Mobile Pump System
A mobile pump system includes: a trailer movable by a vehicle; and a pump mounted to the trailer, the pump configured to pump a fluid. The pump includes an electrically-driven motor mounted to the trailer or is turbine powered by a turbine mounted to the trailer. A method for performing a pressure pumping application is also disclosed.
This application claims priority to U.S. Provisional Patent Application No. 62/666,945, filed May 4, 2018, the disclosure of which is hereby incorporated in its entirety by reference.
BACKGROUND FieldThe present disclosure relates to a mobile pump system and a method for performing a pressure pumping application.
Technical ConsiderationsPressure pumping includes a propagation of fractures through layers of rock using pressurized fluid and/or pumping cement into a wellbore to complete it.
In one non-limiting example of pressure pumping, to extract oil and/or gas trapped in formations beneath the Earth's surface, drilling of a wellbore is required, and the oil and/or gas may be recovered and extracted through the wellbore. Various pumps may be used during the drilling and oil and/or gas recovery process.
In some non-limiting oilfield applications, drilling may include forming horizontal laterals extending out from a vertical section of the wellbore. The formation defining the vertical or lateral section may be fractured in sections, such that a fracture stimulation treatment is completed in the first section before moving on to apply a fracture stimulation treatment on a second section. This may be performed using a plug-and-perf technique in which a perforating gun is used to initiate fractures in the formation in the section after a plug is positioned between the first section and the second section. The plug seals the first section of the lateral from the other sections. This plug-and-perf technique is repeated for each section of the lateral until all intended sections of the lateral are perforated and fracture stimulated.
The plug may be positioned at a predetermined location along the lateral by utilizing a pump system to pump a fluid into the wellbore, which exerts a pressure on the plug. The pressure on the plug moves the plug along the lateral to the desired position. Positioning the plug using the pump is considered an ancillary application, commonly referred to as “pumpdown”.
Existing pumps used in pressure pumping application, such as in ancillary pumpdown applications have numerous drawbacks. For example, existing pumps use an internal combustion engine driven by diesel fuel, which have high carbon footprints. In addition, these existing pumps are cumbersome and require considerable room at the well site. Further, these existing pumps do not allow for sufficiently precise control of flow rate, making it difficult to move the plug to the desired position. Existing pumps are expensive to acquire and maintain, and they create significant noise at a decibel level that is known to harm human hearing without adequate ear protection.
Further, existing pumping systems utilized in pressure pumping applications, including ancillary pressure pumping applications, are not capable of sufficiently low flow rates or precise control of the flow rate. The existing pump systems lack precise control and the ability to operate at lower flow rates because they utilize conventional transmissions that are incapable of smooth increase or decrease in pumping rates. This may be the result of hesitation and slugging common when primary gears disengage and engage the secondary shaft. As a result, existing pressure pumping systems do not effectively remedy screen outs occurring during hydraulic fracturing applications.
Therefore, a pump suitable for pressure pumping applications that overcomes some or all of the disadvantages of existing pumps is desired.
SUMMARYThe present disclosure is directed to a mobile pump system including: a trailer movable by a vehicle; and a pump mounted to the trailer, the pump configured to pump a fluid. The pump includes an electrically-driven motor mounted to the trailer or is turbine powered by a turbine mounted to the trailer.
The pump may be configured to pump the fluid into a wellbore at a tie-in point upstream of a wellhead of the wellbore. The fluid may include water and/or a chemical additive. The pump may include an auger or impeller configured to move the fluid. The pump may not be permanently installed at a site for performing a pressure pumping application. The electrically-driven motor may be fueled by a battery, natural gas, diesel fuel, or gasoline. The pump may be configured to adjust a flow rate of the pump by 1/10th of a bpm. The pump may be in fluid communication with a wellbore. The turbine may be operated using field gas. The mobile pump system may include plurality of pumps mounted to the trailer, where each pump may include an electrically-driven motor mounted to the trailer or may be turbine powered by a turbine mounted on the trailer. The mobile pump system may include controller configured to remotely control the pump. The controller may include a portable computing device. The pump may be configured to pump the fluid at a flow rate as low as 0.1 bpm. The turbine may include a direct coupled gear connection.
