Note: Descriptions are shown in the official language in which they were submitted.
A8146180CA
APPARATUS, SYSTEM, AND METHOD FOR INDICATING A POSITION OF
VALVE OF WELLSITE EQUIPMENT
TECHNICAL FIELD
[00011 This disclosure generally relates to wellsite equipment.
In particular, the
disclosure relates to an apparatus, system, and method for detecting and
indicating a
position of a valve of wellsite equipment.
BACKGROUND
[00021 The oil and gas industry is increasingly incorporating
digitalization to
assist in production monitoring and decision making at a wellsite and on a
well pad.
= When hydrocarbon recovery includes hydraulic fracturing, or otherwise, one
of the key
pieces of information at the wellsite is to know the operational position of
the valves on
the frac free and/or zipper manifold and/or other wellsite equipment. It is
critical to
know whether a valve is open, closed, or in a position in between. Currently,
service
operators send an individual to visually check the position of a valve
actuator. This
may require the individual to enter or pass through one or more hazardous
areas of the
well pad. In other instances, service operators may use some form of reporting
technology for obtaining valve position information that is typically either
mounted to
the free-head valve itself or permanently installed on a specialized
accumulator.
[0003] One drawback of mounting equipment on the frac tree is
that the
differences in valves, including from different vendors or suppliers,
necessitates
different mounting hardware for different valves, which can be inefficient, of
large
physical dimensions and costly for installation. For example, this can be
accomplished
by machining and modifying each valve for a position detection assembly to be
mounted on, which is costly and inefficient as many valves need to be modified
in
order to have enough in circulation to supply for jobs Another example is
installing a
temporary solution, however the types that have been developed are exceedingly
long
due to their shaft contact design for providing contact-based positon
detection.
f0004] A drawback of permanently installed valve-position
equipment, as an
integral part of a specialized accumulator or otherwise, is that the
information acquired
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2
from this equipment may not be readily shared by vendors or suppliers with
other
services requiring it. Not having or sharing all of the data negates, to a
certain degree,
the usefulness of the valve position information because different service
operators on a
wellsite may require the valve position information at a given time, but only
some may
be able to access it. Furthermore, such specialized equipment is costly;
particularly,
when one considers that the specialized unit would likely replace an existing,
non-
specialized unit that performs the same functions properly.
[00051 Therefore, a need exists for an improved way to obtain
valve position
information at the wellsite or well pad.
SUMMARY
[00061 The embodiments of the present disclosure relate to an
apparatus,
system, and method for indicating a position of a valve of wellsite equipment
[0007] Some embodiments of the present disclosure provide an
apparatus for
detecting and indicating a position of a valve of wellsite equipment. The
apparatus
comprising a sensor that is configured to detect the position of a moving part
of a valve
and to provide an output signal indicative of the position of the moving part.
[0008] A system for detecting and indicating an operational
position of a valve,
the system comprising; an apparatus and a processor. The apparatus comprising
a first
end that configured to operably couple to a valve or associated equipment and
a second
end and a sensor. The sensor housed between the first end and the second end,
the
sensor configured to be in communication with a target surface for contactless
detecting
of the operational position of the valve based upon the detected distance
between the
sensor and the target surface and the sensor further configured to indicate
the
operational position by communicating an output signal. The processor is
configured
to receive the output signal and to generate a display signal that indicates
the
operational position of the valve.
[0009] An apparatus for detecting and indicating an operational
position of a
valve. The apparatus comprises: a first end that configured to operably couple
to a
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3
valve or associated equipment and a second end. The apparatus also comprises a
sensor housed between the first end and the second end, the sensor configured
to be in
communication with a target surface for contactless detecting of the
operational
position of the valve based upon the detected distance between the sensor and
the target
surface.
[0010] Some embodiments of the present disclosure relate to a
method A
method for detecting and indicating an operational position of a valve, the
method
comprising: securing an apparatus to a valve or associated equipment, the
apparatus
comprising a sensor, detecting the distance between the sensor and a target
surface of
the valve or associated equipment; and indicating the operational position of
the valve
actuator based on the detected distance
[0011]
[0012] Without being bound by any particular theory, the
embodiments of the
present disclosure provide an apparatus, system, and method that generate
information
about the position of a valve. Knowing the position of the valve provides
information
about flow of fluids towards, through or away from an accumulator of a
wellsite Or well
pad hydraulic system, a frac flow control unit, a frac zipper-manifold, a frac
tree, a well
Christmas tree, a blowout preventer, or therebetween. Such information about
fluid
flow may help avoid accidents at the welisite and/or well pad. Examples of
such
accidents can include when a wellhead valve is opened or closed at the
incorrect time
during a well operation, such as a hydraulic fracking operation or a wireline
operation.
Furthermore, some embodiments of the present disclosure permit aggregating,
displaying and sharing of valve position information between different
individuals
working on the same wellsite and multiple washes of a given well pad and
individuals
who are overseeing operations of multiple wellsites from a remote location.
Furthermore, the embodiments of the present disclosure can be added on to
existing
wellsite equipment without great effort, which facilitates the sharing of
valve position
information across individuals with access to different computer systems and
different
information technology infrastructures. In effect, the embodiments of the
present
disclosure are agnostic to the types, sizes, dimensions and configuration of
valves
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present at the wellsite and to the specific computer and data systems that
individuals
may already be using in relation to wellsite operations.
BRIEF DESCRIPTION OF THE DRAWINGS
[0013] These and other features of the present disclosure will
become more
apparent in the following detailed description in which reference is made to
the
appended drawings.
[0014] FIG. 1 shows an apparatus, according to embodiments of
the present
disclosure, for use with a wellhead valve, wherein FIG. lA is a top-plan view;
FIG. 1B
is a cross-sectional view taken through line AA in FIG. 1A; FIG. IC is a cross-
sectional view taken through line A-A in FIG. LA; and, FIG. 1D is a cross-
sectional
view taken through line A-A in FIG. 1A.
[0015] FIG. 2 shows further embodiments of the apparatus,
wherein PIG. 2A
shows a mid-line cross-sectional view of the apparatus in use with a wellhead
valve;
and, FIG. 2B shows a top-plan view of the apparatus in use with a rotationally
actuated
wellhead valve.
[00161 FIG. 3 shows an apparatus, according to embodiments of the present
disclosure, wherein FIG. 3A is an isometric view of the apparatus; FIG. 3B is
an
isometric view of a mount portion of the apparatus; and, FIG. 3C is an
isometric view
of a housing portion of the apparatus.
