WO2020028987A1 - Production par recirculation de gaz à partir de puits de forage horizontaux - Google Patents

Production par recirculation de gaz à partir de puits de forage horizontaux Download PDF

Info

Publication number
WO2020028987A1
WO2020028987A1 PCT/CA2019/051083 CA2019051083W WO2020028987A1 WO 2020028987 A1 WO2020028987 A1 WO 2020028987A1 CA 2019051083 W CA2019051083 W CA 2019051083W WO 2020028987 A1 WO2020028987 A1 WO 2020028987A1
Authority
WO
WIPO (PCT)
Prior art keywords
wellbore
valve
gas
annulus
production
Prior art date
Application number
PCT/CA2019/051083
Other languages
English (en)
Inventor
Geoff Steele
Eric Laing
Original Assignee
Raise Production Inc.
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 Raise Production Inc. filed Critical Raise Production Inc.
Publication of WO2020028987A1 publication Critical patent/WO2020028987A1/fr

Links

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
    • E21B43/122—Gas lift
    • E21B43/123—Gas lift valves

Definitions

  • the present invention relates to methods of producing oil and gas fluids from a horizontal wellbore.
  • the majority of horizontal wellbores are completed either as a "mono-bore" where pipe of the same dimensions is run from surface down into the vertical, build and horizontal sections.
  • the mono-bore can be run or completed with any number of accessories, such as sliding sleeves, ball drop or the like, or procedures such as perforating and other stimulation techniques, allowing fluid communication from the reservoir to the pipe.
  • a liner of usually a smaller diameter than surface, intermediate or production casing, is run in, usually from the build section into and along the length of the horizontal wellbore section.
  • This liner assembly can have the same accessories and provide the same means of procedures as a mono-bore to provide access to the reservoir.
  • the overall recovery factor is a consideration when deploying artificial lift recovery techniques.
  • the lift solution must address the lift efficiencies in the entire length of the substantially horizontal portion of the producing wellbore.
  • US Patent No. 9,863,414 B2 the entire contents of which are incorporated herein by reference (where permitted)
  • conventional methods of producing a horizontal wellbore are described as not influencing the reservoir much beyond the heel due to preferential depletion of the region of the reservoir which is in closest proximity to the drawdown mechanism.
  • Implementation of such horizontal pumping systems has created awareness of additional challenges and observations.
  • Wellbore traps are created by the varying elevations along the horizontal during the drilling program. Currently very little testing or logging in the horizontal wellbore is being done following the fracture stimulation and before the well is placed on production. However, instrumentation and spinner survey testing is demonstrating that wellbore productivity beyond the first wellbore trap is reduced or non-existent in many cases.
  • embodiments of the present invention comprise a method and system of lifting liquids associated with the production of natural gas from a wellbore which intersects a formation, the wellbore having a vertical section and a horizontal section.
  • This lift method comprises a form of gas injection and/or recirculation.
  • the efficiency of gas injection/re-circulation operations is impacted by a number of variables including, but not limited to, pipe sizing and selection, annular pressure maintenance, injection cycle timing, selected lifting mechanism, directional control of the injected gas, injected versus re-circulated lifting gas.
  • the overall recovery factor is also a consideration when deploying artificial lift recovery techniques.
  • the invention may comprise a system for producing fluids from a reservoir using a wellbore having a vertical section with a casing and a production tubing defining a wellbore annulus, and a horizontal section, the system comprising:
  • crossover valve wherein the crossover valve may be activated to open a bypass from the wellbore annulus through the isolation device
  • a siphon string in fluid communication with the production tubing and having at least one fluid inlet along its length, the siphon string defining an injection annulus with the liner in the horizontal section of the wellbore, wherein the injection annulus is closed to the reservoir except through the at least one production inlet.
  • the crossover valve is activated by a pressure in the wellbore annulus which is greater than a dome pressure of the crossover valve.
  • the crossover valve may be activated by a solenoid actuated or capillary supplied pressure source.
  • the siphon string comprises at least two segments separated by a one-way flow control device, and each segment has at least one fluid inlet.
  • the at least one fluid inlet comprises a gas lift valve.
  • the gas lift valve may be responsive to elevated pressure in the injection annulus to open and allow fluids to enter the siphon string, or may be activated by a solenoid actuated or capillary supplied pressure source.
  • the liner is a secondary liner, disposed within a primary liner, which is optionally cemented into the reservoir.
  • a primary liner which is optionally cemented into the reservoir.