The present disclosure is also directed to a method for performing a pressure pumping application including: providing a mobile pump system including: a trailer movable by a vehicle; and a pump mounted to the trailer, the pump configured to pump a fluid, where the pump includes an electrically-driven motor mounted to the trailer or is turbine powered by a turbine mounted to the trailer.
The method may include pumping the fluid from a fluid container into a wellbore using the pump to move the fluid from the fluid container into the wellbore. The method may include positioning a plug in a lateral of the wellbore using the fluid pumped into the wellbore. The pump may be configured to pump the fluid into the wellbore at a tie-in point upstream of a wellhead of the wellbore. The fluid may include water and/or a chemical additive. The pump may include an auger or impeller configured to move the fluid. The pump may not be permanently installed at a site for performing a pressure pumping application. The electrically-driven motor may be fueled by a battery, natural gas, diesel fuel, or gasoline. The pump may be configured to adjust a flow rate by 1/10th of a bpm. The pump may be in fluid communication with a wellbore. The turbine may be operated using field gas. The pump may be configured to pump the fluid at a flow rate as low as 0.1 bpm. The pump may be remotely controlled by a controller. The controller may include a portable computing device. The pump may be configured to pump the fluid at a flow rate of up to 140 barrels per minute (bpm) at a pressure of up to 20,000 psi.
Further embodiments are set forth in the following numbered clauses:
Clause 1: A mobile pump system comprising: a trailer movable by a vehicle; and a pump mounted to the trailer, the pump configured to pump a fluid, wherein the pump comprises an electrically-driven motor mounted to the trailer or is turbine powered by a turbine mounted to the trailer.
Clause 2: The mobile pump system of clause 1, wherein the pump is configured to pump the fluid into a wellbore at a tie-in point upstream of a wellhead of the wellbore.
Clause 3: The mobile pump system of clause 1 or 2, wherein the fluid comprises water and/or a chemical additive.
Clause 4: The mobile pump system of any of clauses 1-3, wherein the pump comprises an auger or impeller configured to move the fluid.
Clause 5: The mobile pump system of any of clauses 1-4, wherein the pump is not permanently installed at a site for performing a pressure pumping application.
Clause 6: The mobile pump system of any of clauses 1-5, wherein the electrically-driven motor is fueled by a battery, natural gas, diesel fuel, or gasoline.
Clause 7: The mobile pump system of any of clauses 2-6, wherein the pump is configured to adjust a flow rate of the pump by 1/10th of a bpm.
Clause 8: The mobile pump system of any of clauses 1-7, wherein the pump is in fluid communication with a wellbore.
Clause 9: The mobile pump system of any of clauses 1-8, wherein the turbine is operated using field gas.
Clause 10: The mobile pump system of any of clauses 1-9, comprising a plurality of pumps mounted to the trailer, wherein each pump comprises an electrically-driven motor mounted to the trailer or is turbine powered by a turbine mounted on the trailer.
Clause 11: The mobile pump system of any of clauses 1-10, further comprising a controller configured to remotely control the pump.
Clause 12: The mobile pump system of clause 11, wherein the controller comprises a portable computing device.
Clause 13: The mobile pump system of any of clauses 1-12, wherein the pump is configured to pump the fluid at a flow rate as low as 0.1 bpm.
Clause 14: The mobile pump system of any of clauses 1-13, wherein the turbine comprises a direct coupled gear connection.
Clause 15: The mobile pump system of any of clauses 1-14, wherein the pump is configured to pump the fluid at a flow rate of up to 140 barrels per minute (bpm) at a pressure of up to 20,000 psi.
Clause 16: A method for performing a pressure pumping application comprising: providing a mobile pump system comprising: a trailer movable by a vehicle; and a pump mounted to the trailer, the pump configured to pump a fluid, wherein the pump comprises an electrically-driven motor mounted to the trailer or is turbine powered by a turbine mounted to the trailer.
