WO2008153407A1 - Dispositif de pompage fonctionnant au gaz et procédé de pompage de fond de trou d'un liquide dans un puits - Google Patents

Dispositif de pompage fonctionnant au gaz et procédé de pompage de fond de trou d'un liquide dans un puits Download PDF

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Publication number
WO2008153407A1
WO2008153407A1 PCT/NO2008/000205 NO2008000205W WO2008153407A1 WO 2008153407 A1 WO2008153407 A1 WO 2008153407A1 NO 2008000205 W NO2008000205 W NO 2008000205W WO 2008153407 A1 WO2008153407 A1 WO 2008153407A1
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WO
WIPO (PCT)
Prior art keywords
gas
pressure
liquid
channel
manipulation
Prior art date
Application number
PCT/NO2008/000205
Other languages
English (en)
Inventor
Rune Woie
Thor Martin Hegre
Original Assignee
Shore-Tec Consult As
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Shore-Tec Consult As filed Critical Shore-Tec Consult As
Priority to GB0922174.8A priority Critical patent/GB2462783B/en
Priority to US12/663,834 priority patent/US20100284828A1/en
Publication of WO2008153407A1 publication Critical patent/WO2008153407A1/fr

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
    • E21B43/121—Lifting well fluids
    • E21B43/129—Adaptations of down-hole pump systems powered by fluid supplied from outside the borehole
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
    • E21B43/121—Lifting well fluids
    • E21B43/122—Gas lift
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/34—Arrangements for separating materials produced by the well
    • E21B43/38—Arrangements for separating materials produced by the well in the well
    • E21B43/385—Arrangements for separating materials produced by the well in the well by reinjecting the separated materials into an earth formation in the same well

