US20160076320A1 - Modular drilling fluid control system - Google Patents
Modular drilling fluid control system Download PDFInfo
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- US20160076320A1 US20160076320A1 US14/888,761 US201414888761A US2016076320A1 US 20160076320 A1 US20160076320 A1 US 20160076320A1 US 201414888761 A US201414888761 A US 201414888761A US 2016076320 A1 US2016076320 A1 US 2016076320A1
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- 239000012530 fluid Substances 0.000 title claims abstract description 57
- 238000005553 drilling Methods 0.000 title claims abstract description 52
- 238000000034 method Methods 0.000 claims description 10
- 230000007246 mechanism Effects 0.000 claims description 5
- 239000000126 substance Substances 0.000 abstract description 6
- 239000007787 solid Substances 0.000 description 12
- 230000008569 process Effects 0.000 description 5
- 239000002002 slurry Substances 0.000 description 5
- 230000008901 benefit Effects 0.000 description 3
- 230000008859 change Effects 0.000 description 3
- 230000008439 repair process Effects 0.000 description 3
- 241000282375 Herpestidae Species 0.000 description 2
- 239000000203 mixture Substances 0.000 description 2
- 229910000831 Steel Inorganic materials 0.000 description 1
- 229910000870 Weathering steel Inorganic materials 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 230000001934 delay Effects 0.000 description 1
- 230000003111 delayed effect Effects 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 230000002349 favourable effect Effects 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 238000012423 maintenance Methods 0.000 description 1
- 230000007257 malfunction Effects 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 238000003908 quality control method Methods 0.000 description 1
- 239000010959 steel Substances 0.000 description 1
Images
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
-
- 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
Definitions
- the present invention generally relates to drilling fluid control systems for on-shore drilling rigs. More specifically, the present invention relates to modular drilling fluid control systems for on-shore drilling environments having self-contained subsystem modules with standardized interfaces.
- the subsystem modules may be, for example, a drilling fluid storage module, a mud mixing module, a chemical storage module, a back pressure control module, a choke manifold module, a solids control module, a primary shaker module, a secondary shaker module, a solids dryer module, and/or a shaker pit module.
- Drilling fluid often referred to as “mud”, is typically pumped down through the bore of the drill string and exits through ports at the drill bit. Drilling fluid serves many purposes. For example, drilling fluid may lubricate the drill bit.
- Drilling fluid may also be used to control the pressure in the well bore. Additionally, drilling fluid may move solids from the well bore to the surface. To manage the functions of the drilling fluid, a drilling rig has a fluid control system. The fluid control system may be organized into subsystems to accomplish these tasks.
- Subsystems may include, for example, mud mixing systems, drilling fluid circulation systems, back pressure control systems, solids control systems, drilling fluid storage systems and/or chemical storage systems. Each of these subsystems may have different configurations and capabilities depending on the needs of the particular well being drilled.
- the subsystems of a fluid control system are custom designed and then assembled at the drill site. While the major components of a subsystem may be standard, such as a shale shaker, the conduit that connect each major component may be customized, and the utility connections may be specially made for the particular drill rig. Additionally, the major components may also be specially configured for a specific application.
- the entire rig is shut down, and the malfunctioning component is repaired.
- the component may be repaired on-site.
- the process of diagnosing the problem, repairing the component and testing the repair causes delays.
- the nature of the repair may require that the component be removed and subsequently repaired off-site.
- the process of removing and transporting the component is burdensome. If the component is repaired off-site, a spare component is required to replace the malfunctioning component. With either situation, drilling the well may be delayed, and the cost of the well may increase.
- a need therefore, exists for fluid control subsystem modules that have standardized inputs and outputs. Further, a need exists for a modular fluid control system that is easily transportable, configurable and installable. A need also exists for a fluid control system that is designed using previously designed subsystem modules.
- the present invention generally relates to drilling fluid control systems for on-shore drilling rigs. More specifically, the present invention relates to a drilling fluid control system for on-shore drilling environments having self-contained subsystem modules with standardized interfaces.
- the drilling fluid control system may have subsystem modules arranged to fit in an available space at a drill rig site.
- the subsystem modules may be a drilling fluid storage module, a mud mixing module, a chemical storage module, a back pressure control module, a choke manifold module, a solids control module, a primary shaker module, a secondary shaker module, a solids dryer module and/or a shaker pit module.
- the subsystem modules may be arranged to optimize the flow of the drilling fluid through the drilling fluid control system.
- the drilling fluid control system may have an input and an output that may interface with a drill rig.
- the drilling fluid control system may also have interfacing conduit that connects the individual subsystem modules together.
