U.S. patent application number 15/324128 was filed with the patent office on 2017-07-13 for coordinated control for mud circulation optimization.
This patent application is currently assigned to Halliburton Energy Services, Inc.. The applicant listed for this patent is Halliburton Energy Services, Inc.. Invention is credited to Jason D. Dykstra, Yuzhen Xue.
Application Number | 20170198554 15/324128 |
Document ID | / |
Family ID | 57757608 |
Filed Date | 2017-07-13 |
United States Patent
Application |
20170198554 |
Kind Code |
A1 |
Dykstra; Jason D. ; et
al. |
July 13, 2017 |
Coordinated Control For Mud Circulation Optimization
Abstract
Two control strategies may be implemented to optimize mud
circulation in a drilling mud circulation system. In a networked
control strategy, the mud circulation system does not involve any
centralized controller yet all the local controllers can exchange
information in real-time via a central data storage. The
master-slave control strategy involves a centralized optimizer, and
the subsystems are treated as slave systems and are driven by a
visual master control system.
Inventors: |
Dykstra; Jason D.; (Spring,
TX) ; Xue; Yuzhen; (Humble, TX) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
Halliburton Energy Services, Inc. |
Houston |
TX |
US |
|
|
Assignee: |
Halliburton Energy Services,
Inc.
Houston
TX
|
Family ID: |
57757608 |
Appl. No.: |
15/324128 |
Filed: |
July 13, 2016 |
PCT Filed: |
July 13, 2016 |
PCT NO: |
PCT/US2016/042150 |
371 Date: |
January 5, 2017 |
Related U.S. Patent Documents
|
|
|
|
|
|
Application
Number |
Filing Date |
Patent Number |
|
|
62191691 |
Jul 13, 2015 |
|
|
|
Current U.S.
Class: |
1/1 |
Current CPC
Class: |
E21B 21/062 20130101;
E21B 21/08 20130101; E21B 21/063 20130101; E21B 41/0092 20130101;
E21B 21/06 20130101 |
International
Class: |
E21B 41/00 20060101
E21B041/00; E21B 21/08 20060101 E21B021/08; E21B 21/06 20060101
E21B021/06 |
Claims
1. A method comprising: circulating a drilling mud through a mud
circulation system that includes a plurality of subsystems each
having a controller coupled thereto, wherein the plurality of
subsystems comprise one or more selected from the group consisting
of a pump, a drill pipe, a choke, a mud cleaning unit, a mud
treatment unit, and a mud tank; transferring one or more
operational parameters from each of the controllers of the
plurality of subsystems to a central data storage; a first
controller coupled to a first subsystem of the plurality of
subsystems, accessing a first operational parameter from the one or
more operational parameters from the central data storage; and the
first controller optimizing a second operational parameter related
to the first subsystem coupled thereto based on the first
operational parameter operational parameter from the central data
storage.
2. The method of claim 1, wherein the plurality of subsystems
include the pump and the first operational parameter of the pump
comprises one or more selected from the group consisting of pump
rate and rate of change of pump rate.
3. The method of claim 1, wherein the plurality of subsystems
include the drill pipe and the first operational parameter of the
drill pipe comprises one or more one selected from the group
consisting of weight on bit, rate of penetration, and revolution
per minute.
4. The method of claim 1, wherein the plurality of subsystems
include the choke and the first operational parameter of the choke
comprises one or more selected from the group consisting of bottom
hole pressure and rate of change of bottom hole pressure.
5. The method of claim 1, wherein the plurality of subsystems
include the mud cleaning unit and the first operational parameter
of the mud cleaning unit comprises one or more selected from the
group consisting of shaker operational parameters, centrifuge
operational parameters, hydrocyclone operational parameters, and
separator operational parameters.
6. The method of claim 1, wherein the plurality of subsystems
include the mud treatment unit and the first operational parameter
of the mud treatment unit comprises one or more selected from the
group consisting of mixing rate, concentration of materials added
to the mud, and rate of addition of the materials to the mud.
7. The method of claim 1, wherein the plurality of subsystems
include the mud tank and the first operational parameter of the mud
tank comprises one or more selected from the group consisting of
retention time and mixing parameters.
8. A method comprising: circulating a drilling mud through a mud
circulation system that includes a plurality of subsystems each
having a controller coupled thereto, wherein the plurality of
subsystems comprise one or more selected from the group consisting
of a pump, a drill pipe, a choke, a mud cleaning unit, a mud
treatment unit, and a mud tank; optimizing one or more operational
parameters of each of the plurality of subsystems with an
optimization function at a supervisory optimizer controller to
produce one or more optimized operational parameters for each of
the plurality of subsystems; transferring the one or more optimized
operational parameters to the controller coupled to each of the
plurality of subsystems; and operating the plurality of subsystems
based on the one or more optimized operational parameters.
9. The method of claim 8, wherein the plurality of subsystems
include the drill pipe and the operational parameter of the drill
pipe comprises one or more selected from the group consisting of
weight on bit, rate of penetration, revolution per. minute.
10. The method of claim 8, wherein the plurality of subsystems
include the choke and the operational parameter of the choke
comprises one or more selected from the group consisting of bottom
hole pressure and rate of change of bottom hole pressure.
11. The method of claim 8, wherein the plurality of subsystems
include the mud cleaning unit and the operational parameter of the
mud cleaning unit comprises one or more selected from the group
consisting of shaker operational parameters, centrifuge operational
parameters, hydrocyclone operational parameters, and separator
operational parameters.
