weight 25,353 Ibm[11,500 kg] Radiator skid(W x L x H) 8 ft-11 in.[2.70 mJ x 151-9 irn.[4.80 m]x 7 ft.[2.14 mJ Radiator skid welOtt 12,125 Ibm[5500 kg] Deck Load 12.5 PSI(from the two Iongitucti nal I-beams only) Fuel tanks Two,each 160 Gal Unities Air for sung 100 psi Fuel 107 GaIlmin(maximum) Triplex Pump Model HD-2000 Type 8 inch stroke Reciprocating Triplex(Gear Ratio-6.353:1) Hydraulic Horsepower 2000 HHP Fluid End EOPI(4.5°) Maximum Pressure 15,000 PSI Maximum Rate 11.4 BPM Fluid-Ends Available FOPI(3.75'),EOPI(4.57,HOPI(5"),IOPI(5.5'),UOPI(6.5'), 1JOPi(6.76') *A Mark of Schlumberger cJznaa> katunis-fwq SPS-343 S irnuCaf on Pump Skid ENGINE sal Hawepower r.nw xss-HD-1is, neon I � 21116 - MINN-FLUID END:4111" maw let I 3rd \ - - - - -WProems •+-- 15000•-.<,00=;..;s. -.-.-0 s� Milliliti . o.le.Y[tanKI 1 ALLISON MINN ee«9101in 9a 9rar1r�t1 1zs� >.+oerv+ MO�c Lp I 7WiMlp _--_-_—_ w1Or:1.p PtrnpeeYtat11001�DE7e�fea Mew 0.7, -j--s.:4--:^-' I �ne.caatt 10000 1111,-,---;-;--3- ._._ !!� ...,,,_ . i . PLU▪M*ME rrinav-CIO DITERMAL arm RATIO -SWIM tease u MMPI ✓rrr 7600 1 Y— aacu mcCO Pairs r -+au dne� d77:P716 e 5000 2.00 3.00 400 550 5.00 750 0.00 050 100 11.00 1200 NM w 'A Mark of Schlumberger 6i2,za06 „ . a -. -.... — r- \1 ,— rii S-11 .6, 0 r , , , ; ' ''' i --I, i 1 .....•-- - to Walk [latti [) [/).4-1,0G _._ b).44. 1 „. .. e...1 4 . 4... .' ' '11 1# Q; ill 2 '1 r ,i, , ....... _____.....- _.,,,,..„,,,„,..6,4 i-il frpilal F no be=sty wrsimegve ut f`l j , . / , ft U ig,.1 U; i ti kt.1 —-..... The phototreib 111” - Pkute. , ....... .... - — --ailaill. • ',sm.., e -- ..- ' , APPL1CATWW8 up to 5-bblinlin illillhom.:1 11111111 I - AMEN ME „ a Blends endrif.u.unPs with frectwing -;70_tato pads* wil...wp'l'ik 4,, * " A"' , :- L ,,.'.1;ItION,tr.• ' -'- 1, ------- a controls Seld "in , - .:: . s •It- , 3,„ , i designated mode siiill -i... '''' ' , ' ' ''' • system ,,,,,,,,,,i-:44- .... ° Rues In fig a 'dad bYergersthr°rpm ' ''.:/ *eir)i.rr- e•fr '''`'1*.i ''''''''''*41 '''' ''''' Zi'TT. setookaa Pm" :;3)4, ' ,- ! FraccAr tar tem" '•4, ‘4 -'1 MrnUniCiteS*41.1 a CO , 4 4 control ,0, ,- ,-.,- '' •eo, -.' i ,s, - -4:*" " °-.,-.1.. ..7::5'. ' 11 I/ seed engine Opdnwm , 4 , si 4110-bhp--- Density) 1 • o (Pmenuareebb ,,,..,•,n, system coinputer . mow tr-40,4'4,,t t - .4 ' ,y machatdcalIV-deven for ' ' ' ''*- =woe . mate) • -••••.. DiatithubIdaParabe"with 4. automated . Myna a DNV 2.74 terekdAdd fuderwith ® Integrate°Dila feed SergW13 service flied traeledeg • intershootlea Sta • „moo . of fracturing fbartenier . low poosiendsl Skid. ire stud as hbVese" the a P process glee Se5"0/4Steelletivi . POD Blender • 14)0 preciselycattreis .., on noR.D14 Stimulation of blaming end PeeTing Density)computer • • both ramp end ° suede^ The is bis omen rim PlaPPen hder which (Programmable°Pram" the entire Pb m bis POD 11W014/144 d Re - - se edues Murry.The ru...uvt-at designated r and does denoidaeleveletia intichwhe sod to liquid''''''' ganiMiXe to add the , ,,„modes. Plifiki 1S-bbifinik not required ' , to Jos=nn.n.a..,,,,,emsnalossin stair--r it ihve.. ,,mixer, augeris The maxillun Das menvon'op to nd added from PPCK Iant because . r of 441 Ted by thsProP12_ pressure is 1pa" re amountk....,,,okse are PM" dinsibmwredeective PSI"az° 1 dn11°):aeonimbeelrgeedndatenr averaging consists nA ad oftub.integralewpr8.:f°ryi..17eleidd. mixer"T`"- ttet-ce sand hopper. ' A email thenb. from I the slurry . l engine. I Ala 0D-bhp Mese wsibs°°m. ,,, se, ,,„names =mark of•••c•• ,,,vaviroduct,and durs comght0 Niel comPonY'P of um!respective rreversedAI Mint 212 the PWIMI7sc,wribiner 2 i 'BS- 14 SU tri.: u[gtton Skid General Specifications Engin Detroit Diesel`Series 80 8083MK74,400 bhp at 2,100 rpm Fuel Consumption 20.8 galUS/h 78 Lfi Hydraulics Parke?PAVC variable displecemergbed-sensing symem Skid EN 10025 carbon steel fame construction Skid lcamhined) Lwngtb 225.5 in 5.728 nun Width 72 in 1,829 min Height 1841:pia8) 10281 2,593 mm Height loperationai,bandrais 132 in 3,353 mm WeiDntW WI 24,200 Run 11.000 kg MaryiiydmWcs 18 gal US/min at 137.9 bar 88.141Anin at 2,080 psi Fuel Capacity 00 gef1S 2111. Vortex Mbar Sand Gate Type Integral Maximum Discherge Presage 100 psi 8.8 bar Maximum Send Rata 8.000 Nm/rain 4.010 kg/min Maximum Slurry Rate 35 bblhni n 5.884limb' Inlet Connection Ban WECO•FIGM6 Winged-Male Sub(1l Oudot Connocdons 4-in WECO F10208 Female Snb 13) Additive System Dry Add 11) 0.0191o11.780itr/min 540to21,700cm'/aiu PnepNETfiber FeeMu J 101o20061/min 45to80.7kg/min Other Gouges Available Dual-scale or user-cenbgurabb bonen metric aad imperial unite,e.g.,Vokogseva.flowmster CcntfOl System Distributed microprocessor-canto8ed swam Cooing System Standard radiator(i) Skid CerdSed offshore skid designed to DIN 2.74 Ambient Rating nip 118 depF -5 to 4 degC CwrMioaWna Crab Frame Cerdticetion DIN 2.7-3 Engine btisebn Certifications US EPA Non-Road Tar 2 EURO Non-Road Stage II IMO MARPOL 73/78 Amex VI 'Mark el Schlumberger Other com a !t# c+M1W+ .1r1b.COM A nr.product,end service names are the properties et their respective owners. Copyright02015 SthkrmDerger.AN rights reserved. , V1.D 12 Mer 2015 � � 7 r-..-r,-,1.4,-,3, r y� RU 5B Sundry Application,Geology 2A 71/1 3W 1111 58 All wells within% mile radius of RU-5B. API Well Name Well Type Status Zone open to Production/ Injection 50733205130000 Redoubt Unit 5 Producer P &A Hemlock(upper, middle, lower) 50733205130100 Redoubt Unit 5A Producer P&A Hemlock(upper, middle, lower) 50733205130200 Redoubt Unit 5B Producer Shut In Hemlock(upper, middle, lower) & West Forelands 50733205010000 Redoubt Unit 2 Producer P &A Hemlock(upper, middle, lower) 50733205010100 Redoubt Unit 2A Producer Active Oil Hemlock(upper, middle, lower) Producer Table of Well Name, Status, and Type within a '/A mile radius of RU-5B. Well Head Location: Section 14,T. 7 N., R. 14 W., S.M., 1,909' feet from the south line and 318'feet from the east line. The RU 5B well bottom hole location is within section 19, T. 7 N., R. 13 W., 1692'feet from the south line and 674' feet from the west line. The top of the Hemlock formation productive zone is 1731' feet from the south line and 66'from the west line of Section 19. The Tie in Point is 2,573' from the south line of Sec 24, and 1258'feet from the east line. CIE is planning to install a permanent bridge plug over the West Foreland formation and Lower Hemlock formation to isolate and produce out of the Upper and Middle Hemlock. ✓ Fttrif4411, til / I % ''rel ''' o1 of t moi - E )21 �` / "' ,,,,,,,,. ..,........ )7 h., , ,• e / ,° % , 441114\ 4; 1 4, .. . .k ...000,,t. , ,„ ,,,, ' - , , _.... , A .7..„..„ ir 41, i CP 7! rsit s J to s Faults and Fractures in''/:mile radius of RU-5B with all Redoubt field wells. Structural Geology: The RU-5B well was designed to penetrate near mid-structure in the southern fault block. The RU-5B location is up-dip of the RU-3A injector and is positioned structurally higher than the injector to capture and produce oil being water flooded from the down-dip injector. It is interpreted to be in the up thrown block of a NE-SW striking normal fault. The well is situated in the hanging wall of a West thrusting reverse fault bounding the Western edge of the field. Structural dips should be flat to dipping Southwest at low dip angle. This operation will be done in the existing wellbore of RU 56. No faults will be intersected by any wellbore within the estimated fracture wings of—143-282' horizontally or vertically. The Oligocene Upper and Middle members of the Hemlock formation are the primary reservoir targets of this fracture stimulation and can be broken into 4 intervals: Upper, Clay/Silt Zone, Middle and Lower Hemlock. The Miocene lower Tyonek formation overlays the Oligocene Hemlock reservoir which overlays the Eocene West Foreland Formation. There is a —15'thick carbonaceous shale at 11,936-11,950'TVD, 14,760-14,785' MD. Fracture modeling suggest that the expected fracture height is on the order of—121-174'with fracture wings lengths of —143-282'. The gross Upper,Silt, and Middle Hemlock interval in RU 5B is 528'feet thick. Mechanical properties have been modeled using Schlumberger's FracCADE program for shales and Hemlock Formation pressure gradients with depth. The Hemlock formation clean sandstone is estimated to have a fracture gradient in sandstones of 0.770 psi/ft and in situ stress from 9217 psi, a modeled shale fracture gradient of 0.943 psi/ft and in situ stress of 11308 psi in the shale. RU 5 B Well Log: G ALMS/ U 2 RIM 2 C;63 AMC n� •:R. C wax MI '-7 WPC 2OC'a) TK! D. 4 WI__. !SOWJ 4.:1 YO 12 RPM Iter Mali 1 "]20D _ . 1 .'-re, Upper Claystone/Carbonaceous Shale/Coal: ,,, 14,760-14,785' MD(11,936-11,950' TVD) MIEf 1111M1111111111 ,' _. Upper and Middle Hemlock —^---� 151,5 .4.... • A. t t l i11111 ii , Lower Hemlock "_ linill111111111111111111.11111H1111111c . -- -1 Lower Claystone/Carbonaceous Shale/Coal 15,532-15,557'MD(12,479-12,498'TVD) 1566, s/ _ IMITill._.. .. 111.11111MOMMLLILJA. 2111111111111111•6111111111111111111111111111 IIIIINIIIIIIIIIIIII Ii: 1 /' / Iv1 r': /bp•8 i 1 ... ,, y6b \ _________ a, y t i. D Fracture wing radius of 282' shown with blue circle around the RU-5B proposed location throughout the hemlock formation with the top at 14,786' MD, 11,952 TVD. Edge of fracture wings are 600' +from nearest faults. EXHIBIT A—LANDOWNERS, OWNERS AND OPERATORS Landowner Owner Operator As defined in As defined in As defined in AS 31.05.170(7) AS 31.05.170 10 20 AAC 25.990(46) Le_al Descri I tion State of Alaska Cook Inlet Cook Inlet ADL 381203 Energy, LLC Energy, LLC T.7N.,R.14W.,SEWARD MERIDIAN,ALASKA SECTION 13,PROTRACTED,ALL,640 ACRES; SECTION 14,PROTRACTED,ALL,640 ACRES; SECTION 23,PROTRACTED,ALL,640 ACRES; SECTION 24,PROTRACTED,ALL,640 ACRES; SECTION 25,PROTRACTED,ALL,640 ACRES; SECTION 26,PROTRACTED,ALL,640 ACRES. THIS TRACT CONTAINS 3,840 ACRES MORE OR LESS. State of Alaska Cook Inlet Cook Inlet ADL 374002 Energy, LLC Energy, LLC T.7N.,R.13W.,SEWARD MERIDIAN,ALASKA SECTION 19,PROTRACTED,ALL,615 ACRES; SECTION 20,PROTRACTED,ALL,640 ACRES; SECTION 21,PROTRACTED,ALL,640 ACRES; SECTION 28,PROTRACTED,ALL,640 ACRES; SECTION 29,PROTRACTED,ALL,640 ACRES; SECTION 30,PROTRACTED,ALL,617 ACRES; SECTION 31,PROTRACTED,ALL,619 ACRES; SECTION 32,PROTRACTED,ALL,640 ACRES; SECTION 33,PROTRACTED,ALL,640 ACRES. THIS TRACT CONTAINS 5691 ACRES MORE OR LESS. Contact Information: State of Alaska CERTIFIED MAIL 7015 0920 0002 1701 0157 Department of Natural Resources Alaska Division of Oil and Gas 550 W 7th Avenue, Suite 1100 Anchorage, AK 99503 907-269-8800 Cook Inlet Energy, LLC CERTIFIED MAIL 7015 0920 0002 1701 0164 601 W. 5th Avenue, Suite 310 Anchorage, AK 99501 907-334-6745 EXHIBIT B - WELLS WITHIN % MILE RADIUS OF PROPOSED OPERATION T. 7N., R. 14W., S.M. T. 7N., R. 13W., S.M. --,N41\r„ 2 7N/13W % mile - 5A EXHIBIT C -NOTICE OF OPERATIONS GLACIER March 7,2017 CERTIFIED MAIL Landowners,Owners and Operators See Distribution List West Foreland Area Cook Inlet Basin,Alaska Re: Notice of Operations under 20 AAC 25.283 of Cook Inlet Energy,LLC's Sundry Application for a Fracture Stimulation for the RU 5B Well Dear Landowner,Owner and/or Operator, Cook Inlet Energy,LLC,a Glacier Oil and Gas company(GLA)is applying for a Sundry Application under 20 AAC 25.283 to perform a fracture stimulation of the RU 5B well.This Notice is being sent by certified mail to meet the notification requirements under 20 AAC 25.283(ax 1 XA)and 20 AAC 25.283(ax1 XB). The complete application is available for review upon request.If you wish to review the application,please contact Tim Jones,Senior Landman,at the following: Tim Jones Senior Landman Glacier Oil and Gas Corp. 601 W.5th Avenue,Suite 310 Anchorage,AK 99501 Direct:907-433-3811 tjones®glacieroil.com GLA,through a search of the public record,has identified you as a Landowner,Owner or Operator(as defined in AOGCC regulations)within'%mile ofthe proposed RU 5B well trajectory and fracture stimulation.Please contact me should you require additional information. S' y, Tim'• es Seniu .,dman Distribution List:Alaska Division of Oil and Gas Cook Inlet Energy,LLC 601 W 56 Ave.,Suite 310,Anchorage,AK 99501 RU 5B Well Fracture Stimulation March 7,2017 EXHIBIT D Affidavit State of Alaska, Third Judicial District Personally appeared before me, Timothy Jones,who, being duly sworn according to law, deposes and says: 1. I, Timothy Jones, am a Senior Landman for Cook Inlet Energy, LLC and a Registered Professional Landman#84167. 2. The Landowners, Owners and Operators, as defined in relevant state statutes and regulations, identified in Exhibit A are correct to the best of my knowledge. 3. The well location in Exhibit B was taken from Cook Inlet Energy, LLC's Permit to Drill submitted to AOGCC. 4. The Notice in Exhibit C was sent to the Landowners, Owners and Operators identified in Exhibit A by certified mail. Further the affint sayeth naught. 1 r . , 3/7/0 Timothy Jo d. Date RPL#84167 UNITED STATES OF AMERICA § STATE OF ALASKA § Subscribed and sworn to before me on the day of March,2017. OFtItL1ICAL SEA ,,� ty Hooper /r 1 e r *' Notary Public-State of Alaska a ,,y MM Commission Expo 8/28/2020 Notary Public My commission expires: b- 2- Schwartz, Guy L (DOA) From: Stephen Ratcliff <sratcliff@glacieroil.com> Sent: Monday, April 24, 2017 4:26 PM To: Schwartz, Guy L(DOA) Cc: Amanda Dial;Conrad Perry; Leland Tate; Stephen Ratcliff Subject: Frac Sundries - RU-01A, RU-03A, RU-OSB Guy, Per our discussion, please move forward on the approval process for RU-03A Frac Sundry. We will, however,withdraw the Frac sundry requests for RU-05B and RU-01A at this time. Thanks and let me know if you have any questions. Regards, Stephen Ratcliff Glacier Oil and Gas Corporation 601 W.5th Avenue,Suite 310 Anchorage,AK 99501 O-(907)433-3808 C-(907)433-9738 1 STATE OF ALASKA AOIL AND GAS CONSERVATION COM ION REP RT OF SUNDRY WELL OPER IONS 1.Operations Abandon LJ Plug Perforations Li Fracture Stimulate Li Pull Tubing Lf Operations shutdown LJ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill Cl ;rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Set Packer,Run Tubing ❑., 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: COOK INLET ENERGY,LLC Development ❑., Exploratory ❑ 213-107 3.Address: 601 W 5TH AVE SUITE 310,ANCHORAGE, Stratigraphic❑ Service ❑ 6.API Number: AK,99501 50-733-20513-02-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 381203,ADL 374002 REDOUBT UNIT#5B 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A REDOUBT SHOAL,Undefined Oil 11.Present Well Condition Summary: Total Depth measured 15750 feet Plugs measuredN/A f C E I V E D true vertical 12661 feet Junk measured 11082 feet FEB 2 2 2017 Effective Depth measured 15653 feet Packer measured 1661 feet�, �w� true vertical 12579 feet true vertical 1615 fee jam.' Casing Length Size MD TVD Burst Collapse Structural 200' 30" 200' 200' N/A N/A Conductor 3190' 13 3/8" 3190' 2940' 5020 psi 2260 psi Surface 11500' 9 5/8" 11500' 10065' 6870 psi 4760 psi Intermediate 1638' 7 5/8" 12928' 10862' 6890 psi 4790 psi Production Liner 4703' 5 1/2" 15740' 11037' 7740 psi 6390 psi Perforation depth Measured depth 14786-15386 feet y {? True Vertical depth 11952-12366 feet OD MAR 2 O La l`, Tubing(size,grade,measured and true vertical depth) 3 1/2" P110 1855'MD 1786'TVD Packers and SSSV(type,measured and true vertical depth) 9-5/8"Storm Pkr No SSV 1661'MD 1615'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 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 Q Gas U WDSPL U Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-012 Contact Stephen Ratcliff Email sratcliff@glacieroil.com Printed Name Stephen Ratcliff Title Sr.Drilling Engineer Signature Yk— \ Phone 907-433-3808 Date 2I 22 1 it Form 10-404 Revised 5/2015 Submit Original Only • • GLACIER February 22"d, 2017 Ms.Cathy Foerster, Chair EC Alaska Oil and Gas Conservation Commission E 333 West 7th Ave.,Suite 100 FEB Anchorage,Alaska 99501 2 2 201? Gce`` Re: Report of Sundry Cook Inlet Energy, LLC: RU-05B Permit to Drill NO:213-107 API No:50-733-20513-02-00 Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a Report of Sundry Well Operations for RU-05B. The work performed was covered under Approved Sundry 317-012 for pulling the ESP completion and setting a packer and kill string. If you have any questions, please contact me at(907)433-3808. Sincerely, Stephen Ratcliff Sr. Drilling Engineer Cook Inlet Energy, LLC(a Glacier Oil&Gas Corp.owned company) 601 W.5th Avenue STE 310 Anchorage,AK 99501 10-404 • • GLACIER RU-05B Daily Operations Summary API: 50-733-20513-02-00 Permit #: 213-107 Rig: Osprey Rig 35 Date and Footage Drilled as of 24:00 hours. Activity 23 January 2017 Prep to skid rig and take well from production. Line up to circulate well for kill. Pump produced water. 24 January 2017 Continue to circulate and kill well. Skid rig. 25 January 2017 Finish skidding rig. Rig up and pump 9.8ppg OBM down tubing, up annulus. 26 January 2017 Continue circulate OBM, monitor pressures to zero. Set BPV and ND tree. NU BOPE. Pressure test BOPE to 250 psi low,4500 psi high. Test witnessed by AOGCC Rep, Matt Herrera. 27 January 2017 Finish BOPE test.Clean pits. 28 January 2017 Build kill fluid. Repair and test manual choke valve.Observe well—well static. Pull BPV. MU Landing joint, pull on hanger. Packer would not unseat, work pipe to relax packer. 29 January 2017 Continue to work pipe to release packer, packer released.Circulate 8.7ppg brine at 3bpm—monitor well. LD hanger. Pull 3-1/2" completion, LD SSSV and Packer. MU top drive into string and circulate 8.7ppg KCL through choke. 30 January 2017 Continue to circulate through choke. Observe well—static.Connect ESP cable to spoolers and POH laying down 2 7/8" ESP Completion. 31 January 2017 Continue POH with 2 7/8" ESP Completion. Determine ESP Pump assembly parted at ESP Pump Discharge Head. RU slickline and RIH with impression block.Tag at 11082'. RD slickline. RIH with 31/2" PH6 tubing and packer. 01 February 2017 Continue RIH with 9-5/8" packer on 3-1/2" 12.95#P110 PH6 tubing. Set packer at 1661'with tubing tail at 1855'. Land hanger. Test packer and annulus to 1500 psi—good. LD landing joint. RU slickline and RIH. Set Plug in R Nipple at 1769'. Set BPV and ND BOPE. NU Dry hole tree. Rig Release. • RU-05B:Current Wellbore Schematic Version: Current II 1/30/2017 il' ' GLACIER Tubing Hanger-3 1/2"RTS-6-ID 2.682" [Al - .. lir' 9-5/8"x 3-1/2"Storm Packer @ 1661'MD R Profile @+/-1769 MD ti 3 1/2"12.95#P-110 PH6 Tubing-ID 2.625"1/1855 MD 13 3/8" 68#L-80 3,190'MD 18 1/2"Hole ID-12.25" BTC 2,940'TVD t5 F/ft W'. `y. TOL @ 11,037'MD(9 5/8"x 5 1/2") ', _ Fish-ESP Assembly-tag @ 11082'MD • TOL @ 11,290'MD(9 5/8"x 7 5/8") y 9 5/8" 47#L-80 _ 11,500'MD 12 1/4"Hole A _a ID-8.50" BTC 10,065'TVD Window 7 5/8" 29.7#L-80 12,928'MD 8 1/2"Hole . . ID-6.75" BTC 10,862'TVD TOC @ 13,710'MD(CBL 9/17/2013) a Perforations:3-3/8"6 SPF MD TVD Feet . 