CN102076929A - Liquid rod pump - Google Patents

Abstract

The present invention includes a downhole apparatus that includes at least one piston and that uses a power fluid to produce production fluids from a wellbore.

Description

liquid rod pump

Cross References to Related Applications

This application claims U.S. Provisional Patent Application Serial No. 61/133,373, filed June 30, 2008, entitled "Liquid Rod Pump" and U.S. Patent Application Serial No. 61/133,373, filed November 21, 2008, entitled "Liquid Rod Pump" Priority and benefit of Provisional Patent Application Serial No. 61/199,853, the specification and claims of which are hereby incorporated by reference.

technical field

Embodiments of the present invention relate to the pumping and recovery of subsurface fluids, and more particularly to the application of hydraulic principles to facilitate the pumping of fluids without the use of sucker rods.

Background technique

There is currently a need in the petroleum industry for pumps that pump deeper wells, generate greater volumes, and are capable of producing fluids from deviated and curved wells. Current technology does not address the problem of raising water greater than 500 feet while being able to apply the sun and wind to the power source. There are also present problems in certain areas of handling unwanted fluids without the use of additional pumping means to aid in the process. Embodiments of the present invention are able to meet all of the above needs, while also being more energy efficient.

Currently in the petroleum industry, the main type of pump used for deeper wells relies on the pumping unit which was already in use in the petroleum industry in the early 20th century. In downhole situations, earlier techniques have also been used to employ fluid to transmit pressure to the pump.

With current horizontal drilling rigs, pumping units or sucker rod pumps are not effective for this type of drilling. Because of the mechanical connection from the surface to the downhole unit, the pumping unit is locked to a certain precise distance it will travel, and it is difficult to shake the rod in a horizontal position or in a deviated well. Embodiments of the present invention have the ability to vary the stroke and cycle in each pump, which eliminates rod wear and improves efficiency and reduces downhill pump wear.

Current technology does not have a backwash filtration system, which does not allow the pump to be backwashed, thus creating maintenance issues.

Current technology also requires the entire pump and piping to be pulled out for servicing and does not have the ability to drain fluid, so this creates potential environmental issues when pulling the rod and piping from the bore.

Therefore, there currently exists a need for an invention that provides a structure that meets industry needs such as the need for energy efficiency, effortless means of horizontal pumping, handling of unwanted fluid from one area while pumping from a different area Ability to produce valuable fluids. There is also currently a need for pumps that can lift fluids higher than currently possible with pumps powered by the sun and/or wind.

Contents of the invention

Embodiments of the present invention provide a pump that outperforms current fluid lift technology, particularly sucker rod pumps. Embodiments of the invention preferably do not require the use of sucker rods or jacks at the surface. Embodiments also require little maintenance because they can be fluid driven and the mechanical parts remain centered as they travel; therefore, there is less wear and tear on moving parts, especially for offset wells.

One embodiment of the present invention may be installed with conventional oilfield equipment employing downhole installations, including tubing, preferably about 2 to 5 inches of tubing, and more preferably about 2 3/8 (2.375) or about 2 7/ 8 (2.875) inches of pipe. Smaller conduits, preferably about 0.25 to 2 inches of tubing, more preferably about 1 inch or less inside diameter (flexible or rigid tubing), are inserted into the larger tubing to form the annulus for production production. The downhole device preferably employs a conventional close tolerance cylinder and piston with an upward imbalance which allows the downhole device to stop at the top of its stroke when it is not oscillating. Unlike pumpjacks, this pumping technology allows downhole units to pump either long-slow strokes or short-fast strokes. Due to the fluid displacement concept, the downhole device does not require a one-to-one displacement ratio from the surface to the downhole device.

Embodiments of the present invention are preferably about 40% more energy efficient than known pumps.

One embodiment of the present invention provides an improved pumping system that is energy efficient, lightweight, and requires less maintenance than conventional pumping systems.

Another embodiment of the present invention provides a pump system design that pumps from one subterranean zone while distributing unwanted fluids to a different subterranean zone.

Yet another embodiment of the present invention provides a backwash filtration system that prevents conventional filter clogging, sealing and pump starvation.

Embodiments of the present invention preferably include a pumping system with no mechanical movement between surface and downhole devices, supporting the emerging market of inclined drilling of wells 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 shutting down the pump or setting it as a timing device. Variable volume pumping systems are especially used for water pumps located in isolated areas of the earth.

Yet another embodiment of the present invention provides a high capacity pumping system capable of pumping large volumes at low energy by utilizing both directions of the pump stroke, thereby increasing efficiency and allowing it to be powered by solar and/or wind energy.

Yet another embodiment of the invention preferably includes a method of dragging a dry string (pipeline that does not contain fluid) during the process.

An embodiment of the invention is preferably a method for removing production fluids from a wellbore leading to a production zone and to a disposal zone. The method includes the steps of: isolating a production area and a disposal area; propelling a production fluid from the production area to the production system during a stroke of the piston; and propelling the treatment fluid into the disposal area during the same stroke of the piston. The two regions are separated by a packer. This embodiment may also include systematically backflushing the production fluid with the screen filter so that particulates do not enter the system. Disposal and production rates can also be adjusted. The adjustment is preferably based on the volume of treatment fluid in the power/disposal fluid tank.

