Patent Publication Number: US-RE42245-E

Title: System and method for real time reservoir management

Description:
The present application is a continuation of U.S. patent application Ser. No. 09/976,573, filed Oct. 12, 2001 now U.S. Pat. No. 6,853,921 which is a continuation-in-part of U.S patent application Ser. No. 09/816,044 now U.S. Pat. No. 6,356,844, filed Mar. 23, 2001 which is a continuation of Ser. No. 09/357,426 now U.S. Pat. No. 6,266,619, filed Jul. 20, 1999, all of which are hereby incorporated by reference in their entirety as if reproduced herein.This Reissue application Ser. No.  12 / 436 , 632 , filed May  6 ,  2009 , is a divisional of Reissue application Ser. No.  11 / 704 , 369 , filed on Feb.  8 ,  2007 , currently pending, both reissue applications are a reissue of U.S. application Ser. No.  10 / 929 , 584 , filed Aug.  30 ,  2004 , now U.S. Pat. No.  7 , 079 , 952 , which is a continuation of U.S. patent application Ser. No.  09 / 976 , 573 , filed Oct.  12 ,  2001  now U.S. Pat. No.  6 , 853 , 921  which is a continuation- in - part of U.S. patent application Ser. No.  09 / 816 , 044  filed Mar.  23 ,  2001 , now U.S. Pat. No.  6 , 356 , 844 , which is a continuation of U.S. patent application Ser. No.  09 / 357 , 426 , filed Jul.  20 ,  1999 , now U.S. Pat. No.  6 , 266 , 619 . The disclosures of the prior applications are considered part of  ( and are incorporated by reference in )  the disclosure of this application.   
    
