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Home My WebLink About212-172P.I. Supv Comm: Rig Coil Tubing Unit?No Rig Contractor Rig Representative Operator Operator Representative Well Permit to Drill #2121720 Sundry Approval #323-275 Operation Inspection Location Working Pressure, W/H Flange P Pit Fluid Measurement P Working Pressure P P Flow Rate Sensor P Operating Pressure P P Mud Gas Separator P Fluid Level/Condition P P Degasser NA Pressure Gauges P P Separator Bypass P Sufficient Valves P P Gas Detectors FP Regulator Bypass P P Alarms Separate/Distinct P Actuators (4-way valves)P P Choke/Kill Line Connections P Blind Ram Handle Cover P P Reserve Pits P Control Panel, Driller P P Trip Tank NA Control Panel, Remote P P Firewall P P 2 or More Pumps P P Kelly or TD Valves NA Independent Power Supply P P Floor Safety Valves P N2 Backup P P Driller's Console P Condition of Equipment P P Flow Monitor P Flow Rate Indicator P Pit Level Indicators P Valves P PPE P Gauges P Remote Hydraulic Choke P Well Control Trained P Gas Detection Monitor P FOV Upstream of Chokes P Housekeeping P Hydraulic Control Panel P Targeted Turns P Well Control Plan P Kill Sheet Current NA Bypass Line P FAILURES:1 CORRECT BY: COMMENTS Kam St.John 24-JulINSPECT DATE AOGCC INSPECTOR TSI 102 Team Subbing Intl Cook Inlet Energy MISCELLANEOUS Flange/Hub Connections Drilling Spool Outlets Flow Nipple Control Lines RIG FLOOR ALASKA OIL AND GAS CONSERVATION COMMISSION RIG INSPECTION REPORT HCR Valve(s) Manual Valves Annular Preventer Working Pressure, BOP Stack Stack Anchored Choke Line Kill Line Targeted Turns Pipe Rams Blind Rams Tom Matthews Tom Boyd/Paul Smith Locking Devices, Rams BOP STACK The overall inspection was good with this operation. The only FP was 1 H2S sensor (recalibrated and passed). The Sundry was not posted but located in Operator Representative's office. Made copies for the floor. Houskeeping was in good order. CHOKE MANIFOLD Osprey Platform MUD SYSTEM Redoubt Unit 2A Workover CLOSING UNIT 2023-0724_Rig_TSI102_RU-2A_ksj rev. 4-19-2023 JBR; 11/13/2023 By Grace Christianson at 3:01 pm, Oct 06, 2023 Version: Final Date: 10/5/2023 3" BPV with dry hole tree installed 7/28/2023 RKB 44.01' 36" A-36 200' MD 150# Welded 200' TVD 13 3/8" L-80 3,212' MD 68# BTC 2,918' TVD 7,328' MD 7,348' MD Top of clamp on top of Jt 206 7,367' MD Top of tubing - Jt 206 from surface 7,368' MD Top of 7" Liner - 8,148' MD Top of ESP Cable 7,372' MD Length of fish (tubing & ESP) 7,768' MD 9 5/8" L-80 8,527' MD 47# BTC 7,149' TVD Top Of Cement (CBL) - 13,050' MD (2) 3/8" x .049 Dual Flat Chem Inj Lines Summit ESP Assembly Top of Discharge Head @ ~14,982' MD Motors - 456 Series Assume Btm of ESP Assy (anode) @ 15,136' MD (34) Clamps on Pump Assembly (451) Clamps on String (2) SS bands (1) half clamp 7" L-80 15,275' MD 29# BTC 12,460' TVD TD @ 15,360' MD/12,460' TVD 7" Shoe Track Landing Collar 15,136' MD 12147 12182 RU-02A - Actual Schematic Fish: 3-1/2" 12.95# P-110 PH6 tubing, ID - 2.750" Length: 7,768' 8-1/2" Hole 12-1/4" Hole MD 14,518' - 14,596' 15,030' - 15,090' 14,880' - 14,953' 14,860' - 14,880' 2023 TSI WO Details - Assume 3-1/2" tubing ESP fish fell and landed on landing collar in 7" liner Top of Capstring 11778 11840 11871 11888 11889 11945 3-1/2" 12.95# P-110 PH6 tubing, ID - 2.750" Length: 263' Tbg hanger requires 3-1/2 EUE landing joint 10-20' of Capstring Rubber Perforations 3-3/8" Guns, 6 SPF TVD 12195 12245 14,635' - 14,655' 14,835' - 14,860' 14,657' - 14,724' 12034 12055 12055 12071 12072 12132 11999 12035 14,972' - 15,013' 14,792' - 14,836' Temp:°F Wind Speed:Weather:Road Cond:Lease Cond: KB-THF:ftKB-Ground:1 ftKB:2 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 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 18:03 Page 1 of 1 Daily Completion Well Name: Country: RU-02A United States State:Alaska Activity: Well Number: 50-733-20501-01-00 API: RU-02A ESP Replacement Date:Jun 30, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator: Temp:°F Wind Speed:Weather:Road Cond:Lease Cond: KB-THF:ftKB-Ground:1 ftKB:2 ft Day 2 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 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 18:04 Page 1 of 1 Daily Completion Well Name: Country: RU-02A United States State:Alaska Activity: Well Number: 50-733-20501-01-00 API: RU-02A ESP Replacement Date:Jul 15, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator: Temp:°F Wind Speed:Weather:Road Cond:Lease Cond: KB-THF:ftKB-Ground:1 ftKB:2 ft Day 3 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 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 18:04 Page 1 of 1 Daily Completion Well Name: Country: RU-02A United States State:Alaska Activity: Well Number: 50-733-20501-01-00 API: RU-02A ESP Replacement Date:Jul 16, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator: Temp:°F Wind Speed:Weather:Road Cond:Lease Cond: KB-THF:ftKB-Ground:1 ftKB:2 ft Day 4 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 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 18:04 Page 1 of 1 Daily Completion Well Name: Country: RU-02A United States State:Alaska Activity: Well Number: 50-733-20501-01-00 API: RU-02A ESP Replacement Date:Jul 17, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator: Temp:°F Wind Speed:Weather:Road Cond:Lease Cond: KB-THF:ftKB-Ground:1 ftKB:2 ft Day 5 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 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 18:04 Page 1 of 1 Daily Completion Well Name: Country: RU-02A United States State:Alaska Activity: Well Number: 50-733-20501-01-00 API: RU-02A ESP Replacement Date:Jul 18, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator: Temp:°F Wind Speed:Weather:Road Cond:Lease Cond: KB-THF:ftKB-Ground:1 ftKB:2 ft Day 6 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 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 18:04 Page 1 of 1 Daily Completion Well Name: Country: RU-02A United States State:Alaska Activity: Well Number: 50-733-20501-01-00 API: RU-02A ESP Replacement Date:Jul 19, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator: Temp:45 °F Wind Speed:Up to 19 km/h Weather:Partly Cloudy Road Cond:Lease Cond:Good KB-THF:ftKB-Ground:1 ftKB:2 ft Day 7 Rig Name:Rig Release: Licence #: Rig Number:Personnel On Location:21 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 Rig Up / Rig Out / Repair Service Rig Continue to rig up and prepare for RU-2A workover. Adding and repairing deck lighting. Arranging deck space for receiving boat rig loads. Wired power to Koomey Unit. Moved TSI office complex and connect power supply. Glacier Lead Crane Operator mentor TSI Crane Operator, he is approved to operate the crane in a limited capacity (whip line only). 06:00 12:00 6.00 Rig Up / Rig Out / Repair Service Rig Continue to rig up. Discovered that the 13-5/8 riser installed was incorrect length. TSI shipped 2 x 10' sections, should have sent 1 x 15' section. Remove riser and place BOPE equipment on stand and chain to deck. PJSM with Day Crew. Discuss upcoming operations, Lifting operations and working at heights. Rain last night and the decks are slick. Hand over with Night Crew 12:00 18:00 6.00 Rig Up / Rig Out / Repair Service Rig Finish arranging deck space, plan for receiving and spotting rig loads. M/V Endeavor is scheduled to arrive at 23:30 hrs. Slack tide at 01:30 hrs. 18:00 23:00 5.00 Rig Up / Rig Out / Repair Service Rig Arrange decks for receiving boat loads. Spot choke, move iron rack and tool house off main deck. PJSM with Night Crew. Discuss upcoming operations, Lifting operations. Unloading boat. Hand over with Day Crew 23:00 24:00 1.00 Rig Up / Rig Out / Repair Service Rig Off load boat. Pick BOP riser, dunnage, dumpsters, bundle of 5 jts 3 1/2 EUE tubing, TSI work window. Unable to pick TSI jack unit or skid due to rigging shortages. Jack unit laying on skid necessitates taking jack unit off boat 1st and setting on deck on morning boat tide. Total: 24.00 Wellbores Wellbore KOP MD (ft)KOP TVD (ft)TD MD (ft)TD TVD (ft) Main Wellbore 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:Rigging up choke manifold. Making up BOPE on riser., on well head. 24 Hr Summary:Arrange decks for offloading and receiving equipment loads, nipple down BOPE to change to shorter riser, off load MV Endeavor. 24 Hr Forecast:Offload MV Endeavor with snubbing unit, spot on deck, raise and set snubbing, nipple up BOPE prep for BOP test. Remarks: KB-RT:ft www.resourceenergysolutions.com Generated Oct 04, 2023 18:04 Page 1 of 1 Daily Completion Well Name: Country: RU-02A United States State:Alaska Activity: Well Number: 50-733-20501-01-00 API: RU-02A ESP Replacement Date:Jul 20, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Paul Smith (inac 9075290737206-914-7247Wes JeardoeSupervisor: Tom Boyd (i ti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Temp:55 °F Wind Speed:Up to 29 km/h Weather:Partly Cloudy Road Cond:Lease Cond:Good KB-THF:ftKB-Ground:1 ftKB:2 ft Day 8 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: Wellbores Wellbore KOP MD (ft)KOP TVD (ft)TD MD (ft)TD TVD (ft) Main Wellbore 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:Placing snubbing jack section on work window on well, attaching guys to platform. 24 Hr Summary:Unable to take Snubbing skid off boat (Cribbing under Jacking Unit failed and was preventing the removal of the skid) Re arrange equipment on deck to allow the jack to be removed first. Set riser and BOPs on well and torque flanges. Offload boat, place Jacking Unit and skid on main deck. Hook up hoses and prepare to raise Snubbing Unit. Develop plan and move equipment around platform to allow for offload and backload of midnight boat. 24 Hr Forecast:Complete M/V Endeavor off load, backload equipment to boat. Rig up snubbing unit, Hook up PVT, Position equipment to complete workover operation. Remarks:POB 25: Production 2, Drilling 20, Catering 3 Helicopter Trips 3 Boat Trips 2 KB-RT:ft www.resourceenergysolutions.com Generated Oct 04, 2023 18:04 Page 1 of 2 Daily Completion Well Name: Country: RU-02A United States State:Alaska Activity: Well Number: 50-733-20501-01-00 API: RU-02A ESP Replacement Date:Jul 21, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Paul Smith (inac 9075290737206-914-7247Wes JeardoeSupervisor: Tom Boyd (i ti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Time Log Time From Time To Hours Code Comments 00:00 03:30 3.50 Move Equipment / Service Rig Unable to off load boat due to load shifting during transport to rig. Re-arrange deck on platform to accommodate addition equipment. Note: The proposed equipment offload sequence was to offload the Jacking cradle, place it on the deck and then offload the Snubbing Jacks and place it directly in the cradle. Once the load shifted it became necessary to position both large footprint items on the deck (Snubbing Jacks and the cradle) and there was no deck space to accommodate both large footprint items on the deck. Make up lines and valves on choke manifold. 03:30 06:00 2.50 Rig Up / Rig Out / Repair Service Rig Install riser and BOPs on well. PJSM with Day Crew. Discuss upcoming operations, Lifting operations and working at heights. Troubleshoot communication issues. Hand over with Night Crew 06:00 12:30 6.50 Rig Up / Rig Out / Repair Service Rig Torque BOP flange connections. Clean up deck and make room for additional equipment. Instruct personnel how to use Billy Pugh personnel transfer, practice loading and unloading. Transfer personnel to M/V Endeavor. Use spreader bar and lift Snubbing Jacking unit to platform. Lift Jacking stand to platform. Bring all remaining equipment on boat up to platform. 12:30 18:00 5.50 Rig Up / Rig Out / Repair Service Rig Make up rigging for transfer jack to lay down skid /Turn power pack 180 degrees and spot / put unit on to lay down skid / cut slot out of handrail in work window basket for stairs / Hook up hydraulic hoses to unit. PJSM with Night Crew. Discuss upcoming operations, Lifting operations. Unloading boat. Hand over with Day Crew 18:00 24:00 6.00 Rig Up / Rig Out / Repair Service Rig Develop plan and arrange decks to receive loads on midnight tide. Total: 24.00 www.resourceenergysolutions.com Generated Oct 04, 2023 18:04 Page 2 of 2 Daily Completion Well Name: Country: RU-02A United States State:Alaska Activity: Well Number: 50-733-20501-01-00 API: RU-02A ESP Replacement Date:Jul 21, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Paul Smith (inac 9075290737206-914-7247Wes JeardoeSupervisor: Tom Boyd (i ti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Temp:52 °F Wind Speed:Up to 19 km/h Weather:Clear Road Cond:Lease Cond:Good KB-THF:ftKB-Ground:1 ftKB:2 ft Day 9 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: Wellbores Wellbore KOP MD (ft)KOP TVD (ft)TD MD (ft)TD TVD (ft) Main Wellbore 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:General rig up, Making up test joint for BOP shell test. 24 Hr Summary:Unload equipment from M/V Endeavor, could not complete offload due to tide change. Continue to rig up snubbing unit (Coflex Hoses, Window), Rotate window and re assemble, stand up Jacking unit and install on wellhead, secure unit and finish offloading boat. Back load extra material to boat. Continue to assemble Snubbing unit and prep for BOP shell test. 24 Hr Forecast:Finish assembly of snubbing unit. Install test joints and blanking sleeve for shell test, when successful notify AOGCC, Complete rigging up operations for pulling ESP completion, AOGCC BOP test/inspection. Remarks:POB 28: Production 2, Drilling 23, Catering 3 Helicopter Trips 2 (2 Summit, 1 CanRig, 1 TSI) Boat Trips 1 KB-RT:ft www.resourceenergysolutions.com Generated Oct 04, 2023 18:04 Page 1 of 2 Daily Completion Well Name: Country: RU-02A United States State:Alaska Activity: Well Number: 50-733-20501-01-00 API: RU-02A ESP Replacement Date:Jul 22, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Paul Smith (inac 9075290737206-914-7247Wes JeardoeSupervisor: Tom Boyd (i ti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Time Log Time From Time To Hours Code Comments 00:00 01:30 1.50 Rig Up / Rig Out / Repair Service Rig Boat M/V Endeavor pulled into position @ 24:00. Offload boat 10 picks from behind wheelhouse. Boat pulled away from platform due to tide change. Will return at slack tide to tie up and finishoffload heavy picks from stern. 01:30 06:00 4.50 Rig Up / Rig Out / Repair Service Rig Nipple up choke and kill lines, set on well and turn work window for platform orientation to work pipe. Fire up TSI power pack, stand up jack section, prep and set on work window. PJSM with Day Crew. Discuss upcoming operations, Lifting operations and working at heights. Troubleshoot communication issues. Hand over with Night Crew 06:00 08:30 2.50 Rig Up / Rig Out / Repair Service Rig Continue to rig up snubbing unit. Attach guy wires and release crane. Clear deck and position equipment to take on remaining equipment from M/V Endeavor 08:30 13:30 5.00 Rig Up / Rig Out / Repair Service Rig Bring in M/V Endeavor and tie up. Offload remainder of equipment and materials including Summit reels, Vault Equipment, Rig Mats, and TSI equipment. Backload TSI Jack Stand, empty baskets and other equipment not needed for the project. 13:30 18:00 4.50 Rig Up / Rig Out / Repair Service Rig Continue to work on TSI snubbing unit and platform to prepare for workover operations. PJSM with Night Crew. Discuss upcoming operations, Lifting operations. Unloading boat. Hand over with Day Crew 18:00 24:00 6.00 Rig Up / Rig Out / Repair Service Rig Rigging up snubbing unit for operations. Spot and power up accumulator building, install choke and kill lines, function test BOPs, run lines from manifold to gas buster, flow back and panic line, run drill water line from production well room to rig pump tank for BOP test, transfer water to pump tank. Note: Approximately 22:00 hrs discovered that the TSI window is only 10' in length. Requested a 12' - 14' window as per the previous ESP campaign at West Mac. Total: 24.00 www.resourceenergysolutions.com Generated Oct 04, 2023 18:04 Page 2 of 2 Daily Completion Well Name: Country: RU-02A United States State:Alaska Activity: Well Number: 50-733-20501-01-00 API: RU-02A ESP Replacement Date:Jul 22, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Paul Smith (inac 9075290737206-914-7247Wes JeardoeSupervisor: Tom Boyd (i ti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Temp:53 °F Wind Speed:Up to 29 km/h Weather:Clear Road Cond:Lease Cond:Good KB-THF:ftKB-Ground:1 ftKB:2 ft Day 10 Rig Name:Rig Release: Licence #: Rig Number:Personnel On Location:25 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 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:Attempting to get successful BOP shell test, hammering up stack flange leaks. 24 Hr Summary:Rigging up snubbing unit, decision made 10' work window not adequate for ESP running, transport window extensions, remove jack unit from window, wait on weather for transport to platform, receive and install window legs to snubbing unit, set jacks on well, rig up snubbing unit, bleed annulus for BOP test, (simops, hang tarps on snubbing unit rig up "yoyo" line). 24 Hr Forecast:Obtain successful shell test, Notify AOGCC, rig up to pull ESP completion, test BOPE per procedure and AOGCC requirements. Remarks:POB 24: Production 2, Drilling 19, Catering 3 Helicopter Trips 3 (TSI 2 x 4' jack risers out, Canrig 1 PAX in), (TSI 2 x 4' risers out, to/back WestMac hoses, Summit 3 PAX in), (Empty out, 1 Summit, 1 TSI PAX in). Note: TSI PAX for Fury mechanic work Boat Trips 0 KB-RT:ft www.resourceenergysolutions.com Generated Oct 04, 2023 18:04 Page 1 of 2 Daily Completion Well Name: Country: RU-02A United States State:Alaska Activity: Well Number: 50-733-20501-01-00 API: RU-02A ESP Replacement Date:Jul 23, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Paul Smith (inac 9075290737206-914-7247Wes JeardoeSupervisor: Tom Boyd (i ti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Time Log Time From Time To Hours Code Comments 00:00 02:30 2.50 Rig Up / Rig Out / Repair Service Rig Rigging up snubbing equipment for well work. Fill rig pump tank with drill water, run and install flow line from Mud Cross to rig tank, rig up basket and gin pole. Swap out 90 on Co- flex choke hose. Rig up tongs. (simops, Loosen storm clamps of Rig 35 Skid Beams). 02:30 06:00 3.50 Rig Up / Rig Out / Repair Service Rig Rig up work basket and Gin Pole. Swap out 90 on Co-Flex hose. Rig up Tongs. Note: Annulus has 100 psi pressure recorded. Rig up lay-down line. PJSM with Day Crew. Discuss upcoming operations, Lifting operations watch for overhead loads when leaving the quarters. Hand over with Night Crew 06:00 09:00 3.00 Rig Up / Rig Out / Repair Service Rig Vault and TSI assemble Test Joint. Note: at 8:00am meeting discussed the failure of TSI to provide a 12' Operating Window. This was specifically requested by Glacier and was confirmed by TSI that the window was 12'. Last night (7/22/2023) at 21:00 hrs it was discovered that the window was 10'). Advised TSI that dayrate is $0. 09:00 14:00 5.00 Waiting Discuss Window height with TSI and Summit. Source 4' Window riser Extensions. Wait on Fog to bring extensions out to Rig. Prepare to rig down Work Basket and Window. Change out 3-1/2" Slips for 2-7/8" (Pick-up Sub OD). Lower Gin Pole, Lay down Ladders and Lay- Down line. Locate and mobilize hydraulic hoses for Rig 35 skid operations. 14:00 18:00 4.00 Rig Up / Rig Out / Repair Service Rig Hold PJSM for removal of Snubbing Unit work basket, window and replacement of window riser extensions. Pick up 2-7/8" Pick-up Sub and lock into Snubbing unit. Commence replacement of riser extensions. 18:00 20:00 2.00 Rig Up / Rig Out / Repair Service Rig Finish replacing the 2' extensions with 4' extensions. Re-assemble snubbing unit. Use guy lines to level rig and pull lifting jt. from stack. Rig up tongs. Scope out gin pole and install lay down line. 20:00 24:00 4.00 BOPS-Install / Remove / Pressure Test Production operator bleed down tubing annulus from 100 psi. While waiting on well to bleed down conducted SIMOPS of: Hang tarps on work over unit. Rig up "YoYo" line. Total: 24.00 www.resourceenergysolutions.com Generated Oct 04, 2023 18:04 Page 2 of 2 Daily Completion Well Name: Country: RU-02A United States State:Alaska Activity: Well Number: 50-733-20501-01-00 API: RU-02A ESP Replacement Date:Jul 23, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Paul Smith (inac 9075290737206-914-7247Wes JeardoeSupervisor: Tom Boyd (i ti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Temp:50 °F Wind Speed:Up to 39 km/h Weather:Clear Road Cond:Lease Cond:Good KB-THF:ftKB-Ground:1 ftKB:2 ft Day 11 Rig Name:Rig Release: Licence #: Rig Number:Personnel On Location:24 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 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:Rigging up Summit equipment for pulling ESP. 24 Hr Summary:Test BOPE, Move Glacier rig 35 to east side of pony sub. rigging up Summit equipment. 24 Hr Forecast:Complete rig up Summit equipment, install TSI rig tarps, remove BPV, install landing joint, check well for pressure, kill well as necessary, pick up hanger, cut cable install ESP cable to spooler, POH laying 3 1/2 ESP tubing completion. Remarks:BOP test witnessed by AOGCC inspector Kam Stjohn. KB-RT:ft www.resourceenergysolutions.com Generated Oct 04, 2023 18:04 Page 1 of 2 Daily Completion Well Name: Country: RU-02A United States State:Alaska Activity: Well Number: 50-733-20501-01-00 API: RU-02A ESP Replacement Date:Jul 24, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Paul Smith (inac 9075290737206-914-7247Wes JeardoeSupervisor: Tom Boyd (i ti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Time Log Time From Time To Hours Code Comments 00:00 04:00 4.00 BOPS-Install / Remove / Pressure Test PJSM. Annulus = 0 psi on gauge. PJSM, Make up Vault blanking sleeve on 3 1/2" test joint. set and engage hanger, charge pump batteries for filling stack, (simops PJSM, set jacks on Glacier rig 35 for move east), rig fill stack with water, check for leaks. 04:00 06:00 2.00 BOPS-Install / Remove / Pressure Test Attempt to shell test BOPE, 250 psi low 3,000 psi high, tighten flange leak on kill flow cross . 06:00 10:00 4.00 BOPS-Install / Remove / Pressure Test Continue to tighten flanges and prep for shell test. 10:00 13:00 3.00 BOPS-Install / Remove / Pressure Test Fill stack and close annular and pressure test up to 3 closed valves on choke manifold low test 300psi good. High test 2600psi No test (Try to test 4 times all fails) Remove landing joint and inspect seals on test dart (No O-ring seal found on test dart) Re-install landing joint and when treading in vault hand said sleeve didn't act right. Stop and remove landing again to inspect threads and (vault hand made call to his office to verify tool installation was correct. 13:00 14:00 1.00 BOPS-Install / Remove / Pressure Test PJSM. Re-install landing joint as per vaults instructions. Install kelly hose to safety valve to tubing and fill stack and surface and choke manifold with fresh water with rig pump. Close annular and Valves 1,2,3 on choke manifold and pressure test to 300 psi low and 2600 psi high ALL test good both test 5 mins charted. Continue BOPE testing per rig operating procedure Test outside kill and HCR, perform Koomey draw down test, Testing witnesses by AOGCC inspector Kam Stjohn. 14:00 15:00 1.00 Rig Up / Rig Out / Repair Service Rig PJSM. Continue to rig up and perform housekeeping while waiting on inspector to arrive. Could not work on rig tarps due to windy conditions for the man basket. 15:00 18:00 3.00 BOPS-Install / Remove / Pressure Test PJSM, Perform BOP testing. All tests held 5 mins., High test 3,000 psi. 5 mins Test all gas monitors and can rig alarms for inspector, test 1 VBR and Valve 2,4,5,7,8 closed low test 300psi 5 mins High test 3,000 psi 5 mins, good. BOP test 2 VBRs and Valve 6,7,8 closed. test 250 low and 3,000 psi high, 5 mins. good, test. VBRs and Valve 9, closed low test 300 psi., good. BOP test VBRs and super choke test. Test Manuel choke and VBRs 250/ 3,000 psi. good 18:00 20:00 2.00 BOPS-Install / Remove / Pressure Test PJSM, continue BOP testing. Pressure test blind rams and HCR against outside kill valve. 300 psi low 2,500 psi high, good. 20:00 22:30 2.50 Move Equipment / Service Rig Move Drilling Glacier rig #35 7' to the East. Secured Storm clamps. Secure / plug lines and removed jacks and hydraulic system. install air lines to compressor. Rigged in High pressure produced water line from production to rig tank. 22:30 24:00 1.50 Move Equipment / Service Rig Set up extra lights to illuminate lower deck. Clean up deck in preparation for spotting summit equipment. Rigged in fuel system for filling power pack and pump. Installed fuel nozzle on the north side of platform to fuel air compressor Total: 24.00 www.resourceenergysolutions.com Generated Oct 04, 2023 18:04 Page 2 of 2 Daily Completion Well Name: Country: RU-02A United States State:Alaska Activity: Well Number: 50-733-20501-01-00 API: RU-02A ESP Replacement Date:Jul 24, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Paul Smith (inac 9075290737206-914-7247Wes JeardoeSupervisor: Tom Boyd (i ti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Temp:48 °F Wind Speed:Up to 19 km/h Weather:Clear Road Cond:Lease Cond:Good KB-THF:ftKB-Ground:1 ftKB:2 ft Day 12 Rig Name:Rig Release: Licence #: Rig Number:Personnel On Location:25 Safety SITP:0 psi SICP:0 psi Last BOP Press Test:Jul 24, 2023 Last BOP Drill: H2S:No %Last Safety Meeting:Last Rig Inspection:Jul 24, 2023 Time Log Time From Time To Hours Code Comments 00:00 06:00 6.00 Run / Pull / Test Downhole Pump Clear rig 35 pony sub, install Summit spooler on sub, confirm its operational in place, and working environment with Summit, good. Fill rig tank with produced water from production. check annulus for pressure, observed 10 psi, bleed annulus to 0 psi. 06:00 10:00 4.00 Rig Up / Rig Out / Repair Service Rig PJSM, Work on Wind wall around unit (Very windy conditions) Hold meeting on removing hanger without wind wall (Tarps) up Get go ahead to pull hanger out. 10:00 11:30 1.50 Run / Pull / Test Downhole Pump PJSM, remove vaults test dart out of hole and pull and lay down landing joint. Pick up rods to remove back pressure valve. Remove back pressure valve and lay down rods. Make up X- over to sting into hanger on to landing. Pick up landing joint (Landing joint is 2 joints and a 10 -foot pup) and install in stack and sting into hanger and torque up. BOLDS Check well bore pressure. Pull hanger (Pipe moving at 100K) pull hanger to work window (Lay down one joint of landing joint) Stop operations due to Summit safety stand down. Pick up joint to get hanger back down below VBR rams and TIW installed. 11:30 12:30 1.00 Safety Meeting Halliburton ZOOM safety stand down meeting with management to address safety concerns. 12:30 17:30 5.00 Run / Pull / Test Downhole Pump PJSM. Pull hanger and set hanger in air slips at good working height to dress hanger, Previous records stated 150 up wt. 265K down wt. Observed string wt, 100K. remove hanger and cross over from landing joint Pull landing joints out of hole plus 2 joints and 6-foot pup (washing joints with pressure washer in work window as joints coming out of hole). 17:30 24:00 6.50 Run / Pull / Test Downhole Pump POOH from JNT # 4 to JNT # 45 Pulling clamps and spool wire. Change out tong dies. Move Wood Pallet down to lower deck and move lay down line skid in preparation for tiers # 2 hook lay down line back up and function test. Continue to POOH to JNT # 55. Washing completion string with pressure washer in window for cleaning oil from pipe and cable. Total: 24.00 Wellbores Wellbore KOP MD (ft)KOP TVD (ft)TD MD (ft)TD TVD (ft) Main Wellbore 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 @ joint #125 24 Hr Summary:Set in and rig up Summit ESP equipment, work on rig wind walls, pull BPV and BOLDS, pull hanger to floor. Hold Summit safety stand down, lay down hanger and POH with 3 1/2" completion. 24 Hr Forecast:Continue to lay down completion. Observe fish tail and plan for further actions. Remarks:*Previous well records say string weight 150 k dn, 265K up, observed string weight pulling hanger 100k. *No free oil observed in or on pipe layed down on deck. KB-RT:ft www.resourceenergysolutions.com Generated Oct 04, 2023 18:05 Page 1 of 1 Daily Completion Well Name: Country: RU-02A United States State:Alaska Activity: Well Number: 50-733-20501-01-00 API: RU-02A ESP Replacement Date:Jul 25, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Paul Smith (inac 9075290737206-914-7247Wes JeardoeSupervisor: Tom Boyd (i ti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Temp:52 °F Wind Speed:Up to 19 km/h Weather:Partly Cloudy Road Cond:Lease Cond:Good KB-THF:ftKB-Ground:1 ftKB:2 ft Day 13 Rig Name:Rig Release: Licence #: Rig Number:Personnel On Location:25 Safety SITP:0 psi SICP:0 psi Last BOP Press Test:Jul 24, 2023 Last BOP Drill: H2S:No %Last Safety Meeting:Last Rig Inspection:Jul 24, 2023 Wellbores Wellbore KOP MD (ft)KOP TVD (ft)TD MD (ft)TD TVD (ft) Main Wellbore 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:Prep for RU2A equipment load out to boat, offload RU5 tools and equipment for RU5. 24 Hr Summary:POH laying down 3 1/2" ESP completion. Observes end or string @ joint # 205, decision made to run kill string move to RU 5. Prep to run kill string and secure well RU02A. 24 Hr Forecast:Secure RU 02A, Offload RU2 tubular to boat for deck space to rig down and move snubbing unit to RU5, off load boat with RU5 materials. Kill RU5, rig down and move off snubing unto set on deck, nipple down RU5 tree, remove BOPs from RU2 set on RU 5, install and test RU 2 tree, nipple up and prep for BOP test. Remarks:Recovered 6,409' RU02A 3 1/2" completion string. KB-RT:ft www.resourceenergysolutions.com Generated Oct 04, 2023 18:05 Page 1 of 2 Daily Completion Well Name: Country: RU-02A United States State:Alaska Activity: Well Number: 50-733-20501-01-00 API: RU-02A ESP Replacement Date:Jul 26, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Paul Smith (inac 9075290737206-914-7247Wes JeardoeSupervisor: Tom Boyd (i ti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Time Log Time From Time To Hours Code Comments 00:00 00:30 0.50 Run / Pull / Test Downhole Pump Pump 10 bbl produced water to annulus for pipe cleaning. 00:30 05:30 5.00 Run / Pull / Test Downhole Pump Continue POH with ESP completion from jt #56 to jt# 125.. 05:30 06:00 0.50 Run / Pull / Test Downhole Pump Pump 10 bbl to tubing for cleaning tubing. Clear work area Lower dumpster and load clamps. Fill bleed off tank with 2BBLS for pressure washer for pipe cleaning. 06:00 07:00 1.00 Move Equipment / Service Rig Fuel equipment and do slip inspections and tong inspections, Replace to 1 big snap ring on stat heavy slips, Drain water out of air compressor, check and inspect all over head lifting equipment . Cap off heavy winch line control handle and send handle down 07:00 13:00 6.00 Run / Pull / Test Downhole Pump Continue POH with 3 1/2" P110 12.95# PH6 tubing from joint #125 to joint #203. While breaking connection between 202 and 203, the pin of 202 snapped off clean at ~4 threads in the box of 203. Continue POH to tail of fish jt # 205. Observed that the pin of #205 was snapped off clean at ~4 threads in the same way that 202 was broken. Recovered a total of 205 joints = 6,409' of 3 1/2" tubing,. (This number "205" is the count of what was laid down, not the number as ran). #206 was left in the hole looking up with a pin broken off in it's box and a cross collar clamp possibly around tool joint. Measurements of dual cap tubes indicated that ~21 feet of ss cap tubes and 31 feet of cap tube rubber coating is above 206 fish top. ESP cable measurement was 34' from top of 205 at collar clamp, indicating that the ESP cable was parted below tool joint of 206 left in hole. If string fell to bottom of well, top of fish would be estimated at 7399' MD. Close blinds. *Recovered total 204 cross collar clamps and 2 each SS bands (Pump 10 bbls at Joint 150 to casing and 10 bbls down tubing at joint jt # 180) Point of Reference Distance Cap String 20.10 Top of Clamp on Joint 206 1.00 Top of Joint 206 0.00 ESP Cable 4.20 Top of Fish if on Bottom 7,399 Length of fish (tubing & ESP) 7,737 Bottom of well / Top of shoetrack 15,136 7" Shoetrack length 140 7" Casing Shoe 15,275 13:00 18:00 5.00 Run / Pull / Test Downhole Pump PJSM on installing test plug . Install test plug and retest blind rams 300 psi low, 3,100 psi high each test 5 min. Fuel up equipment and housekeeping . Install thread protectors on 3 1/2 ph6. 18:00 19:00 1.00 Tripping Tubing Guy snubbing unit and rig down gin pole for deck management in preparation for offloading PH6 3.5" pipe. Re-wired stroke counter. Rig down gin Pole and lay down line and YO-YO line. 19:00 22:30 3.50 Tripping Tubing Move 3 1/2" PH6 pipe from lower deck onto top deck in bundles of 15 5 bundles total placed. Checked N2 bottle's in accumulator. Punched and inspected fire extinguishers. Checked all Egress routes. Decision made to move off RU02A and move to RU7 22:30 22:30 Tripping Tubing Rig up lay down line and yo yo line. Move pipe to find the 10 jts 3 1/2" PH6 to RIH for landing hanger. Rig up gin pole and basket. Prepare to RIH hole with 10 JNT's and land tubing hanger. 22:30 24:00 1.50 Tripping Tubing PJSM. prep picking up kill string and Landing tubing hanger. Total: 24.00 www.resourceenergysolutions.com Generated Oct 04, 2023 18:05 Page 2 of 2 Daily Completion Well Name: Country: RU-02A United States State:Alaska Activity: Well Number: 50-733-20501-01-00 API: RU-02A ESP Replacement Date:Jul 26, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Paul Smith (inac 9075290737206-914-7247Wes JeardoeSupervisor: Tom Boyd (i ti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Temp:56 °F Wind Speed:Calm Weather:Drizzle/Mist Road Cond:Lease Cond:Good KB-THF:ftKB-Ground:1 ftKB:2 ft Day 14 Rig Name:Rig Release: Licence #: Rig Number:Personnel On Location:26 Safety SITP:0 psi SICP:0 psi Last BOP Press Test:Jul 24, 2023 Last BOP Drill: H2S:No %Last Safety Meeting:Last Rig Inspection:Jul 24, 2023 Time Log Time From Time To Hours Code Comments 00:00 02:30 2.50 Tripping Tubing Tally and drift 10 each 3 1/2" PH6 CTK-6 p-110 tubing . RIH and set in air slips. Lift Hanger to Basket. Make up tubing hanger. Tripping BOP drill held during kill string pick up. 10 joints 3 1/2" PH6 tubing and pup below hanger = 319.57', (10 joints tubing plus 10' pup below hanger). 02:30 04:00 1.50 Install or Change Wellhead Land hanger in wellhead, RILDS, set BPV in hanger, Vault test hanger seals t/ 5.000 psi for 15 min, good test. 04:00 06:00 2.00 Move Equipment / Service Rig Break down Co-flex hoses and BOP lines to clear deck for pipe load to boat. Continue to place pipe in Bundles of 15 in preparation to back load pipe. Arrange and prep loads for backhaul RU2 tubulars and equipment 06:00 15:30 9.50 Move Equipment / Service Rig Continue preparing tools and equipment for offload to boat. 15:30 18:30 3.00 Move Equipment / Service Rig Load out to boat with RU2A tools and production tubing, offload equipment for RU5 well work. 18:30 24:00 5.50 Perforate Arrange drill deck space, set Alaska E-Line unit on drill deck, rig up Eline for perforating RU-5 tubing for circulation. Total: 24.00 Wellbores Wellbore KOP MD (ft)KOP TVD (ft)TD MD (ft)TD TVD (ft) Main Wellbore 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 Alaska E Line for tubing punch. 24 Hr Summary:Prepare for suspend RU 02A and move to RU.5,rack and run kill string land in hanger, test hanger seals to 5K good, prepare decks and loads for boat, work boat, spot and rig up Alaska E Line for tubing punch. 24 Hr Forecast:Punch RU 05B tubing, kill well, set BPV, rig down snubbing unit, remove snubbing unit from RU 02A set on deck, nipple down RU 05B tree, set riser and BOPE from RU 05B onto RU 05B, install and test production tree onto RU 02A set BPV and test, nipple up BOPE on RU 05B, prepare for BOP test. Remarks:48 hour Notice of BOP test submitted to AOGCC for 7/29/23 @ 10 AM. 10 joints 3 1/2" PH6 tubing and pup below hanger = 319.57', (10 joints tubing plus 10' pup below hanger). KB-RT:ft www.resourceenergysolutions.com Generated Oct 04, 2023 18:05 Page 1 of 1 Daily Completion Well Name: Country: RU-02A United States State:Alaska Activity: Well Number: 50-733-20501-01-00 API: RU-02A ESP Replacement Date:Jul 27, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Paul Smith (inac 9075290737206-914-7247Wes JeardoeSupervisor: Tom Boyd (i ti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Temp:65 °F Wind Speed:Up to 19 km/h Weather:Rain Road Cond:Lease Cond:Good KB-THF:ftKB-Ground:1 ftKB:2 ft Day 15 Rig Name:Rig Release: Licence #: Rig Number:Personnel On Location:22 Safety SITP:0 psi SICP:0 psi Last BOP Press Test:Jul 24, 2023 Last BOP Drill: H2S:No %Last Safety Meeting:Last Rig Inspection:Jul 24, 2023 Time Log Time From Time To Hours Code Comments 00:00 03:00 3.00 Perforate PJSM, Rig up Eline on lower deck for perforating RU-05A tubing for well kill circulation. 03:00 04:30 1.50 Perforate RU-05A prep work. Test lubricator to 3,000 psi. Attempt to RIH, tools would not fall. lay down tool string, work on grease head / pack off. stab back on well, observed 400 psi on tubing 100 psi on annulus, tool string still unable to fall, pop off well, add sinker bars, stab back on well and RIH with 10 shot, 6 spf, 3 gram 1/4" shots. 04:30 06:00 1.50 Perforate RIH with tubing punch guns to perforating RU-05A tubing for well kill circulation. 06:00 12:00 6.00 Perforate Continue RIH with tubing punch t/ perforate, tie in depth, fire guns, good indication of firing, top shot @ 14,300' with 10 shot, 6 spf, 3 gram 1/4" shots. All shots fired. POH, rig down Alaska E-Line unit. 12:00 18:00 6.00 Move Equipment / Service Rig PJSM for setting Jack unit, BOPs and riser spool off RU-02A to deck. Position stumps for Jack unit and BOP stack . Install pick up sub in Jack stack and close slips on pick up sub . pull 30K lbs. into slips with crane . Unbolt and disconnect guy lines from Jack unit and work window from BOPs. Pick and install on stump (Jack and window 62K on hook), bolt down and install and tighten up guy lines . Latch on to BOPs with crane and remove BOPs off of riser spool, set on stump and bolt down and install chains for securement. Install pick up cap onto riser spool and remove riser spool off well and lay down spool . Pick up wellhead and install on well RU-05B. 18:00 24:00 6.00 BOPS-Install / Remove / Pressure Test PJSM, Install Wing Valves on Well RU-02A. Test Tree with vault test pump.(Sim-ops) Finish Bottoms up on 5 well kill, (pumped 860 bbl produced water, returned 475 bbl (352 bbl water, 123 bbl oil @ 2 bpm @ 320 psi. , bleed off pressure and flow check, no flow. Install BPV in tubing hanger. Test RU-02A hanger, void and tree to 5,000 psi, witness by production operator. Secure well RU-02A hand over to production. Release to RU-05A. Total: 24.00 Wellbores Wellbore KOP MD (ft)KOP TVD (ft)TD MD (ft)TD TVD (ft) Main Wellbore 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 up snubbing unit, prep for BOP test on RU 05A. 24 Hr Summary:Rig up Alaska Eline unit, RIH, perforate tubing for circulation, circulate, kill well. Set BPV, & move TSI off RU 02A to deck, nipple down RU02A stack and set on drill deck, nipple up tree and test RU 02A tree. (Sim Ops Kill RU 05A with produced water). Release from RU 02A to RU 05A. 24 Hr Forecast:Rig up TSI unit, Nipple up BOP on RU 05A, test BOPE, prep to POH with ESP completion. Remarks:BOP test witness waived by Jim Regg 7/28/23 09:25 AM KB-RT:ft www.resourceenergysolutions.com Generated Oct 04, 2023 18:05 Page 1 of 1 Daily Completion Well Name: Country: RU-02A United States State:Alaska Activity: Well Number: 50-733-20501-01-00 API: RU-02A ESP Replacement Date:Jul 28, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Paul Smith (inac 9075290737206-914-7247Wes JeardoeSupervisor: Tom Boyd (i ti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Temp:°F Wind Speed:Weather:Road Cond:Lease Cond: KB-THF:ftKB-Ground:1 ftKB:2 ft Day 16 Rig Name:Rig Release: Licence #: Rig Number:Personnel On Location: Safety SITP:0 psi SICP:0 psi Last BOP Press Test:Jul 24, 2023 Last BOP Drill: H2S:No %Last Safety Meeting:Last Rig Inspection:Jul 24, 2023 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 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 18:05 Page 1 of 1 Daily Completion Well Name: Country: RU-02A United States State:Alaska Activity: Well Number: 50-733-20501-01-00 API: RU-02A ESP Replacement Date:Jul 29, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Paul Smith (inac 9075290737206-914-7247Wes JeardoeSupervisor: Tom Boyd (i ti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Temp:°F Wind Speed:Weather:Road Cond:Lease Cond: KB-THF:ftKB-Ground:1 ftKB:2 ft Day 17 Rig Name:Rig Release: Licence #: Rig Number:Personnel On Location: Safety SITP:0 psi SICP:0 psi Last BOP Press Test:Jul 24, 2023 Last BOP Drill: H2S:No %Last Safety Meeting:Last Rig Inspection:Jul 24, 2023 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 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 18:05 Page 1 of 1 Daily Completion Well Name: Country: RU-02A United States State:Alaska Activity: Well Number: 50-733-20501-01-00 API: RU-02A ESP Replacement Date:Jul 30, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Paul Smith (inac 9075290737206-914-7247Wes JeardoeSupervisor: Tom Boyd (i ti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Temp:°F Wind Speed:Weather:Road Cond:Lease Cond: KB-THF:ftKB-Ground:1 ftKB:2 ft Day 18 Rig Name:Rig Release: Licence #: Rig Number:Personnel On Location: Safety SITP:0 psi SICP:0 psi Last BOP Press Test:Jul 24, 2023 Last BOP Drill: H2S:No %Last Safety Meeting:Last Rig Inspection:Jul 24, 2023 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 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 18:05 Page 1 of 1 Daily Completion Well Name: Country: RU-02A United States State:Alaska Activity: Well Number: 50-733-20501-01-00 API: RU-02A ESP Replacement Date:Jul 31, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Paul Smith (inac 9075290737206-914-7247Wes JeardoeSupervisor: Tom Boyd (i ti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Temp:°F Wind Speed:Weather:Road Cond:Lease Cond: KB-THF:ftKB-Ground:1 ftKB:2 ft Day 19 Rig Name:Rig Release: Licence #: Rig Number:Personnel On Location: Safety SITP:0 psi SICP:0 psi Last BOP Press Test:Jul 24, 2023 Last BOP Drill: H2S:No %Last Safety Meeting:Last Rig Inspection:Jul 24, 2023 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 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 18:05 Page 1 of 1 Daily Completion Well Name: Country: RU-02A United States State:Alaska Activity: Well Number: 50-733-20501-01-00 API: RU-02A ESP Replacement Date:Aug 1, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Paul Smith (inac 9075290737206-914-7247Wes JeardoeSupervisor: Tom Boyd (i ti 7132025078907-252-5297Jerry Otto (inac....Supervisor: Temp:°F Wind Speed:Weather:Road Cond:Lease Cond: KB-THF:ftKB-Ground:1 ftKB:2 ft Day 20 Rig Name:Rig Release: Licence #: Rig Number:Personnel On Location: Safety SITP:0 psi SICP:0 psi Last BOP Press Test:Jul 24, 2023 Last BOP Drill: H2S:No %Last Safety Meeting:Last Rig Inspection:Jul 24, 2023 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 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 18:05 Page 1 of 1 Daily Completion Well Name: Country: RU-02A United States State:Alaska Activity: Well Number: 50-733-20501-01-00 API: RU-02A ESP Replacement Date:Aug 2, 2023 Job Type:No Proppant Frac Sub Type:WorkOver Completion Operator:Paul Smith (inac 9075290737206-914-7247Wes JeardoeSupervisor: Tom Boyd (i ti 7132025078907-252-5297Jerry Otto (inac....Supervisor: STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________REDOUBT UNIT 2A JBR 09/20/2023 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:4 F/P on Meth Gas Detector Sensor recalibrated and passed. PTD/Sundry not on deck or the standing order but that got resolved passed. 15 Accumulator bottles at 1000 Psi pre charge Test Results TEST DATA Rig Rep:Tom MatthewsOperator:Cook Inlet Energy, LLC.Operator Rep:Tom Boyd/Paul Smith Rig Owner/Rig No.:Team Snubbing TSI 102 PTD#:2121720 DATE:7/24/2023 Type Operation:WRKOV Annular: 250/3000Type Test:INIT Valves: 250/300 Rams: 250/3000 Test Pressures:Inspection No:bopKPS230725124659 Inspector Kam StJohn Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 6 MASP: 2592 Sundry No: 323-275 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location FP Standing Order Posted FP Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 8 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13-5/8"P #1 Rams 1 2-7/8" x 5-1/2 P #2 Rams 1 Blinds P #3 Rams 1 Empty NT #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2-1/16"P HCR Valves 1 2-1/16"P Kill Line Valves 2 2-1/16"P Check Valve 0 NA BOP Misc 1 2-1/16"P System Pressure P3000 Pressure After Closure P1675 200 PSI Attained P28 Full Pressure Attained P90 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P4 @ 2100 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators P PFlow Indicator FP FPMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P28 #1 Rams P6 #2 Rams P6 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill NA0 9 9 9 9 9999 9 9 9 9 9 9 9 FP FP FP FP F/P on Meth Gas Detector PTD/Sundry not on deck standing order 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 2:54:00 PM Attachments:image003.png 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 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' 5HGRXEW8QLW$5HGRXEW8QLW 37' Redoubt Unit 2A(PTD 2121720) 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 Shut-in since May 2020-Producer - RU-2A 9/27/21 4,548 0.3812,01114,177 Hemlock y Sep2021. 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DPH HUJ\//& TXHVW $EDQGRQ 3OXJ3HUIRUDWLRQV )UDFWXUH6WLPXODWH 5HSDLU:H 2SHUDWLRQVVKXWGRZQSDLU:HOO 6XVSHQG 3HUIRUDWH 2WKHU6WLPXODWH 3XOO7XELQJ &KDQJH$SOO7XELQJ SURYHG3URJUDP 3OXJIRU5HGULOO 3HUIRUDWH1HZ3RRO 5HHQWHU6XVS:HOO $OWHU&DVLQJ 2WKHU5XQ(63HU&DVLQJ )RUP5HYLVHG$SSURYHGDSSOLFDWLRQYDOLGIRUPRQWKVIURPGDWHRIDSSURYDO6XEPLW3')WRDRJFFSHUPLWWLQJ#DODVNDJRY 323-275 By Kayla Junke at 3:38 pm, May 10, 2023 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: 2023.05.10 15:09:57 -08'00' SFD 5/30/2023 X DSR-5/10/23 Perform No Flow Test within 14 days of return to production after recompletion. Pressure test production casing to MPSP, 2600 psi after pulling ESP, before running new ESP. Lower test pressure will be considered based on using reservoir fluids to re-calculate MPSP. BOP test to 3000 psi. 3HUIRUDWH BJM 7/7/23 10-404 GCW 07/07/2023 07/07/23 Brett W. Huber, Sr. Digitally signed by Brett W. 