MX2010014371A

MX2010014371A - Liquid rod pump.

Info

Publication number: MX2010014371A
Application number: MX2010014371A
Authority: MX
Inventors: Eugene Darrell Simmons
Original assignee: Eugene Darrell Simmons
Priority date: 2008-06-30
Filing date: 2009-06-30
Publication date: 2011-05-03
Also published as: ZA201100691B; EP2313608A2; CA2728801A1; CN102076929A; JP2011526972A; CN102076929B; CA2728801C; JP5620909B2; EP2313608A4

Abstract

The present invention comprises a downhole unit that includes at least one plunger and that uses a power fluid to recover production fluid from a well.

Description

RUBBER PUMP FOR LIQUID DESCRIPTION OF THE INVENTION The embodiments of the present invention relate to the pumping and recovery of underground liquids and, more particularly, to the use of hydraulic principles to facilitate the pumping of liquids without the use of pumping rods.

Currently, there is a need in the oil industry for a pump that pumps to deeper wells, produces greater volume and is capable of recovering fluids from diagonal drilling wells and curved wells. Current technology can not solve the problem of raising water to more than 152.4 meters (500 feet) and at the same time use solar and wind applications as an energy source. There is also a current problem in certain fields related to the disposal of unwanted fluids without the use of additional pumping devices to assist in the process. The embodiments of the present invention are capable of satisfying all the needs described and, at the same time, save energy.

Nowadays, in the oil industry, the main type of pumps for deeper wells depends on a seesaw, used in the industry since the beginning of the 20th century. The prior technology also uses fluid to transfer pressures to a pump at the bottom of a well.

With the current boom of horizontal drilling, the rocker or suction rod pump is not sufficient for this type of drilling. Due to the mechanical connection of the surface with the unit at the bottom of the well, the rocker arm is locked to the precise distance that must be moved and presents difficulties when oscillating the rods in horizontal positions or in diverted wells. The embodiments of the present invention have the ability to vary in displacement and cycles in each pump, which eliminates the wear of the rods, improves efficiency and reduces wear on the downhill pump.

Current technologies do not have a reverse flow system, which does not allow the pump to eject the flow in reverse, which creates maintenance problems.

Current technologies also require removing the entire pump and tube for repairs and do not have the ability to drain the fluid, which, therefore, creates • "possible environmental problems when removing the rods and the 0 tubes from the hole.

Therefore, there is currently a need for an invention that offers configurations that meet the needs of the industry, such as the need for energy efficiency, a less laborious means to perform horizontal pumping and the ability to discard unwanted fluids from a zone. , while pumping valuable fluids from a different area. There is also a current need for a pump that can raise fluid higher than is currently possible with solar and / or wind pumps.

The embodiments of the present invention provide a pump superior to current fluid lift technologies, in particular, the suction rod pump. Preferably, the embodiments of the present invention do not require the use of pumping rods or a rocker on the surface. The modalities also require lower maintenance costs, since they can be operated with fluid and the mechanical parts remain centered when moving; therefore, less wear occurs in moving parts, in particular, in compensation wells.

One embodiment of the present invention may be installed with conventional oilfield equipment using a bottomhole unit comprising pipe, preferably, a pipeline of about 5.08 cm (2 to 5 inches) and more preferably, a pipeline. about 6.03 cm (2 3/8 inches) or about 7.30 mm (2 7/8 inches). A smaller tube, preferably from about 0.635 cm (0.25 inches) to 5.08 cm (2 inches) and more preferably about 2.54 cm (1 inch) or less inside diameter of the tube (flexible or rigid tubing) is Insert into the larger pipe to create an annular area for production. The bottomhole unit preferably uses traditional barrels and pistons of restricted tolerance and has an ascending decompensation., which allows the unit at the bottom of the well to remain at the top of its path when it is not oscillating. Unlike the rocker arm, this pumping technology allows the unit at the bottom of the well to pump a long and slow run or a fast and reduced travel. Due to the concept of fluid displacement, the unit at the bottom of the well does not require a one to one ratio of displacement from the surface to the unit at the bottom of the well.

The embodiments of the present invention preferably improve energy efficiency by about 40 percent compared to known pumps.

One embodiment of the present invention provides an improved pumping system that saves energy, weighs less and requires less maintenance than traditional pumping systems.

Another embodiment of the present invention provides a pump system design that pumps from an underground zone while simultaneously discarding the '· Unwanted fluids to a different underground area. 5 f A further embodiment of the present invention provides a reverse flow system that prevents traditional filters from clogging, clogging and restricting the fluid pump.

One embodiment of the present invention preferably comprises a pumping system without mechanical movement between the surface and the downhole unit in support of the new emerging diagonal wellbore drilling market to maximize the efficiency of the production zone.

Another embodiment of the present invention provides a variable volume pumping system that can be adjusted from the surface without closing the pump or placing a timer for the pump. The variable volume pump is especially useful for water pumps located in isolated areas of the world.

A further embodiment of the present invention provides a high volume pumping system capable of pumping high volumes at low energy using both directions of the pump's travel, thereby increasing efficiency and allowing it to receive solar energy and / or wind energy.

Yet another embodiment of the present invention preferably comprises a method for extracting a string (pipeline that does not contain fluid) in the process.

