BACKGROUND
[0001] This disclosure relates generally to methods and apparatus for automating drilling
processes. More specifically, this disclosure relates to methods and apparatus for
automating drilling processes utilizing input data from an external surface drilling
rig interface with drilling machinery from a third party source as well as interacting
with third party information downhole to facilitate a single closed loop control of
a plurality of drilling parameters within the drilling system using a networked control
system that can be customized based on the equipment being utilized and the processes
being performed to have the user drive all the machinery drilling the well in an automated
fashion with the users downhole sensing devices.
[0002] To recover hydrocarbons from subterranean formations, wells are generally constructed
by drilling into the formation using a rotating drill bit attached to a drill string.
A fluid, commonly known as drilling mud, is circulated down through the drill string
to lubricate the drill bit and carry cuttings out of the well as the fluid returns
to the surface. The particular methods and equipment used to construct a particular
well can vary extensively based on the environment and formation in which the well
is being drilled. Many different types of equipment and systems are used in the construction
of wells including, but not limited to, rotating equipment for rotating the drill
bit, hoisting equipment for lifting the drill string, pipe handling systems for handling
tubulars used in construction of the well, including the pipe that makes up the drill
string, pressure control equipment for controlling wellbore pressure, mud pumps and
mud cleaning equipment for handling the drilling mud, directional drilling systems,
and various downhole tools.
[0003] The overall efficiency of constructing a well generally depends on all of these systems
operating together efficiently and in concert with the requirements in the well to
effectively drill any given formation. One issue faced in the construction of wells
is that maximizing the efficiency of one system can have undesirable effects on other
systems. For example, increasing the weight acting on the drill bit, known as weight
on bit (WOB), can often result in an increased rate of penetration (ROP) and faster
drilling but can also decrease the life of the drill bit, which can increase drilling
time due to having to more frequently replace the drill bit. Therefore, the performance
of each system being used in constructing a well must be considered as part of the
entire system in order to safely and efficiently construct the well.
[0004] Many conventional automated drilling systems are "closed loop" systems that attempt
to improve the drilling process by sensing a limited number of conditions and adjusting
system performance, manually or automatically, based upon the sensed conditions. Often
these closed loop systems don't have the ability to monitor or consider the performance
of all of the other systems being used or adjust the performance of multiple systems
simultaneously. It is therefore left to human intervention to ensure that the entire
system operates efficiently/satisfactorily.
[0005] Relying on human intervention can become complicated due to the fact that multiple
parties are often involved in well construction. For example, constructing a single
well will often involve the owner of the well, a drilling contractor tasked with drilling
well, and a multitude of other companies that provide specialized tools and services
for the construction of the well. Because of the significant coordination and cooperation
that is required to integrate multiple systems from multiple companies, significant
human intervention is required for efficient operation. Integrating multiple systems
and companies becomes increasingly problematic as drilling processes advance in complexity.
WO2010/101473 discloses a system which operates by automatically determining safe operating limits.
[0006] WO2010/101473 discloses a method of imposing a safeguard during well drilling, wherein performance
process control parameters are controlled through machine controllers, a driller drilling
the well by controlling said process control parameters through said machine controllers
with driller instructions, and wherein process values are measured and input to a
safeguard calculation unit which then calculates safeguard limits for process control
parameters, derived from process limits, such that at least some of said safeguard
limits constitute boundary values of performance process parameter related safeguard
envelopes, characterized in restricting controller output to remain within said safeguard
envelopes, as said controllers are adapted to keep said controller output within said
safeguard envelopes, thereby preventing driller instructions from resulting in performance
process parameters beyond said safeguard envelopes; wherein said safeguard calculation
unit comprises continuously calibrated drilling process models which enable calculation
of safeguard limits for said performance process control parameters, the calculation
being based on at least one of wellbore pressure limits, wellbore stability limits
and mechanical tubing limits as constraints, as well as current process values, and
wherein said safeguard calculations are performed by iterative calculations until
the safeguard limits converge.
[0007] Thus, there is a continuing need in the art for methods and apparatus for automating
drilling processes that overcome these and other limitations of the prior art.
BRIEF SUMMARY OF THE DISCLOSURE
[0008] One embodiment of the disclosure provides a drilling system having a drilling parameter
sensor in communication with a sensor application that generates processed data from
raw data that is received from the drilling parameter sensor. A process application
is in communication with the sensor application and generates an instruction based
on the processed data. A priority controller is in communication with the process
application and evaluates the instruction for release to an equipment controller that
then issues the instruction to one or more drilling components.