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ŶĐŚŽƌĂŐĞ͕<ϵϵϱϬϯ ϭ͘t>>EDʹZhͲϬϮ ZĞƋƵŝƌĞŵĞŶƚƐŽĨϮϬϮϱ͘ϬϬϱ;ĨͿ tĞůů^ƵŵŵĂƌǇ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗ dŚĞǁĞůůŝƐƐŚƵƚŝŶǁŝƚŚĂĨĂŝůĞĚ^WĐŽŵƉůĞƚŝŽŶ͘ ǆŝƐƚŝŶŐWĞƌĨŽƌĂƚŝŽŶƐ͗ D ds ϭϰϱϭϴ͛ʹϭϰϱϵϲ͛ ϭϭϳϳϴ͛ʹϭϭϴϰϬ͛ ϭϰϲϱϳ͛ʹϭϰϳϮϰ͛ ϭϭϴϴϵ͛ʹϭϭϵϰϱ͛ ϭϰϳϵϮ͛ʹϭϰϴϯϲ͛ ϭϭϵϵϵ͛ʹϭϮϬϯϱ͛ ϭϰϴϴϬ͛ʹϭϰϵϱϯ͛ ϭϮϬϳϮ͛ʹϭϮϭϯϮ͛ ϭϰϵϳϮ͛ʹϭϱϬϭϯ͛ ϭϮϭϰϳ͛ʹϭϮϭϴϮ͛ ϭϱϬϯϬ͛ʹϭϱϬϵϬ͛ ϭϮϭϵϱ͛ʹϭϮϮϰϱ͛ ĚĚEĞǁWĞƌĨŽƌĂƚŝŽŶƐ͗ D ds ϭϱϭϬϳ͛ʹϭϱϭϲϳ͛ ϭϮϮϱϵ͛ʹϭϮϯϬϵ͛ ^ĐŽƉĞŽĨtŽƌŬ͗ x<ŝůůǁĞůů xĐŝĚ^ƚŝŵƵůĂƚĞǁĞůůďŽƌĞƉƌŝŽƌƚŽĂƌƌŝǀĂůŽĨƌŝŐ xZŝŐƵƉdĞĂŵ^ŶƵďďŝŶŐ;d͘^ͿZŝŐ xWƵůů^WĐŽŵƉůĞƚŝŽŶĂŶĚƚƵďŝŶŐ xWͬhǁŽƌŬƐƚƌŝŶŐĂŶĚŵĂŬĞĐůĞĂŶŽƵƚƌƵŶ xZ/,ǁŝƚŚƉĞƌĨŐƵŶƐĂŶĚƉĞƌĨŽƌĂƚĞƐĞůĞĐƚĞĚǌŽŶĞƐ xWͬh^WŽŵƉůĞƚŝŽŶĂŶĚZ/,ƚŽнͬͲϭϰ͕ϮϬϬ͛D xEͬKWΘEͬhWƌŽĚƵĐƚŝŽŶdƌĞĞ xdƵƌŶŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶĂŶĚĨůŽǁǁĞůů 'ĞŶĞƌĂůtĞůů/ŶĨŽƌŵĂƚŝŽŶ͗ ZĞƐĞƌǀŽŝƌWƌĞƐƐƵƌĞͬds͗ Ϭ͘ϯϮƉƐŝͬĨƚсϯ͕ϳϲϵƉƐŝΛϭϰ͕ϱϭϴ͛D;ϭϭ͕ϳϳϴ͛dsͿ D^W͗ ZĞƐĞƌǀŽŝƌWƌĞƐƐƵƌĞʹ;'ĂƐ'ƌĂĚŝĞŶƚydsͿ ;Ϭ͘ϯϮƉƐŝͬĨƚyϭϭ͕ϳϳϴ͛dsͿʹ;Ϭ͘ϭƉƐŝͬĨƚyϭϭ͕ϳϳϴ͛dsͿ сϯ͕ϳϲϵƉƐŝʹϭ͕ϭϳϳƉƐŝсϮ͕ϱϵϮƉƐŝ Set test plug in 7" liner below TOC at approx 13,500' and pressure test to 1500 psi. -bjm tĞůůŚĞĂĚdǇƉĞͬWƌĞƐƐƵƌĞZĂƚŝŶŐ͗ ϭϯϱͬϴ͟ϱDtĞůůŚĞĂĚͲϯϭͬϮ͟ϱDƚƌĞĞ 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oŽŶƚŝŶƵŽƵƐůǇŵŽŶŝƚŽƌĂŶŶƵůĂƌƉƌĞƐƐƵƌĞƚŚƌŽƵŐŚƚŚĞƌĞŵĂŝŶĚĞƌŽĨƚŚŝƐŽƉĞƌĂƚŝŽŶ͘ ůĞĞĚƚŚĞƌŵĂůĞǆĐƵƌƐŝŽŶƐͬŽǀĞƌƉƌĞƐƐƵƌĞĂƐŶĞĞĚĞĚ͘ ϴ͘ZĞĐŽƌĚĨůŽǁƌĂƚĞĨƌŽŵZhͲϭ&/d͘ ϵ͘^ŚƵƚŝŶĂŶĚǁĂŝƚĂƉĞƌŝŽĚŽĨŽŶĞŚŽƵƌ ϭϬ͘tŚŝůĞŵŽŶŝƚŽƌŝŶŐͬƌĞĐŽƌĚŝŶŐǁĞůůŚĞĂĚƉƌĞƐƐƵƌĞĂŶĚǁĂƚĞƌǀŽůƵŵĞůŝŶĞƵƉWtĚŽǁŶƚƵďŝŶŐ ĂŶĚŶŽƚĞǀŽůƵŵĞŶĞĐĞƐƐĂƌǇƚŽƐĞĞĂƐƉŝŬĞŝŶƉƌĞƐƐƵƌĞ͘ o^ƚĞƉƐϳĂŶĚϴŽĐĐƵƌƚŽĚĞƚĞƌŵŝŶĞŚŽǁŵƵĐŚůŝƋƵŝĚƚŚĞǁĞůů͞ĚƌŝŶŬƐ͟ďĞĨŽƌĞƚŚĞŚŝŐŚͲ ƉƌĞƐƐƵƌĞůŝŵŝƚƐŽĨƚŚĞKĂƌĞƌĞĂĐŚĞĚ͘ odŚŝƐǁŝůůďĞƵƐĞĚƚŽĞǀĂůƵĂƚĞŚŽǁůŽŶŐƚŚĞƉƌŽĐĞĚƵƌĞǁŝůůƚĂŬĞ ϭϭ͘>ŝŶĞͲƵƉϮďďůŽĨĚŝĞƐĞůƚŽŝƌKƉĞƌĂƚĞĚŽƵďůĞŝĂƉŚƌĂŐŵ;KͿ ƉƵŵƉĂŶĚƉƵŵƉĚŽǁŶƚŚĞ ƚƵďŝŶŐ oŽŶŽƚĞǆĐĞĞĚϮWDŝŶũĞĐƚŝŽŶƌĂƚĞ dƵƌŶŽĨĨK ϭϯ͘>ŝŶĞͲƵƉĂĐŝĚƚŽKĂŶĚƉƵŵƉĚŽǁŶƚŚĞƚƵďŝŶŐ oϭ/^K;Εϭϭϵ>ͿŽĨϭϱй,ůͬŵƵƚƵĂůƐŽůǀĞŶƚ oŽŶŽƚĞǆĐĞĞĚϮWDŝŶũĞĐƚŝŽŶƌĂƚĞ 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/,ǁŝƚŚƚƵďŝŶŐƉƵŶĐŚƚŽϭϯ͕ϵϬϬ͛ĂŶĚƉĞƌĨŽƌĂƚĞƚƵďŝŶŐĂďŽǀĞ^W, ϰ͘<ŝůůǁĞůůǁŝƚŚϴ͘ϱƉƉŐŝŶŚŝďŝƚĞĚƉƌŽĚƵĐĞĚǁĂƚĞƌ ϱ͘ŶƐƵƌĞƚŚĂƚǁĞůůŝƐĚĞĂĚ ZŝŐtŽƌŬŽǀĞƌ ϭ͘DŽǀĞdĞĂŵ^ŶƵďďŝŶŐZŝŐŽŶƚŽZhͲϬϮ͘ Ϯ͘ŚĞĐŬĨŽƌƉƌĞƐƐƵƌĞĂŶĚŶŽƚĞƉƌĞƐƐƵƌĞŝŶƚƵďŝŶŐĂŶĚŝŶĂŶŶƵůƵƐ͘ ϯ͘ZͬůŝŶĞƐĨƌŽŵƚƌĞĞĂŶĚĂŶŶƵůƵƐƚŽƉƌŽĚƵĐƚŝŽŶŝĨŶŽƚĚŽŶĞƉƌŝŽƌ ƚŽƌŝŐŵŽǀĞ͘ ϰ͘ŚĞĐŬĨŽƌĨůŽǁ͕ĞŶƐƵƌĞǁĞůůŝƐĚĞĂĚĂŶĚƐŚƵƚŝŶǁĞůů͘ ϱ͘WůĂĐĞďĂĐŬƉƌĞƐƐƵƌĞǀĂůǀĞŝŶǁĞůůŚĞĂĚ͘ ϲ͘EŽƚŝĨǇK'ϰϴŚŽƵƌƐŝŶĂĚǀĂŶĐĞŽĨƐƚĂƌƚŽĨŽƉĞƌĂƚŝŽŶƐĂŶĚƵƉĐŽŵŝŶŐKWƚĞƐƚ͘ ϳ͘EͬWƌŽĚƵĐƚŝŽŶdƌĞĞ͘ ϴ͘EͬhĂŶĚdĞƐƚϭϯϱͬϴ͟KWǁŝƚŚϮϳͬϴ͟ǆϱ͟sZƌĂŵƐǁŝƚŚďůŝŶĚƐŝŶŵŝĚĚůĞ͘ ϵ͘dĞƐƚKWŽŶϯЪ͟ƚŽϮϱϬƉƐŝůŽǁͬϯϬϬϬƉƐŝŚŝŐŚĂŶĚĐŚĂƌƚ͘ ϭϬ͘ZŝŐƵƉ^WƐƉŽŽůĞƌƐĂŶĚŚĂƌĚǁĂƌĞ͘ Displace wellbore fluids from both tubing and Inner Annulus before pulling tubing. -bjm ϭϭ͘ZĞŵŽǀĞďĂĐŬƉƌĞƐƐƵƌĞǀĂůǀĞ͘ ϭϮ͘Wͬh>ĂŶĚŝŶŐ:ŽŝŶƚĂŶĚŵĂŬĞƵƉƚŽϯϭͬϮ͟dƵďŝŶŐ,ĂŶŐĞƌ͘ Ă͘DĂǆƉƵůůŶŽƚƚŽĞǆĐĞĞĚϮϲϬ͕ϬϬϬǁŝƚŚŽƵƚŵĂŶĂŐĞŵĞŶƚĂƉƉƌŽǀĂů ŝ͘ϴϬйzŝĞůĚŽĨϯͲϭͬϮ͟ϭϮ͘ϱηWͲϭϭϬ ŝŝ͘tͬKtĞŝŐŚƚŽĨůŽĐŬƐ ϭϯ͘ĂĐŬŽƵƚ>ŽĐŬŽǁŶƐĐƌĞǁƐŝŶdƵďŝŶŐ,ĂŶŐĞƌ͘ 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 Ϯϭ͘WͬhϮͲϳͬϴ͟tŽƌŬƐƚƌŝŶŐĂŶĚĂƐŝŶŐ^ĐƌĂƉĞƌƐ ϮϮ͘Z/,ǁŝƚŚƐĐƌĂƉĞƌƐƚŽϭϰ͕ϬϬϬ͛D Ă͘EŽƚĞĂŶǇƚĂŐͲƵƉŽƌƚŝŐŚƚŝŶƚĞƌǀĂůƐ Ϯϯ͘ŝƌĐƵůĂƚĞďŽƚƚŽŵƐƵƉϰƚŝŵĞƐĂŶĚƉƌĞƉƚŽWK, Ϯϰ͘>ͬtŽƌŬ^ƚƌŝŶŐĂŶĚƉƌĞƉĨŽƌƉĞƌĨŽƌĂƚŝŶŐƌƵŶ Ϯϱ͘ZŝŐƵƉͲ>ŝŶĞhŶŝƚΘWͬh'ƵŶƐ Ϯϲ͘ZĞͲWĞƌĨŽƌĂƚĞĂŶĚĂĚĚŶĞǁƉĞƌĨŽƌĂƚŝŽŶƐƚŽƐĞůĞĐƚĞĚǌŽŶĞƐǀŝĂͲ>ŝŶĞ͗ ǆŝƐƚŝŶŐWĞƌĨŽƌĂƚŝŽŶƐ͗ D ds ϭϰϱϭϴ͛ʹϭϰϱϵϲ͛ ϭϭϳϳϴ͛ʹϭϭϴϰϬ͛ ϭϰϲϱϳ͛ʹϭϰϳϮϰ͛ ϭϭϴϴϵ͛ʹϭϭϵϰϱ͛ ϭϰϳϵϮ͛ʹϭϰϴϯϲ͛ ϭϭϵϵϵ͛ʹϭϮϬϯϱ͛ ϭϰϴϴϬ͛ʹϭϰϵϱϯ͛ ϭϮϬϳϮ͛ʹϭϮϭϯϮ͛ ϭϰϵϳϮ͛ʹϭϱϬϭϯ͛ ϭϮϭϰϳ͛ʹϭϮϭϴϮ͛ ϭϱϬϯϬ͛ʹϭϱϬϵϬ͛ ϭϮϭϵϱ͛ʹϭϮϮϰϱ͛ 23a. Run test plug or packer to 13,500' MD and test production casing and liner to 1500 psi. -bjm ĚĚEĞǁWĞƌĨŽƌĂƚŝŽŶƐ͗ D ds ϭϱϭϬϳ͛ʹϭϱϭϲϳ͛ ϭϮϮϱϵ͛ʹϭϮϯϬϵ͛ Ϯϳ͘DŽŶŝƚŽƌƚƌŝƉƚĂŶŬĨŽƌƉƌŽƉĞƌŚŽůĞĨŝůůŝŶŐ͘ Ϯϴ͘WƌĞƉƚŽƉŝĐŬƵƉ^WŽŵƉůĞƚŝŽŶĞƋƵŝƉŵĞŶƚ͕ƐƉŽŽůĞƌƐ͕ĂŶĚƚŽŽůƐ͘ Ϯϵ͘ZŝŐƵƉ^ƵŵŵŝƚĨŽƌ^WŽŵƉůĞƚŝŽŶƐ͘ Ă͘,ŽůĚW:^DĨŽƌ^WZƵŶ͘ ď͘dĞƐƚĂŶĚĐŽŶĨŝƌŵƚŚĂƚĂůůĞƋƵŝƉŵĞŶƚŝƐŽŶůŽĐĂƚŝŽŶĂŶĚƌĞĂĚǇƚŽ Z/,͘ Đ͘EKd͗KDW>d/KE^Wͬdh/E't/>>EKdZKdd͘ ϯϬ͘WŝĐŬƵƉƚŚĞ^WĐŽŵƉůĞƚŝŽŶĂƐƐĞŵďůǇĂƐĚŝƌĞĐƚĞĚ͘ Ă͘EKd͗^ĞƚƚŝŶŐĚĞƉƚŚŽĨ^W,ĂƚнͬͲϭϰ͕ϮϬϬ͛D;ŽŶĨŝƌŵǁŝƚŚ'>ŶŐŝŶĞĞƌ ƉƌŝŽƌƚŽZ/,Ϳ͘ ď͘WƵŵƉƐŚŽƵůĚďĞƐĞƚŝŶůĞƐƐƚŚĂŶϭĚĞŐƌĞĞͬϭϬϬ͛ĚŽŐůĞŐ͘;dŽƉŽĨWƵŵƉƐƐǇ ƚĞŶƚĂƚŝǀĞůǇƐĞƚĨŽƌϭϰ͕ϭϬϬ͛DͿ͘ Đ͘EKd͗ƚŚĞϯͬϴ͟ĨůĂƚƉĂĐŬĐŚĞŵŝĐĂůŝŶũĞĐƚŝŽŶůŝŶĞŝƐƚŽďĞƌƵŶƚŽƚŚĞĂŶŽĚĞŽŶƚŚĞ 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 Date: 5/5/2020 Tbg hanger requires EUE landing joint 36" A-36 200' MD 150# Welded 200' TVD 13 3/8" L-80 3,212' MD 68# BTC 2,918' TVD Top Of Liner - 8,148' MD (Whipstock window 8531-8540' MD) 9 5/8" L-80 8,527' MD 47# BTC 7,149' TVD Top Of Cement (CBL) - 13,050' MD (2) 3/8" x .049 Dual Flat Chem Inj Lines to 14022' MD Summit ESP Assembly Top of Discharge Head @ ~14,022' MD / 11396' TVD Motors - 456 Series Btm of ESP Assy (anode) @ 14,177' MD / 11513' TVD (34) Clamps on Pump Assembly (451) Clamps on String (2) SS bands (1) half clamp 7" L-80 15,275' MD 29# BTC 12,460' TVD TD @ 15,360' MD/12,460' TVD Note: 5/5/2020 well killed for Cold Stack; 1320 bbls produced water pumped downhole, no returns. Perforations REPERF: 14915' - 14940' 14,972' - 15,013' 12195’ – 12245’ 12147’ – 12182’ 12072’ – 12132’ REPERF: 14520' - 14545' & 14560' - 14585' REPERF: 14665' - 14690' & 14700' - 14720' 11889’ – 11945’ 14,792' - 14,836' RU-02A - Actual Schematic 3-1/2" 12.95# P-110 PH6 tubing, ID - 2.750" @ 14014' MD / 11390' TVD 11778’ – 11840’ 8 1/2" Hole 12 1/4" Hole MD TVD 14,518' - 14,596' 15,030' - 15,090' 14,880' - 14,953' NEW: 14,835' - 14,860'12034’ – 12055’ NEW: 14,860' - 14,880'12055’ – 12071’ 14,657' - 14,724' 3-3/8" Guns, 6 SPF 11999’ – 12035’ NEW: 14,635' - 14,655'11871’ – 11888’ 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:Zach Tomco To:McLellan, Bryan J (OGC) Cc:Rob Russell; Zack Hundrup Subject:RE: RU 2A (PTD 212-172) RWO sundry quetions Date:Thursday, June 22, 2023 5:21:40 PM Attachments:image002.png RU2 Acid Job Procedure.pdf Bryan, Comments in red. Regards, Zach Tomco Facilities Engineer Office: (907) 433-3803 Cell: (907) 715-1244 Glacier Oil & Gas From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, June 5, 2023 12:29 PM To: Zach Tomco <ztomco@glacieroil.com> Subject: RU 2A (PTD 212-172) RWO sundry quetions External Sender: Proceed with Caution Zach, A few questions about the sundry application: 1. When was the last production casing pressure test? If >8 yrs, plan to test the casing/liner when the ESP is out of the hole. Last casing pressure test occurred when the well was drilled; this was >8 years ago. We will plan to conduct a casing pressure test for this well. 2. Do you want to calculate MPSP using a reservoir fluid gradient again? If so, send me some information on your fluid properties, density, GOR, watercut, and also the shut-in fluid level and wellhead pressure at the time of the fluid level shot. I’m happy conducting the casing pressure test to the MASP if this is acceptable; this would be 2,592 psig. 3. What is the purpose of the second bypass line going across the center of the choke manifold? I can’t see any valves in the drawing to shut it off. Second bypass line has been removed w/the WMRU-02B and SWORD-01 workovers. This line will not be installed during RU-02A. 4. Please send me the piping diagram for the acid job to show how RU D1 is tied in and any check valves in the system. Attached flowpath demonstrates how acid and PW will be tied into the system. Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 15% HCL Diesel2" AODD Pump Spot 2 bbl of diesel 2" AODD Pump Diesel 15% HCL Spot 12.5 bbl of acid 2" AODD Pump Diesel 15% HCL Spot 2 bbl of diesel .1%0(" 1 2 (1) Set choke to 17 bean (2) Establish 2 bbl/min flowrate (3) Verify choke downstream pressure is 1000 psig 3 .1%0(" Set PSH at 1500 psig SFD 12/2/2022BJM 12/6/22 DSR-12/1/22 Set High Pressure Pilot on Surface Safety Valve to 100 psi prior to pumping into the well to protect the low pressure pumping system from potential well pressures. GCW 12/07/22 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2022.12.07 11:37:34 -09'00' RBDMS JSB 120822 November 23, 2022 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Cook Inlet Energy, LLC, a Glacier Oil and Gas Company (GLA): Redoubt Unit #2A RU 02A Permit to Drill: 212 172 API No.: 50 733 20501 01 00 Dear Commissioner, CIE hereby submits an Application for Sundry Approval for Redoubt Unit 02A, PTD: 212 172, requesting permission to acid stimulate existing perforations. If you have any questions, please contact me at (907) 715 1244. Sincerely, Zach Tomco Facilities Engineer Cook Inlet Energy, LLC (a Glacier Oil & Gas wholly owned company) 188 W. Northern Lights Blvd, STE 510 Anchorage, AK 99503 1. WELL NAME – RU 02A Requirements of 20 AAC 25.005(f) Well Summary Current Status: The well is currently producing. Two acid jobs occurred on 11/3/22 and 11/7/22 to mitigate scale/debris lodged in the immediate vicinity of the ESP. These jobs successfully removed scale build up near the pump, but the well is still producing below historic levels. Analysis suggests the ESP can now lift fluids when they are present, but the reservoir is unable to provide rate. Water chemistry shows this well has a high scale potential. The acid stimulation is targeted to remove scale/debris that has accumulated and blocked flow to the ESP inlet. Existing Perforations: MD (ft) TD (ft) 14518 14596 11778 11840 14635 14655 11871 11888 14657 14724 11889 11945 14792 14836 11999 12035 14835 14860 12034 12055 14860 14880 12055 12071 14880 14953 12072 12132 14920 15013 12147 12182 15030 15090 12195 12245 Scope of Work: Turn off RU2 ESP and allow well to stabilize for 1 hour. Introduce 5 bbl diesel Introduce 30 bbl 5% HCl/mutual solvent pre flush Introduce 119 bbl 12% HCl / 3% HF / mutual solvent Introduce 5 bbl diesel over flush Line up Produced Water to tubing and introduce 56 bbl downhole Shut in tubing and anulus and soak for 24 hours Put well on production. SFD 12/2/2022 14,972' General Well Information: Reservoir Pressure / TVD: 0.38 psi/ft = 4,476 psi @ 14,518’ MD (11,778’ TVD) MASP: Reservoir Pressure – (Gas Gradient X TVD) (0.38 psi/ft X 11,778’ TVD) – (0.1 psi/ft X 11,778’ TVD) = 4,476 psi – 1,177 psi = 3,299 psi Wellhead Type/Pressure Rating: 13 1/8” 5M Wellhead 3 5/8” 5M tree Well Type: Oil Well Estimated Start Date: December 15, 2022 Program Acid Injection 1. Prep well for acid treatment of ESP o Lock Out Well RU 02 ESP VFD 2. Pressure test hoses, connections, etc to 1000 psi o Maximum anticipated treating pressure is 1000 psi 3. Verify PIT 07 3C2 PSH has been set to 1500 psig. 4. Line up diesel to Air Operated Double Diaphragm Pump (AODD) and pump down the tubing o Add 5 BBL o Do not exceed 2 BPM injection rate 5. Turn off AODD 6. Line up 5% HCl /mutual solvent to Air Operated Double Diaphragm Pump (AODD) and pump down the tubing o Add 30 BBL o Do not exceed 2 BPM injection rate 7. Turn off AODD 8. Line up acid to AODD and pump down the tubing o 19 totes (~119 BBL) of 12% HCl / 3% HF / mutual solvent o Do not exceed 2 BPM injection rate 9. Turn off AODD 10. Line up diesel to AODD pump down the tubing o Add 5 BBL o Do not exceed 2 BPM injection rate 11. Line up produced water to AODD pump down the tubing o Add PW to rinse hoses/pumps/acid totes/drums o Do not exceed 2 BPM injection rate 100 psi. Set High Pressure Pilot on Surface Safety Valve to 100 psi prior to pumping into the well to protect the low pressure pumping system from potential well pressures. -bjm o Track volume and discount this amount from total PW volume discussed in step 18. 12. Line up PW to tubing and prep for system flush and hesitation squeeze 13. Pump 56 BBL of produced water down tubing. o Monitor and record pump pressure and flow throughout operation Compare to June 2022 Schlumberger Report o Do not exceed .34 BPM (This is the rate limit for the RU D1 FIT) o Total tubing volume to top of ESP is 103 BBL o This will shortfill the pipe and make sure the acid is placed directly at the perfs. 14. Shut in tubing and annulus for 24 hours, monitor surface pressure 15. Open tubing and leave annulus shut in, bullhead 4 BBL of produced water and monitor pressure o Do not exceed 2 BPM Increase in flow rate during bull head and decrease in pressure can indicate blockage has cleared Beware: If the blockage has cleared, PW rate across RU D1 choke could be significantly higher than previously experienced. o Perform 2nd 4 BBL bullhead 16. Divert PW back to injection o Acid in tubing will be diluted with produced fluids o Acid job fluids can be processed at KPF 17. Restart ESP 18. Rig down acid job equipment 19. Take hourly samples from RU2 production and save for analysis. Do this for 12 hours post start up. Version: Final Date:5/5/2020 Tbg hanger requires EUE landing joint 36" A-36 200' MD 150# Welded 200' TVD 13 3/8" L-80 3,212' MD 68# BTC 2,918' TVD Top Of Liner - 8,148' MD (Whipstock window 8531-8540' MD) 9 5/8" L-80 8,527' MD 47# BTC 7,149' TVD Top Of Cement (CBL) - 13,050' MD (2) 3/8" x .049 Dual Flat Chem Inj Lines to 14022' MD Summit ESP Assembly Top of Discharge Head @ ~14,022' MD / 11396' TVD Motors - 456 Series Btm of ESP Assy (anode) @ 14,177' MD / 11513' TVD (34) Clamps on Pump Assembly (451) Clamps on String (2) SS bands (1) half clamp 7" L-80 15,275' MD 29# BTC 12,460' TVD TD @ 15,360' MD/12,460' TVD Note: 5/5/2020 well killed for Cold Stack; 1320 bbls produced water pumped downhole, no returns. Perforations REPERF: 14915' - 14940' 14,972' - 15,013' REPERF: 14520' - 14545' & 14560' - 14585' REPERF: 14665' - 14690' & 14700' - 14720' 14,792' - 14,836' RU-02A - Actual Schematic 3-1/2" 12.95# P-110 PH6 tubing, ID - 2.750" @ 14014' MD / 11390' TVD 8 1/2" Hole 12 1/4" Hole MD TVD 14,518' - 14,596' 15,030' - 15,090' 14,880' - 14,953' NEW: 14,835' - 14,860' NEW: 14,860' - 14,880' 14,657' - 14,724' 3-3/8" Guns, 6 SPF NEW: 14,635' - 14,655' Set PSH at 100 psig Stimulation Fluids 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:Zach Tomco To:McLellan, Bryan J (OGC) Cc:Zack Hundrup; David Pascal Subject:RE: RU 02A (PTD 212-172) Sundry Date:Tuesday, December 6, 2022 4:01:53 PM Attachments:image001.png image002.png Yes, let’s specify 125 psig for testing pressure hoses and connections. From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, December 6, 2022 3:18 PM To: Zach Tomco <ztomco@glacieroil.com> Cc: Zack Hundrup <ZHundrup@glacieroil.com>; David Pascal <dpascal@glacieroil.com> Subject: RE: RU 02A (PTD 212-172) Sundry Zach, The program in the sundry application has you testing hoses, connections, etc to 1000 psi and says the max treating pressure is 1000 psi. Should I change that to a lower test and max treating pressure, based on our discussion? See below copied from the program Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Zach Tomco <ztomco@glacieroil.com> Sent: Tuesday, December 6, 2022 2:46 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Zack Hundrup <ZHundrup@glacieroil.com>; David Pascal <dpascal@glacieroil.com> Subject: RE: RU 02A (PTD 212-172) Sundry Bryan, The AODD pump that will be used in our operation is rated for 125 psig. RU-02A is a non-flowing well. When the pressure is initially bled off post well shutdown, zero pressure is normally experienced at surface. During this operation, head pressure is being used to spot stimulation fluids, so a low pump pressure is all that is needed to deliver fluid into the tubing. The attached P&ID shows the safety we discussed that will be used to protect our system. PIT 07-3C2 will close the SSV when a pressure of 100 psig is established. This closure value is 80% of the MAWP of this system. Please let me know if you have any additional questions or concerns with this Sundry. Regards, Zach Tomco Facilities Engineer Office: (907) 433-3803 Cell: (907) 715-1244 Glacier Oil & Gas From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, December 6, 2022 1:19 PM To: Zach Tomco <ztomco@glacieroil.com> Subject: RU 02A (PTD 212-172) Sundry External Sender: Proceed with Caution Zach, Could you give me a call to discuss this proposed acid stim sundry application? I have some concerns about using a low pressure diaphragm pump for a stimulation on a well with MPSP of 2500 psi. Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY September 17, 2019 Mr. David Pascal Vice President, Operations Cook Inlet Energy 188 West Northern Lights, Suite 510 Anchorage, AK 99503 RE: No -Flow Verification Redoubt Unit 2A PTD 2121720 Dear Mr. Pascal: 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 On August 12, 2019 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no -flow test of Redoubt Unit 2A located on the Osprey Platform in Cook Inlet. The well is operated by Cook Inlet Energy. The AOGCC Inspector confirmed that the proper test equipment — as outlined in AOGCC Industry Guidance Bulletin 10-004 — was rigged up on Redoubt Unit 2A prior to the test. The well was shut in for a 3 -hour pressure build up followed by opening the well for a flow check through a calibrated flow meter. A slight gas flow — undetectable by the flow meter — and no liquid flow were observed during the flow check. Redoubt Unit 2A 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 2A 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 on the Osprey Platform. Sincerely, James B. Regg Petroleum Inspection Supervisor ecc: P. Brooks AOGCC Inspectors STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Plug Perforations LJ Fracture Stimulate L Pull Tubing L41 Operations shutdown Ll Performed: Suspend ❑ Perforate Q Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: RunESP ❑� 2. Operator Cook Inlet Energy, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development E Exploratory ❑ Stratigraphic ❑ Service ❑ 212-172 3. Address: 188 W. Northern Lights Blvd, Suite 510, 6. API Number: Anchorage, AK, 99503 50-733-20501-01-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 381203, ADL 374002 Redoubt Unit #2A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): None Redoubt Shoal, Undefined Oil 11. Present Well Condition Summary: Total Depth measured 15360 feet Plugs measured none feet true vertical 12460 feet Junk measured none feet Effective Depth measured 15132 feet Packer measured none feet true vertical 12280 feet true vertical none feet Casing Length Size MD TVD Burst Collapse Structural 200' 36" 200' 200' n/a n/a Conductor Surface 3212' 13-3/8" 3212' 2918' 5020 2260 Intermediate 8527' 9-5/8" 8527' 7149' 6870 4760 Production Liner 7213' 7" 15360' 12461' 8160 7020 Perforation depth Measured depth 14518'- 15090' feet True Vertical depth 11778'- 12245' feet Tubing (size, grade, measured and true vertical depth) 3-1/2" Pilo 14014' MD 11390' TVD Packers and SSSV (type, measured and true vertical depth) none 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:'-% 4 LI lob 3 bV Subsequent to operation: 3 - 955 1 340 14. Attachments (required Per 20 AAC 25.070, 25.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations 2 Exploratory ❑ Development2l Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil El Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-163 / 319-2611319-280 Authorized Name: Stephen Ratcliff Contact Name: Stephen Ratcliff Authorized Title: VP of Drilling @9 I Contact Email: sratcliff acieroil.com Authorized Signature: �C..� v `—'e Date kc, Contact Phone: 907-433-3808 Form 10-404 Revised 4/2017 ABDiV1S9t-,"AUb 3 0 2019 Submit Original Only 117 � I� GLACIER August 22nd, 2019 Jessie Chmielowski, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7`^ Ave., Suite 100 Anchorage, Alaska 99501 Re: Report of Sundry Cook Inlet Energy, LLC: RU -02A Permit to Drill NO: 212-172 API No: 50-733-20501-01-00 Dear Commissioner, -.'J i CiJ�t1 L"Y? 7- Cook Inlet Energy (CIE) hereby submits a Report of Sundry Well Operations for RU -02A. The work performed was covered under Approved Sundries 319-163, 319-261 and 319-280 for pulling the ESP completion, adding perforatio nsand reperforatinR and running a new ESP completion. If you have any questions, please contact me at (907) 433-3808. Sincerely, Stephen Ratcliff VP of Drilling Cook Inlet Energy, LLC (a Glacier Oil & Gas Corp. owned company) 188 W. Northern Lights Blvd, Ste 510 Anchorage, AK 99503 10-404 GLACIER RU -02A Daily Operations Summary API: 50-733-20501-01-00 Date and Footage Drilled as of 24:00 hours. Activity 7-20 June 2019 Prep Rig. Permit #: 212-172 Rig: Osprey Rig 35 21 June 2019 Skid rig over RU -02A. N/D tree. N/U BOPE. 22 June 2019 Continue to N/U BOPE. Pull BPV and install TWC. 23 June 2019 Continue to N/U BOPE. R/U BOPE test equipment. 24 June 2019 Test BOPE 250 psi low / 3000 psi high — good. Test witnessed by AOGCC Rep, Matt Herrera. R/D test equipment. Pull TWC. M/U landing jt. Attempt to pull hanger and packer free — no movement. R/U ESP equipment. 25 June 2019 Continue to try to pull packer free — some movement up. R/U for displacement. Test surface lines. Change out wash pipe. 26 June 2019 Retest surface lines — change out wash pipe. Attempt to circulate — no returns. Work pipe attempting to free packer — some movement. 27 June 2019 Continue to try to free packer — able to move down. Reland hanger. L/D Q landing joint. P/U new landingjoint and sub. Pull hanger free. L/D hanger i �SP and landing joint. POH with 3-1/2" tubing— L/D singles. 28 June 2019 Continue POH with 3-1/2" tubing — L/D same. L/D SSSV. Continue POH with tubing — racking back. L/D packer. Continue POH w/ESP. 29 June 2019 Continue POH w/ESP. L/D ESP assembly. Significant amount of control line rubber scraped off down hole. R/U Eline. RIH w/GR and junk basket x 8 runs — full baskets of rubber last 4 runs at 8151'. 30 June 2019 Continue RIH w/GR and junk basket for additional 6 runs with full basket recovery of rubber. R/D Eline. R/U slickline. RIH with 3" bailer and tag at 8168'. RIH w/GR & JB w/no recovery. R/D Slickline. R/U BOPE test equipment. 1 July 2019 Test BOPE to 250 psi low / 3000 psi high. Witness of test waived by AOGCC Rep, Jim Regg. Work on top drive. 2 July 2019 Continue working on top drive. M/U fishing BHA. GLACIER 3 July 2019 RIH with Fishing BHA w/3-1/2" HWDP and 3-1/2" PH6 tubing to 8102'. Wash down to 8148'. Circulate and monitor losses. Work pipe at 8148'. POH to 7916'. 4 July 2019 Reverse circulate. POH w/fishing BHA and L/D same. R/U Slickline. RIH w/8.15" GR and JB to liner top. RIH w/5.83" GR and JB— unable to pass liner top. RIH w/3.97" JB — unable to pass liner top. RIH w/3.62" swedge — unable to pass liner top. 5 July 2019 R/D slickline. M/U 6" bit Liner cleanout assy and RIH on 3-1/2" PH6 tubing to 8148'. Circulate and work through liner top. Clean up debris at 8162'. Continue RIH to 15130'— pushing debris last 50ft. POH to 5515'. 6 July 2019 Continue POH with cleanout assy and L/D same. R/U Eline. RIH with 5-1/2" GR to 15070' MD. P/U and RIH with Gun #1: 25ft of 3-3/8", 6spf, 60deg phase and shoot 14940' to 14915' MD— all shots fired. P/U and RIH with Gun #2: 20ft of 3-3/8", 6spf, 60deg phase and shoot 14880' to 14860' MD — all shots fired. P/U and RIH with Gun #3: 25ft of 3-3/8", 6spf, 60deg phase and shoot 14860' to 14835' MD — all shots fired. P/U and RIH with Gun #4: 20ft of 3-3/8", 6spf, 60deg phase and shoot 14720' to 14700' MD —all shots fired. P/U and RIH with Gun #5: 25ft of 3-3/8", 6spf, 60deg phase and shoot 14690' to 14665' MD —all shots fired. 7 July 2019 P/U and RIH with Gun #6: 20ft of 3-3/8", 6spf, 60deg phase and shoot 14655' to 14635' MD —all shots fired. P/U and RIH with Gun #7: 25ft of 3-3/8", 6spf, 60deg phase and shoot 14585' to 14560' MD —all shots fired. P/U and RIH with Gun #8: 25ft of 3-3/8", 6spf, 60deg phase and shoot 14545' to 14520' MD —all shots fired. R/D Eline. RIH w/PH6, L/D joint singles with ID restrictions. P/U new tubing, rack back. 8 July 2019 Continue POH with tubing, rack back. R/U BOPE test equipment. Test BOPE 250 psi low / 3000 psi high — good. Witness waived by AOGCC Rep, Jim Regg. R/D test equipment. R/U to run ESP completion. P/U ESP assembly. 9 July 2019 Continue M/U ESP assembly. RIH with ESP assembly on 3-1/2" 12.95# P110 PH6 tubing to 9659'. 10 July 2019 Continue RIH with ESP on 3-1/2" PH6 to 14118'. M/U and orient hanger and landing joint. Confirm good meg test. Terminate lines through hanger. Land hanger. Test seals to 5000 psi —good. L/D landing joint. R/D ESP running equipment. 11 July 2019 N/D BOPE. N/U Tree. Prep rig to skid to RU -06. 12 July 2019 Continue to prep rig to skid to RU -06. RU -02A ESP Swap Complete. Hand well over to Production. Skid rig to RU -06. PA GLACIER Top Of Liner - 8,148' MD 12 1/4" Hole Top Of Cement (CBL) -13,050' MD Perforations 3-3/8" Guns, 6 SPF MD ND 14,518' - 14,596' 11778'— 11840' REPERF: 14520'- 14645' 8 14560'- 14585' NEW: 14,635'-14,655' 11871'-11888' 14,657'-14,724' 11889'-11945' REPERF: 14665'- 14690'& 14700'- 14720' 14,792' - 14,836' 11999'— 12035' NEW: 14,835'-14,860' 12034'-12055' NEW: 14,860'-14,880' 12055'-12071' 14,880'- 14,953' 12072'— 12132' REPERF: 14915'-14940' 14,972' -15,013' 12147'— 12182' 15.030'- 15.090' 12195'— 12245' 81/2" Hole RU-O2A - Actual Schematic TD @ 15,360' MD/12,460' ND Version: Final Date: 7/15/2019 Tbg hanger requires EUE landing joint 36" A-36 1 200' MD 150# 1 Welded I 200' ND 133/8" L-80 31212' MD 68# BTC I 2,918'ND (Whipstock window 8531-8540' MD) 1" L-80 8,527' MD 47# BTC 7,149' ND 3-1/2" 12.95# P-110 pHs tubing, ID - 2.750" @ 14014' MD / 11390' ND (2) 3/8" x.049 Dual Flat Chem Inj Lines to 14022' MD Summit ESP Assembly Top of Discharge Head @ —14,022' MD 111396- ND Motors - 456 Series Btm of ESP Assy (anode) @ 14,177' MD / 11513' ND (34) Clamps on Pump Assembly (451) Clamps on String (2) SS bands (1) half clamp T L-80 15,275' MD 29# BTC I 12,460' ND ■■■o■■oomom t £ k fi : )�=- r © 6/ «2womova, ®/ f » a- CL2z OLm )!� (� w 2 §|r '> —0 E}} $tom0 {]// ){)�®#\»a®]{) ) 2^±7; �;«&2;!£■�f=; >E>&� &zzQl#§a01CV-z. 4=E4/ a_a- // § )k\);ID - /} %§ƒ ®!- 0 �,-0 4) I#! }ƒ } - >f/ /2 =£( «(f/ /o0 )§/ J)!f/9«£/ J)ƒ »,d)0. 00C(/t ±I3 U) F— $LL )7« mmm § ) ) \ § \ E 04 \}k� \)/k \\\\ )/k\ if »\ ||)« =k�E � ..2 mo oc (D00 80 ,(a@ \2wz 0.2 / 0 Ow uok� \ , 12 a) )®oE 0 05 Z m$D < w o �®/j$ \\\\D E 0 ; ` G£ LLI \"2 )} (§ 2a e)3 »/ u _() 2 0# - /\ )\ ■■■o■■oomom t £ k fi : )�=- r © 6/ «2womova, ®/ f » a- CL2z OLm )!� (� w 2 §|r '> —0 E}} $tom0 {]// ){)�®#\»a®]{) ) 2^±7; �;«&2;!£■�f=; >E>&� &zzQl#§a01CV-z. 4=E4/ a_a- // § )k\);ID - /} %§ƒ ®!- 0 �,-0 4) I#! }ƒ } - >f/ /2 =£( «(f/ /o0 )§/ J)!f/9«£/ J)ƒ »,d)0. 00C(/t ±I3 U) F— $LL )7« mmm § ) ) \ § \ E 04 \}k� \)/k \\\\ )/k\ if »\ ||)« =k�E � ..2 mo oc (D00 80 ,(a@ \2wz 0.2 / 0 Ow uok� \ , 12 a) )®oE 0 05 Z m$D < w o �®/j$ \\\\D E 0 ; MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �Z ��/�(ig DATE: 8/15/2019 P. I. Supervisor FROM: Bob Noble SUBJECT: No Flow Test Petroleum Inspector Redoubt Unit 2A ' Osprey Platform Cook Inlet Energy PTD 2121720 - 8/12/2019: 1 arrived on the Osprey Platform and met with Cook Inlet Energy (CIE) lead operator Sean Sullivan. We reviewed the method to be used for today's no -flow test on RU 2A then inspected the rig up. CIE had been bleeding the well for several days. I had them shut the well in and started recorded pressures at 15 -minute increments. After 3 hours of shut-in time I observed 0.9 psi on the tubing and the IA. We then opened the valve to the flow meter and there was a very light bobble in the flow meter needle (non - recordable rate). I had them disconnect the flowline to the meter and I could feel slight gas movement on the back of my hand; within a minute I could not feel it any more. - The followina table shows test details: Time Pressures' (psi) Flow Rate' Remarks Gas — scf/hr Liquid — al/hr 10:40 0.5/0.5 0 0 Shut well in 10:55 0.5/0.5 11:10 0.5/0.5 11:25 0.6/0.6 11:40 0.6/0.6 12:10 0.7/0.7 12:25 0.7/0.7 12:40 0.7/0.7 12:55 0.8/0.8 13:10 0.8/0.8 13:25 0.9/0.9 13:40 0.9/0.9 0 0 Oen well to flow 13:41 0 0 End test I Pressures are T/IA/OA ' Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr Attachments: none 2019-0812_No-F low_RU-2A_bn. docx Page 1 of 1 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Stephen Ratcliff VP of Drilling Cook Inlet Energy, LLC 188 W. Northern Lights Blvd., Suite 510 Anchorage, AK 99503 Re: Redoubt Shoal Field, Undefined Oil Pool, Redoubt Unit #2A Permit to Drill Number: 212-172 Sundry Number: 319-280 Dear Mr. Ratcliff: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.olaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Jessie L. Chmielowski Commissioner DATED this I Z day of June, 2019. RBDMS+'JUN 1 31019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED JUN 0 3 1019 AOGCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ OdR I V fW � 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: COOK INLET ENERGY, LLC Exploratory ❑ Development ❑� . Stratigraphic ❑ Service ❑ 212-172 - 3. Address: 6. API Number: 188 W. Northern Lights Blvd, Suite 510, Anchorage, AK 99503 50-733-20501-01-00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 20 AAC 25.055 Will planned perforations require a spacing exception? Yes ❑ No E REDOUBT UNIT #2A . 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): 15360' • 12460' • 15132' 12280' 2592 psi none none Casing Length Size MD TVD Burst Collapse Structural 200' 36" 200' 200' n/a n/a Conductor Surface 3212' 13 3/8" 3212' 2918' 5020 2260 Intermediate 8527' 95/81, 18527' 1 7149' 1 6870 4760 Production Liner 7213' 7" 15360' 1 12461' 18160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 14518'- 15090' 11778'- 12245' 3 1/2" L801P110 14089' Packers and SSSV Type: Baker Hughes Twin Seal Packer Packers and SSSV MD (ft) and TVD (ft): Packer: 2532' MD / 2375' TVD Baker SSSV SSSV: 345'MD/TVD 12. Attachments: Proposal Summary LaJ Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program Q BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/10/2019 OIL ❑� • WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Dale: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stephen Ratcliff Contact Name: Stephen Ratcliff Authorized Title: VP of Drilling Contact Email: sratcliff@glacieroil.com Contact Phone: 907-433-3808 Authorized Signature: �� •— Date: b -3 - 1'� COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3)(/� n ' Plug Integrity ❑ BOP Test E] Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ JUN 13 ga15 uRBDMS Spacing Exception Required? Yes ❑ No Subsequent Form Required: /o ^ / (� Y APPROVED BY Approved by: I COMMISSIONER THE COMMISSION Date: Iq I Submit Farm and Form 10 03 Revised 4/2017 )/Approved application is al 1 frlbt/n a ate Of approval. ttachments it Duplicate, 6-s•�9 GLACIER RECEIVED June 311, 2019 JUN 0 3 2019 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission AOGCC 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Cook Inlet Energy, LLC, a Glacier Oil and Gas Company (GLA): Redoubt Unit #2A RU -02A Permit to Drill: 212-172 API No.: 50-733-20501-01-00 Dear Commissioner, CIE hereby submits an Application for Sundry Approval for Redoubt Unit 02A, PTD: 212-172, requesting permission to re-perf existing perforations when the ESP is pulled. The re -perforations ' would be conducted at the same time as the new perforations are added, previously approved by Sundry 319-261. The ESP pull and rerun is approved under Sundry 319-163. If you have any questions, please contact me at (907) 433-3808. Sincerely, Stephen Ratcliff VP of Drilling Cook Inlet Energy, LLC (a Glacier Oil & Gas wholly owned company) 188 W. Northern Lights Blvd, STE 510 Anchorage, AK 99503 GLACIER 1. WELL NAME — RU -02A 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. Existing Perforations: Scope of Work: • RU Eline • RIH and perforate per program. • RD Eline. General Well Information: Reservoir Pressure / TVD: 0.32 psi/ft = 3,769 psi @ 14,518' MD (11,778' TVD) MASP: Reservoir Pressure — (Gas Gradient X TVD) (0.32 psi/ft X 11,778' TVD) — (0.1 psi/ft X 11,778' TVD) = 3,769 psi — 1,177 psi = 2,592 psi Wellhead Type/Pressure Rating: 13 5/8" 5M Wellhead - 3 1/2" 5M tree BOPE: 13 5/8" IOM — Pipe Rams / Blind Rams / Annular Well Type: Oil Well Estimated Start Date: June 10, 2019 MD TVD 14518'— 14596' 11778'— 11840' 14657'— 14724' 11889'— 11945' 14792'— 148361 11999'— 12035' 14880'— 14953' 12072' — 12132' 14972'— 15013' 12147' —12182' 15030'— 15090' 12195' — 12245' Scope of Work: • RU Eline • RIH and perforate per program. • RD Eline. General Well Information: Reservoir Pressure / TVD: 0.32 psi/ft = 3,769 psi @ 14,518' MD (11,778' TVD) MASP: Reservoir Pressure — (Gas Gradient X TVD) (0.32 psi/ft X 11,778' TVD) — (0.1 psi/ft X 11,778' TVD) = 3,769 psi — 1,177 psi = 2,592 psi Wellhead Type/Pressure Rating: 13 5/8" 5M Wellhead - 3 1/2" 5M tree BOPE: 13 5/8" IOM — Pipe Rams / Blind Rams / Annular Well Type: Oil Well Estimated Start Date: June 10, 2019 GLACIER Program Rig Workover 1. Rig up Eline and lubricator. Test lubricator to 3000 psi. 2. RIH with 3-3/8", 6spf, 60deg phase hollow carrier pert guns and perforate per the table below. a. Perforate bottom up. b. Monitor and record surface pressure in 5 -minute intervals for 30 mins after each pert run. Runs Top, MD Bottom, MD Footage Top, TVD Bottom, TVD 4 14520 14585 65 11780 11831 3 14657 14695 38 11888 11920 2 14700 14720 20 11924 11940 1 14880 14940 60 12071 12121 3. RD Eline. Ems. 5�• "�- RU -02A - Current Completion Diagram Version: Final Date: 7/7/2013 Baker 3-1/2" SSSV - 345' MD Baker Hughes Twin Seal Packer - 2,532' MO CRN Nipple -2,57WMID Top Of Liner- 8,325' MD 12 1/4" Hole Top Of Cement - 13,050' MD Perforations 3-3/8" Guns, 6 SPF MD ND 14,518'- 14,596' 11778'— 11840' 14,6571- 14,724' 11889'— 11945' 14,792' - 14,836' 11999'— 12035' 14,8801- 14,953' 12072'— 12132' 14,972'-15,013' 12147'-12182' 8 1/2"Hole Shoe @ 15267'MD 36" A-36 200' TVD 150# Welded 200'MD 133/8" L-80 2,918' ND 68# BTC 3,212'MD 3-1 /2" P-110 8 L-80 tubing 9 5/8" L-80 I7,149' ND 47# BTC I 8,527' MD (whipstock) Centrilift ESP Assembly Top of Discharge Head @ 14,089' MD 7" 1 L-80 12,460' TVD 29# 1 BTC I 15,360'MD GLACIER RU -02A - Proposed Completion Diagram Top Of Liner- 8,325' MD 121/4" Hole Top Of Cement - 13,050' MD Perforations 3-3/8" Guns, 6 SPF MD ND 14,518' - 14,596' 11778'— 11840' repent 14520'- 14585' 14,657'- 14,724' 11889'— 11945' reperf 14657'- 14695'& 14700'- 14720' 14,792' - 14,836' 11999'— 12035' 14,880' - 14,953' 12072'— 12132' rep rf 14880'- 14940' 14,972' - 15,013' 12147'— 12182' 15,030' - 15,090' 12195'— 12245' 8 1/2" Hole TD @ 15,360' MD/12,460' ND Version: 2.2 Date: 5/15/2019 38" 1 A-36 I 200' MD 150# 1 Welded I 200' ND 13 3/8" L-80 3,212' MD 68# BTC I 2,918' ND (Whipstock window 8531-8540' MD) 9 5/8" L-80 8,527' MD 474 BTC 7,149'ND 3-117' 12.95# P-110 8 L-80 tubing PH6, ID - 2.750" @ 14100' MD Summit ESP Assembly Top of Discharge Head @ 14,100' MD Bottom of ESP Assy @ 14,200' MD 7" L-80 15,275' MD 29# BTC 1 12,460' ND THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Stephen Ratcliff VP of Drilling Cook Inlet Energy, LLC 188 W. Northern Lights Blvd., Suite 510 Anchorage, AK 99503 Re: Redoubt Shoal Field, Undefined Oil Pool, RU 2A Permit to Drill Number: 212-172 Sundry Number: 319-261 Dear Mr. Ratcliff: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www, a ag cc. ala ska.go v Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 01//� Daniel T. Seamount, Jr. Commissioner d r DATED this Z3 day of May, 2019. RBRMSi6wMAV 2 4 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVES:) MAY 2 1 2019 A()r,r;r. 1. Type of Request: Abandon LJ 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: COOK INLET ENERGY, LLC Exploratory ❑ Development ❑✓ • Stratigraphic ❑ Service ❑ 212-172 - 3. Address: 6. API Number: 188 W. Northern Lights Blvd, Suite 510, Anchorage, AK 99503 50-733-20501-01-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 20 AAC 25.055 Will planned perforations require a spacing exception? Yes ❑ No REDOUBT UNIT #2A ' 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): 15360' ' 12460" 15132' 12280' 2592 psi none none Casing Length Size MD TVD Burst Collapse Structural 200' 36" 200' 200' n/a n/a Conductor Surface 3212' 13 3/8" 3212' 2918' 5020 2260 Intermediate 8527' 95/8.. 8527' 17149' 16870 4760 Production Liner 7213' 17" 15360' 12461' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 14518'- 15090' 11778'- 12245' 3 1/2" L80/P110 14089' Packers and SSSV Type: Baker Hughes Twin Seal Packer Packers and SSSV MD (ft) and TVD (ft): Packer: 2532' MD / 2375' TVD Baker SSSV SSSV: 345'MD/TVD 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: 6/1/2019 OIL Q • WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stephen Ratcliff Contact Name: Stephen Ratcliff Authorized Title: VP of Drilling Contact Email: sratcliff@glacieroil.com Contact Phone: 907-433-3808 \ 110% Authorized Signature: Date: 61 111% COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Nil -Ro1 Plug Integrity ❑ BOP Test ❑ mechanical Integrity Test ❑ Location ❑ Clearance r , +a • F/ eW r l e-5-' U -'i� ,.�.. 3O Other: 1( "Na N O•' i� C_ Post Initial Injection MIT Req'd? Yes No R�BDMS Spacing Exception Required? Yes ❑ No Subsequent Form Required: / ©_ 4�/� [� MAY 2 4 2019 APPROVED BY Approved b COMMISSIONER THE COMMISSION Date: 5 L "3 L SApproved AL r7 -Form 10,40 Revised 4/201 application i01dR 1 nt s rom the date of a Submit Form and pproval Attachments in uplicare GLACIER May 211t, 2019 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Cook Inlet Energy, LLC, a Glacier Oil and Gas Company (GLA): Redoubt Unit #2A RU -02A Permit to Drill: 212-172 API No.: 50-733-20501-01-00 Dear Commissioner, CIE hereby submits an Application for Sundry Approval for Redoubt Unit 02A, PTD: 212-172, requesting permission to add perforations when the ESP is pulled. The ESP pull and rerun is approved under Sundry 319-163. It is also requested that a no -flow test be performed to omit the vent valve, production packer, and sub -surface safety valve from the completion within 30 days. If you have any questions, please contact me at (907) 433-3808. Sincerely, Stephen Ratcliff VP of Drilling Cook Inlet Energy, LLC (a Glacier Oil & Gas wholly owned company) 188 W. Northern Lights Blvd, STE 510 Anchorage, AK 99503 4 GLACIER 1. WELL NAME - RU -02A 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. Existing Perforations: Scope of Work: • RU Eline • RIH and perforate per program. • RD Eline. General Well Information: Reservoir Pressure / TVD: 0.32 psi/ft = 3,769 psi @ 14,518' MD (11,778' TVD) MASP: Reservoir Pressure - (Gas Gradient X TVD) (0.32 psi/ft X 11,778' TVD) - (0.1 psi/ft X 11,778' TVD) = 3,769 psi - 1,177 psi = 2,592 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: June 15, 2019 Waivers Requested: A no -flow test be performed to omit the vent valve, production packer, and sub -surface safety valve from the completion within 30 days. MD TVD 14518' - 1459C 11778'-11840' 14657'- 147241 11889'- 11945' 14792'-714836' 11999'- 12035' 14880'- 14953' 12072' - 12132' 14972' - 15013' 12147'- 12182' 15030'- 15090' 12195'- 12245' Scope of Work: • RU Eline • RIH and perforate per program. • RD Eline. General Well Information: Reservoir Pressure / TVD: 0.32 psi/ft = 3,769 psi @ 14,518' MD (11,778' TVD) MASP: Reservoir Pressure - (Gas Gradient X TVD) (0.32 psi/ft X 11,778' TVD) - (0.1 psi/ft X 11,778' TVD) = 3,769 psi - 1,177 psi = 2,592 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: June 15, 2019 Waivers Requested: A no -flow test be performed to omit the vent valve, production packer, and sub -surface safety valve from the completion within 30 days. <4 GLACIER Program Rig Workover 1. Rig up Eline and lubricator. Test lubricator to 3000 psi. 2. RIH with 3-3/8", 6spf, 60deg phase hollow carrier pert guns and perforate per the table below. a. Perforate bottom up. b. Monitor and record surface pressure in 5 -minute intervals for 30 mins after each perf run. Runs Top, MD Bottom, MD Footage Top, TVD Bottom, TVD 3 14635' 14655' 20' 11871' 11887' 2 14835' 14855' 20' 12034' 12050' 1 14855' 14880' 25' 12050' 12071' 3. RD Eline. RU -02A - Current Completion Diagram GLACIER Baker 3-1/2" SSSV - 345' MD Baker Hughes Twin Seal Packer- 2,532' MD CRN Nipple - 2,574' MD Top Of Liner - 8,325' MD 121/4" Hole Top Of Cement- 13,050' MD Perforations 3-3/8" Guns, 6 SPF MD ND 14,518' - 14,596' 11778'— 11840' 14.657'- 14,724' 11889'— 11945' 14,792' - 14,836' 11999'— 12035' 14,880' - 14,953' 12072'— 12132' 14,972'-15,013' 12147'-12182' 15,030' - 15,090' 12195'— 12245' 8 1/2" Hole Shoe @ 15,267' MD Version: Final Date: 7/7/2013 36" A-36 200' ND 150# Welded 200' MD 13 3/8" L-80 2,918'ND 68# BTC 3,212' MD 3-1/2" P-110 d L-80 tubing 95/8" 1L-80 7,149' ND 47# 1 BTC I 8,527' MD (whipstock) Centrilift ESP Assembly Top of Discharge Head @ 14,089' MD 7" L-80 12,460' ND 29# ji BTC 15,360' MD GLACIER RU -02A - Proposed Completion Diagram Top Of Liner - 8,325' MD 12 1/4" Hole Top Of Cement - 13,050' MD Perforations 3-3/8" Guns, 6 SPF MD 14,518' -14,596- 14,635'- 4,596'14,635'- 14,655' 14,6571- 14,724' 14,792' - 14,836' 14,836'- 14,880' 14,880' - 14,953' 14,972' - 15,013' TVD 11778'— 11840' 11871'-11 887' , 11889'— 11945' 11999'— 12035' 12034'— 12071' 12072'— 12132' 12147'— 12182' 81/2" Hole I TD @ 15,360' MD/12,460' TVD Version: 2.2 Date: 5/15/2019 36" A-36 200' MD 150# Welded I 200' TVD 133/8" L-80 3,212'MO 1 2,918' TVD (Whipstock window 8531-8540' MD) 95/8" L-80 1 8,527' MD 47# BTC 7,149'TVD 3-1/2" 12.95# PA 10 8 L-80 tubing PH6, ID - 2.750" @ 14100' MD Summit ESP Assembly Top of Discharge Head @ 14,100' MD Bottom of ESP Assy @ 14,200' MD 7" L-8015,275' MD 29# BTC 12,460' TVD 10,000,000 1,000,000 L Y 0 c� C L CL 100,000 cV C 0 10,000 O 0 o M v � LL 1,000 o `a 3 v C C m 100 N 0 F- F 10 COOK INLET ENERGY, LLC, REDOUBT UNIT 2A (212-172) REDOUBT SHOAL, UNDEFINED OIL Monthly Production Rates 10,000,000 W w 1,000,000 H 0 0 100,000 m 0 3 10,000 S 0 d 1,000 0 v rD ro 100 ro Z O 3 10 s 1 Jan-zuic Jan -ma Jan -2014 Jan -2015 Jan -2016 Jan -2017 Jan -2018 Jan -2019 Jan -2020 Jan -2021 Jan -2022 Produced Gas (MCFM) • GOR Produced Water (SOPM) Produced Oil (BOPM) SP READSH E ET_2121720_Redou bt_Un it-2A_P rod_Cu rves_W ell_OI I_V 120_20190522.xlsx 5/22/2019 THE STATE 01ALASKA GOVERNOR MIKE DUNLEAVY Stephen Ratcliff VP of Drilling Cook Inlet Energy, LLC 188 W Northern Lights Blvd., Suite 510 Anchorage, AK 99503 Re: Redoubt Shoal Field, Undefined Oil Pool, Redoubt Unit 2A Permit to Drill Number: 212-172 Sundry Number: 319-163 Dear Mr. Ratcliff Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Wv W.aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, n G' Jessie L. Chmielowski Commissioner DATED this (0 day of April, 2019. RBDMSI�APR 10 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 APR 0 2 2019 P7-5 `f//ol 1 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q - Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Run ESP n 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: COOK INLET ENERGY, LLC Exploratory ❑ Development Q , Stratigraphic ❑ Service ❑ 212-172 ° 3. Address: 6. API Number: 188 W. Northern Lights Blvd, Suite 510, Anchorage, AK 99503 50-733-20501-01-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 20 AAC 25.055 Will planned perforations require a spacing exception? Yes ❑ No Q REDOUBT UNIT #2A ' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 381203:ADL 374002 REDOUBTSHOAL� 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): 15360' ' 12460' 15132' 12280' 2592 psi none none Casing Length Size MD TVD Burst Collapse Structural 200' 36" 200' 200' We n/a Conductor Surface 3212' 13 3/8" 3212' 2918' 5020 2260 Intermediate 8527' 95/8" 8527' 7749' 6870 1 4760 Production Liner 7213' 7" 15360' 12461' 8160 7020 Perforation Depth MD (fl): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 14518'- 15090' 11778'- 12245' 3 1/2" L80/P110 14089' Packers and SSSV Type: Baker Hughes Twin Seal Packer Packers and SSSV MD (ft) and TVD (ft): Packer: 2532' MD / 2375' TVD Baker SSSV SSSV: 345' MD / TVD 12. Attachments: Proposal Summary Wellbore schematic ED 13. Well Class after proposed work: , Detailed Operations Program 0 BOP Sketch ❑ Exploratory p ry ❑ Stratigraphic ❑ Development ❑� Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/15/2019 OIL Q WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stephen Ratcliff Contact Name: Stephen Ratcliff Authorized Title: VP of Drilling Contact Email: sratcliff@glacieroil.com Contact Phone: 907-433-3808 y l 1 ct Authorized Signature: Date: t 7 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: 1( Q 0 (J 1p5c` P '-7,,f- 4 No 3000 J 44 0-56o /os /-1hw'(A-t T4 -- Post Initial Injection MIT Req'd? Yes No '3BDMSlL6/APR 19 q Spacing Exception Required? Yes No Subsequent Form ❑ Required: [�19 b Approved by: �i COMMISSIONER THE COMMISSMMISS THEAPPROVED�D ION Date: �� y.-'Iq UMUINAL Form 10-403 R vised 4/2017 Approved application is valid for 12 months from the date of approval. Submit Form and Attachments in Duplicate 141 GLACIER April 1", 2019 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 71h Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Cook Inlet Energy, LLC, a Glacier Oil and Gas Company (GLA): Redoubt Unit #2A RU -02A Permit to Drill: 212-172 API No.: 50-733-20501-01-00 Dear Commissioner, CIE hereby submits an Application for Sundry Approval for Redoubt Unit 02A, PTD: 212-172, requesting permission to pull the existing ESP completion 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 completion within n 30 daysLU If you have any questions, please contact me at (907) 433-3808.' �tiS Sincerely, Stephen Ratcliff VP of Drilling Cook Inlet Energy, LLC (a Glacier Oil & Gas wholly owned company) 188 W. Northern Lights Blvd, STE 510 Anchorage, AK 99503 �CVED APR 02 20!19/ AOGC(� GLACIER 1. WELL NAME —RU -02A 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. Existing Perforations: 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 = 3,769 psi @ 14,518' MD (11,778' TVD) MASP: Reservoir Pressure — (Gas Gradient X TVD) (0.32 psi/ft X 11,778' TVD) — (0.1 psi/ft X 11,778' TVD) = 3,769 psi —1,177 psi = 2,592 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: June 15, 2019 ftini. 2 MD TVD 14518'— 14596' 11778'— 11840' 14657'— 14724' 11889' —11945' 14792'— 14836' 11999'— 12035' 14880'— 14953' 12072'— 12132' 14972'— 15013' 12147'— 12182' 15030'— 15090' 12195'— 122451 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 = 3,769 psi @ 14,518' MD (11,778' TVD) MASP: Reservoir Pressure — (Gas Gradient X TVD) (0.32 psi/ft X 11,778' TVD) — (0.1 psi/ft X 11,778' TVD) = 3,769 psi —1,177 psi = 2,592 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: June 15, 2019 ftini. 2 0110 GLACIER Waivers Requested: A no -flow test be performed to omit the vent valve, production packer, and sub -surface safety valve from the completion within 30 days. Program �� L", J4 �� 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. Kill well with produced water. 4. Prep for Rig and Workover operations. 5. Ensure that well is dead. Rig Workover 1. Move Rig 35 onto RU -02A. 2. Check for pressure and note pressure in tubing and in annulus. 3. R/D lines from tree and annulus to production if not done prior to rig move. 4. Check for flow, ensure well is dead and shut in well. 5. Place back pressure valve in wellhead. 6. Notify AOGCC 48 hours in advance of start of operations and upcoming BOP test. 7. N/D Production Tree. 8. N/U and Test 13 5/8" BOPE with 2 7/8" x 5" VBR rams with blinds in middle. 9. Test BOPE on 3 %" to 250 psi low / 3000 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. Pull & L/D 3 1/2" Landing Joint and Tubing Hanger. 15. Check for Flow and confirm well is dead. 16. POH and L/D the following: a. 3 1/2" Tubing b. ESP BHA 17. Monitor trip tank for proper hole filling. 18. Prep to pick up ESP Completion equipment, spoolers, and tools. 19. 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. 20. Pick up the ESP completion assembly as directed. 3 <4 GLACIER a. NOTE: Setting depth of ESP BHA at +/- 14,200' MD (Confirm with GLA Engineer prior to RIH). b. Pump should be set in less than 1 degree/100' dogleg. (Top of Pump Assy tentatively set for 14,100' MD). c. NOTE: the 3/8" flat pack chemical injection line is to be run to the anode on the bottom of the ESP assembly. d. 3/8" Nova Valves to be installed at top of pump assembly. e. The Packer SSSV and Vent Valve will NOT be run with this completion. f. Blank off vent line and SSSV line. g. Cannon clamps at every collar. 21. RIH with ESP completion. Test cable every 500'. Splice cable as needed. 22. At TD, confirm pipe tally. 23. MU landing joint to hanger and set string in slips. 24. 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. 25. Observe well dead. Lay down landing joint and install BPV. 26. Nipple down riser and BOPE. 27. Install and test production tree. Pull BPV. Turn over well to production. 28. Release Rig. 4 Baker Hughes Twin Seal Packer - 2,532' MD 12 1/4" Hole 8 1/2" Hole RU -02A - Current Completion Diagram Version: Final Date: 7/7/2013 Shoe @ 15,267' MD 36" A-36 200'ND 150# 1 Welded 200' MD 13 3/8" L-80 2,918' ND 68# BTC 3,212'MD 3-1/7'P-110 & L-80 tubing 95/8" L-80 7.149' TVD 47# BTC 8,527' MD (whipstock) CentriliR ESP Assembly Top of Discharge Head @ 14,089' MD 7" 80L B29# TC 15 360- MD I RU -02A - Proposed Completion Diagram Top Of Liner - 8,325' MD 12 1/4" Hole Top Of Cement- 13,050' MD Perforations 3-3/8" Guns, 6 SPF MD ND 14,5181- 14,596' 11778'— 11840' 14,657'- 14,724' 11889'— 11945' 14,792'- 14,836' 11999' —12035' 14,880'- 14,953' 12072'— 12132' 14,972' - 15,013' 12147'— 12182' 15,030' - 15,090' 12195'— 12245' 8 1/2" Hole TO @ 15,360' 11 TVD Version: 2.1 Date: 4/1/2019 36" A-36 200' MD 150# 1 Welded 200' TVD 133/8" L-80 3,212' MD 68# BTC 1 2.918' TVD (Whipstock window 8531-8540' MD) 1 8,527' MD 47# BTC 1 7,149'FVD 3-1/2" 12.95# P-110 & L-80 tubing PH6, ID - 2.750" @ 14100' MD Summit ESP Assembly Top of Discharge Heai 14,100' MD Bottom of ESP A55y Q 14,200' MD 7" L-80 15,275' MD 29# BTC 12,460' TVD 0 ro 9 ! o N o U N 0 Q 0 N o j W V Cil Z •(U 06 \ o E M U -I 2 J \ 2 o a t r } W �Jl C7 `n N W ❑ O Q T U) ❑ ❑ ❑ 00 Z Z Z T - Z Z Za.. 