  • the mono-bore and liner completion methods will be considered a primary liner in the horizontal section giving access to the well bore from the reservoir.
  • the system may further comprise a vertical lift system for lifting produced fluids to the surface, comprising a gas assisted plunger lift system, a tubing deployed gas lift system, a siphon string deployed internally to the vertical production tubing, an electric submersible pump, a progressive cavity pump, a reciprocating rod pump, a hydraulically actuated pump or a jet pump.
  • a vertical lift system for lifting produced fluids to the surface comprising a gas assisted plunger lift system, a tubing deployed gas lift system, a siphon string deployed internally to the vertical production tubing, an electric submersible pump, a progressive cavity pump, a reciprocating rod pump, a hydraulically actuated pump or a jet pump.
  • the system may further comprise a controller which is connected to each crossover valve and/or each gas lift valve to activate or vary each valve independently of other valves, wherein the controller is associated with a plurality of sensors obtaining and transmitting production data to the controller.
  • the invention may comprise a method of producing fluids from a reservoir using a wellbore having a vertical section having a wellbore annulus defined between a casing and a production tubing, and a horizontal section, the method comprising the steps of:
  • the crossover valve is passively activated by the injected gas pressure, or alternatively, the crossover valve is activated by a solenoid actuated pressure source.
  • the siphon string comprises at least two segments, each segment having at least one fluid inlet and at least one gas lift valve, and each gas lift valve is operated independently of the other gas lift valves.
  • the fluid is lifted to the surface by a lift solution comprising a gas assisted plunger lift system, a tubing deployed gas lift system, a siphon string deployed internally to the vertical production tubing, an electric submersible pump, a progressive cavity pump, a reciprocating rod pump, a hydraulically actuated pump or a jet pump.
  • a lift solution comprising a gas assisted plunger lift system, a tubing deployed gas lift system, a siphon string deployed internally to the vertical production tubing, an electric submersible pump, a progressive cavity pump, a reciprocating rod pump, a hydraulically actuated pump or a jet pump.
  • the siphon string comprises at least a heel segment and a toe segment, wherein each segment comprises a production inlet.
  • each segment is isolated from an adjacent segment by an isolation device in the annulus.
  • Each segment may comprise a fluid inlet.
  • Flow control devices may be disposed within the siphon string to prevent reverse flow.
  • each segment of the siphon string may comprise a flow through crossover valve, which may be activated by pressure in the injection annulus, or by direct activation. Upon activation, the crossover valve will permit injected gas in the injection annulus to enter the siphon string, to urge fluids towards the heel of the horizontal section.
  • the invention may comprise a method of producing fluids from a reservoir using a wellbore having a vertical section having a wellbore annulus defined between a casing and a production tubing, the method comprising the steps of:
  • the vertical lift mechanism utilized to bring production fluids to the surface may include a gas assisted plunger lift system, a tubing deployed gas lift system, a siphon string deployed internally to the substantially vertical tubing string, which tubing string may be equipped with a series of concentrically disposed gas lift valves integral to a coiled tubing or siphon string.
  • a suitable gas lift valve and system is described in Applicant's co owned US Patent Application no. 15/022,829, published as US20160230520A1, the entire contents of which are incorporated herein by reference, where permitted.
  • Other primary lifting mechanisms deployed into the substantially vertical wellbore segment may be utilized, including but not limited to, electric submersible pumps, progressive cavity pumps, reciprocating rod pumps, hydraulically actuated pumps or jet pumps.
  • one or more capillary lines may be used for transporting injection lift gas, permitting gravity separation in the wellbore annulus and delivering high quality liquids to the primary lift system intake.
  • the method comprises the use of liner production inlets which are equipped with sand control media to retain formation and fracture stimulation sands in the reservoir.
  • the method further comprises the steps of measuring, acquiring and processing downhole production information collected at selected locations in the horizontal section and in the vertical section, and adjusting injection rates in different sections or segments in the system. For example, if the horizontal section comprises a toe segment, an intermediate segment, and a heel segment, the injection rates into each segment may be adjusted to optimize the overall horizontal wellbore productivity.
  • the invention comprises a crossover valve which is integral to the production tubing string and preferably disposed nearest the deepest vertical depth of the well.
  • the crossover valve controls the injection and production cycle of the wellbore.