[0017] FIG. 4 shows further views of the apparatus of FIG. 3,
wherein FIG. 4A
is a top-plan view of the apparatus; and FIG. 4B is a cross-sectional view
taken through
the line A-A in FIG. 4A.
[0018] FIG. 5 shows another embodiment of an apparatus,
according to the
= present disclosure, wherein FIG. SA is a top-plan view of the apparatus;
and, FIG. 5B is
a cross-sectional view taken through the line A-A in FIG. 5A.
[0019] FIG. 6 shows schematic of a system, according to embodiments of the
present disclosure.
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[0020] FIG. 7 shows schematic of another system, according to
embodiments
of the present disclosure.
[0021] FIG. 8 shows a logic flow diagram of a method, according
to
embodiments of the present disclosure, wherein FIG. 7A show the logic of a
method
5 based on the operational position of a valve being in a desired position;
FIG. 7B shows
the logic of a method based on the operational position of a valve being in an
undesirable position; and FIG. 7C shows the logic of a method to remotely
actuate a
valve to an intermediate position.
[0022] FIG. 9 shows a logic flow diagram of a method, according
to
embodiments of the present disclosure.
[0023] FIG. 10 shows steps of a
100241 method for detecting and indicating the operational
position of a valve.
[0025] DETAIXID DESCRIPTION
[0026] The embodiments of the present disclosure relate to an
apparatus,
system, and method for detecting and indicating an operational position of a
valve of
that controls the flow of fluids to, through or away from wellsite equipment.
As used
herein, the expression "wellsite equipment" refers to a component of or a
piece of
equipment that can be used or is used at a wellsite. The valve can occupy
various
operational positions that regulate the flow of fluids through the valve so as
to
influence the operation of the wellsite equipment or so as to control the flow
of fluids
upstream or downstream of the wellsite equipment. For example, the valve can
be, but
is not limited to: a swab valve, a pump-down valve, a crown valve, an
isolation valve, a
hydraulic master-valve, one or more side port valves, one or more zipper
manifold
valves, a flow-back valve, a pump-down valve and any other valve that
contributes to
the functionality of wellsite equipment. Regardless of its position and
function on the
weLlsite, the valve may be a butterfly valve, a plug valve, a ball valve, a
low-torque
valve, a low-torque plug valve, a gate valve, a wedge gate valve, a disc and
stem valve
or any other type of valve that can be actuated by an actuator.
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100271 A number of different control mechanisms regulate the
flow of fluids to,
through and from the welt For example, moving parts of valves within wellsite
equipment can change operational position, by opening and closing, to control
the flow
of fluids to and from the welt For example, a number of valves may be
positioned
through different sections of a surface-borne, hydraulic fracturing systern or
other
systems relate to services being performed on the well. The operational
position of
each valve is controlled by a valve actuator. Valve actuators can control the
operational position of a valve through one or more of manual, hydraulic,
pneumatic or
electronically actuated control mechanisms. Some valve actuators may provide
direct
control of a valve and some valve actuators may be positioned remotely from
the valve
for indirect control of the operational position of a valve.
100281 Some embodiments of the present disclosure relate to an
apparatus,
system and method for detecting and indicating the position of a valve of
weIlsite
equipment. For the purposes of this disclosure, the term "detecting" and
similar terms,
refer to capturing positional information of a movable part of the valve,
relative to a
fixed point. The embodiments of the present disclosure relate to detecting the
distance
between a non-moving sensor and a target surface of a moving part of the valve
without
directly contacting the moving part of the valve (i.e. non-contact detection).
As will be
appreciated by those skilled in the art, the sensor may also be operatively
coupled to the
moving part of the valve and the target surface may be a surface of a non-
moving part
of the valve, a surface of the wellsite equipment, a surface of the apparatus
described
herein or combinations thereof. Furthermore, the embodiments of the present
disclosure allow for detecting the position of a moving part of a valve
throughout the
entire range of intended motion and beyond. This allows a user to know the
location of
the moving part of the valve within its intended range of movement (e.g. 25%
towards
a closed position, 25% towards an open position, 50% from closed and open
positions).
If the moving part of the valve is detected to be outside of its intended
range of
movement, that may indicated maintenance or repair of the valve is required
and/or that
the apparatus may require an adjustment, recoupling or replacement. Detecting
the
position of a moving part of the valve can be a direct or indirect measure of
the
operational position of the valve. For the purposes of this disclosure, the
term
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"indicating" and similar terms, refer to conveying the detected position of
the moveable
valve part.
[0029] Some embodiments of the present disclosure relate to an
apparatus that
is operatively coupleable to a non-moveable part of a valve or associate
wellsite
equipment The apparatus includes a sensor for detecting the position of a
moving part
of the valve wherein the moving part of the valve operates to, directly or
indirectly,
change the operational position of the valve. The sensor is also configured
for
generating an output signal that indicates the position of the moving part of
the valve
and, therefore, the operational position of the valve. When the apparatus is
operatively
coupled to the non-moving part of the valve, the apparatus may detect and
indicate
whether the valve is in a first position, a second position, or an
intermediate position
therebetween. The apparatus may also detect and indicate whether the valve has
moved
to a position beyond its intended range of movement, which may indicated
maintenance, repair or replacement of the valve is required anchor that the
apparatus
requires an adjustment, recoupling or replacement. Moving the valve between
these
operational positions will permit, restrict, or stop at least a portion of
fluids from
flowing to, through or from the valve.
[0030] Some embodiments of the present disclosure relate to a
system for
detecting and indicating the position of a valve that forms part of welisite
equipment.
The system comprises an apparatus with a sensor and a processor. The apparatus
is
operatively coupleable to a non-moving part of the valve end the sensor is
configured to
receive to detect and indicate the position of a moving part of the valve. The
sensor is
also configured to generate and communicate an output signal indicative of the
operational position of the valve.. The processor is operatively coupled to
the at least
one sensor and the processor is configured to receive and process an output
signal from
the sensor. The processor is further configured to generate the processed
output signal
as a display signal. In some embodiments of the present disclosure, the system
further
comprises a remote display unit for receiving the display signal and for
generating a
display that is indicative of the position of the valve. In some embodiments
of the
present disclosure, the remote display unit may form part of a Human-Machine-
Interface (HMI) and/or the remote display unit may be part of an individual
computer
Date Recue/Date Received 2021-06-25
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8
display. In some embodiments of the present disclosure, the system includes
multiple
apparatus that each provide their respective output signals to a single
processor (or to
multiple processors in communication with each other) so that the remote
display unit
can receive display signals that indicate the operational position of multiple
valves at a
wellsite or a well pad at a given time.