- Each subsystem module may have a function with interfaces.
- the subsystem modules with the same function may have the same interfaces so that they are interchangeable. Subsystem modules with the same function may be changed without changing the interfacing conduit.
- Each subsystem module may have a base, a support structure, interfaces and/or internal components. Additionally, the subsystem module may have a floor panel.
- the base may be rectangular in shape and may be configured to fit inside a shipping container. To facilitate transporting the subsystem module by a forklift, the base may have forklift holes. Additionally, the base may have an interface region running the length of the base to secure the subsystem module into the shipping container.
- the support structure may be connected to the base to form a frame. The frame may be configured to fit within the internal dimensions of a standard intermodal shipping container.
- the support structure may have the same length and/or width as the base. Alternatively, the support structure may have a length and/or a width less than the length and/or width of base.
- the subsystem module may have a collapsible support structure and support guides.
- the support guides may be connected to the base. Further, a portion of the collapsible support structure may slide over the support guides so that the collapsible support structure may have a collapsed position and an extended position. Further, the subsystem module may have a locking mechanism that, when engaged, may prevent the collapsible support structure from moving between the collapsed position and the extended position. When the collapsible support frame is in the collapsed position, the subsystem module may fit within the intermodal shipping container.
- An advantage of the present invention is to provide a drilling fluid control system with a modular subsystem where the modular subsystems with the same function may be interchanged.
- the modular subsystem may be changed when the modular subsystem needs repair or when the drilling fluid control system needs a differently configured subsystem with the same function.
- FIG. 1 is a diagram of an embodiment of a fluid control system.
- FIG. 2 is an isometric view of an embodiment of a fluid control system.
- FIG. 3A is a side view of an embodiment of a subsystem module.
- FIG. 3B is a front view of an embodiment of a subsystem module.
- FIG. 4A is an isometric view of an embodiment of a subsystem module with a collapsible frame with the frame in the compact position.
- FIG. 4B is an isometric view of an embodiment of a subsystem module with a collapsible frame with the frame in the extended position.
- the present invention relates to a drilling fluid control system for on-shore drilling environments having subsystem modules with standardized interfaces.
- a slurry refers to a mixture of drilling fluid and solids.
- FIG. 1 and FIG. 2 generally illustrate an embodiment of a drilling fluid control system 100 .
- the drilling fluid control system 100 may have subsystem modules 102 A- 102 H and an output 104 , an input 106 and interfacing conduit 110 .
- the subsystem modules 102 A- 102 H may include an active mud pit module 102 A, a mud mixing module 102 B, a chemical storage module 102 C, a rig pump module 102 D, a back pressure control module 102 E, a primary shaker module 102 F, a secondary shaker module 102 G and/or a shaker pit module 102 H.
- Other modules may include a dryer module (not shown) and/or an operator module (not shown).
- the present invention is not limited to the subsystem modules 102 A- 102 H.
- the subsystem modules 102 A- 102 H required for a particular embodiment will be apparent to a person having ordinary skill in the art.
- the subsystem modules 102 A- 102 H may be connected by the interfacing conduit 110 .
- the output 104 may connect to a drill rig 108 .
- the drilling fluid that exits the output 104 may be pumped by the rig pump module 102 D into a drill string of the drill rig 108 .
- the drilling fluid may be pumped into the well bore of the drill rig 108 .
- Solids from the drilling process may accumulate in the drilling fluid in the well bore to form a slurry.
- the slurry may flow into input 106 and into the back pressure control module 102 E.
- the subsystem modules 102 A- 102 H may be organized according to the requirements of a particular embodiment.
- Each subsystem module 102 A- 102 H may be configured to fit into a shipping container.
- the external dimensions of each module may be designed to fit within the interior dimensions of the shipping container.
- the subsystem module 102 A- 102 H may be configured so that the subsystem module 102 A- 102 H may be separated into more than one unit with each unit configured to fit the internal dimensions of the shipping container.
- the mud mixing module 102 B may be configured so that the mud mixing module 102 B may separate into two units with each individual unit having dimensions to fit into a separate shipping container.
- the shipping container may be any intermodal shipping container suitable for shipping on a truck, a train and/or a cargo ship.
- the subsystem module 102 A- 102 H may be configured to fit an ISO shipping container with dimensions based on the ISO 6346 standard.
- the subsystem module 102 A- 102 H may be configured to fit a twenty-foot intermodal shipping container.
- the subsystem module may be configured to fit a forty-foot intermodal shipping container.
- the shipping container may be made from corrugated weathering steel.
