Note: Descriptions are shown in the official language in which they were submitted.
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DYNAMIC RESPONSE APPARATUS AND
METHODS TRIGGERED BY CONDITIONS
FIELD OF THE DISCLOSURE
The present disclosure relates to an apparatus and methods to provide a
dynamic
response triggered by one or more conditions, such as drilling rig site
conditions.
BACKGROUND OF THE DISCLOSURE
At a drilling rig site, field personnel sometimes generate reports associated
with the
drilling rig site and in accordance with a client's instructions. These
reports may then be
analyzed by the field personnel and/or the client to determine if any action
needs to be taken
at the drilling rig site. In some cases, however, the reports are unnecessary,
and/or the reports
do not include important or otherwise relevant data. Moreover, although some
reports may
include relevant data, such data may not be timely reported and, as a result,
any necessary
response action at the drilling rig site may not be timely. Therefore, what is
needed is an
apparatus or method that addresses the foregoing issues, among others.
SUMMARY OF THE INVENTION
In an exemplary aspect, the present disclosure is directed to a method
including:
generating, using a computer system, a pre-defined custom profile that
specifies a potential
condition of a drilling rig site and monitoring, using the computer system,
one or more
operational parameters at the drilling rig site to determine an actual
condition of the drilling
rig site. The method also includes detecting, using the computer system, that
the actual
condition of the drilling rig site matches the potential condition of the
drilling rig site
specified by the pre-defined custom profile and dynamically responding to the
detection of
the matching conditions. The dynamic response includes one or more of the
following:
automatically controlling, using the computer system, one or more operations
at the drilling
rig site based on the actual condition of the drilling rig site; and
automatically generating,
using the computer system, a report that includes data corresponding to the
actual condition
at the drilling rig site.
In another exemplary aspect, the present disclosure is directed to an
apparatus that
includes a non-transitory computer readable medium; and a plurality of
instructions stored on
the computer readable medium and executable by one or more processors. The
plurality of
instructions include: instructions that cause the one or more processors to
generate a pre-
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defined custom profile that specifies a potential condition of a drilling rig
site; instructions
that cause the one or more processors to monitor one or more operational
parameters at the
drilling rig site to determine an actual condition of the drilling rig site;
instructions that cause
the one or more processors to detect that the actual condition of the drilling
rig site matches
the potential condition of the drilling rig site specified by the pre-defined
custom profile; and
instructions that cause the one or more processors to dynamically respond to
the detection of
the matching conditions. The dynamic response instructions include one or more
of the
following: instructions that cause the one or more processors to automatically
control one or
more operations at the drilling rig site based on the actual condition of the
drilling rig site;
and instructions that cause the one or more processors to automatically
generate a report that
includes data corresponding to the actual condition at the drilling rig site.
In yet another exemplary aspect, the present disclosure is directed to a
method
including generating, using a computer system, a pre-defined custom profile
that specifies a
potential condition of a drilling rig site. The pre-defined custom profile
specifies at least one
of the following: one or more downhole tool parameters; and one or more
wellsite
information transfer specification (WITS) parameters. The method also includes
monitoring,
using the computer system, one or more operational parameters at the drilling
rig site to
determine an actual condition of the drilling rig site; and includes
detecting, using the
computer system, that the actual condition of the drilling rig site matches
the potential
condition of the drilling rig site specified by the pre-defined custom
profile. The method
further includes dynamically responding to the detection of the matching
conditions. The
dynamic response includes automatically generating, using the computer system,
a report that
includes data corresponding to the actual condition at the drilling rig site,
wherein the data
corresponding to the actual condition at the drilling rig site include at
least one of
measurement-while-drilling (MWD) data and logging-while-drilling (LWD) data;
and
automatically transmitting, using the computer system, the report to one or
more pre-
determined locations.
BRIEF DESCRIPTION OF THE DRAWINGS
The present disclosure is best understood from the following detailed
description
when read with the accompanying figures. It is emphasized that, in accordance
with the
standard practice in the industry, various features are not drawn to scale. In
fact, the
dimensions of the various features may be arbitrarily increased or reduced for
clarity of
discussion.
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FIG. 1 is a schematic view of an apparatus according to one or more aspects of
the
present disclosure, the apparatus including a rig monitoring system for a
drilling rig site.
FIG. 2 is a flow-chart diagram of at least a portion of a method according to
one or
more aspects of the present disclosure, the method including a step of
generating a pre-
defined custom profile associated with a potential condition of the drilling
rig site of FIG. 1.
FIG. 3 is a schematic view of the pre-defined custom profile of the method of
FIG. 2
according to one or more aspects of the present disclosure.
