Tubing Pressure Balanced Operating System with Low Operating Pressure

Abstract

A control system for a subsurface safety valve features a control line from the surface leading to one side of an operating piston. The operating piston is exposed to tubing pressure and is in pressure balance from tubing pressure. The opposite end of the operating piston is exposed to a chamber in the housing of the subsurface safety valve and that chamber is open through a port to the surrounding annulus. The operating piston is coupled to the flow tube and a power spring so that pressure in the control line shifts the operating piston and the flow tube against the power spring to rotate the flapper open. Provisions for fail closed mode if certain seals fail are also made though a passage extending from between seals near the upper end of the operating piston to the chamber open to the annulus.

Description

FIELD OF THE INVENTION

The field of this invention is control systems for downhole tools and more specifically control systems that operate through a control line running parallel to a tubular string where the downhole tool is a subsurface safety valve.

BACKGROUND OF THE INVENTION

Subsurface safety valves (SSV) are employed in most wells to prevent uncontrolled flow to the surface. They generally comprise a valve member, known as a flapper, which pivots under the assistance of a torsion spring mounted to the pivot shaft for the flapper. The flapper is urged into the open position by the movement of a hollow tube, known as a flow tube, against it. The downward flow tube movement rotates the flapper against the torsion spring and turns the flapper 90 degrees as the flow tube advances downhole in front of the flapper. In this position, the SSV is open and flow toward the surface is enabled. Normally, the flow tube is moved against the bias of a closure spring to get the flapper to the open position. A control line from the surface that runs parallel to the string and in the surrounding annular space is the source of hydraulic pressure to an operating piston which is operatively engaged to the flow tube. When pressure in the control line is applied the operating piston is urged to move and takes the flow tube with it against the bias of the closure spring as the flapper is pushed into the open position behind the flow tube. If the control line pressure is released the stored energy in the closure spring biases the flow tube away from the flapper to allow the pivot torsion spring on the flapper to move it against a seat to close off flow from downhole. This is the basic flapper valve operation.

Over the years, various developments in control systems have been developed. Some are focused on making sure the flapper closes in the event there is a seal failure in one or more of the system seals or even ruptures of the tubular string and the associated control line. One example of this is U.S. Pat. No. 6,866,101 taking FIG. 5 for example. What is shown there are a control line to one side of the piston and another balance line going back to the surface from the opposite side of the piston. The piston is designed to be in pressure balance from tubing pressure at seals 24 and 28. The piston 10 is normally in hydrostatic pressure balance from the dual control lines to the surface 12 and 14. However, if the tubing and only control line 12 breaks, the annulus pressure builds on top of piston 10 without an offsetting pressure buildup on the opposite side of piston 10. This can result in a fail open mode so the floating piston attached to line 14 can allow the now very much higher annulus pressure to the back side of piston 10 to allow the valve to close. Those skilled in the art will appreciate that there are costs and risks attendant to using a balance line in a hydraulic control system when trying to anticipate various failure modes and ensuring that the safety valve will fail closed. For one thing, running a second control line as a balance line requires additional cost and actual space in the wellbore to fit it in. Apart from these factors, there is the risk of failure and the need to add additional features, as illustrated in this patent to compensate for the variety of failure modes that can occur. An earlier version of this control system that did not account for all potential failure modes can be seen in U.S. Pat. No. 6,173,785.

Other designs have communicated the back side of an operating piston to the annulus as shown in U.S. Pat. No. 6,988,556. However, this feature was in context of isolating the operating piston totally from tubing pressure and transmitting force to a flow tube from an operating piston so isolated by magnetic force. Doing this required two closure springs to account for issues that could arise unique to the use of magnetic force to drive a flow tube from an operating piston.

What is needed and provided by the present invention is a control system featuring an operating piston that is exposed to tubing pressure and in pressure balance from the tubing pressure. The operating piston has a reference pressure on the other side of the operating piston to the annular space preferably through a port communicating the annulus to a chamber in the tool housing in fluid communication with the back side of the operating piston. These and other aspects of the present invention will be more apparent to those skilled in the art from a review of the description of the preferred embodiment and the associated drawings while recognizing that the full scope of the invention is defined by the appended claims.

SUMMARY OF THE INVENTION

A control system for a subsurface safety valve features a control line from the surface leading to one side of an operating piston. The operating piston is exposed to tubing pressure and is in pressure balance from tubing pressure. The opposite end of the operating piston is exposed to a chamber in the housing of the subsurface safety valve and that chamber is open through a port to the surrounding annulus. The operating piston is coupled to the flow tube and a power spring so that pressure in the control line shifts the operating piston and the flow tube against the power spring to rotate the flapper open. Provisions for fail closed mode if certain seals fail are also made through a passage extending from between seals near the upper end of the operating piston to the chamber open to the annulus.

BRIEF DESCRIPTION OF THE DRAWING

FIG. 1 is a half section view of the control system showing a flapper in the closed position.

DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENT

A control line 1 is connected to the housing 12 of a subsurface safety valve S shown in half section. As is typical for subsurface safety valves (SSV) there is a flow tube 10 whose downward movement opens a flapper 8. Downward movement of the flow tube 10 compresses a power spring 9. As long as there is pressure in chamber 2 from control line 1 the operating piston 14 will be displaced down from the position shown in FIG. 1 and the flapper 8 will be rotated 90 degrees from the position shown and the flow tube 10 will be in front of it so that production can occur through the SSV S. Similarly, removal of pressure in the control line 1 will allow power spring 9 to shift the flow tube 10 up so that the flapper 8 can be rotated against a seat (not shown) within housing 12. In the position shown in the FIG. 1, no flow from downhole can pass through the flow tube 10.

Seals 4 and 6 surround operating piston 14 and are preferably of the same size or nearly the same size so as to put the piston 14 in pressure balance from tubing pressure found in zone 16 within the valve housing 12. Seal 6 separates annulus pressure in chamber 7 from tubing pressure in zone 16. Chamber 7 has a port 18 that is open to the surrounding annulus 20. Seal 3 separates pressure in control line 1 from the annulus 20 pressure found between seals 3 and 4. Annulus 20 pressure gets between seals 3 and 4 through passage 22 that extends from chamber 7 through the piston 14 and out the side of piston 14 between seals 3 and 4.

If seal 3 fails, pressure in control line 1 will dissipate into the annulus 20 through passage 22, chamber 7 and port 18 depending on the size of port 18. If the port 18 is fairly small and the leak past seal 3 is fairly significant, then the pressure in control line 1 will equalize with chamber 7 on the other side of the piston 14 and that will allow the power spring 9 to push up the flow tube 10 to let the flapper 8 go to the closed position. If the control line 1 pressure falls, because of a leak in seal 3, to the point that it close to matches the pressure in annulus 20, then the power spring will push the flow tube 10 up to let the valve S close because there would not be any net force on the operating piston 14. If annulus pressure 20 is higher than control line pressure 2, failure of seal 3 will cause pressures in chambers 7 and 2 to equalize and valve will close.

If seal 6 fails, the tubing pressure at 16 will communicate with the annulus 20. If this happens, there will be pressure balance between seals 4 and 6 due to passage 22. From the tubing side there will be an upward force on piston 14 at seal 3 to force piston 14 up to close the flapper 8. However, depending on the size of the leak and the size of port 18 and the pressure difference between tubing pressure at 16 and annulus pressure 20 it is possible to pressurize chamber 7 with tubing pressure leaking into it to push up the piston 14 so that the flapper 8 closes. The surface signal of this condition could be an increasing annulus pressure 20 pressure over time and the control pressure to hold the valve open will increase. On the other hand, if the pressure in the annulus 20 is higher than tubing pressure at 16 when seal 6 fails, the flapper 8 will stay open as long as pressure is maintained in the control line 1. Over time a pressure loss in the annulus 20 may serve as an indicator that seal 6 has failed causing the ESD system to remove pressure from the safety valve thus closing the flapper 8.

If seal 4 fails then seals 3 and 6 will be in pressure balance from the tubing side. Similarly if seal 6 fails, seals 3 and 4 will be in pressure balance from the tubing side due to line 22. Depending on the size of port 18 and whether the pressure in the annulus 20 is higher or lower than tubing pressure at 16, there could be different outcomes. If tubing pressure at 16 exceeds annulus pressure at 20 and port 18 acts as a restriction, then pressure will build up in chamber 7 and create a net upward force on piston 14 to close the valve S. If port 18 is not restrictive under the previous scenario, tubing pressure will escape to the annulus 20 and slowly build its pressure to a point where chamber 7 will rise in pressure and piston 14 will be pushed up with that pressure and power spring 9 upon removal of control pressure. On the other hand, if annulus 20 pressure exceeds the tubing pressure at 16 when seal 4 fails and the valve S is open, the valve will stay open and the annulus 20 will depressurize at some rate into the valve S through line 22 until that condition is sensed within the ESD system. At that point, the ESD system will release control pressure thereby closing the flapper 8.

Those skilled in the art will appreciate the simplicity of the design which allows elimination of a balance line to the surface but still allows taking advantage of the annulus pressure to act in tandem with power spring 9 to urge the piston 14 to a closed position. Depending on the application it may still be advantageous to size the spring 9 to handle the full hydrostatic pressure in control line 1 in the event that annulus pressure 20 gets reduced by high pressure gas within the tubing 16 leaking into the annulus 20 through seals 4 or 6 and temporarily decreasing annulus pressure 20 (by replacing annulus liquid with gas, for example) that may be needed to move the piston 14 along with the force from spring 9. Alternatively, if annulus pressure change is noticed at the surface, the pressure in control line 1 can be removed to let the valve S close even under a leak condition as explained above. Accordingly, the spring 9 can also be sized to offset the net difference in control line 1 hydrostatic and annulus 20 hydrostatic and made a bit stronger to account for seal friction acting on piston 14. Taking annulus pressure into account, it is possible to design the spring 9 to move the piston 14 to the closed position of valve S with a force approximating the hydrostatic pressure less the expected annulus pressure.