Clause 17: The method of clause 16, further comprising: pumping the fluid from a fluid container into a wellbore using the pump to move the fluid from the fluid container into the wellbore.
Clause 18: The method of clause 17, further comprising: positioning a plug in a lateral of the wellbore using the fluid pumped into the wellbore.
Clause 19: The method of any of clauses 16-18, wherein the pump is configured to pump the fluid into the wellbore at a tie-in point upstream of a wellhead of the wellbore.
Clause 20: The method of any of clauses 16-19, wherein the fluid comprises water and/or a chemical additive.
Clause 21: The method of any of clauses 16-20, wherein the pump comprises an auger or impeller configured to move the fluid.
Clause 22: The method of any of clauses 16-21, wherein the pump is not permanently installed at a site for performing a pressure pumping application.
Clause 23: The method of any of clauses 16-22, wherein the electrically-driven motor is fueled by a battery, natural gas, diesel fuel, or gasoline.
Clause 24: The method of any of clauses 16-23, wherein the pump is configured to adjust a flow rate by 1/10th of a bpm.
Clause 25: The method of any of clauses 16-24, wherein the pump is in fluid communication with a wellbore.
Clause 26: The method of any of clauses 16-25, wherein the turbine is operated using field gas.
Clause 27: The method of any of clauses 16-26, wherein the pump is configured to pump the fluid at a flow rate as low as 0.1 bpm.
Clause 28: The method of any of clauses 16-27, wherein the pump is remotely controlled by a controller.
Clause 29: The method of clause 28, wherein the controller comprises a portable computing device.
Clause 30: The method of any of clauses 16-29, wherein the pump is configured to pump the fluid at a flow rate of up to 140 barrels per minute (bpm) at a pressure of up to 20,000 psi.
Additional advantages and details are explained in greater detail below with reference to the exemplary embodiments that are illustrated in the accompanying schematic figures, in which:
For purposes of the description hereinafter, the terms “end,” “upper,” “lower,” “right,” “left,” “vertical,” “horizontal,” “top,” “bottom,” “lateral,” “longitudinal,” and derivatives thereof shall relate to the invention as it is oriented in the drawing figures. However, it is to be understood that the invention may assume various alternative variations and step sequences, except where expressly specified to the contrary. It is also to be understood that the specific devices and processes illustrated in the attached drawings, and described in the following specification, are simply exemplary embodiments or aspects of the invention. Hence, specific dimensions and other physical characteristics related to the embodiments or aspects disclosed herein are not to be considered as limiting.
The present disclosure is directed to a mobile pump system that includes: a trailer movable by a vehicle; and a pump mounted to the trailer, the pump configured to pump a fluid, wherein the pump comprises an electrically-driven motor mounted to the trailer or is turbine powered by a turbine mounted to the trailer. The mobile pump system described herein may be suitable for pressure pumping applications.
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With continued reference to
The lateral 14 may include a plurality of regions, which are of a predetermined length. Hydraulic fracture stimulation treatment may be performed in the lateral 14 individually at each region. Hydraulic fracture stimulation treatment includes pumping a fracturing fluid into the formation. The lateral 14 of the schematic in
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With continued reference to
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In
The second plug 40 may be positioned using the mobile pump system 44 of the present disclosure. The mobile pump system 44 may be used to position the second plug 40 as merely one non-limiting example of how the mobile pump system 44 may be used in a pressure pumping application. However, it will be appreciated that the mobile pump system 44 may be used to complete other pressure pumping applications using the components of the mobile pump system 44 described hereinafter.
The mobile pump system 44 may include a trailer 46 movable by a vehicle (e.g., a cab having a fifth wheel). The trailer 46 may be movable by a vehicle, such as a cab, to and from the production site 10. In this way, the mobile pump system 44 may be conveniently moved from location to location, such as to and from the production site 10, and the mobile pump system 44 does not need to be permanently installed at the production site 10. The trailer 46 may be separable/detachable from the vehicle such that the trailer 46 may be left at the production site 10 and the vehicle driven away, or the trailer 46 may be integrated with the vehicle, such that the vehicle remains at the production site 10 while the mobile pump system 44 is in use and drives away after use of the mobile pump system 44 is completed.