  • the invention comprises a crossover valve which is internal to the production tubing and retrievable through the production tubing and controls the injection and production cycle of the wellbore.
  • Figure 1A shows a schematic representation of a horizontal wellbore equipped with a gas recirculation completion where the wellbore annulus is divided between the substantially vertical section and the substantially horizontal section by an annulus pack off assembly.
  • the annulus pack-off assembly permits communication between the wellbore annulus and the horizontal recirculation annulus through the bypass ports. The communication is controlled by the crossover valve.
  • Figure 1B depicts the schematic representation of a horizontal wellbore equipped with a gas recirculation completion from Figure 1 A with the addition of a segmented siphon string.
  • Figure 1C shows the segmented siphon string of Figure 1B, with gas lift valves associated with each segment.
  • Figure 2 shows an active type crossover valve with variable dome pressure where the gas circulation process is actively controlled using an electric solenoid and the dome pressure may be varied using a regulator and capillary line from surface.
  • Figure 3 shows an active type crossover valve with a fixed dome pressure where the recirculation is actively initiated by a pressurized line from surface and opens the passage from the well annulus above the pack-off assembly to the re-circulation annulus in the substantially horizontal portion of the wellbore.
  • Figure 4 shows a passive type crossover valve with fixed dome pressure where the ambient static annular pressure activates the crossover valve and opens the path between the wellbore annulus above the packer to the re-circulation annulus in the substantially horizontal portion of the wellbore.
  • Figure 5 shows a transverse cross-section of one embodiment of a crossover valve, as used in the completion shown in Figure 1A.
  • Figure 6 is a schematic representation of a gas lift valve, configured for inline use in a siphon string, sectioned along its length to reveal all of the working components.
  • Figure 7 is a detailed view of area A shown in Figure 6, showing the power section valve assembly.
  • Figure 8 is a detailed view of area B of Figure 6, showing the pilot section valve assembly.
  • Figure 9 is a transverse cross-sectional view along line C-C in Figure 6.
  • Figure 10 is a cross sectional view of the crossover valve of Figure 2, shown with the pilot valve assembly in its open position.
  • Figure 11 is a cross sectional of the power section of the gas lift valve of Figure 6, shown with the power valve assembly in its open position.
  • Figure 12 is a cross sectional of the power section of the gas lift valve of Figure 6, shown with the RCV valve in its open position.
  • Figure 13 shows a vertical lift system (horizontally landed rod pump) which receives the output of a horizontal gas lift system of the present invention.
  • Figure 14 shows a schematic representation of a control system of one embodiment of the present invention.
  • the invention relates to a gas recirculation method and system for producing fluids from wellbores having a vertical section and a horizontal section.
  • all terms not defined herein have their common art-recognized meanings.
  • the horizontal section of a wellbore is that section which extends substantially horizontally into a formation or reservoir.
  • the wellbore may not be exactly horizontal overall, or in any given area, but will still be referred to as the horizontal section.
  • the vertical section need not be exactly vertical, but may be at an inclined angle.
  • the vertical section leads from the depth of the horizontal section to the surface.
  • the transitional section between the vertical section and the horizontal section may be curved with a substantially constant radius, or may include relatively linear sections at an inclined angle.
  • the production from the reservoir along the horizontal portion of the wellbore should ideally be proportional to the linear length of exposure to the reservoir.
  • the lack of proportionality between the linear footage and the productivity of the reservoir is directly associated with challenges related to transporting liquids along the length of the horizontal wellbore section.
  • FIG. 1A schematically shows an embodiment of the present invention.
  • the wellbore annulus (40) is sealed with an annular isolation device (53), referred to herein as a pack-off assembly, which seals against the wellbore casing (52) and the production tubing (54).
  • the pack-off assembly (53) is positioned at or near the deepest vertical point in the completion, however this completion may be placed anywhere in the transitional section, or even into the start of the horizontal section.
  • Adjacent to and above the annulus pack-off assembly (53) is a crossover valve (51), which is configured as described below and shown in the Figures.
  • the crossover valve (51) may generally of the type described in U.S. Patent Application No. 15/022,829, published as US20160230520A1, entitled “Crossover Valve System and Method for Gas Production", the entire contents of which are incorporated herein by reference, where permitted. Such valves are responsive to gas pressure to open a bypass port.
