Patent ID: 12252973

DETAILED DESCRIPTION

Petroleum systems modeling is used to predict the generation and expulsion of hydrocarbons from organic-rich source rocks in a subterranean formation to pore space. Hydrocarbon generation in source rocks, as well as secondary cracking reactions, may be either, (a) absorbed inside the kerogen, (b) adsorbed between kerogen surface and pore space surface, and/or (c) expelled into the pore space.

Existing techniques in the petroleum systems modeling domain do not model hydrocarbon diffusive transport processes for hydrocarbons within kerogen (e.g., hydrocarbons that have been absorbed inside kerogen). More specifically, existing techniques in the petroleum systems modeling domain do not model hydrocarbon migration (e.g., expulsion) from the kerogen to pore space. Accordingly, aspects of the present disclosure may include a system and/or technique for accurately modeling hydrocarbon diffusive transport processes within kerogen (e.g., expulsion of hydrocarbons absorbed within kerogen). As a result, prediction of the generation and expulsion of hydrocarbons from organic-rich source rocks is improved using the techniques described herein. More specifically, by modeling hydrocarbon diffusive transport processes within kerogen, the amount of hydrocarbons diffused from the kerogen to the pore space may be determined. In some embodiments, the modeled hydrocarbon expulsion may be used as an input to another model used to model total hydrocarbon migration (e.g., hydrocarbons originating from kerogen and/or other sources).

The systems and methods described herein provide an approach allowing diffusive transport processes to be incorporated into petroleum systems modeling. This may enable a petroleum system modeler to quantify kerogen diffusion effects in organic source rocks, yielding substantially better predictions of hydrocarbon volumes and benefits/risks of recovery. This may also improve predictions of hydrocarbon quality, such as API gravity and/or gas-oil ratio (GOR). The systems and methods described herein can be used for both conventional petroleum systems and unconventional petroleum systems (e.g., containing shale oil). In addition, the systems and methods disclosed herein may improve the reliability of the results of basin and petroleum system modeling.

Reference will now be made in detail to embodiments, examples of which are illustrated in the accompanying drawings and figures. In the following detailed description, numerous specific details are set forth in order to provide a thorough understanding of the invention. However, it will be apparent to one of ordinary skill in the art that the invention may be practiced without these specific details. In other instances, well-known methods, procedures, components, circuits, and networks have not been described in detail so as not to unnecessarily obscure aspects of the embodiments.

It will also be understood that, although the terms first, second, etc. may be used herein to describe various elements, these elements should not be limited by these terms. These terms are only used to distinguish one element from another. For example, a first object or step could be termed a second object or step, and, similarly, a second object or step could be termed a first object or step, without departing from the scope of the present disclosure. The first object or step, and the second object or step, are both, objects or steps, respectively, but they are not to be considered the same object or step.

The terminology used in the description herein is for the purpose of describing particular embodiments and is not intended to be limiting. As used in this description and the appended claims, the singular forms “a,” “an” and “the” are intended to include the plural forms as well, unless the context clearly indicates otherwise. It will also be understood that the term “and/or” as used herein refers to and encompasses any possible combinations of one or more of the associated listed items. It will be further understood that the terms “includes,” “including,” “comprises” and/or “comprising,” when used in this specification, specify the presence of stated features, integers, steps, operations, elements, and/or components, but do not preclude the presence or addition of one or more other features, integers, steps, operations, elements, components, and/or groups thereof. Further, as used herein, the term “if” may be construed to mean “when” or “upon” or “in response to determining” or “in response to detecting,” depending on the context.

Attention is now directed to processing procedures, methods, techniques, and workflows that are in accordance with some embodiments. Some operations in the processing procedures, methods, techniques, and workflows disclosed herein may be combined and/or the order of some operations may be changed.

FIG.1illustrates an example of a system100that includes various management components110to manage various aspects of a geologic environment150(e.g., an environment that includes a sedimentary basin, a reservoir151, one or more faults153-1, one or more geobodies153-2, etc.). For example, the management components110may allow for direct or indirect management of sensing, drilling, injecting, extracting, etc., with respect to the geologic environment150. In turn, further information about the geologic environment150may become available as feedback160(e.g., optionally as input to one or more of the management components110).

