Untitled record
Abstract
A pressurized fracturing fluid is provided with a fracturing pump carrier vehicle comprising a first fracturing pump and a second fracturing pump that are coupled on opposite sides of a dual shaft electric motor. A first transmission line assembly comprises a first coupling coupling that allows the selective coupling and/or uncoupling of the first fracturing pump with the double shaft electric motor. A second driveline assembly comprises a second hitch coupling that allows selective engagement and/or disengagement of the second fracturing pump with the dual-shaft electric motor. The fracturing pump carrier vehicle also comprises a latching panel that allows selective latching or unlatching at the first latching coupling based on receipt of a remote command.

Term
No projected expiry on record.
- Priority
- Filed
- Published
- Today
20 claims: 4 independent, 16 dependent
- 1REIVINDICACIONES 1. Un sistema para bombear y presurizar fluido de fracturación CARACTERIZADO PORQUE comprende:un vehículo transportador móvil, un motor eléctrico primario en el vehículo transportador móvil, una bomba de fracturación instalada en el vehículo transportador móvil, un panel de enganche configurado para recibir un comando remoto para desenganchar la bomba de fracturación respecto del motor eléctrico primario, y un conjunto de línea de transmisión que comprende un acoplamiento de enganche configurado para desenganchar la bomba de fracturación y un eje del motor eléctrico primario que es activado por el panel de enganche en respuesta a la recepción del comando remoto.
- 2El sistema de acuerdo con la reivindicación 1, CARACTERIZADO PORQUE el motor eléctrico primario es un motor eléctrico primario de doble eje que extiende el eje hacia fuera en lados opuestos del motor eléctrico primario de doble eje.
- 3El sistema de acuerdo con la reivindicación 2, CARACTERIZADO PORQUE además comprende una segunda bomba de fracturación instalada en el vehículo transportador móvil y un segundo conjunto de línea de transmisión que comprende un segundo acoplamiento de enganche configurado para desenganchar selectivamente la segunda bomba de fracturación y el motor eléctrico primario de doble eje.
- 4El sistema de acuerdo con la reivindicación 1, CARACTERIZADO 1026802 1 de 6 PORQUE el conjunto de línea de transmisión comprende un eje con cuña y en donde el acoplamiento de enganche está configurado para desenganchar selectivamente el eje con cuña del eje.
- 5El sistema de acuerdo con la reivindicación 4, CARACTERIZADO PORQUE el conjunto de línea de transmisión comprende un acoplamiento fijo que acopla un eje de piñón de la bomba de fracturación con el eje con cuña.
- 6El sistema de acuerdo con la reivindicación 1, CARACTERIZADO PORQUE además comprende una estación de monitoreo instalada en el vehículo transportador móvil y configurada para transmitir el comando remoto al panel de enganche.
- 7El sistema de acuerdo con la reivindicación 1, CARACTERIZADO PORQUE el acoplamiento de enganche está configurado para desengancharse selectivamente cuando el eje está girando.
- 8El sistema de acuerdo con la reivindicación 1, CARACTERIZADO PORQUE el acoplamiento de enganche está configurado para desengancharse selectivamente después que el eje deja de girar.
- 9El sistema de acuerdo con la reivindicación 1, CARACTERIZADO PORQUE la bomba de fracturación incluye un eje de doble piñón.
- 10El sistema de acuerdo con la reivindicación 1, CARACTERIZADO PORQUE además comprende una segunda bomba de fracturación instalada en el vehículo transportador móvil, en donde cada una de la bomba de fracturación y la segunda bomba de fracturación comprende un conjunto de lado fluídico que se instala en un mismo lado del vehículo transportador móvil.
- 11Un vehículo transportador de bomba de fracturación CARACTERIZADO PORQUE comprende:1026802 2 de 6 una primera bomba de fracturación, una segunda bomba de fracturación, un motor eléctrico de doble eje que comprende un eje que tiene un primer extremo y un segundo extremo, un primer conjunto de línea de transmisión que comprende un primer acoplamiento de enganche que permite el selectivo enganche, desenganche o ambos de la primera bomba de fracturación con el primer extremo del eje, un segundo conjunto de línea de transmisión que comprende un segundo acoplamiento de enganche que permite el selectivo enganche, desenganche o ambos de la segunda bomba de fracturación con el segundo extremo del eje, y un panel de enganche que permite el enganche o desenganche selectivo en el primer acoplamiento de enganche en base a la recepción de un comando remoto.
- 12El vehículo transportador de bomba de fracturación de acuerdo con la reivindicación 11, CARACTERIZADO PORQUE el primer conjunto de línea de transmisión comprende un eje con cuña y en donde el acoplamiento de enganche permite el selectivo enganche, desenganche o ambos del eje con cuña y el primer extremo del eje.
- 13El vehículo transportador de bomba de fracturación de acuerdo con la reivindicación 12, CARACTERIZADO PORQUE el primer conjunto de línea de transmisión comprende un acoplamiento fijo que acopla la primera bomba de fracturación al eje con cuña.
- 14El vehículo transportador de bomba de fracturación de acuerdo 1026802 3 de 6 con la reivindicación 11, CARACTERIZADO PORQUE el acoplamiento de enganche permite el selectivo enganche, desenganche o ambos después que el eje deja de girar.
- 15El vehículo transportador de bomba de fracturación de acuerdo con la reivindicación 11, CARACTERIZADO PORQUE la primera bomba de fracturación incluye un eje de doble piñón.
- 16El vehículo transportador de bomba de fracturación de acuerdo con la reivindicación 11, CARACTERIZADO PORQUE cada una de la primera bomba de fracturación y la segunda bomba de fracturación comprende un conjunto de lado fluídico que se orienta hacia un mismo lado del vehículo transportador.
- 17Un método para bombear y presurizar fluido de fracturación, CARACTERIZADO PORQUE el método comprende:recibir un comando de desenganche desde una ubicación remota para un vehículo transportador de bomba de fracturación, desenganchar, en respuesta a la recepción del comando de desenganche, una primera bomba de fracturación instalada en el vehículo transportador de bomba de fracturación con un motor eléctrico primario de doble eje instalado en el vehículo transportador de bomba de fracturación que utiliza un primer conjunto de línea de transmisión, en donde el primer conjunto de línea de transmisión comprende un acoplamiento de enganche que permite el enganche selectivo entre la primera bomba de fracturación y el motor eléctrico primario de doble eje, y accionar una segunda bomba de fracturación instalada en el vehículo transportador de bomba de fracturación con el motor eléctrico 1026802 4 de 6 primario de doble eje después de desenganchar la primera bomba de fracturación respecto del motor eléctrico primario de doble eje utilizando el primer conjunto de línea de transmisión.
- 18El método de acuerdo con la reivindicación 17, CARACTERIZADO PORQUE además comprende:recibir un segundo comando de desenganche desde la ubicación remota para el vehículo transportador de bomba de fracturación, y desenganchar, en respuesta a la recepción del segundo comando de desenganche, la segunda bomba de fracturación con el motor eléctrico primario de doble eje utilizando un segundo conjunto de línea de transmisión, en donde el segundo conjunto de línea de transmisión comprende un segundo acoplamiento de enganche que permite el enganche selectivo entre la segunda bomba de fracturación y el motor eléctrico primario de doble eje.
- 19El método de acuerdo con la reivindicación 18, CARACTERIZADO PORQUE el desenganche de la segunda bomba de fracturación con el motor eléctrico primario de doble eje ocurre después que el motor eléctrico primario de doble eje deja de accionar la segunda bomba de fracturación.
- 20El método de acuerdo con la reivindicación 17, CARACTERIZADO PORQUE cada una de la primera bomba de fracturación y la segunda bomba de fracturación comprende un conjunto de lado fluídico montado en un mismo lado del vehículo transportador de bomba de fracturación. p/p EVOLUTION WELL SERVICES, LLC Clarke, Modet^Cía. (Argentina) S.A. (E-2306) 1026802 5 de 6 CLARKE MODET & CÍA (ARGENTINA) S.A. - 30540437455 Digitally signed by PORTALTRAM ITES - INPI Date:2020.07.28 16:57:18 -03:00 Reason: Firmado Digitalmente por el INPI Location: Buenos Aires, Argentina 1026802
Independent claims20
183 paragraphs in 4 sections, as filed
MOBILE FRACTURATION PUMP TRANSPORTER VEHICLE FOR HYDRAULIC FRACTURATION OF UNDERGROUND GEOLOGICAL FORMATIONS
BACKGROUND
[0001] The oil and gas industry commonly uses hydraulic fracturing to stimulate production from hydrocarbon wells, such as oil and/or gas wells. Hydraulic fracturing, sometimes referred to as hydraulic fracturing or fracking, is the process of injecting fracturing fluid, which is typically a mixture of water, sand, and chemicals, into the subsurface to fracture subterranean geological formations, thereby releasing fracturing reserves. encapsulated hydrocarbons. Typically, fracturing fluid is pumped into a well at a relatively high pressure that is sufficient to cause fissures within underground geological formations. Specifically, once inside the wellbore, the pressurized fracturing fluid is pumped down under pressure and then into the subsurface geological formation to fracture the underground formation. A fluid mixture that may include water, various chemical additives, and proppant agents (for example, sand or ceramic material) may be pumped into the underground formation to fracture and promote the extraction of hydrocarbon reserves, such as oil and/or gas. For example, the fracturing fluid may comprise a liquefied petroleum gas, linear gel water, gel water, gel oil, oily water, oily oil, polyethylene emulsion, foam/emulsion, liquid carbon dioxide (CO2), nitrogen gas ( N2) and/or binary and acidic fluid.
[0002] The implementation of large-scale fracturing operations
1026802 62 at well sites typically requires a large investment in equipment, labor, and fuel. For example, a typical fracturing operation uses a variety of fracturing equipment, large numbers of personnel to operate and maintain the fracturing equipment, relatively large amounts of fuel to power the fracturing operations, and relatively large volumes of fracturing fluids. As such, planning for fracturing operations is often complex and encompasses a variety of logistical challenges including minimizing the footprint of the fracturing operations site, providing adequate power and/or fuel to continuously fuel fracturing operations, fracturing, increase the efficiency of hydraulic fracturing equipment and reduce any environmental impact resulting from fracturing operations. Therefore, numerous innovations and improvements to existing fracturing technology are needed to address the variety of complex logistical challenges facing fracturing operations today.
SYNTHESIS
[0001] The following presents a simplified summary of the content disclosed in order to provide a basic understanding of some aspects of the content disclosed herein. This summary is not an exhaustive overview of the technology disclosed herein. It is not the intention to identify key or critical elements of the invention or to delineate the scope of the invention. The sole purpose is to present some concepts in a simplified form as a prelude to the more detailed description that will be described later.
1026802 of 62
[0002] A system for pumping and pressurizing fracturing fluid, wherein the system comprises: a mobile carrier, a prime electric motor comprising a shaft and installed on the mobile carrier, a transmission line assembly, a pump fracturing installed on the mobile carrier that is coupled to one end of the shaft through the drive line assembly. The driveline assembly comprises a hitch coupling configured to selectively engage and/or disengage the fracturing pump and prime mover and a hitch panel mounted to the mobile carrier and configured to receive a remote command and activate, on response to remote command, engagement and/or disengagement of the fracturing pump and prime mover.