[0009] According to a first aspect of the present invention therefore there is provided
a drilling system comprising:
a plurality of drilling parameter sensors;
a plurality of sensor applications in communication with the drilling parameter sensors
and
operable to generate processed data from raw data received from the drilling parameter
sensors;
a priority controller operable to evaluate and selectively release the operating instructions;
and
an equipment controller in communication with the priority controller and operable
to receive operating instructions from the priority controller and issue the instructions
to one or more drilling components when the instruction is released by the priority
controller (30) and characterized by a plurality of process applications in communication
with the sensor applications and operable to generate operating instructions based
on the processed data generated by the sensor applications,
the priority controller being operable to evaluate a plurality of instructions issued
by the plurality of process applications.
According to a second aspect of the invention there is provided a method of controlling
a drilling process comprising:
collecting data using a plurality of drilling parameter sensors;
transmitting the data to a control system including a plurality of sensor applications
and process applications;
processing the data using the sensor application to provide a representation of a
drilling parameter;
generating an instruction by analyzing the representation of a drilling condition
using the process applications;
evaluating the instruction with a priority controller to determine if the instruction
can be released; and
transmitting the instruction to one or more drilling components when the instruction
is released by the priority controller and characterized by
a plurality of process applications in communication with the sensor applications
and operable to generate operating instructions based on the processed data generated
by the sensor applications, the priority controller being operable to evaluate a plurality
of instructions issued by the plurality of process applications.
BRIEF DESCRIPTION OF THE DRAWINGS
[0010] For a more detailed description of the embodiments of the present disclosure, reference
will now be made to the accompanying drawings.
Figure 1 is a simplified diagram of an automatic drilling system.
Figure 2 is a simplified schematic diagram of a drill string used as part of an automatic
drilling system.
Figure 3 is a simplified diagram of a control system for an automatic drilling system.
DETAILED DESCRIPTION
[0011] It is to be understood that the following disclosure describes several exemplary
embodiments for implementing different features, structures, or functions of the invention.
Exemplary embodiments of components, arrangements, and configurations are described
below to simplify the present disclosure; however, these exemplary embodiments are
provided merely as examples and are not intended to limit the scope of the invention.
Additionally, the present disclosure may repeat reference numerals and/or letters
in the various exemplary embodiments and across the Figures provided herein. This
repetition is for the purpose of simplicity and clarity and does not in itself dictate
a relationship between the various exemplary embodiments and/or configurations discussed
in the various Figures. 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. Finally, the
exemplary embodiments presented below may be combined in any combination of ways,
i.e., any element from one exemplary embodiment may be used in any other exemplary
embodiment, without departing from the scope of the disclosure.
[0012] Additionally, certain terms are used throughout the following description and claims
to refer to particular components. As one skilled in the art will appreciate, various
entities may refer to the same component by different names, and as such, the naming
convention for the elements described herein is not intended to limit the scope of
the invention, unless otherwise specifically defined herein. Further, the naming convention
used herein is not intended to distinguish between components that differ in name
but not function. Additionally, in the following discussion and in the claims, the
terms "including" and "comprising" are used in an open-ended fashion, and thus should
be interpreted to mean "including, but not limited to." All numerical values in this
disclosure may be exact or approximate values unless otherwise specifically stated.
Accordingly, various embodiments of the disclosure may deviate from the numbers, values,
and ranges disclosed herein without departing from the intended scope. Furthermore,
as it is used in the claims or specification, the term "or" is intended to encompass
both exclusive and inclusive cases, i.e., "A or B" is intended to be synonymous with
"at least one of A and B," unless otherwise expressly specified herein. For the purposes
of this application, the term "real-time" means without significant delay.
[0013] Referring initially to Figure 1, automated drilling system 10 can include a drilling
parameter sensor 12 that is in bidirectional communication with a control system 14
via a highspeed communication system 16 that can be capable of real-time, or near
real-time communication. The drilling parameter sensor 12 can be any sensor operable
to sense at least one drilling parameter and provide raw data regarding the drilling
parameter to the control system 14. The drilling parameter sensor 12 may also be configured
to receive operating instructions from the control system 14.
[0014] The drilling parameter sensor 12 can be mounted to any location necessary to sense
the drilling parameter being monitored. For example, drilling parameter sensor 12
may be a downhole sensor or a rig-mounted sensor. A downhole drilling parameter sensor
12 may be disposed at the bottom hole assembly (BHA) or at any location along a drillstring
and may include sensors for measuring downhole drilling parameters including, but
not limited to, WOB, torque, revolutions per minute (RPM), temperature, vibration,
acceleration, pressure, formation characterization, borehole condition, and drilling
fluid condition. A rig-mounted drilling parameter sensor 12 may be configured to monitor
a component of the drilling system, including, but not limited to, top drives, draw
works, pipe handling equipment, pressure control equipment, mud cleaning equipment,
pumps, blow out preventers, iron roughnecks, pipe rackers, centrifuges, shakers, heave
compensators, dynamic positioning systems, accumulators, and valves, to measure one
or more drilling parameters including, but not limited to, WOB, torque, revolutions
per minute (RPM), temperature, vibration, acceleration, and pressure.