One embodiment of the present invention is preferably a method for extracting a production fluid from a well with access to a production zone and access to a waste area. The method includes isolating the production and disposal zones from one another, driving a production fluid from the production zone to a production system during a plunger stroke and driving a waste fluid to a waste fluid during the same run. of the plunger. The two zones are isolated with the use of a packing shutter. This modality may also include systematically backflushing the production fluid using a mesh filter so that the particles are not introduced into the system. The waste and production rates can also be adjusted. The settings are preferably based on the volume of the waste fluid in the energy / waste fluid tank.

Another embodiment of the present invention is preferably an apparatus for removing a production fluid from a well with access to a production zone and a disposal zone. Preferably, this apparatus comprises a packing seal for isolating the production zone from the waste zone, a piston that drives the production fluid from the production zone to a production system during a stroke of the piston. The plunger also drives a waste fluid into the waste zone during the same stroke of the plunger. In this way, the production fluid is recovered and the waste fluid is discarded in the same path of the plunger. This embodiment may optionally comprise a mesh filter to counter-flow the production fluid to ensure that no particles are introduced into the stream.

A further embodiment of the present invention is a method for removing fluid from a well. This method includes discarding a unit at the bottom of the well, at least partially within a well, driving a plunger from the unit at the bottom of the well in a first direction, and driving a production fluid from a production zone. to a production system, and impel the plunger of the unit at the bottom of the well in a second direction and drive the production fluid from the production zone to the production system. The piston of the unit at the bottom of the well preferably has a reciprocal action, which creates the production of the production fluid in each path of the unit at the bottom of the well.

One embodiment of the present invention comprises a system for removing fluid from a well. This system includes a unit at the bottom of the well that is at least 0 partially inside a well, a plunger disposed in the unit at the bottom of the well, where the plunger is driven in a first direction thereby the fluid of 'is impelled. "Production from a production area to a production system, and the plunger is driven in a second direction, 5 thereby driving more production fluid from the production area to the production system. In this embodiment, the plunger preferably has a reciprocal action that leads to the production of production fluid in each path of the bottomhole unit.

Another embodiment of the present invention is a method for removing fluid from a well. This method includes the steps of placing a unit in the bottom of the well that comprises one or more pistons and a tube at least partially in the well, applying a fluid of energy, the fluid of energy moves one or more pistons inside the well. the unit at the bottom of the well, propelling a production fluid to a surface of the well, and placing a valve in or near the unit at the bottom of the well, where the valve is releasably activated at or near the surface from the well, thereby releasing the energy fluid contained within the tube when the tube is removed from the well, so that the energy fluid is released through the valve when the tube is drawn through the well. The valve in this mode is preferably an L-shaped valve. When the tube is withdrawn from the well, the tube is preferably a dry tube. The unit at the bottom of the well of this mode is preferably omitted from the well with the use of a base coupling at the bottom of the unit at the bottom of the well.

Still another embodiment of the present invention is an apparatus for moving fluids from a well. The apparatus preferably includes a downhole unit comprising one or more pistons and a and at least partially in the well, a fluid of energy, wherein the energy fluid moves one or more pistons within the well. the unit at the bottom of the well, a production fluid that moves to a well surface, and a valve disposed at or near the unit at the bottom of the well, where the valve releases the energy fluid contained within the well. tube when extracting the tupo from the well. The valve of this apparatus preferably comprises a L-shaped valve when the tube is withdrawn from the well, this is preferably a dry tube. Optionally, a base coupling is located at the bottom of the unit at the bottom of the well.

The objects, advantages and novel features and additional scope of the applications of the present invention will be set forth in part in the following detailed description, together with the accompanying drawings and in part will be apparent to those skilled in the art in channeling the following or they can be learned by practicing the invention. The invention can be carried out and obtained by means of the instruments and combinations indicated in particular in the appended claims.

BRIEF DESCRIPTION OF THE DRAWINGS The accompanying drawings, which are incorporated and form part of the specification, illustrate one or more embodiments of the present invention and, together with the description, serve to explain the principles of the invention. The drawings are only illustrative for one or more preferred embodiments of the invention and should not be construed as limiting the invention. In the drawings: Figure 1 is a side view drawing illustrating an embodiment of the present invention wherein a pulse unit is connected with a single pulse, whose unit displaces the fluid on the surface and drives a unit at the bottom of the well to move down; Figure 2 is a side view drawing illustrating one embodiment of the present, wherein a pulse unit drives a unit from the bottom of the well in each of a plurality of wells to travel downward in opposite paths of a piston in the pulse unit, - Figure 3 is a cross-sectional drawing drawing illustrating a downhole pump according to one embodiment of the present invention; Figure 4 is a side view drawing illustrating a pulse and energy pack unit for the production / disposal of fluids according to an embodiment of the present invention; Figure 5A is a sectional view drawing illustrating a unit at the bottom of the production / disposal well with a waste zone located below a production zone according to an embodiment of the present invention; Figure 5B is a sectional view drawing illustrating a unit at the bottom of the production / disposal well with a waste zone located above a production zone according to another embodiment of the present invention; Figure 6 is a cross-sectional drawing illustrating a pulse unit using mixed fluid and an energy pack unit that releases excess fluid through a new sliding piston design according to one embodiment of the present invention. invention; Figure 7 illustrates an exploded view of the pulse unit illustrated in Figure 6; Y Figure 8 is a sectional view drawing illustrating a downhole double production pumping unit according to one embodiment of the present invention.

As used throughout the specification and the claims, "a" means one or more.

As used throughout the specification and the claims, "energy packaging" means any device, method, apparatus, system or combination thereof capable of at least partially providing a pumping action for a fluid.

As used throughout the specification and the claims, "pulse" means any device, method, apparatus, system or combination thereof or the like capable of moving fluid.