FIG. 4 is a schematic view of an apparatus according to one or more aspects of
the
present disclosure.
FIG. 5 is a schematic view of a node for implementing one or more aspects of
the
present disclosure.
DETAILED DESCRIPTION
It is to be understood that the following disclosure provides many different
embodiments, or examples, for implementing different features of various
embodiments.
Specific examples of components and arrangements are described below to
simplify the
present disclosure. These are, of course, merely examples and are not intended
to be limiting.
In addition, the present disclosure may repeat reference numerals and/or
letters in the various
examples. This repetition is for the purpose of simplicity and clarity and
does not in itself
dictate a relationship between the various embodiments and/or configurations
discussed.
Moreover, the formation of a first feature over or on a second feature in the
description that
follows may include embodiments in which the first and second features are
formed in direct
contact, and may also include embodiments in which additional features may be
formed
interposing the first and second features, such that the first and second
features may not be in
direct contact.
Referring to FIG. 1, illustrated is a schematic view of an apparatus 10, which
is within
the scope of the present disclosure and includes a monitoring system 11, which
will be
referred to herein in the context of a drilling rig, for monitoring a drilling
rig site 12. The rig
monitoring system 11 includes a computer system, which includes a computer
processor 14.
A computer readable medium 16 is operably coupled to, and in communication
with, the
computer processor 14. Instructions accessible to, and executable by, the
computer processor
14 are stored on the computer readable medium 16. In several exemplary
embodiments, the
computer readable medium 16 includes one or more databases. In several
exemplary
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embodiments, the computer processor 14 is part of a server, a programmable
logic controller
(PLC), or one or more other computing devices.
In several exemplary embodiments, the drilling rig site 12 includes one or
more
drilling rigs employed in oil and/or gas exploration and production
operations; these one or
more drilling rigs may be land-based drilling rigs, jack-up rigs,
semisubmersibles, drill ships,
coil tubing rigs, and casing drilling rigs, among others. In several exemplary
embodiments,
in addition to one or more drilling rigs, the drilling rig site 12 may include
one or more other
types of wellsite equipment such as, for example, one or more downhole tools,
the wellbore,
the wellhead, etc.
In an exemplary embodiment, the rig monitoring system 11 is located, in whole
or in
part, at or near the drilling rig site 12. In several exemplary embodiments,
the rig monitoring
system 11 may be considered to be part of the drilling rig site 12. In several
exemplary
embodiments, the rig monitoring system 11 is located, in whole or in part, at
a location
remote from the drilling rig site 12.
In operation, in an exemplary embodiment with continuing reference to FIG. 1,
the rig
monitoring system 11 continuously monitors parameters/inputs associated with
the drilling
rig site 12. The monitored parameters/inputs include one or more wellsite
information
transfer specification (WITS) parameters 18, one or more downhole tool
parameters 20, other
parameters 22, other inputs 24, or any combination thereof. In an exemplary
embodiment,
the WITS parameters 18 may be omitted. In an exemplary embodiment, the
downhole tool
parameters 20 may be omitted. In response to this monitoring, the rig
monitoring system 11
automatically generates one or more actions, outputs, or both. The
automatically generated
actions/outputs include an automatic action 26 (such as operational control of
one or more
components or systems of the drilling rig site 12), an automatic output 28
(such as a report),
other automatic actions 30, and other automatic outputs 32. In several
exemplary
embodiments, the rig monitoring system 11 continuously monitors a wide variety
of
parameters/inputs and acts upon such parameters/inputs in respective pre-
determined
manners to perform automatic actions which would otherwise be carried out by
human
interaction.
Referring to FIG. 2, illustrated is a flow-chart diagram of at least a portion
of a
method 34. In several exemplary embodiments, the method 34 is implemented in
whole or in
part using the apparatus 10 in whole or in part. In several exemplary
embodiments, the
method 34 is a method of operating the apparatus 10. The method 34 includes at
step 36
generating a pre-defined custom profile 37 (shown in FIG. 3) that specifies a
potential
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condition of the drilling rig site 12. Before, during, or after the step 36,
at step 38 the actual
condition of the drilling rig site 12 is determined by monitoring one or more
operational
parameters. The monitored operational parameters may include the WITS
parameters 18, the
downhole tool parameters 20, the other parameters 22, and the other inputs 24.