Definitions

  • This invention concerns a gas-driven pumping device and a method for allowing pumping of a liquid, for example water and/or oil, out of a well or within the well.
  • the liquid may be comprised of water or oil emanating from a subsurface production formation connected to the well.
  • the liquid may consist of a separated liquid, for example water-containing liquid, emanating from a downhole separator connected to such a production formation.
  • the invention may be used in connection with downhole separation of oil and water emanating from a hydrocarbon- and water-containing production flow, simultaneously injecting water-containing liquid into a subsurface disposal formation.
  • the invention may also be used in all types of wells, including deviated wells and horizontal wells. Background of the invention '
  • the background of the invention is an industrial need for a simple, operationally reliable and cost-efficient pumping solution for downhole use in a well.
  • the prior art comprises many types of conventional and submersible pumping devices for use in a well, including piston pumps, displacement pumps, turbine pumps, centrifugal pumps, etc. Given that a person skilled in the area will be familiar with such pumps, a further description is considered unnecessary.
  • Such conventional downhole pumps generally have relatively complex constructions in common, and/or they have many movable parts. Moreover, they oftentimes receive mechanical, hydraulic or electric power from the surface, which requires suitable connections and equipment in order to provide the driving power. Normally, they are also comprehensive and/or complicated to drive, inspect and maintain. Generally, this causes them to have a limited lifetime and/or a limited area of application, especially in deep wells. This is generally reflected as operational and cost-related disadvantages.
  • the object of the invention is to avoid or substantially reduce the disadvantages of the prior art by providing a novel pumping device and method of pumping a liquid in a well .
  • the invention presupposes that a person skilled in the area will employ relevant knowledge in the area, including various known well technology and well equipment, and to the degree necessary in order to adapt the invention to the well conditions and requirements at hand.
  • known well equipment may include suitable well packers, valves, control equipment, various types of pipes, conduits and materials, etc. Also this will not be discussed any further given that this is considered known to the skilled person.
  • a gas-driven pumping device for pumping a liquid from at least one liquid source in a well and onto at least one receiving region for the liquid is provided, the liquid source having a pressure (Psource) and the receiving region having a pressure (Preceiving) •
  • the pumping device is located in the well.
  • liquid supply channel connecting the pressure manipulation chamber to said liquid source, the liquid supply channel including at least one first check valve for allowing liquid flow only to the pressure manipulation chamber;
  • liquid discharge channel connecting the lower chamber portion of the pressure manipulation chamber to said liquid receiving region, the liquid discharge channel including at least one second check valve for allowing liquid flow only from the pressure manipulation chamber;
  • the gas supply channel connecting the pressure manipulation chamber to at least one gas source containing a pressurized manipulation gas, the gas supply channel including at least one first control valve structured for selective introduction of manipulation gas into the pressure manipulation chamber, and also for regulation of the pressure (P C hamber) of the gas therein; and
  • the gas discharge channel including at least one second control valve structured for selective discharge of manipulation gas from the pressure manipulation chamber, and also for regulation of the pressure (Pcham be r) of the gas therein.
  • the pumping device is structured so as to be able to direct manipulation gas out of the pressure manipulation chamber and also lower the gas pressure (Pchamber) therein to a lower pressure (Pi OWer ) at which a resulting pressure difference (P SO ur ce -Pi owe r) will drive the liquid from the
  • the pumping device is . also structured so as to then be able to direct manipulation gas into the pressure manipulation chamber and increase the gas pressure (Pchamber) therein to an upper pressure (P upP er) at which a resulting pressure difference (P U p P er-Preceding) will drive the liquid from the pressure manipulation chamber and onwards to the receiving region via said liquid discharge channel.
  • the pumping device is structured so as to be able to alternately lower and increase the gas pressure (P chamber ) in the pressure manipulation chamber, the course of which represents one operating cycle, thereby being able to pump liquid from the liquid source and onwards to the receiving region via the pressure manipulation chamber.
  • the present pumping device is based on the ability to change the gas pressure (Pchamber) in the pressure manipulation chamber within a large pressure range, and potentially within several tens of bars. This is achieved by virtue of said gas source being pressurized to a suitable pressure level capable of at least resulting in the particular upper pressure
  • the gas source may thus be arranged with such a suitable pressure level, or a gas source pressurized at least to such a pressure level may be selected.
  • the pressure manipulation chamber may be several hundred meters long and may hold a significant volume of gas and liquid.
