US20100170673A1 - System and method for downhole blowout prevention - Google Patents
System and method for downhole blowout prevention Download PDFInfo
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- US20100170673A1 US20100170673A1 US12/350,557 US35055709A US2010170673A1 US 20100170673 A1 US20100170673 A1 US 20100170673A1 US 35055709 A US35055709 A US 35055709A US 2010170673 A1 US2010170673 A1 US 2010170673A1
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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
- E21B21/10—Valve arrangements in drilling-fluid circulation systems
Definitions
- Blowout prevention is a significant concern in hydrocarbon exploration and production. Blowouts generally refer to uncontrolled fluid or gas flow from an earth formation into a wellbore, which could potentially flow to the surface. Despite health, safety and environment (HSE) issues, this causes loss of income either directly or by reduced or delayed production. Blowout preventers are provided to seal all or a portion of the wellbore in response to a kick, i.e., a sudden flow of formation fluid, such as water, oil and/or gas, into the borehole. Such action prevents the kick from evolving into a blowout at the surface.
- a kick i.e., a sudden flow of formation fluid, such as water, oil and/or gas
- Kicks usually refer to influxes when drilling into an over pressured zone but include also influxes occurring when the well pressure becomes lower than the pore pressure, which is a consequence of loss of circulation fluid occurring when the well pressure is partially higher than the fracture pressure or when drilling into permeable low-pressure formations.
- Typical pressure barriers are used during drilling operations. Such barriers include the use of heavy mud, surface blowout preventers (BOP) and downhole BOPs. Typical blowout prevention devices, and especially downhole BOPs, do not allow for ease of replacement of various components or addition or subtraction of supplemental capabilities.
- a system for monitoring and controlling fluid flow through a borehole in an earth formation includes: a downhole tool configured to be movable within the borehole; and a plurality of interchangeable modules disposed within the downhole tool, the plurality of interchangeable modules including at least a sensor module for detecting a property change in the borehole and a packer module for sealing a portion of the borehole in response to the property change.
- Each of the plurality of interchangeable modules includes a connection configuration, the connection configuration of one of the modules being removably engageable with at least another of the modules.
- a method of monitoring and controlling fluid flow through a borehole in an earth formation includes: disposing a plurality of interchangeable modules within a downhole tool, the plurality of interchangeable modules including at least a sensor module and a packer module, each of the plurality of interchangeable modules including a connection configuration, the connection configuration of one of the modules being removably engageable with at least another of the modules; detecting a change in property in the borehole by the sensor module; and responsive to the change in property being greater than a selected threshold, actuating the packer sub to seal a portion of the borehole.
- FIG. 1 depicts an embodiment of a drilling and/or well logging system including a downhole blowout prevention (BOP) tool;
- BOP downhole blowout prevention
- FIG. 2 depicts an exploded side view of an embodiment of a downhole BOP tool
- FIG. 3 depicts a side view of a bypass sub of FIG. 2 ;
- FIG. 4 depicts a side view of a packer sub of FIG. 2 in a non-actuated position
- FIG. 5 depicts a side view of the packer sub of FIG. 2 in an actuated position
- FIG. 6 depicts a side view of an exemplary embodiment of the downhole tool of FIG. 2 ;
- FIG. 7 depicts a side view of another exemplary embodiment of the downhole tool of FIG. 2 ;
- FIG. 8 depicts a side view of another exemplary embodiment of the downhole tool of FIG. 2 ;
- FIG. 9 is a block diagram of a system for preventing blowouts in a borehole.
- FIG. 10 is a flow chart providing an exemplary method preventing blowouts in a borehole.
- an exemplary embodiment of a drilling and/or well logging system 10 includes a drillstring 11 that is shown disposed in a borehole 12 that penetrates at least one earth formation 14 .
- the drillstring 11 includes a drill pipe, which may be one or more pipe sections or coiled tubing. Drilling fluid, or drilling mud 16 may be pumped through the drillstring 11 and/or the borehole 12 .
- a bottom hole assembly (BHA) 18 is disposed in the system 10 at or near the downhole portion of the drillstring 11 .
- a modular downhole tool 20 is disposed in the BHA 18 or other location in the drillstring 11 , and includes a blowout preventer (BOP) 25 capable of sealing off a portion of the borehole 12 upon detection of an influx of fluid or loss of drilling mud circulation.
- BOP blowout preventer
- the BHA 18 includes a drill bit 22 to drill through earth formations.
- the drill bit 22 is powered by a surface rotary drive, a motor using pressurized fluid (e.g., mud motor, not shown) an electrically driven motor and/or other suitable mechanism.
- drillstring refers to any structure suitable for lowering a tool through a borehole or connecting a drill to the surface, and is not limited to the structure and configuration described herein.
- the drillstring 11 may be configured as a drillstring, production string or other borehole string.
- a “string” refers to any structure, tool or apparatus configured to be lowered within a borehole in an earth formation.
- the tool 20 includes a modular downhole blowout preventer (BOP) assembly that is configured to control influx into and/or loss of fluid from the borehole 12 .
- BOP downhole blowout preventer
- the BOP assembly is included to seal off the borehole 12 in the event of an influx of gas and/or fluid or a loss of circulation.
- blowout refers to uncontrolled fluid or gas flow from an earth formation into a wellbore which could potentially flow to the surface, and/or any fluid or gas flow from the formation and/or the borehole into the surface environment.
- the tool 20 includes at least one of a plurality of modular units serving various functions.
- the tool 20 includes a plurality of modular units.
- Each unit is also referred to herein as a “sub”, which is an interchangeable component of the tool 20 and is connectable to other subs to form selected drillstring sections and/or sections of the BHA 18 .
- subs include but are not limited to an upper crossover sub 28 such as a wired pipe or other adapter sub, a power/pulser sub 30 , a battery sub 31 , a communication sub 32 to receive and send commands, a packer sub 34 , a bypass sub 36 (in one embodiment, the bypass sub 36 is located above the packer sub 34 to allow circulation, as shown in FIG.
