Abstract:
A method of optimizing performance of a well system utilizes a neural network. In a described embodiment, the method includes the step of accumulating data indicative of the performance of the well system in response to variable influencing parameters. The data is used to train a neural network to model an output of the well system in response to the influencing parameters. An output of the neural network may then be input to a valuing model, e.g., to permit optimization of a value of the well system. The optimization process yields a set of prospective influencing parameters which may be incorporated into the well system to maximize its value.

Description:
CROSS-REFERENCE TO RELATED APPLICATION  
       [0001]    The present application claims the benefit under 35 USC §119 of the filing date of prior PCT application no. PCT/US01/09454, filed Mar. 21, 2001, the disclosure of which is incorporated herein by this reference. 
     
    
     
       BACKGROUND  
         [0002]    The present invention relates generally to methods of optimizing the performance of subterranean wells and, in an embodiment described herein, more particularly provides a method of optimizing fields, reservoirs and/or individual wells utilizing neural networks.  
           [0003]    Production of hydrocarbons from a field or reservoir is dependent upon a wide variety of influencing parameters. In addition, a rate of production from a particular reservoir or zone is typically limited by the prospect of damage to the reservoir or zone, water coning, etc., which may diminish the total volume of hydrocarbons recoverable from the reservoir or zone. Thus, the rate of production should be regulated so that an acceptable return on investment is received while enhancing the ultimate volume of hydrocarbons recovered from the reservoir or zone.  
           [0004]    The rate of production from a reservoir or zone is only one of many parameters which may affect the performance of a well system. Furthermore, if one of these parameters is changed, another parameter may be affected, so that it is quite difficult to predict how a change in a parameter will ultimately affect the well system performance.  
           [0005]    It would be very advantageous to provide a method whereby an operator of a well system could conveniently predict how the well system&#39;s performance would respond to changes in various parameters influencing the well system&#39;s performance. Furthermore, it would be very advantageous for the operator to be able to conveniently determine specific values for the influencing parameters which would optimize the economic value of the reservoir or field.  
         SUMMARY  
         [0006]    In carrying out the principles of the present invention, in accordance with an embodiment thereof, a method is provided which solves the above problem in the art.  
           [0007]    In one aspect of the present invention, a method is provided wherein a neural network is trained so that it models the performance of a well system. Data sets including known values for influencing parameters and known values for parameters indicative of the well system&#39;s performance in response to the influencing parameters are used to train the neural network. After training, the neural network may be used to predict how the well system&#39;s performance will be affected by changes in any of the influencing parameters.  
           [0008]    In another aspect of the present invention, the trained neural network may be used along with a reservoir model and a financial model to yield a net present value. Prospective influencing parameters may then be input to the neural network, so that the affects of these parameters on the net present value may be determined. In addition, optimization techniques may be utilized to determine how the influencing parameters might be set up to produce a maximum net present value.  
           [0009]    These and other features, advantages, benefits and objects of the present invention will become apparent to one of ordinary skill in the art upon careful consideration of the detailed description of representative embodiments of the invention hereinbelow and the accompanying drawings. 
       
    
    
     BRIEF DESCRIPTION OF THE DRAWINGS  
       [0010]    [0010]FIG. 1 is a schematic partially cross-sectional view of a method embodying principles of the present invention;  
         [0011]    [0011]FIG. 2 depicts a data accumulation step of the method;  
         [0012]    [0012]FIG. 3 depicts a neural network training step of the method;  
         [0013]    [0013]FIG. 4 depicts an optimizing step of the method; and  
         [0014]    [0014]FIG. 5 depicts another method embodying principles of the present invention. 
     