Another embodiment of the invention is preferably an apparatus for removing production fluids from a wellbore leading to a production area and a disposal area. The apparatus preferably comprises: a packer for isolating said production area from said disposal area; a piston, wherein during a stroke of said piston, said piston pushes production fluid from said production area towards a production system . During the same stroke of the piston, the piston also pushes treatment fluid into the treatment region. Thus, production fluid is withdrawn and disposal fluid is disposed of during the same stroke of the piston. This embodiment may optionally include a screen filter for backflushing the production fluid to ensure that there are no particulates in the fluid stream.

Yet another embodiment of the invention is a method for removing fluid from a wellbore. The method includes the steps of: positioning a downhole device at least partially in a well; urging a piston of the downhole device in a first direction and pushing production fluid from a production zone into the production system; and urging all of the downhole device in a second direction The piston pushes the production fluid from the production area into the production system. The piston of the downhole device preferably reciprocates to produce production fluid with each stroke of the downhole device.

One embodiment of the invention includes a system for removing fluid from a wellbore. The system includes: a downhole device located at least partially within the well; a piston disposed in the downhole device, wherein the piston is urged in a first direction, thereby pushing production fluid from a production zone into the production system, and The piston is pushed also in a second direction, thereby pushing more production fluid from the production area into the production system. In this embodiment, the piston preferably reciprocates to produce production fluid with each stroke of the downhole device.

Another embodiment of the invention is a method for moving fluid from a wellbore. The method includes the steps of: disposing at least partially within a wellbore a downhole device comprising tubing and one or more pistons; applying a motive fluid that moves the one or more pistons of the downhole device; to the surface of the well; and disposing a valve on or near the downhole device, wherein the valve is releasably actuatable at or near the surface of the well, thereby releasing the power fluid in the pipe to release power fluid through the valve when the pipe is removed from the wellbore. The valve in this embodiment is preferably an L-shaped valve. When removing said tubing from said wellbore, said tubing is preferably dry tubing. The downhole assembly of this embodiment is preferably secured in the wellbore with a seat joint at the bottom of the downhole assembly.

Yet another embodiment of the invention is an apparatus for moving fluid from a wellbore. The apparatus preferably comprises: a downhole assembly comprising one or more pistons and tubing disposed at least partially within the wellbore; a dynamic fluid, wherein the dynamic fluid moves the one or more pistons within the downhole assembly; production fluid to the surface of the well; and a valve disposed on or near the downhole apparatus, wherein the valve releases motive fluid contained within the tubing when the tubing is removed from the well. Said valve of the device is preferably an L-shaped valve. When the pipe is removed from the well, it is preferably a dry pipe. A seat sub is optionally fixed at the bottom of the downhole unit.

The objectives, advantages, novelty features and other scope of application of the present invention will be partly proposed in the following detailed description in conjunction with the accompanying drawings, and partly will become apparent to those skilled in the art by examining the following description, or can be obtained through this Practical understanding of invention. The invention can be realized and obtained by means of the instrumentalities and combinations particularly pointed out in the appended claims.

Description of drawings

The accompanying drawings, which are incorporated in and form a part of this specification, illustrate one or more embodiments of the invention and together with the description serve to explain the principles of the invention. The drawings are only for purposes of illustrating one or more preferred embodiments of the invention and are not to be construed as limiting the invention. In the attached picture:

Figure 1 is a side view illustrating an embodiment of the invention wherein a pulsar unit is attached to a single wellbore, the unit moves fluids to the surface and propels downhole equipment downhole;

Figure 2 is a side view, an embodiment of the invention wherein a pulsar unit pushes a downhole device in each of a plurality of wells to move downward on opposite strokes of the pistons in the pulsar unit;

3 is a cross-sectional view illustrating a downhole pump according to an embodiment of the present invention;

Figure 4 is a side view illustrating a pulsar unit and a power unit for production/disposal of fluids according to an embodiment of the present invention;

Figure 5A is a cross-sectional view illustrating a production/disposal downhole assembly according to an embodiment of the present invention, wherein the disposal zone is located below the production zone;

5B is a cross-sectional view illustrating a production/disposal downhole assembly according to another embodiment of the present invention, wherein the disposal zone is located above the production zone;

6 is a cross-sectional view illustrating a pulsar unit utilizing mixed fluids and a power unit releasing excess fluid through a new sliding piston design according to an embodiment of the present invention;

Figure 7 illustrates an enlarged view of the pulsar unit illustrated in Figure 6; and

8 is a cross-sectional view of a downhole dual production extraction unit according to an embodiment of the present invention.

Detailed ways

As used throughout the specification and claims, the indefinite article means one or more.

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

As used throughout the specification and claims, "pulsar" refers to any device, method, apparatus, system, or combination thereof, etc., capable of moving fluids.

