US20140216753A1

US20140216753A1 - Bernoulli Assisted Hydrocarbon Lift System and Method to Prohibit Water-Coning

Info

Publication number: US20140216753A1
Application number: US13/761,604
Authority: US
Inventors: Rodney Dee Smith; Thomas D. Harrison
Original assignee: Individual
Current assignee: Individual
Priority date: 2013-02-07
Filing date: 2013-02-07
Publication date: 2014-08-07

Abstract

The disclosed hydrocarbon lift system and method prohibits water-coning in production of oil from a subterranean reservoir to the earth's surface. The system comprises a well bore with a first and a second section. The first section has perforations which draw a first fluid into and up the well bore based on a negative pump pressure applied thereto. The second section has perforations which draw a second fluid into the well bore based on a differential pressure between the pump pressure and a lower induced pressure therein. The system also comprises a venturi structure fixtured into the well bore. The venturi structure has flaring ends connected by a constricting throat defining perforations therein. The constricting throat perforations draw the second fluid through the second section perforations into the venturi throat in response to the lower induced pressure in the second section created by an increased first fluid velocity there through.

Description

CROSS-REFERENCE TO RELATED APPLICATIONS

This application is a continuation-in-part of U.S. Non-Provisional Utility patent application Ser. No. 13/706,150 entitled Buoyant Ball Assisted Hydrocarbon Lift System and Method filed for Rod D. Smith, et al. on Dec. 5, 2012 which itself is a continuation-in-part of earlier filed U.S. Non-Provisional Utility application Ser. No. 13/568,471, filed Aug. 7, 2012 for Rod D. Smith et al. entitled Buoyant Ball Assisted Hydrocarbon Lift System and Method for Rod D. Smith et al. which claims the benefit of the priority date of earlier filed U.S. Provisional Patent Application Ser. No. 61/659,394, filed Jun. 13, 2012 for Rod D. Smith, each incorporated herein by reference in its entirety.

BACKGROUND AND FIELD OF INVENTION

A phenomenon known as water coning may affect the oil producing capacity of a well to the point the well is no longer profitable. In many oil fields, the oil producing formation is found in a contiguous relationship to a substantially water-saturated, water producing formation. Under static, non-producing conditions the water having a greater density is found beneath the oil producing formation. During production, however, a pressure drop is formed near the well, causing both oil and water to flow radially toward the well bore. The small difference in density and large difference in viscosity between the water and the oil gives rise to upwardly directed pressure gradients around the well. This difference in pressure causes the water to rise a substantial height above the normal or static oil-water interface and forms a conical column around the well bore within the normal oil producing region. This phenomenon is known as water coning.
A result of water coning in a producing well is a rise in the water to oil production ratios, a consequent lowering of oil production and an increase in the cost of lifting the oil, and additional expense incurred in separating the water from the oil, and increase in water to oil ratio, aka cut and therefore and expense of excess water disposal. As production continues, the water level rises even further and the water cone grows in size. Eventually, a point in the production history is reached when production of oil from the well is no longer economical. Many methods and systems have been proposed to address water coning but are either prohibitively expensive or not very effective. Therefore, it is desirable to economically prohibit water coning.
Subterranean wells may be drilled primarily to extract fluids such as water, hydrocarbon liquids and hydrocarbon gases. These fluids exist within the earth to depths often in excess of 5000 meters below the earth's surface. Subterranean traps, called reservoirs, accumulate the fluids in sufficient quantities to make their recovery economically viable. Whether or not a fluid of interest can reach the earth's surface without aid may be a function of the potential energy of the fluid in the reservoir, reservoir driver mechanisms, percentage of gas present, reservoir rock characteristics, near wellbore rock characteristics, physical properties of the desired fluid and associated fluids, depth of the reservoir, wellbore configuration, operating conditions of the surface facilities receiving fluids and the stage of the reservoir's depletion.
Many wells in the early stages of production are capable of producing fluids with little more than a pipe to connect the reservoir with surface facilities, as energy from the reservoir and changing fluid characteristics can lift desired fluids to the surface. However, to improve the economics of a well, it may be necessary to increase the production rate and maximize the recovery of the desired fluid(s) from the well. Transportation of fluids from the reservoir to the surface, that is well bore dynamics, is one of the variables of the well that can be controlled and has a major impact on the economics of a well.
One can improve reservoir and well bore dynamics by two methods: 1) added laterals runners, horizontal drilling into the reservoir, 2) improving the drive mechanisms via steam, nitrogen or ancillary drive mechanisms, 3) designing a wellbore configuration that optimizes and improves the flow characteristics of the fluid in the well bore conduit, and/or 4) aiding in lifting the fluid to surface with artificial lift. Artificial lift can significantly improve production early in life of many wells and may be the only option for wells operating in the later stages of depletion. There are numerous systems of artificial lift available and operating throughout the world. The more common systems are reciprocating rod string and plunger pumps, rotating rod strings and progressive cavity pumps, electric submersible multi-stage centrifugal pump, jet pumps, hydraulic pumps and gas lift systems. To fit in the category of artificial lift, additional energy not from the producing formation or fluids input into the well bore is added to help lift fluids in the liquid paths to the earth's surface. With the depletion of the world's fluid reserves, there is a long felt need to develop an artificial lift system and method that is both economical and practical that will retrieve a greater percentage of oil in place from a given reservoir.