[0003] A fracturing pump carrier vehicle comprising: a first fracturing pump, a second fracturing pump, a dual-shaft electric motor comprising a shaft having a first end and a second end, a first drive line assembly comprising a first hookup coupling allowing hookup and/or selective disengagement of the first fracturing pump with the first end of the shaft, a second transmission line assembly comprising a second coupling coupling that allows selective coupling and/or uncoupling of the second fracturing pump with the second end of the shaft and a coupling panel that allows selective coupling and/or uncoupling in the first latching coupling, selective latching and/or unlatching on the second latching coupling, or both based on receipt of a remote command.
1026802 of 62
[0004] A method of pumping and pressurizing fracturing fluid, wherein the method comprises: receiving a latch and/or unlatch command from a remote location for a frac pump carrier vehicle, latching and/or unlatching, in response to receiving the latch command, a first frac pump installed on the pump carrier vehicle fracturing pump with a dual shaft prime mover installed on the frac pump carrier vehicle using a first set of driveline, wherein the first transmission line assembly comprises a coupling coupling that allows selective coupling between the first fracturing pump and the double-shaft primary electric motor and driving a second fracturing pump installed on the fracturing pump transporter vehicle with the dual-shaft prime mover either after engaging and/or disengaging the first frac pump from the dual-shaft prime mover using the first set of transmission line.
BRIEF DESCRIPTION OF THE FIGURES
[0005] For a more complete understanding of this disclosure, reference will now be made to the following brief description which is made in connection with the accompanying figures and the detailed description, in which like reference numerals represent like parts.
[0006] Figure 1 is a schematic diagram of one embodiment of a well site where various embodiments may operate within.
[0007] Figure 2 is a schematic diagram of one embodiment
1026802 of 62 of a well site that includes a mobile electrical power source comprising three transport vehicles of a mobile fracturing system.
[0008] Figure 3 is a schematic diagram of one embodiment of a well site that includes two wellheads and two data booths.
[0009] Figure 4A is a schematic diagram of one embodiment of the gas turbine generator carrier vehicle.
[0010] Figure 4B is a schematic diagram of one embodiment of the gas turbine generator carrier vehicle.
[0011] Figure 5A is a schematic diagram of one embodiment of an inbound and outbound conveyor vehicle.
[0012] Figure 5B is a schematic diagram of one embodiment of an inbound and outbound conveyor vehicle.
[0013] Figure 5C is a schematic diagram of one embodiment of an intake and exhaust conveyor vehicle that includes a sliding air intake filter housing.
[0014] Figure 6 is a schematic diagram of one embodiment of the two electrical power sources in mobile transport vehicles in one mode of operation.
[0015] Figure 7 is a schematic diagram of one embodiment of a fracturing pump carrier vehicle powered by the mobile electrical power source.
[0016] Figure 7 is a schematic diagram of one embodiment of a source-fed fracturing pump carrier vehicle
1026802 of 62 mobile electric power.
[0017] Figure 8A is a schematic diagram of one embodiment of a mixer carrier vehicle that includes an electric mixer.
[0018] Figure 8B is a schematic diagram of one embodiment of a mixer carrier vehicle that includes an electric mixer.
[0019] Figure 9A of an embodiment of a mixer carrier vehicle including an electric mixer with enclosed mixing hoppers.
[0020] Figure 9B of an embodiment of a mixer carrier vehicle including an electric mixer with enclosed mixing hoppers.
[0021] Figure 10 is a schematic diagram of one embodiment of a networked control system that is used to monitor, control and communicate with a variety of control systems located at one or more well sites.
[0022] Figure 11 is a flow chart of one embodiment of a method for providing a mobile source of electrical power to fracturing operations.
[0023] Figure 12 is a flow chart of one embodiment of a method for pumping fracturing fluid into a wellhead.
[0024] Figure 13 is a schematic diagram of one embodiment of a fracturing pump carrier vehicle configured to remotely engage and/or disengage one or more pumps.
1026802 of 62 with respect to the prime mover.
[0025] Figure 14A is a schematic diagram of one embodiment of a transmission line assembly including a latching coupling located in a latched position.
[0026] Figure 14B is a schematic diagram of one embodiment of a transmission line assembly including a latching coupling located in a latching position.
[0027] Figure 15A is a schematic diagram of one embodiment of a latching panel configured to cause remote latching and/or unlatching of one or more pumps from a prime mover.
[0028] Figure 15B is a schematic diagram of one embodiment of a hydraulic control bank located within a hitch panel.
[0029] Although some embodiments will be described in connection with the illustrative embodiments shown herein, the invention is not limited to those embodiments. On the contrary, all alternatives, modifications and equivalents as defined by the claims are included within the spirit and scope of the invention. In the figures, which are not to scale, the same reference numbers are used throughout the description and in the figures for components and elements having the same structure and prime reference numbers are used for components and elements having the same structure. similar function and construction to those components and elements having the same reference numbers without primes.
DETAILED DESCRIPTION
1026802 of 62
[0030] As used herein, the term carrier vehicle refers to any transportation assembly including but not limited to a trailer, truck, flatbed and/or barge that is used to transport relatively heavy structures, such as fracturing equipment.
[0031] As used herein, the term trailer refers to a transport assembly used for transporting relatively heavy structures, such as fracturing equipment that can be connected and/or disconnected with a motor vehicle used for towing or moving the trailer. In one embodiment, the trailer may include mounting and distribution systems for connecting the trailer to other fracturing equipment within a fracturing system or park.
[0032] As used herein, the term drop trailer refers to a trailer that includes two sections with different vertical heights. One of the sections or the upper section is located level with or above the trailer axles and the other of the sections or the lower section is located at or below level with the trailer axles. In one embodiment, the main beams of the tipped trailer may be supported on the ground when in the operating mode and/or when uncoupled from a motor vehicle, such as a tractor.
[0033] As used herein, the term gas turbine generator refers to both the gas turbine and the generator sections of a gas turbine generator carrier. The gas turbine generator receives a hydrocarbon fuel, such as natural gas, and converts the hydrocarbon fuel into electrical energy.
[0034] As used herein, the term water distribution chamber
1026802 62 intake air is interchangeable and is generally referred to as intake, air intake, and intake manifold throughout this disclosure. Also, the term exhaust manifold is interchangeable and is generally referred to as exhaust diffuser and exhaust manifold throughout this disclosure.
[0035] As used herein, the term gas turbine inlet filter is interchangeable and is generally referred to as inlet filter and inlet filter assembly. The term air intake filter housing is also interchangeable and is generally referred to as filter housing and air filter assembly housing throughout this disclosure. In addition, the term exhaust duct is also interchangeable and is generally referred to as a turbine exhaust stack throughout this disclosure.
[0036] Various exemplary embodiments are disclosed herein that provide mobile electric fracturing operations for one or more well sites. To power fracturing operations, a mobile power source can be configured to provide electrical power to a variety of fracturing equipment located at well sites. The mobile power source can be implemented using at least two carrier vehicles to reduce its footprint at a site. A carrier vehicle, the power generation carrier vehicle, may comprise a gas turbine and generator along with ancillary equipment that supplies electrical power to well sites. For example, the power generation carrier vehicle can produce electrical power in the ranges of approximately
1026802 of 62
15-35 megawatts (MW) when providing electrical power to a single well site. A second carrier vehicle, the intake and exhaust carrier vehicle, may comprise one or more gas turbine intake air filters and a gas turbine exhaust stack. The power generation carrier and the inlet and exhaust carrier may be arranged such that the inlet and exhaust are connected at the side of the gas turbine container rather than through the top of the container. gas turbine container. In one embodiment, the mobile electrical power source may comprise a third supplemental carrier vehicle, an auxiliary gas turbine generator carrier vehicle to provide power to power, start, or power the power generation carrier vehicle and/or provide auxiliary power when peak electrical power demand exceeds the electrical output power of the gas turbine generator carrier vehicle. The auxiliary gas turbine generator carrier vehicle may comprise a smaller gas turbine generator than that used in the power generation carrier vehicle (eg, provides approximately 1-8 MW of electrical power).
[0037] Various exemplary embodiments of implementing mobile fracturing operations using a fracturing pump carrier vehicle comprising a dual shaft electric motor configured to drive at least two pumps are also disclosed herein. The dual shaft electric motor may be an electric motor configured to operate within a desired mechanical power range, such as between about 1,500 horsepower (HP) and about 10,000 HP.
1026802 of 62
Each of the pumps can be configured to operate within a range of desired mechanical power, such as between about 1,500 HP and about 5,000 HP in order to discharge fracturing fluid at relatively high pressures (for example, about 10,000 pounds per inch). square (psi)). In one embodiment, the pumps may be plunger-type pumps comprising one or more plungers for generating high pressure fracturing fluid. The frac pump hauler can install and couple the dual shaft electric motor to the pumps using sub-assemblies that isolate and allow operators to remove the pumps and/or the dual shaft electric motor individually and without disconnecting the hauler of fracturing pump with respect to the mobile fracturing system.
[0038] The disclosure also includes various exemplary embodiments of a network control system that remotely monitors and controls one or more hydraulic fracturing equipment. The various fracturing equipment including but not limited to a mixer, hydration unit, sand handling equipment, chemical additive system and mobile electrical power source can be configured to operate remotely by using a fracking topology. network, such as an Ethernet ring topology network. The network control system can eliminate the implementation of control stations located on and/or in close proximity to fracturing equipment. Instead, a projected location, such as a data booth and/or a remote location away from the fracturing rig's vicinity, can remotely control the fracking rig.
1026802 of 62
[0039] Figure 1 is a schematic diagram of one embodiment of a well site 100 comprising a wellhead 101 and a mobile fracturing system 103. In general, a mobile fracturing system 103 can perform the operations of fracturing to complete a well and/or transform a drilled well into a production well. For example, well site 100 may be a site where operators are in the process of drilling and completing a well. Operators can start the well completion process with vertical drilling, run production casing and cement it into the hole. Operators can also insert a variety of downhole tools into the wellbore and/or as part of a toolstring used to drill the wellbore. After the operators have drilled the well to a certain depth, a horizontal portion of the well can also be drilled and subsequently cemented. Operators can then pack up the drilling rig and a mobile fracturing system 103 can be moved to wellsite 100 to perform fracturing operations that force relatively high-pressure fracturing fluid through wellhead 101. and within underground geological formations to create fissures and cracks within the rock. Fracturing system 103 can be moved off wellsite 100 once operators complete fracturing operations. Typically, fracturing operations at wellsite 100 can last for several days.
