System and method for determining production from a plurality of wells

Abstract

A method includes receiving field measurement data of a plurality of well-pumps disposed respectively in a plurality of wells. The field measurement data are representative of speed data and run-time data of the plurality of well-pumps. The method further includes receiving commingled-flow measurement data. The commingled-flow measurement data are representative of a combined fluid flow data of the plurality of wells. The method further includes determining, by an optimizer unit, well-flow data of the plurality of wells based on the commingled-flow measurement data, the field measurement data, and a plurality of conservation constraints generated by a constraint generator. The well-flow data are representative of fluid flow data from each of the plurality of wells. The method also includes controlling operation of at least one of the plurality of well-pumps based on the well-flow data to control fluid production from the plurality of wells.

1 . A method comprising:
 receiving field measurement data of a plurality of well-pumps disposed respectively in a plurality of wells from a plurality of pump-off controller (POC) sensors, wherein the field measurement data are representative of speed data and run-time data of the plurality of well-pumps;   receiving commingled-flow measurement data using a plurality of commingled-flow measurement sensors, wherein the commingled-flow measurement data are representative of a combined fluid flow data of the plurality of wells;   determining, by an optimizer unit, well-flow data of the plurality of wells based on the commingled-flow measurement data, the field measurement data, and a plurality of conservation constraints generated by a constraint generator, wherein the well-flow data are representative of fluid flow data from each of the plurality of wells; and   controlling operation of at least one of the plurality of well-pumps based on the well-flow data to control fluid production from the plurality of wells.   
     
     
         2 . The method of  claim 1 , wherein the plurality of conservation constraints comprises at least one of a mass conservation constraint, an energy conservation constraint, a heat conservation constraint and a momentum conservation constraint. 
     
     
         3 . The method of  claim 1 , wherein the field measurement data comprises at least one of a temperature value, a pressure value, and a torque value corresponding to the plurality of well-pumps. 
     
     
         4 . The method of  claim 1 , wherein determining the well-flow data comprises:
 determining a power spectral density based on the commingled-flow measurement data;   determining a plurality of peak values corresponding to a plurality of fundamental frequency values of the power spectral density;   identifying a set of wells from the plurality of wells, corresponding to the plurality of peak values, based on subset stroke data from the speed data, corresponding to the plurality of wells; and   determining a plurality of mean flow rate values based on subset duty cycle data from the run-time data, of the identified set of wells.   
     
     
         5 . The method of  claim 1 , wherein determining the well-flow data comprises:
 determining a probability distribution function corresponding to the well-flow data, based on the field measurement data and the commingled-flow measurement data;   determining a cost function based on the probability distribution function; and   performing an optimization using the cost function to determine the well-flow data.   
     
     
         6 . The method of  claim 5 , wherein determining the probability distribution function comprises determining at least one of an apriori distribution function and an aposteriori distribution function of the well-flow data. 
     
     
         7 . The method of  claim 5 , wherein the cost function comprises a plurality of conservation equations determined based on the field measurement data and the commingled-flow measurement data. 
     
     
         8 . The method of  claim 1 , wherein determining the well-flow data comprises estimating a plurality of variance values based on the field measurement data. 
     
     
         9 . The method of  claim 8 , wherein estimating the plurality of variance values comprises determining a correlation matrix based on at least one parameter of the field measurement data. 
     
     
         10 . The method of  claim 8 , wherein estimating the plurality of variance values comprises:
 determining a variance model corresponding to a variance value among the plurality of variance values, wherein the variance model is a polynomial equation; and   determining an estimate of a mean and a standard deviation corresponding to the variance value among the plurality of variance values determined based on the variance model.   
     
