US20230323752A1

US20230323752A1 - Indexing injection valve, method, and system

Info

Publication number: US20230323752A1
Application number: US18/296,092
Authority: US
Inventors: John Burris
Original assignee: Baker Hughes Oilfield Operations LLC
Current assignee: Baker Hughes Oilfield Operations LLC
Priority date: 2022-04-06
Filing date: 2023-04-05
Publication date: 2023-10-12
Also published as: WO2023196393A1

Abstract

An indexing injection valve including a housing having a port therein, a valve member moveable within the housing, an indexer connected to the valve member, the indexer having positions where the valve member is locked open and locked closed, wherein when the valve member is in the closed position pressure uphole of the valve is fixed. A method for managing a fluid sequestration system including injecting fluid in a liquid state into a formation, maintaining pressure above a gas transition pressure, and closing an injection valve while still maintaining pressure of the injected fluid uphole of the injection valve above the gas transition pressure of the fluid. A system including the injection valve further including a barrier valve configured to receive the injection valve and automatically close upon retrieval of the injection valve.

Description

CROSS REFERENCE TO RELATED APPLICATIONS

This application claims the benefit of an earlier filing date from U.S. Provisional Application Ser. No. 63/327,991 filed Apr. 6, 2022, the entire disclosure of which is incorporated herein by reference.

BACKGROUND

In the fluid sequestration industry there is a ubiquitous desire to inject at pressures above a gas transition pressure for the fluid being injected, such as Carbon Dioxide, Hydrogen, etc. Injecting in the liquid phase is more efficient than injecting in the gaseous phase. Difficulties present themselves when the pressure in the formation into which the fluid is being sequestered are below the gas transition pressure since if gas transition occurs efficiency is lost. The transition itself could cause a rapid cooling effect (Joules Thompson Effect) which is deleterious to equipment. Gas transition can herald extreme low temperatures (−80° C.), ice formation, create flow path occlusion and other problems for equipment such as safety valves, injection valves, sliding sleeves, and surface valves/pumps. Generally, when pumping, the pressure is sufficient with a simple downhole orifice to create back pressure. However, when pumping is to be paused, pressure can drop precipitously in low pressure formations, which is likely to cause the issues noted above. The art would well receive alternative configurations and methods that avoid gas transition when pumping is to be paused.

SUMMARY

An embodiment of an indexing injection valve including a housing having a port therein, a valve member moveable within the housing, an indexer operatively connected to the valve member, the indexer having positions where the valve member is locked open and locked closed, wherein when the valve member is in the closed position pressure uphole of the valve is fixed.
An embodiment of a method for managing a fluid sequestration system including injecting fluid in a liquid state into a formation, maintaining pressure above a gas transition pressure for the injected fluid, and closing an injection valve while still maintaining pressure of the injected fluid uphole of the injection valve above the gas transition pressure of the fluid.
An embodiment of a system including the injection valve where the system further includes a barrier valve configured to receive the injection valve and automatically close upon retrieval of the injection valve.
An embodiment of a borehole system including a borehole in a subsurface formation, and an injection valve disposed in the borehole.

BRIEF DESCRIPTION OF THE DRAWINGS

The following descriptions should not be considered limiting in any way. With reference to the accompanying drawings, like elements are numbered alike:

FIG. 1 is a cross sectional view of an injection valve as disclosed herein;

FIG. 1A is an enlarged view of a portion of FIG. 1 ;

FIGS. 2-4 are enlarged views of an indexing portion of FIG. 1 illustrating J-slot positions;

FIG. 5 is the injection valve illustrated in FIG. 1 landed in a landing nipple and anchored therein;

FIG. 6 is a view of the injection valve in a barrier, the injection valve having shifted the barrier open during install;

FIG. 7 is the barrier of FIG. 6 in a closed position, the injection valve having been removed therefrom; and

FIG. 8 is a schematic view of a borehole system including the njection valve disclosed herein.