As used throughout the specification and claims, pipe and tube are to be given a broad meaning and include any device, method, apparatus, system or combination thereof, etc. capable of transporting fluids, including but not limited to pipes, piping systems , channels, conduits, tubing strings, or combinations thereof, made of any material capable of at least temporarily providing a flow path for fluids, including but not limited to metals, composites, synthetic materials, plastics, or combinations thereof.

As used throughout the specification and claims, "downhole device" means a device, method, structure, apparatus, system, or combination thereof, etc., disposed at least partially within a wellbore.

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

As used throughout the specification and claims, "sequential system" means an apparatus, method, structure, apparatus, system or combination thereof capable of activating a pulsar, including but not limited to a pressure sensor or series of pressure sensors.

As used throughout the specification and claims, "production system" means an apparatus, method, structure, apparatus, system, or combination thereof capable of storing or further processing production fluids, including but not limited to storage tanks, surfaces, pipelines , heat exchangers, pumps and combinations thereof.

As used throughout the specification and claims, "packer" is intended to be given a broad meaning and includes any device, method, structures, devices, systems or combinations thereof. For example, a packer can isolate a production zone in a well from a disposal zone.

closed system

Referring to Figure 1, the power unit 10 on the surface is preferably a closed system of hydraulic fluid. Hydraulic fluid is used to transmit power from the hydraulic pump 14 to the pulsar 18, both of which are preferably located at or near the surface being drilled. In a preferred embodiment the hydraulic fluid is not mixed with the power fluid. The dynamic fluid transfers energy from the pulsar 18 and provides downhole pressure on the downhole assembly 200 (see FIG. 2 ). In this embodiment, the hydraulic fluid is preferably also not mixed with the production fluid. Production fluids are products that are pumped from subterranean formations to the surface using embodiments of the present invention. The power fluid is preferably also a closed system. The motive fluid actually drives the movement of the downhole device 200 and, in one embodiment, consists primarily of water. Since water is nearly incompressible, the pressure is transmitted to the downhole device 200 immediately with very high efficiency and with very little compression. If any unanticipated loss of fluid occurs, the power fluid piston 40 creates a vacuum as it returns to the reset position, thus filling any fluid voids in the power tube 204 .

Figure 1 illustrates an embodiment of the present invention comprising a power unit 10 and a pulsar unit 18 that moves fluid at the surface and propels a downhole device 200 to reciprocate.

Figure 1 illustrates a power unit 10, which preferably includes a motor 12, preferably a standard electric motor. Motor 12 may be a typical alternating current (AC) or direct current (DC) motor, which allows for the use of solar or wind energy or artificial power sources. The motor 12 is fixed to a hydraulic pump 14 , which is supported by a reservoir 16 . The reservoir tank 16 is filled with hydraulic fluid and provides hydraulic transmission to the pulsar unit 18 . The pulsar unit 18 is preferably a closed system, so the hydraulic fluid does not mix with the power fluid or production fluid. A line 20 is secured to the reservoir tank 16 and moves hydraulic fluid from the reservoir tank 16 to a hydraulic cylinder 24 sealed with an end cap 28 . A hydraulic piston 22 is accommodated in a hydraulic cylinder 24 . Reservoir 16 and hydraulic cylinders 24 may be made of any suitable material capable of holding hydraulic fluid and operating at the desired high pressures. Hydraulic valve system 26 activates pulsar 18 which oscillates and cycles connecting shaft 30 back and forth. Valve system 26 is preferably controlled by various pressures in the closed power system and activated by spiked pressure from downhole unit 200 . As shown in FIG. 2 , the downhole device 200 preferably travels its entire length until the lower piston 234 bottoms out, thus increasing the pressure in the power tube 204 . Subsequent pressure peaks activate the sequential system. The sequential system then initiates hydraulic fluid flow through the hydraulic valve system 26 and reverses the direction of the hydraulic piston 22 at the surface. Sequential systems can be electrical, mechanical, or a combination thereof.

Motor 12 preferably provides power to drive hydraulic pump 14 , which pumps hydraulic fluid into hydraulic cylinder 24 , which in turn transmits pressure to hydraulic piston 22 . The hydraulic piston 22 preferably moves and transmits power through a connecting shaft 30 . Shaft 30 moves through center coupling 32 . The center coupler 32 is preferably sealed with a sealing member made of any suitable material designed to maintain a pressure differential between the two regions. The connecting shaft 30 is preferably fixed to both the power cylinder 34 and the hydraulic cylinder 24 . The connecting shaft 30 preferably activates and builds pressure in the power tube 204 as the hydraulic piston 22 begins to move toward the power cylinder 34 . The end cap 36 for the power fluid prevents the pressure in the power fluid cylinder 34 from being pushed back towards the hydraulic cylinder 24, and thereby pushes all of the pressure to concentrate in a downward direction. The vent hole 38 allows the power fluid cylinder 34 to suck and vent air and prevents the power fluid piston 40 from locking up when the power tube 204 begins to build up pressure. Pressure is transmitted to the downhole assembly 200 and applied to the top piston 216 (see FIG. 2 ), which begins to move down the wellbore. When the pistons 216 , 222 and 234 are pushed downward, the pressure forces the production fluid to move up the annular region 210 and into the closed housing in the reservoir 16 . The production fluid may then act as a cooling means for the hydraulic fluid located in the second housing in the reservoir tank 16, thereby cooling the hydraulic fluid. The production fluid is also heated by the hydraulic fluid, making the production fluid easier to handle and separate downstream. Hydraulic fluid and production fluid are preferably isolated from each other in reservoir tank 16 . Production fluid preferably moves through reservoir tank 16 and into a storage tank (not shown).