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Exploratory❑ GINJ ❑ WINJ❑ WAG❑ WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number: COOK INLET ENERGY,LLC Aband.: 6/19/2013 ' 212-172 ' 3.Address: 6.Date Spudded: 13.API Number: 601 W 5TH AVE SUITE 310,ANCHORAGE,ALASKA 99501 4/15/2013 • 50-733-20501-01-00 • 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 1918'FSL,320'FEL,SECTION 14,TO7N,R14W,SM 5/30/2013 . REDOUBT UNIT#2A Top of Productive Horizon: 8.KB(ft above MSL): 90'" 15.Field/Pool(s): 2306'FNL,755'FWL,SECTION 19 TO7N,R13W,SM • GL(ft above MSL): N/A REDOUBT SHOAL Total Depth: 9.Plug Back Depth(MD+TVD): r 2450'FSL 1780 FWL Sec 19 TO7N R13W 15,132'MD/12,280'TVD " 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: +//16 Surface: x- 200626 y- 2449942 Zone- 4 15,360'MD/12,460'TVD ' ADL 381203 i 3 7-100k TPI: x- 207441 y- 2445676 Zone- 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- March 29,2469 y- November 22,8595 Zone- 345'MD/345'TVD N/A 18.Directional Survey: Yes E, No ❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) 45' (ft MSL) N/A 21.Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: CBL,CAST-M,CASE,ACE,GR, 8,527'MD/7,149'TVD 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM . HOLE SIZE CEMENTING RECORD PULLED 36" 150# A-36 0' 200' 0' 200' N/A N/A N/A 13 3/8" 68# L80 0' 3,212' 0' 2,918' 17 1/2" 5821 cu ft none 9 5/8" 47# L80 0 8,527' 0' 7,149' 12 1/4" 1070 cu ft none 7" 29# L80 r 8,147' 15,360' 6,839' 12,461' 8.5" 283 sks(526 cult.)class"G" none cement w/additives 24.Open to production or injection? Yes Q No ❑ 25. TUBING RECORD If Yes,list each interval open(MD+TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3 1/2"L80/P110 14,089'MD 2,532'MD/2,375TVD 14,518'MD-14,596'M =78' 14,657'MD-14,724'M =67k 14,792'MD- 14,836'MD=4414,8 O'MD-14,953'MD=73'14,972'MD- 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 15,013'M =41 15,030'MD-15,090'M =60'; Was hydraulic fracturing used during completion? Yes❑ No DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 11,778TVD-11,840TV4 11,889TVD-11,945TVd, 11,999TVD-12,035'ND; CEMENTING DETAILS 283 sks(526 cuft.)class"G"cement w/additives(10%BA-90 12,072TVD-12,132'TVDI 12, ' VD-12,182TVD,` 12,195'TVD-12,245TVD +.005 pps"Static Free"+2.5%BA-56+.8%R-3+2%KCI+ .5%EC-1+.5%CD-32+.1%ASA-301+1 ghs FP-6L+.5% RompI LETI ON I sodium metasilicate)@ 13.5 ppg/1.86 yield Dropped DP ` wiper dart and began displacement w/9.4 ppg OBM 1?i 4 27. 1 rn PRODUCTION TEST Date First Production: IIE { Method of Operation(Flowing,gas lift,etc.): 6/21/2013 --- FLOWING Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 6/22/2013 24 hours Test Period 1281 bbl 262 299 OPEN 205 cu ft/bbl Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 510 PSI 97 PSI 24-Hour Rate — 1281 Bbl 262 299 26.4 28. CORE DATA Conventional Core(s)Acquired? Yes❑ No❑., , Sidewall Cores Acquired? Yes❑ No❑J • If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. Form 10-407 Revised 10/2012 CONTINUED ON REVERSE eflz 13 Submit original onI' 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes ❑.r No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base UPPER HEMLOCK 14,510' 11,772' MIDDLE HEMLOCK 14,792' 11,999' LOWER HEMLOCK 15,028' 12,194' OIL SHOWS(HEMLOCK) 14,518'-15,160' 11,779'-12,302' 14,518'-15,090'MD Well is on production and producing at 1281 bbd. Formation at total depth: LOWER HEMLOCK 15,132' 12,460' 31. List of Attachments: Wellbore schematic.daily drilling summaries,logs, surveys,cutting sample data, 10-407 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: COURTNEY RUST 433-3809 Email: COURTNEY.RUST@COOKINLET.NET _ Printed Name: CONRAD BERRY Title: DRILLING MANAGER 0414. Signature: Phone: 907-433-3816 Date: 7/19/2013 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item lb: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 c,. Cook Inlet Energy_ RECEIVED J U L 19 2013 AOGCC July 19, 2013 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: RU2A Well Completion Cook Inlet Energy, LLC: RU2A Permit to Drill No: 212-172 Dear Ms. Foerster, Enclosed please find the Well Completion Report and Data required by the AOGCC's approval of Permit to Drill #212-172 to drill and complete Well Redoubt Unit#2A Enclosed please find: 1. Well Completion report(AOGCC Form 10-407)with attachements 2. Summary of Daily Drilling Operations 3. List of Formations and other geologic markers encountered and depths 4. List of depth and formation names for oil and gas shows 5. Copy of Production Test data 6. Paper copy of Wellbore Directional Survey 7. Copies of final mudlog and report enclosed in report 2 CD's. 8. Digital version of all logs run in LAS format and directional survey in ascii format 9. Paper copies of all logs run and reproducible file in pdf and tiff format 10. Dry cuttings to AOGCC. If you have any questions,please contact me at(907)-433-3816. Sincerely, Conrad Perry Drilling Manager—Cook Inlet Energy 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 (907)334-6745*(907)334-6735 fax Redoubt Ur. .A Current Completion Diagram 7/17/2013 S' y6 H 36" A-36 200 TVD 150# Welded 200 MD Baker 3 1/2"SSSV @ 345'MD ;? 1..t., Baker Hughes Twin Seal -1116 iii, 13 3/8" L-80 2918 TVD Packer©2,532'MD J a 68# BTC 3212 MD CRN Nipple @ 2,574'MD 3-1/2"P-110&L-80 tubing r TOL @ 8,147'MD n „ r� � . f+' 9 5/8" L-80 8,527'MD r 47# BTC 7,149'TVD • (whipstock) i { k V TOC @ 13,050'MD ti ' Ila Centrilift ESP Assembly (top of discharge head)@ 14,089'MD Perforations: 33/8"6SPF m c 14,518'MD-14,596'MD=78';14,657'MDLIM ICU - 14,724'MD=67';14,792'MD- Shoe @ 15,267'MD 14,836'MD=44';14,880'MD- 14,953'MD=73';14,972'MD- 15,013'MD=41';15,030'MD- 15,090'MD=60' 7" L-80 12,460'TVD 29# BTC 15,360'MD y V 3• d 0 O > N = mo a N (/) a .6 O O) N Tr e— O O O) CO C) 0 CD CO O CO O O N- ti et N- O > a et M et et et et M M et M et et et et et et M M M M M et • O O O O O O O O O O O O O O O O O O O O O O Si 0 E d CT O) CO co CO CO CO CO CO CO t` CO t` t` CO Co Co CO Co Co CO CO T N N N N N N N N N N N N N N N N N N N N N N V J 5 O- I- _ 3 C LL N N N N N N N N e- e- e- N N N N N N Cl N M N N O 0) N N N N N N N N N N N N N N N N N N N N N N j O N N N N N N N N N N N N N N N N N N N N N N O N > d N e- O C) 0 CD e- CO U) CD CO O O CO t` CO et Cn 0 et 0 CO . 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CD CD CD t` CO CO CD CO CD CO CD CO CO h t• t• t` t` t` t` e- CD O i CA 0 e- E 0 e- O w _ CD N CD et et CD CD )- 0 CC) 1n CO O O O 1- et CO E, O ti -o- ) d cn O) CI) CI) CA cn Ct) o) Cl) o) O) O a) Ci) Ci) Oi) O) Ci) 0) m c6 — d I -- - - • • c7)= 00 O CO N- 1A 00 Tr e— CO Tr CO 1s et co O OO O e- N O I O _0 0) e- O O e- e- O e- O O e- e- e- e- O O O e- e- O O M CO F O_ 0 0 0 to 0 0 0 U) ' CA U) C1) CO 1n Cl) 0 0 Cn K) et , r• 0 U CO C) CD N CO 000 CO O J0 a o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o O E 2 m C Et I r l W o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 a) c 2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0'O O O E e- N M et 0 O CD t` CO O e- N M r et 1n CD CO O O e- N M et L P0000 .00000 N N CV N C) E < 0 RU2A Daily Drilling Summary 4/15/13 POH & RD Halliburton E-line. RIH, close pipe rams and pressure test 9 5/8" casing and tubing head alignment. POH. Pull wear ring from tubing head. Change elevators. PU/MU 9 5/8" Olgoonik weight set whipstock, mills &directional tools BHA. 4/16/13 Finish PU Whipstock and assembly. Change elevators. RIH slow to 8,244'.Whipstock set down with 18K @ 8,244'; PU to 190K. Confer w/office. SO to neutral wt., circ. at 5.5 BPM w/550 psi, pulled free at 195K. POH. Clean & LD 9- hipstock and MWD. V` 4/17/13 LD 8-1/2" starter mill & 5" HWDP ("Flex jt."); PU/ MU new 8-1/2" starter& string mill beneath old 8- 1/2" string mill; PU/MU bumper sub &oil jars. Change elevators. RIH w/(9) 6-1/4" DC's, change elevators; RIH w/ (10)4" HWDP--total BHA wt. 25K . RIH w/8-1/2" clean-out mills BHA on 4" DP to 8164. Kelly up. Up wt at 175K, down wt at 145K, rot at 160K. Fill pipe & SPR. RIH &tag up at 8220'. Circ & rotate at 8220 to 8230'. Stalled out. Stop pumping& Rotating. Slide down hole working through tight casing taking 15-25K down drag from 8230'to 8241'. RIH with some spots taking 5K+-drag to tag at 8541' DPM. Set down 4 times at 8541'with 25K. POH to the tight area at 8241'. Work BHA through 8241' -8230' with 25K up drag&20K down drag. Ream area up &down with 3-5K rotary torque, 60 RPM, 800 psi & 300 GPM. Clean up tight area with 12 passes. Stop reaming and trip BHA through area with 5K Up & down drag. Work BHA through 8241' -8230' with 25K up drag& 20K down drag. Ream area up & down with 3-5K rotary torque, 60 RPM, 800 psi & 300 GPM. Clean up tight area with 12 passes. Stop reaming and trip BHA through area with 5K Up& down drag. POH. Change elevators. PU / MU 9-5/8" Olgoonik weight-set whipstock, mills&directional tools BHA--scribe whipstock toolface & UBHO. 4/18/13 Change elevators. RIH w/ (9) 6-1/4" DC's; change elevators; shallow test MWD; RIH w/(10)4" HWDP -- kik., total BHA wt. 30K . RIH w/9-5/8" weight-set whipstock, 8-1/2" starter&string mills, & MWD BHA on 4". c' Fill pipe.Take on approx 80 bbls of LVT base oil into T-106 and approx 160+ bbls of OBM. Within 15' of the EZ Drill Pkr. Start mud pumps, break circulation. Good signal on MWD, orientate tool face/ (IIP whipstock face to 10° left of top (high) side confirm tool face is steady. Set 25 K down on whipstock to , j~ set anchor. Set additional 35K and sheared whipstock anchor bolt; P/U and confirm we are offs whipstock at 8,541' DPM. Begin milling 9-5/8"top of window @ 8,517' DPM and cut to 8,526' W5 4/19/13 Cont.to cut/ mill out window in 9-5/8" casing to 8,527' (note: SD pumps and checked for flow @ 8,526' V --well static). Attempting to cut window w/8K lbs on Mill, 75-85 RPM's, 600 GPM, 3100 to 3250 psi and 5 to 15 K Ft/lbs of torq it appears that mill has stopped cutting. Observed metal shavings "only" est. RU2A Daily Drilling Summary 1 gallon and 3 gallons est. of black goop. Prep to and POH to inspect, C/O Mills. Set wear bushing in tubing head. MU replacement 8-1/2" starter& string mill assembly. RIH w/8-1/2" mills BHA. 4/20/13 Cont. RIH w/8-1/2" mills BHA on 4" DP to 8,444'. Finish cutting/milling out window f/8531't/8540' and drilling new formation to 8,554' DPM --getting back metal shavings on magnets. RU rig's mud to pump down both DP & 9-5/8" casing. Hold JSA to do LOT. Perform LOT on 9-5/8" casing window @ 7,161'TVD log w/9.4 ppg OBM: pumped 8 bbls. at 1/2 BPM rate up to leak-off at 2,049 psi for 14.9 ppg EMW; SD pump and monitored pressure decline to 1,608 psi in 15 mins.; bled back 8 bbls. to trip tank. 4/21/13 Continue POH (Wet),to BHA#7, LD. PU/MU BHA#8: 8 1/2" PDC drill bit#1, mud motor, MWD/ LWD/ PWD collars, (3) Flex collars,Jars, (3) 6-1/4" DC's & (6)4" HWDP-- (note: 10K below jars, 25K total BHA weight; total length =483.04'; sensor distances above bit: directional =40.47', GR=49.07', Resistivity= 56.8' & pressure = 65.09'). 4/22/13 Shallow test MWD tools. RIH to 8,494' (fill DP every 30 stands);fill DP &establish circ. Orient drill bit to 8° left of top side &work thru 9-5/8" casing window to bottom (pumps off)w/5- 10K drag. Work bit through window. 4/23/13 Drill ahead (slide/rotate/survey): 8,554' -9,154' (370'/avg. 41.1 fph); back-ream top single prior to making DP connection . 4/24/13 Drill from 9,154'-9,815' 4/25/13 Drill from 9,822'-10,097'. CBU while working pipe. POH Work tight area 9480' and 9400'. 4/26/13 Continue to circulate and backream out of hole f/8775 -t/8541'. POH Work BHA. Down load MWD. Stand back BHA. BOPE Test. 4/27/13 Cont BOPE test. PJSM. Break down BHA#8. LD MWD &Stab. PU new MWD. Change kick pad from 1.222 to .932. Scribe BHA. Upload MWD. Finish BHA. RIH with HWDP. Surface test MWD. PJSM. Pick up RU2A Daily Drilling Summary 66 joints (22 Stands 2072.56') of 4" drill pipe. Strap & rabbit same. Continue to RIH with BHA#9 & Bit#2 to 5185". Filled Drillpipe every 22 stands. 4/28/13 Continue to RIH. Filled Drillpipe @ 8294'. Continue to RIH. Started taking wt @ 9213'. M/U Top Drive, washed and reamed through tight spot. Continued RIH to 9245'.Tagged up on bridge in hole at 9245'. Attempted to wash through bridge without success. L/D single and P/U stand in order to have working room. Oriented motor to high side. Washed through bridge @ 9245' and continue to RIH to tag at 9830'.' Wash & ream from 9830'to 10088'. Noted 15' of fill on BTM. 4/29/13 Circulate at 200 GPM while slowly working drill string from 10,275'-10,328' above the coal while making repairs to Top Drive 4/30/13 Circulate at 200 GPM while slowly working drill stril from 10,275'-10,328' above the coal while making repairs to Top Drive. 5/1/13 Continue to circulate & reciprocate drillpipe (pumping at 200 gpm &working drillpipe from 10275'to 10328' above the coal seam at 10335'). RIH f/8,473'-t/9,900'with no problems. 5/2/13 Continue to RIH to 10,278'. M/U Top Drive wash & reamed to 10,372'for safety. Encountered no problems. Drilled f/ 10,372'-t/ 10430' (68 @ 45.33 fph). Worked on top drive, Cam Rig Tech fixed issue. Rotate, Slide, f/ 10,430'-t/ 10669'. Slide/ Rotate f/ 10669' t/ 11015'. 5/3/13 Continue to Rotate, Slide, and Survey f/ 11,015-t/ 11,026'. C/O 6" Liner swab on pump#1. Continue to Rotate, Slide f/ 11026't/ 11090', survey @ 11,090' (75' @ 25 fph). Continue to Rotate,Slide, f/ 11,090' t/ 11123". Continue to Rotate, Slide f/ 11123' t/ 11204". Continue to Rotate, Slide f/ 11204't/ 11225'. CBU x 2 while working on Mud Pump#1: C/O Liner/Swab&attempt to C/O Suction Valve Seat, broke Hydraulic Seat puller. Put pump back together. Prep to and POH for short trip F/ 11225'-T/ 10,159'. Max. pull 230k No problems. RIH f/10,135'-t/11,231'with no problems. Wash to 11,115'for safety, Adjusted hole depth with MWD. Continue to wash to bottom @ 11,225', Encountered no fill. Slide f/ 11,225' - 11,235' ( 10' @ 20 fph) RU2A Daily Drilling Summary 5/4/13 Continue to Rotate,Slide, Survey f/ 11,235' -t/11403'. Continue to Rotate,Slide,Survey f/ 11403"-t/ 11506', WOB 10-15, RPM 120,SPM 115 =4000 psi. Continue to Rotate,Slide, Survey f/ 11,506' -t/ 11,545 (39' @ 9.75 fph). C/O Swab on pump#1. Checking rod wash. Continue to Rotate, Slide, Survey f/ 11,545'-t/ 11,614' (69' @ 19.71 fph) 5/5/13 Continue to Rotate, Slide,Survey f/ 11614' -t/ 11758'. Change out a swab and liner mud pump#2. Continue to Rotate, Slide,Survey f/ 11758' -t/ 11897'. Continue to Rotate, Slide, Survey f/ 11897' -t/ 12006'. 5/6/13 Continue to Rotate, Slide, Survey f/12,006'-t/ 12,162'. CBU, observed leak at Top Drive Goose Neck Hammer union, shut down pumping and tighten union. Pump LCM Calcium Carbonate 45 bbl pill on bottom. POH wet to 9 5/8" Casing Window at 8527', Note: Worked thru one tight spot at 9510'worked thru twice with 75 and 50 klbs over pull, third attempt slowly pulled thru with any noticeable overpull. Clean Rig Floor, Mix and pump dry job. Continue to POH, shut down to fill trip tank. 5/7/13 Continue to POH with 4" drillpipe, racking back same. Laying down BHA#9. Broke BIT#2.and gauged bit. Reading the MWD/LWD Tools. L/D MWD and Mud Motor Assy. Clean rig floor, R/U and pull Wear Ring, M/U Test plug on 4" PTECH test joint and set in bowl. Begin testing BOPE. Attempt to test Hydril Annular Bag, after process of elimination it appears annular bag piston seals have failed. Call Hydril Tech and fly from Anchorage. Continue testing BOPE:Test f/250 psi to 5000 psi Floor and IBOP valves, Kill line and choke line valves, choke manifold valves, HCR, Lower/Upper VPR's and Pull 4" PTECH test joint C/O 4" PTECH drillpipe for 5" drill pipe and begin testing: Lower/ Upper VPR's, Dart Valve, Floor Valve, Lower Kelly Cock. Working on Bag of the Hydril. Removing bell nipple,drip pan and loosing bolts on hydril to c/o. Piston seal of the bag. 5/8/13 Continue to disconnect drip pan ,flow line & adaptor, Bell Nipple,trip tank hoses, Koomey lines and removed nuts on Hydril cap. P/U potato masher& installed on the Hydril cap bolted same down in order to P/U lid. Work on raising Hydril cap. Raised cap, removed element & cleaned both bag and thread to cap. Removing Piston from Hydril housing in order to c/o seals. C/O upper/lower seals on piston. Install redressed piston, same element that was pulled (good shape), function test& charge Koomey unit, Prep to test Annular Bag on 5" drillpipe.Test Annular w/5" D.P. f/250 to 2500 psi, (good test). C/O drillpipe f/5" to 4", test f/250 to 2500 psi, (good test). Pull 4" D.P.Test Blind rams f/250 to 5000 psi. Perform Koomey Performance test. Pull Test Plug and fill hole =4 1/2 bbls to fill hole to original level at beginning of test yesterday at 1000 hrs, (Tbg. Hanger bowl). Begin N/U Flow Nipple/ RU2A Daily Drilling Summary Flow line and fill up/ bleed off 2" lines. Install Drip Pan, Bell Nipple. C/O elevators. Installed saver sub clamp and RIH with 4" drillpipe from off driller side. C/O elevators to 5". P/U & M/U "NEW" 5" drillpipe, double torqued,tallied and rabbit. 5/9/13 to P/U & M/U & RIH with 5" drillpipe (double torque & doped, tallied and rabbit)Total of 57 stands(171 jts.5395.05'). Turn elevators around on bails. Filled tubing, Installed 5" stripping rubber. Cleaned Drill floor, removed all tread protectors. POH with 5" drillpipe (Wet). C/O 5" elevators from 4 1/2 elevators in order to move Monel. C/O 4 1/2 to 4" elevators to lay down 4" HWDP. POH with 18 Stds Wet. Held prejob safety meeting with Halliburton, IDA and Crane on P/U & M/U BHA#10. Make sure everything is in place. Picked up Motor, made up &torque Bit#2RR, M/U Float Sub, 6.750" IBS Stabilizer, DM Collar, EWR-P4 Collar, DGR Collar, PWD, HCIM Collar. 5/10/13 Held safety meeting due to Crew Change. Continue to Pick Up and Make Up BHA#10. Surface tested MWD . Confidence Test went O.K. Started to initialize string and tool gave errors. Trouble shoot tool and analyzed that tool quit giving out information due to being too cold. C/O elevators, P/U one jt. Of 5" HWDP and pumped @ 22 spm, 144 psi to get tools. Retest MWD Tool, Shallow Tested O.K. Continue to P/U & M/U BHA#10. Install new 5" bell guide on TDS, fill pipe and check MWD. RIH from 752 to outside of window @ 8670' (filled Drillpipe @ 4237'). Filled drill pipe& MWD @ 8670'. RIH. Worked through ledges @ 10979', 11014', 11220' and 11229'. Ream from 11229'to 11336'.Work& ream through bridge @ 11336'. Got through bridge by orienting tool face to top side. Reamed to 11409'. 5/11/13 Circulate out of the hole from 11022'to 10642'. Packing off with cuttings. Shut down pumps to backoff on pressure to 400 psi SPM Range 40-110 started pump @ low spm until good circ. Raise spm. Pressure 400 psi to max of 3500 psi. Work from 10642'to 10721'. Circulate Bottoms up. Good amount of cuttings at the shakers. Cuttings consisted mainly of splinters of coal. Continue to pump out off hole f/10,721' -t/8747'. Attempts to pull without pumping unsuccessful. Circulate with BHA below the window at 350 GPM to clear cuttings from area. Stroke pipe from 8654'to 8747'. Pull into the casing to 8480'without any problems. Examine Can Rig TDS. RIH with BHA# 10.Tag up at 9200'. Wash & ream from 9200'to 9,506". Wash & Ream f/9,506'-t/10,825'. Reaming Parameters: RPM 85, SPM 70, Pressure 1800 psi., Torque 8500 ft lbs. Changed out saver sub @ 10,933' and elevators from 4"to 5". Picked up and made up x-over. Washed and reamed f/10,933'-t/11,029. Backed reamed and circulated until the hole was clean. Parameters: RPM 85, SPM 70, Pressure 1800 psi. Torque 9000 ft lbs. Reset torque to stall Top Drive @ 17,000 ft. lbs. Installed saver sub safety clamp. Wash and Ream f/11,029'- t/11,313'. Backed reamed and circulated until the hole was clean. Parameters: RPM 85, SPM 70, Pressure 1800 psi. P/U Std. #113 (11,313'- 11,408'). Wash and Reamed, encountered hard reaming with high torque &drag f/11,344-t/11,408.. Wash & Ream various time to eliminate drag&torque. Wash & Ream f/11,408'-t'11,578'. RU2A Daily Drilling Summary 5/12/13 Wash & Ream f/11,578' -t/12,162'Washing and reaming each stand until all drag and torque was eliminated. Washing& Reaming Parameters: RPM 85, SPM 70, Press. 1800 PSI. GPM 273. Last Std.#121 increased GPM 391,SPM 100, Press.4150 psi. Drilling from 12,162'-to 12,295' (133' @ 11.08 fph). Rotating Parameters: WOB 10K, RPM 120, GPM 434, Pressure 4,400 psi. Drill to 12,295'. Back ream 210' while making pump repairs to help with slide drilling. Running on rig power as a precautionary measure for power to the centrifuge. Orient tool face. Rotate,Slide, from 12,252'to 12,288' ( 36' @ 7.2 FPH). Rotating, sliding f/12288-t/12338' (50' @ 33.33 fph). Parameter: WOB 10-15k, GPM 420, RPM 120, Press. 3900 psi,Torque 10,000-11000 ft lbs. Mud Volume 295 bbls @ 22:30 hrs. Lost+/-40 bbls 5/13/13 Continue to Rotating& Sliding f/12338-t/12354' (16' @ 10.66 fph). Mud loss to formation while drilling is at 8-10 bbl/hr. Swab wash out on pump#2, repaired same. Continue to Rotating&Sliding f/ 12354' - t/12387' (33' @ 11 fph). Drilled @12375' and encounter drilling break. P/U drill pipe and checked for flow. No flow and continued to rotate, and slide to 12396'. Continue to treat mud seepage with LCM material Baracarb&Steel Seal. Stop drilling at 12396'. Reduce pump rate to 235 GPM. Work pipe and address mud loss to formation. Work logistics to increase on board LCM material. Lowering mud weight from 9.5 +to 9.3 with centrifuge. Fluid loss to formation remains at 10 bbl/hr. Lower circulation rate to 4 BBL/MIN. Mud loss reduced to 5 bbl/hr. At 12:30 hrs LCM material arrives on helicopters . Mix 50 bbl LCM pill. Running the centrifuge to reduce the mud weight to 9.3 PPG. 13:00 hrs mud weight in 9.3 ppg. Mud weight out 9.5+. Pump 50 bbl, 10 ppg OBM pill with Baracarb 5, 25 & 50, 16 sacks ea at 50 ppb. Displace pill out of the drill string to cover 714' of open hole. Pull 800' out of pill on bottom to 11600'. No hole problems. Circulate at 4 bbls/min above the pill. Monitor fluid volumes. No losses observed. Circulate at 175-200 GPM bring the pill up the hole. MW in 9.3 ppg. MW out 9.4 ppg. RIH to 12354' orienting depth to match with tally. Rotating drillpipe Washpipe washed out. Shut down Pumps. Pulled one stand and racked same back. Working on wash pipe removal. 5/14/13 Moving and working drillpipe. Drillpipe free and hole in good shape. Max. pull 285K. +/-20-25K drag. Finished repairing washpipe.Secured personnel in basket on drill floor prior to testing wash pipe. Worked drillpipe without incident. Drillpipe free. Break circulation. Increase pump rate. Pressure test swivel packing.Wash to bottom from 12,351'. Rotary drilling from 12,396'to 12485'. Rotate & slide Drilling f/12,485' -t/12,518' Rotating Parameters: WOB 13-15k, RPM 70-85, GPM440, Pressure 3900 psi Sliding Parameters:WOB 14-17k, , GPM 440, Pressure 3800-3900 psi. 5/15/13 Rotate &Slide drilling from 12,518' to 12,583'. Work pipe free after sliding 12' to 12,583'. Changed to shore power at 18:00 hrs. Rotate &slide drilling from 12,583' to 12,649'. RU2A Daily Drilling Summary 5/16/13 Drill ahead (rotate): 12,649'-12,686' (37'/37 fph). Drill ahead (rotate, slide & survey): 12,686' -12,770' (84'/8.4 fph). Drill ahead (slide): 12,770' -12,781' (11'/2.7 fph). Drill ahead (rotate, slide & survey): 12,781' - 12,829' (48' /6 fph). 5/17/13 Drill ahead (rotate, slide & survey): 12,829' - 12,887' (58'/7.7 fph). Mix and pump Hi Vis Sweep, Circulate in/out, observed est. 50% increase on cuttings w/sweep at shakers. POH to 11,788',good trip/ smooth hole. RIH t/ 12887', M/U Top Drive, break circulation. Drill ahead (rotate, slide &survey): 12,887' - 12,901' (14'/7 fph). Drill ahead (rotate & slide): 12,901'- 12,922' (21'/7 fph). Take MWD survey; circ. BU. Begin POH w/5" DP up to 12,450' -- note: pulled 1st stand O.K,then had to pump 2nd stand out-tight spots @ 12,785' & 12,768' (up to 50K overpull w/o pump); had 25K overpull @ 12,665'- -wiped out O.K.. 5/18/13 Cont. POH w/5" DP up to 10,934' (bottom of 4" DP). Change out DP elevators & saver sub from 5"to 4". Cont. POH w/4" DP up to 8,670'. CBU, clear cuttings from 9 5/8" csg while mix/pump dry job. Pull thru 9-5/8" casing window, no bobbles or over pulls. PJSM, cont. POH & begin L/D 4" PTECH drill pipe to pipe deck in 18 joint bundles. Cont. POH L/D 4" PTECH drill pipe to pipe deck,then bundle & back-load out to workboat, (note: RIH 27 stands of 4" PTECH DP on left side of derrick) 5/19/13 Finish POH up to top of 5" HWDP/ LD 4" DP to pipe deck & bundle in 18 joints each. Prep. to finish POH w/ BHA#10, lay down Jars, download MWD tools and remove sources. Continue laying down components of BHA and stand back some components for BHA#11. Begin Downloading LWD logs and remove sources, break off Drill Bit, L/D MWD/ LWD Drill Collar. Clean &organize rig floor, pick up 5" test joint, M/U Wear Ring pulling tool, backout lock downs and pull wear ring. Set Test Plug and fill stack w/water.Testing BOPE: 250 psi low& 2,500 psi high test Annular Bag w/5" test joint; 250 psi low& 5,000 psi high test VBR's on 5", choke manifold valves, blind rams, lower& upper Kelly valves,TIW safety& Inside BOP (Gray)valves, choke & kill line valves; perform accumulator test. RD test equip. Set stand of 4" DP from derrick in slips w/safety clamp& back-up snub line, broke out over torqued connection, LD 3 singles 4" DP. (marked 2 w/ red paint as damaged /galled pin & box threads). Pulled test plug from well head. 5/20/13 Set 9" ID wear bushing in well head &secure w/ hold down pins. C/O saver sub on top drive for 5" DP to 4 1/2" IF (NC 50) conn. RIH w/5" HWDP f/derrick. PU (SLM & rabbit w/2.50" drift) new 5" 19.50#S-135 IF DP f/ pipe deck& RIH (note: MU DP conn. 2X to break in new tool joints) -- have 34 joints 5" + HWDP in hole Continue (On Shore Power) P/U 5" drill pipe, (SLM/ Rabbiting each joint). Breaking connections RU2A Daily Drilling Summary /doping threads X 2. Continue (On Shore Power) P/U 5" drill pipe, (SLM/ Rabbiting each joint). Breaking connections/doping threads X 2 -- have 245 joints 5" + HWDP in hole. 5/21/13 Finish P/U 5" drill pipe, (SLM/ Rabbiting each joint); breaking connections/doping threads 2X-- have 255 joints 5" (8,050')+ HWDP in hole. Hang off blocks and slip &cut 110' drill line. CBU @ 8,500' (reciprocate & rotate DP) -- max gas= 114 units. Slug DP and POH (rack back 85 stands in derrick), P/U BHA# 11 and M/U Bit#3. PJSM, Load Nuclear Sources into LWD/ MWD; MU new jars & RIH w/5" HWDP-- BHA#11 weight= 35K; shallow test MWD & motor. P/U 48 additional joints 5" drill pipe, (SLM/ Rabbiting each joint); breaking connections/doping threads 2X. 5/22/13 RIH w/ BHA#11 on 5" DP (fill pipe every 25 stands)to 8,323'. RIH w/ BHA#11 and Bit#3 f/8323't/ 8604'. Continue RIH, encountered tight spot at 10120'. M/U top drive and wash thru tight spot f/ 10120' t/10215'. Continue RIH, encountered tight spot at 10405'. M/U top drive and wash thru tight spot f/ 10405't/ 10560'. Continue RIH, encountered tight spot at 12524'. M/U top drive and wash thru tight spot f/ 12525"t/ 12560". Continue RIH f/12,560' -- had tight spot @ 12,580' --W&R down to 12,922'TD (had 12' fill). Drill ahead (rotate): 12,922' - 12,954' (32'/64 fph) . Flow check @ 12,954'— negative. Drill ahead (rotate&survey): 12,954' - 12,965' (11'/64 fph) -- max. BU gas from 12,922' = 172 units. Lost power to drawworks after making DP conn. --SCR problems, rack back stand &work pipe while troubleshoot SCR. 5/23/13 Drill ahead (rotate): 12,965' - 13,059' (94'/42 fph), BBG = 26 units; back ream hole prior to MWD survey & DP connection. NOTE: Drilling parameters: 15-25K WOB, 85-95 surf. RPM's, 442 GPM/2800 psi, Torq. = 18-20K on bottom/ 17K off bottom.Take MWD survey& make DP conn. Drill ahead (rotate, slide &survey): 13,059' - 13,398' (339'/29.5 fph). Change over to shore power. Drill ahead (rotate, slide &survey): 13,398' - 13,546' (148'/27 fph). BGG = 29 units, max gas= 161 units from 13,465' (coal). 5/24/13 Drill ahead (rotate, slide &survey): 13,546' - 13,761' (159'/26.5 fph). Change to rig power for source testing Caterpillar 3512 generators. Drill ahead : 13,761'- 13,820' (59'/39.3 fph). Circulate, survey& rig service.Add lubrication oil to the TDS. Grease swivel packing. Change to shore power. End rig engine source testing. Drill ahead (slide & rotary): 13,820' - 13,845' (25'/ 16.7 fph). Drilling from 13,845'to 13,913'. Drill ahead (rotate & slide): 13,913' - 14,008' (95'/31.7 fph); backream stand prior to MWD survey& making DP conn. RU2A Daily Drilling Summary 5/25/13 Drill ahead (rotate &slide): 14,008'- 14,047' (39'/26 fph). Oil started coming out top drive breather vent. Drill ahead (rotate): 14,047' - 14,102' (55'/27.5 fph). Circulate & reciprocate at 14,102'. Trouble shoot Can Rig Ross Hill SCR field supply readings *. Work with Can Rig tech support. Rotary drilling from 14,102'to 14,125'; Slide drilling from 14,125'to 14,144' (19' slide). Tight after sliding. Jar off of bottom with 3 jar strokes at 425K. Rotary drill from 14,144'to 14,386' (242'/32.3 fph). Max gas = 101 units from 14,091' (coal). Backream hole,take MWD survey. Circ. BU (rotate & reciprocate pipe). 5/26/13 Cont. circ. well prior to short trip (3X BU) -- rotate & reciprocate pipe. BGG = 15 units. SD pumps & check for flow-- negative. PU off bottom w/pumps on = 355K; PU w/o pump =415K+. Pump out of hole w/1 pump (3 BPM)/ rack back 7 stands,then pulled into tight spot @ 13,695'. Backream out from 13,695' (tight& packing off) up to 13,346' (tight & packing off at 13,365'). Continue backreaming out without problems up to 12,775'. Circulate, rotate & reciprocate from 12,775'to 12,680'. Rotate at 70 RPM, pump at 400 GPM. Continuous drill cuttings followed by large chips of coal at the shakers. Circulated 1.5 bottoms up. RIH from 12,775'. Ream through bridges at 12,912, 13,050". Wash & ream to 13,249'. RIH from 13,249'to bottom at 14,386'. Fill pipe and cleaned 5' of fill from bottom. Drill ahead (rotate): 14,386'- 14,482' (96'/ 17.5 fph) -- picking up &working cautiously through "Hemlock Coal" formation. Circ. well at 235 GPM & rotate/work pipe while production electrician made adjustments to#7 trap communication and replace piston, liner & suction valve in #2 PZ-11 mud pump --found coal fibers in suction valve &seal. Took MWD survey and made DP conn. Drill ahead (rotate): 14,482' - 14,508' (26'/ 13 fph). 5/27/13 Drill ahead (rotate): 14,508'- 14,592' (84'/ 14 fph), backream stand prior to MWD survey& DP conn. Drill ahead (rotate): 14,592'- 14,720' (128'/ 13.5 fph) --WOB 10-20K, RPM 90-100, Pump rate 3000 psi @ 470 GPM. Replace piston and suction valve in # 1 PZ-11 mud pump;. check piston liner-good. Drill ahead (rotate): 14,720'- 14,798' (78'/ 11.1 fph), backream stand prior to MWD survey& DP conn. 5/28/13 Drill ahead (rotate): 14,798'- 14,861' (63'/ 10.5 fph), backream stand prior to MWD survey& DP conn. Drill ahead (rotate): 14,861' - 14,956' (95'/ 17.3 fph), backream stand prior to MWD survey& DP conn. Circulate, reciprocate & rotate from 14,956'to 14,863' while production works on turbine power issues. Drill ahead (rotate): 14,956'- 15,038' (82'/ 13.7 fph) . Pull off of bottom to allow Kustatan Production Facility to make adjustments to Turbine "A". Drill ahead (rotate): 15,038' - 15,098' (60'/ 12 fph), backream stand prior to MWD survey& DP conn. Note: pumped 50 bbls. hi-vis sweep @ 15,075' and increased SPM to give 482 GPM --saw no appreciable effects when sweep came back. RU2A Daily Drilling Summary 5/29/13 Drill ahead (rotate): 15,098' - 15,134' (36'/20.5 fph). Drilling parameters: 10- 18K WOB, 90- 100 Surf. RPM's,482 GPM/3,100 psi,Torq = 20-23K; add LVT base oil & run centrifuge to control MW. PU off bottom, circ. w/ 1 pump, rotate & reciprocate pipe while replace suction valve in mud pump#1. Drill ahead (rotate): 15,134' - 15,160' (26'/17.3 fph), backream stand prior to MWD survey& DP conn. Drill ahead (rotate): 15,160' - 15,242' (82'/13.7 fph). Drill ahead (rotate): 15,242'- 15,252' (10'/ 10 fph). Change swab & liner in mud pump#2. Drill ahead (rotate): 15,252' - 15,357' (105'/ 12.4 fph), backream stand prior to MWD survey& DP conn. 5/30/13 Finish drilling (rotate): 15,357'-15,360' (12,460'TVD); Drilling parameters: 18- 20K WOB, 95 - 100 Surf. ' I % n,/ RPM's,484 GPM/3,000 psi,Torq = 22 - 24K; add LVT base oil & run centrifuge to control MW. Backream 1� hole and take MWD survey; pump 50 bbls. hi-vis sweep into DP. Work& rotate pipe while circ. 50 bbls. hi-vis sweep out from 15,360' -- had increase in sand over shale shakers when sweep came back (approx. 2,000 strokes late). Rack back 1 stand and work& rotate pipe while circ. out BU from 15,337'. Tag TD at 15,360' -- no fill found on bottom. POH to BHA without backreaming or circulation -- maximum pull 415K. Remove nuclear sources & down-load data from LWD tool, finish POH (SLM - no correction)-- LD 8-1/2" PDC bit(in-gauge & no damage or excessive wear). Finish LD Halliburton MWD, LWD tools& mud motor. Pull wear bushing. Close blind rams. Clear&clean rig floor. 5/31/13 Finish clean rig floor. Remove upper VBR pipe rams and install 7" casing rams. RU to test 7" casing rams - -applied 250 psi low pressure against annular preventer on 7"test joint O.K., but XO leaking on high pressure test; start RU Weatherford tongs, pull out 7" test joint to work on XO-- cut 1/2" port/drain hole in XO body to apply pressure from inside to annulus. Clean rig and prep. to run 7" 29#Liner. M/U & RIH w/7" Test joint/Test Plug:test Annular Bag from 250 psi to 2500 psi, upper rams c/o to 7" casing rams tested f/250 psi t/3500 psi. R/D test equipment. P/U 7" casing shoe joint w/8.25" Reamer Shoe, install 8.375" centralizer w/stops above and below centralizer 5'f/top of Reamer shoe.JSA/PJSM w/ all involved with running 7" 29# DWC connection liner. Clean and Bakerlock connection between 1st and 2nd joints,fill 3rd joint with drill. mud and check float equipment,good test. Begin RIH placing 8.375" centralizers on each joint up to joint#45 = 13,451' once we tag bottom. Continue PU & RIH filling 7" casing w/mud &drifting each joint off the pipe rack-- have 109 joints (4,673') in hole as of midnight, placing centralizer on every 4th joint. 6/1/13 Cont. PU/ MU & RIH w/7" casing liner (drifting each joint) & placing 8-3/8" solid centralizer on every 4th joint-- 155 joints (6,665.28' incl. reamer shoe) in hole when Weatherford power tongs failed to grip & M/U 7" csg. (worn cam rollers in tong head). Unable to get power tongs to grip, call for replacements. Work on Weatherford power tongs to grip, (wrap Duct Tape around cam rollers). Tongs back in service, RU2A Daily Drilling Summary have 10 more joints 7"to run. Cont. PU / MU & RIH w/7" casing liner(drifting each joint) & placing 8- 3/8" solid centralizer on every 4th joint, last centralizer on joint 157, RIH 165 jts 7". C/O to 5" drillpipe elevators, prep to P/U 7" Baker 9 5/8" x 7" Flexlok liner hanger pinned to 2362 psi, w/ZXPN liner top Packer w/ HRDE running tool profile &Type II tie-back sleeve, liner wiper plug made up on bottom of Packer w/set pins at 2400 psi, (drillpipe wiper plug loaded in cement head & spare in box Observed 3 tack welds on Packer hydrau shifting sleeve, Conducted JSA w/all involved running Hanger/ Pack. Hot work permit, cover hole &grind tacks. mix up polymer plug material and pack top between Packer& running tool to prevent debris f/falling inside release/running tool mechanism. Rig up 1"fillup hose for filling 5" drillpipe. RIH w/5" drillpipe out of derrick, running speed average 3 mins a stand to 9 5/8" window at 8500'. Make up top drive, Circ/condition mud, Up Wt= 245K, Rot Wt= 211K, Dn Wt= 180K, 15 RPM = 10K ft/lbs, mud coming back at 92° Begin RIH w/5" Drillpipe at 3 min/stand thru the 9 5/8" window, filling each stand w/1" hose, fill complete with top drive at 20 stand intervals down to 15,235' and stuck pipe on making DP conn. (unable to: move pipe up w/375K PU or down w/ 100K SO or rotate w/ 19.4K torq. or circ. w/1400 psi). Pull up to 450K (string air weight+ blocks) &work pipe free, establish circ. and move pipe down hole to 15,275' -- unable to get deeper(85' off TD). Reciprocate/ work pipe 15,275'to 15, 265' (not able to rotate) and circ. BU at 6 BPM/ 1,000 psi. 6/2/13 Cont. reciprocate/work pipe 15,275' to 15, 265' (not able to rotate) and circ. BU at 6 BPM/ 1,000 psi; BGG = 37-61 units. Hold PJSM on PU cement head &cementing. Note: Max Gas units= 347. PU/ MU cement head; RU cement line to cement head. Re-establish circ. (through cement head); install "Tee", block valve, and reverse out& by-pass line to mud pits for cement wash-up. Pressure test cement line to 5000 psi, observed leak at cement head swivel, bleed off pressure and grease up swivel. Attempt 5000 psi pressure test, Good Test. BJ Cement Crew began mixing cement weight material to spacer, having water feed problems, put on 2nd water pump,good pressure. Pumped 25 bbl (out of 40 bbls) 11 ppg Seal Bond Spacer before experiencing BJ Services Air Compressor problems. Build up pressure to 28 psi to cement bulk tanks, blow dry product to cement mixing tank and bleed down to 0 psi in 5 mins. it would take 6 mins to build back up to 28 psi,we batched dry material (weight material) to spacer inconsistently. Called town, decision was made to bring out by boat a full functioning Air Compressor and Spacer Mix from BJ Services yard to OSK Docks. Circ 25 bbl Seal Bond Spacer around (no extra cuttings). Circ/Condition well while waiting on Boat to deliver Air Compressor& 2nd back up compressor. Boat arrived, transfer BJ Air Compressor f/ boat to Cement unit area and C/O spacer sack saver Pod's. R/U Air Compressor and add to spacer pill; BJ Crew primed up equipment while cont. to circ. well. Conduct JSA/ PJSM w/all involved in 7" Liner Cement program. Retest cement line to 4,500 psi. Mixed & pumped 33 bbls. 11.0 ppg "Seal-Bond" Spacer. Mixed & pumped 283 sks(526 cuft.) class "G" cement w/additives (10% BA-90+ .005 ppg "Static Free"+2.5% BA-56+ .8% R-3+2% KCI + .5% EC-1 + .5%CD-32 + .1%ASA-301 + 1 ghs FP-6L+ .5% sodium metasilicate) @ 13.5 ppg/ 1.86 yield. Dropped DP wiper dart and began displacement w/9.4 ppg OBM using BJ cement unit, slowed pump & saw dart latch liner wiper plug at 138 bbls. Mud displaced (approx. 2-1/2 bbls. over calc amount)w/600 psi increase to 1,200 psi shear, cont. displacement. RU2A Daily Drilling Summary 6/3/13 Finished displacement of cement to bump wiper plug/ latch into landing collar at total 408 bbls. pumped (approx. 3.5 bbls. over calc. amount)w/500 psi increase to 1500 psi held 5mins (cement in place @ 1:20AM) increased pressure to 3000psi to hydraulically set liner hanger, released pressure. Released setting tool from liner hanger, pulled up 6'to open "dogs",then sat down & rotated to set liner packer w/65K down weight. Checked floats, holding ok. Closed annular preventer and pressure tested annulus& liner top packer to 2,500 psi/ 10 mins.; bled off pressure &opened annular preventer. RU & reverse circ. out at 4.8 BPM/700 psi (3X BU to clean up cuttings from mud coming back) -- had no cement in returns. RD reverse out&cement lines and LD cement head. Mix and pump dry job,grease blocks and Swivel Packing and fill Trip Tank. POH f/8130' (7"TOL)t/462'. NOTE: 09:30 hrs Swap power t/Rig Gens while KPF ran Gas pipe line Pigs that potentially could take Gas Turbines down. Continued POH, lay down Baker Liner Hanger running tool assy. (NOTE: Run Tool Assy. 100%accounted for, no additional hardware came back). Clean Rig Floor and BOPE. C/O 7" casing rams to 2 7/8"x 5" VPR's, prep to conduct an in house BOPE test. AOGCC State Rep Mr.Jeff Jones on rig to witness testing. MU /set test plug& 5" test joint w/side entry sub,TIW type safety (floor)valve & Inside BOP (Gray)valve,fill BOP stack w/water, rebuild Demco 2" Kill valve on standpipe manifold. Test BOPE: 250 psi low& 5,000 psi high --TIW type safety(floor)valve, upper& lower VBR pipe rams, standpipe Kill valve, choke manifold valves. 6/4/13 Cont.test BOPE: LD 5"test joint and run in 4"test joint w/side entry sub,TIW type safety(floor) valve & Inside BOP;test 4" BOPE: 250 low 5000psi. high;TIW& Inside Gray valves, upper& lower VBR pipe rams; test annular preventer on 4" pipe to 250 psi low& 2,500 psi high; pulled 4" test joint and tested blind rams 250psi low and 5000psi high. pump water out of BOP stack. Note: adjustable choke failed to test-- will repair. Pulled test plug from well head; reset 9" wear bushing in well head. MU Inside Gray (dart) valve to bottom of flex DC's (1 stand); RIH w/flex DC's, 5" HWDP&jars and 25 stands 5" DP to 3,002'. Begin POH w/5" -- LDDP to pipe deck in bundles of 10 joints each (have 30 joints out at midnight). 6/5/13 Continued POH to top of 5" HWDP-- LDDP 5"to pipe deck in bundles of 10 joints each. RIH w/24 stands of 5" Drillpipe from derrick. POH w/23jts. of 5" drillpipe & LDDP to pipe deck in bundles of 10 joints each. R/U to rack back 4" drillpipe to derrick P/U and M/U 4" drillpipe in mouse hole and racked back to derrick. Serviced rig while Mechanic replaced roller bearing in Iron Roughneck (ST-100) spinner. Started back loading the MV Endeavor with 5" drillpipe. 6/6/13 Completed repairs on the ST-100 and tested same. Continue to P/U & M/U 4" drillpipe in mouse hole and rack back same.Total 4" Drillpipe in derrick= 231 joints. Finished Picking Up 4" Drillpipe and racking back to derrick. Changed out 4'to 5" Elevators and POH, laying down 45 joints of 5" drillpipe. L/D 5 RU2A Daily Drilling Summary joints of 5" drillpipe. Swapped over from Land Power to Rig Generators. Continue to POH, laying down 48 jts. Of 5" drillpipe. R/U to cut drill line. Slip and cut 120' of drill line. Laid down BHA. Picked up and Made up Clean Out BHA. Made Up Mill, Scrapper,Junk Baskets, X-over, DC's, HWDP, X-over,Jars, X-over, HWDP. Continue to RIH with 4" drillpipe with Clean Out BHA. MV Endeavor tied up @ +/- 22:30 hrs. everything was offloaded prior to 00:00 hrs. 6/7/13 CONTINUE TO TIH WITH 4" DP TO 7851 C/O HANDLING TOOLS F/4" TO 5" P/AND M/U 9 5/8 SCRAPER& X-OVER AND TORQUE SAME RIH F/7851'T 7945' FILLED DRILLPIPE CONTINUE TO RIH WITH 5" DRILLPIPE AND 9 5/8" SCRAPER. PJSM CIRC BOTTOMS UP. 6/8/13 R/U to circulate and filter brine water on RU2A Started circulating, displacing well to brine water. Shut down displacing well with brine water. While displacing to brine, we saw a large amount of contaminated returns, not cleaning up. Filled pit#1 w/contaminated mud, stopped circ., due to low brine volume and not able to take returns. While building brine and moving mud, we transferred good OBM to T-106 upright (380bbIs)to make space available and avoid further contamination Build volume in pits, Performed rig service and housekeeping. Circulated well and filtered water, as of 00:00 hrs. NTU's= 142. Installed hydraulic drilling choke, actuator and spool. torque bolts. 6/9/13 Continue to circulate and skimmed fluid. Pump Pressure 3056 psi, SPM 108, BPM 10.04. Continue to circulate and filter completion fluid. Pump Pressure 3056 psi,SPM 108, BPM 10.04. NTU's @ 04:00 hrs. = 125 / NTU's @ 05:30 hrs. = 135 C/O micron size on the filters socks to 10 microns. PJSM Circulated and filtered formation water. 12:00 hrs to 15:00 hrs. replaced seal on the Hydraulic Drilling Choke actuator and tested same Tested to low 250 psi/ high 5,000 psi. tested for 5 mins. each on chart. POH with 5" drill pipe. 6/10/13 Pressured up to 500 psi with no problems.TOC @ 13,050' and logged to 12,550'. Bled off log (500 psi) pressure and POH with CBL Tool @ 120 ft/min. Rigging down Halliburton wireline equipment. 6/11/13 Move Wireline unit pieces off Pipe deck; Clear rig floor; Prep floor to run TCP (Halliburton Guns);Change dies in ST100 (Iron Roughneck); Change bales. pick up 2 7/8 YC elevators. PJSM with Halliburton Pick up guns off Pipe rack. Change bales and pick up 4" elevators. Change bales and pick up 4" elevators. P/U & MU Champ Packer and BHA on 4" Drill pipe and RIH all of 4"drill pipe. C/O Elevator P/U & MU Champ Packer and BHA on 4" Drill pipe and RIH all of 4"drill pipe Continue to RIH with 5" Drill Pipe Continue to RIH with 5" Drill Pipe. Note: As per Halliburton 1 min/stand. Approx 3 mins.to a connection. RU2A Daily Drilling Summary 6/12/13 Continue to RIH to 11,962'. Top off stand 119 (11,962')with filtered brine water for Well to be under balance prior to perforating Well. Continue to RIH to 15,100.43' (152 stds+ BHA+ 1Pup JT (11.71')). Held safety meeting with all Halliburton logging & perforation team + IDA crew. R/U E-Line Equipment RIH with Halliburton tool (GR,CCL)to correlate. RIH with Halliburton tool (GR,CCL)to correlate. Started to correlate. POH W/Wireline. Rig down Wireline clear floor. Set Champ Packer at 14448' (set 30K on packer to verify. Rig up floor to take returns through choke and out Degasser to the pits (side entry sub and pup; steel lines from drill pipe to choke; Close rams open mud cross lines pump through annulus and choke to pits close choke and pressure to 2000psi against packer hold for 10 min. DR` Op_BAR AT 11:51 Monitor for returns Clean in the pits. Service rig. Checked fluid level with Nitrogen Sonic recorder. Continue to clean pit room area while waiting on Pollard Wireline Unit to arrive. Boat arrived @+/-20:30 hrs. off loaded same. Well indicated perforation guns had fired. 6/13/13 Pulled out of hole with 4" drillpipe. Issues with spinning out drillpipe due to drillpipe to slick to grab. POH and laying down Halliburton BHA for Perforating. C/O bails and elevators. Held JSA and safety meeting on handling. Continue to POH with BHA#13 (perforating guns) Laying Down guns. 6/14/13 Retrieved wear bushing. Rigged up to test 3 1/2"tubing. Tested Hydril to low 250 psi for 5 mins. & high 2500 psi for 5 mins. Tested Upper and Lower Pipe Rams to Low 250 psi .for 5 mins. & High 3500 psi for 5 mins. on chart. R/D Test Equipment. Rigged up to run completion and wait on valves. Held safety meeting and JSA. Started to make up motor, service seals made up pump intake, UTP, MTR, LTP, DGU Unit and started to make up control lines to DGU Unit. 6/15/13 Finished making up control lines to DGU unit. Making up splice connection to ESP Pump. Tie in control lines from DGU unit that run up to surface and test same. Continue making Splice. Plumb capillary tubes into pump Modify tubing slips (remove front tabs between handles with Weatherfords permission). RIH with Tubing and Baker Centralift ESP. C/O crew& held safety meeting. Performed continuity test and continue to RIH f/1145'-t/6206', continuity test every+/-1000 ft. Swap ESP Spool and Splice ESP Cable. 6/16/13 Continue to splice ESP Cable.Tested splice,test O.K. Continue to RIH f/9,333' -t/11,547'. Performed continuity test every+/- 1000 ft. Made up RN nipple,it.#369 & Packer @ 11,547'. Splice ends on ESP cable. Made up Capillary Lines, Gas Vent Valve with PSI. Tested to 3000 psi for 15 mins. Continue to RIH f/11,547' -t/11,820'. RU2A Daily Drilling Summary 6/17/13 RIH with ESP pump f/ 11,820 -t/12,626.Test continuity every+/- 1000 ft. POH with 2 jts. f/12,626' - t/12,564'. Rig Service, cleaned rig floor, coordinate boat logistics on bring ESP cable from Nikiski. RIH with ESP pump f/ 12,564'-t/12,808. Held PJSM ; Co-ordinate with red dog landing craft for ESP spool. RIH f/12,808'-t/12,932' and splice ESP cable. Performed continuity test. RIH f/ 12,932'-t/13,733'. M/U SSV, function tested with PSI,Tested to 5000 psi for 15 mins. RIH f/13733-t/14045'. M/u Hanger, lower connector for ESP cable, Penetrator and control lines. Performed continuity test.Test O.K. Landed Hanger @ 23:00 hrs. 6-17-2013. Run in lock downs. Performed final test to 5000 psi for 10 mins. Cleared rig floor of Baker Hughes Equipment. Rigging up Pollard Wireline. 6/18/13 RIH with wireline and set plug @ 2567'. R/U to set Baker Hughes packer. Set Baker Hughes packer with 2500 psi. R/U to backside and pressured up to1500 psi to confirm Baker Hughes Packer was set. Pumped down Tubing to 3500 psi and bled off as per Baker Packer Rep. R/U to pump down backside to pressure up to 3000 psi to test Annulus. Tested Annulus to 3000 psi and held same for 30 mins. on chart. RIH with Pollard Wireline and pulled Prong POH removed same and RIH to pull Plug. R/D wireline equipment. Rigged down Sheaves, casing tong, elevators and mouse hole. R/D hose on backside, Cleaned subs and rig floor. PJSM with crews. Crew change. Bled off koomey unit, continue cleaning drip pan in cellar. Nipple Down BOP's and move to pipe deck for move to RU 1. Blow out koomey lines and sucked out Koomey Unit Tank in preparing for new hydraulic fluid. Rigged down Riser and placed same on rig floor for move. Made Up Production tree to Bonnet, lowered and made Up Production Tree to Wellhead. 