[0040] To provide a more transportable and environmentally clean fracturing park, the mobile fracturing system 103 may comprise
1026802 62 a mobile electrical power source 102 configured to generate electrical power by converting hydrocarbon fuel, such as natural gas, that can be obtained from one or more other sources (for example, a producing wellhead) into well site 100, from a remote off-site location, and/or from another relatively convenient location near mobile power source 102. Improving the mobility of the mobile fracturing system 103 can be beneficial because fracturing operations at a well site typically last for several days and then the fracturing equipment is removed from the well site after the fracturing operation is complete. Instead of using a fuel that has a significant impact on air quality (for example, diesel fuel) as a power source and/or receiving electrical power from a distribution network or other type of permanent power generation facility ( for example, located on the well site or off site), The mobile fracturing system 103 uses as its power source a mobile electrical power source 102 that burns cleaner while being transportable along with the other fracturing equipment. Electrical power generated by mobile electrical power source 102 may be supplied to fracturing equipment to power fracturing operations at one or more well sites. As shown in Figure 1, the mobile power source 102 can be implemented using two transport vehicles in order to reduce the footprint of the well site and the ability of operators to move the mobile power source 102. to different well sites and/or different drilling jobs.
1026802 of 62 fracturing. Details regarding the implementation of the mobile electrical power source 102 are described in more detail in Figures 4A-6.
[0041] The mobile electrical power source 102 may supply electrical power to the fracturing equipment in the mobile fracturing system 103 which may include but is not limited to at least one connection apparatus carrier vehicle 112, a plurality of vehicles power carriers 104, at least one auxiliary power carrier 106, at least one mixer carrier 110, at least one data booth 114 and a plurality of fracturing pump carriers 108 that deliver fracturing fluid through wellhead 101 to underground geological formations. The plug-in carrier vehicle 112 may receive electrical power generated from the mobile power source 102 through one or more electrical connections. In one embodiment, the plug-in carrier vehicle 112 may use 13.8 kilovolt (kV) electrical connections to receive power from the mobile electrical power source 102. The plug-in carrier vehicle 112 may comprise a plurality of electrical disconnect switches, fuses, transformers and/or circuit breakers that protect the fracturing equipment. The connection apparatus carrier vehicle 112 can transfer electric power received from the mobile electric power source 102 to the motive power carrier vehicle 104 and the auxiliary power carrier vehicle 106.
[0042] Auxiliary power carrier vehicle 106 may comprise a transformer and control system to control, monitor, and provide power to electrically connected fracturing equipment. In a way
1026802 62 embodiment, the auxiliary power carrier vehicle 106 can receive the 13.8 KV electrical connection and reduce the voltage to 4.8 KV which is provided to the other fracturing equipment, such as the pump carrier vehicle. fracturing 108, mixer carrier 110, sand bin and carrier, hydration equipment, chemical equipment, data booths 114, lighting equipment and any additional ancillary equipment used in fracturing operations. The auxiliary power carrier vehicle 106 can reduce the voltage to 4.8 KV instead of other voltage levels, such as 600 V, in order to reduce the size of the wires for electrical connections and the amount of wiring involved. It is used to connect the mobile fracturing system 103. The control system can be configured to interface with a networked control system such that the auxiliary power carrier vehicle 106 can be monitored and/or controlled from a remote location, such as the data booth 114 or some other location. another type of control center.
[0043] The motive power carrier vehicle 104 can be configured to monitor and control one or more electric motors located on the fracturing pump carrier vehicles 108 through a plurality of connections, such as electrical connections (e.g., wires). copper), fiber optics, wireless, and/or combinations thereof. The connections have been omitted from Figure 1 for the sake of clarity of the figure. The power carrier vehicle 104 may be part of a network control system where each of the power carrier vehicles 104 comprises one or more variable frequency drives (VFDs) that are used for
1026802 62 monitor and control the prime movers on the frac pump haulers 108. The network control system can communicate with each of the prime movers 104 to monitor and/or control each of the frac pump haulers. variable frequency. VFDs can be configured to control the speed and torque of the prime movers by varying the frequency and input voltage at the prime movers. Using Figure 1 as an example, each of the motive power carriers 104 can be configured to drive a plurality of fracturing pump carriers 108. Other relationships between the motive power carrier and the fracturing pump carrier may be used as desired. In one embodiment, the prime mover vehicles 104 may comprise air cleaners and fans that draw air from the environment to cool the VFDs. Other embodiments of the power carrier vehicles 104 may use air conditioning and/or water cooling units to regulate the temperature of the VFDs.
[0044] The fracturing pump carrier vehicle 108 may receive electrical power from the prime mover carrier vehicle 104 to power a prime mover. The prime mover converts electrical energy into mechanical energy to drive one or more pumps. In one embodiment, the prime mover may be a dual shaft electric motor driving two different pumps. The fracturing pump carrier vehicle 108 may be arranged such that a pump is coupled to opposite ends of the dual-shaft electric motor and prevents the
1026802 of 62 coupling of the pumps in series. By avoiding coupling the pumps in series, the frac pump carrier 108 can continue to operate when any one of the pumps fails or has been removed from the frac pump carrier 108. Furthermore, repair of the pumps can be carried out without shutting down the system manifolds that connect the frac pump carrier vehicle 108 with other fracturing equipment within the mobile frac system 103 and wellhead 101. Related details with the implementation of the fracturing pump carrier vehicle 108 are described in more detail in Figures 7A-7B.
[0045] Mixer carrier vehicle 110 may receive electrical power that is supplied through auxiliary power carrier vehicle 106 to power a plurality of electric mixers. A plurality of prime movers may drive one or more pumps that pump the source fluid and mixing additives (for example, sand) into a mixing bowl, mix the source fluid and mixing additives together to form the fracturing fluid, and unload fracturing fluid into the frac pump carrier vehicle 108. In one embodiment, the electric mixer may be a dual configuration mixer comprising electric motors for rotating machinery that is located on a single carrier vehicle which is described in greater detail in US Patent Application Publication Ser. No. 2012/0255734 filed April 6, 2012 by Todd Coli et al. which is titled Mobile, Modular, Electrically Powered System for use in Fracturing Underground Formations.
1026802 of 62 underground) which is incorporated herein in its entirety by way of reference. In another embodiment, a plurality of enclosed mixing hoppers can be used to supply proppants and additives to a plurality of mixing vessels. The electric mixer comprising the enclosed mixing hoppers is described in more detail in Figures 9A and 9B.
[0046] Data booth 114 may be part of a networked control system, in which data booth 114 acts as a control center configured to monitor and provide operating instructions to remotely operate the transport vehicle. mixer 110, mobile electrical power source 102, and fracturing pump carrier vehicle 108 and/or other fracturing equipment within mobile fracturing system 103. For example, data booth 114 may communicate via the networked control system with VFDs located within power carrier vehicle 104 to operate and monitor the status of the electric motors used to drive pumps on the carrier vehicle. of fracturing pump 108. In one embodiment, data booth 114 may communicate with the various fracturing equipment using a network control system having a ring topology. The ring topology can reduce the amount of control wiring used in fracturing operations and increase the capacity and speed of data transfer and communication. The details related to the implementation of the network control system are described in more detail in Figure 10.
[0047] Other fracturing equipment shown in Figure 1, such
1026802 of 62 such as gas treatment carrier vehicle, water tanks, chemical additive chemical tank, hydration unit, sand carrier and sand tank are known to those skilled in the art and are therefore not described in more detail . In one or more embodiments of mobile fracturing system 103, one or more other fracturing equipment shown in Figure 1 may be configured to receive power generated from mobile electrical power source 102. In addition, as shown in Figure 1, one or more embodiments of mobile fracturing system 103 may not include the use of a projectile that receives low-pressure fluid and releases high-pressure fluid toward wellhead 101. The mobile fracturing system network control system 103 can remotely synchronize and/or slave the electric mixer of the mixer carrier 110 with the electric motors of the frac pump carriers 108. Unlike a conventional diesel-powered mixer, electric mixers can perform speed changes by changing the speed of the pumps installed on the 108 frac pump carriers. In other words, if the pumps within the fracturing pump carriers 108 make a change by increasing speed, the electric mixer within a mixer carrier 110 can also automatically compensate for its speed and auxiliary equipment, such as the conveyor. of sand, to accommodate the change in speed. An operator's manual commands cannot be used to effect the gear change.
[0048] Figure 2 is a schematic diagram of one embodiment of a well site 200 that includes a mobile power source.
1026802 62 electric fracturing system 204 comprising three mobile fracturing system carriers 202. Mobile fracturing system 202 may be substantially similar to mobile fracturing system 103 with the exception that the mobile fracturing system comprises a turbine generator carrier auxiliary gas 206. The auxiliary gas turbine generator carrier vehicle 206 can be configured to provide power to start, start, or power the mobile electrical power source 204 and/or provide auxiliary power when peak electrical power demand exceeds the rated power. electrical output of a gas turbine generator carrier vehicle. The auxiliary gas turbine generator carrier vehicle may comprise a smaller gas turbine or diesel generator that generates less power than is used in the gas turbine generator carrier vehicle (e.g., provides approximately 1 - 8 MW of power). electrical). In addition or as an alternative, the auxiliary gas turbine generator carrier vehicle 206 may provide the test, standby, peak power, and/or other emergency standby power capabilities of the mobile fracturing system 202. .
[0049] Figure 2 illustrates that the mobile fracturing system 202 arranges and locates the motive power carrier vehicle 104 and the auxiliary power carrier vehicle 106 in an orientation that is approximately parallel to the connection apparatus carrier vehicle 112 and the auxiliary power carrier vehicle 112. fracturing pump conveyor 108. The location of the motive power carrier vehicle 104 and the auxiliary power carrier vehicle 106 in a parallel orientation rather than an approximately perpendicular orientation,
1026802 62 as shown in Figure 1 can be beneficial, for example, in reducing the footprint of the mobile fracturing system 202. In addition, Figure 2 also illustrates that a fuel source 208, such as natural gas, from a producing wellhead may be located at the well site and used by mobile power source 204 to generate electrical power.
[0050] Although Figures 1 and 2 illustrate a specific configuration of a mobile fracturing system 103 at a well site 100, the disclosure is not limited to that application and/or the specific embodiment illustrated in Figures 1 and two. For example, embodiments of the present disclosure may include a plurality of wellheads 101, a plurality of mixer haulers 110, and a plurality of auxiliary power haulers 106. In addition, mobile electrical power source 102 does not it is limited to use in a fracturing operation and can be applied to power other types of equipment and devices not typically used in a fracturing operation. The use and description of Figures 1 and 2 are exemplary only for the purpose of facilitating description and explanation.
[0051] Figure 3 is a schematic diagram of one embodiment of a well site 300 that includes two wellheads 101 and two data cabinets 114. The two data cabinets 114 may be part of the network control system. which simultaneously monitors and provides operating instructions to the two different wellheads 101. An additional mixer carrier 110 can be added to provide fracturing fluid to the frac pump carriers 108.
1026802 of 62 used to fracture the underground geological structure below the second wellhead 101. Although Figure 3 illustrates that both wellheads 101 are located at the same wellsite 300, other embodiments may have the heads of 101 wells located at different well sites.
