Early detection of scale in oil production wells

Abstract

The disclosed technology is directed to methods and systems for detecting scale within a well production structure. The methods include generating a model for the well production structure. The method also includes executing a first test using the model to generate first scale data and executing a second test based on concurrently adjusting one or more of a plurality of model parameters using updated versions of synthetic or non-synthetic data to generate a plurality of second scale data. The method also includes executing a merging operation between scale data realizations comprised in the plurality of the second scale data to generate scaling signature data. The method further includes initiating generation of one or more of: a scale data visualization, or an intervention report, or an intervention signal for a control operation that mitigates against detected scale.

What is claimed is: 
     
         1 . A method for detecting scale in a well production structure, the method comprising:
 generating, using a computer processor, a model for the well production structure, the model including a plurality of model parameters that are adjusted based on one or more of:
 synthetic data which is not captured by a sensor deployed about the well production structure, and 
 non-synthetic data which is captured by one or more sensors deployed about the well production structure; 
   executing, using the computer processor, a first test using the model to generate first scale data, the first scale data indicating a normal mode of operation of the well production structure such that the normal mode of operation of the well production structure indicates one of:
 an absence of scale within the well production structure, or 
 a presence of substantially minimal scale within the well production structure; 
   executing, using the computer processor, a second test based on concurrently adjusting one or more of the plurality of model parameters using updated versions of the synthetic data or non-synthetic data to generate a plurality of second scale data; and   executing, using the computer processor, a merging operation between scale data realizations comprised in the second scale data to generate scaling signature data, the merging operation including at least a union of the plurality of second scale data relative to the first scale data.   
     
     
         2 . The method of  claim 1 , further comprising initiating, using the computer processor, generation of one or more of:
 a visualization that indicates a superimposition of the scaling signature data over the first scale data, or   an intervention report or an intervention signal for a control operation that mitigates against detected scale in one or more sections of the well production structure based on one or more of the first test or the second test.   
     
     
         3 . The method of  claim 2 , wherein the visualization comprises a 3-dimensional visualization that indicates fluid production signatures indicative of a presence or an absence of scale within a production tubing associated with the production structure. 
     
     
         4 . The method of  claim 1 , wherein the scale comprises an accumulation of one or more organic or inorganic materials within a production tubing comprised in the well production structure, the scale impacting the well production structure by:
 clogging the production tubing and thereby decreasing a rate of fluid production associated with the well production structure; or   decreasing an inner diameter of the production tubing and thereby reducing the rate of fluid production associated with the well production structure.   
     
     
         5 . The method of  claim 1 , wherein the one or more sensors deployed about the well production structure comprise at least one of:
 a multiphase flow sensor;   a wellhead pressure sensor;   a wellhead temperature sensor;   a downhole pressure sensor;   a downhole temperature sensor;   a casing or tubing pressure sensor;   a casing or tubing temperature sensor; and   a wellhead flowrate sensor.   
     
     
         6 . The method of  claim 1 , wherein the first test or the second test comprises a computing simulation that generates that first scale data or the second scale data, respectively. 
     
     
         7 . The method of  claim 1 , wherein:
 the first scale data is generated for a first section of the well production structure; and   the second scale data is generated for a second section of the well production structure.   
     
     
         8 . The method of  claim 6 , wherein the first scale data and the second scale data are merged to determine scale relationship data between the first scale data and the second scale data. 
     
     
         9 . The method of  claim 8 , wherein the scale relationship data is used to determine one of:
 a union relationship between the first scale data and the second scale data;   an intersection between the first scale data and the second scale data; and   a complement relationship between the first scale data and the second scale data.   
     
     
         10 . The method of  claim 1  wherein the model is a 2-phase model comprising:
 at least a pressure parameter associated with the well production structure; and 
 at least a flow rate parameter associated with the well production structure. 
 
     
     
         11 . The method of  claim 1 , wherein the model is a 3-phase model that includes:
 at least a flow rate parameter associated with the well production structure;   at least a pressure parameter associated with the well production structure; and   at least a temperature parameter associated with the well production structure.   
     