[0015] The control system 14 can also be in bidirectional communication with the drilling
components 18 via a networked (wired or wireless is not specifically relevant) communication
system. The control system 14 can provide operating instructions to the drilling components
18 in response to drilling parameters sensed by the drilling parameter sensors 12.
The drilling components 18 can include, but are not limited to, top drives, draw works,
pipe handling equipment, pressure control equipment, mud cleaning equipment, pumps,
blow out preventers, iron roughnecks, pipe rackers, centrifuges, shakers, heave compensators,
dynamic positioning systems, accumulators, and valves. The drilling components 18
can include one or more sensors that can monitor the performance of the equipment
and provide feedback of the performance of the equipment to the control system 14.
[0016] The sensor application 22 and process application 24 can be in bidirectional communication
with the control system 14. The sensor application 22 and the process application
24 are operable to work with the control system 14 to process data received from the
drilling parameter sensor 12, and other sensors, and provide operating instructions
to one or more drilling component 18. In this manner, automated drilling system 10
allows the drilling process to be controlled and executed as well as adjusted and
adapted using verification or command data collected by the drilling parameter sensor
12 or third party system.
[0017] In operation, the raw data collected by the drilling parameter sensor 12 is relayed
by the communication system 16 to the control system 14. This data then enters the
control system 14 where it is prioritized and distributed to one or more sensor applications
22. The data from a single drilling parameter sensor 12 may be provided to one or
more sensor applications 22. Likewise, a single sensor application 22 may receive
data from one or more drilling parameter sensors 12. The sensor application 22 can
process the data received by the drilling parameter sensor 12, or by other sensors,
and communicate the processed data back to the control system 14.
[0018] The control system 14 prioritizes and distributes the processed data to one or more
process applications 24. The processed data can be received by one or more process
applications 24 that can generate an instruction to modify an operating parameter
of one or more drilling components 18. The process applications 24 receive data, including,
but not limited to, data processed by the sensor applications 22, and analyze that
data in order to evaluate the performance of the drilling components and issue instructions
to modify the operating parameters of one or more drilling components 18 as needed.
For example, a process application 24 can be configured to provide instructions to
the drilling components 18 to manage surface WOB, torque, and RPM in response to downhole
WOB, downhole torque and downhole vibration data collected by the drilling parameter
sensor 12. Other process applications 24 can include, but are not limited to applications
for managing control hole cleaning, equivalent circulating density (ECD) management,
managed pressure drilling (MPD), kick detection, directional drilling, and drilling
efficiency.
[0019] The control station 20 can be in bidirectional communication with the control system
14 and provide a user interface that can be accessed by an operator on the rig or
in a remote location. The control station 20 provides a location for providing manual
input to the control system 14 and for manual override of the control system 14 if
needed. The control station 20 can provide visual representation of the operation
of the system including the status of one or more drilling components 18 and a real-time
representation of data received from the drilling parameter sensors 12.
[0020] Automated drilling system 10 provides a customizable, open concept control system
where customized sensor applications 22 and/or process applications 24 allow the drilling
process to be tailored to meet the specific needs of drilling contractors and rig
operators. Automated drilling system 10 allows a plurality of sensor applications
22 and/or process applications 24 to be developed and selectively integrated into
the control system 14 as needed. This enables the automated drilling system 10 to
be easily adapted for a variety of implementations.
[0021] Referring now to Figure 2, an exemplary BHA 40 can include a bit 42, a drive system
44, a sensor module 46, and a communication sub 48. The BHA 40 can be coupled to the
rotating system, 52, or other surface equipment, via drill pipe 50. The bit 42, the
drive system 44, the sensor module 46, and the drill pipe 50 can each include one
or more drilling parameter sensors 12 to measure a selected drilling parameter, including,
but not limited to, WOB, torque, RPM, temperature, vibration, acceleration, and pressure.
[0022] The drilling parameter sensors 12 can be in bidirectional communication with the
communication sub 48 via a wired or wireless connection. The communication sub 48
can be operable to receive data collected from each of the drilling parameter sensors
12 and transmit the data to the surface via communication system 16. The communications
sub 48 can also be operable to receive control signals and other signals from the
surface and relay those signals to one or more sensors 12 or other tools within the
BHA 40.
[0023] The communication system 16 can be any system suitable for the transmission of data
and other signals between the BHA 40 to the surface at relatively high rates of speed.
In certain embodiments, the communication system 16 supports continuous, real-time
communication between the BHA 40 and the surface. Suitable communication systems 16
can utilize communication methods that include, but are not limited to, electric signals
along wired drill pipe, mud-pulse telemetry, fiber optics, wireless signals, acoustic
signals, and electromagnetic signals.
[0024] The data transmitted from the BHA 40 can be received at the surface by surface communications
link 54. The surface communications link 54 may be integrated into a component such
as a swivel, internal blow out preventer (IBOP), or into an instrumented saver sub
coupled to the drill string. The surface communications link 54 can be configured
to transmit data to the communication controller 56 via a wired or wireless link 58.
