DUAL STRING GAS INJECTION SYSTEM WITH FLOW CONTROL

Abstract

A gas lift system improves the recovery of petroleum fluids from a well to the surface through production tubing. The gas lift system has a packer and a lower injection mandrel connected to the production tubing below the packer. The gas lift system further includes a gas lift module connected to the production tubing above the packer, and an injection line that carries pressurized gas from the surface to both the lower injection mandrel and the gas lift module. An upper injection line valve assembly is configured to provide a source of pressurized gas from the injection line to the gas lift module, while an injection line gas lift valve assembly is configured to provide a source of pressurized gas from the injection line to the lower injection mandrel.

Claims

1. A gas lift system for improving the recovery of petroleum fluids from a well to the surface through production tubing, the gas lift system comprising: a packer, wherein the production tubing extends through the packer; a lower injection mandrel connected to the production tubing, wherein the lower injection mandrel is located below the packer; an injection line that carries pressurized gas from the surface to the lower injection mandrel; and an injection line gas lift valve assembly connected to the injection line, wherein the injection line gas lift valve assembly comprises: a seating module; and a flow metering device removably captured within the seating module.

2. The gas lift system of claim 1, wherein the flow metering device is an inline gas lift valve.

3. The gas lift system of claim 2, wherein the injection line gas lift valve assembly further comprises a flow control device.

4. The gas lift system of claim 1, wherein the lower injection mandrel further comprises: an internal injection passage connected to the injection line; and an internal production passage connected to the production tubing.

5. The gas lift system of claim 4, wherein the internal injection passage is laterally offset from the internal production passage.

6. The gas lift system of claim 1, wherein the lower injection mandrel further comprises a sliding sleeve that is configured to selectively deploy to block the movement of fluids between the injection line and the lower injection mandrel.

7. The gas lift system of claim 1, further comprising a gas lift module above the packer, wherein the gas lift module includes a side pocket mandrel.

8. The gas lift system of claim 7, further comprising an upper injection line valve assembly that is configured to provide a source of pressurized gas into the side pocket mandrel of the gas lift module.

9. A gas lift system for improving the recovery of petroleum fluids from a well to the surface through production tubing, the gas lift system comprising: a packer, wherein the production tubing extends through the packer; a lower injection mandrel connected to the production tubing, wherein the lower injection mandrel is located below the packer; a gas lift module connected to the production tubing above the packer, wherein the gas lift module includes a side pocket mandrel; and an injection line that carries pressurized gas from the surface to the lower injection mandrel and the side pocket mandrel of the gas lift module.

10. The gas lift system of claim 9 further comprising an injection line gas lift valve assembly connected to the injection line, wherein the injection line gas lift valve assembly comprises: a seating module; and a flow metering device removably captured within the seating module.

11. The gas lift system of claim 10, wherein the flow metering device is an inline gas lift valve.

12. The gas lift system of claim 10, wherein the injection line gas lift valve assembly is integrated into the packer.

13. The gas lift system of claim 10, wherein the injection line gas lift valve assembly is positioned above the packer.

14. The gas lift system of claim 10, wherein the injection line gas lift valve assembly is positioned below the packer.

15. The gas lift system of claim 9, wherein the lower injection mandrel further comprises a sliding sleeve that is configured to selectively deploy to block the movement of fluids between the injection line and the lower injection mandrel.

16. The gas lift system of claim 9, further comprising an upper injection line valve assembly that is configured to provide a source of pressurized gas into the side pocket mandrel of the gas lift module.

17. A gas lift system for improving the recovery of petroleum fluids from a well to the surface through production tubing, the gas lift system comprising: a packer, wherein the production tubing extends through the packer; a lower injection mandrel connected to the production tubing, wherein the lower injection mandrel is located below the packer; a gas lift module connected to the production tubing above the packer, wherein the gas lift module includes a side pocket mandrel; an injection line that carries pressurized gas from the surface to the lower injection mandrel and the side pocket mandrel of the gas lift module; an upper injection line valve assembly that is configured to provide a source of pressurized gas into the side pocket mandrel of the gas lift module; and an injection line gas lift valve assembly connected to the injection line.

18. The gas lift system of claim 17, wherein the injection line gas lift valve assembly comprises: a seating module; and a flow metering device removably captured within the seating module.

19. The gas lift system of claim 17, wherein the lower injection mandrel further comprises: an internal injection passage connected to the injection line; and an internal production passage connected to the production tubing.

