CA3010427A1 - Method and system for automated adjustment of drilling mud properties - Google Patents
Method and system for automated adjustment of drilling mud properties Download PDFInfo
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- CA3010427A1 CA3010427A1 CA3010427A CA3010427A CA3010427A1 CA 3010427 A1 CA3010427 A1 CA 3010427A1 CA 3010427 A CA3010427 A CA 3010427A CA 3010427 A CA3010427 A CA 3010427A CA 3010427 A1 CA3010427 A1 CA 3010427A1
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- 238000005553 drilling Methods 0.000 title claims abstract description 47
- 238000000034 method Methods 0.000 title claims description 25
- 238000005457 optimization Methods 0.000 claims abstract description 63
- 238000005520 cutting process Methods 0.000 claims abstract description 19
- 239000000654 additive Substances 0.000 claims description 54
- 238000002347 injection Methods 0.000 claims description 24
- 239000007924 injection Substances 0.000 claims description 24
- 230000000996 additive effect Effects 0.000 claims description 21
- 230000004907 flux Effects 0.000 claims description 11
- 238000011144 upstream manufacturing Methods 0.000 claims description 10
- 239000000203 mixture Substances 0.000 claims description 7
- 238000005070 sampling Methods 0.000 claims description 6
- 238000012544 monitoring process Methods 0.000 claims description 3
- 239000008240 homogeneous mixture Substances 0.000 claims description 2
- 230000001939 inductive effect Effects 0.000 claims description 2
- 230000035699 permeability Effects 0.000 claims description 2
- 230000004044 response Effects 0.000 claims description 2
- 230000001052 transient effect Effects 0.000 claims description 2
- 239000012530 fluid Substances 0.000 description 6
- 238000005259 measurement Methods 0.000 description 4
- 230000008901 benefit Effects 0.000 description 3
- 239000000243 solution Substances 0.000 description 3
- 230000000712 assembly Effects 0.000 description 2
- 238000000429 assembly Methods 0.000 description 2
- 238000004140 cleaning Methods 0.000 description 2
- 239000000463 material Substances 0.000 description 2
- 238000013178 mathematical model Methods 0.000 description 2
- 230000007246 mechanism Effects 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 238000013459 approach Methods 0.000 description 1
- 230000009118 appropriate response Effects 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 230000001276 controlling effect Effects 0.000 description 1
- 239000010779 crude oil Substances 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 230000002706 hydrostatic effect Effects 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 230000001105 regulatory effect Effects 0.000 description 1
- 230000009897 systematic effect Effects 0.000 description 1
- 230000007704 transition Effects 0.000 description 1
- 239000002699 waste material Substances 0.000 description 1
Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/06—Arrangements for treating drilling fluids outside the borehole
- E21B21/062—Arrangements for treating drilling fluids outside the borehole by mixing components
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/06—Arrangements for treating drilling fluids outside the borehole
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/08—Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/10—Valve arrangements in drilling-fluid circulation systems
- E21B21/106—Valve arrangements outside the borehole, e.g. kelly valves
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B44/00—Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
- E21B49/08—Obtaining fluid samples or testing fluids, in boreholes or wells
- E21B49/087—Well testing, e.g. testing for reservoir productivity or formation parameters
- E21B49/0875—Well testing, e.g. testing for reservoir productivity or formation parameters determining specific fluid parameters
Landscapes
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Life Sciences & Earth Sciences (AREA)
- Mining & Mineral Resources (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Physics & Mathematics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Mechanical Engineering (AREA)
- Excavating Of Shafts Or Tunnels (AREA)
- Earth Drilling (AREA)
- Control Of Non-Electrical Variables (AREA)
Abstract
Drilling mud properties in a mud recirculation system (13) of an oil and/or gas well drilling assembly (1) are automatically adjusted by an automated mud treating assembly (20,25) that is governed hierarchal primary and secondary optimization and control loops (30,31) that continuously keep the density, viscosity, pH and other mud properties within specifications set by a model-based tertiary optimization and control loop to ensure that the mud properties will lead to sufficient drilled cutting transport, borehole stability, drill bit hydraulics, and minimum friction torque and drag.
Description
METHOD AND SYSTEM FOR AUTOMATED ADJUSTMENT OF DRILLING MUD
PROPERTIES
FIELD OF THE INVENTION
The present invention relates to a method and system for automated adjustment of drilling mud properties in a mud recirculation system of a rig for drilling an underground wellbore.
BACKGROUND OF THE INVENTION
During drilling of underground wellbores for the production of crude oil and/or natural gas a drilling fluid, generally known as drilling mud, is circulated in downward direction through the interior of the drill string and then in upward direction through the surrounding annulus to lift drill cuttings to the surface, to clean and cool the drill bit, to stabilize the borehole, to lubricate the rotating drill string and to provide hydrostatic head for preventing well kicks.
At the wellhead the drill cuttings are removed from the drilling mud in a mud cleaning assembly and the mud volume is adjusted by adding fresh mud and the composition of the re-injected mud is adjusted by adding mud additives in a mud treatment assembly to generate desired mud properties, such as mud density, viscosity and pH.