- the sensor sub 38 includes one or more sensors for detecting a kick.
- the subs are integrated into the BHA 18 and are configured to communicate with the surface via suitable LWD equipment. The individual placement of the subs within the tool 20 is exemplary, as the subs may be placed relative to one another in any suitable configuration.
- Each sub includes a connection mechanism 41 , 43 configured to allow each sub to be removed and/or replaced without disassembly of the tool 20 .
- the connection mechanisms 41 , 43 have a common configuration so that each connection mechanism 41 , 43 of a respective sub is engageable with the connection mechanism 41 , 43 of any other sub.
- Each sub can be replaced with a sub having operating characteristics more suited to the particular conditions encountered.
- the sensor sub 38 can be switched with another sensor sub 38 having a different combination of sensors.
- each sub is individually designed to have selected characteristics.
- the weights and dimensions of each sub is individually determined based on their individual requirements. Housings for each sub include any selected materials or combinations to have selected resistances to the borehole environment, such as pressure, temperature and corrosion.
- the upper crossover sub 28 and the lower crossover sub 42 include electrical conduits 44 for coupling power and/or communication signals from an electric cable or other wire in the drillstring 11 and/or BHA 18 to the modular assembly, i.e., the tool 20 .
- the upper crossover sub 28 may also be configured to couple other power/communication setups to the modular assembly 20 , such as wireline connections and logging-while-drilling (LWD) connections.
- the upper crossover sub 28 is configured to be connected to a drillstring, wired pipe or wireline.
- the power/pulser sub 30 includes a power source 46 such as at least one battery and a suitable electronics unit 48 to regulate voltage, current and/or frequency of power supplied to the modular assembly 20 .
- the power/pulser sub 30 is capable of running the tool 20 at low or even no flow.
- Exemplary batteries include rechargeable batteries, lithium batteries and nickel cadmium (Ni—Cd) batteries.
- the power source 46 is included that individually powers each module.
- the power source 46 includes one or more batteries 46 to operate the sensor sub 38 and one or more batteries 46 to operate the packer sub 34 .
- Various subs are powered by the power source 46 , the wired pipe adapter 28 or any other suitable power source.
- the sensor sub 38 includes at least one sensor 50 configured to measure various properties of the borehole 12 and/or the formation 14 , such as a pressure sensor. Examples of such properties include pressure, flow rate, gas content, mud composition and others.
- the pressure sensor 50 is an electrically conductive member that changes resistance due to changes in strain in response to pressure variations.
- a sensor electronics unit 52 is coupled to the sensor 50 and measures a current change to calculate change in resistance and the corresponding pressure change.
- the sensor electronics unit 52 may include its own power source or measure current applied by the power/pulser sub 30 .
- the sensor electronics unit 52 includes an amplifier to amplify the signal generated therein.
- the sensor sub 38 in addition to pressure sensors, may include any number or type of additional sensors to detect various conditions in and/or characteristics of the borehole, the circulating fluid and/or the formation.
- the decoder sub 40 includes a decoder electronics unit 54 , such as a microprocessor, to receive input from the sensor sub 34 and actuate the packer sub 34 when a sufficient change in a property is detected.
- the decoder electronics unit 54 is configured to recognize when a change in a property occurs beyond a selected threshold, and in response actuate the packer sub 34 to seal off a portion of the borehole 12 .
- the decoder electronics unit 54 is configured to be in a sleeping mode when the tool 20 is out of hole, and to power up when the tool 20 is exposed to pressure to preserve power and protect the tool 20 from premature actuation during transport and storage.
- the bypass sub 36 includes a bypass assembly having a valve 56 and bypass electronics unit 58 for controlling the valve 56 to allow mud to flow from the interior of the drillstring 11 to an exterior of the drillstring 11 and into the borehole 12 .
- the valve 56 is a poppet valve cooperating with a bypass annulus 60 or other conduit to engage in fluid communication with an interior conduit 62 of the drillstring 11 .
- the poppet valve In the closed position shown in FIG. 3 , the poppet valve seals 56 off the annulus 60 to prevent fluid flow between the interior conduit 62 and an exterior of the drillstring 11 .
- the poppet valve 56 In the open position, the poppet valve 56 is moved to allow fluid flow through the annulus.
- the bypass electronics unit 58 includes various sensors and/or motors for sensing a condition in which bypass is needed and/or to actuate the valve 56 .
- the bypass sub includes a string valve 57 , which may be connected to suitable control electronics 59 , for controlling fluid flow through the drillstring 11 .
- the string valve may be a poppet valve or any other suitable valve configuration.
- the bypass assembly and the drillstring valve 57 are housed in separate modules that can be individually removed and attached to the tool 20 .
- the string valve 57 is located below the valve 56 to allow bypass circulation in the event that the string valve 57 is actuated to close the string.
- the packer sub 34 includes a string valve 63 , a packer element 64 and an actuator assembly 66 including a packer valve 67 such as a poppet valve.
- the actuator assembly 66 includes electronics and/or pressure sensors for controlling actuation of the valve 67 and/or the element 64 .
- the actuator assembly 66 in one embodiment, is disposed in communication with the decoder sub 40 , for example, which in turn activates the actuator assembly 66 to cause the packer 64 to inflate or otherwise extend radially toward the sides of the borehole 12 to seal off a section of the borehole 12 .
- FIG. 4 shows the actuator assembly 66 in a non-actuated or drilling position
- FIG. 5 shows the actuator in an actuated position.
- both the drillstring 11 and a fluid conduit 68 within the packer sub 38 housing is sealed off.
- the drilling fluid or mud 16 is now circulated through a circulation port 70 just above the annular seal formed by the poppet valve 67 and directed to an annulus 72 through one or more bores 74 to inflate the packer element 64 .
- the valve 63 is located below the valve 67 to allow for bypass circulation, and may also be located below the packer element 64 .
- the system includes four independently operating valves.