    
     BACKGROUND 
     Historically, most oil and gas reservoirs have been developed and managed under timetables and scenarios as follows: a preliminary investigation of an area was conducted using broad geological methods for collection and analysis of data such as seismic, gravimetric, and magnetic data, to determine regional geology and subsurface reservoir structure. In some instances, more detailed seismic mapping of a specific structure was conducted in an effort to reduce the high cost, and the high risk, of an exploration well. A test well was then drilled to penetrate the identified structure to confirm the presence of hydrocarbons, and to test productivity. In lower-cost onshore areas, development of a field would commence immediately by completing the test well as a production well. In higher cost or more hostile environments such as the North Sea, a period of appraisal would follow, leading to a decision as to whether or not to develop the project. In either case, based on inevitably sparse data, further development wells, both producers and injectors would be planned in accordance with a reservoir development plan. Once production and/or injection began, more dynamic data would become available, thus, allowing the engineers and geoscientists to better understand how the reservoir rock was distributed and how the fluids were flowing. As more data became available, an improved understanding of the reservoir was used to adjust the reservoir development plan resulting in the familiar pattern of recompletion, sidetracks, infill drilling, well abandonment, etc. Unfortunately, not until the time at which the field was abandoned, and when the information is the least useful, did reservoir understanding reach its maximum. 
     Limited and relatively poor quality of reservoir data throughout the life of the reservoir, coupled with the relatively high cost of most types of well intervention, implies that reservoir management is as much an art as a science. Engineers and geoscientists responsible for reservoir management discussed injection water, fingering, oil-water contacts rising, and fluids moving as if these were a precise process. The reality, however, is that water expected to take three years to break through to a producing well might arrive in six months in one reservoir but might never appear in another. Text book “piston like” displacement rarely happens, and one could only guess at flood patterns. 
     For some time, reservoir engineers and geoscientists have made assessments of reservoir characteristics and optimized production using down hole test data taken at selected intervals. Such data usually includes traditional pressure, temperature and flow data is well known in the art. Reservoir engineers have also had access to production data for the individual wells in a reservoir. Such data as oil, water and gas flow rates are generally obtained by selectively testing production from the selected well at selected intervals. 
     Recent improvements in the state of the art regarding data gathering, both down hole and at the surface, have dramatically increased the quantity and quality of data gathered. Examples of such state of the art improvements in data acquisition technology include assemblies run in the casing string comprising a sensor probe with optional flow ports that allow fluid inflow from the formation into the casing while sensing wellbore and/or reservoir characteristics as described and disclosed in international PCT application WO. 97/49894, assigned to Baker Hughes, the disclosure of which is incorporated herein by reference. The casing assembly may further include a microprocessor, a transmitting device, and a controlling device located in the casing string for processing and transmitting real time data. A memory device may also be provided for recording data relating to the monitored wellbore or reservoir characteristics. Examples of down hole characteristics which may be monitored with such equipment include: temperature, pressure, fluid flow rate and type, formation resistivity, cross-well and acoustic seismometry, perforation depth, fluid characteristics and logging data. Using a microprocessor, hydrocarbon production performance may be enhanced by activating local operations in additional downhole equipment. A similar type of casing assembly used for gathering data is described and illustrated in international PCT application WO 98/12417, assigned to BP Exploration Operating Company Limited, the disclosure of which is incorporated by reference. 
     Recent technology improvements in downhole flow control devices are disclosed in UK Patent Application GB 2,320,731A which describes a number of downhole flow control devices which may be used to shut off particular zones by using downhole electronics and programing with decision making capacity, the disclosure of which is incorporated by reference. 
     Another important emerging technology that may have a substantial impact on managing reservoirs is time lapsed seismic, often referred to a 4-D seismic processing. In the past, seismic surveys were conducted only for exploration purposes. However, incremental differences in seismic data gathered over time are becoming useful as a reservoir management tool to potentially detect dynamic reservoir fluid movement. This is accomplished by removing the non-time varying geologic seismic elements to produce a direct image of the time-varying changes caused by fluid flow in the reservoir. By using 4-D seismic processing, reservoir engineers can locate bypassed oil to optimize infill drilling and flood pattern. Additionally, 4-D seismic processing can be used to enhance the reservoir model and history match flow simulations. 
     International PCT application WO 98/07049, assigned to Geo-Services, the disclosure of which is incorporated herein by reference, describes and discloses state of the art seismic technology applicable for gathering data relevant to a producing reservoir. The publication discloses a reservoir monitoring system comprising: a plurality of permanently coupled remote sensor nodes, wherein each node comprises a plurality of seismic sensors and a digitizer for analog signals; a concentrator of signals received from the plurality of permanently coupled remote sensor nodes; a plurality of remote transmission lines which independently connect each of the plurality of remote sensor nodes to the concentrator, a recorder of the concentrated signals from the concentrator, and a transmission line which connects the concentrator to the recorder. The system is used to transmit remote data signals independently from each node of the plurality of permanently coupled remote sensor nodes to a concentrator and then transmit the concentrated data signals to a recorder. Such advanced systems of gathering seismic data may be used in the reservoir management system of the present invention as disclosed hereinafter in the Detailed Description section of the application. 
     Historically, down hole data and surface production data has been analyzed by pressure transient and production analysis. Presently, a number of commercially available computer programs such as Saphir and PTA are available to do such an analysis. The pressure transient analysis generates output data well known in the art, such as permeability-feet, skin, average reservoir pressure and the estimated reservoir boundaries. Such reservoir parameters may be used in the reservoir management system of the present invention. 
     In the past and present, geoscientists, geologists and geophysicists (sometimes in conjunction with reservoir engineers) analyzed well log data, core data and SDL data. The data was and may currently be processed in log processing/interpretation programs that are commercially available, such as Petroworks and DPP. Seismic data may be processed in programs such as Seisworks and then the log data and seismic data are processed together and geostatistics applied to create a geocellular model. 
     Presently, reservoir engineers may use reservoir simulators such as VIP or Eclipse to analyze the reservoir. Nodal analysis programs such as WEM, Prosper and Openflow have been-used in conjunction with material balance programs and economic analysis programs such as Aries and ResEV to generate a desired field wide production forecast. Once the field wide production has been forecasted, selected wells may be produced at selected rates to obtain the selected forecast rate. Likewise, such analysis is used to determine field wide injection rates for maintenance of reservoir pressure and for water flood pattern development. In a similar manner, target injection rates and zonal profiles are determined to obtain the field wide injection rates. 
     It is estimated that between fifty and seventy percent of a reservoir engineer&#39;s time is spent manipulating data for use by each of the computer programs in order for the data gathered and processed by the disparate programs (developed by different companies) to obtain a resultant output desired field wide production forecast. Due to the complexity and time required to perform these functions, frequently an abbreviated incomplete analysis is performed with the output used to adjust a surface choke or recomplete a well for better reservoir performance without knowledge of how such adjustment will affect reservoir management as a whole. 
     SUMMARY OF THE INVENTION 
     The present invention comprises a field wide management system for a petroleum reservoir on a real time basis. Such a field wide management system includes a suite of tools (computer programs) that seamlessly interface with each other to generate a field wide production and injection forecast. The resultant output of such a system is the real time control of downhole production and injection control devices such as chokes, valves and other flow control devices and real time control of surface production and injection control devices. Such a system and method of real time field wide reservoir management provides for better reservoir management, thereby maximizing the value of the asset to its owner. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
       The disclosed invention will be described with reference to the accompanying drawings, which show important sample embodiments of the invention and which are incorporated in the specification hereof by reference. A more complete understanding of the present invention may be had by reference to the following Detailed Description when taken in conjunction with the accompanying drawings, wherein: 
         FIG. 1  is a block diagram of the method of field wide reservoir management of the present invention; 
         FIG. 2  is a cross section view of a typical well completion system that may be used in the practice of the present invention; 
         FIG. 3  is a cross section of a flat back cable that may be used to communicate data from sensors located in a wellbore to the data management and analysis functions of the present invention and communicate commands from the reservoir management system of the present invention to adjust downhole well control devices; 
         FIG. 4  is a block diagram of the system of real time reservoir management of the present invention;  FIG. 4  is a generalized diagrammatic illustration of one exemplary embodiment of the system of  FIG. 4 ; 
         FIG. 5  illustrates exemplary operations which can be performed by the controller of  FIG. 4A  to implement the data management function of  FIG. 4 ; 
         FIG. 6  illustrates exemplary operations which can be performed by the controller of  FIG. 4A  to implement the nodal analysis function and the material balance function of  FIG. 4 ; 
         FIG. 7  illustrates exemplary operations which can be performed by the controller of  FIG. 4A  to implement the reservoir simulation function of  FIG. 4 ; and 
         FIG. 8  illustrates exemplary operations which can be performed by the controller of  FIG. 4A  to implement the risked economics function of FIG.  4 . 
     