- the dimensions of the subsystem modules 102 A- 102 H are not limited to fit within the twenty-foot intermodal container or within the forty-foot intermodal container.
- the subsystem modules 102 A- 102 H may be configured to fit into any other shipping container known to persons of skill in the art.
- the subsystem modules 102 A- 102 H may be stackable.
- the subsystem modules 102 A- 102 H may also be arranged to optimize the drilling fluid control system 100 and/or to fit within the available space at the drilling site.
- each subsystem module 102 may have a base 200 , a support structure 202 , interfaces 204 A- 204 C and/or internal components 206 . Additionally, as shown in FIGS. 4A and 4B , the subsystem module 102 may have a floor panel 210 .
- the base 200 may be rectangular in shape and may be configured to fit inside a shipping container.
- the base 200 may have forklift holes 212 to facilitate transporting the subsystem module 102 by a forklift.
- the base 200 may have an interface region 208 running the length of the base 200 to secure the subsystem module 102 into the shipping container.
- the support structure 202 may be connected to the base 200 to form a frame that fits within the internal dimensions of the shipping container.
- the support structure 202 may have the same length and/or width as the base 200 .
- the support structure 202 may have a length and/or a width less than the length and/or width of base 200 .
- the subsystem module 102 may not have a support structure 202 .
- the support structure 202 may be constructed of conventional steel hollow structural sections.
- the subsystem module 102 may have a collapsible support structure 300 , support guides 302 and locking mechanisms 304 .
- the support guides 302 may extend perpendicularly from the base 200 .
- a portion of the collapsible support structure 300 may slide over the support guides 302 .
- the collapsible support structure 300 may move up and down on the support guides 302 so that the collapsible support structure 300 has a collapsed position and an extended position.
- Engaging the locking mechanisms 304 may prevent the collapsible support structure 300 from moving between the collapsed position and the extended position. Releasing the locking mechanisms 304 may allow the collapsible support structure 300 to move between the collapsed position and the extended position.
- FIG. 4A shows the collapsible support structure 300 in the collapsed position.
- FIG. 4B shows the collapsible support structure 300 in the extended position.
- the collapsible support structure 300 may be in the collapsed position to allow the subsystem module 102 to fit into a standard intermodal shipping container. Having the collapsible support structure 300 in the extended position may allow internal components 206 that require more space while the subsystem module 102 is in operation than otherwise may fit in the subsystem module 102 with the support structure 202 .
- the interfaces 204 A- 204 C of each subsystem module 102 may include inputs 204 A, outputs 204 B and/or utility connections 204 C.
- the inputs 204 A may include conduit to input drilling fluid into the subsystem module 102 .
- the back pressure control module 102 E may have a conduit input to receive slurry from the drill rig 108 .
- the inputs 204 A may also include an opening on top of the subsystem module 102 .
- the shaker pit module 102 H may have an input on top to receive solids from a primary shaker module 102 F.
- the outputs 204 B may be conduit for fluid.
- the output 204 B of the rig pump module 102 D may be a conduit to supply drilling fluid to the drill rig 108 via the output 104 of the drilling fluid control system 100 .
- the outputs 204 B may be conduit for solids.
- the secondary shaker module 102 G may have the output 204 B to conduct solids to the shaker pit module 102 H.
- the subsystem module 102 may have multiple outputs 204 B.
- the primary shaker module 102 F may have an outlet 204 B for fluid connected to the secondary shaker module 102 G and an outlet 204 B for solids connected to shaker pit module 102 H.
- a subsystem module may not have an output 204 B.
- shaker pit module 102 H may not have an output 204 B.
- Modules that require power and/or connections to computer controls may have utility connections 204 C.
- the back pressure control module 102 E may have a utility connection 204 C that has a power connection and a connection to a computer control system that controls and/or monitors pressure in the well bore.
- the subsystem module 102 may not have the utility connection 204 C.
- the chemical storage module 102 C may not have a utility connection.
- the above examples are not the only embodiments of the present invention. Whether the subsystem module 102 requires the interfaces 204 A- 204 C will be apparent to a person having ordinary skill in the art.
- Each subsystem module 102 has a function.
- the internal components 206 of the subsystem module 102 are different depending on the function of the subsystem module 102 .
- the function of the primary shaker module 102 F may be to separate the drilling fluid from the slurry.
- the internal components 206 of the primary shaker module 102 F may include a shale shaker such as the MD-3 shale shaker manufactured by the assignee of the present invention.
- a subsystem module 102 that has the same function may have different internal components 206 .
