Multi-agent, multi-objective wellbore gas-lift optimization
A system and method for controlling a gas supply to provide gas lift for wellbore(s) using Bayesian optimization. A computing device controls a gas supply to inject gas into wellbore(s). The computing device receives first reservoir data associated with a first subterranean reservoir and simulates production using the first reservoir data, using a model for the first subterranean reservoir. The production simulation provides first production data. The computing device receives second reservoir data associated with a subterranean reservoir and simulates production using the second reservoir data, using a model for the second subterranean reservoir. The production simulation provides second production data. A Bayesian optimization of an objective function of the first and second production data subject to any gas injection constraints can be performed to produce gas-lift parameters. The gas-lift parameters can be applied to the gas supply to control injection of gas into the wellbore(s).
1 . A system comprising:
a gas supply arrangement to inject gas into a plurality of wellbores in proximity to production tubing, wherein the plurality of wellbores comprises a plurality of clustered wellbores; and
a computing device in communication with the gas supply arrangement, the computing device including a non-transitory memory device comprising instructions that are executable by the computing device to cause the computing device to perform operations comprising:
receiving, from a first robot associated with a first wellbore, first reservoir data associated with a first subterranean reservoir to be penetrated by the first wellbore, the first wellbore being associated with a first cluster of wellbores of the plurality of clustered wellbores;
simulating production using the first reservoir data associated with the first subterranean reservoir and using a physics-based model, a machine learning model, or a hybrid physics-based machine learning model for the first subterranean reservoir to provide first production data;
receiving, from a second robot associated with a second wellbore, second reservoir data associated with a second subterranean reservoir to be penetrated by the second wellbore, the second wellbore being associated with a second cluster of wellbores of the plurality of clustered wellbores;
simulating production using the second reservoir data associated with the second subterranean reservoir and using the physics-based model, the machine learning model, or the hybrid physics-based machine learning model for the second subterranean reservoir to provide second production data;
performing a Bayesian optimization of an objective function of the first and second production data subject to gas injection constraints and convergence criteria to produce gas-lift parameters, the Bayesian optimization being performed for each of the first cluster of wellbores, the second cluster of wellbores, and across the plurality of clustered wellbores; and
applying the gas-lift parameters to the gas supply arrangement by performing a gas-lift control using the first robot or the second robot based on the gas-lift parameters in response to the convergence criteria being met to control an injection of gas into at least one wellbore of the plurality of wellbores.
2 . The system of claim 1 , further comprising:
a production tubing string disposed in the at least one wellbore of the plurality of clustered wellbores;
an injection port connected to the production tubing string to inject gas into the production tubing string downhole; and
a gas storage device connected to the production tubing string.
3 . The system of claim 1 , wherein the gas-lift parameters comprise gas injection rate and choke size.
4 . The system of claim 3 , wherein the gas injection rate is constant or a function of time.
5 . The system of claim 1 , wherein the convergence criteria comprise a maximum number of iterations and a convergence within a specified tolerance to a maximum production rate and a minimum friction value for the production tubing.
6 . The system of claim 1 , the operations further comprising:
transmitting a signal to the first robot or the second robot associated with at least one of the plurality of clustered wellbores to perform the gas-lift control based on the gas-lift parameters.
7 . The system of claim 6 , wherein the at least one of the plurality of clustered wellbores is the first wellbore, the system further comprising:
the first robot having a first sensor, the first sensor to detect the first reservoir data and receive real-time production data associated with the first wellbore, wherein the first robot transmits the first reservoir data to the computing device; and
the second robot having a second sensor, the second sensor to detect the second reservoir data and receive real-time production data associated with the second wellbore, wherein the second robot transmits the second reservoir data to the computing device.
8 . A method comprising:
receiving, from a first robot associated with a first wellbore and by a processing device, first reservoir data associated with a first subterranean reservoir to be penetrated by the first wellbore, the first wellbore being associated with a first cluster of wellbores of a plurality of clustered wellbores;
simulating, by the processing device, production using the first reservoir data associated with the first subterranean reservoir and using a physics-based model, a machine learning model, or a hybrid physics-based machine learning model for the first subterranean reservoir to provide first production data;
receiving, from a second robot associated with a second wellbore and by the processing device, second reservoir data associated with a second subterranean reservoir to be penetrated by the second wellbore, the second wellbore being associated with a second cluster of wellbores of the plurality of clustered wellbores;
simulating, by the processing device, production using the second reservoir data associated with the second subterranean reservoir and using the physics-based model, the machine learning model, or the hybrid physics-based machine learning model for the second subterranean reservoir to provide second production data;
performing, by the processing device, a Bayesian optimization of an objective function of the first and second production data subject to gas injection constraints and convergence criteria to produce gas-lift parameters, the Bayesian optimization being performed for each of the first cluster of wellbores, the second cluster of wellbores, and across the plurality of clustered wellbores; and
applying, by the processing device, the gas-lift parameters to a gas supply arrangement by performing a gas-lift control using the first robot or the second robot based on the gas-lift parameters in response to the convergence criteria being met to control an injection of gas into the first wellbore or the second wellbore.
