Subsurface safety valve system and method
The well system includes a casing and production tubing and a control unit that can receive measurements of temperature and pressure of fluid in the tubing-casing annulus (TCA). A subsurface safety valve (SSSV) connected to the tubing can switch to an open or closed state in response to a change in pressure of the fluid. An expected thermal expansion or contraction of the TCA fluid is calculated based on the received measurements, and the control unit determines, based on the expected thermal expansion or contraction and on a calculated TCA volume, a volume necessary to be added to or released from the TCA to maintain the fluid within an optimal pressure range. The control unit can also receive an indication of an emergency condition and transmit a signal to activate a release valve to release from the TCA a volume of fluid sufficient to cause the SSSV to close.
1. A well system comprising:
a production tubing positioned within a casing within a wellbore, wherein an inner surface of the casing and an outer surface of the production tubing partially defines a tubing-casing annulus;
a subsurface safety valve connected to the production tubing and configured to selectively switch, in response to a change in pressure of a fluid in the tubing-casing annulus, between an open state in which produced fluid is permitted through the production tubing and a closed state in which produced fluid is prevented from flowing through the production tubing; and
a control unit comprising a non-transitory computer readable medium storing computer instructions executable by one or more processors to perform operations, the operations comprising:
receiving measurements of temperature and pressure of the fluid in the tubing-casing annulus;
calculating an expected thermal expansion or contraction of the fluid in the tubing-casing annulus based on the received measurements;
determining, based on the expected thermal expansion or contraction of the fluid in the tubing-casing annulus and on a calculated volume of the tubing-casing annulus, a volume of the fluid necessary to be added to or released from the tubing-casing annulus to maintain the fluid within an optimal pressure range in the tubing-casing annulus for normal operations in which the subsurface safety valve is in the open state;
receiving an indication of an emergency condition; and
transmitting, in response to the receipt of the indication of the emergency condition, a signal to activate a release valve to release, from the tubing-casing annulus, a volume of fluid sufficient to cause the subsurface safety valve to switch from the open state to the closed state.
2. The system of claim 1 , wherein the operations further comprise, in response to a determination by the control unit that an additional volume of fluid is necessary to maintain the fluid within the optimal pressure range in the tubing-casing annulus for normal operations, transmitting a signal to activate a pump to add the additional volume of fluid to the tubing-casing annulus.
3. The system of claim 2 , wherein the operations further comprise, in response to a determination by the control unit that a release of fluid is necessary to maintain the fluid within the optimal pressure range in the tubing-casing annulus, transmitting a signal to activate the release valve to release the fluid in a volume sufficient to maintain the fluid within the optimal pressure range.
4. The system of claim 3 , wherein the pump draws the additional volume from a tank disposed at the surface, and wherein the tank is configured to receive the fluid released from the tubing-casing annulus.
5. The system of claim 1 , wherein subsurface safety valve comprises:
a main body with a central bore therethrough, the central bore fluidically connected to the production tubing;
a closure member that permits fluid flow through the central bore when in an open position and that prevents fluid flow through the central bore when in a closed position, wherein the subsurface safety valve is in the open state when the closure member is in the open position and in the closed state when the closure member is in a closed position;
a pressure orifice through the main body having an outer end and an inner end, wherein the outer end is exposed to a pressure of fluid in the tubing-casing annulus;
a piston partially defining a piston chamber, the piston chamber fluidically connected to the inner end of the pressure orifice, the piston configured to move the closure member to the open position in response to an increase in pressure in the pressure chamber.
6. The system of claim 5 , wherein the piston is configured to allow movement of the closure member from the open position to the closed position in response to a decrease in the pressure of the fluid in the tubing-casing annulus.
7. The system of claim 5 , wherein a pressure of fluid in the piston chamber is equal to the pressure of the fluid in the tubing-casing annulus.
8. The system of claim 1 , wherein a downhole boundary of the tubing-casing annulus is defined by an upper surface of an annular production packer element.