     
         11 . A system comprising:
 a plurality of sensors disposed in an oil field, wherein the plurality of sensors comprises a plurality of pump-off controller (POC) sensors disposed on a plurality of well-pumps and a plurality of commingled-flow measurement sensors disposed on a pool-line;   a data acquisition unit configured to:
 receive field measurement data of a plurality of well-pumps disposed respectively in a plurality of wells from the plurality of POC sensors, wherein the field measurement data are representative of speed data and run-time data of the plurality of well-pumps; and 
 receive commingled-flow measurement data using the plurality of commingled-flow measurement sensors, wherein the commingled-flow measurement data are representative of a combined fluid flow data of the plurality of wells; 
   an optimizer unit communicatively coupled to the data acquisition unit and configured to:
 generate a plurality of conservation constraints using a constraint generator, based on the commingled-flow measurement data and the field measurement data; and 
 determine well-flow data corresponding to the plurality of wells based on the commingled-flow measurement data, the field measurement data, and the plurality of conservation constraints, wherein the well-flow data are representative of fluid flow data from each of the plurality of wells; and 
   a controller communicatively coupled to the data acquisition unit and the optimizer unit and configured to control operation of at least one of the plurality of well-pumps based on the well-flow data to control fluid production from the plurality of wells.   
     
     
         12 . The system of  claim 11 , wherein the optimizer unit is configured to generate at least one of a mass conservation constraint, an energy conservation constraint, a heat conservation constraint and a momentum conservation constraint. 
     
     
         13 . The system of  claim 11 , wherein the data acquisition unit is configured to acquire at least one of a flow value, a temperature value, a pressure value, a torque value corresponding to the plurality of well-pumps. 
     
     
         14 . The system of  claim 11 , wherein the optimizer unit is configured to:
 determine a power spectral density based on the commingled-flow measurement data;   determine a plurality of peak values corresponding to a plurality of fundamental frequencies of the power spectral density;   identify a set of wells from the plurality of wells, corresponding to the plurality of peak values, based on subset stroke data from the speed data, corresponding to the plurality of wells; and   determine a plurality of mean flow rate values based on subset duty cycle data from the run-time data, of the identified set of wells.   
     
     
         15 . The system of  claim 11 , wherein the optimizer unit is configured to:
 determine a probability distribution function corresponding to the well-flow data, based on the field measurement data and the commingled-flow measurement data;   determine a cost function based on the probability distribution function; and   perform an optimization using the cost function to determine the well-flow data.   
     
     
         16 . The system of  claim 15 , wherein the optimizer unit is configured to determine the probability distribution function comprises determining at least one of an apriori distribution function and an aposteriori distribution function of the well-flow data. 
     
     
         17 . The system of  claim 16 , wherein the optimizer unit is configured to determine a cost function based on a plurality of conservation equations determined based on the field measurement data and the commingled-flow measurement data. 
     
     
         18 . The system of  claim 11 , wherein the optimizer unit is configured to estimate a plurality of variance values corresponding to the well-flow data based on the field measurement data. 
     
     
         19 . The system of  claim 18 , wherein the optimizer unit is configured to determine a correlation matrix corresponding to the oil field based on at least one parameter of the field measurement data. 
     
     
         20 . The system of  claim 18 , wherein the optimizer unit is configured to:
 determine variance model corresponding to a variance value among the plurality of variance values, wherein the variance model is a polynomial equation;   determine an estimate of a mean and a standard deviation corresponding to the variance value among the plurality of variance values determined based on the variance model.   
     
     
         21 . A non-transitory computer readable medium having instructions to enable at least one processor module to:
 receive field measurement data of a plurality of well-pumps disposed respectively in a plurality of wells from a plurality of pump-off controller (POC) sensors, wherein the field measurement data are representative of strokes per minute data and duty cycle data of the plurality of well-pumps;   receive commingled-flow measurement data using a plurality of commingled-flow measurement sensors, wherein the commingled-flow measurement data are representative of a combined fluid flow data of the plurality of wells;   determine well-flow data of the plurality of wells based on the commingled-flow measurement data, the field measurement data, and a plurality of conservation constraints generated by a constraint generator, wherein the well-flow data are representative of fluid flow data from each of the plurality of wells; and   control operation of at least one of the plurality of well-pumps based on the well-flow data to control fluid production from the plurality of wells.