With continued reference to
The pump 48 may be configured to pump the positioning fluid 42, or any other fluid, at a flow rate of up to 60 barrels per minute (bpm), such as up to 80 bpm, up to 100 bpm, up to 120 bpm, up to 140 bpm or higher. A barrel is defined as 42 US gallons, which is approximately 159 Liters. The pump 48 may be configured to pump the positioning fluid 42 at far lower flow rates, and may pump the positioning fluid 42 at a flow rate as low as 0.1 bpm (when the pump is not turned off such that it's flow rate would be 0 bpm). The pump 48 may be controlled such that its flow rate may be controlled within 1/10th of a bpm, resulting in a flow rate within 1/10th of a bpm compared to a predetermined flow rate. The pump may be configured to adjust the flow rate by 1/10th of a bpm (e.g., adjust the flow rate of the pump 48 from 60.0 bpm to 59.9 bpm or from 0.2 bpm to 0.1 bpm). Existing pressure pumping systems, including ancillary pressure pumping applications, are not capable of such low flow rates or such precise control of the flow rate. The existing pump systems lack precise control and the ability to operate at lower flow rates because they utilize conventional transmissions that are incapable of smooth increase or decrease in pumping rates. This may be the result of hesitation and slugging common when primary gears disengage and engage the secondary shaft.
The ability to pump at lower rates and to more precisely control the flow rate of the pump 48 may be especially useful in post-occurrence remedying of “screen outs,” which are common in hydraulic fracturing applications. A screen out occurs when proppant and fluid (of the positioning fluid 42, for example) can no longer be injected into the formation. This may be due to resistant stresses of the formation becoming too excessive or surface-originated reasons resulting in loss of viscosity to carry proppant so that it falls out of suspension and plugs perforations in the wellbore 12. In this way, the wellbore 12 becomes “packed” with proppant, which does not allow any further operations to continue due to high pressures that cannot be overcome from these blockages.
In response to screen outs, the wellbore 12 may be opened at the surface 11 to relieve pressure and to carry at least some of the proppant out of the wellbore 12 and create a pathway to continue fluid injection to clear the wellbore 12 and allow operations to continue, which is a dangerous operation. An attempt to continue pumping operations at low rates to avoid reaching maximum pressure so that the proppant that is packed is forced through perforations and into the wellbore 12 may be attempted. However, due to the limitations of existing pumps with conventional engines and transmissions, the pump cannot pump at low enough rates to avoid again reaching maximum pressure. As a result, existing systems are often required to switch to a coiled tubing procedure to wash the proppant out and carry it back to the surface so that the wellbore 12 is finally clear. The coiled tubing procedure results in shutdown of operations for 3-4 days and is additionally expensive to complete.
In contrast, existing systems are able to overcome these screen outs successfully without reverting to the coiled tubing procedure because the electric motor or the turbine 50 of the pump 48 allows the pump 48 to inject fluid for displacement at lower rates (as low as 0.1 bpm) over the course of hours or days without the risks posed by existing systems.
The ability to pump fluids at lower rates and to more precisely control the flow rate of the pump 48 may be especially useful in prevention or mitigation of the adiabatic effect which can cause wireline cable melting and/or failure during pump down operations, which are common in hydraulic fracturing applications. On pump downs and related jobs involving wireline operations with pump assist, the wellhead is equipped with a lubricator and flow tubes to enable operations in a wellbore that can have pressure of several thousand pounds or more of pressure. The process of bringing the lubricator and the wellbore to the same pressure is known as “equalization.” When the air in the lubricator compresses faster than it can be evacuated, the adiabatic compression can cause the temperature to rise to as much as 1,200° F. (−650° C.). At high temperatures, the insulating material of the cable would melt and the metallurgy of the steel in the cable would change, causing the actual wire in the wireline to become brittle and break, even to the point of severing the wireline within the lubricator. A common name for this condition is “wireline burn up” though other colloquialisms and phrases (such as “E-line burn”) describe the same condition.