- the valves are incorporated into the bypass sub 36 and/or the packer sub 34 and are configured with the bypass valve 56 located above the packer valve 67 .
- the packer valve 67 is configured as independently operating inflation and deflation valves.
- the string valve 63 which may be located in the separate string valve sub 37 and/or the bypass sub 36 , is located below the bypass valve 56 and the packer valve(s) 67 .
- SIDPP shut-in drill pipe pressure
- This configuration is also useful in performing drill stem testing.
- the actuator assembly 66 includes one or more of an electric motor, a translational mechanism such as a roller screw, the valve 67 , and the circulation port 70 .
- the electric motor is started by the decoder sub 40 when the detected pressure change is beyond a selected threshold.
- motor current is continuously controlled by the decoder electronics 54 during actuation. The motor current increases at the end position of the poppet stroke, and is switched off by the decoder electronics 54 at a predetermined value. In one embodiment, if any unforeseen motor loads should occur during actuation, the decoder electronics 54 are configured to control the current to prevent damage to the packer sub 34 .
- the circulation port 70 extends from an exterior of the packer sub 34 to the interior conduit 68 through which mud or other fluid or gas is introduced.
- the poppet valve 67 seals the drillstring 11 and opens the circulation port 70 to allow fluid to enter the annulus 72 and inflate the packer element 64 .
- the packer is automatically deflated by internal stresses in the packer element when the circulation port 70 is closed and the tool 20 is in the drilling mode.
- one or more of the components of the actuator assembly 66 each form their own modular sub-assembly.
- the actuator assembly 66 and the packer element 64 are each disposed within their own modular sub.
- the tool 20 is not limited to the exemplary number and types of subs or modules described herein. Any number or type of modules may be included to provide selected functionality for blowout prevention and other uses.
- the tool 20 includes all of the subs 28 , 30 , 32 , 34 , 36 , 38 , 40 and 42 described herein in the order shown. However, any number of subs may be added or omitted, or the order of the subs changed. Tool modifications may also introduce additional functions such as multi-operational circulation ports, drillstring chokes and test plugs for traditional BOPs.
- Each modular unit is interchangeable and includes the standardized connection interface 41 , 43 to allow for each sub to be interchangeable with any other sub.
- the connection interface 41 , 43 is standardized among all of the subs to allow for each sub to be interchangeable with any other sub. Such interchangeability allows for the BHA 18 and/or tool 20 to be easily adjusted to account for different operation needs.
- all electric wires for communication to other modules are located in the center of each module for simple connection and disconnection.
- one or more of the subs are encased in a protective housing, for example a resilient or rubberized casing to protect the sub from shocks and vibrations.
- connections 41 , 43 include shaft connections, threaded connections, bayonet and pin connections.
- each sub has a male connection 41 and a female connection 43 , which may be tapered or straight.
- each connection 41 , 43 includes an electrical and/or signal connection to couple power and communication signals between subs.
- sensors 50 include sensors that are used to measure properties of the formation 14 , to measure properties of the borehole 12 and/or to assess the stresses on and operation of the tool 20 .
- sensors 50 include pressure sensors, current sensors, vibration sensors, temperature sensors flow rate sensors, gas content and/or mud composition sensors and others.
- the tool 20 is equipped with transmission equipment to communicate ultimately to a surface processing unit 26 .
- Such transmission equipment allows the tool 20 to send critical data to the surface, stop or otherwise control pipe rotation, stop or otherwise control axial movement, control fluid flow, receive and decode commands sent downhole to activate the tool, and perform other functions.
- Such transmission equipment may take any desired form, and different transmission media and connections may be used. Examples of connections include wired pipe, fiber optic, wireless connections, mud pulse telemetry and any other suitable communication utilized in logging-while-drilling (LWD) equipment.
- LWD logging-while-drilling
- the surface processing unit 26 and/or the tool 20 include components as necessary to provide for storing and/or processing data collected from the tool 20 .
- Exemplary components include, without limitation, at least one processor, storage, memory, input devices, output devices and the like.
- the surface processing unit 26 optionally is configured to control the tool 20 .
- FIGS. 6-8 illustrate various examples of the tool 20 .
- the tool 20 in a first example, includes a wired pipe adapter sub 76 in a modular connection with a BOP sub 78 , that includes a battery sub.
- the tool 20 in a second example, includes a bi-directional power and communications module 80 in a modular connection with the BOP sub 78 .
- the tool 20 in a third example, includes a low flow pulser/decoder sub 82 in a modular connection with the BOP sub 78 .
- a system 80 for preventing blowouts, or other device used in conjunction with the BHA 18 and/or the drillstring 11 may be incorporated in a computer or other processing unit capable of receiving data from the tool 20 .
- the processing unit may be included with the tool 20 or included as part of the surface processing unit 26 .
- the system 80 includes a computer 81 coupled to the tool 20 .
- exemplary components include, without limitation, at least one processor, storage, memory, input devices, output devices and the like. As these components are known to those skilled in the art, these are not depicted in any detail herein.
- the computer 81 may be disposed in at least one of the surface processing unit 24 and the tool 20 .
- FIG. 10 illustrates a method for preventing blowouts in a borehole.
- the method includes one or more of stages 101 - 104 described herein.
- the method may be performed continuously or intermittently as desired.
- the method is described herein in conjunction with the tool 20 and optionally the decoder sub 40 , although the method may be performed in conjunction with any number and configuration of processors, sensors and tools.
- the method may be performed by one or more processors or other devices capable of receiving and processing measurement data, such as the microprocessor and/or the computer 81 .
- the method includes the execution of all of stages 101 - 104 in the order described. However, certain stages 101 - 104 may be omitted, stages may be added, or the order of the stages changed.
- the modular assembly 20 is assembled by connecting each sub in operable communication via the connections 41 , 43 .
- the selection of subs and the position within the assembly depend on the assessment of the blow out risk and the property chosen to trigger an adequate reaction.
- a change in a property, such as pressure, that is greater than a selected threshold is detected.
