METHODS AND SYSTEMS FOR UPDATING A BASIN MODEL TO IDENTIFY HYDROCARBONS USING PALEOBATHYMETRY

Description

BACKGROUND

Paleobathymetry is the study of ancient water depths within subterranean regions. Paleobathymetry may inform a basin model that aims to predict the evolution of a subterranean region of interest. Accordingly, the basin model may predict the generation, migration, and present location of hydrocarbons within the subterranean region of interest. However, paleobathymetry may rely on dense fossil information that may be difficult and expensive to obtain for a specific subterranean region of interest.

SUMMARY

This summary is provided to introduce a selection of concepts that are further described below in the detailed description. This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.

In general, in one aspect, embodiments relate to a method. The method includes obtaining a paleoenvironment chart that includes water depths and obtaining an isopach map of a subterranean region of interest. The isopach map includes a sedimentary thickness at each position within the subterranean region of interest. The method further includes determining a paleobathymetry map by converting the sedimentary thickness at each position to a water depth among the water depths, updating, using a basin modeling system, a basin model of the subterranean region of interest by inputting the paleobathymetry map into the basin model, and identifying, using an interpretation workstation, a location of hydrocarbons within the subterranean region of interest based, at least in part, on the updated basin model.

In general, in one aspect, embodiments relate to a system. The system includes a computer system, basin modeling system, and interpretation workstation. The computer system is configured to receive a paleoenvironment chart that includes water depths and receive an isopach map of a subterranean region of interest. The isopach map includes a sedimentary thickness at each position within the subterranean region of interest. The computer system is further configured to determine a paleobathymetry map by converting the sedimentary thickness at each position to a water depth among the water depths. The basin modeling system is configured to update a basin model of the subterranean region of interest by inputting the paleobathymetry map into the basin model. The interpretation workstation is configured to identify a location of hydrocarbons within the subterranean region of interest based, at least in part, on the updated basin model.

Other aspects and advantages of the claimed subject matter will be apparent from the following description and the appended claims.

BRIEF DESCRIPTION OF DRAWINGS

Specific embodiments of the disclosed technology will now be described in detail with reference to the accompanying figures. Like elements in the various figures are denoted by like reference numerals for consistency.

FIGS. 1 and 2 each display a paleoenvironment chart in accordance with one or more embodiments.

FIG. 3 displays an isopach map in accordance with one or more embodiments.

FIG. 4 displays a gross depositional environment (GDE) map in accordance with one or more embodiments.

FIG. 5 displays a paleobathymetry map in accordance with one or more embodiments.

FIG. 6 displays fossil information in accordance with one or more embodiments.

FIGS. 7 and 8 each display a paleostructure map in accordance with one or more embodiments.

FIG. 9 describes a method in accordance with one or more embodiments.

FIG. 10 illustrates a computer system in accordance with one or more embodiments.

FIG. 11 illustrates a drilling system in accordance with one or more embodiments.

FIG. 12 describes a system in accordance with one or more embodiments.

DETAILED DESCRIPTION

In the following detailed description of embodiments of the disclosure, numerous specific details are set forth in order to provide a more thorough understanding of the disclosure. However, it will be apparent to one of ordinary skill in the art that the disclosure may be practiced without these specific details. In other instances, well-known features have not been described in detail to avoid unnecessarily complicating the description.

Throughout the application, ordinal numbers (e.g., first, second, third, etc.) may be used as an adjective for an element (i.e., any noun in the application). The use of ordinal numbers is not to imply or create any particular ordering of the elements nor to limit any element to being only a single element unless expressly disclosed, such as using the terms “before,” “after,” “single,” and other such terminology. Rather, the use of ordinal numbers is to distinguish between the elements. By way of an example, a first element is distinct from a second element, and the first element may encompass more than one element and succeed (or precede) the second element in an ordering of elements.

It is to be understood that the singular forms “a,” “an,” and “the” include plural referents unless the context clearly dictates otherwise. Thus, for example, reference to “a paleoenvironment chart” includes reference to one or more of such charts.

Terms such as “approximately,” “substantially,” etc., mean that the recited characteristic, parameter, or value need not be achieved exactly, but that deviations or variations, including for example, tolerances, measurement error, measurement accuracy limitations and other factors known to those of skill in the art, may occur in amounts that do not preclude the effect the characteristic was intended to provide.

It is to be understood that one or more of the steps shown in the flowcharts may be omitted, repeated, and/or performed in a different order than the order shown. Accordingly, the scope disclosed herein should not be considered limited to the specific arrangement of steps shown in the flowcharts.

Although multiple dependent claims are not introduced, it would be apparent to one of ordinary skill that the subject matter of the dependent claims of one or more embodiments may be combined with other dependent claims.

