Methods and Systems For Determination of Fluid Invasion In Reservoir Zones

Abstract

Methods and systems are described for stimulating a subterranean hydrocarbon-bearing reservoir, one method comprising contacting the formation with a treating fluid, and monitoring the movement of the treating fluid in the reservoir by providing one or more sensors for measurement of temperature and/or pressure which is disposed on a support adapted to maintain a given spacing between the sensors and the fluid exit. In some embodiments the support is coiled tubing. This abstract allows a searcher or other reader to quickly ascertain the subject matter of the disclosure. It will not be used to interpret or limit the scope or meaning of the claims.

1 . A method comprising: 
 (a) contacting a hydrocarbon-bearing reservoir with a treatment fluid;    (b) monitoring the movement of the treatment fluid in the reservoir by providing one or more sensors for measurement of temperature and/or pressure, wherein the sensors are disposed on a support adapted to maintain a given spacing between the sensors and the fluid exit; and,    (c) adjusting one or more parameters selected from composition of the treatment fluid, injection rate of the treatment fluid, and pressure of the treatment fluid in response to the monitoring of movement.    
   
   
       2 . The method of  claim 1  wherein the adjusting is made in real time.  
   
   
       3 . The method of  claim 1  wherein the support is coiled tubing.  
   
   
       4 . The method of  claim 1  wherein the support extends substantially along a full length of a wellbore extending into the reservoir.  
   
   
       5 . The method of  claim 1  wherein the treatment fluid and a second fluid are injected from different flow paths.  
   
   
       6 . The method of  claim 1  wherein the support comprises a tubular and the one or more sensors comprises at least one temperature sensor placed at a known location on the tubular, the method further comprising: 
 (a) inserting the tubular into a wellbore extending into the reservoir, the tubular comprising a section of tubing having at least one treatment fluid injection port;    (b) the contacting comprises injecting the treatment fluid through the at least one fluid injection port;    (c) generating diagnostic plot curves of temperature derivative with respect to time and temperature derivative with respect to tubular depth, both obtained at a known fixed distance from the treatment fluid injection port; and    (d) interpreting shape of the diagnostic plot curves to determine location of regions of the hydrocarbon-bearing reservoir exhibiting flow of the injected treatment fluid, where the flow ranges from zero to a non-zero value.    
   
   
       7 . The method of  claim 6  wherein the generating diagnostic plot curves occurs in real time.  
   
   
       8 . The method of  claim 6  wherein the interpreting shape of the diagnostic plot curves employs one or more plot curve interpretation algorithms for temperature and/or pressure to identify regions in the reservoir that are readily accepting the treatment fluid.  
   
   
       9 . The method of  claim 6  comprising smoothing the diagnostic plot curves to reduce any noise in the diagnostic plot curves prior to the interpreting shape of the diagnostic plot curves.  
   
   
       10 . The method of  claim 1  comprising moving the support during the monitoring.  
   
   
       11 . The method of  claim 1  wherein the support comprises a tubular and the one or more sensors comprises at least one temperature sensor placed at a known location on the tubular, the method further comprising: 
 (a) inserting the tubular into a wellbore in the reservoir, the tubular comprising a section of tubing having at least one treatment fluid injection port;    (b) the contacting comprises injecting the treatment fluid through the tubular and through the at least one treatment fluid injection port; and    (c) measuring time of arrival of the injected treatment fluid at the temperature sensor.    
   
   
       12 . The method of  claim 11  comprising providing two or more temperature sensors and measuring the time for the injected treatment fluid to travel between two temperature sensors.  
   
   
       13 . The method of  claim 1  wherein the support comprises a tubular and the one or more sensors comprises at least one temperature sensor placed at a known location on the tubular, the method further comprising: 
 (a) inserting the tubular into a wellbore in the reservoir, the tubular comprising a section of tubing having at least one treatment fluid injection port;    (b) injecting the treatment fluid through the tubular, through the section of tubular, and through the at least one treatment fluid injection port, the treatment fluid having a first fluid property value;    (c) injecting a second fluid through an annulus between the tubular and the wellbore, the second fluid having a second fluid property value that is different from the first fluid property value; and    (d) measuring a differential between the first and second fluid property values.    
   