- Information regarding the property change may be sent to the surface for decision.
- decisions include reacting conventionally without use of the downhole BOP, and/or stopping string movement and activating the downhole BOP, and/or running an automatic process at the surface and/or downhole. Transmitting the information to surface may be done with wired pipe, conventional mud pulse telemetry or other suitable means.
- a pressure code is generated in the pulser sub in response to the change in pressure.
- a code depending on the selected action is transmitted inside the drillstring 11 (via pulse, wired pipe, etc.) to the packer sub 34 and/or the decoder sub 40 , and the packer sub 34 is actuated to cause the packer element 64 to seal off a portion of the borehole 12 .
- the packer sub 34 is actuated, both the drillstring 11 and the borehole 12 are sealed off.
- Actuation moves the poppet valves 63 and 67 , e.g., after the electronic unit in the actuator assembly 66 has accepted the code.
- the drillstring 11 is closed and the circulation port 70 is opened to seal off the lower part of the borehole 12 .
- the section of the borehole 12 above the packer sub 34 is circulated with mud 16 of sufficient density to equalize pressure in the borehole 12 to regain control of the borehole pressure and stabilize the borehole 12 .
- the packer sub 34 is reset back to normal drilling mode, e.g., by sending a new pressure code.
- the systems and methods described herein provide various advantages over prior art techniques.
- the embodiments described herein offer greatly increased system flexibility, which allows the tool to be easily adjusting to coincide with changing operational needs. Examples of such embodiments are described above.
- various analyses and/or analytical components may be used, including digital and/or analog systems.
- the system may have components such as a processor, storage media, memory, input, output, communications link (wired, wireless, pulsed mud, optical or other), user interfaces, software programs, signal processors (digital or analog) and other such components (such as resistors, capacitors, inductors and others) to provide for operation and analyses of the apparatus and methods disclosed herein in any of several manners well-appreciated in the art.
- teachings may be, but need not be, implemented in conjunction with a set of computer executable instructions stored on a computer readable medium, including memory (ROMs, RAMs), optical (CD-ROMs), or magnetic (disks, hard drives), or any other type that when executed causes a computer to implement the method of the present invention.
- ROMs, RAMs random access memory
- CD-ROMs compact disc-read only memory
- magnetic (disks, hard drives) any other type that when executed causes a computer to implement the method of the present invention.
- These instructions may provide for equipment operation, control, data collection and analysis and other functions deemed relevant by a system designer, owner, user or other such personnel, in addition to the functions described in this disclosure.
- a sample line, sample storage, sample chamber, sample exhaust, pump, piston, power supply e.g., at least one of a generator, a remote supply and a battery
- vacuum supply e.g., at least one of a generator, a remote supply and a battery
- refrigeration i.e., cooling
- heating component e.g., heating component
- motive force such as a translational force, propulsional force or a rotational force
- magnet electromagnet
- sensor electrode
- transmitter, receiver, transceiver e.g., transceiver
- controller e.g., optical unit, electrical unit or electromechanical unit
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Abstract
A system for monitoring and controlling fluid flow through a borehole in an earth formation is disclosed. The system includes: a downhole tool configured to be movable within the borehole; and a plurality of interchangeable modules disposed within the downhole tool, the plurality of interchangeable modules including at least a sensor module for detecting a property change in the borehole and a packer module for sealing a portion of the borehole in response to the property change. Each of the plurality of interchangeable modules includes a connection configuration, the connection configuration of one of the modules being removably engageable with at least another of the modules. A method of monitoring and controlling fluid flow through a borehole in an earth formation is also disclosed.
Description
- Blowout prevention is a significant concern in hydrocarbon exploration and production. Blowouts generally refer to uncontrolled fluid or gas flow from an earth formation into a wellbore, which could potentially flow to the surface. Despite health, safety and environment (HSE) issues, this causes loss of income either directly or by reduced or delayed production. Blowout preventers are provided to seal all or a portion of the wellbore in response to a kick, i.e., a sudden flow of formation fluid, such as water, oil and/or gas, into the borehole. Such action prevents the kick from evolving into a blowout at the surface. Kicks usually refer to influxes when drilling into an over pressured zone but include also influxes occurring when the well pressure becomes lower than the pore pressure, which is a consequence of loss of circulation fluid occurring when the well pressure is partially higher than the fracture pressure or when drilling into permeable low-pressure formations.
- Various independent pressure barriers are used during drilling operations. Such barriers include the use of heavy mud, surface blowout preventers (BOP) and downhole BOPs. Typical blowout prevention devices, and especially downhole BOPs, do not allow for ease of replacement of various components or addition or subtraction of supplemental capabilities.
- A system for monitoring and controlling fluid flow through a borehole in an earth formation includes: a downhole tool configured to be movable within the borehole; and a plurality of interchangeable modules disposed within the downhole tool, the plurality of interchangeable modules including at least a sensor module for detecting a property change in the borehole and a packer module for sealing a portion of the borehole in response to the property change. Each of the plurality of interchangeable modules includes a connection configuration, the connection configuration of one of the modules being removably engageable with at least another of the modules.
- A method of monitoring and controlling fluid flow through a borehole in an earth formation includes: disposing a plurality of interchangeable modules within a downhole tool, the plurality of interchangeable modules including at least a sensor module and a packer module, each of the plurality of interchangeable modules including a connection configuration, the connection configuration of one of the modules being removably engageable with at least another of the modules; detecting a change in property in the borehole by the sensor module; and responsive to the change in property being greater than a selected threshold, actuating the packer sub to seal a portion of the borehole.