SUMMARY OF THE INVENTION

A hydrocarbon lift system and method as disclosed, prohibits water-coning in production of oil from a subterranean reservoir to the earth's surface. The system comprises a well bore having at least a first section and a second section. The first section has a plurality of perforations configured to draw a first fluid into and up the well bore based on a pump pressure applied thereto. The second section has a plurality of perforations configured to draw a second fluid into and through the well bore based on a differential pressure between the pump pressure and a lower induced pressure therein. The system also comprises a venturi structure configured to be fixed by a packer into the well bore. The venturi structure has flaring ends connected by a constricting throat defining a plurality of perforations therein. The constricting throat perforations are configured to draw the second fluid through the second section perforations into the venturi throat in response to the lower induced pressure in the second section created by an increased first fluid velocity predicted by Bernoulli's equation as further explained below through the venturi throat with respect to the velocity of the first fluid through the well bore.
A buoyant ball assisted hydrostatic lift system and method lifts a fluid from an enclosed subterranean reservoir to the earth's surface. The disclosed system also includes a pipe string configured with a quiescent gas therein under a steady state gas pressure with any quiescent gas escape offset by an equal gas input. The system also includes a plurality of buoyant balls in the pipe string; the balls configured to at least one of displace a fluid mass and have a surface friction moving in a fluid therein. The system additionally includes a column of the buoyant balls in the pipe string, an aggregate weight of the balls in the column configured to entrain the balls into a fluid in an annulus formed with an outer bore pipe. The system further includes a hydrostatic pressure differential in the annulus with respect to the reservoir via the buoyant balls, the pressure configured to lift the entraining fluid and the entrained balls in the annulus to the surface.
An embodiment of the disclosed system enhances petroleum production via a column of buoyant balls entrained in a pressurized fluid in the pipe string, the entrained buoyant balls are configured to enable a pressure differential in the annulus with respect to the pressure in the reservoir and lift the entrainment via the annulus to the earth's surface. The embodied system may also be configured to vice versa entrain the column of buoyant balls in a pressurized fluid in the annulus, the entrained buoyant balls configured to enable a pressure differential in the pipe string with respect to the pressure in the reservoir and lift the entrainment via the pipe string to the earth's surface.
The disclosed method includes providing a pipe string configured with a quiescent gas therein under a steady state gas pressure with a quiescent gas escape offset by an equal gas input. The method also includes providing a plurality of buoyant balls in the pipe string; the balls configured to at least one of displace a fluid mass and have a surface friction moving in a fluid therein. The method additionally includes providing a column of the buoyant balls in the pipe string, an aggregate weight of the balls in the column configured to entrain the balls into a fluid in an annulus formed with an outer bore pipe. The method further includes creating a hydrostatic pressure differential in the annulus with respect to the reservoir via the buoyant balls, the pressure configured to lift a fluid in the annulus to the surface. The disclosed method yet includes recovering the buoyant balls from the fluid lifted to the earth's surface in a recovery reservoir at atmospheric pressure.
Other aspects and advantages of embodiments of the disclosure will become apparent from the following detailed description, taken in conjunction with the accompanying drawings, illustrated by way of example of the principles of the disclosure.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 is a cross sectional view of a buoyant ball assisted hydrostatic lift system comprising a static pressurized column of buoyant balls in accordance with an embodiment of the present disclosure.

FIG. 2 is a block diagram of a method for buoyant ball assisted hydrostatic lift in accordance with an embodiment of the present disclosure.

FIG. 3 is a cross sectional view of a buoyant ball recovery system in accordance with an embodiment of the present disclosure.

FIG. 4 is a cross sectional view of a buoyant ball recovery system where a ball hopper is vented in accordance with an embodiment of the present disclosure.

FIG. 5 is a cross sectional view of a buoyant ball recovery system where the balls enter the pipe string in accordance with an embodiment of the present disclosure.

FIG. 6 is a cross sectional view of a buoyant ball recovery system where the hopper is filled with liquid in accordance with an embodiment of the present disclosure.

FIG. 7 is a cross sectional view of a buoyant ball assisted hydrocarbon lift system comprising an entrained column of buoyant balls in a fluid in accordance with an embodiment of the present disclosure.

FIG. 8 is a cross sectional view of a Bernoulli assisted hydrocarbon lift system and method to prohibit water coning in accordance with an embodiment of the present disclosure.

FIG. 9 is a cross sectional view of a wellbore comprising a venturi throat and pressure differential enhancing scoups therein in accordance with an embodiment of the present disclosure.

FIG. 10 is a cross sectional view of a system to prohibit water coning via a venturi and assist hydrocarbon lift by gravity-fed buoyant balls in accordance with an embodiment of the present disclosure.

FIG. 11 is a cross sectional view of a system to prohibit water coning via a venturi and assist hydrocarbon lift by pressurized buoyant balls in accordance with an embodiment of the present disclosure.

FIG. 12 is a flow chart of a method for prohibiting water coning via a venturi in according to an embodiment of the disclosure.

FIG. 13 is a flow chart of a method for prohibiting water coning and increasing production by gravity-fed buoyant balls in accordance with an embodiment of the present disclosure.

FIG. 14 is a flow chart of a method for prohibiting water coning and increasing production by pressurized buoyant balls in accordance with an embodiment of the present disclosure.

FIG. 15 is a cross-sectional depiction of an engineered spherical buoyant object designed to optimize lifting forces in accordance with an embodiment of the present disclosure.

Throughout the description, similar or same reference numbers may be used to identify similar or same elements depicted in multiple embodiments. Although specific embodiments of the invention have been described and illustrated, the invention is not to be limited to the specific forms or arrangements of parts so described and illustrated. The scope of the invention is to be defined by the claims appended hereto and their equivalents.