  • said supply channels and discharge channels from the pressure manipulation chamber may be comprised of, for example
  • the pumping device may also employ suitable sensors, valve means and control devices for appropriate control of the gas- and liquid flow into and out of the pressure manipulation chamber, but also for appropriate control of the liquid's level within the pressure manipulation chamber in the course of said operating cycle.
  • suitable sensors, valve means and control devices for appropriate control of the gas- and liquid flow into and out of the pressure manipulation chamber, but also for appropriate control of the liquid's level within the pressure manipulation chamber in the course of said operating cycle.
  • one or several water level stop devices and gas flow control devices may be employed for this purpose.
  • such equipment is considered to be prior art and therefore will not be discussed in detail.
  • Said water level stop device may, for example, comprise one or several floats, float seats and sensors known per se capable of distinguishing a liquid from a gas at one or several water levels within the pressure manipulation chamber.
  • sensors may distinguish differences in physical properties of the liquid and the gas, for example differences in pressure, density, temperature, resistivity, acoustic travel time, optical properties and alike.
  • said gas flow control device may, for example, be connected devices and sensors known per se capable of distinguishing different properties of a liquid and/or gas at one or several water levels within the pressure manipulation chamber.
  • the gas flow control device may then be structured so as to be able to register such differences and/or properties and, based on this, may allow control of said flow of overpressured manipulation gas to and from the pressure manipulation chamber.
  • Said sensors may, for example, distinguish differences in pressure, density, temperature,
  • said manipulation gas may consist of any suitable gas, for example a hydrocarbon gas, air, carbon dioxide or nitrogen.
  • said liquid supply channel is connected in a flow-communicating manner to at least one water production formation connected to the well, the water production formation thus constituting said liquid source; and whereas said liquid discharge channel is connected in a flow- communicating manner to the surface of the well, the surface thus constituting the receiving region for water emanating from the water production formation.
  • the present pumping device may be used, for example, to pump and produce water emanating from a subsurface water reservoir, for example a ground water occurrence.
  • a subsurface water reservoir for example a ground water occurrence.
  • a water reservoir contains hydrostatically pressurized water, which normally implies that the water will not flow to the surface by itself.
  • said liquid supply channel is connected in a flow-communicating manner to at least one oil production formation connected to the well, the oil production formation thus constituting said liquid source; whereas said liquid discharge channel is connected in a flow- communicating manner to the surface of the well, the surface thus constituting the receiving region for oil emanating from the oil production formation.
  • the present pumping device may be used, for example, to pump and produce oil emanating from a subsurface oil reservoir.
  • the present pumping device may replace a so-called jacking pump, which comprises a downhole oscillating piston pump connected to a mechanical driving device on the surface via a long pump rod extending to the surface.
  • said gas discharge channel may comprise at least one gas bleed channel filled with manipulation gas for selective discharge of so-called lift gas into said liquid discharge channel, whereby a gas pressure gradient will be present in the gas bleed channel, whereas a liquid pressure gradient will be present in the liquid discharge channel;
  • the gas-filled gas bleed channel connects the upper chamber portion of the pressure manipulation chamber in a flow-communicating manner to a shallower depth level in the liquid discharge channel where the liquid (i.e. water or oil) has a liquid pressure (P S haiiower) ;
  • said shallower depth level is selected at a depth where the liquid pressure (Psh a ii o w e r) / via the gas pressure gradient in the gas bleed channel, will result in said lower gas pressure (Pi OWe r) in the pressure manipulation chamber, insofar as the lower gas pressure (Pi OW er) will be substantially smaller than a corresponding liquid pressure at the same level in the liquid discharge channel.
  • the difference between the densities of the manipulation gas and the liquid flow is utilized to provide the lower gas pressure (Pi owe r) in the pressure manipulation chamber.
  • the pumping device is also structured so as to be able to selectively direct manipulation gas into the
  • P25395PC00DEPRIO liquid discharge channel as lift gas for the liquid (i.e. water or oil) .
  • said gas source may be comprised of at least one of the following gas sources: - a gas source at the surface; and
  • a further embodiment will now be described, the embodiment being specifically directed toward downhole separation and injection of water separated from a hydrocarbon- and water- containing production flow emanating from a subsurface reservoir.
  • said liquid supply channel is connected in a flow-communicating manner to a water- containing liquid in at least one hydrocarbon-water-separator located in the well, the separator constituting said liquid source ;