    
    
     DETAILED DESCRIPTION 
     Reference is now made to the Drawings wherein like reference characters denote like or similar parts throughout the Figures. 
     Referring now to  FIGS. 1 and 4 , the present invention comprises a method and system of real time field wide reservoir management. Such a system includes a suite of tools (computer programs of the type listed in Table 1) that seamlessly interface with each other in accordance with the method to generate a field wide production and injection forecast. It will be understood by those skilled in the art that the practice of the present invention is not limited to the use of the programs disclosed in Table 1. Programs listed in Table 1 are merely some of the programs presently available for practice of the invention. 
     The resultant output of the system and method of field wide reservoir management is the real time control of downhole production and injection control devices such as chokes, valves, and other flow control devices (as illustrated in  FIGS. 2 and 3  and otherwise known in the art) and real time control of surface production and injection control devices (as known in the art). The real time control described herein need not necessarily be instantaneous, but can be delayed depending on how the control is communicated to the downhole production and injection control devices. Field wide reservoir management does not require that every well in a field be controlled. 
     Efficient and sophisticated “field wide reservoir data” is necessary for the method and system of real time reservoir management of the present invention. Referring now to blocks  1 ,  2 ,  3 ,  5  and  7  of  FIG. 1 , these blocks represent some of the types of “field wide reservoir data” acquired generally through direct measurement methods and with devices as discussed in the background section, or by methods well known in the art, or as hereinafter set forth in the specification. It will be understood by those skilled in the art that it is not necessary for the practice of the subject invention to have all of the representative types of data, data collection devices and computer programs illustrated and described in this specification and the accompanying Figures, nor is the present invention limited to the types of data, data collection devices and computer programs illustrated herein. As discussed in the background section, substantial advancements have been made and are continuing to be made in the quality and quantity of data gathered. 
     In order to provide for more efficient usage of “field wide reservoir data”, the data may be divided into two broad areas: production and/or injection (hereinafter “production/injection”) data and geologic data. Production/injection data includes accurate pressure, temperature, viscosity, flow rate and compositional profiles made available continuously on a real time basis or, alternatively, available as selected well test data or daily average data. 
     Referring to box  18 , production/injection data may include downhole production data  1 , seabed production data  2  and surface production data  3 . It will be understood that the present invention may be used with land based petroleum reservoirs as well as subsea petroleum reservoirs. Production/injection data is pre-processed using pressure transient analysis in computer programs such as Saphir by Kappa Engineering or PTA by Geographix to output reservoir permeability, reservoir pressure, permeability-feet and the distance to the reservoir boundaries. 
     Referring to box  20 , geologic data includes log data, core data and SDL data represented by block  5  and seismic data represented by block  7 . Block  5  data is pre-processed as illustrated in block  6  using such computer programs such as Petroworks by Landmark Graphics, Prizm by Geographix and DPP by Halliburton to obtain water and oil saturations, porosity, and clay content. Block  5  data is also processed in stratigraphy programs as noted in block  6 A by programs such as Stratworks by Landmark Graphics and may be further pre-processed to map the reservoir as noted in block  6 B using a Z-Map program by Landmark Graphics. 
     Geologic data also includes seismic data block  7  that may be conventional or real time 4D seismic data (as discussed in the background section). Seismic data may be collected conventionally by periodically placing an array of hydrophones and geophones at selected places in the reservoir or 4D seismic may be collected on a real time basis using geophones placed in wells. Block  7  seismic data is processed and interpreted as illustrated in block  8  by such programs as Seisworks and Earthcube by Landmark Graphics to obtain hydrocarbon indicators, stratigraphy and structure. 
     Output from blocks  6  and  8  is further pre-processed as illustrated in block  9  to obtain geostatistics using Sigmaview by Landmark Graphics. Output from blocks  8 ,  9  and  6 B are input into the Geocellular (Earthmode) programs illustrated by block  10  and processed using the Stratamodel by Landmark Graphics. The resultant output of block  10  is then upscaled as noted in block  11  in Geolink by Landmark Graphics to obtain a reservoir simulation model. 
     Output from upscaling  11  is input into the data management function of block  12 . Production/injection data represented by downhole production  1 , seabed production  2  and surface production  3  may be input directly into the data management function  12  (as illustrated by the dotted lines) or pre-processed using pressure transient analysis as illustrated in block  4  as previously discussed. Data management programs may include Openworks, Open/Explorer, TOW/cs and DSS32, all available from Landmark Graphics and Finder available from Geoquest. 
     Referring to box  19  of  FIG. 1 , wherein there is disclosed iterative processing of data gathered by and stored in the data management program. Reservoir simulation may be accomplished by using data from the data management function  12  using VIP by Landmark Graphics or Eclipse by Geoquest. Material Balance calculations may be performed using data from the reservoir simulation  13  and data management function  12  to determine hydrocarbon volumes, reservoir drive mechanisms and production profiles, using MBAL program of Petroleum Experts. 
     Nodal Analysis  15  may be performed using the material balance data output of  14  and reservoir simulation data of  13  and other data such as wellbore configuration and surface facility configurations to determine rate versus pressure for various system configurations and constraints using such programs as WEM by P. E. Moseley and Associates, Prosper by Petroleum Experts, and Openflow by Geographix. 