DETAILED DESCRIPTION

Reference will now be made to exemplary embodiments illustrated in the drawings and specific language will be used herein to describe the same. It will nevertheless be understood that no limitation of the scope of the disclosure is thereby intended. Alterations and further modifications of the inventive features illustrated herein and additional applications of the principles of the inventions as illustrated herein, which would occur to one skilled in the relevant art and having possession of this disclosure, are to be considered within the scope of the invention.
As known to those skilled in the art, the equation of steady state fluid flow of continuity requires that the speed of the fluid at a constriction increase. Bernoulli's equation then shows that the pressure must fall there. That is, if the velocity increases through the constriction, then the pressure must decrease. This decrease in pressure may be used to draw a more viscous oil into the wellbore while allowing the lower viscous and higher density water to enter the well bore through perforations in the wellbore adjacent the water strata and thus avoid a water cone as disclosed herein.
The velocity of a fluid through the venturi throat is directly proportional to the cross sectional area of the venturi throat to a first order. Therefore, since the velocity of the fluid in turn determines the pressure differential seen by the oil entering the venturi through the perforations in the well bore and the venturi throat, the differential pressure may be controlled by the diameter of the venturi throat. Of course, the velocity of the fluid through the venturi throat is directly influenced by the pumping pressure applied by the lift system, but the diameter of the venturi throat also has a bearing on the fluid velocity.
Present best known methods may include artificial lift via a high pressure source at the surface of a well to inject gas down an annulus and into a tubing bore. The compressed gas may be injected into the product stream through valves and may create an aeration or bubbling effect in the liquid column. The gas bubbles may expand as they rise to the surface, displacing liquid around them. This may decrease the density and weight of the fluid and create a differential pressure between the reservoir and the well bore and allow the well to produce at its optimum rate. However, the recovery and necessary recompression of gases used for lifting is expensive and cumbersome. There is a long felt need in the market of hydrostatic artificial lift systems for a system and method that is both economical and practical without the expensive use of gases.
The term ‘pipe string’ as used throughout the present disclosure defines a column or string of pipe that transmits the lifting and/or drilling mechanisms. The term ‘annulus’ used throughout the disclosure defines a ring of space between a well bore inner wall and a pipe string outer wall where the pipe string is positioned within the well bore. The term ‘fluid’ as used throughout the present disclosure defines both a gas and a liquid. The term ‘ball’ as used throughout the present disclosure may refer to circular, semi-circular, spherical and other geometrical bead-like or bubble-like devices having rigid or semi-rigid walls and various sizes, shapes, porosities, specific gravities and various configurations including dimples, cavities (external and internal), recesses and the like. The term ‘entrainment’ may include both an entraining fluid and the buoyant objects entrained therein. The term ‘quiescent’ used throughout the disclosure follows the common definition of being motionless and at rest and therefore refers to a substantially motionless gas at rest. Similarly, the term ‘steady state’ follows the common definition of a stable condition that does not change over time and therefore refers to a stable gas pressure that does not change over time because any gas escape is offset by an equal gas input. Also, the term ‘packed,’ is synonymous with the term ‘fixed,’ and variations thereof such as ‘packing’ and ‘fixing’ or ‘fixturing’ etc, referring to semi-permanently and/or permanently disposing an object/fixture into a predetermined location in the well bore.
The purpose of the disclosed apparatus, system and method is to improve the volume of discharged fluids flowing from a well bore. In the alternative, if the well is within equilibrium and can no longer naturally flow, the disclosed process may initiate natural flow again. This is accomplished by changing the hydrostatic pressure within a fluid column through a mechanism of displacing fluid mass with buoyant balls sharing the space within the casing in a flowing well. This reduction in hydrostatic pressure may increase the net amount of fluids flowing in a given increment of time.
One embodiment of the disclosure takes advantage of the down pipe that is normally used to contain the flow of fluids to the surface and uses it as a conduit to transfer the buoyant balls down the bore hole to a desired depth. To facilitate the process of getting the balls to the bottom of the pipe, gas pressure is used to push down the water table in this center pipe (aka pipe string) to varying depths forming a gas column. As an example, at approximately a 5,000 foot level, if the water table ascended from the reservoir to the top (or the surface) of that pipe, and if there was no more natural reservoir pressure to push the liquid beyond the surface, it may take approximately (depending on the specific gravity of the liquid) 2200 psi of gas pressure to push the water table that was at the surface all the way down the pipe to the 5,000 foot predetermined level.
In an embodiment of the disclosure, the gas does not exit the bottom of pipe string, but instead, only enough pressure is administered to take the water table down to a very short distance from the end of the pipe. This creates a hollow void of steady state gas pressure occupying the internal volume of the pipe all the way back up to the surface. In contrast, the annulus between the pipe string and the well bore could be full of liquid from the reservoir to any point, all the way up to the surface.
Embodiments of the disclosure include small or large buoyant balls fed into the pipe string. Under the force of gravity, the balls may fall all the way down to the water table 5,000 feet below. Since the balls are buoyant, they may float on the water table at the bottom of the pipe. As the accumulated amount of buoyant balls land on top of each other, the aggregated weight will eventually push the lower balls down into the liquid until they reach the end of the pipe and start their ascension up the annulus entrained in the fluid(s) of the reservoir.
As the volume of balls increase in the annulus, the hydrostatic pressure housed in the annulus may start decreasing. The resisting force that the column is putting on the reservoir starts to lower and the spread between the reservoir's pressure and the column resisting hydrostatic pressure gets wider. This increase in differential pressure may allow the well to start flowing again, or increase the volume of a well that is currently flowing. The annulus may thus be used to discharge the flow coming to the surface verses the concentric pipe that is conventionally used as a gas column A disclosed mechanism gathers these buoyant balls at the surface and puts them in an apparatus that allows them to overcome the pressure required to reenter the gas column described earlier.
FIG. 1 is a cross sectional view of a buoyant ball assisted hydrostatic lift system comprising a static pressurized column of buoyant balls in accordance with an embodiment of the present disclosure. The disclosed buoyant ball assisted hydrostatic lift system 100 lifts a fluid 105 from an enclosed subterranean reservoir to the earth's surface 110. The disclosed system 100 includes a pipe string 115 configured with a quiescent gas therein under a steady state gas pressure with any quiescent gas escape offset by an equal gas input. The system also includes a plurality of buoyant balls 120 gravity-fed down the pipe string 115, the balls configured to at least one of displace a fluid mass 105 and have a surface friction moving in a fluid 105 therein. The surface friction may come from a design and/or a type of covering on the buoyant ball's surface as disclosed herein. Materials and designs having larger surface friction may increase the hydrostatic pressure differential as discussed herein. Conversely, materials and designs having less surface friction may decrease the hydrostatic pressure differential. Any design increasing the surface area of a buoyant ball may increase its surface friction and therefore increase the pressure differential in the annulus or vice versa in the pipe string. The pressure differential (pressure loss) may result from a heating the fluid(s) due to the surface friction of the entrained balls causing a net loss of energy in the enclosed system including the present disclosure and the well thereof. The system 100 additionally includes a column 125 of the buoyant balls 120 in the pipe string 115, an aggregate weight of the balls 120 in the column 125 configured to entrain the balls 120 into a fluid 105 in an annulus 130 formed with an outer bore pipe 135. The system further includes a hydrostatic pressure differential lifting the entrained balls in the annulus 130 with respect to the reservoir via the buoyant balls 120, the pressure differential configured to lift the fluid 105 in the annulus 130 to the surface 110. A ball reservoir 140 and a recovery reservoir 145 are also depicted. As shown, the balls 120 fall from the reservoir 140 into the pipe string 115 under weight of gravity through the quiescent gas to an entrainment point near the end of the pipe string depicted by height 154. Water 105 may be present in the reservoir and lifted into the recovery reservoir 145 via the disclosed system and method.