The communication controller 56 can be coupled to the control system 14 and operable
to manage the flow of data between the control system 14 and the surface communications
link 54. The communications controller 56 can also be in bidirectional communication
with other sensors located at the surface, including sensors mounted on drilling components
18.
[0025] Referring now to Figure 3, the control system 14 can include an internal communication
bus 26, a network interface 28, a priority controller 30, data storage 32, a simulator
interface 34, and a hardware controller 36. The internal communication bus 26 can
also be in bidirectional communication with one or more sensor applications 22, one
or more process applications 24, a control station 20, and communication controller
56. The network interface 28 can also be in bidirectional communication with external
sources and users of information so that drilling operations and rig performance can
be remotely monitored and controlled.
[0026] In operation, raw data from drilling parameter sensors 12, and other sources, is
received by internal communication bus 26 via communication controller 56. The internal
communication bus 26 sends the data to the network interface 28. The network interface
28 receives raw data from the plurality of drilling parameter sensors 12, other sensors,
and from external sources, such as offsite engineering or technical experts. The network
interface 28 categorizes and sorts this data and then distributes the data back through
the internal communication bus 26 to the sensor applications 22 and/or process applications
24 that can process that data.
[0027] In order to provide flexibility and support the use of the control system 14 with
a variety of drilling and completion operations, the control system 14 can be configured
with customized sensor applications 22 and process applications 24 as needed for the
particular operation. This allows control system 14 to be easily customized for use
with specific drilling parameter sensors and the equipment available on a specific
rig. If the rig equipment or drilling parameter sensors are changed, the corresponding
applications on the control system 14 can also be changed without having to reprogram
the entire control system.
[0028] The sensor application 22 can be operable to receive raw data from one or more drilling
parameter sensors 12, or other sensors, and generate processed data. The sensor application
22 can be operable to generate processed data representing downhole conditions including,
but not limited to, WOB, torque, RPM, temperature, vibration, acceleration, and pressure.
The processed data is then transmitted by internal communication bus 26 to the process
applications 24 that can utilize the processed data to generate an instruction.
[0029] The processed data can be received by one or more process applications 24 that can
generate an instruction that may modify an operating parameter of one or more drilling
components 18, display a status of the drilling operation, or cause another function
to be performed. The process applications 24 receive data, including, but not limited
to, data processed by the sensor applications 22, and analyze that data in order to
evaluate the performance of the drilling components and issue instructions to modify
the operating parameters of one or more drilling components 18 as needed. For example,
a process application 24 can be configured to provide instructions to the drilling
components 18 to manage surface WOB, torque, and RPM in response to downhole WOB,
downhole torque and downhole vibration data collected by a drilling parameter sensor
12. Other process applications 24 can include, but are not limited to applications
for managing control hole cleaning, equivalent circulating density (ECD) management,
managed pressure drilling (MPD), kick detection, directional drilling, and drilling
efficiency.
[0030] Multiple sensor applications 22 and process applications 24 can simultaneously be
in bidirectional communication with the control system 14. As described above, the
sensor applications 22 and/or the process applications 24 can analyze and/or process
collected data to generate an answer, which can include an instruction, measurement,
operating condition, data point, or other information. Instructions generated by the
process applications are then transmitted to the priority controller 30.
[0031] The priority controller 30 monitors the performance of the entire drilling process
and determines if the instructions generated by the process applications 24 can be
implemented. For example, if a process application 24 generates an instruction for
a drilling component to perform a certain function, the priority controller 30 determines
if that function can be safely performed. Once an instruction has been cleared by
the priority controller 30, that answer released by the priority controller 30 and
can be sent to the hardware controller 36 or other component of the control system.
The needs of the drilling operation will be given priority after the system has assessed
priority, solely as an example a priority plan could be listed as follows: (1) safety
considerations as defined by on site conditions; (2) machine limitations (could be
assessed based on work yet to be done before maintenance is to be performed and available
materials to maintain) as may be defined by equipment suppliers and supply chain;
(3) well restrictions to avoid collapse or fracture as may be defined by the geologist
and verified by defined on site personnel; (4) formation target accuracy as may be
defined by the directional driller; (5) rate of penetration as may be defined by the
company man; and (6) quality of well as may be defined by the petrophysicist.
[0032] Once the instruction has been released by the priority controller 30, it can be routed
to one or more of the hardware controller 36, simulator interface 34, data storage
32, or other system components. The hardware controller 36, which can include one
or more primary logic controllers and/or single board controllers, can provide operating
instructions to one or more drilling components 18. Data storage 32 can store both
raw and processed data as well as any instructions sent to the drilling components
18. The simulator interface 34 may receive all the instructions that hardware controller
36 sends to the drilling components 18 so that those instructions can be provided
to a drilling simulator that can replicate the instructions and predict the outcome
of the operation.