DETAILED DESCRIPTION

A detailed description of one or more embodiments of the disclosed apparatus and method are presented herein by way of exemplification and not limitation with reference to the Figures.
Referring to FIG. 1 , an indexing injection valve 10 is illustrated. Valve 10 comprises a housing 12 having a port 14 extending between an outside surface 16 of the housing 12 to an inside surface 18 of the housing 12. A seal 19 is disposed on the outside surface 16 of housing 12 in some embodiments to seal against a radially outwardly positioned tubular structure not shown in FIG. 1 , but could be, for example, a string in which the valve 10 is installed. A valve member 20 is disposed within the housing 12 and is longitudinally movable therein upon application of pressure from uphole of the valve 10. The valve member 20 includes an aperture 22 that extends from an outside surface 24 of the valve member 20 to an inside surface 26 of the valve member 20, the inside surface defining a tubular flow area 28. Referring to FIG. 1A, the valve member 20 further includes a sealing element (such as a protrusion, O-Ring, packing element) 30 that is configured and dimensioned to seal on surface 32 of housing 12 to form a fluid tight seal when the sealing element is positioned on the seal surface 32. In the seated position, fluid does not flow through the aperture 22, and valve 10 is closed. When the sealing element 30 is spaced from the seal surface 32 due to the valve member 20 being moved in a rightward direction in the drawings, fluid is free to flow from a space 36 outside of the through port 14 and through aperture 22 into the area 28 and downhole from there when in use.
Referring back to FIG. 1 and also to FIGS. 2-4 , an indexing portion 40 of the valve 10 includes an indexer 42 that in an embodiment may be a J-slot or similar construction that responds to longitudinal movement to rotate through positions associated with the valve member 20 being in open and closed positions. Indexer 40 further includes a biaser 44 that biases a plunger 46 toward the left of the drawing and a pilot piston 48. Pilot piston 48 must have a differential pressure thereacross to actuate the valve 10. The pressure across piston 48 pushes plunger 46 to the right in the figure compressing the biaser 44, which may in an embodiment be a spring such as, for example, a coil spring or a gas spring, thereby causing the indexer 42 to cycle. It is noted that pressure containment member 43, which may be simply a tight gap between components as illustrated or may be an actual seal between those components, which if a seal will support construction of the valve 10 to house an atmospheric chamber or other pressure chamber between seal 43, housing 12, valve member 20 and pilot piston 48.
In FIGS. 2-4 , various positions of the indexer 42 may be appreciated and also the positions of the valve member 20 during these shifting positions of the indexer 42. With the indexer in the position of FIG. 4 , the valve member 20 is in the open position and is locked there. Pumping pressure may be adjusted to desired pressure without the valve closing. Flow through valve 10 in this position is indicated by arrows 45 shown on FIG. 1 . In the position of FIG. 2 however, the valve member 20 is in the closed position and pressure uphole (left of the Figure) is easily maintained at a pressure above the gas transition pressure because there are no losses of pressure to the formation which may have a pressure lower than the gas transition pressure. FIG. 3 illustrates positions of components during a higher-pressure event that is applied to cause the shifting.
The system avoids difficulties in the prior art because the valve 10 may be actively opened and closed and hence the pressure on the portion of the string uphole of the valve 10 may be maintained at above the gas transition pressure and avoid the possibility of rapid cooling to extreme cool temperatures, ice formation or other damage associated with gas transition in the valve 10 itself or uphole thereof and pump systems are not required to maintain high pressures that in fact many existing pump systems would be unable to maintain.
Valve 10 is not flow rate dependent, also a benefit to the industry.
Referring to FIG. 5 , the valve 10 is illustrated in a landing nipple 50 that may be a part of a string in a borehole (not illustrated this figure but generically seen in FIG. 8 ). It will be appreciated that the valve 10 further includes an anchor 54 having a profile 56 that is received in a recess 58 of the nipple 50.
Referring to FIGS. 6 and 7 , the valve 10 is illustrated in a barrier 60 that is open when the valve 10 is inserted therein as in FIG. 6 and which barrier closes when the valve 10 is retrieved therefrom as in FIG. 7 . As illustrated, the barrier 60 could be a ball barrier system however other barriers such as flapper type and sliding sleeves could be utilized.
Referring back to FIG. 1 , some embodiments include an orifice 62 that ensures any inadvertent gas phase transition is more likely to occur downhole of the orifice 62 than uphole of the orifice 62. This protects the valve 10 from gas phase transition issues.
Referring to FIG. 8 , a borehole system 70 is illustrated schematically. The system 70 includes a borehole 72 in a subsurface formation 74. There may be a string 76 in the borehole 72. A valve 10 is disposed in the borehole 72.
Set forth below are some embodiments of the foregoing disclosure:
Embodiment 1: An indexing injection valve including a housing having a port therein, a valve member moveable within the housing, an indexer operatively connected to the valve member, the indexer having positions where the valve member is locked open and locked closed, wherein when the valve member is in the closed position pressure uphole of the valve is fixed.