In the following description of FIGS. 1-12, any component described regarding a figure, in various embodiments disclosed herein, may be equivalent to one or more like-named components described regarding any other figure. For brevity, descriptions of these components will not be repeated regarding each figure. Thus, each and every embodiment of the components of each figure is incorporated by reference and assumed to be optionally present within every other figure having one or more like-named components. Additionally, in accordance with various embodiments disclosed herein, any description of the components of a figure is to be interpreted as an optional embodiment which may be implemented in addition to, in conjunction with, or in place of the embodiments described regarding a corresponding like-named component in any other figure.

Methods and systems are disclosed to update a basin model of a subterranean region of interest using a paleobathymetry map. Paleobathymetry is the study of ancient water depths (i.e., paleodepths) and seafloor topography within subterranean regions. Paleobathymetry is a crucial tool in geology that aids in the understanding of past environments, ocean circulation patterns, tectonic processes, and the evolution of marine ecosystems and other geological features within the subterranean region of interest.

The paleobathymetry map may be input into the basin model to update the basin model. The basin model may aim to predict an evolution of the subterranean region of interest over geological time. As such, the basin model may predict depositional history, hydrocarbon generation, hydrocarbon migration, and a current location of hydrocarbons within the subterranean region of interest, such as a subterranean region of interest that includes a rift basin.

The disclosed methods may be an improvement over other methods that identify hydrocarbons using a basin model. Other methods may require benthic foraminifera or other marine microfossils (generically “fossil information” or “fossil assemblages”) to be acquired from wells, often densely-packed wells, within the subterranean region of interest to determine a paleobathymetry map input into the basin model. Accordingly, the absence of, scarcity of, and/or inability to determine the presence of benthic foraminifera or other marine microfossils across the subterranean region of interest may make it difficult to determine a paleobathymetry map. If a paleobathymetry map is excluded from a basin model, the basin model may assume paleobathymetry is unchanging over geological time and present-day seafloor topography is similar to ancient water depths, which may be unreasonable assumptions especially at a regional scale. Further, other methods may rely on seismic data in the form of a seismic depth map, which may be expensive and time consuming to obtain, to determine a paleobathymetry map input into the basin model. To overcome these challenges, the disclosed methods rely on a previously-determined paleoenvironment chart that includes water depths, an isopach map that includes sedimentary thicknesses, and, in some embodiments, a gross depositional environment (GDE) map to determine a paleobathymetry map input into the basin model.

FIGS. 1 and 2 each display a paleoenvironment chart 100 in accordance with one or more embodiments. The paleoenvironment chart 100 displayed in FIG. 1 comes from information presented in FIG. 5.1 of Adegoke, et al., eds. Cenozoic foraminifera and calcareous nannofossil biostratigraphy of the Niger Delta. Elsevier, 2016.

The paleoenvironment chart 100 displayed in FIG. 2 comes from information presented in FIG. 3 of Ayyad, H., El-Sharnoby, A., El-Morsy, A., Ahmed, M., & El-Deeb, A. (2018). Quantitative reconstruction of paleoenvironmental conditions in the Gulf of Suez during the Burdigalian-Langhian (early to middle Miocene) using benthic foraminifera. Palaeogeography, Palaeoclimatology, Palaeoecology, 503, 51-68.

In some embodiments, the paleoenvironment chart 100 includes water depths 105a. In some embodiments, one or more of the water depths 105a may be explicitly provided in the paleoenvironment chart 100. In other embodiments, one or more of the water depths 105a may be interpolated from one or more explicitly-provided water depths 105a provided in the paleoenvironment chart 100. In other embodiments, the paleoenvironment chart 100 further includes paleoenvironments 110. In still other embodiments, the paleoenvironment chart 100 also includes fossil information 200. The paleoenvironment chart 100 may include water depths 105a, paleoenvironments 110, and/or fossil information 200 associated with a specific subterranean region.

FIG. 3 displays an isopach map 300 of a subterranean region of interest 305 in accordance with one or more embodiments. The isopach map 300 includes a sedimentary thickness at each position 310 within the subterranean region of interest 305 as shown by the scale bar. Each position 310 may be a spatial position where x and y in FIG. 3 refer to orthogonal spatial dimensions located on the surface of the earth.

In some embodiments, the isopach map 300 may be determined from seismic data. The seismic data may be obtained across the subterranean region of interest 305 using a seismic acquisition system. The seismic acquisition system may generate and record seismic waves emitted into the subterranean region of interest 305. In some embodiments, the seismic data may be processed to determine a seismic depth map. In other embodiments, the isopach map 300 may be determined from a geological survey. The geological data may be obtained across the surface of the subterranean region of interest 305 using a geological acquisition system. In still other embodiments, the isopach map 300 may be determined from and/or calibrated using biostratigraphic data acquired within one or more wells 315a, b within the subterranean region of interest 305. The biostratigraphic data may include well log data obtained using a well logging system. However, a person of ordinary skill in the art will appreciate that still other data may be obtained over the subterranean region of interest 305 and used to determine the isopach map 300.