[0033] In one embodiment, a sensor application 22 can monitor one or more drilling parameter
sensors 12 to compute a mechanical specific energy (MSE) and ROP. This data can be
transmitted to a process application 24 that can vary one or more drilling parameters
including, but not limited to, surface WOB, surface torque, and mud motor pressure.
The process application 24 then can continue to receive information from the sensor
application and adjust the drilling parameters in order to optimize the drilling process
as desired by either minimizing MSE or maximizing ROP. Other sensor applications 22
can provide real time downhole measurements of downhole WOB, downhole torque, and
downhole RPM that the process application 24 can use to optimize the drilling process.
[0034] In another embodiment, a sensor application 22 can receive data from one or more
drilling parameter sensors 12 to determine downhole vibrations, oscillations, stick-slip
movement, or other dynamic movement in the drill string that can reduce the efficiency
of the drilling process. The processed data can be sent to a process application 24
that will vary drilling parameters including, but not limited to, surface RPM and
surface WOB, in order to reduce any undesired movements.
[0035] In yet another embodiment, a process application 24 may be a pump pressure management
application that utilizes processed data generated by one or more sensor applications
22 that acquire raw data from drilling parameter sensors monitoring downhole pressure,
pump pressure, annulus pressure, and other wellbore pressures. The pump pressure management
application can control the fluid pressure being pumped into the wellbore, by varying
pump pressure, and then monitor the pressure returning to the surface to evaluate
a variety of drilling conditions including, but not limited to, kick detection, hole
cleaning, wellbore stability, and other flow issues.
1. A drilling system comprising:
a plurality of drilling parameter sensors (12);
a plurality of sensor applications (22) in communication with the drilling parameter
sensors (12) and operable to generate processed data from raw data received from the
drilling parameter sensors (12);
a priority controller (30) operable to evaluate and selectively release the operating
instructions; and
an equipment controller (36) in communication with the priority controller and operable
to receive operating instructions from the priority controller and issue the instructions
to one or more drilling components when the instruction is released by the priority
controller (30) and characterized by
a plurality of process applications (24) in communication with the sensor applications
(22) and operable to generate operating instructions based on the processed data generated
by the sensor applications (22), the priority controller (30) being operable to evaluate
a plurality of instructions issued by the plurality of process applications (24).
2. The system of claim 1, further comprising a control station (20) coupled to the equipment
controller (36) and operable to display the status of one or more drilling components.
3. The system of claim 1 or claim 2, further comprising a network interface (28) operable
to control data transmission between the drilling parameter sensors (12), the process
applications (24), and the sensor applications (22).
4. The system of claim 3, further comprising data storage (32) coupled to the network
interface (28).
5. The system of any one of claims 1 to 4, further comprising a simulator interface (34)
operable to receive instructions from the priority controller.
6. The system of any one of the preceding claims and incorporating a bottom hole assembly
(BHA) (40) wherein a downhole sensor (12) is disposed at the bottom hole assembly
(40).
7. The system of any one of the previous claims and wherein the system further comprises
a bit (42), a drive system (44), a sensor module (46) and a drill pipe (50), which
can each include one or more drilling parameter sensors (12) to measure a selected
drilling parameter, including, but not limited to, weight on bit (WOB), torque, revolutions
per minute (RPM), temperature, vibration, acceleration and pressure.
8. The system of any one of the preceding claims and wherein the plurality of drilling
parameter sensors (12) comprises at least one rig mounted sensor and is configured
to monitor such equipment as top drives, draw works, pipe handling equipment, pressure
control equipment, mud cleaning equipment, pumps, blow out preventers, iron roughnecks,
pipe rackers, centrifuges, shakers, heave compensators, dynamic positioning systems,
accumulators and valves.
9. A method of controlling a drilling process comprising:
collecting data using a plurality of drilling parameter sensors (12);
transmitting the data to a control system including a plurality of sensor applications
(22) and process applications (24);
processing the data using the sensor application (22) to provide a representation
of a drilling parameter;
generating an instruction by analyzing the representation of a drilling condition
using the process applications (24);
evaluating the instruction with a priority controller (30) to determine if the instruction
can be released; and
transmitting the instruction to one or more drilling components when the instruction
is released by the priority controller (30) and characterized by
a plurality of process applications (24) in communication with the sensor applications
(22) and operable to generate operating instructions based on the processed data generated
by the sensor applications (22), the priority controller (30) being operable to evaluate
a plurality of instructions issued by the plurality of process applications (24).
10. The method of claim 9, further comprising transmitting additional data to the control
system from a network interface (28).
11. The method of claim 9 or claim 10, further comprising coupling data storage (32) to
the network interface.
12. The method of any one of claims 9 to 11 further comprising transmitting the instruction
to a simulator interface (34).
13. The method of any one of claims 9 to 12, further comprising displaying a status of
one or more drilling components on a control station (20).