     Risked Economics  16  may be performed using Aries or ResEV by Landmark Graphics to determine an optimum field wide production/injection rate. Alternatively, the target field wide production/injection rate may be fixed at a predetermined rate by factors such as product (oil and gas) transportation logistics, governmental controls, gas, oil or water processing facility limitations, etc. In either scenario, the target field wide production/injection rate may be allocated back to individual wells. 
     After production/injection for individual wells is calculated the reservoir management system of the present invention generates and transmits a real time signal used to adjust one or more interval control valves located in one or more wells or adjust one or more subsea control valves or one or more surface production control valves to obtain the desired flow or injection rate. As above, transmission of the real time signal is not necessarily instantaneous, and can be delayed depending on the communication method. For example, the reservoir management system may signal an operator to adjust a valve. The operator may then travel into the field to make the adjustment or may telephone another operator near the valve to make the adjustment. Also, it will be understood by those skilled in the art that an inter-relationship exists between the interval control valves. When one is opened, another may be closed. The desired production rate for an individual well may be input directly back into the data management function  12  and actual production from a well is compared to the target rate on a real time basis. The system may include programming for a band width of acceptable variances from the target rate such that an adjustment is only performed when the rate is outside the set point. 
     Opening or closing a control valve  17  to the determined position may have an almost immediate effect on the production/injection data represented by blocks  1 ,  2 ,  3 ; however, on a long term basis the reservoir as a whole is impacted and geologic data represented by blocks  5  and  7  will be affected (See dotted lines from control valve  17 ). The present invention continually performs iterative calculations as illustrated in box  19  using reservoir simulation  13 , material balance  14 , nodal analysis  15  and risked economics  16  to continuously calculate a desired field wide production rate and provide real time control of production/injection control devices. 
     The method on field wide reservoir management incorporates the concept of “closing the loop” wherein actual production data from individual wells and on a field basis. 
     To obtain an improved level of reservoir performance, downhole controls are necessary to enable reservoir engineers to control the reservoir response much like a process engineer controls a process facility. State of the art sensor and control technology now make it realistic to consider systematic development of a reservoir much as one would develop and control a process plant. An example of state of the art computers and plant process control is described in PCT application WO 98/37465 assigned to Baker Hughes Incorporated. 
     In the system and method of real time reservoir management of the present invention, the reservoir may be broken into discreet reservoir management intervals—typically a group of sands that are expected to behave as one, possibly with shales above and below. Within the wellbore, zonal isolation packers may be used to separate the producing and/or injection zones into management intervals. An example reservoir management interval might be 30 to 100 feet. Between zonal isolation packers, variable chokes may be used to regulate the flow of fluids into or out of the reservoir management interval. 
     U.S. Pat. No. 5,547,029 by Rubbo, the disclosure of which is incorporated by reference, discloses a controlled reservoir analysis and management system that illustrates equipment and systems that are known in the art and may be used in the practice of the present invention. Referring now to  FIG. 2 , one embodiment of a production well having downhole sensors and downhole control that has been successfully used in the Norwegian sector of the North Sea, the Southern Adriatic Sea and the Gulf of Mexico is the “SCRAMSJ” concept. It will be understood by those skilled in the art that the SCRAMSJ concept is one embodiment of a production well with sensors and downhole controls that may be used in practicing the subject invention. However, practice of the subject invention is not limited to the SCRAMSJ concept. 
     SCRAMSJ is a completion system that includes an integrated data-acquisition and control network. The system uses permanent downhole sensors and pressure-control devices as well known in the art that are operated remotely through a control network from the surface without the need for traditional well-intervention techniques. As discussed in the background section, continuous monitoring of downhole pressure, temperatures, and other parameters has been available in the industry for several decades, the recent developments providing for real-time subsurface production and injection control create a significant opportunity for cost reductions and improvements in ultimate hydrocarbon recovery. Improving well productivity, accelerating production, and increasing total recovery are compelling justifications for use of this system. 
     As illustrated in  FIG. 2 , the components of the SCRAMSJ System  100  may include: 
     (a) one or more interval control valves  110  which provide an annulus to tubing flow path  102  and incorporates sensors  130  for reservoir data acquisition. The system  100  and the interval control valve  110  includes a choking device that isolate the reservoir from the production tubing  150 . It will be understood by those skilled in the art that there is an inter-relationship between one control valve and another as one valve is directed to open another control valve may be directed to close; 