During or
after the step 38, at step 40 it is detected that the actual condition of the
drilling rig site 12
determined at the step 38 matches the potential condition of the drilling rig
site 12, as
specified by the pre-defined custom profile generated at the step 36. This
detection at the
step 40 triggers a dynamic response at step 42. In an exemplary embodiment,
the step 42
includes at step 44 automatically controlling one or more operations at the
drilling rig site 12
based on the actual condition thereof determined at the step 40. In an
exemplary
embodiment, the step 42 includes at step 46 automatically generating a report
that includes
data corresponding to the actual condition of the drilling rig site 12. In an
exemplary
embodiment, the step 42 includes at step 48 automatically transmitting the
report generated at
the step 46 to one or more pre-determined locations.
In an exemplary embodiment, the step 42 includes the steps 44, 46 and 48. In
an
exemplary embodiment, the step 42 does not include the step 44. In an
exemplary
embodiment, the step 42 does not include the steps 46 and 48. In an exemplary
embodiment,
the step 42 does not include the step 48. In an exemplary embodiment, the step
42 does not
include either the step 44 or the step 48.
Referring to FIG. 3, illustrated is a schematic view of the pre-defined custom
profile
37, which is generated at the step 36 of the method 34. In an exemplary
embodiment, the
pre-defined custom profile 37 specifies one or more WITS parameters 50 at the
drilling rig
site 12, one or more downhole tool parameters 52 at the drilling rig site 12,
a drilling depth
interval parameter 54 at the drilling rig site 12, a time interval parameter
56 at the drilling rig
site 12, a drilling depth target parameter 58 at the drilling rig site 12, a
tripping condition
parameter 60 at the drilling rig site 12, and an end-of-day summary parameter
62 at the
drilling rig site 12. In an exemplary embodiment, the pre-defined custom
profile 37 may not
specify any of the WITS parameters 50. In an exemplary embodiment, the pre-
defined
custom profile 37 may not specify any of the downhole tool parameters 52. It
should be
understood that appropriate parameters, conditions, etc. may be selected
depending on the
function being monitored, such as in loading a complex weapon,
raising/lowering a
drawbridge, controlling a traffic network or water/sewage pipelines, or the
like, and that
references herein to drilling rigs and wellsites and WITS are exemplary only.
In an
exemplary embodiment, the pre-defined custom profile 37 specifies that one or
more of the
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WITS parameters 50 must be met under at least one pre-defined derivative
constraint (e.g.,
first derivative constraint, first and second derivative constraints, etc.).
In an exemplary
embodiment, the pre-defined custom profile 37 specifies that one or more of
the downhole
tool parameters 52 must be met under at least one pre-defined derivative
constraint (e.g., first
derivative constraint, first and second derivative constraints, etc.).
In an exemplary embodiment, at the step 38, as noted above, the rig monitoring
system 38 determines an actual condition of the drilling rig site 12 and
compares the actual
condition (or the parameters corresponding thereto) with the potential
condition (or the
parameters corresponding thereto) specified by the pre-defined custom profile
37. At the step
40, it is detected when the actual condition of the drilling rig site 12
matches the potential
condition specified by the pre-defined custom profile 37, and a dynamic
response is made at
the step 42. In several exemplary embodiments, the foregoing conditions match
if the
operational parameters monitored at the step 38 are equivalent to, or are
within a range of, the
parameters specified by the pre-defined custom profile 37, i.e., one or more
of the parameters
50, 52, 54, 56, 58, 60 and 62.
In an exemplary embodiment, a plurality of pre-defined custom profiles 37 are
generated at the step 36, and the one or more operational parameters monitored
at the step 38
are associated with different modes of operation of the drilling rig site 12,
with each pre-
defined custom profile 37 corresponding to a different operational mode; the
potential
conditions for which a match is detected at the step 40 is specified by one or
more of the pre-
defined custom profiles 37 in the plurality of pre-defined custom profiles 37.
In an exemplary embodiment, at the step 42, the dynamic response of the rig
monitoring system 11 is triggered by the actual environment or condition(s) of
the drilling rig
site 12, as detected by the rig monitoring system 11 at the step 40. In other
words, the
detection of the actual environment or condition(s) at the drilling rig site
12 at the step 38
triggers the dynamic response at the step 42.
In an exemplary embodiment, the dynamic response at the step 42 is carried out
at
least at the step 44, which includes automatically controlling one or more
operations at the
drilling rig site 12. In several exemplary embodiments, at the step 42 one or
more of the
following operations are automatically controlled by the rig monitoring system
11:
measurement-while-drilling (MWD) operations; logging-while-drilling (LWD)
operations;
geosteering operations; tubular handling operations; drilling operations;
tubular make-up
operations; and tubular break-out operations.