  • separator is connected in a flow-communicating manner to a hydrocarbon- and water-containing production flow emanating from at least one production formation connected to the well;
  • the separator is structured so as to be able to at least separate said production flow into said water- containing liquid and into a hydrocarbon-containing liquid;
  • hydrocarbon-containing liquid in the separator is connected in a flow-communicating manner to at least one production channel for production of the hydrocarbon- containing liquid;
  • liquid discharge channel is connected in a flow-communicating manner to at least one disposal formation connected to the well, the disposal formation constituting
  • water-containing liquid and hydrocarbon-containing liquid do not presuppose 100 % presence of water and hydrocarbons, respectively, but refer herein to main constituents of water and hydrocarbons, respectively.
  • hydrocarbon-containing part of the production flow may contain only hydrocarbon liquid, possibly a mixture of hydrocarbon liquid and hydrocarbon gas.
  • said disposal formation is porous and permeable, but it may also be non-porous and impermeable.
  • the fluid pressure in the pores of the disposal formation (the pore pressure)
  • the fracture pressure of the formation must be overcome. This circumstance must be accounted for when said upper gas pressure (P upP er) in the pressure manipulation chamber is to be determined.
  • said gas discharge channel may comprise at least one gas bleed channel filled with manipulation gas for selective discharge of lift gas into said production channel, whereby a gas pressure gradient will be present in the gas bleed channel, whereas a liquid pressure gradient will be present in the production channel; - wherein the gas-filled gas bleed channel connects the upper chamber portion of the pressure manipulation chamber in a flow-communicating manner to a shallower depth level in the production channel where the hydrocarbon-containing liquid
  • P25395PC00DEPRIO has a liquid pressure (P S haiiower) ;
  • said shallower depth level is selected at a depth where the liquid pressure (P S haiiower) , via the gas pressure gradient in the gas bleed channel, will result in said lower gas pressure (Piower) in the pressure manipulation chamber, insofar as the lower gas pressure (Pi ower ) will be substantially smaller than a corresponding liquid pressure at the same level in the production channel.
  • the difference between the densities of the manipulation gas and the hydrocarbon-containing liquid is utilized to provide the lower gas pressure (Pi o w er ) in the pressure manipulation chamber.
  • the pumping device is also structured so as to be able to selectively direct manipulation gas into the production channel as lift gas for the hydrocarbon-containing liquid.
  • said gas source may be comprised of at least one of the following gas sources:
  • Said at least one hydrocarbon-water-separator may comprise at least one cyclone separator.
  • US 5.711.374 (corresponding to WO 94/13930) and US 5.296.153 (corresponding to WO 94/18432) describe cyclone separators capable of being used in connection with the present invention. Both of these publications describe injection of separated water into a subsurface disposal formation. However, the water injection takes place by means of conventional downhole pumps, which
  • P25395PC00DEPRIO are comprised by the prior art, including the pump types mentioned above, among others.
  • said at least one hydrocarbon- water-separator may also comprise at least one gravity separator.
  • US 6.092.599 (corresponding to WO 99/15755) describes a downhole oil-water separation system capable of being used in connection with the present invention, the separation system of which is based on gravity separation of a hydrocarbon-containing production flow. This separation system is shown used in a vertical well. Conventional downhole pumps are used to produce separated water to the surface, or to inject the water into a subsurface disposal ⁇ formation.
  • the gravity separator may be comprised of a horizontal gravity separator located in a horizontal portion of the well, the gravity separator of which may be several hundred meters long. If required, the horizontal well may also comprise several horizontal gravity separators.
  • US 6.277.286 (corresponding to WO 98/41304) describes a horizontal gravity separator capable of being used in connection with the present invention. Also this publication describes use of conventional downhole pumps for injecting separated water into a subsurface disposal formation, possibly via a sidetrack well.
  • the at least one hydrocarbon-water-separator may also comprise at least one gas separation device for separation of gas from said production flow.
  • US 6.691.781 describes a horizontal gravity separator for separation of both gas, water and oil from a production flow. Also this type of separator may be used in connection with the present
  • the pressure manipulation chamber may be located at a distance from the at least one separator. If required or desirable, the pressure manipulation chamber may be located several hundred meters away from said separator.
  • the present pumping device being structured so as to be able to change the gas pressure (P C ham b er) in the pressure manipulation chamber within a large pressure range, whereby a correspondingly large pressure height (and lifting height) is obtained for the pumping device.