[0052] Mobile Source of Electric Power
[0053] The mobile electrical power source may be part of the mobile fracturing system used at a well site as depicted in Figures 1-3. In other words, the mobile electrical power source can be configured to be transportable to different locations (for example, different well sites) along with other fracturing equipment (for example, frac pump carriers) that are part of the system. mobile fracturing system and cannot be left behind after fracturing operations are completed. The mobile source of electrical energy can include at least two different transport vehicles that improve the mobility of the dedicated electrical energy by simplifying and minimizing the operations of the mobilization and immobilization process. For example, the mobile power source can improve mobility by allowing a mobilization and immobilization time period of approximately 24 hours. The mobile power source also incorporates a two-vehicle footprint, in which the same two-vehicle system can be used for both transportation and operating modes. Although Figures 4A-6 illustrate embodiments of implementing a mobile power source using two different carrier vehicles, other mobile power source embodiments
1026802 The gas turbine generator, air inlet filter housing, gas turbine exhaust stack, and other components shown in Figures 4A - 6 can be installed on a different number of carriers ( for example, all on one carrier vehicle or on more than two carrier vehicles). To provide electrical power for fracturing operations at one or more locations (for example, well sites), the mobile electrical power source is designed to unify and mobilize a gas turbine and a generator adapted to convert a fuel. of hydrocarbons, such as natural gas, into electrical energy.
[0054] Figures 4A and 4B are schematic diagrams of one embodiment of the gas turbine generator carrier vehicle 400. Figure 4A illustrates a side profile view of the gas turbine generator carrier vehicle 400 with a turbine container 402 that surrounds the components within the gas turbine generator carrier vehicle 400 and includes cavities for an air manifold chamber. inlet 404, an exhaust manifold 406, and a container vent inlet 418. Figure 4B illustrates a side profile view of the gas turbine generator carrier vehicle 400 depicting the components within the turbine container 402. As shown in Figure 4B, the gas turbine generator carrier vehicle 400 may comprise the following equipment: (1) an inlet air plenum 404, (2) a gas turbine 407 (for example, General Electric (GE) 2500), (3) a 406 exhaust manifold, (4) a 408 generator, (5) a 410 generator circuit breaker, and (6) a 412 control system. Other components not shown in Figure 4B
1026802 of 62 but which may also be located on the gas turbine generator carrier vehicle 400 include a turbine lubricating oil system, a fire suppression system, and a generator lubricating oil system.
[0055] Gas turbine generator carrier vehicle 400 includes gas turbine 407 for generating mechanical power (i.e., rotation of a shaft) from a hydrocarbon fuel source, such as natural gas, natural gas liquefied, condensed and/or other liquid fuels. As shown in Fig. 4B, the gas turbine shaft is connected with the generator 408 in such a way that the generator 408 converts the mechanical energy supplied by the rotation of the shaft and produces electrical energy. Gas turbine 407 may be a gas turbine, such as the GE LM2500 family of gas turbines, Pratt and Whitney FT8 gas turbines, or any other gas turbine that generates sufficient mechanical power for a generator 408 to power to fracturing operations at one or more well sites. Generator 408 may be a BDAX 62-170ER Brush generator or any other generator configured to generate electrical power for fracturing operations at one or more well sites. For example, the combination of gas turbine 407 and generator 408 within a gas turbine generator carrier vehicle 400 can generate electrical power from a range of between at least about 15 megawatts (MW) and about 35 MW. . Other types of gas turbine generators with power ratings greater than about 35 MW or less than about 15 MW can also be used depending on the amount of power needed at the well sites. In a way
1026802 of embodiment 62, to increase the mobility of the gas turbine generator carrier vehicle 400, the gas turbine 407 can be configured to fit within a dimension of approximately 14.5 feet long and approximately four feet in diameter and/or generator 408 can be configured to fit within a dimension of approximately 18 feet long and approximately 7 feet wide.
[0056] Generator 408 may be housed within turbine container 402 which includes air vent systems internal to generator 408 that draw air to the air inlet located at the front and/or rear of generator 408 and discharge air out on the sides via air vents 414. Other embodiments may have the air vents located at different locations on the generator container 408. In one embodiment, the air inlets may be intake vents and the air outlets may be outlet vents that protect the generator from inclement weather. A separate generator vent tube unit can be installed on top of the 400 gas turbine generator carrier vehicle.
[0057] Turbine container 402 may also comprise one or more gas turbine inlet filters configured to provide ventilation air and combustion air through one or more inlet air manifolds 404 to gas turbine 407 Additionally, 418 container vent inlets can be added to increase the amount of ventilation air. The ventilation air may be the air used to cool the gas turbine 407 and to vent the gas turbine casing 402. The combustion air may be the air that is supplied to the gas turbine 407 to aid in cooling.
1026802 of 62 production of mechanical energy. Inlet air manifold 404 may be configured to collect intake air from the gas turbine inlet filter and supply the intake air to the gas turbine. Exhaust manifold 406 may be configured to collect gas turbine exhaust air and supply the exhaust air to the gas turbine exhaust stack.
[0058] To improve the mobility of the gas turbine generator carrier vehicle 400, the air inlet filter housing and the gas turbine exhaust stack are configured to connect from at least one side of the gas container. turbine 402, as opposed to connecting both the air inlet filter housing and the exhaust stack of the gas turbine, at the top of the turbine container 402 or to connect the air intake filter housing at one end of the gas turbine generator carrier vehicle 400 and to connect the exhaust manifold from the side of the turbine container 402. The air inlet filter housing and exhaust stack of the inlet and exhaust carrier vehicle's gas turbine may be connected to the turbine container 402 using one or more expansion connections extending from one or both of the transport vehicles located on the sides of the turbine container 402. Any form of connection that provides a coupling between the turbine canister 402 and the air inlet filter housing and gas turbine exhaust stack without the use of a crane, forklift and/or any other means may be used. external mechanical to connect expansion connections on site and/or connect air inlet filter housing and gas turbine exhaust stack on side
1026802 62 of the turbine container 402. The expansion connections may comprise a conduit and/or an expansion joint to connect the air inlet filter housing and exhaust stack of the gas turbine to the turbine container 402. In addition, routing the gas turbine exhaust stack and air intake filter housing through the sides of the turbine canister 402 can provide complete aerodynamic modeling where the intake airflow and the exhaust airflow exhaust are used to achieve the rated output speed of the gas turbine. The inbound and outbound transporter vehicle is described in more detail below in Figures 5A and 5B.
[0059] To improve mobility across a variety of roadways, the gas turbine generator carrier vehicle 400 in Figures 4A and 4B may have a maximum height of approximately 13 feet 6 inches, a maximum width of approximately 8 feet 6 inches and a maximum length of approximately 66 feet. In addition, the gas turbine generator carrier vehicle 400 may comprise at least three axles that are used to support and distribute weight on the gas turbine generator carrier vehicle 400. Other embodiments of the turbine generator carrier vehicle of gas 400 can be transport vehicles that exceed three axles depending on the total weight of the transport vehicle. The dimensions and number of axles can be adjusted to allow road transportation that typically requires certain height, length and weight restrictions.
[0060] In one embodiment, the gas turbine 407 and generator 408 may be installed on a designed transportation structure 416, a sub-base,
1026802 62 sub-platform, or any other substructure used to support the mounting of the 407 gas turbine and 408 generator. An individual designed carrying frame can be used to align the connections between the gas turbine 407, generator 408, intake manifold 404 and exhaust manifold 406 and/or lower the gas turbine and generator. by configuring a flush mount with the 416 individual designed carrier frame. The individual designed transportation structure 416 can allow for easy alignment and connection of the gas turbine 407 and generator 408 compared to using a separate sub-base for the gas turbine 407 and generator 408. Other ways of embodiments of the gas turbine generator carrier vehicle 400 may use a plurality of sub-bases, for example, by installing the gas turbine 407 on one sub-base and installing the generator 408 on another sub-base.
[0061] Figure 4B illustrates that generator circuit breaker 410 and control systems 412 may be located on gas turbine generator carrier vehicle 400. Generator circuit breaker 410 may comprise one or more circuit breakers that are configured to protect generator 408 from current and/or voltage fault conditions. Generator breaker 410 may be a medium voltage (MV) breaker panel. In one embodiment, the generator circuit breaker may have approximately three panels, two for the generator and one for a feeder that protects the relays in the circuit breaker. In one embodiment, generator breaker 410 may be a vacuum breaker. Control system 412 can be configured to control, monitor, regulate, and adjust the power output of gas turbine 407 and generator 408. By
1026802 For example, control system 412 may monitor and balance the load produced by fracturing operations by generating sufficient electrical power to meet load demands. The 412 control system can also be configured to synchronize and communicate with a networked control system that allows a data booth or other computer systems located at a remote location (for example, off the well site) to control , monitor, regulate and adjust the power output of the 408 generator. Although Figure 4B illustrates that the generator circuit breaker 410 and/or control system 412 may be installed on the gas turbine generator carrier vehicle 400, other mobile power source embodiments may install the generator circuit breaker. generator 410 and/or control system 412 at other locations (eg, the plug-in carrier vehicle).
[0062] Other equipment that may also be located on the gas turbine generator carrier vehicle 400, but not shown in Figures 4A and 4B include the turbine lubricating oil system, gas fuel valves, the of lubricating oil from the generator and the fire extinguishing system. Lube oil systems or consoles, which generally refer to both turbine lube oil system and generator lube oil system within this disclosure, can be configured to provide generator lube oil filtration and cooling systems. and the turbine. In one embodiment, the turbine lube oil console area of the carrier vehicle may also contain the fire suppression system which may comprise sprinklers, water vapor, cleaning agent, foam spray, carbon dioxide, etc.
1026802 62 carbon and/or other equipment used to extinguish a fire or provide fire protection for the 407 gas turbine. Mounting the turbine lube oil consoles and fire suppression system on the 400 gas turbine generator carrier reduces the footprint of this carrier by eliminating the need for an auxiliary carrier and connections for the turbine and generator lubricating oil, filtration and cooling systems and the fire suppression system for the gas turbine generator carrier vehicle. The turbine and generator lube oil systems can be installed on a platform that is located below the generator 408 or at any other location on the gas turbine generator carrier vehicle 400.
[0063] Figures 5A and 5B are schematic diagrams of embodiments of an entry and exit transporter vehicle 500. Specifically, Figure 5A depicts the entry and exit transporter vehicle 500 when it is in the transport mode and the Figure 5B depicts the inbound and outbound transporter vehicle 500 when in the operating mode. As shown in Figures 5A and 5B, the intake and exhaust carrier vehicle 500 includes an air intake filter housing 502 and a gas turbine exhaust stack 504. Although not shown in Figures 5A and 5B, one or more gas turbine intake filters and ventilation systems can be located or housed in the air intake filter housing 302.