In practice, to avoid wireline burn-up, the lubricator may first be filled with fluid prior to equalizing; this practice can mitigate much of the air and therefore most of the energy to cause damage. In order to fill the lubricator with fluid without inducing wireline burn-up, the fluid must be introduced at very low rates so that the air can be evacuated at an equivalent rate so as not to introduce temperature increases caused by compressing air rapidly. However, due to the limitations of existing pump systems with conventional engines and transmissions, the pump cannot pump at low enough rates to completely avoid against reaching damaging high temperatures. In contrast, the pump 48 would be able to overcome this situation successfully because the electric motor or the turbine 50 of the pump 48 allows the pump 48 to inject fluid for displacement of the air in the lubricator at lower rates (as low as approximately 0.1 bpm) without the risks posed by existing systems.
The pump 48 may be configured to pump fluid at a pressure of up to 20,000 psi, such as up to 15,000 psi, up to 12,000 psi, up to 10,000 psi, up to 8,000 psi, or up to 6,000 psi, although higher pressures are also contemplated.
With continued reference to
With continued reference to
The mobile pump system 44 described herein may be used for any pressure pumping in which its characteristics are suitable and is not limited to the above-described application. For example, the mobile pump system 44 may be used in hydraulic fracturing applications. Hydraulic fracturing applications include any application associated with hydraulic fracturing performed at a production site. Hydraulic fracturing refers to fluid injected down the wellbore through perforations exceeding the minimum fracture pressure needed to fracture the rock in the formation. An example of a hydraulic fracturing application includes ancillary applications (“pumpdown”), such as positioning a plug (previously described), drillout applications, injecting acid into the formation, pressure testing casing, injecting diverter materials, “toe preps” involving initiating the first fracture network in a well, and the like. Drillout applications may include applications performed after the drilling and fracturing process has concluded and the well is being prepared to deliver hydrocarbon production. As one example, a drillout application may include milling or drilling out plugs previously positioned in the laterals and removing debris from the milled plugs by pumping the debris from the plug location to the surface.
The mobile pump system 44 allows for the reduction of capital costs compared to existing pump systems as the mobile pump system 44 requires less capital costs to build and operate. The mobile pump system 44 also significantly reduces repair and maintenance costs compared to existing systems. The use of the electric motor or turbine 50 to drive the pump 48 helps to reduce repair and maintenance costs. The electric motor or turbine 50 has a higher run time before requiring repairs compared to conventional internal combustion engines (motors) used in existing pumps, which are diesel driven, for example. Keeping the electric motor or turbine 50 cool and lubricated allows the electric motor or turbine 50 to have a longer running life compared to the motors used in existing systems. The electric motor or turbine 50 also run more efficiently compared to the motors used in existing systems, such as in terms of emissions and consumption of fuel.
The mobile pump system 44 using the electric motor or turbine 50 to drive the pump 48 also requires significantly less fuel compared to existing systems. The electric motor or turbine 50 may utilize natural gas powered electric generation, such as the field gas available at a production site. Thus, sulfur and other pollutants that arise from diesel combustion in conventional internal combustion motors are not present in the combustion of natural gas powered electric generation. The inclusion of the electric motor or the turbine 50 in the mobile pump system 44 also reduces the noise associated with the mobile pump system 44 as pumps used in existing systems provide significant noise pollution and make it difficult to operate such pumps in residential areas (e.g., near housing plans, schools, hospitals, and the like).
The mobile pump system 44 includes a more compact design of the pumps 48 compared with existing systems. Multiple pumps 48 may be included on the trailer 46. The more compact system contributes to a safe production site 10 as there are less components at the production site 10 to cause a navigational and/or tripping hazard. This compact design also allows for the mobile pump system 44 to be set-up faster, resulting in less wasted time and faster time to production. Moreover, the mobile pump system 44 may include multiple of at least on component included in the system, such as multiple pumps 48, multiple electric motors or turbines 50, multiple controllers 80, and the like. The redundancy associated with certain of the components mounted on the trailer 46 of the mobile pump system 44 allows the system to avoid stopping operation of the pressure pumping application should one of the redundant components fail.