  • This feature provides the present pumping device with a substantial advantage with respect to known suction pumps, which are based on generating an underpressure relative to an ambient pressure, generally atmospheric air pressure. Such a suction pump will therefore be able to provide a driving pressure difference limited upwards to ca.
  • suction pumps are not useful in most wells. For that matter, this also applies to other types of pumps having limited pressure height (and lifting height) .
  • said at least one disposal formation may be situated shallower and/or deeper than the at least one production formation.
  • the at least one disposal formation may comprise at least one disposal layer in the at least one production formation, for
  • P25395PC00DEPRIO example a water-containing layer underlying a hydrocarbon- containing layer of the same formation.
  • the pressure manipulation chamber may also have various designs.
  • the pressure manipulation chamber may be located in or on the outside of a pipe in the well, for example a production tubing, casing or coiled tubing.
  • the pressure manipulation chamber may also be located in an annulus in the well, for example between two well pipes or between a well pipe and the wall of a well.
  • the present pumping device may comprise at least two pressure manipulation chambers structured for cooperative pumping of liquid from said liquid source and onwards to said receiving region; and - wherein said pressure manipulation chambers are arranged with a phase-lagged operating cycle relative to each other, whereby a smoother induction and pumping of liquid is achieved.
  • the chambers may be arranged with opposite operating cycle relative to each other.
  • the pumping device may possibly comprise several such pairs of cooperative pressure manipulation chambers.
  • a method of pumping a liquid from at least one liquid source in a well and onto at least one receiving region for the liquid is provided, the liquid source having a pressure (P sou r ce ) and the receiving region having a pressure (Preceding) •
  • the pumping device comprises at least one pressure manipulation chamber extending in the longitudinal direction of the well and including a lower chamber portion and an upper chamber portion, and wherein said pressure manipulation chamber is connected in a flow-communicating manner to the following channels: - at least one liquid supply channel connecting the pressure manipulation chamber to said liquid source, the liquid supply channel including at least one first check valve for allowing liquid flow only to the pressure manipulation chamber; - at least one liquid discharge channel connecting the lower chamber portion of the pressure manipulation chamber to said liquid receiving region, the liquid discharge channel including at least one second check valve for allowing liquid flow only from the pressure manipulation chamber; - at least one gas supply channel connecting the pressure manipulation chamber to at least one gas source containing a pressurized manipulation gas, the gas supply channel including at least one first control valve structured for selective introduction of manipulation gas into the pressure manipulation chamber, and also for regulation of the pressure (P C hamber) of the gas therein; and
  • the gas discharge channel including at least one second control valve structured for selective discharge of manipulation gas from the pressure manipulation chamber, and also for regulation of the pressure (Pchamber) of the gas therein.
  • the method also comprises the following steps:
  • the method also comprises the following steps:
  • the method may comprise the following steps:
  • a gas discharge channel comprising at least one gas bleed channel and filling it with manipulation gas for selective discharge of lift gas into said liquid discharge channel, whereby a gas pressure gradient is present in the gas bleed channel, whereas a liquid pressure gradient is present in the liquid discharge channel;
  • the difference between the densities of the manipulation gas and the liquid is utilized to provide the lower gas pressure (Piower) in the pressure manipulation chamber.
  • the pumping device is also structured to selectively direct manipulation gas into the liquid discharge channel as lift gas for the liquid (i.e. water or oil) .
  • said gas source may be comprised of at least one of the following gas sources:
  • the method may also be directed specifically toward downhole separation and injection of water being separated from a hydrocarbon- and water-containing production flow emanating from a subsurface reservoir.
  • the method may also comprise the following steps:
  • separator is connected in a flow- communicating manner to a hydrocarbon- and water-containing production flow emanating from at least one production formation connected to the well;
  • the separator is structured so as to be able to at least separate said production flow into said water- containing liquid and into a hydrocarbon-containing liquid;
  • P25395PC00DEPRIO separator in a flow-communicating manner to at least one production channel for production of the hydrocarbon- containing liquid
  • a gas discharge channel comprising at least one gas bleed channel and filling it with manipulation gas for selective discharge of lift gas into said production channel, whereby a gas pressure gradient is present in the gas bleed channel, whereas a liquid pressure gradient is present in the production channel;
  • the pumping device is also structured to selectively direct manipulation gas into the production channel as lift gas for the hydrocarbon- containing liquid.
  • said gas source may be comprised of at least one of the following gas sources:
  • Said at least one hydrocarbon-water-separator may comprise at least one cyclone separator and/or at least one gravity separator.
  • the gravity separator may be comprised of a horizontal gravity separator, which is being located in a horizontal portion of the well.
  • the at least one hydrocarbon-water-separator may also comprise at least one gas separation device for separation of gas from said production flow.
  • the pressure manipulation chamber may be located at a distance from the at least one separator, and optionally several hundred meters away from said separator, which is not possible with conventional suction pumps or similar.
  • said at least one disposal formation may be situated shallower and/or deeper than the at least one
  • the at least one disposal formation may comprise at least one disposal layer in the at least one production formation.
  • the pressure manipulation chamber may also be located in or on the outside of a pipe in the well, or it may be located in an annulus in the well.
  • the method may also comprise the following steps :
  • each pumping device includes at least one pressure manipulation chamber
  • At least two pumping devices may be connected in parallel or in series, depending on the particular need.
  • Figures 1-6 show a first embodiment of the invention
  • Figures 7-12 show a second embodiment of the invention.
  • Figures 1-6 show a first embodiment of a gas-driven pumping device 2 located in a subsurface well 4 including, among other things, an outer casing 6 and an inner production tubing 8.
  • the well 4 is shown as a vertical well in all of figure 1-12, in practice it may also be a deviated well or a horizontal well.
  • the casing 6 is also provided with perforations 10, 12, which are positioned vis-a-vis a production formation 14 and a shallower disposal formation 16, respectively, the disposal formation 16 having a pressure (Prec e iving) and constituting a receiving region for liquid.
  • the pumping device 2 comprises a pressure manipulation chamber 18 located in an annulus 19 in the well 4, the annulus of which may extend for several hundred meters in the longitudinal direction of the well 4.
  • the pressure manipulation chamber 18 is defined between the casing 6 and the production tubing 8, and between a first (upper) well packer 20 and a second (lower) well packer 22.
  • the second well packer 22 is located immediately above the disposal formation 16, whereas a third well packer 24 is located immediately below the disposal formation 16.
  • an injection annulus 26 is defined between the second well packer 22 and the third well packer 24, and between the casing 6 and the production tubing 8.
  • the production tubing 8 extends deeper down into the well 4 and onto an oil-water gravity separator 28, which is shown very schematically in all of figures 1-12.
  • the gravity separator 28 is connected, among other things, to the production tubing 8, but it is also connected in flow- communicating manner to said production formation 14 via at
  • P25395PC00DEPRIO least one inlet 30 in the separator 28, and via the perforations 10 in the casing 6.
  • an oil- and water-containing production flow 32 is directed into the well 4 and further into the gravity separator 28, which has a pressure (P SOu r ce ) •
  • the gravity separator 28 which constitutes a liquid source for the pumping device 2
  • the production flow 32 is separated into a lower water layer 34 and into an upper oil layer 36.
  • the separation will take place in a natural manner owing to a density difference between water 34 and oil 36.
  • the upper oil layer is connected in a flow-communicating manner to the production tubing 8 for production of oil 36 to the surface of the well 4.
  • separator 28 is shown located in a vertical well in all of figures 1-12, it may just as well be located in a deviated well or in a horizontal well.
  • the separator may be comprised of a horizontal gravity separator located in a horizontal portion of the well.
  • Other types of downhole separators may also be used, for example cyclone separators.
  • the pressure manipulation chamber 18, which includes a lower chamber portion 38 and an upper chamber portion 40, is connected in a flow-communicating manner to the following flow channels: a water supply pipe 42, a water discharge pipe 44, a gas supply pipe 46 and a gas discharge pipe 48.
  • Said water supply pipe 42 connects the pressure manipulation chamber 18 to the lower water layer 34 in the separator 28.
  • the water supply pipe 42 is provided with a first check valve 50 for allowing water flow only to the pressure manipulation
  • P25395PC00DEPRIO chamber 18 The possible flow direction is indicated with a black arrow on all of figures 1-12. Yet further, the pipe 42 has been inserted in a pressure-sealing manner through said second and third well packers 22, 24.
  • Said water discharge pipe 44 connects the lower chamber portion 38 of the pressure manipulation chamber 18 in a flow- communicating manner to said injection annulus 26, which is connected in a flow-communicating manner to said disposal formation 16 via the perforations 12 in the casing 6.
  • the water discharge pipe 44 is provided with a second check valve 52 for allowing water flow only from the pressure manipulation chamber 18 and into the injection annulus 26.
  • the possible flow direction is indicated with a black arrow on all of figures 1-12.
  • the pipe 44 has been inserted in a pressure-sealing manner through said second well packer 22.
  • said first and second check valves 50, 52 are preferably structured so as to open at a specific pressure level, which is adapted to the well conditions and purposes in question.