9. The system of claim 1 , wherein the volume of fluid sufficient to cause the subsurface safety valve to switch from the open state to the closed state is determined based in part on the calculated expected thermal expansion or contraction of the fluid in the tubing-casing annulus based on the received measurements.
10. The system of claim 1 , wherein the calculating an expected thermal expansion or contraction of the fluid in the tubing-casing annulus based on the received measurements is in real-time with the received measurements.
11. A method, comprising:
receiving, by a control unit comprising a non-transitory computer readable medium storing computer instructions executable by one or more processors to perform operations, measurements of temperature and pressure of a fluid in a tubing-casing annulus defined by an inner surface of a casing positioned in a wellbore and an outer surface of a production tubing positioned within the casing, wherein a subsurface safety valve is connected to the production tubing and is configured to selectively switch, in response to a change in pressure of the fluid in the tubing-casing annulus, between:
an open state in which produced fluid is permitted through the production tubing; and
a closed state in which produced fluid is prevented from flowing through the production tubing;
calculating, by the control unit, an expected thermal expansion or contraction of the fluid in the tubing-casing annulus based on the received measurements;
determining, by the control unit and based on the expected thermal expansion or contraction of the fluid in the tubing-casing annulus and a calculated volume of the tubing-casing annulus, a volume of the fluid necessary to be added to or released from the tubing-casing annulus to maintain the fluid within an optimal pressure range in the tubing-casing annulus for normal operations in which the subsurface safety valve is in the open state;
receiving, by the control unit, an indication of an emergency condition; and
transmitting, by the control unit and in response to the receipt of the indication of the emergency condition, a signal to activate a release valve to release from the tubing-casing annulus a volume of fluid sufficient to cause the subsurface safety valve to switch from the open state to the closed state.
12. The method of claim 11 , further comprising transmitting, by the control unit and in response to a determination by the control unit that an additional volume of fluid is necessary to maintain the fluid within the optimal pressure range in the tubing-casing annulus for normal operations, a signal to activate a pump to add the additional volume of fluid to the tubing-casing annulus.
13. The method of claim 12 , further comprising transmitting, by the control unit and in response to a determination by the control unit that a release of fluid is necessary to maintain the fluid within the optimal pressure range in the tubing-casing annulus, a signal to activate the release valve to release the fluid in a volume sufficient to maintain the fluid within the optimal pressure range.
14. The method of claim 13 , wherein the pump draws the additional volume from a tank disposed at the surface, and wherein the tank is configured to receive the fluid released from the tubing-casing annulus.
15. The method of claim 11 , wherein subsurface safety valve comprises:
a main body with a central bore therethrough, the central bore fluidically connected to the production tubing;
a closure member that permits fluid flow through the central bore when in an open position and that prevents fluid flow through the central bore when in a closed position, wherein the subsurface safety valve is in the open state when the closure member is in the open position and in the closed state when the closure member is in a closed position;
a pressure orifice through the main body having an outer end and an inner end, wherein the outer end is exposed to a pressure of fluid in the tubing-casing annulus; and
a piston partially defining a piston chamber, the piston chamber fluidically connected to the inner end of the pressure orifice, the piston configured to move the closure member to the open position in response to an increase in pressure in the piston chamber.
16. The method of claim 15 , wherein the piston is configured to allow the closure member to move from the open position to the closed position in response to a decrease in the pressure of the fluid in the tubing-casing annulus.
17. The method of claim 15 , wherein a pressure of fluid in the piston chamber is equal to the pressure of the fluid in the tubing-casing annulus.
18. The method of claim 11 , wherein a downhole boundary of the tubing-casing annulus is defined by an upper surface of an annular production packer element.
19. The method of claim 11 , wherein the volume of fluid sufficient to cause the subsurface safety valve to switch from the open state to the closed state is determined based in part on the calculated expected thermal expansion or contraction of the fluid in the tubing-casing annulus based on the received measurements.
20. The method of claim 11 , wherein the calculating an expected thermal expansion or contraction of the fluid in the tubing-casing annulus is based on the received measurements is in real-time with the received measurements.