As used throughout the specification and the claims, pipe and tube have a broad meaning and include any device, method, apparatus, system or combination thereof or the like capable of transporting fluid including but not limited to tubes, pipes, channels ducts, strings, combinations thereof and the like made of any material capable of at least temporarily providing a flow path for the fluid, including, but not limited to metals, compounds, synthetics, plastics, combinations of the same, and similar.

As used throughout the specification and the claims, "downhole unit" means a device, method, structure, apparatus, system or combination thereof and the like that are disposed at least partially within a hole. .

- As used throughout the specification and the claims, "plunger" means a device, method, structure, apparatus, system or combination thereof capable of pressurizing a fluid.

As used throughout the specification and the claims, "sequence system" means a device, method, structure, apparatus, system or combinations thereof, capable of activating a pulse device, including but not limited to a sensor. 5 pressure or a series of pressure sensors.

As used throughout the specification and the claims, "production system" means a device, method, structure, apparatus, system or combination thereof, capable of storing or processing yet or more the production fluid including but not limited to to a tank, a surface, a tube, a heat exchanger, a pump and combinations thereof.

As used throughout the specification and the claims, "packaging seal" has a broad meaning and includes any device, method, apparatus, structure, system or combination thereof capable of isolating or separating one area in a hole from another. zone in a hole. For example, a packing shutter can isolate a production zone from a waste area in a well. 0 Closed System With reference to Figure 1, the energy pack 10 on the surface is preferably a closed hydraulic fluid system. The hydraulic fluid is used to '' < '|- transferring energy from the hydraulic pump 14 to a device 25 18 of pulses, of which both are preferably at or near the surface of a well. In a preferred embodiment, the hydraulic fluid is not mixed with an energy fluid. The energy fluid transfers energy from pulse device 18 and provides downward pressure in unit 200 at the bottom of the well (see Figure 2). In this embodiment, the hydraulic fluid is also preferably not mixed with a production fluid. The production fluid is the product pumped to the surface from an underground reservoir with the use of the modalities of the present invention. The energy fluid is also preferably a closed system. Actually, the energy fluid drives the movement of the unit 200 at the bottom of the well, and in one embodiment, it is mostly made up of water. Because the water can practically not be compressed, the pressure is immediately transferred to the bottom 200 unit with very high efficiency and very little compression. If any unanticipated fluid loss occurs, the 40 fluid energy piston creates ':'; A vacuum as it returns to a zero position and thus 0 fills any fluid space in the power tube 204.

Figure 1 illustrates an embodiment of the present invention comprising an energy pack 10 'and a pulse unit 18 which moves fluid on the surface and drives the unit 200 at the bottom of the well for reciprocal action. Figure 1 illustrates the power pack 10 which preferably comprises a motor 12, preferably a standard electric motor. The motor 12 can be an alternating current (AC) or direct current (DC) motor, which allows the application of a solar, wind or manual energy source. The motor 12 is attached to the hydraulic pump 14, which is supported by a tank 16 of the tank. The tank 16 is filled with hydraulic fluid and provides the fluid conduit for the pulse unit 18. The pulse unit 18 is preferably a closed system, in this way, the hydraulic fluid is not mixed with the energy fluid or the production fluid. The line 20 is fastened to the tank tank 16 and moves the hydraulic fluid from the tank tank 16 to the hydraulic cylinder 24 which is sealed with the use of the side cover 28. The hydraulic piston 22 is housed in the hydraulic cylinder 24. The reservoir tank 16 and the hydraulic cylinder 24 can be made of any suitable material capable of retaining hydraulic fluid and operating at high required pressures. The hydraulic valve system 26 activates the pulsing device 18 which oscillates and completes cycles connecting the shaft 30 back and forth. The valve system 26 is preferably controlled through various pressures in the closed energy system and activated by a peak pressure from the bottom 200 unit. As illustrated in Figure 2, the unit 200 at the bottom of the well preferably moves along its entire length, until the lower plunger 234 reaches the lowest point, thereby increasing the pressure in the tube 204 of Energy. The peak in the pressure then reaches a sequence system. The sequencing system then starts the flow of hydraulic fluid through the hydraulic valve system 26 and reverses the direction of the hydraulic piston 22 on the surface. The sequence system can be electrical, mechanical or a combination thereof.

The motor 12 preferably provides the energy leading to the hydraulic pump 14, which boosts the hydraulic fluid to the hydraulic cylinder 24 which then transfers the pressure to the hydraulic piston 22. The hydraulic piston 22 preferably moves and transfers the energy through the connection shaft 30. The shaft 30 moves through the central coupling 32. The central coupling 32 is preferably sealed with a sealing gasket made of any suitable material designed to maintain the pressure differences between the two areas. The connecting shaft 30 is preferably secured to the cylinder 34 of fluid power and the hydraulic cylinder 24. The connection tree 30 is preferably activated andAs the hydraulic piston 22 begins to move towards the cylinder 34 of energy fluid, it accumulates pressure in the energy tube 204. The side cover 36 for the energy fluid prevents the pressure in the energy fluid cylinder 34 from pushing back the hydraulic cylinder 24 and thereby drives all the pressure by concentrating in the downward direction. The respirator 38 allows the energy fluid cylinder 34 to vent 5 inwardly and outwardly and prevents the energy fluid piston 40 from blocking as the power tube 204 begins to build up pressure. The pressure is transferred to the unit 200 at the bottom of the well and applied to the upper plunger 216 (see Figure 2) begins to move downward 0 in the well. As the plungers 216, 222, and 234 are pushed down, that pressure drives the production fluid to move to the annular area 210 to a closed frame in the reservoir tank 16. The production fluid can then be used as a cooling device for the hydraulic fluid, located in a second frame in the tank 16, which cools the hydraulic fluid. The production fluid is also heated through the hydraulic fluid, which makes the production fluid more : 1 ·· easy to process and separate downstream. Preferably, the hydraulic fluid and the production fluid are isolated from each other in the reservoir tank 16. The production fluid preferably moves through the reservoir tank 16 and into the storage tank (not shown).