14,786-14,848 11,952-11,989 62 - 14,862-14,880 11,997-12,009 18 FAY -n 14,888-14,915 12,014-12,030 29 flims 14,922-14,928 12,035-12,038 6 11 14,956-14,965 12,057-12,063 9 -- 14,972-14,988 12,068-12,079 16 15,008-15,018 12,092-12,098 10 15,116-15,140 12,166-12,183 24 II 15,171-15,184 12,206-12,215 13 15,265-15,272 12,274-12,280 7 0 Itgl 15,304-15,326 12,303-12320 22 631 to yy III 15,356-15,362 12,343-12,347 6 I� 111 15,378-15,386 12,360-12,366 8 JIM Flll�tl Total Perforations 230 =k I 1111j 5 1/2 17#L-80 15,740'MD 6 3/4"Hole ID-4.767" BTC 12,653'TVD *...,\ ?it, •s9 THE STATE Alaska Oil and Gas ti � � o LAsKA. Conservation Commission i,,,,, ti '# i� 333 West Seventh Avenue��,"�'2 `. GOVERNOR BILL WALKER �� Anchorage, Alaska 99501-3572 ;; ` Q. Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Stephen Ratcliff Sr. Drilling and Completion EngineerMAR 2 s nil Cook Inlet Energy, LLC SCONE° 601 W. 5th Ave., Ste. 310 Anchorage,AK 99501 Re: Redoubt Shoal Field,Undefined Oil Pool, RU 5B Permit to Drill Number: 213-107 Sundry Number: 317-053 Dear Mr. Ratcliff: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 731- 51.4,4'AA-- Cathy P Foerster Chair DATED this �J day of February, 2017. RBDMS t k-- - d - 7 2017 G4Ci1/C6? • STATE OF ALASKA • fr�AN 213/i ALASKA OIL AND GAS CONSERVATION COMMISSION ,A APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑✓ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Pull Packer,Run ESP 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: COOK INLET ENERGY,LLC Exploratory ❑ Development ❑✓ . 213-107 • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 601 W 5TH AVE SUITE 310,ANCHORAGE,AK,99501 50-733-20513-02-00 , 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No ❑., / REDOUBT UNIT#5B . 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 381203,ADL 374002 • REDOUBT SHOAL,UNDEFINED OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 15,750'MD ' 12,661' . 15,653' . 12,579'. 2764 psi NONE NONE Casing Length Size MD TVD Burst Collapse Structural 200' 36" 200' 200' Conductor 3190' 13 3/8" 3190' 2940' 5020 PSI 2260 PSI Surface 11500' 9 5/8" 11500' 10065' 6870 PSI 4760 PSI Intermediate 1638' 7 5/8" 12928' 10862' 6890 PSI 4790 PSI Production __ -- __ -- Liner 4703' 5 1/2" 15740' 11037' 7740 PSI 6390 PSI Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 14786'-15386' • 11952'-12366' Planned:3 1/2"9.3# Planned:L80 Planned: 1750'MD Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Planned:Storm Packer Planned:Packer at 1500'MD/1468'TVD 12.Attachments: Proposal Summary U Wellbore schematic Q 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: 15-Feb-17 Commencing Operations: OIL ❑., • WINJ ❑ WDSPL ❑ Suspended ❑., 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Stephen Ratcliff Email sratcliff@glacieroil.com Printed Name Title Stephen Ratcliff Sr.Drilling&Completion Engineer Signature <-e--S1.--- Phone Date "--A 907-433-3808 30 -"sw a - 2.0\7 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Q Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ p5 F 2_1-5 I '•. Other: 3 500 /n5- t_)'-'26/‘' 731-1-- Post Post Initial Injection MIT Req'd? Yes ❑ No ❑ _ 7 2017 Spacing Exception Required? Yes ❑ No V Subsequent Form Required: )(?-y Q RBDMS L " eAPPROVED BY Approved by: 7' ' (l.___., COMMISSIONER THE COMMISSION Date: 2 -3 . ( 7 0 Riteipto Submin Form ane Form 10-403 vised 1112015 valid for 12 months from the date of approval. Attachments in Duplicate fg 4113-- 2.- -- 17 deZ72-/( 7 • • . < RECEIVED GLACIER JAN 302017 January 30th, 2017 AOGCC Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry: RU-05B— Application to Run ESP Completion Cook Inlet Energy: 50-733-20513-02-00, PTD: 213-107 Dear Ms. Foerster, Cook Inlet Energy, LLC, hereby submits an Application for Sundry Approval for Redoubt Unit 05B, PTD: 213-107, requesting permission to run the ESP completion. If you have any questions, please contact me at 907.433.3808. Sincerely, \\ Stephen Ratcliff Sr. Drilling& Completions Engineer Cook Inlet Energy, LLC (a Glacier Oil & Gas wholly owned company) 601 W. 5th Avenue STE 310 Anchorage, AK 99501 1 • . < • GLACIER 1. WELL NAME— RU-05B Requirements of 20 AAC 25.005(f) Well Summary Current Status: The well is shut-in due to a failed ESP. r Scope of Work: • Rig up Rig 35 & NU BOPE 3i7_&Z" • Pull Storm Packer and kill string. • RIH with ESP Completion. • N/D BOPE. • Turn well over to production. General Well Information: Reservoir Pressure/TVD: 0.32 psi/ft 4,000 psi @ 15,386' MD (12,366' TVD) MASP: Reservoir Pressure— (Gas Gradient X TVD) (0.32 psi/ft X 12,366' TVD)— (0.1 psi/ft X 12,366') = 4,000 psi — 1236 psi = 2,764 psi Wellhead Type/Pressure Rating: 13 5/8" 5M Wellhead - 3 1/2" 5M tree BOPE: 13 5/8" 10M —Pipe Rams/ Blind Rams/Annular Well Type: Oil Well Estimated Start Date: February 15, 2017 Waivers Requested: None CIE Drilling Manager CIE Sr. Drilling Engineer CIE Production Manager Conrad Perry Stephen Ratcliff David Kumar (907) 727-7404 (907) 433-3808 (907) 433-3822 cperry@glacieroil.com sratcliff@glacieroil.com dkumar@glacieroil.com 2 • GLACIER Program Rig Workover General Note: Prior to this work, the plan is to run approximately 1750' of 3 1/2" tubing currently in the well and set a Storm Packer at +/- 1500' MD. SLt wo y 3/1-v!L General Note: Full opening Safety Valve will be on rig floor at all times with appropriate crossovers for all pipe being run below rotary table. 1. Move rig onto RU-05B. 2. Check for pressure and note pressure in tubing and in annulus. 3. Notify AOGCC 48 hours in advance of start of operations and upcoming BOP test. 4. N/D Dry Hole Tree. 5. N/U and Test 13 5/8" BOPE with 2 7/8" x 5" VBR rams with blinds in middle. 6. Test BOPE on 2 7/8" and 3 %2" to 250 psi low/,3500 psi high and chart. 7. Remove back pressure valve. &PV 8. P/U Landing Joint and make up to 4 1/2" Tubing Hanger. 9. Back out Lock Down screws in Tubing Hanger. 10. Pickup with straight pull to release storm packer at 1500' MD. 11. Pull & L/D Landing Joint and Tubing Hanger. 12. Check for Flow and confirm well is dead. 13. POH and L/D 3-1/2"tubing and storm packer. 14. Prep to pick up ESP Completion equipment, spoolers, and tools. 15. Rig up Summit for ESP Completions. o Hold PJSM for ESP Run. o Test and confirm that all equipment is on location and ready to RIH. o NOTE: COMPLETION ESP/TUBING WILL NOT BE ROTATED. 16. Pick up the ESP completion assembly as directed. o NOTE: Setting depth of ESP BHA at 14,465' MD (Confirm with GLA Engineer prior to RIH). p o Pump should be set in less than 1 degree/100' dogleg. (Top of Pump Assy tentatively set for +/- 14,340' MD). o NOTE: the 3/8" flat pack chemical injection line is to be run to the anode on the bottom of the ESP assembly. 3 • GLACIER o 3/8" Nova Valves to be installed at top of pump assembly. 17. RIH with ESP completion on 3-1/2" 9.3# L80 EUE & 2-7/8" 6.5# L80 EUE tubing. o Test cable every 1000'. o Crossover from 3-1/2" to 2-7/8" tubing at +/- 10,000'. 18. Install ESP packer, vent valve and SSSV assembly. Test cable every 1000'. o 3/8" control lines run independently from vent valve to surface and SSSV to surface. 19. Set Packer at 500' MD. V 20. Monitor trip tank for proper hole filling. Splice cable as needed. At TD, confirm pipe tally, MU landing joint and set string in slips. 21. Dress hanger and control lines. Land hanger, run in screws, test hanger to 5000 psi. 22. Test Annulus above packer to 2000 psi. 23. Observe well dead. Lay down landing joint and install BPV. 24. Nipple down riser and BOPE. 25. Install and test production tree to 5,000 psi. Turn over well to production. 26. Release Rig. 4 S RU-05B Planned:Current Wellbore Schematic • Version: Planned 1/30/2017 . < Tubing Hanger-3 1/2"RTS-6-ID 2.682" GLACIER I 3 1/2"12.95#P-110 PH6 Tubing-ID 2.625"t11750'MD 1 I 4-----------9-5/8"x 3-1/2"Storm Packer w/2.567"R-profile or 2.329 Profile @+/-1500'MD . 13 3/8" 68#L-80 3,190'MD 18 1/2"Hole ID-12.25" BTC 2,940'TVD t TOL@ 11,037'MD(9 5/8"x 5 1/2") TOL @ 11,290'MD(9 5/8"x 7 5/8") 9 5/8" 47#L-80 11,500'MD 12 1/4"Hole , ID-8.50" BTC 10,065'TVD Window 7 5/8" 29.7#L-80 12,928'MD 8 1/2"Hole ' ID-6.75" BTC 10,862'TVD TOC @ 13,710'MD(CBL 9/17/2013) • Perforations:3-3/8"6 SPF MD TVD Feet 14,786-14,848 11,952-11,989 62 14,662-14,880 11,997-12,009 18 m ICC m 14,888-14,915 12,014-12,030 29 14,922-14,928 12,035-12,038 6 14,956-14,965 12,057-12,063 9 14,972-14,988 12,068-12,079 16 15,008-15,018 12,092-12,098 10 37 15,116-15,140 12,166-12,183 24 15,171-15,184 12,206-12,215 13 15,265-15,272 12,274-12,280 7 m m 15,304-15,326 12,303-12320 22 CIO It= 15,356-15,362 12,343-12,347 6 15,378-15,386 12.360-12,366 8 Total Perforations 230 ms m MI rn j11 lihi 5 1/2 17#L-80 15,740'MD 6 3/4'Hole ID-4.767" BTC 12,653'TVD • RU-O5B Proposed Wellbore Schematic Version: V1.0 24-Jan-17 Tubing Hanger-ACME 3.725'MCA top connection/ GLACIER 3 1/2"RTS-6 btm connection-ID 2.682" 3 1/2"9.3#L80 EUE Tubing-ID 2.992"t/330'MD 3-1/2"SSSV-ID 2.992"@ 300'MD 3/8"Stainless Line N 1"Vent Valve @ 500'MD/500'TVD 1, c r TriPoint 9 5/8"Hydroset II ESP Dual Packer @ 500'MD 3 1/2"X-Nipple-ID 2.813" • 13 3/8" 68#L-80 3,190'MD 18 1/2"Hole ID-12.25" BTC 2,940'TVD t )CO-3 1/2"x 2 7/8"Tubing @ 10,000'MD/8,756'TVD TOL @ 11,037'MD(9 5/8"x 5 1/2") TOL @ 11,290'MD(9 5/8"x 7 5/8") A 0. . 9 5/8" 47#L-80 11,500'MD 12 1/4"Hole 4 , ID-8.50" BTC 10,065'TVD 2 7/8"6.5#L80 EUE Tubing-ID 2.441"f/14,332'- 10,000'MD Window 7 5/8" 29.7#L-80 12,928'MD 8 1/2"Hole ID-6.75" BTC 10,862'TVD TOC @ 13,710'MD(CBL 9/17/2013) ESP Pump Assembly Top of Discharge Head @ 14,332'MD/11,678'TVD u � L.11pa�, Lv" ill ` Bottom of ESP Assembly @ 14,465'MD Perforations:3-3/8"6 SPF MD TVD Feet 14,786-14,848 11,952-11,989 62 _ 14,862-14,880 11,997-12,009 18 14,888-14,915 12,014-12,030 29 14,922-14,928 12,035-12,038 6 14,956-14,965 12,057-12,063 9 14,972-14,988 12,068-12,079 16 15,008-15,018 12,092-12,098 10 IC 15,116-15,140 12,166-12,183 24 15.171-15,184 12,206-12,215 13 15,265-15,272 12,274-12,280 7 15,304-15,326 12,303-12320 22 ICC 15,356-15,362 12,343-12,347 6 15,378-15,386 12,360-12,366 8 Total Perforations 230cue 1.1 51/2 17#L-80 15,740'MD 6 3/4"Hole ID-4.767" BTC 12,653'TVD or Tk .1.1" 1//7,•4.* THE STATE Alaska Oil and Gas fALAS�o Conservation Commission i-{ =�_ :- 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 SFA S� Fax: 907.276.7542 www.aogcc.alaska.gov Stephen Ratcliff SCANNED MAR 2 2 2017, Sr. Drilling Engineer Cook Inlet Energy, LLC 601 W. 5th Ave., Suite 310 Anchorage, AK 99501 Re: Redoubt Shoal Field, Undefined Pool, Redoubt Unit 5B Permit to Drill Number: 213-107 Sundry Number: 317-012 Dear Mr. Ratcliff: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. Foerster Chair DATED this (3y of January, 2017. RBDMS L `IAN 2 5 2017 • RECEIVED • STATE OF ALASKA Jp1 z 17 ALASKA OIL AND GAS CONSERVATION COMMISSION {- 1 ii, 1 APPLICATION FOR SUNDRY APPROVALS OG 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Run Tba,RBP a 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: COOK INLET ENERGY,LLC Exploratory ❑ Development ❑., , 213-107 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 601 W 5TH AVE SUITE 310,ANCHORAGE,AK,99501 50-733-20513-02-00 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 ❑i REDOUBT UNIT#5B 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 381203,ADL 374002 REDOUBT SHOAL, Undefined Oil J 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): fiTotal,l�epth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 15,750'MD 12 f9� 15,653' 12,579' 2764 NONE NONE Casing Lengthy�79Size MD TVD Burst Collapse Structural 200' 36" 200' 200' Conductor 3190' 13 3/8" 3190' 2940' 5020 PSI 2260 PSI Surface 11500' 9 5/8" 11500' 10065' 6870 PSI 4760 PSI Intermediate 1638' 7 5/8" 12928' 10862' 6890 PSI 4790 PSI Production __ __ Liner 4703' 5 1/2" 15740' 11037' 7740 PSI 6390 PSI Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 14786'-15386' ' 11952'-12366' 2 7/8"7.9# P110 14332' Packers and SSSV Type: Baker Twin Seal Packer Packers and SSSV MD(ft)and TVD(ft): , Packer @ 585'MD/583'TVD Baker TE5 3 1/2"SSSV , SSSV @ 330'MD/330'TVD 12.Attachments: Proposal Summary U Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program 2 BOP Sketch ❑i Exploratory ❑ Stratigraphic ❑ Development Li . Service ❑ 14.Estimated Date for /y 15.Well Status after proposed work: Commencing Operations: OIL ❑✓ ' WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Stephen Ratcliff Email sratcliff@glacieroil.com Printed Name Title Stephen Ratcliff Sr.Drilling&Completion Engineer Signature c� C-N Phone Date 907-433-3808 1/11/2017 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: O k2___J \� Plug Integrity ❑ BOP Test 217 Mechanical IntegrityCI Test ❑ Location Clearance Other: : L{S x pS.; /o -7-,-,-;F Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMS L(--- JAN Spacing Exception Required? Yes ii No No Subsequent Form Required: J L,_, ! t ;� 5 �Q�� 2,3 ,,,,,6___ APPROVED BY Approved by / COMMISSIONER THE COMMISSION Dater /3 -/ M �l�, Submit orm and Form 10-403 evised 11/2015 Approved application is vali n f e t of approval. Attachments in Duplicate • • GLACIER January 11th, 2017 RECEIVED Ms. Cathy Foerster, Chair JAN 11 2017 Alaska Oil and Gas Conservation Commission A,QGCC 333 West 7th Ave., Suite 100 AOGCC Anchorage, Alaska 99501 RE: Sundry: RU-05B— Application to Pull Completion Cook Inlet Energy: 50-733-20513-02-00, PTD: 213-107 Dear Ms. Foerster, Cook Inlet Energy, LLC, hereby submits an Application for Sundry Approval for Redoubt Unit 05B, PTD: 213-107, requesting permission to change the approved program under Sundry_316-544. The current ESP completion will be pulled, a retrievable bridge plug will be set and a short string of 3- 1/2" tubing will be utilized. If you have any questions, please contact me at 907.433.3808. Sincerely, Stephen Ratcliff Sr. Drilling & Completions Engineer Cook Inlet Energy, LLC (a Glacier Oil & Gas wholly owned company) 601 W. 5th Avenue STE 310 Anchorage, AK 99501 1 • < • • GLACIER 1. WELL NAME— RU-05B Requirements of 20 AAC 25.005(f) Well Summary Current Status: The well is shut-in due to a failed ESP. Scope of Work: • Rig up Rig 35 & NU BOPE • Pull ESP completion and tubing. • RIH with Retrievable Bridge Plug and set at 11,300' MD • RIH with 300' of 3-1/2" Tubing. • N/D BOPE & Secure well. General Well Information: Reservoir Pressure/TVD: 0.32 psi/ft 4,000 psi @ 15,386' MD (12,366' TVD) MASP: Reservoir Pressure— (Gas Gradient X TVD) (0.32 psi/ft X 12,366' TVD) — (0.1 psi/ft X 12,366') =4,000 psi — 1236 psi = 2,764 psi Wellhead Type/Pressure Rating: 13 5/8" 5M Wellhead - 3 1/2" 5M tree BOPE: 13 5/8" 5M — Pipe Rams/ Blind Rams/Annular Well Type: Oil Well Estimated Start Date: ASAP Waivers Requested: None CIE Drilling Manager CIE Sr. Drilling Engineer CIE Production Manager Conrad Perry Stephen Ratcliff David Kumar (907) 727-7404 (907) 433-3808 (907) 433-3822 cperry@glacieroil.com sratcliff@glacieroil.com dkumar@glacieroil.com 2 • • • GLACIER Program Pre-Rig 1. Conduct pre-job safety meeting with all personnel on location. o Review upcoming work and discuss safety first. 2. Lock out safety systems and power oil 3. Confirm that the SSSV is open. 4. Prep for Rig and Workover operations. 5. Ensure that well is dead. Rig Workover General Note: There is 3 %2" crossed over to 2 7/8" tubing currently in the well. General Note: Full opening Safety Valve will be on rig floor at all times with appropriate crossovers for all pipe being run below rotary table. 1. Move rig onto RU-05B. 2. Check for pressure and note pressure in tubing and in annulus. o Note: The Twin seal packer has a vent line from 585' MD. 3. R/U lines from tree and annulus to production if not done prior to rig move. 4. Check for flow and shut in well. ' ;rc wok 4-s 5. Place back pressure valve in wellhead. 47W Tu, 6. Notify AOGCC 48 hours in advance of start of operations and upcoming BOP test. 7. N/D Production Tree. 8. N/U and Test 13 5/8" BOPE with 2 7/8" x 5" VBR rams with blinds in middle. 9. Test BOPE on 2 7/8" and 31/2" to 250 psi low/4500 psi high and chart. 10. Rig up ESP spoolers and hardware. 11. Remove back pressure valve. 12. P/U Landing Joint and make up to 3 1/2" Tubing Hanger. 13. Back out Lock Down screws in Tubing Hanger. 14. Pick up with straight pull to release packer at 585' MD. o Max Pull not to Exceed 115,000 lbs • W/O Weight of Blocks 15. Kill well with 8.7 ppg produced water+ KCI, circulate wellbore volume. o Be prepared for circulating gas buildup below packer. o Track fluid volume to identify losses if they occur. 3 • • GLACIER • Have salt pill prepared if losses are identified. 16. Pull & L/D 3 1/2" Landing Joint and Tubing Hanger. 17. Check for Flow and confirm well is dead. 18. POH and LID the following: o 3 1/2" Tubing �'A o sssv a> \;^'7 o Twin Seal Packer with vent valve t $ o 2-7/8"Tubing o ESP BHA 19. Rig up E-line. 20. RIH and set Retrievable Bridge Plug at 11,300' MD. 21. Pressure test RBP to 1500 psi to ensure set. �-` ' 22. Rig down E-line. t A195 23. P/U 3-1/2" 12.95# P-110 PH6 tubing. 24. RIH to 300' MD. ,„ 25. M/U Landing Joint and set tubing string in slips. —(13-41 e)e 26. Land tubing hanger and test seals to 5,000 psi through test port. scoop-- 27. °'p27. L/D Landing Joint. 28. Set Back Pressure Valve o Observe that well is dead. 1,01\4r0 29. Nipple down BOPE. 30. Nipple up tree and test to 5,000 psi. 31. Secure well. (-/3-11 4 • • RU-05B Current Wellbore Schematic-10113/13 Version: Final October 13,2013 Cook Inlet Energy Tubing Hanger-3 1/2"RTS-6-ID 2.682" _ -��-3 1/2"12.95#P-110 PH6 Tubing-ID 2.625"1/330'MD L Baker 3-1/2"SSSV @ 330'MD i'- 4--- X/O F/3 1/2"to 2 7/8"Tubing @ 336'MD ; I k r Vent Valve @ 582'MD I TriPoint 9 5/8"Hydroset II ESP Dual Packer @ 585'MD E l €"4-� R Nipple @ 704'MD 13 3/8" 68#L-80 3,190'MD 18 1/2"Hole I ' , ID-12.25" BTC 2,940'TVD l ' TOL @ 11,037'MD(9 5/8"x 5 1/2") MN TOL @ 11,290'MD(9 5/8"x 7 5/8") 9 5/8" 47#L-80 11,500'MD 12 1/4"Hole it ID-8.50" BTC 10,065'TVD 2 7/8"7.9#P-110 BTS-6 Tubing-ID 2.229"f114,332'- 336'MD Window 7 5/8" 29.7#L-80 12,928'MD 8 1/2"Hole ID-6.75" BTC 10,862'ND 2 7/8"7.9#P-110 BTS-6 Tubing TOC @ 13,710'MD(CBL 9/17/2013) 44 j. `. �` Schlumberger ESP Pump Assembly 11 Top of Discharge Head @ 14,332 MD/11,678'TVD 1 Illi.: 1 , Bottom of ESP Assembly @ 14,465'MD Perforations:3-3/8"6 SPF MD TVD Feet 14,786-14,848 11,952-11,989 62 14,862-14,880 11,997-12,009 18 ` -• 14,888-14,915 12,014-12,030 29 Iy"' 14,922-14,928 12,035-12,038 6 j''jl,�', 11 14,956-14,965 12,057-12,063 9 14,972-14,988 12,068-12,079 16 82 .