- the primary shaker module 102 F may instead have a Mongoose Pro Shale Shaker manufactured by the assignee of the present invention.
- the present invention is not limited to the above example.
- the internal components 206 necessary for the subsystem module 102 will be apparent to a person having ordinary skill in the art.
- the subsystem modules 102 of the drilling fluid control system 100 are interchangeable with the subsystem modules 102 with the same function. That is, the interfaces 204 A- 204 C of the subsystem module 102 with the same function are in the same location relative to the subsystem module 102 . Additionally, the subsystem modules are configured so that the base 200 and the support structure 202 are substantially the same for subsystem modules 102 that have the same function. Because the interfaces 204 A- 204 C, the base 200 and the support structure 202 are the same in a subsystem module 102 regardless of the composition of the internal components 206 , one subsystem module 102 may be interchanged with another subsystem module 102 with the same function.
- a primary shaker module 102 F with the internal components 206 that include a MD-3 shale shaker may be replaced with a primary shaker module 102 F with the internal components 206 that include a Mongoose Pro shale shaker.
- the subsystem modules 102 may be changed when the needs of the drilling fluid control system 100 change with a minimum of downtime. Additionally, replacing the subsystem module 102 may not require changes to the interfacing conduit 110 .
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Abstract
A drilling fluid control system (100) has subsystem modules (102A-102H), an output (104) and an input (106) connected with interconnecting conduit (110). Each subsystem module (102A-102H) has a function. The subsystem modules (102A-102H) may be an active mud pit module (102A), a mud mixing module (102B), a chemical storage module (102C), a rig pump module (102D), a back pressure control module (102E), a primary shaker module (102F), a secondary shaker module (102G) and/or a shaker pit module (102H). The subsystem modules (102A-102H) with the same function may be interchanged without changing the input (102), the output (102) and the interconnecting conduit (110) of the drilling fluid control system (100). Additionally, the sub-system modules (102A-102H) are configured to fit within intermodal shipping containers.
Description
- This application claims the benefit of U.S. Provisional Patent Application No. 61/819,045, filed 3 May 2013 (Mar. 05, 2013), the disclosure of which is incorporated herein by reference.
- The present invention generally relates to drilling fluid control systems for on-shore drilling rigs. More specifically, the present invention relates to modular drilling fluid control systems for on-shore drilling environments having self-contained subsystem modules with standardized interfaces. The subsystem modules may be, for example, a drilling fluid storage module, a mud mixing module, a chemical storage module, a back pressure control module, a choke manifold module, a solids control module, a primary shaker module, a secondary shaker module, a solids dryer module, and/or a shaker pit module.
- Boreholes are frequently drilled into the Earth's formation to recover deposits of hydrocarbons and other desirable materials trapped beneath the Earth's surface. Traditionally, a well is drilled using a drill bit attached to the lower end of what is known in the art as a drill string. The drill string is traditionally a long string of sections of drill pipe that are connected together end-to-end through rotary threaded pipe connections. The drill string is rotated by a drilling rig at the surface thereby rotating the attached drill bit. Drilling fluid, often referred to as “mud”, is typically pumped down through the bore of the drill string and exits through ports at the drill bit. Drilling fluid serves many purposes. For example, drilling fluid may lubricate the drill bit. Drilling fluid may also be used to control the pressure in the well bore. Additionally, drilling fluid may move solids from the well bore to the surface. To manage the functions of the drilling fluid, a drilling rig has a fluid control system. The fluid control system may be organized into subsystems to accomplish these tasks.
- Subsystems may include, for example, mud mixing systems, drilling fluid circulation systems, back pressure control systems, solids control systems, drilling fluid storage systems and/or chemical storage systems. Each of these subsystems may have different configurations and capabilities depending on the needs of the particular well being drilled.
- Traditionally, the subsystems of a fluid control system are custom designed and then assembled at the drill site. While the major components of a subsystem may be standard, such as a shale shaker, the conduit that connect each major component may be customized, and the utility connections may be specially made for the particular drill rig. Additionally, the major components may also be specially configured for a specific application.
- Designing a new fluid control system requires that each subsystem be individually designed, including the interconnecting conduit and the utility connections. The position of each individual bolt and the length of each pipe is designed and prototyped. This process extends the design time and introduces errors into the system. After the subsystem is designed, each discrete part is ordered or manufactured and then transported to the drill site. The fluid control system is then assembled from discrete parts. However, a drill rig may not be in a favorable environment which makes assembly of the subsystems difficult and cumbersome. Additionally, on-site assembly complicates quality control and maintenance procedures. As a result, the time required to set up a new drill rig and the costs associated with exploring a new drill site may increase dramatically.