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In an exemplary embodiment, the dynamic response at the step 42 is carried out
at
least at the step 46, which includes automatically generating a report that
includes data
corresponding to the actual condition of the drilling rig site 12. In an
exemplary
embodiment, the data corresponding to the actual condition of the drilling rig
site 12 includes
MWD data and/or LWD data.
In an exemplary embodiment, at the step 48, the report automatically generated
at the
step 46 is transmitted to one or more pre-determined locations. In an
exemplary embodiment,
at the step 48, the report is automatically e-mailed to different e-mail
addresses on a pre-
defined recipient list, which different e-mail addresses are the respective
pre-determined
locations at the step 48. In an exemplary embodiment, the pre-defined custom
profile 37
specifies at least one of the one or more pre-determined locations at the step
48. In several
exemplary embodiments, at least one of the one or more predetermined locations
at the step
48 is at the drilling rig site 12, or is remote from the drilling rig site 12.
In an exemplary
embodiment, at the step 48, the report automatically generated at the step 46
is transmitted
via text message to different telephone numbers, which different telephone
numbers are the
respective pre-determined locations at the step 48. In an exemplary
embodiment, at the step
48, the report automatically generated at the step 46 is transmitted via an
automated
telephone call to different telephone numbers, which different telephone
numbers are the
respective pre-determined locations at the step 48. In an exemplary
embodiment, at the step
48, the report automatically generated at the step 46 is transmitted via
instant messaging.
In an exemplary embodiment, in the method 34, the pre-defined custom profile
37
generated at the step 36 specifies that the one or more WITS parameters 50
and/or the one or
more downhole tool parameters 52 must be met under definable first and second
derivative
constraints. The one or more operational parameters monitored at the step 38
are associated
with an MWD operation. The MWD operation is automatically controlled at the
step 44,
and/or the report automatically generated at the step 46 includes data
associated with the
MWD operation.
In an exemplary embodiment, in the method 34, the pre-defined custom profile
37
generated at the step 36 specifies the depth-drilled interval parameter 54 and
the time-drilled
interval parameter 56 so that the report is automatically generated at the
step 44 when a
wellbore at the drilling rig site 12 has been drilled by a certain depth
amount, or the wellbore
has been drilled for a certain amount of time.
The operation of the apparatus 10, and/or the execution of the method 34,
provides the
ability to generate custom-defined reports, as well as the ability to define
that the custom-
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defined reports are to be generated when specific environmental conditions
occur, such as
when a certain WITS and/or downhole tool data profile is met under definable
first and
second derivative constraints).
In several exemplary embodiments, the operation of the apparatus 10, and/or
the
execution of the method 34, provides complete customization of report timing.
The operation
of the apparatus 10, and/or the execution of the method 34, provides the
ability to define a
large amount of rig-site situations at which reports are to be automatically
generated. As a
result, the operator at the drilling rig site 12, and/or office personnel at
one or more locations
remote from the drilling rig site 12, have the opportunity to respond to
potentially critical rig-
site situations in the most efficient manner possible. The operator, and/or
office personnel at
one or more locations remote from the drilling rig site 12, are informed of
the rig-site
situation, but are also provided with the data most relevant to making the
correct decision in
response to the rig-site situation, thereby dramatically improving drilling
efficiency.
Moreover, in addition to the operator at the drilling rig site 12 and/or
office personnel at one
or more locations remote from the drilling rig site 12, the operation of the
apparatus 10,
and/or the execution of the method 34, provides efficient communication of
well-site data to
all key decision-makers and stakeholders, enabling faster and more reliable
responses to
critical rig-site situations. In an exemplary embodiment, only the key
decision-makers and
stakeholders responsible for a particular critical alert or decision are
alerted, which minimizes
unnecessary interruption of those responsible for other alerts and decisions.
Thus, the
apparatus and methods can minimize or eliminate "alert fatigue" caused by
information
overload when every issue is sent to everyone every time.
In several exemplary embodiments, the operation of the apparatus 10, and/or
the
execution of the method 34, provides the potential for faster, more efficient,
and on-target
well-bore placement due to more informed and relevant decision making on the
part of the
operator at the drilling rig site 12, and/or office personnel at one or more
locations remote
from the drilling rig site 12.
In several exemplary embodiments, the operation of the apparatus 10, and/or
the
execution of the method 34, reduces the amount of repetitive tasks conducted
by field staff
(e.g., manual well-site report generation), allowing the field staff to
concentrate on job-
specific functions such as, for example, data analysis and interpretation.
Moreover, the
amount of personnel at the drilling rig site 12 may be reduced, thereby
increasing margins
through reduced per-job costs, and improving rig-site safety.