     (b) an HF Retrievable Production Packer  160  provides a tubing-to-casing seal and pressure barrier, isolates zones and/or laterals from the well bore  108  and allows passage of the umbilical  120 . The packer  160  may be set using one-trip completion and installation and retrieval. The packer  160  is a hydraulically set packer that may be set using the system data communications and hydraulic power components. The system may also include other components as well known in the industry including SCSSV  131 , SCSSV control line  132 , gas lift device  134 , and disconnect device  136 . It will be understood by those skilled in the art that the well bore log may be cased partially having an open hole completion or may be cased entirely. It will also be understood that the system may be used in multilateral completions; 
     (c) SEGNETJ Protocol Software is used to communicate with and power the SCRAMSJ system. The SEGNETJ software, accommodates third party products and provides a redundant system capable of by-passing failed units on a bus of the system; 
     (d) a dual flatback umbilical  120  which incorporates electro/hydraulic lines provides SEGNET communication and control and allows reservoir data acquired by the system to be transmitted to the surface. 
     Referring to  FIG. 3 , the electro and hydraulic lines are protected by combining them into a reinforced flatback umbilical  120  that is run external to the production-tubing string (not shown). The flatback  120  comprises two galvanized mild steel bumber bars  121  and  122  and an incolony ¼ inch tube  123  and  124 . Inside tube  124  is a copper conductor  125 . The flatback  120  is encased in a metal armor  126 ; and 
     (e) a surface control unit  160  operates completion tools, monitors the communications system and interfaces with other communication and control systems. It will be understood that an interrelationship exists between flow control devices as one is directed to open another may be directed to close. 
     A typical flow control apparatus for use in a subterranean well that is compatible with the SCRAMSJ system is illustrated and described in pending U.S. patent application Ser. No. 08/898,567 filed Jul. 21, 1997 by inventor Brett W. Boundin, the disclosure of which is incorporated by reference. 
     Referring now to blocks  21 ,  22 ,  23  of  FIG. 4 , these blocks represent sensors as illustrated in  FIG. 2 , or discussed in the background section (and/or as known in the art) used for collection of data such as pressure, temperature and volume, and 4D seismic. These sensors gather production/injection data from one or more wells that includes accurate pressure, temperature, viscosity, flow rate and compositional profiles available continuously on a real time basis. 
     Referring to box  38 , in the system of the present invention, production/injection data is pre-processed using pressure transient analysis programs  24  in computer programs such as Saphir by Kappa Engineering or PTA by Geographix to output reservoir permeability, reservoir pressure, permeability-feet and the distance to the reservoir boundaries. 
     Referring to box  40 , geologic data including log, cores and SDL is collected with devices represented by blocks  25  and  26  as discussed in the background section, or by data sensors and collections well known in the art. Block  25  data is pre-processed as illustrated in block  26  using such computer programs Petroworks by Landmark Graphics, Prizm by Geographix and DPP by Halliburton to obtain water and oil saturations, porosity, and clay content. Block  25  data is also processed in stratigraphy programs as noted in block  26 A by programs such as Stratworks by Landmark Graphics and may be further pre-processed to map the reservoir as noted in block  26 B using a Z-Map program by Landmark Graphics. 
     Geologic data also includes seismic data obtained from collectors known in the art and represented by block  27  that may be conventional or real time 4D seismic data (as discussed in the background section). Seismic data is processed and interpreted as illustrated in block  28  by such programs as Seisworks and Earthcube by Landmark Graphics to obtain hydrocarbon indicators, stratigraphy and structure. 
     Output from blocks  26  and  28  is further pre-processed as illustrated in block  29  to obtain geostatistics using Sigma-view by Landmark Graphics. Output from blocks  28 ,  29  and  26 B are input into the Geocellular (Earthmodel) programs illustrated by block  30  and processed using the Stratamodel by Landmark Graphics. The resultant output of block  30  is then upscaled as noted in block  31  in Geolink by Landmark Graphics to obtain a reservoir simulation model. 
     Output from the upscaling program  31  is input into the data management function of block  32 . Production/injection data collected by downhole sensors  21 , seabed production sensors  22  and surface production sensors  23  may be input directly into the data management function  22  (as illustrated by the dotted lines) or pre-processed using pressure transient analysis as illustrated in block  22  as previously discussed. Data Management programs may include Openworks, Open/Explorer, TOW/cs and DSS32, all available from Landmark Graphics and Finder available from Geoquest. 
     Referring to box  39  of  FIG. 4 , wherein there is disclosed iterative processing of data gathered by and stored in the data management program  32 . The Reservoir Simulation program  33  uses data from the data management function  32 , and can use data received from the Nodal Analysis program  35  to develop its simulation. The Reservoir Simulation program  33  can also output data to the Nodal Analysis program  35 . Examples of Reservoir Simulation programs include VIP by Landmark Graphics or Eclipse by Geoquest. The Material Balance program uses data from the reservoir simulation  33  and data management function  22  to determine hydrocarbon volumes, reservoir drive mechanisms and production profiles. One of the Material Balance programs known in the art is the MBAL program of Petroleum Experts. 
     The Nodal Analysis program  35  uses data from the Material Balance program  34  and Reservoir Simulation program  33  and other data such as wellbore configuration and surface facility configurations to determine rate versus pressure for various system configurations. Additionally, the Nodal Analysis program  35  shares information with the Reservoir simulation program  33 , so that each program, Nodal Analysis  35  and Reservoir Simulation  33 , may iteratively update and account for changes in the output of the other. Nodal Analysis programs include WEM by P. E. Moseley and Associates, GAP and Prosper by Petroleum Experts, and Openflow by Geographix. 