12. The method of claim 8, wherein the plurality of subsystems
include the mud treatment unit and the operational parameter of the
mud treatment unit comprises one selected from the group consisting
of mixing rate, concentration of materials added to the mud, and
rate of addition of the materials to the mud.
13. The method of claim 8, wherein the plurality of subsystems
include the mud tank and the operational parameter of the mud tank
comprises one selected from the group consisting of retention time
and mixing parameters.
14. A mud circulation system comprising: a drill pipe within a
wellbore penetrating a subterranean formation and coupled to a
first controller; a pump configured to convey a drilling mud
through the drill string and the wellbore and coupled to a second
controller; at least one subsystem coupled to a third controller
that include one selected from the group consisting of a choke, a
mud cleaning unit, a mud treatment unit, and a mud tank; a
non-transitory computer-readable medium coupled to the drill
string, the pump, or both and encoded with instructions that, when
executed, cause the system to perform a method comprising:
circulating a drilling mud through the mud circulation system;
transferring a plurality of operational parameters from each of the
controllers to a central data storage; at least one of the
controllers accessing a first operational parameter of the
plurality of operational parameters from the central data storage;
and the at least one of the controllers optimizing a second
operational parameter based on the first operational parameter from
the central data storage.
15. The mud circulation system of claim 14, wherein the at least
one controller is coupled to the drill pipe and the operational
parameter of the drill pipe comprises one selected from the group
consisting of weight on bit, rate of penetration, and revolution
per minute.
16. The mud circulation system of claim 14, wherein the at least
one controller is coupled to the choke and the operational
parameter of the choke comprises one selected from the group
consisting of bottom hole pressure and rate of change of bottom
hole pressure.
17. The mud circulation system of claim 14, wherein the at least
one controller is coupled to the mud cleaning unit and the
operational parameter of the mud cleaning unit comprises one
selected from the group consisting of shaker operational
parameters, centrifuge operational parameters, hydrocyclone
operational parameters, and separator operational parameters.
18. The mud circulation system of claim 14, wherein the at least
one controller is coupled to the mud treatment unit and the
operational parameter of the mud treatment unit comprises one or
more selected from the group consisting of mixing rate,
concentration of materials added to the mud, and rate of addition
of the materials to the mud.
19. The mud circulation system of claim 14, wherein the at least
one controller is coupled to the mud tank and the operational
parameter of the mud tank comprises one or more selected from the
group consisting of retention time, and mixing parameters.
20. (canceled)
Description
BACKGROUND
[0001] The mud circulation systems and components that make up the
drilling mud circulation system thereof are complex and include
many subsystems such as mud pipes, solid removers (e.g., shakers),
mixers, pumps, and chokes. The mud density, viscosity, flow rate,
and pump pressure are important manipulating variables to ensure a
safe and smooth drilling process. In literature, several control
methods have been proposed for controlling the pump, shaker, and
mixer to get mud with desired quality. Mud quality refers to the
ability for the mud to retain the cutting removing efficiency and
preserve the borehole stability. Higher quality muds increase the
efficiency and efficacy of drilling operations.
[0002] In current mud circulation systems, each subsystem of the
mud circulation system has an independent controller. This
framework is referred to as "decentralized control strategy." The
obvious drawback of a decentralized control strategy is that each
controller only monitors its own performance. Simple examples show
that turning on two feedback systems, each with its own sensor and
actuator, simultaneously, can lead to disastrous loss of
performance, or even instability. This is due to the interaction of
the subsystems such that each controller will compete or even
contradict with the other subsystems/controllers and thus reduce
the overall system's performance. In the mud control, for example,
if the controller on the choke and the controller on the pump are
trying to control the flow rate/pressure independently, the choke
controller may be saturated quickly because it does not consider
the output from the pump controller. This may reduce the overall
performance of the mud pressure/flow rate adjustment or even damage
the choke.
BRIEF DESCRIPTION OF THE DRAWINGS
[0003] The following figures are included to illustrate certain
aspects of the embodiments, and should not be viewed as exclusive
embodiments. The subject matter disclosed is amenable to
considerable modifications, alterations, combinations, and
equivalents in form and function, as will occur to those skilled in
the art and having the benefit of this disclosure.
[0004] FIG. 1 illustrates an exemplary mud circulation system
suitable for implementing the methods described herein.
[0005] FIG. 2 illustrates an exemplary layout of a networked
control strategy for a mud circulation system.
[0006] FIG. 3 illustrates the cooperation of the mud subsystem
controllers in the networked control strategy.
[0007] FIG. 4 illustrates the adaption of weight used in the
networked control strategy.
[0008] FIG. 5 illustrates an exemplary layout of a master-slave
control strategy for a mud circulation system.
[0009] It should be understood, however, that the specific
embodiments given in the drawings and detailed description thereto
do not limit the disclosure. On the contrary, they provide the
foundation for one of ordinary skill to discern the alternative
forms, equivalents, and modifications that are encompassed together
with one or more of the given embodiments in the scope of the
appended claims.
DETAILED DESCRIPTION
[0010] Disclosed herein are methods and systems for enhancing
workflow performance in the oil and gas industry. More
specifically, the present application relates to optimizing mud
(also known as "drilling mud") circulation through coordinated
control schemes.