- 15,008-15,010 12,092-12,098 10 15,116-15,140 12,166-12,183 24El 15,171-15,184 12,206-12,215 13 - 15,265-15,272 12,274-12,280 7 15,304-15,326 12,303-12320 22 f 15,356-15,362 12,343-12,347 6 Il 15,378-15,386 12,360-12,366 8 i --- Total Perforations 230 5 1/2 : 17#L-80 15,740'MD 6 3/4"Hole l,. ID-4.767" BTC 12,653'TVD • RU-05B Proposed Wellbore Schematic Version: Planned - < 1/11/2017 GLACIER I I Tubing Hanger-3 1/2"RTS-6-ID 2.682" - 3 1/2"12.95#P-110 PH6 Tubing-ID 2.625"t/300'MD 13 3/8" 68#L-80 3,190'MD 18 1/2"Hole ID-12.25" BTC 2,940'TVD :lx TOL @ 11,037'MD(9 5/8"x 5 1/2") r - . C, . 5-1/2"Retrievable Bridge Plug @ 11,300'MD TOL @ 11,290'MD(9 5/8"x 7 5/8") 9 5/8" 47#L-80 11,500'MD 12 1/4"Hole / ID-8.50" BTC 10,065'TVD Window 7 5/8" 29.7#L-80 12,928'MD 8 1/2"Hole , , ID-6.75" BTC 10,862'TVD - TOC @ 13,710'MD(CBL 9/17/2013) Perforations:3-3/8"6 SPF MD TVD Feet 14,786-14,848 11,952-11,989 62 _ 14,862-14,880 11,997-12,009 18 m CON KG 14,888-14,915 12,014-12,030 29 14,922-14,928 12,035-12,038 6 14,956-14,965 12,057-12,063 9 IC 14,972-14,988 12,068-12,079 16 15,008-15,018 12,092-12,098 10 �S�` 15,116-15,140 12,166-12,183 24 'I 15,171-15,184 12,206-12,215 13 ES 15,265-15,272 12,274-12,280 7 m CO 15,304-15,326 12,303-12320 22 m m 15,356-15,362 12,343-12,347 6 15,378-15,386 12,360-12,366 8 Total Perforations 230 'mx m a m 5 1/2 17#L-80 15,740'MD 6 3/4"Hole ID-4.767" BTC 12,653'TVD OF 7' • • c \� Iyy�� THE STATE Alaska Oil and Gas Nv►'i �i� of Conservation Commission _ ALAS sf - __ 333 West Seventh Avenue 1. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 C4'41LAS1‘1* Fax: 907.276.7542 www.aogcc.alaska.gov Stephen Ratcliff N�En p 2 7 Sr. Drilling Engineer Cook Inlet Energy, LLC 601 West 5th Avenue, Suite 310 Anchorage, AK 99501 Re: Redoubt Shoal Unit, Undefined Oil Pool, Redoubt Unit#5B Permit to Drill Number: 213-107 Sundry Number: 316-544 Dear Mr. Ratcliff: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, • Cathy P. Foerster Chair DATED this VI day of October, 2016. REIMS t Y NOV - 1 2016 • STATE OF ALASKA • RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION OCT 2 0 2016 • APPLICATION FOR SUNDRY APPROVALS r�-s c 0 l�,!!",f��cc//6 20 AAC 25.280 AOG 1.Type of Request: Abandon ❑ Plug Perforations 7 Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ SuspendPerforate o0 5 p j ❑ Other Stimulate ❑ Pull� 2 Change Approved Program❑ Plug for Redrill 111 Perforate New Pool 111Re-enterSusp Well ❑ Alter Casing ❑ Other: Run Tubing I� 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: COOK INLET ENERGY,LLC Exploratory E Development I]., 213-107 ' 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 601 W 5TH AVE SUITE 310,ANCHORAGE,AK,99501 50-733-20513-02-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? j' .- Will planned perforations require a spacing exception? Yes ❑ No Dv 17)14 REDOUBT UNIT#5B , 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 381203,ADL 374002 REDOUBT SHOAL UA EJ iit.M.4 O Its 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 15,750'MD ,12,579' a 15,653' • 12,579' 2764 NONE NONE Casing Length Size MD ND Burst Collapse Structural 200' 36" 200' 200' Conductor 3190' 13 3/8" 3190' 2940' 5020 PSI 2260 PSI Surface 11500' 9 5/8" 11500' 10065' 6870 PSI 4760 PSI Intermediate 1638' 7 5/8" 12928' 10862' 6890 PSI 4790 PSI Production __ __ __ _ __ Liner 4703' 5 1/2" 15740' 11037' 7740 PSI 6390 PSI Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 14786'-15386' d 11952'-12366' 2 7/8"7.9# P110 14332' Packers and SSSV Type: Baker Twin Seal Packer Packers and SSSV MD(ft)and ND(ft): Packer @ 585'MD/583'TVD Baker TE5 3 1/2"SSSV SSSV @ 330'MD/330'ND 12.Attachments: Proposal Summary 2 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program Q BOP Sketch Q Exploratory ❑ Stratigraphic❑ Development 2 % Service ❑ 14.Estimated Date for 15.Well S t after proposed work: 10-Dec-16 � ' ❑ WDSPL , Commencing Operations: OIL WINJ ❑ Suspended 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Stephen Ratcliff Email sratcliff@glacieroil.com Printed Name Title Stephen Ratcliff Sr.Drilling&Completion Engineer Signature ..---1_..\) Phone Date 907-433-3808 10/20/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ICe —54{4E Plug Integrity ❑ BOP Test [ Mechanical Integrity Test ❑ Location Clearance 0 Other: t 0 f S,:- D(° - ) . S n °ri l✓oC ..{.`:1, d-, Hv co r,...,.,,,,L,,,.:,,.. s t ., > Le, Post Initial Injection MIT Req'd? Yes No SpicingSpving Exceptkion(2 q ? Yes ❑ No Subsequent Form Required: �® -'I CY-I -L- RBDMS (,v NOV - 1 2016 Pa APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date:l'O _ 1. G4 Submit Form and Form 10-40 evised 11/2015 CaleGpilintd for 12 months frog;the date of approval. w Attachments in Duplicate • • RECEIVED GLACIER OCT 20 2016 October 20, 2016 AOGCC Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry: RU-05B— Application to Pull Completion Cook Inlet Energy: 50-733-20513-02-00, PTD: 213-107 Dear Ms. Foerster, Cook Inlet Energy, LLC, hereby submits an Application for Sundry Approval for Redoubt Unit 05B, PTD: 213-107, requesting permission to pull the current ESP completion and run and cement 3-1/2" tubing in preparation for future stimulation activities. If you have any questions, please contact me at 907.433.3808. Sincerely, \\:\ Stephen Ratcliff Sr. Drilling& Completions Engineer Cook Inlet Energy, LLC (a Glacier Oil & Gas wholly owned company) 601 W. 5th Avenue STE 310 Anchorage, AK 99501 1 • RU-05B Current Wellbore Schematic-10/1 Version: Final _ Cook Inlet Energy_ • October 13,2013 Tubing Hanger-3 1/2"RTS-6-ID 2.682" 3 1/2"12.95#P-110 PH6 Tubing-ID 2.625"U330'MD Baker 3-1/2"SSSV @ 330'MD t '3 4 X/O F/3 1/2"to 2 7/8"Tubing @ 336'MD Yi 6 Vent Valve @ 582'MD TriPoint 9 5/8"Hydroset II ESP Dual Packer @ 585'MD R Nipple @ 704'MD 18 1/2"Hole I 13 3/8" 68#L-80 3,190'MD ID-12.25" BTC 2,940'TVD 1 � TOL @ 11,037'MD(9 5/8"x 5 1/2") TOL @ 11,290'MD(9 5/8"x 7 5/8") u' 9 5/8" 47#L-80 11,500'MD 12 1/4"Hole ID-8.50" BTC 10,065'TVD 2 7/8"7.9#P-110 BTS-6 Tubing-ID 2.229"f/14,332'- 336'MD Window 7 5/8" 29.7#L-80 12,928'MD 8 1/2"Hole ID-6.75" BTC 10,862'TVD 2 7/8"7.9#P-110 BTS-6 Tubing TOC @ 13,710'MD(CBL 9/17/2013) Schlumberger ESP Pump Assembly Top of Discharge Head @ 14,332'MD/11,678'TVD { I 1 ( Bottom of ESP Assembly @ 14,465'MD Perforations:3-3/8"6 SPF MD TVD Feet 14,786-14,848 11,952-11,989 62 14,862-14,880 11,997-12,009 18 Cf� 14,888-14,915 12,014-12,030 29 14,922-14,928 12,035-12,038 6 14,956-14,965 12,057-12,063 9 14,972-14,988 12,068-12,079 16 15,008-15,018 12,092-12,098 10 15,116-15,140 12,166-12,183 24 15,171-15,184 12,206-12,215 13 15,265-15,272 12,274-12,280 7 C'21 15,304-15,326 12,303-12320 22 t 15,356-15,362 12,343-12,347 6 15,378-15,386 12,360-12,366 8 Total Perforations 230 5 1/2 17#L-80 15,740'MD 6 3/4"Hole , ID-4.767" BTC 12,653'TVD . RU-05B-Interim Wellbore Schematic • Date: 18-Oct-16 Version: 1.0 • GLACIER Tubing Hanger-3 1/2"RTS-6-ID 2.682" 36" 150#A-36 200'MD ID-34.00" Welded 200'TVD\L. '41 13 3/8" 68#L-80 3,190'MD 18 1/2"Hole ` ID-12.25" BTC 2,940'TVD vl TOL @ 11,037'MD(9 5/8"x 5 1/2") TOL @ 11,290'MD(9 5/8"x 7 5/8") ■ o 9 5/8" 47#L-80 11,500'MD 12 1/4"Hole ID-8.50" BTC 10,065'TVD Dual 3/8"Stainless Flat Pack Lines Window 7 5/8" 29.7#L-80 12,928'MD 8 1/2"Hole ID-6.75" BTC 10,862'TVD 3 1/2"12.95#P-110 PH6 Tubing-ID 2.625"©15,645' MD TOC @ 13,710'MD(CBL 9/17/2013) 6 w.644 V -' Y Old Perforations:3-3/8"6 SPF MD TVD Feet 14,786-15,386 11,952-12,366 230 5 1/2 17#L-80 15,740'MD 6 3/4"Hole ID-4.767" BTC 12,653'TVD • GLACIER 1. WELL NAME— RU-05B Requirements of 20 AAC 25.005(f) Well Summary Current Status: The well is shut-in due to a failed ESP. Scope of Work: • Rig up Rig 37 & NU BOPE • Pull ESP completion and tubing. • RIH with 3-1/2" Tubing and cement. • N/D BOPE & Secure well. General Well Information: Reservoir Pressure/TVD: 0.32 psi/ft 4,000 psi @ 15,386' MD (12,366' TVD) MASP: Reservoir Pressure—(Gas Gradient X TVD) (0.32 psi/ft X 12,366' TVD) —(0.1 psi/ft X 12,366') =4,000 psi — 1236 psi = 2,764 psi Wellhead Type/Pressure Rating: 13 5/8" 5M Wellhead - 3 1/2" 5M tree t BOPE: 13 5/8"&IC/I —Pipe Rams/ Blind Rams/Annular Well Type: Oil Well Estimated Start Date: December 10, 2016 Waivers Requested: None CIE Drilling Manager CIE Sr. Drilling Engineer CIE Production Manager Conrad Perry Stephen Ratcliff David Kumar (907) 727-7404 (907) 433-3808 (907) 433-3822 cperry@glacieroil.com sratcliff@glacieroil.com dkumar@glacieroil.com 2 • GLACIER Program Pre-Rig 1. Conduct pre-job safety meeting with all personnel on location. o Review upcoming work and discuss safety first. 2. Lock out safety systems and power oil 3. Confirm that the SSSV is open. 4. Prep for Rig and Workover operations. 5. Ensure that well is dead. Rig Workover General Note:There is 3 %" crossed over to 2 7/8" tubing currently in the well. :, General Note: Full opening Safety Valve will be on rig floor at all times with appropriate crossovers a for all pipe being run below rotary table. 1. Move rig onto RU-05B. 2. Check for pressure and note pressure in tubing and in annulus. o Note: The Twin seal packer has a vent line from 585' MD. 3. R/U lines from tree and annulus to production if not done prior to rig move. 4. Check for flow and shut in well. 5. Place back pressure valve in wellhead. 6. Notify AOGCC 48 hours in advance of start of operations and upcoming BOP test. 7. N/D Production Tree. 8. N/U and Test 13 5/8" BOPE with 2 7/8" x 5"_VBR ramswith blinds in middle. Ai`' 9. Test BOPE on 2 7/8" and 3 %2"to 250 psi low/4500 psi high and chart. 10. Rig up ESP spoolers and hardware. 11. Remove back pressure valve. 12. P/U Landing Joint and make up to 3 1/2" Tubing Hanger. 13. Back out Lock Down screws in Tubing Hanger. 14. Pick up with straight pull to release packer at 585' MD. o Max Pull not to Exceed 115,000 lbs • W/O Weight of Blocks 15. Kill well with 8.7 ppg produced water+ KCI, circulate wellbore volume. o Be prepared for circulating gas buildup below packer. o Track fluid volume to identify losses if they occur. • Have salt pill prepared if losses are identified. 3 41/ 110 GLACIER 16. Pull & L/D 3 1/2" Landing Joint and Tubing Hanger. 17. Check for Flow and confirm well is dead. 18. POH and LID the following: o 3 1/2" Tubing o SSSV o Twin Seal Packer with vent valve o 2-7/8" Tubing o ESP BHA 19. P/U 3-1/2" 12.95# P-110 PH6 tubing. 20. RIH to 15,645' MD. Run centralizers as planned per cementing program. 21. RU Cementing equipment and test lines to 4500 psi. 22. Pump 15bbls of 11.5ppg Spacer, followed by 22 bbls of 16.5ppg Class G cement and displace with 127 bbls of 8.6ppg sea water. o113 rf (i . r Sy:`) 23. M/U Landing Joint and set tubing string in slips. 24. Land tubing hanger and test seals to 5,000 psi through test port. 25. L/D Landing Joint. L � . j,Jo 3Soo p$y 26. RD Cementing equipment. 27. Set Back Pressure Valve o Observe that well is dead. 28. Nipple down BOPE. 29. Nipple up tree and test to 5,000 psi. 30. Secure well. Separate Application for Sundry will be submitted for Stimulation Operations. Ce L 4-0 n..�-i fin. roc- c. - Tse /4- as-op /n•ZG Gc 4 0 1110 . GLACIER r-, — moo 1: ta ik A ill , 11111 , Lall". I I. /4 100374 Fia r rA 4 ,,1 FA SIC VL MOW ,.: VA:MR UM ill* yr Air., )47 IT 2 30 FT 2 11.4 114 (.:r i7firatieklitt = 14 iNrA I I 16..1 I r4 a d j .f , ,MN . .iir IIt' I-zct : ' A .. 7.--:::. .....: ..1416.411,i," . f IIIIIMI. . IltE FICTIA31 Cif RCM ..":...-, „„,' i ._ ..-- si- ,.... x I -. , r trr-,r X II var IVI!, I . ,,Z•e' - _,....-- DRILLNG RIG ARRANGEMENT -- EAST SIDE APPOi. DiX, --- VONHEIS limism. TINKIWA. • -. ... - DRILLAG RIG i—Tf..--Viiithia-- 6 • 11 GLACIER REDOUBT UNIT#7 WELLHEAD SCHEMATIC A 1 1 1 26.31' PR. jr�• .Ili. 3-1/8 5000 80.68' I'S ''"`?I Pk 3-1/8 5000 . ,.Il. 'Inrlpl. 1863" ; ~ n �, "' 13-5/8 5000 685 q iiN*- Pei 28.OD' ,11111/1-____ 5 liO OUT Of P05a 1 2-1/16 5000 N/YR 11 1111- Iii.'J!11m O13-5/8 5000 685 2-1/16 5000 N/Ki 24.75- Irl i.1 if* .1111i I,II - 1�1: JII 19.50" 11 36'00 CASNC 13-3/8'OD CASING 3-1/2 W WWI 9-5/8'00.CASINC ALL D6KNS10.G ARE APPROX. 7 • • • 114• GLACIER • 7,0111112 6.26-12104 BOP Schematic:key MI.Floor' NW:Mx Dow KB Elevation 0....J tYyei from 133a F7ote 1 Jap d Ammar • ., 1. 1L /ee.Jrr UMW — ��f 134Ir ill Aurwlat • M i 134fr111.Wail 413P saw I J.4r•o Jive a----, _..,..• • - -••�. lab l M J r� = gamer mania . .a��,a 11.4117 ✓.Tt NW 8YA U.. .ii ail ai, as ' 11 'I 92 ---+ MI l6 JJt1 • Chat.r into ,t-77 atir• -' 1teeD p1Jm — sio. : • _ v stria r a 1347•OK•4140nr>per• 13 .SK X 13 be SO.tamnrxovtw m ow.w Level VIIIIMMOIN I Canto.Loc11emi&woe l I I 1 •• J 1 i 8 • S • Schwartz, Guy L (DOA) From: Stephen Ratcliff <sratcliff@glacieroil.com> Sent: Monday,October 24, 2016 4:24 PM To: Schwartz, Guy L(DOA);Stephen Ratcliff Subject: Re: RWO to pull ESP and run Tubing RU 5B (PTD 213-107) Guy, After the frac,we will run a free point and then cut tubing at TOC. We will then run our ESP to+/-300'above the top of tubing. Sorry,didn't include that step on the last email. This will be the same for both wells. Regards, Stephen Ratcliff Senior Drilling&Completions Engineer/Superintendent Glacier Oil and Gas Corporation 601 W.5th Avenue,Suite 310 Anchorage,AK 99501 0-(907)433-3808 C-(907)433-9738 From:"Schwartz,Guy L(DOA)"<guy.schwartz@alaska.gov> Date: Monday,October 24,2016 at 4:22 PM To:Stephen Ratcliff<sratcliff@glacieroil.com> Subject: RE: RWO to pull ESP and run Tubing RU 5B(PTD 213-107) Stephen, Guess I am confused how you will run a ESP inside of 3'A"tubing. Are you going to cut and pull it above the TOC? Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITYNOTICE: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:Stephen Ratcliff[mailto:sratcliff@glacieroil.com] Sent: Monday,October 24,2016 4:20 PM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov>;Stephen Ratcliff<sratcliff@gIacieroil.com> Cc:Amanda Dial<adial@glacieroil.com>;Conrad Perry<cperry@glacieroil.com> Subject: Re: RWO to pull ESP and run Tubing RU 5B(PTD 213-107) Guy, 1 • Similar to my RU-01A email, no issue with running the CBL to identify the TOC. We can also test the backside to confirm that we have no communication. We will hold pressre on the backside during the frac so I would want to test this anyways. We will also run an ESP assembly after the frac. Note that it is our plan to include a packer,vent valve,and SSSV in the ESP completion. RU-01A and RU-05B will both be the same. Regards, Stephen Ratcliff Senior Drilling&Completions Engineer/Superintendent Glacier Oil and Gas Corporation 601 W.5th Avenue,Suite 310 Anchorage,AK 99501 0-(907)433-3808 C-(907)433-9738 From: "Schwartz,Guy L(DOA)"<guy.schwartz@alaska.gov> Date: Monday,October 24,2016 at 4:12 PM To:Stephen Ratcliff<sratcliff@glacieroil.com> Subject: RWO to pull ESP and run Tubing RU 5B(PTD 213-107) Stephen, In this RWO to run tubing and cement I have a couple of questions. 1.What is the final completion strategy after the frac stimulation? 2.Since this will be essentially a cement packer completion you will need to pressure test the new IA(3 122"x casing) and run a CBL to verify the TOC. 3.Your procedure does not include circulating or Bull heading KWF before pulling the tubing hanger and unseating vent packer. The vent should be open as long as there is hydraulic pressure to system allowing circulation past it. Reagrds, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guy.schwartz(e alaska.gov). 2 CCooookk IInnlleett EEnneerrggyy RRUU--55BB REDOUBT SHOALS Section 14 – T7N - R13W, SM Upper Cook Inlet, Alaska April 23, FINAL WELL REPORT Benjamin Handley – Logging Geologist TTyylleerr DDrreettkkee -- Logging Geologist Cook Inlet Energy RU-5B 2 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT AND CREW.................................................................................... 3 1.1 EQUIPMENT SUMMARY........................................................................................................ 3 1.2 PERSONNEL.......................................................................................................................... 3 2 GENERAL WELL DETAILS........................................................................................................... 4 2.1 OBJECTIVES.......................................................................................................................... 4 2.2 WELL RESUME...................................................................................................................... 4 2.3 HOLE DATA............................................................................................................................ 5 3 GEOLOGICAL DATA..................................................................................................................... 6 3.1 FORMATION / ZONE MARKER TOPS................................................................................... 6 3.2 ZONE SUMMARIES................................................................................................................ 7 3.2.1 Tyonek Formation .......................................................................................................... 7 3.2.2 Hemlock Formation ........................................................................................................ 9 3.2.3 West Foreland Formation ............................................................................................. 11 3.3 WELL LITHOLOGY............................................................................................................... 13 3.4 SAMPLING PROGRAM AND DISTRIBUTION .....................................................................18 4 DRILLING DATA.......................................................................................................................... 19 4.1 DAILY ACTIVITY SUMMARY ............................................................................................... 19 4.2 SURVEY DATA..................................................................................................................... 21 4.3 MUD RECORD...................................................................................................................... 28 4.4 BIT RECORD........................................................................................................................ 29 5 DAILY REPORTS......................................................................................................................... 