     Risked Economics programs  36  such as Aries or ResEV by Landmark Graphics determine the optimum field wide production/injection rate which may then be allocated back to individual wells. After production/injection by individual wells is calculated the reservoir management system of the present invention generates and transmits real time, though not necessarily instantaneous, signals (designated generally at  50  in  FIG. 4 ) used to adjust interval control valves located in wells or adjust subsea control valves or surface production control valves to obtain the desired flow or injection rate. The desired production rate may be input directly back into the data management function  32  and actual production/injection from a well is compared to the target rate on a real time basis. Opening or closing a control valve  37  to the pre-determined position may have an almost immediate effect on the production/injection data collected by sensors represented by blocks  21 ,  22  and  33 , however, on a long term basis, the reservoir as a whole is impacted and geologic data collected by sensors represented by blocks  25  and  27  will be affected (see dotted line from control valve  37 ). The present invention may be used to perform iterative calculations as illustrated in box  39  using the reservoir simulation program  23 , material balance program  24 , nodal analysis program  25  and risked economics program  26  to continuously calculate a desired field wide production rate and provide real time, though not necessarily instantaneous, control of production control devices. 
       FIG. 4A  is a generalized diagrammatic illustration of one exemplary embodiment of the system of FIG.  4 . In particular, the embodiment of  FIG. 4A  includes a controller  400  coupled to receive input information from information collectors  401 . The controller  400  processes the information received from information collectors  401 , and provides real time, though not necessarily instantaneous, output control signals to controlled equipment  402 . The information collectors  401  can include, for example, the components illustrated at  38  and  40  in FIG.  4 . The controlled equipment  402  can include, for example, control valves such as illustrated at  37  in FIG.  4 . The controller  400  includes information (for example, data and program) storage and an information processor (CPU). The information storage can include a database for storing information received from the information collectors  401 . The information processor is interconnected with the information storage such that controller  400  is capable, for example, of implementing the functions illustrated at  32 - 36  in FIG.  4 . As shown diagrammatically by broken line in  FIG. 4A , operation of the controlled equipment  402  affects conditions  404  (for example, well-bore conditions) which are monitored by the information collectors  401 . 
       FIG. 5  illustrates exemplary operations which can be performed by the controller  400  of  FIG. 4A  to implement the data management function  32  of FIG.  4 . At  51 , the production/injection (P/I) data both measured (for example, from box  38  of  FIG. 4 ) and simulated (for example, output from box  33  of  FIG. 4 ) is monitored in real time. Any variances in the P/I data are detected at  52 . If variances are detected at  52 , then at  53 , the new P/I data is updated in real time to the Nodal Analysis and Material Balance functions  34  and  35  of FIG.  4 . At  54 , geologic data, for example, from box  40  of  FIG. 4 , is monitored in real time. If any changes in the geologic data are detected at  55 , then at  56 , the new geologic data is updated in real time to the Reservoir Simulation function  33  of FIG.  4 . 
       FIG. 6  illustrates exemplary operations which can be performed by the controller  400  of  FIG. 4A  to implement the Nodal Analysis function  35  and the Material Balance function  34  of FIG.  4 . At  61 , the controller monitors for real time updates of the P/I data from the data management function  32 . If any update is detected at  62 , then conventional Nodal Analysis and Material Balance functions are performed at.  63  using the real time updated P/I data. At  64 , new parameters produced at  63  are updated in real time to the Reservoir Simulation function  33 . 
       FIG. 7  illustrates exemplary operations which can be performed by the controller  400  of  FIG. 4A  to implement the Reservoir Simulation function  33  of FIG.  4 . At  71 , the controller  400  monitors for a real time update of geologic data from the data management function  32  or for a real time update of parameters output from either the Nodal Analysis function  35  or the Material Balance function  34  in FIG.  4 . If any of the aforementioned updates are detected at  72 , then the updated information is used in conventional fashion at  73  to produce a new simulation forecast. Thereafter at  74 , the new simulation forecast is compared to a forecast history (for example, a plurality of earlier simulation forecasts) and, if the new simulation is acceptable at  75  in view of the forecast history, then at  76  the new forecast is updated in real time to the Risked Economics function  36  of FIG.  4 . 
     Referring to the comparison and decision at  74  and  75 , a new forecast could be rejected, for example, if it is considered to be too dissimilar from one or more earlier forecasts in the forecast history. If the new forecast is rejected at  75 , then either another forecast is produced using the same updated information (see broken line at  78 ), or another real time update of the input information is awaited at  71 . The broken line at  77  further indicates that the comparison and decision steps at  74  and  75  can be omitted as desired in some embodiments. 
       FIG. 8  illustrates exemplary operations which can be performed by the controller  400  of  FIG. 4A  to implement the Risked Economics function  36  of FIG.  4 . At  81 , the controller monitors for a real time update of the simulation forecast from the Reservoir Simulation function  33  of FIG.  4 . If any update is detected at  82 , then the new forecast is used in conventional fashion to produce new best case settings for the controlled equipment  402 . Thereafter at  84 , equipment control signals such as illustrated at  50  in  FIG. 4  are produced in real rime based on the new best case settings. 
     The following Table 1 includes a suite of tools (computer programs) that seamlessly interface with each other to generate a field wide production/injection forecast that is used to control production and injection in wells on a real time basis. 
     
