Detection of fluid losses or gains in managed pressure drilling operations
Disclosed embodiments relate to MPD well drilling methods, for example detecting fluid gains or losses even in transient conditions. For example, data relating to one or more parameter of the drilling system may be corrected/filtered using one or more technique. The corrected data can be used to calculate flowrate difference (DeltaFR), and possible fluid losses or gains in the system can be detected by calculating a virtual trip tank (VTT) using DeltaFR. In some embodiments, the technique can compensate for drillstring movement. In some embodiments, an adaptive moving average may be applied to the data to reduce noise. In some embodiments, bilateral filtering may be applied to the data, for example to address issues arising from movement of a choke in the drilling system. In some embodiments, updated baselines may be applied to remove any offset. Systems related to such methods are also disclosed.
1 . A method for drilling a well using a managed pressure drilling system, comprising:
drilling a wellbore with a drillstring, including circulating fluid through the wellbore during drilling;
receiving, at a control system, data from one or more sensor relating to one or more parameter of the drilling system;
applying, by the control system, an adaptive moving average technique on the data to provide corrected data;
calculating, by the control system using the corrected data, a flowrate difference (DeltaFR) between flow-out rate and flow-in rate;
compensating for drillstring movement, wherein compensating for drillstring movement comprises:
providing flowrate of drilling fluid in a drilling system;
providing depth data for the drillstring;
estimating drillstring velocity based on the depth data of the drillstring using a filter;
calculating flowrate variation caused by drillstring movement based on estimated velocity and the drillstring outer diameter; and
using the calculated flowrate variation to correct the provided flowrate,
wherein the filter for estimating drillstring velocity is a Kalman filter
detecting possible fluid losses or gains by calculating, using the control system, a virtual trip tank using DeltaFR; and
responsive to detecting possible fluid losses or gains, initiating an action in the drilling system to address detected fluid losses or gains, wherein initiating an action comprises altering one of the following in the drilling system: bottom hole pressure, backpressure, pump rate, or combinations thereof.
2 . The method of claim 1 , wherein calculating the virtual trip tank (VTT) is based on VTT=Σ(DeltaFR)×Δt.
3 . The method of claim 1 , wherein applying an adaptive moving average technique comprises:
evaluating quality of the data;
determining a timeframe based on the quality of the data; and
using the timeframe to determine an adaptive moving average for the data.
4 . The method of claim 3 , wherein using the timeframe to determine an adaptive moving average comprises averaging the data over the timeframe.
5 . The method of claim 3 wherein evaluating the quality of the data comprises calculating a standard deviation of the data in a pre-selected timeframe, and using the standard deviation to determine quality.
6 . The method of claim 1 , wherein compensating for drillstring movement comprises subtracting flowrate attributable to drillstring movement from measured fluid flowrate.
7 . The method of claim 1 , further comprising, prior to applying an adaptive moving average technique, determining any phase delay; and
in the event of phase delay, accounting for phase delay prior to using the calculated flowrate variation to correct the provided flowrate.
8 . The method of claim 1 , further comprising updating and applying baselines to remove any offset.
9 . The method of claim 1 , wherein calculating the flowrate difference (DeltaFR) takes into account baseline offset.
10 . The method of claim 1 , further comprising monitoring, using one or more sensors, the one or more parameter including flow-in rate, flow-out rate, density, choke position, and/or drillstring velocity.
11 . The method of claim 1 , further comprising, responsive to detecting fluid gains beyond capacity of the system, initiating shut-in of the system.
12 . The method of claim 1 , further comprising, responsive to detecting fluid gains within capacity of the system, circulating the fluid gain out of the system.
13 . The method of claim 1 , further comprising adjusting a choke manifold, a backpressure pump, a mud pump, or combinations thereof.
14 . A method for drilling a well using a managed pressure drilling system, comprising:
drilling a wellbore with a drillstring, including circulating fluid through the wellbore during drilling;
receiving, at a control system, data from one or more sensor relating to one or more parameter of the drilling system;
applying, by the control system, an adaptive moving average technique on the data to provide corrected data;
calculating, by the control system using the corrected data, a flowrate difference (DeltaFR) between flow-out rate and flow-in rate;
detecting possible fluid losses or gains by calculating, using the control system, a virtual trip tank using DeltaFR; and
responsive to detecting possible fluid losses or gains, initiating an action in the drilling system to address detected fluid losses or gains, wherein initiating an action comprises altering one of the following in the drilling system: bottom hole pressure, backpressure, pump rate, or combinations thereof;
further comprising filtering parameter data to remove oscillations caused by movement of a choke manifold, wherein filtering data to remove oscillation comprises applying bilateral filtering to the data.
15 . The method of claim 14 , further comprising updating and applying baselines to remove any offset, wherein calculating the flowrate difference (DeltaFR) takes into account baseline offset.
16 . The method of claim 14 , further comprising compensating for drillstring movement.
17 . A system for drilling a wellbore, comprising:
a control system configured to implement the method of claim 1 ; and
a drillstring disposed in the wellbore.
18 . The system of claim 17 , further comprising an RCD configured to seal an annulus of the wellbore, a choke manifold in fluid communication with the annulus, and a mud pump in fluid communication with the choke manifold and the drillstring.
19 . The system of claim 18 , further comprising:
a drilling fluid handling system in fluid communication with both the choke manifold and the mud pump;
a back-pressure pump configured to apply backpressure to the annulus; and
one or more sensors.