9 . The method of claim 8 , wherein the first wellbore and the second wellbore each include a production tubing string, the method further comprising:
injecting gas into the production tubing string downhole; and
capturing gas at a gas storage device connected to the production tubing string.
10 . The method of claim 8 , wherein the gas-lift parameters comprise gas injection rate and choke size.
11 . The method of claim 10 , wherein the gas injection rate is constant or a function of time.
12 . The method of claim 8 , wherein the convergence criteria comprise a maximum number of iterations and a convergence within a specified tolerance to a maximum production rate and a minimum friction value for the production tubing.
13 . The method of claim 8 , further comprising:
transmitting a signal to the first robot or the second robot associated with at least one of the plurality of clustered wellbores to perform the gas-lift control based on the gas-lift parameters.
14 . The method of claim 13 , further comprising:
receiving, from the first robot having a first sensor, real-time production data associated with the first wellbore, the real-time production data associated with the first wellbore being the first reservoir data;
receiving, from the second robot having a second sensor, real-time production data associated with the second wellbore, the real-time production data associated with the first wellbore being the second reservoir data;
transmitting, using the first robot, the first reservoir data to the processing device; and
transmitting, using the second robot, the second reservoir data to the processing device.
15 . A non-transitory computer-readable medium comprising instructions that are executable by a processing device for causing the processing device to perform operations comprising:
receiving, from a first robot associated with a first wellbore and by the processing device, first reservoir data associated with a first subterranean reservoir to be penetrated by the first wellbore, the first wellbore being associated with a first cluster of wellbores of a plurality of clustered wellbores;
simulating, by the processing device, production using the first reservoir data associated with the first subterranean reservoir and using a physics-based model, a machine learning model, or a hybrid physics-based machine learning model for the first subterranean reservoir to provide first production data;
receiving, from a second robot associated with a second wellbore and by the processing device, second reservoir data associated with a second subterranean reservoir to be penetrated by the second wellbore, the second wellbore being associated with a second cluster of wellbores of the plurality of clustered wellbores;
simulating production using the second reservoir data associated with the second subterranean reservoir and using the physics-based model, the machine learning model, or the hybrid physics-based machine learning model for the second subterranean reservoir to provide second production data;
performing a Bayesian optimization of an objective function of the first and second production data subject to gas injection constraints and convergence criteria to produce gas-lift parameters, the Bayesian optimization being performed for each of the first cluster of wellbores, the second cluster of wellbores, and across the plurality of clustered wellbores; and
applying the gas-lift parameters to a gas supply arrangement by performing a gas-lift control using the first robot or the second robot based on the gas-lift parameters in response to the convergence criteria being met to control an injection of gas into the first wellbore or the second wellbore.
16 . The non-transitory computer-readable medium of claim 15 , wherein the first wellbore and the second wellbore each include production tubing string, the operations further comprising:
injecting gas into the production tubing string downhole; and
capturing gas at a gas storage device connected to the production tubing string.
17 . The non-transitory computer-readable medium of claim 15 , wherein the gas-lift parameters comprise gas injection rate and choke size, and wherein the gas injection rate is constant or a function of time.
18 . The non-transitory computer-readable medium of claim 15 , wherein the convergence criteria comprise a maximum number of iterations and a convergence within a specified tolerance to a maximum production rate and a minimum friction value for the production tubing.
19 . The non-transitory computer-readable medium of claim 15 ,
wherein the processing device comprises a robotic operating system, the non-transitory computer-readable medium comprising instructions that are executable by the processing device for causing the processing device to perform operations further comprising:
transmitting a signal to the first robot or the second robot associated with at least the first wellbore or the second wellbore to perform the gas-lift control based on the gas-lift parameters.
20 . The non-transitory computer-readable medium of claim 19 , the operations further comprising:
receiving, from the first robot having a first sensor, real-time production data associated with the first wellbore, the real-time production data associated with the first wellbore being the first reservoir data;
receiving, from the second robot having a second sensor, real-time production data associated with the second wellbore, the real-time production data associated with the first wellbore being the second reservoir data;
transmitting, using the first robot, the first reservoir data to the processing device; and
transmitting, using the second robot, the second reservoir data to the processing device.