    
     DETAILED DESCRIPTION  
       [0015]    Representatively illustrated in FIG. 1 is a method  10  which embodies principles of the present invention. In the following description of the method  10  and other apparatus and methods described herein, directional terms, such as “above”, “below”, “upper”, “lower”, etc., are used only for convenience in referring to the accompanying drawings. Additionally, it is to be understood that the various embodiments of the present invention described herein may be utilized in various orientations, such as inclined, inverted, horizontal, vertical, etc., and in various configurations, without departing from the principles of the present invention.  
         [0016]    The method  10  is described herein as being used in conjunction with a well system including production wells  12 ,  14 ,  16  as depicted in FIG. 1. However, it is to be clearly understood that the method  10  is merely an example of a wide variety of methods which may incorporate principles of the present invention. Other examples include methods wherein the well system includes a greater or fewer number of wells, the well system includes one or more injection wells, the well system drains a greater or fewer number of reservoirs, the well system includes wells which produce from, or inject into, a greater or fewer number of zones, etc. Thus, the principles of the present invention may be used in methods wherein the well system is merely one well draining a single reservoir via one zone intersected by the well, and in methods wherein a large number of wells are used to drain multiple reservoirs and water flood or steam injection, etc., is used to enhance production.  
         [0017]    As depicted in FIG. 1, each of the wells  12 ,  14 ,  16  intersects two reservoirs  18 ,  20 . Two production valves or chokes are used in each well to regulate production from the individual reservoirs, that is, well  12  includes valves V 1  and V 2  to regulate production from reservoirs  18 ,  20 , respectively, well  14  includes valves V 3 , V 4  to regulate production from reservoirs  18 ,  20 , respectively, and well  16  includes valves V 5 , V 6  to regulate production from reservoirs  18 ,  20 , respectively.  
         [0018]    An output of well  12  is designated Q 1 , an output of well  14  is designated Q 2 , and an output of well  16  is designated Q 3  in FIG. 1. These outputs Q 1 , Q 2 , Q 3  include parameters such as production rate of oil, production rate of gas, production rate of water, oil quality, gas quality, etc. These parameters are indicative of the output of each well. Of course, other parameters, and greater or fewer numbers of parameters, may be used to indicate a well&#39;s output in methods embodying principles of the present invention. In addition, it should be understood that, as used herein, the term “well output” is used to indicate performance of a well and may be used to describe the performance of an injection well, as well as the performance of a production well. For example, the “output” of an injection well may be indicated by parameters such as injection rate, steam temperature, etc.  
         [0019]    It will be readily appreciated that the outputs Q 1 , Q 2 , Q 3  may be changed by varying the positions of the valves V 1 , V 2 , V 3 , V 4 , V 5 , V 6 . For example, by decreasing the flow area through the valve V 1 , production from the reservoir  18  in the well  12  may be decreased, and by increasing the flow area through the valve V 2 , production from the reservoir  20  in the well  12  may be increased.  
         [0020]    However, since production from the reservoir  18  in any of the wells  12 ,  14 ,  16  influences production from the reservoir  18  in the other wells, production from the reservoir  20  influences production from the reservoir  20  in the other wells, and production from either of the reservoirs may influence production from the other reservoir, the outputs Q 1 , Q 2 , Q 3  of the wells are interrelated in a very complex manner. In addition, production rates from each of the reservoirs  18 ,  20  should be maintained within prescribed limits to prevent damage to the reservoirs, while ensuring efficient and economical operation of the wells  12 ,  14 ,  16 .  
         [0021]    In the method  10 , data is accumulated to facilitate training of a neural network  22  (see FIG. 3), so that the neural network may be used to predict the well outputs Q 1 , Q 2 , Q 3  in response to parameters influencing those outputs. The data is representatively illustrated in FIG. 2 as multiple data sets  24 . The data sets  24  include parameters  26  influencing the outputs of the individual wells  12 ,  14 ,  16  and parameters  28  indicative of the well outputs Q 1 , Q 2 , Q 3 . In the simplified example depicted in FIG. 2, the influencing parameters  26  are positions of the valves Vi, V 2 , V 3 , V 4 , V 5 , V 6  at n instances. Thus, data set  1  includes a position V 1 , 1  of valve V 1 , position V 2 , 1  of valve V 2 , position V 3 , 1  of valve V 3 , etc. The indicative parameters  28  include production rates from the wells  12 ,  14 ,  16 . Thus, data set  1  includes a production rate Q 1 , 1  from well  12 , a production rate Q 2 , 1  from well  14  and a production rate Q 3 , 1  from well  16 .  
         [0022]    It is to be clearly understood that the influencing parameters  26  and indicative parameters  28  used in the simplified example of data sets  24  depicted in FIG. 2 are merely examples of a wide variety of parameters which may be used to train neural networks in methods embodying principles of the present invention. For example, another influencing parameter could be steam injection rate, and another indicative parameter could be oil gravity or water production rate, etc. Therefore, it may be seen that any parameters which influence or indicate well output may be used in the data sets  24 , without departing from the principles of the present invention.  
         [0023]    The data sets  24  are accumulated from actual instances recorded for the wells  12 ,  14 ,  16 . The data sets  24  may be derived from historical data including the various instances, or the data sets may be accumulated by intentionally varying the influencing parameters  26  and recording the indicative parameters  28  which result from these variations.  
         [0024]    Referring additionally now to FIG. 3, the neural network  22  is trained using the data sets  24 . Specifically, the influencing parameters  26  are input to the neural network  22  to train the neural network to output the indicative parameters  28  in response thereto. Such training methods are well known to those skilled in the neural network art.  