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In several exemplary embodiments, the operation of the apparatus 10, and/or
the
execution of the method 34, provides for thorough auditing of data and
consistent data
reporting and formatting throughout the life of a job at the drilling rig site
12. As a result,
the risk of incorrect or improper data presentation is reduced.
In several exemplary embodiments, the operation of the apparatus 10, and/or
the
execution of the method 34, offers the potential to predict potential well-
site disasters well
before any occurrences thereof by providing constant monitoring of well-site
variable trends,
both downhole and at the surface of the drilling rig site 12.
Referring to FIG. 4, illustrated is a schematic view of apparatus 100. The
apparatus
100 demonstrates an exemplary environment in which an apparatus within the
scope of the
present disclosure may be implemented. In several exemplary embodiments, the
apparatus
100 is positioned at, and forms part of, the drilling rig site 12.
As shown in FIG. 4, the apparatus 100 is or includes a land-based drilling rig
for
drilling a wellbore within a subterranean formation. However, one or more
aspects of the
present disclosure are applicable or readily adaptable to any type of wellsite
equipment, such
as a drilling rig. The drilling rig may include without limitation one or more
jack-up rigs,
semisubmersibles, drill ships, coil tubing rigs, and casing drilling rigs,
among others.
Apparatus 100 includes a mast 105 supporting lifting gear above a rig floor
110. The lifting
gear includes a crown block 115 and a traveling block 120. The crown block 115
is coupled
at or near the top of the mast 105, and the traveling block 120 hangs from the
crown block
115 by a drilling line 125. The drilling line 125 extends from the lifting
gear to draw-works
130, which is configured to reel the drilling line 125 out and in to cause the
traveling block
120 to be lowered and raised relative to the rig floor 110. A hook 135 may be
attached to the
bottom of the traveling block 120. A top drive 140 may be suspended from the
hook 135. A
quill 145 extending from the top drive 140 may be attached to a saver sub 150,
which may be
attached to a tubular lifting device 152. The tubular lifting device 152 can
be engaged with a
drill string 155 suspended within and/or above a wellbore 160. The drill
string 155 may
include one or more interconnected sections of drill pipe 165, among other
components. It
should be understood that the use of the term "pipe" herein is merely an
exemplary type of
tubular and that various other types of tubulars (e.g., casing) can often be
substituted
depending on the desired operation. One or more pumps 180 may deliver drilling
fluid to the
drill string 155 through a hose or other conduit 185, which may be connected
to the top drive
140 and also through other components for managed pressure drilling
operations. The
drilling fluid may pass through a central passage of the tubular lifting
device 152. In an
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alternative embodiment, the top drive 140, quill 145 and sub 150 may not be
utilized between
the hook 125 and the tubular lifting device 152, such as where the tubular
lifting device 152
is coupled directly to the hook 125, or where the tubular lifting device 152
is coupled to the
hook 125 via other components.
In several exemplary embodiments, one or more of the operational parameters of
the
apparatus 100 may be monitored at the step 38, and one or more of the
foregoing operations
of the apparatus 100 may be automatically controlled at the step 44 of the
method 34. In
several exemplary embodiments, the report automatically generated at the step
46, as well as
automatically transmitted at the step 48, may include data corresponding to
actual conditions
of the apparatus 100 and its various operational states, or at least a portion
of the apparatus
100 and its operational state.
Referring to FIG. 5, an exemplary node 200 for implementing one or more
embodiments of one or more of the above-described apparatus, elements, methods
and/or
steps, and/or any combination thereof, is depicted. The node 200 includes a
microprocessor
200a, an input device 200b, a storage device 200c, a video controller 200d, a
system memory
200e, a display 200f, and a communication device 200g, all of which are
interconnected by
one or more buses 200h. In several exemplary embodiments, the storage device
200c may
include a floppy drive, hard drive, CD-ROM, optical drive, any other form of
storage device
and/or any combination thereof. In several exemplary embodiments, the storage
device 200c
may include, and/or be capable of receiving, a floppy disk, CD-ROM, DVD-ROM,
or any
other form of computer-readable medium that may contain executable
instructions. In
several exemplary embodiments, the communication device 200g may include a
modem,
network card, or any other device to enable the node to communicate with other
nodes. In
several exemplary embodiments, any node represents a plurality of
interconnected (whether
by intranet or Internet) computer systems, including without limitation,
personal computers,
mainframes, PDAs, smartphones and cell phones.