A vice versa embodiment of the disclosed hydrostatic lift system wherein the steady state gas pressure and the column of buoyant balls are vice versa disposed in the annulus and an entrainment comprising the entraining fluid and the entrained buoyant balls is vice versa disposed in the pipe string, enables a hydrostatic pressure differential in the pipe string to lift the entrainment to the earth's surface via the pipe string. The embodiment includes an annulus pipe string configured with a quiescent gas therein under a steady state gas pressure with any quiescent gas escape offset by an equal gas input. The system also includes a plurality of buoyant balls in the annulus; the balls configured to at least one of displace a fluid mass and have a surface friction moving in a fluid therein. The system additionally includes a column of the buoyant balls in the annulus, an aggregate weight of the balls in the column configured to entrain the balls into a fluid in a pipe string positioned within an outer bore pipe. The system further includes a hydrostatic pressure differential in the pipe string with respect to the reservoir via the buoyant balls, the pressure configured to lift a fluid in the pipe string to the surface.
Another embodiment of the disclosed hydrostatic lift system includes buoyant balls 120 of a specific gravity less than a ratio of 1 in relation to the specific gravity of a fluid in the annulus 130. Also, the steady state gas pressure in the pipe string 115 forces a water table in the pipe string 115 submerged in the reservoir below the surface 110 and proximal to a bottom end of the pipe string submerged in the reservoir. Additionally, the column 120 of buoyant balls 125 forms under an aggregate weight of the buoyant balls 120 and extends from a bottom end of the pipe string 115 to a column height 154 greater than a height of the fluid 156 in the string pipe 115 and the annulus 130. In other words, a product of the ball density with the height of ball column 154 and gravity may be greater than a product of the fluid density with the height of fluid 156 and gravity. Ball density may be less than fluid density and gravity cancels out so the height of the column may be greater than the height of the fluid (Hc>>Hf). Embodiments include various column heights where balls of greater density and weight allow shorter columns able to entrain the balls in the fluid(s). Also, the hydrostatic pressure is a product of gravity acting on a fluid density of any fluids in the pipe string 115 and the annulus displaced by the aggregate volume of the buoyant balls 120 therein and the height of the fluids from a confluence of the balls in the fluids to an overflow of the annulus 130 at the surface 110 into a catch reservoir 145. The fluid in the disclosed system may comprise at least one of water and a petroleum fluid.
In an embodiment of the disclosed hydrostatic lift system, the surface friction of the buoyant balls 120 moving through the fluid(s) 105 creates a loss of hydrostatic pressure in the annulus 130 and creates a lift of the fluid(s) 105 at a greater hydrostatic pressure in the subterranean reservoir to the surface 110 through the annulus 130. From a conservation of energy perspective of the closed system 100, the loss of potential energy in the annulus 130 due to the friction of the balls 120 moving there through create a pressure loss which lifts the fluid(s) in the annulus.
Embodiments of the hydrostatic lift system may further include a reservoir 140 of the buoyant balls 120, the reservoir 140 disposed adjacent a top of the pipe string 115 proximal the surface 110, the reservoir 140 configured to provide buoyant balls 120 for the column 125 of the buoyant balls 120 in the pipe string 115 at the steady state gas pressure. Also, a catch reservoir 145 may be disposed adjacent a top of the annulus 130 proximal the surface 110, the reservoir 145 configured to provide a catch for the lifted fluid(s) 105 and 150 and the buoyant balls 120. Additionally, a recovery hopper and a series of valves (depicted in FIG. 3-6) may be configured to separate the buoyant balls 120 from the fluid(s) 105 and 150 rising to the surface 110 into the catch reservoir 145 at atmospheric pressure. Embodiments of FIG. 1 include devices and systems for recovering the buoyant balls or buoyant objects from the reservoir 145 similar or the same to those depicted in FIG. 3 through FIG. 6 inclusive.
FIG. 2 is a block diagram of a method for buoyant ball assisted hydrostatic lift in accordance with an embodiment of the present disclosure. The disclosed method includes providing 310 a pipe string configured with a quiescent gas therein under a steady state gas pressure with a quiescent gas escape offset by an equal gas input. The method also includes providing 320 a plurality of buoyant balls gravity fed down the pipe string, the balls configured to at least one of displace a fluid mass and have a surface friction moving in a fluid therein. The method additionally includes providing 330 a column of the buoyant balls in the pipe string, an aggregate weight of the balls in the column configured to entrain the balls into a fluid in an annulus formed with an outer bore pipe. The method further includes creating 340 a hydrostatic pressure differential in the annulus with respect to the reservoir via the buoyant balls, the pressure configured to lift a fluid in the annulus to the surface. The disclosed method may yet include recovering 350 the buoyant balls from the fluid lifted to the surface in a recovery reservoir at atmospheric pressure.
An embodiment of the hydrostatic lift method includes forcing a water table in the pipe string submerged in the pipe string below the surface and proximal to a bottom end of the pipe string submerged in the reservoir via the steady state gas pressure. Also, the buoyant balls may provide an aggregate volume greater than a volume of the annulus. The buoyant balls may also form a column extending from a bottom end of the pipe string to a column height greater than a height of the fluid in the pipe string and the annulus. A height of the buoyant balls greater than a combined height of the pipe string and the annulus may be required for the balls to be entrained in the fluid(s) of the annulus. Also, a hydrostatic pressure differential created in the annulus with respect to the reservoir via the buoyant balls further comprises displacing a volume of fluids in the annulus and the pipe string from a bottom of the pipe string to an overflow of the annulus at the surface into a catch reservoir 145.
An embodiment of the hydrostatic lift method may further comprise providing a reservoir of the buoyant balls 140, the reservoir 140 disposed adjacent a top of the pipe string proximal the surface, the reservoir 140 configured to provide buoyant balls for the column of the buoyant balls gravity fed down the pipe string in a the steady state gas pressure. A catch reservoir 145 may be disposed adjacent a top of the annulus proximal the surface, the reservoir configured to provide a catch for the lifted fluid(s) and the buoyant balls. Recovering the buoyant balls from the fluid lifted to the surface in a recovery reservoir may comprise separating the buoyant balls from the fluid via a series of valves. Also, in order to reintroduce the buoyant balls into the column of buoyant balls in the pipe string, a ball reservoir may be disposed adjacent a top of the pipe string proximal the surface, the reservoir configured at the steady state gas pressure.
FIG. 3 is a cross sectional view of a buoyant ball recovery system in accordance with an embodiment of the present disclosure. The disclosed buoyant ball assisted hydrostatic lift system 100 lifts a fluid 105 and 150 from an enclosed subterranean reservoir to the earth's surface 110. The disclosed system 100 includes a pipe string 115 configured at a steady state gas pressure with any quiescent gas escape offset by an equal gas input. The system also includes a plurality of buoyant balls 120 in the pipe string 115, the balls configured to at least one of displace a fluid mass 105/150 and have a surface friction moving in the fluid(s) therein. The system 100 additionally includes a column 125 of the buoyant balls 120 in the pipe string 115, an aggregate weight of the balls 120 in the column 125 configured to entrain the balls 120 into a fluid 105/150 in an annulus 130 formed with an outer bore pipe 135. Embodiments of the present disclosure include various column heights where balls of greater density and weight allow shorter columns of balls gravity fed down the pipe string able to entrain the balls in the fluid(s). The system further includes a hydrostatic pressure differential in the annulus 130 with respect to the reservoir via the buoyant balls 120, the pressure configured to lift the fluid 105 in the annulus 130 to the surface 110. A ball reservoir 140 and a recovery reservoir 145 are also depicted. Water 105 may be present in the reservoir and lifted into the recovery reservoir 145 via the disclosed system and method.