- Additionally, when a component of the fluid control system malfunctions, the entire rig is shut down, and the malfunctioning component is repaired. The component may be repaired on-site. However, the process of diagnosing the problem, repairing the component and testing the repair causes delays. Alternatively, the nature of the repair may require that the component be removed and subsequently repaired off-site. Often, the process of removing and transporting the component is burdensome. If the component is repaired off-site, a spare component is required to replace the malfunctioning component. With either situation, drilling the well may be delayed, and the cost of the well may increase.
- During the operating life of a drilling rig, the requirements of the fluid control system may change. Traditionally, to change a subsystem, each component of the subsystem is removed individually. Additionally, a new subsystem is designed, transported and installed. The new subsystem is then be tested. This process may introduce errors into the system that may be costly to remedy.
- A need, therefore, exists for fluid control subsystem modules that have standardized inputs and outputs. Further, a need exists for a modular fluid control system that is easily transportable, configurable and installable. A need also exists for a fluid control system that is designed using previously designed subsystem modules.
- The present invention generally relates to drilling fluid control systems for on-shore drilling rigs. More specifically, the present invention relates to a drilling fluid control system for on-shore drilling environments having self-contained subsystem modules with standardized interfaces. The drilling fluid control system may have subsystem modules arranged to fit in an available space at a drill rig site. The subsystem modules may be a drilling fluid storage module, a mud mixing module, a chemical storage module, a back pressure control module, a choke manifold module, a solids control module, a primary shaker module, a secondary shaker module, a solids dryer module and/or a shaker pit module. The subsystem modules may be arranged to optimize the flow of the drilling fluid through the drilling fluid control system. Further, the drilling fluid control system may have an input and an output that may interface with a drill rig. The drilling fluid control system may also have interfacing conduit that connects the individual subsystem modules together. Each subsystem module may have a function with interfaces. Further, the subsystem modules with the same function may have the same interfaces so that they are interchangeable. Subsystem modules with the same function may be changed without changing the interfacing conduit.
- Each subsystem module may have a base, a support structure, interfaces and/or internal components. Additionally, the subsystem module may have a floor panel. The base may be rectangular in shape and may be configured to fit inside a shipping container. To facilitate transporting the subsystem module by a forklift, the base may have forklift holes. Additionally, the base may have an interface region running the length of the base to secure the subsystem module into the shipping container. Further, the support structure may be connected to the base to form a frame. The frame may be configured to fit within the internal dimensions of a standard intermodal shipping container. The support structure may have the same length and/or width as the base. Alternatively, the support structure may have a length and/or a width less than the length and/or width of base.
- In an embodiment, the subsystem module may have a collapsible support structure and support guides. The support guides may be connected to the base. Further, a portion of the collapsible support structure may slide over the support guides so that the collapsible support structure may have a collapsed position and an extended position. Further, the subsystem module may have a locking mechanism that, when engaged, may prevent the collapsible support structure from moving between the collapsed position and the extended position. When the collapsible support frame is in the collapsed position, the subsystem module may fit within the intermodal shipping container.
- An advantage of the present invention is to provide a drilling fluid control system with a modular subsystem where the modular subsystems with the same function may be interchanged. The modular subsystem may be changed when the modular subsystem needs repair or when the drilling fluid control system needs a differently configured subsystem with the same function.
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FIG. 1 is a diagram of an embodiment of a fluid control system. -
FIG. 2 is an isometric view of an embodiment of a fluid control system. -
FIG. 3A is a side view of an embodiment of a subsystem module. -
FIG. 3B is a front view of an embodiment of a subsystem module. -
FIG. 4A is an isometric view of an embodiment of a subsystem module with a collapsible frame with the frame in the compact position. -
FIG. 4B is an isometric view of an embodiment of a subsystem module with a collapsible frame with the frame in the extended position. - The present invention relates to a drilling fluid control system for on-shore drilling environments having subsystem modules with standardized interfaces. As used herein, a slurry refers to a mixture of drilling fluid and solids.