30 Enclosures: 2”/ 100’ Formation Log (MD and TVD 2”/ 100’ Combo Log (MD and TVD) 2”/ 100’ Gas Ratio Log (MD and TVD) 2”/ 100’ Drilling Dynamics Log (MD and TVD) Final Well Data on CD Cook Inlet Energy RU-5B 3 1 MUDLOGGING EQUIPMENT AND CREW 1.1 EQUIPMENT SUMMARY Parameter Equipment Type And Position Total Downtime Comments Ditch Gas Electric Driven QGM Gas Trap Mounted In Possum Belly; FID Total Hydrocarbon Analyzer And Chromatograph 1 Due to swapping power on the rig. Lost lag reference. Rate of Penetration (ROP) Primary Draw works Belt Driven Encoder On Drum Shaft (Totco) 0 Pump stroke counter Externally Mounted Magnetic Proximity Sensor (Totco) 0 Hook load / Weight on bit (WOB) Hydraulic Pressure Transducer (Totco) 0 Drill string torque Varco Analog Feed 0 Top drive rotary (RPM) Varco Analog Feed 0 Standpipe Pressure Solid State Pressure Transducer (Totco) 0 Casing Pressure Solid State Pressure Transducer (Totco) 0 Mud flow in / out (MFI / MFO) MFI: Calculated From SPM MFO: Flow Paddle (Totco) 0 Pit volumes Sonic Pit Probes 0 Driller’s work station Explosion Proof Touch Screen (Totco) 0 Company Man’s work station Totco 0 Tool pusher’s work station Totco 0 Mud Engineer’s work station Totco 0 Pits work station Totco 0 MWD / LWD WITS Feed WITS 0 1.2 PERSONNEL Unit Number: ML04 Mudloggers Years Days Technician Days Sample Catchers Days Benjamin Handley 4 14 Roustabouts Tyler Dretke 3 17 Cook Inlet Energy RU-5B 4 2 GENERAL WELL DETAILS 2.1 OBJECTIVES Osprey RU-5B is a development oil well planned to side track off of the previous RU-5A well utilizing the existing casing program down to 12,915’ MD. RU-5B will kick off from the 7 5/8” casing at 12,915’ and drill a 6 3/4” hole section from 12,915’ to 15,750’ MD. The well will be completed with 5 ½” production tubing and an ESP completion. 2.2 WELL RESUME Operator: Cook Inlet Energy Well Name: RU-5B Field and Pool: Redoubt Shoals Unit - Hemlock State : County Alaska Kenai Borough Company Representatives: Carlos Cretsinger, Keith Carter, Stephen Ratcliff, Todd Jessen Location: SEC. 14, T7N, R13W Elevation: KB 89.10’ Classification: Development Oil API #: 50-733-20513-02-00 PERMIT # 213-1070 AFE #: 111010 Rig Name / Type: Osprey Rig #1 Primary Target: Hemlock Spud Date :-> Finish Date :-> 8/27/13 – 9/7/2013 Total Depth: 15,750’ Total Depth Formation: West Foreland Mudlogging Company Canrig Drilling Technology, LTD MWD Company: Halliburton / Sperry Tools Run: MWD: Survey, Gamma, Resistivity Directional Drilling: Halliburton / Sperry Drilling Fluids Company: Halliburton / Baroid Cook Inlet Energy RU-5B 5 2.3 HOLE DATA Maximum Depth Shoe Depth Hole Section MD TVD T.D. Formation Mud Weight (ppg) Deviation (oinc) Casing MD TVD F.I.T. 6.75” 15750’ 12661’ West Foreland 9.3 31.39° 5 1/2” 15735’ 12648’ Cook Inlet Energy RU-5B 6 3 GEOLOGICAL DATA 3.1 FORMATION / ZONE MARKER TOPS ACTUAL FORMATION MD (ft) TVD SSTVD (ft) Tyonek 12915’ 10856' -10767' Tyonek Blue Marker 13001' 10892' -10802' Tyonek Correlation Marker 13779' 11337' -11248' RU 3 Gas Zone Estimate 13990' 11475' -11386' Hemlock Coal 14712' 11909' -11820' Upper Hemlock 14800' 11960' -11871' Silt Zone 15022' 12101' -12012' Middle Hemlock 15090' 12148' -12059' Lower Hemlock 15352' 12340' -12251' Possible O/W 15414' 12387' -12298' West Foreland Coal 15531' 12479' -12390' West Foreland 15662' 12586' -12497' TD 15750' 12661 -12572' Cook Inlet Energy RU-5B 7 3.2 ZONE SUMMARIES 3.2.1 Tyonek Formation Tyonek : Window, 10856' TVD, -10767' TVDSS Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 272.2 0.7 44.5 98 0 20.5 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 13043 25 1068 151 155 156 221 235 315 13187 98 10448 54 30 27.5 28.9 52.9 49.3 13262 95 13113 58.4 16.02 15.12 17.04 26.7 30.4 13373 62 7097 65.1 12.4 16.9 76.5 63.9 58.4 Tuffaceous siltstone , tuffaceous siltstone, brownish gray to olive gray with grayish black hues. Crumbly tenacity. Tabular to wedgelike cuttings with one smooth side from pdc bit. Blocky to splintery fracture; smooth to silty texture. Dominantly massive with occasional thin black laminations; common grading to Tuffaceous claystone; common to scattered coal fragments. Sand , largely clear to translucent white to brown to light orange and occasionally opaque cream; tuffaceous framework where present, but predominantly unconsolidated grains of mostly quartz and feldspar, with abundant darker lithic fragments; minor amounts of coal and mica; lower medium to upper fine grain size, very well sorted; commonly subrounded with few larger more angular fragments; moderate to high sphericity; few grains larger than medium size; colors and features obscured by obm. Tuffaceous claystone , Dominantly brownish gray to olive gray With brownish black hues; crumbly to Occasionally stiff tenacity; tabular to wedgelike cuttings; earthy to blocky fracture; clayey to smooth texture; waxy texture when probed; dull to waxy luster; color and features obscured by obm. Cook Inlet Energy RU-5B 8 RU 3 Gas Zone : 13990' MD, 11475' TVD, -11386' TVDSS Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 191.8 .9 42.5 119 6 33.4 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 14008 71 9793 54 13 25 - 5 15 14059 78 10915 85 20 3 - 2 2 14125 70 11372 78 17 8 - 6 6 14339 119 18598 94 19 - - - - 14410 49 6808 130 - - - - - 14542 44 5687 91 8 - - - - Tuffaceous Siltstone- Dusky yellowish brown to greenish black to brownish gray, occasionally with reddish hues; appears now as a secondary member in a sand/tuffaceous sandstone and usually blends in with it; cuttings universally finely ground, soft and friable; texture from smooth to silty to slightly abrasive, but never granular; no contacts or structure were observed; earthy to blocky fracture; cuttings irregular to nodular, often bit deformed, polished on one side and jagged on the other; dull to waxy luster; frequently peppered with coal chips; siltstone cuttings only very slightly calcitic, associated sand is highly reactive with acid, appearing to be more active amongst the component grains than the cement. Tuffaceous sandstone - Dominantly moderate brown to grayish Brown with pale reddish brown to Grayish red hues; individual grains are Opaque to rarely clear and pale brown to Pale reddish brown with occasional dusky Red; dominantly quartz framework with Common plagioclase and scattered lithic Fragments; common to scattered black Coal fragments; lower fine to upper Medium grained with occasional grading To upper fine; well to fairly sorted; Subangular to subrounded with occasional Rounded; mod to low sphericity; no Visible surface features due to obm contamination; primarily unconsolidated With occasional soft to easily friable Fragments; moderate reaction to hcl; Color and features skewed by obm Cook Inlet Energy RU-5B 9 3.2.2 Hemlock Formation Hemlock Coal : 14712' MD, 11909' TVD, -11820' TVDSS Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 155.2 3.7 60.2 53 23 31.8 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 14744 53 7114 153 - - - - - Tuffaceous sandstone - Moderate brown to reddish brown with medium gray to grayish brown hues. Individual grains are dominantly pale brown to pale reddish brown. Quartz framework with common plagioclase and scattered lithic fragments. Opaque to rarely clear. Common staining from obm. Easily friable to unconsolidated. Minor reaction hcl. Upper fine to lower fine grained. Well to fairly sorted. Subrounded to subangular. Mod to high sphericity. Features and color skewed by obm . Tuffaceous siltstone - Dominantly medium gray to grayish brown with dark gray hues. Crumbly to stiff tenacity. Flaky to scaly cuttings. Hackly to blocky fracture. Dull to earthy with occasional subsparkly luster. Silty to gritty texture. Dominantly massive with occasional thin banding; features and color skewed by obm. Upper Hemlock : 14800' MD, 11960' TVD, -11871' TVDSS Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 134.2 1.1 51.2 56 24 38.5 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 14809 50 8002 344 77 17 18 - - 14824 51 8176 366 81 17 20 - - 14877 56 8329 429 93 17 27 - - 14979 51 10390 307 54 11 18 - - Tuffaceous sandstone - Dominantly medium gray to brownish gray with light gray to pale brown hues. Individual grains are opaque to clear with common pale brown staining. Easily friable to soft with common unconsolidated grains. Fine grained. Well sorted. Subangular to subrounded. Moderate to high sphericity. Primarily quartz with common plagioclase and scattered lithic fragments. Tuffaceous Siltstone - Dominantly medium gray to brownish gray with olive black hues. Crumbly to occasionally stiff tenacity. Flaky to scaly cuttings habit with common smooth side from bit cut. Blocky to splintery fracture. Dull to earthy with occasional greasy luster. Silty to gritty and rarely abrasive. Dominantly massive with occasional thin olive black to black laminations. Commonly grades to tuffaceous sandstone. Colors and Features skewed by obm. Cook Inlet Energy RU-5B 10 Silt Zone : 15022' MD, 12101' TVD, -12012' TVDSS Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 135.7 2.3 61.9 32 21 25.6 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 15024 32 6282 140 28 7 16 - - Tuffaceous Siltstone- Dominantly medium gray to brownish gray with olive black hues; crumbly to occasionally stiff tenacity; flaky to scaly cuttings habit with common smooth side from bit cut; blocky to splintery fracture; dull to earthy with occasional greasy luster; silty to gritty rarely abrasive; dominantly massive with occasional thin olive black to black laminations; commonly grades to tuffaceous sandstone; colors and features skewed by OBM. Middle Hemlock : 15090' MD, 12148' TVD, -12059' TVDSS Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 139.7 0.6 37.4 30 14 22 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 15336 27 5547 372 39 15 19 - - Tuffaceous Siltstone- Moderate brown to medium gray with olive black to grayish brown hues; crumbly to occasionally brittle to crunchy; flaky to scaly cuttings habit; blocky to irregular fracture; dull to earthy with occasional subsparkly luster; silty to gritty to subsucrosic texture; dominantly massive with occasional thinly laminated beds; no reaction to HCl; features and colors skewed by OBM. Tuffaceous Sandstone- Overall sample dark yellowish brown to olive gray to olive black with individual grains running the gamut from clear to translucent amber to opaque light green, dark pink, yellow, brown, and black; cuttings mostly lumpy consistency with very low consolidation and all easily friable; open to occasionally irregular fracture; massive to rarely nodular cuttings habit; generally earthy luster, but scattered vitreous grains make samples slightly sparkly; grains fine to upper medium, occasionally somewhat larger; moderately well to well sorted; angular to subrounded, mostly subangular; low to moderate sphericity; approximately 40% quartz, 40% plagioclase and 20% other lithics, including scattered common calcite grains giving whole sample a spotty strong effervescence. Cook Inlet Energy RU-5B 11 Lower Hemlock : 15352' MD, 12340' TVD, -12251' TVDSS Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 123.6 2.0 30.0 21 9 16.8 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N No major gas peaks Tuffaceous Siltstone- Various colors along the darkish brown spectrum and often mottled; appearing only irregularly now and often ground to sand size and blending in with the dissociated sandstone; dense to crumbly tenacity; stiff to punky consistency; irregular fracture; nodular to somewhat elongated cuttings habit with most cuttings showing clear PDC bit deformation; dull to slightly waxy luster; smooth to silty to rarely abrasive texture; often faintly banded and evidently either occurring in thin beds or possibly as slough from above; generally only has a scattered pinpoint reaction to acid; colors and some features muddled by OBM. Tuffaceous Sandstone- Dominantly olive gray to brownish gray with light gray to medium gray hues; individual grains are dominantly opaque to clear with common pale brown staining from OBM contamination; quartz framework with common plagioclase and scattered lithic fragments; lower fine to upper medium with occasional upper fine grains; well to fair sorting; rounded to subrounded with scattered subangular; moderate to high sphericity; occasional visible frosting but surface features largely skewed by OBM; friable to easily friable with common unconsolidated sand; grain supported; scattered angular coal fragments; massive with no visible structure; oil indicators skewed by OBM. 3.2.3 West Foreland Formation West Foreland Coal : 15531' MD, 12479' TVD, -12390' TVDSS Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 89.7 1.7 23.8 23 6 14.3 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 15615 23 4008 441 28 - - - - Tuffaceous Sandstone- Dominantly moderate brown to medium gray with reddish brown to pale brown hues; individual grains are dominantly opaque to translucent with a pale brown stain from OBM; quartz framework with common plagioclase and occasional scattered angular coal fragments; lower fine to upper fine with occasional upper medium sized grains; well to fair sorting; rounded to subrounded with occasional subangular; mod to high sphericity; some visible etching but surface features skewed by OBM; friable to easily friable with abundant unconsolidated sand; clast supported; massive with no visible bedding; interbedded with small coal seams; color and features skewed by OBM. Cook Inlet Energy RU-5B 12 West Foreland : 15662' MD, 12586' TVD, -12497' TVDSS Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 84.8 4.3 28.3 13 5 9.3 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N No major gas peaks Tuffaceous Siltstone- Various browns from medium to dark usually with reddish or greenish hues, mostly olive gray to olive black; commonly dense to somewhat sectile tenacity, occasionally very tough; irregular to earthy to blocky fracture; cuttings often shaped by PDC bit, but hard cuttings nodular; dull to earthy luster; silty to gritty texture and sometimes abrasive; thinly bedding with occasional faint banding; slightly reactive with HCl; colors and surface textures partially covered by OBM. Cook Inlet Energy RU-5B 13 3.3 WELL LITHOLOGY Sand (12915' - 13040') = largely clear to translucent white to brown to light orange and occasionally opaque cream; tuffaceous framework where present, but predominantly unconsolidated; grains mostly quartz and feldspar, with abundant darker lithic fragments; minor amounts of coal and mica; lower medium to upper fine grain size, very well sorted; commonly subrounded with few larger more angular fragments; moderate to high sphericity; few grains larger than medium size; colors and features obscured by OBM. Coal (13040' - 13050') = grains black and shiny; blocky to somewhat flaky; strongly planar fracture; grains somewhat larger than the associated sand, medium to upper medium size; angular with very low sphericity; accompanied by a 25 unit gas rise with little c1-c5. Tuffaceous Siltstone (13050' - 13160') = brownish gray to olive gray with grayish black hues; crumbly tenacity; tabular to wedgelike cuttings w/ one smooth side from PDC bit; blocky to splintery fracture; smooth to silty texture; dominantly massive with occasional thin black laminations; common grading to tuffaceous claystone; common to scattered coal fragments; color and features obscured by OBM. Tuffaceous Claystone (13160' - 13210') = dominantly brownish gray to olive gray with brownish black hues; crumbly to occasionally stiff tenacity; tabular to wedgelike cuttings; earthy to blocky fracture; clayey to smooth texture; waxy texture when probed; dull to waxy luster; color and features obscured by OBM. Tuffaceous Siltstone (13210' - 13290') = dominantly dark gray to medium dark gray with brownish gray to brownish black hues; poorly indurated; crumbly to stiff tenacity; tabular to wedgelike cuttings with smooth bit deformed side; blocky to earthy fracture; dull to earthy luster; silty to smooth texture occasionally mottled; dominantly massive with rare thin laminations; common grading into a silty tuffaceous claystone; scattered black to brownish black coal fragments; coal fragments are brittle to tough; blocky to flaky cuttings; colors and features are skewed by OBM. Tuffaceous Claystone (13290' - 13355') = dominantly medium dark gray to brownish gray with blackish gray hues; crumbly to occasionally stiff; tabular to wedgelike cuttings habit; dull to earthy luster; clayey to smooth texture; waxy when probed; common grading to clayey tuffaceous siltstone; massive with no visible structure; colors and features skewed by OBM. Coal (13355' - 13395') = jet black and lustrous; highly fragmented and brittle; cuttings medium to large, unsorted; blocky to planar fracture; fresh surfaces sometimes appear slightly gritty; commonly finely interbedded with tuffaceous material, occasionally thickly interbedded; common laminae and rarely fissile. Tuffaceous Siltstone (13395' - 13470') = color difficult to distinguish through OBM, appears moderate reddish brown to moderate brown; tuff framework with some fine siliceous material; silty to gritty texture, grading to smooth clayey tuffaceous claystone; crumbly to slightly dense tenacity; irregular to earthy fracture, occasionally somewhat mushy; nodular to sub-tabular cuttings habit; earthy luster made resinous by OBM; trace laminae and commonly banded, interbedding with coal and tuffaceous claystone; oil indicators obscured by OBM. Tuffaceous Claystone (13470' - 13560') = moderate brown to grayish orange, sometimes with reddish hues; somewhat lighter and less red in color than the tuffaceous siltstone; curdy to stiff consistency; dense to sectile tenacity; irregular to mushy fracture; cuttings massive to nodular, most often shaped by bit; cuttings appear greasy on outside surfaces, but inside dull to somewhat waxy; smooth to clayey texture grading to silty to gritty tuffaceous siltstone; generally thick structure with some banding; coal less prevalent in this zone, though still many larger fragments in samples; sand common as a coating on claystone and siltstone cuttings. Cook Inlet Energy RU-5B 14 Sand (13560' - 13630') = unconsolidated and commonly appearing embedded in or crusted on tuffaceous claystone and siltstone cuttings, also appearing interstitially; often clear to translucent white, sometime opaque cream and less often colored reddish or greenish; generally stained brown by OBM; grains fine to lower medium size and well sorted; subrounded with fair sphericity; approximately 45% quartz, 45% feldspar & 10% other lithics. Tuffaceous Claystone (13630' - 13710') = moderate brown to dark reddish brown with medium gray hues; crumbly to stiff tenacity with stiff to clumpy consistency; tabular to nodular with often bit smoothed sides; dull to