FIG. 2 illustrates an embodiment of the invention comprising a downhole assembly 200 connected to the pulsar unit 18 seen in FIG. 1 .

In one embodiment of the present invention, as shown in FIG. 2 , the safety valve 202 is preferably an L-shaped valve and installed in the power pipe 204 , between the top of the downhole device 200 and the start position of the power pipe 204 . Relief valve 202 allows power fluid to drain from power line 204 while downhole assembly 200 is being pulled toward the surface, eg, in the event that maintenance is required. The relief valve 202 allows repair personnel to drag dry strings, pipes that do not contain fluid, rather than wet strings. The ability to drag the dry string prevents power fluid from spilling onto the ground. Preferably, the safety valve 202 is initially installed closed, then it is twisted and the power tube 204 is then slid upwards, pulling the power tube 204 up and out of the wellbore. As the power tube 204 is pulled upwards, it passes through the vent holes 206 and 208 which discharge the power fluid, thus pulling the "dry" string upwards. In one embodiment, maintenance personnel do not drag the wet string when removing the tubing.

Annular region 210 is the region through which production fluid travels up and to the surface. The downhole assembly 200 is preferably secured with a seat joint 212 at the bottom of the downhole assembly 200 . Seat joint 212 may also be mounted on top of downhole unit 200 , thus suspending downhole unit 200 from seat joint 212 . Annular region 210 includes the region between power tube 204 and outer conduit 214 . The production fluid is retained in the annulus 210 when the downhole device 200 is secured, or, if the downhole device 200 is not secured, the production fluid is released into the formation.

The downhole device 200 preferably receives pressure from the pulsar unit 18 on the top piston 216 . When pressure is applied to top piston 216, it moves downward, as do connecting shaft 218 and pistons 222 and 234. Piston 216 is preferably held in place by cylinder 220 . Pressure on top piston 216 is converted to thrust and activates piston 222 . Piston 222 is preferably used to equalize pressure. Downhole device 200 develops an upward thrust that is greater than a downward thrust when downhole device 200 is stationary because formation region 224 has a lower pressure than downhole device 200 , which creates an upward imbalance on downhole device 200 . Therefore, the energy available from the ground alone is sufficient to move pistons 216, 222 and 234 downward. The top of piston 222 is preferably exposed to the formation through vent 226 . Coupling 228 seals cylinder 220 thereby creating a pressure differential across the top of piston 222 . While the top of piston 222 is exposed to the formation, the bottom of piston 222 is exposed to annular region 210 via through-orifice 230 , which creates upward pressure with coupler 232 to separate fluid pressure. The coupling 232 is designed to prevent equalization of pressure in the region 224 exposed to the formation. The top of the piston 234 is exposed to the formation and the bottom of the piston 234 is exposed to the production fluid and is used to move the production fluid out of the valve arrangement 236 and up into the annulus 210 . Production fluid preferably moves into and out of the production chamber 238 . Valve arrangement 236 preferably includes a one-way check valve between chamber 238 and annular region 210 , wherein production fluid preferably travels from chamber 238 to annular region 210 . Valve arrangement 240 also includes a one-way check valve that prevents production fluid in cavity 238 from returning to the formation. As the downhole assembly 200 moves downward, the downward pressure pushes the valve assembly 236 open, thereby delivering production fluid upward to the annulus 210 . As downhole device 200 is retracted upward, the upward force opens valve arrangement 240 to receive production fluid from the formation into cavity 238 after the production fluid has been filtered through filtration system 242 .

Filtration system 242 preferably includes a mesh filter mounted on the bottom of downhole unit 200 . Filtration system 242 will not clog because the upper chamber of downhole device 200 is vented to the formation. This ventilation allows fluid to oscillate into and out of the downhole device 200 . Downhole pressure from downhole device 200 creates an outward pressure of fluid from cavity 238 , blowing away any debris that may accumulate near the filter and preventing unfiltered fluid flow in upper chambers 224 and 244 from entering downhole device 200 .

multiple drilling

Referring to FIG. 3 , one embodiment of the present invention includes a power unit 300 and a pulsar 312 . Downhole devices 302 and 304 preferably operate with only one surface unit, power unit 300 and pulsar 302 , thereby further improving the efficiency of pulsar 312 . In one configuration, when utilizing the powerpack 300, the pulsar 312 can be used to pump two or more wells. In this embodiment, pistons 306 and 308 oscillate back and forth, thereby producing production fluid on the downstroke of both downhole devices 302 and 304 . The production fluid is then used to cool the hydraulic fluid in reservoir tank 314 while the production fluid is heated for easier separation of oil and water in the production fluid before it is sent to tank 316 .