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FIG. 1 andFIG. 2 generally illustrate an embodiment of a drillingfluid control system 100. The drillingfluid control system 100 may havesubsystem modules 102A-102H and anoutput 104, aninput 106 and interfacingconduit 110. Thesubsystem modules 102A-102H may include an activemud pit module 102A, amud mixing module 102B, achemical storage module 102C, a rig pump module 102D, a backpressure control module 102E, aprimary shaker module 102F, asecondary shaker module 102G and/or ashaker pit module 102H. Other modules may include a dryer module (not shown) and/or an operator module (not shown). However, the present invention is not limited to thesubsystem modules 102A-102H. Thesubsystem modules 102A-102H required for a particular embodiment will be apparent to a person having ordinary skill in the art. Thesubsystem modules 102A-102H may be connected by theinterfacing conduit 110. - The
output 104 may connect to adrill rig 108. The drilling fluid that exits theoutput 104 may be pumped by the rig pump module 102D into a drill string of thedrill rig 108. The drilling fluid may be pumped into the well bore of thedrill rig 108. Solids from the drilling process may accumulate in the drilling fluid in the well bore to form a slurry. The slurry may flow intoinput 106 and into the backpressure control module 102E. However, thesubsystem modules 102A-102H may be organized according to the requirements of a particular embodiment. - Each
subsystem module 102A-102H may be configured to fit into a shipping container. The external dimensions of each module may be designed to fit within the interior dimensions of the shipping container. Additionally, thesubsystem module 102A-102H may be configured so that thesubsystem module 102A-102H may be separated into more than one unit with each unit configured to fit the internal dimensions of the shipping container. For example, themud mixing module 102B may be configured so that themud mixing module 102B may separate into two units with each individual unit having dimensions to fit into a separate shipping container. - The shipping container may be any intermodal shipping container suitable for shipping on a truck, a train and/or a cargo ship. The
subsystem module 102A-102H may be configured to fit an ISO shipping container with dimensions based on the ISO 6346 standard. For example, thesubsystem module 102A-102H may be configured to fit a twenty-foot intermodal shipping container. Alternatively, the subsystem module may be configured to fit a forty-foot intermodal shipping container. Additionally, the shipping container may be made from corrugated weathering steel. However, the dimensions of thesubsystem modules 102A-102H are not limited to fit within the twenty-foot intermodal container or within the forty-foot intermodal container. Thesubsystem modules 102A-102H may be configured to fit into any other shipping container known to persons of skill in the art. - As shown in
FIG. 2 , thesubsystem modules 102A-102H may be stackable. Thesubsystem modules 102A-102H may also be arranged to optimize the drillingfluid control system 100 and/or to fit within the available space at the drilling site. - Referring to
FIGS. 3A and 3B , eachsubsystem module 102 may have a base 200, asupport structure 202, interfaces 204A-204C and/orinternal components 206. Additionally, as shown inFIGS. 4A and 4B , thesubsystem module 102 may have afloor panel 210. The base 200 may be rectangular in shape and may be configured to fit inside a shipping container. The base 200 may haveforklift holes 212 to facilitate transporting thesubsystem module 102 by a forklift. Additionally, thebase 200 may have aninterface region 208 running the length of the base 200 to secure thesubsystem module 102 into the shipping container. Thesupport structure 202 may be connected to the base 200 to form a frame that fits within the internal dimensions of the shipping container. Thesupport structure 202 may have the same length and/or width as thebase 200. Alternatively, thesupport structure 202 may have a length and/or a width less than the length and/or width ofbase 200. In a further embodiment, thesubsystem module 102 may not have asupport structure 202. Thesupport structure 202 may be constructed of conventional steel hollow structural sections. - Referring to
FIGS. 4A and 4B , thesubsystem module 102 may have acollapsible support structure 300, support guides 302 and lockingmechanisms 304. The support guides 302 may extend perpendicularly from thebase 200. A portion of thecollapsible support structure 300 may slide over the support guides 302. Thecollapsible support structure 300 may move up and down on the support guides 302 so that thecollapsible support structure 300 has a collapsed position and an extended position. Engaging the lockingmechanisms 304 may prevent thecollapsible support structure 300 from moving between the collapsed position and the extended position. Releasing the lockingmechanisms 304 may allow thecollapsible support structure 300 to move between the collapsed position and the extended position.FIG. 4A shows thecollapsible support structure 300 in the collapsed position.FIG. 4B shows thecollapsible support structure 300 in the extended position. Thecollapsible support structure 300 may be in the collapsed position to allow thesubsystem module 102 to fit into a standard intermodal shipping container. Having thecollapsible support structure 300 in the extended position may allowinternal components 206 that require more space while thesubsystem module 102 is in operation than otherwise may fit in thesubsystem module 102 with thesupport structure 202. - The