earthy luster; silty to clayey texture; massive with no visible structure; color and features skewed by OBM. Sand (13710' - 13790') = dominantly moderate brown to medium gray with brownish black hues; individual grains are opaque to occasionally clear with common pale brown staining from OBM; dominantly composed of quartz with common feldspar and scattered lithics; subrounded to subangular with occasional angular; lower fine to upper medium grained; fair to well sorted; moderate to high sphericity; unconsolidated with no visible matrix; commonly interbedded with tuffaceous siltstone and claystone; scattered to common angular coal fragments. Tuffaceous Claystone (13790' - 13825') = moderate brown to grayish brown with medium gray hues; crumbly to stiff tenacity; nodular to tabular cuttings with PDC bit cut; blocky to earthy fracture; dull to earthy luster; smooth to clayey texture; massive with no visible structure; features skewed by OBM. Tuffaceous Siltstone (13825' - 13935') = dominantly dusky reddish brown to medium dark gray with common brownish gray to brownish black hues; poorly indurated; crumbly to sometimes stiff tenacity; nodular to tabular cuttings or wedgelike cuttings with smooth side deformed by bit; earthy to open, occasionally blocky fracture; dull to earthy luster, resinous on oily surfaces; smooth to silty texture; massive structure with trace thin laminations and rare banding; common grading into silty tuffaceous claystone; associated with scatter black to brownish black coal fragments; coal is brittle to tough; blocky to flaky cuttings; all cuttings coated with abundant quartz/feldspar sand; colors and features obscured by OBM residue. Tuffaceous Sandstone (13935' - 14010') = mostly unconsolidated and at best loosely bound and friable; individual grains as described for sand above, variously colored, mostly through the brown scale, but often white, cream, or translucent and rarely hued reddish, greenish, bluish, or yellowish; fine fragmentary black lithics also common; upper fine to medium grained, well to very well sorted; dominant quartz/plagioclase framework; subrounded moderately spherical grains; surface features obscured by oil residue; cemented by calcite. Coal (14010' - 14040') = black to brownish black to blackish gray; fragments highly fractured and very angular with sometimes sharp edges; cuttings platy to flaky, occasionally appearing splintery; crunchy to brittle, mostly depending on microfractures; blocky to planar, rarely subconcoidal fracture; different surfaces dull to polished, sometimes resinous; smooth to abrasive texture, trace fibrous and often bit abraded; scattered very fine laminations; associated with gradually increasingly organized tuffaceous sandstone. Tuffaceous Sandstone (14040'-14190') = dominantly medium gray to pale reddish brown with grayish red hues; individual grains are dominantly opaque and pale brown to light brown; quartz framework with common plagioclase and scattered lithic fragments; dominantly unconsolidated with occasional soft to easily friable; lower fine to upper medium grain size; fair to well sorted; subangular to subrounded; mod to high sphericity; color and surface features skewed by OBM. Cook Inlet Energy RU-5B 15 Tuffaceous Claystone (14190'-14265') = moderate brown to dusky reddish brown with medium gray hues; crumbly to stiff tenacity; nodular to tabular cuttings; dull to earthy luster; silty to clayey texture; massive with no visible structure; color and features skewed by OBM. Tuffaceous Sandstone (14265'-14355') = dominantly moderate brown to grayish brown with pale reddish brown to grayish red hues; individual grains are opaque to rarely clear and pale brown to pale reddish brown with occasional dusky red; dominantly quartz framework with common plagioclase and scattered lithic fragments; common to scattered black coal fragments; lower fine to upper medium grained with occasional grading to upper fine; well to fairly sorted; subangular to subrounded with occasional rounded; mod to low sphericity; no visible surface features due to OBM contamination; primarily unconsolidated with occasional soft to easily friable fragments; moderate reaction to HCl; color and features skewed by OBM. Tuffaceous Siltstone (14355'-14405') = dominantly moderate brown to dusky brown with moderate gray hues; crumbly to rarely stiff; flaky to tabular cuttings; blocky to hackly fracture; dull to earthy luster; silty to gritty texture; massive with rare thin black laminations; color and features are skewed by OBM. Tuffaceous Sandstone (14405'-14475') = moderate brown to grayish brown with pale brown hues; individual grains are opaque and pale brown to reddish brown in color; common staining from oil based mud; quartz with common plagioclase and scattered lithic fragments; unconsolidated to occasionally soft to easily friable; upper fine to lower fine occasionally upper medium grained; well to fair sorted; subangular to subrounded; mod to high sphericity; features and color skewed by OBM. Tuffaceous Siltstone (14475' - 14580') = dusky yellowish brown to greenish black to brownish gray, occasionally with reddish hues; appears now as a secondary member in a sand/tuffaceous sandstone and usually blends in with it; cuttings universally finely ground, soft and friable; texture from smooth to silty to slightly abrasive, but never granular; no contacts or structure were observed; earthy to blocky fracture; cuttings irregular to nodular, often bit deformed, polished on one side and jagged on the other; dull to waxy luster; frequently peppered with coal chips; siltstone cuttings only very slightly calcitic, associated sand is highly reactive with acid, appearing to be more active amongst the component grains than the cement. Tuffaceous Claystone (14580' - 14640') = very similar in color and general features to and grading with siltstone described above; various hues of dark brown; smooth to clayey texture; soft to dense tenacity; irregular to mushy fracture; cuttings nodular, finely ground and typically shaped by PDC bit; earthy to waxy luster; finely bedded with hairline microlaminae; not reactive with acid; heavily stained by OBM. Tuffaceous Sandstone (14670'-14730') = moderate brown to reddish brown with medium gray to grayish brown hues; individual grains are dominantly pale brown to pale reddish brown; quartz framework with common plagioclase and scattered lithic fragments; opaque to rarely clear; common staining from OBM; easily friable to unconsolidated; minor reaction HCl; upper fine to lower fine; well to fairly sorted; subround to subangular; mod to high sphericity; features and color skewed by OBM. Tuffaceous Siltstone (14740'-14785') = dominantly medium gray to grayish brown with dark gray hues; crumbly to stiff tenacity; flaky to scaly cuttings; hackly to blocky fracture; dull to earthy with occasional subsparkly luster; silty to gritty texture; dominantly massive with occasional thin banding; features and color skewed by OBM. Coal (14795'-14825') = dominantly black to grayish brown with brownish black hues; angular to tabular cuttings; brittle to crunchy tenacity; blocky fracture; greasy to resinous luster; gritty to sucrosic texture; interbedded with tuffaceous sandstone and siltstone. Cook Inlet Energy RU-5B 16 Tuffaceous Sandstone (14835'-14888') = dominantly medium gray to brownish gray with light gray to pale brown hues; individual grains are opaque to clear with common pale brown staining; easily friable to soft with common unconsolidated grains; fine grained; well sorted; subangular to subrounded; moderate to high sphericity; primarily quartz with common plagioclase and scattered lithic fragments. Tuffaceous Siltstone (14888'-14995') = dominantly medium gray to brownish gray with olive black hues; crumbly to occasionally stiff tenacity; flaky to scaly cuttings habit with common smooth side from bit cut; blocky to splintery fracture; dull to earthy with occasional greasy luster; silty to gritty rarely abrasive; dominantly massive with occasional thin olive black to black laminations; commonly grades to tuffaceous sandstone; colors and features skewed by OBM. Tuffaceous Sandstone (14995'-15095') = dominantly moderate brown to moderate reddish brown with pale red to dusky red and medium gray hues; individual grains are dominantly opaque with common clear with pale brown staining; quartz with scattered plagioclase and scattered lithic fragments; easily friable to occasionally friable with abundant unconsolidated sands; scattered weak HCl reaction; dominantly clast supported; lower fine to upper medium sized grains; well to fair sorting; subrounded to rounded with scattered angular; mod to high sphericity; surface features and color skewed by OBM; commonly interbedded with thin coal stringers; coal is black to brownish black; angular; brittle to tough. Tuffaceous Siltstone (15095'-15160') = moderate brown to medium gray with olive black to grayish brown hues; crumbly to occasionally brittle to crunchy; flaky to scaly cuttings habit; blocky to irregular fracture; dull to earthy with occasional subsparkly luster; silty to gritty to subsucrosic texture; dominantly massive with occasional thinly laminated beds; no reaction to HCl; features and colors skewed by OBM. Tuffaceous Sandstone (15160' - 15280') = overall sample dark yellowish brown to olive gray to olive black with individual grains running the gamut from clear to translucent amber to opaque light green, dark pink, yellow, brown, and black; cuttings mostly lumpy consistency with very low consolidation and all easily friable; open to occasionally irregular fracture; massive to rarely nodular cuttings habit; generally earthy luster, but scattered vitreous grains make samples slightly sparkly; grains fine to upper medium, occasionally somewhat larger; moderately well to well sorted; angular to subrounded, mostly subangular; low to moderate sphericity; approximately 40% quartz, 40% plagioclase and 20% other lithics, including scattered common calcite grains giving whole sample a spotty strong effervescence. Tuffaceous Siltstone (15280' - 15370') = various colors along the darkish brown spectrum and often mottled; appearing only irregularly now and often ground to sand size and blending in with the dissociated sandstone; dense to crumbly tenacity; stiff to punky consistency; irregular fracture; nodular to somewhat elongated cuttings habit with most cuttings showing clear PDC bit deformation; dull to slightly waxy luster; smooth to silty to rarely abrasive texture; often faintly banded and evidently either occurring in thin beds or possibly as slough from above; generally only has a scattered pinpoint reaction to acid; colors and some features muddled by OBM. Tuffaceous Sandstone (15400'-15490') = dominantly olive gray to brownish gray with light gray to medium gray hues; individual grains are dominantly opaque to clear with common pale brown staining from OBM contamination; quartz framework with common plagioclase and scattered lithic fragments; lower fine to upper medium with occasional upper fine grains; well to fair sorting; rounded to subrounded with scattered subangular; moderate to high sphericity; occasional visible frosting but surface features largely skewed by OBM; friable to easily friable with common unconsolidated sand; grain supported; scattered angular coal fragments; massive with no visible structure; oil indicators skewed by OBM. Tuffaceous Sandstone (15500'-15590') = dominantly moderate brown to medium gray with reddish brown to pale brown hues; individual grains are dominantly opaque to translucent with a pale brown stain from OBM; quartz framework with common plagioclase and occasional scattered angular coal fragments; Cook Inlet Energy RU-5B 17 lower fine to upper fine with occasional upper medium sized grains; well to fair sorting; rounded to subrounded with occasional subangular; mod to high sphericity; some visible etching but surface features skewed by OBM; friable to easily friable with abundant unconsolidated sand; clast supported; massive with no visible bedding; interbedded with small coal seams; color and features skewed by OBM. Tuffaceous Siltstone (15590' - 15670') = various browns from medium to dark usually with reddish or greenish hues, mostly olive gray to olive black; commonly dense to somewhat sectile tenacity, occasionally very tough; irregular to earthy to blocky fracture; cuttings often shaped by PDC bit, but hard cuttings nodular; dull to earthy luster; silty to gritty texture and sometimes abrasive; thinly bedding with occasional faint banding; slightly reactive with HCl; colors and surface textures partially covered by OBM. Overall Lithology (15670' - 15750') = little change from previous sample descriptions; noticeable increase in tuffaceous siltstone fraction in last few hundred feet; tuffaceous sandstone progressively better consolidated, still soft but less free sand; coal increased in the last 60', possibly slough; siltstone slightly firm to firm, usually bit deformed, commonly faintly banded and often shows incipient fissility, breaks blocky to planar and comes in nodules and wedges; sandstone obviously more granular, less organized, usually clumpy and soft, medium fine to medium grained and well sorted; siltstone and coal often ground small enough to blend in with sand; colors unchanged. Cook Inlet Energy RU-5B 18 3.4 SAMPLING PROGRAM AND DISTRIBUTION Set Type and Purpose Interval Frequency Distribution 1 Cleaned and Spun Dry 12930’ - 15750’ 30’ Cook Inlet Energy Attn: Greg Kirkland 601 W. 5 th Ave, Suite 310 Anchorage, AK 99501 Cook Inlet Energy RU-5B 19 4 DRILLING DATA 4.1 DAILY ACTIVITY SUMMARY August 27, 2013: Continue wireline Operations, Set CIBP @ 12928', R/D wireline, P/U whipstock and RIH t/ 12928'. Set whipstock and begin milling window in 7.625" casing. August 28, 2013: Continue milling window to 12935', pump sweep and circulate, POOH to check bit, RIH w/ new bit, mill F/12923' T/12930'. August 29, 2013 Continue milling window and drilling rat hole to 12951', perform FIT to 12.0 ppg EMW, POOH and begin picking up directional BHA. August 30, 2013 Continue P/U BHA and shallow test tools. RIH to 1295’ and drill to 13138’. August 31, 2013 Continue drilling F/ 13138' T/13704' with slides as needed. September 1, 2013: Continue drilling ahead F/13704' T/13780', Slide F/13780' T/14038', Circulate bottoms up and pump pill. September 2, 2013: Backream out F/14038', T/12293', Pump out of the 7 5/8" liner to 11290', pump dry job and POOH. September 3, 2013: Finish picking up directional BHA, Surface test MWD tools, RIH T/12875', wash down tight spots f/12875 t/12905', RIH on elevators to 13420', RIH to 14040'. Drill f/14040' t/14265'. September 4, 2013: Drill F/14265' T/14681' sliding as needed. September 5, 2013: Continue drilling f/14681' t/14887'. Circulate bottoms up and POOH to 12815'. Begin RIH. September 6, 2013: Continue RIH and drill f/14887' T/15453'. September 7, 2013: Continue drilling f/15453' t/ TD at 15750'. Circulate hole clean and begin reaming out. September 8, 2013: Ream out from 151220’ to 9 5/8” casing. Circulate and POOH. Begin testing BOPs. September 9, 2013: Finish testing BOPs, P/U hanger and RIH September 10, 2013: Continue RIH w/ liner. Wash down f/ 13379’ t/15125’ due to tight spot. Cook Inlet Energy RU-5B 20 September 11, 2013: Run liner to bottom, rig up cementers and begin cementing, r/d cementers and POOH. September 12, 2013: Lay down HWDP and POOH f/905 to surface. Rig up weatherford and inject fluid, test BOPs, service rig, M/U mill and RIH w/ tubing. 4. 2 S U R V E Y D A T A Me a s u r e d De p t h In c l i n a t i o n A z i m u t h T V D Ve r t i c a l Se c t i o n +NS - + E W - D L S ( f t ) ( d e g ) ( d e g ) ( f t ) ( f t ) ( f t ) ( f t ) ( de g / 1 0 0 f t ) 0. 0 0 0 . 0 0 0 . 0 0 0 . 0 0 0 . 0 0 0 . 0 0 0 . 0 0 0 . 0 0 12 9 . 1 0 0 . 0 0 0 . 0 0 1 2 9 . 1 0 0 . 0 0 0 . 0 0 0 . 0 0 0 . 0 0 14 3 . 1 0 0 . 2 5 4 2 . 0 0 1 4 3 . 1 0 0 . 0 0 0 . 0 2 0 . 0 2 1 . 7 9 17 3 . 1 0 0 . 1 0 3 5 6 . 0 0 1 7 3 . 1 0 - 0 . 0 1 0 . 1 0 0 . 0 6 0 . 6 5 20 4 . 1 0 0 . 2 5 2 3 2 . 0 0 2 0 4 . 1 0 - 0 . 0 5 0 . 0 8 0 . 0 1 1 . 0 2 23 4 . 1 0 0 . 9 0 2 0 6 . 0 0 2 3 4 . 1 0 0 . 0 0 - 0 . 1 7 - 0 . 1 5 2 . 2 8 29 4 . 1 0 2 . 8 0 1 9 8 . 0 0 2 9 4 . 0 6 0 . 6 6 - 1 . 9 9 - 0 . 8 1 3 . 1 9 38 3 . 1 0 5 . 3 7 2 1 2 . 0 0 3 8 2 . 8 3 2 . 0 5 - 7 . 5 9 - 3 . 6 9 3 . 0 8 47 2 . 1 0 7 . 8 2 2 1 1 . 6 8 4 7 1 . 2 4 3 . 5 0 - 1 6 . 2 7 - 9 . 0 7 2 . 7 5 56 2 . 1 0 9 . 7 7 2 1 1 . 5 0 5 6 0 . 1 7 5 . 5 1 - 2 8 . 0 0 - 1 6 . 2 8 2 . 1 7 67 7 . 6 0 1 2 . 4 7 2 1 1 . 3 7 6 7 3 . 5 0 8 . 8 3 - 4 7 . 0 0 - 2 7 . 8 9 2 . 3 4 76 7 . 0 0 1 2 . 4 5 2 1 1 . 1 9 7 6 0 . 7 9 1 1 . 7 4 - 6 3 . 4 9 - 3 7 . 9 1 0 . 0 5 85 5 . 2 0 1 1 . 9 7 2 0 7 . 0 6 8 4 7 . 0 0 1 5 . 2 4 - 7 9 . 7 7 - 4 6 . 9 9 1 . 1 3 94 3 . 1 0 1 1 . 8 6 1 9 6 . 0 4 9 3 3 . 0 1 2 0 . 9 4 - 9 6 . 5 7 - 5 3 . 6 4 2 . 5 9 10 3 5 . 8 0 1 1 . 9 8 1 8 3 . 3 8 1 0 2 3 . 7 3 3 0 . 5 5 - 1 1 5 . 3 3 - 5 6 . 8 4 2 .82 11 2 9 . 7 0 1 3 . 6 5 1 6 6 . 7 8 1 1 1 5 . 3 2 4 5 . 2 4 - 1 3 5 . 8 5 - 5 4 . 8 8 4 .29 12 2 3 . 1 0 1 6 . 5 3 1 5 2 . 0 9 1 2 0 5 . 5 2 6 6 . 3 8 - 1 5 8 . 3 3 - 4 6 . 1 3 5 .10 13 1 9 . 3 0 1 7 . 1 0 1 4 6 . 2 6 1 2 9 7 . 6 2 9 2 . 6 4 - 1 8 2 . 1 9 - 3 1 . 8 7 1 .85 14 1 3 . 4 0 1 8 . 9 1 1 3 9 . 4 1 1 3 8 7 . 1 1 1 2 0 . 9 7 - 2 0 5 . 2 8 - 1 4 . 2 6 2.96 15 0 8 . 6 0 2 1 . 7 4 1 3 8 . 7 1 1 4 7 6 . 3 8 1 5 3 . 6 2 - 2 3 0 . 2 5 7 . 4 1 2 . 98 16 0 3 . 9 0 2 4 . 4 2 1 3 7 . 2 4 1 5 6 4 . 0 4 1 9 0 . 6 1 - 2 5 7 . 9 8 3 2 . 4 4 2 .88 17 0 0 . 2 0 2 6 . 6 9 1 3 5 . 9 8 1 6 5 0 . 9 2 2 3 1 . 8 7 - 2 8 8 . 1 5 6 0 . 9 9 2 .42 17 9 6 . 4 0 2 8 . 5 6 1 3 7 . 4 1 1 7 3 6 . 1 5 2 7 6 . 1 7 - 3 2 0 . 6 2 9 1 . 5 7 2 .06 18 9 0 . 8 0 3 1 . 4 4 1 3 6 . 5 4 1 8 1 7 . 8 9 3 2 3 . 0 1 - 3 5 5 . 1 1 1 2 3 . 7 8 3.09 19 8 5 . 2 0 3 1 . 1 9 1 3 7 . 0 9 1 8 9 8 . 5 4 3 7 1 . 7 3 - 3 9 0 . 8 8 1 5 7 . 3 6 0.40 20 8 0 . 0 0 3 0 . 1 5 1 3 7 . 7 8 1 9 8 0 . 0 8 4 1 9 . 6 7 - 4 2 6 . 4 9 1 9 0 . 0 7 1.16 21 7 2 . 9 0 2 8 . 4 3 1 3 8 . 9 3 2 0 6 1 . 1 0 4 6 4 . 6 4 - 4 6 0 . 4 4 2 2 0 . 2 8 1.95 22 6 7 . 6 0 2 8 . 0 9 1 4 1 . 8 1 2 1 4 4 . 5 2 5 0 8 . 7 3 - 4 9 4 . 9 6 2 4 8 . 8 7 1.48 23 5 8 . 6 0 2 9 . 9 1 1 3 9 . 1 3 2 2 2 4 . 1 1 5 5 2 . 1 0 - 5 2 8 . 9 6 2 7 6 . 9 7 2.46 Co o k I n l e t E n e r g y RU - 5 B 22 Me a s u r e d De p t h In c l i n a t i o n A z i m u t h T V D Ve r t i c a l Se c t i o n +NS - + E W - D L S ( f t ) ( d e g ) ( d e g ) ( f t ) ( f t ) ( f t ) ( f t ) ( de g / 1 0 0 f t ) 24 5 1 . 3 0 3 2 . 0 4 1 3 9 . 2 7 2 3 0 3 . 5 8 5 9 9 . 1 9 - 5 6 5 . 0 8 3 0 8 . 1 4 2.30 25 4 5 . 3 0 2 9 . 9 4 1 3 9 . 1 1 2 3 8 4 . 1 6 6 4 6 . 9 6 - 6 0 1 . 