Referring to
The production site 10 may include at least one fracturing trailer 58A-58F, each including at least one fracturing pump 60A-60F. The production site 10 may further include sand and fracturing fluid storage tanks 62, which include sand and fracturing fluid used to keep fractures in the formation open. The production site 10 may further include a water tank 64 for pumping water into the first wellbore 12A. The water tank 64 may be in addition to or the same as the fluid tank 54 containing the positioning fluid 42. The production site 10 may further include a chemical storage tank 66, which may store any useful chemical, such as a friction reducer (e.g., polyacrylamide or a guar-based chemical). The fracturing pumps 60A-60F may be in fluid communication with at least one of the sand and fracturing fluid storage tanks 62, the water tank 64, and the chemical storage tank 66 to pump the various materials and/or fluids contained therein into the first wellbore 12A via piping 70. The piping 70 may include an isolation valve 72 for isolating the fracturing pumps 60A-60F from the first wellbore 12A when the fracturing pumps 60A-60F are not pumping fluid/material into the first wellbore 12A.
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An exemplary graphical user interface (GUI) displayed on the controller 80 is shown in
Beyond providing the capability to adjust certain parameters of the system, the GUI may display on the controller various diagnostic and monitoring information. As non-limiting examples, the GUI may display electric motor or the turbine temperature, fluid levels, and pump revolutions per minute.
Referring to
The mobile pump system 82 may include an electrical transformer 88 mounted on the trailer 84. The electrical transformer 88 may increase or decrease a voltage from an external power source for use by one of the components of the mobile pump system 82. This may allow components of the mobile pump system 82 to be powered by an external power source not included on the trailer 84 by electrically connecting the external power source to the transformer 88, which may be electrically connected to the other components.
The mobile pump system 82 may include the variable frequency drive 90 mounted on the trailer 84. The variable frequency drive 90 may include an electro-mechanical drive system to control motor speed and/or torque of the electric motor 94 by varying motor input frequency and/or voltage.
The mobile pump system 82 may include the heat exchanger 92 mounted on the trailer 84 to regulate temperature of at least one of the other components (e.g., the electric motor 94 and/or the pump 96), such that the component can operate more efficiently. The heat exchanger 92 may function as a cooler to prevent a component of the mobile pump system 82 from overheating.
The mobile pump system 82 may include the electric motor 94 mounted on the trailer 84, the electric motor 94 as previously described herein. The mobile pump system 82 may also include the pump 96a, 96b (a single or multiple pumps may be included) mounted on the trailer 84. The pump 96a, 96b may include the features previously described herein in connection with pump 48. The pump 96a, 96b may be driven by the electric motor 94.
With continued reference to
Referring to
The mobile pump system 102 may include an inlet filter silencer 106 mounted on the trailer 84 to reduce noise emitted by any of the components included in the mobile pump system 102.
The mobile pump system 102 may include a turbine 108a, 108b (a single or multiple turbines may be included) mounted on the trailer 84 and connected to the pump 96a, 96b. The turbine 108a, 108b may be enclosed in a housing. The turbine 108a, 108b may be an on-board (on the trailer 84) turbine to generate power on the trailer 84 for driving the pumps 96a, 96b. The turbine 108a, 108b may be directly coupled to the pump 96a, 96b via a gearbox 110a, 110b (a single or multiple gearboxes may be included), which may include gear reduction components. The turbine 108a, 108b may be powered by using field gas (e.g., natural gas) introduced to the turbine to spin the turbine blades to create power to rotate the pump 96a, 96b. The power generated by the turbine 108a, 108b may drive the pump 96a, 96b. The turbine 108a, 108b may be included in the mobile pump system 102 in addition to or in lieu of the electric motor 94a, 94b shown in the mobile pump system 82 shown in
Referring to
The fuel tank 114 may be used as a backup fuel supply in the event of a fuel supply interruption. A fuel supply interruption may include the interruption of field gas (e.g., natural gas supplied directly from the production site at which the mobile pump system 112 is located) to the mobile pump system 112. Inclusion of the fuel tank 114 on the trailer 84 allows the mobile pump system 112 to continue operation even in the event of such a fuel supply interruption, without the deployment of an emergency backup power supply to the production site.