Further depicted in FIG. 3, a hopper 155 (aka hopper area) may be disposed between the ball reservoir 145 and the pipe string 115. A valve 160 may be disposed on the top of the hopper 155 that separates the ball reservoir 145 from the hopper area and a valve 165 on the bottom of the hopper 155 separates the hopper 155 from the high pressure zone there below in the pipe string. These valves 160 and 165 open and close to allow the balls to enter the hopper area 155 and the pipe string 115. After a pressure differential is mitigated, the balls 120 fall into the high pressure zone as gravity acts upon them. Valves 160 and 165 are depicted as slide valves, however, there are many other valves that may be used in embodiments of the present disclosure.
Again referring to FIG. 3, the lower valve 165 is closed, the vent valve 170 is closed and the upper hopper valve 160 is also closed. Prior to the upper slide valve 160 opening, a high pressure pump 175 pumps fluid from the reservoir 180 into the hopper chamber area 155. During the pumping sequence, the vent valve 170 is open to the high pressure zone. As the water table rises to the top of the hopper, the vent valve 170 to the high pressure zone is closed. The pump 175 is turned off and at that time the upper slide valve 160 opens. FIG. 3 highlights the hopper area full of fluid. The upper slide valve 160 is open to the ball reservoir above it. The vent valve to the high pressure zone is closed and the lower hopper slide valve 165 is closed.
FIG. 4 is a cross sectional view of a buoyant ball recovery system where a ball hopper is vented in accordance with an embodiment of the present disclosure. Elements depicted are similar or the same as the elements depicted in FIG. 3. The lower slide valve 165 is closed. The upper slide valve 160 is open and the vent valve 170 is closed. The ball reservoir 145 is full of buoyant balls 120 that are now floating on top of the fluid level. At this point, the pump 175 is turned on and the fluid is pumped out of the hopper area 155 into the reservoir 180. As the fluid is pumped out, the buoyant balls 120 float on the fluid and descend into the hopper area 155.
FIG. 5 is a cross sectional view of a buoyant ball recovery system where the balls enter the pipe string in accordance with an embodiment of the present disclosure. Elements depicted are similar or the same as the elements depicted in FIG. 3. The upper valve 160 is closed separating the ball reservoir 145 from the hopper area 155. The pump 175 has been turned off and the vent valve 170 to the high pressure zone is open. The vent valve 170 vents to the high pressure zone while opened and allows the pressure to come to equilibrium in the hopper area 155 with the high pressure zone. At the end of this event, the lower slide valve 165 opens allowing the balls 120 to descend into the high pressure zone as gravity acts upon them. When the hopper 155 is emptied of its balls 120, the lower slide valve 165 closes again.
FIG. 6 is a cross sectional view of a buoyant ball recovery system where the hopper is filled with liquid in accordance with an embodiment of the present disclosure. Elements depicted are similar or the same as the elements depicted in FIG. 3. The lower slide valve 165 is closed. The upper slide valve 160 is closed and the vent valve 170 leading to the high pressure zone is left open. The pump 175 is turned on. The pump 175 is sufficiently powerful to overcome the pressure differential and proceeds to fill the hopper area 155 again with fluid from the reservoir 180. Upon topping off the hopper area 155, the pump 175 turns off, the vent valve 170 to the high pressure zone is closed and the process repeats itself starting back at FIG. 3.
FIG. 7 is a cross sectional view of a buoyant ball assisted hydrocarbon lift system comprising an entrained column of buoyant balls in a fluid in accordance with an embodiment of the present disclosure. Reference numbers similar or same to reference numbers in other drawings are used to identify similar or same elements as described immediately herein and in other supporting descriptions. The disclosed buoyant ball assisted hydrocarbon lift system 100 lifts a petroleum fluid 105 from an enclosed subterranean reservoir to the earth's surface 110. The disclosed system 100 includes a pipe string 115. The system also includes a plurality of buoyant balls 120 in the pipe string 115, the balls configured to at least one of displace a fluid mass 105 and a fluid mass 150 and have a surface friction moving in a fluid(s) therein. The column of buoyant balls is entrained in a fluid 150 in the pipe string, the entrained buoyant balls 120 are configured to enable a pressure differential in the annulus 130 with respect to the pressure in the reservoir and lift the entrainment via the annulus 130 to the earth's surface 110. The embodied system may also be configured to vice versa entrain the column of buoyant balls 120 in a fluid in the annulus 130, the entrained buoyant balls 120 are configured to enable a pressure differential in the pipe string 115 with respect to the pressure in the reservoir and lift the entrainment via the pipe string 115 to the earth's surface 110. The system 100 additionally includes a column 125 of the buoyant balls 120 in the pipe string 115, an aggregate weight of the balls 120 in the column 125 configured to entrain the balls 120 into a fluid 105 in an annulus 130 formed with an outer bore pipe 135. A ball reservoir 140 and a recovery reservoir 145 are also depicted. The ball reservoir 140 may be pressurized via a surface pump which may also pressurize the entrainment in the pipe string 115. Water 150 may be present in the reservoir and lifted into the recovery reservoir 145 via the disclosed system and method. Embodiments of FIG. 1 include devices and systems for recovering the buoyant balls or buoyant objects from the reservoir 145 similar or the same to those depicted in FIG. 3 through FIG. 6 inclusive.
The buoyant balls 120 depicted in the ball reservoir 140 and in the pipe string 115 may be controlled on entry therein in order to uniformly entrain the balls in the first fluid (lower fluid may be water 105 as depicted). The first fluid may be a hydrocarbon mixture of water and production by-products according to recovery demands and recycling methods employed. The balls therefore may be throttled and may be dumped according to production schedules and flow rates required. The buoyant balls may therefore be introduced into the ball reservoir 140 entrained in the fluid 150 or the balls may be introduced separately into the ball reservoir 140 and entrained in the fluid 150 in the ball reservoir 140 under a pressure generated by a pump. In any case, the fluid 150 may fill any space between and around the buoyant balls in the column 125 such that an introduction of an additional buoyant ball at the top of the column may push and otherwise eject a buoyant ball at the bottom of the column 125 into the annulus 130. Likewise, an introduction of an additional buoyant ball 120 into the ball reservoir 140 when filled with entrainment comprising buoyant balls 120 and fluid(s) 150 may push and otherwise eject or release a buoyant ball 120 at the bottom of the column 125 into the annulus 130. The density of the buoyant balls depicted in the column 125 is not meant to limit the present disclosure which includes embodiments of higher density and lower density. Therefore, the density of the buoyant balls entrained in the first fluid 150 may be pre-determined by the petroleum production rate desired and the dynamics of the hydrocarbon reservoir being pumped and the efficiency of the mechanisms and methods disclosed herein. Also, the pressure that may be used to entrain the buoyant balls in the fluid 150 in the ball reservoir 140 may be predetermined. The entrainment trajectory depicted in recovery reservoir 145 is not intended to limit the claims of the present disclosure which may include pressures above and below the pressure depicted by the trajectory of the entrainment into the recovery reservoir 145.
An embodiment of a hydrocarbon lift system is disclosed herein for lifting petroleum fluid(s) 105 and 150 from an enclosed subterranean reservoir to the earth's surface 110, the system comprising a plurality of buoyant balls 120 entrained in a pipe string 115 in a first fluid 150, the balls 120 configured to at least one of displace a fluid mass and have a surface friction moving in the first fluid 150 therein. The system also includes an entrained column of the buoyant balls 120 in the pipe string 115, an aggregate weight of the balls 120 and the first fluid 150 configured to entrain the balls 120 into a second fluid 105 in an annulus 130 formed with an outer bore pipe 135. The system further includes a pressure differential in the annulus 130 with respect to the reservoir via the entrained buoyant balls 120, the pressure configured to lift the second fluid 105 and the entrained balls 120 to enhance petroleum production in the annulus 130 to the surface 110.