In the example ofFIG.1, the management components110include a seismic data component112, an additional information component114(e.g., well/logging data), a processing component116, a simulation component120, an attribute component130, an analysis/visualization component142and a workflow component144. In operation, seismic data and other information provided per the components112and114may be input to the simulation component120.

In an example embodiment, the simulation component120may rely on entities122. Entities122may include earth entities or geological objects such as wells, surfaces, bodies, reservoirs, etc. In the system100, the entities122can include virtual representations of actual physical entities that are reconstructed for purposes of simulation. The entities122may include entities based on data acquired via sensing, observation, etc. (e.g., the seismic data112and other information114). An entity may be characterized by one or more properties (e.g., a geometrical pillar grid entity of an earth model may be characterized by a porosity property). Such properties may represent one or more measurements (e.g., acquired data), calculations, etc.

In an example embodiment, the simulation component120may operate in conjunction with a software framework such as an object-based framework. In such a framework, entities may include entities based on pre-defined classes to facilitate modeling and simulation. A commercially available example of an object-based framework is the MICROSOFT® .NET® framework (Redmond, Washington), which provides a set of extensible object classes. In the .NET® framework, an object class encapsulates a module of reusable code and associated data structures. Object classes can be used to instantiate object instances for use in by a program, script, etc. For example, borehole classes may define objects for representing boreholes based on well data.

In the example ofFIG.1, the simulation component120may process information to conform to one or more attributes specified by the attribute component130, which may include a library of attributes. Such processing may occur prior to input to the simulation component120(e.g., consider the processing component116). As an example, the simulation component120may perform operations on input information based on one or more attributes specified by the attribute component130. In an example embodiment, the simulation component120may construct one or more models of the geologic environment150, which may be relied on to simulate behavior of the geologic environment150(e.g., responsive to one or more acts, whether natural or artificial). In the example ofFIG.1, the analysis/visualization component142may allow for interaction with a model or model-based results (e.g., simulation results, etc.). As an example, output from the simulation component120may be input to one or more other workflows, as indicated by a workflow component144.

As an example, the simulation component120may include one or more features of a simulator such as the ECLIPSE™ reservoir simulator (Schlumberger Limited, Houston Tex.), the INTERSECT™ reservoir simulator (Schlumberger Limited, Houston Tex.), etc. As an example, a simulation component, a simulator, etc. may include features to implement one or more meshless techniques (e.g., to solve one or more equations, etc.). As an example, a reservoir or reservoirs may be simulated with respect to one or more enhanced recovery techniques (e.g., consider a thermal process such as SAGD, etc.).

In an example embodiment, the management components110may include features of a commercially available framework such as the PETREL® seismic to simulation software framework (Schlumberger Limited, Houston, Texas). The PETREL® framework provides components that allow for optimization of exploration and development operations. The PETREL® framework includes seismic to simulation software components that can output information for use in increasing reservoir performance, for example, by improving asset team productivity. Through use of such a framework, various professionals (e.g., geophysicists, geologists, and reservoir engineers) can develop collaborative workflows and integrate operations to streamline processes. Such a framework may be considered an application and may be considered a data-driven application (e.g., where data is input for purposes of modeling, simulating, etc.).

In an example embodiment, various aspects of the management components110may include add-ons or plug-ins that operate according to specifications of a framework environment. For example, a commercially available framework environment marketed as the OCEAN® framework environment (Schlumberger Limited, Houston, Texas) allows for integration of add-ons (or plug-ins) into a PETREL® framework workflow. The OCEAN® framework environment leverages .NET® tools (Microsoft Corporation, Redmond, Washington) and offers stable, user-friendly interfaces for efficient development. In an example embodiment, various components may be implemented as add-ons (or plug-ins) that conform to and operate according to specifications of a framework environment (e.g., according to application programming interface (API) specifications, etc.).

FIG.1also shows an example of a framework170that includes a model simulation layer180along with a framework services layer190, a framework core layer195and a modules layer175. The framework170may include the commercially available OCEAN® framework where the model simulation layer180is the commercially available PETREL® model-centric software package that hosts OCEAN® framework applications. In an example embodiment, the PETREL® software may be considered a data-driven application. The PETREL® software can include a framework for model building and visualization.

