Inflatable DST Equipment An Overview Presentation

Inflatable Drillstem Testing Highlights Confirms the presence of commercial volumes of hydrocarbons Provides accurate readings of pressure and temperature values in well bore Manufactured to meet the requirements of sour service Designed to run in vertical, deviated and horizontal well bores 1 of 2

Inflatable Drillstem Testing Highlights Inflatable Straddle Packers function to achieve selective zonal isolation Capable of testing multiple zones in one downhole trip Saves costs of casings, perforating and setting bridge plugs if the well is water bearing or unproductive 2 of 2

Sample Drillstem Testing String 1. Bar Drop Reverse Circulating Sub 2. Over Pressure Kill Reverse Valve 3. Hydraulic Downhole Shut-in Tool 4. Bottom Hole Sampler 5. Recorder Carrier 6. Squeeze Relief 7. TD Hydraulic Jars 8. Safety Joint 9. Downhole Inflate Pump 10. Screen 11. Inflatable Upper Packer 12. Recorder Carrier 13. Interval Spacing with Bypass Pipe 14. Inflatable Bottom Packer 15. Drag Spring

Component Overview The Bar Drop Sub is designed as a back-up circulating device to reverse out the string. To function, a bar is dropped from surface through the test string. It shears a knock-off rod inside the tool. Once sheared it is then possible to reverse or forward circulate. Bar Drop Reverse Circulating Sub 1 of 3

Component Overview Bar Drop Sub only functions in a vertical position. If not possible to run the Bar Drop Sub in vertical position, a rupture disc must be run in place of the knock-off rod. The rupture disc is a shear style disc that bursts at a predetermined value. Bar Drop Reverse Circulating Sub 2 of 3

Component Overview To rupture the disc, pressure the test string up to and beyond the predetermined shear value. Once ruptured the string will allow you to reverse or forward circulate. Bar Drop Reverse Circulating Sub 3 of 3

Component Overview A downhole valve that allows for multiple openings and closings. The Shut-in Tool allows running into the hole with an empty test string. This eliminates the hydrostatic pressure on the formation at setting depth. Hydraulic Downhole Shut-in Tool CLOSED OPEN 1 of 3

Component Overview Functioned by slacking weight on the multiple shut- in tool. When weight is slacked off ( E.G. 10,000 lbs for five minutes) the valve will open. To close, pick the string back up to the neutral weight and the valve will close immediately. Hydraulic Downhole Shut-in Tool CLOSED OPEN 2 of 3

Component Overview The tool is also used to achieve periods of flow and downhole shut-in during testing, eliminating false data from the test string wellbore storage. The designed delayed tool opening avoids accidental activation while running in the hole. Hydraulic Downhole Shut-in Tool CLOSED OPEN 3 of 3

Component Overview The primary circulating device that allows the reversing out of hydrocarbons from the DST string following a successful test. Functioned by a pressure activated internal sleeve that shifts to open six circulating ports. Over Pressure Kill Reverse Valve 1 of 2

Component Overview After you apply the predetermined amount of pressure to open the valve, the DST string can be either forward or reverse circulated. Over Pressure Kill Reverse Valve 2 of 2

Component Overview Designed to capture a downhole fluid sample. Works in conjunction with the Hydraulic Multiple Shut-in Tool. Captures a sample of the last formation tested prior to tripping out of the well. Bottom Hole Sampler 1 of 2

Component Overview This is an optional tool to be run during testing at the client’s request. Bottom Hole Sampler 2 of 2

Component Overview Carries and protects the downhole memory guages. Each Recorder Carrier can house three guages. Can be placed at any location in the test string. Carriers can be run at multiple locations on the DST string. Locations based on clients’ data collection requirements. Recorder Carrier INTERNAL EXTERNAL

Component Overview The Squeeze Relief Sub is run in the DST string to effectively allow the upper and lower packers to equalize while running in and out of the well. Squeeze Relief Sub

Component Overview Run in the DST string to provide a means of jarring and freeing of stuck tools in the event of downhole issues. Functions by applying an over-pull to the string. When the tool is pulled into tension, a metering system inside the Jars slowly extends until a free point is reached. TD Hydraulic Jars 1 of 2

Component Overview Once the free point is reached, the tools provide the effect of a hammer striking an anvil. This gives a downhole “jar” to the tools. The Jars can be functioned several times if required. TD Hydraulic Jars 2 of 2

Component Overview Designed for use in extremely rare emergency systems where the DST DHA is stuck and unable to be freed using conventional methods. This tool allows you to back- off the stuck BHA with several hand rotations and pull out of the hole allowing recovery of all tools located above the Safety Joint. Safety Joint 1 of 2

Component Overview The lower portion of the DST string can be recovered with larger Jars or fishing tools once the BHA is recovered. Safety Joint 2 of 2

Component Overview Designed to inflate the upper and lower packers. Capable of multiple inflation and deflations in one trip. Functions through the rotation of the DST string aided by the drag string. Dual action piston provides superior pumping capabilities for faster inflation times. Downhole Inflate Pump UP DOWN

Component Overview To be run directly below the Downhole Inflate Pump. Used to filter out debris, and allow only clean drilling fluid to enter the pump and inflate the packers. Screen

Component Overview This assembly provides the upper seal for selective zonal isolation. Inflated by pressure supplied from the Downhole Inflate Pump. The bottom Sub on the packer also provides communication point from the string to the formation of interest. Upper Inflatable Packer

Component Overview Used to space out the packers in order to achieve the appropriate testing interval in the formation of interest. In addition, the Interval Spacing conveys pressure from the upper packer to the lower packer. Interval Spacing with Bypass Pipe 1 of 2

Component Overview Housed in the Interval Spacing is the Bypass Pipe, which allows communication from the upper packer to the lower packer. This prevents the string from getting differentially stuck. Interval Spacing with Bypass Pipe 2 of 2

Component Overview The Bottom Packer assembly provides the bottom seal for selective zonal isolation. The packer is inflated by pressure supplied from the Downhole Inflate Pump. Bottom Inflate Packer

Component Overview Placed at the bottom of the DST string to provide an anchor for the Downhole Inflate Pump. The Drag String stops the bottom of the BHA from rotating. This allows the remainder of test string to be rotated which functions the pump and inflates the packers. Drag Spring 1 of 2

Component Overview The Drag String aids in communication between the upper and lower packer to prevent the BHA from getting differentially stuck. Drag Spring 2 of 2

Contact Information Dylan Winkler – International Sales Manager T C Curtis Makar – Operations Manager T ext 2259 C