isolated disposal area

Referring to Figures 4 and 5A-5B, another embodiment of the present invention includes a pulsar 402 and downhole device 500 that allow recovery of production of fluids from one region of a wellbore while having untreated fluids disposed of in a second region of the wellbore. required fluid capacity. In this embodiment, once the piston 527 bottoms out, the pressure peaks in the power line 504, opening the pressure relief valve 522 and pushing the unwanted power fluid through the packer 508 into an isolated area suitable for disposal of the unwanted fluid . When all the unwanted fluid has been disposed of into the disposal area 526, the power fluid piston 422 will press up against the end cap 426, creating an additional pressure spike which triggers the sequence system to reverse the pulsar 420 and pass the Opening valve 430 introduces additional power fluid for the next cycle. The Pulsar 402 has two operating pressure levels and serves two different functions, one pressure level for extracting production fluids from the formation and another pressure level for disposing of unwanted fluids.

Figure 4 illustrates an embodiment of the invention comprising a power unit 400 and a pulsar 402 for producing subsurface liquids.

This embodiment preferably utilizes two zones of the well in a downhole situation, with production fluids being extracted from one zone of the formation while unwanted fluids are disposed of in a second zone of the formation.

The power unit 400 and the pulsar 402 preferably include a motor 404 . Motor 404 is preferably a standard weatherproof AC or DC power supply. Powerpack 400 preferably includes a reservoir 406, which preferably contains hydraulic fluid. Reservoir 406 may be made of any suitable material capable of holding hydraulic fluid. Reservoir 406 has a relatively low pressure and may be configured with an additional chamber to allow production fluid to flow through, thereby forming a heat exchanger for cooling the hydraulic fluid. In this embodiment, motor 404 generates power and provides power to hydraulic pump 408 . Hydraulic fluid is pumped to unit 410 via hydraulic pump 408 and develops a high pressure as it passes through high pressure hydraulic line 412 . Line 412 may be made of any material capable of handling high pressure. Line 412 supplies hydraulic fluid to hydraulic cylinder 414 supported by end cap 416 . The hydraulic fluid pushes against the hydraulic piston 418, which oscillates back and forth. The hydraulic piston 418 is preferably mounted with close tolerance clearances and is connected to a connecting shaft 420 . The hydraulic piston 418 moves towards the connecting shaft 420 which then transmits power to the power fluid piston 422 . This action builds pressure on the power fluid cylinder 424 held in place by the end cap 426 until the power fluid/disposal fluid is released through the outlet 428 .

When the pulsar 402 backs toward the hydraulic cylinder 414 to the reset position, the one-way check valve 430 is preferably pushed open to replace the power fluid cylinder 424 in the event of any undesired loss of power fluid during the return stroke of the pulsar 402 Power fluid in. Any voiding of the power fluid creates a vacuum which allows the one-way check valve 430 to open, thereby ensuring that the downstroke of the pulsar 402 utilizes the power fluid fully to ensure that the downhole unit 500 travels the full travel distance for which it is designed, i.e. minimizes point.

As power fluid piston 422 oscillates toward end cap 426 , production fluid travels up the annular region and into production tank 432 . The power fluid/disposal fluid is separated from the production fluid and placed in tank 434 and reused through line 436 to fill power fluid cylinder 424 for starting another cycle. In this embodiment, the power fluid/disposal fluid is used to activate the downhole device 500 . The downhole assembly 500 preferably lifts production fluids to the surface and also disposes of unwanted fluids in a disposal zone. The disposal area can be above or below the production area. Figure 5A illustrates an embodiment of the invention in which the disposal area is located below the production area. Figure 5B illustrates an embodiment of the invention in which the disposal area is located above the production area.

By adjusting the reciprocating set points of pistons 418 and 422, the volumetric displacement of disposal fluid removed from tank 434 relative to the amount of production fluid entering tank 432 can be adjusted to produce an optimal production/disposal ratio. This adjustment allows more treatment fluid to be disposed of in the treatment area as the tank 434 approaches the limit of its capacity. Alternatively, the fluid handling rate may be reduced as 434 approaches an empty state. Those skilled in the art will readily recognize that various means for such a reciprocating set point include electronic sensors and/or physical alterations to connecting shaft 420 , pistons 418 and/or 422 and caps 416 and 426 . In one embodiment, the electronic circuitry is preferably configured to adjust the reciprocation set point based on the fluid levels of tank 434 and/or tank 432, or alternatively based on some other measured value or user-specified criteria.

Figures 5A and 5B illustrate an embodiment of the invention comprising a dual purpose production/disposal downhole assembly 500 working in conjunction with the pulsar 402 and powerpack 400 of Figure 4 . The downhole device 500 preferably pumps production fluid from one region of the formation to the tank 432 and disposes of unwanted fluid in another region of the formation on the same stroke of the pulsar 402 .