- The following descriptions should not be considered limiting in any way. With reference to the accompanying drawings, like elements are numbered alike:
-
FIG. 1 depicts an embodiment of a drilling and/or well logging system including a downhole blowout prevention (BOP) tool; -
FIG. 2 depicts an exploded side view of an embodiment of a downhole BOP tool; -
FIG. 3 depicts a side view of a bypass sub ofFIG. 2 ; -
FIG. 4 depicts a side view of a packer sub ofFIG. 2 in a non-actuated position; -
FIG. 5 depicts a side view of the packer sub ofFIG. 2 in an actuated position; -
FIG. 6 depicts a side view of an exemplary embodiment of the downhole tool ofFIG. 2 ; -
FIG. 7 depicts a side view of another exemplary embodiment of the downhole tool ofFIG. 2 ; -
FIG. 8 depicts a side view of another exemplary embodiment of the downhole tool ofFIG. 2 ; -
FIG. 9 is a block diagram of a system for preventing blowouts in a borehole; and -
FIG. 10 is a flow chart providing an exemplary method preventing blowouts in a borehole. - Referring to
FIG. 1 , an exemplary embodiment of a drilling and/or welllogging system 10 includes adrillstring 11 that is shown disposed in aborehole 12 that penetrates at least oneearth formation 14. Thedrillstring 11 includes a drill pipe, which may be one or more pipe sections or coiled tubing. Drilling fluid, or drillingmud 16 may be pumped through thedrillstring 11 and/or theborehole 12. In one embodiment, a bottom hole assembly (BHA) 18 is disposed in thesystem 10 at or near the downhole portion of thedrillstring 11. Amodular downhole tool 20 is disposed in theBHA 18 or other location in thedrillstring 11, and includes a blowout preventer (BOP) 25 capable of sealing off a portion of theborehole 12 upon detection of an influx of fluid or loss of drilling mud circulation. In one embodiment, the BHA 18 includes adrill bit 22 to drill through earth formations. Thedrill bit 22 is powered by a surface rotary drive, a motor using pressurized fluid (e.g., mud motor, not shown) an electrically driven motor and/or other suitable mechanism. - As described herein, “borehole” or “wellbore” refers to a single hole that makes up all or part of a drilled well. As described herein, “formations” refer to the various features and materials that may be encountered in a subsurface environment. Accordingly, it should be considered that while the term “formation” generally refers to geologic formations of interest, that the term “formations,” as used herein, may, in some instances, include any geologic points or volumes of interest (such as a survey area). In addition, it should be noted that the drillstring may be any structure suitable for lowering a tool through a borehole or connecting a drill to the surface, and is not limited to the structure and configuration described herein. The
drillstring 11 may be configured as a drillstring, production string or other borehole string. As used herein, a “string” refers to any structure, tool or apparatus configured to be lowered within a borehole in an earth formation. - Referring to
FIG. 2 , in one embodiment, thetool 20 includes a modular downhole blowout preventer (BOP) assembly that is configured to control influx into and/or loss of fluid from theborehole 12. The BOP assembly is included to seal off theborehole 12 in the event of an influx of gas and/or fluid or a loss of circulation. As described herein, “blowout” refers to uncontrolled fluid or gas flow from an earth formation into a wellbore which could potentially flow to the surface, and/or any fluid or gas flow from the formation and/or the borehole into the surface environment. - The
tool 20 includes at least one of a plurality of modular units serving various functions. In one embodiment, thetool 20 includes a plurality of modular units. Each unit is also referred to herein as a “sub”, which is an interchangeable component of thetool 20 and is connectable to other subs to form selected drillstring sections and/or sections of theBHA 18. Examples of subs include but are not limited to anupper crossover sub 28 such as a wired pipe or other adapter sub, a power/pulser sub 30, abattery sub 31, acommunication sub 32 to receive and send commands, apacker sub 34, a bypass sub 36 (in one embodiment, thebypass sub 36 is located above thepacker sub 34 to allow circulation, as shown inFIG. 2 ), astring valve sub 37, a sensor sub 38 (e.g., for kick detection), adecoder sub 40, and alower crossover sub 42 connected to the string or theBHA 18. In one embodiment, thesensor sub 38 includes one or more sensors for detecting a kick. In one embodiment, the subs are integrated into theBHA 18 and are configured to communicate with the surface via suitable LWD equipment. The individual placement of the subs within thetool 20 is exemplary, as the subs may be placed relative to one another in any suitable configuration. - Each sub includes a
connection mechanism tool 20. In one embodiment, theconnection mechanisms connection mechanism connection mechanism - Each sub can be replaced with a sub having operating characteristics more suited to the particular conditions encountered. For example, the
sensor sub 38 can be switched with anothersensor sub 38 having a different combination of sensors. In one embodiment, each sub is individually designed to have selected characteristics. For example, the weights and dimensions of each sub is individually determined based on their individual requirements. Housings for each sub include any selected materials or combinations to have selected resistances to the borehole environment, such as pressure, temperature and corrosion. - In one embodiment, the
upper crossover sub 28 and thelower crossover sub 42 include electrical conduits 44 for coupling power and/or communication signals from an electric cable or other wire in thedrillstring 11 and/orBHA 18 to the modular assembly, i.e., thetool 20. Theupper crossover sub 28 may also be configured to couple other power/communication setups to themodular assembly 20, such as wireline connections and logging-while-drilling (LWD) connections. In one embodiment, theupper crossover sub 28 is configured to be connected to a drillstring, wired pipe or wireline. - In one embodiment, the power/
pulser sub 30 includes apower source 46 such as at least one battery and asuitable electronics unit 48 to regulate voltage, current and/or frequency of power supplied to themodular assembly 20. In one embodiment, the power/pulser sub 30 is capable of running thetool 20 at low or even no flow. Exemplary batteries include rechargeable batteries, lithium batteries and nickel cadmium (Ni—Cd) batteries. In one embodiment, thepower source 46 is included that individually powers each module. For example, thepower source 46 includes one ormore batteries 46 to operate thesensor sub 38 and one ormore batteries 46 to operate thepacker sub 34. Various subs are powered by thepower source 46, thewired pipe adapter 28 or any other suitable power source. - In one embodiment, the