   
       14 . The method of  claim 13  comprising tracking a fluid interface between the treatment fluid and the second fluid, and if the interface is not at a desired location in the wellbore, adjusting flow rate of the treatment fluid, the second fluid, or both to move the interface to the desired location.  
   
   
       15 . The method of  claim 1  wherein the support comprises a tubular and the one or more sensors comprises at least one temperature sensor placed at a known location on the tubular, comprising 
 (a) predicting temperatures as a function of reservoir permeability distribution at the one or more sensors placed at known locations on the tubular;    (b) inserting the tubular into the wellbore, the tubular comprising a tubular section having at least one treatment fluid injection port;    (c) injecting the treatment fluid through the at least one fluid injection port;    (d) measuring actual temperatures at the one or more sensors; and    (e) calculating error between the predicted and the measured temperatures, and minimizing the errors by iteratively adjusting the permeability distribution along the wellbore length.    
   
   
       16 . A system comprising: 
 (a) a support adapted to maintain a given spacing between one or more sensors for measurement of temperature and/or pressure in a hydrocarbon-bearing reservoir, the support comprising a fluid inlet, a fluid passage, and at least one treatment fluid injection port;    (b) and means for monitoring movement of a treatment fluid in the reservoir.    
   
   
       17 . The system of  claim 16  wherein the support comprises a tubular comprising a section of tubing having the at least one fluid injection port and at least one temperature sensor placed at a known location on the tubular, the system further comprising: 
 (a) a pump for injecting the treatment fluid through the tubular, through the section of tubular, and through the at least one fluid injection port;    (b) a unit for generating diagnostic plot curves of temperature derivative with respect to time and temperature derivative with respect to coiled tubing depth, both obtained at a known fixed distance from the treatment fluid injection port; and    (c) a curve shape interpreting unit for interpreting the curves to determine location of regions of a hydrocarbon-bearing reservoir exhibiting flow of the injected fluid, where the flow ranges from zero to a non-zero value.    
   
   
       18 . The system of  claim 16  wherein the support comprises a tubular comprising a section of tubing having the at least one treatment fluid injection port and at least one temperature sensor placed at a known location on the tubular, the system further comprising: 
 (a) a pump for injecting the treatment fluid through the tubular, thorough the section of tubular, and through the at least one treatment fluid injection port; and    (b) a measuring unit for measuring time of arrival of the injected treatment fluid at the temperature sensor.    
   
   
       19 . The system of  claim 16  wherein the support comprises a tubular comprising a section of tubular having the at least one treatment fluid injection port and at least one temperature sensor placed at a known location on the tubular, the system further comprising: 
 (a) a first pump for injecting the treatment fluid through the tubular, through the section of tubular, and through the at least one treatment fluid injection port, the treatment fluid having a first fluid property value;    (b) a second pump for injecting a second fluid through an annulus between the tubular and the wellbore, the second fluid having a second fluid property value that is different from the first fluid property value; and    (c) a measuring unit for measuring a differential between the first and second fluid property values.    
   
   
       20 . The system of  claim 16  wherein the support comprises a tubular comprising a section of tubular having the at least one treatment fluid injection port and at least one temperature sensor placed at a known location on the tubular, the system further comprising: 
 (a) a prediction unit for predicting a temperature as a function of reservoir permeability distribution at one or more sensors placed at known locations on the tubular to be injected into a wellbore of a reservoir;    (b) means for inserting the tubular into the wellbore;    (c) a pump for injecting the treatment fluid through the tubular, through the section of tubular, and through the at least one treatment fluid injection port;    (d) a measuring unit for measuring actual temperatures at the one or more sensors; and    (e) a calculation unit for calculating error between the predicted and the measured temperatures, and for minimizing the errors by iteratively adjusting the permeability distribution along the wellbore length.    
   
   
       21 . A method of treating a subterranean formation comprising: 
 (a) providing a support comprising a tubular and one or more sensors, the one or more sensors comprising at least one temperature sensor placed at a known location on the tubular;    (b) inserting the tubular into a wellbore extending into the reservoir, the tubular comprising a section of tubing having at least one treatment fluid injection port;    (d) contacting a hydrocarbon-bearing reservoir with a treatment fluid; and,    (e) monitoring the movement of the treatment fluid in the reservoir by providing one or more sensors for measurement of temperature and/or pressure, wherein the sensors are disposed on a support adapted to maintain a given spacing between the sensors and the fluid exit.