Methods and systems for validation of permeability models based on cumulative flow

Abstract

Examples of methods and systems are disclosed. The methods may include measuring, using flowmeter, a measured fluid flow rate at a plurality of depths in a well penetrating a hydrocarbon reservoir. The methods may also include, determining, using a reservoir simulator, a normalized cumulative fluid flow rate for the well based on the measured fluid flow rate at the plurality of depths, receiving a reservoir simulation model for the hydrocarbon reservoir, determining a normalized fluid flow capacity for the well based on the reservoir simulation model, and updating the reservoir simulation model based, at least in part, on the normalized cumulative fluid flow rate and the normalized fluid flow capacity.

1 . A method comprising:
 measuring, using a flowmeter, a measured fluid flow rate at a plurality of depths in a well penetrating a hydrocarbon reservoir;   using a reservoir simulator:
 determining a normalized cumulative fluid flow rate for the well based on the measured fluid flow rate at the plurality of depths; 
 receiving a reservoir simulation model for the hydrocarbon reservoir; 
 determining a normalized fluid flow capacity for the well based on the reservoir simulation model; and 
 updating the reservoir simulation model based, at least in part, on the normalized cumulative fluid flow rate and the normalized fluid flow capacity. 
   
     
     
         2 . The method of  claim 1 , wherein the reservoir simulation model comprises a permeability matrix. 
     
     
         3 . The method of  claim 1 , wherein the reservoir simulation model comprises a fracture permeability. 
     
     
         4 . The method of  claim 1 , wherein determining the normalized cumulative fluid flow rate comprises determining a first combination of the measured fluid flow rate at the plurality of depths. 
     
     
         5 . The method of  claim 4 , wherein
 the measured fluid flow rate at the plurality of depths comprises a measured fluid flow rate at a surface of the well; and   determining the normalized cumulative fluid flow rate further comprises determining a quotient of the first combination and the measured fluid flow rate at the surface of the well.   
     
     
         6 . The method of  claim 1 , wherein:
 the reservoir simulation model comprises a fluid flow capacity of the well, a plurality of layers, and a corresponding plurality of layer fluid flow capacities; and   determining the normalized fluid flow capacity comprises determining a quotient of a second combination of the plurality of layer fluid flow capacities and the fluid flow capacity of the well.   
     
     
         7 . The method of  claim 5 , wherein determining the first combination comprises performing integration with respect to depth. 
     
     
         8 . The method of  claim 1 , wherein updating the reservoir simulation model is based, at least in part, on a difference between the normalized cumulative fluid flow rate and the normalized fluid flow capacity. 
     
     
         9 . The method of  claim 1 , further comprising,
 receiving, using the reservoir simulator, a fluid pressure distribution at a first time, wherein the fluid pressure distribution represents fluid pressure throughout at least a first portion of the hydrocarbon reservoir; and   simulating, using the reservoir simulator and the updated reservoir simulation model, the fluid pressure distribution at a second time, wherein the second time is later than the first time.   
     
     
         10 . The method of  claim 9 , further comprising:
 identifying, using a reservoir interpretation system, a location for drilling an infill well based, at least in part, on the fluid pressure distribution at the second time;   planning, using a wellbore planning system, a wellbore trajectory to intersect the location; and   drilling, using a drilling system, the infill well guided by the planned wellbore trajectory.   
     
     
         11 . A system comprising:
 a flowmeter configured to measure a measured fluid flow rate at a plurality of depths in a well penetrating a hydrocarbon reservoir; and   a reservoir simulator configured to receive the measured fluid flow rate at a plurality of depths and to:
 determine a normalized cumulative fluid flow rate for the well based on the measured fluid flow rate at the plurality of depths, 
 receive a reservoir simulation model for the hydrocarbon reservoir, 
 determine a normalized fluid flow capacity for the well based on the reservoir simulation model, and 
 update the reservoir simulation model based, at least in part, on the normalized cumulative fluid flow rate and the normalized fluid flow capacity. 
   
     
     
         12 . The system of  claim 11 , wherein the reservoir simulation model comprises a permeability matrix. 
     
     
         13 . The system of  claim 11 , wherein the reservoir simulation model comprises a fracture permeability. 
     
     
         14 . The system of  claim 11 , wherein:
 the reservoir simulation model comprises a fluid flow capacity of the well, a plurality of layers, and a corresponding plurality of layer fluid flow capacities, and   the reservoir simulator is further configured to determine the normalized fluid flow capacity based on a quotient of a first combination of the plurality of layer fluid flow capacities and the fluid flow capacity of the well.   
     
     
         15 . The system of  claim 11 , wherein the reservoir simulator is further configured to determine the normalized cumulative fluid flow rate based, at least in part, on a second combination of the measured fluid flow rate at the plurality of depths. 
     
     
         16 . The system of  claim 15 , wherein the reservoir simulator is further configured to determine the second combination by performing integration with respect to depth. 
     
     
         17 . The system of  claim 15 , wherein
 the measured fluid flow rate at the plurality of depths comprises a measured fluid flow rate at a surface of the well; and   the reservoir simulator is further configured to determine the normalized cumulative fluid flow rate based on a quotient between the second combination and the measured fluid flow rate at the surface of the well.   
     
     
         18 . The system of  claim 11 , wherein the reservoir simulator is further configured to update the reservoir simulation model based, at least in part, on a difference between the normalized cumulative fluid flow rate and the normalized fluid flow capacity. 
     
     
         19 . The system of  claim 11 , wherein the reservoir simulator is further configured to:
 receive a fluid pressure distribution at a first time, wherein the fluid pressure distribution represents fluid pressure throughout at least a first portion of the hydrocarbon reservoir; and   simulate, using the updated reservoir simulation model, the fluid pressure distribution at a second time.   
     
     
         20 . The system of  claim 19 , further comprising:
 a reservoir interpretation system configured to identify a location for drilling an infill well based, at least in part, on the fluid pressure distribution at the second time;   a wellbore planning system configured to plan a wellbore trajectory to intersect the location; and   a drilling system configured to drill the infill well guided by the planned wellbore trajectory.