14. The method of any one of claims 9 to 13 including a drilling system having a bit (42),
a drive system (44), a sensor module (46) and a drill pipe (50), wherein the plurality
of drilling parameter sensors (12) comprises a plurality of downhole sensors and at
least one rig mounted sensor; and wherein said bit (42), said drive system (44), said
sensor module (46) and said drill pipe (50) can each include one or more drilling
parameter sensors (12) to measure a selected drilling parameter, including, but not
limited to, weight on bit (WOB), torque, revolutions per minute (RPM), temperature,
vibration, acceleration and pressure and the at least one rig mounted sensor is configured
to monitor such equipment as top drives, draw works, pipe handling equipment, pressure
control equipment, mud cleaning equipment, pumps, blow out preventers, iron roughnecks,
pipe rackers, centrifuges, shakers, heave compensators, dynamic positioning systems,
accumulators and valves.
1. Bohrsystem, umfassend:
eine Vielzahl von Bohrparametersensoren (12);
eine Vielzahl von Sensoranwendungen (22), die mit den Bohrparametersensoren (12) in
Kommunikation stehen und die fähig sind, verarbeitete Daten aus Rohdaten zu erzeugen,
welche von den Bohrparametersensoren (12) empfangen werden;
ein Vorrechtssteuergerät (30), das fähig ist, die Betriebsinstruktionen zu beurteilen
und selektiv freizugeben; und
ein Ausrüstungssteuergerät (36), das mit dem Vorrechtsteuergerät in Kommunikation
steht und fähig ist, Betriebsinstruktionen von dem Vorrechtssteuergerät zu empfangen
und die Instruktionen an ein oder mehrere Bohrkomponenten auszugeben, wenn die Instruktion
von dem Vorrechtssteuergerät (30) freigegeben wird, und gekennzeichnet durch eine Vielzahl von Verfahrensanwendungen (24), die mit den Sensoranwendungen (22)
in Kommunikation stehen und die fähig sind, Betriebsinstruktionen auf Basis von den
verarbeiteten Daten, die durch die Sensoranwendungen (22) erzeugt werden, zu erzeugen,
wobei das Vorrechtsteuergerät (30) fähig ist eine Vielzahl von Instruktionen, die
von der Vielzahl von Verfahrensanwendungen (24) ausgegeben werden, zu beurteilen.
2. System nach Anspruch 1, ferner umfassend eine Steuerstation (20), die mit dem Ausrüstungssteuergerät
(36) verbunden ist und fähig ist, den Status von ein oder mehreren Bohrkomponenten
darzustellen.
3. System nach Anspruch 1 oder 2, ferner umfassend eine Netzwerkschnittstelle (28), die
fähig ist die Datenübertragung zwischen den Bohrparametersensoren (12), den Verfahrensanwendungen
(24) und den Sensoranwendungen (22) zu steuern.
4. System nach Anspruch 3, ferner umfassend einen Datenspeicher (32), der mit der Netzwerkschnittstelle
(28) verbunden ist.
5. System nach einem der Ansprüche 1 bis 4, ferner umfassend eine Simulatorschnittstelle
(34), die fähig ist, Instruktionen von dem Vorrechtsteuergerät zu empfangen.
6. System nach einem der vorhergehenden Ansprüche, das eine Bodenlochanordnung (BHA für
Englisch: bottom whole assembly) (40) umfasst, wobei ein Bohrlochsensor (12) an der
Bodenlochanordnung (40) angeordnet ist.
7. System nach einem der vorhergehenden Ansprüche, wobei das System ferner einen Bohreinsatz
(42), ein Antriebssystem (44), ein Sensormodul (46) und ein Bohrrohr (50) umfasst,
die jeweils ein oder mehrere Bohrparametersensoren (12) umfassen können, um einen
ausgewählte Bohrparameter zu messen, einschließlich von, jedoch nicht darauf beschränkt,
der Belastung an dem Boreinsatz (WOB für Englisch: weight on bit), Drehmoment, Umdrehungen
pro Minute (RPM), Temperatur, Vibration, Beschleunigung und Druck.
8. System nach einem der vorhergehenden Ansprüche, wobei die Vielzahl von Bohrparametersensoren
(12) mindestens einen an der Boranlage befestigten Sensor umfasst und konfiguriert
ist, Ausrüstung zu überwachten, wie zum Beispiel Kraftdrehköpfe, Zuganlagen, Ausrüstung
zur Handhabung von Rohren, Drucksteuerausrüstung, Schlammreinigungsausrüstung, Pumpen,
Blowout-Preventer, Gestängeverschraubungen, Rohrgestelle, Zentrifugen, Schüttler,
Seegang-Kompensatoren, dynamische Positionierungssysteme, Akkumumatoren und Ventile.