[0011] During drilling, many systems/units are coupled through the
mud flow. Each of the systems has its own controller that can
impact the mud circulation quality. If each unit is only controlled
independently without considering the other units output,
limitation, or response time, the result will be sub-optimal or it
may even damage the hardware. The coordinated control schemes of
the present disclosure may be used to derive a true optimal mud
circulation, coordinate all the units, and enable the units to
exchange information such that all the units can make their
contribution to the global optima without contradicting the other
systems.
[0012] FIG. 1 illustrates an exemplary mud circulation system (also
referred to herein as a "mud circulation system") suitable for
implementing the methods described herein. While FIG. 1 generally
depicts a land-based drilling assembly, those skilled in the art
will readily recognize that the principles described herein are
equally applicable to subsea drilling operations that employ
floating or sea-based platforms and rigs without departing from the
scope of the disclosure.
[0013] As illustrated, the drilling assembly 100 may include a
drilling platform 102 that supports a derrick 104 having a
traveling block 106 for raising and lowering a drill string 108.
The drill string 108 may include, but is not limited to, drill pipe
and coiled tubing, as generally known to those skilled in the art.
A kelly 110 supports the drill string 108 as it is lowered through
a rotary table 112. A drill bit 114 is attached to the distal end
of the drill string 108 and is driven either by a downhole motor
and/or via rotation of the drill string 108 from the well surface.
As the bit 114 rotates, it creates a borehole 116 that penetrates
various subterranean formations 118.
[0014] A pump 120 (e.g., a pump) circulates mud 122 through a feed
pipe 124 and to the kelly 110, which conveys the mud 122 downhole
through the interior of the drill string 108 and out through one or
more orifices in the drill bit 114. The mud 122 is then circulated
back to the surface via an annulus 126 defined between the drill
string 108 and the walls of the borehole 116. At the surface, the
recirculated or spent mud 122 exits the annulus 126 and may be
conveyed through chokes 136 (also referred to as a choke manifold)
to one or more mud cleaning unit(s) 128 (e.g., a shaker, a
centrifuge, a hydrocyclone, a separator (including magnetic and/or
electrical separators), a desilter, a desander, a separator, a
filter, a heat exchanger, any fluid reclamation equipment, and the
like) via an interconnecting flow line 130. After passing through
the mud cleaning unit(s) 128, a "cleaned" mud 122 is deposited into
a nearby retention pit 132 (e.g., a mud pit or mud tank). While
illustrated arranged at the outlet of the wellbore 116 via the
annulus 126, those skilled in the art will readily appreciate that
the mud cleaning unit(s) 128 may be arranged at any other location
in the drilling assembly 100 to facilitate its proper function,
without departing from the scope of the disclosure.
[0015] At the retention pit 132 (or before or after), the mud
circulation system may include mud treatment unit(s). The mud 122
may be treated to change its composition and properties. For
example, weighting agents like barite may be added to the mud 122
to increase its density. In another example, base fluid may be
added to the mud 122 to decrease its density. In the illustrated
mud circulation system 100, the addition of materials to the mud
122 may be achieved with a mixing hopper 134 communicably coupled
to or otherwise in fluid communication with the retention pit 132.
The mixing hopper 134 may include, but is not limited to, mixers
and related mixing equipment known to those skilled in the art. In
other embodiments, however, the materials may be added to the mud
122 at any other location in the drilling assembly 100. In at least
one embodiment, for example, there could be more than one retention
pit 132, such as multiple retention pits 132 in series. Moreover,
the retention pit 132 may be representative of one or more fluid
storage facilities and/or units where the materials may be stored,
reconditioned, and/or regulated until added to the mud 122.
[0016] The various components of the mud circulation system 100 may
further include one or more sensors, gauges, pumps, compressors,
and the like used store, monitor, regulate, convey, and/or
recondition the exemplary muds 122 (e.g., sensors and gauges to
measure the composition and/or pressure of the mud, compressors to
change the pressure of the mud, and the like).
[0017] While not specifically illustrated herein, the disclosed mud
circulation system 100 may include drill collars, mud motors,
downhole motors, and/or pumps associated with the drill string 108,
MWD/LWD tools and related telemetry equipment, sensors or
distributed sensors associated with the drill string 108, downhole
heat exchangers, valves and corresponding actuation devices, tool
seals, packers and other wellbore isolation devices or components,
and the like. The mud circulation system 100 may further include
control systems (e.g., the controllers and control systems
described further herein) that are capable of executing the
mathematical algorithms, methods, and mud circulation system
control described herein. The mud circulation system 100 may also
further include a control system 138 communicably coupled to
various components of the mud circulation system 100 (e.g., the
mixer 134, a downhole motor, the pump 120, sensors, and the like)
and be capable of executing the mathematical algorithms, methods,
and mud circulation system control described herein.
[0018] The methods described herein use coordinated control schemes
to manage the drilling mud circulation system and optimize,
maintain, or enhance the mud quality. In this disclosure, two
coordinated control schemes are proposed to improve the mud
circulation efficiency.
[0019] The first coordinated control scheme described herein is a
"networked control strategy." In the proposed framework, the mud
circulation system has physically distributed processing power and
networked (wired/wireless) communication. Each subsystem (e.g., the
shaker, mixer, pump, choke, and the like) has its own local
controller and computation power.
[0020] No supervisory controller is adopted in the networked
control strategy so that all the local controllers can calculate
its best control input in their own time scale and in parallel
(thus it provides high efficiency). This scheme naturally matches
the physically distributed mud subsystems and satisfies the hard
constraints of each subsystem. Moreover, it has high fault
tolerance such that the failure of one subsystem may not be fatal
to the overall performance.