As an example, a framework may include features for implementing one or more mesh generation techniques. For example, a framework may include an input component for receipt of information from interpretation of seismic data, one or more attributes based at least in part on seismic data, log data, image data, etc. Such a framework may include a mesh generation component that processes input information, optionally in conjunction with other information, to generate a mesh.

In the example ofFIG.1, the model simulation layer180may provide domain objects182, act as a data source184, provide for rendering186and provide for various user interfaces188. Rendering186may provide a graphical environment in which applications can display their data while the user interfaces188may provide a common look and feel for application user interface components.

As an example, the domain objects182can include entity objects, property objects and optionally other objects. Entity objects may be used to geometrically represent wells, surfaces, bodies, reservoirs, etc., while property objects may be used to provide property values as well as data versions and display parameters. For example, an entity object may represent a well where a property object provides log information as well as version information and display information (e.g., to display the well as part of a model).

In the example ofFIG.1, data may be stored in one or more data sources (or data stores, generally physical data storage devices), which may be at the same or different physical sites and accessible via one or more networks. The model simulation layer180may be configured to model projects. As such, a particular project may be stored where stored project information may include inputs, models, results and cases. Thus, upon completion of a modeling session, a user may store a project. At a later time, the project can be accessed and restored using the model simulation layer180, which can recreate instances of the relevant domain objects.

In the example ofFIG.1, the geologic environment150may include layers (e.g., stratification) that include a reservoir151and one or more other features such as the fault153-1, the geobody153-2, etc. As an example, the geologic environment150may be outfitted with any of a variety of sensors, detectors, actuators, etc. For example, equipment152may include communication circuitry to receive and to transmit information with respect to one or more networks155. Such information may include information associated with downhole equipment154, which may be equipment to acquire information, to assist with resource recovery, etc. Other equipment156may be located remote from a well site and include sensing, detecting, emitting or other circuitry. Such equipment may include storage and communication circuitry to store and to communicate data, instructions, etc. As an example, one or more satellites may be provided for purposes of communications, data acquisition, etc. For example,FIG.1shows a satellite in communication with the network155that may be configured for communications, noting that the satellite may additionally or instead include circuitry for imagery (e.g., spatial, spectral, temporal, radiometric, etc.).

FIG.1also shows the geologic environment150as optionally including equipment157and158associated with a well that includes a substantially horizontal portion that may intersect with one or more fractures159. For example, consider a well in a shale formation that may include natural fractures, artificial fractures (e.g., hydraulic fractures) or a combination of natural and artificial fractures. As an example, a well may be drilled for a reservoir that is laterally extensive. In such an example, lateral variations in properties, stresses, etc. may exist where an assessment of such variations may assist with planning, operations, etc. to develop a laterally extensive reservoir (e.g., via fracturing, injecting, extracting, etc.). As an example, the equipment157and/or158may include components, a system, systems, etc. for fracturing, seismic sensing, analysis of seismic data, assessment of one or more fractures, etc.

As mentioned, the system100may be used to perform one or more workflows. A workflow may be a process that includes a number of worksteps. A workstep may operate on data, for example, to create new data, to update existing data, etc. As an example, a may operate on one or more inputs and create one or more results, for example, based on one or more algorithms. As an example, a system may include a workflow editor for creation, editing, executing, etc. of a workflow. In such an example, the workflow editor may provide for selection of one or more pre-defined worksteps, one or more customized worksteps, etc. As an example, a workflow may be a workflow implementable in the PETREL® software, for example, that operates on seismic data, seismic attribute(s), etc. As an example, a workflow may be a process implementable in the OCEAN® framework. As an example, a workflow may include one or more worksteps that access a module such as a plug-in (e.g., external executable code, etc.).

FIG.2illustrates an example environment in accordance with aspects of the present disclosure. As shown inFIG.2, environment200includes a kerogen expulsion modeling server210, a petroleum system modeling server220, an operations management server230, and a network240.