sensor sub 38 includes at least onesensor 50 configured to measure various properties of theborehole 12 and/or theformation 14, such as a pressure sensor. Examples of such properties include pressure, flow rate, gas content, mud composition and others. In one embodiment, thepressure sensor 50 is an electrically conductive member that changes resistance due to changes in strain in response to pressure variations. In one embodiment, asensor electronics unit 52 is coupled to thesensor 50 and measures a current change to calculate change in resistance and the corresponding pressure change. Thesensor electronics unit 52 may include its own power source or measure current applied by the power/pulser sub 30. In one embodiment, thesensor electronics unit 52 includes an amplifier to amplify the signal generated therein. Thesensor sub 38, in addition to pressure sensors, may include any number or type of additional sensors to detect various conditions in and/or characteristics of the borehole, the circulating fluid and/or the formation. - The
decoder sub 40, in one embodiment, includes adecoder electronics unit 54, such as a microprocessor, to receive input from thesensor sub 34 and actuate thepacker sub 34 when a sufficient change in a property is detected. Thedecoder electronics unit 54 is configured to recognize when a change in a property occurs beyond a selected threshold, and in response actuate thepacker sub 34 to seal off a portion of theborehole 12. In one embodiment, thedecoder electronics unit 54 is configured to be in a sleeping mode when thetool 20 is out of hole, and to power up when thetool 20 is exposed to pressure to preserve power and protect thetool 20 from premature actuation during transport and storage. - Referring to
FIG. 3 , thebypass sub 36 includes a bypass assembly having avalve 56 andbypass electronics unit 58 for controlling thevalve 56 to allow mud to flow from the interior of thedrillstring 11 to an exterior of thedrillstring 11 and into theborehole 12. In one embodiment, thevalve 56 is a poppet valve cooperating with a bypass annulus 60 or other conduit to engage in fluid communication with aninterior conduit 62 of thedrillstring 11. In the closed position shown inFIG. 3 , the poppet valve seals 56 off the annulus 60 to prevent fluid flow between theinterior conduit 62 and an exterior of thedrillstring 11. In the open position, thepoppet valve 56 is moved to allow fluid flow through the annulus. In one embodiment, thebypass electronics unit 58 includes various sensors and/or motors for sensing a condition in which bypass is needed and/or to actuate thevalve 56. In one embodiment, the bypass sub includes astring valve 57, which may be connected tosuitable control electronics 59, for controlling fluid flow through thedrillstring 11. The string valve may be a poppet valve or any other suitable valve configuration. In one embodiment, the bypass assembly and thedrillstring valve 57 are housed in separate modules that can be individually removed and attached to thetool 20. In one embodiment, thestring valve 57 is located below thevalve 56 to allow bypass circulation in the event that thestring valve 57 is actuated to close the string. - Referring to
FIGS. 4 and 5 , thepacker sub 34 includes astring valve 63, apacker element 64 and anactuator assembly 66 including apacker valve 67 such as a poppet valve. Although thestring valve 63 and thevalve 67 are shown as poppet valves, either may take any suitable configuration. Theactuator assembly 66 includes electronics and/or pressure sensors for controlling actuation of thevalve 67 and/or theelement 64. Theactuator assembly 66, in one embodiment, is disposed in communication with thedecoder sub 40, for example, which in turn activates theactuator assembly 66 to cause thepacker 64 to inflate or otherwise extend radially toward the sides of the borehole 12 to seal off a section of theborehole 12.FIG. 4 shows theactuator assembly 66 in a non-actuated or drilling position, andFIG. 5 shows the actuator in an actuated position. When thepacker sub 34 is in the actuated mode, both thedrillstring 11 and afluid conduit 68 within thepacker sub 38 housing is sealed off. The drilling fluid ormud 16 is now circulated through acirculation port 70 just above the annular seal formed by thepoppet valve 67 and directed to anannulus 72 through one ormore bores 74 to inflate thepacker element 64. In one embodiment, thevalve 63 is located below thevalve 67 to allow for bypass circulation, and may also be located below thepacker element 64. - In one embodiment, the system includes four independently operating valves. For example, the valves are incorporated into the
bypass sub 36 and/or thepacker sub 34 and are configured with thebypass valve 56 located above thepacker valve 67. In one embodiment, thepacker valve 67 is configured as independently operating inflation and deflation valves. Thestring valve 63, which may be located in the separatestring valve sub 37 and/or thebypass sub 36, is located below thebypass valve 56 and the packer valve(s) 67. Such a configuration allows for increased flexibility to perform various functions such as measuring the bottom hole pressure development inside the drill pipe, i.e., the shut-in drill pipe pressure (SIDPP), releasing a kick through the drill pipe instead of the annulus, and bullheading the formation. This configuration is also useful in performing drill stem testing. - In one embodiment, the
actuator assembly 66 includes one or more of an electric motor, a translational mechanism such as a roller screw, thevalve 67, and thecirculation port 70. In one embodiment, the electric motor is started by thedecoder sub 40 when the detected pressure change is beyond a selected threshold. In one embodiment, motor current is continuously controlled by thedecoder electronics 54 during actuation. The motor current increases at the end position of the poppet stroke, and is switched off by thedecoder electronics 54 at a predetermined value. In one embodiment, if any unforeseen motor loads should occur during actuation, thedecoder electronics 54 are configured to control the current to prevent damage to thepacker sub 34. - The
circulation port 70 extends from an exterior of thepacker sub 34 to theinterior conduit 68 through which mud or other fluid or gas is introduced. In the actuated mode, thepoppet valve 67 seals thedrillstring 11 and opens thecirculation port 70 to allow fluid to enter theannulus 72 and inflate thepacker element 64. In one embodiment, the packer is automatically deflated by internal stresses in the packer element when thecirculation port 70 is closed and thetool 20 is in the drilling mode. - In one embodiment, one or more of the components of the
actuator assembly 66, such as the electronics unit, motor, roller screw and thepoppet valve 67 each form their own modular sub-assembly. In another embodiment, theactuator assembly 66 and thepacker element 64 are each disposed within their own modular sub. - Although the embodiment shown in