Figure 2 illustrates an embodiment of the present invention comprising a downhole unit 200 that is connected to a pulse unit 18, see Figure 1.

In one embodiment of the present invention, as illustrated in Figure 2, the exhaust valve 202 is preferably an L-shaped valve and is installed in the power tube 204 between the top of the unit 200 in the bottom of the well and the beginning of the energy tube 204. The exhaust valve 202 allows the energy fluid to drain from the energy tube 204 as the unit 200 at the bottom of the well is drawn to the surface, for example, in the case of necessary repairs. The exhaust valve 202 allows a repair team to remove a dry string, a tube that does not contain fluid, instead of a wet string. The ability to extract a dry string prevents the spillage of energy on a surface. Preferably, the exhaust valve 202 is initially closed, then bent and the energy tube 204 slides upward and pushes the energy tube 204 up and out of the hole. When the energy tube 204 is removed, it passes through the respirators 206 and 208 which drain the energy fluid, thus, extracting a "dry" string. In one embodiment, when removing a tube, a repair team does not remove a wet string. 1: The annular area 210 is the area through which the production fluid is moved to the surface. The 200 unit at the bottom of the well is preferably located at the base 212 in the bottom of the 200 unit at the bottom of the well. The base coupler 212 can also be installed in the upper part of the unit 200 at the bottom of the well, whereby the unit 200 is suspended at the bottom of the well with respect to the base coupling 212. The annular area 210 comprises the area between the energy tube 204 and outer pipe 214. As the unit 200 at the bottom of the well is placed, the production fluid remains in the annular area 210 or, if the unit 200 at the bottom, of the well is not placed, the production fluid is released to the reservoir.

The unit 200 at the bottom of the well preferably receives pressure from a pulse unit 18 in the upper plunger 216. When pressure is applied to the upper plunger 216, it moves in a downward direction, such as the connecting shaft 218 and the pistons 222 and 234. The plunger 216 is preferably held in place by the cylinder 220. The pressure in the The upper plunger 216 turns into a f ferza and activates the plunger 222. The plunger 222 is preferably used to balance the pressure. The unit 200 at the bottom of the well creates a rising force greater than a downward force when the unit 200 at the bottom of the well remains static, because the area 224 of the reservoir has less pressure than the unit 200 at the bottom of the well, this creates an upward decompensation in unit 200 at the bottom of the well. Therefore, the only energy required i- from the surface is sufficient to move the pistons 216, 222 and 234 downwards. The upper part of the plunger 222 is preferably exposed to the reservoir through the vent 226. The coupling 228 seals the cylinder 220, thereby creating a pressure differential in the upper part of the plunger 222. Although the upper part of the plunger 222 is exposed to the reservoir, the bottom of the plunger 222 is exposed to the annular area 210 through the breathing opening 230, which creates an upward pressure with the use of the coupling 232 to separate the fluid pressures. Coupling 232 is designed to prevent pressures from becoming uniform in area 224, which is exposed to the deposit. The upper part of the plunger 234 is exposed to the reservoir and the bottom of the plunger 234 is exposed to the production fluid and used to move the production fluid to the outside of the valves 236 and to the upper part of the annular area 210. The production fluid preferably moves in and out of the production chamber 238. The valves 236 preferably comprise unilateral check valves between the chamber 238 and the annular area 210, where the production fluid is preferably displaced from the chamber 238 to the annular area 210. The valves 240 also comprise unilateral check valves that prevent the production fluid in the chamber 238 from returning to the reservoir. As the unit 200 at the bottom of the well moves downward, the downward pressure drives the valves 236 to open, whereby production fluid is sent to the upper part of the annular area 210. As the unit 200 at the bottom of the well moves up again, the upward force opens the valves 240 to accept the production fluid in the chamber 238 from the reservoir after filtering the fluid through the filter system 242.

The filter system 242 preferably comprises a mesh filter installed in the bottom of the unit 200 at the bottom of the well. The filter system 242 is not obstructed, because the upper chambers of the 200 unit at the bottom of the well are ventilated to the reservoir. This venting allows the fluid to oscillate in and out of the 200 unit at the bottom of the well. The downward pressure from the bottom well unit 200 creates an external fluid force from the chamber 238, which removes any residue that may accumulate around the filter and prevents the unfiltered fluid flow in the upper chambers 224 and 244 from enter in unit 200 at the bottom of the well.

Multiple Wells With reference to Figure 3, one embodiment of the present invention comprises an energy pack 300 and a pulse device 312. The units 302 and 304 at the bottom of the well preferably operate with only one surface unit, ie, an energy pack 300 and a pulse device 302, thereby further improving the efficiency of the pulse device 312. In one configuration, when using the power pack 300, the pulse device 312 can be used to pump two or more wells. In this embodiment, the pistons 306 and 308 oscillate back and forth so as to recover the production fluid in the downward travel in the two units 302 and 304 at the bottom of the well. The production fluid is then used to cool the hydraulic fluid in reservoir tank 314 and at the same time, the production fluid is heated for a simpler separation of oil and water in the production fluid before being sent to the tank 316 .

