Transcript file

An Overview Presentation
Inflatable DST Equipment
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
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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
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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
Bar Drop Reverse Circulating Sub
• 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.
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Component Overview
Bar Drop Reverse Circulating Sub
• 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.
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Component Overview
Bar Drop Reverse Circulating Sub
• 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.
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Component Overview
Hydraulic Downhole Shut-in Tool
• 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.
CLOSED
OPEN
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Component Overview
Hydraulic Downhole Shut-in Tool
• Functioned by slacking
weight on the multiple shutin 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.
CLOSED
OPEN
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Component Overview
Hydraulic Downhole Shut-in Tool
• 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.
CLOSED
OPEN
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Component Overview
Over Pressure Kill Reverse Valve
• 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.
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Component Overview
Over Pressure Kill Reverse Valve
• After you apply the
predetermined amount of
pressure to open the valve,
the DST string can be either
forward or reverse circulated.
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Component Overview
Bottom Hole Sampler
• 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.
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Component Overview
Bottom Hole Sampler
• This is an optional tool to be
run during testing at the
client’s request.
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Component Overview
Recorder Carrier
• 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.
INTERNAL
EXTERNAL
Component Overview
Squeeze Relief Sub
• 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.
Component Overview
TD Hydraulic Jars
• 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.
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Component Overview
TD Hydraulic Jars
• 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.
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Component Overview
Safety Joint
• 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 backoff the stuck BHA with several
hand rotations and pull out of
the hole allowing recovery of
all tools located above the
Safety Joint.
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Component Overview
Safety Joint
• The lower portion of the DST
string can be recovered with
larger Jars or fishing tools
once the BHA is recovered.
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Component Overview
Downhole Inflate Pump
• 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.
DOWN
UP
Component Overview
Screen
• 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.
Component Overview
Upper Inflatable Packer
• 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.
Component Overview
Interval Spacing with Bypass Pipe
• 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.
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Component Overview
Interval Spacing with Bypass Pipe
• 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.
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Component Overview
Bottom Inflate Packer
• The Bottom Packer assembly
provides the bottom seal for
selective zonal isolation.
• The packer is inflated by
pressure supplied from the
Downhole Inflate Pump.
Component Overview
Drag Spring
• 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.
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Component Overview
Drag Spring
• The Drag String aids in
communication between the
upper and lower packer to
prevent the BHA from getting
differentially stuck.
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Contact Information
Dylan Winkler – International Sales Manager
[email protected]
T 403 570 2208
C 403 861-7122
Curtis Makar – Operations Manager
[email protected]
T 403 720 5155 ext 2259
C 403 807 3999