  • the crossover valve is configured with a pressure set point to facilitate the circulation of accumulated annulus gas, by way of bypass ports (55) through the annulus pack-off assembly.
  • the crossover valve (51) may comprise a pilot section open to the wellbore annulus and having a predetermined closing pressure, a power section, and a bypass valve to direct injected gas to the injection annulus (58) through the bypass ports (55) through the pack-off (53).
  • the production tubing (54) below the pack-off (53) is referred to herein as the siphon string.
  • the siphon string (54) may comprise coiled tubing or small jointed tubing.
  • the horizontal section of the wellbore has an outer annulus between the open-hole reservoir (62) and a liner (60), which may be a primary or a secondary liner.
  • the injection annulus (58) exists between the siphon string (54) and the liner (60).
  • the liner (60) is sealed to the reservoir (62), except for production inlets (59) as shown, which preferably include a one-way valve.
  • the production inlets (59) may preferably be equipped with sand control media to retain formation and fracture stimulation sands in the reservoir (62).
  • a production inlet 59
  • the liner (60) may be bonded in horizontal wellbore section with a cement sheath between the liner (60) and the horizontal open hole.
  • the liner (60) assembly may be suspended in the intermediate wellbore casing (52) and transits the horizontal wellbore section, as is shown in Figure 1A.
  • the liner may be a secondary liner (60) within an existing cemented or non- cemented liner (not shown) which is a primary liner, which has access to flow from reservoir sand face either selectively or throughout the horizontal length of the wellbore by means of perforations or fracturing ports.
  • Non-cemented existing liners would be primarily used to maintain well bore integrity with non-perforated or fractured natural flow into the primary liner.
  • the secondary liner (60) concentric within the primary liner is then closed to the reservoir except through a production inlet (59).
  • a plurality of production inlets (59) are strategically located and integral to the liner along the substantially horizontal segment of the wellbore.
  • Injection gas from the crossover valve (51) may enter the injection annulus (58) through the bypass ports (55). If the pressure in the injection annulus (58) is higher than the pressure inside the siphon string (54), liquids and gases in the injection annulus (58) will enter through a siphon check valve assembly (57) at the terminus of the siphon string (54). Fluids within the siphon string (54) then transit towards the heel (56) of the well.
  • the siphon string (54) is configured into one or more segments (81), wherein each segment is separated from an adjacent segment with a one-way flow control valve (82).
  • the terminal segment may comprise a terminal siphon check valve assembly (57A), and each siphon string segment may comprise a fluid inlet (57B), which may be configured with a one way check valve.
  • the top end (62) of a crossover valve (51) is a blind end, while a bottom sub (64) is adapted to pass through a pack-off element.
  • Gas from the well annulus (40) may enter through port (66) and through a secondary flow control barrier (68) which is internal to the valve assembly and then enter the annulus space by way of the bypass ports (55) through the annulus pack-off assembly (53).
  • the valve (51) is biased to a closed position by way of the pilot section which is energized by the pressurized dome and mechanical spring section (67). This section (67) is gas charged by way of the valve (65) in fixed dome pressure applications or controlled via capillary line (not shown) pressure in variable dome pressure applications.
  • each wellbore segment (81) may be furnished with either active or passive gas lift valves (10), each valve having either fixed or variable dome pressures.
  • active or passive gas lift valves (10) are generally similar in
  • FIG. 10 An exemplary gas lift valve (10) is shown schematically in Figures 6 to 9.
  • an exemplary gas lift valve assembly (10), configured for inline use comprises a number of inner tubular elements (11) assembled together to define an internal production flow path, and an outer housing (12).
  • inline use means that the gas lift valve has an inner bore, allowing for fluids to flow through the assembly, and may be installed inline within a siphon string.
  • valve assembly comprises a pilot section (13) and a power section (14), connected by an intermediate pup joint (16) defining an annular fluid passage (17).
  • valve assembly (10) is adapted to be run on wireline into the siphon string.
  • the valve may be an integral component of the siphon string.
  • the pilot section (13) comprises a concentric sliding pilot piston (18), a pilot valve seat (20) and an annulus pressure opening (22) in the outer housing (12).
  • the pilot piston (18) In its closed position, as shown in Figures 6 and 8, the downhole end of the pilot piston (18) is seated against valve seat (20), closing off the pup joint fluid passage (17) from external pressure.
  • the pilot piston (18) is appropriately sealed with seals which slide against the inner surface of the housing (12) and the outer surface of the inner tubing (11).