9. Verfahren zum Steuern von einem Bohrverfahren, umfassend:
Sammeln von Daten unter Verwerdung von einer Vielzahl von Bohrparametersensoren (12);
Übermitteln der Daten zu einem Steuersystem, das eine Vielzahl von Sensoranwendungen
(22) und Verfahrensanwendungen (24) umfasst;
Verarbeiten der Daten unter Verwerdung der Sensoranwendung (22), um eine Repräsentation
von einem Bohrparameter bereitzustellen;
Erzeugen von einer Instruktion durch Analysieren von der Repräsentation von einem
Bohrzustand, wobei die Verfahrensanwendungen (24) verwendet werden;
Beurteilen von der Instruktion mit einem Vorrechtsteuergerät (30), um zu bestimmen,
ob die Instruktionen freigegeben werden kann; und
Übertragen von der Instruktion zu ein oder mehreren Bohrkomponenten, wenn die Instruktion
durch das Vorrechtsteuergerät (30) freigegeben wird, und gekennzeichnet durch
eine Vielzahl von Verfahrensanwendungen (24), die mit den Sensoranwendungen (22) in
Kommunikation stehen und die fähig sind, Betriebsinstruktionen auf Basis von den verarbeiteten
Daten, die durch die Sensoranwendungen (22) erzeugt werden, zu erzeugen, wobei das
Vorrechtsteuergerät (30) fähig ist eine Vielzahl von Instruktionen, die von der Vielzahl
von Verfahrensanwendungen (24) ausgegeben werden, zu beurteilen.
10. Verfahren nach Anspruch 9, ferner umfassend das Übertragen von zusätzlichen Daten
von einer Netzwerkschnittstelle (28) zu dem Steuersystem.
11. Verfahren nach Anspruch 9 oder 10, ferner umfassend das Verbinden des Datenspeichers
(32) mit der Netzwerkschnittstelle.
12. Verfahren nach einem der Ansprüche 9 bis 11, ferner umfassend das Übertragen von der
Instruktion zu einer Simulatorschnittstelle (34).
13. Verfahren nach einem der Ansprüche 9 bis 12, ferner umfassend das Darstellen von einem
Status von ein oder mehreren Bohrkomponenten auf einer Steuerstation (20).
14. Verfahren nach einem der Ansprüche 9 bis 13, umfassend ein Rohrsystem, das einen Bohreinsatz
(42), ein Antriebssystem (44), ein Sensormodul (46) und ein Bohrrohr (50) aufweist,
wobei die Vielzahl von Bohrparametersensoren (12) eine Vielzahl von Bohrlochsensoren
und mindestens einen an der Boranlage befestigten Sensor umfasst; und wobei der Bohreinsatz
(42), das Antriebssystem (44), das Sensormodul (46) und das Bohrrohr (50) jeweils
ein oder mehrere Bohrparametersensoren (12) umfassen können, um einen ausgewählten
Bohrparameter zu messen, einschließlich von, jedoch nicht darauf beschränkt, der Belastung
an dem Boreinsatz (WOB für Englisch: weicht on bit), Drehmoment, Umdrehungen pro Minute
(RPM), Temperatur, Vibration, Beschleunigung und Druck, und der mindestens eine an
der Boranlage befestigte Sensor konfiguriert ist, Ausrüstung zu überwachten, wie zum
Beispiel Kraftdrehköpfe, Zuganlagen, Ausrüstung zur Handhabung von Rohren, Drucksteuerausrüstung,
Schlammreinigungsausrüstung, Pumpen, Blowout-Preventer, Gestängeverschraubungen, Rohrgestelle,
Zentrifugen, Schüttler, Seegang-Kompensatoren, dynamische Positionierungssysteme,
Akkumulatoren und Ventile.
1. Système de forage comprenant :
une pluralité de capteurs de paramètre de forage (12) ;
une pluralité d'applications de capteur (22) en communication avec les capteurs de
paramètre de forage (12) et exploitables pour générer des données traitées issues
de données brutes reçues des capteurs de paramètre de forage (12) ;
un régulateur de priorité (30) exploitable pour évaluer et délivrer sélectivement
les instructions d'exploitation ; et
un régulateur d'équipement (36) en communication avec le régulateur de priorité et
exploitable pour recevoir des instructions d'exploitation du régulateur de priorité
et émettre les instructions vers un ou de plusieurs composants de forage lorsque l'instruction
est délivrée par le régulateur de priorité (30) et caractérisé par
une pluralité d'applications de processus (24) en communication avec les applications
de capteur (22) et exploitables pour générer des instructions d'exploitation sur la
base des données traitées générées par les applications de capteur (22), le régulateur
de priorité (30) étant exploitable pour évaluer une pluralité d'instructions émises
par la pluralité d'applications de processus (24).
2. Système selon la revendication 1, comprenant en outre une station de régulation (20)
couplée au régulateur d'équipement (36) et exploitable pour afficher le statut d'un
ou de plusieurs composants de forage.