FIG. 2 includessubs tool 20 is not limited to the exemplary number and types of subs or modules described herein. Any number or type of modules may be included to provide selected functionality for blowout prevention and other uses. In one embodiment, thetool 20 includes all of thesubs - Each modular unit is interchangeable and includes the
standardized connection interface connection interface BHA 18 and/ortool 20 to be easily adjusted to account for different operation needs. In one embodiment, all electric wires for communication to other modules are located in the center of each module for simple connection and disconnection. In one embodiment, one or more of the subs are encased in a protective housing, for example a resilient or rubberized casing to protect the sub from shocks and vibrations. - Examples of
connections FIG. 2 , each sub has amale connection 41 and afemale connection 43, which may be tapered or straight. In one embodiment, eachconnection - Referring again to
FIG. 2 ,sensors 50, in other embodiments, include sensors that are used to measure properties of theformation 14, to measure properties of theborehole 12 and/or to assess the stresses on and operation of thetool 20. Examples ofsuch sensors 50 include pressure sensors, current sensors, vibration sensors, temperature sensors flow rate sensors, gas content and/or mud composition sensors and others. - Referring again to
FIG. 1 , in one embodiment, thetool 20 is equipped with transmission equipment to communicate ultimately to asurface processing unit 26. Such transmission equipment allows thetool 20 to send critical data to the surface, stop or otherwise control pipe rotation, stop or otherwise control axial movement, control fluid flow, receive and decode commands sent downhole to activate the tool, and perform other functions. Such transmission equipment may take any desired form, and different transmission media and connections may be used. Examples of connections include wired pipe, fiber optic, wireless connections, mud pulse telemetry and any other suitable communication utilized in logging-while-drilling (LWD) equipment. - In one embodiment, the
surface processing unit 26 and/or thetool 20 include components as necessary to provide for storing and/or processing data collected from thetool 20. Exemplary components include, without limitation, at least one processor, storage, memory, input devices, output devices and the like. Thesurface processing unit 26 optionally is configured to control thetool 20. -
FIGS. 6-8 illustrate various examples of thetool 20. Referring toFIG. 6 , in a first example, thetool 20 includes a wiredpipe adapter sub 76 in a modular connection with aBOP sub 78, that includes a battery sub. Referring toFIG. 7 , in a second example, thetool 20 includes a bi-directional power andcommunications module 80 in a modular connection with theBOP sub 78. Referring toFIG. 8 , in a third example, thetool 20 includes a low flow pulser/decoder sub 82 in a modular connection with theBOP sub 78. - Referring to
FIG. 9 , there is provided asystem 80 for preventing blowouts, or other device used in conjunction with theBHA 18 and/or thedrillstring 11. Thesystem 80 may be incorporated in a computer or other processing unit capable of receiving data from thetool 20. The processing unit may be included with thetool 20 or included as part of thesurface processing unit 26. - In one embodiment, the
system 80 includes acomputer 81 coupled to thetool 20. Exemplary components include, without limitation, at least one processor, storage, memory, input devices, output devices and the like. As these components are known to those skilled in the art, these are not depicted in any detail herein. Thecomputer 81 may be disposed in at least one of thesurface processing unit 24 and thetool 20. - Generally, some of the teachings herein are reduced to an algorithm that is stored on machine-readable media. The algorithm is implemented by the
computer 81 and provides operators with desired output. -
FIG. 10 illustrates a method for preventing blowouts in a borehole. The method includes one or more of stages 101-104 described herein. The method may be performed continuously or intermittently as desired. The method is described herein in conjunction with thetool 20 and optionally thedecoder sub 40, although the method may be performed in conjunction with any number and configuration of processors, sensors and tools. The method may be performed by one or more processors or other devices capable of receiving and processing measurement data, such as the microprocessor and/or thecomputer 81. In one embodiment, the method includes the execution of all of stages 101-104 in the order described. However, certain stages 101-104 may be omitted, stages may be added, or the order of the stages changed. - In the
first stage 101, subs are selected and themodular assembly 20 is assembled by connecting each sub in operable communication via theconnections - In the
second stage 102, a change in a property, such as pressure, that is greater than a selected threshold is detected. Information regarding the property change may be sent to the surface for decision. Such decisions include reacting conventionally without use of the downhole BOP, and/or stopping string movement and activating the downhole BOP, and/or running an automatic process at the surface and/or downhole. Transmitting the information to surface may be done with wired pipe, conventional mud pulse telemetry or other suitable means. In one embodiment, a pressure code is generated in the pulser sub in response to the change in pressure. - In the
third stage 103, a code depending on the selected action is transmitted inside the drillstring 11 (via pulse, wired pipe, etc.) to thepacker sub 34 and/or thedecoder sub 40, and thepacker sub 34 is actuated to cause thepacker element 64 to seal off a portion of theborehole 12. When thepacker sub 34 is actuated, both thedrillstring 11 and the borehole 12 are sealed off. Actuation moves thepoppet valves actuator assembly 66 has accepted the code. Thedrillstring 11 is closed and thecirculation port 70 is opened to seal off the lower part of theborehole 12. - In the
fourth stage 104, the section of theborehole 12 above thepacker sub 34 is circulated withmud 16 of sufficient density to equalize pressure in the borehole 12 to regain control of the borehole pressure and stabilize theborehole 12. After theborehole 12 is stabilized, thepacker sub 34 is reset back to normal drilling mode, e.g., by sending a new pressure code. - The systems and methods described herein provide various advantages over prior art techniques. The embodiments described herein offer greatly increased system flexibility, which allows the tool to be easily adjusting to coincide with changing operational needs. Examples of such embodiments are described above.