A fluid handling system is described in WO 97/42395 Al, specifically for underbalanced drilling operations. A
control unit determines or computes values of a number of operating parameters of the fluid handling system and controls the operation of the various devices based on such parameters according to programs and models provided to the control unit. The control unit, which receives signals from sensors, is coupled to the various devices in the system
PROPERTIES
FIELD OF THE INVENTION
The present invention relates to a method and system for automated adjustment of drilling mud properties in a mud recirculation system of a rig for drilling an underground wellbore.
BACKGROUND OF THE INVENTION
During drilling of underground wellbores for the production of crude oil and/or natural gas a drilling fluid, generally known as drilling mud, is circulated in downward direction through the interior of the drill string and then in upward direction through the surrounding annulus to lift drill cuttings to the surface, to clean and cool the drill bit, to stabilize the borehole, to lubricate the rotating drill string and to provide hydrostatic head for preventing well kicks.
At the wellhead the drill cuttings are removed from the drilling mud in a mud cleaning assembly and the mud volume is adjusted by adding fresh mud and the composition of the re-injected mud is adjusted by adding mud additives in a mud treatment assembly to generate desired mud properties, such as mud density, viscosity and pH.
A fluid handling system is described in WO 97/42395 Al, specifically for underbalanced drilling operations. A
control unit determines or computes values of a number of operating parameters of the fluid handling system and controls the operation of the various devices based on such parameters according to programs and models provided to the control unit. The control unit, which receives signals from sensors, is coupled to the various devices in the system
- 2 -for controlling the operations of the devices, including control valves. The control unit periodically or continually determines the required drilling fluid mix as a function of one or more of the selected operating parameters and operates a control valve to discharge a correct amount of additive materials to obtain the desired mix.
At the moment, there is no integrated solution utilizing a combination of integrated hardware and software that makes use of the measurement data to predict the downhole condition and control the mud properties in order to mitigate or avoid operational issues.
There is a need for an improved mud additive injection control system and method which overcome the drawbacks of the prior art.
Furthermore there is a need for a more efficient mud system management that minimizes waste and use of materials used to treat the mud and minimize operational downtime, due to for example a stuck drill pipe and/or drill pipe vibration, and operational issues, such as lack of well control and/or borehole instability due to the failure of keeping the mud properties at the desired specification.
SUMMARY OF THE INVENTION
In one aspect of the invention, there is provided a method for automated adjustment of drilling mud properties in a mud recirculation system of a rig for drilling an underground wellbore, the method comprising inducing hierarchal primary and secondary optimization and control loops to adjust injection rates of mud additives into a circulated mud stream flowing through an automated mud treating assembly, to continuously keep mud properties, comprising density, viscosity, pH and optionally other mud
At the moment, there is no integrated solution utilizing a combination of integrated hardware and software that makes use of the measurement data to predict the downhole condition and control the mud properties in order to mitigate or avoid operational issues.
There is a need for an improved mud additive injection control system and method which overcome the drawbacks of the prior art.
Furthermore there is a need for a more efficient mud system management that minimizes waste and use of materials used to treat the mud and minimize operational downtime, due to for example a stuck drill pipe and/or drill pipe vibration, and operational issues, such as lack of well control and/or borehole instability due to the failure of keeping the mud properties at the desired specification.
SUMMARY OF THE INVENTION
In one aspect of the invention, there is provided a method for automated adjustment of drilling mud properties in a mud recirculation system of a rig for drilling an underground wellbore, the method comprising inducing hierarchal primary and secondary optimization and control loops to adjust injection rates of mud additives into a circulated mud stream flowing through an automated mud treating assembly, to continuously keep mud properties, comprising density, viscosity, pH and optionally other mud
3 properties, within specifications set by a model-based tertiary optimization and control loop.
In another aspect of the invention, there is provided a system for automated adjustment of drilling mud properties in a mud recirculation system of a rig for drilling an underground wellbore, the system comprising hierarchal primary and secondary optimization and control loops to adjust injection rates of mud additives into a mud circulation conduit in an automated mud treating assembly, arranged to continuously keep mud properties, comprising density, viscosity, pH and optionally other mud properties, within specifications set a model-based tertiary optimization and control loop.
These and other features, embodiments and advantages of the method and system as proposed herein are described in the accompanying claims, abstract and the following detailed description of non-limiting embodiments depicted in the accompanying drawing, in which description reference numerals are used which refer to corresponding reference numerals that are depicted in the drawing.
Objects and other features depicted in the figure and/or described in this specification, abstract and/or claims may be combined in different ways by a person skilled in the art.
BRIEF DESCRIPTION OF THE DRAWING
The systems and methods will be described hereinafter by way of example in more detail with reference to Figure 1, which is a schematic representation of a drilling assembly provided with an automated mud additive injection control system. No limitations are intended to the details of construction or design herein shown, other than as described in the claims below.
In another aspect of the invention, there is provided a system for automated adjustment of drilling mud properties in a mud recirculation system of a rig for drilling an underground wellbore, the system comprising hierarchal primary and secondary optimization and control loops to adjust injection rates of mud additives into a mud circulation conduit in an automated mud treating assembly, arranged to continuously keep mud properties, comprising density, viscosity, pH and optionally other mud properties, within specifications set a model-based tertiary optimization and control loop.
These and other features, embodiments and advantages of the method and system as proposed herein are described in the accompanying claims, abstract and the following detailed description of non-limiting embodiments depicted in the accompanying drawing, in which description reference numerals are used which refer to corresponding reference numerals that are depicted in the drawing.