20. The gas lift system of claim 19, wherein the internal injection passage is laterally offset from the internal production passage.

Description

BRIEF DESCRIPTION OF THE DRAWINGS

[0011] FIG. 1 is a side view of a first embodiment of a gas lift system deployed in a conventional well in which the injection line gas lift valve assembly is located above the packer.

[0012] FIGS. 2A and 2B are cross-sectional views of the injection line gas lift valve assembly depicting the operation of the flow control device.

[0013] FIG. 3 is a side view of a second embodiment of a gas lift system deployed in a conventional well in which the injection line gas lift valve assembly is located below the packer.

[0014] FIG. 4 is a side view of a third embodiment of a gas lift system deployed in a conventional well in which the injection line gas lift valve assembly is located within the packer.

WRITTEN DESCRIPTION

[0015] As used herein, the term “petroleum” refers broadly to all mineral hydrocarbons, such as crude oil, gas and combinations of oil and gas. The term “fluid” refers generally to both gases and liquids, and “two-phase” or “multiphase” refers to a fluid that includes a mixture of gases and liquids. “Upstream” and “downstream” can be used as positional references based on the movement of a stream of fluids from an upstream position in the wellbore to a downstream position on the surface. Although embodiments of the present invention may be disclosed in connection with a conventional well that is substantially vertically oriented, it will be appreciated that embodiments may also find utility in horizontal, deviated or unconventional wells.

[0016] Turning to FIG. 1, shown therein is a gas lift system 100 disposed in a well 102. The well 102 includes a casing 104 and a series of perforations 106 that admit wellbore fluids from a producing geologic formation 108 through the casing 104 into the well 102. An annular space 110 is formed between the gas lift system 100 and the casing 104. The gas lift system 100 is connected to production tubing 112 that conveys produced wellbore fluids from the formation 108, through the gas lift system 100, to a wellhead 114 on the surface. In most installations, the production tubing 112 extends through a packer 116 or other zone isolation device to an area of the well 102 near the perforations 106.

[0017] The gas lift system 100 also includes an injection line 118 that extends from the surface through the wellhead 114 to a lower injection mandrel 120. The lower injection mandrel 120 can be positioned below the packer 116, within the packer 116, or above the packer 116. To accommodate the production tubing 112 and the injection line 118, the packer 116 is configured to provide two separated flow paths through the packer 116. One suitable device for use as the packer 116 is the Baker Hughes Parallel Head, which is available commercially from Baker Hughes Company of Houston, Tex. This type of parallel flow device is typically used for gas lift production operations.

[0018] The lower injection mandrel 120 is configured for connection to both the production tubing 112 and the injection line 118. The lower injection mandrel 120 includes an internal injection passage 121 that is joined to an internal production passage 123 that extends through the primary longitudinal axis of the lower injection mandrel 120. The internal production passage 123 is connected to the production tubing 112 or an intermediate conduit between the lower injection mandrel 120 and the production tubing 112. The internal injection passage 121 is laterally offset from the internal production passage 123 and is connected to the injection line 118.

[0019] The injection passage 121 transfers the pressurized gas from the injection line 118 to the wellbore fluid within the internal production passage 123. A sliding sleeve 122 or other flow control device can be located inside the lower injection mandrel 120 to selectively close or block the internal injection passage 121 from the internal production passage 123. When deployed, the sliding sleeve 122 prevents the exchange of fluids through the lower injection mandrel 122 by blocking wellbore fluids from entering the injection line 118 and also preventing pressurized gases in the injection line 118 from entering the production tubing 112.

[0020] The gas lift system 100 includes an injection line gas lift valve assembly 124 that is connected in line with the injection line 118. The injection line gas lift valve assembly 124 can be connected between adjacent sections of the injection line 118 above the packer 116 (FIG. 1), below the packer 116 (FIG. 3), or within the packer 116 (FIG. 4). In some embodiments, the injection line gas lift valve assembly 124 is connected directly to the internal injection passage 121 of the lower injection mandrel 120.

[0021] As illustrated in FIGS. 2A and 2B, the injection line gas lift valve assembly 124 includes a seating module 126 and a flow metering device 128. The flow metering device 128 is configured to throttle or regulate the flow of pressurized gas through the injection line 118. In some embodiments, the flow metering device 128 is a standard, inline gas lift valve that is configured to selectively permit the flow of pressurized gas through the injection line gas lift valve assembly 124. In some applications, the flow metering device 128 is configured to open when a threshold pressure gradient is established across the flow metering device 128. In other applications, the flow metering device 128 is electronically actuated. In yet other applications, the flow metering device 128 is an orifice or other device that presents a constant reduction of the pressure in the injection line 118.