Another embodiment of the disclosed hydrocarbon lift system may further comprise a pump attached to the pipe string, the pump configured to pressurize the first fluid and the buoyant balls entrained therein from the pipe string. The column of buoyant balls entrained in the first fluid may be vice versa disposed in the annulus and the entrained buoyant balls in the second fluid may be vice versa disposed in the pipe string to enable a pressure differential in the pipe string to lift the buoyant balls and the second fluid to the earth's surface. The column of buoyant balls forms under an aggregate weight of the buoyant balls and the first fluid and extends from a bottom end of the pipe string to a column height greater than a height of the fluid in the pipe string and the annulus.
A further embodiment of the hydrocarbon lift system for lifting petroleum fluid(s) from an enclosed subterranean reservoir to the earth's surface, comprises a column of a plurality of buoyant balls in a pipe string configured to entrain the buoyant balls into a fluid in an annulus formed with an outer bore pipe. The disclosed system additionally includes a pressure differential in the annulus with respect to the reservoir via the entrained buoyant balls, the pressure differential configured to lift the fluid and the entrained balls in the annulus to the surface.
The column of buoyant balls may further comprise a density of buoyant balls entrained in the first fluid predetermined by a specific gravity of the first fluid and a weight of each buoyant ball therein. Also, the column of buoyant balls may further comprise a density of buoyant balls entrained in the first fluid predetermined by an external pressure on the buoyant balls and the first fluid. Additionally, a second density of buoyant balls entrained in the second fluid may be based on the first density and on the specific gravity of the second fluid.
Therefore, the embodiments of the hydrocarbon lift system included herein comprise the surface friction of the buoyant balls moving through the fluid to create a loss of hydrostatic pressure in the annulus and create a lift of the fluid(s) at a lower pressure in the subterranean reservoir to the surface through the annulus.
A hydrocarbon lift system for lifting petroleum fluid(s) from an enclosed subterranean reservoir to the earth's surface is also comprised in an embodiment of the present disclosure. The system includes a plurality of buoyant balls configured in a column in a pipe string, the balls configured to at least one of displace a fluid mass and have a surface friction moving in a fluid. The system also includes a first pressure configured to entrain the buoyant balls in a first fluid in the pipe string and move the buoyant balls there through into a second fluid in an annulus formed with an outer bore pipe. The system additionally includes a pressure differential in the annulus created via a second pressure of the entrained buoyant balls in the second fluid with respect to a subterranean reservoir pressure, the pressure differential configured to lift the second fluid to the surface and enhance petroleum production in the annulus.
An embodiment of the hydrocarbon lift system is disclosed wherein the column of buoyant balls entrained in the first fluid is vice versa disposed in the annulus and the entrained buoyant balls in the second fluid is vice versa disposed in the pipe string to enable a pressure differential in the pipe string with respect to the subterranean pressure to lift the buoyant balls and the second fluid to the earth's surface.
FIG. 8 is a cross sectional view of a Bernoulli assisted hydrocarbon lift system and method to prohibit water coning in accordance with an embodiment of the present disclosure. Reference numbers similar or same to reference numbers in other drawings are used to identify similar or same elements as described immediately herein and in other supporting descriptions. The system depicted includes a well bore 135 having at least a first section 200 and a second section 210, the first section 200 having a plurality of perforations 205 configured to draw a first fluid labeled ‘water’ into and up the well bore 135 to the earth's surface 110 based on a pump pressure applied thereto. Though the well bore perorations are depicted as fluted structures protruding from the well bore, the perforations may also simply be holes or orifices therein of various or constant diameters. The second section 210 having a plurality of perforations 215 is configured to draw a second fluid labeled ‘oil’ into the well bore 135 based on a differential pressure between the pump pressure and a lower induced pressure therein. Also, a venturi structure is configured to be packed into the well bore 135, the venturi structure having flaring ends 220 connected by a constricting throat 225 defining a plurality of perforations 230 therein configured to draw the second fluid labeled ‘oil’ through the second section perforations 215 into the venturi throat 225 in response to the lower induced pressure in the second section 210 created by an increased or accelerated first fluid velocity through the venturi throat 225. The packing or fixturing 240 assists in disposing the venturi structure in the second section 210 of the well bore 135. The packing may be comprised of materials and secured by methods know to those persons of ordinary skill in the art. The packing material may be placed adjacent the well bore and the flaring ends of the venturi structure, the packing material configured to semi-permanently fix the venturi structure in a predetermined section of the well bore. Alternatively, the venturi structure may be built into a predetermined section of the well bore. The plug 250 may also be comprised of packing secured by methods common in the industry. The packing/plug 250 may prevent unwanted fluids and materials entering the well bore from further below the first section.
An embodiment of the present disclosure may further comprise a pass through tube extending a length from the well bore head to a section below the first section of well bore pipe, the pass through tube configured to pass recovered first flow from the surface back down into the well. Also, a number of first section perforations in the well bore may be greater than a number of second section perforations in the well bore in an embodiment. Alternatively, a diameter of the first section perforations in the well bore may be greater than a diameter of the second section perforations in the well bore in another embodiment. Vice versa, a number of second section perforations in the well bore may also be greater than a number of first section perforations in the well bore.
In another embodiment of the present disclosure, a diameter of the flaring ends of the venturi structure may be larger than a diameter of the constricting throat. Also, a diameter of the flaring ends of the venturi structure may be approximately the same as an inner diameter of the well bore. Additionally, a diameter of the constricting throat of the venturi structure may be substantially constant from one flaring end to another flaring end of the venturi structure.
In yet another embodiment, the first section may be disposed below the second section with respect to the surface and both the first and second sections are disposed beneath a terminus of a pipe string within the well bore. Also, a diameter of the constricting throat of the venturi structure may be remotely adjustable via electromechanical devices and electromagnetic wave communication up to an inner diameter of the well bore and is remotely adjustable down to approximately zero based on the induced pressure predetermined by an operator.
FIG. 9 is a cross sectional view of a wellbore comprising a venturi throat and pressure differential enhancing scoups therein in accordance with an embodiment of the present disclosure. Reference numbers similar or same to reference numbers in other drawings are used to identify similar or same elements as described immediately herein and in other supporting descriptions. The pressure differential enhancing scoups 235 may enhance or create a larger pressure differential between the pump pressure and the induced pressure in the second section created by an increased first fluid velocity through the venturi perforations 230 into the venturi throat 225. The scoups 235 form an approximate 15 degree angle with the venturi throat 225 and may extend over a perforation of the venturi throat 225 and thus are configured to assist in drawing the second flow labeled ‘oil’ into the venturi throat 225. The scoups 235 may be formed integrally with the venturi throat 230 or they may be separately disposed thereon.