  • the pilot piston (18) is biased towards its closed position by a mechanical spring (26), or a gas spring (28), or a combination of a mechanical spring and a gas spring.
  • a pilot pressure chamber (28) is fdled with a gas, preferably an inert gas such as nitrogen, through a valve (24), and resists upward movement of the pilot piston (18).
  • a gas preferably an inert gas such as nitrogen
  • the external pressure in the injection annulus (58) required to activate the pilot section (13) must overcome the closing (dome) pressure, which is the sum of the gas pressure in the chamber of the gas spring (28) and the pressure exerted by the mechanical spring (26).
  • gas (G) is injected into the injection annulus (58) until the annular pressure is greater than the closing pressure.
  • the injected gas bears on the pilot piston (18) through the external pressure opening (22), and the pilot piston (18) is urged upwards as injected gas fdls the pilot chamber (23), until the external pressure equals the closing pressure exerted by the mechanical spring (26) and the gas spring (28).
  • the pilot piston (18) unseats, the injected gas in the pilot chamber (23) then travels through the pup joint fluid passage (17) and enters an activation chamber in the power section (14), bearing upon the power piston (30), which is also a sealed concentric sliding piston.
  • the power piston (30) is biased in a closed position by a mechanical spring (31).
  • the power piston (30) pushes against a mandrel (32) having a valve face (34) which is seated against an injection gas inlet (36) through the outer housing (12).
  • the injection gas inlet (36) may be provided in a circumferential groove (38) around the outer housing (12) which has an angled conical section.
  • the valve face (34) has a matching conical section which sealingly engages the injection gas inlet (36) when closed.
  • the injected gas has sufficient pressure to unseat the RC valve (50), and pass through crossover port (52) and enters the internal production flow path of the valve (10).
  • the RC valve (50) is biased closed by a mechanical spring (51) ( Figures 11 and 12), the force of which may be overcome by the injected gas pressure.
  • the RC valve (50) is shown seated (closed) in Figure 11 and unseated (open) in Figure 12.
  • valve face (34) seats on and closes the injection gas inlet (36).
  • the RC valve (50) will then close and the gas lift valve assembly (10) again isolates the siphon string (54) from the injection annulus (58).
  • the restrictive bypass (42) is always open, but provides sufficient resistance to gas flow to allow gas pressure from the pilot section (13) to open the power piston (30) through the activation passage, while allowing equalization within a reasonably short period of time, in one embodiment, in the order of a few minutes.
  • the valve assembly (10) will open an injection opening at annular pressures above the pilot section (13) closing pressure, and will begin a closing sequence when the annular pressure drops below the closing pressure.
  • the closing pressure of the pilot section (13) of the valve (10) is adjusted by adjusting the strength of the mechanical spring (26) and the gas spring (28), if both are used.
  • the selected closing pressure may be determined by considering the well depth, annulus volume available and gas/liquid ratios.
  • the gas spring (28) can be charged to a very high pressure during assembly of the valve assembly (10), before use in the field, and can then be adjusted to a desired pressure for the particular downhole conditions it will encounter before installation down hole.
  • the mechanical spring (26) provides a fixed closing pressure, while the gas spring (28) may provide a variable customizable closing pressure.
  • the gas spring (28) may be connected with gas capillary lines, a regulator, and a controller.
  • the gas spring (28) may thus be charged with gas to increase the pilot section (13) closing pressure, or gas may be discharged to decrease the pilot section (13) closing pressure, after installation, as desired.
  • a capillary line may be used to directly activate the power section (14), and a pilot section (13) may not be necessary.
  • the gas lift valve (10) comprises three actuating components, the pilot section, the power section and the RC valve (50), which interact by gas pressure and not physical linkage. External pressure causes the pilot section (13) to expose an activation chamber to the external pressure, thereby activating the power section (14), which opens an injection opening which then opens the RC valve (50).
  • the horizontal segment of the wellbore completion may be divided into two or more adjacent zones.
  • Figures 1A and 1B show two zones depicted as Zone A and Zone B, which are separated from the other by an outer annulus pack-off assembly (63).
  • Zone A has production communication from the reservoir (62) into a first compartment (61) while Zone B has production communication into a second compartment (71).
  • Fluids may migrate from the first and second compartments (61, 71) through production inlets (59) into the injection annulus (58).
  • Each production inlet (59) is preferably equipped with a check valve assembly to permit one-way fluid communication from reservoir into the injection annulus (58).
  • the crossover valve (51) may be passively or actively controlled.