Isolated Waste Area With reference to Figures 4 and 5A-5B, another embodiment of the present invention comprises a pulse device 402 and a downhole unit 500 that allows the recovery of fluid production from an area ; In a well and at the same time has the ability to discard or an unwanted fluid in a second zone in the well. In this embodiment, once the plunger 527 is brought to the lowest point, the pressure increases to a peak amount in the power tube 504, which opens the pressure relief valve 522 and drives the unwanted energy fluid to through the packing plug 508 to an insulated area suitable for discarding unwanted fluid. When all the desired fluid is discarded in the waste zone 526, the energy fluid piston 422 comes into contact with the side cover 42 6, which creates an additional peak in pressure, which triggers a frequency system to reverse the pressure. 42 0 pulse device and extracting an additional energy fluid upon opening the valve 430 for the next cycle. The pulse device 402 has two levels of operating pressure and provides two different functions, one level of pressure for recovering the production fluid from one reservoir and the other level of pressure for discarding unwanted fluid.

Figure 4 illustrates an embodiment of the present invention comprising an energy pack 400 and a pulse device 402 for recovering underground liquids.

This mode preferably uses two areas of a well in a downhole situation when pumping production fluid out of a reservoir zone and at the same time discarding unwanted fluid in a second reservoir zone.

The power pack 400 and the pulse device 402 preferably comprise a motor 404. The engine 404 is preferably a standard waterproof AC or DC power supply. The energy pack 400 preferably includes a reservoir 406, which preferably comprises a hydraulic fluid. The reservoir 406 may be made of any suitable material capable of retaining the hydraulic fluid. The reservoir 406 has a more or less low pressure and can be applied with an additional chamber to allow the production fluid to flow through it., with what you create a. heat exchanger to cool the hydraulic fluid. In this mode, the engine 404 generates energy and transfers that energy to the hydraulic pump 408. The hydraulic fluid is pumped through the hydraulic pump 408 to the unit 410, and generates high pressure as it passes through the high pressure hydraulic line 412. Line 412 may be made capable of any material capable of withstanding high pressures. The line 412 supplies hydraulic fluid to the hydraulic cylinder 414 that rests on the side cover 416. The hydraulic fluid is pushed against the hydraulic piston 418, which oscillates back and forth. The hydraulic piston 418 is preferably installed with a restricted tolerance gap and is connected to the connection shaft 420. The hydraulic piston 418 moves towards the shaft 420, which then transfers energy to the piston 422 of energy fluid. This action creates pressure in the cylinder 424 of energy fluid that is held in place by the side cap 426 until the waste fluid / energy fluid is released through the outlet 428.

. Preferably a one-way check valve 430 is opened to replace the energy fluid in a cylinder 424 of energy fluid in the case of any unanticipated loss of energy fluid during the return path of the pulse device 402, according to the device 402 of pulses moves back towards the hydraulic cylinder 414 to the zero position. Any energy fluid space may create a vacuum, which may allow the opening of a one-sided check valve 430 thereby ensuring that the downward stroke of the pulse device 402 completely pools the fluid to ensure that the unit 500 at the bottom of the well moves through the entire distance for which it was designed, that is, to the lowest point.

As the energy fluid piston 422 swings toward the side cover 426, the production fluid travels to an annular area in the production tank 432. The energy / waste fluid is separated from the production fluid and placed in tank 434 and reused through line 436 to fill cylinder 424 with energy fluid to start another cycle. In this embodiment, the energy / waste fluid is used to activate the unit 500 at the bottom of the well. The unit 500 at the bottom of the well preferably raises the production fluid to the surface and also discards unwanted fluid in a waste zone. The waste area can be above or below a production zone. Figure 5A illustrates an embodiment of the present invention with the waste zone located below the production zone. Figure 5B illustrates an embodiment of the present invention with the waste zone 5 located above the production zone.

By modifying the reciprocal set points for the pistons 418 and 422, the volumetric displacement of the waste fluid removed from the tank 434 in relation to the quantity of production fluid entering the tank 432 0 can be adjusted so as to produce an index optimized production / disposal. This adjustment allows more waste fluid to be discarded in the waste area as tank 434 reaches its capacity limit. Alternatively, as tank 434 approaches an empty state, the rate of fluid discharge 5 may decrease. Those skilled in the art will readily appreciate various ways for such reciprocal adjustment points that include electronic sensors and / or physical alterations to the connecting shaft 420, the pistons 418 and / or 422 as well as the 0 caps 416 and 426. In one embodiment, preferably an electronic circuit is provided that adjusts the points of reciprocity based on the fluid levels of tank 434 and / or tank 432 or alternatively, based on some '-' another measure or criterion specified by the user. 5 'Figures 5A and 5B illustrate embodiments of the present invention comprising a downstream production / disposal well unit 500 that operates in conjunction with pulse device 402 and power pack 400 in Figure 4. The unit 500 at the bottom of the well preferably pumps production fluid from one area of a reservoir to the tank 432 and discards unwanted fluids in another area of a reservoir in the same pulse path 402.