[0021] Each local controller calculates its control input to drive
the overall cost function to optimal, based on all the subsystems'
states and control inputs (obtained via communication). The
networked control strategy has shown success in chemical plant
control where all the subsystems/local controllers are coordinated
so that the overall system's performance would converge to the
optimal.
[0022] FIG. 2 illustrates an exemplary layout of a networked
control strategy for a mud circulation system 200. The illustrated
mud circulation system 200 uses solid arrows 202 between subsystems
212-222 to illustrate mud flow direction. As illustrated, the mud
circulation system includes, in order, a pump 212 (e.g., pump 120
of FIG. 1), a choke 214 (e.g., choke 136 of FIG. 1), a drilling
control 216 (e.g., drill string 108, kelly 110, and rotary table
112) that controls the drill bit operational parameters (e.g.,
revolutions per minute, weight on bit, and rate of penetration), a
mud cleaning unit(s) 218 (e.g., mud cleaning unit(s) 128 of FIG.
1), a mud treatment unit(s) 220 (e.g., mixer 134 of FIG. 1), and a
mud tank 222 (e.g., retention pit 132 of FIG. 1) that flows back
into the pump 212. Each of the subsystems 212-222 have individual
controllers 224-234, respectively, (also referred to as local
controllers or control systems).
[0023] Each controller 224-234 of the subsystems 212-222 may
communicate (illustrated with dashed arrows 204) with a central
data storage 210. The central data storage 210 may communicated
back to the subsystems 212-222 the real-time data about one or more
of the other subsystems 212-222. The mud circulation system 200 is
modelled as a distributed/coordinated system that contains not only
the subsystems' models but also the subsystems' interaction models.
Each subsystem may include an advanced controller and state
predictor (e.g., model predictive control (MPC)) to calculate the
optimal control command and to compensate delays. The local
controllers 224-234 may be used to calculate the best local control
policies under the local constraints to try to optimize overall
objective of the mud circulation system.
[0024] The proposed networked control layout may be used for
various mud circulation control applications, for example, to
optimize the rate of penetration (ROP) of the drill bit, to
regulate the bottom hole pressure (BHP), to retain the cutting
transmission efficiency, to minimize the mud cost while drilling,
and the like. For example, operational parameters of or otherwise
related to the pump 212 (e.g., pump rate, rate of change of pump
rate, and the like, and any combination thereof) may be measured,
shared with other subsystems 214-222 via the central data storage
210, and optimized. Operational parameters of or otherwise related
to the mud circulation system 216 (e.g., weight on bit, rate of
penetration, revolution per minute, and the like, and any
combination thereof) may be measured, shared with other subsystems
212-214,218-222 via the central data storage 210, and optimized.
Operational parameters of or otherwise related to the choke 214
(e.g., BHP, rate of change of BHP, and the like, and any
combination thereof) may be measured, shared with other subsystems
212,216-222 via the central data storage 210, and optimized.
Operational parameters of or otherwise related to the mud cleaning
system 218 (e.g., shaker operational parameters, centrifuge
operational parameters, hydrocyclone operational parameters,
separator operational parameters, and the like, and any combination
thereof) may be measured, shared with other subsystems
212-216,220-222 via the central data storage 210, and optimized.
Operational parameters of or otherwise related to the mud treatment
system 220 (e.g., mixing rate, concentration of materials added to
the mud, rate of addition of the materials to the mud, and the
like, and any combination thereof) may be measured, shared with
other subsystems 212-218,222 via the central data storage 210, and
optimized. Operational parameters of or otherwise related to the
mud tank 222 (e.g., retention time, mixing parameters, and the
like, and any combination thereof) may be measured, shared with
other subsystems 212-220 via the central data storage 210, and
optimized.
[0025] For example, FIG. 3 illustrates an exemplary layout 300 of
the cooperation of the subsystem controllers 302-310 to maximize
the ROP while drilling through a narrow kick-loss pressure margin
(i.e., drilling through a portion of the formation where the
difference between the kick pressure and the fracture pressure is
small). The cost function is constructed according to Equation
1.
cost = .intg. a 1 ( ROP - ROP * ) 2 + a 2 ( P b - P kick + P loss 2
) 2 + a 3 w 2 + a 4 c 2 + a 5 q 2 Equation 1 ##EQU00001##
where P.sub.b denotes the estimated or measured BHP, the P.sub.kick
denotes the kick pressure, the P.sub.loss denotes the fracture
pressure, the w denotes the bit wear and the motor wear, the c
denotes the mud and drilling cost, the q denotes the quality
(smoothness) index of the wellbore (smaller q represents higher
wellbore quality), the a.sub.1 to a.sub.5 denote the weights, here
for a.sub.i>0 for any i. The values of weights a.sub.1 to
a.sub.5 are adaptable for different situations.