Objects and other features depicted in the figure and/or described in this specification, abstract and/or claims may be combined in different ways by a person skilled in the art.
BRIEF DESCRIPTION OF THE DRAWING
The systems and methods will be described hereinafter by way of example in more detail with reference to Figure 1, which is a schematic representation of a drilling assembly provided with an automated mud additive injection control system. No limitations are intended to the details of construction or design herein shown, other than as described in the claims below.
- 4 -DETAILED DESCRIPTION OF THE DEPICTED EMBODIMENT
A method and system are proposed for automated adjustment of drilling mud properties in a mud recirculation system. Such mud recirculation system may form part of a drilling assembly for excavating an underground wellbore. The mud recirculation system may be applied on a rig for drilling an underground formation.
In one proposed method for automated adjustment of drilling mud properties in a mud recirculation system of a rig for drilling an underground wellbore, hierarchal primary and secondary optimization and control loops are induced to control an automated mud treating assembly which injects additives that continuously keep density, viscosity, pH and other mud properties within the specifications. Rather than that these specifications are set by an operator, a tertiary model-based optimization and control loop may be run to set the specifications.
This may be implemented by three nested optimization and control loops as follows: the tertiary optimization and control loop determines specifications for mud properties comprising density, viscosity, pH and optionally other mud properties on the basis of a model which optimizes desired downhole properties of the injected mud for assessed downhole drilling conditions. These mud property specifications are fed as setpoints to the secondary optimization and control loop, which determines the required additives to achieve the desired setpoint mud properties. The required additives as computed by the secondary loop then become the setpoints for the primary control loops, which open additive injection valves to achieve the required additives. The tertiary optimization and control loop may also determine setpoints of flow rate of the circulated mud stream, which may be fed directly to
A method and system are proposed for automated adjustment of drilling mud properties in a mud recirculation system. Such mud recirculation system may form part of a drilling assembly for excavating an underground wellbore. The mud recirculation system may be applied on a rig for drilling an underground formation.
In one proposed method for automated adjustment of drilling mud properties in a mud recirculation system of a rig for drilling an underground wellbore, hierarchal primary and secondary optimization and control loops are induced to control an automated mud treating assembly which injects additives that continuously keep density, viscosity, pH and other mud properties within the specifications. Rather than that these specifications are set by an operator, a tertiary model-based optimization and control loop may be run to set the specifications.
This may be implemented by three nested optimization and control loops as follows: the tertiary optimization and control loop determines specifications for mud properties comprising density, viscosity, pH and optionally other mud properties on the basis of a model which optimizes desired downhole properties of the injected mud for assessed downhole drilling conditions. These mud property specifications are fed as setpoints to the secondary optimization and control loop, which determines the required additives to achieve the desired setpoint mud properties. The required additives as computed by the secondary loop then become the setpoints for the primary control loops, which open additive injection valves to achieve the required additives. The tertiary optimization and control loop may also determine setpoints of flow rate of the circulated mud stream, which may be fed directly to
- 5 -the pump control system without intervention by the secondary and primary optimization and control loops.
The mud properties may be measured by a sensor assembly that measures density, viscosity, pH and/or other properties of the mud in the mud recirculation system at the rig upstream and/or downstream of the automated mud treating assembly, which sensor assembly may comprise an upstream sensor assembly comprising primary and secondary untreated mud property sensors for monitoring the properties of the untreated mud flowing from a cuttings removal system to the automated mud treating assembly. The primary untreated mud flux property sensor may be arranged in the mud recirculation system between the secondary untreated mud flux property sensor and the mud treating assembly.
The automated mud treating assembly may comprise additive injection control devices, suitably injection control valves, that are controlled by the primary optimization and control loop to meet the injection rates of each additive set by set by the secondary optimization and control loop that is connected to the tertiary optimization and control loop that determines the appropriate ranges or setpoints for density, viscosity, pH
and other mud properties in order to meet multiple operational objectives, such as maximizing cutting transport capabilities of the drilling mud and maintaining wellbore mechanical stability.
Optionally, the primary, secondary and tertiary optimization and control loops operate at different time scales and hierarchies, whereby:
- the tertiary optimization and control loop is the master of the secondary optimization and control loop and operates at the highest time scale or lower sampling rate;
and
The mud properties may be measured by a sensor assembly that measures density, viscosity, pH and/or other properties of the mud in the mud recirculation system at the rig upstream and/or downstream of the automated mud treating assembly, which sensor assembly may comprise an upstream sensor assembly comprising primary and secondary untreated mud property sensors for monitoring the properties of the untreated mud flowing from a cuttings removal system to the automated mud treating assembly. The primary untreated mud flux property sensor may be arranged in the mud recirculation system between the secondary untreated mud flux property sensor and the mud treating assembly.
The automated mud treating assembly may comprise additive injection control devices, suitably injection control valves, that are controlled by the primary optimization and control loop to meet the injection rates of each additive set by set by the secondary optimization and control loop that is connected to the tertiary optimization and control loop that determines the appropriate ranges or setpoints for density, viscosity, pH
and other mud properties in order to meet multiple operational objectives, such as maximizing cutting transport capabilities of the drilling mud and maintaining wellbore mechanical stability.