6/19/13 Finished M/U Tree to Wellhead. Fill Void and Tested to 5000 psi for 15 mins. Tested Continuity on ESP cable. Assisted Production with tree spools. Bolted up blind flange on Tree in order to test tree to 5000 psi. Rebuilt test pump and tested Tree to 5,000 psi for 10 mins. Bolted up blind flange on Tree in order to test tree to 5000 psi. Rebuilt test pump and tested Tree to 5,000 psi for 10 mins. Pulled two-way check valve and removed blind flange. Installed Actuator valve on tree 7/18/2013 Redoubt Unit#2A, API# 50-733-20501-01 Geologic Markers CONFIDENTIAL Name Measured Depth ND Upper Hemlock 14,510' 11,772' Middle Hemlock 14,792' 11,999' Lower Hemlock 15,028' 12,194' 7/18/2013 Redoubt Unit#2A, API#50-733-20501-01 Oil and Gas Shows CONFIDENTIAL Name Measured Depth TVD Hemlock 14,518'-15,160' 11,779'-12,302' Oil Shows HALLIBURTON INSITE DIRECTIONAL SURVEY REPORT Cook Inlet Energy Redoubt Unit#2A Redoubt Unit Shoal Undefined Kenai Peninsula Borough Alaska USA AK-XX-0009794632 SURVEYS TO 8456.53'MD ARE FROM PARENT WELL INTERPOLATED AZIMUTHS FROM 8522.00'TO 8829.18'MD MWD SURVEYS ARE SAG CORECTED. FINAL SURVEY IS PROJECTED TO TD. Measured Vertical Vertical Depth Inclination Direction Depth Latitude Departure Section Dogleg (feet) (degrees) (degrees) (feet) (feet) (feet) (feet) (deg/100ft) 129.10 0.00 0.00 129.10 0.00 N 0.00 E 0.00 TIE-IN 171.10 0.10 228.54 171.10 0.02 S 0.03 W -0.01 0.24 201.10 0.10 168.54 201.10 0.07 S 0.04 W 0.00 0.33 230.10 0.50 254.54 230.10 0.13 S 0.16 W -0.07 1.73 260.10 0.90 260.54 260.10 0.20 S 0.52 W -0.33 1.35 290.10 0.80 268.54 290.09 0.24 S 0.96 W -0.68 0.52 349.10 1.25 318.54 349.09 0.23 N 1.80 W -1.64 1.62 412.10 1.60 334.54 412.07 1.54 N 2.63 W -3.04 0.84 499.10 1.90 87.54 499.04 2.70 N 1.71 W -2.88 3.36 529.10 2.00 94.54 529.03 268 N, 0.69 W -2.01 0.86 559.10 2.20 110.54 559.01 2.43 N 0.37E -0.98 2.06 588.10 3.00 112.54 587.98 1.95 N 1.59 E 0.31 2.78 650.10 2.10 138.54 649.92 0.47 N 3.84 E 3.00 2.33 739.10 1.50 175.54 738.88 1.91 S 5.01 E 5.26 1.43 800.10 2.10 207.54 799.85 3.70 S 4.56 E 5.83 1.88 889.10 3.40 194.54 888.74 7.70 S 3.14 E 6.75 1.61 979.10 5.00 178.54 978.50 14.20 S 2.57E 9.73 219 1069.10 6.20 156.54 1068.08 22.58 S 4.60 E 15.91 2.71 1167.10 9.00 143.54 1165.22 33.61 S 11.27E 27.42 3.34 1258.10 11.50 136.54 1254.76 45.92 S 21.74E 42.83 3.06 1354.10 14.00 130.54 1348.39 60.42 S 37.15 E 63.60 2.94 1472.64 17.34 132.11 1462.51 81.59 S 61.16E 95.19 2.84 1571.36 20.22 130.55 1555.96 102.55 S 85.04 E 126.56 2.96 1665.75 22.30 124.89 1643.93 123.40 S 112.12E 160.59 3.09 1761.37 24.59 122.18 1731.66 144.38 S 143.85 E 198.61 2.65 1857.89 27.10 123.45 1818.52 167.20 S 179.19 E 240.68 2.66 1953.97 30.02 120.80 1902.90 191.58 S 218.11 E 286.60 3.31 2048.42 33.35 118.57 1983.26 216.10 S 261.21 E 336.15 3.74 2145.90 35.82 118.21 2063.51 242.41 S 309.89 E 391.36 2.54 2239.64 35.23 118.92 2139.80 268.45 S 357.73E 445.72 0.77 2333.14 35.24 121.44 2216.18 295.57 S 404.35E 499.62 1.55 2429.53 36.82 122.90 2294.13 325.77 S 452.33 E 556.31 1.87 2522.97 38.42 122.76 2368.14 356.69 S 500.25 E 613.34 1.71 2621.19 37.24 122.60 2445.71 389.22 S 550.95 E 673.58 1.21 2717.05 37.57 123.02 2521.86 420.77 S 599.89 E 731.80 0.44 2814.51 38.94 122.89 2598.39 453.60 S 650.52 E 792.14 1.41 2910.09 39.48 122.76 2672.45 486.36 S 701.30 E 852.56 0.57 3001.94 38.61 122.70 2743.78 517.64 S 749.97 E 910.41 0.95 3098.10 37.31 122.30 2819.60 549.43 S 799.85 E 969.56 1.38 3195.10 35.31 121.89 2897.76 579.95 S 848.50 E 1027.00 2.08 3289.49 35.34 122.62 2974.77 609.08 S 894.65 E 1081.57 0.45 3383.51 36.58 123.34 3050.87 639.14 S 940.96 E 1136.78 1.39 3480.70 37.98 123.54 3128.20 671.58 S 990.08 E 1195.63 1.45 3575.85 36.14 124.41 3204.13 703.62 S 1037.63 E 1252.94 2.01 3670.19 36.89 123.80 3279.95 735.10 S 1084.11 E 1309.04 0.88 Page 1 of 4 HALLIBURTON Redoubt Unit#2A MeasureVertical Vertical Depth Inclination Direction Depth Latitude Departure Section Dogleg t) (degrees) (degrees) (feet) (feet) (feet) (feet) (deg/1008) 3766.15 38.17 122.82 3356.05 767.19 S 1132.97 E 1367.48 1.47 3863.88 38.84 122.94 3432.53 800.23 S 1184.06 E 1428.32 0.69 3958.10 39.38 123.47 3505.64 832.78 S 1233.79 E 1487.74 0.67 4057.26 39.80 123.58 3582.05 867.68 S 1286.47 E 1550.92 0.43 • 4150.20 39.66 124.13 3653.53 900.78 S 1335.80 E 1610.30 0.41 4244.90 39.57 123.65 3726.48 934.45 S 1385.92 E 1670.65 0.34 4341.40 39.25 123.71 3801.04 968.43 S 1436.90 E 1731.89 0.33 4435.43 39.07 123.24 3873.95 1001.18 S 1486.43 E 1791.25 0.37 4531.68 39.10 123.58 3948.66 1034.60 S 1537.08 E 1851.92 0.22 4628.87 38.60 123.63 4024.35 1068.35 S 1587.86 E 1912.87 0.52 4726.07 38.42 123.60 4100.41 1101.85 S 1638.26 E 1973.37 0.19 4819.04 38.13 123.76 4173.39 1133.79 S 1686.18 E 2030.94 0.33 4916.63 37.73 123.13 4250.37 1166.86 S 1736.23 E 2090.91 0.57 5011.58 37.52 123.28 4325.57 1198.60 S 1784.73 E 2148.86 0.24 5107.63 37.52 123.13 4401.75 1230.64 S 1833.67E 2207.35 0.10 5203.38 37.24 123.37 4477.84 1262.52 S 1882.28 E 2265.47 0.33 5297.72 37.37 123.38 4552.88 1293.97 S 1930.03 E 2322.63 0.14 5392.39 37.41 122.86 4628.10 1325.38 S 1978.17 E 2380.11 0.34 5489.11 37.11 123.22 4705.08 1357.31 S 2027.26 E 2438.66 0.38 5585.50 37.04 123.58 4781.98 1389.30 S 2075.77 E 2496.76 0.24 5680.41 36.91 123.60 4857.80 1420.89 5 2123.32 E 2553.82 0.14 5773.95 37.32 123.18 4932.40 1451.95 S 2170.45 E 2610.25 0.52 5870.60 37.55 123.56 5009.14 1484.27 S 2219.51 E 2668.99 0.34 5965.90 37.48 123.42 5084.73 1516.30 S 2267.91 E 2727.01 0.12 6034.81 37.76 123.36 5139.31 1539.45 S 2303.03 E 2769.06 0.41 6131.00 37.85 123.19 5215.31 1571.80 S 2352.32 E 2828.01 0.14 6227.55 37.79 123.18 5291.58 1604.21 5 2401.87 E 2887.21 0.06 6323.34 37.22 123.66 5367.57 1636.33 S 2450.54 E 2945.51 0.67 6418.79 37.04 123.96 5443.67 1668.39 S 2498.42 E 3003.10 0.27 6512.84 36.78 124.09 5518.87 1700.00 S 2545.23 E 3059.55 0.29 6610.84 36.28 124.12 5597.62 1732.71 S 2593.53 E 3117.85 0.51 6706.32 36.12 124.04 5674.67 1764.31 S 2640.23 E 3174.21 0.17 6801.33 35.82 124.23 5751.56 1795.63 S 2686.42 E 3229.98 0.34 6895.22 35.53 124.72 5827.83 1826.62 S 2731.56 E 3284.69 0.43 114 6992.09 35.86 124.09 5906.50 1858.56 S 2778.19 E 3341.17 0.51 7087.03 36.09 124.14 5983.34 1889.84 S 2824.36 E 3396.91 0.24 7185.62 36.33 123.41 6062.88 1922.22 S 2872.77 E 3455.12 0.50 7279.22 35.71 124.50 6138.59 1952.96 S 2918.43 E 3510.14 0.95 7376.09 35.53 124.35 6217.33 1984.86 S 2964.96 E 3566.51 0.21 7473.50 36.50 123.86 6296.13 2016.97 S 3012.39 E 3623.75 1.04 imi Pr 7565.19 36.48 123.94 6369.84 2047.39 S 3057.64 E 3678.25 0.06 7662.07 36.17 124.19 6447.89 2079.54 S 3105.18 E 3735.61 0.35 7756.89 35.88 124.18 6524.58 2110.87 S 3151.31 E 3791.34 0.31 7851.23 35.70 123.87 6601.11 2141.75 S 3197.04 E 3846.48 0.27 7949.59 35.32 123.43 6681.17 2173.41 S 3244.59 E 3903.59 0.47 8001.50 36.56 123.26 6723.20 2190.16 S 3270.04 E 3934.05 2.40 8043.45 37.18 122.62 6756.76 2203.84 S 3291.17 E 3959.22 1.74 8084.92 37.22 122.44 6789.79 2217.33 S 3312.30 E 3984.29 0.28 8135.86 37.52 121.76 6830.27 2233.76 S 3338.50 E 4015.21 1.00 8186.35 37.32 123.18 6870.38 2250.23 S 3364.38 E 4045.89 1.75 8233.78 37.26 122.78 6908.11 2265.87 S 3388.48 E 4074.62 0.53 8279.15 37.26 122.16 6944.22 2280.62 S 3411.66 E 4102.09 0.83 8327.80 36.50 122.97 6983.13 2296.33 S 3436.26 E 4131.28 1.85 8411.60 36.01 121.62 7050.71 2322.81 S 3478.15 E 4180.84 1.12 8456.53 35.82 121.83 7087.10 2336.67 S 3500.56 E 4207.19 0.50 Date PtIntect20 May 2013 Page 2 of 4 HALLIBURTON Redoubt Unit#2A MIIIIIIr � ,. �� . Veru Measured Depth Inclination Direction Depth Latitude Departure Section Dogleg (feet) (degrees) (degrees) (feet) (feet) (feet) (feet) (deg/100ft) 8522.00 35.37 122.15 7140.34 2356.86 S 3532.88 E 4245.30 0.74 8588.10 38.00 122.47 7193.34 2377.97 S 3566.25 E 4284.78 3.99 8639.05 37.61 12270 7233.59 2394.79 S 3592.57 E 4316.02 0.82 8734.65 39.44 123.14 7308.38 2427.15 S 3642.55 E 4375.55 1.94 8829.81 40.08 123.55 7381.53 2460.61 S 3693.39 E 4436.40 0.73 8925.18 39.28 123.96 7454.93 2494.44 S 3744.02 E 4497.27 0.88 9019.36 40.61 126.19 7527.14 2529.20 S 3793.49 E 4557.65 2.07 9112.63 41.22 121.15 7597.64 2563.03 S 3844.30 E 4618.67 3.60 9204.52 40.97 121.01 7666.89 2594.21 S 3896.03 E 4679.06 0.29 9300.02 40.57 119.90 7739.22 2625.82 S 3949.79 E 4741.39 0.87 9394.49 40.11 120.58 7811.22 2656.61 S 4002.62 E 4802.51 0.67 9488.86 39.48 120.20 7883.73 2687.17 S 4054.72E 4862.88 0.72 9583.51 38.58 120.59 7957.26 2717.33 S 4106.13 E 4922.46 0.99 9679.22 38.89 120.37 8031.91 2747.70 S 4157.74 E 4982.32 0.35 9771.83 38.96 120.24 8103.96 2777.06 S 4207.98 E 5040.48 0.12 9866.49 38.79 119.88 8177.66 2806.82 S 4259.40E 5099.85 0.30 9961.11 38.98 118.87 8251.31 2835.96 S 4311.16 E 5159.18 0.70 10054.94 38.62 118.49 8324.44 2864.17 S 4362.74 E 5217.86 0.46 10147.60 39.12 117.04 8396.58 2891.26 S 4414.19 E 5275.84 1.12 10241.54 38.17 119.15 8469.95 2918.87 S 4465.94 E 5334.35 1.73 10336.77 39.28 118.87 8544.25 2947.76 S 4518.04 E 5393.83 1.18 10429.31 40.22 118.80 8615.39 2976.30 S 4569.88 E 5452.91 1.02 10523.72 39.81 119.45 8687.70 3005.84 S 4622.91E 5513.53 0.62 10617.87 39.37 118.49 8760.25 3034.91 S 4675.40 E 5573.44 0.80 10713.75 38.90 119.01 8834.62 3064.01 S 4728.45 E 5633.84 0.60 10807.11 40.05 119.88 8906.69 3093.19 S 4780.14 E 5693.13 1.37 10901.39 40.13 120.31 8978.82 3123.64 S 4832.67E 5753.81 0.31 10997.99 40.80 119.55 9052.31 3154.91 S 4887.00 E 5816.45 0.86 11090.35 40.20 119.92 9122.54 3184.66 S 4939.08 E 5876.38 0.70 11183.32 40.50 120.09 9193.39 3214.76 S 4991.21 E 5936.53 0.34 11276.83 39.91 119.65 9264.81 3244.83 S 5043.55 E 5996.85 0.70 11373.42 39.85 119.36 9338.93 3275.33 S 5097.45 E 6058.71 0.20 11466.03 39.23 119.49 9410.35 3304.29 S 5148.80E 6117.60 0.68 11561.75 39.89 118.61 9484.15 3333.89 S 5202.10 E 6178.48 0.90 11654.72 39.92 118.73 9555.47 3362.51 S 5254.43 E 6238.01 0.09 11750.11 39.72 118.57 9628.73 3391.79 S 5308.03 E 6298.98 0.24 11844.34 39.36 118.25 9701.40 3420.34 S 5360.80 E 6358.84 0.44 11939.43 38.36 119.47 9775.44 3449.12 S 5413.05 E 6418.40 1.32 12032.11 38.43 118.92 9848.08 347720 S 5463.30 E 6475.89 0.38 12123.50 38.00 118.44 9919.89 3504.33 S 5512.89 E 6532.32 0.57 12219.64 37.79 118.62 9995.75 3532.54 S 5564.77 E 6591.25 0.25 12313.56 38.24 117.84 10069.75 3559.90 S 5615.74 E 6648.96 0.70 12409.73 38.58 118.23 10145.11 3587.98 S 5668.47E 6708.55 0.43 12502.72 38.62 117.46 10217.78 3615.08 S 5719.77E 6766.40 0.52 12598.05 38.77 118.16 10292.18 3642.88 S 5772.48 E 6825.83 0.49 12693.04 38.88 118.19 10366.19 3671.00 S 5824.98 E 6885.24 0.12 12787.90 38.79 117.24 10440.08 3698.66 S 5877.64 E 6944.55 0.64 12823.49 38.75 118.46 10467.83 3709.08 S 5897.34 E 6966.77 2.15 12879.71 38.55 119.72 10511.74 3726.15 S 5928.03E 7001.83 1.44 12923.49 38.91 119.80 10545.89 3739.74 S 5951.80 E 7029.20 0.83 13017.51 37.95 119.60 10619.54 3768.70 S 6002.57 E 7087.58 1.03 13112.48 36.63 118.28 10695.10 3796.54 S 6052.91 E 7145.03 1.63 13208.30 38.03 120.30 10771.29 3824.98 S 6103.57 E 7203.06 1.94 13303.12 38.33 120.91 10845.83 3854.82 S 6154.02 E 7261.65 0.51 13397.04 39.33 121.33 10918.99 3885.26 S 6204.43E 7320.52 1.10 Date Printed30 May2013 Page 3 of 4 • HALLIBURTON Redoubt Unit#2A Measured Vertical Vertical Depth Inclination Direction Depth Latitude Departure Section Dogleg (fes (degrees) (degrees) (feet) (feet) (feet) (feet) (deg/100ft) 13493.39 39.29 121.92 10993.54 3917.27 S 6256.40 E 7381.56 0.39 13587.50 39.36 122.00 11066.34 3948.83 S 6307.00 E 7441.20 0.09 13682.96 40.53 122,91 11139.52 3981.73 S 6358.71 E 7502.49 1.37 13776.91 40.40 123.45 11211.00 4015.10 S 6409.75 E 7563.45 0.40 13872.69 41.04 123.71 11283.59 4049.66 S 6461.80 E 7625.91 0.69 13965.19 40.77 123.13 11353.50 4083.02 S 6512.35 E 7686.46 0.50 14062.33 41.11 122.40 11426.88 4117.46 S 6565.88E 7750.11 0.60 14156.57 40.43 122.59 11498.25 4150.52 S 6617.79E 7811.65 0.73 14251.18 40.03 121.70 11570.49 4183.04 S 6669.52 E 7872.75 0.74 14345.87 39.16 120.22 11643.45 4214.09 S 6721.27 E 7933.09 1.36 14439.25 38.58 118.92 11716.16 4243.01 S 6772.23 E 7991.63 1.07 14533.59 37.60 117.42 11790.41 4270.49 S 6823.53 E 8049.68 1.43 14627.15 36.51 115.17 11865.07 4295.47 S 6874.06 E 8105.76 1.86 14725.71 35.57 111.34 11944.78 4318.38 S 6927.30 E 8163.03 2.48 14819.24 34.85 106.27 12021.21 4335.77 S 6978.30 E 8215.47 3.22 14915.65 34.19 97.25 12100.70 4346.91 S 7031.65 E 8266.57 5.34 15009.86 34.28 90.93 12178.61 4350.68 S 7084.46 E 8313.29 3.77 15103.93 35.13 84.15 12255.98 4348.35 S 7137.89 E 8357.29 4.20 15198.47 37.09 78.43 12332.37 4339.86 S 7192.90 E 8399.35 4.12 15292.46 37.62 74.35 12407.10 4326.43 S 7248.30 E 8439.12 2.69 15318.76 37.43 73.84 12427.95 4322.04 S 7263.70 E 8449.83 1.38 15360.00 37.43 73.84 12460.70 4315.07 S 7287.78E 8466.50 0.00 CALCULATION BASED ON MINIMUM CURVATURE METHOD SURVEY COORDINATES RELATIVE TO WELL SYSTEM REFERENCE POINT TVD VALUES GIVEN RELATIVE TO DRILLING MEASUREMENT POINT VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION IS COMPUTED ALONG A DIRECTION OF 122.14 DEGREES(TRUE) A TOTAL CORRECTION OF 17.15 DEG FROM MAGNETIC NORTH TO TRUE NORTH HAS BEEN APPLIED HORIZONTAL DISPLACEMENT IS RELATIVE TO THE WELL HEAD. HORIZONTAL DISPLACEMENT(CLOSURE)AT 15360.00 FEET IS 8469.45 FEET ALONG 120.63 DEGREES(TRUE) SURVEYS TO 8456.53'MD ARE FROM PARENT WELL INTERPOLATED AZIMUTHS FROM 8522.00'TO 8829.18'MD MWD SURVEYS ARE SAG CORECTED. 4 FINAL SURVEY IS PROJECTED TO TD. ALL ,aiii.Date Printed 30 May 2013 Page 4 of 4 Cook Inlet Energy_ tottompop 't� t Cook Inlet Energy RU-2A REDOUBT SHOALS Section 14 — T7N - R14W, SM Upper Cook Inlet, Alaska FINAL WELL REPORT Lees F. Browne Jr. — Senior Geological Adviser Steve Pike — Senior Logging Geologist Britton Adams — Logging Geologist cANRIG DRILLING TECHNOLOGY LTD. I Cook Inlet Energy- I �i Contents'. • ` Daily Reports � '', ; DML Data �`,ti Final\Netl RePp1 \;3.. LAS Files -. • <, Log PDF Files l t o9 TIFF Fi. 3 may is i. :u., --4.•� ,a • i _ • ..,•iL n • '''. -1ir ' j • final Vie ,l I f . !.!„.!-. c0040 • I - 1 - ruga_cd_finalwellrpt_mudlogs.txt Volume in drive E is CIE - RU-2A volume Serial Number is 9481-F59C Directory of E:\ 07/18/2013 03:08 PM <DIR> DAILY REPORTS 07/18/2013 03:08 PM <DIR> DML DATA 07/18/2013 03:08 PM <DIR> FINAL WELL REPORT 07/18/2013 03:08 PM <DIR> LAS FILE 07/18/2013 03:08 PM <DIR> LOG PDF FILES 07/18/2013 03:08 PM <DIR> TIFF FILES 0 File(s) 0 bytes Directory of E:\DAILY REPORTS 07/18/2013 03:08 PM <DIR> . 07/18/2013 03:08 PM <DIR> . . 04/23/2013 11:09 AM 25,322 Cook Inlet 42313.pdf 04/24/2013 02:52 AM 27,392 Cook Inlet 42413.pdf 04/25/2013 01: 50 AM 26,371 Cook Inlet 42513.pdf 04/26/2013 01:08 AM 27,197 Cook Inlet 42613.pdf 04/27/2013 01:27 AM 26,870 Cook Inlet 42713.pdf 04/28/2013 01:10 AM 26,752 Cook Inlet 42813.pdf 04/29/2013 12:26 AM 28,189 Cook Inlet 42913.pdf 04/29/2013 11:17 PM 26,485 Cook Inlet 43013.pdf 04/30/2013 11:20 PM 26,454 Cook Inlet 50113.pdf 05/02/2013 12:00 AM 26,803 Cook Inlet 50213.pdf 05/03/2013 01:10 AM 27,572 Cook Inlet 50313.pdf 05/04/2013 01:14 AM 28,692 Cook Inlet 50413.pdf 05/05/2013 01:22 AM 27,449 Cook Inlet 50513.pdf 05/06/2013 01:17 PM 27,319 Cook Inlet 50613.pdf 05/07/2013 12: 50 PM 28,364 Cook Inlet 50713.pdf 05/08/2013 01:45 PM 26,273 Cook Inlet 50813.pdf 05/09/2013 02:41 PM 26,861 Cook Inlet 50913.pdf 05/10/2013 01:06 PM 26,498 Cook Inlet 51013.pdf 05/11/2013 02:07 PM 27,306 Cook Inlet 51113.pdf 05/12/2013 12: 56 AM 26,676 Cook Inlet 51213.pdf 05/13/2013 02:30 AM 27,519 Cook Inlet 51313.pdf 05/15/2013 02:27 AM 27,721 Cook Inlet 51413.pdf 05/16/2013 02:34 AM 27,370 Cook Inlet 51513.pdf 05/17/2013 02:21 AM 27,277 Cook Inlet 51613.pdf 05/18/2013 01:41 AM 27,740 Cook Inlet 51713.pdf 05/19/2013 01:40 AM 27,262 Cook Inlet 51813.pdf 05/20/2013 01:40 AM 26,790 Cook Inlet 51913.pdf 05/21/2013 01:49 AM 26, 529 Cook Inlet 52013.pdf 05/22/2013 01:42 AM 27,032 Cook Inlet 52113.pdf 05/23/2013 01:14 AM 27,583 Cook Inlet 52213.pdf 05/24/2013 01: 59 AM 27,256 Cook Inlet 52313.pdf 05/25/2013 02:03 AM 27,678 Cook Inlet 52413.pdf 05/26/2013 01:49 AM 27,716 Cook Inlet 52513.pdf 05/27/2013 02:03 AM 28,170 Cook Inlet 52613.pdf 05/28/2013 01:39 AM 27,948 Cook Inlet 52713.pdf 05/29/2013 01:59 AM 28,386 Cook Inlet 52813.pdf 05/31/2013 02:11 AM 28,239 Cook Inlet 52913.pdf 05/31/2013 02:02 AM 26,870 Cook Inlet 53013.pdf 05/17/2013 02:12 AM 26,815 Cook Inlet51613.pdf 06/11/2013 09:11 AM 936,966 Osprey Morn Rpts.zip 40 File(s) 1,999,712 bytes Directory of E:\DML DATA 07/18/2013 03:08 PM <DIR> . 07/18/2013 03:08 PM <DIR> . . Page 1 ruga_cd_finalwellrpt_mudlogs.txt 07/18/2013 01:35 PM 25,045,947 RU-2A.dbf 07/18/2013 01:35 PM 118,784 RU-2A.mdx 06/13/2013 05:40 PM 1,312 RU-2A_SCL.DBF 06/13/2013 05:40 PM 6,144 RU-2A_SCL.MDX 05/30/2013 01:58 AM 447,698 RU-2A_tvd.dbf 05/30/2013 01: 58 AM 94,208 RU-2A_tvd.mdx 07/18/2013 02:40 PM 433 ru-2a.hdr 06/13/2013 05:40 PM 63,082 ru-2ar.dbf 06/13/2013 05:40 PM 36,864 ru-2ar.mdx 9 File(s) 25,814,472 bytes Directory of E:\FINAL WELL REPORT 07/18/2013 03:08 PM <DIR> 07/18/2013 03:08 PM <DIR> 07/18/2013 02:11 PM 658,276 Cook Inlet Energy RU-2A Final well Report.pdf 1 File(s) 658,276 bytes Directory of E:\LAS FILE 07/18/2013 03:08 PM <DIR> 07/18/2013 03:08 PM <DIR> 07/18/2013 11:11 AM 4,276,053 RU-2A.las 1 File(s) 4,276,053 bytes Directory of E:\LOG PDF FILES 07/18/2013 03:08 PM <DIR> 07/18/2013 03:08 PM <DIR> . . 07/18/2013 11:15 AM 3,901,268 RU-2A DRILLING DYNAMICS MD.pdf 07/18/2013 11:16 AM 3,026, 508 RU-2A DRILLING DYNAMICS TVD.pdf 07/18/2013 01:31 PM 3,378,805 RU-2A FORMATION LOG MD.pdf 07/18/2013 01: 50 PM 2,641,194 RU-2A FORMATION LOG TVD.pdf 07/18/2013 11:22 AM 4, 506,867 RU-2A GAS RATIO LOG MD.pdf 07/18/2013 11:18 AM 3,484,650 RU-2A GAS RATIO LOG TVD.pdf 07/18/2013 01:26 PM 3,389,215 RU-2A LWD COMBO LOG MD.pdf 07/18/2013 01:25 PM 2,715,110 RU-2A LWD COMBO LOG TVD.pdf 8 File(s) 27,043,617 bytes Directory of E:\TIFF FILES 07/18/2013 03:08 PM <DIR> 07/18/2013 03:08 PM <DIR> . . 07/18/2013 02:36 PM 77,732,368 RU-2A_DRILLING DYNAMICS MD.tif 07/18/2013 02:36 PM 60, 557,451 RU-2A_DRILLING DYNAMICS TVD.tif 07/18/2013 02:36 PM 80,466,938 RU-2A_FORMATION LOG MD.tif 07/18/2013 02:36 PM 56,135,707 RU-2A_FORMATION LOG TVD.tif 07/18/2013 02:36 PM 83,030,988 RU-2A_GAS RATIO LOG MD.tif 07/18/2013 02:36 PM 65,094,601 RU-2A_GAS RATIO LOG TVD.tif 07/18/2013 02:36 PM 88,197,449 RU-2A_LWD COMBO LOG MD.tif 07/18/2013 02:36 PM 59,877,286 RU-2A_LWD COMBO LOG TVD.tif 8 File(s) 571,092,788 bytes Total Files Listed: 67 File(s) 630,884,918 bytes 18 Dir(s) 0 bytes free Page 2 r U) a b b b b 0 \ 2 C U) L U) 0 / • \ 6 m 2 ,- ,- C Ch IT'D 0 / b m b b in E / k A A CO 8 (0 CO C t = n ai L L6 o m2 \ w a w a / G G G G > e J = ,- r .- e- § k .t- 2 3 S _ / o2 re) 0 § in $ 2 k \ u. 8 0 a « ® E ^ ® /a 044. § § CL C § as 4t § % 7 § co 2f $ 2 m 0 \ k k M ® o . Q 2 I% o \ // - 7 = c S _1 > f ¥ 2 § $ / 2To § { CL 2 -0 k E 2 o # E / E 0Lu I ca „ 7 \ 0 E £ _ \ P c 0 . . § \ 2 E \ \ / , � � § o 4 ° t i § m -I • . \ o co k / 0 \ E 0 0 0 % o o o < . 1 . , C C C C � w < < \ \ Et ce ce c c a o cc ce ce n n_ & r n n n n n n k \ d k d . d d d m N- _ n n n n . N § COi § CO§ § .- CO k cc '0k k 0 t k k \ kka k k kk To To 0m f f _ .,:::,,,,,:,,fiamal"4"5-*:-.f'i:::;:::::::'..".:- - /7 11ii 4 I 1 3 ''' tt - WELL LOG TRANSMITTAL To: State of Alaska June 17, 2013 Alaska Oil and Gas Conservation Commission Attn.: Makana Bender 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501-3539 RE: LWD Formation Evaluation Logs: RU-02A AK-MW-0009794632 RU-02A 50-733-20501-01-00 1", 2",&5" MD Triple Combo Logs: 1 Color Log each scale 1",2",&5"TVD Triple Combo Logs: 1 Color Log each scale Digital Log Images, LAS Data, & LIS Data w/verification listing 1 CD ROM PLEASE ACKNOWLEDGE RECEIPT BY RETURNING A SIGNED AND DATED COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Buster Bryant/Ben Schulze 6900 Arctic Blvd. Anchorage,Alaska 99518 Office: 907-273-3539/907-273-3536 Fax: 907-273-3535 Buster.Bryant@halliburton.com Benjamin.Schulze@halliburton.com Date: Signed: ru2a_cdl_data_aogcc.txt volume in drive E is CIE_RU2A_Data volume Serial Number is 548D-6905 Directory of E:\ 07/19/2013 10:49 AM <DIR> CD1_DATA 0 File(s) 260 bytes Directory of E:\CD1_DATA 07/19/2013 10:49 AM <DIR> . 07/19/2013 11:01 AM <DIR> . . 07/18/2013 05:19 PM <DIR> DIRECTIONAL 07/19/2013 10:52 AM <DIR> LOGS_RU2 07/18/2013 05:48 PM <DIR> LOGS_RU2A 07/18/2013 05:43 PM 361,853 RU2A_LogTransmittal_toAOGCC.pdf 1 File(s) 363,657 bytes Directory of E:\CD1_DATA\DIRECTIONAL 07/18/2013 05:19 PM <DIR> . 07/19/2013 10:49 AM <DIR> . . 07/18/2013 05:15 PM 13,743 RU-02A MWD Survey.las 07/18/2013 05:16 PM 293,767 RU-02A MWD Survey.pdf 07/16/2013 11:41 AM 12,667 RU2A_dirsurvey.prn 3 File(s) 320,657 bytes Directory of E:\CD1_DATA\LOGS_RU2 07/19/2013 10: 52 AM <DIR> . 07/19/2013 10:49 AM <DIR> . . 07/18/2013 04:20 PM 597,112,458 RU-2 ACE_11APR13.dlis 07/18/2013 03: 54 PM 4,334,739 RU-2 ACE_11APR13.las 07/15/2013 09:37 AM 27,995,623 RU-2 ACE_11APR13.pdf 07/15/2013 09:32 AM 65,198,034 RU-2 ACE_11APR13_img.tiff 07/18/2013 04:23 PM 697,115,300 RU-2_CASE_11APR13.dlis 07/18/2013 03: 53 PM 3,958,960 RU-2_CASE_11APR13.las 07/15/2013 09:35 AM 8,375,789 RU-2_CASE_11APR13.pdf 07/15/2013 09:31 AM 22, 590,236 RU-2_CASE_11APR13_img.tiff 07/18/2013 04:42 PM 50,116, 562 RU-2_CAST_11APR13.pdf 07/18/2013 04:36 PM 151,479,714 RU-2_CAST_11APR13_img.tiff 07/18/2013 03: 52 PM 1, 578,415 RU-2_CAST_CBL_11APR13_GR_CCL.LAS 07/18/2013 03: 52 PM 45,257,004 RU-2_CAST_CBL_11APR13_MAIN.LAS 07/18/2013 03: 51 PM 1,299,447 RU-2_CAST_CBL_11APR13_REPEAT.LAS 07/18/2013 04:44 PM 13,398,074 RU-2_CBL_11APR13.pdf 07/18/2013 04:19 PM 41,245, 532 RU-2_CBL_11APR13_img.tiff 15 File(s) 1,731,057,199 bytes Directory of E:\CD1_DATA\LOGS_RU2A 07/18/2013 05:48 PM <DIR> . 07/19/2013 10:49 AM <DIR> . . 07/18/2013 05:49 PM <DIR> CASTMLOgs 07/18/2013 05:47 PM <DIR> TCPLog 0 File(s) 880 bytes Directory of E:\CD1_DATA\LOGS_RU2A\CASTMLogs 07/18/2013 05:49 PM <DIR> . 07/18/2013 05:48 PM <DIR> . . 07/18/2013 05:49 PM <DIR> Analysis 07/18/2013 05:49 PM <DIR> FIELD PRINTS 07/18/2013 05:49 PM <DIR> LAS Page 1 ru2a_cdl_data_aogcc.txt 0 File(s) 1,332 bytes Directory of E:\CD1_DATA\LOGS_RU2A\CASTMLogs\Analysis 07/18/2013 05:49 PM <DIR> 07/18/2013 05:49 PM <DIR> . . 06/11/2013 10:03 AM 4,199,989 RU-2AJ\CE_10JUN13.las 06/11/2013 10:06 AM 7,586,769 RU-2A_ACE_10JUN13.pdf 06/11/2013 10:09 AM 7,399,100 RU-2A ACE_10JUN13_img.tiff 06/11/2013 10:10 AM 5,138,630 RU-2A_CASE_10JUN13.1as 06/11/2013 10:11 AM 2,974,686 RU-2A_CASE_10JUN13.pdf 06/11/2013 10:12 AM 2,908, 506 RU-2A_CASE_10JUN13_img.tiff 6 File(s) 30,208,336 bytes Directory of E:\CD1_DATA\LOGS_RU2A\CASTMLogs\FIELD PRINTS 07/18/2013 05:49 PM <DIR> 07/18/2013 05:49 PM <DIR> 06/11/2013 10:00 AM 5,838,944 RU-2A_CAST-M_CBL_10JUN13.pdf 06/11/2013 10:23 AM 73,175,610 RU-2A_CAST-M_CBL_10JUN13_img.tiff 2 File(s) 79,014,966 bytes Directory of E:\CD1_DATA\LOGS_RU2A\CASTMLogs\LAS 07/18/2013 05:49 PM <DIR> 07/18/2013 05:49 PM <DIR> 06/11/2013 01:47 PM 3,058,992 RU-2A_CAST-M_CBL_10JUN13_FreePipe.LAS 06/11/2013 01:46 PM 31, 535,097 RU-2A_CAST-M_CBL_10JUN13_Main.LAS 06/11/2013 01:46 PM 4,797,021 RU-2A_CAST-M_CBL_10JUN13_Repeat.LAS 3 File(s) 39,391, 558 bytes Directory of E:\CD1_DATA\LOGS_RU2A\TCPLog 07/18/2013 05:47 PM <DIR> 07/18/2013 05:48 PM <DIR> . . 06/25/2013 10:31 AM 999,101 RU-2A_CORRELATION_12JUN13.LAS 06/25/2013 10:31 AM 831,180 RU-2A_CORRELATION_12JUN13.pdf 06/25/2013 10:31 AM 4,413,700 RU-2A_CORRELATION_12JUN13_img.tiff 3 File(s) 6,244,417 bytes Total Files Listed: 33 File(s) 1,886,603,262 bytes 27 Dir(s) 0 bytes free Page 2 ru2a_cdl_data_aogcc.txt Volume in drive E is CIE_RU2A_Data volume Serial Number is 548D-B905 Directory of E:\ 07/19/2013 10:49 AM <DIR> CD1_DATA 0 File(s) 260 bytes Directory of E:\CD1_DATA 07/19/2013 10:49 AM <DIR> . 07/19/2013 11:01 AM <DIR> . . 07/18/2013 05:19 PM <DIR> DIRECTIONAL 07/19/2013 10: 52 AM <DIR> LOGS_Ru2 07/18/2013 05:48 PM <DIR> LOGS_RU2A 07/18/2013 05:43 PM 361,853 RU2A_LogTransmittal_toA000C.pdf 1 File(s) 363,657 bytes Directory of E:\CD1_DATA\DIRECTIONAL 07/18/2013 05:19 PM <DIR> . 07/19/2013 10:49 AM <DIR> . . 07/18/2013 05:15 PM 13,743 RU-02A MWD Survey.las 07/18/2013 05:16 PM 293,767 RU-02A MWD Survey.pdf 07/16/2013 11:41 AM 12,667 RU2A_dirsurvey.prn 3 File(s) 320,657 bytes Directory of E:\CD1_DATA\LOGS_RU2 07/19/2013 10:52 AM <DIR> . 07/19/2013 10:49 AM <DIR> . . 07/18/2013 04:20 PM 597,112,458 RU-2 ACE_11APR13.dlis 07/18/2013 03: 54 PM 4,334,739 RU-2 ACE_11APR13.las 07/15/2013 09:37 AM 27,995,623 RU-2_ACE_11APR13.pdf 07/15/2013 09:32 AM 65,198,034 RU-2 ACE_11APR13_im .tiff 07/18/2013 04:23 PM 697,115,300 RU-2_CASE_11APR13.dlis 07/18/2013 03: 53 PM 3,958,960 RU-2_CASE_11APR13.las 07/15/2013 09:35 AM 8,375,789 RU-2_CASE_11APR13.pdf 07/15/2013 09:31 AM 22, 590,236 RU-2_CASE_11APR13_img.tiff 07/18/2013 04:42 PM 50,116, 562 RU-2_CAST_11APR13.pdf 07/18/2013 04:36 PM 151,479,714 RU-2_CAST_11APR13_img.tiff 07/18/2013 03:52 PM 1,578,415 RU-2_CAST_CBL_11APR13_GR_CCL.LAS 07/18/2013 03:52 PM 45,257,004 Ru-2_CAST_CBL_11APR13_MAIN.LAS 07/18/2013 03:51 PM 1,299,447 RU-2_CAST_CBL_11APR13_REPEAT.LAS 07/18/2013 04:44 PM 13,398,074 RU-2_CBL_11APR13.pdf 07/18/2013 04:19 PM 41,245,532 RU-2_CBL_11APR13_img.tiff 15 File(s) 1,731,057,199 bytes Directory of E:\CD1_DATA\LOGS_RU2A 07/18/2013 05:48 PM <DIR> . 07/19/2013 10:49 AM <DIR> . . 07/18/2013 05:49 PM <DIR> CASTMLOgs 07/18/2013 05:47 PM <DIR> TCPLOg 0 File(s) 880 bytes Directory of E:\CD1_DATA\LOGS_RU2A\CASTMLOg5 07/18/2013 05:49 PM <DIR> . 07/18/2013 05:48 PM <DIR> . . 07/18/2013 05:49 PM <DIR> Analysis 07/18/2013 05:49 PM <DIR> FIELD PRINTS 07/18/2013 05:49 PM <DIR> LAS Page 1 ru2a_cdl_data_aogcc.txt 0 File(s) 1,332 bytes Directory of E:\CD1_DATA\LOGS_RU2A\CASTMLogs\Analysis 07/18/2013 05:49 PM <DIR> 07/18/2013 05:49 PM <DIR> 06/11/2013 10:03 AM 4,199,989 RU-2A ACE_10JUN13.las 06/11/2013 10:06 AM 7, 586,769 RU-2A_ACE_10JUN13.pdf 06/11/2013 10:09 AM 7,399,100 RU-2A ACE_10JUN13_img.tiff 06/11/2013 10:10 AM 5,138,630 RU-2A_CASE_10JUN13.las 06/11/2013 10:11 AM 2,974,686 RU-2A_CASE_10JUN13.pdf 06/11/2013 10:12 AM 2,908,506 RU-2A_CASE_10JUN13_img.tiff 6 File(s) 30,208,336 bytes Directory of E:\CD1_DATA\LOGS_RU2A\CASTMLogs\FIELD PRINTS 07/18/2013 05:49 PM <DIR> 07/18/2013 05:49 PM <DIR> . . 06/11/2013 10:00 AM 5,838,944 RU-2A_CAST-M_CBL_10JUN13.pdf 06/11/2013 10:23 AM 73,175,610 RU-2A_CAST-M_CBL_10JUN13_img.tiff 2 File(s) 79,014,966 bytes Directory of E:\CD1_DATA\LOGS_RU2A\CASTMLogs\LAS 07/18/2013 05:49 PM <DIR> 07/18/2013 05:49 PM <DIR> 06/11/2013 01:47 PM 3,058,992 RU-2A_CAST-M_CBL_10JUN13_FreePipe.LAS 06/11/2013 01:46 PM 31, 535,097 RU-2A_CAST-M_CBL_10JUN13_Main.LAS 06/11/2013 01:46 PM 4,797,021 RU-2A_CAST-M_CBL_10JUN13_Repeat.LAS 3 File(s) 39,391, 558 bytes Directory of E:\CD1_DATA\LOGS_RU2A\TCPLog 07/18/2013 05:47 PM <DIR> 07/18/2013 05:48 PM <DIR> 06/25/2013 10:31 AM 999,101 RU-2A_CORRELATION_12JUN13.LAS 06/25/2013 10:31 AM 831,180 RU-2A_CORRELATION_12JUN13.pdf 06/25/2013 10:31 AM 4,413,700 RU-2A_CORRELATION_123UN13_img.tiff 3 File(s) 6,244,417 bytes Total Files Listed: 33 File(s) 1,886,603,262 bytes 27 Dir(s) 0 bytes free Page 2 CANRIG Company Cook Inlet Ener 3 Well • RU-2A Field Redout Shoals Coordinates 1918' FSL,320' FEL, SEC.14, T7N, R14W, SM. County, State Kenai,Alaska API Index 50-733-20501-00 Sample Set Set#1 RU-2A Box Number 1 of 6 Depths 8600' - 10100' ti CANRIG Com.any Cook Inlet Ener, Well RU-2A Field Redout Shoals Coordinates 1918' FSL,320' FEL, SEC.14, T7N, R14W, SM. Count , State Kenai,Alaska API Index 50-733-20501-00 Sample Set Set#1 RU-2A Box Number 2 of 6 Depths 10100' — 11600' CANRIG ,/ Company Cook Inlet Energy Well RU-2A Field Redout Shoals Coordinates 1918' FSL, 320' FEL, SEC.14, T7N, R14W, SM. II County, State Kenai,Alaska API Index 50-733-20501-00 II Sample Set Set#1 RU-2A II Box Number 3 of 6 Depths 11600' — 13100' III CANRIG Company Cook Inlet Energy Well RU-2A Field Redout Shoals Coordinates 1918' FSL,320' FEL, SEC.14,T7N, R14W, SM. County, State Kenai,Alaska API Index 50-733-20501-00 Sample Set Set#1 RU-2A Box Number 4 of 6 Depths 13100' — 14530' CANRIG Company Cook Inlet Energy Well RU-2A Field Redout Shoals Coordinates 1918' FSL,320' FEL, SEC.14,T7N,R14W, SM. County, State Kenai,Alaska API Index 50-733-20501-00 Sample Set Set#1 RU-2A Box Number 5 of 6 Depths 530 4:1130V-72_13100" 1 O30 0 Q CANRIG Company Cook Inlet Energy Well RU-2A Field Redout Shoals 11 Coordinates 1918' FSL,320' FEL, SEC.14,T7N, R14W, SM. County, State Kenai,Alaska API Index 50-733-20501-00 Sample Set Set#1 RU-2A Box Number 6 of 6 Depths I b D ' 14:1004-4,446-30' l;=, , r Y.T 1 RECEIVEE • Cook Inlet Energy, LLC JUL 1 9 2013 601 W. 5th Avenue, Suite 310 AOGCC Anchorage, Alaska 99501 1 )-1 Phone: (907) 334-6745 Fax: (907) 334-6735 d- DATA TRANSMITTAL Date: July 19, 2013 To: Howard Okland From: Barbara Kruk AOGCC Cook Inlet Energy, LLC 333 W. 7th Ave, Suite 100 601 W. 5th Avenue, Suite 310 Anchorage, AK 99501 Anchorage, AK 99501 Phone: (907)279-1433 Phone: (907)433-3802 FAX: (907) 334-6735 TRANSMITTAL DESCRIPTION ?3G Well Data for Redoubt Unit#2A, API#50-733-20501-01 In accordance with Alaska Regulations 20 AAC25.537(b),we request that confidentiality be extended to all of the following information. Item No. Qty Description 1 1 Well Completion report(AOGCC form 10-407),with attachments. 2 1 Copy of daily drilling reports or a summary report of daily drilling. (15 pages) 3 1 List of formations and other geologic markers encountered, and their depths MD and TVD 4 1 List of depth and formation name for oil and gas shows 5 1 Paper copy of directional survey(4 pages) 6 1 Paper copy of final mudlog and report enclosed in report 1 CD 1 File Listing for 1 CD enclosed in Canrig Well Report(2 pages) 7 1 Digital version of well logs in LAS format and digital version of directional surveys in ascii. 8 - Paper copy of all Logs run (8 paper copies)- No sepia provided pdf&tiff format files on DVD ** Paper Logs and Digital files delivered directly to AOGCC by Halliburton for RU-2A Bottom Log Top Log Log Date Run# Interval Interval Description 1 04/11/13 1 8,653' 6,500 + RU-2 CBL(Field Print) 1 04/11/13 1 8,667' 150V RU-2 CAST-M 1 04/13/13 1 8,654' 130' RU-2 Casing Inspection Log 0 4/13-5/30/13 1 15,360' 8,541'J RU-2A Triple Combo Log** 1 6/10-6/11/13 1 15,265' 12,55 4 RU-2A CAST-M/Cement Bond Log 1 06/11/13 1 15,260' 12,550'RU-2A CAST-M/Casing Inspection 1 06/11/13 1 15,260' 12,55 RU-2A CAST-M/Advanced Cement Evaluation 1 06/12/13 1 14,373' 14,000)RU-2A GR/CCL TCP Correlation Log 1 Copy of Transmittal from Halliburton to AOGCC for Log data submittal&located on DVD(1 page) Transmittals_CIE_AOGCC.xlsx/AOGCC 7 19 13 RU2A Cook Inlet Energy, LLC 601 W. 5th Avenue, Suite 310 Anchorage, Alaska 99501 Phone: (907) 334-6745 Fax: (907) 334-6735 DATA TRANSMITTAL Date: July 19, 2013 9 Dry Cuttings 1 Box 1 of 6-Dry Cuttings samples depth 8,600'- 10,100' Box 2 of 6-Dry Cuttings samples depth 10,100'- 11,600' 1 Box 3 of 6-Dry Cuttings samples depth 11,600'- 13,100' 1 Box 4 of 6-Dry Cuttings samples depth 13,100'- 14,530' 1 Box 5 of 6-Dry Cuttings samples depth 14,530'- 15,030' 1 Box 6 of 6-Dry Cuttings samples depth 15,030'- 15,360' 10 1 File Listing for DVD containing Items 7 and 8 above(4 pages) 11 1 Copy of Production Test Data( page) Please sign below to acknowl ere t. Received By: Date: Returned to Codk Inl nergy, LLC Date Accepted By: Transmittals CIE AOGCC.xlsx/AOGCC 7 19 13 RU2A Ii'YrsC ,� 1 2913 AO( CC WELL LOG TRANSMITTAL To: State of Alaska June 7, 2013 Alaska Oil and Gas Conservation Commission Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501-3539 RE: LWD Formation Evaluation Logs: RU-02A AK-MW-0009794632 RU-02A 50-733-20501-01-00 1", 2",&5" MD Triple Combo Logs: 1 Color Log each scale 1", 2",&5"TVD Triple Combo Logs: 1 Color Log each scale Digital Log Images, LAS Data, & LIS Data w/verification listing 1 CD ROMA- a- 1sP Q PLEASE ACKNOWLEDGE RECEIPT BY RETURNING A SIGNED AND DATED COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Buster Bryant/Ben Schulze 6900 Arctic Blvd. Anchorage,Alaska 99518 Office: 907-273-3539/907-273-3536 Fax: 907-273-3535 Buster.Bryant@halliburton.com Benjamin.Schulze( halliburton.com Date: � ai. ..,.. .1-6b3 Signed: l2 _ °Z- Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday, May 31, 2013 10:39 AM To: 'Conrad Perry' Cc: 'courtney.rust@cookinlet.net; Bettis, Patricia K(DOA) Subject: RE: RU-2A PTD 212-172 API 50-733-20501-01-00 Conrad, We reviewed the OH and Mud log ... there are no hydrocarbon zones ( other than Coal seams and associated gas) above your new proposed TOC for RU-2A. You have approval to cement well as proposed ( new TOC at 12650' MD) Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: Schwartz, Guy L(DOA) Sent: Friday, May 31, 2013 8:34 AM To: 'Conrad Perry' Cc: courtney.rustt a'eookinletnet; Bettis, Patricia K (DOA) Subject: RE: RU-2A PTD 212-172 API 50-733-20501-01-00 As long as there are no Hydrocarbons through the interval your proposal will meet regulations. Your request is approved pending results of the OH LWD logs through the area of interest. Once well is drilled give us a call regarding any Hydrocarbon shows above 12700' and let us review OH logs as well. Please forward me your new cementing program so I can update the well file. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: Conrad Perry [maiito:conrad.perryacookiniet.net] Sent: Thursday, May 30, 2013 5:10 PM To: Schwartz, Guy L (DOA) Cc: courtney.rustctcookinlet.net Subject: RU-2A PTD 212-172 API 50-733-20501-01-00 Guy, I would like to request a change the TOC on the 7" liner on RU-2A from the liner hanger at 8200' MD to 11,650'. The well has been TD'd at 15,360' MD and the highest known hydrocarbon is a gas sand at 12700'. We are running a linerhanger packer. This change will reduce the risk of lost circulation over our productive interval,while still exceeding the requirement for 500'above any hydrocarbon zone. We will also be able use a 15.8 ppg slurry rather than a 13.5 ppg. Best Regards, 1 conrad Drilling Manager Cook Inlet Energy, LLC 601 W. 5th Avenue STE 310 Anchorage,AK 99501 (907)433-3816—Office (907)727-7404-Cell (907)344-0584- Home (907)260-5356-Cabin conrad.perry)cookiniet net 2 BAKER HUGHES Proposal No: 1001147866K COOK INLET ENERGY LLC REDOUBT UNIT#2A REDOUBT SHOAL Field pT^/ Kenai Offshore County, Alaska I May 25, 2013 Cement Proposal Prepared for: Prepared by: Courtney Rust Kenneth Nix Engineer Region Engineer Cook Inlet Energy Bus Phone: 907-727-7404 Email: cperry@att.net Service Point: Service Representatives: BJS, KENAI Rod Edwards Bus Phone: 907-7764084 Account Manager (907)659-2329 Bus Phone: 907-267-3487 Fax: 907-776-5606 Mobile: 907-229-6536 Powered by PowerVision Gr4105 Operator Name: COOK _ET ENERGY LLC Well Name: REDOUBT UNIT#2A BAKER Job Description: 7" liner HUGHES Date: May 25, 2013 Proposal No: 1001147866K JOB AT A GLANCE Depth (TVD) 12,750 ft Depth (MD) 15,500 ft Hole Size 8.5 in Liner Size/Weight 7in, 26 lbs/ft Pump Via Drill Pipe 4" O.D. (3.340" .I.D) 14 Casing 7" O.D. (6.276" .I.D) 26 Total Mix Water Required 2,638 gals Weighted Spacer SealBond Spacer 40 bbls Density 11.0 ppg Slurry Class G Tail 283 sacks Density 13.5 ppg Yield 1.86 cf/sack Displacement Completion Fluid 362 bbls Density 8.5 ppg Repo,l Piloted on May 25 2013 11 03 AM Page 1 Gr4109 Have more questions? You can find us at: h tt p://www.ba ke rh u g h es.c om/prod u cts-and-services/press u re-pu m pi n g Operator Name: COOK _ET ENERGY LLC Fr Well Name: REDOUBT UNIT#2A BAKER Job Description: 7" liner HUGHES Date: May 25, 2013 Proposal No: 1001147866K WELL DATA ANNULAR GEOMETRY ANNULAR I.D. DEPTH(ft) (in) MEASURED I TRUE VERTICAL 8.681 CASING I 8,500 I 8,500 8.500 HOLE I 15,500 I 12,750 SUSPENDED PIPES DIAMETER (in) WEIGHT DEPTH(ft) O.D. I.D. (lbs/ft) MEASURED I TRUE VERTICAL 7.000 I 6.276 I 26 I 15.500 I 12,750 Drill Pipe 4.0 (in) OD, 3.34 (in) ID, 8,300 ft 14 (Ibs/ft) set @ Liner 7.0 (in) OD, 6.276 (in) ID, 26 15,420 ft (lbs/ft) set @ Depth to Top of Liner 8,300 ft Float/Landing Collar set @ 15,420 ft Mud Density 8.50 ppg Mud Type Oil Based Est. Static Temp. 195 ° F Est. Circ. Temp. 171 ° F VOLUME CALCULATIONS 2,850 ft x 0.1268 cf/ft with 40% excess = 507 cf 80 ft x 0.2148 cf/ft with 0% excess = 17 cf (inside pipe) TOTAL SLURRY VOLUME = 524 cf 93 bbls X5, 54)° — z �s� lZ1 CD N �vG JA- ,s13,Vif Page 2 Gr4117 Have more questions? You can find us at: http://www.bakerh ughes.com/products-and-services/pressure-pumping Operator Name: COO. JLET ENERGY LLC r� Well Name: REDOUBT UNIT#2A BAKER Job Description: 7" liner HUGHES Date: May 25, 2013 Proposal No: 1001147866K FLUID SPECIFICATIONS Weighted Spacer 40.0 bbls SealBond Spacer + 142.5 lbs/bbl Barite - Sacked + 75 gals SS-2 @ 11 ppg VOLUME VOLUME FLUID CU-FT FACTOR AMOUNT AND TYPE OF CEMENT Slurry 524 / 1.86 = 283 sacks Class G Cement+ 10% bwoc BA-90 + 0.005 lbs/sack Static Free + 2.5% bwoc BA-56 + 0.8% bwoc R-3 + 2% bwow Potassium Chloride + 0.5% bwoc EC-1 +0.5% bwoc CD-32 + 0.1% bwoc ASA-301 + 1 gals/100 sack FP-6L + 0.5% bwoc Sodium Metasilicate + 82.7% Fresh Water Displacement 362.4 bbls Completion Fluid @ 8.5 ppg CEMENT PROPERTIES SLURRY NO.1 Slurry Weight (ppg) 13.50 Slurry Yield (cf/sack) 1.86 Amount of Mix Water (gps) 9.32 Amount of Mix Fluid (gps) 9.33 Report Footed on May 25 2013 11 03 AM G,4129 Page 3 Have more questions? You can find us at: http://www.bakerh ughes.com/products-and-serviceslpressure-pumping &o1 Ufa( ZA P71) Z l z I-7 zo Regg, James B (DOA) From: Regg, James B (DOA) 41/61(-5 Sent: Tuesday, April 16, 2013 8:58 AM To: Conrad Perry Cc: Schwartz, Guy L (DOA); Osprey Drilling; courtney.rust@cookinlet.net; 'David Hall'; Schwartz, Guy L (DOA); DOA AOGCC Prudhoe Bay Subject: RE: BOP tests CI Energy's request to commence testing BOPE on Miller Rig 35 at intervals not to exceed 14 days is approved.This approval applies to development drilling only; BOPE testing during workovers must be completed at intervals not to exceed 7 days unless otherwise approved by AOGCC. Please be aware that AOGCC will not grant time extensions to the 14-day interval except when engaged in active emergency well control. As provided in 20 AAC 25.035,AOGCC reserves the right to rescind the authorization to test BOPE at 14-day intervals based on performance. Jim Regg AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 From: Conrad Perry [mailto:conrad.perryftcookinlet.net] Sent: Monday, April 15, 2013 3:26 PM To: Regg, James B (DOA) Cc: Schwartz, Guy L (DOA); Osprey Drilling; courtney.rust@cookinlet.net; 'David Hall' Subject: BOP tests Jim, ,i ✓ Rig 35 on the Osprey has just transitioned from well abandonment of RU-2 to sidetracking RU-2A. Our last BOP test was the 12th of April and we would like permission to extend BOP testing to a two week interval. conrad Drilling Manager Cook Inlet Energy, LLC 601 W. 5th Avenue STE 310 Anchorage,AK 99501 (907)433-3816—Office (907) 727-7404-Cell conrad.perry@cookinlet.net 1 MMMIMOIMIMMMMNMMMMMMMMMMMMMI w\��F fit I 7 s THE STATE Alaska Oil and Gas °ALASKA Conservation Commission Ott GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF . " p. Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 David Hall CEO Cook Inlet Energy, LLC 601 W. 5th Ave., Suite 310 Anchorage, AK 99501 Re: Redoubt Shoal Field, Undefined Pool, Redoubt Unit #2A Cook Inlet Energy, LLC Permit No: 212-172 Surface Location: 1918' FSL, 320' FEL, SEC. 14, T7N, R14W, SM Bottomhole Location: 2475' FSL, 1505' FWL, SEC. 19, T7N, R13W, SM Dear Mr. Hall: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy P. oerster Chair DATED this Ii day of February, 2013. STATE OF ALASKA A ;A OIL AND GAS CONSERVATION COM, ION PERMIT TO DRILL �.��,I,ii, 42'20 AAC 25.005 la.Type of Work: . lb.Proposed Well Class: Development-Oil U. Service- Winj ❑ Single Zone © lc.Specify if well is proposed for: Drill ❑ Redrill 2 Stratigraphic Test❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Re-entry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q Single Well❑ 11.Well Name and Number: COOK INLET ENERGY,LLC Bond No. ub 61212870 , REDOUBT UNIT#2A 3.Address: 6.Proposed Depth: i z. 12. field/Pool(s): ,601 W.5TH AVE.,SUITE 310,ANCHORAGE,AK 99501 MD: 15,451 . TVD: 1 , - R DOUBT UNIT SHOAL UNDEFINED 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number: Surface: 1918'FSL,320'FEL,Section 14,TO7N,R14W,SM . ADL 381203 , A_7.. 37�‘.;1?_�, 0.i S /i Top of Productive Horizon: 8.Land Use Permit: 7 13.Approximate Spud Date: 2306'FNL,755'FWL,Section 19,TO7N,R13W,SM n/a 11/25/2012 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2475'FSL, 1505'FWL,Section 19,TO7N,R13W,SM 23526 17623' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10,KB Elevation above MSL: • 90 feet 15.Distance to Nearest Well Open Surface: x-200626 y- 2449942 Zone-4 GL Elevation above MSL: to Same Pool: 2140' 16.Deviated wells: Kickoff depth: 8500 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 39 degrees Downhole: 5967 Surface: 4782 - 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 8.5 7"L80 29# L 80 BTC 7000 8300 3 15451 12750 R EC /v ED NOV 0 7 2012 19. 'PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) AOGCC Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): 15,325 12,607' BP@ 15,2.18 13,465 10,965 13,465'MD Casing Length Size Cement Volume MD TVD Conductor/Structural 200 36"150#A-36 n/a 200 200 Surface 3212 13 3/8"L-80 5710 cu ft 3,212 2918 Intermediate 9011 9 5/8"L80 645 cu ft 9,011 7534 Production 5561 7 5/8"L80 171 cu ft 14,320 11746 Liner 1213 5 1/2"L80 191 cu ft 15325 12601 Perforation Depth MD(ft): 14,420-15,256' Perforation Depth TVD(ft): 11,826'-12,556' 20. Attachments: Property Plat ❑ BOP Sketch Q Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements2 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Printed Name David Hall r� Title CEO Signature % `✓�eK Phone 907-433-3804 Date //s/��Z Commission Use Only Permit to DrilAPI Number Permit Approval See cover letter for other � Number: 4'2:, /-72- - 50- 73`3"2 j01'' ("00 Date: /lAkk�f requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,\\\ g,s hydrates,or gas contained in shales:[� Other: *. 5000 c3 DSS SOF 7-;-S(-- Samples req'd: Yes❑ No[ Mud log req'd. Yes ❑ o -A- Z,Sbo p 5L. Ahw' „- �sc H2S measures: Yes❑ N/o_L Directional svy r d: Ym [ No❑ y- �� Ar.- Jean,, TGSr z0 �`S�1°Sc� "�y.2G``�c?cee 'Tz"" , 1�1 .75- f L-z./.3 a ,,,,7//� i. /,5 (- z(- s f4 6i /t1z� proc,A. Qh.. - LL � !�/U- �1e4> V io APP OVED BY THE COMMISSION DATE: - i — DCOMMISSIONER X 2 Q -( �,1P `/_ ORL1t1 is l 09) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit in Dupiicat u, 0 ./ 2 _ Cook Inlet Energy_ ECEIVED NOV 0 720V. November 6, 2012 AOGCC Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage,Alaska 99501 Re: Application for Permit to Drill Cook Inlet Energy, LLC: Redoubt Unit#2A Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a Permit to Drill application to sidetrack drill for the Redoubt Unit#2A well located on CIE lease #374002, off the Osprey Platform. The well operations will recover the current completion abandon the 7 5/8" cased lower section, sidetrack to a more desirable area of the formation and d complete an ESP e3 procedure. 194.1141 Cook Inlet Energy requests a waiver for AOGCC regulation 20AAC25.112 for setting the VA cement retainer more than 500 feet above the top perforation due to a fish at 13,465' Also, attached are the completed Form 10-401, current and proposed wellbore schematics, MASP calculations, Rig Drawing, and a BOP configuration diagram. Rig#35 will be used to complete this work over commencing approximately November 25, 2012 If you have any questions,please contact me at (907)-433-3804. Sincerely, David Hall CEO - Cook Inlet Energy 601 W.5`h Avenue,Suite 310,Anchorage,AK 99501 (907)334-6745*(907)334-6735 fax Table of Contents Rig#35 Schematic 4 Current Completion 5 RU 2 Sidetrack Procedure 6 Proposed Wellbore Diagram 12 Directional Plan 13 BOP Sketch 15 Logging Plan 22 Mud Logging Plan 22 Solids Control and Equipment 22 Drilling Waste Storage 22 Cementing Program 23 Bit Proposal 27 Regulatory Waiver and Special Procedures 27 3 Rig #35 Schematic CROWN , #S ` WI NDWALLS ‘k:t It ■ i, RACKING BD ' IF 411 STD GAL DERRICK I� 1.0 II( HOOK LOAD �� "A, 147 K SETBACK r , I' 147 FTX 30 FT i• '112, �.Ilk s• la Irt /01 G c ►1 ✓ � JJHI. I IWI. 'Iri \ ► I I r t ED t I I - la i w r,i 1 _i'\-DOOR C n€ '1'1 I VA �1_7,�. '.''''.."1"`" ,r RAISED PIPE RACK 1' " "I„ 20 FT HIGH ' II111741►�!►\I i. iI PLATFORM CAP BEAM 1/- APPROX 5 1/2 FT ■_ I I �� U DRILLING RIG ARRANGEMENT - EAST SIDE CONFIDENTIAL and PROPRIETARY RIGHTS APPROVAL DWG____ THIS DRAVANG IS NOT TO BE USED VOORHEES� � TINKHAM FOR COMPETITIVE BIDS 111 2 6/18/11 UPDATED 11.. OSPREY DRILLING RIG s� REV DAIS DESCRIPTION BY CHK APR DAM' 5/5/11 INUMBIER' RVRIG1O1O ISL 4 Current Completion Redoubt Unit#2 Completion-January 2005 i 1 7 36" A-36 200 TVD 150# Welded 200 MD 13 3/8" L-80 2918 TVD i 68# BTC 3212 MD 1 I N II 4 • 3-1/2"P-110&L-80 tubing i TOL @ 8,759 MD ' I II �II k 9 5/8" L-80 7534 TVD Sliding Sleeve @ 11,707'MD �. § / 47# BTC 9011 MD I Packer set @ 11,761'MD - .1v 1 Sliding Sleeve @ 11,817'MDII Centrilift ESP Assembly (top of discharge head)@ 'iL 11,864'MD r r 1�-L.-- -.. /3, loo µ' : ip Top of Fish @ 13,465'(fish length=620') Ar >; iell K LLC-3 Valve set in Baker - Model FA Packer @ TOL @14112 MD :; 14015 MD I l 7 5/8" L-80 11746 TVD Perforations: - 29.7# Hydril 521 14320 MD 14,420'-14,542' 14,550'-14,612' ' 14,682'-14,788' — 14,782'-14,834' ..=...-_ i= Perforations 14,840'-14,942' 14,948'-14,980' 14,974'-14,996' :_ 15,002'-15,020' 15,014'-15,130' — EZ Dill @ 15218 MD 15,136'-15,152' 15,146'-15,192' xi-,, 5 1/2" L-80 12601 TVD 15,228'-15,256' 17# Hydril 521 15325 MD 33/8"6SPF 5 Proposed Wellbore Diagram Proposed RU-2A Wellbore Diagram 36" A-36 200 TVD 150 it Welded 200 MD AL., 13 318" L-80 2918 TVD 68 tt BTC 3212 MD • 3-1/2"P-110 8 L-80 tubing r TOL ray 8.306 MD 41 •• IN rj 9 51/8" L-80 7034'TVD 47 u BTC 8500'MD Of- Centnlift ESP Assembly (top of discharge head)@ 13,500'MD Perforations:TBD - 33!8"6SPF ■ e 7 L-80 I 18,:,1'T`.D 294BTC 14 670'MD 12 RU 2 Sidetrack Procedure 11/2/2012 DecomDletion General Note: There is a very good chance that the pump and packer assembly are stuck in the 7 5/8"casing. Numerous examples of collapsed casing are in this field. A new abandonment procedure must be written and - submitted to the AOGCC for approval if it cannot be recovered. 1. Notify AOGCC of start of operations on RU-2 and upcoming BOP test. 2. Move rig over well. Fill active pit with produced water (8.6ppg). Kill well by circulating water down the tubing, through the ESP and up the annulus. (Reservoir pressure in the Hemlock at 12,000 TVD is expected to be approximately 8.0 ppg EMW). While circulating, weight up the water in small increments with NACL, if necessary, until it is heavy enough to kill the well. • .2 s We ) 5oc)c,p 3. Install BPV, N/D tree, N/U BOPE. Test BOPE to , si. [Note: at the discretion of the Drilling Supervisor and AOGCC Inspector (if present), blind rams will be tested after tubing is pulled from hole if there is a chance a gas bubble will settle under BPV, making it difficult or dangerous to release.] Pull BPV. M/U landing joint to tubing hanger, back out lock-down screws and pull hanger to drill floor Unseating Weatherford Hydrow II Packer. (Weatherford Hydrow II packer at 11,761' is straight pull release)Note: tubing is 3 1/2", 12.95 P-110 (to be re-checked in field well files). 5. Once the tubing hanger has been pulled to the drill floor, circulate minimum of two --- bottoms 'bottoms up. 6. Ensure the well is dead and POH with the tubing (current install shows 377 joints, see attached current completion detail), checking for NORM while POH. LID tubing and completion jewelry and send to shore. 7. Rig up wireline and run CBL (bottom 500' minimum) and Casing inspection log (to surface) in 9 5/8" casing. 8. MU a 9 5/8"test tool, run and set it at 8,750' (just above the top of the 7 5/8" liner). 