Real-Time Model for Diverter Drop Decision using DAS and Step Down Analysis

Abstract

A system includes at least one processor, and a memory coupled to the at least one processor having instructions stored therein. When executed by the at least one processor, the instructions cause the at least one processor to perform functions including functions to: apply a treatment at a first well in the subterranean formation, wherein the treatment is for stimulating production; perform a step down analysis of the first well at each of a plurality of stages of the first well; determine a downhole flow distribution at each of the plurality of stages; develop a model for correlating the downhole flow distribution and the step down analysis at each of the plurality of stages; use the developed model to estimate a downhole flow distribution at a stage of a second well; and determine whether to bypass a deployment of the diverter material at the stage of the second well based on the estimated downhole flow distribution.

What is claimed is: 
     
         1 . A method for deploying diverter material in a subterranean formation during stimulation treatment, comprising:
 applying a treatment at a first well in the subterranean formation, wherein the treatment is for stimulating production;   performing a step down analysis of the first well at each of a plurality of stages of the first well;   determining a downhole flow distribution at each of the plurality of stages;   developing a model for correlating the downhole flow distribution and the step down analysis at each of the plurality of stages;   using the developed model to estimate a downhole flow distribution at a stage of a second well; and   determining whether to bypass a deployment of the diverter material at the stage of the second well based on the estimated downhole flow distribution.   
     
     
         2 . The method of  claim 1 , wherein:
 the second well is in a vicinity of the first well; and   the first well and the second well are in a same pad or a similar type of region.   
     
     
         3 . The method of  claim 1 , wherein determining the downhole flow distribution at each of the plurality of stages comprises determining the downhole flow distribution based on distributed acoustic sensing (DAS) data of the corresponding stage. 
     
     
         4 . The method of  claim 3 , wherein DAS data for determining the downhole flow distribution is unavailable at the stage of the second well. 
     
     
         5 . The method of  claim 1 , wherein determining the downhole flow distribution at each of the plurality of stages comprises determining the downhole flow distribution based on at least one of geomechanics modeling data, distributed temperature sensing (DTS) data, microseismic data, distributed strain sensing data, or tiltmeter data of the corresponding stage. 
     
     
         6 . The method of  claim 1 , wherein developing the model for correlating the downhole flow distribution and the step down analysis at each of the plurality of stages comprises correlating a uniformity measure of the downhole flow distribution and the step down analysis. 
     
     
         7 . The method of  claim 6 , wherein determining whether to bypass the deployment of the diverter material at the stage of the second well comprises determining to bypass the deployment if the uniformity measure is greater than a particular threshold value. 
     
     
         8 . The method of  claim 7 , wherein the particular threshold value is equal to X times (1 minus a mean value of the uniformity measure), wherein X denotes a number greater than or equal to 1. 
     
     
         9 . The method of  claim 8 , wherein, if X is greater than 1, determining whether to bypass the deployment of the diverter material at the stage of the second well further comprises:
 determining to apply a continuous diverter deployment if the uniformity measure is less than the particular threshold value and greater than (1 minus the mean value of the uniformity measure); and   determining to apply a discrete diverter deployment if the uniformity measure is less than (1 minus the mean value of the uniformity measure).   
     
     
         10 . The method of  claim 1 , wherein applying the treatment, performing the step down analysis, determining the downhole flow distribution, developing the model, using the developed model, and determining whether to bypass the deployment of the diverter material are performed in real-time. 
     
     
         11 . A system for deploying diverter material in a subterranean formation during stimulation treatment, comprising:
 at least one processor; and   a memory coupled to the at least one processor having instructions stored therein, which when executed by the at least one processor, cause the at least one processor to perform functions including functions to:   apply a treatment at a first well in the subterranean formation, wherein the treatment is for stimulating production;   perform a step down analysis of the first well at each of a plurality of stages of the first well;   determine a downhole flow distribution at each of the plurality of stages;   develop a model for correlating the downhole flow distribution and the step down analysis at each of the plurality of stages;   use the developed model to estimate a downhole flow distribution at a stage of a second well; and   determine whether to bypass a deployment of the diverter material at the stage of the second well based on the estimated downhole flow distribution.   
     
     
         12 . The system of  claim 11 , wherein:
 the second well is in a vicinity of the first well; and   the first well and the second well are in a same pad or a similar type of region.   
     
     
         13 . The system of  claim 11 , wherein the instructions cause the at least one processor to determine the downhole flow distribution at each of the plurality of stages by determining the downhole flow distribution based on distributed acoustic sensing (DAS) data of the corresponding stage. 
     
     
         14 . The system of  claim 13 , wherein DAS data for determining the downhole flow distribution is unavailable at the stage of the second well. 
     
     
         15 . The system of  claim 11 , wherein the instructions cause the at least one processor to determine the downhole flow distribution at each of the plurality of stages by determining the downhole flow distribution based on at least one of geomechanics modeling data, distributed temperature sensing (DTS) data, microseismic data, distributed strain sensing data, or tiltmeter data of the corresponding stage. 
     
     
         16 . The system of  claim 11 , wherein the instructions cause the at least one processor to develop the model by correlating a uniformity measure of the downhole flow distribution and the step down analysis. 
     
     
         17 . The system of  claim 16 , wherein the instructions cause the at least one processor to determine whether to bypass the deployment of the diverter material by determining to bypass the deployment if the uniformity measure is greater than a particular threshold value. 
     
     
         18 . The system of  claim 17 , wherein the particular threshold value is equal to X times (1 minus a mean value of the uniformity measure), wherein X denotes a number greater than or equal to 1. 
     
     
         19 . The system of  claim 18 , wherein the instructions cause the at least one processor to determine whether to bypass the deployment of the diverter material by, if X is greater than 1, determining to apply a continuous diverter deployment if the uniformity measure is less than the particular threshold value and greater than (1 minus the mean value of the uniformity measure), and determining to apply a discrete diverter deployment if the uniformity measure is less than (1 minus the mean value of the uniformity measure). 
     
     
         20 . The system of  claim 11 , wherein the instructions cause the at least one processor to perform the functions in real-time.