Optionally, the primary, secondary and tertiary optimization and control loops operate at different time scales and hierarchies, whereby:
- the tertiary optimization and control loop is the master of the secondary optimization and control loop and operates at the highest time scale or lower sampling rate;
and
- 6 -- the secondary optimization and control loop is governed by, also called the slave of, the tertiary optimization and control loop and operates at the lower time scale or higher sampling rate than the tertiary optimization and control loop but higher time scale and lower sampling rate than the primary optimization and control loop which is governed by, also called the slave of, the secondary optimization and control loop.
The tertiary optimization and control loop may comprise an optimization module that determines the ranges or the setpoints of the primary treated mud properties given the objective functions of the tertiary optimization and control loop such as ensuring sufficient cutting transport, wellbore mechanical stability and given estimates of:
a) drill string torque and drag;
b) borehole stability and permeability;
c) size, volume, weight, density and composition of drill cuttings; and d) downhole mud velocity, pH, viscosity, density and composition.
The ranges of the mud property values as determined by the optimization module of the tertiary loop may suitably be included as the desired ranges to be honoured by a multivariable control algorithm in the secondary control loop. The multivariable control algorithm suitably provides a setpoint for the injection rate of each one of the injected mud additives. The multivariable control algorithm may be a Model Predictive Controller (MPC) algorithm that casts the multivariable control problem as an optimal control problem with an objective function of minimizing the deviation of the primary treated mud properties from the desired ranges given the minimum and maximum amount of additives to be added at each cycle and the models between mud properties to be controlled and additives as well as
The tertiary optimization and control loop may comprise an optimization module that determines the ranges or the setpoints of the primary treated mud properties given the objective functions of the tertiary optimization and control loop such as ensuring sufficient cutting transport, wellbore mechanical stability and given estimates of:
a) drill string torque and drag;
b) borehole stability and permeability;
c) size, volume, weight, density and composition of drill cuttings; and d) downhole mud velocity, pH, viscosity, density and composition.
The ranges of the mud property values as determined by the optimization module of the tertiary loop may suitably be included as the desired ranges to be honoured by a multivariable control algorithm in the secondary control loop. The multivariable control algorithm suitably provides a setpoint for the injection rate of each one of the injected mud additives. The multivariable control algorithm may be a Model Predictive Controller (MPC) algorithm that casts the multivariable control problem as an optimal control problem with an objective function of minimizing the deviation of the primary treated mud properties from the desired ranges given the minimum and maximum amount of additives to be added at each cycle and the models between mud properties to be controlled and additives as well as
- 7 -the drilling and mud flux circulation rates, which casts the mud properties control problem into a multivariable optimization solution with constraints over a selected time horizon that take into account the amount of time required for the mud to be circulated through the borehole and back to the drilling rig at earth surface.
The multivariable control MPC algorithm may be provided with models identifying mathematical relationships between the additives, mud properties and measured variations in drilling rates that affect variations in drill cuttings concentration.
The proposed method may be implemented in a system for automated adjustment of drilling mud properties in the mud recirculation system.
An example of an implementation of an automated mud treatment system and method is illustrated with reference to Figure 1. Figure 1 shows a drilling assembly 1 comprising a drill bit 2 that is rotated by a drill string 3 as illustrated by arrows 4 to excavate an underground borehole 5.
Drilling mud 6 is pumped down through the drill string 3 as illustrated by arrows 7 and up through the surrounding annulus 8 as illustrated by arrow 9 to lift drill cuttings 10 to the earth surface 11, where the drill cuttings are removed from the returned mud 6 in a mud shaker and filter assembly 12.
The cleaned mud 6 is subsequently transported via a mud recirculation conduit 13 and a top drive swivel 14 back into the drill string 3. Even though the mud is recirculated, and as such there is strictly speaking no begin and end to the circuit, for the purpose of interpretation of terms such as "upstream", "downstream", and for defining the order in which certain parts of equipment are configured relative to each other in the mud
The multivariable control MPC algorithm may be provided with models identifying mathematical relationships between the additives, mud properties and measured variations in drilling rates that affect variations in drill cuttings concentration.
The proposed method may be implemented in a system for automated adjustment of drilling mud properties in the mud recirculation system.
An example of an implementation of an automated mud treatment system and method is illustrated with reference to Figure 1. Figure 1 shows a drilling assembly 1 comprising a drill bit 2 that is rotated by a drill string 3 as illustrated by arrows 4 to excavate an underground borehole 5.
Drilling mud 6 is pumped down through the drill string 3 as illustrated by arrows 7 and up through the surrounding annulus 8 as illustrated by arrow 9 to lift drill cuttings 10 to the earth surface 11, where the drill cuttings are removed from the returned mud 6 in a mud shaker and filter assembly 12.
The cleaned mud 6 is subsequently transported via a mud recirculation conduit 13 and a top drive swivel 14 back into the drill string 3. Even though the mud is recirculated, and as such there is strictly speaking no begin and end to the circuit, for the purpose of interpretation of terms such as "upstream", "downstream", and for defining the order in which certain parts of equipment are configured relative to each other in the mud
- 8 -circulation system, the mud share and filter assembly 12 is taken to be "the end" of the mud recirculation cycle, which is considered to be the most "downstream" end of the cycle.
The most "upstream" end of the cycle is the transition from the mud share and filter assembly 12 into the mud recirculation conduit 13.