7 1 3 3 9 . 7 7 2.24 26 4 1 . 5 0 2 9 . 7 3 1 3 6 . 1 5 2 4 6 7 . 6 1 6 9 4 . 3 8 - 6 3 7 . 0 6 3 7 2 . 0 1 1.55 27 3 6 . 0 0 2 8 . 3 3 1 3 4 . 4 9 2 5 5 0 . 2 4 7 4 0 . 0 4 - 6 6 9 . 6 8 4 0 4 . 2 4 1.71 28 2 8 . 7 0 2 9 . 1 7 1 3 2 . 8 9 2 6 3 1 . 5 1 7 8 4 . 5 3 - 7 0 0 . 4 7 4 3 6 . 4 8 1.23 29 2 3 . 3 0 2 9 . 1 4 1 3 5 . 3 1 2 7 1 4 . 1 3 8 3 0 . 4 9 - 7 3 2 . 5 3 4 6 9 . 5 7 1.25 30 1 8 . 0 0 3 1 . 7 6 1 3 5 . 2 6 2 7 9 5 . 7 6 8 7 8 . 2 7 - 7 6 6 . 6 3 5 0 3 . 3 4 2.77 31 1 0 . 2 0 3 3 . 4 5 1 3 4 . 0 3 2 8 7 3 . 4 3 9 2 7 . 7 8 - 8 0 1 . 5 3 5 3 8 . 6 9 1.97 31 6 0 . 4 8 3 4 . 7 0 1 3 3 . 9 8 2 9 1 5 . 0 8 9 5 5 . 8 8 - 8 2 1 . 1 0 5 5 8 . 9 5 2.49 32 5 0 . 7 6 3 4 . 1 9 1 3 3 . 8 8 2 9 8 9 . 5 3 1 0 0 6 . 8 3 - 8 5 6 . 5 3 5 9 5 . 7 3 0 . 5 7 33 4 5 . 4 2 3 4 . 1 4 1 3 3 . 7 9 3 0 6 7 . 8 5 1 0 5 9 . 8 6 - 8 9 3 . 3 5 6 3 4 . 0 7 0 . 0 8 34 4 0 . 3 9 3 4 . 0 7 1 3 3 . 3 9 3 1 4 6 . 4 9 1 1 1 3 . 0 1 - 9 3 0 . 0 6 6 7 2 . 6 4 0 . 2 5 35 3 6 . 1 3 3 3 . 0 6 1 3 7 . 6 7 3 2 2 6 . 2 7 1 1 6 5 . 6 7 - 9 6 7 . 8 0 7 0 9 . 7 2 2 . 6 9 36 3 3 . 0 5 3 3 . 2 8 1 3 7 . 5 9 3 3 0 7 . 4 0 1 2 1 8 . 2 2 - 1 0 0 6 . 9 7 7 4 5 . 4 6 0 . 2 3 37 2 9 . 9 6 3 2 . 3 1 1 3 8 . 4 9 3 3 8 8 . 8 6 1 2 7 0 . 1 9 - 1 0 4 6 . 0 0 7 8 0 . 5 6 1 . 1 2 38 2 6 . 0 1 3 2 . 1 1 1 3 8 . 4 0 3 4 7 0 . 1 3 1 3 2 0 . 8 3 - 1 0 8 4 . 3 1 8 1 4 . 5 2 0 . 2 1 39 2 0 . 2 5 3 2 . 4 3 1 3 8 . 6 3 3 5 4 9 . 8 2 1 3 7 0 . 5 9 - 1 1 2 2 . 0 1 8 4 7 . 8 5 0 . 3 6 40 1 4 . 8 3 3 1 . 8 4 1 3 8 . 4 1 3 6 2 9 . 9 1 1 4 2 0 . 3 4 - 1 1 5 9 . 7 0 8 8 1 . 1 7 0 . 6 4 41 0 9 . 4 6 3 1 . 6 8 1 3 8 . 0 8 3 7 1 0 . 3 7 1 4 6 9 . 6 3 - 1 1 9 6 . 8 6 9 1 4 . 3 4 0 . 2 5 42 0 4 . 9 8 3 1 . 8 2 1 3 8 . 1 9 3 7 9 1 . 5 9 1 5 1 9 . 3 9 - 1 2 3 4 . 2 9 9 4 7 . 8 8 0 . 1 6 43 0 0 . 2 1 3 1 . 7 0 1 3 8 . 2 1 3 8 7 2 . 5 6 1 5 6 9 . 0 0 - 1 2 7 1 . 6 6 9 8 1 . 2 9 0 . 1 3 43 9 6 . 5 5 3 1 . 9 2 1 3 8 . 2 5 3 9 5 4 . 4 3 1 6 1 9 . 2 5 - 1 3 0 9 . 5 3 1 0 1 5 . 12 0 . 2 3 44 9 1 . 3 8 3 1 . 8 2 1 3 8 . 4 7 4 0 3 4 . 9 7 1 6 6 8 . 7 9 - 1 3 4 6 . 9 5 1 0 4 8 . 39 0 . 1 6 45 8 6 . 7 2 3 2 . 0 9 1 3 8 . 6 4 4 1 1 5 . 8 6 1 7 1 8 . 6 8 - 1 3 8 4 . 7 7 1 0 8 1 . 79 0 . 3 0 46 7 5 . 5 7 3 0 . 9 9 1 3 7 . 9 3 4 1 9 1 . 5 8 1 7 6 4 . 6 7 - 1 4 1 9 . 4 7 1 1 1 2 . 71 1 . 3 1 46 7 5 . 5 7 3 0 . 9 9 1 3 7 . 9 3 4 1 9 1 . 5 8 1 7 6 4 . 6 7 - 1 4 1 9 . 4 7 1 1 1 2 . 71 1 . 3 1 47 7 0 . 7 9 3 0 . 6 9 1 3 8 . 6 7 4 2 7 3 . 3 4 1 8 1 2 . 9 7 - 1 4 5 5 . 9 1 1 1 4 5 . 18 0 . 5 1 48 6 2 . 3 4 3 1 . 0 1 1 3 8 . 6 5 4 3 5 1 . 9 4 1 8 5 9 . 3 8 - 1 4 9 1 . 1 6 1 1 7 6 . 19 0 . 3 5 49 5 7 . 1 4 3 1 . 4 9 1 3 9 . 1 0 4 4 3 2 . 9 8 1 9 0 7 . 9 7 - 1 5 2 8 . 2 0 1 2 0 8 . 54 0 . 5 6 Co o k I n l e t E n e r g y RU - 5 B 23 Me a s u r e d De p t h In c l i n a t i o n A z i m u t h T V D Ve r t i c a l Se c t i o n +NS - + E W - D L S ( f t ) ( d e g ) ( d e g ) ( f t ) ( f t ) ( f t ) ( f t ) ( de g / 1 0 0 f t ) 50 5 1 . 8 6 3 2 . 0 1 1 3 8 . 4 5 4 5 1 3 . 5 3 1 9 5 7 . 2 2 - 1 5 6 5 . 6 9 1 2 4 1 . 39 0 . 6 6 51 4 7 . 5 4 3 1 . 7 7 1 3 8 . 4 0 4 5 9 4 . 7 6 2 0 0 7 . 2 2 - 1 6 0 3 . 5 0 1 2 7 4 . 93 0 . 2 5 52 4 2 . 9 5 3 1 . 3 9 1 3 6 . 6 2 4 6 7 6 . 0 5 2 0 5 6 . 7 5 - 1 6 4 0 . 3 5 1 3 0 8 . 67 1 . 0 6 53 3 9 . 1 1 3 2 . 0 1 1 3 6 . 9 8 4 7 5 7 . 8 6 2 1 0 6 . 9 2 - 1 6 7 7 . 1 8 1 3 4 3 . 26 0 . 6 7 54 3 3 . 7 2 3 2 . 5 4 1 3 6 . 9 4 4 8 3 7 . 8 5 2 1 5 7 . 0 7 - 1 7 1 4 . 1 1 1 3 7 7 . 74 0 . 5 6 55 2 6 . 8 3 3 1 . 1 6 1 3 7 . 7 0 4 9 1 6 . 9 4 2 2 0 5 . 8 0 - 1 7 5 0 . 2 2 1 4 1 1 . 05 1 . 5 4 56 2 3 . 4 9 3 0 . 2 5 1 3 7 . 6 7 5 0 0 0 . 0 5 2 2 5 4 . 7 1 - 1 7 8 6 . 7 2 1 4 4 4 . 28 0 . 9 4 57 1 4 . 7 3 3 0 . 1 8 1 3 7 . 8 1 5 0 7 8 . 8 9 2 3 0 0 . 2 0 - 1 8 2 0 . 7 0 1 4 7 5 . 16 0 . 1 1 58 0 8 . 7 4 3 0 . 2 7 1 3 8 . 1 5 5 1 6 0 . 1 2 2 3 4 7 . 0 7 - 1 8 5 5 . 8 6 1 5 0 6 . 84 0 . 2 1 59 0 0 . 1 2 3 0 . 4 4 1 3 8 . 1 9 5 2 3 8 . 9 8 2 3 9 2 . 7 8 - 1 8 9 0 . 2 7 1 5 3 7 . 63 0 . 1 9 59 9 5 . 9 6 3 0 . 5 4 1 3 7 . 8 1 5 3 2 1 . 5 6 2 4 4 0 . 9 3 - 1 9 2 6 . 4 1 1 5 7 0 . 17 0 . 2 3 60 9 1 . 0 9 3 0 . 6 9 1 3 6 . 7 0 5 4 0 3 . 4 3 2 4 8 8 . 9 8 - 1 9 6 1 . 9 8 1 6 0 3 . 05 0 . 6 1 61 8 7 . 6 6 3 0 . 8 5 1 3 7 . 0 0 5 4 8 6 . 4 1 2 5 3 8 . 0 3 - 1 9 9 8 . 0 3 1 6 3 6 . 84 0 . 2 3 62 8 1 . 4 2 3 1 . 2 2 1 3 6 . 8 2 5 5 6 6 . 7 5 2 5 8 6 . 0 2 - 2 0 3 3 . 3 3 1 6 6 9 . 86 0 . 4 1 63 7 6 . 9 5 3 1 . 3 1 1 3 6 . 9 1 5 6 4 8 . 4 0 2 6 3 5 . 2 4 - 2 0 6 9 . 5 1 1 7 0 3 . 76 0 . 1 1 64 6 9 . 8 8 3 1 . 6 1 1 3 7 . 1 3 5 7 2 7 . 6 7 2 6 8 3 . 3 7 - 2 1 0 4 . 9 9 1 7 3 6 . 83 0 . 3 5 65 6 3 . 4 2 3 1 . 9 3 1 3 7 . 8 9 5 8 0 7 . 2 0 2 7 3 2 . 2 0 - 2 1 4 1 . 3 1 1 7 7 0 . 09 0 . 5 5 66 7 1 . 8 6 3 1 . 2 0 1 3 8 . 1 5 5 8 9 9 . 5 9 2 7 8 8 . 4 1 - 2 1 8 3 . 5 0 1 8 0 8 . 06 0 . 6 8 67 6 6 . 3 1 3 0 . 8 1 1 3 8 . 4 2 5 9 8 0 . 5 5 2 8 3 6 . 5 5 - 2 2 1 9 . 8 2 1 8 4 0 . 44 0 . 4 4 68 6 1 . 4 2 3 0 . 6 6 1 3 7 . 9 4 6 0 6 2 . 3 0 2 8 8 4 . 6 6 - 2 2 5 6 . 0 4 1 8 7 2 . 85 0 . 3 0 69 5 6 . 8 8 3 0 . 3 3 1 3 7 . 5 6 6 1 4 4 . 5 6 2 9 3 2 . 6 5 - 2 2 9 1 . 9 0 1 9 0 5 . 42 0 . 4 0 70 5 2 . 8 2 2 9 . 9 6 1 3 7 . 2 9 6 2 2 7 . 5 2 2 9 8 0 . 4 3 - 2 3 2 7 . 3 8 1 9 3 8 . 01 0 . 4 1 71 4 5 . 7 2 2 9 . 5 4 1 3 8 . 0 1 6 3 0 8 . 1 8 3 0 2 6 . 1 1 - 2 3 6 1 . 4 5 1 9 6 9 . 07 0 . 5 9 72 3 7 . 2 6 3 0 . 1 5 1 3 6 . 5 7 6 3 8 7 . 5 8 3 0 7 1 . 3 0 - 2 3 9 4 . 9 2 1 9 9 9 . 97 1 . 0 3 73 3 0 . 3 6 3 0 . 4 5 1 3 7 . 4 1 6 4 6 7 . 9 6 3 1 1 7 . 9 2 - 2 4 2 9 . 2 6 2 0 3 2 . 01 0 . 5 6 74 2 2 . 9 0 3 0 . 7 4 1 3 8 . 8 2 6 5 4 7 . 6 2 3 1 6 4 . 5 4 - 2 4 6 4 . 3 3 2 0 6 3 . 45 0 . 8 4 75 1 8 . 2 5 3 0 . 6 3 1 3 8 . 3 2 6 6 2 9 . 6 2 3 2 1 2 . 6 5 - 2 5 0 0 . 8 1 2 0 9 5 . 65 0 . 2 9 76 1 3 . 5 2 3 0 . 5 1 1 4 0 . 3 6 6 7 1 1 . 6 5 3 2 6 0 . 4 5 - 2 5 3 7 . 5 6 2 1 2 7 . 22 1 . 1 0 77 0 6 . 4 6 3 2 . 4 5 1 3 9 . 1 1 6 7 9 0 . 9 1 3 3 0 8 . 2 8 - 2 5 7 4 . 5 8 2 1 5 8 . 59 2 . 2 0 Co o k I n l e t E n e r g y RU - 5 B 24 Me a s u r e d De p t h In c l i n a t i o n A z i m u t h T V D Ve r t i c a l Se c t i o n +NS - + E W - D L S ( f t ) ( d e g ) ( d e g ) ( f t ) ( f t ) ( f t ) ( f t ) ( de g / 1 0 0 f t ) 78 0 2 . 5 9 3 2 . 3 6 1 3 7 . 3 5 6 8 7 2 . 0 7 3 3 5 9 . 2 6 - 2 6 1 3 . 0 0 2 1 9 2 . 90 0 . 9 9 78 9 5 . 1 7 3 2 . 5 3 1 3 6 . 5 4 6 9 5 0 . 2 0 3 4 0 8 . 5 6 - 2 6 4 9 . 2 9 2 2 2 6 . 81 0 . 5 0 79 9 0 . 8 5 3 2 . 4 4 1 3 4 . 7 4 7 0 3 0 . 9 1 3 4 5 9 . 6 9 - 2 6 8 6 . 0 3 2 2 6 2 . 74 1 . 0 1 80 8 3 . 7 9 3 2 . 6 3 1 3 3 . 8 6 7 1 0 9 . 2 6 3 5 0 9 . 5 3 - 2 7 2 0 . 9 4 2 2 9 8 . 51 0 . 5 5 81 7 9 . 8 2 3 2 . 3 6 1 3 3 . 9 5 7 1 9 0 . 2 6 3 5 6 1 . 0 0 - 2 7 5 6 . 7 1 2 3 3 5 . 68 0 . 2 9 82 7 7 . 2 3 3 2 . 0 3 1 3 3 . 9 0 7 2 7 2 . 6 9 3 6 1 2 . 7 8 - 2 7 9 2 . 7 2 2 3 7 3 . 06 0 . 3 4 83 7 0 . 5 1 3 1 . 6 6 1 3 3 . 3 0 7 3 5 1 . 9 3 3 6 6 1 . 9 0 - 2 8 2 6 . 6 6 2 4 0 8 . 70 0 . 5 2 84 6 4 . 6 8 3 2 . 3 3 1 3 4 . 9 3 7 4 3 1 . 8 0 3 7 1 1 . 6 6 - 2 8 6 1 . 3 9 2 4 4 4 . 52 1 . 1 6 85 5 5 . 8 6 3 1 . 8 3 1 3 3 . 8 0 7 5 0 9 . 0 5 3 7 5 9 . 9 4 - 2 8 9 5 . 2 5 2 4 7 9 . 13 0 . 8 6 86 5 1 . 4 6 3 1 . 1 8 1 3 3 . 2 1 7 5 9 0 . 5 6 3 8 0 9 . 8 0 - 2 9 2 9 . 6 5 2 5 1 5 . 37 0 . 7 5 87 4 6 . 2 9 3 0 . 6 6 1 3 3 . 2 0 7 6 7 1 . 9 2 3 8 5 8 . 4 5 - 2 9 6 3 . 0 1 2 5 5 0 . 88 0 . 5 5 88 3 8 . 6 7 3 0 . 2 5 1 3 5 . 1 2 7 7 5 1 . 5 5 3 9 0 5 . 1 5 - 2 9 9 5 . 6 2 2 5 8 4 . 47 1 . 1 4 89 3 7 . 4 4 3 0 . 1 6 1 3 6 . 4 5 7 8 3 6 . 9 1 3 9 5 4 . 5 8 - 3 0 3 1 . 2 3 2 6 1 9 . 12 0 . 6 8 90 3 0 . 8 6 2 9 . 4 3 1 3 6 . 2 6 7 9 1 7 . 9 8 4 0 0 0 . 7 1 - 3 0 6 4 . 8 2 2 6 5 1 . 16 0 . 7 9 91 2 2 . 1 5 2 9 . 0 3 1 3 5 . 8 5 7 9 9 7 . 6 5 4 0 4 5 . 0 4 - 3 0 9 6 . 9 2 2 6 8 2 . 10 0 . 4 9 92 1 4 . 0 4 2 8 . 2 1 1 3 5 . 5 7 8 0 7 8 . 3 1 4 0 8 8 . 8 4 - 3 1 2 8 . 4 3 2 7 1 2 . 83 0 . 9 0 93 0 9 . 3 3 2 8 . 9 9 1 3 4 . 6 8 8 1 6 1 . 9 7 4 1 3 4 . 2 7 - 3 1 6 0 . 7 5 2 7 4 5 . 02 0 . 9 3 94 0 3 . 1 3 2 9 . 6 2 1 3 5 . 3 6 8 2 4 3 . 7 7 4 1 8 0 . 0 0 - 3 1 9 3 . 2 3 2 7 7 7 . 47 0 . 7 6 94 9 7 . 6 9 3 0 . 0 1 1 3 6 . 0 9 8 3 2 5 . 8 1 4 2 2 6 . 7 8 - 3 2 2 6 . 8 9 2 8 1 0 . 29 0 . 5 6 95 9 1 . 5 9 3 1 . 1 6 1 3 6 . 1 8 8 4 0 6 . 6 5 4 2 7 4 . 2 8 - 3 2 6 1 . 3 4 2 8 4 3 . 39 1 . 2 3 96 8 7 . 7 8 3 1 . 1 6 1 3 6 . 0 6 8 4 8 8 . 9 6 4 3 2 3 . 7 6 - 3 2 9 7 . 2 1 2 8 7 7 . 89 0 . 0 6 97 7 9 . 4 5 3 1 . 1 4 1 3 5 . 4 8 8 5 6 7 . 4 1 4 3 7 0 . 9 4 - 3 3 3 1 . 1 9 2 9 1 0 . 97 0 . 3 3 98 7 5 . 6 8 3 1 . 0 5 1 3 6 . 6 4 8 6 4 9 . 8 2 4 4 2 0 . 3 6 - 3 3 6 6 . 9 7 2 9 4 5 . 45 0 . 6 3 99 6 9 . 9 8 3 0 . 9 3 1 3 6 . 0 4 8 7 3 0 . 6 6 4 4 6 8 . 6 1 - 3 4 0 2 . 1 0 2 9 7 8 . 97 0 . 3 5 10 0 6 4 . 2 3 3 0 . 7 0 1 3 6 . 9 5 8 8 1 1 . 6 0 4 5 1 6 . 5 8 - 3 4 3 7 . 1 2 3 0 1 2 .2 1 0 . 5 5 10 1 5 7 . 8 5 3 1 . 1 2 1 3 6 . 6 4 8 8 9 1 . 9 2 4 5 6 4 . 3 3 - 3 4 7 2 . 1 7 3 0 4 5 .1 4 0 . 4 8 10 2 5 1 . 5 9 3 0 . 1 6 1 3 6 . 4 6 8 9 7 2 . 5 8 4 6 1 1 . 7 9 - 3 5 0 6 . 8 5 3 0 7 7 .9 9 1 . 0 3 10 3 4 6 . 2 4 2 9 . 5 9 1 3 6 . 9 1 9 0 5 4 . 6 5 4 6 5 8 . 6 1 - 3 5 4 1 . 1 5 3 1 1 0 .3 3 0 . 6 5 10 4 4 0 . 6 6 2 9 . 5 4 1 3 6 . 9 9 9 1 3 6 . 7 7 4 7 0 4 . 8 6 - 3 5 7 5 . 2 0 3 1 4 2 .1 4 0 . 0 7 Co o k I n l e t E n e r g y RU - 5 B 25 Me a s u r e d De p t h In c l i n a t i o n A z i m u t h T V D Ve r t i c a l Se c t i o n +NS - + E W - D L S ( f t ) ( d e g ) ( d e g ) ( f t ) ( f t ) ( f t ) ( f t ) ( de g / 1 0 0 f t ) 10 5 3 3 . 1 3 2 9 . 2 9 1 3 6 . 9 6 9 2 1 7 . 3 2 4 7 4 9 . 9 4 - 3 6 0 8 . 4 0 3 1 7 3 .1 2 0 . 2 7 10 6 2 7 . 1 8 2 9 . 4 7 1 3 6 . 7 4 9 2 9 9 . 2 8 4 7 9 5 . 7 4 - 3 6 4 2 . 0 6 3 2 0 4 .6 8 0 . 2 2 10 7 2 1 . 8 1 2 9 . 4 5 1 3 6 . 4 0 9 3 8 1 . 6 7 4 8 4 1 . 9 8 - 3 6 7 5 . 8 6 3 2 3 6 .6 8 0 . 1 8 10 8 1 9 . 1 2 2 9 . 2 6 1 3 6 . 7 4 9 4 6 6 . 4 9 4 8 8 9 . 3 7 - 3 7 1 0 . 5 0 3 2 6 9 .4 7 0 . 2 6 10 9 1 3 . 0 0 2 8 . 3 7 1 3 7 . 0 8 9 5 4 8 . 7 4 4 9 3 4 . 2 8 - 3 7 4 3 . 5 5 3 3 0 0 .3 8 0 . 9 6 11 0 1 0 . 1 9 2 7 . 6 3 1 3 7 . 0 9 9 6 3 4 . 5 5 4 9 7 9 . 5 6 - 3 7 7 6 . 9 6 3 3 3 1 .4 5 0 . 7 6 11 1 0 4 . 4 1 2 7 . 7 6 1 3 7 . 6 4 9 7 1 7 . 9 8 5 0 2 2 . 9 9 - 3 8 0 9 . 1 8 3 3 6 1 .1 1 0 . 3 0 11 1 3 8 . 6 6 2 7 . 9 1 1 3 6 . 8 1 9 7 4 8 . 2 7 5 0 3 8 . 8 5 - 3 8 2 0 . 9 2 3 3 7 1 .9 7 1 . 2 1 11 1 9 7 . 3 8 2 8 . 1 3 1 3 7 . 0 0 9 8 0 0 . 1 0 5 0 6 6 . 2 4 - 3 8 4 1 . 0 6 3 3 9 0 .8 2 0 . 4 0 11 2 3 3 . 4 3 2 8 . 3 2 1 3 7 . 0 6 9 8 3 1 . 8 7 5 0 8 3 . 1 6 - 3 8 5 3 . 5 3 3 4 0 2 .4 4 0 . 5 3 11 2 3 3 . 4 3 2 8 . 3 2 1 3 7 . 0 6 9 8 3 1 . 8 7 5 0 8 3 . 1 6 - 3 8 5 3 . 5 3 3 4 0 2 .4 4 0 . 5 3 11 2 8 9 . 0 4 2 8 . 9 6 1 3 7 . 7 5 9 8 8 0 . 6 7 5 1 0 9 . 5 9 - 3 8 7 3 . 1 6 3 4 2 0 .4 8 1 . 3 0 11 3 8 3 . 4 9 2 9 . 1 9 1 3 7 . 7 1 9 9 6 3 . 2 2 5 1 5 5 . 0 6 - 3 9 0 7 . 1 2 3 4 5 1 .3 5 0 . 2 4 11 4 7 2 . 1 0 2 8 . 8 6 1 3 8 . 1 1 1 0 0 4 0 . 7 0 5 1 9 7 . 6 5 - 3 9 3 9 . 0 2 3 4 8 0. 1 7 0 . 4 3 11 4 9 2 . 4 5 3 0 . 9 0 1 3 7 . 9 2 1 0 0 5 8 . 3 5 5 2 0 7 . 6 8 - 3 9 4 6 . 5 6 3 4 8 6. 9 5 1 0 . 0 4 11 5 7 9 . 4 3 3 6 . 7 9 1 3 7 . 0 8 1 0 1 3 0 . 5 6 5 2 5 5 . 6 9 - 3 9 8 2 . 2 4 3 5 1 9. 6 8 6 . 7 9 11 6 3 5 . 9 1 4 1 . 7 0 1 3 6 . 5 4 1 0 1 7 4 . 2 8 5 2 9 1 . 1 6 - 4 0 0 8 . 2 8 3 5 4 4. 1 4 8 . 7 1 11 6 8 2 . 7 8 4 1 . 7 0 1 3 6 . 4 2 1 0 2 0 9 . 2 8 5 3 2 2 . 1 4 - 4 0 3 0 . 8 9 3 5 6 5. 6 1 0 . 1 7 11 7 4 3 . 4 9 4 2 . 5 1 1 3 8 . 5 4 1 0 2 5 4 . 3 2 5 3 6 2 . 4 9 - 4 0 6 0 . 8 9 3 5 9 3. 1 1 2 . 6 9 11 7 8 0 . 0 1 4 4 . 5 6 1 3 9 . 3 6 1 0 2 8 0 . 8 0 5 3 8 7 . 3 3 - 4 0 7 9 . 8 6 3 6 0 9. 6 3 5 . 8 2 11 8 7 1 . 2 0 4 7 . 9 2 1 3 9 . 5 7 1 0 3 4 3 . 8 6 5 4 5 2 . 2 9 - 4 1 2 9 . 9 1 3 6 5 2. 4 2 3 . 6 9 11 9 6 5 . 6 1 5 2 . 1 9 1 3 8 . 5 8 1 0 4 0 4 . 4 6 5 5 2 3 . 7 4 - 4 1 8 4 . 5 7 3 6 9 9. 8 4 4 . 5 9 12 0 1 3 . 4 9 5 4 . 5 2 1 3 7 . 6 3 1 0 4 3 3 . 0 4 5 5 6 1 . 7 7 - 4 2 1 3 . 1 6 3 7 2 5. 4 9 5 . 1 2 12 1 0 7 . 4 5 5 6 . 2 0 1 3 7 . 0 8 1 0 4 8 6 . 4 4 5 6 3 8 . 4 3 - 4 2 7 0 . 0 2 3 7 7 7. 8 6 1 . 8 5 12 1 7 3 . 8 0 5 7 . 3 2 1 3 7 . 3 1 1 0 5 2 2 . 8 1 5 6 9 3 . 4 9 - 4 3 1 0 . 7 3 3 8 1 5. 5 7 1 . 7 1 12 2 6 2 . 4 5 5 9 . 1 6 1 3 6 . 8 6 1 0 5 6 9 . 4 7 5 7 6 8 . 2 8 - 4 3 6 5 . 9 3 3 8 6 6. 8 9 2 . 1 2 12 3 5 7 . 3 2 6 0 . 3 1 1 3 6 . 6 5 1 0 6 1 7 . 2 9 5 8 4 9 . 6 5 - 4 4 2 5 . 6 2 3 9 2 3. 0 3 1 . 2 3 12 4 5 0 . 8 8 6 2 . 1 0 1 3 5 . 8 0 1 0 6 6 2 . 3 5 5 9 3 1 . 1 5 - 4 4 8 4 . 8 1 3 9 7 9. 7 6 2 . 0 7 12 5 4 6 . 7 4 6 3 . 7 7 1 3 6 . 0 3 1 0 7 0 5 . 9 7 6 0 1 6 . 0 5 - 4 5 4 6 . 1 3 4 0 3 9. 1 4 1 . 7 6 Co o k I n l e t E n e r g y RU - 5 B 26 Me a s u r e d De p t h In c l i n a t i o n A z i m u t h T V D Ve r t i c a l Se c t i o n +NS - + E W - D L S ( f t ) ( d e g ) ( d e g ) ( f t ) ( f t ) ( f t ) ( f t ) ( de g / 1 0 0 f t ) 12 6 4 2 . 6 8 6 5 . 5 8 1 3 5 . 7 2 1 0 7 4 7 . 0 0 6 1 0 2 . 3 1 - 4 6 0 8 . 3 7 4 0 9 9. 5 2 1 . 9 1 12 7 3 4 . 4 5 6 6 . 7 7 1 3 6 . 2 5 1 0 7 8 4 . 0 7 6 1 8 5 . 7 9 - 4 6 6 8 . 7 5 4 1 5 7. 8 5 1 . 4 0 12 8 2 6 . 0 1 6 7 . 3 3 1 3 6 . 9 7 1 0 8 1 9 . 7 8 6 2 6 9 . 5 4 - 4 7 3 0 . 0 2 4 2 1 5. 7 7 0 . 9 5 12 9 1 5 . 0 0 6 5 . 0 6 1 3 7 . 9 1 1 0 8 5 5 . 6 9 6 3 5 0 . 2 6 - 4 7 8 9 . 9 8 4 2 7 0. 8 3 2 . 7 3 12 9 3 9 . 7 8 6 5 . 9 6 1 3 7 . 2 9 1 0 8 6 5 . 9 6 6 3 7 2 . 6 2 - 4 8 0 6 . 6 3 4 2 8 6. 0 4 4 . 2 9 13 0 3 5 . 4 6 6 4 . 5 9 1 3 4 . 8 6 1 0 9 0 5 . 9 9 6 4 5 9 . 0 2 - 4 8 6 9 . 2 2 4 3 4 6. 3 2 2 . 7 2 13 1 3 0 . 1 7 6 2 . 0 7 1 3 2 . 3 7 1 0 9 4 8 . 5 0 6 5 4 3 . 4 7 - 4 9 2 7 . 6 1 4 4 0 7. 5 6 3 . 5 5 13 2 2 3 . 3 9 5 9 . 7 1 1 2 9 . 7 9 1 0 9 9 3 . 8 5 6 6 2 4 . 8 8 - 4 9 8 1 . 1 3 4 4 6 8. 9 3 3 . 5 0 13 3 1 4 . 9 3 5 6 . 5 5 1 2 7 . 1 1 1 1 0 4 2 . 1 9 6 7 0 2 . 5 7 - 5 0 2 9 . 4 9 4 5 2 9. 7 8 4 . 2 5 13 4 1 2 . 3 7 5 3 . 4 3 1 2 5 . 3 8 1 1 0 9 8 . 0 8 6 7 8 2 . 2 0 - 5 0 7 6 . 6 8 4 5 9 4. 1 2 3 . 5 2 13 5 0 4 . 3 9 5 1 . 1 2 1 2 5 . 0 5 1 1 1 5 4 . 3 9 6 8 5 4 . 7 3 - 5 1 1 8 . 6 5 4 6 5 3. 5 7 2 . 5 3 13 5 9 8 . 7 0 4 8 . 8 8 1 2 3 . 2 6 1 1 2 1 5 . 0 1 6 9 2 6 . 5 9 - 5 1 5 9 . 2 2 4 7 1 3. 3 4 2 . 7 8 13 6 9 4 . 5 5 4 7 . 0 2 1 2 1 . 7 3 1 1 2 7 9 . 2 0 6 9 9 7 . 1 5 - 5 1 9 7 . 4 7 4 7 7 3. 3 6 2 . 2 7 13 7 8 7 . 4 4 4 7 . 1 9 1 2 2 . 3 4 1 1 3 4 2 . 4 3 7 0 6 4 . 5 5 - 5 2 3 3 . 5 6 4 8 3 1. 0 5 0 . 5 1 13 8 8 2 . 5 0 4 9 . 2 4 1 2 1 . 4 0 1 1 4 0 5 . 7 7 7 1 3 4 . 7 2 - 5 2 7 0 . 9 8 4 8 9 1. 2 4 2 . 2 8 13 9 7 7 . 7 9 5 0 . 7 0 1 1 9 . 5 3 1 1 4 6 7 . 0 6 7 2 0 6 . 6 7 - 5 3 0 7 . 9 6 4 9 5 4. 1 3 2 . 1 5 14 0 7 2 . 7 7 5 2 . 5 3 1 1 9 . 4 3 1 1 5 2 6 . 0 4 7 2 7 9 . 8 7 - 5 3 4 4 . 5 9 5 0 1 8. 9 4 1 . 9 3 14 1 6 7 . 6 8 5 4 . 9 7 1 1 9 . 9 1 1 1 5 8 2 . 1 5 7 3 5 5 . 1 7 - 5 3 8 2 . 4 8 5 0 8 5. 4 4 2 . 6 0 14 2 6 1 . 3 5 5 4 . 7 2 1 1 8 . 8 7 1 1 6 3 6 . 0 9 7 4 3 0 . 4 4 - 5 4 2 0 . 0 7 5 1 5 2. 1 7 0 . 9 5 14 3 5 5 . 2 5 5 1 . 8 0 1 1 7 . 6 0 1 1 6 9 2 . 2 5 7 5 0 4 . 1 1 - 5 4 5 5 . 6 7 5 2 1 8. 4 4 3 . 2 9 14 4 4 9 . 1 0 5 1 . 4 9 1 1 6 . 0 4 1 1 7 5 0 . 4 9 7 5 7 5 . 7 7 - 5 4 8 8 . 8 8 5 2 8 4. 1 2 1 . 3 4 14 5 4 2 . 3 5 5 1 . 2 0 1 1 5 . 7 1 1 1 8 0 8 . 7 4 7 6 4 6 . 3 9 - 5 5 2 0 . 6 6 5 3 4 9. 6 4 0 . 4 2 14 6 3 7 . 7 4 5 3 . 6 3 1 1 7 . 4 7 1 1 8 6 6 . 9 2 7 7 1 9 . 9 2 - 5 5 5 4 . 5 1 5 4 1 7. 2 1 2 . 9 4 14 7 3 2 . 0 3 5 6 . 7 0 1 1 7 . 9 7 1 1 9 2 0 . 7 7 7 7 9 5 . 5 4 - 5 5 9 0 . 5 1 5 4 8 5. 7 1 3 . 2 8 14 8 2 4 . 6 7 5 2 . 9 6 1 1 5 . 4 4 1 1 9 7 4 . 1 3 7 8 6 9 . 2 4 - 5 6 2 4 . 5 6 5 5 5 3. 3 3 4 . 6 1 14 9 1 9 . 6 3 4 9 . 9 8 1 1 2 . 5 3 1 2 0 3 3 . 2 8 7 9 4 0 . 6 3 - 5 6 5 4 . 7 9 5 6 2 1. 1 6 3 . 9 5 15 0 1 4 . 7 3 4 7 . 1 3 1 0 9 . 0 6 1 2 0 9 6 . 2 4 8 0 0 7 . 9 5 - 5 6 8 0 . 1 3 5 6 8 7. 7 6 4 . 0 6 15 1 0 8 . 8 3 4 5 . 8 1 1 0 6 . 1 8 1 2 1 6 1 . 0 5 8 0 7 1 . 0 4 - 5 7 0 0 . 7 9 5 7 5 2. 7 6 2 . 6 2 15 2 0 2 . 9 6 4 2 . 8 2 9 9 . 0 1 1 2 2 2 8 . 4 4 8 1 2 9 . 3 9 - 5 7 1 5 . 2 2 5 8 1 6 .8 2 6 . 1 9 Co o k I n l e t E n e r g y RU - 5 B 27 Me a s u r e d De p t h In c l i n a t i o n A z i m u t h T V D Ve r t i c a l Se c t i o n +NS - + E W - D L S ( f t ) ( d e g ) ( d e g ) ( f t ) ( f t ) ( f t ) ( f t ) ( de g / 1 0 0 f t ) 15 2 9 7 . 0 4 4 1 . 4 7 9 0 . 9 2 1 2 2 9 8 . 2 4 8 1 8 1 . 0 4 - 5 7 2 0 . 7 3 5 8 7 9 .6 0 5 . 9 4 15 3 9 0 . 4 6 4 0 . 0 3 8 4 . 8 6 1 2 3 6 9 . 0 4 8 2 2 6 . 2 8 - 5 7 1 8 . 5 4 5 9 4 0 .4 8 4 . 5 0 15 4 8 5 . 5 7 3 8 . 7 2 7 8 . 2 6 1 2 4 4 2 . 5 9 8 2 6 6 . 3 1 - 5 7 0 9 . 7 4 6 0 0 0 .1 0 4 . 6 1 15 5 8 0 . 2 0 3 5 . 1 0 7 2 . 1 6 1 2 5 1 8 . 2 7 8 2 9 9 . 1 5 - 5 6 9 5 . 3 7 6 0 5 5 .0 1 5 . 4 4 15 6 7 3 . 9 8 3 2 . 2 4 6 5 . 9 0 1 2 5 9 6 . 3 3 8 3 2 4 . 4 6 - 5 6 7 6 . 8 9 6 1 0 3 .5 3 4 . 7 9 15 6 8 6 . 0 3 3 1 . 3 9 6 4 . 8 7 1 2 6 0 6 . 5 7 8 3 2 7 . 1 9 - 5 6 7 4 . 2 4 6 1 0 9 .3 1 8 . 3 7 15 7 5 0 . 0 0 3 1 . 3 9 6 4 . 8 7 1 2 6 6 1 . 1 8 8 3 4 1 . 2 1 - 5 6 6 0 . 0 9 6 1 3 9 .4 7 0 . 0 0 Co o k I n l e t E n e r g y RU - 5 B 28 4. 3 M U D R E C O R D C o n t r a c t o r : H a l l i b u r t o n / B a r o i d M u d T y p e : E n v i r o m u l O i l B a s e M u d ( 1 2 9 1 5 ’ t o 1 5 7 5 0 ’ ) DA T E D E P T H MW V I S PV YP GE L S FL FC S O L I D S OI L / W A T E R SA N D E. S T A B Lime 8/ 2 7 / 2 0 1 3 12 9 3 0 9 . 1 0 75 2 4 1 5 9 / 1 1 / 1 3 5 . 2 0/ 2 5. 8 6 0 . 5 / 3 1 . 5 0 . 1 0 3 0 7 5 . 0 5 8/ 2 8 / 2 0 1 3 12 9 3 0 9 . 1 + 73 2 2 1 6 7 / 9 / 1 0 3 . 6 0/ 2 5. 3 6 0 . 5 / 3 2 . 0 0 . 1 0 2 6 1 3 . 8 8 8/ 2 9 / 2 0 1 3 12 9 5 1 9 . 2 0 73 2 4 1 6 8 / 1 0 / 1 2 3 . 6 0/ 2 5. 3 6 0 . 5 / 3 2 . 0 0 . 1 0 2 6 0 3 . 8 8 8/ 3 0 / 2 0 1 3 13 1 3 8 9 . 3 0 78 3 3 2 0 9 / 1 2 / 1 4 3 . 2 0/ 2 5. 9 6 0 . 5 / 3 1 . 5 0 . 1 0 2 7 4 6 . 3 5 8/ 3 1 / 2 0 1 3 13 7 0 4 9 . 3 0 79 2 6 1 8 1 2 / 1 8 / 1 9 2. 2 0/ 2 6. 4 6 2 . 5 / 2 8 . 0 0 . 1 0 3 5 7 5 . 8 3 9/ 1 / 2 0 1 3 1 4 0 4 0 9 . 3 0 79 3 1 1 9 1 4 / 1 7 / 1 9 2. 2 0/ 2 6. 2 6 4 . 0 / 2 7 . 0 0 . 1 0 42 1 5 . 8 3 9/ 2 / 2 0 1 3 1 4 0 4 0 9 . 4 0 76 2 7 1 9 1 2 / 1 5 / 1 8 2. 0 0/ 2 6. 7 6 4 . 0 / 2 6 . 5 0 . 1 0 48 5 5 . 8 3 9/ 3 / 2 0 1 3 1 4 0 4 0 9 . 3 0 74 2 6 1 8 1 2 / 1 4 / 1 7 2. 4 0/ 2 6. 9 6 5 . 0 / 2 5 . 5 0 . 1 0 47 9 5 . 5 7 9/ 4 / 2 0 1 3 1 4 0 4 0 9 . 2 + 72 3 0 1 9 1 2 / 1 5 / 1 8 2. 2 0/ 2 6. 4 6 4 . 5 / 2 6 . 5 0 . 1 0 47 0 5 . 1 8 9/ 5 / 2 0 1 3 1 4 8 8 7 9 . 3 0 72 2 8 1 9 1 2 / 1 5 / 1 7 2. 2 0/ 2 6. 3 6 5 . 0 / 2 6 . 5 0 . 1 0 5 3 2 5 . 3 1 9/ 6 / 2 0 1 3 1 5 4 5 3 9 . 3 0 72 2 7 1 9 1 2 / 1 5 / 1 7 2. 2 0/ 2 6. 6 6 4 . 5 / 2 6 . 5 0 . 1 0 5 1 6 4 . 5 3 9/ 7 / 2 0 1 3 1 5 7 5 0 9 . 3 0 82 2 8 1 9 1 2 / 1 4 / 1 6 2. 2 0/ 2 5. 9 6 4 . 5 / 2 7 . 0 0 . 1 0 5 0 6 4 . 1 4 9/ 8 / 2 0 1 3 1 5 7 5 0 9 . 4 5 83 2 6 1 9 1 1 / 1 3 / 1 5 2. 2 0/ 2 6. 6 6 4 . 5 / 2 6 . 5 0 . 1 0 5 2 5 4 . 0 1 9/ 9 / 2 0 1 3 1 5 7 5 0 9 . 4 0 72 2 6 1 8 1 1 / 1 4 / 1 6 2. 2 0/ 2 6. 4 6 4 . 5 / 2 6 . 5 0 . 1 0 5 2 0 4 . 0 1 9/ 1 0 / 2 0 1 3 15 7 5 0 9 . 4 0 64 2 5 1 2 9 / 1 2 / 1 4 2 . 2 0/ 2 6. 3 6 4 . 5 / 2 6 . 5 0 . 1 0 4 7 7 3 . 8 8 9/ 1 1 / 2 0 1 3 15 7 5 0 9 . 4 0 67 2 5 1 3 9 / 1 2 / 1 5 2 . 2 0/ 2 6. 3 6 4 . 5 / 2 6 . 5 0 . 1 0 4 7 1 3 . 8 8 9/ 1 2 / 2 0 1 3 15 7 5 0 9 . 4 7 0 2 5 1 3 9 / 1 2 / 1 5 2 . 2 0/ 2 6. 3 6 4 . 5 / 2 6 . 5 0 . 1 0 4 7 0 3 . 8 8 Co o k I n l e t E n e r g y RU - 5 B 29 4. 