3. Système selon la revendication 1 ou la revendication 2, comprenant en outre une interface
réseau (28) exploitable pour réguler une transmission de données entre les capteurs
de paramètre de forage (12), les applications de processus (24) et les applications
de capteur (22).
4. Système selon la revendication 3, comprenant en outre une unité de stockage de données
(32) couplé à l'interface réseau (28).
5. Système selon l'une quelconque des revendications 1 à 4, comprenant en outre une interface
de simulateur (34) exploitable pour recevoir des instructions du régulateur de priorité.
6. Système selon l'une quelconque des revendications précédentes, et incorporant un ensemble
fond de trou (BHA) (40) dans lequel un capteur de fond de puits (12) est disposé au
niveau de l'ensemble fond de trou (40).
7. Système selon l'une quelconque des revendications précédentes, et dans lequel le système
comprend en outre un trépan (42), un système d'entraînement (44), un module de capteur
(46) et une tige de forage (50), qui peuvent chacun inclure un ou plusieurs capteurs
de paramètre de forage (12) pour mesurer un paramètre de forage sélectionné, incluant,
sans s'y limiter, le poids au trépan (WOB), le couple, les tours par minute (TR/MIN),
la température, les vibrations, l'accélération et la pression.
8. Système selon l'une quelconque des revendications précédentes, et dans lequel la pluralité
de capteurs de paramètre de forage (12) comprend au moins un capteur monté sur appareil
de forage et est configuré pour surveiller des équipements tels que des entraînements
par le haut, des treuils de forage, un équipement de manutention de tige, un équipement
de régulation de pression, un équipement de nettoyage de boue, des pompes, des blocs
obturateurs de puits, des sondeurs, des parcs à tiges, des centrifugeuses, des secoueurs,
des compensateurs de pilonnement, des systèmes de positionnement dynamique, des accumulateurs
et des vannes.
9. Procédé de régulation d'un processus de forage comprenant :
la collecte de données à l'aide d'une pluralité de capteurs de paramètre de forage
(12) ;
la transmission des données à un système de régulation incluant une pluralité d'applications
de capteur (22) et d'applications de processus (24) ;
le traitement des données à l'aide de l'application de capteur (22) pour fournir une
représentation d'un paramètre de forage ;
la génération d'une instruction par l'analyse de la représentation d'une condition
de forage à l'aide des applications de processus (24) ;
l'évaluation de l'instruction avec un régulateur de priorité (30) pour déterminer
si l'instruction peut être délivrée ; et
la transmission de l'instruction à un ou plusieurs composants de forage lorsque l'instruction
est délivrée par le régulateur de priorité (30) et caractérisé par
une pluralité d'applications de processus (24) en communication avec les applications
de capteur (22) est exploitables pour générer des instructions d'exploitation sur
la base des données traitées générées par les applications de capteur (22), le régulateur
de priorité (30) étant exploitable pour évaluer une pluralité d'instructions émises
par la pluralité d'applications de processus (24).
10. Procédé selon la revendication 9, comprenant en outre la transmission de données additionnelles
au système de régulation à partir d'une interface réseau (28).
11. Procédé selon la revendication 9 ou la revendication 10, comprenant en outre le couplage
d'une unité de stockage de données (32) à l'interface réseau.
12. Procédé selon l'une quelconque des revendications 9 à 11, comprenant en outre la transmission
de l'instruction à une interface de simulateur (34).
13. Procédé selon l'une quelconque des revendications 9 à 12, comprenant en outre l'affichage
d'un statut d'un ou de plusieurs composants de forage sur une station de régulation
(20).
14. Procédé selon l'une quelconque des revendications 9 à 13, incluant un système de forage
comportant un trépan (42), un système d'entraînement (44), un module de capteur (46)
et une tige de forage (50), dans lequel la pluralité de capteurs de paramètre de forage
(12) comprend une pluralité de capteurs en fond de puits et au moins un capteur monté
sur appareil de forage ; et dans lequel ledit trépan (42), ledit système d'entraînement
(44), ledit module de capteur (46) et ladite tige de forage (50) peuvent inclure chacun
un ou plusieurs capteurs de paramètre de forage (12) pour mesurer un paramètre de
forage sélectionné, incluant, sans s'y limiter, le poids au trépan (WOB), le couple,
les tours par minute (TR/MIN), la température, les vibrations, l'accélération et la
pression et l'au moins un capteur monté sur appareil de forage est configuré pour
surveiller des équipements tels que des entraînements par le haut, des treuils de
forage, un équipement de manutention de tige, un équipement de régulation de pression,
un équipement de nettoyage de boue, des pompes, des blocs obturateurs de puits, des
sondeurs, des parcs à tiges, des centrifugeuses, des secoueurs, des compensateurs
de pilonnement, des systèmes de positionnement dynamique, des accumulateurs et des
vannes.