The mud recirculation conduit 13 is connected to a mud mixing tank 15 in which additional mud can be added from a mud tank 16 and in which the mud is mixed by a mixer 17 to homogenize the mud 6 before it is pumped back into the drill string 3 by a mud pump assembly 17,18. The mud mixing tank 15 may be referred to as untreated mud mixing tank 15, as it is located upstream of a mud treating assembly 20 to which the mud recirculation conduit 13 is furthermore connected. In this mud treating assembly 20 mud additives 21-24 are injected into the mud, to ultimately adjust mud properties, such as density, viscosity and pH.
The mud treating assembly 20 is suitably equipped with an automated additive injection control system 25 that automatically adjusts the injection rates of each of the mud additives 21-24 on the basis of measurements of the properties of untreated mud 6 upstream of the treating assembly 20 by primary and secondary untreated mud property sensors 26-27 and measurements of the treated mud 6 downstream of the treating assembly 20 by primary and secondary treated mud property sensors 28-29. An untreated mud mixing tank 15 may be arranged in the mud recirculation system 13 between the primary and secondary untreated mud property sensors 26-27.
The primary and secondary untreated and treated mud property sensors 26-27 and 28-29 form part of a hierarchical closed loop control system which contains two closed loops 30-31, where loop 30 is configured as a primary or master control loop and the other loop 31 is
The most "upstream" end of the cycle is the transition from the mud share and filter assembly 12 into the mud recirculation conduit 13.
The mud recirculation conduit 13 is connected to a mud mixing tank 15 in which additional mud can be added from a mud tank 16 and in which the mud is mixed by a mixer 17 to homogenize the mud 6 before it is pumped back into the drill string 3 by a mud pump assembly 17,18. The mud mixing tank 15 may be referred to as untreated mud mixing tank 15, as it is located upstream of a mud treating assembly 20 to which the mud recirculation conduit 13 is furthermore connected. In this mud treating assembly 20 mud additives 21-24 are injected into the mud, to ultimately adjust mud properties, such as density, viscosity and pH.
The mud treating assembly 20 is suitably equipped with an automated additive injection control system 25 that automatically adjusts the injection rates of each of the mud additives 21-24 on the basis of measurements of the properties of untreated mud 6 upstream of the treating assembly 20 by primary and secondary untreated mud property sensors 26-27 and measurements of the treated mud 6 downstream of the treating assembly 20 by primary and secondary treated mud property sensors 28-29. An untreated mud mixing tank 15 may be arranged in the mud recirculation system 13 between the primary and secondary untreated mud property sensors 26-27.
The primary and secondary untreated and treated mud property sensors 26-27 and 28-29 form part of a hierarchical closed loop control system which contains two closed loops 30-31, where loop 30 is configured as a primary or master control loop and the other loop 31 is
- 9 -configured as a secondary or slave control loop. Both closed loop 30-31 make use of assemblies of substantially similar mud property sensors 26-29, located in predefined positions upstream and downstream of the mud treating assembly 20, providing necessary data for mud property monitoring and control.
The automated mud treating system 25 may comprise an additive injection optimization module comprising a computer programmed with algorithms known as Wells Advanced Kernels (WAKs) and a mathematical optimization module to provide the secondary multivariable control loop (for example the MPC alogrithm) with specifications for mud properties such as density, viscosity, pH and optionally other mud properties based on advanced drilling parameters modelling and real time data. Setpoints for circulation flow rate, which may also be computed, may be fed directly to the rig mud pump assembly 17,18. Given the specifications for the mud properties, the secondary multivariable control loop then computes the required mud additives 21-24. The required mud additives 21-24 as computed by the secondary optimization and control loop become the set points for the primary closed loop control system 30, which adjusts the valve openings accordingly to meet the setpoints of each of the mud additives 21-24.
The automated drilling mud treating system 20, 25 is able to adjust mud properties more accurately than manually controlled drilling fluid additive systems that may still be present on the drilling rig 33 for start-up and/or as a back-up in case of malfunctioning of the automated mud treating system 20,25. The automated additive injection control system 20,25 automatically adjusts during at least part of the drilling operations the drilling fluid additive injection rates to adjust the mud properties to a desired set-point based on a predefined reference signal.
The automated mud treating system 25 may comprise an additive injection optimization module comprising a computer programmed with algorithms known as Wells Advanced Kernels (WAKs) and a mathematical optimization module to provide the secondary multivariable control loop (for example the MPC alogrithm) with specifications for mud properties such as density, viscosity, pH and optionally other mud properties based on advanced drilling parameters modelling and real time data. Setpoints for circulation flow rate, which may also be computed, may be fed directly to the rig mud pump assembly 17,18. Given the specifications for the mud properties, the secondary multivariable control loop then computes the required mud additives 21-24. The required mud additives 21-24 as computed by the secondary optimization and control loop become the set points for the primary closed loop control system 30, which adjusts the valve openings accordingly to meet the setpoints of each of the mud additives 21-24.
The automated drilling mud treating system 20, 25 is able to adjust mud properties more accurately than manually controlled drilling fluid additive systems that may still be present on the drilling rig 33 for start-up and/or as a back-up in case of malfunctioning of the automated mud treating system 20,25. The automated additive injection control system 20,25 automatically adjusts during at least part of the drilling operations the drilling fluid additive injection rates to adjust the mud properties to a desired set-point based on a predefined reference signal.