interfaces 204A-204C of eachsubsystem module 102 may includeinputs 204A, outputs 204B and/orutility connections 204C. Theinputs 204A may include conduit to input drilling fluid into thesubsystem module 102. For example, the backpressure control module 102E may have a conduit input to receive slurry from thedrill rig 108. Theinputs 204A may also include an opening on top of thesubsystem module 102. For example, theshaker pit module 102H may have an input on top to receive solids from aprimary shaker module 102F. Theoutputs 204B may be conduit for fluid. For example, theoutput 204B of the rig pump module 102D may be a conduit to supply drilling fluid to thedrill rig 108 via theoutput 104 of the drillingfluid control system 100. Alternatively, theoutputs 204B may be conduit for solids. For example, thesecondary shaker module 102G may have theoutput 204B to conduct solids to theshaker pit module 102H. Thesubsystem module 102 may havemultiple outputs 204B. For example, theprimary shaker module 102F may have anoutlet 204B for fluid connected to thesecondary shaker module 102G and anoutlet 204B for solids connected toshaker pit module 102H. Additionally, a subsystem module may not have anoutput 204B. For example,shaker pit module 102H may not have anoutput 204B. Modules that require power and/or connections to computer controls may haveutility connections 204C. For example, the backpressure control module 102E may have autility connection 204C that has a power connection and a connection to a computer control system that controls and/or monitors pressure in the well bore. Alternatively, thesubsystem module 102 may not have theutility connection 204C. For example, thechemical storage module 102C may not have a utility connection. However, the above examples are not the only embodiments of the present invention. Whether thesubsystem module 102 requires theinterfaces 204A-204C will be apparent to a person having ordinary skill in the art. - Each
subsystem module 102 has a function. Theinternal components 206 of thesubsystem module 102 are different depending on the function of thesubsystem module 102. For example, the function of theprimary shaker module 102F may be to separate the drilling fluid from the slurry. Theinternal components 206 of theprimary shaker module 102F may include a shale shaker such as the MD-3 shale shaker manufactured by the assignee of the present invention. However, asubsystem module 102 that has the same function may have differentinternal components 206. For example, theprimary shaker module 102F may instead have a Mongoose Pro Shale Shaker manufactured by the assignee of the present invention. However, the present invention is not limited to the above example. Theinternal components 206 necessary for thesubsystem module 102 will be apparent to a person having ordinary skill in the art. - The
subsystem modules 102 of the drillingfluid control system 100 are interchangeable with thesubsystem modules 102 with the same function. That is, theinterfaces 204A-204C of thesubsystem module 102 with the same function are in the same location relative to thesubsystem module 102. Additionally, the subsystem modules are configured so that thebase 200 and thesupport structure 202 are substantially the same forsubsystem modules 102 that have the same function. Because theinterfaces 204A-204C, thebase 200 and thesupport structure 202 are the same in asubsystem module 102 regardless of the composition of theinternal components 206, onesubsystem module 102 may be interchanged with anothersubsystem module 102 with the same function. For example, aprimary shaker module 102F with theinternal components 206 that include a MD-3 shale shaker may be replaced with aprimary shaker module 102F with theinternal components 206 that include a Mongoose Pro shale shaker. Thesubsystem modules 102 may be changed when the needs of the drillingfluid control system 100 change with a minimum of downtime. Additionally, replacing thesubsystem module 102 may not require changes to theinterfacing conduit 110. - While the present disclosure has been described with respect to a limited number of embodiments, those skilled in the art, having benefit of this disclosure, will appreciate that other embodiments may be devised which do not depart from the scope of the disclosure as described herein. Accordingly, the scope of the present disclosure should be limited only by the attached claims.
Claims (20)
1. A system comprising:
subsystem modules each having an operational function and internal components associated with the operational function wherein each subsystem module further has a base and a support structure connected to the base to form a frame;
interfaces on the subsystem modules; and
interfacing conduit connecting the subsystem modules.
2. The system of claim 1 wherein the frame is configured to fit within a shipping container.
3. The system of claim 1 further comprising:
a collapsible support structure connected to support guides connected to the base and extending perpendicularly from the base wherein a portion of the collapsible support structure moves in a first direction relative to the support guides to configure the collapsible support structure in a collapsed position and further wherein the collapsible support structure moves in a second direction relative to the support guides to configure the collapsible support structure in an extended position.
4. The system of claim 3 further comprising:
a locking mechanism configured to restrict the collapsible support structure from moving between the collapsed position and the extended position.
5. The system of claim 1 wherein the interfaces of each subsystem module have at least one of an input, an output or a utility connection.
6. The system of claim 1 wherein the subsystem modules having the same operational function are interchangeable with each other.
7. The system of claim 1 wherein the subsystem modules are configured so that the base and the support structure are substantially the same for subsystem modules that have the same operational function.
8. The system of claim 1 wherein the subsystem modules having the same operational function may be replaced without changing the interfacing conduit.