[0026] FIG. 4 illustrates the adaption of weight a.sub.2. To safely
and effectively drilling, the borehole pressure shall be within the
drilling window 400, which is defined as the pressures between the
pore pressure 402 and fracture pressure 404 of the formation. When
drilling through a narrow portion 406 of the drilling window 400 as
illustrated in the plot on the right of FIG. 4, a.sub.2 shall be
adjusted to a dominant value such that the pressure is tightly
regulated. When drilling through a wide portion 408 of the drilling
window 400, the pressure regulation may be somewhat relaxed and
thus a.sub.2 can have a relative smaller value. The coordinated
subsystem controllers 302-310 should perform determine operating
conditions for the corresponding component of the mud circulation
system so as to minimize the cost function subject to the
mechanical constraints as well as the subsystems' and the
subsystems' interaction models. These interaction models show the
coupling between the various systems. For example, a value
performance is based on the input pressure, and if fed by a pump
(e.g., pump 120 of FIG. 1), that pressure is dependent on the speed
and applied torque to the pump. Since the interaction models
describe the dynamic coupling and are included in the cost function
analysis at the local sub-system level, the model will optimize the
process across all relevant system states. Equation 2 may be used
to describe the local control calculations.
u.sub.i=argmin.sub.u.sub.i.sub..epsilon..OMEGA..sub.i cost Equation
2
where the u.sub.i denotes the i.sup.th subsystem's control law, and
the .OMEGA..sub.i denotes the input space of the i.sup.th
subsystem.
[0027] The optimal local control law calculated such that it
minimizes the overall cost function. Referring again to FIG. 3,
there are five subsystem controllers 302-310 each associated with a
subsystem, communicably coupled to a central data storage 312, and
coordinating to fulfill the optimization objective. For example,
the model executed by a first subsystem controller 302 may describe
the viscosity (state) as a function of the current mud volume, the
flow in rate, and the clay/bentonite additions (input). Then, the
first subsystem controller 302 may output an action (e.g., addition
of clay/bentonite 314) to be performed by a first mud treatment
system 316 to achieve the desired viscosity that fulfills the
optimization objective. Then, a real-time viscosity 318 at the
first mud treatment 316 system may be measured and communicated to
the central data storage 312. The model executed by a second
subsystem controller 304 may describe the density (state) as a
function of the current mud volume, the flow in rate, and the
weighing material additions (input). Then, the second subsystem
controller 304 may output an action (e.g., addition of weighting
material 320) to be performed by a second mud treatment system 322
to achieve the desired density that fulfills the optimization
objective. Then, a real-time density 324 at the second mud
treatment system 322 may be measured and communicated to the
central data storage 312. The model executed by a third subsystem
controller 306 may describe the pressure/pump flow out rate
(states) as function of the mud tank volume and pump motor rpm
(input). Then, the third subsystem controller 306 may output an
operational parameter (e.g., a pump rpm and/or pump pressure 326)
to be performed by a pump 328 to achieve the desired the
pressure/pump flow out rate that fulfills the optimization
objective. Then, a real-time pressure/pump flow out rate 330 at the
pump 328 may be measured and communicated to the central data
storage 312. The model executed by a fourth subsystem controller
308 may describe pressure/choke flow out rate (states) as function
of the choke valve position, pump pressure, and choke flow in rate
(input). Then, the fourth subsystem controller 308 may output an
operational parameter (e.g., the choke valve position, pump
pressure, and choke flow in rate 332) to be performed by a choke
334 to achieve the desired pressure/choke flow out rate that
fulfills the optimization objective. Then, a real-time
pressure/choke flow out rate 336 at the choke 334 may be measured
and communicated to the central data storage 312. The model
executed by a fifth subsystem controller 310 may describe the ROP
(state) as a function of WOB and/or RPM of the drill bit (input).
Then, the fifth subsystem controller 310 may output an operational
parameter (e.g., WOB and/or RPM of the drill bit 338) to be
performed by a drill rig and string 340 to achieve the desired ROP
that fulfills the optimization objective. Then, a real-time ROP 342
of the drill bit may be measured and communicated to the central
data storage 312.
[0028] The interaction model reflects how the interaction states
are affected by each subsystem's inputs. For example, the
interaction models between (1) the subsystem comprising the fifth
subsystem controller 310 and drill rig and string 340 and (2) the
other four subsystems describe how the ROP is affected by the pump
pressure, flow rate, and the mud viscosity/density addition. The
interaction models between subsystems may be derived by the
decentralized identifications. The central data storage 312 stores
the up-to-date kick-loss pressure profile 344 (P.sub.kick and
P.sub.loss with respect to the TVD), the real-time
estimated/measured TVD/BHP 346, the subsystems' models, the
subsystems' interaction models, each subsystems' real-time states,
interaction states, and control inputs. All the subsystems can
access this information upon availability.
[0029] At current time step k, each subsystem collects the
estimated/measured TVD/BHP, the other subsystems' states, inputs,
and the interaction states. Based on all the models, each
controller's control command is designed subject to its subsystem's
constraints and to optimize the overall cost function, as shown in
Equation 2. Due to that the search region for each subsystem's
control input/states is much smaller than that for the overall
inputs/states, the computation load for each subsystem to seek for
the optimal control input is substantially lower than that of a
centralized controller. Once the calculation is done for each
controller and the control command is implemented, the subsystem's
states, input and interaction states are transmitted to the central
data storage 312 and are accessible for new calculations for all
the controllers at time step k+1. In this example, the other four
subsystems can all impact the BHP. Therefore, the subsystems are
coupled together but each has its own constraints (e.g., cost of
adding weighting material is a constraint for the second subsystem
controller 304, maximum pump pressure is a constraint in constraint
for the third subsystem controller 306, and the maximum valve
opening is a constraint for the second subsystem controller 308)
and timescales (e.g., pump and choke have much faster time scales
than mud mixer). The advantage of the proposed control scheme is
that it does not only coordinate the controllers to optimize the
cost function but also takes advantages of the different time
scales of the three subsystems to further improve the efficiency.