(0031] Some embodiments of the present disclosure relate to a
method of
detecting and indicating a position of a valve that forms part of wellsite
equipment
The method comprises the steps of coupling an apparatus to a non-moving part
of a
valve, detecting the operational position of the valve by detecting the
position of a
moving part of the valve and observing an output signal generated by the
sensor.
[00321 As discussed elsewhere herein, several issues and/or
inefficiencies exist
with conventional technologies for indicating the position of a valve at a
wellsite. For
example, knowing the operational position of a valve that controls the flow of
fluids
towards, through or from a piece of welIsite equipment may be beneficial to
the safe
and efficient wellsite operations by letting one or more operators know the
operational
position of the valve, so as to know the operational state of the wellsite
equipment.
[0033] The technology of the present disclosure is suitable for
several
applications and use with different types of wellsite equipment. With
reference below
to the drawings herein, the present disclosure discusses the technology in the
context of
indicating the operational position of a valve and the skilled person will
appreciate that
various applications and wellsite equipment uses are applicable. For example,
the
embodiments of the present disclosure can be used for detecting and indicating
the
operational position of a valve of at least the following wellsite equipment;
a frac flow
conirol unit, a frac zipper-manifold, a frac tree, a wellhead Christmas tree,
a blowout
preventer, or any valve therebetween.
[0034] Unless defined otherwise, all technical and scientific
terms used herein
have the same meaning as commonly understood by one of ordinary skill in the
art to
which this disclosure belongs. Exemplary terms are defined below for ease in
understanding the subject matter of the present disclosure.
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[00351 As used herein, the term "about", when referring to a
measurable value,
refers to an approximately +/-10% variation from a given value. It is
understood that
such a variation is always included in any given value provided herein,
whether or not
it is specifically referred to.
[00361 As used herein, the term "and/or refers to and encompasses any and
all
possible combinations of one or more of the associated listed items (e.g. one
or the
other, or both), as well as the lack of combinations when interrupted in the
alternative
(or).
[0037J As used herein, the term "accumulator" refers to
equipment that forms
part of a wellsite hydraulic system that is used for opening and closing
valves and
blowout preventers of wellsite equipment. Accumulators typically have four
components: a hydraulic pump, a hydraulic tank, accumulator bottles for
storing
hydraulic energy and valves for regulating the hydraulic equipment. An
accumulator
may also be referred to as a closing station or a closing unit. An accumulator
may also
control the position of a valve actuator of each of the frac tree valves
and/or the zipper
manifold valves.
10038] As used herein, the term "consultant" refers to a
representative of an
exploration-and-producing oil company who may be present at the well pad or
remote
from the well pad and duly authorized to make procedural decisions about
operations at
the well pad or multiple well pads.
100391 As used herein, the term "frac tree" refers to an
assembly of valves,
gauges and chokes that are part of a wellhead and used for the fracturing
process. The
frac tree can include multiple valves that control the flow of fluids through,
to or from
the well, to control pressure between different sections of the wellhead.
[00401 As used herein, the term "wellhead" refers to the equipment and
components present at the surface end of a well that may include a frac tree,
a
Christmas tree, a blowout preventer assembly, and that at least partially
provides
physical support to the well below the surface end.
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[0041] As used herein, the term "wellhead technician" refers to
an individual
person who actuates the valves on a wellsite, whether the valves are
hydraulically,
electronically, pneumatically or manually actuated, directly or indirectly.
[00421 As used herein, the term "well pad" refers to a physical
location that
5 comprises two or more wellsites and such wellsites are in proximity to
each other to
facilitate the sharing of wellsite equipment, personnel and/or other
operational
infrastructure for operations to be performed on such wensites.
[0043] As used herein, the term "wellsite" refers to a physical
location in
proximity to one or more geological formations and where well operations are
10 occurring on an oil and/or gas well.
100441 As used here, the term "zipper manifold" also referred
to as a "frac
zipper manifold" refers to a manifold that is used for conducting and
directing high-
pressure, hydraulic fracturing fluid from a source into one or more wells on a
well pad.
Zipper manifolds can include hydraulically actuated or manually actuated
valves that
regulate the fluid flow within the manifold. Zipper manifold may also be used
interchangeably with the terms "frac line" or "trunk line".
[00451 The etabodiments of the present disclosure will now be
described and in
reference to FIG. 1 through to FIG. 10.
[0046] FIG. 1 shows a non-limiting example of an apparatus 10
that is
configured to detect and indicate the operational position of a wellhead valve
2000
The wellhead valve defines a central bore 2001 which the valve body 2012 can
move
between a closed position (FIG. 1B) and an open position (FIG. 1C). The valve
body
2012 can move linearly between the closed and open position under the
influence of an
actuator 2002, which in FIG. 1 is a hydraulic actuator. When the valve body
2012
23 moves, a valve stem 2010 moves in the same fashion and direction so that
a target
surface 2011 of the valve stem 2010 will move towards and away from the
apparatus.
The valve stem is protected within a valve guard 2014, which may also be
referred to as
a valve shroud.
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A81461SOCA
11
[0047] The apparatus 10 can be operatively coupled to a non-
moving portion of
a valve, a surface of wellsite equipment so that a sensor 50 of the apparatus
10 is in
fluid communication and, therefore, acoustic communication and/or visual
communication and/or electromagnetic communication with the target surface
2011 of
the valve. As shown in the comparison of FIG. 1B the apparatus 10 can be
operatively
coupled at one end to the valve guard 2014. As shown in FIG. 1B, IC and 1D,
the
apparatus 10 is configured to operatively couple to valve guards 2014, 2014C
and
20I4D (as but one example of a non-moving part of the valve) of various
shapes,
dimensions and configurations without requiring effort to pre-measure the
valve guard
and then to manufacture a specific apparatus that meets the specific valve
guard to
which the apparatus 10 is intended to be operatively coupled. Without being
bound by
any particular theory, the apparatus 10 is configured to be operatively
coupled to a non-
moving part of the valve (which also refers to other non-moving surfaces of
the wellsite
equipment) to accommodate outer diameter (or similar external diameters for
non-
circular components) between 0.25-25 inches, 0.5-20 inches,
0.75-15 inches, 1-10 inches, 1.5-73 inches, 2-5 inches and all ranges of sizes
therebetween.