The mobile pump system 112 may include a conditioning system 116 configured to condition the gas from the fuel tank 114 or the field gas supplied to the mobile pump system 112. The conditioning system 116 may include a gas heater to drop out solids and/or water from the gas and return it to the supply line. The conditioning system 116 may include at least one filter to filter out impurities in the fuel that could cause the system to malfunction.
Although the invention has been described in detail for the purpose of illustration based on what is currently considered to be the most practical and preferred embodiments, it is to be understood that such detail is solely for that purpose and that the invention is not limited to the disclosed embodiments, but, on the contrary, is intended to cover modifications and equivalent arrangements that are within the spirit and scope of the appended claims. For example, it is to be understood that the present invention contemplates that, to the extent possible, one or more features of any embodiment can be combined with one or more features of any other embodiment.
Claims
1. A mobile pump system comprising:
- a trailer movable by a vehicle; and
- a pump mounted to the trailer, the pump configured to pump a fluid, wherein the pump comprises an electrically-driven motor mounted to the trailer or is turbine powered by a turbine mounted to the trailer.
2. The mobile pump system of claim 1, wherein the pump is configured to pump the fluid into a wellbore at a tie-in point upstream of a wellhead of the wellbore.
3. The mobile pump system of claim 1, wherein the fluid comprises water and/or a chemical additive.
4. The mobile pump system of claim 1, wherein the pump comprises an auger or impeller configured to move the fluid.
5. The mobile pump system of claim 1, wherein the pump is not permanently installed at a site for performing a pressure pumping application.
6. The mobile pump system of claim 1, wherein the electrically-driven motor is fueled by a battery, natural gas, diesel fuel, or gasoline.
7. The mobile pump system of claim 2, wherein the pump is configured to adjust a flow rate of the pump by 1/10th of a bpm.
8. The mobile pump system of claim 1, wherein the pump is in fluid communication with a wellbore.
9. The mobile pump system of claim 1, wherein the turbine is operated using field gas.
10. The mobile pump system of claim 1, comprising a plurality of pumps mounted to the trailer, wherein each pump comprises an electrically-driven motor mounted to the trailer or is turbine powered by a turbine mounted on the trailer.
11. The mobile pump system of claim 1, further comprising a controller configured to remotely control the pump.
12. The mobile pump system of claim 11, wherein the controller comprises a portable computing device.
13. The mobile pump system of claim 1, wherein the pump is configured to pump the fluid at a flow rate as low as 0.1 bpm.
14. The mobile pump system of claim 1, wherein the turbine comprises a direct coupled gear connection.
15. A method for performing a pressure pumping application comprising:
- providing a mobile pump system comprising: a trailer movable by a vehicle; and a pump mounted to the trailer, the pump configured to pump a fluid, wherein the pump comprises an electrically-driven motor mounted to the trailer or is turbine powered by a turbine mounted to the trailer.
16. The method of claim 15, further comprising:
- pumping the fluid from a fluid container into a wellbore using the pump to move the fluid from the fluid container into the wellbore.
17. The method of claim 16, further comprising:
- positioning a plug in a lateral of the wellbore using the fluid pumped into the wellbore.
18. The method of claim 15, wherein the pump is configured to pump the fluid into the wellbore at a tie-in point upstream of a wellhead of the wellbore.
19. The method of claim 15, wherein the pump is configured to adjust a flow rate by 1/10th of a bpm.
20. The method of claim 15, wherein the pump is configured to pump the fluid at a flow rate as low as 0.1 bpm.
Type: Application
Filed: May 2, 2019
Publication Date: Nov 7, 2019
Inventors: Matthew Curry (McMurray, PA), Christopher Combs (Spring, TX)
Application Number: 16/401,464