     
         12 . A computer program for detecting scale in a well production structure, the computer program comprising instructions, that when executed by a computer processor of a computing device, causes the computing device to:
 generate a model for the well production structure, the model including a plurality of model parameters that are adjusted based on one or more of:
 synthetic data which is not captured by a sensor deployed about the well production structure, and 
 non-synthetic data which is captured by one or more sensors deployed about the well production structure; 
   execute a first test using the model to generate first scale data, the first scale data indicating a normal mode of operation of the well production structure such that the normal mode of operation of the well production structure indicates one of:
 an absence of scale within the well production structure, or 
 a presence of substantially minimal scale within the well production structure; 
   execute a second test based on concurrently adjusting one or more of the plurality of model parameters using updated versions of the synthetic data or non-synthetic data to generate a plurality of second scale data;   execute a merging operation between scale data realizations comprised in the second scale data to generate scaling signature data, the merging operation including at least a union of the plurality of second scale data relative to the first scale data; and   initiate generation of one or more of:
 a visualization that indicates a superimposition of the scaling signature data over the first scale data, or 
 an intervention report or an intervention signal for a control operation that mitigates against detected scale in one or more sections of the well production structure based on one or more of the first test or the second test. 
   
     
     
         13 . The computer program of  claim 12 , wherein the first test or the second test comprises a computing simulation that generates that first scale data or the second scale data, respectively. 
     
     
         14 . The computer program of  claim 12 , wherein the model is one of a 2-phase model or a 3-phase model. 
     
     
         15 . A system for or detecting scale in a well production structure, the system comprising:
 a computer processor, and   memory storing a signal processing engine that comprises instructions that are executable by the computer processor to:
 generate a model for the well production structure, the model including a plurality of model parameters that are adjusted based on one or more of:
 synthetic data which is not captured by a sensor deployed about the well production structure, and 
 non-synthetic data which is captured by one or more sensors deployed about the well production structure; 
 
 execute a first test using the model to generate first scale data, the first scale data indicating a normal mode of operation of the well production structure such that the normal mode of operation of the well production structure indicates one of:
 an absence of scale within the well production structure, or 
 a presence of substantially minimal scale within the well production structure; 
 
 execute a second test based on concurrently adjusting one or more of the plurality of model parameters using updated versions of the synthetic data or non-synthetic data to generate a plurality of second scale data; 
 execute a merging operation between scale data realizations comprised in the second scale data to generate scaling signature data, the merging operation including at least a union of the plurality of second scale data relative to the first scale data; 
 initiate generation of one or more of:
 a visualization that indicates a superimposition of the scaling signature data over the first scale data, or 
 an intervention report or an intervention signal for a control operation that mitigates against detected scale in one or more sections of the well production structure based on one or more of the first test or the second test. 
 
   
     
     
         16 . The system of  claim 15 , wherein the scale comprises an accumulation of one or more organic or inorganic materials within a production tubing comprised in the well production structure, the scale impacting the well production structure by:
 clogging the production tubing and thereby decreasing a rate of fluid production associated with the well production structure; or   decreasing an inner diameter of the production tubing and thereby reducing the rate of fluid production associated with the well production structure.   
     
     
         17 . The system of  claim 15 , wherein the one or more sensors deployed about the well production structure comprise at least one of:
 a multiphase flow sensor;   a wellhead pressure sensor;   a wellhead temperature sensor;   a downhole pressure sensor;   a downhole temperature sensor;   a casing or tubing pressure sensor;   a casing or tubing temperature sensor; and   a wellhead flowrate sensor.   
     
     
         18 . The system of  claim 15 , wherein the first test or the second test comprises a computing simulation that generates that first scale data or the second scale data, respectively. 
     
     
         19 . The system of  claim 15 , wherein the model is a 2-phase model comprising:
 at least a pressure parameter associated with the well production structure; and   at least a flow rate parameter associated with the well production structure.   
     
     
         20 . The system of  claim 15 , wherein the model is a 3-phase model that includes:
 at least a flow rate parameter associated with the well production structure;   at least a pressure parameter associated with the well production structure; and   at least a temperature parameter associated with the well production structure.