[0048] FIG. 2A shows another embodiment of the apparatus,
referred to as
apparatus 10B, which has all of the same components, features and
functionality of
apparatus 10 (described further below) with the exception that the apparatus
10B
includes a fitted valve guard 12A as part of the apparatus 10B. This fitted
valve guard
12A can be operatively coupled with and sealed against the other components of
the
valve and/or wells ite equipment so as to prevent fluid and debris intrusion
that may
interfere with the valve's movement
[0049] FIG. 2B shows another embodiment of the apparatus, referred to as
apparatus IOC, which has all of the same components, features and
functionality of
apparatus 10 (described further below) with the exception that the apparatus
10C is
configured to be used with a rotationally actuated (rather than linearly
actuated) valve.
The apparatus 10C further comprises a housing 11 that can be positioned
adjacent the
rotary actuator 2006 (in this case a wheel handle). The apparatus 10C also
includes a
target surface 2011 that can be operatively coupled to the rotational actuator
shaft 2016
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12
(in this case the threaded member upon which the rotatory actuator 2006
rotates). In
this embodiment, as the rotatory actuator 2006 moves towards or away from the
apparatus IOC the target surface 2011 will move linearly towards and away from
the
apparatus 10C but with minimal or no rotation, which allows the apparatus 10C
to
detect the position of a moving part of the Valve in a contactless fashion.
[00501 Without being bound by any particular theory, the
embodiments of the
present disclosure allow for contactless (i.e. non-contact) detection of the
position of a
moving part of a valve. The benefits of contactless detection is that the
apparatus 10
can be more compact (i.e. occupy a smaller physical space) and, therefore,
more stable
than currently available contact-based position sensors. This is an important
feature
when the embodiments of the present disclosure are deployed on a wellsite
because the
compact physical footprint will mitigate inadvertent accidents caused by
contacting
other equipment that is being moved around the wellsite. Furthermore, the
apparatus 1-
can be positioned in such a manner as to he closer to the valve, which may
provide the
benefit of a reduced cantilever as the apparatus extends outwardly from the
valve.
Furthermore, the contactless detection of the position of the moving part of
the valve
provided by the embodiments of the present disclosure may also reduce the wear
and
tear of the components of the present disclosure.
[0051] FIG. 3 shows the apparatus 10 as comprising 10 has a
first end 12A and
an opposite second end 14B. The first end 12A is configured to be operatively
coupled
to a non-moving part of a valve (as shown in FIG. 1 and FIG. 2). Some non-
limiting
examples of such non-moving parts of the valve include a valve bonnet, a stem
shroud,
a valve body, a flange, a yoke and the like. Furthermore, for the purpose of
this
disclosure, the term "non-moving part(s) of the valve" is also understood to
include
other surfaces of the wellsite equipment of which the valve is a functional
component.
Because the non-moving part of the valve can vary based on the type of well
site
equipment, type of valve, equipment/valve manufacturer, equipment/valve model
and
the like, the first end 13A can be of various dimensions to operatively couple
the first
end 12A of the apparatus 10 to the non-moving part of the valve. The
adaptability of
the first end 12A of the apparatus 10 to take various configurations and
dimensions
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13
allows the apparatus 10 to be used on valves of different shapes, dimensions
and
configurations.
[0052] In some embodiments of the present disclosure, the
apparatus 10
includes a mount portion 12, which may also be referred to as a mount and
mounting
portion, and a housing portion 14. The mount 12 may define the first end 12A
of the
apparatus 10 and the housing portion 14 may define the second end 14B of the
apparatus 10.
[00531 In some embodiments of the present disclosure, the mount
12 may
comprise a ring plate 13A that defines an inner aperture. The diameter of the
inner
aperture can be of such a dimension that it is able to be positioned about a
portion of
the non-moving part of the valve. The first end 12A may also include a
coupling
mechanism that removably couples the first end 12A about the non-moving part.
FIG-
3 shows the non-limiting example of brace members 15 that are connected at one
end to
the ring plate 13A, extending away therefrom. The brace members 15 each define
one
or more apertures for receiving a coupling member 16 therethrough. FIG. 3A and
FIG.
3B each show the non-limiting examples of coupling members 16 as being
threaded
members with a first end 16A that can be positioned to abut against a surface
of the
non-moving part and tightened thereagainst in order to removably couple the
first end
12A to the non-moving part of the valve. As will be appreciated by those
skilled in the
art, the dimensions and mamier by which the mount 12 is operatively coupled to
the
non-moving part can be varied and is not limited by the examples provided in
this
disclosure. For example, the mount 12 may completely encircle about a portion
of the
non-moving part of the valve or not. The removable coupling performed by the
mount
12 need only be strong enough so as to maintain the position of the apparatus
10
relative to the moving part of the valve for the time frame during which it is
desirable
to !mow the operational position of the valve while the apparatus 10 is
exposed to the
environment of the wellsite.
[0054] The housing portion 14 refers to a part of the apparatus
10 that encloses
and/or protects and/or couples to and/or otherwise retains a sensor 50 in a
given, fixed
position relative to the non-moving part of the valve. The housing portion 14
is
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14
configured to receive the sensor 50 therewithin. By "configured to receive" it
is meant
that the structure of the housing portion 14 allows for at least a portion of
the sensor 50
to be enclosed and/or protected and/or coupled to and/or otherwise retained by
the
housing portion 14. For example, the housing portion 14 may defme an interior
space
51 of suitable size and shape to accommodate at least a portion of the sensor
14 (see
FIG. 4).
[005g[ The apparatusl 0 may be monolithic or modular. For
example, the
mount 12 and the housing portion 14 may be formed as a single monolithic
component
Or as separate modular portions that together form the apparatus 10. For
example and
as shown in the non-limiting embodiment illustrated in FIG. 3, the mount 12
and the
housing portion 14 may be separate and distinct pieces that can be removably
coupled
together. Non-limiting examples of this modular form of the apparatus 10, the
mount
12 and the housing portion 14 may be coupled together by a flanged connection
made
up a second ring plate 138 of the mount 12 and corresponding flange plate 18
that
forms part of the housing portion 14. The second ring plate 13B and the flange
plate 18
are removably coupled together by one or more securing members such as screws,
pins,
shanks, bolts or combinations thereof Without being bound by any particular
theory,
when the mount 12 and the housing portion 14 are modular, that can allow an
user of
the apparatus the ease of having different mounts 12 of various dimensions and
configurations available to best ensure that the apparatus 10 can be removably
coupled
to the non-moving part of the valve in a desired fashion.
[0056] The apparatus 10 may be of any material suitable for
withstanding the
wellsite environment. In some embodiments, portions of the apparatus 10 is
made of
metal or a metallic alloy such as steel, including conventional steel or high-
tensile steel.