With the proposed distributed control scheme of the networked
control strategy the short time scale subsystems (e.g., pump 328
(e.g., pump 120 of FIG. 1) and choke 334 (e.g., choke 136 of FIG.
1)) may run the control multiple times while the slow scale system
is running one iteration (e.g., mud mixer 316,322 (e.g., mixer 134
of FIG. 1)). This may reduce the response time of the overall
system in regulating the pressure. Moreover, as each subsystem has
access to the other subsystems models, the time delay between
subsystems can be compensated by model based predictions.
[0030] The second coordinated control scheme described herein is a
"master-slave control strategy." In the proposed framework, the
subsystems (e.g., the shaker, mixer, pump, and mud circulation
systems) may be controlled and coordinated through a center
controller.
[0031] For example, FIG. 5 illustrates a mud circulation system 500
employing an exemplary master-slave control strategy. A supervisory
optimizer controller 502 (e.g., controller 138 of FIG. 1) optimizes
the mud circulation control system by calculating the optimal set
point of the manipulate variables for each slave subsystem (e.g.,
the mud flow-in rate and the mud viscosity) based on, for example,
the needs to minimize the cost function in Equation 1. Illustrated
are four slave subsystems: a shaker subsystem 504 (comprising a
shaker 512 (e.g., mud cleaning unit(s) 128 of FIG. 1) and a
proportional-integral-derivative (PID) controller 522, which as
illustrated applies proportional gain (P.sub.i) and integral gain
(I.sub.i) to the inputs from the supervisory optimizer controller
502), a mixer subsystem 506 (comprising a mixer 514 (e.g., mixer
134 of FIG. 1) and a PID controller 524), a pump subsystem 508
(comprising a pump 516 (e.g., pump 120 of FIG. 1) and a PID
controller 526), and a drill rig and string subsystem 510
(comprising a drill rig/string 518 (e.g., drill string 108, kelly
110, and rotary table 112) and a PID controller 528). The
supervisory optimizer controller 502 (e.g., controller 138 of FIG.
1) adopts a virtual master control system 530 to drive the mud
circulation system 500 to the desired viscosity and flow-in rate
520.
[0032] For each subsystem 504-510, a virtual inertia (I) is
involved in the master control system 530 such that the rates of
the subsystems with different time scales are coupled. The feedback
of the master control system 530 is the input of the slave systems
532. Within each subsystem, the input (feedback of the master
control system 530, which may be, for example, shaker drive for the
shaker subsystem 504, flow addition rate for the mixer subsystem
506, pump drive for the pump subsystem 508, and torque for the
drill rig and string subsystem 510) is then transferred into the
subsystem's corresponding reference signals via inverse function
block (f.sub.i.sup.-1) where a control loop feedback mechanism is
applied via the PID controllers 522-528. The subsystems'
adjustments (D.sub.i) are fed forward to the master control system
530. With the proposed layout of the master-slave control strategy,
the convergence of the master system 530 and thus the mud control
process is sped up and all the subsystems are by nature operating
within its operating limit.
[0033] The proposed methods provide two approaches to networked
control architectures that coordinate all the subsystems involved
in the mud circulation in order to optimize mud circulation
efficiency and mud quality.
[0034] Numerous other variations and modifications will become
apparent to those skilled in the art once the above disclosure is
fully appreciated. It is intended that the following claims be
interpreted to embrace all such variations, modifications and
equivalents. In addition, the term "or" should be interpreted in an
inclusive sense.
[0035] The control system(s) described herein and corresponding
computer hardware used to implement the various illustrative
blocks, modules, elements, components, methods, and algorithms
described herein can include a processor configured to execute one
or more sequences of instructions, programming stances, or code
stored on a non-transitory, computer-readable medium. The processor
can be, for example, a general purpose microprocessor, a
microcontroller, a digital signal processor, an application
specific integrated circuit, a field programmable gate array, a
programmable logic device, a controller, a state machine, a gated
logic, discrete hardware components, an artificial neural network,
or any like suitable entity that can perform calculations or other
manipulations of data. In some embodiments, computer hardware can
further include elements such as, for example, a memory (e.g.,
random access memory (RAM), flash memory, read only memory (ROM),
programmable read only memory (PROM), erasable programmable read
only memory (EPROM)), registers, hard disks, removable disks,
CD-ROMS, DVDs, or any other like suitable storage device or
medium.
[0036] Executable sequences described herein can be implemented
with one or more sequences of code contained in a memory. In some
embodiments, such code can be read into the memory from another
machine-readable medium. Execution of the sequences of instructions
contained in the memory can cause a processor to perform the
process steps described herein. One or more processors in a
multi-processing arrangement can also be employed to execute
instruction sequences in the memory. In addition, hard-wired
circuitry can be used in place of or in combination with software
instructions to implement various embodiments described herein.
Thus, the present embodiments are not limited to any specific
combination of hardware and/or software.
[0037] As used herein, a machine-readable medium will refer to any
medium that directly or indirectly provides instructions to a
processor for execution. A machine-readable medium can take on many
forms including, for example, non-volatile media, volatile media,
and transmission media. Non-volatile media can include, for
example, optical and magnetic disks. Volatile media can include,
for example, dynamic memory. Transmission media can include, for
example, coaxial cables, wire, fiber optics, and wires that form a
bus. Common forms of machine-readable media can include, for
example, floppy disks, flexible disks, hard disks, magnetic tapes,
other like magnetic media, CD-ROMs, DVDs, other like optical media,
punch cards, paper tapes and like physical media with patterned
holes, RAM, ROM, PROM, EPROM and flash EPROM.