         [0025]    The neural network  22  may be any type of neural network, such as a perceptron network, Hopfield network, Kohonen network, etc. Furthermore, the training method used in the method  10  to train the network  22  may be any type of training method, such as a back propagation algorithm, the special algorithms used to train Hopfield and Kohonen networks, etc.  
         [0026]    After the neural network  22  has been trained, it will output the indicative parameters  28  in response to input thereto of the influencing parameters  26 . Thus, the neural network  22  becomes a model of the well system. At this point, prospective values for the influencing parameters may be input to the neural network  22  and, in response, the neural network will output resulting values for the indicative parameters. That is, the neural network  22  will predict how the well system will respond to chosen values for the influencing parameters. For example, in the method  10 , the neural network  22  will predict the outputs Q 1 , Q 2 , Q 3  for the wells  12 ,  14 ,  16  in response to inputting prospective positions of the valves V 1 , V 2 , V 3 , V 4 , V 5 , V 6  to the neural network.  
         [0027]    The output of the neural network  22  may be very useful in optimizing the economic value of the reservoirs  18 ,  20  drained by the well system. As discussed above, production rates can influence the ultimate quantity and quality of hydrocarbons produced from a reservoir, and this affects the value of the reservoir, typically expressed in terms of “net present value” (NPV).  
         [0028]    Referring additionally now to FIG. 4, the method  10  is depicted wherein the neural network  22 , trained as described above and illustrated in FIG. 2, is used to evaluate the NPV of the reservoirs  18 ,  20 . The neural network  22  output is input to a conventional geologic model  30  of the reservoirs  18 ,  20  drained by the well system. The reservoir model  30  is capable of predicting changes in the reservoirs  18 ,  20  due to changes in the well system as output by the neural network  22 . An example of such a reservoir model is described in U.S. patent application Ser. No. 09/357,426, entitled A SYSTEM AND METHOD FOR REAL TIME RESERVOIR MANAGEMENT, the entire disclosure of which is incorporated herein by this reference.  
         [0029]    The output of the reservoir model  30  is then input to a conventional financial model  32 . The financial model  32  is capable of predicting an NPV based on the reservoir characteristics output by the reservoir model  30 .  
         [0030]    As shown in FIG. 4, prospective positions for the valves V 1 , V 2 , V 3 , V 4 , V 5 , V 6  are input to the trained neural network  22 . The neural network  22  predicts outputs Q 1 , Q 2 , Q 3  of the well system, which are input to the reservoir model  30 . The reservoir model  30  predicts the effects of these well outputs Q 1 , Q 2 , Q 3  on the reservoirs  18 ,  20 . The financial model  32  receives the output of the reservoir model  30  and predicts an NPV. Thus, an operator of the well system can immediately predict how a prospective change in the positions of one or more production valves will affect the NPV.  
         [0031]    In addition, using conventional numerical optimization techniques, the operator can use the combined neural network  22 , reservoir model  30  and financial model  32  to obtain a maximum NPV. That is, the combined neural network  22 , reservoir model  30  and financial model  32  may be used to determine the positions of the valves V 1 , V 2 , V 3 , V 4 , V 5 , V 6  which maximize the NPV.  
         [0032]    Referring additionally now to FIG. 5, another method  40  embodying principles of the present invention is representatively illustrated. Rather than modeling the performance of a field including multiple wells, as in the method  10 , the method  40  utilizes a neural network  42  to model the performance of a single well, such as the well  12  described above and depicted in FIG. 1.  
         [0033]    In the method  40 , the data sets  44  used to train the neural network include instances of positions of the valves V 1  and V 2 , and resulting instances of production rates of oil (Qoil), production rates of water (Qwater) and production rates of gas (Qgas) from the well  12 . As shown in FIG. 5, the valve positions are input to the neural network  42 , and the neural network is trained to output the resulting production rates Qoil, Qwater, Qgas in response. Thus, the neural network  42  in the method  40  models the performance of the well  12  (a well system having a single well).  
         [0034]    Similar to the method  10 , the neural network  42  in the method  40  may be used to predict the performance of the well  12  in response to input to the neural network of prospective positions of the valves V 1 , V 2  after the neural network is trained. An operator of the well  12  can, thus, predict how the performance of the well  12  will be affected by changes in the positions of the valves V 1 , V 2 . Use of a reservoir model and a financial model, as described above for the method  10 , will also permit an operator to predict how the NPV will be affected by the changes in the positions of the valves V 1 , V 2 . Furthermore, numerical optimization techniques may be utilized to determine positions of the valves V 1 , V 2  which maximize the NPV.  
         [0035]    The method  40 , thus, demonstrates that the principles of the present invention may be utilized for well systems of various configurations. Note, also, that neural networks may be trained in various manners, for example, to predict various parameters indicative of well system performance, in keeping with the principles of the present invention.  
         [0036]    Of course, a person skilled in the art would, upon a careful consideration of the above description of representative embodiments of the invention, readily appreciate that many modifications, additions, substitutions, deletions, and other changes may be made to the specific embodiments, and such changes are contemplated by the principles of the present invention. Accordingly, the foregoing detailed description is to be clearly understood as being given by way of illustration and example only, the spirit and scope of the present invention being limited solely by the appended claims.