4 B I T R E C O R D BI T NO SI Z E MA K E TY P E S / N JE T S (T F A ) IN O U T F E E T H O U R S AV E RO P WO B C O N D I T I O N 0 6 - 3 / 4 ” W h i p s t o c k M i l l 1 2 9 1 5 ’ 1 2 9 3 2 ’ 1 7 ’ 6 . 5 2 . 6 1 6 - 3 / 4 ” H u g h e s M X - 7 5 2 0 1 3 5 3 3 x 1 8 1 2 9 3 2 ’ 1 2 9 5 1 ’ 1 9 ’ 4 . 0 4 . 8 1 - 3 - W T - A - E - 1 - S D - B H A 2 6 - 3 / 4 ” H u g h e s D P 5 0 5 X 7 1 4 6 5 3 7 3 x 1 6 , 2 x 1 8 1 2 9 5 1 ’ 1 4 03 8 ’ 1 0 8 7 ’ 3 6 . 7 2 9 . 6 2 1 . 5 0 - 1 - C T - T - X - I - R R - P R 3 6 - 3 / 4 ” H D B S E M 6 5 D 1 2 2 7 3 6 8 9 6 x 1 2 1 4 0 3 8 ’ 1 5 7 5 0 ’ 1 7 1 2’ 5 7 . 4 2 9 . 8 2 1 . 4 3 - 5 - B T - G - X - 1 - W T - T D Cook Inlet Energy RU-5B 30 5 DAILY REPORTS DATE: TIME: PRESENT OPERATION: PRESENT DEPTH: DEPTH YESTERDAY: SAMPLE DEPTH: 24 HOUR FOOTAGE: REPORT FOR: & @ @ @ BIT DATA MWD/LWD SUMMARY to MUD REPORT HIGH LOW AVERAGE CURRENT AVG @ @ @ @ @ @ @ @ @ @ @ @ HIGH LOW AVERAGE TRIP = @ @ WIPER= Zone Gas (Range) = Survey Gas (Range) = AIR-Kelly Cut Gas (Range) = Down Time, Downlink (Range) = @ @ HIGH = @ @ AVG = @ @ Current = @ @ AVG = @ @ Background = LITHOLOGY LAG SUMMARY bbl // @ SPM / @ PERSONNEL REPORT BY Current Formation: Current Lithology% : General Lithology: LITHOLOGY/REMARKS INCLINATION MUD TYPE: INTERVAL Cake I-O-Char-Loc-B-G-Pull 5.8% Sol OF VIS SURVEY DATA 15 DEPTH 75 0 DAILY WELLSITE REPORT 5.05 5.2 YP Gels 7,301' RU-5B Type 1 Size 6.13 ''SMITH FH16H BHA TYPE: Milling Assembly CASING DATA Cook Inlet Energy Osprey DEPTH: INTERVAL: 13.375 '' No. FT/HR N/A E-Stab FT/LBS N/A 9.1 Salt DRILLING PARAMETERS GAS SUMMARY (units) 75 CURRENT 15 15 OIL DESCRIPTION MW 13.87 RATE OF PENETRATION SURFACE TORQUE 61% Oil PV ETHANE (C-2) PROPANE (C-3) CONNECTION WEIGHT ON BIT GAS FLOW IN CIRCULATING GAS 16 POM BUTANE (C-4) PENTANE (C-5) HYDROCARBON SHOWS 24 KLBS Lime 32% Cl- N/A Oil/H2O RPM PSI N/A TOPDRIVE RPM N/A PUMP PRESSURE 19.0 GPM N/A Jessen, Todd 7.625 ''12,930' 307 Hours 97 2 TOOLS: Flowline Temp: 9/11/13 FL 11,500' Footage IN OUT 24:00 CONDITION 12,930' Milling Window 12,928' Cretsinger, Carlos 2' 8/28/13 12,930' 12,928' 3,190'9.625 '' JETS 3X16 S/N TVD AZIMUTH Oil +N/S- COORDINATES +E/W- ' MUD BASE: Enviromul Tyler Dretke $2,500 Continue wireline Operations, Set CIBP @ 12928', R/D wireline, P/U whipstock and RIH t/ 12928'. Set whipstock and begin milling window in 7.625" casing. 12930'43 min 90 3903 Tyler Dretke, Ben Handley strokes 389 % Theoretical 100% 0 0 DAILY COST CHROMATOGRAPHY (ppm) Annular Volume DAILY ACTIVITY SUMMARY METHANE (C-1) DATE: TIME: PRESENT OPERATION: PRESENT DEPTH: DEPTH YESTERDAY: SAMPLE DEPTH: 24 HOUR FOOTAGE: REPORT FOR: & @ @ @ BIT DATA MWD/LWD SUMMARY to MUD REPORT HIGH LOW AVERAGE CURRENT AVG @ @ @ @ @ @ @ @ @ @ @ @ HIGH LOW AVERAGE TRIP = @ @ WIPER= Zone Gas (Range) = Survey Gas (Range) = AIR-Kelly Cut Gas (Range) = Down Time, Downlink (Range) = @ @ HIGH = @ @ AVG = @ @ Current = @ @ AVG = @ @ Background = LITHOLOGY LAG SUMMARY bbl // @ SPM / @ PERSONNEL REPORT BY 0 0 DAILY COST CHROMATOGRAPHY (ppm) Annular Volume DAILY ACTIVITY SUMMARY METHANE (C-1) strokes 701 % Theoretical 100% Tyler Dretke $2,500 Continue milling window to 12935', pump sweep and circulate, POOH to check bit, RIH w/ new bit, mill F/12923' T/12930'. 12930'98 min 72 7033 Tyler Dretke, Ben Handley TVD AZIMUTH Oil +N/S- COORDINATES +E/W- ' MUD BASE: Enviromul 12,928' 3,190'9.625 '' JETS 3X16 S/N 24:00 CONDITION 12,930' Milling Window 12,930' Cretsinger, Carlos 0' 8/28/13 12,930' 11,500' Footage IN OUT 7' 12,932' 12,935' 2 TOOLS: Flowline Temp: 7/9/10 FL Jessen, Todd 7.625 ''12,930' 261 Hours 10.0 GPM N/A RPM PSI N/A TOPDRIVE RPM N/A PUMP PRESSURE 22 KLBS Lime 32% Cl- N/A Oil/H2O POM BUTANE (C-4) PENTANE (C-5) HYDROCARBON SHOWS FLOW IN CIRCULATING GAS 0 WEIGHT ON BIT GAS CONNECTION ETHANE (C-2) PROPANE (C-3) MW 13.87 RATE OF PENETRATION SURFACE TORQUE 61% Oil PV CURRENT 0 4 OIL DESCRIPTION 18 9.15 Salt DRILLING PARAMETERS GAS SUMMARY (units) FT/HR N/A E-Stab FT/LBS N/A Cook Inlet Energy Osprey DEPTH: INTERVAL: 13.375 '' No. Type 1 Size 6.13 ''SMITH FH16H BHA TYPE: Milling Assembly CASING DATA DAILY WELLSITE REPORT 3.88 3.6 YP Gels 12,930' RU-5B 0 VIS SURVEY DATA 3x16 16 DEPTH 2 73 Cake I-O-Char-Loc-B-G-Pull 5.8% Sol OF LITHOLOGY/REMARKS SMITH FH16H INCLINATION MUD TYPE: INTERVAL 6.75 '' Current Formation: Current Lithology% : General Lithology: DATE: TIME: PRESENT OPERATION: PRESENT DEPTH: DEPTH YESTERDAY: SAMPLE DEPTH: 24 HOUR FOOTAGE: REPORT FOR: & @ @ @ BIT DATA MWD/LWD SUMMARY to MUD REPORT HIGH LOW AVERAGE CURRENT AVG @ @ @ @ @ @ @ @ @ @ @ @ HIGH LOW AVERAGE TRIP = @ @ WIPER= Zone Gas (Range) = Survey Gas (Range) = AIR-Kelly Cut Gas (Range) = Down Time, Downlink (Range) = @ @ HIGH = @ @ AVG = @ @ Current = @ @ AVG = @ @ Background = LITHOLOGY LAG SUMMARY bbl // @ SPM / @ PERSONNEL REPORT BY DAILY COST CHROMATOGRAPHY (ppm) Annular Volume DAILY ACTIVITY SUMMARY METHANE (C-1) strokes 701 % Theoretical 100% Tyler Dretke $2,500 Continue milling window and drilling rat hole to 12951', perform FIT to 12.0 ppg EMW, POOH and begin picking up directional BHA. 12951'78 min 90 7034 Tyler Dretke, Ben Handley TVD AZIMUTH Oil +N/S- COORDINATES +E/W- ' MUD BASE: Enviromul 12,951' 3,190'9.625 '' JETS 3x16 2x18 7146537 S/N 24:00 CONDITION 12,951' Make Up BHA 12,930' George Brewster 21' 8/29/13 12,951' 11,500' Footage IN OUT 97 2 TOOLS: Flowline Temp: 8/10/13 FL Aaron Penini 7.625 ''12,930' 260 Hours 6.0 GPM N/A RPM PSI N/A TOPDRIVE RPM N/A PUMP PRESSURE 24 KLBS Lime 32% Cl- N/A Oil/H2O POM BUTANE (C-4) PENTANE (C-5) HYDROCARBON SHOWS FLOW IN CIRCULATING GAS 0 WEIGHT ON BIT GAS CONNECTION ETHANE (C-2) PROPANE (C-3) MW 13.87 RATE OF PENETRATION SURFACE TORQUE 61% Oil PV CURRENT 0 0 OIL DESCRIPTION 10 9.2 Salt DRILLING PARAMETERS GAS SUMMARY (units) FT/HR N/A E-Stab FT/LBS N/A Cook Inlet Energy Osprey DEPTH: INTERVAL: 13.375 '' No. Type 2 Size 6.75 ''Hughes PDC DP505x BHA TYPE: Directional Assembly CASING DATA DAILY WELLSITE REPORT 3.88 3.6 YP Gels 7,301' RU-5B VIS SURVEY DATA 16 DEPTH 73 Cake I-O-Char-Loc-B-G-Pull 5.3% Sol OF LITHOLOGY/REMARKS INCLINATION MUD TYPE: INTERVAL Current Formation: Current Lithology% : General Lithology: DATE: TIME: PRESENT OPERATION: PRESENT DEPTH: DEPTH YESTERDAY: SAMPLE DEPTH: 24 HOUR FOOTAGE: REPORT FOR: & @ @ @ BIT DATA MWD/LWD SUMMARY to MUD REPORT HIGH LOW AVERAGE CURRENT AVG @ @ @ @ @ @ @ @ @ @ @ @ HIGH LOW AVERAGE TRIP = @ @ WIPER= @ @ Zone Gas (Range) = Survey Gas (Range) = AIR-Kelly Cut Gas (Range) = Down Time, Downlink (Range) = @ @ HIGH = @ @ AVG = @ @ Current = @ @ AVG = @ @ Background = LITHOLOGY LAG SUMMARY bbl // @ SPM / @ PERSONNEL REPORT BY 8039 12,989'0 Slide 0 0 DAILY COST CHROMATOGRAPHY (ppm) Annular Volume DAILY ACTIVITY SUMMARY 13,041'3 METHANE (C-1) 13,041'37 36 13,064' 7 strokes 705 % Theoretical 100% 12,826' Tyler Dretke $2,500 Continue milling window and drilling rat hole to 12951', perform FIT to 12.0 ppg EMW, POOH and begin picking up directional BHA. 13114'99 min 77 7637 Tyler Dretke, Ben Handley TVD AZIMUTH Oil +N/S- COORDINATES +E/W- ' 10,855.69' MUD BASE: Enviromul 4,270.83' E 12,951' 3,190'9.625 '' JETS 3x16 2x18 7146537 S/N 24:00 CONDITION 13,140' DRILLING 12,951' George Brewster 189' 8/30/13 13,114' 11,500' Footage IN OUT 10,819.78' 97 2 TOOLS: Flowline Temp: 9/11/13 4,215.77' E 4,730.02' S FL Aaron Penini 13,064' 44.7 7.625 ''12,930' 274 Hours 13,064' 287 13,001'293 5.8 GPM 293 RPM PSI 3925 TOPDRIVE RPM 26 PUMP PRESSURE 27 KLBS Lime 129.6 32% 0.0 Cl- 16.8 Oil/H2O POM BUTANE (C-4) PENTANE (C-5) HYDROCARBON SHOWS 13,113' 13,040' CUTTINGS GAS FLOW IN DITCH GAS 0 13,113'54.6 WEIGHT ON BIT 0.7 32 13,111' GAS 13,054' 0 CONNECTION 282 ETHANE (C-2) PROPANE (C-3) 156 1111 16 151 302 MW 10.81 RATE OF PENETRATION SURFACE TORQUE 61% Oil PV 551 13,041' 13,047' 9 382 88 129 CURRENT 0 0 OIL DESCRIPTION 13,041' 13,064'3 13,064' 25 13,064' 9.3 Salt 12.0 13,050' DRILLING PARAMETERS GAS SUMMARY (units) FT/HR 7068 E-Stab FT/LBS 13,097'48.8 7580 Cook Inlet Energy Osprey DEPTH: INTERVAL: 65.06° 13.375 '' No. Type 2 Size 6.75 ''Hughes PDC DP505x BHA TYPE: Directional Assembly CASING DATA DAILY WELLSITE REPORT 6.35 3.2 YP 137.91° Gels 136.97° 7,301' RU-5B 0 0 Slide 25 3635 3889 13,057' VIS SURVEY DATA 20 DEPTH 12,915' 72 Cake I-O-Char-Loc-B-G-Pull 4,789.98' S 6.3% Sol OF LITHOLOGY/REMARKS 4090 13,107' INCLINATION MUD TYPE: INTERVAL 67.33° Current Formation: Current Lithology% : General Lithology: Sand, Tuffaceous Siltstone, Tuffaceous Claystone, Coal 50% Sand, 20% Tuffaceous Siltstone, 20% Tuffaceous Claystone, 10% Coal DATE: TIME: PRESENT OPERATION: PRESENT DEPTH: DEPTH YESTERDAY: SAMPLE DEPTH: 24 HOUR FOOTAGE: REPORT FOR: & @ @ @ BIT DATA MWD/LWD SUMMARY to MUD REPORT HIGH LOW AVERAGE CURRENT AVG @ @ @ @ @ @ @ @ @ @ @ @ HIGH LOW AVERAGE TRIP = @ @ WIPER= @ @ Zone Gas (Range) = Survey Gas (Range) = AIR-Kelly Cut Gas (Range) = Down Time, Downlink (Range) = @ @ HIGH = @ @ AVG = @ @ Current = @ @ AVG = @ @ Background = LITHOLOGY LAG SUMMARY bbl // @ SPM / @ PERSONNEL REPORT BY Sand, Tuffaceous Siltstone, Tuffaceous Claystone, Coal 30% Sand, 40% Tuffaceous Siltstone, 30% Tuffaceous Claystone Current Formation: Current Lithology% : General Lithology: LITHOLOGY/REMARKS 4326 13,237' INCLINATION MUD TYPE: INTERVAL 51.12° Cake I-O-Char-Loc-B-G-Pull 5,029.49' S 6.4% Sol OF VIS SURVEY DATA 18 DEPTH 13,598' 79 0 0 Slide 67 3458 3885 13,606' DAILY WELLSITE REPORT 5.83 2.2 YP 123.26° Gels 125.05° 7,301' RU-5B Type 2 Size 6.75 ''Hughes PDC DP505x BHA TYPE: Directional Assembly CASING DATA Cook Inlet Energy Osprey DEPTH: INTERVAL: 48.88° 13.375 '' No. FT/HR 4944 E-Stab FT/LBS 13,615'38.4 8333 9.3 Salt 19.8 13,308' DRILLING PARAMETERS GAS SUMMARY (units) 13,187' 13,381'0 13,249' 98 13,132' 31 34 CURRENT 15 20 OIL DESCRIPTION 122 13,373' 13,372' 4 98 310 MW 13.16 RATE OF PENETRATION SURFACE TORQUE 63% Oil PV ETHANE (C-2) PROPANE (C-3) 37 13113 907 69 0 CONNECTION 2672 WEIGHT ON BIT 2.7 80 13,662' GAS 13,577' 13,555' CUTTINGS GAS FLOW IN DITCH GAS 6 13,634'75.4 POM BUTANE (C-4) PENTANE (C-5) HYDROCARBON SHOWS 13,262' 26 KLBS Lime 272.2 28% 0.0 Cl- 41.5 Oil/H2O RPM PSI 3610 TOPDRIVE RPM 45 PUMP PRESSURE 13,659'299 22.6 GPM 292 Aaron Penini 13,248' 45.1 7.625 ''12,930' 357 Hours 13,121' 291 11,154.39' 112 2 TOOLS: Flowline Temp: 12/18/19 4,468.93' E 4,981.13' S FL 11,500' Footage IN OUT 24:00 CONDITION 13,704' DRILLING 13,140' George Brewster 564' 8/31/13 13,662' 12,951' 3,190'9.625 '' JETS 3x16 2x18 7146537 S/N TVD AZIMUTH Oil +N/S- COORDINATES +E/W- ' 11,215.01' MUD BASE: Enviromul 4,529.78' E 13,504' Tyler Dretke $2,500 Continue drilling F/ 13138' T/13704' with slides as needed. 13704'102 min 77 7821 Tyler Dretke, Ben Handley strokes 722 % Theoretical 100% 11 26 13,611' 4 0 0 DAILY COST CHROMATOGRAPHY (ppm) Annular Volume DAILY ACTIVITY SUMMARY 13,579'5 METHANE (C-1) 13,190' 9959 13,401'0 Slide DATE: TIME: PRESENT OPERATION: PRESENT DEPTH: DEPTH YESTERDAY: SAMPLE DEPTH: 24 HOUR FOOTAGE: REPORT FOR: & @ @ @ BIT DATA MWD/LWD SUMMARY to MUD REPORT HIGH LOW AVERAGE CURRENT AVG @ @ @ @ @ @ @ @ @ @ @ @ HIGH LOW AVERAGE TRIP = @ @ WIPER= @ @ Zone Gas (Range) = Survey Gas (Range) = AIR-Kelly Cut Gas (Range) = Down Time, Downlink (Range) = @ @ HIGH = @ @ AVG = @ @ Current = @ @ AVG = @ @ Background = LITHOLOGY LAG SUMMARY bbl // @ SPM / @ PERSONNEL REPORT BY 9493 13,938'0 Slide 0 0 DAILY COST CHROMATOGRAPHY (ppm) Annular Volume DAILY ACTIVITY SUMMARY 13,870'12 METHANE (C-1) 13,954'12 37 13,765' 0 strokes 731 % Theoretical 100% 13,882' Tyler Dretke $2,500 Continue drilling ahead F/13704' T/13780', Slide F/13780' T/14038', Circulate bottoms up and pump pill. 14038'103 min 77 7918 Tyler Dretke, Ben Handley TVD AZIMUTH Oil +N/S- COORDINATES +E/W- ' 11,463.63' MUD BASE: Enviromul 4,831.05' E 12,951' 3,190'9.625 '' JETS 3x16 2x18 7146537 S/N 24:00 CONDITION 14,038' Reaming 13,704' George Brewster 334' 9/1/13 14,038' 11,500' Footage IN OUT 11,405.77' 112 2 TOOLS: Flowline Temp: 14/17/19 4,773.36' E 5,197.47' S FL Aaron Penini 13,733' 41.1 7.625 ''12,930' 421 Hours 13,824' 275 14,007'297 31.5 GPM 293 RPM PSI 3709 TOPDRIVE RPM 19 PUMP PRESSURE 31 KLBS Lime 181.5 27% 0.0 Cl- 49.3 Oil/H2O POM BUTANE (C-4) PENTANE (C-5) HYDROCARBON SHOWS 13,870' 13,886' CUTTINGS GAS FLOW IN DITCH GAS 14 14,026'62.1 WEIGHT ON BIT 10.1 79 13,774' GAS 13,994' 0 CONNECTION 4316 ETHANE (C-2) PROPANE (C-3) 31 9992 1704 99 310 MW 20.82 RATE OF PENETRATION SURFACE TORQUE 64% Oil PV 39 13,703' 13,703' 0 41 14 11 CURRENT 10 20 OIL DESCRIPTION 13,870' 13,799'0 13,799' 72 13,824' 9.3 Salt 22.9 13,851' DRILLING PARAMETERS GAS SUMMARY (units) FT/HR 2508 E-Stab FT/LBS 14,032'30.5 8800 Cook Inlet Energy Osprey DEPTH: INTERVAL: 50.87° 13.375 '' No. Type 2 Size 6.75 ''Hughes PDC DP505x BHA TYPE: Directional Assembly CASING DATA DAILY WELLSITE REPORT 5.83 2.2 YP 119.18° Gels 121.40° 7,301' RU-5B 0 0 Slide 73 3173 3783 13,995' VIS SURVEY DATA 19 DEPTH 13,973' 79 Cake I-O-Char-Loc-B-G-Pull 5,233.56' S 6.7% Sol OF LITHOLOGY/REMARKS 4249 13,992' INCLINATION MUD TYPE: INTERVAL 49.24° Current Formation: Current Lithology% : General Lithology: Sand, Sandstone, Tuffaceous Siltstone, Tuffaceous Claystone, Coal 40% Sandstone, 20% Sand, 30% Tuffaceous Siltstone, 10% Tuffaceous Claystone DATE: TIME: PRESENT OPERATION: PRESENT DEPTH: DEPTH YESTERDAY: SAMPLE DEPTH: 24 HOUR FOOTAGE: REPORT FOR: & @ @ @ BIT DATA MWD/LWD SUMMARY to MUD REPORT HIGH LOW AVERAGE CURRENT AVG @ @ @ @ @ @ @ @ @ @ @ @ HIGH LOW AVERAGE TRIP = @ @ WIPER= @ @ Zone Gas (Range) = Survey Gas (Range) = AIR-Kelly Cut Gas (Range) = Down Time, Downlink (Range) = @ @ HIGH = @ @ AVG = @ @ Current = @ @ AVG = @ @ Background = LITHOLOGY LAG SUMMARY bbl // @ SPM / @ PERSONNEL REPORT BY 0 0 DAILY COST CHROMATOGRAPHY (ppm) Annular Volume DAILY ACTIVITY SUMMARY METHANE (C-1) strokes 731 % Theoretical 100% 13,882' Tyler Dretke $2,500 Backream out F/14038', T/12293', Pump out of the 7 5/8" liner to 11290', pump dry job and POOH. 14038'103 min 77 7918 Tyler Dretke, Ben Handley TVD AZIMUTH Oil +N/S- COORDINATES +E/W- ' 11,463.63' MUD BASE: Enviromul 4,831.05' E 12,951' 3,190'9.625 '' JETS 3x16 2x18 7146537 S/N 24:00 CONDITION 14,038' Make Up BHA 14,038' George Brewster 0' 9/2/13 14,038' 11,500' Footage IN OUT 11,405.77' 112 2 TOOLS: Flowline Temp: 12/15/18 4,773.36' E 5,197.47' S FL Aaron Penini 7.625 ''12,930' 485 Hours 30.0 GPM N/A RPM PSI N/A TOPDRIVE RPM N/A PUMP PRESSURE 27 KLBS Lime 27% Cl- N/A Oil/H2O POM BUTANE (C-4) PENTANE (C-5) HYDROCARBON SHOWS CUTTINGS GAS FLOW IN CIRCULATING GAS 10 WEIGHT ON BIT GAS CONNECTION ETHANE (C-2) PROPANE (C-3) MW 12.32 RATE OF PENETRATION SURFACE TORQUE 64% Oil PV CURRENT 0 0 OIL DESCRIPTION 45 9.4 Salt DRILLING PARAMETERS GAS SUMMARY (units) FT/HR N/A E-Stab FT/LBS N/A Cook Inlet Energy Osprey DEPTH: INTERVAL: 50.87° 13.375 '' No. Type 2 Size 6.75 ''Hughes PDC DP505x BHA TYPE: Directional Assembly CASING DATA DAILY WELLSITE REPORT 5.83 2.0 YP 119.18° Gels 121.40° 7,301' RU-5B 0 VIS SURVEY DATA 19 DEPTH 13,973' 74 Cake I-O-Char-Loc-B-G-Pull 5,233.56' S 6.7% Sol OF LITHOLOGY/REMARKS INCLINATION MUD TYPE: INTERVAL 49.24° Current Formation: Current Lithology% : General Lithology: Sand, Sandstone, Tuffaceous Claystone, Tuffaceous Siltstone, Coal 40% Sandstone, 20% Sand, 30% Tuffaceous Siltstone, 10% Tuffaceous Claystone DATE: TIME: PRESENT OPERATION: PRESENT DEPTH: DEPTH YESTERDAY: SAMPLE DEPTH: 24 HOUR FOOTAGE: REPORT FOR: & @ @ @ BIT DATA MWD/LWD SUMMARY to MUD REPORT HIGH LOW AVERAGE CURRENT AVG @ @ @ @ @ @ @ @ @ @ @ @ HIGH LOW AVERAGE TRIP = @ @ WIPER= @ @ Zone Gas (Range) = Survey Gas (Range) = AIR-Kelly Cut Gas (Range) = Down Time, Downlink (Range) = @ @ HIGH = @ @ AVG = @ @ Current = @ @ AVG = @ @ Background = LITHOLOGY LAG SUMMARY bbl // @ SPM / @ PERSONNEL REPORT BY Tuffaceous Sandstone, Tuffaceous Claystone, Tuffaceous Siltstone, Sand, Coal 60% Tuffaceous Sandstone, 20% Sand, 10%Tuffaceous Claystone, 10% Tuffaceous Siltstone Current Formation: Current Lithology% : General Lithology: LITHOLOGY/REMARKS HDBS EM65D 4182 14,093' INCLINATION MUD TYPE: INTERVAL 6.75 '' 54.97° Cake I-O-Char-Loc-B-G-Pull 5,344.59' S 0-1-CT-T-X-I-RR-PR 6.9% Sol OF VIS SURVEY DATA 6x12 18 DEPTH 14,073' 3 74 0 0 Slide 74 3478 3832 14,156' DAILY WELLSITE REPORT 5.57 2.4 YP 119.43° Gels 119.91° 7,301' RU-5B Type 2 Size 6.75 ''Hughes PDC DP505x BHA TYPE: Directional Assembly CASING DATA Cook Inlet Energy Osprey DEPTH: INTERVAL: 52.53° 13.375 '' 12273689 No. FT/HR 6459 E-Stab FT/LBS 14,168'44.3 8850 9.3 Salt 22.9 14,041' DRILLING PARAMETERS GAS SUMMARY (units) 14,059' 14,169'0 14,039' 78 14,173' 2 4 CURRENT 30 40 OIL DESCRIPTION 13 14,123' 14,123' 0 8 298 MW 11.47 RATE OF PENETRATION SURFACE TORQUE 65% Oil PV ETHANE (C-2) PROPANE (C-3) 20 11372 3539 85 0 CONNECTION 6034 WEIGHT ON BIT 1.8 79 14,048' GAS 14,134' 14,087' CUTTINGS GAS FLOW IN DITCH GAS 25 14,173'58.3 POM BUTANE (C-4) PENTANE (C-5) HYDROCARBON SHOWS 14,125' 26 KLBS Lime 186.6 26% 0.0 Cl- 29.9 Oil/H2O RPM PSI 3688 TOPDRIVE RPM 54 PUMP PRESSURE 14,183'290 248u 41.3 GPM 289 Stephen Ratcliff 14,209' 54.2 7.625 ''12,930' 479 Hours 14,173' 283 11,582.15' 106 2 TOOLS: Flowline Temp: 12/14/17 7,355.17' E 5,382.48' S FL 11,500' Footage IN OUT 1,089' 14,040' 14,040' 24:00 CONDITION 14,265' DRILLING 14,038' Keith Carter 227' 9/3/13 14,220' 12,951' 3,190'9.625 '' JETS 3x16 2x18 7146537 S/N TVD AZIMUTH Oil +N/S- COORDINATES +E/W- ' 11,526.00' MUD BASE: Enviromul 4,954.13' E 14,167' Tyler Dretke $2,500 Finish picking up directional BHA, Surface test MWD tools, RIH T/12875', wash down tight spots f/12875 t/12905', RIH on elevators to 13420', RIH to 14040'. Drill f/14040' t/14265'. 14221'106 min 75 7983 Tyler Dretke, Ben Handley strokes 737 % Theoretical 100% 9 48 14,039' 0 0 0 DAILY COST CHROMATOGRAPHY (ppm) Annular Volume DAILY ACTIVITY SUMMARY 14,059'31 METHANE (C-1) 14,059' 9289 14,051'0 Slide DATE: TIME: PRESENT OPERATION: PRESENT DEPTH: DEPTH YESTERDAY: SAMPLE DEPTH: 24 HOUR FOOTAGE: REPORT FOR: & @ @ @ BIT DATA MWD/LWD SUMMARY to MUD REPORT HIGH LOW AVERAGE CURRENT AVG @ @ @ @ @ @ @ @ @ @ @ @ HIGH LOW AVERAGE TRIP = @ @ WIPER= @ @ Zone Gas (Range) = Survey Gas (Range) = AIR-Kelly Cut Gas (Range) = Down Time, Downlink (Range) = @ @ HIGH = @ @ AVG = @ @ Current = @ @ AVG = @ @ Background = LITHOLOGY LAG SUMMARY bbl // @ SPM / @ PERSONNEL REPORT BY 9918 14,380'0 Slide 0 0 DAILY COST CHROMATOGRAPHY (ppm) Annular Volume DAILY ACTIVITY SUMMARY 14,414'11 METHANE (C-1) 14,603'8 65 #N/A strokes 737 % Theoretical 100% 14,449' Tyler Dretke $2,500 Drill F/14265' T/14681' sliding as needed. 