Embodiment 2: The valve as in any prior embodiment wherein the indexer is a J-slot.
Embodiment 3: The valve as in any prior embodiment wherein the indexer further includes a pilot piston requiring a differential pressure thereacross to actuate the indexer.
Embodiment 4: The valve as in any prior embodiment wherein the indexer includes a spring.
Embodiment 5: The valve as in any prior embodiment wherein the indexer is responsive to excess pressure events to both open and close the valve member.
Embodiment 6: The valve as in any prior embodiment wherein the pressure events are at a pressure greater than a gas transition temperature of a liquid being injected through the valve.
Embodiment 7: The valve as in any prior embodiment wherein the valve member opens or closes a fluid pathway between an annular space about the housing and a space downhole of the valve.
Embodiment 8: The valve as in any prior embodiment wherein the valve includes no internal flow path extending uphole of the valve.
Embodiment 9: The valve as in any prior embodiment further including an anchor to anchor the valve in a tubing string.
Embodiment 10: The valve as in any prior embodiment wherein the valve member includes a seal that is sealed to the housing such that a pressure chamber is created between the pilot piston and the seal.
Embodiment 11: The valve as in any prior embodiment wherein the pressure chamber is an atmospheric pressure chamber.
Embodiment 12: The valve as in any prior embodiment further including a restriction downhole of the valve.
Embodiment 13: A method for managing a fluid sequestration system including injecting fluid in a liquid state into a formation, maintaining pressure above a gas transition pressure for the injected fluid, and closing an injection valve while still maintaining pressure of the injected fluid uphole of the injection valve above the gas transition pressure of the fluid.
Embodiment 14: The method as in any prior embodiment further including installing the valve in any prior embodiment into a borehole accessing the formation.
Embodiment 15: The method as in any prior embodiment further including landing the injection valve in a barrier valve that is open when the injection valve is present and closed when the injection valve is removed.
Embodiment 16: The method as in any prior embodiment further including anchoring the injection valve in a nipple.
Embodiment 17: A system including the injection valve as in any prior embodiment where the system further includes a barrier valve configured to receive the injection valve and automatically close upon retrieval of the injection valve.
Embodiment 18: The system as in any prior embodiment wherein the barrier valve is a ball valve.
Embodiment 19: A borehole system including a borehole in a subsurface formation, and an injection valve as in any prior embodiment disposed in the borehole.
The use of the terms “a” and “an” and “the” and similar referents in the context of describing the invention (especially in the context of the following claims) are to be construed to cover both the singular and the plural, unless otherwise indicated herein or clearly contradicted by context. Further, it should be noted that the terms “first,” “second,” and the like herein do not denote any order, quantity, or importance, but rather are used to distinguish one element from another. The terms “about”, “substantially” and “generally” are intended to include the degree of error associated with measurement of the particular quantity based upon the equipment available at the time of filing the application. For example, “about” and/or “substantially” and/or “generally” can include a range of ±8% or 5%, or 2% of a given value.
The teachings of the present disclosure may be used in a variety of well operations. These operations may involve using one or more treatment agents to treat a formation, the fluids resident in a formation, a borehole, and/or equipment in the borehole, such as production tubing. The treatment agents may be in the form of liquids, gases, solids, semi-solids, and mixtures thereof. Illustrative treatment agents include, but are not limited to, fracturing fluids, acids, steam, water, brine, anti-corrosion agents, cement, permeability modifiers, drilling muds, emulsifiers, demulsifiers, tracers, flow improvers etc. Illustrative well operations include, but are not limited to, hydraulic fracturing, stimulation, tracer injection, cleaning, acidizing, steam injection, water flooding, cementing, etc.
While the invention has been described with reference to an exemplary embodiment or embodiments, it will be understood by those skilled in the art that various changes may be made and equivalents may be substituted for elements thereof without departing from the scope of the invention. In addition, many modifications may be made to adapt a particular situation or material to the teachings of the invention without departing from the essential scope thereof. Therefore, it is intended that the invention not be limited to the particular embodiment disclosed as the best mode contemplated for carrying out this invention, but that the invention will include all embodiments falling within the scope of the claims. Also, in the drawings and the description, there have been disclosed exemplary embodiments of the invention and, although specific terms may have been employed, they are unless otherwise stated used in a generic and descriptive sense only and not for purposes of limitation, the scope of the invention therefore not being so limited.