In an embodiment of the present invention, the The production fluid is transferred to the surface through the annular area 502 which is the area between the energy tube 504 and the production tube 506. The energy tube 504 preferably comprises a tube of about 1.27 to 12.7 cm (0.5 to 5 inches) and, more preferably, a tube of About 1.9 to 7.6 cm (0.75 to 3 inches) and more preferably a tube of about 2.54 cm (1 inch) and, preferably the production tube 506 comprises a tube of about 0 to 12.7 cm (0 to 5 inches) and greater * '' prefer a tube of 5 to 10 cm (2 to 4 inches) and 20 preferably a tube of about 7.3 cm (2 7/8 inches).

The unit 500 at the bottom of the well is preferably established in a hole with packing plug 508. Standard equipment can be used to provide the separation of a production zone and a waste area. The unit 500 At the bottom of the well, it is preferably installed with a pipe capable of transferring fluid at the desired pressures.

The waste fluid / energy chamber 520 is preferably a closed system that transfers pressure from the surface to the upper part of the plunger 510. The upper coupling 512 preferably maintains the separation of the pressures. The bottom of the plunger 510 is exposed to the annular area 502. The production fluid in the annular area 502 creates the upward force in the pistons 510 and 514.

The area under the plunger 514 separates the pressures and fluids between the pistons 514 and 527 with the coupling 516. The vent 518 comprises energy / waste fluid and serves as the connecting rod for the pistons 510, 514 and 527. The valve 522 of The high pressure exhaust is installed at the bottom of the vent 518 for the waste of the energy / waste fluid, and does not open unless the pressure in the downhole unit 500 exceeds the normal operating production pressures, in the that the moment when the high pressure exhaust valve 522 is opened and the excess waste fluid is driven to the waste area through the packing plug 508.

In one embodiment of the present invention, the waste / energy fluid exerts a downward pressure on the plunger 510, which causes the plungers 510, 514 and 521 to travel in a downward direction. This downward pressure drives the production fluid to the annular area 502 through the check valve 524. When the assembly 510, 514 and 527 reach the bottom of a desired distance, the plungers 510, 514 and 527 reach the lower part and the pressure is accommodated in the unit 500 at the bottom of the well until the downward pressure of fluid Waste / energy exceeds the production operating pressure. At that point, the high pressure exhaust valve 522 opens and deposits the unwanted fluid in the waste area 526 through the packing plug 508. The opening of the high pressure exhaust valve 522 reaches a sequencing system and the energy fluid piston 422 (Figure 4) moves towards the hydraulic piston 418, thereby moving the pistons 510, 514 and 527 in an upward direction. The unidirectional retention valve 528 absorbs the production fluid in each oscillation of the unit 500 at the bottom of the well. The check valve 524 for the outlet is on the opposite side of the pipe and urges the production fluid to the top of the annular area 502. The screen filter 530 is attached to the valve system 528, which can prevent debris from entering the unit 500 at the bottom of the well. As illustrated in Figures 5A and 5B, the unit 500 at the bottom of the well can be installed with a waste area 526 either above or below the production zone 532.

Figure 6 illustrates an embodiment of the present invention comprising a power pack 600 and a pulse device 602 that preferably mix the energy and production fluids and release fluids through the exhaust valves 604 and 606. Figure 7 illustrates an exploded drawing of the pulse device 602.

This embodiment of the present invention comprises an energy pack 600 on the surface with the device 10 602 of pulses equipped to mix the production fluids and the 'energy fluids. Preferably, the power pack 600 comprises an electric motor for the power supply 616, which may be a DC motor or an AC motor adaptable for solar, wind or manual operation.

Alternatively, the power pack 600 can be executed only with a solar or wind power supply. The motor is preferably mounted in a hydraulic fuel tank 618 and connected to the pump 620 "Hydraulic The 622 hydraulic power line connects with 20 the sequence system 626 and used to transfer energy to the camera C to oscillate the pistons 628, 610 and 614 in the pulse device 602. The pulse device 602 preferably comprises three separate fluid chambers (A, B and C), one of which (Chamber C) has 25 hydraulic fluid and preferably is a completely closed system. The hydraulic fluid is preferably withdrawn from the tank 618 through the hydraulic pump 620 and is driven into the Chamber C, which drives the piston 628 in a direction towards Chamber B and causes the piston 614 to drive the fluid disposed within the chamber. the Chamber B towards the tube 814. Then, the fluid drives the plunger 810 (see Figure 8), which generates the production of fluid within the chamber 811 of the unit 800 at the bottom of the well to be propelled up the tube 808 through valve 804 and upward to tube 608. Once chamber 811 closes and plunger 810 is placed against coupling 812, a pressure peak occurs on side B and system 626 sequence activates the piston 628 to move the connecting shaft 624 and the pistons 610, 614 and 628 towards the chamber A, whereby production fluid is sent down to the side A and the excess fluid is sent upwards and out from camera B to through valve 606 upon opening cone valve 702 disposed in piston 614.

After releasing the excess fluid through the valve 606 and pistons 806 and 810 reach the lowest point, another pressure peak occurs and the sequence system 626 reverses the direction and, then, the connection shaft 624 moves towards the tube 814 and close the cone valve 702. The cone valve 702 is preferably closed using a stop, seat, detentor, combinations thereof or the like which are arranged in the piston 614. The cone valve 702 can be optionally closed using a stop, seat, detent, combination of the same or similar that is located in the chamber B. The pressure of the moving piston 614 towards the tube 814 drives the fluid down the tube 814 and drives the pistons 806 and 810 upwards, which drives the fluid from the chamber 811 up the ventilation tube 808, through the valve 804 and up the tube 608..When the excess fluid between the chamber A from the tube 608, the cone valve 700 opens and releases the excess fluid out of the valve 604. When all the excess fluid is released through the valve 604 and when the chamber 811 closes, another pressure peak occurs and the system and sequence 626 drives a directional change of the piston 628. The 628 piston then pushes the piston 610 towards the tube 614 and closes the cone valve 700. The cone valve is preferably closed using a stop, seat, stop, combination thereof or the like which is disposed in the piston 610. The cone valve 700 can optionally be closed using a stop, seat, detentor or combination thereof. same or similar that is located in the chamber B. This cycle is repeated with each oscillation of the pulse device 602. This process continues in one cycle, since the same fluid is used to activate the 800 unit at the bottom of the well and has the capacity to release the excess fluid in the upward path of each cycle.