In some embodiments of the present disclosure, portions of the apparatus 10
are made
of plastic, a polymer or a polymer blend. The mount 12 and the housing portion
14 can
be made of the same material or not.
[0057] The housing portion 14 is configured to receive the
sensor 50. The
housing portion 14 may receive the sensor 50 entirely therewithin, or not. In
some
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embodiments of the present disclosure, the sensor 50 is removably couplabled
to the
housing portion 14.
[0058] The sensor 50 is configured to detect the position of a
moving part of the
valve and to provide an output signal that indicates the operational position
of the valve
5 relative to a fixed reference point Examples of sensors 50 that are
suitable for use in
the apparatus, system, and methods of the present disclosure include any type
of sensor
that can detect the distance between the sensor 50 and a target surface, which
is
preferably a surface of the moving part of the valve, but may also be a non-
moving
surface of the valve if the .sensor 50 is operatively coupled to the moving
part of the
10 valve. A non-limiting example of such a sensor is a time of flight (TOF)
sensor. In
some embodiments of the present disclosure, the TOF sensor may be an
ultrasonic TOF
sensor assembly that comprises an ultrasonic sound source, an ultrasonic sound
detector and a processor. While known in the art, such an ultrasonic (TOF)
sensor
operates by the sound source emitting ultrasonic soundwaves at a target which
reflects
15 the soundwaves. The reflected soundwaves are detected by the ultrasonic
sound
detector. The microprocessor compares the time differential between when the
emitted
soundwaves are emitted and when the received soundwaves are received to
determine
the distance between the emitter and the target The microprocessor then
converts this
time differential into a time differential output signal that is then
communicated
externally to the apparatus 10 as either a voltage signal or a current signal.
The
microprocessor may also compensate for other factors such as noise and
temperature to
improve the accuracy of the distance calculations.
[0059] As will be appreciated by those skilled in the art, TOF
sensors other than
ultrasonic TOF sensors are also contemplated herein, such as laser TOP sensor
assembly, LIDAR TOP sensor assembly, a radar TOF sensor assembly or
combinations
thereof. As will be appreciated by those skilled in the art, other types of
sensors are
also contemplated herein, such as a string pot sensor assembly, a rotary
potentiometer/rotary encoder, a linear variable differential transformer
(LVDT) sensor
assembly, a limit switch assembly, a magnetic pick-up sensor assembly or
combinations thereof.
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16
100601 As shown in the non-limiting illustration of FIG. 3, the
housing portion
14 may also define the inner surface of an optional focusing tube 54. The
focusing tube
54 may comprise at least a portion of which that has a conical cross-sectional
shape.
As shown in FIG. 32, the first end of the focusing tube 54 that is proximal
the mount 12
may have a smaller cross-sectional area than the opposite, second end of the
focusing
tube 54 that is proximal the sensor 50. Without being bound by any particular
theory,
the conical cross-sectional shape of the focusing tube 54 may focus the
soundwaves
within the focusing tube travelling in one direction and filter soundwaves in
the other
direction, which may enabling the sensor 50 to determine the position of the
target
through a smaller aperture than other designs allow for. In some embodiments
of the
present disclosure, the inner surface of the housing portion 14 can be shaped,
for
example by machining or otherwise, to define the cross-sectional shape of the
focusing
tube 54. Alternatively, an insert body may be fixed within the housing portion
14 and
the insert body will include an inner surface that defines the cross-sectional
shape of the
focusing tube 54.
100611 In some embodiments of the present disclosure, the
housing portion 14
may be monolithic or modular. As shown in the non-limiting illustration of
FIG. 4, the
housing portion 14 can comprise three separate modular components, namely a
first
end component 32, a second end component 30 and an intermediate component 31.
100621 The first end component 32 may include the flange plate IS and be
removeably couplable to the mount 12 as described herein above.
100631 The second end component 30 may define an timer plenum
51 in which
at least a portion of the sensor 50 is received and through which electronic
cables (not
shown) can extend from the sensor 50 out through a cable extension 24 via a
cable
2,5 conduit 26 to terminate in a cable connector 28. The electronic cables
are configured to
conduct electronic signals, electronic power or both to and from the sensor
50. The
cable connector 28 ,can be a multi-pin connector that is configured to
operatively
connect the electronic cables within the plenum 51 to provide external power
and/or
communication channels. In some embodiments of the present disclosure, the
sensor
50 may be powered by a battery and the sensor 50 may be configured to
wirelessly
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17
communicate the output signal generated by the microprocessor arid to receive
wireless
commands from a user.
[0064] The intermediate component 31 can be removably connected
to the
second end component 30 by flanges 34 and 36 and connection members that
extend
therethrough. The intermediate component 31 may also include a fixing body 56
that is
configured to protect the sensitive electronic components of the sensor 50, to
maintain
the orientation of the sensor 50 within the housing portion 14 and,
optionally, to define
a portion of the focusing tube 54. In some embodiments of the present
disclosure, the
fixing body 56 also reduce external interference, such as noise and thermal
fluctuations,
with the operation of the sensor 50. The intermediate component 31 may also
removably connect with the first end component 32. In some embodiments of the
present disclosure, a quick release connection may be used to removably
connect the
intermediate component 31 and the first end component 32. The quick release
connection may include a biased clamp member 20 and a retention member 22. The
biased clamp member 20 can include a biasing member that forces two opposing
handles away from each other, which in turn creates an inward compression
force that
acts upon a portion of the intermediate component 32 and the tint end
component 32.
The retention member 22 can be used to lock the biased clamp member 20 in a
desired
position, so as to maintain the clamping force. In order to release the
clamping force,
the retention member 22 can be loosened and the two handles of the biased
clamping
member 20 can be moved towards each other to reduce or relieve the clamping
force
As will be appreciated by those skilled in the art, other types of quick
release
connections are also contemplated by the present disclosure. Without being
bound by
any particular theory, the embodiments of the present disclosure that include
the quick
release connection may provide an operator access to maintain and/or replace
the
sensor 50 without having to decouple the mounting 12 from the non-moving part
of the
valve and without having to decouple the first end component 32 from the mount
12.
[0065] FIG. 5 shows another embodiment of the present
disclosure that relates
to an apparatus 10A that has the same components as described hereinabove
regarding
the apparatus 10 with the addition of a push rod assembly 100. The push rod
assembly
100 is configured to be operatively coupled to the moving part of the valve,
such that
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18
when the moving part of the valve moves to change the operational position of
the
valve, the push rod assembly 100 will also move and that movement can be
detected by
the sensor 50.