       
         
           
               
               
               
               
               
             
               
                 TABLE 1 
               
               
                   
               
               
                   
                   
                   
                 Computer 
                   
               
               
                   
                   
                   
                 Program 
               
               
                   
                   
                   
                 (Commercial 
                 Source of 
               
               
                   
                   
                   
                 Name or Data 
                 Program (name 
               
               
                 Flow Chart Number 
                 Input Data 
                 Output Data 
                 Source) 
                 of company) 
               
               
                   
               
             
            
               
                 1. Downhole Prod. 
                 Pressure, temp, 
                 Annulus (between 
                   
                   
               
               
                 (across reservoir interval) 
                 flow rates 
                 tubing and 
               
               
                   
                   
                 casing) annular 
               
               
                   
                   
                 and tubing 
               
               
                   
                   
                 pressure (psi), 
               
               
                   
                   
                 temp (degrees, 
               
               
                   
                   
                 Fahrenheit, Centi- 
               
               
                   
                   
                 grade), flow rate) 
               
               
                 2. Seabed prod. (at 
                 Pressure, temp, 
                 Pressure, 
               
               
                 subsea tree &amp; subsea 
                 flow rates 
                 temperature 
               
               
                 manifold) 
               
               
                 3. Surface prod. (at 
                 Pressure, temp, 
                 Pressure, 
               
               
                 separators, compressors, 
                 flow rates 
                 temperature 
               
               
                 manifolds, other surface 
               
               
                 equipment) 
               
               
                 4. Pressure Transient 
                 Pressure, temp, 
                 Reservoir 
                 Saphir 
                 Kappa 
               
               
                 Analysis 
                 flow rates 
                 Permeability 
                   
                 Engineering 
               
               
                   
                   
                 Reservoir 
                 PTA 
                 Geographix 
               
               
                   
                   
                 Pressure, Skin, 
               
               
                   