This design presents a piston 14 that operates in pressure balance from tubing pressure at 16 while eliminating the expense and risk of a second balance control line. In some applications, there may not be room in the wellbore for such a second control line.

Redundant systems can be provided that involve the described control system where the pistons are each linked to a flow tube with each system, when placed in service operating as described above. The redundant system not in use can be isolated to shield the hydrostatic pressure in that control line from adding to the force the closure spring needs to overcome to get the flow tube to move up.

The above description is illustrative of the preferred embodiment and many modifications may be made by those skilled in the art without departing from the invention whose scope is to be determined from the literal and equivalent scope of the claims below.

Claims

1. A control system for control of a component of a downhole tool, said tool defining an annulus around it when disposed downhole, comprising:

an actuating piston, sealingly mounted using at least one seal in a housing, one of said piston or said housing being operably connected to the component;

a control line from said housing to the well surface, said control line in fluid communication with a first end of said piston;

said second end of said piston in fluid communication the annulus.

2. The system of claim 1, wherein:

said component comprises a flow tube in a subsurface safety valve;

said piston is operably connected to the flow tube;

said seals putting said piston in pressure balance to pressures within said housing.

3. The system of claim 2, further comprising:

a biasing member acting on said piston;

said piston movable from a first position under the bias of said biasing member, where the SSV is closed, to a second position where the force from said biasing member is overcome by applied pressure in said control line to open the SSV.

4. The system of claim 2, further comprising:

said housing defines an opening through which said piston is operably connected to the flow tube;

said piston comprising a passage therein to direct leakage flow therethrough in the event of failure of at least one of said seals.

5. The system of claim 4, wherein:

said piston comprises a pair of spaced seals adjacent said first end and at least one seal adjacent said second end;

said passage extends from between said spaced seals to said second end of said piston.

6. The system of claim 5, wherein:

said biasing member comprises a spring or other stored energy source which exerts a force on said piston toward said piston's first position which exceeds the hydrostatic force in said control line less the hydrostatic force in the annulus and plus the weight and frictional forces acting on or through said piston.

7. The system of claim 5, wherein:

said piston comprises a rod piston;

said biasing member comprises a return spring which can be overcome with an applied pressure in said control line of less than the hydrostatic pressure in said control line.

8. A method of controlling a downhole tool which is disposed in a well to define an annulus around it and having an internal component actuated by a piston, comprising:

mounting said piston in a housing, said housing having a passage therethrough;

operatively connecting said piston to the internal component disposed in said passage;

providing seals in contact with said piston that are exposed to pressure in said passage;

actuating said piston to move in a first direction by a control line from the surface;

offsetting the hydrostatic forces on said piston from said control line with an opening in said housing putting an opposite end of said piston in fluid communication to the annulus.

9. The method of claim 8, comprising:

providing a leak path through said piston to the annulus;

directing leakage from said passage and past said seals to said leak path.

10. The method of claim 9, further comprising:

providing a pair of spaced seals in contact with said piston above an access opening to said passage, with one being uppermost and the other, lowermost;

running said leak path from between said spaced seals to a lower end of said piston in communication with the annulus;

providing a lower seal on said piston below said access opening and above a lower end of said piston.

11. The method of claim 10, further comprising:

providing a return spring acting on said piston to bias it toward a position to move said internal component;

sizing said return spring to overcome hydrostatic forces in said control line and weight and frictional forces acting on or through said piston minus the pressure in the annulus.

12. The method of claim 9, further comprising:

installing the downhole tool in a well where the fluids passing through said passage are at a greater pressure than hydrostatic pressure in the annulus;

using said leak path as part of the configuration which allows failure of at least one of said seals to put said piston in a position where the internal component closes said passage.

13. The method of claim 9, further comprising:

pressure-balancing said piston with respect to pressures in said passage;

forming said piston as a rod piston;

using said leak path to allow said piston to move to a position where the internal component closes said passage in situations where at least one of said seals leaks.

14. The method of claim 10, further comprising:

allowing control line pressure to equalize to the annulus if the uppermost of said spaced seals fails.

15. The method of claim 14, further comprising:

allowing said piston to move to a position where the internal component closes said passage if said control line leaks into the surrounding annulus.

16. The method of claim 15, further comprising:

allowing said piston to move to a position where the internal component closes said passage if fluid from the annulus leaks past at least one seal due to annulus pressure being higher than pressure in said housing.

17. The method of claim 14, further comprising:

allowing the internal component to close said passage as control line pressure leaks past said uppermost seal through said leak path to equalize pressure on said piston.

18. The method of claim 16, further comprising:

sizing said spring so that said piston can be shifted to open said passage with said component with a force less than the hydrostatic pressure in said control line.

19. The method of claim 8, comprising:

making the downhole tool a subsurface safety valve and the internal component an assembly of a flow tube moving a flapper in said passage.