  • Said gas supply pipe 46 connects the pressure manipulation chamber 18 to a gas source 54 containing a pressurized manipulation gas 56, which in the present embodiments is comprised of hydrocarbon gas.
  • the gas source 54 is shown schematically in all of figures 1-12.
  • manipulation gas 56 may be supplied to the pressure manipulation chamber 18 directly from a pressurized annulus 19 overlying said first well packer 20.
  • the gas supply pipe 46 is provided with a first control valve 58 structured for selective introduction of manipulation gas 56 into the
  • P25395PC00DEPRIO pressure manipulation chamber 18 and also for regulation of the pressure (P C hamber) of the gas 56 therein.
  • Any suitable valve means with associated cables, couplings and regulation devices may be used for this purpose.
  • the pipe 46 has been inserted in a pressure-sealing manner through the first well packer 20.
  • Said gas discharge pipe 48 leads out of the upper chamber portion 40 of the pressure manipulation chamber 18 and directly into the production tubing 8.
  • the gas discharge pipe 48 is provided with a second control valve 60 structured for selective discharge of manipulation gas 56 from the pressure manipulation chamber 18, and also for regulation of the pressure (P C h a m be r) of the gas 56 therein.
  • the manipulation gas 56 functions as a lift gas 56' for the oil 36 in the production tubing 8.
  • any suitable valve means with associated cables, couplings and regulation devices may be used for this purpose.
  • Figure 1 shows the start-up of the pumping device 2, wherein said first control valve 58 is open, and manipulation gas 56 is directed into the pressure manipulation chamber 18 via said gas supply pipe 46 in order to pressurize the chamber 18 to a gas pressure (P C hamber) •
  • the gas flow direction is indicated with a black arrow at the outlet of the gas supply pipe 46.
  • the gas pressure (Pchamber) is increased to a level in vicinity of the opening pressure for said second check valve
  • manipulation gas 56 is directed out of the pressure manipulation chamber 18 via said gas discharge pipe 48 and lowers the gas pressure (P C h a m be r) in the chamber 18 to a lower pressure (Piower) at which a resulting pressure difference (Psource-Piower) drives water 34 from the separator 28 and onwards into the pressure manipulation chamber 18 via the water supply pipe 42.
  • manipulation gas 56 is directed into the production tubing 8 as said lift gas 56' for the oil 36 flowing therein.
  • the gas flow direction is indicated with a black arrow at the outlet of the gas discharge pipe 48. This is shown in figure 2.
  • Figures 3 and 4 show two different stages the course of filling water 34 into the pressure manipulation chamber 18.
  • the water 34 is filled up to an upper water level 62 in the pressure manipulation chamber 18, the discharge of manipulation gas 56 simultaneously decreasing. This is shown in figure 4.
  • pressurized manipulation gas 56 is directed from the gas source 54 and into the pressure manipulation chamber 18 and increases the gas pressure (P C hamber) therein to an upper pressure (P U p P er) at which a resulting pressure difference (P upP er-Preceiving) drives water 34 from the pressure manipulation chamber 18 and into the injection annulus 26 via the water discharge pipe 44.
  • Figures 7-12 show a second embodiment of a gas-driven pumping device 2 according to the invention. This second embodiment comprises most of the central elements of the first embodiment of the invention.
  • This embodiment however, comprises a pressure manipulation chamber 18 located as a separate unit on the outside of said production tubing 8, and in said annulus 19 in the well 4.
  • a second difference is that the pressure manipulation chamber 18 is located at a distance from, and shallower than, both the separator 28 and the disposal formation 16.
  • a third difference is that said gas discharge pipe 48 now has been replaced by a gas bleed pipe 48' filled with manipulation gas 56 for selective discharge of lift gas 56' into the production tubing 8.
  • a gas pressure gradient will be present in the gas bleed pipe 48', whereas an oil pressure gradient will be present in the production
  • the gas-filled gas bleed pipe 48' is also provided with a second control valve 60 for selective discharge of manipulation gas 56, and also for regulation of the gas pressure (P C hamber) in the pressure manipulation chamber 18. Furthermore, the gas bleed pipe 48' is provided with a third check valve 66 for allowing gas flow only from the pressure manipulation chamber 18. The possible gas flow direction is indicated with a black arrow in all of figures 7-12.
  • the gas bleed pipe 48' connects the upper chamber portion 40 of the pressure manipulation chamber 18 in a flow-communicating manner to a shallower depth level 68 in the production tubing 8 where the oil 36 has an oil pressure ( P sh allower) •
  • both a gas discharge pipe 48 and a gas bleed pipe 48' provided each with a control valve 60, may be used.
  • This shallower depth level 68 has been chosen at a depth where the oil pressure (Pshaiiower) / via the gas pressure gradient in the gas bleed pipe 48', will result in said lower gas pressure (Pi OW er) in the pressure manipulation chamber 18.
  • the gas pressure (Pi OWer ) will be substantially smaller than a corresponding oil pressure at the same level in the production tubing 8.
  • this pumping device 2 is structured so as to be able to selectively direct manipulation gas 56 into the production tubing 8 as lift gas 56' for the flow of oil 36 from the separator 28.