[0064] Figures 5A and 5B illustrate that the air intake filter housing 502 can be installed on the intake and exhaust carrier vehicle 500 in a fixed location. Other embodiments of the vehicle
1026802 The 62 intake and exhaust conveyor 500 can install the air intake filter housing 502 in such a configuration that the air intake filter housing 502 can slide in one or more directions when transitioning between operating mode. operation and mode of transportation. For example, as shown in Figure 5C, the air intake filter housing 502 can be slid out in operating mode and slid back in for transport mode. The air intake filter housing slide 502 can be used to align the air intake filter housing 502 with the gas turbine container intake air manifold installed on the gas turbine generator carrier vehicle . In another embodiment, the air inlet filter housing 502 can be installed on a turntable with the ability to engage the inlet air plenum of the gas turbine container installed on the gas turbine generator carrier vehicle. gas. The air intake filter housing 502 may comprise a plurality of noise reducing mufflers. The different mounting embodiments of the air inlet filter housing 502 may depend on the amount of clean air and the air flow dynamics that need to be supplied to the gas turbine for combustion.
[0065] Gas turbine exhaust stack 504 may comprise gas turbine exhaust 508, an exhaust extension 506 configured for noise control, and an exhaust end connector 510. Exhaust extension 506 may comprise a plurality of mufflers that reduce the noise of the inlet and exhaust carrier vehicle 500. As
1026802 As shown in Figure 5A, the gas turbine exhaust stack 504 can be installed so that it is initially supported sideways during transport mode. In the operating mode, the gas turbine exhaust stack 504 can rotate without the use of external mechanical means such that the gas turbine exhaust stack 504 is installed on the intake and exhaust conveyor vehicle 500 in its base and in the vertical position. In operating mode, gas turbine exhaust stack 504 can be positioned using hydraulic, pneumatic, and/or electric motors such that it aligns and connects with exhaust end connector 510 and exhaust manifold. of the gas turbine container shown in Figures 4A and 4B.
[0066] Exhaust end connector 510 can be adjusted to accommodate and align gas turbine exhaust stack 504 with the gas turbine container exhaust manifold. In the operating mode, the exhaust end connector 510 can be moved forward in a lateral direction, that is in the direction towards the gas turbine container. The exhaust end connector 510 can be moved rearward in the lateral direction, which is the direction away from the gas turbine container, when transitioning to transport mode. Other embodiments of gas turbine exhaust stack 504 may have gas turbine exhaust 508 and exhaust end connector 510 connected as a single component such that exhaust end connector 510 and stack gas turbine exhaust 504 rotate together during the transition between transport and operating modes.
1026802 of 62
[0067] In another embodiment, during transportation, the gas turbine exhaust stack 504 may be sectioned into a first section and a second section. For example, the first section may correspond to gas turbine exhaust 508 and the second section may correspond to exhaust extension 506. The first gas turbine exhaust stack section 508 may be in the vertical position and the second gas turbine exhaust stack section 506 may be installed adjacent to the first gas turbine exhaust section. For transport. The first section and the second section can be hinged together so that the second section can be rotated up to stack on top of the first section for operation mode. In another embodiment, the gas turbine exhaust stack 504 can be configured such that the entire gas turbine exhaust stack 504 can be lowered or raised while installed on the inbound and outbound carrier vehicle. exhaust 500. [0068] Typically, the air intake filter housing 502 and gas turbine exhaust stack 504 may be transported on separate carrier vehicles and subsequently craned onto the top of the gas turbine container and are installed on the gas turbine generator carrier vehicle during the operating mode. The separate carrier vehicles carrying the air intake filter housing 502 and the gas turbine exhaust stack 504 may not be used during the operating mode. However, by adapting the air intake filter housing 502 and the gas turbine exhaust stack 504 so that they are installed on a single carrier vehicle and interface with at least one side of the
1026802 62 gas turbine installed on the gas turbine generator carrier vehicle, the inlet and exhaust carrier vehicle can be co-located with the gas turbine generator carrier vehicle, and subsequently connect the inlet and exhaust manifold chambers air for operation mode. The result is relatively quick assembly and disassembly that eliminates the use of cranes, forklifts and/or any other external mechanical means for heavy loads at the operating site.
[0069] Figure 6 is a schematic diagram of one embodiment of the two electrical power sources in carrier vehicles 600 when in the operating mode. Figure 6 illustrates a top down view of the coupling between the inlet and exhaust carrier vehicle 500 and the gas turbine carrier vehicle 400 during the operating mode. The exhaust expansion connection 602 can be moved and connected (for example, using hydraulic means) with the exhaust end connector 510 without using external mechanical means in order to connect the gas turbine exhaust stack of the carrier vehicle. intake and exhaust with the exhaust manifold of the gas turbine generator carrier vehicle. The inlet expansion connections 604 are movable and can connect the air intake filter housing of the inlet and exhaust carrier and the inlet air manifold of the gas turbine generator carrier. The two carrier vehicles 400 and 500 can be parked in a predetermined orientation and distance such that the exhaust expansion connection 602 and intake expansion connections 604 have the ability to
1026802 of 62 connect the two transporter vehicles 400 and 500.
[0070] In one embodiment, to adjust the positioning, alignment, and distance in order to connect the two carrier vehicles 400 and 500, each of the carrier vehicles 400 and 500 may include a hydraulic transfer system. For example, the hydraulic transfer system may translate and align the carrier vehicle 500 in a position without connecting the two carrier vehicles 400 and 500 with the motor vehicles (eg, a tractor or other type of motor vehicle). Using Figures 4 and 5 as an example, the hydraulic translation system may comprise a plurality of outriggers and/or support legs 412 that are used to translate carrier vehicle 400 and/or carrier vehicle 500 back and forth. forward and/or sideways. At each stabilizer and/or support leg 412, the hydraulic translation system may comprise a first hydraulic cylinder that lifts the carrier vehicle and a second hydraulic cylinder that translates the carrier vehicle in the projected orientation or direction. A hydraulic travel system on the hauler increases mobility by reducing the precision needed when the two haulers are parked close to each other.
[0071] Figure 11 is a flow chart of one embodiment of a method 1100 for providing a mobile source of electrical power to fracturing operations. Method 1100 can be initiated at block 1102 by transporting a mobile source of electrical power with other fracturing equipment to a well site that includes a non-producing well. Method 1100 can then proceed to block 1104 and convert
1026802 of 62 the mobile source of electrical energy from the mode of transport to the mode of operation. The same transport vehicles can be used during the conversion from transport mode to operation mode. In other words, carrier vehicles are not added and/or removed when the mobile power source is set to the operating mode. Furthermore, method 1100 can be performed without the use of a forklift, crane, and/or other external mechanical means when transitioning from the mobile source of electrical power to the mode of operation. The process of converting two transport trailers is described in more detail in Figures 4A - 6.
[0072] Method 1100 may then proceed to block 1106 and generate electrical power using the mobile electrical power source to power fracturing operations at one or more well sites. In one embodiment, method 1100 may generate electrical power by converting hydrocarbon fuel to electrical power through the use of a gas turbine generator. Method 1100 may then proceed to block 1108 and convert the mobile power source from operating mode to transport mode. Similar to the 1104 block, the 1108 block conversion process can use the same transport vehicles without the need to use a forklift, crane and/or other external mechanical means to transition from the mobile source of electrical power back to transport mode . Method 1100 can then proceed to block 1110 to remove the mobile power source along with other fracturing equipment from the well site once fracturing operations are complete.
[0073] Fracking Pump Carrier Vehicle
1026802 of 62
[0074] Figures 7A and 7B are schematic diagrams of embodiments of a frac pump carrier 700 powered by the mobile source of electrical power as depicted in Figures 4A-6. The frac pump carrier 700 may include a prime mover 704 that powers two separate pumps 702A and 702B. By combining a single 704 prime mover attached to two separate 702A and 702B pumps on one hauler you can reduce the number of haulers in a fracturing operation for pumps, prime movers, variable frequency drives (VFDs), drainage piping , suction hoses and/or distributor transport vehicles. While Figures 7A and 7B illustrate that the frac pump carrier 700 supports a single prime mover 704 powering two separate pumps 702A and 702B, other embodiments of the frac pump carrier 700 may include a plurality of motors. primaries 704 where each feeds pumps 702A and 702B.
[0075] The design of a 710 tip-top trailer can provide mobility, improve safety and ergonomics for when crew members perform routine maintenance and pump operation since the tip-top layout places the pumps closer to the trailer. ground when the main beams of the trailer rest on the ground in the operating mode. As shown in Figures 7A and 7B, the drop trailer 710 has an upper section above the trailer axles that could contain or where the fracturing pump trailer 708 power and control systems could be installed. fracturing pump trailer power and control system 708 may comprise one or more drives
1026802 62 electrical, transformers, controls (for example, a programmable logic controller (PLC) located on the 700 frac pump carrier), and cables for connecting the motive power trailers and /or a separate electric pumping system. Electric drives can provide control, monitoring, and reliability functionality so as to prevent damage to a grounded or shorted prime mover 704 and/or prevent overheating of components (eg, semiconductor chips) within electric drives. . The lower section that may be located below the trailer axles may contain or have installed the prime mover 704 and pumps 702A and 702B connected on opposite sides of each other.
[0076] In one embodiment, prime mover 704 may be a dual shaft electric motor having a motor shaft protruding on opposite sides of the electric motor. The dual shaft electric motor can be any desired type of alternating current (AC) or direct current (DC) motor. In one embodiment, the dual shaft electric motor may be an induction motor and in another embodiment the dual shaft electric motor may be a permanent magnet motor. Other embodiments of prime mover 704 may include other electric motors that are configured to provide approximately 5,000 HP or more. For example, the double shaft electric motor can supply motive power in a range between about 1,500 HP and about 10,000 HP. Specific to some embodiments, the dual-shaft electric motor may be an electric motor of approximately 5,000 nominal HP or an electric motor of approximately
1026802 of 62
10000 . Prime mover 704 may be driven by at least one variable frequency drive rated at up to a maximum of approximately 5,000 HP and may receive electrical power generated from the mobile electrical power source.
[0077] As shown in Figures 7A and 7B, one side of prime mover 704 drives one pump 702A and the opposing side of prime mover 704 drives a second pump 702B. The 702A and 702B pumps are not configured in a series configuration relative to the 704 prime mover. In other words, the 704 prime mover independently drives each 702A and 702B pump such that if one pump fails, the same pump fails. can disconnect and the other pump can continue to operate. The 704 prime mover, which could be a twin-shaft electric motor, eliminates the use of diesel engines and transmissions. Furthermore, the use of a dual-shaft electric motor in a carrier vehicle can prevent dissonance or feedback when power is transferred to the pumps. In one embodiment, the prime mover 704 can be configured to supply at least about 5000 HP distributed between the two pumps 702A and 702B. For example, the prime mover 704, which may be a dual shaft electric motor, may provide approximately 2500 HP to one of the pumps 702A and approximately 2500 HP to the other pump 702B in order to provide a total of approximately 5000 HP. Other embodiments may have the prime mover 704 supplying less than 5,000 HP or more than 5,000 HP. For example, prime mover 704 can supply a total of approximately 3,000 HP by supplying approximately 1,500 HP to one of the pumps and approximately 1,500 HP to the other pump. Another example might have the 704 prime mover supplying a
1026802 62 total of approximately 10,000 HP and supplying approximately 5,000 HP to one of the 702A pumps and approximately 5,000 HP to the other 702B pump. Specifically, in one or more embodiments, prime mover 704 can operate at operating HP of approximately 3,000 HP, 3,500 HP, 4,000 HP, 4,500 HP, 5,000 HP, 5,200 HP, 5,400 HP, 6,000 HP, 7,000 HP, 8,000 HP, 9,000 HP and/or 10,000 HP.
