Pressure response test to detect leakage of rotating control device
A method includes initiating a managed pressure drilling (MPD) operation in an MPD system including a rotating control device (RCD) including at least one sealing element and a plurality of pressures sensors placed relative to the at least one scaling element. The RCD is positioned in the MPD system so as to receive fluid exiting an annulus of a wellbore. Further, the method includes creating a pressure spike in the annulus of the wellbore during the MPD operation, and monitoring a pressure differential between the plurality of pressure sensors to determine whether there is a leakage within the RCD.
1 . A method, comprising:
initiating a managed pressure drilling operation in a managed pressure drilling system comprising:
a rotating control device comprising:
at least one sealing element; and
a plurality of pressure sensors placed relative to the at least one sealing element,
wherein the rotating control device is positioned in the managed pressure drilling system so as to receive fluid exiting an annulus of a wellbore;
creating a pressure spike in the annulus of the wellbore during the managed pressure drilling operation; and
monitoring a pressure differential between the plurality of pressure sensors to determine whether there is a leakage within the rotating control device,
wherein the managed pressure drilling system further comprises:
a choke manifold connected to the rotating control device via a primary line; and
a backpressure pump having an inlet and an outlet,
wherein the inlet of the backpressure pump is connected to a fluid source,
wherein the outlet of the backpressure pump is connected to a backpressure line,
wherein the backpressure line is fluidly connected to the rotating control device, and
wherein the backpressure line is a dedicated test line that is connected directly to the rotating control device.
2 . The method of claim 1 , further comprising replacing the at least one sealing element when the pressure differential between the plurality of pressure sensors exceeds a predetermined threshold.
3 . The method of claim 1 , wherein the plurality of pressure sensors comprises: a first pressure sensor placed above the at least one sealing element, and a second pressure sensor placed below the at least one sealing element.
4 . The method of claim 1 ,
wherein the at least one sealing element comprises: an upper sealing element; and a lower sealing element,
wherein the plurality of pressure sensors comprises: a first pressure sensor placed above the upper and lower sealing elements; a second pressure sensor placed below the upper and lower sealing elements; and an intermediate pressure sensor placed between the upper and lower sealing elements.
5 . The method of claim 1 , wherein a pump connected to the rotating control device creates the pressure spike in the annulus of the wellbore during the managed pressure drilling operation.
6 . The method of claim 1 , wherein creating the pressure spike in the annulus of the wellbore during the managed pressure drilling operation comprises restricting a flow of the fluid flowing through the choke manifold.
7 . The method of claim 1 , wherein creating the pressure spike in the annulus of the wellbore during the managed pressure drilling operation comprises pumping a backpressure fluid into the backpressure line using the backpressure pump.
8 . The method of claim 1 , wherein the managed pressure drilling system is connected to a drilling fluid circulation system comprising:
at least one tank containing drilling fluid;
at least one drilling fluid pump operable to move the drilling fluid from the at least one tank and into a fluid passage of a drill string disposed in the wellbore via a fluid conduit disposed between the at least one drilling fluid pump and the rotating control device; and
drilling fluid reconditioning equipment located downstream of the choke manifold that cleans or reconditions the drilling fluid before returning the drilling fluid to the tank.
9 . The method of claim 8 , wherein the drilling fluid reconditioning equipment comprises a shaker.
10 . The method of claim 8 , wherein the fluid source connected to the inlet of the backpressure pump is the at least one tank.
11 . The method of claim 1 , wherein the rotating control device is placed on top of a blowout preventer stack in the managed pressure drilling system.
12 . A test system for a managed pressure drilling system comprising:
a rotating control device comprising:
at least one sealing element;
a plurality of pressure sensors placed relative to the at least one sealing element,
wherein the rotating control device is positioned in the managed pressure drilling system so as to receive fluid exiting an annulus of a wellbore; and
a test port;
a pump; and
a choke manifold connected to the rotating control device via a primary line,
wherein at least one of the pump and the choke manifold is configured to create a pressure spike in the annulus of the wellbore during a managed pressure drilling operation,
wherein the plurality of pressure sensors are configured to generate pressure sensor data indicative of a condition of the at least one sealing element as a result of creating the pressure spike in the annulus of the wellbore during the managed pressure drilling operation, and
wherein the pump is configured to direct fluid into the test port of the rotating control device to create the pressure spike in the annulus of the wellbore during the managed pressure drilling operation.
13 . The test system of claim 12 , wherein the plurality of pressure sensors comprises: a first pressure sensor placed above the at least one sealing element, and a second pressure sensor placed below the at least one sealing element.
14 . The test system of claim 12 ,
wherein the at least one sealing element comprises: an upper sealing element; and a lower sealing element,
wherein the plurality of pressure sensors comprises: a first pressure sensor placed above the upper and lower sealing elements; a second pressure sensor placed below the upper and lower sealing elements; and an intermediate pressure sensor placed between the upper and lower sealing elements.
15 . The test system of claim 12 , wherein the pump is a backpressure pump having an inlet and an outlet,
wherein the inlet of the backpressure pump is connected to a fluid source, and
wherein the outlet of the backpressure pump is connected to a backpressure line, and
wherein the backpressure line is fluidly connected to the rotating control device.
16 . The test system of claim 15 , wherein the backpressure line is connected to the primary line at a location upstream of the choke manifold.
17 . The test system of claim 15 , further comprising:
a drilling fluid circulation system comprising:
at least one tank containing drilling fluid;
at least one drilling fluid pump operable to move the drilling fluid from the at least one tank and into a fluid passage of a drill string disposed in the wellbore via a fluid conduit disposed between the at least one drilling fluid pump and the rotating control device; and
drilling fluid reconditioning equipment located downstream of the choke manifold that cleans or reconditions the drilling fluid before returning the drilling fluid to the tank.
18 . The test system of claim 17 , wherein the fluid source connected to the inlet of the backpressure pump is the at least one tank.
19 . The test system of claim 12 , wherein the rotating control device is placed on top of a blowout preventer stack in the managed pressure drilling system.
20 . A test system for a managed pressure drilling system comprising:
a rotating control device comprising:
at least one sealing element;
a plurality of pressure sensors placed relative to the at least one sealing element, wherein the rotating control device is positioned in the managed pressure drilling system so as to receive fluid exiting an annulus of a wellbore; and
a test port;
a pump; and
a choke manifold connected to the rotating control device via a primary line,
wherein at least one of the pump and the choke manifold is configured to create a pressure spike in the annulus of the wellbore during a managed pressure drilling operation,
wherein the plurality of pressure sensors are configured to generate pressure sensor data indicative of a condition of the at least one sealing element as a result of creating the pressure spike in the annulus of the wellbore during the managed pressure drilling operation, and
wherein the pump is a backpressure pump having an inlet and an outlet,
wherein the inlet of the backpressure pump is connected to a fluid source, and
wherein the outlet of the backpressure pump is connected to a backpressure line, and
wherein the backpressure line is fluidly connected to the rotating control device, and
wherein the backpressure line is fluidly connected to the rotating control device via the test port.