9. The system of claim 1 wherein the interfaces of the subsystem module having the same operational function are located in the same location relative to the subsystem module.
10. The system of claim 1 wherein the subsystem modules are stackable.
11. The system of claim 1 wherein the base has an interface region extending a length of the base to secure the subsystem module into a shipping container.
12. The system of claim 1 further comprising:
an input and an output configured to interface the subsystem modules with a drilling rig.
13. The system of claim 1 wherein the subsystem modules are separated into more than one unit with each unit configured to fit within a shipping container.
14. The system of claim 1 wherein the subsystem modules are configured to fit within an available space at a drilling site.
15. The system of claim 1 wherein the subsystem modules are movable to optimize the operation of the system.
16. A method of providing a modular fluid control system, the method comprising:
attaching subsystem modules to a base and a support structure connected to the base to form a frame wherein each subsystem module has an operational function and internal components associated with the operational function and further wherein each subsystem module has interfaces; and
connecting the interfaces of the subsystem modules with conduit.
17. The method of claim 16 further comprising:
configuring the subsystem modules to optimize the operation of the modular fluid control system.
18. The method of claim 16 further comprising:
connecting an input to receive fluid into one of the subsystem modules and connecting an output to supply fluid to a drilling rig.
19. A system comprising:
subsystem modules arranged in support frames wherein the subsystem modules each have a function and internal components associated with the function; and
conduit connecting the subsystem modules to provide control of a fluid through the subsystem modules.
20. The system of claim 19 wherein the subsystem modules are configured to separate into more than one unit with each unit configured to fit within a shipping container.
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
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US14/888,761 US20160076320A1 (en) | 2013-05-03 | 2014-05-02 | Modular drilling fluid control system |
Applications Claiming Priority (3)
Application Number | Priority Date | Filing Date | Title |
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US201361819045P | 2013-05-03 | 2013-05-03 | |
US14/888,761 US20160076320A1 (en) | 2013-05-03 | 2014-05-02 | Modular drilling fluid control system |
PCT/US2014/036530 WO2014179666A1 (en) | 2013-05-03 | 2014-05-02 | Modular drilling fluid control system |
Publications (1)
Publication Number | Publication Date |
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US20160076320A1 true US20160076320A1 (en) | 2016-03-17 |
Family
ID=51843966
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
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US14/888,761 Abandoned US20160076320A1 (en) | 2013-05-03 | 2014-05-02 | Modular drilling fluid control system |
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US (1) | US20160076320A1 (en) |
WO (1) | WO2014179666A1 (en) |
Cited By (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20170350371A1 (en) * | 2016-06-01 | 2017-12-07 | Senvion Gmbh | Device and arrangement for the horizontal preassembly of a wind turbine rotor |
Citations (1)
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US4438817A (en) * | 1982-09-29 | 1984-03-27 | Armco Inc. | Subsea well with retrievable piping deck |
Family Cites Families (5)
Publication number | Priority date | Publication date | Assignee | Title |
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US6357365B1 (en) * | 1999-11-18 | 2002-03-19 | Hoover Group, Inc. | Intermediate bulk container lifting rack |
US20070108246A1 (en) * | 2005-11-15 | 2007-05-17 | Jennings Bill J | Extendible hauling rack |
US8083935B2 (en) * | 2007-01-31 | 2011-12-27 | M-I Llc | Cuttings vessels for recycling oil based mud and water |
US8695809B2 (en) * | 2007-05-16 | 2014-04-15 | M-I Llc | Return drilling fluid processing |
US8231316B2 (en) * | 2009-01-23 | 2012-07-31 | Danny Ness | Offshore cargo rack for use in transferring fluid holding tank loads between a marine vessel and an offshore platform |
-
2014
- 2014-05-02 US US14/888,761 patent/US20160076320A1/en not_active Abandoned
- 2014-05-02 WO PCT/US2014/036530 patent/WO2014179666A1/en active Application Filing
Patent Citations (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4438817A (en) * | 1982-09-29 | 1984-03-27 | Armco Inc. | Subsea well with retrievable piping deck |
Cited By (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20170350371A1 (en) * | 2016-06-01 | 2017-12-07 | Senvion Gmbh | Device and arrangement for the horizontal preassembly of a wind turbine rotor |
US11035345B2 (en) * | 2016-06-01 | 2021-06-15 | Senvion Gmbh | Device and arrangement for the horizontal preassembly of a wind turbine rotor |
Also Published As
Publication number | Publication date |
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WO2014179666A1 (en) | 2014-11-06 |
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