[0078] Fracturing pump carrier vehicle 700 can reduce the footprint of fracturing equipment at a well site by placing two pumps 702A and 702B on a single carrier vehicle. Larger pumps can be coupled to a dual shaft electric motor operating at higher horsepower to produce further reductions in equipment footprint. In one embodiment, each of the pumps 702A and 702B may be a quintuplex pump located on a single carrier vehicle. Other embodiments may include other types of plunger-type pumps, such as triplex pumps. Each of the 702A and 702B pumps can operate in a range of approximately 1,500 HP to approximately 5,000 HP. Specifically, in one or more embodiments, each of the 702A and 702B pumps can operate at HP operating conditions of approximately 1,500 HP, 1,750 HP, 2,000 HP, 2,250 HP, 2,500 HP, 2,600 HP, 2,700 HP, 3,000 HP. , 3500 HP, 4000 HP, 4500 HP and/or 5000 HP. The pumps 702A and 702B may not be configured in a series configuration where the prime mover 704 drives a first pump 702A and then the first pump 702B drives a second pump 702B.
[0079] Figure 7A also illustrates that each pump 702A and 702B that
1026802 62, also generally referred to in this disclosure as pump 702, is installed on fracturing pump carrier vehicle 700 in the same orientation. In particular, each pump 702 is installed such that the fluidic side assembly 716 of each pump 702 faces the same side of the fracturing pump carrier vehicle 700. Also, in Figure 7A, the drive side assembly 718 of each pump 702 faces the same side as the frac pump carrier vehicle 700. In other words, for a given pump 702 (for example, pump 702A), fluidic side assembly 716 and drive side assembly 718 are located on opposite sides of fracturing pump carrier vehicle 700. As shown in Figure 7A, both the fluidic side assembly 716 and the drive side assembly 718 of a pump 702 can be oriented toward sides of the frac pump carrier 700 that are approximately orthogonal or perpendicular to the front end 720. and to the rear end 722 of the fracturing pump carrier vehicle 700. Having the fluidic side 716 of each pump 702 facing the same side of the transport frac pump 700 can be beneficial in simplifying and reducing the amount of tubing used to route both the low pressure fluid line and the high pressure line. high pressure fluid in and out of the 700 frac pump carrier. For example, if the fluidic side assembly 716 of the pumps 702A and 702B faces opposite sides of the frac pump carrier 700, the frac pump carrier 700 may include tubing that routes both fluid lines to low pressure and high pressure fluid lines on both sides of the frac pump carrier vehicle
1026802 of 62
700. Alternatively, if the fluidic side assembly 716 of the pumps 702A and 702B faces the same side of the frac pump carrier vehicle 700, at least most of the tubing that routes both the low-pressure fluid lines and the High pressure fluid lines could be located on one side of the 700 frac pump carrier.
[0080] In one embodiment, to install the two pumps 702, where the fluidic side assembly 716 faces the same side of the frac pump carrier vehicle 700, one of the pumps 702 (for example, pump 702B ) can be configured with a right-hand drive sprocket while the other 702 pump (for example, the 702A pump) is configured with a drive sprocket located on the opposite side of the 702 pump, which can be referred to as a left-hand drive sprocket. In particular, a pump 702 with a right-hand drive sprocket may be designed to be installed on a specific side of the prime mover 704, such as the side of the prime mover 704 that faces the rear end 722 (for example, the end with trailer axles) and the 702 pump with a left-hand sprocket can be designed to be installed on the other side of the 704 prime mover, such as the side of the prime mover 704 facing toward the front end 720 (eg, trailer hitch). Because the pumps 702 are located on opposite sides of the prime mover 704, placing the sprockets on different sides of the pumps 702 allows the fluidic side assembly 716 of each pump 702 to face the same side of the transport vehicle. 700 frac pump.
[0081] In another embodiment, the fracturing pump carrier vehicle 700 may include one or more pumps 702 configured with a dual
1026802 62 724 sprocket. A 702 pump with the dual sprocket configuration would include both a left-hand sprocket and a right-hand sprocket. Figure 7B illustrates that each pump 702A and 702B has a double pinion 724 where the two pinion ends are located on opposite sides of each other. Having 702 pumps configured with a double 724 pinion provides additional flexibility compared to 702 pumps with either a right hand or left hand pinion. Specifically, a pump 702 with a double sprocket 724 may have the ability to be installed on both sides of the prime mover 704 while the fluidic side assembly 716 of each pump 702 faces the same side of the frac pump carrier vehicle 700. .
[0082] Another advantage of having the fluidic side assemblies 716 face the same side of the frac pump carrier vehicle 700 is to avoid damage to the pump 702 at different loads and/or the requirement to install a separate frac pump. measure. In embodiments where the fluidic-side fluid assemblies 716 are oriented in opposing directions, the pump sprockets 702A and 702B may be rotating in opposing directions when driven by prime mover 704. A pinion, either a right-hand pinion, a left-hand pinion or a double pinion 724, may be located within drive-side assembly 718 and includes a pinion shaft and one or more pinion gears configured to generate rotary motion. of the drive side assembly 718. The rotational motion can generate a torque that displaces the plungers in the fluidic side assembly 716 used to pump and pressurize the fracturing fluid. Typically, to produce the torque, a
1026802 62 pinion gear can interface with a swing gear that drives a crankshaft which in turn moves the fluidic side plungers. Pinion gear and swing gear are commonly worm gears configured to engage with each other by rotating in a specified direction. If the pinion shaft, pinion gear, and swing gear are rotated in a direction opposite to the projected direction, the pinion gear can rotate the swing gear until the pinion gear generates enough torque to break the swing gear and damage the 702 pump. To avoid damage to the 702 pumps, one of the 702 pumps would have to be sized to provide torque when the pinion rotates in a direction opposite to conventional fracturing pumps. The inclusion of a custom frac pump on the 700 frac pump carrier could not only lead to increased manufacturing cost, but also decreased operational and maintenance flexibility by requiring the 702A and 702B pumps to be installed. on projecting sides of the 704 prime mover.
[0083] The prime mover 704 and each of the pumps 702A and 702B can be installed in sub-assemblies configured to be isolated to allow individual removal from the fracturing pump carrier vehicle. In other words, the prime mover 704 and each of the pumps 702A and 702B can be taken out of service and replaced without shutting down or compromising other parts of the fracturing system. The prime mover 704 and the pumps 702A and 702B can be connected to each other through couplings that are disconnected when removed from the frac pump carrier vehicle 700. If the prime mover needs to be replaced or removed
1026802 of 62
704 for repair, the prime mover subassembly can be separated from the frac pump carrier 700 without removing the two pumps 702A and 702B from the frac pump carrier. For example, pump 702A can be isolated from fracturing pump carrier vehicle 700, removed, and replaced with a new pump 702A. If the 704 prime mover and/or the 702A and 702B pumps require service, an operator can isolate the various components of the fluid lines and disconnect, unplug, and remove the 704 prime mover and/or the 702A and 702B pumps from the transport vehicle. frac pump. In addition, each pump subassembly 702A and 702B can be disconnected and removed from the fracturing pump carrier vehicle 700 without removing the other pump and/or prime mover 704. As such, it may not be necessary to disconnect the fracturing pump carrier vehicle 700 from the delivery system and remove it from its location. Instead, replacements for prime mover 704 and/or pumps 702A and 702B can be brought back online and reconnected with fracturing pump carrier vehicle 700.
[0084] To implement independent removal of the subassemblies, the two pumps 702A and 702B can be coupled to the prime mover 704 via a driveline assembly 706 that is adapted to provide remote operation engaging and/or disengaging one or both. pumps 702A and 702B of prime mover 704. Driveline assembly 706 may comprise one or more couplings and one or more driveshafts. For example, driveline assembly 706 may comprise a fixed coupling that connects to one of the pumps 702A or 702B, a wedge shaft 712, and a latching coupling (e.g., drive coupling).
1026802 of 62 splined teeth 714). The wedge shaft 712 can interconnect the fixed coupling (for example, a flexible coupling or universal joint-based coupling) with a spline tooth coupling 714 that connects with the prime mover 704. The fixed coupling can directly connect the wedge shaft 712 with the pump sprocket or indirectly connect the keyed shaft 712 with the pump sprocket using a pump drive shaft. To engage and/or disengage one or both of the pumps 702A and 702B from the prime mover 704, the splined tooth coupling 714 may include a splined slip sleeve coupling and a motor coupling that provides alignment of the drive shaft with the keyed shaft. 712. Hydraulic fluid and/or mechanical power may be used to adjust the splined slip sleeve coupling to engage and/or disengage pumps 702A and 702B from prime mover 704. Other embodiments of couplings that can be used to engage and/or disengage wedge shaft 712 from prime mover 704 may include torque tubes, pneumatic clutches, electromagnetic clutches, hydraulic clutches, and/or other clutches and disconnects that have manual and/or remotely operated disconnect devices.
[0085] Figure 13 is a schematic diagram of one embodiment of a fracturing pump carrier vehicle 1300 configured to remotely engage and/or disengage one or more pumps 702 from prime mover 704. Although Figure 13 illustrates that prime mover 704 is a dual-shaft electric motor, other embodiments of frac pump carrier vehicle 1300 may use other types of electric motors, such as an electric motor having
1026802 of 62 a single axis extending out. As shown in Figure 13, the frac pump carrier vehicle 1300 may comprise a hitch panel 1302 and a monitoring station 1304, such as a human monitoring interface (HMI) station. monitoring interface). Latch panel 1302 may include a control system that adjusts a latch engagement to transition between an engaged and disengaged position. In one embodiment, latch panel 1302 may include levers or switches that can be manually operated by an operator to engage or disengage wedge shaft 712 from the motor shaft using the latch coupling. In addition or as an alternative, latching panel 1302 may include electronic controllers that receive instructions from remote locations, such as a monitoring station 1304, another location on the wellsite (for example, a data booth), and/or outside. location for engaging and/or disengaging the pumps 702 from the prime mover 704. In response to receiving a remote command, latching panel 1302 may activate the latching and/or unlatching of one or more of the pumps from drive motor 704. For example, if pump 702A is latched and pump 702B was off. latched, in response to receiving the remote command, the latching panel 1302 can activate the latching of the pump 702A and the unlatching of the pump 702B. The remote command can also produce a result where both pumps 702 disengage or engage with the prime mover.
[0086] Latch panel 1302 can vary its mounting location on frac pump carrier vehicle 1300 and the latching mechanism.