In one embodiment of the invention, production fluid is delivered to the surface through annulus 502 , which is the area between power tube 504 and production tube 506 . Power tubing 504 preferably includes about 0.5 to 5 inches of tubing, more preferably about 0.75 to 3 inches of tubing, most preferably about 1 inch of tubing, and production tubing 506 preferably includes about 0 to 5 inches of tubing, more preferably 2 to 4 inches of tubing, most preferably About 2 7/8 (2.875) inch tubing is preferred. Downhole device 500 is preferably disposed in a wellbore with packer 508 . Standard equipment can be used to separate production and disposal areas. The downhole assembly 500 is preferably fitted with tubing capable of delivering fluid at a target pressure.

Disposal/motive fluid chamber 520 is preferably a closed system that transmits pressure from the ground to the top of piston 510 . Top coupling 512 preferably maintains pressure separation. The bottom of the piston 510 is exposed to the annular region 502 . Production fluid in annular region 502 creates an upward thrust on pistons 510 and 514 .

The area below piston 514 separates pressure and fluid between pistons 514 and 527 with coupling 516 . Vent 518 contains power/disposal fluid and serves as a connecting rod to pistons 510 , 514 and 527 . A high pressure relief valve 522 is installed at the bottom of the vent hole 518 for disposal of fluid/power fluid and does not open until the pressure in the downhole unit 500 exceeds the normal operating production pressure, at which point the high pressure relief valve 522 opens and disposes of excess Fluid is pushed through packer 508 into the disposal area.

In an embodiment of the invention, the treatment/motive fluid exerts downward pressure on piston 510, causing pistons 510, 514, and 521 to travel downward. This downward pressure pushes production fluid into annular region 502 through check valve 524 . When the pistons 510, 514, and 527 have reached the bottom of the target distance, the pistons 510, 514, and 527 bottom out and build up pressure in the downhole assembly 500 until the downhole pressure from the disposal fluid/power fluid exceeds the production operating pressure . At this point, high pressure relief valve 522 opens and deposits unwanted fluid in disposal area 526 through packer 508 . Opening of high pressure relief valve 522 initiates the sequence system and power fluid piston 422 ( FIG. 4 ) moves toward hydraulic piston 418 , thereby moving pistons 510 , 514 , and 527 in an upward direction. One-way check valve 528 absorbs production fluid with each oscillation of downhole device 500 . A check valve 524 for the outlet is on the opposite side of the pipe and pushes the production fluid up to the annulus 502 . Connected to the valve system 528 is a screen 530 capable of preventing debris from entering the downhole assembly 500 . As shown in FIGS. 5A and 5B , downhole device 500 may be installed such that disposal zone 526 is above or below production zone 532 .

FIG. 6 illustrates an embodiment of the invention comprising a powerpack 600 and a pulsar 602 that preferably mix power and production fluids and release the fluids through relief valves 604 and 606 . FIG. 7 illustrates an enlarged view of pulsar 602 .

This embodiment of the invention includes a power unit 600 on the surface, and a pulsar 602 equipped to mix production and power fluids. The power unit 600 preferably includes an electric motor for the power source 616, which may be a DC motor or an AC motor suitable for solar or wind power or manual operation. Alternatively, power unit 600 may run solely on solar or wind power sources. The motor is preferably mounted on hydraulic fuel tank 618 and connected to hydraulic pump 620 . Hydraulic power line 622 is connected to sequence system 626 and is used to transmit power to chamber C to oscillate pistons 628 , 610 and 614 in pulsar 602 . The pulsar 602 preferably includes three separate fluid chambers (A, B, and C), one of which (chamber C) is preferably a hydraulic fluid fully enclosed system. Hydraulic fluid is preferably removed from tank 618 via hydraulic pump 620 and pushed into chamber C, pushing piston 628 in a direction toward chamber B and causing piston 614 to push fluid located in chamber B along conduit 814 . This fluid then pushes up piston 810 (see FIG. 8 ), causing production fluid within cavity 811 of downhole device 800 to be pushed down the vent line through valve 804 and down the conduit 608 . Once chamber 811 is closed and piston 810 rests on coupler 812, a pressure spike occurs on side B and sequence system 626 activates piston 628 to move connecting shaft 624 and pistons 610, 614, and 628 toward chamber A, thereby opening Cone valve 702 on piston 614 sends production fluid down side A and excess fluid up out of chamber B via valve 606 .

After excess fluid is released through valve 606 and pistons 806 and 810 bottom out, another pressure spike occurs and sequence system 626 reverses direction, connecting shaft 624 then moves toward conduit 814 and closes cone valve 702 . Cone valve 702 is preferably closed using a stop, seat, lock, or combination thereof on piston 614 . Optionally, the cone valve 702 may be closed using a stop, a seat, a locking device, or a combination thereof located in chamber B. The pressure created by moving piston 614 toward line 814 pushes fluid down line 814 and up pistons 806 and 810 which pushes fluid from chamber 811 up vent line 808 , through valve 804 and up line 608 . When excess fluid enters chamber A from conduit 608 , cone valve 700 opens and releases excess fluid out of valve 604 . When all excess fluid is released through valve 604 and when chamber 811 is closed, another pressure spike occurs and sequence system 626 pushes piston 628 to change direction. Piston 628 then pushes piston 610 toward conduit 614 and closes cone valve 700 . The cone valve 700 is preferably closed using a stop, seat, lock, or combination thereof on the piston 610 . The cone valve 700 may optionally be closed with a stop, seat, lock, or combination thereof located in chamber B. This cycle is repeated with each oscillation of the pulsar 602. The process continues to cycle as the same fluid is used to activate the downhole device 800, with the ability to release excess fluid on the upstroke of each cycle.