The kerogen expulsion modeling server210may include one or more computing devices that models expulsion, diffusion, migration, and/or transport processes of hydrocarbons within kerogen. In some embodiments, the kerogen expulsion modeling server210may receive a petroleum systems model from the petroleum system modeling server220, identify cells in the petroleum systems model in which kerogen is present, simulate hydrocarbon movement within the kerogen, model hydrocarbon movement and hydrocarbon diffusion to pore space, and output the modeled hydrocarbon movement and diffusion (e.g., to the petroleum system modeling server220and/or the operations management server230). By modeling the hydrocarbon movement, diffusion, migration, expulsion, and/or transport processes of hydrocarbon within kerogen, a prediction of hydrocarbon volumes (e.g., in pore space) and associated benefits/risks of recovery may be improved.

The petroleum system modeling server220may include one or more computing devices that generates and provides a petroleum systems model to the kerogen expulsion modeling server210. In some embodiments, the petroleum systems model may include a model, illustration, and/or data representing different groups of cells associated with different layers in a geological space. As previously discussed, the kerogen expulsion modeling server210may use the petroleum systems model to identify kerogens within the geological space, and model hydrocarbon diffusion within the kerogen to a pore space. In some embodiments, the petroleum system modeling server220may receive (e.g., from the kerogen expulsion modeling server210), a model of hydrocarbon diffusion within the kerogen and use the outputs of the model as input to a model that predicts hydrocarbon volumes in the pore space.

The operations management server230may include one or more computing devices that may receive any variety of information from the kerogen expulsion modeling server210and/or the petroleum system modeling server220as inputs to an operation management process. For example, the operations management server230may receive (e.g., from the kerogen expulsion modeling server210) a model of hydrocarbon diffusion within kerogen and may use this model as part of an operation management process (e.g., a process to manage, modify, initiate an oil and gas recovery task based on the results of the model of hydrocarbon diffusion within kerogen, and/or control the operations of drilling equipment used in wellbore drilling, oil and gas recovery, etc.). Additionally, or alternatively, the operations management server230may receive (e.g., from the petroleum system modeling server220), a model that predicts hydrocarbon volumes in a pore space and/or reservoir, and use results from this model as part of the operation management process.

The network240may include network nodes and one or more wired and/or wireless networks. For example, the network240may include a cellular network (e.g., a second generation (2G) network, a third generation (3G) network, a fourth generation (4G) network, a fifth generation (2G) network, a long-term evolution (LTE) network, a global system for mobile (GSM) network, a code division multiple access (CDMA) network, an evolution-data optimized (EVDO) network, or the like), a public land mobile network (PLMN), and/or another network. Additionally, or alternatively, the network240may include a local area network (LAN), a wide area network (WAN), a metropolitan network (MAN), the Public Switched Telephone Network (PSTN), an ad hoc network, a managed Internet Protocol (IP) network, a virtual private network (VPN), an intranet, the Internet, a fiber optic-based network, and/or a combination of these or other types of networks. In embodiments, the network240may include copper transmission cables, optical transmission fibers, wireless transmission, routers, firewalls, switches, gateway computers and/or edge servers.

The quantity of devices and/or networks in the environment200is not limited to what is shown inFIG.2. In practice, the environment200may include additional devices and/or networks; fewer devices and/or networks; different devices and/or networks; or differently arranged devices and/or networks than illustrated inFIG.2. Also, in some implementations, one or more of the devices of the environment200may perform one or more functions described as being performed by another one or more of the devices of the environment200. Devices of the environment200may interconnect via wired connections, wireless connections, or a combination of wired and wireless connections.

FIG.3illustrates a grid which may be a part of a petroleum system model, according to an embodiment. As described herein, the grid represents subterranean layers in a geological space. The grid includes a first set of cells310, a second set of cells320, a third set of cells330, and a fourth set of cells340. The approach described herein may be performed for each cell in the grid independently. Cells310may represent a sea water layer, cells320may represent an accumulation layer, cells330may represent a source rock layer, and cells340may represent reservoir rock layers.

Some of the layers, represented by the cells inFIG.3, may include kerogen, while others may not. As described herein, aspects of the present disclosure may model the hydrocarbon expulsion of hydrocarbons that are within kerogen. Thus, the cells ofFIG.3in which kerogen is present may be further analyzed to model hydrocarbon expulsion within these cells. That is, sub-grids may be created for those cells in the grid ofFIG.3having kerogen.