9. Pressure test the 9 5/8" casing to 3000 psi for 30 min, record on chart. POH. 10. AOGCC must be notified 24 hours in advance of plugging the perforations. ✓ 11. M/U a cement retainer for 7-5/8", 29.7# casing, RIH and set retainer at 13,400' (^'65' above top of fish at 13,465'). Note: A waiver must be given as this is over 500' above the top perforations. P.et. 2 AA( z s•t iz(c)(t)c`—) 12. Establish injection into the perforations below the retainer, recording three rates and injection pressures. Un-sting from retainer. 6 13. Mix and pump 50 bbls of fresh water followed by 70 bbls of cement as follows: Cement to consist of 342 sx Class G Slurry Wt. 15.8 ppg Slurry Yield 1.15 cf/sk 14. Displace cement to the stinger. Sting into the retainer and squeeze 67 bbls of cement below the retainer and into the perfs. Un-sting from the retainer and place the last 3 bbls of cement on top of the retainer. Pull up 2 stands and reverse out. f.29.31 15. Pressure test cement plug, 7-5/8" liner and 9-5/8" casing to 3,000 psi for 10 minutes. GLL 16. Displace production fluid with 9.5 ppg Oil based mud. Pull out of hole and procee with sidetrack procedure to drill Redoubt Unit #2A. Sidetrack Drilling Procedure 17. M/U a 9-5/8" bridge plug on drill pipe. RIH and set the bridge plug at 8,500'MD or depth where 9 5/8" is fully cemented for the kickoff. 18. M/U the following 9-5/8" Select Oil Tools Bottom Trip Whipstock System: • 9-5/8" Bottom trip anchor w/3-1/2" IF box • 9-5/8"Select whipstock w/3-1/2" IF pin • Starter window mill w/3-1/2" Reg pin(shear screw set for 35,000 lbs.) • Full gauge upper watermelon mill w/3-1/2" IF box X pin • 1 joint 4" HWDP • 4-3/4" bumper sub • 4-3/4" MWD survey tool w/3-1/2" IF box X pin • UBHO wireline orientation sub w/3-1/2" box X pin • 9 ea 4-3/4" drill collars w/3-1/2" IF box X pin • 18 ea 5" HWDP w/3-1/2" IF box X pin • 5" Drill pipe to surface 19. Attach the anchor/whipstock assembly to the milling assembly via the 35k whipstock shear bolt. Then align the UBHO sub and MWD (scribe as required) with the whipstock face. This should be witnessed by the Cook Inlet Energy drilling supervisor, Olgnoonik tool hand and MWD engineer. (The UBHO orientation sub will only be used as a backup if there is an MWD failure.) 20. RIH with whipstock assembly, taking great care while running it through the BOP stack and wellhead. Run the assembly at 90 to 120 seconds per stand. Ensure the string is fully stopped when setting the rotary slips while RIH. These precautions are necessary to avoid any weakening of the whipstock shear mechanism or pre- setting of the packer. 7 21. With the bottom of assembly +/-20' above the bridge plug at +8,500', establish up and down weights, with and without circulation. Ensure sufficient stroke to tag packer and set whipstock. Do not create any sudden movements that might weaken the whipstock shear mechanism. 22. Survey the whipstock face with the MWD tool and orient the whipstock as per directional driller recommendations. Take a minimum o f three surveys, then reciprocate the assembly and verify the whipstock face has not rotated. Re- orient and survey as necessary. 23. Once orientation and depth have been verified, set down on the bridge plug with 18- 20 k lbs to shear the slip mechanism and set the bottom trip anchor. Verify the bottom trip anchor has set by picking up a maximum of 5K lbs over the string pick up weight. �( 24. Ensure +9.5 ppg mud is formulated as specified in the mud program. Install i' ,��a1r ditch magnets to capture milled casing cuttings. � Z S��cA) 25. With the bottom trip anchor set and the work string hanging in neutral at the Kh whipstock, slack off 35 k lbs to shear the whipstock bolt. /r,,,r�' tc 26. Pick up to neutral, break circulation and establish rotation at 50-60 rpm. Lower D/C`� the milling assembly and commence milling with 2-4k lbs WOB and 50-60 rpm for srA' the first foot or two. Gradually increase the rpm to 100-135 as needed and use a maximum 8-10k lbs WOB while milling. Maintain a minimum annular velocity of 150'/min and a minimum mud yield point of 40 to ensure carrying capacity for metal cuttings removal. 27. Continue milling until the upper watermelon mill is out in the open hole (after approximately 29' of milling). Condition the hole and POH. Check the OD of the upper watermelon mill. If it is more than 1/8" under gauge, a second reaming N./ trip will be required. iv 8.5" Hole Section /Z—/7Z, Objective: Drill 8.5" sidetrack hole and run and cement 7" production liner. Planned Depth 15,451' MD, 12,500' TVD Section Length 6,951' Planned KOP 8,500' A > Drilling Parameters: Flow Rate 450 -650 gal/m RPM 60-160 rpm WOB 5-35 k lb ROP 50-200 ft/hr 8 Bit Details: Primary: 8.5" PDC bit Secondary: 8.5" PDC bit Mud System: Oil base mud. See attached mud program 28. M/U a 8.5" rotary steerable assembly as follows: • 8.5" PDC Bit • 7" PDM • BTM Sleeve Stabilizer • Float Sub • Integral Blade • 6 3/4" DM Collar • 6 3/4" EWR-P4 Collar • 6 3/4" DGR Collar • 6 3/4" PWD • 6 3/4" HCIM Collar • 6 3/4" Pulser • Flex Collars • 5"x 3" HWDP#49.3—NC50(IF) • Jar • 5"x 3" HWDP#49.3—NC50(IF) • 5", 19.5#NC50(IF) DP f o 3 29. RIH. Directionally drill a 8.5" hole as specified in the directional program, Proper hole cleaning is the major factor in successfully drilling this hole section. Maintain tangent angle and directionally drill 8.5" hole from the 9-5/8"casing window to TD per the directional program. Use the oil-base mud system as specified in the mud program. Use mud loggers to allow monitoring of progress through the section. Run MWD for directional control throughout the hole section. Note: Special Tripping and other operational procedures will be given to the driller to minimize swab and surge pressures on the hole. 30. Flow check all major drilling breaks. Avoid circulating in the same spot for extended periods of time to avoid excessive washout at one depth. Add lubricants as required to reduce torque and drag. 31. The 7" liner setting point will be identified by the Cook Inlet Energy geologist using mud logging information. At section TD, condition hole and POH. 9 Run and Cement 7" Liners +n -� 4 , -lb 5°019-56 G 32. M/U and run 7", 29#, L-80, BTC-M Tiner on 4" drill pipe as follows. Perform all measurements and equipment checks before running the liner. 33. Ensure liner hanger is located 300' above the window milled in the 9-5/8" casing. • 7" Baker V float shoe • 1 joint 7" liner w/float collar made up on pin end of joint#2 • 1 joint 7" liner w/Baker type II landing collar made up on the pin end of joint #3.Also equipped w/1-7/16" ball seat and catcher sub pinned for+2,500 psi shear. • +6,290 of 7",29#, L-80 Liner • Baker 9-5/8"x 7" HMC liner hanger pinned for 1,500 psi(±15%) • Baker 9-5/8"x 7"ZXP liner top packer w/C-2 running tool profile and Type II tie-back sleeve,drill pipe wiper plug and liner wiper plug. 34. Baker-Lock all float equipment and the bottom 4 joints of liner. Centralizers will be used for this liner according to Cook Inlet Energy oil policy. 35. RIH w/Baker liner hanger assembly. i 3 c✓/,(- L11-/R— 36. Run 10 stds of HWDP and circulate one drill pipe volume. Continue RIH with liner on DP to 8.5" window. Break circulation at 8.5" window. Obtain pick-up and slack-off values. 37. Continue to RIH to TD with liner on drill pipe. Tag bottom with 7" liner. Top of the liner is planned at 8200' MD. 38. P/U a sufficient distance to allow a safe and convenient make-up operation of the cementing head and test lines to 500/5,000 psi. Circulate and condition the hole for cementing while reciprocating the liner. Maximize flow rate while cleaning hole. Do not exceed the liner hanger setting pressure. 39. The top of cement is planned at the top of the liner at 8200' MD. While ✓ reciprocating the liner, pump cement as follows, carefully monitoring torque and flow rate while rotating: • Verify DP indicator is activated • Pump 40 bbls of 13.5ppg weighted spacer • Follow weighted spacer with 190 bbls(including 30%excess in open hole)of class G cement mixed as: Class G cement at 15.8 ppg+additives+fresh water(See detailed cement program for 7" liner) • Follow the cement with the DP wiper dart and displace with drilling mud. • Slow pump down 5 bbls short of the DP wiper dart landing on the landing collar. • Bump plug w/500 psi • Limit over-displacement to 3 bbls(80'shoe track) 10 40. Once liner wiper plug bumps, hold the pressure for 2 minutes. Do not exceed 500psi over the final pumping pressure. 41. Set liner hanger by pressuring up to 1,800 psi down the drill string. The HMC liner hanger will be set at this point. 5/0 liner weight plus 10,000 lbs to ensure liner hanger is set. Bleed off pressure and P/U to neutral weight at the liner hanger. Rotate 12 turns to the right to release the running tool. P/U to ensure tool is released. Note: Do not P/U enough to disengage sleeve pack-off from tie back sleeve. 42. Bleed pressure to 500 psi and slowly P/U to clear packoff from liner tie-back sleeve. 43. Clear the rotating dog sub from tie-back sleeve. Set down 45,000# at the tool, rotating if necessary. 44. Pull up 1 stand and reverse out cement at maximum rate while reciprocating and rotating drill pipe. 45. POH 3coZ P5L. 46. RIH with 7" scraper and scrape the liner to TD. Test casing and liner to 1500"psi 47. Rig up and run cement bond log. 74- /-2-,•/-3 Perforation and ESP Completion 48. Rig up to run in hole with TCP guns. The perforating program will be issued by CIE geologist based on logs. 49. Run in hole with perf guns and perforate 7" casing. POOH 50. Test and inspect new Centrilift ESP and new Phoenix tool before running in hole. 51. Pick up new Centrilift ESP completion and RIH. Test cable every 1000'. No P.AucEt. 52. Monitor trip tank for proper hole filling. Splice cable as needed. At TD, confirm pipe tally, MU landing joint and set string in slips. 53. Dress hanger and control lines. Land hanger, run in screws, test hanger to 5000 psi. 54. Lay down landing joint and install BPV. Observe well dead. 55. Nipple down riser and BOPE. 56. Install production tree. Turn over well to production. Release Rig Directional Plan 500 •V16 CGriANY DETAILS'. Coo,FIM Energy HALLIBURTON :36035°0 35.52 12211 71na 43002 36 662 1o°1la 0..00 423201'550' Ceeleon MWnLL Mem.CMe.6.. 5620.00 36.55 111.5 71311.75 331.75 3631.711 2.00 6500 4211.77 Env SMOMn:ISCN/$A 6555.00 36.55 110.44 711.4 336427 3547.61 0.00 6.66 0131.62 San :n CY6116M. Sperry Drilling Services 403.1 30.37 12066 17200.00 2131102 3361336600 20000 OW 116600 MY2At1MMseTMM.1 2 00 26.70 4356.80 Beer Surface. 15451.0! 36.37 1 12300.00 -4503.31 311736 54117 . Ratio Project:Cook bust - CABNO newts Site:Redoubt REFERENCE INFORMATION IVO MD lama 8. Well:Redoubt Unit 42 , 2744.91 3003.00 Cas42 13.318 Co-ar2inate(WE)Reference WO Redoubt Un4 42 True NorM • 7989.09 9348.55 9 511' 9841 Wenbore:Plan RU-24 VMicel(IVO)Reference Plan RedeubtUnite290 000(Plan RedoubtUn 142) ' 12/99.99 15451.07 7- 7 Plan:Plan RU-2A WPI,a(Redoubt Unit t/2/Plan RU-2A) ensu ed Deppth t Re erenceMiniLuna ul°dOcsUnn.21090 000(Plan RedoubtUnne2) CalcuWELL DETALS:Redo.Unit 52 WELLBORE TARGET DETAILS(MAP CO.ORDINATES) . Wald 0.00, 10.00Name TVD 097.8 0E/-W Northing p Easti g Sue .N/-S 0E/-W Noreen EaMyq Llavala Lpo•6W 2A N Slot RU-24 TO reel 11775.00 -4290.00 980.00 2445480.48 207314.72 Circle(Ra2u6:150.00) 0.00 0.00 244994300 209296.00 90.595457 -151.970701 WEAR(-VPnt(+)(800 Win) SURVEY PROGRAM 2400 250 3200 3600 4000 4400 480 5200 560 6000 6100 680 Dere:2012-10.15700.0 Validated.Yes Version III I1 111111 lit 1lilt tt1111ill 1tt1 Depth From peppy To Swey/Plan Tool Start Dir 12°/100':8500'MD,7122.581VD:65°LT TF 172.0 135500 RUa2(RU42) C8-GYRO-SS 1173.54 850000 MWD SAG(R1102) MW00SAG 8500 930.0 P.RU-21 WP4a(Pkn RU-2A)0MWD Inlerp Asi _ End Dir:8520'MD,7138.75'TVD 9300 15451 08 Plan RU-2A WP4 a(Plan RU-2A) MWD. SAG _- ..-.: __ _. __ - _- Stan Dr 2°/100':8550'MD,7162.84'TVD -2400- -__ --2400 _ -- End Dir:8704.53'MD,1284.63'TVD � -2800 -280 - Qy.5-3295 $ --320 99 g +-3600- --5600 0 Z. _ 80%cont. - +a - -4000 S Total Depth.15451.08'MD,12500'TVD vie. 4 -1499_ `•_-. _ _-110 RU-2A Hembdr T8t tevl . -4500- --4w0 Redoubt Unit 42/Plan RU-2A WP4.a - Redoubt Unit#2/RU#2 - •520 520 -5600I111IIIIII111111IIIII111iIIIIIIIIIl 111 ' IIIIIIIIIIIIII " ' I " I11I111111 -560 2400 280 3200 360 4000 4400 4800 5200 5600 6000 6400 680 7200 7600 800 840 8800 9200 960 WEEK-1/Eael(+)(8001t/in) • 13 HALLIBURTON P WELL DETAILS:Redoubt Unit#2 Water Depth: 4000• , Sperry Drilling +N/-�S +E/-W Nodhin9 Easting Latittude Longitude Slot 00 0.00 244994200 20062600 60695487 -151070704 • • SECTION DETAILS Project: Cook Inlet Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target Site: Redoubt 1 8500.00 35.52 122.11 7122.58 -2349.82 3521.62 0.00 0.00 423201 Well: Redoubt Unit#2 2 852000 36.59 118.46 7138.75 -2355.75 3531.79 1200 -65.00 4243.77 3 8550.00 36.59 118.46 7162.84 -2364.27 3547.51 0.00 0.00 4261.62 Wellbore: Plan RU-2A 4 8704.53 39.37 120.66 7284.63 -241122 363018 2.00 26.79 4356.60 Plan RU-2A WP4.a 5 14513.22 39.37 120.66 1177500 -429000 6800.00 0.00 0.00 8040.14 RU-2A Hemlock Tgt revl 6 15451.08 39.37 120.66 12500.00 -4593.34 7311.79 0.00 000 8634.87 57 SURVEY PROGRAM Date 2012-10-15700:0000 Validated:Yes Vernon Depth From Depth To Survey/Plan Tool 172.00 135500 RU82`RU#2) C8-GYRO-SS 6000 1473.54 8500.00 MWD SAG(RU#2) MWD+SAG 8500.00 9300.00 Plan RU-2A WP4.a(Plan RU-2A) MWD_Interp Azi 9300.00 15451.08 Plan RU-2A WP4.a(Plan RU-2A) MWD+SAG 6500- Start Dir 12°/100':8500'MD,7122.58TVD:65°LT TF REFERENCE INFORMATION Co-ordinate(WE)Reference:Well Redoubt tIne#2.True North End Dir :8520'MD,7138.75'ND Vertical(TVD)Reference:Plan RedoubtUni6a2@ 90.006(Plan:RedoubtUnita2) Measured Depth Reference Plan:RedorbtUni6s2 90.006(Plan:RedoubtUnil#2) 9 Calculation Method:Minimum Curvature 7000 - Start Dir 2°/100':8550'MD,7162.84TVD CASING DETAILS _ End Dir:8704.53'MD,7284.83'TVD TVD MD Name Size 2744.81 3003.00 Case2 13-3/8 7500- 7000.00 8348.55 9 5/8" 9-5/8 12499.99 15451.07 7" 7 COMPANY DETAILS. Cook Inlet Energy 8000 1i Calculation Method:Milkmen Curvature Error Sysem ISCWSA Scan Method:Tray.Cylinder North Error Surface.Elliptical Conic �i, Wamn g Method Error Rata 8500- Z- 500-Q 9000- a O - O 9500 t n m a 110000-- a) 2 I=10500- 11000 11500- Top Hemlock RU-2A Hemlock Tgt revT - 12000- Mid Hemlock Lwr Hemlock 7" 12500- Total Depth:15451.08'MD,12500'ND Plan RU-2A WP4.a RU#2 13000 13500 -r T . i - -r_-- , .-- - - -... I 1 I 1 I .'T-T T- 11 , . 1 i 1 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000 Vertical Section at 122.14°(1000 ft/in) • • 14 BOP Sketch ' 7;32012 5-2 -12'ID,.BOP Schematic:;•e'.• "Rig Floor" Well!RL11 KB Elevation Dare: 5126!2012 - -1.....m. I Measure distances from"Rig Flggr" —11.1111111L111 Ilnp of An pular Hydril ICentpr Ilydri1 _• ` 13-51W'5k Rdnular , lit.rill MI,I I. i. I :— 6 VCP13-S�H't 0i.HydrHydraVCPleg.Ccntar a"Rare•1 ,AI 11.7.11 -7P-13 SM '��i-f�-jfar' per•] 13 dL"17k Hydr I ••per III 61 ni R:ms Il CA-1rnrH Intl• r� �a mome. PI171 >.f•x nutr_pw III 111 111 R1J UL I Ems°►=�� $II� r a I1Cp —. r K 1 CHH --.. 1 r CM4.1 i,,. • it urn rm.11-1 1'11— �J • v fX�0) ...,• 1-li 4"U('rams L, it US.I 13 5'8'IC 1."A'18'8'SK aJapiar spool n igrn 1C e'G G'cu1d •rel 13E!S'5kX13bit"5k ti+cr Ir in .11 _ I � rd 1 vr.ii LLI''-'L I .i.Y.)SgLI 1'.1'' • III ILI IIIW Cents LC LNthAv'3,1ewa 1 • I - I 15 Wellhead Schematic Si 45.87" Ise 11111.1 ° '!y\ r/3-1/8 5000 VG 230 1/2"LP PORT W/PLUG 80.66" LI "I 101lIll" 3-1/8 5000 VG 230 W/ACT. JJ ••"w7 3-1/8 5000 VG 230 111111...--_,-- 1/2"LP PORT . • ' W/PLUG 11 1 !AL 3-1/8 5000 VG 230 .'.... 10/1 1 ' 1 3-1/8 5000 1 MI nu RN 18.63 _ ' LA—")&11.11"-j u1 i' ii u1 �D U J L L- '! ■ 13-5/8 5000 6bx 1 __ -- - _ - (1 A"E _IY 3"H-BPV PREP �� 'I ` 2.950 MIN BORE !� lug°---- 3-1/2'OD PH-6 2800 _ l � 2-1/16 5,000 ■1 ==Iii Li1I1I .IillH2 C _ __,r1` ' 13-5/8 5000 6BX _„Y 1 —III _ 2-1/16 5,000 24.75 ■ iI.f1! I ill lin i. 1 1 ■ .�= 12.75” 1.844" t 1 ■ ■ 13.50" 5.031" viii 'II •I : i �• • . 19.50" '_ , _N i g1 I m _41 WELL RU-2 WELL RU-5 1 13-3/8" OD CASING 3-1/2"OD TUBIN 9-5/8" OD CASING ALL DIMENSIONS ARE APPROX. SYSTEMS ENGINEERING V@tCOgfay 13-3/8 X 9-5/8 X 3-1/2 OD 5,000 MSP MULTIBOWL ASSY i PRODUCER WELL DRAWN BY:C. RICE DATE:14 OCT 2004 FIE REFERENCE: FOREST 014 OSPREY L DRAV.NG NO. ENG. APPR.: DATE: XIVXX SCALE: FALL (PROJECT NO.:=XX I SP-4482-2A 16 Geo-Mechanical Plot Geothermal Temperature Profile MD TVD Temperature Gradient (It (ft: (deaE: 01KIFl10.0.ft, 0.0 0.0 80 0.0 90.0 90.0 80 -0.0 160.0 159.9 77 -1.8 15226.0 12345.4 190 0.9 ft. degF 75 100 125 150 175 200 =,- I I I I I T4b4(ar Fk,gs t 0 0 1 Temp. Profile 6t.. 119 min (Reference depth for pressure conversion to equivalent density or pressure gradient is RIG_FLCCR: Formation Data MD E.M. Pore Name L,itholQgy (ft; (Ib/gal: (Ib?gal:: 1320.0 13.00 9.50 Siltstone 2480.0 13.00 9.50 Sandstone 4800.0 13.00 9.50 Shale 5400.0 13.50 9.50 Sandstone 6000.0 13.50 9.50 Coal 9500.0 14.00 9.50 Sandstone 11250.0 14.00 9.50 Coal 13000.0 14.00 9.50 Sandstone 13500.0 14.50 9.50 Coal 14200.0 15.00 9.50 Sandstone " 14938.0 16.00 9.50 Sandstone 15226.0 16.00 9.50 Sandstone 17 Casing Program Casing Program TVD (ft) Connection API rating Casing Btm Mud Wt Wt# Hole size Burst Collapse tension sizes (in) (ft) (lb/ft) (lb/ft) Grade Type OD (in) (in) (psi) (psi) (kips) 9 5/8" 8,500 9.2 47 L80 BTC-M 10.625 - 6870 _ 4760 1086 • 7" 12,750 9.6 29 L80 BTC-M 7.656 8.5 8160 7020 676 Field and Well Data Max Pore press (psi) -RU 2 RFT 5701.8 9.0 ppg EMW Assumed Gas Gradient 0.1 95/8" FIT @ 7,565'TVD-10.5 EMW Maximum Pressures Setting Casing Depth MASCP Maximum Allowable Surface Casing MASP Max Anticipated Surface Pressure Size (tvd) Pressure (psi) (psi) 9 5/8" 7,122 4782 3,362 7" 12,750 4782 4,600 MASP based on FIT test preformed on 9 5/8" leak off test 3/21/02 Well Control and Casing Design Calculations rasing Size 9 5/8" Setting Depth: 8500' MD 7122' TVD 1. Collapse Equivilent mud weight used. (Equivilent mud weight x.052 x depth (tvd))-(gas gradient x depth tvd) �j 9.0 x.052 x 7122' 2620.896 psi Safety factor 1.8 2. Burst A. Frac Press@ shoe (Equiv Mud Weight+0.5 ppg) X.052 X Depth (tvd) - (.1 psi/ft x Depth (tvd)) 3361.584 psi B.Surface pressure due to pore pressure Max Pore Pressure-Gas Gradient x next Casing Depth 4600 psi Lessor of A or B 3,362 psi Safety factor 2 3. Tensile Loads no buoyancy, hung in air = (Depth (tvd)x Weight/Ft) a.Tension Force NA-alread run and cemented lb Safety factor Maximum Allowable Surface Casing Pressure MASCP= (0.7 x Casing Burst)-(Mud wt-Backup Fluid Wt.)x.052 x TVD Casing Size: 7" Setting Depth: 15,451' MD 12500' TVD 1. Collapse Equivilent mud weight used. (Equivilent mud weight x.052 x depth (tvd))-(gas gradient x depth tvd) 9.0 x.052 x 12500' 4600 psi Safety factor 1.5 2. Burst A. Frac Press@ shoe (Equiv Mud Weight+0.5 ppg)X.052 X Depth (tvd)-(.1 psi/ft x Depth (tvd)) NA psi B.Surface pressure due to pore pressure Max Pore Pressure-Gas Gradient x next Casing Depth 4600 psi Lessor of A or B 4,600 psi Safety factor 1.8 3.Tensile Loads no buoyancy, hung in air= (Depth (tvd)x Weight/Ft) a.Tension Force 448 Klb Safety factor 1.5 Maximum Allowable Surface Casing Pressure MASCP= (0.8 x Casing Burst)-(Mud wt-Backup Fluid Wt.)x.052 x TVD MASCP= 5878 psi BUT-7" is Liner,so constrained by 9 5/8" Maximum Allowable Surface Pressure of 4782 19 Drilling Fluid Program Hole Casing Mud Size Size Casing MD TVD Mud Weight (in) (in) Program (ft) (ft) System (Ib/gal) 8,457 9.6)5 NOP 9.0—9.2 window 14,67".3 11 con OM 9.2—10.7 i 20 Cook Inlet Energy Redoubt Unit: RU-2A Sidetrack OH Interval Drillirg Fluid System MegaDril 0B11 Key Products MAPCO200, IMG 430.Lime,Actimu1 Brine(10.6 ppg CaCl2), r.11 WATE (Barite) Solids Control Shakers, Mud cleaner. Centrfuge Lithologic instability near the wellbore. Potential Problems Lost Circulation Hole cleaning,. Production Interval Drill•in Fluid Properties Properties Initial Value Density(ppg) 9.2 ppg - Initial Make-Up Weight 10.7 ppg- Possible by TD Funnel Viscosity(seconds) 45 -65 Yield Point(cP) 25 -35 Pl]stic 'Jiscosity(Ib?100 sf) 20 -30 Oil :Water 70 : 30 Electrical Stability(mlVolts) 650 -900 HTHF Fluid Loss (rn1130 mint200 psi/150°F) <4 New OBM Formula MAPCO 200 0.602 bbl IMG 400 3.0 ppb Lime 6.0 ppb ACTIMUL 9.0 ppb MI WATE(depend inch on mud weight) 100 ppb VERSATROL 6 ppb Brine(10.6 ppg CaCl2) 0.165 bbl 21 Logging Plan Open-hole Triple Combo Logging services(Gamma Ray,Neutron,Density and Resistivity). Estimated open-hole logging interval from TD of 12,750' up to surface casing depth,and continue logging Gamma / Ray and Neutron services to surface. Mud Logging Plan Mud loggers will catch 30'ditch samples and maintain a wet and dry cut. Samples to be sent to state as / required by regulations. Solids Control and Equipment Item Equipment Specifications Shakers 2-4 panel (2'x4') shale shakers Desander 3 cone desander Desilter 20 cone desilter Mud Cleaner 4 panel (2'x4') mud cleaner Centrifuge Make/Model not available yet Drilling Waste Storage Drilling wastes will be either granular solids (cuttings), or liquids (drilling mud or water). Cuttings will be stored in cuttings boxes for shipment to the West McArthur grind and inject plant. - Liquids will be stored in tanks and either disposed of in the Osprey disposal well or sent to the West McArthur facility. 22 Cementing Program JOB AT A GLANCE Casing Size/Weight 9 518in. 47 Ibsft Pump Via Drill Pipe 4"O.D. (3.340".I.D) 14# Total Mix Water Required 1,914 gals Pre-Flush Fresh water ahead 10 bbls Density 8.3 ppg Plug Slurry Class G 390 sacks Density 15.8 ppg Yield 1.15&sack Displacement Drilling fluid 150 bbls Density 8.5 ppg 23 Operator Name: COOK INLET ENERGY LLC V 1 Well Name: REDOUBT UNIT#2A BAKER Job Description: 15.8 ppg Plug below Retainer at 13900ft HUGHE Date: August 15, 2012 Proposal No: 10011478E FLUID SPECIFICATIONS P s Pre-Flush 10.0 bbls Fresh water ahead @ 8.34 ppg PLUG VOLUME VOLUME NO. CU-FT FACTOR AMOUNT AND TYPE OF CEMENT 1 450 / 1.15 = 390 sacks Class G Cement+ 0.05% bwoc Static Free + 0.9% bwoc R-3 + 0.3% bwoc CD-32 + 0.2% bwoc FL-52 + 1 gals/100 sack FP-6L+ 43.6% Fresh Water Displacement = 149.8 bbls Drilling fluid @ 8.5 ppg CEMENT PROPERTIES PLUG .) JPEL NO.1 :•111.6 Slurry Weight (ppg) 15.80! Slurry Yield (cf/sack) 1.15 —` . Amount of Mix Water (gps) 4.91• Amount of Mix Fluid (gps) 4.92 PLUG GEOMf=TRY 7�" c's i')(�y PLUG PLUG ! TOP BOTTOM 1 13900 ft to 14993 ft with 8.6 inch ID Casing Due to the possibility of solids bridging at the perfs, a solids free pre-flush is recomended. • 24 Operator Name: COOK INLET ENERGY LLC �.. Well Name: REDOUBT UNIT#2A BAKER Job Description: 7"liner 15.8 ppg Class G HUGHES Date: August 15,2012 Proposal No: 1001147866E JOB AT A GLANCE Depth(TVD) 12,750 ft Depth(MD) 15,500 ft Hole Size 8.5 in Liner Size/Weight 7in, 26 lbs/ft Pump Via Drill Pipe 4"O.D. (3.340".I.D) 14 Casing 7"O.D. (6.276".I.D) 26 Total Mix Water Required 5,419 gals Weighted Spacer SealBond Spacer 75 bbls Density 11.0 ppg Cement Slurry Class G 1,108 sacks Density 15.8 ppg Yield 1.16 cf/sack Displacement Completion Fluid 362 bbls Density 8.5 ppg Report PrnYU on August 21 2012616 PM Page 4 G1u109 Have more questions? You can find us at: http:/lwww.bakerh ug hes.comlprod ucts-and-services/press u re-pumping 25 Operator Name: COOK INLET ENERGY LLC 1 I Well Name: REDOUBT UNIT#2A BAKER Job Description: 7"liner 15.8 ppg Class G HUGHES Date: August 15,2012 Proposal No: 1001 147866E WELL DATA ANNULAR GEOMETRY ANNULAR I.D. DEPTH(ft) (In) MEASURED TRUE VERTICAL 8.681 CASING I 8,500 I 8,500 8.500 HOLE I 15,500 I 12,750 SUSPENDED PIPES DIAMETER (in) WEIGHT DEPTH(ft) O.D. I.D. (lbs/ft) MEASURED I TRUE VERTICAL 7.000 I 6.276 I 26 I 15,500 I 12,750 Drill Pipe 4.0(in)OD, 3.34(in)ID, 8,300 ft 14(lbs/ft)set @ Liner 7.0(in)OD, 6.276(in)ID,26 15,420 ft (lbs/ft)set @ Depth to Top of Liner 8,300 ft Float/Landing Collar set @ 15,420 ft Mud Density 8.50 ppg Mud Type Oil Based Est.Static Temp. 195 °F Est.Circ.Temp. 154 °F VOLUME CALCULATIONS 200 ft x 0.1438 cf/ft with 0% excess = 29 cf 7,000 ft x 0.1268 cf/ft with 40% excess = 1243 cf 80 ft x 0.2148 cf/ft with 0% excess = 17 cf(inside pipe) TOTAL SLURRY VOLUME= 1,289 cf__ 230 bbls, Report Pr,eleS on. August 21.2012810 PM Page 5 . Have more questions? You can find us at: http://www.bakerhughes.com/products-and-services/press u re-pumping 26 Bit Proposal Bit Summary Interval MD Size Recommended Estimated (ft) (in) Type WOB-RPM ROP ft-hr 8,500- 14,513 8.5 FX65D 20-250 50 14,513- 15,451 8.5 FX74D 20-250 20 Regulatory Waiver and Special Procedures AOGCC Regulation 20AAC25.112 (c) (D) by the down squeeze method using a cement - retainer or production packer set no less than 50 feet but no more than 500 feet above the perforated interval, a volume of cement pumped through the retainer or packer sufficient to fill the wellbore from 100 feet below the base of the perforated interval to the retainer or packer; Cook Inlet Energy requests a waiver for setting the cement retainer more than 500 feet above the top perforation due to a fish at 13,465'. 27 Page 1 of 3 Schwartz, Guy L (DOA) From: courtney Rust[courtney.rust@cookinlet.net] Sent: Friday, February 08, 2013 11:51 AM To: Schwartz, Guy L (DOA) Subject: Re: Redout 2A(PTD 212-172) Attachments: RU2A-cmtprop.docx Guy, I apologize I must have missed the FIT/LOT value question. And yes the P&A Sundry has been submitted. From your RU2A comments: 1. 6000 was a typo, we will adjust the program to pressure test to 5000 psi 2. We expect at 10.5 ppg EMW based on RU-2, however, the minimum will be 10.3 ppg EMW. That is 1 ppg over expected pore pressure of 9.0 ppg+ .3 ppg ECD safety factor. 3. Understood, I will make that adjustment. 4. Understood. 5. I have attached the proper cement information for the 7 5/8" Thanks, Courtney From: "Schwartz,Guy L(DOA)" <guy.schwartz@alaska.gov> Date:Thursday, February 7, 2013 9:22 AM To:courtney Rust<courtney.rust@cookinlet.net> Subject: RE: Redout 2A(PTD 212-172) Thanks.. any progress on the other questions... most of those can be addressed with an email. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: courtney Rust [mailto:courtney.rust@cookinlet.net] Sent: Wednesday, February 06, 2013 3:24 PM To: Schwartz, Guy L(DOA) Subject: Re: Redout 2A (PTD 212-172) Guy, Anti collision summary,as requested. Thanks! Courtney From: "Schwartz, Guy L(DOA)" <guy.schwartz@alaska.gov> 2/8/2013 Page 2 of 3 Date:Tuesday, February 5, 2013 12:26 PM To: courtney Rust<courtney.rust@cookinlet.net> Cc: "Davies,Stephen F(DOA)"<steve.davies@alaska.gov> Subject: RE: Redout 2A(PTD 212-172) I have the P &A sundry... I still need follow-up on the below items to finish up the PTD for RU 2A Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Courtney Rust [mailto:courtney.rust@cookinlet.net] Sent:Tuesday, January 29, 2013 11:47 AM To: Schwartz, Guy L (DOA) Subject: RE: Redout 2A (PTD 212-172) I have the sundry in my hands, it is coming to you shortly. I am working through your list of comments now. From: Schwartz, Guy L(DOA) [mailto:quy.schwartz@alaska.00v] Sent: Tuesday, January 29, 2013 11:39 AM To: Schwartz, Guy L (DOA); courtney Rust Cc: Davies, Stephen F (DOA) Subject: RE: Redout 2A (PTD 212-172) I also did not see any Anti collision info.. Has the P &A sundry been submitted for RU 2 Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Schwartz, Guy L(DOA) Sent: Tuesday, January 29, 2013 11:28 AM To: 'courtney Rust' Cc: Davies, Stephen F (DOA) Subject: Redout 2A (PTD 212-172) Courtney, I have some comments for the PTD . 1. In step#3 , testing to 6000 psi is not advised as the wellhead has a working pressure of 5000 Psi. I recommend reducing the BOP test pressure to 5000 psi. 2. in step 27 , once you drill out of the window a LOT or FIT must be performed with in 20-50' of the window. I need to know the minimum FIT/LOT value to drill ahead safely. 3. When you get ready to run 7" casing , need to change out Rams to 7" and test. Also , a FOSV and x-over must be on the rig floor ready to connect into the casing in case of a well control issue. 4. Since the ESP completion will not have a packer a"No Flow Test"will need to be done after production starts. 5. the Cement plug (390 sx) for the P &A appears to be calculated using 9 5/8"casing instead of 7 5/8" . 2/8/2013 Page 3 of 3 Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 2/8/2013 t j Cook Inlet Energy Cook Inlet Redoubt Redoubt Unit#2 Plan RU-2A Plan RU-2A WP4.a Sperry Drilling Services Clearance Summary Anticollision Report 15 October, 2012 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Redoubt-Redoubt Unit#2-Plan RU-2A-Plan RU-2A WP4.a Well Coordinates: 2,449,942.00 N,200,626.00 E (60°41'43.75"N,151°40'14.5x.W) Datum Height: Plan:RedoubtUnit#2 @ 90.00ft(Plan:RedoubtUnit#2) Scan Range: 8,500.00 to 15,451.08 ft.Measured Depth. Scan Radius is 1,732.11 ft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Version: 2003.16 Build: 73 Scan Type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Scan Type: 25.00 HALLIBURTON a•111 Sperry Drilling Services Cook Inlet Energy HALLIBURTON Cook Inlet Anticollision Report for Redoubt Unit#2 - Plan RU-2A WP4.a Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Redoubt-Redoubt Unit#2-Plan RU-2A-Plan RU-2A WP4.a Scan Range: 8,500.00 to 15,451.08 ft.Measured Depth. Scan Radius is 1,732.11 ft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (ft) (ft) (ft) (ft) ft Redoubt Redoubt Unit#1-RU#1-RU#1 8,548.36 1,407.77 8,548.36 1,216.78 8,600.00 7.371 Ellipse Separation Pass- Redoubt Unit#1-RU#1-RU#1 9,317.67 1,536.66 9,317.67 1,312.73 9,425.00 6.862 Clearance Factor Pass- Redoubt Unit#2-Plan RU-2A-RU-2A Rig Surveys ' " " " Redoubt Unit#2-RU#2-RU#2 - - - -= Redoubt Unit#5-RU 5B-RU-5B WP02 8,500.00 1,154.13 8,500.00 995.69 8,575.00 7.284 Ellipse Separation Pass- Redoubt Unit#5-RU 5B-RU-5B WP02 14,901.29 1,553.88 14,901.29 1,207.70 15,325.00 4.489 Clearance Factor Pass- Redoubt Unit#5-RU#5-RU#5 8,500.00 1,154.38 8,500.00 995.95 8,575.00 7.286 Clearance Factor Pass- Redoubt Unit#5-RU#5A-RU#5A 8,500.00 1,154.38 8,500.00 995.95 8,575.00 7.287 Clearance Factor Pass- Redoubt Unit#6-RU#6-RU#6 8,554.92 1,205.17 8,554.92 1,034.17 8,525.00 7.048 Ellipse Separation Pass- Redoubt Unit#6-RU#6-RU#6 12,215.97 1,729.50 12,215.97 1,446.44 12,225.00 6.110 Clearance Factor Pass- Redoubt Unit#6-RU#6 PB1-RU#6 PB1 8,554.92 1,205.17 8,554.92 1,034.99 8,525.00 7.082 Ellipse Separation Pass- Redoubt Unit#6-RU#6 PB1-RU#6 PB1 12,215.97 1,729.50 12,215.97 1,447.26 12,225.00 6.128 Clearance Factor Pass- Redoubt Unit#7-RU#7PB1-RU#7PB1 8,531.94 723.30 8,531.94 532.98 8,425.00 3.800 Ellipse Separation Pass- Redoubt Unit#7-RU#7PB1-RU#7PB1 11,014.80 885.14 11,014.80 615.20 10,925.00 3.279 Clearance Factor Pass- Survey tool oroarant From To Survey/Plan Survey Tool (ft) (ft) 172.00 1,355.00 CB-GYRO-SS 1,473.54 8,500.00 MWD+SAG 8,500.00 9,300.00 Plan RU-2A WP4.a MWD_Interp Azi 9,300.00 15,451.08 Plan RU-2A WP4.a MWD+SAG 15 October.2012 71:58 Page 2 of 5 COMPASS Cook Inlet Energy HALLIBURTON Cook Inlet Anticollision Report for Redoubt Unit#2 - Plan RU-2A WP4.a Ellipse error terms are correlated across survey tool tie-on points Calculated ellipses incorporate surface errors Separation is the actual distance between ellipsoids Distance Between centres is the straight line distance between wellbore centres Clearance Factor=Distance Between Profiles/(Distance Between Profiles-Ellipse Separation) All station coordinates were calculated using the Minimum Curvature method 15 October 2012- 11 58 Page 3 of 5 COMPASS Cook Inlet Energy HALLIBURTON Cook Inlet Anticollision Report for Redoubt Unit#2 - Plan RU-2A WP4.a Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to Plan:RedoubtUnit#2 @ 90.00ft(Plan:RedoubtUnit#2). Northing and Easting are relative to Redoubt Unit#2. Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04. Central Meridian is-150.00°,Grid Convergence at Surface is: -1.46°. Ladder Plrtt r. , • - d�„r LEGEND 5 1500 1111 'x , r .`✓. -$- RU D1,Gr-ofTeledrift,Gyroffeledrift V7 t,[) r f ' $ Redoubt Urit 41,RUN1,RUN1 A r r: 06 -�-Redoubt Unit#2,Plan RU-2A RU-2ARR Suveys'A 0 ' '- 44-Redoubt Unt 02,RU#2,RUN2 V7 1000_ -iF-Redoubt Unit N3,RUN3,RUNt3 b8 Q - -Redoubt Unt N4,RUN4,RUN4 V21 (n �� .4Redoubt Lint Unit 44,R UN4 PB R UN4 P 17 Redoubt N4,RUNS P822,RUN4 P89 V2 V17 Y ---Redcubt Unt 04,RUN4A R UN4A'6 N i Redoubt U re N5,RU 5B,R U.69 WP0210 U 500 r Redoubt Urit 45.RUN5,RUN5 V15 -$ Redoubt Unt N5,RUN5A R UNSA'R a) -e- Redoubt Urit#6.RU#6.RUN6 V20 - Redoubt Unit N@,RUib PBI,RUN@ FBI V19 ' Redoubt Unt#7,RU#7P81.RU#7PB1V23 ' -'p-- Plan RU-2AWP4.a 0 0 3000 6000 9000 12000 15000 Measured Depth(3000 ft/in) 15 October,2012-11:58 Page 4 of 5 COMPASS Cook Inlet Energy HALLIBURTON Cook Inlet Anticollision Report for Redoubt Unit #2 - Plan RU-2A WP4.a Clearance Factor Plot: Measured Depth versus Separation(Clearance)Factor 171 1 - F•41 LEGEND d. _ r,,,, -f3; RU D1,G}rtn7Tekdnt,GyrolTeledrift\? S _ T` l j { 1 Redolbt Unt N1,RUN1,RUN1\R 0 ` - 4t-- Redoubt Unt N2,Plan RU-2A RU-2ARig Surreys\.0 iff Redoubt Ung N2,RUN2,R UN2\7 o -t-- Redotbt Unt N3,R UN3,RUN3\8 m - — Redoubt Ung N4,R UM,RUN4 V21 — Redotht Unt N4,RUN4PB1,RUN4PB1 V14 4-6 _ 4- Redmbt Unt N4,RUN4 PB2,RUN4PB2 VI m - -Et Redolbt Uni N4,RUN4A RUN4AV6 r1 _ -t Redolbt Unt 05,RU 5B,RU-6BWP02W --- -` Redolbt Unt N5,RUNS,RUNS VI5 - - Redabt Unt N5,RUN5A RUNSA\Ai AT,tla rote,-_A - - $ Redotbt Unt 06,RUNB,RUN0Vm - -t Redotbt Unt NB,RUNB P51,RUN6 PB1 V19 - :Li,DUIIb P:F IA Redoubt Unt N7,RUN7PB1,RUN7PB1 V23 - -- $- Play RU-2AW P4a o.0.0, 1111111111111 , 1111 1111 1111 � � 11 � � 11111111111111 -.1111 1 1'_70 0Q0 37770 200 32--0 7.300 p.7-0 10000 1150 I_I.09 13750 IS000 M ea steed Depth(2500 ftAn) 15 October,2012- 11:58 Page 5 of 5 COMPASS Operator Name: COOK INLET ENERGY LLC Well Name: REDOUBT UNIT#2A BAKER Job Description: 15.8 ppg Plug below Retainer at 13400ft HUGHES Date: November 5,2012 Proposal No: 1001147866F JOB AT A GLANCE Casing Size/Weight 7 5/8 in, 29.7 lbs/ft Pump Via Drill Pipe 4"O.D. (3.340".I.D) 14 Total Mix Water Required 1,687 gals Pre-Flush Fresh water ahead 50 bbls Density 8.3 ppg Plug Slurry Class G 342 sacks Density 15.8 ppg Yield 1.15 cf/sack Displacement Drilling fluid 143 bbls Density 8.5 ppg Page 1 Have more questions?You can find us at: http://www.bakerhughes.com/products-and-services/pressu re-pumping Operator Name: COOK INLET ENERGY LLC m.. Well Name: REDOUBT UNIT#2A BAKER Job Description: 15 8 ppg Plug below Retainer at 134008 HUGHES Date: November 5,2012 Proposal No: 1001147866F FLUID SPECIFICATIONS Pre-Flush 50.0 bbls Fresh water ahead @ 8.34 ppg PLUG VOLUME VOLUME NO. CU-FT FACTOR AMOUNT AND TYPE OF CEMENT 1 394 / 1.15 = 342 sacks Class G Cement+0.05%bwoc Static Free+0.4%bwoc R-3+0.3%bwoc CD-32+ 0.2%bwoc FL-52+1 gals/100 sack FP-6L+ 43.8%Fresh Water Displacement = 143.4 bbls Drilling fluid @ 8.5 ppg CEMENT PROPERTIES PLUG NO.1 Slurry Weight (ppg) 15.80 Slurry Yield (cf/sack) 1.15 Amount of Mix Water (gps) 4.93 Amount of Mix Fluid (gps) 4.94 PLUG GEOMETRY PLUG PLUG TOP BOTTOM 1 13400 ft to 14859 ft with 6.875 inch ID Casing Due to the possibility of solids bridging at the perfs,a solids free pre-flush is recommended. Page 2 Hare mon ques0ons' You can find us al hop Nwww bak.huphss wMpoduGsand-servicss/pnssua-pun4mg Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, January 29, 2013 11:28 AM To: 'courtney Rust' Cc: Davies, Stephen F (DOA) Subject: Redout 2A(PTD 212-172) Courtney, I have some comments for the PTD 1. In step#3 , testing to 6000 psi is not advised as the wellhead has a working pressure of 5000 Psi. I recommend reducing the BOP test pressure to 5000 psi. 2. in step 27 , once you drill out of the window a LOT or FIT must be performed with in 20-50' of the window. I need to know the minimum FIT/LOT value to drill ahead safely. 3. When you get ready to run 7"casing , need to change out Rams to 7"and test. Also , a FOSV and x- over must be on the rig floor ready to connect into the casing in case of a well control issue. 4. Since the ESP completion will not have a packer a"No Flow Test"will need to be done after production starts. 5. the Cement plug (390 sx) for the P&A appears to be calculated using 9 5/8" casing instead of 7 5/8" . Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 1/29/2013 Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Monday, November 26, 2012 11:35 AM To: 'David Hall' Cc: 'courtney Rust' Subject: RE: Redoubt Unit#2A(PTD 212-172) Spacing Exception David, I received your phone messages. My apologies—I was on vacation, and I recorded a vacation voice-mail greeting on AOGCC's phone system, but apparently failed to activate it. Per Regulation 20 AAC 25.055(a)(3), in an undefined oil pool only one well may be drilled and completed within a governmental quarter section. According to AOGCC's records, planned well Redoubt Unit No. 2A will be the second well completed in the NW 1/4 of Section 19. So unless I'm wrong, or AOGCC's records are incorrect, a spacing exception will be required. Please let me know if you have questions. Regards, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 Fax: 907-276-7542 1 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, January 23, 2013 10:42 AM To: 'courtney Rust' Subject: RU 2A redrill (PTD 212-171) Courtney, I have the PTD application for RU 2A sidetrack in my hands. I don't see where you submitted a 10-403 sundry to P &A Redoubt Unit 2. The steps are included in the PTD application but this must be a separate sundry application to abandon the RU 2 for the sidetrack. Steps 1-27 are actually the steps that should be included in the sundry to abandon RU 2. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 1/23/2013 Davies, Stephen F (DOA) From: courtney Rust[courtney.rust@cookinlet.net] Sent: Saturday, December 08, 2012 12:33 PM To: Davies, Stephen F (DOA) Subject: Re: Redoubt Unit#2 (PTD 212-172) Attachments: NAM 739 Forest Final Report.pdf Steve, Here it is. Page 15 shows 0%H2S. Sorry for the delay! Courtney From: "Davies, Stephen F (DOA)" <steve.davies@alaska.gov> Date:Thursday, December 6, 2012 1:23 PM To: courtney Rust<courtney.rustC«cookinlet.net> Subject: RE: Redoubt Unit#2 (PTD 212-172) Hi Courtney, Did you all ever get a chance to check on H2S measurements from the Redoubt Unit wells? Thanks, Steve Davies AOGCC From: Courtney Rust [mailto:courtney.rust@cookinlet.net] Sent: Monday, November 26, 2012 11:59 AM To: Davies, Stephen F (DOA) Subject: RE: Redoubt Unit #2 (PTD 212-172) I have tasked this out to our geologist and hope to have an answer for you very soon. From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Monday, November 26, 2012 11:25 AM To: courtney Rust Subject: RE: Redoubt Unit #2 (PTD 212-172) Courtney, Did you ever get a chance to check on H2S measurements from the Redoubt Unit wells? I need the information to complete my review of the Redoubt Unit No. 2A permit to drill application. Regards, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 1 Schlumberger Fluid Analysis on Bottomhole Samples Forest Oil Co. Redoubt Shoal Oil Field Redoubt Unit#2 Final Report Prepared For Paul Winslow Forest Oil Co. Standard Conditions Used: Pressure:14.696 psia Temperature:60°F Prepared By: Nikhil Joshi/Suyu Ye Reviewed By:Dennis D'Cruz Oilphase Houston A Schlumberger Company 2315 Schlumberger Street,Building 15 Houston,Texas,77023 (713)921-9500 Date:April 2002 Report NAM 739A Client: Forest Oil Field: Redoubt Shoal Oil Field Schlumberger Well: Redoubt Unit 2 Sand: Table 7: Reservoir Fluid Analysis(Sample#1.02) (Sample#1.02;SSB 9958-MA, 14005 ft.MD) Components Flashed Liquid Flashed Gas Monophasic Fluid Mole% Mass% Mole% Mass% : Mole% Mass Nitrogen 0.00 0.00 5.99 5.96 2.06 0.33 Carbon Dioxide 0.00 0.00 0.01 0.01 0.00 0.00 Hydrogen Sulfide 0,00 0.00 0.00 0.00 0.00 0.00 Methane 0.03 0.00 62.65 35.72 21.58 1.96 Ethane 0.07 0.01 6.05 6.47 2.13 0.36 Propane 0.45 0.08 9.88 15.48 3.69 0.92 1-Butane 0.43 0.10 3.72 7.68 1.56 0.51 N-Butane 1.15 0.26 5.57 11.50 2.67 0.88 -Pentane 1.22 0.35 2.13 5.46 1.53 0.63 N-Pentane 1.56 0.44 1.82 4.67 1.65 0.67 pseudo C6H14 ` 2.82 0.93 1.21 3.63 2.27 1.08 pseudo C7H16 6.23 2.35 0.76 2.59 4.35 2.36 pseudo C8H18 8.37 3.52 0.18 0.70 5.55 3.36 pseudo C9H20 6.23 2.96 0.02 0.09 4.09 2.80 pseudo C10H22 6.30 3.32 0.00 0.02 4.14 3.14 pseudo C11 H24 5.05 2.92 0.00 0.01 3.31 2.76 pseudo C12H26 4.23 2.67 0.00 0.00 2.77 2.53 pseudo C13H28 4.21 2.89 0.00 0.00 2.76 2.74 pseudo C14H30 3.79 2.83 0.00 0.00 2.49 2.67 pseudo C15H32 3.60 2.92 0.00 0.00 2.36 2.76 pseudo C16H34 2.88 2.51 1.89 2.37 pseudo C17H36 2.39 2.22 1.57 2.10 pseudo Cl 8H38 2.86 2.82 1.88 2.67 pseudo Cl 9H40 2.86 2.96 1.88 2.79 pseudo C20H42 2.12 2.29 1.39 2.16 pseudo C21 H44 1.81 2.07 1.19 1.96 pseudo C22H46 ; 1.76 2.07 1.15 1.96 pseudo C23H48 1.37 1.68 0.90 1.58 pseudo C24H50 1.63 2.07 1.07 1.96 pseudo C25H52 1.29 1.71 0.85 1.62 pseudo C26H54 1.15 1.58 0.76 1.49 pseudo C27H56 1.18 1.67 0.77 1.58 pseudo C28H58 1.07 1.56 0.70 1.48 pseudo C29H60 1.12 1.68 0.73 1.59 C30+ 18.77 42.56 12.31 40.22 1 Total 100 100 100 100 100 100 MW 254.49 28.14 176.60 MW of C30+ 577 577 MOLE RATIO 0.6559 0.3441 15 WCP-Oilphase PVT Report NAM 739A Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Monday, November 26, 2012 11:25 AM To: 'courtney Rust' Subject: RE: Redoubt Unit#2 (PTD 212-172) Courtney, Did you ever get a chance to check on H2S measurements from the Redoubt Unit wells? I need the information to complete my review of the Redoubt Unit No. 2A permit to drill application. Regards, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 Fax: 907-276-7542 1 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME 7C-d",-.>1Z /64 PTD# 2 /Z i/Development Service Exploratory Stratigraphic Test Non-Conventional Well /�/ FIELD: Ade;G7"c /(/'C t I- POOL: �� / of/1/ Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( _ PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. 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C Q -I 0 Qo aIQ Q w Q 0 Q Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. CCooookk IInnlleett EEnneerrggyy RRUU--22AA REDOUBT SHOALS Section 14 – T7N - R14W, SM Upper Cook Inlet, Alaska April 23, FINAL WELL REPORT Lees F. Browne Jr. – Senior Geological Adviser Steve Pike – Senior Logging Geologist Britton Adams – Logging Geologist Cook Inlet Energy RU-2A 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 ......................................................................................................13 3.3 WELL LITHOLOGY ....................................................................................................16 3.4 SAMPLING PROGRAM AND DISTRIBUTION ...........................................................30 4 DRILLING DATA.......................................................................................................................... 31 4.1 DAILY ACTIVITY SUMMARY.....................................................................................31 4.2 SURVEY DATA..........................................................................................................35 4.3 MUD RECORD...........................................................................................................37 4.4 BIT RECORD .............................................................................................................39 5 DAILY REPORTS......................................................................................................................... 40 Enclosures: 2”/ 100’ Formation Log (MD and TVD) 2”/ 100’ LWD Combo Log (MD and TVD) 2”/ 100’ Gas Ratio Log (MD and TVD) 2”/ 100’ Drilling Dynamics Log (MD and TVD) Final Well Data on CD Cook Inlet Energy RU-2A 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 Clean and Service Occasional loss due to loss of rig / mudlogging unit power Rate of Penetration (ROP) Primary Draw works Belt Driven Encoder On Drum Shaft (Quadco) 0 Pump stroke counter Externally Mounted Magnetic Proximity Sensor (Quadco) 0 Hook load / Weight on bit (WOB) Hydraulic Pressure Transducer (Quadco) 0 Drill string torque Varco Analog Feed 0 Top drive rotary (RPM) Varco Analog Feed 0 Standpipe Pressure Solid State Pressure Transducer 0 Casing Pressure Solid State Pressure Transducer 0 Mud flow in / out (MFI / MFO) MFI: Derived From SPM MFO: Flow Paddle (Quadco) 0 Pit volumes Radar Pit Probes 0 Driller’s work station Explosion Proof Touch Screen Quadco 0 Company Man’s work station Quadco 0 Tool pusher’s work station Quadco 0 Mud Engineer’s work station Quadco 0 Pits work station Quadco 0 MWD / LWD WITS Feed WITS 0 1.2 PERSONNEL Unit Number: ML04 Mudloggers Years Days Technician Days Sample Catchers Days Lees F. Browne 33 52 Steve Forrest 2 Omar Hinostroza 30 Steve Pike 12 41 Dicky Hudgins 30 Britten Adams 2 3 Cook Inlet Energy RU-2A 4 2 GENERAL WELL DETAILS 2.1 OBJECTIVES Osprey RU-2A is a development oil well planned to side track off of the original RU-2 well utilizing the existing casing program down to 8554’ MD. RU-2A will kick off from the 9 5/8” casing at 8554’ and drill a 8 1/2” hole section from 8554’ to 15325’ MD. 7” production casing will be run and cemented. The well will be completed with 4 ½” production tubing and an ESP completion. 2.2 WELL RESUME Operator: Cook Inlet Energy Well Name: RU-2A Field and Pool: Redoubt Shoals Unit Hemlock State : County Alaska; Kenai Borough Company Representatives: Don Jones, Mike Murray, Don Faulkner, Warren Johnson Location: SEC 14, T 7 N, R 14W SM Elevation: KB 89.10’ Classification: Development Oil API #: 50-733-20501-01-00 PERMIT # 212-172 AFE #: 111008 Rig Name / Type: Osprey Rig #1 Primary Target: Hemlock Oil, Tynonek G Sand Gas Spud Date :-> Finish Date :-> 4/23/13 – 5/29/13 Total Depth: 15360’ Total Depth Formation: West Foreland Mudlogging Company CANRIG DRILLING TECHNOLOGY, LTD MWD Company: Halliburton Tools Run: MWD: Survey, Gamma, Resis, Neu Por, Neu Den Directional Drilling: Halliburton Drilling Fluids Company: HALLIBURTON / BAROID Cook Inlet Energy RU-2A 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. 