1026802 62 control is used to engage and/or disengage the pumps 702 from the drive motor 704. Although Figure 13 illustrates that the latch panel 1302 is located at the front end of the frac pump carrier vehicle 1300, other embodiments may have the latch panel 1302 located in other locations, such as as part of the systems. 708 trailer power and control systems and/or in the vicinity of the 708 trailer power and control systems. The control mechanism implemented by latch panel 1302 may be based on the type of latch coupling used to engage and/or disengage pumps 702 and prime mover 704. For example, latch panel 1302 may be a hydraulic control bank that is described in more detail in Figures 15A and 15B that includes hydraulic controllers (eg, hydraulic and electronic control valves) that manage hydraulic fluid pressure when the hitch coupling is a spline tooth coupling.
[0087] Monitoring station 1304 which may be part of trailer power and control systems 708 may include hardware and/or software that allows an operator to manage and control (eg, provide instructions) to hitch panel 1302 to engage and/or disengage pumps 702 from drive motor 704. For example, monitoring station 1304 can be configured with a safety control system that prevents the execution of latching and/or unlatching instructions when the prime mover and/or pumps are running. In one embodiment, monitoring station 1304 may also include network components for remote reception of latching instructions and/or
1026802 of 62 disengagement by connecting to a network control system that communicates with other fracturing equipment and/or control systems. The network control system is described in more detail in Figure 10.
[0088] The fracturing pump carrier vehicle 1300 may also include proximity sensors (not shown in Figure 13) used to determine whether the hitch coupling is in an engaged or disengaged position when remote monitoring is performed. at monitoring station 1304, at another location on the wellsite (eg, data booth), and/or offsite. In one embodiment, proximity sensors may be attached to the latching coupling and/or located in close proximity to the latching coupling to determine whether the pumps 702 are engaged and/or disengaged with the prime mover 704. The information obtained by the proximity sensors can also be useful in allowing the monitoring station 1304 and/or other control systems that are part of the network control system (for example, the data booth) to determine the number of bombs in operation (for example, none, one, or two) of the 1300 frac pump carrier. An operator and/or control system can use the number of pumps to accurately measure the fluid pumping rate during operations.
[0089] Figures 14A and 14B are schematic diagrams of one embodiment of a driveline assembly 1400 used to remotely engage and/or disengage a pump from a prime mover. Figure 14A illustrates that latching coupling 1410 is in an engaged position while Figure 14B illustrates that latching coupling 1410 is in a disengaged position. When manual instructions and/or
1026802 62 remotes to move latching coupling 1410 into a latching position, latching coupling 1410 can translate rotational motion of motor shaft 1408 from the prime mover to the keyed shaft (for example, a drive shaft or drive pinion). the bomb). In a disengaged position, latching coupling 1410 disengages the keyed shaft from motor shaft 1408 from the prime mover such that rotational motion is not transferred to the keyed shaft even though motor shaft 1408 continues spinning. In Figures 14A and 14B, the wedged shaft is located below the shaft cover 1406 used to mount proximity sensors 1404a and 1404b.
[0090] Figures 14A and 14B also illustrate that latch coupling 1410 includes a splined tooth coupling with a sleeve that moves back and forth using hydraulic cylinders 1402 (eg, hydraulic heads). When the hydraulic cylinders 1402 move the sleeve in a projected direction (for example, in the direction of the pump) the splined tooth coupling can engage with the wedge shaft and transfer rotary motion from the motor shaft 1408 to the wedge shaft. . When the hydraulic cylinders 1402 move the sleeve in an opposing direction (for example, in the direction of the prime mover), the splined tooth coupling can disengage the wedged shaft and isolate the rotational motion that the motor shaft 1408 generates from the drive shaft. shaft with wedge Other embodiments may use mechanical power instead of hydraulic power to move the splined tooth coupling sleeves. As shown in Figures 14A and 14B, the motor shaft 1408 can refer to one end of the dual shaft that protrudes out of the motor.
1026802 of 62 primary. Other embodiments could have the motor shaft 1408 as being a driveline shaft that is coupled to one end of the prime mover dual shaft. In other words, the latch coupling 1410 may directly or indirectly connect the wedge shaft latch coupling 1410 to a prime mover.
[0091] Driveline assembly 1400 may also include one or more proximity sensors 1404A and 1404B for determining the position of latch coupling 1410 and one or more fixed couplings 1412 used to directly or indirectly couple the keyed shaft and a pump sprocket. In Figure 14A, proximity sensor 1404A can detect when latching coupling 1410 is in a latched position and in Figure 14B, proximity sensor 1404B can detect when latching coupling 1410 has moved to a latched position. disengage. Figures 14A and 14B also depict fixed couplings 1412 that couple the keyed shaft to a pump sprocket. The 1400 Drive Line Assembly can vary the number of 1412 Fixed Couplings and Intermediate Drive Shafts based on space availability, misalignment tolerances and if necessary to deflect pump vibrations to prevent them from affecting prime mover operation . Also, in one or more embodiments, the pump sprocket can be slightly axially displaced or translated (for example, 1/16<sup>avo</sup> inch). Having 1412 fixed couplings and intermediate drive shafts can allow the pump pinion shaft to shift or translate slightly without damaging the motor shaft and/or the prime mover bearings. Examples of fixed couplings 1412 may include but are not limited to flexible couplings and/or a flexible coupling.
1026802 of 62 based on a universal joint.
[0092] Although Figures 14A and 14B illustrate a specific embodiment of a transmission line assembly 1400, the disclosure is not limited to the specific embodiment illustrated in Figures 14A and 14B. For example, latch coupling 1410 can be implemented using other types of couplings, such as torque tubes, pneumatic clutches, electromagnetic clutches, hydraulic clutches. The latch coupling type 1401 can then determine which one powers the latching and/or unlatching operation, such as hydraulic, mechanical, and/or electrical power. In addition, latching coupling 1410 can be configured to statically and/or dynamically latch and/or disengage the wedged shaft relative to motor shaft 1408. In a static hitch and/or trip, the pumps and/or prime mover may not be operational when the hitch and/or trip occurs. For example, the motor shaft 1408 is not rotating when static latching and/or unlatching is performed. In a dynamic engage and/or disengage, the pumps, prime mover, and/or motor shaft 1408 are rotating when the engage and/or disengage occurs. For example, instead of using a splined tooth coupling, driveline assembly 1400 may use a pneumatic clutch to perform dynamic engagement and/or disengagement. The use and description of Figures 14A and 14B are exemplary only for the purpose of facilitating description and explanation.
[0093] Figure 15A is a schematic diagram of one embodiment of a latching panel 1500 configured to cause remote latching and/or unlatching of one or more pumps with a motor.
1026802 62 and Figure 15B is a schematic diagram of one embodiment of a hydraulic control bank 1502 located within a latch panel 1500. Figure 15A illustrates that the latch panel 1500 includes a hydraulic control bank 1502 with one or more hydraulic levers 1504 that can be manually operated by operators to activate the engagement and/or disengagement of one or more pumps from a prime mover. As shown in Figure 15B, adjustment of hydraulic levers 1504 can activate hydraulic control valves 1506 that adjust hydraulic fluid pressures to move a latching coupling, such as a splined-tooth coupling, into a latched position. and/or disengage. Hydraulic control bank 1502 may also include electronic control valves 1508 that adjust hydraulic fluid pressures based on instructions received from a remote location, such as a monitoring station, another wellsite location (for example, a data booth), and/or off-site. In one embodiment, electronic control valves 1508 may include one or more electronic solenoids that adjust hydraulic fluid pressures to engage and/or disengage one or more pumps from the prime mover. In addition or as an alternative, the latch panel 1500 can also be configured to prevent latching and/or unlatching while the prime mover motor shaft is rotating (for example, when an operator attempts to adjust the hydraulic levers and/or instructions are received). remotes) in cases where the latching coupling is configured to perform static latching and/or unlatching only.
[0094] Figure 12 is a flowchart of one embodiment of
1026802 of 62 a method 1200 for pumping fracturing fluid into a wellhead. Method 1200 starts at block 1202 and receives electrical power to power at least one prime mover. The prime mover may be a dual shaft electric motor located on a frac pump carrier vehicle as shown in Figures 7A and 7B. Method 1200 may then proceed to block 1204 and receive fracturing fluid produced by one or more mixers. In one embodiment, the mixers may be electric mixers that include enclosed mixing hoppers.
[0095] Method 1200 then proceeds to block 1206 and drives one or more pumps using the at least one prime mover to pressurize the fracturing fluid. In one embodiment, the pumps may be located on opposite sides and both may be driven by a single shaft of the dual shaft electric motor when the latching couplings of both pumps are in the latched position. In other words, when two pumps are running and are engaged, the method 1200 can drive the two pumps in a parallel configuration instead of a series configuration. If one of the pumps is removed and/or unhooked, the method 1200 may continue to drive the remaining pump. Method 1200 may receive manual latching and/or unlatching instructions and/or from a remote location to latch and/or unlatch the pumps before or during actuation of the pumps. Method 1200 can then proceed to block 1208 and pump the pressurized fracturing fluid to a wellhead.
[0096] Mixer Transporter Vehicle
[0097] Figures 8A and 8B are schematic diagrams of one form of
1026802 62 embodiment of a mixer carrier vehicle 800 including an electric mixer 806. Figure 8A illustrates a top down view of the mixer carrier vehicle 800 and Figure 8B illustrates a side profile view of the mixer carrier vehicle 800. The mobile electrical power source, as depicted in Figures 1-6, can power the mixer conveyor vehicle 800. The 806 electric mixer may be a dual configuration mixer as described in US Patent Application Publication No. 2012/0255734 with a mixing capacity of approximately 240 bpm. The dual configuration mixer may comprise electric motors for all rotating machinery and may be installed on a single carrier vehicle. The dual configuration mixer can have two separate mixing units that are configured to be independent and redundant. For example, either or both of the mixing units may receive a source fluid through the mixing unit's inlet manifolds. The source fluid may come from the same source or from different sources. The source fluid may then be mixed by either or both of the mixing bowls and subsequently discharged out of either or both of the mixing unit outlet manifolds. Other embodiments of mixer carrier vehicle 800 may have a single mixer configuration that includes a single mixing unit.
[0098] Figures 8A and 8B illustrate a drop trailer design 802 that provides mobility and improves ergonomics when crew members perform routine maintenance and electric mixer operations.
1026802 of 62
806 as the stowed positions of the mixer bowls, pumps and pipes lower them to ground level and the main beams of the trailer are supported on the ground in the operating mode.
[0099] Similar to the drop trailer 710, the drop trailer 802 may comprise an upper section above the trailer axles and a lower section below the trailer axles. In one embodiment, the electric mixer 806 and associated equipment on the trailer may be remotely controlled and monitored through a network control system. As shown in Figures 8A and 8B, a mixer control system 804 comprising a PLC, transformers, and one or more variable frequency drives are installed in the upper section of the mixer carrier vehicle 800. To provide remote control and monitoring functions, the network can interface and communicate with the PLC (for example, provide operating instructions), and the PLC can then control one or more variable frequency drives installed on the mixer trailer to drive one or more electric mixer motors. Remote operation of the 800 Mixer Carrier Vehicle can prevent equipment operators from being exposed to hazardous environments and prevent potential exposure to concentrated chemicals, silica dust, and rotating machinery. For example, typically a conventional mixer carrier vehicle includes an operator's station that manually operates the mixer. By using the network control and mixer control system 804 for remote control, the station can be removed from the mixer carrier vehicle 800. It is recalled that a data booth can act as a hub to provide the
1026802 of 62 functions and remote control and monitoring instructions for the 804 mixer control system.