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  • Jet Pumps And Other Pumps (AREA)

Abstract

L'invention concerne un dispositif de pompage fonctionnant au gaz (2) et un procédé de pompage de fond de trou d'un liquide (34) provenant d'au moins une source de liquide (28) dans un puits (4) et sur au moins une région de réception (16) pour le liquide (34). Le dispositif de pompage (2) comprend une chambre de manipulation de pression (18) ayant une partie de chambre inférieure (38) et une partie de chambre supérieure (40), la chambre de manipulation de pression (18) étant raccordée en communication fluidique à : - un canal d'alimentation en liquide (42) reliant la chambre de manipulation de pression (18) à la source de liquide (28); - un canal de refoulement de liquide (44) reliant la partie de chambre inférieure (38) à la région de réception de liquide (16); un canal d'alimentation en gaz (46) reliant la chambre de manipulation de pression (18) à une source de gaz (54) avec un gaz de manipulation sous pression (56); un canal de refoulement de gaz (48) sortant de la partie de chambre supérieure (40) de la chambre de manipulation de pression (18). En diminuant et augmentant alternativement la pression de gaz (Pchambre), le liquide (34) est pompé de la source de liquide (28) et transmis à la région de réception (16) via la chambre de manipulation de pression (18).
PCT/NO2008/000205 2007-06-11 2008-06-09 Dispositif de pompage fonctionnant au gaz et procédé de pompage de fond de trou d'un liquide dans un puits WO2008153407A1 (fr)

Priority Applications (2)

Application Number Priority Date Filing Date Title
GB0922174.8A GB2462783B (en) 2007-06-11 2008-06-09 A gas-driven pumping device and a method for downhole pumping of a liquid in a well
US12/663,834 US20100284828A1 (en) 2007-06-11 2008-06-09 Gas-Driven Pumping Device and a Method for Downhole Pumping of a Liquid in a Well

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
NO20072954 2007-06-11
NO20072954A NO20072954A (no) 2007-06-11 2007-06-11 Gassdrevet pumpeanordning og fremgangsmåte for pumping av en væske i en brønn

Publications (1)

Publication Number Publication Date
WO2008153407A1 true WO2008153407A1 (fr) 2008-12-18

Family

ID=39768608

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/NO2008/000205 WO2008153407A1 (fr) 2007-06-11 2008-06-09 Dispositif de pompage fonctionnant au gaz et procédé de pompage de fond de trou d'un liquide dans un puits

Country Status (4)

Country Link
US (1) US20100284828A1 (fr)
GB (1) GB2462783B (fr)
NO (1) NO20072954A (fr)
WO (1) WO2008153407A1 (fr)

Cited By (2)

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Publication number Priority date Publication date Assignee Title
WO2013010244A1 (fr) * 2011-07-19 2013-01-24 Evan Koslow Appareil et procédés de production de gaz naturel utilisant une phase de recyclage de gaz pour évacuer du liquide d'un puits
WO2019054955A1 (fr) * 2017-09-15 2019-03-21 Nasir Serkan Moteur de pompe submersible pouvant fonctionner avec de l'air comprimé

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US10844700B2 (en) * 2018-07-02 2020-11-24 Saudi Arabian Oil Company Removing water downhole in dry gas wells
US10995595B2 (en) 2019-02-04 2021-05-04 Saudi Arabian Oil Company System and method for artifically recharging a target reservoir via water injection from a local source
US11555571B2 (en) 2020-02-12 2023-01-17 Saudi Arabian Oil Company Automated flowline leak sealing system and method

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* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2013010244A1 (fr) * 2011-07-19 2013-01-24 Evan Koslow Appareil et procédés de production de gaz naturel utilisant une phase de recyclage de gaz pour évacuer du liquide d'un puits
WO2019054955A1 (fr) * 2017-09-15 2019-03-21 Nasir Serkan Moteur de pompe submersible pouvant fonctionner avec de l'air comprimé

Also Published As

Publication number Publication date
GB2462783B (en) 2012-04-25
GB2462783A (en) 2010-02-24
US20100284828A1 (en) 2010-11-11
GB0922174D0 (en) 2010-02-03
NO325707B1 (no) 2008-07-07
NO20072954A (no) 2008-07-07

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