- In support of the teachings herein, various analyses and/or analytical components may be used, including digital and/or analog systems. The system may have components such as a processor, storage media, memory, input, output, communications link (wired, wireless, pulsed mud, optical or other), user interfaces, software programs, signal processors (digital or analog) and other such components (such as resistors, capacitors, inductors and others) to provide for operation and analyses of the apparatus and methods disclosed herein in any of several manners well-appreciated in the art. It is considered that these teachings may be, but need not be, implemented in conjunction with a set of computer executable instructions stored on a computer readable medium, including memory (ROMs, RAMs), optical (CD-ROMs), or magnetic (disks, hard drives), or any other type that when executed causes a computer to implement the method of the present invention. These instructions may provide for equipment operation, control, data collection and analysis and other functions deemed relevant by a system designer, owner, user or other such personnel, in addition to the functions described in this disclosure.
- Further, various other components may be included and called upon for providing aspects of the teachings herein. For example, a sample line, sample storage, sample chamber, sample exhaust, pump, piston, power supply (e.g., at least one of a generator, a remote supply and a battery), vacuum supply, pressure supply, refrigeration (i.e., cooling) unit or supply, heating component, motive force (such as a translational force, propulsional force or a rotational force), magnet, electromagnet, sensor, electrode, transmitter, receiver, transceiver, controller, optical unit, electrical unit or electromechanical unit may be included in support of the various aspects discussed herein or in support of other functions beyond this disclosure.
- One skilled in the art will recognize that the various components or technologies may provide certain necessary or beneficial functionality or features. Accordingly, these functions and features as may be needed in support of the appended claims and variations thereof, are recognized as being inherently included as a part of the teachings herein and a part of the invention disclosed.
- While the invention has been described with reference to exemplary embodiments, it will be understood by those skilled in the art that various changes may be made and equivalents may be substituted for elements thereof without departing from the scope of the invention. In addition, many modifications will be appreciated by those skilled in the art to adapt a particular instrument, situation or material to the teachings of the invention without departing from the essential scope thereof Therefore, it is intended that the invention not be limited to the particular embodiment disclosed as the best mode contemplated for carrying out this invention, but that the invention will include all embodiments falling within the scope of the appended claims.
Claims (20)
1. A system for monitoring and controlling fluid flow through a borehole in an earth formation, the system comprising:
a downhole tool configured to be movable within the borehole; and
a plurality of interchangeable modules disposed within the downhole tool, the plurality of interchangeable modules including at least a sensor module for detecting a property change in the borehole and a packer module for sealing a portion of the borehole in response to the property change,
each of the plurality of interchangeable modules including a connection configuration, the connection configuration of one of the modules being removably engageable with at least another of the modules.
2. The system of claim 1 , wherein the downhole tool includes a segmented tool body having a plurality of segments, each segment having compatible connection mechanisms to allow each of the plurality of interchangeable modules to be replaced.
3. The system of claim 1 , wherein the connection includes a common connection configuration, the connection configuration of one of the modules being engageable with any other of the modules.
4. The system of claim 1 , wherein the property change is detection of an influx of fluid or loss of fluid circulation.
5. The system of claim 1 , wherein the sensor module includes at least one additional sensor for measuring selected characteristics of at least one of the borehole and the formation
6. The system of claim 5 , wherein the property change is selected from a change in at least one of a pressure, flow rate, gas content and fluid composition.
7. The system of claim 1 , further comprising at least one additional module selected from at least one of an upper crossover module, a power/pulser module, a communication module, a bypass module, a decoder module and a lower crossover module.
8. The system of claim 1 , wherein the connection configurations are selected from one of a shaft connection, a threaded connection, a bayonet connection and a pin connection.
9. The system of claim 1 , wherein the packer module includes an actuator and a packer, the actuator configured to cause the packer to extend radially toward a surface of the borehole.
10. The system of claim 9 , wherein the actuator includes at least one valve, and the packer is an inflatable member surrounding an annulus, the valve being actuateable to open a circulation port and cause drilling fluid to enter the annulus and inflate the packer.
11. A method of monitoring and controlling fluid flow through a borehole in an earth formation, the method comprising:
disposing a plurality of interchangeable modules within a downhole tool, the plurality of interchangeable modules including at least a sensor module and a packer module, each of the plurality of interchangeable modules including a connection configuration, the connection configuration of one of the modules being removably engageable with at least another of the modules.
detecting a change in property in the borehole by the sensor module; and
responsive to the change in property being greater than a selected threshold, actuating the packer sub to seal a portion of the borehole.
12. The method of claim 11 , wherein detecting the change in property includes detecting an influx of fluid or loss of fluid circulation.
13. The method of claim 11 , further comprising measuring at least one additional selected characteristic of at least one of the borehole and the formation.
14. The method of claim 11 , wherein detecting the change in property includes detecting a change in at least one of a pressure, flow rate, gas content and fluid composition.
15. The method of claim 11 , wherein disposing the plurality of interchangeable modules includes connecting each of the plurality of modules together via the common connection configuration.
16. The method of claim 11 , wherein the packer module includes an actuator and a packer, and actuating the packer module includes causing the packer to extend radially toward a surface of the borehole.
17. The method of claim 16 , wherein the actuator includes at least one valve, the packer is an inflatable member surrounding an annulus, and actuating the packer module includes opening a circulation port and causing drilling fluid to enter the annulus and inflate the packer.
18. The method of claim 11 , further comprising circulating a fluid having a selected density in a section of the borehole to equalize pressure in the borehole.
19. The method of claim 11 , wherein the plurality of interchangeable modules includes at least one additional module selected from at least one of an adapter sub, a power/pulser sub, a bypass sub, and a decoder sub.
20. The method of claim 11 , wherein the connection configurations are selected from one of a shaft connection, a threaded connection, a bayonet and a pin connection.
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US12/350,557 US20100170673A1 (en) | 2009-01-08 | 2009-01-08 | System and method for downhole blowout prevention |
Applications Claiming Priority (1)
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US12/350,557 US20100170673A1 (en) | 2009-01-08 | 2009-01-08 | System and method for downhole blowout prevention |
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US12/350,557 Abandoned US20100170673A1 (en) | 2009-01-08 | 2009-01-08 | System and method for downhole blowout prevention |
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