[00100] Figures 9A and 9B are schematic diagrams of one embodiment of a mixer conveyor vehicle 900 including an electric mixer 902 with enclosed mixing hoppers 904. Figure 9A illustrates a top down view of the mixer conveyor vehicle. mixer 900 and Figure 9B illustrates a profile side view of the mixer carrier vehicle 900. Electric mixer 902 is substantially similar to electric mixer 806, except that electric mixer 902 uses enclosed mixing hoppers 904 to add proppants and additives to the mixing bowl. Figures 9A and 9B illustrate that the electric mixer 902 is a dual configuration mixer that includes two enclosed mixing hoppers 904 powered by two electric motors where each of the electric motors can operate on an enclosed mixer hopper 904.
[00101] Mixers comprising open hoppers and augers typically have proppants (eg sand) and/or additives exposed to inclement weather. In situations where precipitation occurs at the wellsite, operators can cover open hoppers and augers with covers, tarps, and/or other covers to prevent precipitation from contaminating proppants and/or additives. The closed mixer hopper 904 replaces the open hopper and augers that are typically included in a mixer (for example, the electric mixer 806 in Figures 8A and 8B) with closed mixing hoppers 904 (Figures 9A and 9B). By replacing the open hopper and
1026802 of 62 augers with 904 enclosed mixing hoppers, the 900 mixer carrier vehicle can have the advantages of dust-free volumetric measurements of proppant, dust-free mixing of proppant and additives, moderate transport of proppant proppant agents, perform accurate volumetric measurements, increase proppant transport efficiency with low slip, prevent proppant packaging from vibration, produce consistent volume independent of angle of repose, and measure and mix wet sand. Other benefits include the elimination of gearboxes and increased operator safety with the drum closed.
[00102] Network Control System
[00103] Figure 10 is a schematic diagram of one embodiment of a networked control system 1000 that is used to monitor, control, and communicate with a variety of control systems located at one or more well sites. Figure 10 illustrates that the networked control system 1000 may have a ring topology that interconnects the control center 1002, blender carrier 1004, chemical additives unit 1006, hydration unit 1008, and feed carriers. 1012 fracturing pumps. A ring topology network can reduce the amount of control wiring used in fracturing operations and increase the capacity and speed of data transfer and communication. In addition, the ring topology can allow bidirectional communication and control by the control center 1002 of the equipment connected to the network control system 1000. For example, the control center may have the ability to monitor and control the other equipment in
1026802 of 62 fracturing 1010 and third-party equipment 1014 when added to the networked control system 1000 and multiple pieces of equipment communicating with each other. In other network topologies, such as a star or mesh topology, the other fracturing rigs 1010 and third-party rigs 1014 may be limited to one-way communication where data is transmitted from the fracturing rig 1010 and/or the third-party rigs. from third parties 1014 to control center 1002, but not in the opposite direction or between different pieces of equipment.
[00104] In one embodiment, the networked control system 1000 may be a network, such as an Ethernet network, that connects and communicates with the individual control systems of each of the fracturing rigs. Control center 1002 can be configured to monitor, control and provide operating instructions to the various fracturing equipment. For example, the control center 1002 may communicate with variable frequency drives located within the prime mover 104 that operate and monitor the status of the electric motors used to drive the pumps on the fracturing pump hauler 108. In one embodiment, control center 1002 may be one or more data booths. More data cabinets can be used when fracturing operations include fracturing more than two wellheads simultaneously.
[00105] At least one embodiment is disclosed and variations, combinations and/or modifications of the embodiment(s) and/or of the features of the embodiment(s) made by a person skilled in the art are within the scope of disclosure. The forms of
1026802 Alternative embodiments resulting from the combination, integration, and/or omission of features of the embodiment(s) are also within the scope of the disclosure. Where numerical ranges or limitations are expressly stated, such expressed ranges or limitations may be understood to include iterative ranges or limitations of similar magnitude that fall within the expressly stated ranges or limitations (for example, between about 1 and about 10 includes, 2, 3, 4, etc., greater than 0.10 includes 0.11, 0.12, 0.13, etc.). The use of the term approximately means ± 10% of the subsequent number unless otherwise indicated.
[00106] The use of the term optionally with respect to any element of a claim means that the element is required or alternatively, the element is not required, where both alternatives are within the scope of the claim. The use of broader terms, such as comprises, includes, and having may be understood to provide support for more specific terms, such as consisting of, consisting essentially of and substantially comprised of. Therefore, the scope of protection is not limited to the description set forth above, but is defined by the claims that follow, where the scope includes all equivalents of the contents of the claims. Any and all claims are incorporated as further disclosure in the specification and the claims are embodiment(s) of the present disclosure.
[00107] While various embodiments have been provided in this disclosure, it is to be understood that the systems and methods disclosed may be
1026802 62 incorporated in many other specific forms without departing from the spirit or scope of this disclosure. The present examples are to be considered as illustrative and not restrictive and it is intended that the details given herein are not limiting. For example, the various elements or components may be combined or integrated into another system or certain features may be omitted or not implemented.
[00108] In addition, the techniques, systems, subsystems, and methods described and illustrated in the various embodiments as discrete or separate may be combined or integrated with other systems, modules, techniques, or methods without departing from the scope of the present disclosure. Other elements shown or described as coupled or directly coupled or communicating with each other may be indirectly coupled or communicate through some interface, device or intermediate component, whether electrical, mechanical or otherwise.
1026802 of 62
CLARKE MODET & CIA (ARGENTINA) SA - 30540437455
Digitally signed by PORTALTRAM ITES - INPI
Date: 2020.07.28 16:57:18 -03:00
Reason: Digitally Signed by INPI
Location: Buenos Aires, Argentina
1026802
Contents4
18 sheets
Sheet 1 Sheet 2 Sheet 3 Sheet 4 Sheet 5 Sheet 6 Sheet 7 Sheet 8 Sheet 9 Sheet 10 Sheet 11 Sheet 12 Sheet 13 Sheet 14 Sheet 15 Sheet 16 Sheet 17 Sheet 18
66 members in 13 offices
Priority claims3
| Document | Office | Kind | Date |
|---|---|---|---|
| 201615253686 | United States of America | A | |
| 15253686 | – | – | – |
| US201615253686 | – | – | – |
Members66
| Document | Office | Kind | |
|---|---|---|---|
| CA2970527A1 | Canada | A1 | |
| CA2970542A1 | Canada | A1 | |
| US2016177675A1 | United States of America | A1 | |
| US2016177678A1 | United States of America | A1 | |
| WO2016100524A1 | World Intellectual Property Organization (WIPO) | A1 | |
| WO2016100535A1 | World Intellectual Property Organization (WIPO) | A1 | |
| US2016369609A1 | United States of America | A1 | |
| US9534473B2 | United States of America | B2 | |
| US9562420B2 | United States of America | B2 | |
| US2017104389A1 | United States of America | A1 | |
| AR103159A1 | Argentina | A1 | |
| AR103160A1 | Argentina | A1 | |
| AU2015364678A1 | Australia | A1 | |
| CN107208557A | China | A | |
| EP3234321A1 | European Patent Office (EPO) | A1 | |
| KR20170121158A | Republic of Korea | A | |
| AR106020A1 | Argentina | A1 | |
| MX2017008146A | Mexico | A | |
| MX2017008148A | Mexico | A | |
| JP2018508705A | Japan | A | |
| CA2970542C | Canada | C | |
| JP6415748B2 | Japan | B2 | |
| EP3234321A4 | European Patent Office (EPO) | A4 | |
| AU2015364678B2 | Australia | B2 | |
| KR101948225B1 | Republic of Korea | B1 | |
| KR20190016610A | Republic of Korea | A | |
| AU2019200899A1 | Australia | A1 | |
| AR111052A2 | Argentina | A2 | |
| US2019203572A1 | United States of America | A1 | |
| US10374485B2 | United States of America | B2 | |
| CA2970527C | Canada | C | |
| US10378326B2 | United States of America | B2 | |
| KR101981198B1 | Republic of Korea | B1 | |
| CN107208557B | China | B | |
| US2019356199A1 | United States of America | A1 | |
| CN110513155A | China | A | |
| EP3234321B1 | European Patent Office (EPO) | B1 | |
| DK3234321T3 | Denmark | T3 | |
| AU2019200899B2 | Australia | B2 | |
| AU2020220087A1 | Australia | A1 | |
| EP3719281A1 | European Patent Office (EPO) | A1 | |
| SI3234321T1 | Slovenia | T1 | |
| MX2021006935A | Mexico | A | |
| US11070109B2 | United States of America | B2 | |
| AU2020220087B2 | Australia | B2 | |
| AU2021245123A1 | Australia | A1 | |
| US11168554B2 | United States of America | B2 | |
| US2021351660A1 | United States of America | A1 | |
| US2021351661A1 | United States of America | A1 | |
| AR119508A2This record | Argentina | A2 | |
| US2022034211A1 | United States of America | A1 | |
| CN110513155B | China | B | |
| EP3719281B1 | European Patent Office (EPO) | B1 | |
| DK3719281T3 | Denmark | T3 | |
| HUE061407T2 | Hungary | T2 | |
| AU2021245123B2 | Australia | B2 | |
| US11799356B2 | United States of America | B2 | |
| AU2023258385A1 | Australia | A1 | |
| US2024030782A1 | United States of America | A1 | |
| US11891993B2 | United States of America | B2 | |
| US2024247646A1 | United States of America | A1 | |
| US12149153B2 | United States of America | B2 | |
| US2025038618A1 | United States of America | A1 | |
| MX378234B | Mexico | B | |
| MX383620B | Mexico | B | |
| AU2023258385B2 | Australia | B2 |
1 legal event, as the office reported them to INPADOC
Events
| Event | Code | |
|---|---|---|
| Grant, registrationFG | FG |
Numbers
- Publication
- 119508
- Publication, DOCDB
- 119508
- Publication, EPODOC
- AR119508
- Application
- 102116
- Application, DOCDB
- P200102116
- Application, EPODOC
- AR2020P102116
Titles2
- Spanish
- VEHÍCULO TRANSPORTADOR MÓVIL DE BOMBA DE FRACTURACIÓN PARA LA FRACTURACIÓN HIDRÁULICA DE FORMACIONES GEOLÓGICAS SUBTERRÁNEAS
- English
- MOBILE FRACTURATION PUMP TRANSPORTER VEHICLE FOR HYDRAULIC FRACTURATION OF UNDERGROUND GEOLOGICAL FORMATIONS
Classification
- IPC, 7
- E21B43 26
- F04B9 02
- F04B17 03
- F04B17 06
- F04B23 04
- F16D25 10
- F16D48 06