8.5” 15360’ 12460’ West Foreland 9.3 37.43° 9 5/8” 8554’ 7166’ - Cook Inlet Energy RU-2A 6 3 GEOLOGICAL DATA 3.1 FORMATION / ZONE MARKER TOPS ACTUAL FORMATION MD (ft) TVD (ft) SSTVD (ft) T-10 9200 7663 7574 MGS 10930 9001 8912 8500’ SAND 11437 9388 9298 PINK MKR 12071 9878 9789 TYONEK BLUE MKR 13190 10757 10668 RU 3 GAS SAND 13679 11137 11048 G ZN 13790 11221 11132 HEMLOCK COAL 14440 11717 11628 UPR HEMLOCK 14510 11772 11683 SILT ZONE 14726 11945 11855 MIDDLE HEMLOCK 14792 11999 11910 LWR HEMLOCK 15028 12194 12104 WF COAL 15220 12351 12262 WEST FORELAND 15360 12461 12372 Cook Inlet Energy RU-2A 7 3.2 ZONE SUMMARIES 3.2.1 Tyonek Formation T-10 : 9200’ MD, 7663’ TVD, 7574’ SSTVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 587 1 58 123 3 21 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 10145 123 23226 59 - - - - - COAL = BLACK WITH UNIFORM EVEN COLOR HUES; FIRM; RESINOUS LUSTER WITH EARTHY LUSTRES AT CONTACTS WITH INCREASED CARBON CLAY CONTENT; MATTE TEXTURE; HACKLY TO IRREGULAR PDC BIT FRACTURES; CUTTINGS OF VARIOUS SIZES FROM PDC BIT SHEARING AND GRINDING; COMPOSED OF PREDOMINANTLY BITUMINOUS COAL; SLIGHT VISIBLE BLEEDING GAS NOTED ON LARGER CUTTINGS. TUFFACEOUS SILTSTONE = LIGHT GRAY TO MEDIUM GRAY WITH SCATTERED WHITE ASH BLEBS INTERBEDDED; POORLY INDURATED WITH INCREASED ASH CONTENT TO MODERATE INDURATION IN SILTIER SECTIONS; BRITTLE TO MODERATELY RESISTANT; PDC GROOVED FRACTURE AND HABIT; EARTHY TO GREASY LUSTERS; SILTY TO GRITTY TO ASHY TEXTURES; MASSIVE GRADATIONAL ASHY SILTS, TRACE FRAMBOIDAL PYRITE AND INTERBEDDED TUFFITE; SPOTTY CONGLOMERATE SAND. SAND/SANDSTONE = MILKY WHITE TO WHITE WITH LIGHT TO MEDIUM GRAY WITH SOME TRANSLUCENT TO CLEAR; PREDOMINANTLY QUARTZ GRAIN SAND MATRIX WITH ABUNDANT DARK COLORED DARK COLORED LITHIC FRAGMENTS; UPPER FINE GRAIN TO UPPER COARSE GRAIN SAND; POORLY SORTED; VERY WELL ROUNDED TO SUBANGULAR; MODERATE TO HIGH SPHERICITY; THICKER BEDS OF MOSTLY LOOSE UNCEMENTED SAND INTERBEDDED WITH VERY THIN LENSES OF VERY FINE TO FINE GRAINED SILICEOUS CEMENTED FRIABLE SANDSTONES WITH THICKER BEDS OF TUFFACEOUS SILTSTONES, LAMINATED DARK COLORED CARBONACEOUS MATERIAL. TUFFACEOUS CLAYSTONE = DARK GRAY TO MEDIUM DARK GRAY WITH SOME LIGHT GRAY; MOSTLY CRUMBLY TO SLIGHTLY CRUNCHY; IRREGULAR FRACTURE; MASSIVE TO PDC GROOVED CUTTING HABIT; RESINOUS TO SOMEWHAT GREASY LUSTER; PREDOMINANTLY CLAYEY TEXTURE GRADING TO VERY SILTY WITH LESSER AMOUNTS OF GRITTY TEXTURE; THINNER BEDS OF TUFFACEOUS CLAYSTONES INTERBEDDED WITH THICKER BEDS OF TUFFACEOUS SILTSTONES, AND LAMINATIONS OF WHITE TO BUFF COLORED TUFF, AND DARK COLORED CARBONACEOUS CLAY + CARBON SHALE. Cook Inlet Energy RU-2A 8 MGS : 10930’ MD, 9001’ TVD, 8912’ SSTVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 242 1 47 72 4 13 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 11250 72 10888 37 - - - - - SAND/TUFFACEOUS SAND = VERY LIGHT GRAY; CLAST SIZE COARSE LOWER TO MEDIUM LOWER; TRACE VERY COARSE UPPER SUB ANGULAR TO SUB ROUND; SCATTERED ANGULAR BIT IMPACTED FRAGMENTS; MODERATE DEVELOPED SPHERICITY; TRACE PROLATED GRAINS; GENERALLY EQUANT; MODERATE SORTING; IMPACTED TO CHIP TEXTURE; SUB MATURE NATURE; BOTH GRAIN AND SILT/ASH MATRIX WHICH IS PORE FILLING AND ACTING AS A LITHIFYING AGENT; COMPOSED QUARTZ WITH SECONDARY CHERT AND TRACE LITHICS; POOR TO SOME FAIR POROSITY; POOR PERMEABILITY; NO OIL INDICATORS: OBM TUFFACEOUS SILTSTONE = MEDIUM GRAY TO DARK GRAY WITH SOME LIGHT GRAY; CLUMPY TO SLIGHTLY FIRM; CRUMBLY TO CRUNCHY; AMORPHOUS TO IRREGULAR FRACTURE; MASSIVE TO PDC GROOVED CUTTINGS HABIT; MOSTLY EARTHY TO SLIGHTLY GREASY; PREDOMINANTLY SILTY GRADING TO CLAYEY AND GRITTY; THICKER BEDS OF TUFFACEOUS SILTSTONES INTERBEDDED WITH THIN BEDS OF TUFFACEOUS CLAYSTONES AND VERY THIN BEDS OF VERY FRIABLE TUFFACEOUS SANDSTONES; ABUNDANT LAMINATIONS OF CARBONACEOUS MATERIAL AND TUFF; VERY THIN COALS BEDS THROUGHOUT. SANDSTONE/SAND = LIGHT GRAY TO WHITE WITH SOME TRANSLUCENT TO CLEAR; VERY FRIABLE QUARTZ GRAIN SAND SUPPORTED WITH A SILTY TO CLAYEY TO TUFFACEOUS MATRIX, SLIGHTLY CEMENTED; UPPER FINE GRAIN TO UPPER COARSE; POORLY SORTED; VERY ANGULAR TO SUBANGULAR WITH SOME VERY WELL ROUNDED TO SUBROUNDED; MODERATE TO HIGH SPHERICITY; THICKER BEDS OF FRIABLE SILICEOUS CEMENTED SANDSTONE AND LOOSE QUARTZ SAND INTERBEDDED WITH TUFFACEOUS SILTSTONES AND CLAYSTONES; OBM FLUORESCENCE. Cook Inlet Energy RU-2A 9 8500’ SAND : 11437’ MD, 9388’ TVD, 9298’ SSTVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 130 1 33 75 7 16 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 11452 75 12953 74 - - - - - TUFFACEOUS CLAYSTONE = DARK GRAY TO MEDIUM GRAY; SLIGHTLY FIRM TO CLUMPY; MOSTLY BRITTLE TO SOMEWHAT CRUNCHY; IRREGULAR FRACTURE; MASSIVE CUTTINGS HABIT TO PDC GROOVED CUTTINGS HABIT; EARTHY TO SLIGHTLY DULL; MOSTLY CLAYEY TEXTURE, WITH SOME GRADING TO SILTY; VERY THIN BEDS OF TUFFACEOUS CLAYSTONES INTERBEDDED WITH THICKER BEDS OF TUFFACEOUS SILTSTONES AND THIN BEDS OF LOOSE UNCEMENTED QUARTZ SAND AND FRIABLE SILICEOUS CEMENTED SANDSTONES; ABUNDANT LAMINATIONS OF CARBONACEOUS MATERIALS AND SMALL BEDS OF COAL; LARGER COAL BED WAS OBSERVED AT 11400' TO 11415' AND 11450' TO 11460'. TUFFACEOUS SANDSTONE/SAND = OFF WHITE TO VERY LIGHT GRAY BECOMING YELLOWISH GRAY IN SILT/ASH MATRIX; CLAST SIZE MEDIUM UPPER TO FINE UPPER; SUB ROUND; WELL DEVELOPED SPHERICITY; EQUANT GRAINS; MODERATE SORTING; POLISH-PITTED- IMPACT TEXTURE; SUB MATURE NATURE; MODERATE TO ABUNDANT ASH/SILT MATRIX GRADING TO SANDY TUFFACEOUS SANDSTONE; ASHY WITH PORE FILLING AND LITHIFYING AGENT; COMPOSED OF >90% QUARTZ SECONDARY CHERT AND TRACE LITHICS; POOR POROSITY; SOME LOOSE SANDS; OIL BASE MUD. TUFFACEOUS SILTSTONE = LIGHT GRAY TO MEDIUM GRAY TO LIGHT HUES OF BROWNISH GRAY; POOR TO MODERATE INDURATION; PDC BIT FRACTURE AND HABIT; EARTHY TO GREASY LUSTER; SILTY TEXTURE; MASSIVE GRADATIONAL TUFFACEOUS SILTS INTERBEDDED WITH ASH, VERY FINE SAND AND OR PYRO CLASTIC RELIC SHARDS AND VARIOUS DETRITAL MATERIAL. COAL = BLACK MOTTLED BROWN BLACK AT CONTACTS; BRITTLE TO FIRM AT MASS CENTER; RESINOUS TO EARTHY LUSTER; UNIFORM PDC BIT HACKLY FRACTURE/HABIT; COMPOSED OF BITUMINOUS TO LIGNITIC. PINK MKR: 12071’ MD, 9878’ TVD, 9789’ SSTVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 172 0 28 78 1 14 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 13052 78 16181 12 - - - - - Cook Inlet Energy RU-2A 10 TUFFACEOUS CLAYSTONE = DARK GRAY TO MEDIUM GRAY; SLIGHTLY FIRM TO CLUMPY; MOSTLY BRITTLE TO SOMEWHAT CRUNCHY; IRREGULAR FRACTURE; MASSIVE CUTTINGS HABIT TO PDC GROOVED CUTTINGS HABIT; EARTHY TO SLIGHTLY DULL; MOSTLY CLAYEY TEXTURE, WITH SOME GRADING TO SILTY; VERY THIN BEDS OF TUFFACEOUS CLAYSTONES INTERBEDDED WITH THICKER BEDS OF TUFFACEOUS SILTSTONES AND VERY THIN LENSES OF LOOSE UNCEMENTED SAND; ABUNDANT LAMINATIONS OF CARBONACEOUS MATERIAL AND COAL.. TUFFACEOUS SILTSTONE = MEDIUM GRAY TO DARK GRAY; SLIGHTLY FIRM TO CLUMPY; MOSTLY CRUNCHY TO SOMEWHAT BRITTLE; IRREGULAR FRACTURE; PDC GROOVED TO SOMEWHAT MASSIVE CUTTINGS HABIT; EARTHY TO SLIGHTLY DULL; MOSTLY SILTY TEXTURE, WITH SOME GRADING TO CLAYEY; VERY THICKER BEDS OF TUFFACEOUS SILTSTONES INTERBEDDED WITH THINNER BEDS OF TUFFACEOUS CLAYSTONES, AND VERY THIN LENSES OF LOOSE UNCEMENTED QUARTZ SAND; ABUNDANT LAMINATIONS OF CARBONACEOUS MATERIAL AND VERY THIN BEDS OF COAL. SAND = VERY LIGHT GRAY; CLAST SIZE RANGES MEDIUM UPPER TO FINE UPPER; SUB ROUND; MODERATE TO SOME WELL DEVELOPED SPHERICITY; SOME PROLATED GRAINS; GENERAL EQUANT GRAIN DIMENSIONS; MODERATE TO WELL SORTING; IMPACTED TO POLISHED TEXTURE; MATURE NATURE; ARENACEOUS; DOMINANT GRAIN SUPPORT; NO VISIBLE MATRIX MATERIAL; UNCONSOLIDATED; GOOD ESTIMATED POROSITY AND PERMEABILITY NO OIL INDICATORS w/ OIL BASE MUD. SAND/TUFFACEOUS SANDSTONE = CLEAR, WITH LIGHT BROWNISH GRAY HUES; PREDOMINANTLY QUARTZ SAND MATRIX WITH ABUNDANT LIGHT AND DARK COLORED LITHIC FRAGMENTS THROUGHOUT THE SAMPLE; UPPER FINE GRAIN TO UPPER MEDIUM GRAIN SAND; FAIR TO WELL SORTED; VERY WELL ROUNDED TO SUBROUNDED WITH SOME VERY ANGULAR; MODERATE TO HIGH SPHERICITY; THINNER BEDS OF LOOSE QUARTZ SAND AND VERY FINE GRAINED, FRIABLE TUFFACEOUS SANDSTONES INTERBEDDED WITH THICK BEDS OF TUFFACEOUS SILTSTONES AND TUFFACEOUS CLAYSTONES; OBM FLUORESCENCE; NO OTHER PETROLEUM INDICATORS WERE OBSERVED. COAL = BLACK TO GRAYISH BLACK; VERY STIFF TO FIRM; MOSTLY DENSE TO BRITTLE ALONG BEDDING PLANES; PREDOMINANTLY IRREGULAR FRACTURE WITH SOME BLOCKY; MOSTLY MASSIVE WITH SOME PLATY CUTTINGS HABIT; VITREOUS LUSTER; VERY SMOOTH TEXTURE; LAMINATIONS OF SMALLER COALS. TYONEK BLUE MKR : 13190’ MD, 10757’ TVD, 10668’ SSTVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 264 1 57 161 14 32 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 13465 161 27106 39 27 - - - - Cook Inlet Energy RU-2A 11 SAND/SANDSTONE = MOSTLY CLEAR, WITH LIGHT BROWNISH GRAY HUES; PREDOMINANTLY QUARTZ SAND MATRIX WITH ABUNDANT LIGHT AND DARK COLORED LITHIC FRAGMENTS THROUGHOUT THE SAMPLE; UPPER FINE GRAIN TO UPPER MEDIUM GRAIN SAND; FAIR TO WELL SORTED; VERY WELL ROUNDED TO SUBROUNDED WITH SOME VERY ANGULAR; MODERATE TO HIGH SPHERICITY; THINNER BEDS OF LOOSE QUARTZ SAND AND VERY FINE GRAINED, AND VERY FRIABLE SANDSTONES INTERBEDDED WITH THICK BEDS OF TUFFACEOUS SILTSTONES AND TUFFACEOUS CLAYSTONES; OBM FLUORESCENCE; NO OTHER PETROLEUM INDICATORS WERE OBSERVED. TUFFACEOUS SILTSTONE = DARK GRAY TO MEDIUM DARK GRAY WITH SOME MEDIUM GRAY; MOSTLY STIFF TO SLIGHTLY CLAYEY; BRITTLE; AMORPHOUS TO IRREGULAR FRACTURE; MOSTLY MASSIVE CUTTINGS HABIT, WITH PDC GROOVED; MOSTLY EARTHY TO SLIGHTLY DULL LUSTER; VERY SILTY TEXTURE WITH SOME GRADING TO CLAYEY AND SLIGHTLY GRITTY; THICK BEDS OF TUFFACEOUS SILTSTONES INTERBEDDED WITH THIN BEDS OF TUFFACEOUS CLAYTONES AND VERY FINE GRAINED FRIABLE TUFFACEOUS SANDSTONES AND LOOSE QUARTZ SAND; ABUNDANT LAMINATIONS OF TUFF, AND CARBONACEOUS MATERIAL WITH VERY SMALL COALS. TUFFACEOUS SILTSTONE/DEVITRIFIED ASH = YELLOWISH GRAY MOTTLED WHITE (ASH) TO MEDIUM GRAY; POORLY INDURATED; BRITTLE; CRUMBLY; SLIGHTLY COHESIVE; NON ADHESIVE; PDC TO EARTHY FRACTURE WITH DEVELOPED SUB NODULAR HABIT THROUGH WELLBORE EROSIONAL TRANSPORT OF FRAGILE DEVITRIFIED ASH; EARTHY MOTTLED GREASY LUSTER; ASHY TEXT; MICRO TO THIN ASH BLEBS AND LAMINAR PATTERNS; TRACE VISIBLE ASH EXPANSION; INTERBEDDED MEDIUM GRAIN LOOSE SAND AND TUFFACEOUS SANDSTONE IN THIN BEDS COAL = BLACK; FIRM; RESINOUS LUSTER; HACKLY PDC FRACTURE; MATTE TEXTURE; COMPOSED OF BITUMINOUS COAL AND CARBON SHALE NEAR CONTACTS; NO VISIBLE BLEEDING GAS. TUFFACEOUS SAND / SAND = VERY LIGHT GRAY TO YELLOWISH GRAY IN ASH MATRIX; CLAST SIZE RANGE COARSE LOWER TO MEDIUM LOWER; SUB ROUND; WELL DEVELOPED SPHERICITY; EQUANT GRAIN DIMENSIONS; MODERATE SORTING; POLISH TEXTURE; SUB MATURE NATURE; BOTH LOOSE GRAINS AND AS ABUNDANT ASH/SILT MATRIX SUPPORT AND INTERBEDDED; PORE FILLING AND LOOSELY ATTACHED; COMPOSED OF >90% QUARTZ; TRACE CHERT; POOR POROSITY AND PERMEABILITY; NO OIL INDICATORS WITH OIL BASE MUD. RU 3 GAS SAND : 13679’ MD, 11137’ TVD, 11048’ SSTVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 127 0 48 140 16 27 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 13778 140 19556 73 36 - - - - Cook Inlet Energy RU-2A 12 TUFFACEOUS SILTSTONE = MEDIUM DARK GRAY TO DARK GRAY WITH SOME MEDIUM GRAY; STIFF TO MOSTLY CLUMPY; VERY BRITTLE; MOSTLY AMORPHOUS TO IRREGULAR FRACTURE; PDC GROOVED TO MASSIVE CUTTINGS HABIT; MOSTLY EARTHY TO DULL LUSTER; VERY SILTY TEXTURE WITH SOME GRADING TO GRITTY AND CLAYEY; VERY THICK BEDS OF TUFFACEOUS SILTSTONES INTERBEDDED WITH VERY FINE GRAINED, FRIABLE TUFFACEOUS SANDSTONES, WITH LESSER AMOUNTS OF LOOSE QUARTZ SAND; ABUNDANT LAMINATIONS OF TUFF, CARBONACEOUS MATERIALS AND VERY THIN COALS THROUGHOUT THE SAMPLE . G ZN: 13790’ MD, 11221’ TVD, 11132’ SSTVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 414 1 52 164 10 24 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 13886 164 25910 202 44 - - - - COAL = BLACK; VERY STIFF; VERY STIFF FIRM TO MOSTLY DENSE; HACKLY PDC FRACTURE; MASSIVE CUTTINGS HABIT; VITREOUS LUSTER; SMOOTH; NO OFF GASSING WAS OBSERVED . SAND/TUFFACEOUS SANDSTONE = PREDOMINANTLY TRANSLUCENT TO CLEAR , WITH LIGHT BROWNISH GRAY HUES; PREDOMINANTLY QUARTZ SAND MATRIX WITH ABUNDANT LIGHT AND DARK COLORED LITHIC FRAGMENTS THROUGHOUT; UPPER FINE GRAIN TO UPPER MEDIUM GRAIN SAND; FAIR TO WELL SORTED; VERY ANGULAR TO SUBANGULAR WITH SOME SUB ROUNDED; MODERATE TO HIGH SPHERICITY; THINNER BEDS OF LOOSE QUARTZ SAND AND FINE GRAINED, AND VERY FRIABLE TUFFACEOUS SANDSTONES INTERBEDDED WITH THICK BEDS OF TUFFACEOUS SILTSTONES AND TUFFACEOUS CLAYSTONES; OBM FLUORESCENCE; NO OTHER PETROLEUM INDICATORS WERE OBSERVED. SAND = VERY LIGHT GRAY TO WHITE BECOMING LIGHT YELLOWISH GRAY w/ INTERBEDDED ASH; CLAST SIZE RANGES COARSE LOWER TO MEDIUM LOWER SCATTERED COARSE UPPER; SUB ROUND TO ROUNDED; MODERATE TO WELL DEVELOPED SPHERICITY; GENERAL EQUANT GRAIN DIMENSIONS; MODERATE SORTING; POLISH TEXTURE; SUB MATURE NATURE; MODERATE TO ABUNDANT ASH SILT MATRIX; DOMINANT MATRIX SUPPORT; MINOR TUFFACEOUS SANDSTONE; ASH MATRIX IS HYDROPHILIC; COMPOSED OF >90% QUARTZ TRACE CHERT; POOR POROSITY AND POOR PERMEABILITY; NO OIL INDICATORS w/ OBM. TUFFACEOUS SILTSTONE = VERY LIGHT GRAY TO SALT AND PEPPER TO OFF WHITE IN ASHY SECTIONS; POORLY INDURATED; BRITTLE; VERY SLIGHT COHESIVE SLIGHTLY ADHESIVE; PDC GROOVED FRACTURE AND HABIT WITH EROSIONAL SUB NODULAR FEATURES FROM WELL BORE TRANSPORT; SILTY TO ASHY TEXTURE; VISIBLE PYROCLASTIC RELIC SHARDS IN MASS; DETRITAL GRADATIONAL BEDS OF SILT, ASH AND SAND. DEVITRIFIED ASH = SALT AND PEPPER TO OFF WHITE TO VERY LIGHT GRAY HUES; VERY SOFT; GREASY LUSTER; ASHY TEXTURE; REWORKED AND REDEPOSITED; VISIBLE PYRO CLASTIC RELIC SHARDS WITH VARIOUS DETRITAL MATERIAL INTERBEDDED; EXPANSIVE WHEN REHYDRATED. Cook Inlet Energy RU-2A 13 3.2.2 Hemlock Formation HEMLOCK COAL: 14440’ MD, 11717’ TVD, 11628’ SSTVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 117 1 26 44 20 26 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 14456 44 6001 83 18 - - - - SAND/SANDSTONE = VERY LIGHT GRAY TO PINKISH GRAY (INTEBEDDED TUFF); CLAST SIZE FINE UPPER TO MEDIUM UPPER; SUB ROUND TO ROUNDED; WELL DEVELOPED SPHERICITY; MODERATE SORTING; POLISH TO PITTED TEXTURE; BOTH GRAIN AND MATRIX SUPPORTED OF ASH/TUFF; PORE FILLS AND LOOSELY ATTACHED; COMPOSED OF >90% QUARTZ MINOR CHERT; FAIR POROSITY AND POOR PERMEABILITY; NO OIL INDICATORS UPR HEMLOCK: 14510’ MD, 11772’ TVD, 11683’ SSTVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 61 1 18 33 15 27 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 14628 33 4683 259 52 26 17 14 13 SAND/SANDSTONE/CONGLOMERATE SAND = VERY LIGHT GRAY TO YELLOWISH GRAY; CLAST SIZE COARSE UPPER TO MEDIUM LOWER; SUB ROUND; TRACE ANGULAR BIT IMPACTED COARSE GRAINS; POOR DEVELOPED SPHERICITY; POLISH TO PITTED TEXTURES; SANDSTONES MODRATELY RESISTANT TO SHEARING CLUSTERS; DOMINANT GRAIN SUPPORT WITH SLIGHT MATRIX SUPPORT IN PARTS; COMPOSED OF PREDOMINANTLY QUARTZ SECONDARY CHERT, TRACE ARGILLITE, FELDSPAR; FAIR POROSITY AND PERMEABILITY OBM FLUORESCENCE. SANDSTONE/SAND = WHITE, TRANSLUCENT TO CLEAR, YELLOWISH GRAY, PINKISH GRAY AND LIGHT BLUISH GRAY HUES; UPPER FINE GRAIN TO UPPER COARSE; FAIR TO POOR SORTED; VERY ANGULAR TO SUBANGULAR, WITH SOME VERY WELL ROUNDED; HIGH SPHERICITY MATRIX SAND UNCEMENTED SAND INTERBEDDED WITH MOSTLY GRAIN SUPPORTED FINE GRAINED, FRIABLE SANDSTONES; OBM FLUORESCENCE THROUGHOUT SAMPLE. . Cook Inlet Energy RU-2A 14 SILT ZONE : 14726’ MD, 11945’ TVD, 11855’ SSTVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 46 1 15 30 18 23 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 14734 30 3962 288 24 7 7 9 10 TUFFACEOUS SILTSTONE = YELLOWISH GRAY TO VERY LIGHT GRAY AND VARIOUS HUES OF BOTH MODERATE INDURATION MODERATE RESISTANT; MODERATE COHESIVE; NON ADHESIVE; PDC BIT GROOVED FRACTURE AND HABIT; EARTHY LUSTER; SILTY TO ABRASIVE TEXTURE; GRADATIONAL SILTS COMPOSED OF >90% FRIABLE SILT AND MICRO VARIOUS DETRITAL MATERIAL . MIDDLE HEMLOCK : 14792’ MD, 11999’ TVD, 11910’ SSTVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 46 1 18 35 19 27 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 14935 35 4073 431 35 12 13 2 - CONGLOMERATE SAND, SAND, SANDSTONE = VERY LIGHT GRAY TO LIGHT YELLOWISH GRAY TO LIGHT GREENISH GRAY; CLAST SIZE COARSE UPPER TO MEDIUM LOWER; ANGULAR BIT IMPACT GRAINS TO SUB ROUND MEDIUM MATRIX SANDS; MODERATE DEVELOPED SPHERICITY IN MEDIUM MATRIX SANDS TO LOW IN COARSE GRAINS; POOR SORTING; BIMODAL w/ COARSE AND MEDIUM GRAINS; POLISH AND CHIP COARSE TO IMPACT MEDIUM GRAINS; MODERATE TO WEAK SILICEOUS CEMENT; GRAIN SUPPORTED; COMPOSED OF 90% QUARTZ, 10% CHERT AND LITHIC FRAGMENTS; FAIR POROSITY AND PERMEABILITY; NO OIL INDICATORS WITH OIL BASE MUD IN THE SYSTEM. LWR HEMLOCK : 15028’ MD, 12194’ TVD, 12104’ SSTVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 47 1 22 35 17 26 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 15202 35 4369 583 58 - - 2 - Cook Inlet Energy RU-2A 15 CONGLOMERATE SAND/SAND = VERY LIGHT GRAY TO LIGHT GRAY TO LIGHT YELLOWISH GRAY; CLAST SIZE VERY COARSE UPPER TO MEDIUM LOWER; MEAN SIZE IS COARSE LOWER TO MEDIUM UPPER; ANGULAR BIT IMPACTED COARSE GRAINS TO SUB ROUND MEDIUM MATRIX GRAINS; LOW TO MODERATE DEVELOPED SPHERICITY; POOR SORTING; POLISH AND CHIP COARSE GRAINS TO IMPACT MEDIUM GRAINS; MATURE NATURE; DOMINANT UNCONSOLIDATED WITH SCATTERED WEAK CONSOLIDATED CLUSTERS; DOMINANT GRAIN SUPPORT; VERY LITTLE INTER GRAIN ASH/SILT; COMPOSED OF 90% QUARTZ, 10% CHERT, TRACE LITHICS; FAIR ESTIMATED POROSITY AND PERMEABILITY; NO OIL INDICATORS WITH OIL BASE MUD. WEST FORELAND WF COAL : 15220’ MD, 12351’ TVD, 12262’ SSTVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 59 2 18 35 10 21 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 15234 35 4311 496 32 - - 2 6 TUFFACEOUS SILTSTONE = MEDIUM GRAY TO LIGHT GRAY TO LIGHT YELLOWISH GRAY; POOR TO MODERATE INDURATION; CRUMBLY; SLIGHT TO MODERATE COHESIVENESS; NON ADHESIVE; PDC BIT GROOVED FRACTURE AND HABIT TO SUB NODULAR SMALLER CLUSTERS; EARTHY LUSTER; SILTY TO GRITTY TEXTURE; THIN BEDS OF GRADATIONAL TUFFACEOUS SILT GRADING TO MEDIUM GRAIN UNCONSOLIDATED SAND. SAND/CONGLOMERATE SAND = VERY LIGHT GRAY; TRANSLUCENT; CLAST SIZE COARSE LOWER TO FINE LOWER; MEAN SIZE MEDIUM UPPER TO FINE UPPER; SUB ANGULAR TO SUB ROUND; MODERATE DEVELOPED SPHERICITY; INCREASE IN PROLATED GRAINS; ANGULAR BIT IMPACTED COARSER GRAINS; CHIP TO IMPACT TEXTURE; SUB MATURE TO MATURE NATURE; UNCONSOLIDATED; GRAIN SUPPORT WITH SECONDARY MATRIX SUPPORT; FAIR ESTIMATED POROSITY AND PERMEABILITY GRADED BEDS OF TUFFACEOUS SILT AND SAND; NO OIL INDICATORS WITH OIL BASE MUD. WEST FORELAND : 15360’ MD, 12461’ TVD, 12372’ SSTVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 59 2 18 35 10 21 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 15234 35 4311 496 32 - - 2 6 Cook Inlet Energy RU-2A 16 3.3 WELL LITHOLOGY SAND (8590 - 8665) = MILKY WHITE TO WHITE, WITH SOME LIGHT TO MEDIUM GRAY, TRANSLUCENT TO CLEAR; PREDOMINANTLY QUARTZ GRAIN SAND MATRIX, WITH SOME DARK COLORED LITHIC FRAGMENTS THROUGHOUT SAMPLE; UPPER VERY FINE TO UPPER MEDIUM GRAIN; MOSTLY FAIR TO WELL SORTED THROUGHOUT; VERY WELL ROUNDED TO SUBROUNDED, WITH SOME SUBANGULAR TO VERY ANGULAR; MODERATE TO HIGH SPHERICITY; THICKER BEDS OF QUARTZ SAND INTERBEDDED WITH LIGHT GRAY TO WHITE TO BUFF COLORED TUFFACEOUS SILTSTONES; OBM FLUORESCENCE THROUGHOUT; NO OTHER PETROLEUM INDICATORS WERE OBSERVED. TUFFACEOUS SILTSTONE (8670 - 8740) = WHITE TO LIGHT GRAY TO BUFF, DARK GRAY TO BLACK HUES; MOSTLY MUSHY TO SLIGHTLY PASTY; PREDOMINANTLY BRITTLE TO CRUMBLY; IRREGULAR FRACTURE; AMORPHOUS CUTTINGS HABIT; RESINOUS TO SLIGHTLY WAXY LUSTER IN PLACES; VERY SILTY TO CLAYEY TEXTURE WITH SOME SLIGHTLY GRITTY; THINNER BEDS OF TUFFACEOUS SILTSTONE INTERBEDDED WITH FINE GRAINED MOSTLY LOOSE UNCEMENTED QUARTZ SAND; THIS SAMPLE WAS SLIGHTLY CALCAREOUS; DARK COLORED CARBONACEOUS MATERIAL THROUGHOUT THE SAMPLE. SAND/SANDSTONE (8745 - 8840) = CLEAR TO TRANSLUCENT WITH WHITE, MILKY WHITE, LIGHT GRAY TO DARK GRAY, BUFF, AND VERY PALE GREEN TO LIGHT BLUE GREEN HUES; MOSTLY LOOSE QUARTZ GRAIN SAND WITH ABUNDANT DARK COLORED LITHIC FRAGMENTS; UPPER VERY FINE GRAIN TO LOWER COARSE GRAIN; POOR TO FAIRLY SORTED; VERY ANGULAR TO VERY WELL ROUNDED; MODERATE TO HIGH SPHERICITY; THICKER SEAMS OF MOSTLY LOOSE UNCEMENTED QUARTZ SAND INTERBEDDED WITH VERY THIN BEDS OF VERY FRIABLE SLIGHTLY CALCAREOUS CEMENTED SANDSTONES AND TUFFACEOUS SILTSTONES AND TUFFACEOUS CLAYSTONES; VERY THIN BEDS OF BLACK COAL AND DARK COLORED CARBONACEOUS MATERIAL; VERY LITTLE OFF GASSING; OBM FLUORESCENCE; NO OTHER PETROLEUM INDICATORS WERE OBSERVED. TUFFACEOUS CLAYSTONE (8845 - 8905) = LIGHT GRAY TO MEDIUM DARK GRAY; PASTY TO MUSHY; CRUMBLY; MOSTLY IRREGULAR FRACTURE WITH SOME SLIGHTLY PLANAR; MASSIVE CUTTING HABIT; EARTHY LUSTER WITH SOME GREASY TO RESINOUS; VERY CLAYEY TEXTURE GRADING TO SILTY WITH SOME SLIGHTLY GRITTY IN PLACES; THINNER BEDS OF TUFFACEOUS CLAYSTONES INTERBEDDED WITH LOOSE QUARTZ SAND AND TUFFACEOUS SILTSTONES; LAMINATIONS OF DARK COLORED CARBONACEOUS MATERIAL THROUGHOUT. COAL (8890 - 8910) = BLACK TO GRAYISH BLACK; VERY FIRM TO STIFF; DENSE TO TUFF; MOSTLY IRREGULAR TO BLOCKY FRACTURE; MASSIVE CUTTINGS HABIT; VERY RESINOUS TO SOMEWHAT VITREOUS; MOSTLY SMOOTH TEXTURE; THICKER BEDS OF COAL; SOME OFF GASSING OBSERVED; OCCURS AS THICK HOMOGENOUS BED AT 8890-8910 AND AS THIN TO LAMINAE AFTER 8910’. SAND/SANDSTONE (8910-9040) = VERY LIGHT GRAY TO PALE YELLOWISH ORANGE AND PINK GRAY HUES WITH INTERBEDDED TUFF + ASH MATRIX IN SANDSTONES @ 9000’; CLAST SIZE RANGES FROM MEDIUM LOWER TO VERY FINE UPPER AND GRADING TO SILT; MODERATE DEVELOPED SPHERICITY; EQUANT GRAINS; MODERATE TO POOR SORTING; IMPACT TO PIT TEXTURES; SUB MATURE NATURE; SAND GRADES TO DENSE SANDSTONE @ 9000’ WITH BOTH MATRIX AND SECONDARY GRAIN SUPPORT; ASH AND SILT ACTING AS LITHIFYING AGENT; POOR TO FAIR POROSITY @ 8975’ DECREASING WITH DEPTH TO POOR @ 9020’; OIL BASE MUD. COAL (9040-9080) = BLACK EVEN COLOR HUE; FIRM; RESINOUS TO SUB EARTHY LUSTRE; HACKLY TO IRREGULAR FRACTURE; SOME PDC GROUND UP CUTTINGS; SLIGHT VISIBLE BLEED OF GASES FROM CUTTINGS; COMPOSED OF TWO BEDS OF BITUMINOUS COAL AT 9040’ + 9070’. Cook Inlet Energy RU-2A 17 SAND/TUFFACEOUS SANDSTONE (9080-9210) = VERY LIGHT GRAY TO WHITISH HUES IN ASH LADEN SANDSTONES; CLAST SIZE MEDIUM LOW TO FINE LOWER GRADING TO SILT; SUB ROUND TO ROUNDED; MODERATE TO WELL DEVELOPED SPHERICITY; EQUANT GRAINS; MODERATE SORT IN SAND TO POOR IN SANDSTONES; MATURE SAND TO IMMATURE SANDSTONES; TUFFACEOUS SANDSTONES DISAGGRATED EASILY AND ARE MATRIX SUPPORTED; COMPOSED OF >90% QUARTZ, TRACE CHERT; SMALL COAL @ 9125’; INCREASED MEDIUM GRAY TUFFACEOUS SILTS BENEATH COAL HORIZON WITH INCREASED SILT CONTENT DISPLAYING PDC BIT CUTTING WITH PDC METAMORPHISM CAUSED BY COMPRESSIVE DISPLACEMENT MATRIX FAILURE AND PLASTIC DEFORMATION WITH CUTTINGS DISPLAYING IMPACT CUT PIECES WITH PARALLEL CRENULATIONS ON ONE SIDE AND POLISHED SMOOTH ON THE OTHER SIDE. COAL (9210-9235) = BLACK WITH UNIFORM EVEN COLOR HUES; FIRM; RESINOUS LUSTER WITH EARTHY LUSTRES AT CONTACTS WITH INCREASED CARBON CLAY CONTENT; MATTE TEXTURE; HACKLY TO IRREGULAR PDC BIT FRACTURES; CUTTINGS OF VARIOUS SIZES FROM PDC BIT SHEARING AND GRINDING; COMPOSED OF PREDOMINANTLY BITUMINOUS COAL; SLIGHT VISIBLE BLEEDING GAS NOTED ON LARGER CUTTINGS. TUFFACEOUS SILTSTONE (9235-9290 ) = LIGHT GRAY TO MEDIUM GRAY WITH SCATTERED WHITE ASH BLEBS INTERBEDDED; POORLY INDURATED WITH INCREASED ASH CONTENT TO MODERATE INDURATION IN SILTIER SECTIONS; BRITTLE TO MODERATELY RESISTANT; PDC GROOVED FRACTURE AND HABIT; EARTHY TO GREASY LUSTERS; SILTY TO GRITTY TO ASHY TEXTURES; MASSIVE GRADATIONAL ASHY SILTS TRACE FRAMBOIDAL PYRITE AND INTERBEDDED TUFFITE; SPOTTY CONGLOMERATE SAND AND SAND @ 9265’. SAND/SANDSTONE (9320 - 9400) = MILKY WHITE TO WHITE WITH LIGHT TO MEDIUM GRAY WITH SOME TRANSLUCENT TO CLEAR; PREDOMINANTLY QUARTZ GRAIN SAND MATRIX WITH ABUNDANT DARK COLORED DARK COLORED LITHIC FRAGMENTS; UPPER FINE GRAIN TO UPPER COARSE GRAIN SAND; POORLY SORTED; VERY WELL ROUNDED TO SUBANGULAR; MODERATE TO HIGH SPHERICITY; THICKER BEDS OF MOSTLY LOOSE UNCEMENTED SAND INTERBEDDED WITH VERY THIN LENSES OF VERY FINE TO FINE GRAINED SILICEOUS CEMENTED FRIABLE SANDSTONES WITH THICKER BEDS OF TUFFACEOUS SILTSTONES, LAMINATED DARK COLORED CARBONACEOUS MATERIAL. COAL (9390 - 9400) = BLACK; VERY HARD; MOSTLY DENSE; IRREGULAR TO SOMEWHAT BLOCKY FRACTURE; MASSIVE CUTTINGS HABIT; RESINOUS TO SLIGHTLY GREASY; SOME OFF GASSING. TUFFACEOUS SILTSTONE (9435 - 9490) = LIGHT GRAY TO MEDIUM DARK GRAY; MUSHY TO PASTY; MOSTLY CRUMBLY WITH SOME CRUNCHY; PREDOMINANTLY IRREGULAR FRACTURE; MASSIVE TO PDC CURVED CUTTINGS HABIT; WAXY TO SLIGHTLY GREASY LUSTER; MOSTLY SILTY TEXTURE WITH GRADING FROM CLAYEY TO GRITTY; THICKER BEDS OF TUFFACEOUS SILTSTONE INTERBEDDED WITH THINNER BEDS OF LOOSE QUARTZ SAND AND LAMINATED CARBONACEOUS MATERIAL. SAND/SANDSTONE (9495 - 9565) = WHITE TO MILKY WHITE, WITH SOME LIGHT GRAY, CLEAR AND TRANSLUCENT HUES; QUARTZ SAND MATRIX; UPPER VERY FINE TO UPPER COARSE; POORLY SORTED; VERY WELL ROUNDED TO VERY ANGULAR; MODERATE TO HIGH SPHERICITY; VERY THIN BEDS OF LOOSE QUARTZ SAND INTERBEDDED WITH THIN LENSES OF VERY FINE, SLIGHTLY CEMENTED SANDSTONES, THICKER BEDS OF TUFFACEOUS SILTSTONES WITH LAMINATED CARBONACEOUS MATERIAL THROUGHOUT; OBM FLUORESCENCE; NO OTHER PETROLEUM INDICATORS WERE OBSERVED. Cook Inlet Energy RU-2A 18 TUFFACEOUS CLAYSTONE (9570 - 9625) = DARK GRAY TO MEDIUM GRAY; SLIGHTLY FIRM TO MUSHY; CRUMBLY TO CRUNCHY; IRREGULAR FRACTURE; AMORPHOUS TO PDC CURVED CUTTING HABIT; DULL TO WAXY LUSTER; PREDOMINANTLY CLAYEY TEXTURE WITH SOME GRADING TO SILTY AND GRITTY; THICK BEDS OF TUFFACEOUS CLAYSTONE LAMINATED WITH MASSIVE AMOUNTS OF CARBONACEOUS MATTER, AND VERY SMALL AMOUNTS OF TUFF, WITH LESSER AMOUNTS OF SAND/SANDSTONES. SAND (9630 - 9690) = MILKY WHITE TO WHITE, WITH SOME LIGHT GRAY TO MEDIUM GRAY AND TRANSLUCENT TO CLEAR; PREDOMINANTLY QUARTZ SAND MATRIX WITH ABUNDANT DARK COLORED LITHIC FRAGMENTS; LOWER FINE TO UPPER COARSE GRAIN SAND; POORLY SORTED THROUGHOUT; SUBROUNDED TO WELL ROUNDED WITH SOME SUBANGULAR; MODERATE TO HIGH SPHERICITY; THICKER BEDS OF MOSTLY LOOSE UNCEMENTED SAND. TUFFACEOUS SILTSTONE (9690-9740) = LIGHT GRAY TO MEDIUM GRAY AND VARIOUS HUES OF BOTH COLORS; POOR TO MODERATE INDURATED; CRUMBLY; SLIGHT TO MODERATE COHESIVE; NO ADHESIVENESS; PDC GROOVED CUTTINGS WITH IMPACTION IN LONG AXIS PROFILES; EARTHY LUSTER; SILTY TO GRITTY TEXTURE; MASSIVE GRADATIONAL BEDS OF TUFFACEOUS SILT; COMPOSED OF >90% FRIABLE SILT AND MINOR ASH, CARBON FINES AND VARIOUS DETRITAL MATERIAL; TRACE PARALLEL PATTERNS OF DARK CARBON CLAYS; SMALL COAL @ 9720’. TUFFACEOUS SILTSTONE (9740-9845 ) = LIGHT GRAY TO MEDIUM GRAY WITH SCATTERED DARK YELLOWISH BROWN IN CARBON RICH LAYERS; MODERATE INDURATION; MODERATE COHESIVE; NON ADHESIVE; PDC GROOVED FRACTURE AND HABIT; EARTHY LUSTER; MASSIVE SLIGHTLY GRADATIONAL TUFFACEOUS SILTS AND CLAYS; COMPOSED OF 80% SILT, 20% CLAY WITH MINOR MICRO LAMINATED CARBON RICH LAYERS TRACE ASH BLEBS AND VARIOUS DETRITAL MATERIAL. COAL (9845-9870 ) = BLACK TO MOTTLED GRAY BLACK; FIRM OVERALL TO BECOMING SOFTER NEAR CONTACTS WITH TUFFACEOUS SILT AND GENERATION OF IMMATURE CARBON CLAY AND CARBON SILTS; RESINOUS TO EARTHY LUSTER MATTE TEXTURE; HACKLY FRACTURE; TRACE DISSEMINATED AND FRAMBOIDAL PYRITE. TUFFACEOUS SILTSTONE (9870-9940) = LIGHT GRAY TO MEDIUM DARK GRAY; MOSTLY MUSHY TO CLUMPY; VERY CRUMBLY AND BRITTLE; IRREGULAR FRACTURE; MOSTLY MASSIVE TO PDC GROOVED CUTTINGS HABIT; SLIGHTLY GREASY TO SOMEWHAT WAXY LUSTER; MOSTLY SILTY GRADING TO CLAYEY AND GRITTY IN PLACES; THICK BEDS OF TUFFACEOUS SILTSTONES INTERBEDDED WITH THINNER BEDS OF TUFFACEOUS CLAYSTONES AND WITH LAMINATED CARBONACEOUS MATERIAL AND LESSER AMOUNTS OF LAMINATED TUFF; TWO SMALL COAL BEDS WERE ENCOUNTERED AT 9885’ MD AND 9910’ MD. TUFFACEOUS CLAYSTONE (9945 - 10015) = DARK GRAY TO MEDIUM DARK GRAY WITH SOME LIGHT GRAY; MOSTLY CRUMBLY TO SLIGHTLY CRUNCHY; IRREGULAR FRACTURE; MASSIVE TO PDC GROOVED CUTTING HABIT; RESINOUS TO SOMEWHAT GREASY LUSTER; PREDOMINANTLY CLAYEY TEXTURE GRADING TO VERY SILTY WITH LESSER AMOUNTS OF GRITTY TEXTURE; THINNER BEDS OF TUFFACEOUS CLAYSTONES INTERBEDDED WITH THICKER BEDS OF TUFFACEOUS SILTSTONES, AND LAMINATIONS OF WHITE TO BUFF COLORED TUFF, AND DARK COLORED CARBONACEOUS CLAY + CARBON SHALE @ 9995’. Cook Inlet Energy RU-2A 19 COAL (10010 - 10020) = BLACK TO GRAYISH BLACK; MOSTLY VERY DENSE WITH SOME SLIGHTLY BRITTLE ALONG BEDDING PLANES; PREDOMINANTLY IRREGULAR FRACTURE WITH SOME PLANAR; MOSTLY MASSIVE WITH SOME PLATY CUTTINGS HABIT; VITREOUS LUSTER; VERY SMOOTH TEXTURE; THINNER BEDDING STRUCTURE WITH LAMINATIONS OF COAL AND CARBONACEOUS MATERIAL; SOME OFF GASSING WAS OBSERVED. SAND (10110 - 10205) = WHITE TO MILKY WHITE, WITH SOME LIGHT GRAY TO MEDIUM GRAY AND TRANSLUCENT TO CLEAR; PREDOMINANTLY QUARTZ SAND MATRIX WITH ABUNDANT DARK COLORED LITHIC FRAGMENTS; LOWER FINE TO UPPER MEDIUM GRAIN SAND; POORLY SORTED THROUGHOUT; SUBROUNDED TO WELL ROUNDED WITH SOME SUBANGULAR; MODERATE TO HIGH SPHERICITY; THICKER BEDS OF MOSTLY LOOSE UNCEMENTED SAND INTERBEDDED WITH THINNER BEDS OF VERY FRIABLE SILICEOUS CEMENTED SANDSTONES, AND TUFFACEOUS SILTSTONES AND TUFFACEOUS CLAYSTONES, WITH LAMINATIONS OF ABUNDANT CARBONACEOUS MATERIAL WITH VERY THIN COALS; THICKER COALS WERE ENCOUNTERED AT 10140 MD; OBM FLUORESCENCE; NO OTHER PETROLEUM INDICATORS WERE OBSERVED. TUFFACEOUS SILTSTONE (10210 - 10270) = MEDIUM DARK GRAY TO MEDIUM GRAY; MOSTLY CLUMPY WITH SOME SLIGHTLY STIFF; CRUNCHY TO CRUMBLY; PREDOMINANTLY IRREGULAR FRACTURE; AMORPHOUS TO SOMEWHAT MASSIVE CUTTINGS HABIT; DULL TO SLIGHTLY EARTHY LUSTER; VERY SILTY TEXTURE GRADING TO SOMEWHAT GRITTY; THINNER BEDS OF TUFFACEOUS SILTSTONES INTERBEDDED WITH THICKER BEDS OF LOOSE QUARTZ SAND AND THIN LENSES OF FRIABLE SILICEOUS CEMENTED SANDSTONES. SAND/SANDSTONE (10275 - 10370) = CLEAR TO TRANSLUCENT WITH SOME WHITE, MILKY WHITE, LIGHT GRAY AND MEDIUM GRAY HUES; QUARTZ GRAIN SAND MATRIX WITH ABUNDANT DARK COLORED LITHIC FRAGMENTS; UPPER FINE GRAIN SAND TO UPPER COARSE GRAIN; POORLY SORTED; VERY WELL ROUNDED TO SUBROUNDED WITH SOME VERY ANGULAR TO SUBANGULAR; MODERATE TO HIGH SPHERICITY; THICKER BEDS OF LOOSE UNCEMENTED QUARTZ SAND INTERBEDDED WITH THIN BEDS OF VERY FRIABLE SILICEOUS CEMENTED SANDSTONES AND TUFFACEOUS SILTSTONES GRADING TO CLAYSTONES; OBM FLUORESCENCE. TUFFACEOUS SILTSTONE (10370-10430) = MEDIUM LIGHT GRAY TO MEDIUM DARK GRAY; POOR TO MODERATE INDURATION; CRUMBLY; SLIGHT TO MODERATE COHESIVE; NON ADHESIVE; PDC BIT GROOVED FRACTURE AND HABIT; EARTHY LUSTER; SILTY TEXTURE; SMALL COAL @ 10370 + 10400’; SCATTERED UNCONSOLIDATED MEDIUM UPPER TO FINE UPPER SANDS @ 10435’. SAND/SANDSTONE (10445 - 10520) = CLEAR TO TRANSLUCENT, WITH SOME WHITE, LIGHT GRAY HUES; PREDOMINANTLY QUARTZ SAND MATRIX WITH ABUNDANT DARK COLORED LITHIC FRAGMENTS; UPPER FINE TO UPPER COARSE GRAIN SAND; POORLY SORTED; WELL ROUNDED TO SUBROUNDED WITH SOME VERY ANGULAR TO SUBANGULAR; MODERATE TO HIGH SPHERICITY; THICKER BEDS OF LOOSE UNCEMENTED SAND WITH VERY THIN BEDS OF VERY FRIABLE SILICEOUS CEMENTED INTERBEDDED WITH TUFFACEOUS SILTSTONES AND TUFFACEOUS CLAYSTONES; OBM FLUORESCENCE; NO OTHER PETROLEUM INDICATORS WERE OBSERVED. TUFFACEOUS SILTSTONE (10525 - 10605) = MEDIUM GRAY TO DARK GRAY WITH SOME LIGHT GRAY; CLUMPY TO SLIGHTLY FIRM; CRUMBLY TO CRUNCHY; IRREGULAR TO AMORPHOUS FRACTURE; MASSIVE TO PDC GROOVED CUTTINGS HABIT; MOSTLY DULL TO SLIGHTLY WAXY; PREDOMINANTLY SILTY GRADING TO CLAYEY AND GRITTY; THICKER BEDS OF TUFFACEOUS SILTSTONES INTERBEDDED WITH THINNER BEDS OF LOOSE UNCEMENTED SAND AND SANDSTONES; SOME PYRITE OBSERVED BOTH IN CRYSTALLINE AND SECONDARY MINERALIZATION; ABUNDANT LAMINATIONS OF CARBONACEOUS MATERIAL AND VERY THIN COAL LENSES; THICKER COAL BED AT 10580’ TO 10590’. Cook Inlet Energy RU-2A 20 TUFFACEOUS CLAYSTONE (10610 - 10670) = DARK GRAY TO MEDIUM GRAY WITH SOME GRAYISH BLACK; SLIGHTLY FIRM TO CLUMPY; MOSTLY BRITTLE WITH SOME VERY CRUMBLY; AMORPHOUS TO IRREGULAR FRACTURE; PDC GROOVED CUTTING HABIT WITH SOME SLIGHTLY MASSIVE; DULL TO EARTHY LUSTER; VERY CLAYEY TEXTURE GRADING TO SILTY AND GRITTY IN PLACES; VERY THIN BEDS OF TUFFACEOUS CLAY GRADING INTO TUFFACEOUS SILTSTONE; ABUNDANT LAMINATIONS OF CARBONACEOUS MATERIAL. TUFFACEOUS SILTSTONE (10675 - 10755) = DARK GRAY TO MEDIUM GRAY WITH SOME LIGHT GRAY; SLIGHTLY FIRM TO CLUMPY; CRUMBLY TO CRUNCHY; AMORPHOUS TO IRREGULAR FRACTURE; MASSIVE TO PDC GROOVED CUTTINGS HABIT; MOSTLY WAXY TO SLIGHTLY EARTHY; PREDOMINANTLY SILTY GRADING TO CLAYEY AND GRITTY; THICKER BEDS OF TUFFACEOUS SILTSTONES INTERBEDDED WITH THIN BEDS OF TUFFACEOUS CLAYSTONES AND VERY THIN BEDS OF VERY FRIABLE SILICEOUS CEMENTED SANDSTONES; ABUNDANT LAMINATIONS OF CARBONACEOUS MATERIAL WITH VERY THIN COALS; SOME PYRITE IN BOTH CRYSTALLINE AND SECONDARY MINERALIZATION. SAND/SANDSTONE (10760 - 10800) = CLEAR TO TRANSLUCENT, WITH WHITE, MILKY WHITE, LIGHT TO MEDIUM GRAY HUES; MOSTLY QUARTZ GRAIN SAND MATRIX THROUGHOUT; UPPER FINE GRAIN SAND TO UPPER COARSE; POORLY SORTED; VERY WELL ROUNDED TO SUBROUNDED WITH SOME SUBANGULAR TO WELL ANGULAR; MODERATE TO HIGH SPHERICITY; THICKER BEDS OF FRIABLE SILT WITH DEPTH; MATRIX SUPPORTED TO SECONDARY GRAIN SUPPORT LOCALLY; POOR POROSITY AND PERMEABILITY; NO OIL SHOWS WITH OIL BASE MUD MASKING INDICATORS. TUFFACEOUS SILTSTONE (10800-10925) = MODERATE GRAY WITH SUBTLE HUES CHANGES TOWARD DARKER CARBON HUES WITH DEPTH; POOR TO MODERATE INDURATION; SLIGHTLY CRUMBLY TO SLIGHTLY WAXY TENACITY; SLIGHT TO MODERATE COHESIVENESS; NON ADHESIVE; PDC BIT METAMORPHISM CUTTINGS CAUSED BY COMPRESSIVE DISPLACEMENT MATRIX FAILURE AND PLASTIC DEFORMATION IMPACT IN LONG AXIS PROFILE SOME WITH PARALLEL CRENULATIONS WITH POLISHED SMOOTH ON THE OTHER SIDE; GRADATION WITH CLAY CONTENT BUT CONSISTENT THROUGHOUT; COMPOSED OF 80% SILT, 20% VERY FINE SAND DEVITRIED ASH BLEBS, CARBON CLAYS AND DETRITAL MATERIAL; LOCAL COALS AND CARBONACEOUS CLAYS AT COAL CONTACTS. SAND/TUFFACEOUS SAND (10925-11000) = VERY LIGHT GRAY; CLAST SIZE COARSE LOWER TO MEDIUM LOWER; TRACE VERY COARSE UPPER SUB ANGULAR TO SUB ROUND; SCATTERED ANGULAR BIT IMPACTED FRAGMENTS; MODERATE DEVELOPED SPHERICITY; TRACE PROLATED GRAINS; GENERALLY EQUANT; MODERATE SORTING; IMPACTED TO CHIP TEXTURE; SUB MATURE NATURE; BOTH GRAIN AND SILT/ASH MATRIX WHICH IS PORE FILLING AND ACTING AS A LITHIFYING AGENT; COMPOSED QUARTZ WITH SECONDARY CHERT AND TRACE LITHICS; POOR TO SOME FAIR POROSITY; POOR PERMEABILITY; NO OIL INDICATORS: OBM TUFFACEOUS SILTSTONE (11030 - 11115) = MEDIUM GRAY TO DARK GRAY WITH SOME LIGHT GRAY; CLUMPY TO SLIGHTLY FIRM; CRUMBLY TO CRUNCHY; AMORPHOUS TO IRREGULAR FRACTURE; MASSIVE TO PDC GROOVED CUTTINGS HABIT; MOSTLY EARTHY TO SLIGHTLY GREASY; PREDOMINANTLY SILTY GRADING TO CLAYEY AND GRITTY; THICKER BEDS OF TUFFACEOUS SILTSTONES INTERBEDDED WITH THIN BEDS OF TUFFACEOUS CLAYSTONES AND VERY THIN BEDS OF VERY FRIABLE TUFFACEOUS SANDSTONES; ABUNDANT LAMINATIONS OF CARBONACEOUS MATERIAL AND TUFF; VERY THIN COALS BEDS THROUGHOUT; A LARGER COAL BED WAS OBSERVED AT 11060’ TO 11075’. Cook Inlet Energy RU-2A 21 SANDSTONE/SAND (11120 - 11190 ) = LIGHT GRAY TO WHITE WITH SOME TRANSLUCENT TO CLEAR; VERY FRIABLE QUARTZ GRAIN SAND SUPPORTED WITH A SILTY TO CLAYEY TO TUFFACEOUS MATRIX, SLIGHTLY CEMENTED; UPPER FINE GRAIN TO UPPER COARSE; POORLY SORTED; VERY ANGULAR TO SUBANGULAR WITH SOME VERY WELL ROUNDED TO SUBROUNDED; MODERATE TO HIGH SPHERICITY; THICKER BEDS OF FRIABLE SILICEOUS CEMENTED SANDSTONE AND LOOSE QUARTZ SAND INTERBEDDED WITH TUFFACEOUS SILTSTONES AND CLAYSTONES; OBM FLUORESCENCE. SAND/TUFFACEOUS SANDSTONE (11190-11270) =VERY LIGHT GRAY; CLAST SIZE COARSE LOWER TO FINE UPPER; SUB ANGULAR TO SUB ROUND; MODERATE TO WELL DEVELOPED SPHERICITY; GENERAL EQUANT GRAINS; MODERATE SORT; IMPACT TO PITTED TEXTURE; SUB MATURE NATURE; NON CALCAREOUS; UNCONSOLIDATED WEAK CONSOLIDATED CLUSTERS WITH DEPTH; BOTH GRAIN AND ASH MATRIX SUPPORT COMPOSED OF >90% QUARTZ, TRACE CHERT; POOR TO LOCAL MODERATE POROSITY; POOR PERMEABILITY; GRADING TO TUFFACEOUS SANDSTONE @ 11240 WITH INCREASED ASH BEDS AT 11260’. TUFFACEOUS SILTSTONE (11320 - 11390) = DARK GRAY TO MEDIUM GRAY WITH SOME LIGHT GRAY; SLIGHTLY CLUMPY TO FIRM; CRUMBLY TO CRUNCHY; AMORPHOUS TO IRREGULAR FRACTURE; MASSIVE TO PDC GROOVED CUTTINGS HABIT; MOSTLY WAXY TO SLIGHTLY EARTHY; PREDOMINANTLY SILTY GRADING TO CLAYEY AND GRITTY; THICKER BEDS OF TUFFACEOUS SILTSTONES INTERBEDDED WITH THINNER BEDS OF TUFFACEOUS CLAYSTONES AND ABUNDANT LAMINATIONS OF VOLCANIC TUFF AND CARBONACEOUS MATERIAL THROUGHOUT THE SAMPLE. TUFFACEOUS CLAYSTONE (11395 - 11475) = DARK GRAY TO MEDIUM GRAY; SLIGHTLY FIRM TO CLUMPY; MOSTLY BRITTLE TO SOMEWHAT CRUNCHY; IRREGULAR FRACTURE; MASSIVE CUTTINGS HABIT TO PDC GROOVED CUTTINGS HABIT; EARTHY TO SLIGHTLY DULL; MOSTLY CLAYEY TEXTURE, WITH SOME GRADING TO SILTY; VERY THIN BEDS OF TUFFACEOUS CLAYSTONES INTERBEDDED WITH THICKER BEDS OF TUFFACEOUS SILTSTONES AND THIN BEDS OF LOOSE UNCEMENTED QUARTZ SAND AND FRIABLE SILICEOUS CEMENTED SANDSTONES; ABUNDANT LAMINATIONS OF CARBONACEOUS MATERIALS AND SMALL BEDS OF COAL; LARGER COAL BED WAS OBSERVED AT 11400’ TO 11415’ AND 11450’ TO 11460’. TUFFACEOUS SANDSTONE/SAND (11475-11575) = OFF WHITE TO VERY LIGHT GRAY BECOMING YELLOWISH GRAY IN SILT/ASH MATRIX; CLAST SIZE MEDIUM UPPER TO FINE UPPER; SUB ROUND; WELL DEVELOPED SPHERICITY; EQUANT GRAINS; MODERATE SORTING; POLISH-PITTED- IMPACT TEXTURE; SUB MATURE NATURE; MODERATE TO ABUNDANT ASH/SILT MATRIX GRADING TO SANDY TUFFACEOUS SANDSTONE; ASHY WITH PORE FILLING AND LITHIFYING AGENT; COMPOSED OF >90% QUARTZ SECONDARY CHERT AND TRACE LITHICS; POOR POROSITY; SOME LOOSE SANDS; OIL BASE MUD. TUFFACEOUS SILTSTONE (11575-11600 ) = LIGHT GRAY TO MEDIUM GRAY TO LIGHT HUES OF BROWNISH GRAY; POOR TO MODERATE INDURATION; PDC BIT FRACTURE AND HABIT; EARTHY TO GREASY LUSTER; SILTY TEXTURE; MASSIVE GRADATIONAL TUFFACEOUS SILTS INTERBEDDED WITH ASH, VERY FINE SAND AND OR PYRO CLASTIC RELIC SHARDS AND VARIOUS DETRITAL MATERIAL. COAL (11600-11630) = BLACK MOTTLED BROWN BLACK AT CONTACTS; BRITTLE TO FIRM AT MASS CENTER; RESINOUS TO EARTHY LUSTER; UNIFORM PDC BIT HACKLY FRACTURE/HABIT; COMPOSED OF BITUMINOUS TO LIGNITIC. Cook Inlet Energy RU-2A 22 TUFFACEOUS SANDSTONE AND SAND (11630 - 11725 ) = VERY LIGHT GRAY SAND TO VERY PALE ORANGE IN TUFFACEOUS SANDSTONES w/ ASH/SILT/CLAY MATRIX; CLAST SIZE MEDIUM LOWER TO COARSE LOWER WITH SCATTERED COARSE UPPER; ROUNDED GRAINS WITH GOOD SPHERICITY; EQUANT GRAINS; MODERATE SORTING; POLISH TO PITTED TO IMPACT TEXT SUB MATURE NATURE; UNCONSOLIDATED GRAIN SUPPORT TO CONSOLIDATED ASH/SILT MATRIX SUPPORT BECOMING ABUNDANT IN PARTS; PORE FILLING; ACTS AS LITHIFYING AGENT; COMPOSED OF >90% QUARTZ, SECONDARY CHERT BECOMING SUB ARENACEOUS @ 11665’; POOR TO GOOD POROSITY AND PERMEABILITY; OBM FLUORESCENCE; NO OTHER PETROLEUM INDICATORS WERE OBSERVED. TUFFACEOUS SILTSTONE (11750 - 11830) = MEDIUM GRAY TO DARK GRAY; SLIGHTLY FIRM TO CLUMPY; MOSTLY BRITTLE TO SOMEWHAT CRUMBLY; IRREGULAR FRACTURE; MASSIVE CUTTINGS HABIT TO PDC GROOVED CUTTINGS HABIT; EARTHY TO SLIGHTLY DULL; MOSTLY SILTY TEXTURE, WITH SOME GRADING TO CLAYEY; THICKER BEDS OF TUFFACEOUS SILTSTONES INTERBEDDED WITH THINNER BEDS OF TUFFACEOUS CLAYSTONES AND THIN BEDS OF LOOSE UNCEMENTED QUARTZ SAND AND FRIABLE SILICEOUS CEMENTED SANDSTONES; ABUNDANT LAMINATIONS OF CARBONACEOUS MATERIALS AND SMALL BEDS OF COAL. COAL (11823 - 11833) = BLACK TO GRAYISH BLACK; VERY STIFF TO FIRM; MOSTLY DENSE TO BRITTLE ALONG BEDDING PLANES; PREDOMINANTLY IRREGULAR FRACTURE WITH SOME PLANAR; MOSTLY MASSIVE WITH SOME PLATY CUTTINGS HABIT; VITREOUS LUSTER; VERY SMOOTH TEXTURE; SMALLER COAL SEAM AT 11863’ TO 11868’ MD. TUFFACEOUS SILTSTONE (11833-11905) = VERY LIGHT GRAY TO LIGHT GRAY; POOR TO MODERATE INDURATION; CRUMBLY; SLIGHTLY COHESIVE; NON ADHESIVE; PDC BIT FRACTURE AND HABIT WITH LONG AXIS PROFILE AND SMOOTH POLISHED BIT BURN; EARTHY TO GREASY LUSTER; SILTY TEXTURE; MASSIVE GRADATIONAL BEDS OF TUFFACEOUS SILTSTONE COMPOSED OF 90% FRIABLE SILT, 10% ASH BLEBS, VERY FINE SAND, CARBON CLAY AND TUFFACEOUS CLAY; TRACE DISSEMINATED PYRITE. COAL BEDS (11905-12005) = BLACK MOTTLED BROWNISH BLACK TO GRAYISH BLACK AT CONTACTS; BRITTLE TO FIRM; EARTHY TO RESINOUS LUSTER; MATTE TEXTURE; HACKLY PDC GROUND UP CUTTINGS FRACTURE; COAL GRADING TO VERY CARBONACEOUS CLAY IN PARTS; NO VISIBLE BLEEDING GAS; OCCURS AS THIN BEDS WITH TUFFACEOUS SILT TUFFACEOUS SILTSTONE (12005-12050) = VERY LIGHT GRAY TO LIGHT GRAY; POOR TO MODERATE INDURATION; CRUMBLY TO CRUNCHY; SLIGHTLY COHESIVE; NON ADHESIVE; PDC BIT FRACTURE AND HABIT; EARTHY TO GREASY LUSTER; SILTY TEXTURE; MASSIVE BEDS OF TUFFACEOUS SILT WITH THIN BEDS OF COAL; CARBON SILT + CLAY NEAR COAL CONTACTS. TUFFACEOUS CLAYSTONE (12045 - 12115) = DARK GRAY TO MEDIUM GRAY; SLIGHTLY FIRM TO CLUMPY; MOSTLY BRITTLE TO SOMEWHAT CRUNCHY; IRREGULAR FRACTURE; MASSIVE CUTTINGS HABIT TO PDC GROOVED CUTTINGS HABIT; EARTHY TO SLIGHTLY DULL;MOSTLY CLAYEY TEXTURE, WITH SOME GRADING TO SILTY; VERY THIN BEDS OF TUFFACEOUS CLAYSTONES INTERBEDDED WITH THICKER BEDS OF TUFFACEOUS SILTSTONES AND VERY THIN LENSES OF LOOSE UNCEMENTED SAND; ABUNDANT LAMINATIONS OF CARBONACEOUS MATERIAL AND COAL; SOME VOLCANIC TUFF OBSERVED AT 12075’ TO 12100’ MD. Cook Inlet Energy RU-2A 23 TUFFACEOUS SILTSTONE (12185 - 12255 ) = MEDIUM GRAY TO DARK GRAY; SLIGHTLY FIRM TO CLUMPY; MOSTLY CRUNCHY TO SOMEWHAT BRITTLE; IRREGULAR FRACTURE; PDC GROOVED TO SOMEWHAT MASSIVE CUTTINGS HABIT; EARTHY TO SLIGHTLY DULL; MOSTLY SILTY TEXTURE, WITH SOME GRADING TO CLAYEY; VERY THICKER BEDS OF TUFFACEOUS SILTSTONES INTERBEDDED WITH THINNER BEDS OF TUFFACEOUS CLAYSTONES, AND VERY THIN LENSES OF LOOSE UNCEMENTED QUARTZ SAND; ABUNDANT LAMINATIONS OF CARBONACEOUS MATERIAL AND VERY THIN BEDS OF COAL. COAL (12260-12270) = BLACK; FIRM; EARTHY TO RESINOUS LUSTRE; MATTE TEXTURE; PDC GROUND UP HACKLY CUTTINGS; COMPOSED OF BITUMINOUS TO LIGNITIC COAL; NO VISIBLE GAS BLEEDS FROM CUTTINGS. SAND (12270-12340) = VERY LIGHT GRAY; CLAST SIZE RANGES MEDIUM UPPER TO FINE UPPER; SUB ROUND; MODERATE TO SOME WELL DEVELOPED SPHERICITY; SOME PROLATED GRAINS; GENERAL EQUANT GRAIN DIMENSIONS; MODERATE TO WELL SORTING; IMPACTED TO POLISHED TEXTURE; MATURE NATURE; ARENACEOUS; DOMINANT GRAIN SUPPORT; NO VISIBLE MATRIX MATERIAL; UNCONSOLIDATED; GOOD ESTIMATED POROSITY AND PERMEABILITY NO OIL INDICATORS w/ OIL BASE MUD. TUFFACEOUS SILTSTONE (12400 - 12470) = MEDIUM GRAY TO DARK GRAY; SLIGHTLY CLUMPY TO FIRM; MOSTLY BRITTLE TO SOMEWHAT CRUNCHY; IRREGULAR FRACTURE; PDC GROOVED TO SOMEWHAT MASSIVE CUTTINGS HABIT; DULL TO SLIGHTLY EARTHY LUSTER; MOSTLY SILTY TEXTURE WITH SOME GRADING TO CLAYEY IN PLACES; INTERBEDDED WITH THIN BEDS OF TUFFACEOUS CLAYSTONES AND VERY THIN BEDS OF VERY FRIABLE SANDSTONE AND LOOSE QUARTZ SAND; ABUNDANT LAMINATIONS OF CARBONACEOUS MATERIAL AND VERY THIN BEDS OF COAL. TUFFACEOUS SILTSTONE (12515 - 12590 ) = MEDIUM DARK GRAY TO DARK GRAY WITH SOME MEDIUM GRAY; MOSTLY CLUMPY TO SLIGHTLY STIFF; VERY BRITTLE; IRREGULAR TO AMORPHOUS FRACTURE; PDC GROOVED TO MASSIVE CUTTINGS HABIT; PREDOMINANTLY DULL TO SLIGHTLY GREASY LUSTER; VERY SILTY TEXTURE WITH SOME GRADING TO CLAYEY AND SLIGHTLY GRITTY; THICK BEDS OF TUFFACEOUS SILTSTONES INTERBEDDED WITH THINS BEDS OF TUFFACEOUS CLAYTONES AND VERY FINE GRAIN FRIABLE SANDSTONES WITH UNCONSOLIDATED MEDIUM SAND GRAINS; SECTION BECOMING ASHY AT 12580’. TUFFACEOUS SILTSTONE (12590-12650) = YELLOWISH GRAY TO MEDIUM GRAY BECOMING MEDIUM DARK GRAY WITH DEPTH AND NEAR COAL BEDS; POOR INDURATION; BRITTLE; CRUMBLY; SLIGHTLY COHESIVE; NON ADHESIVE PDC BIT GROOVED FRACTURE AND HABIT; EARTHY TO GREASY LUSTER WITH INCREASED ASH CONTENT AT 12620’; SILTY TO ASHY TEXTURE; MASSIVE GRADATIONAL ASH SILTS; SLIGHT UNCONSOLIDATED QUARTZ MEDIUM GRAIN SANDS LOOSE; THIN TUFFACEOUS SAND STONE BEDS; THIN COALS AND CARBON SHALE AT 12625-12660’. SAND/TUFFACEOUS SANDSTONE (12690-12770) = CLEAR, WITH LIGHT BROWNISH GRAY HUES; PREDOMINANTLY QUARTZ SAND MATRIX WITH ABUNDANT LIGHT AND DARK COLORED LITHIC FRAGMENTS THROUGHOUT THE SAMPLE; UPPER FINE GRAIN TO UPPER MEDIUM GRAIN SAND; FAIR TO WELL SORTED; VERY WELL ROUNDED TO SUBROUNDED WITH SOME VERY ANGULAR; MODERATE TO HIGH SPHERICITY; THINNER BEDS OF LOOSE QUARTZ SAND AND VERY FINE GRAINED, FRIABLE TUFFACEOUS SANDSTONES INTERBEDDED WITH THICK BEDS OF TUFFACEOUS SILTSTONES AND TUFFACEOUS CLAYSTONES; OBM FLUORESCENCE; NO OTHER PETROLEUM INDICATORS WERE OBSERVED. Cook Inlet Energy RU-2A 24 TUFFACEOUS SILTSTONE (12770-12830 ) = LIGHT OLIVE GRAY TO MEDIUM GRAY TO YELLOWISH GRAY AND DARKER HUES AT COAL CONTACTS; POOR TO MODERATE INDURATION; BRITTLE; SLIGHTLY COHESIVE; NON ADHESIVE PDC BIT GROOVED FRACTURE AND HABIT; SILT TO GRITTY TEXTURE; MASSIVE GRADATIONAL BEDS OF TUFFACEOUS SILT INTERBEDDED WITH SAND, ASH BLEBS AND CARBON CLAY; SMALL COALS AT 12790’ AND 12825’, NO VISIBLE BLEEDING GAS NOTED. COAL (12866 - 12884) = BLACK TO GRAYISH BLACK; VERY STIFF TO FIRM; MOSTLY DENSE TO BRITTLE ALONG BEDDING PLANES; PREDOMINANTLY IRREGULAR FRACTURE WITH SOME BLOCKY; MOSTLY MASSIVE WITH SOME PLATY CUTTINGS HABIT; VITREOUS LUSTER; VERY SMOOTH TEXTURE; LAMINATIONS OF SMALLER COALS WITH A LARGER COAL AT 12866’ TO 12884’ MD. TUFFACEOUS SILTSTONE (12884-13000 ) = YELLOWISH GRAY TO MEDIUM LIGHT GRAY AND VARIOUS HUES OF BOTH COLORS; POORLY INDURATED; BRITTLE; CRUMBLY, SLIGHTLY COHESIVE, NON ADHESIVE; PDC BIT FRACTURE AND HABIT; EARTHY TO GREASY LUSTER; SILT TO ASH TEXTURE; INTERBEDDED ASH AND CLAY WITH INCREASE MEDIUM GRAIN SAND. SAND (13005 - 13070) = CLEAR TO TRANSLUCENT, WITH WHITE, MILKY WHITE, LIGHT TO MEDIUM GRAY HUES; MOSTLY QUARTZ GRAIN SAND MATRIX THROUGHOUT; UPPER FINE GRAIN SAND TO UPPER MEDIUM; POORLY SORTED; VERY WELL ROUNDED TO SUBROUNDED WITH SOME SUBANGULAR TO WELL ANGULAR; MODERATE TO HIGH SPHERICITY; THINNER BEDS OF LOOSE QUARTZ SAND INTERBEDDED WITH THICKER BEDS OF TUFFACEOUS SILTSTONES; OBM FLUORESCENCE; NO OTHER PETROLEUM INDICATORS WERE OBSERVED. TUFFACEOUS SILTSTONE (13075 - 13140 ) = MEDIUM DARK GRAY TO DARK GRAY WITH SOME MEDIUM GRAY; MOSTLY CLUMPY TO SLIGHTLY STIFF; VERY BRITTLE; IRREGULAR TO AMORPHOUS FRACTURE; PDC GROOVED TO MASSIVE CUTTINGS HABIT; PREDOMINANTLY DULL TO SLIGHTLY GREASY LUSTER; VERY SILTY TEXTURE WITH SOME GRADING TO CLAYEY AND SLIGHTLY GRITTY; THICK BEDS OF TUFFACEOUS SILTSTONES INTERBEDDED WITH THINS BEDS OF TUFFACEOUS CLAYTONES; ABUNDANT LAMINATIONS OF CARBONACEOUS MATERIALS WITH VERY THIN COALS. SAND/SANDSTONE (13145 - 13220 ) = MOSTLY CLEAR, WITH LIGHT BROWNISH GRAY HUES; PREDOMINANTLY QUARTZ SAND MATRIX WITH ABUNDANT LIGHT AND DARK COLORED LITHIC FRAGMENTS THROUGHOUT THE SAMPLE; UPPER FINE GRAIN TO UPPER MEDIUM GRAIN SAND; FAIR TO WELL SORTED; VERY WELL ROUNDED TO SUBROUNDED WITH SOME VERY ANGULAR; MODERATE TO HIGH SPHERICITY; THINNER BEDS OF LOOSE QUARTZ SAND AND VERY FINE GRAINED, AND VERY FRIABLE SANDSTONES INTERBEDDED WITH THICK BEDS OF TUFFACEOUS SILTSTONES AND TUFFACEOUS CLAYSTONES; OBM FLUORESCENCE; NO OTHER PETROLEUM INDICATORS WERE OBSERVED. TUFFACEOUS SILTSTONE (13225 - 13305) = DARK GRAY TO MEDIUM DARK GRAY WITH SOME MEDIUM GRAY; MOSTLY STIFF TO SLIGHTLY CLAYEY; BRITTLE; AMORPHOUS TO IRREGULAR FRACTURE; MOSTLY MASSIVE CUTTINGS HABIT, WITH PDC GROOVED; MOSTLY EARTHY TO SLIGHTLY DULL LUSTER; VERY SILTY TEXTURE WITH SOME GRADING TO CLAYEY AND SLIGHTLY GRITTY; THICK BEDS OF TUFFACEOUS SILTSTONES INTERBEDDED WITH THIN BEDS OF TUFFACEOUS CLAYTONES AND VERY FINE GRAINED FRIABLE TUFFACEOUS SANDSTONES AND LOOSE QUARTZ SAND; ABUNDANT LAMINATIONS OF TUFF, AND CARBONACEOUS MATERIAL WITH VERY SMALL COALS. Cook Inlet Energy RU-2A 25 TUFFACEOUS SILTSTONE AND COAL (13305 - 13370 ) =LIGHT GRAY TO MEDIUM LIGHT GRAY; SOME YELLOWISH GRAY; POOR TO MODERATE INDURATION; SLIGHT TO MODERATE COHESIVE; NON ADHESIVE; PDC BIT FRACTURE AND HABIT CAUSED BY COMPRESSIVE DISPLACEMENT MATRIX FAILURE AND PLASTIC DEFORMATION; EARTHY LUSTER; SILT TEXTURE; GRADATIONAL TUFFACEOUS SILT COMPOSED OF >90% SILT AND VARIOUS DETRITAL MATERIAL; TRACE ASH CONGLOMERATE SAND, SAND AND THIN COALS. TUFFACEOUS SILTSTONE/DEVITRIFIED ASH (13370 - 13455) = YELLOWISH GRAY MOTTLED WHITE (ASH) TO MEDIUM GRAY; POORLY INDURATED; BRITTLE; CRUMBLY; SLIGHTLY COHESIVE; NON ADHESIVE; PDC TO EARTHY FRACTURE WITH DEVELOPED SUB NODULAR HABIT THROUGH WELLBORE EROSIONAL TRANSPORT OF FRAGILE DEVITRIFIED ASH; EARTHY MOTTLED GREASY LUSTER; ASHY TEXT; MICRO TO THIN ASH BLEBS AND LAMINAR PATTERNS; TRACE VISIBLE ASH EXPANSION; INTERBEDDED MEDIUM GRAIN LOOSE SAND AND TUFFACEOUS SANDSTONE IN THIN BEDS. COAL (13455 - 13465 ) = BLACK; FIRM; RESINOUS LUSTER; HACKLY PDC FRACTURE; MATTE TEXTURE; COMPOSED OF BITUMINOUS COAL AND CARBON SHALE NEAR CONTACTS; NO VISIBLE BLEEDING GAS. TUFFACEOUS SAND / SAND (13465 - 13550 ) = VERY LIGHT GRAY TO YELLOWISH GRAY IN ASH MATRIX; CLAST SIZE RANGE COARSE LOWER TO MEDIUM LOWER; SUB ROUND; WELL DEVELOPED SPHERICITY; EQUANT GRAIN DIMENSIONS; MODERATE SORTING; POLISH TEXTURE; SUB MATURE NATURE; BOTH LOOSE GRAINS AND AS ABUNDANT ASH/SILT MATRIX SUPPORT AND INTERBEDDED; PORE FILLING AND LOOSELY ATTACHED; COMPOSED OF >90% QUARTZ; TRACE CHERT; POOR POROSITY AND PERMEABILITY; NO OIL INDICATORS WITH OIL BASE MUD. TUFFACEOUS SILTSTONE (13550 - 13610) = YELLOWISH GRAY TO LIGHT OLIVE GRAY TO LIGHT GRAY TO RARE BROWNISH GRAY AND VARIOUS HUES OF ALL COLORS; BRITTLE; POOR INDURATION; SLIGHTLY COHESIVE; NON ADHESIVE; PDC GROOVED FRACTURE AND HABIT EARTHY TO GREASY LUSTER; SILTY TO ASHY TEXTURE; MASSIVE GRADATIONAL TUFFACEOUS SILT WITH INTERBEDDED DEVITRIFIED ASH BECOMING PREVALENT AFTER 13590’. DEVITRIFIED ASH (13610 - 13640) = WHITE TO VERY LIGHT OLIVE GRAY; MOTTLED DARK HUES; POOR INDURATION; MATTE TEXTURE; ASHY TEXTURE; REWORKED AND INTERBEDDED SILT AND DETRITAL MATERIAL. TUFFACEOUS SILTSTONE (13650 - 13725 ) = MEDIUM DARK GRAY TO DARK GRAY WITH SOME MEDIUM GRAY; STIFF TO MOSTLY CLUMPY; VERY BRITTLE; MOSTLY AMORPHOUS TO IRREGULAR FRACTURE; PDC GROOVED TO MASSIVE CUTTINGS HABIT; MOSTLY EARTHY TO DULL LUSTER; VERY SILTY TEXTURE WITH SOME GRADING TO GRITTY AND CLAYEY; VERY THICK BEDS OF TUFFACEOUS SILTSTONES INTERBEDDED WITH VERY FINE GRAINED, FRIABLE TUFFACEOUS SANDSTONES, WITH LESSER AMOUNTS OF LOOSE QUARTZ SAND; ABUNDANT LAMINATIONS OF TUFF, CARBONACEOUS MATERIALS AND VERY THIN COALS THROUGHOUT THE SAMPLE. COAL (13720-13735 ) = BLACK; VERY STIFF; VERY STIFF FIRM TO MOSTLY DENSE; HACKLY PDC FRACTURE; MASSIVE CUTTINGS HABIT; VITREOUS LUSTER; SMOOTH; NO OFF GASSING WAS OBSERVED. Cook Inlet Energy RU-2A 26 SAND/TUFFACEOUS SANDSTONE (13760-13840) PREDOMINANTLY TRANSLUCENT TO CLEAR, WITH LIGHT BROWNISH GRAY HUES; PREDOMINANTLY QUARTZ SAND MATRIX WITH ABUNDANT LIGHT AND DARK COLORED LITHIC FRAGMENTS THROUGHOUT; UPPER