14221'106 min 75 7983 Tyler Dretke, Ben Handley TVD AZIMUTH Oil +N/S- COORDINATES +E/W- ' 11,808.74' MUD BASE: Enviromul 4,954.13' E 12,951' 3,190'9.625 '' JETS 3x16 2x18 7146537 S/N 24:00 CONDITION 14,681' DRILLING 14,265' Keith Carter 416' 9/4/13 14,654' 11,500' Footage IN OUT 1,089' 14,040' 14,040' 11,750.49' 106 2 TOOLS: Flowline Temp: 12/15/18 7,355.17' E 5,382.48' S FL Stephen Ratcliff 14,355' 40.9 7.625 ''12,930' 470 Hours 14,355' 283 14,450'294 31.1 GPM 295 RPM PSI 3878 TOPDRIVE RPM 15 PUMP PRESSURE 30 KLBS Lime 191.8 26% 0.0 Cl- 51.1 Oil/H2O POM BUTANE (C-4) PENTANE (C-5) HYDROCARBON SHOWS 14,340' 14,222' CUTTINGS GAS FLOW IN DITCH GAS 7 14,582'65.3 WEIGHT ON BIT 0.3 84 14,560' GAS 14,476' 0 CONNECTION 4329 ETHANE (C-2) PROPANE (C-3) 20 19155 1093 136 302 MW 11.47 RATE OF PENETRATION SURFACE TORQUE 65% Oil PV 0 0 0 0 CURRENT 22 25 OIL DESCRIPTION 14,339' 14,368'0 #N/A 119 14,355' 9.25 Salt 21.7 14,414' DRILLING PARAMETERS GAS SUMMARY (units) FT/HR 1838 E-Stab FT/LBS 14,619'22.7 9134 Cook Inlet Energy Osprey DEPTH: INTERVAL: 51.20° 13.375 '' 12273689 No. Type 2 Size 6.75 ''Hughes PDC DP505x BHA TYPE: Directional Assembly CASING DATA DAILY WELLSITE REPORT 5.18 2.2 YP 115.77° Gels 116.04° 7,301' RU-5B 0 0 Slide 72 3507 3850 14,417' VIS SURVEY DATA 6x12 19 DEPTH 14,542' 3 72 Cake I-O-Char-Loc-B-G-Pull 5,344.59' S 0-1-CT-T-X-I-RR-PR 6.4% Sol OF LITHOLOGY/REMARKS HDBS EM65D 4098 14,380' INCLINATION MUD TYPE: INTERVAL 6.75 '' 51.49° Current Formation: Current Lithology% : General Lithology: Tuffaceous Sandstone, Tuffaceous Claystone, Tuffaceous Siltstone, Sand, Coal 60% Tuffaceous Sandstone, 10% Sand, 10%Tuffaceous Claystone, 20% Tuffaceous Siltstone DATE: TIME: PRESENT OPERATION: PRESENT DEPTH: DEPTH YESTERDAY: SAMPLE DEPTH: 24 HOUR FOOTAGE: REPORT FOR: & @ @ @ BIT DATA MWD/LWD SUMMARY to MUD REPORT HIGH LOW AVERAGE CURRENT AVG @ @ @ @ @ @ @ @ @ @ @ @ HIGH LOW AVERAGE TRIP = @ @ WIPER= @ @ Zone Gas (Range) = Survey Gas (Range) = AIR-Kelly Cut Gas (Range) = Down Time, Downlink (Range) = @ @ HIGH = @ @ AVG = @ @ Current = @ @ AVG = @ @ Background = LITHOLOGY LAG SUMMARY bbl // @ SPM / @ PERSONNEL REPORT BY Tuffaceous Sandstone, Tuffaceous Claystone, Tuffaceous Siltstone, Sand, Coal 40% Tuffaceous Sandstone, 10% Sand, 40% Tuffaceous Siltstone, 10% Coal Hemlock Current Formation: Current Lithology% : General Lithology: LITHOLOGY/REMARKS HDBS EM65D 4188 14,741' INCLINATION MUD TYPE: INTERVAL 6.75 '' 56.70° Cake I-O-Char-Loc-B-G-Pull 5,624.56' S 0-1-CT-T-X-I-RR-PR 6.3% Sol OF VIS SURVEY DATA 6x12 19 DEPTH 14,825' 3 72 0 0 Slide 72 3670 3929 14,794' DAILY WELLSITE REPORT 5.31 2.2 YP 115.44° Gels 117.97° 14,887' RU-5B Type 2 Size 6.75 ''Hughes PDC DP505x BHA TYPE: Directional Assembly CASING DATA Cook Inlet Energy Osprey DEPTH: INTERVAL: 52.96° 13.375 '' 12273689 No. FT/HR N/A E-Stab FT/LBS 14,677'N/A 9671 9.3 Salt 18.0 14,758' DRILLING PARAMETERS GAS SUMMARY (units) 14,877' 14,760'1 14,760' 57 14,666' 23 0 CURRENT 0 10 OIL DESCRIPTION 0 14,876'45 298 MW 8.58 RATE OF PENETRATION SURFACE TORQUE 65% Oil PV ETHANE (C-2) PROPANE (C-3) 93 8615 2388 443 0 CONNECTION 4940 WEIGHT ON BIT 4.1 77 14,708' GAS 14,699' 14,761' CUTTINGS GAS FLOW IN DITCH GAS 19 14,656'63.3 POM BUTANE (C-4) PENTANE (C-5) HYDROCARBON SHOWS 14,876' 28 KLBS Lime 155.2 27% 0.0 Cl- N/A Oil/H2O RPM PSI N/A TOPDRIVE RPM N/A PUMP PRESSURE 14,887'289 33.7 GPM N/A Stephen Ratcliff 14,666' 48.2 7.625 ''12,930' 532 Hours 14,666' 287 11,920.77' 106 2 TOOLS: Flowline Temp: 12/15/17 5,485.71' E 5,590.51' S FL 11,500' Footage IN OUT 1,089' 14,040' 14,040' 24:00 CONDITION 14,887' RIH w/ Directional BHA 14,681' Keith Carter 206' 9/5/13 14,887' 12,951' 3,190'9.625 '' JETS 3x16 2x18 7146537 S/N TVD AZIMUTH Oil +N/S- COORDINATES +E/W- ' 11,974.13' MUD BASE: Enviromul 5,553.33' E 37.7 14,732' Tyler Dretke $2,500 Continue drilling f/14681' t/14887'. Circulate bottoms up and POOH to 12815'. Begin RIH 14887'109 min 75 8178 Tyler Dretke, Ben Handley strokes 755 % Theoretical 100% 48 169 #N/A 0 0 0 DAILY COST CHROMATOGRAPHY (ppm) Annular Volume DAILY ACTIVITY SUMMARY 14,876'38 METHANE (C-1) 14,876' 10305 14,820'0 Slide DATE: TIME: PRESENT OPERATION: PRESENT DEPTH: DEPTH YESTERDAY: SAMPLE DEPTH: 24 HOUR FOOTAGE: REPORT FOR: & @ @ @ BIT DATA MWD/LWD SUMMARY to MUD REPORT HIGH LOW AVERAGE CURRENT AVG @ @ @ @ @ @ @ @ @ @ @ @ HIGH LOW AVERAGE TRIP = @ @ WIPER= @ @ Zone Gas (Range) = Survey Gas (Range) = AIR-Kelly Cut Gas (Range) = Down Time, Downlink (Range) = @ @ HIGH = @ @ AVG = @ @ Current = @ @ AVG = @ @ Background = LITHOLOGY LAG SUMMARY bbl // @ SPM / @ PERSONNEL REPORT BY 11184 15,400'0 Slide 0 0 DAILY COST CHROMATOGRAPHY (ppm) Annular Volume DAILY ACTIVITY SUMMARY 15,313'69 METHANE (C-1) 14,888'27 242 15,247' 1 strokes 772 % Theoretical 100% 37.7 15,390' Tyler Dretke $2,500 Continue RIH and drill f/14887' T/15453'. 15407'111 min 75 8362 Tyler Dretke, Ben Handley TVD AZIMUTH Oil +N/S- COORDINATES +E/W- ' 12,298.24' MUD BASE: Enviromul 5,553.33' E 12,951' 3,190'9.625 '' JETS 3x16 2x18 7146537 S/N 24:00 CONDITION 15,453' DRILLING 14,887' Keith Carter 566' 9/6/13 15,407' 11,500' Footage IN OUT 1,089' 14,040' 14,040' 12,369.04' 106 2 TOOLS: Flowline Temp: 12/15/17 5,940.48' W 5,718.54' S FL Stephen Ratcliff 14,950' 42.8 7.625 ''12,930' 516 Hours 15,371' 283 15,294'292 25.6 GPM 289 RPM PSI 3976 TOPDRIVE RPM 50 PUMP PRESSURE 27 KLBS Lime 139.7 27% 0.0 Cl- 21.2 Oil/H2O POM BUTANE (C-4) PENTANE (C-5) HYDROCARBON SHOWS 14,980' 15,104' CUTTINGS GAS FLOW IN DITCH GAS 10 15,289'69.8 WEIGHT ON BIT 3.3 79 15,169' GAS 15,357' 0 CONNECTION 5014 ETHANE (C-2) PROPANE (C-3) 71 10528 1580 478 298 MW 7.38 RATE OF PENETRATION SURFACE TORQUE 65% Oil PV 26 15,183' 14,993' 0 35 18 9 CURRENT 10 17 OIL DESCRIPTION 14,980' 15,371'12 15,065' 52 15,371' 9.3 Salt 20.6 14,925' DRILLING PARAMETERS GAS SUMMARY (units) FT/HR 10487 E-Stab FT/LBS 15,029'26.5 10167 Cook Inlet Energy Osprey DEPTH: INTERVAL: 41.47° 13.375 '' 12273689 No. Type 2 Size 6.75 ''Hughes PDC DP505x BHA TYPE: Directional Assembly CASING DATA DAILY WELLSITE REPORT 4.53 2.2 YP 90.92° Gels 84.86° 14,887' RU-5B 0 0 Slide 65 3523 4045 14,888' VIS SURVEY DATA 6x12 19 DEPTH 15,297' 3 72 Cake I-O-Char-Loc-B-G-Pull 5,624.56' S 0-1-CT-T-X-I-RR-PR 6.6% Sol OF LITHOLOGY/REMARKS HDBS EM65D 4301 15,065' INCLINATION MUD TYPE: INTERVAL 6.75 '' 40.03° Current Formation: Current Lithology% : General Lithology: Tuffaceous Sandstone, Sand, Scattered Coal, Tuffaceous Siltstone 80% Tuffaceous Sandstone, 20% Sand Hemlock DATE: TIME: PRESENT OPERATION: PRESENT DEPTH: DEPTH YESTERDAY: SAMPLE DEPTH: 24 HOUR FOOTAGE: REPORT FOR: & @ @ @ BIT DATA MWD/LWD SUMMARY to MUD REPORT HIGH LOW AVERAGE CURRENT AVG @ @ @ @ @ @ @ @ @ @ @ @ HIGH LOW AVERAGE TRIP = @ @ WIPER= @ @ Zone Gas (Range) = Survey Gas (Range) = AIR-Kelly Cut Gas (Range) = Down Time, Downlink (Range) = @ @ HIGH = @ @ AVG = @ @ Current = @ @ AVG = @ @ Background = LITHOLOGY LAG SUMMARY bbl // @ SPM / @ PERSONNEL REPORT BY Tuffaceous Sandstone, Sand, Scattered Coal, Tuffaceous Siltstone 30% Tuffaceous Siltstone, 10% Sand, 10% Coal, 50% Tuffaceous Siltstone Hemlock Current Formation: Current Lithology% : General Lithology: LITHOLOGY/REMARKS HDBS EM65D 4317 15,641' INCLINATION MUD TYPE: INTERVAL 6.75 '' 31.39° Cake I-O-Char-Loc-B-G-Pull 5,660.09' S 0-1-CT-T-X-I-RR-PR 5.9% Sol OF VIS SURVEY DATA 6x12 19 DEPTH 15,750' 3 72 0 0 Slide 57 3687 4075 15,688' DAILY WELLSITE REPORT 4.14 2.2 YP 64.87° Gels 64.87° 14,887' RU-5B Type 2 Size 6.75 ''Hughes PDC DP505x BHA TYPE: Directional Assembly CASING DATA Cook Inlet Energy Osprey DEPTH: INTERVAL: 31.39° 13.375 '' 12273689 No. FT/HR 9628 E-Stab FT/LBS 15,579'26.2 10870 9.3 Salt 22.9 15,600' DRILLING PARAMETERS GAS SUMMARY (units) 15,615' 15,655'11 15,749' 23 15,655' 9 5 CURRENT 0 0 OIL DESCRIPTION 12 15,649' 15,432' 0 18 298 MW 8.83 RATE OF PENETRATION SURFACE TORQUE 65% Oil PV ETHANE (C-2) PROPANE (C-3) 49 4958 1269 573 0 CONNECTION 3044 WEIGHT ON BIT 11.9 82 15,551' GAS 15,733' 15,465' CUTTINGS GAS FLOW IN DITCH GAS 6 15,534'36.5 POM BUTANE (C-4) PENTANE (C-5) HYDROCARBON SHOWS 15,598' 28 KLBS Lime 123.6 27% 0.0 Cl- 17.6 Oil/H2O RPM PSI 3462 TOPDRIVE RPM 47 PUMP PRESSURE 15,719'293 14.6 GPM 257 Stephen Ratcliff 15,745' 27.7 7.625 ''12,930' 506 Hours 15,743' 287 12,606.57' 106 2 TOOLS: Flowline Temp: 12/14/16 6,109.31' E 5,674.24' S FL 11,500' Footage IN OUT 15,750' 1,089' 14,040' 14,040' 24:00 CONDITION 15,750' DRILLING 15,453' Keith Carter 297' 9/7/13 15,750' 12,951' 3,190'9.625 '' JETS 3x16 2x18 7146537 S/N TVD AZIMUTH Oil +N/S- COORDINATES +E/W- ' 12,661.18' MUD BASE: Enviromul 6,139.47' E 37.7 15,686' Tyler Dretke $2,500 Continue drilling f/15453' t/ TD at 15750'. Circulate hole clean and begin reaming out. 15407'113 min 75 8449 Tyler Dretke, Ben Handley strokes 780 % Theoretical 100% 24 320 15,749' 0 0 0 DAILY COST CHROMATOGRAPHY (ppm) Annular Volume DAILY ACTIVITY SUMMARY 15,598'89 METHANE (C-1) 15,750' 11482 15,710'0 Slide DATE: TIME: PRESENT OPERATION: PRESENT DEPTH: DEPTH YESTERDAY: SAMPLE DEPTH: 24 HOUR FOOTAGE: REPORT FOR: & @ @ @ BIT DATA MWD/LWD SUMMARY to MUD REPORT HIGH LOW AVERAGE CURRENT AVG @ @ @ @ @ @ @ @ @ @ @ @ HIGH LOW AVERAGE TRIP = @ @ WIPER= @ @ Zone Gas (Range) = Survey Gas (Range) = AIR-Kelly Cut Gas (Range) = Down Time, Downlink (Range) = @ @ HIGH = @ @ AVG = @ @ Current = @ @ AVG = @ @ Background = LITHOLOGY LAG SUMMARY bbl // @ SPM / @ PERSONNEL REPORT BY 0 0 DAILY COST CHROMATOGRAPHY (ppm) Annular Volume DAILY ACTIVITY SUMMARY METHANE (C-1) strokes 780 % Theoretical 100% 37.7 15,686' Tyler Dretke $2,500 Ream out from 15120' to 9 5/8" casing. Circulate and POOH. Begin testing BOPs 15407'113 min 75 8449 Tyler Dretke, Ben Handley TVD AZIMUTH Oil +N/S- COORDINATES +E/W- ' 12,661.18' MUD BASE: Enviromul 6,139.47' E 12,951' 3,190'9.625 '' JETS 3x16 2x18 7146537 S/N 24:00 CONDITION 15,750' DRILLING 15,750' Keith Carter 0' 9/8/13 15,750' 11,500' Footage IN OUT 15,750' 1,089' 14,040' 14,040' 12,606.57' 106 2 TOOLS: Flowline Temp: 11/13/15 6,109.31' E 5,674.24' S FL Stephen Ratcliff 7.625 ''12,930' 525 Hours 7.0 GPM N/A RPM PSI N/A TOPDRIVE RPM N/A PUMP PRESSURE 26 KLBS Lime 27% Cl- N/A Oil/H2O POM BUTANE (C-4) PENTANE (C-5) HYDROCARBON SHOWS CUTTINGS GAS FLOW IN CIRCULATING GAS 0 WEIGHT ON BIT GAS CONNECTION ETHANE (C-2) PROPANE (C-3) MW 7.38 RATE OF PENETRATION SURFACE TORQUE 65% Oil PV CURRENT 0 0 OIL DESCRIPTION 10 9.45 Salt DRILLING PARAMETERS GAS SUMMARY (units) FT/HR N/A E-Stab FT/LBS N/A Cook Inlet Energy Osprey DEPTH: INTERVAL: 31.39° 13.375 '' 12273689 No. Type 2 Size 6.75 ''Hughes PDC DP505x BHA TYPE: Directional Assembly CASING DATA DAILY WELLSITE REPORT 4.01 2.2 YP 64.87° Gels 64.87° 14,887' RU-5B 0 VIS SURVEY DATA 6x12 19 DEPTH 15,750' 3 73 Cake I-O-Char-Loc-B-G-Pull 5,660.09' S 0-1-CT-T-X-I-RR-PR 6.6% Sol OF LITHOLOGY/REMARKS HDBS EM65D INCLINATION MUD TYPE: INTERVAL 6.75 '' 31.39° Current Formation: Current Lithology% : General Lithology: No new lithology No new lithology DATE: TIME: PRESENT OPERATION: PRESENT DEPTH: DEPTH YESTERDAY: SAMPLE DEPTH: 24 HOUR FOOTAGE: REPORT FOR: & @ @ @ BIT DATA MWD/LWD SUMMARY to MUD REPORT HIGH LOW AVERAGE CURRENT AVG @ @ @ @ @ @ @ @ @ @ @ @ HIGH LOW AVERAGE TRIP = @ @ WIPER= @ @ Zone Gas (Range) = Survey Gas (Range) = AIR-Kelly Cut Gas (Range) = Down Time, Downlink (Range) = @ @ HIGH = @ @ AVG = @ @ Current = @ @ AVG = @ @ Background = LITHOLOGY LAG SUMMARY bbl // @ SPM / @ PERSONNEL REPORT BY No new lithology No new lithology Current Formation: Current Lithology% : General Lithology: LITHOLOGY/REMARKS HDBS EM65D INCLINATION MUD TYPE: INTERVAL 6.75 '' 31.39° Cake I-O-Char-Loc-B-G-Pull 5,660.09' S 0-1-CT-T-X-I-RR-PR 6.4% Sol OF VIS SURVEY DATA 6x12 18 DEPTH 15,750' 3 72 0 DAILY WELLSITE REPORT 4.01 2.2 YP 64.87° Gels 64.87° 15,750' RU-5B Type 2 Size 6.75 ''Hughes PDC DP505x BHA TYPE: Directional Assembly CASING DATA Cook Inlet Energy Osprey DEPTH: INTERVAL: 31.39° 13.375 '' 12273689 No. FT/HR N/A E-Stab FT/LBS N/A 9.4 Salt DRILLING PARAMETERS GAS SUMMARY (units) 0 CURRENT 0 0 OIL DESCRIPTION MW 8.83 RATE OF PENETRATION SURFACE TORQUE 65% Oil PV ETHANE (C-2) PROPANE (C-3) CONNECTION WEIGHT ON BIT GAS CUTTINGS GAS FLOW IN CIRCULATING GAS 0 POM BUTANE (C-4) PENTANE (C-5) HYDROCARBON SHOWS 26 KLBS Lime 27% Cl- N/A Oil/H2O RPM PSI N/A TOPDRIVE RPM N/A PUMP PRESSURE 0.0 GPM N/A Stephen Ratcliff 7.625 ''12,930' 520 Hours 12,606.57' 106 2 TOOLS: Flowline Temp: 11/14/16 6,109.31' E 5,674.24' S FL 11,500' Footage IN OUT 15,750' 1,089' 14,040' 14,040' 24:00 CONDITION 15,750' DRILLING 15,750' Keith Carter 0' 9/9/13 15,750' 12,951' 3,190'9.625 '' JETS 3x16 2x18 7146537 S/N TVD AZIMUTH Oil +N/S- COORDINATES +E/W- ' 12,661.18' MUD BASE: Enviromul 6,139.47' E 37.7 15,686' Tyler Dretke $3,197 Finish testing BOPs, P/U hanger and RIH 15407'113 min 75 8449 Tyler Dretke, Ben Handley strokes 780 % Theoretical 100% 0 0 DAILY COST CHROMATOGRAPHY (ppm) Annular Volume DAILY ACTIVITY SUMMARY METHANE (C-1) DATE: TIME: PRESENT OPERATION: PRESENT DEPTH: DEPTH YESTERDAY: SAMPLE DEPTH: 24 HOUR FOOTAGE: REPORT FOR: & @ @ @ BIT DATA MWD/LWD SUMMARY to MUD REPORT HIGH LOW AVERAGE CURRENT AVG @ @ @ @ @ @ @ @ @ @ @ @ HIGH LOW AVERAGE TRIP = @ @ WIPER= @ @ Zone Gas (Range) = Survey Gas (Range) = AIR-Kelly Cut Gas (Range) = Down Time, Downlink (Range) = @ @ HIGH = @ @ AVG = @ @ Current = @ @ AVG = @ @ Background = LITHOLOGY LAG SUMMARY bbl // @ SPM / @ PERSONNEL REPORT BY 0 0 DAILY COST CHROMATOGRAPHY (ppm) Annular Volume DAILY ACTIVITY SUMMARY METHANE (C-1) strokes 780 % Theoretical 100% 37.7 15,686' Tyler Dretke $2,500 Continue RIH with Liner. Wash down f/13379' t/15125' due to tight spot. 15407'113 min 75 8449 Tyler Dretke, Ben Handley TVD AZIMUTH Oil +N/S- COORDINATES +E/W- ' 12,661.18' MUD BASE: Enviromul 6,139.47' E 12,951' 3,190'9.625 '' JETS 3x16 2x18 7146537 S/N 24:00 CONDITION 15,750' RIH w/ liner 15,750' Keith Carter 0' 9/10/13 15,750' 11,500' Footage IN OUT 15,750' 1,089' 14,040' 14,040' 12,606.57' 106 2 TOOLS: Flowline Temp: 9/12/14 6,109.31' E 5,674.24' S FL Stephen Ratcliff 7.625 ''12,930' 477 Hours 15.0 GPM N/A RPM PSI N/A TOPDRIVE RPM N/A PUMP PRESSURE 25 KLBS Lime 27% Cl- N/A Oil/H2O POM BUTANE (C-4) PENTANE (C-5) HYDROCARBON SHOWS CUTTINGS GAS FLOW IN CIRCULATING GAS 0 WEIGHT ON BIT GAS CONNECTION ETHANE (C-2) PROPANE (C-3) MW 10.87 RATE OF PENETRATION SURFACE TORQUE 65% Oil PV CURRENT 0 15 OIL DESCRIPTION 20 9.4 Salt DRILLING PARAMETERS GAS SUMMARY (units) FT/HR N/A E-Stab FT/LBS N/A Cook Inlet Energy Osprey DEPTH: INTERVAL: 31.39° 13.375 '' 12273689 No. Type 2 Size 6.75 ''Hughes PDC DP505x BHA TYPE: Directional Assembly CASING DATA DAILY WELLSITE REPORT 3.88 2.2 YP 64.87° Gels 64.87° 15,750' RU-5B 0 VIS SURVEY DATA 6x12 12 DEPTH 15,750' 3 64 Cake I-O-Char-Loc-B-G-Pull 5,660.09' S 0-1-CT-T-X-I-RR-PR 6.3% Sol OF LITHOLOGY/REMARKS HDBS EM65D INCLINATION MUD TYPE: INTERVAL 6.75 '' 31.39° Current Formation: Current Lithology% : General Lithology: No new lithology No new lithology DATE: TIME: PRESENT OPERATION: PRESENT DEPTH: DEPTH YESTERDAY: SAMPLE DEPTH: 24 HOUR FOOTAGE: REPORT FOR: & @ @ @ BIT DATA MWD/LWD SUMMARY to MUD REPORT HIGH LOW AVERAGE CURRENT AVG @ @ @ @ @ @ @ @ @ @ @ @ HIGH LOW AVERAGE TRIP = @ @ WIPER= @ @ Zone Gas (Range) = Survey Gas (Range) = AIR-Kelly Cut Gas (Range) = Down Time, Downlink (Range) = @ @ HIGH = @ @ AVG = @ @ Current = @ @ AVG = @ @ Background = LITHOLOGY LAG SUMMARY bbl // @ SPM / @ PERSONNEL REPORT BY No new lithology No new lithology Current Formation: Current Lithology% : General Lithology: LITHOLOGY/REMARKS HDBS EM65D INCLINATION MUD TYPE: INTERVAL 6.75 '' 31.39° Cake I-O-Char-Loc-B-G-Pull 5,660.09' S 0-1-CT-T-X-I-RR-PR 6.3% Sol OF VIS SURVEY DATA 6x12 13 DEPTH 15,750' 3 67 0 DAILY WELLSITE REPORT 3.88 2.2 YP 64.87° Gels 64.87° 15,750' RU-5B Type 2 Size 6.75 ''Hughes PDC DP505x BHA TYPE: Directional Assembly CASING DATA Cook Inlet Energy Osprey DEPTH: INTERVAL: 31.39° 13.375 '' 12273689 No. FT/HR N/A E-Stab FT/LBS N/A 9.4 Salt DRILLING PARAMETERS GAS SUMMARY (units) 20 CURRENT 0 0 OIL DESCRIPTION MW 10.87 RATE OF PENETRATION SURFACE TORQUE 65% Oil PV ETHANE (C-2) PROPANE (C-3) CONNECTION WEIGHT ON BIT GAS CUTTINGS GAS FLOW IN CIRCULATING GAS 0 POM BUTANE (C-4) PENTANE (C-5) HYDROCARBON SHOWS 25 KLBS Lime 27% Cl- N/A Oil/H2O RPM PSI N/A TOPDRIVE RPM N/A PUMP PRESSURE 15.0 GPM N/A Stephen Ratcliff 7.625 ''12,930' 471 Hours 12,606.57' 106 2 TOOLS: Flowline Temp: 9/12/15 6,109.31' E 5,674.24' S FL 11,500' Footage IN OUT 15,750' 1,089' 14,040' 14,040' 24:00 CONDITION 15,750' POOH 15,750' Keith Carter 0' 9/11/13 15,750' 12,951' 3,190'9.625 '' JETS 3x16 2x18 7146537 S/N TVD AZIMUTH Oil +N/S- COORDINATES +E/W- ' 12,661.18' MUD BASE: Enviromul 6,139.47' E 37.7 15,686' Tyler Dretke $2,500 Run liner to bottom, rig up cementers and begin cementing, r/d cementers and POOH. 15407'113 min 75 8449 Tyler Dretke, Ben Handley strokes 780 % Theoretical 100% 0 0 DAILY COST CHROMATOGRAPHY (ppm) Annular Volume DAILY ACTIVITY SUMMARY METHANE (C-1) DATE: TIME: PRESENT OPERATION: PRESENT DEPTH: DEPTH YESTERDAY: SAMPLE DEPTH: 24 HOUR FOOTAGE: REPORT FOR: & @ @ @ BIT DATA MWD/LWD SUMMARY to MUD REPORT HIGH LOW AVERAGE CURRENT AVG @ @ @ @ @ @ @ @ @ @ @ @ HIGH LOW AVERAGE TRIP = @ @ WIPER= @ @ Zone Gas (Range) = Survey Gas (Range) = AIR-Kelly Cut Gas (Range) = Down Time, Downlink (Range) = @ @ HIGH = @ @ AVG = @ @ Current = @ @ AVG = @ @ Background = LITHOLOGY LAG SUMMARY bbl // @ SPM / @ PERSONNEL REPORT BY No new lithology No new lithology Current Formation: Current Lithology% : General Lithology: LITHOLOGY/REMARKS HDBS EM65D INCLINATION MUD TYPE: INTERVAL 6.75 '' 31.39° Cake I-O-Char-Loc-B-G-Pull 5,660.09' S 0-1-CT-T-X-I-RR-PR 6.3% Sol OF VIS SURVEY DATA 6x12 13 DEPTH 15,750' 3 70 0 DAILY WELLSITE REPORT 3.88 2.2 YP 64.87° Gels 64.87° 15,750' RU-5B Type 2 Size 6.75 ''Hughes PDC DP505x BHA TYPE: Directional Assembly CASING DATA Cook Inlet Energy Osprey DEPTH: INTERVAL: 31.39° 13.375 '' 12273689 No. FT/HR N/A E-Stab FT/LBS N/A 9.4 Salt DRILLING PARAMETERS GAS SUMMARY (units) 0 CURRENT 0 0 OIL DESCRIPTION MW 10.87 RATE OF PENETRATION SURFACE TORQUE 65% Oil PV ETHANE (C-2) PROPANE (C-3) CONNECTION WEIGHT ON BIT GAS CUTTINGS GAS FLOW IN CIRCULATING GAS 0 POM BUTANE (C-4) PENTANE (C-5) HYDROCARBON SHOWS 25 KLBS Lime 27% Cl- N/A Oil/H2O RPM PSI N/A TOPDRIVE RPM N/A PUMP PRESSURE 0.0 GPM N/A Stephen Ratcliff 7.625 ''12,930' 470 Hours 12,606.57' 106 2 TOOLS: Flowline Temp: 9/12/15 6,109.31' E 5,674.24' S FL 11,500' Footage IN OUT 15,750' 1,089' 14,040' 14,040' 24:00 CONDITION 15,750' Service Rig 15,750' Keith Carter 0' 9/12/13 15,750' 12,951' 3,190'9.625 '' JETS 3x16 2x18 7146537 S/N TVD AZIMUTH Oil +N/S- COORDINATES +E/W- ' 12,661.18' MUD BASE: Enviromul 6,139.47' E 37.7 15,686' Tyler Dretke $2,500 Lay down HWDP and POOH f/ 905' to Surface. Rig up weatherford and inject fluid, test BOPs, service rig, M/u mill and RIH w/ tubing. 15407'113 min 75 8449 Tyler Dretke,Jim Foradas strokes 780 % Theoretical 100% 0 0 DAILY COST CHROMATOGRAPHY (ppm) Annular Volume DAILY ACTIVITY SUMMARY METHANE (C-1)