FIG.4illustrates a sub-grid of a cell in a petroleum systems model and of hydrocarbon transport processes throughout kerogen, according to an embodiment. For example,FIG.4illustrates a sub-grid of one of the cells from the petroleum system modeling grid shown inFIG.3. More specifically, the sub-grid is of one of the cells ofFIG.3having kerogen. The sub-grid inFIG.4may include sub-cells. More particularly, the sub-cells410represent cells inside kerogen, the sub-cells420represent cells located in a vicinity between the kerogen and pore space surface, and the sub-cells430represents free pore space. The circles440and arrows450illustrate the movement of hydrocarbons inside the kerogen and towards the pore space (e.g., sub-cells430). The techniques described herein may model the movement of hydrocarbons inside the kerogen and towards the pore space as illustrated inFIG.4. More specifically, the techniques described herein may quantify the amount or volume of hydrocarbons that migrate from within kerogen to the pore space.

FIG.5illustrates an example flowchart of a process for modeling expulsion of hydrocarbons within kerogen. The blocks ofFIG.5may be implemented in the environment ofFIG.2, for example, and are described using reference numbers of elements depicted inFIG.2. The flowchart illustrates the architecture, functionality, and operation of possible implementations of systems, methods, and computer program products according to various embodiments of the present disclosure.

In some embodiments, process500may be performed for a particular geological time-step. Process500may be repeated or looped for additional geological time-steps (e.g., starting from 500 million years to present day, with time-steps ranging from 0.0001-10 million years).

As shown inFIG.5, process500may include receiving input data relating to subterranean formation for a geological space (as at510). For example, the kerogen expulsion modeling server210may receive input data relating to subterranean formation for a geological space (e.g., input data regarding source rocks and/or other subterranean information for the geological space). Examples of input data that the kerogen expulsion modeling server210may receive may include a petroleum systems model for the geological space (e.g., from the petroleum system modeling server220). For example, the input data may include a petroleum systems model in the form of a grid (e.g., such as the grid ofFIG.3). In some embodiments, the grid may include multiple grid cells that can be separated into one or more (e.g., three) different categories: (i) cells inside the kerogen that are not affected by any surface effects, (ii) cells in the vicinity of the kerogen/pore space surface for which adsorption has a suppressing effect on the diffusion coefficient, and (iii) cells considering the pore space.

Additionally, or alternatively, the input data may include simulated or predicted subterranean data regarding the geological space and/or source rocks in the geological space (e.g., temperature data, rock stress data, porosity, geomechanics data, pressure data, etc.). For example, the kerogen expulsion modeling server210may receive the include simulated or predicted subterranean data (e.g., from the petroleum system modeling server220), or the kerogen expulsion modeling server210may itself run simulations on a petroleum systems model of the geological space to determine the simulated or predicted data.

In some embodiments, the input data may include information identifying areas in the geological space having kerogen, and the amounts of hydrocarbon in the kerogen. Additionally, or alternatively, the input data may include information that can be used to calculate hydrocarbon generation in source rocks, as well as hydrocarbon absorption inside kerogen. For example, hydrocarbon generation in source rocks, as well as secondary cracking reactions, may be described by a set of kinetic equations based on the Arrhenius law. The calculated amounts of hydrocarbon may be (a) absorbed inside the kerogen, (b) adsorbed on kerogen/pore space surface, and/or (c) expelled into the pore space. In some embodiments, the kerogen expulsion modeling server210may receive information regarding the hydrocarbon generation as part of the input data, or may calculate the hydrocarbon generation using the input data (e.g., more specifically, temperature distribution data).