[0038] Some embodiments described herein include a method
comprising: circulating a drilling mud through a mud circulation
system that includes components (also referred to herein as
subsystems) each having a controller coupled thereto; transferring
operational parameters from each of the controllers to a central
data storage; each controller accessing the operational parameters
provided by other controllers via the central data storage; and
each controller optimizing the operational parameters of the
component coupled thereto based on the operational parameters
provided by the other controllers. Such methods may further
include: (1) wherein the components include a pump, a drill pipe, a
choke, a mud cleaning unit, a mud treatment unit, and a mud tank;
(2) wherein the components include a pump and the operational
parameters of the pump include at least one of: pump rate or rate
of change of pump rate; (3) wherein the components include a drill
pipe and the operational parameters of the drill pipe include at
least one of: weight on bit, rate of penetration, or revolution per
minute; (4) wherein the components include a choke and the
operational parameters of the choke include at least one of: bottom
hole pressure or rate of change of bottom hole pressure; (5)
wherein the components include a mud cleaning unit and the
operational parameters of the mud cleaning unit include at least
one of: shaker operational parameters, centrifuge operational
parameters, hydrocyclone operational parameters, or separator
operational parameters; (6) wherein the components include a mud
treatment unit and the operational parameters of the mud treatment
unit include at least one of: mixing rate, concentration of
materials added to the mud, or rate of addition of the materials to
the mud; (7) wherein the components include a mud tank and the
operational parameters of the mud tank include at least one of:
retention time or mixing parameters.
[0039] Some embodiments described herein include a system
comprising: a flow path circulating a mud and including components
each having a controller coupled thereto; and a central data
storage communicable coupled to each controller. Such systems may
include: wherein the components include a pump, a drill pipe, a
choke, a mud cleaning unit, a mud treatment unit, and a mud
tank.
[0040] Some embodiments described herein include a method
comprising: circulating a drilling mud through a mud circulation
system that includes components each having a controller coupled
thereto; optimizing the operational parameters of each of the
components with an optimization function to produce optimized
operational parameters; transferring operational parameters from
each of the components to a controller; and operating the
components based on the optimized operational parameters. Such
method may further include: wherein the optimization function is a
cost function.
[0041] Some embodiments described herein include a system
comprising: a flow path circulating a mud and including components
each having a controller coupled thereto; and a central optimizer
communicably coupled to each controller and configured to operate
each controller within the operational limits of the component
coupled thereto. Such systems may include: wherein the components
include a pump, a drill pipe, a choke, a mud cleaning unit, a mud
treatment unit, and a mud tank.
[0042] Embodiments described herein include Embodiment A,
Embodiment B, Embodiment C, and Embodiment D.
[0043] Embodiment A is a method comprising: circulating a drilling
mud through a mud circulation system that includes a plurality of
subsystems each having a controller coupled thereto, wherein the
plurality of subsystems comprise one or more selected from the
group consisting of a pump, a drill pipe, a choke, a mud cleaning
unit, a mud treatment unit, and a mud tank; transferring one or
more operational parameters from each of the controllers of the
plurality of subsystems to a central data storage; a first
controller coupled to a first subsystem of the plurality of
subsystems, accessing a first operational parameter from the one or
more operational parameters from the central data storage; and the
first controller optimizing a second operational parameter related
to the first subsystem coupled thereto based on the first
operational parameter operational parameter from the central data
storage.
[0044] Embodiment A may optionally include one or more of the
following: Element 1: wherein the plurality of subsystems include
the pump and the first operational parameter of the pump comprises
one or more selected from the group consisting of pump rate and
rate of change of pump rate; Element 2: wherein the plurality of
subsystems include the drill pipe and the first operational
parameter of the drill pipe comprises one or more one selected from
the group consisting of weight on bit, rate of penetration, and
revolution per minute; Element 3: wherein the plurality of
subsystems include the choke and the first operational parameter of
the choke comprises one or more selected from the group consisting
of bottom hole pressure and rate of change of bottom hole pressure;
Element 4: wherein the plurality of subsystems include the mud
cleaning unit and the first operational parameter of the mud
cleaning unit comprises one or more selected from the group
consisting of shaker operational parameters, centrifuge operational
parameters, hydrocyclone operational parameters, and separator
operational parameters; Element 5: wherein the plurality of
subsystems include the mud treatment unit and the first operational
parameter of the mud treatment unit comprises one or more selected
from the group consisting of mixing rate, concentration of
materials added to the mud, and rate of addition of the materials
to the mud; and Element 6: wherein the plurality of subsystems
include the mud tank and the first operational parameter of the mud
tank comprises one or more selected from the group consisting of
retention time and mixing parameters. Any combination of the
foregoing may optionally be applied to Embodiment A.
[0045] Embodiment B is a method comprising circulating a drilling
mud through a mud circulation system that includes a plurality of
subsystems each having a controller coupled thereto, wherein the
plurality of subsystems comprise one or more selected from the
group consisting of a pump, a drill pipe, a choke, a mud cleaning
unit, a mud treatment unit, and a mud tank; optimizing one or more
operational parameters of each of the plurality of subsystems with
an optimization function at a supervisory optimizer controller to
produce one or more optimized operational parameters for each of
the plurality of subsystems; transferring the one or more optimized
operational parameters to the controller coupled to each of the
plurality of subsystems; and operating the plurality of subsystems
based on the one or more optimized operational parameters.