[0066] The push rod assembly 100 comprises an assembly housing
101 that is
removably couplable at one end to the second ring plate 13B by a flange 118A
and to
the flange plate 18 of the fn-st end component 32 by a flange 118B. The push
rod
assembly 10 also comprises a rod 102 and a piston cap 104 is connected to one
end of
the rod 102. The rod 102 and the piston cap 104 are both positioned within the
assembly housing 101. The rod 102 can be inserted into a valve shroud of the
valve and
forced against the moving part of the valve, such as the valve stem, via a
biasing
member 106 that creates a biating force that pushes the rod 102 towards the
valve stem
(as shown by the arrow X in FIG. 5B). In other embodiments of the present
disclosure,
the rod 102 is connected to the moving part of the valve by adhesive, one or
more
magnets, a mechanical attachment or combinations thereof, such that when the
moving
part of the valve moves, thus changing the operational position of the valve,
the rod 102
will move similarly. Movement of the rod 102 will cause the piston cap 104 to
also
move and the change in position of the piston cap 104 will change the time of
flight
analysis conducted by the microprocessor of the sensor 50. While the focusing
tube
54A is shown as not having a conical cross-sectional shape in FIG. 5B, the
skilled
person will appreciate that such a shape is still contemplated by this
disclosure.
[00671 Without being bound by any particular theories, the push
rod assembly
100 enables the sensor 50 to read the operational position of a valve that has
a small
aperture and/or that that otherwise would not be suitable for position
detection by the
sensor 50. Without being bound by any particular theory, the push rod assembly
100
translates movement of the moving part of the valve, such as but not limited
to the
valve stem, to movement of the piston cap 104 and the piston cap 104 provides
a larger
target surface against which the sensor 50 can emit and receive ultrasonic
sound waves.
The push rod assembly 100 also isolates the sensor 50 and the sensor read path
(i.e.
between the emitter and the target) from environmental issues such as water,
grease,
debris and ice by enclosing the rod 102 and the piston cap 104 inside the
assembly
housing 101.
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19
[00681 In operation, the two apparatus 10, 10A work in a
similar fashion. The
sensor 50 emits ultrasonic sound waves that travel in a first direction (shown
as arrow
X in FIG. 4 and FIG. 5). The sound waves travel along the sensor read path
through
the focusing tube 54, 54A and reflect off the target surface. In the case of
apparatus 10,
the target surface is a surface of the moving part of the valve, such as but
not limited to
the valve stem. In the case of apparatus 10A, the target surface is the piston
cap 104.
The reflected sound waves then travel in a second opposite direction (shown as
arrow
Y in FIG. 3 and FIG. 4) along the sensor read path through the focusing tube
54, 54A to
strike a receiving end 52 of the sensor 50. From there, the microprocessor
generates
the time differential output signal, as described above, and electronically
communicates
that externally.
[0069] As will be appreciated by those skilled in the art, the
detected position of
the moving part of the valve is indicative of the operational position of the
valve. For
example, a valve whose operational position controls the flow of fluids
towards,
through or away from a piece of wellsite equipment. The output signal
generated by
the sensor 50 may indicate that the valve is in a first operational position
and, therefore,
it is indicated that the valve is in an open position. When the output signal
indicates the
actuator is in a second operational position, the output signal will indicate
that the valve
is in a closed position. Actuating the valve between an open position and a
closed
position regulate the flow of fluids through the valve, which in turn
regulates the flow
of fluids towards, through Or away from the associated welIsite equipment. In
some
embodiments, the output signal may indicate that the valve is in an
inteimediate
operational position between the first position and the second position and,
therefore,
this indicates that the valve is in a partially open position and fluid flow
through the
valve may be partially restricted as compared to when the valve is in an open
position.
100701 Some embodiments of the present disclosure provide a
system 1000 for
detecting and indicating an operational position of a valve of weIlsite
equipment (see
FIG. 6). The system 1000 comprises one or more of apparatus 10 or 10A that are
each
configured to detecting the position of the moving part of the valve and
providing an
output signal that indicates the operational position of the valve and a
processor 400 for
receiving and processing the output signal into a processed output signal.
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[00711 As used herein, the term "processor" is intended to
refer to a computing
unit that executes a program. In some embodiments of the present disclosure,
the
program executed = converts the output signal from the at least one sensor
into a
processed output signal. The processor 400 may be one or more single-core or
5 multiple-core computing processors such as INTEL microprocessors (INTEL is
a
registered trademark of Intel Corp., Santa Clara, CA, USA), AMD
microprocessors
(AMD is a registered trademark of Advanced Micro Devices Inc., Sunnyvale, CA,
USA), ARM microprocessors (ARM is a registered trademark of Arm Ltd.,
Cambridge, UK) manufactured by a variety of manufactures such as Qualcomm of
San
10 Diego, California, USA, under the ARM 9 architecture, or the like.
For the purposes of
this disclosure, the term "processor" may be used to refer to multiple
processors that
are operatively connected to each other, for example, as sub-processors of a
master
processor
[00721 In some embodiments of the present disclosure, the
system 1000
15 actuator further comprises one or more remote display units 500
for receiving the
processed signal and displaying an image indicative of the operational
position of the
one or more valves that each have an associated apparatus 10 or 10A. By
"remote
display unit" it is meant that the display unit need not be positioned at the
well. For
example, the remote display unit may be in a service truck, a trailer or a
control center
20 at the well site or at a control center that is at a remote
location distant from the well
site. The remote display unit 500 may comprise one or more display modules for
displaying images, such as monitors, LCD displays, LED displays, projectors,
and the
like_ The remote display unit 500 may be a physically integrated part of the
processor
400 and/or the user interfaces (for example, the display of a laptop computer
or tablet),
or may be a display device physically separate from, but functionally coupled
to, other
components of the processor and/or the user interfaces (for example, the
monitor of a
desktop computer). In an embodiment, the remote display unit 500 may be a
Human-
Machine-Interface (HMI). At least one advantage of the remote display unit 500
is a
reduction of transport of individuals to wellsite locations. Another advantage
of a
remote display unit 500 is that the operational position of multiple valves on
multiple
wellsites/well pads can be monitored by multiple users both at the
welIsite/well pad
Date Recue/Date Received 2021-06-25
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21
and/or at a centralized control center. As will be appreciated by the skilled
person, the
arrows depicted in FIG. 6 represent electronic communication, wired, wireless
of both,
between the different components of the system 1000.
[00731 In some embodiments of the present disclosure, the
system 1000
described herein may be integrated into an existing control system at a
wellsite arid/or
at a remote location.