Process500also may include generating a sub-grid of a portion of the geological space having kerogen (as at520). For example, the kerogen expulsion modeling server210may generate a sub-grid of a portion of the geological space having kerogen (e.g., similar to the sub-grid shown inFIG.4). As an illustrative example, the kerogen expulsion modeling server210may generate a sub-grid of one cell in the petroleum systems model (e.g., represented by a grid similar to that shown inFIG.3) in which the cell has kerogen. As part of the generation of the sub-grid, the kerogen expulsion modeling server210may divide the sub-grid into sub-cells, and may insert data representing hydrocarbons into the sub-grid. For example, the kerogen expulsion modeling server210may insert data representing hydrocarbons based on the hydrocarbon absorption information (e.g., received as input data at block510, and/or calculated based on the input data at block510). Further, the data representing hydrocarbons may include the volume, sizes, etc. of the hydrocarbons. In this way, the sub-grid includes sub-cells with information identifying hydrocarbon locations and amounts within the cells. Thus, the sub-grid is now prepared to be used as a basis for modeling hydrocarbon transport, movement, diffusion, and expulsion. For the sake of simplicity, the sub-grid may be a one-dimensional equidistant grid. However, as will be appreciated, other grid types (e.g., two-dimensional grids or three-dimensional grids) as well as non-equidistant grids may also or instead be used and the techniques described herein are not limited to one-dimensional grids.

Process500further may include simulating hydrocarbon diffusion within kerogen (as at530). For example, the kerogen expulsion modeling server210may simulate hydrocarbon within kerogen (e.g., using the sub-grid generated at520). Diffusion of a hydrocarbon component (e.g., methane) absorbed inside the kerogen may be modeled, for example, by Fick's law of diffusion:
{right arrow over (J)}=D{right arrow over (∇)}c(1)

In equation 1, J is the mass flux [kg s−1], D is a diffusion coefficient [m2s−1], and c is the mass concentration [kg m−1]. Equation 1 may be solved numerically, using the sub-grid generated at520.

In some embodiments, diffusion coefficients can be considered to be uniform inside the kerogen. Adsorbed amounts can reduce or block the expulsion of hydrocarbons. To model this, the (effective) diffusion coefficients of surface cells may be altered as follows:

D=(1-α⁢madmadmax)⁢D0,(2)

In equation 2, D0represents the original diffusion coefficient, madrepresents the current adsorbed mass, madmaxrepresents the maximum adsorbed mass, and α represents a parameter controlling the strength of the adsorption blocking. For example, α=1 would stop the diffusive transport completely if the adsorption container is completely filled (i.e., mad=madmax), and α=0 yields a model where diffusion and adsorption is completely decoupled. In some embodiments, the diffusion coefficient may also be based on type of kerogen/kerogen properties, and temperature. As described herein, the simulating hydrocarbon diffusion may produce a set of data that may be used to generate a model of hydrocarbon diffusion and expulsion to pore space.

Process500also may include modeling the hydrocarbon diffusion and expulsion to pore space (as at540). For example, the kerogen expulsion modeling server210may model the hydrocarbon diffusion and expulsion to pore space based on the simulations executed at block530. In some embodiments, the modeling may involve converting or packaging the simulated data into a presentable format or model.

Process500further may include outputting the modeled hydrocarbon diffusion and expulsion (as at550). For example, the kerogen expulsion modeling server210may output the modeled hydrocarbon diffusion and expulsion to an external system, (e.g., any system or application that is external to the modeling of the hydrocarbon diffusion). As one example, the kerogen expulsion modeling server210may output the modeled hydrocarbon diffusion and expulsion to a different application hosted by the kerogen expulsion modeling server210, the petroleum system modeling server220, and/or to the operations management server230. In some embodiments, the modeled hydrocarbon diffusion and expulsion may be used as an input to an application that predicts hydrocarbon volume or accumulation (e.g., in pore space). As described herein, the operations management server230may use the model as part of any variety of operation management process (e.g., a process to manage, modify, initiate an oil and gas recovery task based on the results of the model of hydrocarbon diffusion within kerogen, and/or control the operations of drilling equipment used in wellbore drilling, oil and gas recovery, etc.).

In some embodiments, process500may also include visualizing the model of hydrocarbon diffusion. For example, the simulation of hydrocarbon diffusion in the model may be visualized, e.g., over a period of time. Further, the visualizing as described above, the systems and methods disclosed herein provide an efficient and easily controllable approach to include kerogen diffusion effects into a petroleum systems model, which may improve modelling of hydrocarbon expulsion of source rocks.