                   
                 distance to 
               
               
                   
                   
                 boundaries 
               
               
                 5. Logs, Cores, SDL 
                   
                 Pressure, 
               
               
                   
                   
                 temperature 
               
               
                 6. Log processing 
                   
                 Saturations 
                 Petroworks 
                 Landmark 
               
               
                 (interpretation) 
                   
                 Porosity 
                   
                 Graphics 
               
               
                   
                   
                 Clay Content 
                 Prizm 
                 Geographix 
               
               
                   
                   
                   
                 DPP 
                 Halliburton 
               
               
                 6A. Stratigraphy 
                   
                   
                 Stratworks 
                 Landmark 
               
               
                   
                   
                   
                   
                 Graphics 
               
               
                 6B. Mapping 
                   
                   
                 Z-Map 
                 Landmark 
               
               
                   
                   
                   
                   
                 Graphics 
               
               
                 7. Seismic Data 
               
               
                 8. Seismic Processing 
                   
                 Hydrocarbon 
                 Seisworks 
                 Landmark 
               
               
                 and Interpretation 
                   
                 indicators 
                 Earthcube 
                 Graphics 
               
               
                   
                   
                 Stratigraphy 
               
               
                   
                   
                 Structure 
               
               
                 9. Geostatistics 
                   
                   
                 Sigmaview 
                 Landmark 
               
               
                   
                   
                   
                   
                 Graphics 
               
               
                 10. Geocellular 
                   
                   
                 Stratamodel 
                 Landmark 
               
               
                   
                   
                   
                   
                 Graphics 
               
               
                 11. Upscaling 
                   
                   
                 Geolink 
                 Landmark 
               
               
                   
                   
                   
                   
                 Graphics 
               
               
                   
                   
                   
                   
                 Geoquest 
               
               
                 12. Data Management, 
                 Outputs from other boxes 
                   
                 Finder 
                 Landmark 
               
               
                 Data Repository 
                   
                   
                 Open works 
                 Graphics 
               
               
                   
                   
                   
                 Open/Explore 
               
               
                   
                   
                   
                 TOW/cs 
               
               
                   
                   
                   
                 DSS32 
               
               
                 13. Reservoir simulation 
                 Field or well production 
                   
                 VIP 
                 Landmark 
               
               
                   
                 profile with time 
                   
                   
                 Graphics 
               
               
                   
                   
                   
                 Eclipse 
                 Geoquest 
               
               
                 14. Material Balance 
                 Fluid Saturations, 
                 Hydrocarbon, in- 
                 MBAL 
                 Petroleum 
               
               
                   
                 Pressure reservoir 
                 place reservoir 
                   
                 Experts 
               
               
                   
                 geometry, temp, fluid 
                 drive mechanism, 
               
               
                   
                 physical prop., flow rate, 
                 production profile 
               
               
                   
                 reservoir physical 
               
               
                   
                 properties 
               
               
                 15. Nodal Analysis, 
                 Wellbore configurations, 
                 Rate vs. Pressure 
                 WEM 
                 P. E. Mosely &amp; 
               
               
                 Reservoir and Fluid 
                 surface facility 
                 for various 
                   
                 Associates 
               
               
                 properties 
                 configurations 
                 system and 
                 GAP 
                 Petroleum 
               
               
                   
                   
                 constraints 
                 Prosper 
                 Experts 
               
               
                   
                   
                   
                 Openflow 
                 Geographix 
               
               
                 16. Risked Economics 
                 Product Price Forecast, 
                 Rate of return, net 
                 Aries 
                 Landmark 
               
               
                   
                 Revenue Working 
                 present value, 
                 ResEV 
                 Graphics 
               
               
                   
                 Interest, Discount Rate, 
                 payout, profit vs. 
               
               
                   
                 Production Profile, 
                 investment ratio 
               
               
                   
                 Capital Expense, 
                 and desired field 
               
               
                   
                 Operating Expense 
                 wide production 
               
               
                   
                   
                 rates. 
               
               
                 17. Control Production 
                   
                 Geometry 
               
               
                   
               
            
           
         
       
     
     It will be understood by those skilled in the art that the practice of the present invention is not limited to the use of the programs disclosed in Table 1, or any of the aforementioned programs. These programs are merely examples of presently available programs which can be suitably enhanced for real time operations, and used to practice the invention. 
     It will be understood by those skilled in the art that the method and system of reservoir management may be used to optimize development of a newly discovered reservoir and is not limited to utility with previously developed reservoirs. 
     A preferred embodiment of the invention has been illustrated in the accompanying Drawings and described in the foregoing Detailed Description, it will be understood that the invention is not limited to the embodiment disclosed, but is capable of numerous modifications without departing from the scope of the invention as claimed.