In several exemplary embodiments, one or more of the components of the
apparatus
10, the rig monitoring system 11, the drilling rig site 12, the apparatus 100,
or any
combination thereof, include at least the node 200 and/or components thereof,
and/or one or
more nodes that are substantially similar to the node 200 and/or components
thereof. In
several exemplary embodiments, one or more of the above-described components
of the node
200 and/or the apparatus 10, the rig monitoring system 11, the drilling rig
site 12, or the
apparatus 100 include respective pluralities of same components.
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In several exemplary embodiments, a computer system typically includes at
least
hardware capable of executing machine readable instructions, as well as the
software for
executing acts (typically machine-readable instructions) that produce a
desired result. In
several exemplary embodiments, a computer system may include hybrids of
hardware and
software, as well as computer sub-systems.
In several exemplary embodiments, hardware generally includes at least
processor-
capable platforms, such as client-machines (also known as personal computers
or servers),
and hand-held processing devices (such as smart phones, tablet computers,
personal digital
assistants (PDAs), or personal computing devices (PCDs), for example). In
several exemplary
embodiments, hardware may include any physical device that is capable of
storing machine-
readable instructions, such as memory or other data storage devices. In
several exemplary
embodiments, other forms of hardware include hardware sub-systems, including
transfer
devices such as modems, modem cards, ports, and port cards, for example.
In several exemplary embodiments, software includes any machine code stored in
any
memory medium, such as RAM or ROM, and machine code stored on other devices
(such as
floppy disks, flash memory, or a CD ROM, for example). In several exemplary
embodiments, software may include source or object code. In several exemplary
embodiments, software encompasses any set of instructions capable of being
executed on a
node such as, for example, on a client machine or server.
In several exemplary embodiments, combinations of software and hardware could
also be used for providing enhanced functionality and performance for certain
embodiments
of the present disclosure. In an exemplary embodiment, software functions may
be directly
manufactured into a silicon chip. Accordingly, it should be understood that
combinations of
hardware and software are also included within the definition of a computer
system and are
thus envisioned by the present disclosure as possible equivalent structures
and equivalent
methods.
In several exemplary embodiments, computer readable mediums include, for
example,
passive data storage, such as a random access memory (RAM) as well as semi-
permanent
data storage such as a compact disk read only memory (CD-ROM). One or more
exemplary
embodiments of the present disclosure may be embodied in the RAM of a computer
to
transform a standard computer into a new specific computing machine. In
several exemplary
embodiments, data structures are defined organizations of data that may enable
an
embodiment of the present disclosure. In an exemplary embodiment, a data
structure may
provide an organization of data, or an organization of executable code.
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In several exemplary embodiments, any networks and/or one or more portions
thereof
may be designed to work on any specific architecture. In an exemplary
embodiment, one or
more portions of any networks may be executed on a single computer, local area
networks,
client-server networks, wide area networks, intemets, hand-held and other
portable and
wireless devices and networks.
In several exemplary embodiments, a database may be any standard or
proprietary
database software, such as Oracle, Microsoft Access, SyBase, or DBase II, for
example. In
several exemplary embodiments, the database may have fields, records, data,
and other
database elements that may be associated through database specific software.
In several
exemplary embodiments, data may be mapped. In several exemplary embodiments,
mapping
is the process of associating one data entry with another data entry. In an
exemplary
embodiment, the data contained in the location of a character file can be
mapped to a field in
a second table. In several exemplary embodiments, the physical location of the
database is
not limiting, and the database may be distributed. In an exemplary embodiment,
the database
may exist remotely from the server, and run on a separate platform. In an
exemplary
embodiment, the database may be accessible across the Internet. In several
exemplary
embodiments, more than one database may be implemented.
In several exemplary embodiments, a plurality of instructions stored on a
computer
readable medium may be executed by one or more processors to cause the one or
more
processors to carry out or implement in whole or in part the above-described
operation of
each of the above-described exemplary embodiments of the apparatus 10, the rig
monitoring
system 11, the drilling rig site 12, the apparatus 100, the method 34, and/or
any combination
thereof. In several exemplary embodiments, such a processor may include one or
more of the
microprocessor 200a, the computer processor 14, any processor(s) that are part
of the
components of the apparatus 10 or 100, and/or any combination thereof, and
such a computer
readable medium may be distributed among one or more components of the
apparatus 10, the
rig monitoring system 11, the drilling rig site 12, the apparatus 100, and/or
any combination
thereof. In several exemplary embodiments, such a processor may execute the
plurality of
instructions in connection with a virtual computer system. In
several exemplary
embodiments, such a plurality of instructions may communicate directly with
the one or more
processors, and/or may interact with one or more operating systems,
middleware, firmware,
other applications, and/or any combination thereof, to cause the one or more
processors to
execute the instructions.