Referring to Figures 6-8, this embodiment of the invention can be used in shallow wells and can employ either rigid or flexible tubing for pressure transfer and production. This embodiment can also be installed as a mobile or fixed installation. In one embodiment of the invention, the pulsar 602 is preferably about 3 to 20 inches in diameter, more preferably about 5 to 15 inches in diameter, and most preferably about 7 to 10 inches in diameter. Pistons 610 and 614 are preferably mounted with close tolerance clearances from pulsar 602 , so the diameter of pistons 610 and 614 is preferably close to the diameter of pulsar 602 . Cone valves 700 and 702 are preferably about 0 to 4 inches in diameter, more preferably about 1 to 3 inches in diameter. Thus, excess fluid is preferably pushed out of the relatively small diameters of the cone valves 700 and 702 disposed on the larger diameter pistons 610 and 614 . If the unit 800 is installed with flexible lines, preferably a small cable is attached to the unit 800 and wrapped with both lines to give the unit 800 the required tensile strength during removal.

Figure 8 illustrates an embodiment of the invention comprising a downhole device 800 capable of producing fluid from both sides of its travel.

Figure 8 is a continuation of the pump assembly illustrated in Figures 6-7. Figure 8 shows the lower part of the assembly. The unit 800 in this embodiment is capable of producing fluid on each side of its stroke (referred to as the A side and the B side). On side A, line 608 receives pressure from fluid at the surface which pushes check valve 804 closed, pistons 806 and 810 move down, pushes fluid out of chamber 820 through valve 816, and up line 814 on side B, And fluid is also pushed out of chamber 826 while filling chamber 811 through A-side valve 828 .

When pistons 806 and 810 bottom out, a pressure spike occurs in chamber A, which activates sequence system 626 which then sends hydraulic fluid into chamber C and moves connecting shaft 624 and piston 610 toward side B , 614 and 628 , which pushes fluid along conduit 814 and moves pistons 810 and 806 up until piston 810 abuts against coupler 812 . As the piston 614 moves toward the conduit 814 , the cone valve 700 provided on the piston 610 opens, allowing excess fluid in chamber A to escape the valve 604 . When all excess fluid is released through valve 604 and when chamber 811 is closed, a pressure spike occurs on side B and sequence system 626 activates and pushes piston 628 towards side A which in turn closes cone valve 700 and along line 608 Push fluid. Fluid pushes pistons 806 and 810 downward, and fluid from cavity 820 is pushed upward along B-side conduit 814 . As fluid is pushed down side A and up side B, the cone valve 702 provided on the piston 614 opens and excess fluid is released through valve 606 . When pistons 806 and 810 bottom out and all excess fluid is released through valve 606, a pressure spike occurs on side A which triggers sequence system 626 which activates piston 628 to move towards side B.

This embodiment forms two production areas, chambers 820 and 811. Valve 816 sends fluid from chamber 820 up B-side conduit 814 as downward pressure pushes piston 806 downward. As upward pressure pushes piston 806 upward, chamber 820 is refilled with production fluid through valve 818 . When downward pressure pushes piston 810 downward, cavity 811 fills with production fluid via valve 828 . Production fluid in cavity 811 moves up vent tube 808 and into A-side conduit 608 as upward pressure pushes piston 810 upward. Simultaneously, cavity 820 is filled with production fluid via valve 818 . The production fluid mixes with the A-side production/power fluid, which allows this fluid to overflow the piston 806 . This process is carried out cyclically and continues to oscillate, whereby production takes place. As the pistons 806 and 810 move, a vacuum is created which opens the production chamber 820 and draws in additional production fluid. During the same stroke, the bottom of piston 806 pushes stored fluid out of check valve 816 and up through power/production line 814 . This process allows efficient pumping and enhances the ability to produce fluids in variable volumes.

marginal well

Embodiments of the present invention allow marginal and reuse. Marginal wells are those wells drilled that would otherwise be removed from production due to high energy and maintenance costs. Marginal wells are again profitable when employing pulsars of embodiments of the present invention.

Asai

Embodiments of the invention may also produce fluids from shallow wells. Flexible lines and hydraulic reels are preferably used in isolated areas where electrical power is not available. In one embodiment, a small power unit can be mounted on a skid with a reel, which allows the pulsar unit to be installed in a very short time without the use of a drilling rig.

deviated well

The pulsar of the present invention can be pumped from deviated wells without wear and tear on the tubing placed from the surface to the downhole device.