FIG. 10 is a cross sectional view of a system to prohibit water coning via a venturi and assist hydrocarbon lift by gravity-fed buoyant balls in accordance with an embodiment of the present disclosure. Reference numbers similar or same to reference numbers in other drawings are used to identify similar or same elements as described immediately herein and in other supporting descriptions. Although the depicted lift systems herein other lift systems may also be used in conjunction with the disclosed Bernoulli venturi systems and methods. The system depicted may include a section 260 comprising a pipe string 115 configured with a quiescent gas therein under a steady state gas pressure with any quiescent gas escape offset by an equal gas input. The section 260 may also include a plurality of buoyant balls 120 gravity-fed down the pipe string 115, a column 125 of the buoyant balls 120 in the pipe string 115, an aggregate weight of the balls 120 in the column 125 configured to entrain the balls 120 into a fluid in an annulus 130 formed with an outer bore pipe 135. The section 260 may further include a hydrostatic pressure differential lifting the entrained balls in the annulus 130 with respect to the reservoir via the buoyant balls 120, the pressure differential configured to lift the fluid in the annulus 130 to the surface 110.
FIG. 11 is a cross sectional view of a system to prohibit water coning via a venturi and assist hydrocarbon lift by pressurized buoyant balls in a fluid in accordance with an embodiment of the present disclosure. Reference numbers similar or same to reference numbers in other drawings are used to identify similar or same elements as described immediately herein and in other supporting descriptions. The disclosed system may include a section 270 comprising a pipe string 115, a plurality of buoyant balls 120 pressurized and entrained in the pipe string 115, and in an annulus 130 formed with an outer bore pipe 135. The section 270 may further include a hydrostatic pressure differential lifting the entrained balls in the annulus 130 with respect to the reservoir via the buoyant balls 120, the pressure differential configured to lift the fluid 105 in the annulus 130 to the surface 110.
FIG. 12 is a flow chart of a method for prohibiting water coning via a venturi in accordance with an embodiment of the present disclosure. The method comprises providing 410 a well bore having at least a first section and a second section, the first section having a plurality of perforations configured to draw a water flow into and through the well bore based on a pump pressure applied thereto, the second section having a plurality of perforations configured to draw an oil flow into and through the well bore based on a differential pressure between the pump pressure and a lower induced pressure therein. The method also includes packing or fixturing 420 a venturi structure into the well bore, the venturi structure having flaring ends connected by a constricting throat defining a plurality of perforations therein configured to draw oil through the second section perforations into the venturi throat in response to the lower induced pressure in the second section created by a greater water flow velocity through the venturi throat with respect to a water flow velocity through the well bore. The method additionally includes drawing 430 the water flow through the first section perforations into the venturi throat in response to the pressure applied to the well bore head and drawing the oil flow through the second section perforations into the venturi throat in response to the lower induced pressure and drawing both the water flow and the oil flow through the well bore to the surface due to the pressure applied to the well bore head.
FIG. 13 is a flow chart of a method for prohibiting water coning and increasing production by gravity-fed buoyant balls in accordance with an embodiment of the present disclosure. The method includes the steps 410, 420 and 430 of the flow chart of FIG. 12. The method further includes the step of providing 450 a pipe string configured with a quiescent gas therein under a steady state gas pressure with any quiescent gas escape offset by an equal gas input; providing a plurality of buoyant balls gravity fed down the pipe string, the balls configured to at least one of displace a fluid mass and have a surface friction moving in a fluid therein; providing a column of the buoyant balls in the pipe string, an aggregate weight of the balls in the column configured to entrain the balls into a fluid in an annulus formed with an outer bore pipe; and providing a hydrostatic pressure differential in the annulus with respect to the reservoir via the buoyant balls, the pressure configured to lift a fluid in the annulus to the surface.
FIG. 14 is a flow chart of a method for prohibiting water coning and increasing production by pressurized buoyant balls in accordance with an embodiment of the present disclosure. The method includes the steps 410, 420 and 430 of the flow chart of FIG. 12. The method further includes providing 460 a plurality of buoyant balls entrained in a pipe string in a first fluid, the balls configured to at least one of displace a fluid mass and have a surface friction moving in the first fluid therein; providing an entrained column of the buoyant balls in the pipe string, an aggregate weight of the balls and the first fluid configured to entrain the balls into a second fluid in an annulus formed with an outer bore pipe; and providing a pressure differential in the annulus with respect to the reservoir via the entrained buoyant balls, the pressure configured to lift the second fluid and the entrained balls to enhance petroleum production in the annulus to the surface.
An embodiment of the present disclosure may further comprise recovering water from the oil at the surface and pumping the recovered water via a pass through tube extending a length from the well bore head to an area below the first section of well bore pipe as also explained above in relation to other embodiments.
FIG. 15 is a cross-sectional depiction of an engineered spherical buoyant object designed to optimize lifting forces and flow rates in accordance with an embodiment of the present disclosure. Reference numbers similar or same to reference numbers in other drawings are used to identify similar or same elements as described immediately herein and in other supporting descriptions. The broken line circle depicts a spherical cross-section approximated by the engineered semi-spherical object 290 shown in cross-section. The object depicted is merely an example of different shapes and sizes an engineered and/or designed buoyant object may have according to the present disclosure. In other words, a frontal area of a buoyant object may be substantially flat. Also, cavities may be disposed on side surfaces or areas thereof, the cavities configured to capture a fluid and carry it to the surface for recovery. An engineered buoyant object (ball) 290 depicted and other engineered shapes of a predetermined size and shape traveling at a given velocity may have a frontal effect on the liquid it is traveling upward through. The liquid immediately on top of the buoyant object 290 has a mass of a specific gravity. The accumulation of the liquid mass and the specific gravity of that liquid in a vertical column may be the sum of the weight of the column and/or the bottom psi. A buoyant object 290 may travel faster or slower depending on the vertical height of the buoyant object. Considering a snapshot moment in time, focusing on the liquid just ahead of the rising object 290; this liquid will have its weight as it relates to the column weight altered to a lower value as it flows around the solid buoyant object 290 rising upward through the column, thus changing the psi at the bottom of the column to some degree. The buoyant object's 290 frontal push, as well as the tailing turbulence, distorts the bottom column's psi over and above the effects of the buoyant object's 290 lighter mass (as compared to the liquid's specific gravity) in the column, thus affecting an effective buoyancy of the designer object. An engineered placement of a large volume of buoyant objects 290 in a liquid column would have a large effect on the bottom column's weight or psi as they ascend vertically through the column. The discharged flow rates may vary based on the size and shape of each buoyant object 290 and the accumulated volume of the objects in relation to the liquid's volume they are rising through. Thus, an engineered designer shape should enhance or retard this effect (effective buoyancy) in an embodiment of the disclosure. The slower the buoyant object goes the less turbulence is generated on the trailing side. The faster the buoyant object goes the more turbulence is generated on the trailing side changing the effective weight of the buoyant object due to other forces acting on the buoyant object.
Although the operations of the method(s) herein are shown and described in a particular order, the order of the operations of each method may be altered so that certain operations may be performed in an inverse order or so that certain operations may be performed, at least in part, concurrently with other operations. In another embodiment, instructions or sub-operations of distinct operations may be implemented in an intermittent and/or alternating manner.
While the forgoing examples are illustrative of the principles of the present disclosure in one or more particular applications, it will be apparent to those of ordinary skill in the art that numerous modifications in form, usage and details of implementation can be made without the exercise of inventive faculty, and without departing from the principles and concepts of the invention. Accordingly, it is not intended that the disclosure be limited, except as by the specification and claims set forth herein.