- 10 -The mud treating system 20 is arranged in an additives and mud mixing tank 34, which is designed in such a way to ensure sufficient mixing quality and appropriate response time to bring the mud properties back to a desired specification, and a set of physical actuators, such as additive injection pumps and control valves (not shown), for automatic addition of the mud additives 21-24. The size of the mixing tank 34 may suitably be determined by taking into account the following aspects:
- the minimum residence time required by the characteristics of the drilling mud to ensure a homogeneous mixture when additives are added; and - the balance between the response time required by the secondary multivariable control loop to bring the properties of the primary untreated mud to the desired values or ranges while ensuring that the addition of the additives as the result of the controller's actions does not lead to major fluctuations in the steady state or transient values of the primary treated and secondary untreated mud properties.
The flow rates of the mud additives 21-24 into the additives and mud mixing tank 34 are regulated by the automated additive injection control system 25, which uses the data generated by the mud flux property sensor assemblies 26,27 about the untreated mud 6 returned from the borehole 5 is compared to reference signals or desired specifications of the mud properties, which can originate from operators or from an automatic set point optimization module based on the Wells Advance Kernel (WAK) prediction.
Any deviations (error signals) from the desired setpoints will trigger the control algorithm to compute required amount of additives 21-24 to be added to the mud 6 and these computations are sent to the control valves of the mud treating assembly 20, 25.
- the minimum residence time required by the characteristics of the drilling mud to ensure a homogeneous mixture when additives are added; and - the balance between the response time required by the secondary multivariable control loop to bring the properties of the primary untreated mud to the desired values or ranges while ensuring that the addition of the additives as the result of the controller's actions does not lead to major fluctuations in the steady state or transient values of the primary treated and secondary untreated mud properties.
The flow rates of the mud additives 21-24 into the additives and mud mixing tank 34 are regulated by the automated additive injection control system 25, which uses the data generated by the mud flux property sensor assemblies 26,27 about the untreated mud 6 returned from the borehole 5 is compared to reference signals or desired specifications of the mud properties, which can originate from operators or from an automatic set point optimization module based on the Wells Advance Kernel (WAK) prediction.
Any deviations (error signals) from the desired setpoints will trigger the control algorithm to compute required amount of additives 21-24 to be added to the mud 6 and these computations are sent to the control valves of the mud treating assembly 20, 25.
- 11 -The automated mud treating system 20,25 may furthermore be provided with an MPC algorithm, which casts the mud properties control problem into a multivariable optimization solution with constraints over a certain time horizon to take into account the amount of time required for the mud 6 to be circulated through the borehole 5 and back to the surface 11. The MPC algorithm is a control approach that takes the time horizon and input constraints into account.
The MPC algorithm may be provided with models identifying mathematical relationships between the additives, mud properties, and also measured disturbances such as variations in drilling rates that affect variations in drill cuttings 10 concentration. The effects of disturbances can change the relationship between the additives 21-24 and mud properties, which may be automatically corrected by the MPC algorithm.
There are two options to correct the models in the MPC
algorithm:
I) One option is to correct the model by adding a filter, for example a Kalman Filter, that corrects and updates the model continuously based on measurement data.
II) Another option is to use an automatic model-rebuilding mechanism if the amount of updates from the Kalman Filter is too big. The automatic model-rebuilding mechanism is carried out by varying the additive signals systematically in such a way that meaningful mathematical relationships can still be derived without disturbing the drilling operations. The input signals and measured mud properties resulting from this systematic variation is then used to derive a new model for the control algorithm.
The required mud property specification and associated additive injection setpoints in the automated mud treating system 20,25 can be updated automatically by means of an
The MPC algorithm may be provided with models identifying mathematical relationships between the additives, mud properties, and also measured disturbances such as variations in drilling rates that affect variations in drill cuttings 10 concentration. The effects of disturbances can change the relationship between the additives 21-24 and mud properties, which may be automatically corrected by the MPC algorithm.
There are two options to correct the models in the MPC
algorithm:
I) One option is to correct the model by adding a filter, for example a Kalman Filter, that corrects and updates the model continuously based on measurement data.
II) Another option is to use an automatic model-rebuilding mechanism if the amount of updates from the Kalman Filter is too big. The automatic model-rebuilding mechanism is carried out by varying the additive signals systematically in such a way that meaningful mathematical relationships can still be derived without disturbing the drilling operations. The input signals and measured mud properties resulting from this systematic variation is then used to derive a new model for the control algorithm.
The required mud property specification and associated additive injection setpoints in the automated mud treating system 20,25 can be updated automatically by means of an
- 12 -optimization algorithm. Given the mud weight and the viscosity profile of the mud, the Wells Advanced Kernels (WAKs) may provide a prediction of the cutting transport state, the equivalent circulating density, and, optionally, the torque and drag profile along the borehole 5 and, also optionally, the elastic borehole stability. The mathematical models between the mud properties and these parameters can be derived by feeding the kernels with mud property values and fit models between the mud properties and the cuttings transport, drill string torque and drag and borehole stability. Given the selected mathematical model(s) and operational objective(s), such as maximize borehole cleaning and maximize borehole stability and applying a linear or nonlinear optimization algorithm, the appropriate setpoints for the mud additive injection rates can be derived automatically from the selected model(s).
Therefore, the method and system described herein are 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, combined and/or practiced in different but equivalent manners apparent to those skilled in the art having the benefit of the teachings herein.