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In view of all of the above and the figures, one of ordinary skill in the art
will readily
recognize that the present disclosure introduces a method that includes
generating, using a
computer system, a pre-defined custom profile that specifies a potential
condition of a drilling
rig site; monitoring, using the computer system, one or more operational
parameters at the
drilling rig site to determine an actual condition of the drilling rig site;
detecting, using the
computer system, that the actual condition of the drilling rig site matches
the potential
condition of the drilling rig site specified by the pre-defined custom
profile; and dynamically
responding to the detection of the matching conditions, wherein the dynamic
response
includes one or more of the following: automatically controlling, using the
computer system,
one or more operations at the drilling rig site based on the actual condition
of the drilling rig
site; and automatically generating, using the computer system, a report that
includes data
corresponding to the actual condition at the drilling rig site. According to
one aspect, the pre-
defined custom profile specifies at least one of the following: one or more
downhole tool
parameters; and one or more wellsite information transfer specification (WITS)
parameters.
According to another aspect, the pre-defined custom profile specifies that the
one or more
downhole tool parameters must be met under at least one pre-defined derivative
constraint.
According to yet another aspect, the pre-defined custom profile specifies that
the one or more
WITS parameters must be met under at least one pre-defined derivative
constraint.
According to still yet another aspect, the dynamic response includes the step
of automatically
generating, using the computer system, the report that includes the data
corresponding to the
actual condition at the drilling rig site, wherein the dynamic response
further includes
automatically transmitting, using the computer system, the report to one or
more pre-
determined locations. According to still yet another aspect, the pre-defined
custom profile
specifies at least one of the one or more pre-determined locations. According
to still yet
another aspect, the dynamic response includes the step of automatically
generating, using the
computer system, the report that includes the data corresponding to the actual
condition at the
drilling rig site, and wherein the data corresponding to the actual condition
at the drilling rig
site include at least one of measurement-while-drilling (MWD) data and logging-
while-
drilling (LWD) data. According to still yet another aspect, the dynamic
response includes the
step of automatically generating, using the computer system, the report that
includes the data
corresponding to the actual condition at the drilling rig site, and wherein
the pre-defined
custom profile specifies at least a depth-drilled interval parameter and a
time-drilled interval
parameter so that the report is automatically generated when a wellbore at the
drilling rig site
has been drilled by a depth amount, or has been drilled for an amount of time,
or both.
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According to still yet another aspect, the pre-defined custom profile
specifies at least one of
the following: a depth target parameter; a tripping condition parameter; and
an end-of-day
summary parameter. According to still yet another aspect, the dynamic response
includes the
step of automatically controlling, using the computer system, one or more
operations at the
drilling rig site based on the actual condition of the drilling rig site, and
wherein the one or
more operations controlled at the drilling rig site include one or more of the
following:
MWD operations; LWD operations; geo steering operations; tubular handling
operations;
drilling operations; tubular make-up operations; and tubular break-out
operations.
The present disclosure also introduces an apparatus that includes a non-
transitory
computer readable medium; and a plurality of instructions stored on the
computer readable
medium and executable by one or more processors, the plurality of instructions
including
instructions that cause the one or more processors to generate a pre-defined
custom profile
that specifies a potential condition of a drilling rig site; instructions that
cause the one or
more processors to monitor one or more operational parameters at the drilling
rig site to
determine an actual condition of the drilling rig site; instructions that
cause the one or more
processors to detect that the actual condition of the drilling rig site
matches the potential
condition of the drilling rig site specified by the pre-defined custom
profile; and instructions
that cause the one or more processors to dynamically respond to the detection
of the matching
conditions, wherein the dynamic response instructions include one or more of
the following:
instructions that cause the one or more processors to automatically control
one or more
operations at the drilling rig site based on the actual condition of the
drilling rig site; and
instructions that cause the one or more processors to automatically generate a
report that
includes data corresponding to the actual condition at the drilling rig site.
According to one
aspect, the pre-defined custom profile specifies at least one of the
following: one or more
downhole tool parameters; and one or more wellsite information transfer
specification
(WITS) parameters. According to another aspect, the pre-defined custom profile
specifies
that the one or more downhole tool parameters must be met under at least one
pre-defined
derivative constraint. According to yet another aspect, the pre-defined custom
profile
specifies that the one or more WITS parameters must be met under at least one
pre-defined
derivative constraint. According to still yet another aspect, the dynamic
response instructions
include the instructions that cause the one or more processors to
automatically generate the
report that includes the data corresponding to the actual condition at the
drilling rig site, and
wherein the dynamic response instructions further include instructions that
cause the one or
more processors to automatically transmit the report to one or more pre-
determined locations.