[0046] Embodiment B may optionally include one or more of the
following: Element 7: wherein the plurality of subsystems include
the drill pipe and the operational parameter of the drill pipe
comprises one or more selected from the group consisting of weight
on bit, rate of penetration and revolution per minute; Element 8:
wherein the plurality of subsystems include the choke and the
operational parameter of the choke comprises one or more selected
from the group consisting of bottom hole pressure, and rate of
change of bottom hole pressure; Element 9: wherein the plurality of
subsystems include the mud cleaning unit and the operational
parameter of the mud cleaning unit comprises one or more selected
from the group consisting of shaker operational parameters,
centrifuge operational parameters, hydrocyclone operational
parameters, and separator operational parameters; Element 10:
wherein the plurality of subsystems include the mud treatment unit
and the operational parameter of the mud treatment unit comprises
one or more selected from the group consisting of mixing rate,
concentration of materials added to the mud, and rate of addition
of the materials to the mud; and Element 11: wherein the plurality
of subsystems include the mud tank and the operational parameter of
the mud tank comprises one or more selected from the group
consisting of retention time and mixing parameters. Any combination
of the foregoing may optionally be applied to Embodiment B.
[0047] Embodiment C is a mud circulation system comprising: a drill
pipe within a wellbore penetrating a subterranean formation and
coupled to a first controller; a pump configured to convey a
drilling mud through the drill string and the wellbore and coupled
to a second controller; at least one subsystems coupled to a third
controller that include one or more selected from the group
consisting of a choke, a mud cleaning unit, a mud treatment unit,
and a mud tank; a non-transitory computer-readable medium coupled
to the drill string, the pump, or both and encoded with
instructions that, when executed, cause the system to perform the
method of Embodiment A or Embodiment B, including any optionally
elements described herein.
[0048] Embodiment D is a non-transitory computer-readable medium
communicably coupled to a mud circulation system and encoded with
instructions that, when executed, cause the mud circulation system
to perform the method of Embodiment A or Embodiment B, including
any optionally elements described herein.
[0049] Numerous other variations and modifications will become
apparent to those skilled in the art once the above disclosure is
fully appreciated. It is intended that the following claims be
interpreted to embrace all such variations, modifications and
equivalents. In addition, the term "or" should be interpreted in an
inclusive sense.
[0050] Unless otherwise indicated, all numbers expressing
quantities of ingredients, properties such as molecular weight,
reaction conditions, and so forth used in the present specification
and associated claims are to be understood as being modified in all
instances by the term "about." Accordingly, unless indicated to the
contrary, the numerical parameters set forth in the following
specification and attached claims are approximations that may vary
depending upon the desired properties sought to be obtained by the
embodiments of the present invention. At the very least, and not as
an attempt to limit the application of the doctrine of equivalents
to the scope of the claim, each numerical parameter should at least
be construed in light of the number of reported significant digits
and by applying ordinary rounding techniques.
[0051] One or more illustrative embodiments incorporating the
invention embodiments disclosed herein are presented herein. Not
all features of a physical implementation are described or shown in
this application for the sake of clarity. It is understood that in
the development of a physical embodiment incorporating the
embodiments of the present invention, numerous
implementation-specific decisions must be made to achieve the
developer's goals, such as compliance with system-related,
business-related, government-related and other constraints, which
vary by implementation and from time to time. While a developer's
efforts might be time-consuming, such efforts would be,
nevertheless, a routine undertaking for those of ordinary skill in
the art and having benefit of this disclosure.
[0052] While compositions and methods are described herein in terms
of "comprising" various components or steps, the compositions and
methods can also "consist essentially of" or "consist of" the
various components and steps.
[0053] Therefore, the present invention is well adapted to attain
the ends and advantages mentioned as well as those that are
inherent therein. The particular embodiments disclosed above are
illustrative only, as the present invention may be modified and
practiced in different but equivalent manners apparent to those
skilled in the art having the benefit of the teachings herein.
Furthermore, no limitations are intended to the details of
construction or design herein shown, other than as described in the
claims below. It is therefore evident that the particular
illustrative embodiments disclosed above may be altered, combined,
or modified and all such variations are considered within the scope
and spirit of the present invention. The invention illustratively
disclosed herein suitably may be practiced in the absence of any
element that is not specifically disclosed herein and/or any
optional element disclosed herein. While compositions and methods
are described in terms of "comprising," "containing," or
"including" various components or steps, the compositions and
methods can also "consist essentially of" or "consist of" the
various components and steps. All numbers and ranges disclosed
above may vary by some amount. Whenever a numerical range with a
lower limit and an upper limit is disclosed, any number and any
included range falling within the range is specifically disclosed.
In particular, every range of values (of the form, "from about a to
about b," or, equivalently, "from approximately a to b," or,
equivalently, "from approximately a-b") disclosed herein is to be
understood to set forth every number and range encompassed within
the broader range of values. Also, the terms in the claims have
their plain, ordinary meaning unless otherwise explicitly and
clearly defined by the patentee. Moreover, the indefinite articles
"a" or "an," as used in the claims, are defined herein to mean one
or more than one of the element that it introduces.
* * * * *