Prospective kick loss detection for off-shore drilling

Patent metadata

Field	Value
Publication number	US-2021180418-A1
Application number	US-201916711739-A
Country	US
Kind code	A1
Filing date	Dec 12, 2019
Priority date	Dec 12, 2019
Publication date	Jun 17, 2021
Grant date	—

Abstract

Certain aspects and features relate to a system that monitors for kick and lost circulation in the riser string of an offshore drilling rig. The system compensates for annulus outflow fluctuation induced by wave (heave) motion in order to reduce false alarms, resulting in fewer drilling operation disruptions. The system includes a sensor or sensors disposable with respect to a drilling rig subject to rig motion. A processor receives a real-time position signal indicative of the rig motion from the sensor and applies a state observer to the position signal to determine annular flow parameters. The system models an annular flow for the wellbore to produce a modeled flow signal that reflects a position of the drilling rig relative to influx flow. The system uses the modeled flow to determine kick-loss-alarm parameters that take into account the heave motion.

First claim

What is claimed is:

1 . A system comprising:
at least one sensor disposable with respect to a drilling rig subject to rig motion; a processor communicatively coupled to the at least one sensor; and a non-transitory memory device comprising instructions that are executable by the processor to cause the processor to perform operations comprising:
receiving, in real time from the at least one sensor, a position signal indicative of the rig motion;
applying a state observer to the position signal to determine annular flow parameters;
modeling an annular flow for a wellbore associated with the drilling rig to produce a modeled flow signal based on the annular flow parameters, the modeled flow signal reflecting a position of the drilling rig relative to influx flow;
determining kick-loss-alarm parameters from the modeled flow signal; and
applying the kick-loss-alarm parameters to an alarm module.

2 . The system of claim 1 , wherein the at least one sensor comprises a heave motion sensor and the rig motion comprises wave-induced rig motion.

3 . The system of claim 1 , wherein the operation of modeling the annular flow further comprises:
applying a linear quadratic estimation filter to the position signal to estimate a velocity of the rig motion in a state vector and to estimate an influx flow variation; and optimizing a gain of the state observer based on the velocity of the rig motion and the influx flow variation.

4 . The system of claim 1 , wherein the operation of determining the kick-loss-alarm parameters comprises adjusting an alarm threshold for at least one of kick or loss based on the rig motion as determined from the modeled flow signal.

5 . The system of claim 4 , further comprising a display device, and wherein the operations further comprise:
determining a standard deviation from a statistical distribution of influx flow variation; calculating a confidence level for the alarm threshold based on the standard deviation; and displaying the confidence level on a display device.

6 . The system of claim 1 , wherein the operation of modeling the annular flow further comprises producing a physics-based model based on a pumping effect of a telescope joint, annulus fluid return, and mass conservation.

7 . The system of claim 1 , wherein the operation of modeling the annular flow further comprises producing a machine-learning model that determines, based on the position signal over time, an annular area and a bias term quantifying pumping efficiency.

8 . A method comprising:
receiving, by a processing device in real time from at least one sensor, a position signal indicative of rig motion; applying, by the processing device, a state observer to the position signal to determine annular flow parameters; modeling, by the processing device, an annular flow for a wellbore to produce a modeled flow signal based on the annular flow parameters, the modeled flow signal reflecting a position of a drilling rig relative to influx flow; determining, by the processing device, kick-loss-alarm parameters from the modeled flow signal; and applying, by the processing device, the kick-loss-alarm parameters to an alarm module.

9 . The method of claim 8 , wherein the at least one sensor comprises a heave motion sensor and the rig motion comprises wave-induced rig motion.

10 . The method of claim 8 , wherein modeling the annular flow further comprises:
applying a linear quadratic estimation filter to the position signal to estimate a velocity of the rig motion in a state vector and to estimate influx flow variation; and optimizing a gain of the state observer based on the velocity of the rig motion and the influx flow variation.

11 . The method of claim 8 , wherein determining the kick-loss-alarm parameters comprises adjusting an alarm threshold for at least one of kick or loss based on the rig motion as determined from the modeled flow signal.

12 . The method of claim 11 further comprising:
determining a standard deviation from a statistical distribution of influx flow variation;
calculating a confidence level for the alarm threshold based on the standard deviation; and
displaying the confidence level on a display device.

13 . The method of claim 8 , wherein modeling the annular flow further comprises producing a physics-based model based on a pumping effect of a telescope joint, annulus fluid return, and mass conservation.

14 . The method of claim 8 , wherein modeling the annular flow further comprises producing a machine-learning model that determines, based on the position signal over time, an annular area and a bias term quantifying pumping efficiency.

15 . A non-transitory computer-readable medium that includes instructions that are executable by a processor for causing the processor to perform operations related to kick and loss detection, the operations comprising:
receiving, in real time from at least one sensor, a position signal indicative of rig motion; applying a state observer to the position signal to determine annular flow parameters; modeling an annular flow for a wellbore to produce a modeled flow signal based on the annular flow parameters, the modeled flow signal reflecting a position of a drilling rig relative to influx flow; determining kick-loss-alarm parameters from the modeled flow signal; and applying the kick-loss-alarm parameters to an alarm module.

16 . The non-transitory computer-readable medium of claim 15 , wherein the operation of modeling the annular flow further comprises:
applying a linear quadratic estimation filter to the position signal to estimate a velocity of the rig motion in a state vector and to estimate an influx flow variation; and optimizing a gain of the state observer based on the velocity of the rig motion and the influx flow variation.

17 . The non-transitory computer-readable medium of claim 15 , wherein the operation of determining the kick-loss-alarm parameters comprises adjusting an alarm threshold for at least one of kick or loss based on the rig motion as determined from the modeled flow signal.

18 . The non-transitory computer-readable medium of claim 17 , wherein the operations further comprise:
determining a standard deviation from a statistical distribution of influx flow variation; calculating a confidence level for the alarm threshold based on the standard deviation; and displaying the confidence level on a display device.

19 . The non-transitory computer-readable medium of claim 15 , wherein the operation of modeling the annular flow further comprises producing a physics-based model based on a pumping effect of a telescope joint, annulus fluid return, and mass conservation.

20 . The non-transitory computer-readable medium of claim 15 , wherein the operation of modeling the annular flow further comprises producing a machine-learning model that determines, based on the position signal over time, an annular area and a bias term quantifying pumping efficiency.

Assignees

• Halliburton Energy Services Inc

Inventors

• Sun Zhijie
• Ren Rui
• Darbe Robert P
• Rowe Mathew Dennis

Classifications

• E21B33/128

  with a member expanded radially by axial pressure (E21B33/122, E21B33/124 take precedence) · CPC title

• E21B33/126 Primary

  with fluid-pressure-operated elastic cup or skirt (E21B33/122, E21B33/124 take precedence) · CPC title

• E21B33/134

  Bridging plugs · CPC title

• G06F2113/08

  Fluids · CPC title

• G06F30/28 Primary

  using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD] · CPC title