It is therefore evident that the particular illustrative embodiments disclosed above may be altered, combined and/or modified and all such variations are considered within the scope of the present invention as defined in the accompanying claims.
Therefore, the method and system described herein are 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, combined and/or practiced in different but equivalent manners apparent to those skilled in the art having the benefit of the teachings herein.
It is therefore evident that the particular illustrative embodiments disclosed above may be altered, combined and/or modified and all such variations are considered within the scope of the present invention as defined in the accompanying claims.
Claims (15)
1. A method for automated adjustment of drilling mud properties in a mud recirculation system of a rig for drilling an underground wellbore, the method comprising inducing hierarchal primary and secondary optimization and control loops to adjust injection rates of mud additives into a circulated mud stream flowing through an automated mud treating assembly, to continuously keep mud properties, comprising density, viscosity, pH and optionally other mud properties, within specifications set by a model-based tertiary optimization and control loop.
2. The method of claim 1, wherein the primary optimization and control loop governs opening and closing of additive injection control valves of the automated mud treating assembly to meet injection rates of each additive set by set by the secondary optimization and control loop that is connected to the tertiary optimization and control loop that determines the appropriate ranges or setpoints for the mud properties in order to meet multiple operational objectives, such as maximizing cutting transport capabilities of the drilling mud and maintaining wellbore mechanical stability.
3. The method of claim 1 or 2, wherein the mud properties are measured by a sensor assembly that measures the mud properties of the mud in the mud recirculation system at the rig upstream and/or downstream of the automated mud treating assembly.
4. The method of claim 3, wherein the sensor assembly comprises an upstream sensor assembly comprising primary and secondary untreated mud flux property sensors for monitoring the properties of the untreated mud flowing from a cuttings removal system to the automated mud treating assembly, wherein the primary untreated mud flux property sensor is arranged in the mud recirculation system between the secondary untreated mud flux property sensor and the mud treating assembly.
5. The method of any one of the preceding claims, wherein:
- the primary, secondary and tertiary optimization and control loops operate at different time scales and hierarchies;
- the tertiary optimization and control loop is the master of the secondary optimization and control loop and operates at the highest time scale or lower sampling rate; and - the secondary optimization and control loop is governed by the tertiary optimization and control loop and operates at the lower time scale or higher sampling rate than the tertiary optimization and control loop but higher time scale and lower sampling rate than the primary optimization and control loop which is governed by the secondary optimization and control loop.
- the primary, secondary and tertiary optimization and control loops operate at different time scales and hierarchies;
- the tertiary optimization and control loop is the master of the secondary optimization and control loop and operates at the highest time scale or lower sampling rate; and - the secondary optimization and control loop is governed by the tertiary optimization and control loop and operates at the lower time scale or higher sampling rate than the tertiary optimization and control loop but higher time scale and lower sampling rate than the primary optimization and control loop which is governed by the secondary optimization and control loop.
6. The method of claim 4 or 5, wherein the sensor assembly further comprises a downstream sensor assembly comprising primary and secondary treated mud property sensors for measuring density, viscosity, pH and/or other properties of the treated mud in the mud recirculation system at the rig downstream of the mud treating assembly, wherein the primary treated mud flux property sensor is arranged in the mud recirculation system between the mud treating assembly and the secondary treated mud property sensor; and wherein:
- the primary optimization and control loop is connected to a sensor assembly that measures the actual injection rate of each additive in the automated mud treating assembly;
the secondary optimization and control loop is connected to the sensor assembly that measures the primary untreated and treated mud properties;
the tertiary optimization and control loop is connected to the primary untreated mud sensor assembly and optionally to the secondary untreated mud sensor assembly.
- the primary optimization and control loop is connected to a sensor assembly that measures the actual injection rate of each additive in the automated mud treating assembly;
the secondary optimization and control loop is connected to the sensor assembly that measures the primary untreated and treated mud properties;
the tertiary optimization and control loop is connected to the primary untreated mud sensor assembly and optionally to the secondary untreated mud sensor assembly.
7. The method of any one of claims 4 to 6, wherein the primary treated mud flux property sensor forms part of the secondary optimization and control loop and the secondary treated mud flux property sensor forms part of the tertiary optimization and control loop.
8. The method of any one of the preceding claims, wherein the tertiary optimization and control loop comprises an optimization module that determines the ranges or the setpoints of the primary treated mud properties given the objective functions of the tertiary optimization and control loop such as ensuring sufficient cutting transport, wellbore mechanical stability and estimates of:
a) drill string torque and drag;
b) borehole stability and permeability;
c) size, volume, weight, density and composition of drill cuttings; and d) downhole mud velocity, pH, viscosity, density and composition.
a) drill string torque and drag;
b) borehole stability and permeability;
c) size, volume, weight, density and composition of drill cuttings; and d) downhole mud velocity, pH, viscosity, density and composition.
9. The method of claim 8, wherein the ranges of the mud property values as determined by the optimization module are included as the desired ranges to be honoured by a multivariable control algorithm in the secondary control loop.
10. The method of claim 9, wherein the multivariable control algorithm is a Model Predictive Controller (MPC) algorithm that casts the multivariable control problem as an optimal control problem with an objective function of minimizing the deviation of the primary treated mud properties from the desired ranges given the minimum and maximum amount of additives to be added at each cycle and the models between mud properties to be controlled and additives as well as the drilling and mud flux circulation rates.