Claims

What is claimed is:

1. A hydrocarbon lift system for prohibiting water-coning in production of oil from a subterranean reservoir to the earth's surface, the system comprising:

a well bore having at least a first section and a second section, the first section having a plurality of perforations configured to draw a first fluid into and up the well bore based on a pump pressure applied thereto, the second section having a plurality of perforations configured to draw a second fluid into the well bore based on a differential pressure between the pump pressure and a lower induced pressure therein; and

a venturi structure configured to be fixtured into the well bore, the venturi structure having flaring ends connected by a constricting throat defining a plurality of perforations therein configured to draw the second fluid through the second section perforations into the venturi throat in response to the lower induced pressure in the second section created by an increased first fluid velocity through the venturi throat.

2. The hydrocarbon lift system of claim 1, further comprising a pass through tube extending a length from the well bore head to a section below the first section of well bore pipe, the pass through tube configured to pass recovered first flow from the surface back down into the well.

3. The hydrocarbon lift system of claim 1, further comprising a scoup structure adjacent a venturi throat perforation, the scoup structure configured to assist in drawing the second flow there through into the venturi throat, an opening defined by the scoup directed upward at a 15 degree angle to the well bore plus or minus a 10% manufacturing tolerance.

4. The hydrocarbon lift system of claim 1, further comprising a plug/packer into the well bore below the first and second sections of well bore pipe, the plug configured to prohibit extraneous fluid flow and materials from entering the well bore during production.

5. The hydrocarbon lift system of claim 1, further comprising a packing material placed adjacent the well bore and the flaring ends of the venturi structure, the packing material configured to semi-permanently fix the venturi structure in a predetermined section of the well bore.

6. The hydrocarbon lift system of claim 1, wherein a number of first section perforations in the well bore is greater than a number of second section perforations in the well bore.

7. The hydrocarbon lift system of claim 1, wherein a diameter of the first section perforations in the well bore is greater than a diameter of the second section perforations in the well bore.

8. The hydrocarbon lift system of claim 1, wherein a number of second section perforations in the well bore is greater than a number of first section perforations in the well bore.

9. The hydrocarbon lift system of claim 1, wherein a diameter of the flaring ends of the venturi structure is larger than a diameter of the constricting throat.

10. The hydrocarbon lift system of claim 1, wherein a diameter of the flaring ends of the venturi structure is approximately the same as an inner diameter of the well bore.

11. The hydrocarbon lift system of claim 1, wherein the first section is disposed below the second section with respect to the surface and both the first and second sections are disposed beneath a terminus of a pipe string within the well bore.

12. The hydrocarbon lift system of claim 1, wherein a diameter of the constricting throat of the venturi structure is remotely adjustable up to an inner diameter of the well bore and is remotely adjustable down to approximately zero based on the induced pressure difference predetermined by an operator.

13. A hydrocarbon lift system for prohibiting water-coning in production of oil from a subterranean reservoir to the earth's surface, the system comprising:

a well bore having at least a first section and a second section, the first section having a plurality of perforations configured to draw a water flow into and through the well bore based on a pump pressure applied thereto, the second section having a plurality of perforations configured to draw an oil flow into and through the well bore based on a differential pressure between the pump pressure and a lower induced pressure therein; and

a venturi structure configured to be fixtured into the well bore, the venturi structure having flaring ends connected by a constricting throat defining a plurality of perforations therein configured to draw oil through the second section perforations into the venturi throat in response to the lower induced pressure in the second section created by an accelerated water flow through the venturi throat and flow with the oil there through to the surface.

14. The hydrocarbon lift system of claim 14, further comprising a pass through tube extending a length from the well bore head to a section below the first section of well bore pipe, the pass through tube configured to pass a recovered water flow to the surface back down into the well.

15. The hydrocarbon lift system of claim 14, further comprising a scoup structure adjacent a venturi throat perforation, the scoup structure configured to assist in drawing the second flow there through into the venturi throat, an opening defined by the scoup directed upward at a 15 degree angle to the well bore plus or minus a 10% manufacturing tolerance.

16. The hydrocarbon lift system of claim 14, further comprising;

a plurality of buoyant balls entrained in a pipe string in oil and water, the balls configured to at least one of displace a fluid mass and have a surface friction moving in the oil and water therein;

an entrained column of the buoyant balls in the pipe string, an aggregate weight of the balls and the oil and water configured to entrain the balls into the oil and water in an annulus formed with an outer bore pipe; and

a pressure differential in the annulus with respect to the reservoir via the entrained buoyant balls, the pressure configured to lift the oil and water and the entrained balls to enhance petroleum production in the annulus to the surface.

17. The hydrocarbon lift system of claim 14, further comprising;

a pipe string configured with a quiescent gas therein under a steady state gas pressure with any quiescent gas escape offset by an equal gas input;

a plurality of buoyant balls gravity fed down the pipe string, the balls configured to at least one of displace a fluid mass and have a surface friction moving in a fluid therein;

a column of the buoyant balls in the pipe string, an aggregate weight of the balls in the column configured to entrain the balls into a fluid in an annulus formed with an outer bore pipe; and

a hydrostatic pressure differential in the annulus with respect to the reservoir via the buoyant balls, the pressure configured to lift a fluid in the annulus to the surface.

18. The hydrocarbon lift system of claim 14, further comprising a designer buoyant object introduced into the well bore, the designer buoyant object engineered to assist in the flow of water and oil to the surface, the designer buoyant object comprising at least one concavity on a surface thereof, the concavity engineered to one of carry a fluid to the surface and increase an effective buoyant force on the object.

19. A hydrocarbon lift method for prohibiting water-coning in production of oil from a subterranean reservoir to the earth's surface, the method comprising:

providing a well bore having at least a first section and a second section, the first section having a plurality of perforations configured to draw a water flow into and through the well bore based on a pump pressure applied thereto, the second section having a plurality of perforations configured to draw an oil flow into and through the well bore based on a differential pressure between the pump pressure and a lower induced pressure therein;

fixturing a venturi structure into the well bore, the venturi structure having flaring ends connected by a constricting throat defining a plurality of perforations therein configured to draw oil through the second section perforations into the venturi throat in response to the lower induced pressure in the second section created by a greater water flow velocity through the venturi throat with respect to a water flow velocity through the well bore; and

drawing the water flow through the first section perforations into the venturi throat in response to the pressure applied to the well bore head and drawing the oil flow through the second section perforations into the venturi throat in response to the lower induced pressure and drawing both the water flow and the oil flow through the well bore to the surface due to the pressure applied to the well bore head.

20. The hydrocarbon lift method of claim 19, further comprising recovering water from the oil at the surface and pumping the recovered water via a pass through tube extending a length from the well bore head to an area below the first section of well bore pipe.