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According to still yet another aspect, the pre-defined custom profile
specifies at least one of
the one or more pre-determined locations. According to still yet another
aspect, the dynamic
response instructions include the instructions that cause the one or more
processors to
automatically generate the report that includes the data corresponding to the
actual condition
at the drilling rig site, and wherein the data corresponding to the actual
condition at the
drilling rig site include at least one of measurement-while-drilling (MWD)
data and logging-
while-drilling (LWD) data. According to still yet another aspect, wherein the
dynamic
response instructions include the instructions that cause the one or more
processors to
automatically generate the report that includes the data corresponding to the
actual condition
at the drilling rig site, and wherein the pre-defined custom profile specifies
at least a depth-
drilled interval parameter and a time-drilled interval parameter so that the
report is
automatically generated when a wellbore at the drilling rig site has been
drilled by a depth
amount, or has been drilled for an amount of time, or both. According to still
yet another
aspect, the pre-defined custom profile specifies at least one of the
following: a depth target
parameter; a tripping condition parameter; and an end-of-day summary
parameter.
According to still yet another aspect, the dynamic response instructions
include the
instructions that cause the one or more processors to automatically control
the one or more
operations at the drilling rig site based on the actual condition of the
drilling rig site, and
wherein the one or more operations controlled at the drilling rig site include
one or more of
the following: MWD operations; LWD operations; geosteering operations; tubular
handling
operations; drilling operations; tubular make-up operations; and tubular break-
out operations.
The present disclosure also introduces a method that includes generating,
using a
computer system, a pre-defined custom profile that specifies a potential
condition of a drilling
rig site, wherein the pre-defined custom profile specifies at least one of the
following: one or
more downhole tool parameters; and one or more wellsite information transfer
specification
(WITS) parameters; monitoring, using the computer system, one or more
operational
parameters at the drilling rig site to determine an actual condition of the
drilling rig site;
detecting, using the computer system, that the actual condition of the
drilling rig site matches
the potential condition of the drilling rig site specified by the pre-defined
custom profile; and
dynamically responding to the detection of the matching conditions, wherein
the dynamic
response includes automatically generating, using the computer system, a
report that includes
data corresponding to the actual condition at the drilling rig site, wherein
the data
corresponding to the actual condition at the drilling rig site include at
least one of
measurement-while-drilling (MWD) data and logging-while-drilling (LWD) data;
and
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automatically transmitting, using the computer system, the report to one or
more pre-
determined locations. According to one aspect, the dynamic response further
includes
automatically controlling, using the computer system, one or more operations
at the drilling
rig site based on the actual condition of the drilling rig site, the one or
more operations
including at least one of MWD operations and LWD operations.
The present disclosure also introduces an apparatus according to one or more
aspects
of the present disclosure.
The present disclosure also introduces a method including at least one step
according
to one or more aspects of the present disclosure.
The present disclosure also introduces a system including at least one
component
having at least one character according to one or more aspects of the present
disclosure.
The present disclosure also introduces a kit including at least one component
having
at least one character according to one or more aspects of the present
disclosure.
In several exemplary embodiments, in addition to the oil and gas industry, the
exemplary embodiments described above, and/or one or more aspects of the
present
disclosure, may be readily applied to any industry in which critical,
important, or relevant
data must be communicated to pertinent individuals who require such
information to make
informed decisions in the most efficient, timely manner possible; such
industries include, for
example, the medical industry in which health care professionals could be
informed of drastic
changes in a patient's health in real time or near real time, rather than
risking delays by being
informed through traditional communication channels.
The foregoing outlines features of several embodiments so that a person of
ordinary
skill in the art may better understand the aspects of the present disclosure.
Such features may
be replaced by any one of numerous equivalent alternatives, only some of which
are
disclosed herein. One of ordinary skill in the art should appreciate that they
may readily use
the present disclosure as a basis for designing or modifying other processes
and structures for
carrying out the same purposes and/or achieving the same advantages of the
embodiments
introduced herein. One of ordinary skill in the art should also realize that
such equivalent
constructions do not depart from the spirit and scope of the present
disclosure, and that they
may make various changes, substitutions and alterations herein without
departing from the
spirit and scope of the present disclosure.
The Abstract at the end of this disclosure is provided to allow the reader to
quickly
ascertain the nature of the technical disclosure. It is submitted with the
understanding that it
will not be used to interpret or limit the scope or meaning of the claims.
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