11. The method of claim 10, wherein the multivariable control algorithm is provided with models identifying mathematical relationships between the additives, mud properties and measured variations in drilling rates that affect variations in drill cuttings concentration.
12. A system for automated adjustment of drilling mud properties in a mud recirculation system of a rig for drilling an underground wellbore, the system comprising hierarchal primary and secondary optimization and control loops to adjust injection rates of mud additives into a mud circulation conduit in an automated mud treating assembly, arranged to continuously keep mud properties, comprising density, viscosity, pH and optionally other mud properties, within specifications set a model-based tertiary optimization and control loop.
13. The system of claim 12, wherein the primary optimization and control that governs opening and closing of the additive control valves of the automated mud treating assembly, to meet the injection rates of each additive set by set by the secondary optimization and control loop that is connected to the tertiary optimization and control loop that determines the appropriate ranges or setpoints for the mud properties in order to meet multiple operational objectives, such as maximizing cutting transport capabilities of the drilling mud and maintaining wellbore mechanical stability.
14. The system of claim 12 or 13, wherein the system comprises a sensor assembly that measures the mud properties of the mud in the mud recirculation system at the rig upstream and/or downstream of the automated mud treating assembly.
15. The system of any one of claims 12-14, wherein the mud treating assembly comprises an additives and mud mixing tank, the size of which is determined by two aspects:
- the minimum residence time required by the characteristics of the drilling mud to ensure a homogeneous mixture when additives are added; and - the balance between the response time required by the secondary multivariable control loop to bring the properties of the primary untreated mud to the desired values or ranges while ensuring that the addition of the additives as the result of the controller's actions does not lead to major fluctuations in the steady state or transient values of the primary treated and secondary untreated mud properties.
- the minimum residence time required by the characteristics of the drilling mud to ensure a homogeneous mixture when additives are added; and - the balance between the response time required by the secondary multivariable control loop to bring the properties of the primary untreated mud to the desired values or ranges while ensuring that the addition of the additives as the result of the controller's actions does not lead to major fluctuations in the steady state or transient values of the primary treated and secondary untreated mud properties.
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| EP16152522.5 | 2016-01-25 | ||
| PCT/EP2017/051329 WO2017129523A1 (en) | 2016-01-25 | 2017-01-23 | Method and system for automated adjustment of drilling mud properties |
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| CA3010427A1 true CA3010427A1 (en) | 2017-08-03 |
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| WO2019046904A1 (en) * | 2017-09-08 | 2019-03-14 | Australian Mud Company Pty Ltd | A drilling mud management system and method |
| US11428099B2 (en) | 2019-05-15 | 2022-08-30 | Saudi Arabian Oil Company | Automated real-time drilling fluid density |
| US10989046B2 (en) * | 2019-05-15 | 2021-04-27 | Saudi Arabian Oil Company | Real-time equivalent circulating density of drilling fluid |
| US20210017847A1 (en) * | 2019-07-19 | 2021-01-21 | Baker Hughes Oilfield Operations Llc | Method of modeling fluid flow downhole and related apparatus and systems |
| US11598165B2 (en) * | 2019-08-06 | 2023-03-07 | Kyle Collins | Automated drilling-fluid additive system and method |
| GB2582841B (en) * | 2019-08-19 | 2021-09-08 | Clear Solutions Holdings Ltd | Automated fluid system |
| US20220234010A1 (en) * | 2021-01-25 | 2022-07-28 | Saudi Arabian Oil Company | Automated recycled closed-loop water based drilling fluid condition monitoring system |
| US11655690B2 (en) | 2021-08-20 | 2023-05-23 | Saudi Arabian Oil Company | Borehole cleaning monitoring and advisory system |
| US12037857B2 (en) * | 2021-11-30 | 2024-07-16 | Saudi Arabian Oil Company | Method and system for determining hole cleaning efficiency based on wellbore segment lengths |
| CN114233220B (en) * | 2022-01-13 | 2022-06-03 | 东北石油大学 | Method for reducing friction resistance of water-based drilling fluid mud cake with high harmful solid content |
| WO2024091449A1 (en) * | 2022-10-26 | 2024-05-02 | Schlumberger Technology Corporation | Devices, systems, and methods for drilling fluid management |
| US20240167347A1 (en) * | 2022-11-17 | 2024-05-23 | Saudi Arabian Oil Company | Method and system for drilling fluid monitoring |
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| US3473368A (en) * | 1967-12-27 | 1969-10-21 | Mobil Oil Corp | Method and apparatus for continuously monitoring properties of thixotropic fluids |
| DE69704158T2 (en) * | 1996-05-03 | 2001-08-02 | Baker Hughes Inc., Houston | SYSTEM FOR RINSING TREATMENT IN THE CLOSED CIRCUIT FOR USE IN WELL HOLES |
| US20020112888A1 (en) * | 2000-12-18 | 2002-08-22 | Christian Leuchtenberg | Drilling system and method |
| US7823656B1 (en) * | 2009-01-23 | 2010-11-02 | Nch Corporation | Method for monitoring drilling mud properties |
| CN104053496A (en) * | 2011-11-18 | 2014-09-17 | M-I有限公司 | Mixing methods and systems for fluids |
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| US20190055797A1 (en) | 2019-02-21 |
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| EP3408491B1 (en) | 2020-04-29 |
| EP3408491A1 (en) | 2018-12-05 |
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