In some embodiments, the methods of the present disclosure may be executed by a computing system.FIG.6illustrates an example of such a computing system600, in accordance with some embodiments. The computing system600may include a computer or computer system601A, which may be an individual computer system601A or an arrangement of distributed computer systems. The computer system601A includes one or more analysis modules602that are configured to perform various tasks according to some embodiments, such as one or more methods disclosed herein. To perform these various tasks, the analysis module602executes independently, or in coordination with, one or more processors604, which is (or are) connected to one or more storage media606. The processor(s)604is (or are) also connected to a network interface607to allow the computer system601A to communicate over a data network609with one or more additional computer systems and/or computing systems, such as601B,601C, and/or601D (note that computer systems601B,601C and/or601D may or may not share the same architecture as computer system601A, and may be located in different physical locations, e.g., computer systems601A and601B may be located in a processing facility, while in communication with one or more computer systems such as601C and/or601D that are located in one or more data centers, and/or located in varying countries on different continents).

A processor may include a microprocessor, microcontroller, processor module or subsystem, programmable integrated circuit, programmable gate array, or another control or computing device.

The storage media606may be implemented as one or more computer-readable or machine-readable storage media. Note that while in the example embodiment ofFIG.6storage media606is depicted as within computer system601A, in some embodiments, storage media606may be distributed within and/or across multiple internal and/or external enclosures of computing system601A and/or additional computing systems. Storage media606may include one or more different forms of memory including semiconductor memory devices such as dynamic or static random access memories (DRAMs or SRAMs), erasable and programmable read-only memories (EPROMs), electrically erasable and programmable read-only memories (EEPROMs) and flash memories, magnetic disks such as fixed, floppy and removable disks, other magnetic media including tape, optical media such as compact disks (CDs) or digital video disks (DVDs), BLURAY® disks, or other types of optical storage, or other types of storage devices. Note that the instructions discussed above may be provided on one computer-readable or machine-readable storage medium, or may be provided on multiple computer-readable or machine-readable storage media distributed in a large system having possibly plural nodes. Such computer-readable or machine-readable storage medium or media is (are) considered to be part of an article (or article of manufacture). An article or article of manufacture may refer to any manufactured single component or multiple components. The storage medium or media may be located either in the machine running the machine-readable instructions, or located at a remote site from which machine-readable instructions may be downloaded over a network for execution.

In some embodiments, computing system600contains one or more petroleum system modeling module(s)608that may perform at least a portion of the method500. It should be appreciated that computing system600is merely one example of a computing system, and that computing system600may have more or fewer components than shown, may combine additional components not depicted in the example embodiment ofFIG.6, and/or computing system600may have a different configuration or arrangement of the components depicted inFIG.6. The various components shown inFIG.6may be implemented in hardware, software, or a combination of both hardware and software, including one or more signal processing and/or application specific integrated circuits.

Further, the steps in the processing methods described herein may be implemented by running one or more functional modules in information processing apparatus such as general purpose processors or application specific chips, such as ASICs, FPGAs, PLDs, or other appropriate devices. These modules, combinations of these modules, and/or their combination with general hardware are included within the scope of the present disclosure.

Computational interpretations, models, and/or other interpretation aids may be refined in an iterative fashion; this concept is applicable to the methods discussed herein. This may include use of feedback loops executed on an algorithmic basis, such as at a computing device (e.g., computing system600,FIG.6), and/or through manual control by a user who may make determinations regarding whether a given step, action, template, model, or set of curves has become sufficiently accurate for the evaluation of the subsurface three-dimensional geologic formation under consideration.

The foregoing description, for purpose of explanation, has been described with reference to specific embodiments. However, the illustrative discussions above are not intended to be exhaustive or limiting to the precise forms disclosed. Many modifications and variations are possible in view of the above teachings. Moreover, the order in which the elements of the methods described herein are illustrate and described may be re-arranged, and/or two or more elements may occur simultaneously. The embodiments were chosen and described in order to best explain the principals of the disclosure and its practical applications, to thereby enable others skilled in the art to best utilize the disclosed embodiments and various embodiments with various modifications as are suited to the particular use contemplated.