With reference to Figures 6-8, this embodiment of the present invention can be used to narrow wells and can use fluted or flexible lines to transfer pressures and production. This mode can also be installed as a portable or permanent installation. In one embodiment of the present invention, the pulse device 602 preferably has about 7.6 to 50.8 cm (3 to 20 inches) in diameter and more preferably, about 17.7 to 25.4 cm (7 to 10 inches in diameter). The pistons 610 and 614 are preferably installed with a restricted tolerance gap with the pulse device 602., in this way, the diameter of the pistons 610 and 614 are preferably closed to the diameter of the pulse device 602. Cone valves 700 and 702 preferably have about 0 to 10 (0 to 4 inches) in diameter and more preferably have a diameter of about 2.54 to 7.62 cm (1 to 3 inches). In this way, the excess fluid is preferably expelled from the more or less small diameters of the conical valves 700 and 702 which are arranged in the pistons 610 and 614 of larger diameter. If the unit 800 is installed with flexible lines, it is preferred that a small cable be attached to the unit 800 and interlocked with the two lines to provide the necessary tensile strength during the removal of the unit 800.

Figure 8 illustrates an embodiment of the present invention comprising a bottom-hole unit 800 that is capable of recovering fluid from both sides of its path.

Figure 8 is a continuation of the pump assembly illustrated in Figures 6-7. Figure 8 shows the lower section of the assembly. The unit 800 in this mode is capable of producing fluid on each side of its path, called Side A and Side B. As the tube 608 of Side A receives fluid pressure at the surface, the fluid forces the closure of the valve 804 of retention, the plungers 806 and 810 move downward and push fluid out of the chamber 820 through the valve 816 and up the tube 814 on the B side and also push the fluid out of the chamber 826 and at the same time, it fills camera 811 through valve 828 on side A.

When the plungers 806 and 810 reach the lowest point, a peak occurs in the pressure in the chamber A which activates the sequence system 626 which then sends hydraulic fluid to the chamber C and moves the connecting shaft 624 and the pistons 610, 614 and 628 to the side B, which pushes the fluid down the tube 814 and moves the pistons 810 and 806 upwards until the plunger 810 comes into contact with the coupling 812. As the piston 614 moves towards the tube 814 , the conical valve 700 disposed in the piston 610, opens and allows excess fluid in the chamber A to escape through the valve 604. When all the excess fluid is released through the valve 604 and when the chamber 811 closes, a pressure peak occurs on the B side and the sequence system 626 is activated and forces the piston 628 to move to the A side, which then closes the conical valve 700 and drives the fluid down the tube 608. The fluid drives the 806 pistons and 810 to move downward and the fluid in the chamber 820 is pushed up the tube 814 on the B side. As the fluid is pushed down from the A side and urged upward from the B side, the conical valve 702 disposed in the piston 614 opens and excess fluid is released through valve 606. When plungers 806 and 810 reach the lowest point and all excess fluid is released through valve 606, a pressure peak occurs at side A which triggers sequence system 626, which activates plunger 628 to move to side B.

This embodiment creates two production areas, the chambers 820 and 811. When the downward pressure drives down the plunger 806, the valve 816 sends fluid from the chamber 820 up the tube 814 on the B side. As the upward pressure drives the plunger 806 to move upwardly, chamber 820 is again filled with production fluid through valve 818. When downward pressure pushes plunger 810 down, chamber 811 is filled with production fluid through valve 828 When the upward pressure urges the plunger 810 to move upward, the production fluid in the chamber 811 moves upward of the ventilation tube 808 through the valve 804 and in the tube 608 on the A side. At the same time, the 820 chamber is filled with production fluid through valve 818. The production fluid is mixed with the production / energy fluid from side A, which allows the fluid to escape to through plunger 806. This process goes through a cycle and continues to oscillate, thereby creating production. As the plungers 806 and 810 move, a vacuum is created, which opens the production chamber 820 and introduces additional production fluid. Within the same path, the bottom plunger 806 drives the stored fluid out of the stop valve 816 up through the energy / production tube 814. This process allows an effective pumping and greater capacity to recover fluid with variable volumes.

Marginal wells The embodiments of the present invention allow marginal wells to be put back into operation. Marginal wells are those wells that would otherwise be eliminated from production due to high energy and maintenance costs. Marginal costs become profitable again when using a pulse device of one embodiment of the present invention.

Shallow Wells The embodiments of the present invention can also recover fluid from shallow wells. Flexible lines and hydraulic reels are preferably used in isolated areas where there is no available electric power. In one embodiment, a small energy package can be mounted on a ramp with a reel that allows a pulse unit to be installed in a very short time and without the use of a rig.

Deviated Wells A pulse device of the present invention can pump from diverted wells without the wear of the pipe that is placed from the hole to the surface of the downhole unit.