Angle Drilling

Embodiments of the present invention may be used in wells drilled deviated from formations. Embodiments of the present invention can be pumped across the field and subsequently in the bottom wellbore in a vertical or any inclined position. Due to the high demand and high energy costs for horizontal drilling activities, embodiments of the present invention offer a great advantage in the market by having the ability to be installed in a vertical position and angled away from the horizontal position.

efficient pumping

Other embodiments of the present invention allow pumping on both sides of the stroke in the downhole installation, which increases efficiency and thus provides an ideal design for applications utilizing solar and wind energy.

filtering system

One embodiment of the present invention includes a unique filtration system that prevents sand and other small debris from accumulating in the downhole device. A major problem with downhole pump filtration systems in existing pumping technology is that if a small mesh filter is placed on the downhole pump, debris has a tendency to seal or clog the filter and prevent fluid flow into the pump . If a large grate is placed on the downhole, this filter allows sand and small debris to enter the pump causing wear in the downhole. This embodiment of the invention preferably backflushes the filter on every cycle of the pump, thereby allowing smaller mesh filters to be installed without clogging or sealing. This embodiment also filters out broken sand, particularly because of the presence of broken sand in new wells, which increases the life of pistons and barrels in downhole devices.

volume adjustment

Once the power pack, pulsar and downhole device of the present invention are installed and pumped, the output can be adjusted without timers and without shutting down the system. A variable hydraulic pump at the surface allows the owner/operator to adjust the system based on the output of the well.

aesthetics

Embodiments of the invention may be installed underground so that it is not visible from above ground. Power units and pulsars on the ground can be mounted at or below ground level to maintain the appearance of the terrain.

Although the invention has been described in detail with particular reference to these preferred embodiments, other embodiments can achieve the same effect. Various changes and modifications of the present invention will be apparent to those skilled in the art, and the present invention is intended to cover in the appended claims all such modifications and equivalents. The entire disclosures of all references, applications, patents and publications cited above are hereby incorporated by reference.

Claims (20)

CLAIMS 1. A method for removing production fluids from wells leading to a production area and to a disposal area, the method comprising the steps of: Separation of production and disposal areas; Pushes production fluid from the production area to the production system during the piston stroke; and The treatment fluid is pushed into the treatment area during the same stroke of the piston. 2. The method of claim 1, wherein separating the production zone and the disposal zone is provided by a packer. 3. The method of claim 1, further comprising the step of systematically backflushing the production fluid. 4. The method of claim 3, wherein the step of backwashing utilizes a screen filter. 5. The method of claim 1, further comprising the step of adjusting disposal and production ratios. 6. The method of claim 6, wherein the adjustment is based on the volume of treatment fluid in the tank. 7. An apparatus for removing production fluids from wells leading to production and disposal areas, the apparatus comprising: a packer for isolating said production area from said disposal area; a piston, wherein during a stroke of the piston, the piston pushes production fluid from the production area to the production system; and Wherein during the same stroke of the piston, the piston pushes treatment fluid into the treatment region. 8. The apparatus of claim 7, further comprising a screen for backflushing production fluid. 9. A method for removing fluid from a wellbore comprising the steps of: disposing a downhole device at least partially in the wellbore; pushing a piston of the downhole device in a first direction and pushing production fluid from the production zone into the production system; and Pushing the piston of the downhole device in a second direction pushes production fluid from the production zone into the production system. 10. The method of claim 9, wherein the piston of the downhole device is reciprocated to produce production fluid with each stroke of the downhole device. 11. A system for removing fluid from a wellbore comprising: a downhole device located at least partially within the well; a piston disposed in the downhole device, wherein the piston is urged in a first direction, thereby pushing production fluid from the production zone into the production system; and Wherein the piston is pushed in a second direction, thereby pushing production fluid from the production area into the production system. 12. The system of claim 11, wherein the piston reciprocates to produce production fluid with each stroke of the downhole device. 13. A method for moving fluid from a wellbore comprising the steps of: disposing at least partially within the wellbore a downhole device comprising tubing and one or more pistons; applying a dynamic fluid that moves the one or more pistons in the downhole device; push production fluids to the surface of the well; and providing a valve on or near the downhole assembly, wherein the valve is releasably actuatable at or near the surface of the wellbore, thereby releasing power contained within the pipe when the pipe is removed from the wellbore fluid to release power fluid through the valve when the tubing is removed from the well. 14. The method of claim 13, wherein the valve is an L-shaped valve. 15. The method of claim 13, the pipe removed from the wellbore comprising dry pipe. 16. The method of claim 13, wherein the downhole device is secured in the wellbore with a seat knuckle at the bottom of the downhole device. 17. An apparatus for moving fluid from a wellbore comprising: a downhole device comprising tubing disposed at least partially within a wellbore and one or more pistons; a dynamic fluid, wherein the dynamic fluid moves the one or more pistons within the downhole device; production fluids that are moved to the surface of the well; and A valve is disposed on or near the downhole assembly, wherein the valve releases the motive fluid contained within the tubing when the tubing is removed from the wellbore. 18. The apparatus of claim 17, wherein the valve is an L-shaped valve. 19. The apparatus of claim 17, wherein the pipe removed from the well comprises dry pipe. 20. The apparatus of claim 17, further comprising a seat section, wherein the seat section is secured at the bottom of the downhole unit.

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