  • the crossover valve (51) may have a fixed dome pressure and passively activated by the pressure provided by injected gas in the well annulus (40), energized by a pressurized gas source on surface.
  • the crossover valve (51) may be actively controlled.
  • the crossover valve (51) may be configured to control the gas recirculation process with an electronic control module (37) as depicted in Figure 2.
  • the electronic control module may be operatively connected to a surface controller, or may operate in accordance with its own internal logic.
  • the dome pressure in the pilot section of said crossover valve (51) may be adjusted (33) and the section activated by way of a solenoid actuated pressure source (41), thereby permitting active control over the injection pressures and process.
  • the broken line (35) schematically represents the pressure communication between the pressurized wellbore annulus (40) above the pack-off assembly (53) and the inlet port of the crossover valve assembly (51).
  • the crossover valve (51) with the control module in this embodiment actively controls the injected recirculation gas movement between the well annulus (40) and the injection annulus (58).
  • the crossover valve (51) may be configured with a fixed dome pressure and directly activated by a pressure source via capillary line (43) or the like, as shown in Figure 3. Direct activation of the pilot section then opens communication between the pressurized well annulus (40) above the annulus pack-off assembly (53) to the horizontal circulation annulus through the bypass ports (55). Accordingly, the crossover valve (51) may be opened directly, regardless of the pressure in the well annulus (40).
  • the crossover valve (51) may be activated, either passively or actively, to pressurize the injection annulus (58) with injection gas. This pressure causes the fluids to enter the siphon string (54) and be pushed toward the vertical section, where the fluids may then be lifted to the surface.
  • production information or data may be collected from sensors such as pressure, flow rate, and/or temperatures sensors (Sl, S2, S3) disposed at selected locations in the horizontal section and in the vertical section, and operatively connected to a controller.
  • Activation of the crossover valve (51) and/or any of the gas lift valves (10) and the injection rate into the injection annulus may then be scheduled intermittently, or triggered by suitable conditions in the system.
  • the controller may comprise a processor and memory, and may operate in accordance with its own internal logic, or may process user inputs, either directly or remotely to control the downhole components.
  • Each downhole valve may then be activated independently, to manage flow rates in each segment or section of the horizontal section independently. For example, all valves (10) may be operated in unison in appropriate conditions, or specific segments may be shut down while the others remain open, or be activated while the others remain shut.
  • a segmented siphon string (54) comprises multiple lift valves (10)
  • the injection rates in at least one of the transitional section, toe segment, intermediate segment, or heel segment may be independently adjusted to optimize the horizontal wellbore productivity.
  • Each of the multiple lift valves (10) are preferably actively controlled to adjust their dome pressure.
  • the lift valves (10) may be selectively opened in response to a given pressure in the injection annulus (58).
  • a horizontally landed rod pump (70) is configured with a fluidseeker (44) which receives and sorts multiphase flow from the siphon string.
  • the fluidseeker is generally of the type described in co-pending application PCT/CA2019/050301 entitled HORIZONTAL WELLBORE SEPARATION SYSTEM AND METHOD, filed on March 12, 2019, the entire contents of which are incorporated herein by reference, where permitted.
  • the fluidseeker (44) assembly is upstream from a wavebreaker or annulus pack off device (not shown).
  • the output (45) from the lift gas system enters and bypasses the fluidseeker (44) assembly internally and then exits to the annular space (48) where separation by retention time and gravity takes place and ultimately the high quality fluid is delivered to the lift system intake by way of the external intake (46) of the fluidseeker (44) assembly and the recovery flow tube (50) which is internal to the separator section.
  • references in the specification to "some embodiments”, “an embodiment”, etc., indicate that the embodiment described may include a particular aspect, feature, structure, or characteristic, but not every embodiment necessarily includes that aspect, feature, structure, or characteristic. Moreover, such phrases may, but do not necessarily, refer to the same embodiment referred to in other portions of the specification. Further, when a particular aspect, feature, structure, or characteristic is described in connection with an embodiment, it is within the knowledge of one skilled in the art to combine, affect or connect such aspect, feature, structure, or characteristic with other embodiments, whether or not such connection or combination is explicitly described. In other words, any element or feature may be combined with any other element or feature in different embodiments, unless there is an obvious or inherent incompatibility between the two, or it is specifically excluded.