FINE GRAIN TO UPPER MEDIUM GRAIN SAND; FAIR TO WELL SORTED; VERY ANGULAR TO SUBANGULAR WITH SOME SUBROUNDED; MODERATE TO HIGH SPHERICITY; THINNER BEDS OF LOOSE QUARTZ SAND AND FINE GRAINED, AND VERY FRIABLE TUFFACEOUS SANDSTONES INTERBEDDED WITH THICK BEDS OF TUFFACEOUS SILTSTONES AND TUFFACEOUS CLAYSTONES; OBM FLUORESCENCE; NO OTHER PETROLEUM INDICATORS WERE OBSERVED. SAND (13840 - 13910) = VERY LIGHT GRAY TO WHITE BECOMING LIGHT YELLOWISH GRAY w/ INTERBEDDED ASH; CLAST SIZE RANGES COARSE LOWER TO MEDIUM LOWER SCATTERED COARSE UPPER; SUB ROUND TO ROUNDED; MODERATE TO WELL DEVELOPED SPHERICITY; GENERAL EQUANT GRAIN DIMENSIONS; MODERATE SORTING; POLISH TEXTURE; SUB MATURE NATURE; MODERATE TO ABUNDANT ASH SILT MATRIX; DOMINANT MATRIX SUPPORT; MINOR TUFFACEOUS SANDSTONE; ASH MATRIX IS HYDROPHILIC; COMPOSED OF >90% QUARTZ TRACE CHERT; POOR POROSITY AND POOR PERMEABILITY; NO OIL INDICATORS w/ OBM. TUFFACEOUS SILTSTONE (13910 - 13970 ) = VERY LIGHT GRAY TO SALT AND PEPPER TO OFF WHITE IN ASHY SECTIONS; POORLY INDURATED; BRITTLE; VERY SLIGHT COHESIVE SLIGHTLY ADHESIVE; PDC GROOVED FRACTURE AND HABIT WITH EROSIONAL SUB NODULAR FEATURES FROM WELL BORE TRANSPORT; SILTY TO ASHY TEXTURE; VISIBLE PYROCLASTIC RELIC SHARDS IN MASS; DETRITAL GRADATIONAL BEDS OF SILT, ASH AND SAND. DEVITRIFIED ASH (13970 - 14010 ) = SALT AND PEPPER TO OFF WHITE TO VERY LIGHT GRAY HUES; VERY SOFT; GREASY LUSTER; ASHY TEXTURE; REWORKED AND REDEPOSITED; VISIBLE PYRO CLASTIC RELIC SHARDS WITH VARIOUS DETRITAL MATERIAL INTERBEDDED; EXPANSIVE WHEN REHYDRATED. SAND/TUFFACEOUS SANDSTONE (14035-14115 ) = PREDOMINANTLY CLEAR TO TRANSLUCENT, WITH LIGHT BROWNISH GRAY HUES; MOSTLY QUARTZ SAND MATRIX WITH ABUNDANT LIGHT AND DARK COLORED LITHIC FRAGMENTS THROUGHOUT; UPPER FINE GRAIN TO UPPER MEDIUM GRAIN SAND; FAIR TO WELL SORTED; VERY ANGULAR TO SUBANGULAR WITH SOME SUBROUNDED; MODERATE TO HIGH SPHERICITY; THINNER BEDS OF LOOSE QUARTZ SAND AND FINE GRAINED, VERY FRIABLE TUFFACEOUS SANDSTONES INTERBEDDED WITH THICK BEDS OF TUFFACEOUS SILTSTONES; LAMINATIONS OF CARBONACEOUS MATERIAL, TUFF AND VERY THIN COALS THROUGHOUT SAMPLE. ASH (14120 - 14150) = WHITE TO LIGHT GRAY WITH SOME LIGHT BROWNISH GRAY; CLUMPY; VERY SOFT; AMORPHOUS CUTTINGS HABIT; RESINOUS TO WAXY; VERY ASHY TEXTURE; ASH LAMINATIONS THROUGH THE SAMPLE. TUFFACEOUS SILTSTONE (14150 - 14220 ) = MEDIUM LIGHT GRAY TO MEDIUM DARK GRAY TO LIGHT OLIVE GRAY WITH SCATTERED OFF WHITE (INTERBEDDED ASH); MODERATELY INDURATED BECOMING POORLY INDURATED IN ASHY SILTS; MODERATE COHESIVE; NON ADHESIVE; PDC BIT GROOVED FRACTURE AND HABIT WITH SOFT SEDIMENT DEFORMATION IN GREATER CLAY/ASH MATRIX; EARTHY TO SOME GREASY LUSTER; SILTY TO ASHY TEXT; GRADATIONAL BEDS OF TUFFACEOUS SILT; COMPOSED OF 60% SILT, 20% CLAY, 20% ASH AND VARIOUS DETRITAL MATERIAL; THIN COAL BEDS. Cook Inlet Energy RU-2A 27 SAND/TUFFACEOUS SANDSTONE (14220-14295) = VERY LIGHT GRAY WITH DIVERSE HUES IN MATRIX ASH AND SILT; CLAST SIZE COARSE LOWER TO MEDIUM LOWER; SUB ROUND; WELL DEVELOPED SPHERICITY; EQUANT DIMENSIONS; MODERATE SORTING; POLISH TEXTURE; SUB MATURE NATURE; ABUNDANT ASH/SILT MATRIX; DOMINANT MATRIX SUPPORT; PORE FILLING AND LOOSELY ATTACHED; COMPOSED OF >90% QTZ; POOR POROSITY AND PERMEABILITY; NO OIL INDICATORS WITH OIL BASE MUD. COAL (12495 - 14320 ) = BLACK TO BROWNISH BLACK AT CONTACTS IN CARBON CLAY; FIRM; RESINOUS TO EARTHY LUSTERS; HACKLY FRACTURE FROM PDC BIT; MATTE TEXTURE; NO VISIBLE GAS BLEEDS; COALS OCCUR AS THIN SEPARATE BED PLANES. TUFFACEOUS SILTSTONE (14320 - 14390 ) = LIGHT OLIVE GRAY TO LIGHT GRAY AND VARIOUS HUES OF BOTH; MODERATELY INDURATED; MODERATE COHESIVE; NON ADHESIVE; PDC BIT FRACTURE AND HABIT; EARTHY TO GREASY LUSTER; SILTY TEXTURE; GRADATIONAL SILTS WITH ASH AND SAND. SAND/TUFFACEOUS SANDSTONE (14400-14465 ) = WHITE, LIGHT GRAY, PINKISH GRAY, AND YELLOWISH GRAY HUES; PREDOMINANTLY QUARTZ GRAIN SAND MATRIX WITH LESSER AMOUNTS OF CHERT AND LITHIC FRAGMENTS; UPPER FINE TO LOWER COARSE GRAIN SAND; WELL ROUNDED TO VERY ANGULAR; HIGH SPHERICITY; OBM FLUORESCENCE; NO OTHER PETROLEUM INDICATORS WERE OBSERVED. SAND/SANDSTONE (14465 - 14495) = VERY LIGHT GRAY TO PINKISH GRAY (INTEBEDDED TUFF); CLAST SIZE FINE UPPER TO MEDIUM UPPER; SUB ROUND TO ROUNDED; WELL DEVELOPED SPHERICITY; MODERATE SORTING; POLISH TO PITTED TEXTURE; BOTH GRAIN AND MATRIX SUPPORTED OF ASH/TUFF; PORE FILLS AND LOOSELY ATTACHED; COMPOSED OF >90% QUARTZ MINOR CHERT; FAIR POROSITY AND POOR PERMEABILITY; NO OIL INDICATORS. SAND/SANDSTONE CONGLOMERATE SAND (14500-14580 ) = VERY LIGHT GRAY TO YELLOWISH GRAY; CLAST SIZE COARSE UPPER TO MEDIUM LOWER; SUB ROUND; TRACE ANGULAR BIT IMPACTED COARSE GRAINS; POOR DEVELOPED SPHERICITY; POLISH TO PITTED TEXTURES; SANDSTONES MODERATELY RESISTANT TO SHEARING CLUSTERS; DOMINANT GRAIN SUPPORT WITH SLIGHT MATRIX SUPPORT IN PARTS; COMPOSED OF PREDOMINANTLY QUARTZ SECONDARY CHERT, TRACE ARGILLITE, FELDSPAR; FAIR POROSITY AND PERMEABILITY OBM FLUORESCENCE. CONGLOMERATE SANDSTONE/CONGLOMERATE/ SANDSTONE/SAND (14595 - 14660) = CLEAR, TRANSLUCENT, WHITE, LIGHT GRAY, LIGHT BLUISH GRAY AND PINKISH GRAY HUES; LOWER MEDIUM TO UPPER COARSE GRAINS; VERY ANGULAR TO SUBANGULAR; LOW TO HIGH SPHERICITY; PREDOMINANTLY GRAIN SUPPORETED SANDSTONE WITH SOME SLIGHTLY MATRIX SUPPORTED; MOSTLY QUARTZ SAND MATRIX WITH 20% CHERT, AND 10% CLASTICS AND TUFF; OBM FLUORESCENCE THROUGHOUT SAMPLE; NO OTHER PETROLEUM INDICATORS WERE OBSERVED. Cook Inlet Energy RU-2A 28 SANDSTONE/SAND (14665 - 14720) = WHITE, TRANSLUCENT TO CLEAR, YELLOWISH GRAY, PINKISH GRAY AND LIGHT BLUISH GRAY HUES; UPPER FINE GRAIN TO UPPER COARSE; FAIR TO POOR SORTED; VERY ANGULAR TO SUBANGULAR, WITH SOME VERY WELL ROUNDED; HIGH SPHERICITY MATRIX SAND UNCEMENTED SAND INTERBEDDED WITH MOSTLY GRAIN SUPPORTED FINE GRAINED, FRIABLE SANDSTONES; OBM FLUORESCENCE THROUGHOUT SAMPLE. TUFFACEOUS SILTSTONE (14720 - 14770) = YELLOWISH GRAY TO VERY LIGHT GRAY AND VARIOUS HUES OF BOTH MODERATE INDURATION MODERATE RESISTANT; MODERATE COHESIVE; NON ADHESIVE; PDC BIT GROOVED FRACTURE AND HABIT; EARTHY LUSTER; SILTY TO ABRASIVE TEXTURE; GRADATIONAL SILTS COMPOSED OF >90% FRIABLE SILT AND MICRO VARIOUS DETRITAL MATERIAL. CONGLOMERATE SAND, SAND, SANDSTONE (14770 - 14850) = VERY LIGHT GRAY TO LIGHT YELLOWISH GRAY TO LIGHT GREENISH GRAY; CLAST SIZE COARSE UPPER TO MEDIUM LOWER; ANGULAR BIT IMPACT GRAINS TO SUB ROUND MEDIUM MATRIX SANDS; MODERATE DEVELOPED SPHERICITY IN MEDIUM MATRIX SANDS TO LOW IN COARSE GRAINS; POOR SORTING; BIMODAL w/ COARSE AND MEDIUM GRAINS; POLISH AND CHIP COARSE TO IMPACT MEDIUM GRAINS; MODERATE TO WEAK SILICEOUS CEMENT; GRAIN SUPPORTED; COMPOSED OF 90% QUARTZ, 10% CHERT AND LITHIC FRAGMENTS; FAIR POROSITY AND PERMEABILITY; NO OIL INDICATORS WITH OIL BASE MUD IN THE SYSTEM. SAND (14860 - 14920 ) = TRANSLUENT TO CLEAR DOMINANT WITH OCCASION YELLOWISH BROWN AND LIGHT GREEN COLORS; QUARTZ DOMINANT WITH OCCASION REDDISH TO ORANGE TUFF, CHERT, AND LITHIC CLASTICS; UNCON-SOLDATED GRAINS; UPPER FINE TO VERY COARSE GRAIN SIZE; POORLY SORTING; ANGULAR TO SLIGHT ROUNDED ANGULARITY; LOW TO MODERATE SPHERICITY; MODERATE TO HIGH HCL REACTION IN BULK SAMPLE TEST; NO OIL INDICTORS DUE TO OIL BASE MUD IN SYSTEM. CONGLOMERATE SAND/SAND (14920 - 15010 ) = VERY LIGHT GRAY TO LIGHT GRAY TO LIGHT YELLOWISH GRAY AND VARIOUS HUES OF ALL; CLAST SIZE RANGE VERY COARSE LOWER TO MEDIUM LOWER; ANGULAR BIT IMPACTED GRAIN IN COARSE TO SUB ROUND IN MEDIUM GRAINS; LOW (COARSE) TO MEDIUM (MEDIUM GRAINS) DEVELOPED SPHERICITY; POOR SORTING; BIMODAL WITH COARSE AND MEDIUM GRAINS; POLISH TO CHIP COARSE, IMPACTED MEDIUM; MATURE NATURE; SUB ARENACEOUS; UNCONSOLIDATED WITH SCATTERED WEAKLY CONSOLIDATED SANDSTONES; DOMINANT GRAIN SUPPORT; VERY LITTLE INTERGRAIN MATERIAL COMPOSED OF 90% QUARTZ, 10% CHERT AND TRACE LITHIC FRAGMENTS; FAIR ESTIMATED POROSITY AND PERMERABILITY; NO OIL INDICATORS WITH OIL BASE MUD (OBM). CONGLOMERATE SAND/SAND (15010 - 15100 ) = VERY LIGHT GRAY TO LIGHT GRAY TO LIGHT YELLOWISH GRAY; CLAST SIZE VERY COARSE UPPER TO MEDIUM LOWER; MEAN SIZE IS COARSE LOWER TO MEDIUM UPPER; ANGULAR BIT IMPACTED COARSE GRAINS TO SUB ROUND MEDIUM MATRIX GRAINS; LOW TO MODERATE DEVELOPED SPHERICITY; POOR SORTING; POLISH AND CHIP COARSE GRAINS TO IMPACT MEDIUM GRAINS; MATURE NATURE; DOMINANT UNCONSOLIDATED WITH SCATTERED WEAK CONSOLIDATED CLUSTERS; DOMINANT GRAIN SUPPORT; VERY LITTLE INTER GRAIN ASH/SILT; COMPOSED OF 90% QUARTZ, 10% CHERT, TRACE LITHICS; FAIR ESTIMATED POROSITY AND PERMEABILITY; NO OIL INDICATORS WITH OIL BASE MUD. Cook Inlet Energy RU-2A 29 CONGLOMERATE SAND/SAND (15145 - 15200 ) = CLEAR TO SMOKEY DOMINANT WITH OCCASION VERY PALE BROWN, LIGHT OLIVE GRAY COLOR; QUARTZ DOMINANT WITH CHERT, TRACES OF ORANGE-REDDISH TUFF; TRACES OF LITHIC; UPPER FINE TO LOWER COARSE GRAIN SIZE; POOR TO VERY POOR SORTING; ROUNDED TO SUBANGULAR ANGULARITY; LOW TO MODERATE SPHERICITY; UNCONSOLIDATED SANDS WITH OCCASION CONSOLIDATED SANDSTONES; LOW TO MODERATE HCL REACTION; NO OIL INDICTORS DUE TO OIL BASE MUD. TUFFACEOUS SILTSTONE (15200 - 15260 ) = MEDIUM GRAY TO LIGHT GRAY TO LIGHT YELLOWISH GRAY; POOR TO MODERATE INDURATION; CRUMBLY; SLIGHT TO MODERATE COHESIVENESS; NON ADHESIVE; PDC BIT GROOVED FRACTURE AND HABIT TO SUB NODULAR SMALLER CLUSTERS; EARTHY LUSTER; SILTY TO GRITTY TEXTURE; THIN BEDS OF GRADATIONAL TUFFACEOUS SILT GRADING TO MEDIUM GRAIN UNCONSOLIDATED SAND. SAND/CONGLOMERATE SAND (15260 - 15260) = VERY LIGHT GRAY; TRANSLUCENT; CLAST SIZE COARSE LOWER TO FINE LOWER; MEAN SIZE MEDIUM UPPER TO FINE UPPER; SUB ANGULAR TO SUB ROUND; MODERATE DEVELOPED SPHERICITY; INCREASE IN PROLATED GRAINS; ANGULAR BIT IMPACTED COARSER GRAINS; CHIP TO IMPACT TEXTURE; SUB MATURE TO MATURE NATURE; UNCONSOLIDATED; GRAIN SUPPORT WITH SECONDARY MATRIX SUPPORT; FAIR ESTIMATED POROSITY AND PERMEABILITY GRADED BEDS OF TUFFACEOUS SILT AND SAND; NO OIL INDICATORS WITH OIL BASE MUD. SAND/CONGLOMERATE SAND (15260 - 15360) = VERY LIGHT GRAY; TRANSLUCENT; CLAST SIZE COARSE LOWER TO FINE LOWER; MEAN SIZE MEDIUM UPPER TO FINE UPPER; SUB ANGULAR TO SUB ROUND; MODERATE DEVELOPED SPHERICITY; INCREASE IN PROLATED GRAINS; ANGULAR BIT IMPACTED COARSER GRAINS; CHIP TO IMPACT TEXTURE; SUB MATURE TO MATURE NATURE; UNCONSOLIDATED; GRAIN SUPPORT WITH SECONDARY MATRIX SUPPORT; FAIR ESTIMATED POROSITY AND PERMEABILITY; GRADED BEDS OF TUFFACEOUS SILT AND SAND; NO OIL INDICATORS WITH OIL BASE MUD. Cook Inlet Energy RU-2A 30 3.4 SAMPLING PROGRAM AND DISTRIBUTION Set Type and Purpose Interval Frequency Distribution 1 Cleaned and Spun Dry 8600’ - 14540’ 14540’ - 15220’ 15220’ - 15360’ 30’ 10’ 30’ Cook Inlet Energy Attn: Greg Kirkland 601 W. 5 th Ave, Suite 310 Anchorage, AK 99501 2 Cleaned and Spun Dry 8600’ - 14540’ 14540’ - 15220’ 15220’ - 15360’ 30’ 10’ 30’ Cook Inlet Energy Attn: Greg Kirkland 601 W. 5 th Ave, Suite 310 Anchorage, AK 99501 Cook Inlet Energy RU-2A 31 4 DRILLING DATA 4.1 DAILY ACTIVITY SUMMARY April January 23, 2013: Prepare to drill open hole. April 24, 2013: Work on Top Drive. Trip in the hole to the top of the window (8517'). Work through the window with pumps off. Circulate and condition the mud and tag bottom and slide/rotate to 9155' (midnight). April 25, 2013: Drill and slide formation from 9155’ to 9820’. April 26, 2013: Drill and slide formation from 9820' to 10099'. Circulate bottoms up four times and pull out of the hole on elevators to 9300' and start to pump out of the hole. April 27, 2013: Continue to pump and back ream out of the hole to the window. Shut down the mud pumps and worked the BHA through the casing window. Pulled up past the window into the casing and tried to circulate. The hole packed off and we lost 10 BBLS of mud into the formation. Worked the pipe and staged the pumps on and worked the pack off and was able to trip out of the hole. Laid down the BHA and started to test the BOPE. April 27, 2013: Continue to pump and back ream out of the hole to the window. Shut down the mud pumps and worked the BHA through the casing window. Pulled up past the window into the casing and tried to circulate. The hole packed off and we lost 10 BBLS of mud into the formation. Worked the pipe and staged the pumps on and worked the pack off and was able to trip out of the hole. Laid down the BHA and started to test the BOPE. April 28, 2013: Completed testing the BOPE. Pick up BHA #9 with new bit and run in the hole. Pick up 2000' of 4" drill pipe and continue to trip in the hole to drill. April 29, 2013: Trip in the hole to 9245' and work drill pipe through tight coal. Trip into the hole to 9830' (coal) and wash down to TD (10099'). Shakers display a large increase in cuttings with trip gas of 56 units. Work the drill pipe and circulate the hole clean. Drill formation from 10099' to 10372'. Lost the rotary on the top drive. Trouble shoot the SCR while moving the drill pipe. Staged down the mud pumps to 200 gpm to avoid wash outs around coals. At present waiting on new breakers for the top drive. Continue to circulate and move the drill string. April 30, 2013: Waiting on parts for the top drive and circulating and moving the drill pipe at slow pump rates (200 gpm). May 01, 2013: Circulate drilling mud while reciprocating the hole while waiting on parts for the top drive. May 02, 2013: Circulate and reciprocate the drill string. Pull up into the shoe and continue to trouble shooting the top drive. Cut and slip new drill line. Trip into the hole to drill formation. Running in smooth/slick @ 10,000'. May 03, 2013: Trip in the hole from the window. Wash down the last stand. Running in the hole clean. Wiper gas was 40 units. Drilling and sliding to 11016' (midnight). May 04, 2013: Drill and slide formation to 11220' and observed a decrease in flow of cuttings at the shakers while sliding. Observed an over pull from 11160' to 11145' while back reaming. Increase RPM to Cook Inlet Energy RU-2A 32 110 and work tight spot. Drill and slide to 11224' and the rig lost power. Power loss of one hour. Staged up pumps and resumed full returns with reciprocating and rotation freely. Repair rig pumps while circulating at 290 GPM, 60RPM and start wiper trip to 10115'. Pulled freely with two small tight spots at 10620' and 10520' with 235k over pull. Worked through spots and pulled through them without problems. Continued to work on pump #2 at 10115'. Trip in the hole with no tight spots and wash down from 11120' to bottom. Wiper gas was 42 units. May 05, 2013: Drill and slide to 11620'. Back reaming through all slides and coal seams. Pump #1 down for 1.5 hours. Circulate at 56 spm while working on the pump. May 06, 2013: Drill and slide formation to 12006'. Back ream through all slides and coals. May 07, 2013: Drill and slide formation to 12162'. Lost 20 BBLS to the formation drilling the last stand from 12068 to 12162'. Flow checked the well at 12162' (TD) and no static loses observed. Circulated bottoms up once with the drill pipe rotating and reciprocating freely and the shakers free of cuttings. Spot a 50 bbl wellbore strengthening pill from 12162' (TD) to 11487'. Trip out of the hole on elevators. One tight spot at 9460' (15' coal). Pulled the BHA through the window into casing. Rigged up injection lines and begin to lay down 4" drill pipe and inject slop mud and water. May 08, 2013: Laydown BHA, rig up to test BOPE, test BOPE 4" and 5" drill pipe . May 09, 2013: Replace bag and finish testing BOPE. The well lost 2.5 BBLS while testing BOPE and picking up drill pipe. Filled the well with 2.5 BBLS. Trip in with 4" drill pipe and start to pick up 5" drill pipe. May 10, 2013: Pick up 5" drill pipe and 4" drill pipe and rack back in the derrick. Lay down 4" HWDP and start to pick up drilling BHA. May 11, 2013: Pick up and make up new BHA. Rerun bit #2. Trip in hole on elevators and filling the hole at 4210' and 8690'. Hole tight at 10150' (coal) four minutes. Worked through. Hole tight at 11014' (coal). Pump through. Hole tight at 11248' (coal). Hole becoming tighter. Pumping down. Pump down to 11400'. Maximum gas noted was 41 units. Pull out of the hole to 10925' at Midnight. May 12, 2013: Continue to trip out of the hole and work through and pumping tight spots to the window (8480'). Work on Top Drive pipe handler (3.5 hours). Trip into the hole to 9112' and start reaming to 11473'. Hole tight from 9000' to 9300' and 11350' to 11400'. Maximum gas reaming the last 24 hours was 15 units. May 13, 2013: Wash and ream to bottom (12162'). Trip gas was 34 units. (Maximum gas tripping in the hole was 42 units). Drill to 12294'. Work on rig pump #2 (3 hours). Circulate at 229 gal/min. Drill/slide formation to 12340'. May 14, 2013: Continue to repair Top Drive wash pipe (7 hours). Down Time Gas (DTG) was 85 units. Wash down from 12354' to 12396' and drill formation to 12518'. Circulate and work on pump pump #1 swab at midnight. May 15, 2013: Complete changing out swab and liner in mud pump #1. Drill formation to 12655'. May 16, 2013: Drill and slide formation to 12831’. May 17, 2013: Drill formation to 12890'. Pumped a high viscosity sweep and circulated out samples and condition the hole. Wiper trip to 11788'. Tripped to bottom with no problems and drill/slide to 12923'. Circulate bottoms up and begin to pull out of the hole. Cook Inlet Energy RU-2A 33 . May 18, 2013: Pull out of the hole to 10832'. Change elevators and saver sub. Pull out of the hole to 8670'. Circulate and work the drill pipe and pump a weighted slug. Maximum gas was 16 units. Pull out of the hole to 8380'. Start to pull out of the hole and lay down 4" drill pipe to 2129'. Run in the hole with the 4" drill pipe from the derrick to 4570' and pull out of the hole laying down the 4" drill pipe. May 19, 2013: Circulated and pumped a weighted slug. Maximum gas was 7 units. Pull out of the hole to 752'. Lay down the 4" drill pipe. Remove nuke sources. Down load MWD and commence to test the BOPE. May 20, 2013: Run in the hole with 5" HWDP and run in the hole with single 5" drill pipe. No drilling mud circulated. May 21, 2013: Run in the hole with 5 inch drill pipe to 8500'. Slip and cut new drilling line and circulate bottoms up with 113 units of trip gas at the shoe. Pull out of the hole to the surface. Upload the MWD and inspect the draw works. Run in the hole with the HWDP and test the MWD tools (8 units of gas circ). Pick up and run in the hole with the remaining 48 joints of 5" drill pipe until midnight (2261'). May 22, 2013: Run in the hole to 12570'. Top drive lost power. Circulate and work the drill pipe while troubleshooting the top drive. Trip gas was 318 units (migration). Run in the hole and drill ahead to 12965'. Lost rig power three times. Top drive leaking fluids. Circulate drilling mud and work on top drive. May 23, 2013: Finish working on leak on the top drive. Drill and slide formation to 13547'. May 24, 2013: Drill formation to 13815'. Quadco system down. Rack back one stand and work on Quadco while circulating. Drill formation to 14009'. Lost power to the top drive. Circulating drilling mud and working the drill pipe. Trouble shoot top drive problem. May 25, 2013: Finish repairing the top drive and drill to 14104'. Top drive leaking oil. Circulate and repair the top drive oil leak. Drill ahead to 14390 and circulate bottoms up until the shakers are clean before a wiper trip. May 26, 2013: Circulate bottoms up three times. Back ream out of the hole for short trip. Hole has several tight spots pulling off bottom. Increased flow rate and RPM to drilling parameters and circulate bottoms up 1.5 times at 12685'. The shakers had a steady flow of cuttings at the shaker. Slight amount of larger coal fragments. Wash down to 13255' and run in on elevators to 14295' and was down the last stand. Wiper gas was 109 units. Drill ahead to 14483' and circulate on pump #2 at 60 spm while repairing pump #1. Drilling ahead to midnight. May 27, 2013: Circulate bottoms up three times. Back ream out of the hole for short trip. Hole has several tight spots pulling off bottom. Increased flow rate and RPM to drilling parameters and circulate bottoms up 1.5 times at 12685'. The shakers had a steady flow of cuttings at the shaker. Slight amount of larger coal fragments. Wash down to 13255' and run in on elevators to 14295' and was down the last stand. Wiper gas was 109 units. Drill ahead to 14483' and circulate on pump #2 at 60 spm while repairing pump #1. Drilling ahead to midnight. May 28, 2013: Drill formation to 14720'. Pump a 40 bbl high viscosity sweep. Pump #1 lost a swab. Circulate with pump #2 at 70 spm. Sweep was not seen at the surface and shakers. Cook Inlet Energy RU-2A 34 May 29, 2013: Drill formation to 15075' and pumped a high viscosity sweep. Surface to surface was 12400 strokes with no significant cuttings increased at the shakers. Cuttings are elongating themselves as they transport up the well bore. Sample percentages also reflect this. May 30, 2013: Drill formation to 15209'. Lost a swab on mud pump #1, slow pump #2 to 210 gpm and rotate and reciprocate the drill pipe while working on pump #1. Drill formation to 15256' and lost a swab on pump #2. Circulate and work on pump #2. Drill to 15360' (TD) and circulate the hole. 4.2 SURVEY DATA Measured Depth Inclination Azimuth TVD Vertical Section +NS - +EW- DLS ( ft ) ( deg ) ( deg ) ( ft ) ( ft ) ( ft ) (ft ) (deg/100 ft) 8456.53 35.82 121.83 7087.10 4207.19 -2336.67 +3500.56 0.50 8522.00 35.37 122.15 7140.34 4245.30 -2356.86 +3532.88 0.74 8588.10 38.00 122.47 7193.34 4284.78 -2377.97 +3566.25 3.99 8639.05 37.61 122.70 7233.59 4316.02 -2394.79 +3592.57 0.82 8734.65 39.44 123.14 7308.38 4375.55 -2427.15 +3642.55 1.94 8829.81 40.08 123.55 7381.53 4436.40 -2460.61 +3693.39 0.73 8925.18 39.28 123.96 7454.93 4497.27 -2494.44 +3744.02 0.88 9019.36 40.61 126.19 7527.14 4557.65 -2529.20 +3793.49 2.07 9112.63 41.22 121.15 7597.64 4618.67 -2563.03 +3844.30 3.60 9204.52 40.97 121.01 7666.89 4679.06 -2594.21 +3896.03 0.29 9300.02 40.57 119.90 7739.22 4741.39 -2625.82 +3949.79 0.87 9394.49 40.11 120.58 7811.22 4802.51 -2656.61 +4002.62 0.67 9488.86 39.48 120.20 7883.73 4862.88 -2687.17 +4054.72 0.72 9583.51 38.58 120.59 7957.26 4922.46 -2717.33 +4106.13 0.99 9679.22 38.89 120.37 8031.91 4982.32 -2747.70 +4157.74 0.35 9771.83 38.96 120.24 8103.96 5040.48 -2777.06 +4207.98 0.12 9866.49 38.79 119.88 8177.66 5099.85 -2806.82 +4259.40 0.30 9961.11 38.98 118.87 8251.31 5159.18 -2835.96 +4311.16 0.70 10054.94 38.62 118.49 8324.44 5217.86 -2864.17 +4362.74 0.46 10147.60 39.12 117.04 8396.58 5275.84 -2891.26 +4414.19 1.12 10241.54 38.17 119.15 8469.95 5334.35 -2918.87 +4465.94 1.73 10336.77 39.28 118.87 8544.25 5393.83 -2947.76 +4518.04 1.18 10429.31 40.22 118.80 8615.39 5452.91 -2976.30 +4569.88 1.02 10523.72 39.81 119.45 8687.70 5513.53 -3005.84 +4622.91 0.62 10617.87 39.37 118.49 8760.25 5573.44 -3034.91 +4675.40 0.80 10713.75 38.90 119.01 8834.62 5633.84 -3064.01 +4728.45 0.60 10807.11 40.05 119.88 8906.69 5696.13 -3093.19 +4780.14 1.37 10901.39 40.13 120.31 8978.82 5753.81 -3123.64 +4832.67 0.31 10997.99 40.80 119.55 9052.31 5816.45 -3154.91 +4887.00 0.86 11090.35 40.20 119.92 9122.54 5876.38 -3184.66 +4939.06 0.70 11183.32 40.50 120.09 9193.39 5936.53 -3214.76 +4991.21 0.34 11276.83 39.91 119.65 9264.81 5996.55 -3244.83 +5043.55 0.70 11373.42 39.85 119.36 9338.93 6058.71 -3275.33 +5097.45 0.20 11466.03 39.23 119.49 9410.35 6117.60 -3304.29 +5148.80 0.68 11561.75 39.89 118.61 9484.15 6178.48 -3333.89 +5202.10 0.90 11654.72 39.92 118.73 9555.47 6238.01 -3362.51 +5254.43 0.09 11750.11 39.72 118.57 9628.73 6298.98 -3391.79 +5308.03 0.24 11844.34 39.36 118.25 9701.40 6358.84 -3420.34 +5360.80 0.44 11939.43 38.36 119.47 9775.44 6418.40 -3449.12 +5413.05 1.32 12032.11 38.43 118.92 9848.08 6475.89 -3477.20 +5462.30 0.38 Cook Inlet Energy RU-2A 36 Measured Depth Inclination Azimuth TVD Vertical Section +NS- +EW- DLS ( ft ) ( deg) ( deg ) ( ft ) (ft) ( ft ) ( ft ) (deg/100 ft ) 12123.50 38.00 118.44 9919.89 6532.32 -3504.33 +5512.89 0.57 12219.64 37.79 118.62 9995.75 6591.25 -3532.54 +5564.77 0.25 12313.56 38.24 117.84 10069.75 6648.96 -3559.90 +5615.74 0.70 12409.73 38.58 118.23 10145.11 6708.55 -3587.98 +5668.47 0.43 12502.72 38.62 117.46 10217.78 6766.40 -3615.08 +5719.77 0.52 12598.05 38.77 118.16 10292.18 6825.83 -3642.88 +5772.48 0.49 12693.04 38.88 118.19 10366.19 6885.98 -3671.00 +5824.98 0.12 12787.90 38.79 117.24 10440.08 6944.55 -3698.66 +5877.64 0.64 12823.49 38.75 118.46 10467.83 6966.77 -3709.08 +5897.34 2.15 12879.71 38.55 119.72 10511.74 7001.83 -3726.15 +5928.03 1.44 12923.49 38.91 119.80 10545.89 7029.20 -3739.74 +5951.80 0.83 13017.51 37.95 119.60 10619.54 7057.58 -3768.70 +6002.57 1.03 13112.48 36.63 118.28 10695.10 7145.03 -3796.54 +6052.91 1.63 13208.30 38.03 120.30 10771.29 7203.06 -3824.98 +6103.57 1.24 13303.12 38.33 120.91 10845.83 7261.65 -3854.82 +6154.02 0.51 13397.04 39.33 121.33 10918.99 7320.52 -3885.26 +6204.43 1.10 13493.39 39.29 121.92 10993.54 7381.56 -3917.27 +6256.40 0.39 13587.50 39.36 122.00 11066.34 7441.20 -3948.83 +6307.00 0.09 13682.96 40.53 122.91 11139.52 7502.49 -3981.73 +6358.71 1.37 13776.91 40.40 123.45 11211.00 7563.45 -4015.10 +6409.75 0.40 13872.69 41.04 123.71 11283.59 7625.91 -4049.66 +6461.80 0.69 13965.19 40.77 123.13 11353.50 7686.46 -4083.02 +6512.35 0.50 14062.33 41.11 122.40 11426.88 7750.11 -4117.46 +6565.88 0.60 14156.57 40.43 122.59 11498.25 7811.65 -4150.52 +6617.79 0.73 14251.18 40.03 121.70 11570.49 7872.75 -4183.04 +6669.52 0.74 14345.87 39.16 120.22 11643.45 7933.09 -4214.09 +6721.27 1.36 14439.25 38.58 118.92 11716.16 7991.63 -4243.23 +6772.23 1.07 14533.59 37.60 117.42 11790.41 8049.68 -4270.49 +6823.53 1.43 14627.15 36.51 115.17 11865.07 8105.76 -4295.47 +6874.06 1.86 14725.71 35.57 111.34 11944.78 8163.03 -4318.38 +6927.30 2.48 14819.24 34.85 106.27 12021.21 8215.47 -4335.77 +6978.30 3.22 14915.65 34.19 97.25 12100.70 8266.57 -4346.91 +7031.65 5.34 15009.86 34.28 90.93 12178.62 8313.29 -4350.68 +7084.46 3.77 15103.93 35.13 84.15 12255.98 8357.29 -4348.35 +7137.89 4.20 15198.47 37.09 78.43 12332.37 8399.35 -4339.86 +7192.90 4.12 15292.46 37.62 74.35 12407.10 8439.12 -4326.43 +7248.30 2.69 15318.76 37.43 73.84 12427.95 8449.83 -4322.04 +7263.70 1.38 15360.00 37.43 73.84 12460.70 8466.50 -4315.07 +7287.78 0.00 Cook Inlet Energy RU-2A 37 4.3 MUD RECORD Contractor: Baroid Mud Type: Enviromul Oil Base Mud (8555’ to 15360’) DATE DEPTH MW VIS PV YP GELS FL FC SOLIDS OIL/WATER SAND E. STAB Lime 4-22-13 8561 9.40 122 34 24 14/18/22 0/2 5.2 60.0/31.0 246 4.53 4-23-13 9100 9.25 101 34 25 19/24/28 0/2 5.9 64.0/27.0 0.10 483 5.05 4-24-13 9750 9.40 109 37 28 19/23/27 0/2 6.7 62.5/27.5 0.10 470 5.05 4-25-13 10097 9.30 85 29 24 16/19/21 0/2 5.9 64.0/27.0 0.10 455 4.79 4-26-13 10097 9.30 85 29 25 16/19/21 0/2 5.9 64.0/27.0 0.10 455 4.79 4-27-13 10097 9.40 111 21 23 16/19/21 0/2 5.9 64.0/27.0 0.10 436 4.79 4-28-13 10372 9.30 78 21 21 63.0/26.0 0/2 6.5 65.0/26.0 0.10 498 5.18 4-29-13 10372 9.30 85 22 21 12/17/19 0/2 6.1 65.0/26.0 0.10 498 5.18 4-30-13 10372 9.35 77 20 21 11/15/19 0/2 5.9 65.0/26.0 0.10 502 5.18 5-01-13 10372 9.35 86 21 19 11/15/19 0/2 5.8 64.0/27.0 0.10 495 5.57 5-02-13 10965 9.35 62 25 21 11/16/21 0/2 6.5 65.5/25.0 0.10 495 5.57 5-03-13 11224 9.40 67 21 21 12/17/21 0/2 6.5 66.0/24.5 0.10 596 5.18 5-04-13 11594 9.35 58 21 20 11/14/18 0/2 6.6 66.5/24.0 0.10 666 5.18 5-05-13 11976 9.35 60 18 20 11/15/18 0/2 6.1 67.0/24.0 0.10 660 5.18 5-06-13 12162 9.45 63 19 20 10/14/18 0/2 5.7 68.0/23.5 0.10 649 5.05 5-07-13 12162 9.40 91 18 21 11/14/18 0/2 6.7 67.0/23.5 0.10 674 5.05 5-08-13 12162 9.45 96 20 21 11/14/18 0/2 6.7 67.5/23.0 0.10 689 5.05 5-09-13 12162 9.45 93 20 20 11/14/18 0/2 6.7 67.5/23.0 0.10 721 4.92 5-10-13 12162 9.45 95 20 20 11/15/18 0/2 6.7 67.5/23.0 0.10 718 4.79 5-11-13 12162 9.50 80 20 17 10/13/16 0/2 7.2 67.0/23.0 0.10 665 5.44 5-12-13 23325 9.45 62 24 19 12/14/19 0/2 7.2 67.0/23.0 0.10 710 4.14 5-13-13 12396 9.45 70 23 20 12/15/20 0/2 7.6 67.0/23.0 0.10 720 3.37 5-14-13 12518 9.25 57 20 18 10/14/18 0/2 6.7 67.5/24.0 0.10 820 5.18 5-15-13 12652 9.20 65 22 19 12/14/18 0/2 6.8 66.0/25.0 0.10 888 5.31 5-16-13 12840 9.2 68 24 18 12/16/19 0/2 6.2 67.5/24.0 0.10 909 4.92 5-17-13 12922 9.2 60 22 18 11/15/19 0/2 6.1 68.0/23.5 0.10 915 4.53 5-18-13 12922 9.2 67 23 18 11/15/21 0/2 6.3 68.0/23.5 0.10 924 4.14 Cook Inlet Energy RU-2A 38 DATE DEPTH MW VIS PV YP GELS FL FC SOLIDS OIL/WATER SAND E. STAB Lime 5-19-13 12922 9.2 67 22 19 11/16/21 0/2 6.3 68.0/23.5 0.10 907 3.76 5-20-13 12923 9.20 71 22 19 10/15/19 0/2 6.3 68.0/23.5 0.10 902 3.50 5-21-13 12923 9.20 75 22 19 11/15/19 0/2 6.3 68.0/23.5 0.10 921 3.37 5-22-13 12923 9.20 73 22 19 11/14/19 0/2 6.0 68.0/23.5 0.10 893 3.24 5-23-13 13518 9.35 64 24 20 11/16/21 0/2 6.3 69.0/22.0 0.10 965 2.98 5-24-13 14006 9.30 69 22 19 12/15/19 0/2 7.8 67.5/22.0 0.10 949 3.88 5-25-13 14386 9.20 68 21 19 12/17/21 0/2 7.7 70.0/20.0 0.10 1046 4.66 5-26-13 14485 9.30 70 23 19 12/16/20 0/2 7.2 71.5/19.0 0.10 1006 5.83 5-27-13 14777 9.2 68 24 19 12/15/20 0/2 7.3 72.5/18.0 0.10 1011 5.31 5-28-13 15077 9.3 64 24 19 13/18/22 0/2 7.7 72.5/17.5 0.10 1017 5.18 5-29-13 15340 9.2+ 58 24 17 11/18/22 0/2 7.2 72.5/18.0 0.10 1070 5.83 5-30-13 15360 9.2+ 65 27 16 13/19/22 0/2 7.3 74.0/16.5 0.10 1089 5.57 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 1 8 . 5 ” H D B S F X 6 5 D P D C 1 1 6 1 1 1 5 0 3 x 1 2 , 3 x 1 6 8 5 5 5 ’ 1 0 1 99 ’ 1 5 4 5 ’ 3 9 6 1 2 7 1 - 3 - C T - G - X - W T - 1 / 1 6 - B H A 2 8 . 5 ” H D B S F X 7 4 D P D C 1 1 7 4 5 8 2 6 3 x 1 2 , 3 x 1 6 1 0 1 9 9 ’ 1 2 16 2 ’ 1 9 6 3 ’ 6 5 . 5 3 0 2 5 1 - 2 - W T - I - X - B H A 2R R 8 . 5 ” H D B S F X 7 4 D P D C 1 1 7 4 5 8 2 6 3 x 1 2 , 3 x 1 6 1 0 1 9 9 ’ 12 9 2 3 ’ 2 7 2 4 ’ 1 2 1 . 7 5 2 2 2 3 1 - 3 - C T - G - X - I - W T - B H A 3 8. 5 ” H D B S F X D 8 4 D P D C 1 2 0 5 6 2 2 3 9 5 x 1 2 , 3 x 1 3 1 2 9 2 4 ’ 1 5 36 0 ’ 2 4 3 8 ’ 9 0 : 2 7 4 0 2 1 2 - 1 - W T - A - X - I - B T - T D Cook Inlet Energy RU-2A 40 5 DAILY REPORTS COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR MURRAY, DATE Apr 26, 2013 DEPTH 10099.00000 PRESENT OPERATION TRIP OUT TO TEST BOPE TIME 24 HOURS YESTERDAY 9820.00000 24 HOUR FOOTAGE 279' CASING INFORMATION 9 5/8" @ 8554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10054.94 38.62 118.49 8324.44 9961.11 38.98 118.87 8251.31 9866.49 38.79 119.88 8177.66 9771.22 38.89 120.37 8031.91 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 8.5" HDBS FX65D 11611150 3X12, 3X16 8554 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 302.3 @ 10084.00000 2.2 @ 10042.00000 42.4 54.50896 FT/HR SURFACE TORQUE 9280 @ 9949.00000 3177 @ 9824.00000 6451.8 7805.00000 AMPS WEIGHT ON BIT 71 @ 10039.00000 6 @ 9995.00000 33.5 37.00000 KLBS ROTARY RPM 87 @ 9985.00000 1 @ 9822.00000 67.3 80.00000 RPM PUMP PRESSURE 4178 @ 9826.00000 3820 @ 9995.00000 3998.0 4018.00000 PSI DRILLING MUD REPORT DEPTH 10097' MW 9.3 VIS 85 PV 29 YP 24 FL - Gels 16/19/21 CL- - FC 0/2 SOL 5.9 SD 0.10 OIL 70.3/29.7 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 45 @ 9869.00000 11 @ 9837.00000 19.1 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 5891 @ 9869.00000 791 @ 9830.00000 1773.5 CONNECTION GAS HIGH 0 ETHANE (C-2) 24 @ 9850.00000 0 @ 10041.00000 2.9 AVG 0 PROPANE (C-3) 0 @ 10099.00000 0 @ 10099.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 10099.00000 0 @ 10099.00000 0.0 CURRENT BACKGROUND/AVG 5 (TOOH) PENTANE (C-5) 0 @ 10099.00000 0 @ 10099.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILTSTONE, TUFFACEOUS CLAYSTONE, COAL, CARBON CLAY, SAND, SANDSTONE PRESENT LITHOLOGY 10099' = SAND 40%, SANDSTONE 10%, TUFFACEOUS CLAYSTONE 10%, TUFFACEOUS SILTSTONE 40% DAILY ACTIVITY SUMMARY Drill and slide formation from 9820' to 10099'. Circulate bottom's up four times and pull out of the hole on elevators to 9300' and start to pump out of the hole. EPOCH PERSONNEL ON BOARD BROWNE, PIKE + 2 SC DAILY COST $3290 REPORT BY LEES F. BROWNE JR. Page 1 of 1Daily Report 4/26/2013 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnerg ... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR MURRAY, FAULKNER DATE Apr 27, 2013 DEPTH 10099.00000 PRESENT OPERATION TESTING BOPE TIME 24 HOURS YESTERDAY 10099.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 8554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10054.94 38.62 118.49 8324.44 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 8.5" HDBS FX65D 11611150 3X12, 3X16 8554 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10099' MW 9.3 VIS 85 PV 29 YP 24 FL - Gels 16/19/21 CL- - FC 0/2 SOL 5.9 SD 0.10 OIL 70.3/29.7 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 2 @ TOOH 0 @ TOOH 1 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) @ @ CONNECTION GAS HIGH - ETHANE (C-2) @ @ AVG - PROPANE (C-3) @ @ CURRENT - BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 10099' = SAND 40%, SANDSTONE 10%, TUFFACEOUS CLAYSTONE 10%, TUFFACEOUS SILTSTONE 40% DAILY ACTIVITY SUMMARY Continue to pump and back ream out of the hole to the window. Shut down the mud pumps and worked the BHA through the casing window. Pulled up past the window into the casing and tried to circulate. The hole packed off and we lost 10 bbls of mud into the formation. Worked the pipe and staged the pumps on and worked the pack off and was able to trip out of the hole. Laid down the BHA and started to test the BOPE. EPOCH PERSONNEL ON BOARD BROWNE, PIKE + 2 SC DAILY COST $3340 REPORT BY LEES F. BROWNE JR. Page 1 of 1Daily Report 4/27/2013 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnerg ... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR MURRAY, FAULKNER DATE Apr 28, 2013 DEPTH 10099.00000 PRESENT OPERATION TRIP IN HOLE TO DRILL TIME 24 HOURS YESTERDAY 10099.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 8554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10054.94 38.62 118.49 8324.44 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 8.5" HDBS FX65D 11611150 3X12, 3X16 8554 10099 1545 39 1-3-CT-G-X-WT-1/16 BHA 2 8.5" HDBS FX74D 11745826 3X12, 3X16 10099 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10099' MW 9.4 VIS 111 PV 21 YP 23 FL - Gels 16/19/21 CL- - FC 0/2 SOL 5.9 SD 0.10 OIL 70.3/29.7 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1 @ CIRC 0 @ CIRC 0 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) @ @ CONNECTION GAS HIGH - ETHANE (C-2) @ @ AVG - PROPANE (C-3) @ @ CURRENT - BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 10099' = 40% SANDSTONE 10%, TUFFACEOUS CLAYSTONE 10%, TUFFACEOUS SILTSTONE 40% DAILY ACTIVITY SUMMARY Completed testing the BOPE. Pick up BHA #9 with new bit and run in the hole. Pick up 2000' of 4" drill pipe and continue to trip in the hole to drill. EPOCH PERSONNEL ON BOARD BROWNE, PIKE + 2 SC DAILY COST $3315 REPORT BY LEES F. BROWNE JR. Page 1 of 1Daily Report 4/28/2013 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnerg ... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR MURRAY, FAULKNER DATE Apr 29, 2013 DEPTH 10372.00000 PRESENT OPERATION CIRCULATE / WAIT ON PARTS TIME 24 HOURS YESTERDAY 10099.00000 24 HOUR FOOTAGE 273' CASING INFORMATION 9 5/8" @ 8554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10241.54 38.17 119.15 8469.95 10147.60 39.12 117.04 8396.58 10054.94 38.62 118.49 8324.44 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" HDBS FX74D 11745826 3X12, 3X16 10099 273 4:28 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 203.6 @ 10161.00000 2.2 @ 10189.00000 76.7 36.41123 FT/HR SURFACE TORQUE 9820 @ 10322.00000 6110 @ 10100.00000 7876.4 8249.00000 AMPS WEIGHT ON BIT 66 @ 10198.00000 23 @ 10100.00000 42.5 42.70000 KLBS ROTARY RPM 123 @ 10307.00000 69 @ 10106.00000 101.0 118.00000 RPM PUMP PRESSURE 4319 @ 10137.00000 3979 @ 10189.00000 4192.0 4033.00000 PSI DRILLING MUD REPORT DEPTH 10327' MW 9.3 VIS 78 PV 21 YP 21 FL - Gels 11/17/22 CL- - FC 0/2 SOL 6.5 SD 0.10 OIL 71.4/28.6 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 123 @ 10145.00000 14 @ 10099.00000 35.8 TRIP GAS 56 @ 10099' CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 23226 @ 10145.00000 1124 @ 10099.00000 4756.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 59 @ 10144.00000 0 @ 10220.00000 17.9 AVG 0 PROPANE (C-3) 0 @ 10372.00000 0 @ 10372.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 10372.00000 0 @ 10372.00000 0.0 CURRENT BACKGROUND/AVG 15 circ PENTANE (C-5) 0 @ 10372.00000 0 @ 10372.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILTSTONE, TUFFACEOUS CLAYSTONE, SAND, SANDSTONE, CONGLOMERATE SAND, COAL PRESENT LITHOLOGY 10372' = SAND 40%, SANDSTONE 10%, TUFFACEOUS CLAYSTONE 10%, TUFFACEOUS SILTSTONE 40% DAILY ACTIVITY SUMMARY Trip in the hole to 9245' and work drill pipe through tight coal. Trip into the hole to 9830' (coal) and wash down to TD (10099'). Shakers display a large increase in cuttings with trip gas of 56 units. Work the drill pipe and circulate the hole clean. Drill formation from 10099' to 10372'. Lost the rotary on the top drive. Trouble shoot the SCR while moving the drill pipe. Staged down the mud pumps to 200 gpm to avoid wash outs around coals. At present waiting on new breakers for the top drive. Continue to circulate and move the drill string. EPOCH PERSONNEL ON BOARD BROWNE, PIKE + 2 SC DAILY COST $3340 REPORT BY LEES F. BROWNE JR. Page 1 of 1Daily Report 4/29/2013 file://C:\Documents and Settings\EpochAdmin\Desktop\Cook Inlet RU2A\Morning Report... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR MURRAY, FAULKNER DATE Apr 30, 2013 DEPTH 10372.00000 PRESENT OPERATION WAITING ON TOP DRIVE PARTS TIME 24 HOURS YESTERDAY 10372.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10241.54' 38.17 119.15 8469.95' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" HDBS FX74D 11745826 3X12, 3X16 10099 273 4:28 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10372' MW 9.3 VIS 85 PV 22 YP 21 FL - Gels 12/17/19 CL- - FC 0/2 SOL 6.1 SD 0.10 OIL 71.4/28.6 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 19 @ CIRC 8 @ CIRC 12 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) @ @ CONNECTION GAS HIGH - ETHANE (C-2) @ @ AVG - PROPANE (C-3) @ @ CURRENT - BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 8 PENTANE (C-5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 10372' = SAND 40%, SANDSTONE 10%, TUFFACEOUS CLAYSTONE 10%, TUFFACEOUS SILTSTONE 40% DAILY ACTIVITY SUMMARY Waiting on parts for the top drive and circulating and moving the drill pipe at slow pump rates (200 gpm). EPOCH PERSONNEL ON BOARD BROWNE, PIKE + 2 SC DAILY COST $3340 REPORT BY LEES F. BROWNE JR. Page 1 of 1Daily Report 4/29/2013 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnerg ... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR MURRAY, FAULKNER DATE May 01, 2013 DEPTH 10372.00000 PRESENT OPERATION CIRCULATE AND WAIT ON TOP DRIVE PARTS TIME 24 HOURS YESTERDAY 10372.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 8554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10241.54 38.17 119.15 8469.95 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" HDBS FX74D 11745826 3X12, 3X16 10099 273 4:28 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10372' MW 9.3+ VIS 77 PV 20 YP 21 FL - Gels 11/15/19 CL- - FC - SOL 5.9 SD 0.10 OIL 71.4/28.6 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 13 @ CIRC 8 @ CIRC 9 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) @ @ CONNECTION GAS HIGH - ETHANE (C-2) @ @ AVG - PROPANE (C-3) @ @ CURRENT - BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 9 PENTANE (C-5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 10372' = SAND 40%, SANDSTONE 10%, TUFFACEOUS CLAYSTONE 10%, TUFFACEOUS SILTSTONE 40% DAILY ACTIVITY SUMMARY Circulate drilling mud while reciprocating the hole while waiting on parts for the top drive. EPOCH PERSONNEL ON BOARD BROWNE, PIKE + 2 SC DAILY COST $3340 REPORT BY LEES F. BROWNE JR. Page 1 of 1Daily Report 4/30/2013 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnerg ... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR MURRAY, FAULKNER DATE May 02, 2013 DEPTH 10372.00000 PRESENT OPERATION TRIP IN THE HOLE TO DRILL TIME 24 HOURS YESTERDAY 10372.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 8554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10241.54 38.17 119.15 8469.95 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" HDBS FX74D 11745826 3X12, 3X16 10099 273 4:28 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10372' MW 9.3+ VIS 86 PV 21 YP 19 FL - Gels 11/15/19 CL- - FC 0/2 SOL 5.8 SD 0.10 OIL 70.3/29.7 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 9 @ CIRC 7 @ CIRC 8 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) @ @ CONNECTION GAS HIGH - ETHANE (C-2) @ @ AVG - PROPANE (C-3) @ @ CURRENT - BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 10372' = SAND 40%, SANDSTONE 10%, TUFFACEOUS CLAYSTONE 10%, TUFFACEOUS SILTSTONE 40% DAILY ACTIVITY SUMMARY Circulate and reciprocate the drill string. Pull up into the shoe and continue to trouble shooting the top drive. Cut and slip new drill line. Trip into the hole to drill formation. Running In smooth/slick @ 10,000' EPOCH PERSONNEL ON BOARD BROWNE, PIKE + 2 SC DAILY COST $3340 REPORT BY LEES F BROWNE JR. Page 1 of 1Daily Report 5/1/2013 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnergy\ ... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR JONES, FAULKNER DATE May 03, 2013 DEPTH 11015.00000 PRESENT OPERATION DRILLING FORMATION TIME 24 HOURS YESTERDAY 10372.00000 24 HOUR FOOTAGE 643 CASING INFORMATION 9 5/8" @ 8554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10713.75 38.90 119.01 8834.62 10617.87 39.37 118.49 8760.25 10523.72 39.81 119.45 8687.70 10429.31 40.22 118.80 8615.39 10336.77 39.28 118.87 8544.25 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" HDBS FX74D 11745826 3X12, 3X16 10099 916 19:50 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 242.0 @ 10944.00000 3.1 @ 10967.00000 55.5 10.60362 FT/HR SURFACE TORQUE 10393 @ 10840.00000 6375 @ 10431.00000 7353.6 8375.00000 AMPS WEIGHT ON BIT 70 @ 10961.00000 0 @ 10626.00000 25.6 38.70000 KLBS ROTARY RPM 118 @ 10372.00000 SLIDE @ 10442.00000 93.4 117.00000 RPM PUMP PRESSURE 4511 @ 10430.00000 3668 @ 10488.00000 4067.4 3959.00000 PSI DRILLING MUD REPORT DEPTH 10965' MW 9.3+ VIS 62 PV 25 YP 21 FL - Gels 11/16/21 CL- - FC 0/2 SOL 6.5 SD 0.10 OIL 72.4/27.6 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 61 @ 10372.00000 3 @ 10805.00000 13.4 TRIP GAS - CUTTING GAS @ @ WIPER GAS 40 @ 10372' CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 8614 @ 10372.00000 477 @ 10805.00000 1921.9 CONNECTION GAS HIGH 4 ETHANE (C-2) 28 @ 10785.00000 0 @ 10939.00000 4.2 AVG 1 PROPANE (C-3) 0 @ 11015.00000 0 @ 11015.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 11015.00000 0 @ 11015.00000 0.0 CURRENT BACKGROUND/AVG 13 PENTANE (C-5) 0 @ 11015.00000 0 @ 11015.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILTSTONE, TUFFACEOUS CLAYSTONE, SAND, SANDSTONE, COAL, CARBON CLAY, TUFFACEOUS SANDSTONE, CONGLOMERATE SAND, CONGLOMERATE PRESENT LITHOLOGY 11016' = TUFFACEOUS SILTSTONE 40%, tUFFACEOUS SANDSTONE 20%, SAND 20%, CONGLOMERATE SAND 10%, CONGLOMERATE 10% DAILY ACTIVITY SUMMARY Trip in the hole from the window. Wash down the last stand. Running in the hole clean. Wiper gas was 40 units. Drilling and sliding to 11016' (midnight). EPOCH PERSONNEL ON BOARD BROWNE, PIKE + 2 SC DAILY COST $3340 REPORT BY LEES F. BROWNE JR. Page 1 of 1Daily Report 5/3/2013 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnergy\ ... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR JONES, FAULKNER DATE May 04, 2013 DEPTH 11248.00000 PRESENT OPERATION DRILLING FORMATION TIME 24 HOURS YESTERDAY 11015.00000 24 HOUR FOOTAGE 233' CASING INFORMATION 9 5/8" @ 8554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11183.32 40.50 120.09 9193.39 11090.35 40.20 119.92 9122.54 10997.99 40.80 119.55 9052.31 10901.39 40.13 120.31 8978.82 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" HDBS FX4D 11745826 3X12, 3X16 10099 1149' 26:45 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 180.9 @ 11154.00000 2.1 @ 11248.00000 47.1 2.05550 FT/HR SURFACE TORQUE 9873 @ 11024.00000 7736 @ 11131.00000 5505.5 0.00000 AMPS WEIGHT ON BIT 73 @ 11233.00000 4 @ 11125.00000 22.9 71.70000 KLBS ROTARY RPM 122 @ 11131.00000 108 @ 11112.00000 68.9 0.00000 RPM PUMP PRESSURE 4258 @ 11241.00000 3823 @ 11160.00000 3647.3 4199.00000 PSI DRILLING MUD REPORT DEPTH 11,224' MW 9.4 VIS 67 PV 21 YP 21 FL - Gels 12/17/21 CL- - FC 0/2 SOL 6.5 SD 0.10 OIL 72.9/27.1 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 32 @ 11070.00000 4 @ 11016.00000 9.4 TRIP GAS - CUTTING GAS @ @ WIPER GAS 42 @ 11224' CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 4535 @ 11070.00000 457 @ 11016.00000 1304.5 CONNECTION GAS HIGH 0 ETHANE (C-2) 37 @ 11219.00000 0 @ 11031.00000 10.3 AVG 0 PROPANE (C-3) 0 @ 11248.00000 0 @ 11248.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 11248.00000 0 @ 11248.00000 0.0 CURRENT BACKGROUND/AVG 13 PENTANE (C-5) 0 @ 11248.00000 0 @ 11248.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND, SANDSTONE, TUFFACEOUS SANDSTONE, CONGLOMERATE SANDSTONE, TUFFACEOUS SILTSTONE, TUFFACEOUS CLAYSTONE, COAL PRESENT LITHOLOGY 11248' = SAND 20%, TUFFACEOUS SILTSTONE 60%, TUFFACEOUS SANDSTONE 10%, CONGLOMERATE SANDS 10% DAILY ACTIVITY SUMMARY Drill and slide formation to 11220' and observed a decrease in flow of cuttings at the shakers while sliding. Observed an overpull from 11160' to 11145' while back reaming. Increase RPM to 110 and work tight spot. Drill and slide to 11224' and the rig lost power. Power loss of one hour. Staged up pumps and resumed full returns with reciprocating and rotation freely. Repair rig pumps while circulating at 290 GPM, 60RPM and start wiper trip to 10115'. Pulled freely with two small tight spots at 10620' and 10520' with 235k overpull. Worked through spots and pulled through them without problems. Continued to work on pump #2 at 10115'. Trip in the hole with no tight spots and wash down from 11120' to bottom. Wiper gas was 42 units. EPOCH PERSONNEL ON BOARD BROWNE, PIKE + 2 SC DAILY COST $3340 REPORT BY LEES F. BROWNE JR. Page 1 of 1Daily Report 5/4/2013 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnergy\ ... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR JONES, FAULKNER DATE May 05, 2013 DEPTH 11620.00000 PRESENT OPERATION DRILLING FORMATION TIME 24 HOURS YESTERDAY 11248.00000 24 HOUR FOOTAGE 372' CASING INFORMATION 9 5/8" @ 8554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11373.42 39.85 119.36 9338.93 11276.83 39.91 119.65 9264.81 11183.32 40.50 120.09 9193.39 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" HDBS FX4D 11745826 3X12, 3X16 10099 1521 42:15 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 125.1 @ 11309.00000 0.7 @ 11503.00000 36.0 15.18456 FT/HR SURFACE TORQUE 10032 @ 11547.00000 7385 @ 11480.00000 7774.8 7837.00000 AMPS WEIGHT ON BIT 71 @ 11248.00000 5 @ 11545.00000 22.6 10.30000 KLBS ROTARY RPM 121 @ 11396.00000 SLIDE @ 11432.00000 100.9 120.00000 RPM PUMP PRESSURE 4249 @ 11607.00000 3792 @ 11404.00000 4072.1 4162.00000 PSI DRILLING MUD REPORT DEPTH 11594' MW 9.3+ VIS 58 PV 21 YP 20 FL - Gels 11/14/18 CL- - FC 0/2 SOL 6.6 SD 0.10 OIL 73.5/26.5 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 75 @ 11452.00000 8 @ 11576.00000 17.2 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 12953 @ 11452.00000 118 @ 11357.00000 2796.4 CONNECTION GAS HIGH 0 ETHANE (C-2) 49 @ 11571.00000 0 @ 11469.00000 13.5 AVG 0 PROPANE (C-3) 0 @ 11620.00000 0 @ 11620.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 11620.00000 0 @ 11620.00000 0.0 CURRENT BACKGROUND/AVG 10 PENTANE (C-5) 0 @ 11620.00000 0 @ 11620.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND, CONGLOMERATE SAND, TUFFACEOUS SANDSTONE, TUFFACEOUS SILTSTONE, TUFFACEOUS CLAYSTONE, COAL, CARBON CLAY PRESENT LITHOLOGY 11600' = 100% TUFFACEOUSSILTSTONE DAILY ACTIVITY SUMMARY Drill and slide to 11620'. Back reaming through all slides and coal seams. Pump #1 down for 1.5 hours. Circulate at 56 spm while working on the pump. EPOCH PERSONNEL ON BOARD BROWNE, PIKE + 2 SC DAILY COST $3340 REPORT BY LEES F. BROWNE JR. Page 1 of 1Daily Report 5/5/2013 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnergy\ ... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR JONES, FAULKNER DATE May 06, 2013 DEPTH 12006.00000 PRESENT OPERATION DRILLING FORMATION TIME 24 HOURS YESTERDAY 11620.00000 24 HOUR FOOTAGE 386' CASING INFORMATION 9 5/8" @ 8554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11750.11 39.72 118.57 9628.73 11654.72 39.92 118.73 9555.47 11561.75 39.89 118.61 9484.15 11466.03 39.23 119.49 9410.35 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" HDBS FX4D 11745826 3X12, 3X16 10099 1907 57:49 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 130.4 @ 11641.00000 1.5 @ 11848.00000 33.9 39.73510 FT/HR SURFACE TORQUE 11450 @ 11955.00000 7554 @ 11880.00000 7355.2 9236.00000 AMPS WEIGHT ON BIT 73 @ 11894.00000 1 @ 11793.00000 18.8 9.00000 KLBS ROTARY RPM 122 @ 11914.00000 60 @ 11880.00000 91.5 115.00000 RPM PUMP PRESSURE 4279 @ 11977.00000 3941 @ 11755.00000 4128.0 4156.00000 PSI DRILLING MUD REPORT DEPTH 11976' MW 9.3+ VIS 60 PV 18 YP 20 FL - Gels 11/15/18 CL- - FC 0/2 SOL 6.1 SD 0.10 OIL 73.6/26.4 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 57 @ 11738.00000 7 @ 11933.00000 16.0 TRIP GAS - CUTTING GAS 0 @ 12006.00000 0 @ 12006.00000 0.0 WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 10964 @ 11917.00000 793 @ 11991.00000 2791.4 CONNECTION GAS HIGH 0 ETHANE (C-2) 74 @ 11690.00000 0 @ 11931.00000 21.8 AVG 0 PROPANE (C-3) 0 @ 12006.00000 0 @ 12006.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 12006.00000 0 @ 12006.00000 0.0 CURRENT BACKGROUND/AVG 19 PENTANE (C-5) 0 @ 12006.00000 0 @ 12006.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY COAL, CARBON CLAY, TUFFACEOUS SILTSTONE, TUFFACEOUS CLAYSTONE, SAND, SANDSTONE, TUFFACEOUS SANDSTONE, CONGLOMERATE PRESENT LITHOLOGY 12006' = 60% COAL, 10% CARBON CLAY, 10% TUFFACEOUS SILTSTONE, 20% TUFFACEOUS CLAYSTONE DAILY ACTIVITY SUMMARY Drill and slide formation to 12006'. Back ream through all slides and coals. EPOCH PERSONNEL ON BOARD BROWNE, PIKE + 2 SC DAILY COST $3340 REPORT BY LEES F. BROWNE JR. Page 1 of 1Daily Report 5/6/2013 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnergy\ ... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR JONES, FAULKNER DATE May 07, 2013 DEPTH 12162.00000 PRESENT OPERATION POOH TO TEST BOPE TIME 24 HOURS YESTERDAY 12006.00000 24 HOUR FOOTAGE 156' CASING INFORMATION 9 5/8" SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12126.12 37.87 118.17 9922.01 12032.11 38.43 118.92 9848.08 11939.43 38.36 119.47 9775.44 11844.34 39.36 118.25 9701.40 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" HDBS FX4D 11745826 3X12, 3X16 10099 12162 2063 65:30 BHA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 76.5 @ 12043.00000 3.5 @ 12060.00000 24.2 21.58377 FT/HR SURFACE TORQUE 11065 @ 12035.00000 8194 @ 12060.00000 7748.1 9276.00000 AMPS WEIGHT ON BIT 41 @ 12113.00000 7 @ 12041.00000 17.4 13.40000 KLBS ROTARY RPM 122 @ 12060.00000 114 @ 12041.00000 98.8 118.00000 RPM PUMP PRESSURE 4234 @ 12035.00000 3976 @ 12017.00000 4173.9 4154.00000 PSI DRILLING MUD REPORT DEPTH 12162' MW 9.4+ VIS 63 PV 19 YP 20 FL - Gels 10/14/18 CL- - FC 0/2 SOL 5.7 SD 0.10 OIL 74.3/25.7 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 51 @ 12160.00000 9 @ 12146.00000 15.0 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 16181 @ 12158.00000 1776 @ 12146.00000 2954.4 CONNECTION GAS HIGH 0 ETHANE (C-2) 100 @ 12158.00000 10 @ 12083.00000 24.5 AVG 0 PROPANE (C-3) 0 @ 12162.00000 0 @ 12162.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 12162.00000 0 @ 12162.00000 0.0 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 0 @ 12162.00000 0 @ 12162.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILTSTONE, TUFFACEOUS CLAYSTONE, COAL, CARBON CLAY, ASH, SAND PRESENT LITHOLOGY 12162' = TUFFACEOUS SILTSTONE 60%, CARBON CLAY 10%, COAL 10%, TUFFACEOUS CLAYSTONE 10%, SAND 10% DAILY ACTIVITY SUMMARY Drill and slide formation to 12162'. Lost 20 bbls to the formation drilling the last stand from 12068 to 12162'. Flow checked the well at 12162' (TD) and no static loses observed. Circulated bottoms up once with the drill pipe rotating and reciprocating freely and the shakers free of cuttings. Spot a 50 bbl wellbore strengthening pill from 12162' (TD) to 11487'. Trip out of the hole on elevators. One tight spot at 9460' (15' coal). Pulled the BHA through the window into casing. Rigged up injection lines and begin to lay down 4" drill pipe and inject slop mud and water. EPOCH PERSONNEL ON BOARD BROWNE, PIKE + 2 SC DAILY COST $3340 REPORT BY LEES F. BROWNE JR. Page 1 of 1Daily Report 5/7/2013 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnergy\ ... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR JONES, FAULKNER DATE May 08, 2013 DEPTH 12162.00000 PRESENT OPERATION TEST BOPE TIME 24 HOURS YESTERDAY 12162.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 8554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12126.12 37.87 118.17 9922.01 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" HDBS FX4D 11745826 3X12, 3X16 10099 2063 65:30 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 12162' MW 9.4+ VIS 63 PV 19 YP 20 FL - Gels 10/14/18 CL- - FC 0/2 SOL 5.7 SD 0.10 OIL 74.3/25.7 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) @ @ CONNECTION GAS HIGH - ETHANE (C-2) @ @ AVG - PROPANE (C-3) @ @ CURRENT - BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 12162' = 60% TUFFACEOUS SILTSTONE, 10% CARBON CLAY, 10% COAL, 10% TUFFACEOUS CLAYSTONE, 10% SAND DAILY ACTIVITY SUMMARY Laydown BHA, rig up to test BOPE, test BOPE 4" and 5" drill pipe. EPOCH PERSONNEL ON BOARD BROWNE, PIKE + 2 SC DAILY COST $3340 REPORT BY LEES F. BROWNE JR. Page 1 of 1Daily Report 5/8/2013 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnergy\ ... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR JONES, FAULKNER DATE May 09, 2013 DEPTH 12162.00000 PRESENT OPERATION TRIP IN w/ 5" SINGLE DRILL PIPE TIME 24 HOURS YESTERDAY 12162.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 8554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12126.12 37.87 118.17 9922.01 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" HDBS FX4D 11745826 3X12, 3X16 10099 2063 65:30 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 12162' MW 9.4+ VIS 96 PV 20 YP 21 FL - Gels 11/14/18 CL- - FC 0/2 SOL 6.7 SD 0.10 OIL 74.6/25.4 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) @ @ CONNECTION GAS HIGH - ETHANE (C-2) @ @ AVG - PROPANE (C-3) @ @ CURRENT - BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 12162' = 60% TUFFACEOUS SILTSTONE, 10% CARBON CLAY, 10% COAL, 10% TUFFACEOUS CLAYSTONE, 10% SAND DAILY ACTIVITY SUMMARY Replace bag and finish testing BOPE. The well lost 2.5 bbls while testing BOPE and picking up drill pipe. Filled the well with 2.5 bbls. Trip in with 4" drill pipe and start to pick up 5" drill pipe. EPOCH PERSONNEL ON BOARD BROWNE, PIKE + 2 SC DAILY COST $3340 REPORT BY LEES F. BROWNE JR. Page 1 of 1Daily Report 5/9/2013 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnergy\ ... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR MURRAY, FAULKNER DATE May 10, 2013 DEPTH 12162.00000 PRESENT OPERATION PICKING UP BHA TO DRILL TIME 24 HOURS YESTERDAY 12162.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 8554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12126.12 37.87 118.17 9922.01 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" HDBS FX4D 11745826 3X12, 3X16 10099 2063 65:30 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 12162' MW 9.4+ VIS 93 PV 20 YP 20 FL - Gels 11/14/18 CL- - FC 0/2 SOL 6.7 SD 0.10 OIL 74.6/25.4 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) @ @ CONNECTION GAS HIGH - ETHANE (C-2) @ @ AVG - PROPANE (C-3) @ @ CURRENT - BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 12162' = 60% TUFFACEOUS SILTSTONE, 10% CARBON CLAY, 10% COAL, 10% TUFFACEOUS CLAYSTONE, 10% SAND DAILY ACTIVITY SUMMARY Pick up 5" drill pipe and 4" drill pipe and rack back in the derrick. Lay down 4" HWDP and start to pick up drilling BHA. EPOCH PERSONNEL ON BOARD BROWNE, PIKE + 2 SC DAILY COST $3340 REPORT BY LEES F. BROWNE JR. Page 1 of 1Daily Report 5/10/2013 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnerg ... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR MURRAY, FAULKNER DATE May 11, 2013 DEPTH 12162.00000 PRESENT OPERATION WORKING TIGHT HOLE TIME 24 HOURS YESTERDAY 12162.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 8554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12126.12 37.87 118.17 922.01 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 RR 8.5" HDBS FX4D 11745826 3X12, 3X16 10099 2063 65:30 rr 1-1-WT-A-X-I-N RR DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 12162' MW 9.4+ VIS 93 PV 20 YP 20 FL - Gels 11/14/18 CL- - FC 0/2 SOL 6.7 SD 0.10 OIL 74.6/25.4 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 41 @ TIH 2 @ TIH 5 TRIP GAS 41 @ 11400' CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) @ @ CONNECTION GAS HIGH - ETHANE (C-2) @ @ AVG - PROPANE (C-3) @ @ CURRENT - BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 4 PENTANE (C-5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 12162' = 60% TUFFACEOUS SILTSTONE, 10% CARBON CLAY, 10% COAL, 10% TUFFACEOUS CLAYSTONE, 10% SAND DAILY ACTIVITY SUMMARY Pick up and make up new BHA. Rerun bit #2. Trip in hole on elevators and filling the hole at 4210' and 8690'. Hole tight at 10150' (coal) four minutes. Worked through. Hole tight at 11014' (coal). Pump through. Hole tight at 11248' (coal). Hole becoming tighter. Pumping down. Pump down to 11400'. Maximum gas noted was 41 units. Pull out of the hole to 10925' at midnight EPOCH PERSONNEL ON BOARD BROWNE, PIKE + 2 SC DAILY COST $3340 REPORT BY LEES F. BROWNE JR. Page 1 of 1Daily Report 5/11/2013 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnerg ... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR DATE May 12, 2013 DEPTH 12162.00000 PRESENT OPERATION REAMING TO BOTTOM TO DRILL TIME 24 HOURS YESTERDAY 12162.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 8554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12126.12 37.87 118.17 9922.01 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2RR 8.5" HDBS FX4D 11745826 3X12, 3X16 10099 2063 65:30 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 15 @ RIH 2 @ RIH 5 TRIP GAS 15 @ 10724' CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) @ @ CONNECTION GAS HIGH - ETHANE (C-2) @ @ AVG - PROPANE (C-3) @ @ CURRENT - BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 3 PENTANE (C-5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 12162' = 60% TUFFACEOUS SILTSTONE, 10% CARBON CLAY, 10% COAL, 10% TUFFACEOUS CLAYSTONE, 10% SAND DAILY ACTIVITY SUMMARY Continue to trip out of the hole and work through and pumping tight spots to the window (8480'). Work on Top Drive pipe handler (3.5 hours). Trip into the hole to 9112' and start reaming to 11473'. Hole tight from 9000' to 9300' and 11350' to 11400'. Maximum gas reaming the last 24 hours was 15 units. EPOCH PERSONNEL ON BOARD BROWNE, PIKE + 2 SC DAILY COST $3340 REPORT BY LEES F. BROWNE JR. Page 1 of 1Daily Report 5/12/2013 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnerg ... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR MURRAY, FAULKNER DATE May 12, 2013 DEPTH 12320.00000 PRESENT OPERATION DRILLING FORMATION TIME 24 HOURS YESTERDAY 12162.00000 24 HOUR FOOTAGE 158' CASING INFORMATION 9 5/8" @ 8554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12219.64 37.79 118.62 9995.75 12123.50 38.00 118.44 9919.89 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2RR 8.5" HDBS FX4D 11745826 3X12, 3X16 10099 2241 74:58 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 148.4 @ 12295.00000 0.9 @ 12315.00000 28.7 25.23586 FT/HR SURFACE TORQUE 15419 @ 12282.00000 9276 @ 12162.00000 8562.5 11580.00000 AMPS WEIGHT ON BIT 60 @ 12298.00000 0 @ 12187.00000 18.5 0.00000 KLBS ROTARY RPM 120 @ 12247.00000 1 @ 12298.00000 84.6 113.00000 RPM PUMP PRESSURE 4454 @ 12170.00000 3863 @ 12310.00000 4201.5 3935.00000 PSI DRILLING MUD REPORT DEPTH 12162' MW 9.5 VIS 80 PV 20 YP 17 FL - Gels 10/13/16 CL- - FC 0/2 SOL 7.2 SD 0.10 OIL 74.4/25.6 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 18 @ 12262.00000 1 @ 12185.00000 4.2 TRIP GAS 34 units @ 12162' CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 3095 @ 12263.00000 282 @ 12185.00000 718.2 CONNECTION GAS HIGH 0 ETHANE (C-2) 34 @ 12162.00000 0 @ 12300.00000 3.7 AVG 0 PROPANE (C-3) 0 @ 12320.00000 0 @ 12320.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 12320.00000 0 @ 12320.00000 0.0 CURRENT BACKGROUND/AVG 7 PENTANE (C-5) 0 @ 12320.00000 0 @ 12320.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND, TUFFACEOUS SILTSTONE, TUFFACEOUS CLAYSTONE, CARBON CLAY, COAL PRESENT LITHOLOGY 12340' = 100% SAND DAILY ACTIVITY SUMMARY Wash and ream to bottom (12162'). Trip gas was 34 units. (Maximum gas tripping in the hole was 42 units). Drill to 12294'. Work on rig pump #2 (3 hours). Circulate at 229 gal/min. Drill/slide formation to 12340'. EPOCH PERSONNEL ON BOARD BROWNE, PIKE + 2 SC DAILY COST $3340 REPORT BY LEES F. BROWNE JR. Page 1 of 1Daily Report 5/13/2013 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnerg ... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR MURRAY, FAULKNER DATE May 15, 2013 DEPTH 12518.00000 PRESENT OPERATION WORK ON MUD PUMP #1 TIME 24 HOURS YESTERDAY 12396.00000 24 HOUR FOOTAGE 122' CASING INFORMATION 9 5/8" @ 8554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12409.73 38.58 118.23 10145.11 12313.56 38.34 117.84 10069.75 12219.64 37.79 118.62 9995.75 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2RR 8.5" HDBS FX4D 11745826 3X12, 3X16 10099 2419 90:13 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 50.7 @ 12493.00000 0.9 @ 12507.00000 13.9 5.50268 FT/HR SURFACE TORQUE 14901 @ 12427.00000 4403 @ 12511.00000 10086.6 0.00000 AMPS WEIGHT ON BIT 40 @ 12474.00000 5 @ 12512.00000 24.7 16.90000 KLBS ROTARY RPM 113 @ 12424.00000 1 @ 12515.00000 66.1 2.00000 RPM PUMP PRESSURE 4242 @ 12422.00000 3814 @ 12474.00000 4051.5 3839.00000 PSI DRILLING MUD REPORT DEPTH 12518' MW 9.2+ VIS 57 PV 20 YP 18 FL - Gels 10/14/18 CL- - FC 0/2 SOL 6.7 SD 0.10 OIL 73.8/26.2 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 37 @ 12420.00000 4 @ 12509.00000 13.1 TRIP GAS - CUTTING GAS @ @ WIPER GAS DTG 85 @ 12396' CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 6994 @ 12420.00000 759 @ 12518.00000 2352.8 CONNECTION GAS HIGH 0 ETHANE (C-2) 52 @ 12420.00000 0 @ 12455.00000 13.0 AVG 0 PROPANE (C-3) 0 @ 12518.00000 0 @ 12518.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 12518.00000 0 @ 12518.00000 0.0 CURRENT BACKGROUND/AVG 5 PENTANE (C-5) 0 @ 12518.00000 0 @ 12518.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILTSTONE, SAND, SANDSTONE, CARBON CLAY, TUFFACEOUS CLAYSTONE AND COAL PRESENT LITHOLOGY 12500' = TUFFACEOUS SILTSTONE 30%, TUFFACEOUS CLAYSTONE 30%, CARBON CLAY 30%, COAL 10% DAILY ACTIVITY SUMMARY Continue to repair Top Drive wash pipe (7 hours). Down Time Gas (DTG) was 85 units. Wash down from 12354' to 12396' and drill formation to 12518'. Circulate and work on pump pump #1 swab at midnight. EPOCH PERSONNEL ON BOARD BROWNE, PIKE+ 2 SC DAILY COST $3340 REPORT BY LEES F. BROWNE JR. Page 1 of 1Daily Report 5/15/2013 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnerg ... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR MURRAY, JOHNSON DATE May 16, 2013 DEPTH 12655.00000 PRESENT OPERATION DRILLING FORMATION TIME 24 HOURS YESTERDAY 12518.00000 24 HOUR FOOTAGE 137' CASING INFORMATION 9 5/8" @ 8554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12409.73' 38.58 118.23 10145.11' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2RR 8.5" HDBS FX4D 11745826 3X12, 3X16 10099 2556 100:32 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 88.7 @ 12655.00000 0.5 @ 12600.00000 23.4 88.66591 FT/HR SURFACE TORQUE 13669 @ 12534.00000 9230 @ 12533.00000 6775.3 10376.00000 AMPS WEIGHT ON BIT 66 @ 12563.00000 4 @ 12531.00000 20.0 15.00000 KLBS ROTARY RPM 115 @ 12542.00000 1 @ 12573.00000 61.0 97.00000 RPM PUMP PRESSURE 4184 @ 12540.00000 3214 @ 12572.00000 3905.7 3620.00000 PSI DRILLING MUD REPORT DEPTH 12652' MW 9.2 VIS 65 PV 22 YP 19 FL - Gels 12/14/18 CL- - FC 0/2 SOL 6.8 SD 0.010 OIL 72.5/27.5 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 54 @ 12642.00000 4 @ 12518.00000 14.9 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 7844 @ 12642.00000 759 @ 12518.00000 2449.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 59 @ 12630.00000 0 @ 12530.00000 9.3 AVG 0 PROPANE (C-3) 0 @ 12655.00000 0 @ 12655.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 12655.00000 0 @ 12655.00000 0.0 CURRENT BACKGROUND/AVG 14 PENTANE (C-5) 0 @ 12655.00000 0 @ 12655.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILTSTONE, TUFFACEOUS CLAYSTONE, SAND, SANDSTONE, TUFFACEOUS SANDSTONE, CARBON CLAY, COAL PRESENT LITHOLOGY 12655' = 70% TUFFACEOUS SILTSTONE, 20% TUFFACEOUS CLAYSTONE, 10% TUFFACEOUS SANDSTONE DAILY ACTIVITY SUMMARY Complete changing out swab and liner in mud pump #1. Drill formation to 12655'. EPOCH PERSONNEL ON BOARD BROWNE, PIKE + 2 SC DAILY COST $3340 REPORT BY LEES F. BROWNE JR. Page 1 of 1Daily Report 5/16/2013 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnerg ... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR MURRAY, JOHNSON DATE May 16, 2013 DEPTH 12655.00000 PRESENT OPERATION DRILLING FORMATION TIME 24 HOURS YESTERDAY 12518.00000 24 HOUR FOOTAGE 137' CASING INFORMATION 9 5/8" @ 8554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12409.73' 38.58 118.23 10145.11' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2RR 8.5" HDBS FX4D 11745826 3X12, 3X16 10099 2556 100:32 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 88.7 @ 12655.00000 0.5 @ 12600.00000 23.4 88.66591 FT/HR SURFACE TORQUE 13669 @ 12534.00000 9230 @ 12533.00000 6775.3 10376.00000 AMPS WEIGHT ON BIT 66 @ 12563.00000 4 @ 12531.00000 20.0 15.00000 KLBS ROTARY RPM 115 @ 12542.00000 1 @ 12573.00000 61.0 97.00000 RPM PUMP PRESSURE 4184 @ 12540.00000 3214 @ 12572.00000 3905.7 3620.00000 PSI DRILLING MUD REPORT DEPTH 12652' MW 9.2 VIS 65 PV 22 YP 19 FL - Gels 12/14/18 CL- - FC 0/2 SOL 6.8 SD 0.010 OIL 72.5/27.5 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 54 @ 12642.00000 4 @ 12518.00000 14.9 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 7844 @ 12642.00000 759 @ 12518.00000 2449.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 59 @ 12630.00000 0 @ 12530.00000 9.3 AVG 0 PROPANE (C-3) 0 @ 12655.00000 0 @ 12655.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 12655.00000 0 @ 12655.00000 0.0 CURRENT BACKGROUND/AVG 14 PENTANE (C-5) 0 @ 12655.00000 0 @ 12655.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILTSTONE, TUFFACEOUS CLAYSTONE, SAND, SANDSTONE, TUFFACEOUS SANDSTONE, CARBON CLAY, COAL PRESENT LITHOLOGY 12655' = 70% TUFFACEOUS SILTSTONE, 20% TUFFACEOUS CLAYSTONE, 10% TUFFACEOUS SANDSTONE DAILY ACTIVITY SUMMARY Complete changing out swab and liner in mud pump #1. Drill formation to 12655'. EPOCH PERSONNEL ON BOARD BROWNE, PIKE + 2 SC DAILY COST $3340 REPORT BY LEES F. BROWNE JR. Page 1 of 1Daily Report 5/17/2013 file://C:\Documents and Settings\EpochAdmin\Desktop\Cook Inlet RU2A\Morning Report... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR JONES, JOHNSON DATE May 18, 2013 DEPTH 12922.00000 PRESENT OPERATION TRIP OUT OF THE HOLE TIME 24 HOURS YESTERDAY 12831.00000 24 HOUR FOOTAGE 91' CASING INFORMATION 9 5/8" @ 8554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12787.90 38.79 117.24 10440.08 12693.04 38.88 118.19 10366.19 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2RR 8.5" HDBS FX4D 11745826 3X12, 3X16 10099 12922 2823 121:40 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 48.2 @ 12872.00000 0.4 @ 12862.00000 14.2 10.83966 FT/HR SURFACE TORQUE 12301 @ 12874.00000 9557 @ 12844.00000 6645.2 11925.00000 AMPS WEIGHT ON BIT 48 @ 12903.00000 2 @ 12847.00000 18.3 0.00000 KLBS ROTARY RPM 118 @ 12889.00000 1 @ 12915.00000 62.2 116.00000 RPM PUMP PRESSURE 3987 @ 12896.00000 3588 @ 12906.00000 3825.2 3817.00000 PSI DRILLING MUD REPORT DEPTH 12823' MW 9.2 VIS 60 PV 22 YP 18 FL - Gels 11/15/19 CL- - FC 0/2 SOL 6.1 SD 0.10 OIL 74.3/25.7 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 64 @ 12877.00000 5 @ 12852.00000 20.2 TRIP GAS - CUTTING GAS @ @ WIPER GAS 39 @ 12890' CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 8623 @ 12875.00000 991 @ 12850.00000 2886.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 86 @ 12880.00000 0 @ 12853.00000 12.5 AVG 0 PROPANE (C-3) 0 @ 12922.00000 0 @ 12922.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 12922.00000 0 @ 12922.00000 0.0 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 0 @ 12922.00000 0 @ 12922.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILTSTONE, SAND, TUFFACEOUS SANDSTONE, CARBON CLAY COAL PRESENT LITHOLOGY 12922' = 70% TUFFACEOUS SILTSTONE, 20% TUFFACEOUS SANDSTONE (INTERBEDDED), 10% TUFFACEOUS CLAYSTONE DAILY ACTIVITY SUMMARY Drill formation to 12890'. Pumped a high viscosity sweep and circulated out samples and condition the hole. Wiper trip to 11788'. Tripped to bottom with no problems and drill/slide to 12923'. Circulate bottoms up and begion to pull out of the hole. EPOCH PERSONNEL ON BOARD BROWNE, PIKE + 2 SC DAILY COST $3340 REPORT BY LEES F. BROWNE JR. Page 1 of 1Daily Report 5/18/2013 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnerg ... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR JONES, JOHNSON DATE May 19, 2013 DEPTH 12922.00000 PRESENT OPERATION TRIP OUT OF THE HOLE TIME 24 HOURS YESTERDAY 12922.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 8554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12787.90 38.79 117.24 10440.08 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2RR 8.5" HDBS FX4D 11745826 3X12, 3X16 1009 12922 2823 121:40 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 12922' MW 9.2 VIS 67 PV 23 YP 18 FL - Gels 11/15/21 CL- - FC 0/2 SOL 6.3 SD 0.10 OIL 74.3/25.7 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 16 @ CIRC 0 @ POOH 3 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 12922' = 70% TUFFACEOUS SILTSTONE, 20% TUFFACEOUS SANDSTONE, 10% TUFFACEOUS CLAYSTONE DAILY ACTIVITY SUMMARY Pull out of the hole to 10832'. Change elevators and saver sub. Pull out of the hole to 8670'. Circulate and work the drill pipe and pump a weighted slug. Maximum gas was 16 units. Pull out of the hole to 8380'. Start to pull out of the hole and lay down 4" drill pipe to 2129'. Run in the hole with the 4" drill pipe from the derrick to 4570' and pull out of the hole laying down the 4" drill pipe. EPOCH PERSONNEL ON BOARD BROWNE, PIKE + 2 SC DAILY COST $3340 REPORT BY LEES F. BROWNE JR. Page 1 of 1Daily Report 5/19/2013 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnerg ... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR JONES, JOHNSON DATE May 20, 2013 DEPTH 12922.00000 PRESENT OPERATION TESTING BOPE TIME 24 HOURS YESTERDAY 12922.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 8554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12787.90 38.79 117.24 10440.08 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2RR 8.5" HDBS FX4D 117458826 3X12, 3X16 10099 12922 2823 121:40 1-3-CT-G-X-I-WT BHA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 12922' MW 9.2 VIS 67 PV 22 YP 19 FL - Gels 11/16/21 CL- - FC 0/2 SOL 6.3 SD 0.10 OIL 74.3/25.7 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 7 @ CIRC 0 @ SURFACE 0-1 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) @ @ CONNECTION GAS HIGH - ETHANE (C-2) @ @ AVG - PROPANE (C-3) @ @ CURRENT - BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 12922' = 70% TUFFACEOUS SILTSTONE, 20% TUFFACEOUS SANDSTONE, 10% TUFFACEOUS CLAYSTONE DAILY ACTIVITY SUMMARY Circulatedand pumped a weighted slug. Maximum gas was 7 units. Pull out of the hole to 752'. Lay down the 4" drill pipe. Remove nuke sources. Down load MWD and commence to test the BOPE. EPOCH PERSONNEL ON BOARD BROWNE, PIKE + 2 SC DAILY COST $3340 REPORT BY LEES F BROWNE JR. Page 1 of 1Daily Report 5/20/2013 file://C:\Documents and Settings\EpochAdmin\Desktop\Cook Inlet RU2A\Morning Report... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR JONES, JOHNSON DATE May 21, 2013 DEPTH 12922.00000 PRESENT OPERATION PICK UP 5" DRILL PIPE TIME 24 HOURS YESTERDAY 12922.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 8554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12787.90 38.79 117.24 10440.08 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" HDBS FX84D 12056239 5X12, 3X13 12922 0 0 2RR 8.5" HDBS FX4D 117458826 3X12, 3X16 10099 12922 2823 121:40 1-3-CT-G-X-I-WT BHA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 12922' MW 9.2 VIS 71 PV 22 YP 19 FL - Gels 10/15/19 CL- - FC 0/2 SOL 6.3 SD 0.10 OIL 74.3/25.7 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ 0 @ 0 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) @ @ CONNECTION GAS HIGH - ETHANE (C-2) @ @ AVG - PROPANE (C-3) @ @ CURRENT - BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 12922' = 70% TUFFACEOUS SILTSTONE, 20% TUFFACEOUS SANDSTONE, 10% TUFFACEOUS CLAYSTONE DAILY ACTIVITY SUMMARY Run in the hole with 5" HWDP and run in the hole with single 5" drill pipe. No drilling mud circulated. EPOCH PERSONNEL ON BOARD BROWNE, PIKE + 2 SC DAILY COST $3340 REPORT BY LEES F. BROWNE JR. Page 1 of 1Daily Report 5/21/2013 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnerg ... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR JONES, JOHNSON DATE May 22, 2013 DEPTH 12922.00000 PRESENT OPERATION TRIP IN HOLE TO DRILL TIME 24 HOURS YESTERDAY 12922.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 95/8" @ 8554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12787.90 38.79 117.24 10440.08 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" HDBS FX84D 12056239 5X12, 3X13 12922 0 0 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 12922 MW 9.2 VIS 75 PV 22 YP 19 FL - Gels 11/15/19 CL- - FC 0/2 SOL 6.3 SD 0.10 OIL 74.3/25.7 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 113 @ 8500' 0 @ TIH 4 TRIP GAS 113 @ 8500' CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) @ @ CONNECTION GAS HIGH - ETHANE (C-2) @ @ AVG - PROPANE (C-3) @ @ CURRENT - BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 12922' = 70% TUFFACEOUS SILTSTONE, 20% TUFFACEOUS SANDSTONE, 10% TUFFACEOUS CLAYSTONE DAILY ACTIVITY SUMMARY Run in the hole with 5 inch drill pipe to 8500'. Slip and cut new drilling line and circulate bottoms up with 113 units of trip gas at the shoe. Pull out of the hole to the surface. Upload the MWD and inspect the draw works. Run in the hole with the HWDP and test the MWD tools (8 units of gas circ). Pick up and run in the hole with the remaining 48 joints of 5" drill pipe until midnight (2261'). EPOCH PERSONNEL ON BOARD BROWNE, PIKE + 2 SC DAILY COST $3340 REPORT BY LEES F. BROWNE JR. Page 1 of 1Daily Report 5/22/2013 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnerg ... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR JONES, JOHNSON DATE May 23, 2013 DEPTH 12965.00000 PRESENT OPERATION WORK ON TOP DRIVE TIME 24 HOURS YESTERDAY 12922.00000 24 HOUR FOOTAGE 43' CASING INFORMATION 9 5/8" @ 8554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12923.49 38.91 119.80 10578.10 12787.90 38.79 117.24 10440.08 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" HDBS FX84D 120562239 5X12, 3X13 12922 43 1 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 159.8 @ 12948.00000 10.8 @ 12922.00000 54.5 15.44137 FT/HR SURFACE TORQUE 19830 @ 12955.00000 11925 @ 12922.00000 18635.1 16810.00000 AMPS WEIGHT ON BIT 25 @ 12965.00000 5 @ 12924.00000 15.1 25.70000 KLBS ROTARY RPM 116 @ 12922.00000 83 @ 12963.00000 92.7 92.00000 RPM PUMP PRESSURE 3817 @ 12922.00000 2804 @ 12923.00000 3401.8 3048.00000 PSI DRILLING MUD REPORT DEPTH 12922' MW 9.2 VIS 73 PV 22 YP 19 FL - Gels 11/14/19 CL- - FC 0/2 SOL 6.0 SD 0.10 OIL 74.3/25.7 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 35 @ 12965.00000 18 @ 12923.00000 1.7 TRIP GAS 318 @ 12542' CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 2062 @ 12922.00000 2062 @ 12922.00000 48.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 12965.00000 0 @ 12965.00000 0.0 AVG 0 PROPANE (C-3) 0 @ 12965.00000 0 @ 12965.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 12965.00000 0 @ 12965.00000 0.0 CURRENT BACKGROUND/AVG 54 PENTANE (C-5) 0 @ 12965.00000 0 @ 12965.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILTSTONE, TUFFACEOUS CLAYSTONE, CARBON COAL, COAL, TUFFACEOUS SANDSTONE PRESENT LITHOLOGY 12965' = TUFFACEOUS SILTSTONE 100% DAILY ACTIVITY SUMMARY Run in the hole to 12570'. Top drive lost power. Circulate and work the drill pipe while troubleshooting the top drive. Trip gas was 318 units (migration). Run in the hole and drill ahead to 12965'. Lost rig power three times. Top drive leaking fluids. Circulate drilling mud and work on top drive. EPOCH PERSONNEL ON BOARD BROWNE, PIKE + 2 SC DAILY COST $3340 REPORT BY LEES F. BROWNE JR. Page 1 of 1Daily Report 5/23/2013 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnerg ... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR MURRAY, JOHNSON DATE May 24, 2013 DEPTH 13547.00000 PRESENT OPERATION DRILLING TIME 24 HOURS YESTERDAY 12965.00000 24 HOUR FOOTAGE 582' CASING INFORMATION 9 5/8" @ 8554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 13493.39 39.29 121.92 10993.54 13397.04 39.33 121.33 10918.99 13303.12 38.33 120.91 10845.83 13208.30 38.03 120.30 10771.29 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" HDBS FX84D 120562239 5X12, 3X13 12922 625 13:42 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 264.0 @ 13491.00000 0.7 @ 13077.00000 53.8 128.94300 FT/HR SURFACE TORQUE 20258 @ 13463.00000 1219 @ 13363.00000 14336.5 0.00000 AMPS WEIGHT ON BIT 85 @ 13178.00000 3 @ 13237.00000 29.8 51.80000 KLBS ROTARY RPM 96 @ 13346.00000 1 @ 13491.00000 63.8 0.00000 RPM PUMP PRESSURE 3726 @ 13360.00000 2553 @ 13479.00000 2883.6 2840.00000 PSI DRILLING MUD REPORT DEPTH 13518' MW 9.3+ VIS 64 PV 24 YP 20 FL - Gels 11/16/21 CL- - FC 0/2 SOL 6.3 SD 0.10 OIL 75.8/24.2 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 161 @ 13465.00000 15 @ 13410.00000 29.6 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 27106 @ 13464.00000 1922 @ 13410.00000 4511.2 CONNECTION GAS HIGH 0 ETHANE (C-2) 117 @ 13459.00000 11 @ 13214.00000 30.6 AVG 0 PROPANE (C-3) 27 @ 13478.00000 0 @ 13503.00000 3.4 CURRENT 0 BUTANE (C-4) 0 @ 13547.00000 0 @ 13547.00000 0.0 CURRENT BACKGROUND/AVG 61 PENTANE (C-5) 0 @ 13547.00000 0 @ 13547.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILTSTONE, TUFFACEOUS SANDSTONE, SAND, CONGLOMERATE SAND, COAL, CARBON CLAY, ASH PRESENT LITHOLOGY 13550' = 20% ASH, 10% CONGLOMERATE SAND, 10% SAND, 60% TUFFACEOUS SILTSTONE DAILY ACTIVITY SUMMARY Finish working on leak on the top drive. Drill and slide formation to 13547' EPOCH PERSONNEL ON BOARD BROWNE, PIKE DAILY COST $2500 REPORT BY LEES F. BROWNE JR. Page 1 of 1Daily Report 5/24/2013 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnerg ... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR MURRAY, JOHNSON DATE May 25, 2013 DEPTH 14009.00000 PRESENT OPERATION CIRC / WORK ON TOP DRIVE TIME 24 HOURS YESTERDAY 13547.00000 24 HOUR FOOTAGE 462' CASING INFORMATION 9 5/8" @ 8554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 13682.96 40.53 122.91 11139.52 13587.50 39.36 122.00 11066.34 13493.39 39.29 121.92 10993.54 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" HDBS FX84D 120562239 5X12, 3X13 12922 1087 22:16 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 414.2 @ 13953.00000 0.4 @ 13726.00000 52.4 16.70146 FT/HR SURFACE TORQUE 21841 @ 13976.00000 929 @ 13554.00000 13152.7 19632.00000 AMPS WEIGHT ON BIT 86 @ 13750.00000 1 @ 13955.00000 20.5 10.50000 KLBS ROTARY RPM 99 @ 13770.00000 1 @ 13950.00000 52.8 78.00000 RPM PUMP PRESSURE 3544 @ 13788.00000 2572 @ 13652.00000 2696.8 2893.00000 PSI DRILLING MUD REPORT DEPTH 14006' MW 9.3 VIS 69 PV 22 YP 19 FL - Gels 12/15/19 CL- - FC 0/2 SOL 7.8 SD 0.10 OIL 75.4/24.8 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 245 @ 13897 12 @ 13969.00000 23.8 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 25910 @ 13865.00000 1497 @ 13970.00000 3532.2 CONNECTION GAS HIGH 0 ETHANE (C-2) 139 @ 13630.00000 11 @ 13599.00000 27.4 AVG 0 PROPANE (C-3) 36 @ 13778.00000 0 @ 13704.00000 1.8 CURRENT 0 BUTANE (C-4) 0 @ 14009.00000 0 @ 14009.00000 0.0 CURRENT BACKGROUND/AVG 14 PENTANE (C-5) 0 @ 14009.00000 0 @ 14009.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILTSTONE, SAND, TUFFACEOUS SANDSTONE, CARBON CLAY, COAL PRESENT LITHOLOGY 14009' = 30% CARBON CLAY, 20% COAL, 20% TUFFACEOUS CLAY, 30% TUFFACEOUS SILT DAILY ACTIVITY SUMMARY Drill formation to 13815'. Quadco system down. Rack back one stand and work on Quadco while circulating. Drill formation to 14009'. Lost power to the top drive. Circulating drilling mud and working the drill pipe. Trouble shoot top drive problem. EPOCH PERSONNEL ON BOARD BROWNE, PIKE DAILY COST $2500 REPORT BY LEES F. BROWNE JR. Page 1 of 1Daily Report 5/25/2013 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnerg ... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR MURRAY, JOHNSON DATE May 26, 2013 DEPTH 14390.00000 PRESENT OPERATION CIRC FOR WIPER TRIP TIME 24 HOURS YESTERDAY 14009.00000 24 HOUR FOOTAGE 381' CASING INFORMATION 9 5/8" @ 8554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 14345.87 39.16 120.22 11643.45 14251.18 40.03 121.70 11570.49 14156.57 40.43 122.59 11498.25 14062.33 41.11 122.40 11426.88 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" HDBS FX84D 120562239 5X12, 3X13 12922 1468 31:05 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 232.9 @ 14213.00000 1.0 @ 14036.00000 54.5 20.86050 FT/HR SURFACE TORQUE 21744 @ 14098.00000 16386 @ 14105.00000 17778.6 20797.00000 AMPS WEIGHT ON BIT 71 @ 14049.00000 3 @ 14106.00000 22.4 17.70000 KLBS ROTARY RPM 99 @ 14085.00000 61 @ 14108.00000 69.2 72.00000 RPM PUMP PRESSURE 3173 @ 14263.00000 2481 @ 14010.00000 2948.4 2841.00000 PSI DRILLING MUD REPORT DEPTH 14386' MW 9.2 VIS 68 PV 21 YP 19 FL - Gels 12/17/21 CL- - FC 0/2 SOL 7.7 SD 0.10 OIL 77.8/22.2 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 101 @ 14091.00000 10 @ 14013.00000 24.9 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 19582 @ 14091.00000 1382 @ 14010.00000 3856.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 202 @ 14275.00000 0 @ 14144.00000 42.1 AVG 0 PROPANE (C-3) 44 @ 14092.00000 0 @ 14060.00000 2.9 CURRENT 0 BUTANE (C-4) 0 @ 14390.00000 0 @ 14390.00000 0.0 CURRENT BACKGROUND/AVG 15 PENTANE (C-5) 0 @ 14390.00000 0 @ 14390.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILTSTONE, TUFFACEOUS CLAYSTONE, SAND, TUFFACEOUS SANDSTONE, CARBON CLAY COAL PRESENT LITHOLOGY 14390' = 60% TUFFACEOUS SILTSTONE, 10% TUFFACEOUS CLAYSTONE, 10% CONGLOMERATE SAND, 10% SAND, 10% ASH DAILY ACTIVITY SUMMARY Finish repairing the top drive and drill to 14104'. Top drive leaking oil. Circulate and repair the top drive oil leak. Drill ahead to 14390 and circulate bottoms up until the shakers are clean before a wiper trip. EPOCH PERSONNEL ON BOARD BROWNE, PIKE DAILY COST $2500 REPORT BY LEES F. BROWNE JR. Page 1 of 1Daily Report 5/26/2013 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnerg ... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR MURRAY, JOHNSON DATE May 27, 2013 DEPTH 14504.00000 PRESENT OPERATION DRILLING TIME 24 HOURS YESTERDAY 14390.00000 24 HOUR FOOTAGE 114' CASING INFORMATION 9 5/8" @ 8554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 14345.87 39.16 120.22 11643.45 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" HDBS FX84D 120562239 5X12, 3X13 12922 1582 37:11 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 117.7 @ 14484.00000 1.2 @ 14494.00000 24.7 5.20579 FT/HR SURFACE TORQUE 21290 @ 14485.00000 18145 @ 14437.00000 20536.6 19713.00000 AMPS WEIGHT ON BIT 37 @ 14484.00000 0 @ 14444.00000 11.7 19.40000 KLBS ROTARY RPM 84 @ 14413.00000 72 @ 14390.00000 77.7 78.00000 RPM PUMP PRESSURE 3024 @ 14398.00000 2814 @ 14472.00000 2943.5 2862.00000 PSI DRILLING MUD REPORT DEPTH 14485' MW 9.3 VIS 70 PV 23 YP 19 FL - Gels 12/16/20 CL- - FC 0/2 SOL 7.2 SD 0.10 OIL 79.0/21.0 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 57 @ 14391.00000 14 @ 14398.00000 25.5 TRIP GAS CUTTING GAS @ @ WIPER GAS 109 @ 14390 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 8790 @ 14391.00000 2171 @ 14398.00000 3531.7 CONNECTION GAS HIGH 0 ETHANE (C-2) 83 @ 14482.00000 17 @ 14398.00000 37.1 AVG 0 PROPANE (C-3) 14 @ 14500.00000 0 @ 14407.00000 0.1 CURRENT 0 BUTANE (C-4) 0 @ 14504.00000 0 @ 14504.00000 0.0 CURRENT BACKGROUND/AVG 23 PENTANE (C-5) 0 @ 14504.00000 0 @ 14504.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILTSTONE, ASH, COAL, CARBON CLAY, SAND, SANDSTONE, TUFFACEOUS SANDSTONE PRESENT LITHOLOGY 14500' = 50% TUFFACEOUS SILTSTONE, 30% SAND, 10% SANDSTONE, 10% CONGLOMERATE DAILY ACTIVITY SUMMARY Circulate bottoms up three times. Back ream out of the hole for short trip. Hole has several tight spots pulling off bottom. Increased flow rate and RPM to drilling parameters and circulate bottoms up 1.5 times at 12685'. The shakers had a steady flow of cuttings at the shaker. Slight amount of larger coal fragments. Wash down to 13255' and run in on elevators to 14295' and was down the last stand. Wiper gas was 109 units. Drill ahead to 14483' and circulate on pump #2 at 60 spm while repairing pump #1. Drilling ahead to midnight. EPOCH PERSONNEL ON BOARD BROWNE, PIKE DAILY COST $2500 REPORT BY LEES F. BROWNE JR. Page 1 of 1Daily Report 5/27/2013 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnerg ... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR MURRAY, JONES DATE May 28, 2013 DEPTH 14774.00000 PRESENT OPERATION DRILLING FORMATION TIME 24 HOURS YESTERDAY 14504.00000 24 HOUR FOOTAGE 270' CASING INFORMATION 9 5/8" @ 8554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 14627.15 36.51 115.17 11865.07 14533.59 37.60 117.42 11790.41 14439.25 38.58 118.92 11716.16 14345.87 39.16 120.22 11643.45 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" HDBS FX84D 120562239 5X12, 3X13 12922 1852 56:13 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 60.8 @ 14621.00000 1.0 @ 14735.00000 17.5 22.51553 FT/HR SURFACE TORQUE 23347 @ 14624.00000 18139 @ 14563.00000 21350.2 20245.00000 AMPS WEIGHT ON BIT 26 @ 14586.00000 7 @ 14662.00000 16.7 18.10000 KLBS ROTARY RPM 112 @ 14681.00000 71 @ 14578.00000 91.9 86.00000 RPM PUMP PRESSURE 3186 @ 14624.00000 2768 @ 14554.00000 2967.6 2985.00000 PSI DRILLING MUD REPORT DEPTH 14774 MW 9.2 VIS 68 PV 24 YP 19 FL - Gels 12/15/20 CL- - FC 0/2 SOL 7.3 SD 0.10 OIL 80.1/19.9 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 33 @ 14628.00000 15 @ 14524.00000 25.8 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 4683 @ 14614.00000 2127 @ 14771.00000 3177.1 CONNECTION GAS HIGH 0 ETHANE (C-2) 288 @ 14727.00000 36 @ 14504.00000 167.1 AVG 0 PROPANE (C-3) 53 @ 14628.00000 2 @ 14521.00000 25.9 CURRENT 0 BUTANE (C-4) 47 @ 14610.00000 1 @ 14747.00000 23.2 CURRENT BACKGROUND/AVG 21 PENTANE (C-5) 34 @ 14610.00000 2 @ 14774.00000 15.9 HYDROCARBON SHOWS HEMLOCK OIL SHOW INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 14532 MD TO 14698 UPPER HEMLOCK 100% CONGLOMERATE SAND,SAND,SANDSTONE, CONGLOMERATE BEFORE 25 MAX 33 AFTER 28 CLEAN CONGLOMERATE SAND WITH C4 AND C5 NOTED AND THROUGH THE UPPER HEMLOCK SEE HYDROCARBON SHOW REPORT #1 LITHOLOGY SAND, SANDSTONE, CONGLOMERATE SAND, CONGLOMERATE PRESENT LITHOLOGY 14770' = 70% TUFFACEOUS SILTSTONE, 10% CONGLOMERATE SAND, 10% SAND, 10% SANDSTONE DAILY ACTIVITY SUMMARY Drill formation to 14720'. Pump a 40 bbl high viscosity sweep. Pump #1 lost a swab. Circulate with pump #2 at 70 spm. Sweep not seen at the surface. EPOCH PERSONNEL ON BOARD BROWNE, PIKE DAILY COST $2500 REPORT BY LEES F. BROWNE JR. Page 1 of 1Daily Report 5/28/2013 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnerg ... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR MURRAY, JOHNSON DATE May 28, 2013 DEPTH 15077.00000 PRESENT OPERATION DRILLING FORMATION TIME 24 HOURS YESTERDAY 14774.00000 24 HOUR FOOTAGE 303' CASING INFORMATION 9 5/8" @ 8554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 15009.86 34.28 90.93 12178.62 14915.65 34.19 97.25 12100.70 14819.24 34.85 106.27 12021.21 14725.71 35.57 111.34 11944.78 14627.15 36.51 115.17 11865.07 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" HDBS FX84D 120562239 5X12, 3X13 12922 2155 75:38 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 46.0 @ 14874.00000 0.5 @ 15015.00000 17.8 13.55455 FT/HR SURFACE TORQUE 23446 @ 14891.00000 17256 @ 15071.00000 21605.2 20774.00000 AMPS WEIGHT ON BIT 32 @ 14957.00000 6 @ 14881.00000 14.6 17.10000 KLBS ROTARY RPM 110 @ 14876.00000 73 @ 15060.00000 94.2 78.00000 RPM PUMP PRESSURE 3129 @ 14868.00000 2677 @ 15038.00000 2938.2 2834.00000 PSI DRILLING MUD REPORT DEPTH 15077' MW 9.3 VIS 64 PV 24 YP 19 FL - Gels 13/18/22 CL- - FC 0/2 SOL 7.7 SD 0.10 OIL 80.6/19.4 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 35 @ 14935.00000 17 @ 15054.00000 26.2 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 4073 @ 14894.00000 1749 @ 15054.00000 2849.9 CONNECTION GAS HIGH 0 ETHANE (C-2) 431 @ 14920.00000 81 @ 15056.00000 250.5 AVG 0 PROPANE (C-3) 35 @ 14894.00000 10 @ 15053.00000 21.0 CURRENT 0 BUTANE (C-4) 41 @ 14894.00000 1 @ 14774.00000 15.6 CURRENT BACKGROUND/AVG 19 PENTANE (C-5) 27 @ 14839.00000 0 @ 14922.00000 6.9 HYDROCARBON SHOWS MID HEMLOCK OIL SHOW REPORT #2 INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 14810 TO 15000 Conglomerate sand, sand BEFORE 23 MAX 35 AFTER 24 Conglomerate sand and sand angular coarse grain with med matrix sands. Pixler plot shows as high gravity oil. See show report #2 LITHOLOGY SAND, CONGLOMERATE SAND, CONGLOMERATE, CONGLOMERATE SANDSTONE PRESENT LITHOLOGY 15070' = 40% CONGLOMERATE, 10% CONGLOMERATE SANDSTONE, 40% CONGLOMERATE SAND, 10% SAND DAILY ACTIVITY SUMMARY Drill formation to 15075' and pumped a high viscosity sweep. Surface to surface was 12400 strokes with no significant cuttings increased at the shakers. Cuttings are elongating themselves as they transport up the well bore. Sample percentages also reflect this. EPOCH PERSONNEL ON BOARD BROWNE, ADAMS DAILY COST $2550 REPORT BY LEES F. BROWNE JR. Page 1 of 1Daily Report 5/29/2013 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnerg ... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR MURRAY, JOHNSON DATE May 28, 2013 DEPTH 15077.00000 PRESENT OPERATION DRILLING FORMATION TIME 24 HOURS YESTERDAY 14774.00000 24 HOUR FOOTAGE 303' CASING INFORMATION 9 5/8" @ 8554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 15009.86 34.28 90.93 12178.62 14915.65 34.19 97.25 12100.70 14819.24 34.85 106.27 12021.21 14725.71 35.57 111.34 11944.78 14627.15 36.51 115.17 11865.07 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" HDBS FX84D 120562239 5X12, 3X13 12922 2155 75:38 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 46.0 @ 14874.00000 0.5 @ 15015.00000 17.8 13.55455 FT/HR SURFACE TORQUE 23446 @ 14891.00000 17256 @ 15071.00000 21605.2 20774.00000 AMPS WEIGHT ON BIT 32 @ 14957.00000 6 @ 14881.00000 14.6 17.10000 KLBS ROTARY RPM 110 @ 14876.00000 73 @ 15060.00000 94.2 78.00000 RPM PUMP PRESSURE 3129 @ 14868.00000 2677 @ 15038.00000 2938.2 2834.00000 PSI DRILLING MUD REPORT DEPTH 15077' MW 9.3 VIS 64 PV 24 YP 19 FL - Gels 13/18/22 CL- - FC 0/2 SOL 7.7 SD 0.10 OIL 80.6/19.4 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 35 @ 14935.00000 17 @ 15054.00000 26.2 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 4073 @ 14894.00000 1749 @ 15054.00000 2849.9 CONNECTION GAS HIGH 0 ETHANE (C-2) 431 @ 14920.00000 81 @ 15056.00000 250.5 AVG 0 PROPANE (C-3) 35 @ 14894.00000 10 @ 15053.00000 21.0 CURRENT 0 BUTANE (C-4) 41 @ 14894.00000 1 @ 14774.00000 15.6 CURRENT BACKGROUND/AVG 19 PENTANE (C-5) 27 @ 14839.00000 0 @ 14922.00000 6.9 HYDROCARBON SHOWS MID HEMLOCK OIL SHOW REPORT #2 INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 14810 TO 15000 Conglomerate sand, sand BEFORE 23 MAX 35 AFTER 24 Conglomerate sand and sand angular coarse grain with med matrix sands. Pixler plot shows as high gravity oil. See show report #2 LITHOLOGY SAND, CONGLOMERATE SAND, CONGLOMERATE, CONGLOMERATE SANDSTONE PRESENT LITHOLOGY 15070' = 40% CONGLOMERATE, 10% CONGLOMERATE SANDSTONE, 40% CONGLOMERATE SAND, 10% SAND DAILY ACTIVITY SUMMARY Drill formation to 15075' and pumped a high viscosity sweep. Surface to surface was 12400 strokes with no significant cuttings increased at the shakers. Cuttings are elongating themselves as they transport up the well bore. Sample percentages also reflect this. EPOCH PERSONNEL ON BOARD BROWNE, ADAMS DAILY COST $2550 REPORT BY LEES F. BROWNE JR. Page 1 of 1Daily Report 5/31/2013 file://C:\Documents and Settings\EpochAdmin\Desktop\Cook Inlet RU2A\Morning Report... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR DATE May 30, 2013 DEPTH 15360.00000 PRESENT OPERATION PREPARE TO TEST BOPE TIME 01:22:10 YESTERDAY 15360.00000 24 HOUR FOOTAGE 0' CASING INFORMATION 9 5/8" @ 8554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 15360 37.43 73.84 12460.70 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" HDBS FX84D 120562239 5X12, 3X13 12922 15360 2438 90:27 2-1-WT-A-X-I-BT TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 15360' MW 9.2+ VIS 65 PV 27 YP 16 FL - Gels 13/19/22 CL- - FC 0/2 SOL 7.3 SD 0.10 OIL 81.8/18.2 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 16 @ 15360 0 @ TOOH 13 CIRC TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) @ @ CONNECTION GAS HIGH - ETHANE (C-2) @ @ AVG - PROPANE (C-3) @ @ CURRENT - BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG - PENTANE (C-5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 15360' = 70% TUFFACEOUS SILTSTONE, 30% SAND DAILY ACTIVITY SUMMARY Total depth of 15360' reached at midnight. Circulated bottoms up and pumped a 50 bbl high viscosity sweep. 3% wash out calculated. Circulated bottoms up three times while rotating and reciprocating the drill string. Ttip out of the hole on elevators to surface and lay down the BHA. Rig up to test BOPE. EPOCH PERSONNEL ON BOARD BROWNE, ADAMS DAILY COST $2500 REPORT BY LEES F. BROWNE JR. Page 1 of 1Daily Report 5/31/2013 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnerg ... COOK INLET ENERGY DAILY WELLSITE REPORT RU-2A REPORT FOR JONES, JOHNSON DATE May 16, 2013 DEPTH 12831.00000 PRESENT OPERATION DRILLING FORMATION TIME 24 HOURS YESTERDAY 12655.00000 24 HOUR FOOTAGE 176' CASING INFORMATION 9 5/8" @ 8554' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12693.04 38.88 118.19 10366.19 12598.05 38.77 118.16 10292.18 12502.72 38.62 117.46 10217.78 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2RR 8.5" HDBS FX4D 11745826 3X12, 3X16 10099 2732 114:54 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 112.9 @ 12683.00000 0.7 @ 12804.00000 21.9 2.74970 FT/HR SURFACE TORQUE 14485 @ 12714.00000 9927 @ 12668.00000 8640.8 10382.00000 AMPS WEIGHT ON BIT 49 @ 12766.00000 3 @ 12814.00000 16.4 39.50000 KLBS ROTARY RPM 118 @ 12733.00000 1 @ 12817.00000 76.3 93.00000 RPM PUMP PRESSURE 4044 @ 12794.00000 3519 @ 12771.00000 3840.9 3602.00000 PSI DRILLING MUD REPORT DEPTH 12840' MW 9.2 VIS 68 PV 24 YP 18 FL - Gels 12/16/19 CL- - FC - SOL 6.2 SD 0.10 OIL 73.8/26.2 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL - TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 65 @ 12663.00000 5 @ 12820.00000 12.4 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 11249 @ 12663.00000 1086 @ 12771.00000 2195.9 CONNECTION GAS HIGH 0 ETHANE (C-2) 61 @ 12664.00000 0 @ 12697.00000 4.8 AVG 0 PROPANE (C-3) 10 @ 12663.00000 0 @ 12661.00000 0.1 CURRENT 0 BUTANE (C-4) 0 @ 12831.00000 0 @ 12831.00000 0.0 CURRENT BACKGROUND/AVG 10 PENTANE (C-5) 0 @ 12831.00000 0 @ 12831.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILTSTONE, TUFFACEOUS CLAYSTONE, CARBON CLAY, COAL, SAND, TUFFACEOUS SANDSTONE PRESENT LITHOLOGY 12831' = CARBON CLAY 40%, TUFFACEOUS CLAYSTONE 30%, TUFFACEOUS SILTSTONE 20%, COAL 10% DAILY ACTIVITY SUMMARY Drill and slide formation to 12831'. EPOCH PERSONNEL ON BOARD BROWNE, PIKE + 2 SC DAILY COST $3340 REPORT BY LEES F. BROWNE JR. Page 1 of 1Daily Report 5/17/2013 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\CookInletEnerg ...