Angular drilling One embodiment of the present invention can be used in wells that are drilled with a lag with respect to a reservoir. The embodiments of the invention can pump through a field and then pump in a vertical position or in any angular downhole position. With the high demand for horizontal drilling activity and the high cost of energy, the embodiments of the present invention create a great advantage in the market by having the ability to be installed in a vertical position and to deflect the angle in a horizontal position.

Efficient Pumping The additional embodiments of the present invention allow the pumping on both sides of a path in a downhole unit, which improves efficiency, thus offering an ideal design for its application in the use of solar and wind energy.

Filter system One embodiment of the present invention comprises a unique filtering system that prevents sand and other small debris from accumulating in the downhole unit. One of the main problems with downhole pumping systems in the existing pumping technology is if a small mesh filter is placed in the downhole pump, the debris tends to clog or clog the filter and avoid that the flow of fluid enters the pump. If a mesh is placed in the downhole unit, the filter allows sand and small debris to pass to the pump, which causes wear within the downhole unit. Preferably, this embodiment of the present invention creates a reverse flow in the filter in each cycle of the pump, which allows to install a smaller mesh filter without clogging or clogging. This mode also filters the sand from the milling, which increases the life of the pistons and barrels in the downhole unit, especially due to the presence of fracturing sand in new wells.

Volume Adjustments Once an energy package, pulse unit and downhole unit of the present invention are installed and pumped, it is possible to adjust the output without a timer and without the need to turn off the system. The variable hydraulic pumps on the surface allow the owner / operator to adjust the system according to the outlet of the well.

Esthetic The embodiments of the invention can be installed underground, which makes them invisible from the surface. The energy package and pulse device on the surface can be installed at ground level or below in order to maintain the appearance of the ground.

Although the invention has been described in detail with reference to these preferred embodiments, other embodiments may obtain the same results. The variations and modifications of the present invention will be obvious to those skilled in the art and it is intended to cover all such modifications and equivalents in the appended claims. Full descriptions of all references, applications, patents and publications cited are incorporated herein by reference.

Claims

1. A method for removing a production fluid from a well with access to a production zone and access to a waste area, the method characterized in that it comprises: isolate the production and disposal areas; driving a production fluid from the production zone to a production system during the course of a piston; and drive a waste liquid to the waste area during the same stroke of the plunger.

2. The method according to claim 1, characterized in that isolating the production zone and the waste zone is provided by a packing obturator.

3. The method in accordance with the claim 1, further characterized in that it comprises systematically generating a reverse flow of the production fluid.

4. The method according to claim S, characterized in that the step of creating reverse flow uses a mesh filter.

5. The method according to claim 1, further characterized in that it comprises adjusting the waste and production indices.

6. The method according to claim 6, characterized in that the adjustment is based on the volume of waste fluid in a tank.

7. An apparatus for removing a production fluid from a well with access to a production zone and a waste area, the apparatus characterized in that it comprises: a packing shutter to isolate the production zone from the waste area; a piston, wherein the piston drives the production fluid from the production zone to a production system during a stroke of the piston; Y wherein the plunger drives a waste fluid in the waste area during a same stroke of the plunger.

8. The apparatus according to claim 7, further characterized in that it comprises a mesh filter to create a reverse flow of the production fluid.

9. A method for removing fluid from a well characterized because it comprises: dispose a bottom unit of the well at least partially inside a well; driving a plunger of the downhole unit in a first direction and driving the production fluid from a production zone into a production system; e '·' impel the plunger of the downhole unit in a second direction and drive the production fluid from the production zone to the production system.

10. The method according to claim 9, characterized in that the plunger of the downhole unit has a reciprocal action that generates the production of the production fluid in each path of the downhole unit.

11. A system for removing fluid from a well characterized because it comprises: a downhole unit at least partially inside a well; a plunger disposed in the downhole unit, wherein the plunger is driven in a first direction, which drives the production fluid from a production zone to a production system; Y wherein the plunger is driven in a second direction, which drives the production fluid from the production zone to the production system.

12. The system according to claim 11, characterized in that the plunger has a reciprocal action that generates the production of the production fluid in each path of the downhole unit.

13. A method for moving fluid from a well, characterized in that it comprises: arranging a downhole unit comprising one or more pistons and a tube, at least partially inside the well; apply a fluid of energy, the energy fluid moves one or more pistons inside the downhole unit; drive a production fluid to a well surface; Y dispose a valve in or near the downhole unit, where the valve is releasably activated on or near a well surface, thereby releasing energy fluid contained within the tube when the well tube is removed , so that the energy fluid is released through the valve when extracting the tube through the well.

14. The method according to claim 13, characterized in that the valve is an L-shaped valve.

15. The method according to claim 13, characterized in that the tube extracted from the well comprises a dry tube.

16. The method according to claim 13, characterized in that the downhole unit is placed in the well using a base coupling in the lower part of the downhole unit.

! ' 17. An apparatus for moving fluid from a well, characterized in that it comprises: a downhole unit comprising one or more pistons and a tube, at least partially inside the well; an energy fluid, wherein the energy fluid moves one or more pistons inside the downhole unit; a production fluid that moves to a well surface; Y a valve disposed on or near the downhole unit, where the valve releases the energy fluid contained within the tube when the tube is withdrawn from the well.

18. The apparatus according to claim 17, characterized in that the valve comprises an L-shaped valve.

19. The apparatus according to claim 17, characterized in that the tube extracted from the well comprises a dry tube.

20. The apparatus according to claim 17, further characterized in that it comprises a base coupling, wherein the base coupling is placed in the lower part of the downhole unit.