Landscapes

  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Jet Pumps And Other Pumps (AREA)

Abstract

Cette invention concerne un système et un procédé de production de fluides à partir d'un réservoir à l'aide d'un puits de forage ayant une section verticale ayant un espace annulaire de puits de forage défini entre un tubage et une colonne de production, et une section horizontale. Ledit procédé comprend l'utilisation d'une vanne d'intercommunication et d'un dispositif d'isolation d'espace annulaire pour isoler l'espace annulaire du puits de forage. Une colonne perdue et une colonne de siphon s'étendant en dessous du dispositif d'isolation d'espace annulaire à travers la section horizontale du puits de forage ont des entrées de production et des entrées de fluide respectivement, la colonne perdue et la colonne de siphon définissant un espace annulaire d'injection fermé au réservoir sauf à travers les entrées de production. Du gaz est injecté dans l'espace annulaire de puits de forage et à travers une dérivation dans le dispositif d'isolation d'espace annulaire et dans l'espace annulaire d'injection. Le fluide est ainsi amené à pénétrer dans la colonne de siphon et à s'écouler dans la section horizontale vers la section verticale. La vanne d'intercommunication et les vannes d'extraction au gaz peuvent être activées de manière passive ou activées de manière active.
PCT/CA2019/051083 2018-08-07 2019-08-07 Production par recirculation de gaz à partir de puits de forage horizontaux WO2020028987A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US201862715680P 2018-08-07 2018-08-07
US62/715,680 2018-08-07