Claims

What is claimed is:

1. An indexing injection valve comprising:

a housing having a port therein;

a valve member moveable within the housing;

an indexer operatively connected to the valve member, the indexer having positions where the valve member is locked open and locked closed, wherein when the valve member is in the closed position pressure uphole of the valve is fixed.

2. The valve as claimed in claim 1 wherein the indexer is a J-slot.

3. The valve as claimed in claim 1 wherein the indexer further includes a pilot piston requiring a differential pressure thereacross to actuate the indexer.

4. The valve as claimed in claim 1 wherein the indexer includes a spring.

5. The valve as claimed in claim 1 wherein the indexer is responsive to excess pressure events to both open and close the valve member.

6. The valve as claimed in claim 1 wherein the pressure events are at a pressure greater than a gas transition temperature of a liquid being injected through the valve.

7. The valve as claimed in claim 1 wherein the valve member opens or closes a fluid pathway between an annular space about the housing and a space downhole of the valve.

8. The valve as claimed in claim 1 wherein the valve includes no internal flow path extending uphole of the valve.

9. The valve as claimed in claim 1 further including an anchor to anchor the valve in a tubing string.

10. The valve as claimed in claim 3 wherein the valve member includes a seal that is sealed to the housing such that a pressure chamber is created between the pilot piston and the seal.

11. The valve as claimed in claim 10 wherein the pressure chamber is an atmospheric pressure chamber.

12. The valve as claimed in claim 1 further including a restriction downhole of the valve.

13. A method for managing a fluid sequestration system comprising:

injecting fluid in a liquid state into a formation;

maintaining pressure above a gas transition pressure for the injected fluid; and

closing an injection valve while still maintaining pressure of the injected fluid uphole of the injection valve above the gas transition pressure of the fluid.

14. The method as claimed in claim 13 further including installing the valve as claimed in claim 1 into a borehole accessing the formation.

15. The method as claimed in claim 14 further including landing the injection valve in a barrier valve that is open when the injection valve is present and closed when the injection valve is removed.

16. The method as claimed in claim 14 further including anchoring the injection valve in a nipple.

17. A system including the injection valve as claimed in claim 1 where the system further includes a barrier valve configured to receive the injection valve and automatically close upon retrieval of the injection valve.

18. The system as claimed in claim 17 wherein the barrier valve is a ball valve.

19. A borehole system comprising:

a borehole in a subsurface formation; and

an injection valve as claimed in claim 1 disposed in the borehole.