[0022] The seating module 118 can be a landing nipple, latch or other setting assembly with an internal seal profile that matches the configuration of the flow metering device 128. This allows the flow metering device 128 to be securely and removably locked into position within the injection line 118 using standard, commercially available setting assemblies. Suitable seating modules 118 include the SureSet and Select brand setting assemblies available from Baker Hughes Company of Houston, Tex. The ability to use the standardized seating module 118 greatly facilitates the installation and removal of the flow metering device 128 and other components within the injection line gas lift valve assembly 124.

[0023] The injection line gas lift valve assembly 124 optionally includes a flow control device 130. The flow control device 130 can be a check valve (as depicted in FIGS. 2A and 2B), or a selectively actuated choke that prevents the backflow of fluids from the lower injection mandrel 120 into the injection line gas lift assembly 124. The inclusion of the flow control device 130 facilitates the removal of the flow metering device 128 for exchange or repair. For example, in FIG. 2A, the injection line gas lift valve assembly 124 is depicted in a normal mode of operation in which gas is passing through the flow metering device 128 and the flow control device 130. In FIG. 2B, the flow control device 130 is closed to prevent the backflow of fluids from the lower injection mandrel 120 and the flow metering device 128 is being removed from the injection line gas lift valve assembly 124.

[0024] The injection line gas lift valve assembly 124 provides several advantages over prior art systems in which the injection line is connected directly to gas lift modules within internal gas lift valves housed inside pocket mandrels. Combining a standard gas lift valve or other flow metering device 128 with a conventional seating module 126 facilitates the installation and removal of the flow metering device 128 using conventional tools. Unlike typical gas lift systems, a kickover tool is not needed to retrieve a gas lift valve from a laterally offset side pocket mandrel. Additionally, the placement of the gas lift valve or other flow metering device 128 within the injection line gas lift valve assembly 124 rather than the conventional side pocket mandrel permits the use of larger gas lift valves, which are capable of larger throughput.

[0025] In operation, pressurized fluids or gases are injected from the surface through the injection line 118 and injection line gas lift valve assembly 124 to the lower injection mandrel 120. In accordance with well-established gas lift principles, when the pressure gradient across the flow metering device 128 exceeds a threshold value, the pressurized gases are admitted into the production tubing 112 through the injection line gas lift valve assembly 124 and lower injection mandrel 120. The pressurized gases combine with the produced fluids in the lower injection mandrel 120 to reduce the overall density of the fluid, which facilitates the recovery of the produced fluids from the well 102. The gas lift system 100 may find utility in recovering liquid and multiphase hydrocarbons, as well as in unloading water-based fluids from the well 102.

[0026] As depicted in FIG. 4, in some embodiments, the gas lift system 100 may also include a conventional gas lift module 132 that has a side pocket mandrel 134. In these embodiments, the gas lift system 100 can include one or more upper injection line valve assemblies 136 that are configured to also provide a path for pressurized gases to directly enter into the side pocket mandrel 134. In these embodiments, a connector 138 conduit extends between a gas discharge in the upper injection line valve assembly 136 and a gas intake of the side pocket mandrel 134 of the conventional gas lift module 132. The upper injection line valve assembly 136 can be configured with a diverter valve that opens when exposed to a pressure gradient that exceeds a threshold opening pressure to direct pressurized gas into the gas lift module 132 instead of, or in addition to, the lower injection mandrel 120. In other applications, a conventional gas lift valve within the side pocket mandrel 134 can be configured to control the inflow of pressurized gases from the injection line 118. In these embodiments, the upper injection line valve assembly includes a branched delivery system that provides pressurized gases to both the upper gas lift module 132 and the lower injection mandrel 120.

[0027] It is to be understood that even though numerous characteristics and advantages of various embodiments of the present invention have been set forth in the foregoing description, together with details of the structure and functions of various embodiments of the invention, this disclosure is illustrative only, and changes may be made in detail, especially in matters of structure and arrangement of parts within the principles of the present invention to the full extent indicated by the broad general meaning of the terms in which the appended claims are expressed. It will be appreciated by those skilled in the art that the teachings of the present invention can be applied to other systems without departing from the scope and spirit of the present invention.