[00741 The program that is executable by the processor 400 can
be used to map
and calibrate the output signal of sensor 50 of each apparatus 10 or 10A to a
respective
operational position. For example, processor 400 can create a well
identification
number and a valve identification number for each well and valve that will be
operatively connected to the system 1000. Next the operator can actuate the
valve into
a first operational position and then instruct the processor 400, optionally
via a HMI
functionality of the remote display unit 500) to add the output signal of the
sensor 50 to
indicate a first operational position, this is referred to as a first
calibration step. The
processor 400 will also assign a created well valve identification number to
the valve
associated with the sensor 50 that provides an altered output signal (as
between prior to
actuating the valve and after actuating the valve). When all valves have been
associated a valve identification number, each valve will be mapped within the
system
1000 and each valve identification number may then be displayed on the remote
display
unit 500 in such a manner that the user will be able to discern the
operational position
of all valves that are assigned a valve identification number. The operator
may also
perform the first calibration step multiple times for each valve and the
program will
calculate an average to assist in more precisely calibrating the output signal
for the first
operational position, this may be referred to as a further first calibration
step. Next the
operator can actuate the valve into the second operational position and then
instruct the
processor 400 to add the output signal of the sensor 50 as indicating the
second
operational position, this may be referred to as a second calibration step.
The
calibration of the sensor 50 output signal to indicate that the valve is in
the second
operational position can also be averaged over multiple adding steps by
performing
further second calibration steps.
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22 =
[00751 If desired, depending on the specific valve function,
the operator may
also actuate the valve to one or more intermediate operational positions and
instruct the
program to add the output signal of the sensor 50 as indicating as one or more
intermediate operational positions of valve. Alternatively or additionally,
the program
can be instructed that any output signal of the sensor 50 that is between the
measure of
the first operational position and the second operational signal will indicate
an
intermediate position.
100761 Preferably, each sensor 50 must be calibrated to the
valve it is installed
on in order to provide an accurate indication of the operational position of
the valve.
The calibration process takes a measurement of the sensor 50 output signals in
the first
operational position, the second operational position or therebetween.
[00771 Optionally, the user can also use the processor 400 to
apply an
acceptable variance imnge, also referred to as a dead band, within the output
signal to
filter any signal noise within the sensor 50 output signal and to allow for
any physical
inconsistency or errors in physical positioning of the valve. For example,
after
following the steps above and establishing that an output signal of X (volts
or current)
indicates that the valve is in the first operational position and an output
signal of Y
(volts or current) indicates that the valve is in the second operational
position, the
processor can calculate the difference between X and Y to establish a range
between
the two output signals and applies a scale of 0-100 of the calculated range.
The user
can then instruct the processor 400 calculate a desired percentage of the
established
scale so that a signal within Z1% (on either side) of X will be indicative of
the valve
being in the first operational position and that a signal within Z2% of Y will
be
indicative of the valve being in the second operational position. Z1 need not
equal Z2.
The applied scale will also indicate to the user the relative percentage that
a valve is
open or closed, which may also be calculated (based upon inputting applicable
dimensional measurements into the processor 400) to determine an actual
distance that
a valve is in an open operational position or a closed operational position.
100781 FIG. 7 shows a farther embodiment of a system 1000A that
has the same
components as system 1000, with the further components of the processor 400
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23
includes a digitizer 402, a microprocessor 404 and a calibration module 406.
The
digitizer is configured to convert the output signal from a voltage signal or
a current
signal to a digital signal. The microprocessor 404 is configured to process
the digital
signal according to the instructions provided by the program and the user. The
calibration module 406 is configured to perform and calculate the calibration
method
described above. The system 1000A may further comprise a database module 1002
for
storing all processed signal data received by the processor 400 and for
delivering to
such stored data to a remote database infrastructure 1010, such as a cloud-
based or
server based database. Optionally, the user may access the stored data
directly from the
remote database infrastructure 1010, via HMI features of the remote display
unit 500,
or indirectly through the database module 1002.
[00791 In some embodiments of the present disclosure, the
system 1000A may
also comprise a remote valve control (RVC) system 2000 that includes a data
processor
module 2002, an automation controller 2004, a remote valve actuator (RVA)
controller
IS 2006 and one or more RVA actuators 2008n (one for each valve that is
being remotely
controlled by the system 2000). The data processor module 2002 is configured
to
receive the data within the processed signal output from the processor 400 and
to
further process that data, which reflects the position that a given valve is
in. The data
processor module 2002 may then determine whether or not it is appropriate to
change
the operational position of the valve, as described further below. In event
that the data
processor module 2002 determines that the operational position of the valve
can be
changed, the data processor module 2002 may send a change position command to
an
automation controller 2004, which is configured to translate and direct a
change
operational position command to a hardware controller 2006, which in turn can
cause
the actuator 2008n to move the actuator of the valve and change the
operational
position of the valve, with or without a user's further intervention. In the
event that the
data processor module 2002 determines that the operational position of the
valve
should not be changed, then it can send no further commands or it can send a
maintain
position command to the actuator 2008n, via the automation controller 2004 and
the
SO hardware controller 2006.
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24
(0080j Once each apparatus 10/10A is mapped to its associated
valve, each
actuator 2008n can also be mapped to the same valve. So that a user can use
the system
1000A to receive an indication as to the operational position of a given valve
and then
directly actuate that valve to change its operational position. For example,
each
actuator 2008n is configured to be controlled by receiving commands remotely
by a
user, directly by a user or in an automated fashion under control of a
controller,
microcontroller, a processor or microprocessor (as described above). The
actuator
2008n is further configured to move the actuator so as to move a valve between
the first
operational position, the second operational position and the intermediate
operational
position between the first and second positions.
[00811 Each actuator 2008n comprises a motor that can be
electrically powered,
pneumatically powered or hydraulically powered. Each type of motor has its own
advantages and may be selected according to its particular application. For
example,
electrically powered motors are easily reprogammable, environmentally
friendly, and
can be precisely and flexibly controlled. Suitable and non-limiting examples
of such
electrically powered motors can include direct current (DC) motors,
synchronous and
asynchronous motors, alternating current (AC) motors, stepper motors, and
servomotors. Pneumatically powered motors are simple to use, they are durable,
can
provide a high-force output, and they can be used in hazardous environments.
Suitable
examples of pneumatically powered motors include rack and pinion actuators and
rotary vane actuators. A non-limiting example of a pneumatic rotary vane
actuator is a
Model 07 Actuator, commercially available from '<Metro1.54 LTD. Hydraulic
rotary
actuators can be used for applications that requiring high torque in order to
move the
actuator of a given valve. Common design configurations for such hydraulically
powered motors include piston type, vane type, or gear type.