Publications (1)

Publication Number Publication Date
WO2020028987A1 true WO2020028987A1 (fr) 2020-02-13

Family

ID=69413869

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/CA2019/051083 WO2020028987A1 (fr) 2018-08-07 2019-08-07 Production par recirculation de gaz à partir de puits de forage horizontaux

Country Status (1)

Country Link
WO (1) WO2020028987A1 (fr)

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
RU2745806C1 (ru) * 2020-02-25 2021-04-01 Федеральное государственное бюджетное образовательное учреждение высшего образования "Уфимский государственный нефтяной технический университет" Автоматическое устройство для перепуска затрубного газа в колонну насосно-компрессорных труб

Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5103911A (en) * 1990-02-12 1992-04-14 Shell Oil Company Method and apparatus for perforating a well liner and for fracturing a surrounding formation
US20050103497A1 (en) * 2003-11-17 2005-05-19 Michel Gondouin Downhole flow control apparatus, super-insulated tubulars and surface tools for producing heavy oil by steam injection methods from multi-lateral wells located in cold environments
US7073594B2 (en) * 2000-03-02 2006-07-11 Shell Oil Company Wireless downhole well interval inflow and injection control
US9863414B2 (en) * 2011-12-15 2018-01-09 Raise Production Inc. Horizontal and vertical well fluid pumping system

Patent Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5103911A (en) * 1990-02-12 1992-04-14 Shell Oil Company Method and apparatus for perforating a well liner and for fracturing a surrounding formation
US7073594B2 (en) * 2000-03-02 2006-07-11 Shell Oil Company Wireless downhole well interval inflow and injection control
US20050103497A1 (en) * 2003-11-17 2005-05-19 Michel Gondouin Downhole flow control apparatus, super-insulated tubulars and surface tools for producing heavy oil by steam injection methods from multi-lateral wells located in cold environments
US9863414B2 (en) * 2011-12-15 2018-01-09 Raise Production Inc. Horizontal and vertical well fluid pumping system

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
RU2745806C1 (ru) * 2020-02-25 2021-04-01 Федеральное государственное бюджетное образовательное учреждение высшего образования "Уфимский государственный нефтяной технический университет" Автоматическое устройство для перепуска затрубного газа в колонну насосно-компрессорных труб

Similar Documents

Publication Publication Date Title
US8997870B2 (en) Method and apparatus for separating downhole hydrocarbons from water
US7455116B2 (en) Injection valve and method
US20200199987A1 (en) Crossover valve system and method for gas production
US9238953B2 (en) Completion method for stimulation of multiple intervals
US5865252A (en) One-trip well perforation/proppant fracturing apparatus and methods
US7665535B2 (en) Rigless one-trip system and method
US9739113B2 (en) Completions fluid loss control system
US8573310B2 (en) Gas lift apparatus and method for producing a well
US20130140040A1 (en) Downhole fluid recirculation valve
US10767456B2 (en) Methods and systems for recovering oil from subterranean reservoirs
WO2020028987A1 (fr) Production par recirculation de gaz à partir de puits de forage horizontaux
WO2014198887A1 (fr) Procédé de complétion et système de fond de trou
US11492880B2 (en) Gas operated, retrievable well pump for assisting gas lift
US9404350B2 (en) Flow-activated flow control device and method of using same in wellbores
EP2984278A1 (fr) Agencement et procédé d'extraction de débris d'un puits

Legal Events

Date Code Title Description
121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 19848702

Country of ref document: EP

Kind code of ref document: A1

NENP Non-entry into the national phase

Ref country code: DE

32PN Ep: public notification in the ep bulletin as address of the adressee cannot be established

Free format text: NOTING OF LOSS OF RIGHTS PURSUANT TO RULE 112(1) EPC (EPO FORM 1205 DATED 23.06.2021)

122 Ep: pct application non-entry in european phase

Ref document number: 19848702

Country of ref document: EP

Kind code of ref document: A1