[0082] In some embodiments of the present disclosure, the
actuator 2008n may
comprise another mechanism than the motor for moving the actuator of the
valve, such
as a linear actuator or another type of rotary actuator. The linear actuator
and the rotary
actuator can be electrically powered, pneumatically powered or hydraulically
powered.
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100831 FIG. 8 provides logic flow diagrams that illustrate how
the system
1000A can operate a method to remotely control and monitor the operational
position
of one or more valves on a wellsite/well pad. FIG, 8A represents a scenario
where the
sensor 50 (shown as VPS1) has detected the position of a moving part of the
valve and
5 is indicating that position be sending the output signal data to the
processor 400 (shown
as logic control). Within the processor 400, a determination is made whether
or not the
specific valve should maintain its current operational position (i.e. status)
or whether or
not it is safe to proceed to a next step of changing the operational position
of the valve.
The determination of whether or not it is safe to proceed is based upon a full
mapping
10 of all applicable valves on the well site/well pad being stored within
the processor 400
and further data inputs into the processor 400 that will allow a user to
understand what
step of a particular service is being performed at the time. For example, the
further data
inputs may indicate that there is currently a high pressure flow of fracturing
fluids
being directed into the well. As such, that is not a safe time to change the
operational
15 position of a master valve from open to closed. This is but one example
of how the
valve position information provided by the apparatus 10/10A can be integrated
into a
data capture and storage system that allows users to receive visual
indications, for
example on the HMI of the remote display unit 500, and to make decisions -
based on
the step of a well service operation that is occurring - as to whether or not
to change the
20 operational position of one or more valves. The skilled person will
appreciate that
various forms of further data inputs can be integrated to alert the user as to
the step of a
particular service that is being performed at a given time. Such integrated
systems are
described in the Applicant's prior filed patent application (FCT/CA2019/050890
entitled APPARATUS, SYSTEM AND PROCESS FOR R.EGULATING A
25 CONTROL MECHANISM OF A WELL), the entire disclosure of which is
incorporated herein by reference.
[0084] FIG. SR represents a scenario where the sensor 50 (shown
as VPS1) has
detected the position of a moving part of the valve and is indicating that
position be
sending the output signal data to the processor 400 (shown as Logic Control)
where a
valve position lockout is present on each valve. The valve position lockout is
configured to prevent movement of a locked out valve from its current
operational
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26
position. When a lockout is unlocked, the operational position of the valve
can be
changed. The lockout mechanism can be a physical barrier that restricts
physical
interaction or movement with a valve's actuator or the lockout mechanism can
be a
systematic barrier that prevents the flow of power (hydraulic, pneumatic or
electrical)
to a mechanically controlled valve actuator. In other embodiments of the
present
disclosure, the lockout mechanism can be a digital lockout, whereby the flow
of
electrical, pneumatic and hydraulic power for performing an operation on a
well is
controllable by a digital control system of which the processors 400 can
control one or
more aspects of. Non-limiting examples of such digital control system are
described in
Applicant's prior flied patent application (PCT/CA2019/050890 entitled
APPARATUS, SYSTEM AND PROCESS FOR REGULATING A CONTROL
MECHANISM OF A WELL). In the event that the sensor 50 indicates that the valve
is
not in a desired operational position for a step of the operation that is
being performed
on the well or soon to be performed on the well, the processor 400 can proceed
to
unlock the lockout on the valve and this will result in a further signal being
communicated to the processor 400, which will then assess whether or not the
unlocked
status is acceptable or not. If acceptable, the user may then proceed to the
next step of
the process. If the unlocked status is not acceptable, then the lockout may be
re-locked
to prevent any change in the operational position of the valve.
[0085] FIG. 8C represents a scenario where it is desired to move the valve
to an
intermediate position so that the apparatus 10/10A indicates that the valve is
approximately halfway between the 0 and 100 of the applied scale (as discussed
above).
[00861 FIG. 9 shows a scenario where the system 1000A where
each valve that
is included has its own apparatus 10/10A (shown as VPS1) and its own actuator
2008
(shown as RVA).
[0087] hi some embodiments, the present disclosure provides a
method 2000
for detecting and indicating an operational position of valve of wellsite
equipment. The
method 2000 comprises a step 2100 of releasably coupling an apparatus 10/10A
to a
non-moving part of the valve or wellsite equipment. The method 2000 also
comprises
a step of detecting 2200 the position of a moving part of the valve, relative
to a fixed
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27
point (or otherwise), a step 2202 of indicating the detected position of the
moving part
of the valve by communicating an output signal. Optionally, the method
comprises a
step 2204 of observing the output signal so that operators of one or more
services being
performed at a given well can make operational decisions.
100881 The step 2200 of detecting a position of the actuator may be
performed
by the sensor 50. The sensor 50 may be in fluid communication and, therefore
acoustic
communication with a moving part of the valve. Alternatively, the sensor 50
may be
coupled to the moving part of the valve and in fluid communication with a non-
moving
part of the valve (which acts as the target surface).
[0089] In some embodiments of the present disclosure, the step 2202 of
indicating comprises: a step 2210 of processing the output signal into a
processed
output signal; and a step 2220 of converting the processed output signal and
transmitting the processed output signal, via wired or wireless electronic
communication, for display on a display unit, that may be remote from the
valve itself,
or not. In an embodiment, the processing step is by a processor such as the
processor
400 described elsewhere herein. In an embodiment, the display unit may be the
remote
display unit 500 described elsewhere herein. In an embodiment, the image is a
graphical image, an alphanumeric image, a colour, or any combination thereof.
In an
embodiment, a change of the graphical image, such as for example a colour
change,
may indicate whether the actuator is in a first position, a second position or
therebetween. Furthermore, the data that is used to generate the image can be
used in
numerical form for further control or analysis work.
[0090] In an embodiment, the processed output signal (and the
associated image
displayed on a remote display unit) indicates the position of a moving part of
the valve.
The position of the moving part of the valve indicates the operational
position of the
valve being an open position, a closed position, or, optionally, an
intermediate position.
[0091] The image on the display unit may infonn a consultant or
other user to
make operational decisions about service operations being performed at the
well pad
for example, for example whether or not to actuate one or more valves of
wellsite
Date Recue/Date Received 2021-06-25
A8146180CA
28
equipment, turn on or off one or more fluid pumps, extend or retract wireline
or coiled
tubing from the well, or other operationnl decisions that are apparent to
those skilled in
the art.
Date Recue/Date Received 2021-06-25