FIG. 4 displays a GDE map 400 of the subterranean region of interest 305 in accordance with one or more embodiments. The GDE map 400 includes a paleoenvironment 110 at each position 310 within the subterranean region of interest 305 as shown by the scale bar. The paleoenvironment 110 includes, without limitation, deep marine, shallow marine, marginal marine, reef, fore-reef, lagoon, non-marine, deltaic, terrestrial fluvial/floodplain, and fluvial complex/system. In some embodiments, the paleoenvironments 110 may be separated by boundaries, such as a paleoshoreline boundary or basin-floor boundary.

In some embodiments, the GDE map 400 may be determined from the seismic data. In some embodiments, the seismic data may be processed and interpreted to determine the GDE map 400. In other embodiments, the GDE map 400 may be determined from and/or calibrated using the biostratigraphic data. The biostratigraphic data may include the well log data, rock core data, and/or fossil information 200 obtained from the one of more wells 315a, b within the subterranean region of interest 305.

In some embodiments, the sedimentary thickness at each position 310 within the isopach map 300 may be converted to a water depth 105a among the water depths 105a within the paleoenvironment chart 100. To do so, the disclosed methods may rely on the idea that sedimentary thickness and water depth 105a are inversely related. In other words, as sedimentary thickness increases from thin to thick, water depth 105a decreases from deep to shallow. Each sedimentary thickness within the isopach map 300 may be converted to a water depth 105a based on, for example, a simple relationship or calibration curve that quantifies the inverse relationship between sedimentary thickness and water depth 105a based, at least in part, on the paleoenvironment chart 100. In some embodiments, the simple relationship or calibration curve may be calibrated and/or validated using the seismic data, geological data, biostratigraphic data (e.g., well log data, rock core data, and fossil information 200), and/or any combination or portion thereof. In some embodiments, the simple relationship or calibration curve may interpolate some water depth, sedimentary thickness pairs. Conversion of sedimentary thickness at each position 310 within the isopach map 300 to water depth 105a may result in the paleobathymetry map.

In other embodiments, the GDE map 400 may be additionally used to determine the paleobathymetry map. In some embodiments, the isopach map 300 and GDE map 400 may be aligned using one or more boundaries, well locations, and/or other geological features within the subterranean region of interest 305 prior to conversion. In these embodiments, the simple relationship or calibration curve may be further calibrated based on the paleoenvironment 110 at each position 310 within the GDE map 400. In these embodiments, a simple relationship or calibration curve may be determined for each paleoenvironment 110 within the GDE map 400.

In still other embodiments, sedimentary thickness and/or water depth 105a may be normalized such that one or more normalized simple relationships or calibration curves are determined and used for conversion.

Before or after conversion, in some embodiments, the isopach map 300, GDE map 400, paleobathymetry map, and/or one or more calibration curves may be smoothed using any smoothing method known to a person of ordinary skill in the art. Smoothing may mitigate edge boundary effects and/or random noise.

FIG. 5 displays a paleobathymetry map 500 of the subterranean region of interest 305 in accordance with one or more embodiments. The paleobathymetry map 500 includes a water depth 105a at each position 310 within the subterranean region of interest 305 as shown by the scale bar.

In some embodiments, the paleobathymetry map 500 may be calibrated and/or validated by comparing fossil information 200 obtained from the one or more wells 315a, b within the subterranean region of interest 305 to previously-determined fossil information 200 associated to quantitative and/or qualitative water depths 105a, b. FIG. 6 displays previously-determined fossil information 200 associated to qualitative water depths 105b in accordance with one or more embodiments. The information displayed in FIG. 6 comes from information presented in FIG. 6.21 from BouDagher-Fadel, M. (2013). Biostratigraphic and Geological Significance of Planktonic Foraminifera (2nd ed.). London, UK. Further, FIG. 2 displays previously-determined fossil information 200 associated with quantitative water depths 105a.

For example, benthonic and planktonic foraminiferal assemblages located in well x 315a within the subterranean region of interest 305 indicate a moderately-high diversity of planktonic foraminiferal assemblage. The planktonic foraminiferal assemblage includes Orbulina suturalis, Orbulina bilobata and Praeorbulina transitoria together with species of Globigerinoides and Globigerina. As displayed in FIG. 6, these assemblage and species may indicate deposition in middle neritic to outer neritic, which are associated with deeper qualitative water depths 105b. Further, deep marine benthonic foraminifera located in well x 315a, which includes Uvigerina canariensis and Sphaeroidina bulloides, may indicate deposition in outer neritic, which are associated with deeper water depths 105a as displayed in FIG. 2. Further still, planktonic foraminiferal assemblage located in well y 315b within the subterranean region of interest 305 indicate a rich presence of species of Praeorbulina, Orbulina, and Bulimina, which are associated with a deeper water depth 105a, b as displayed in FIGS. 2 and 6.

In some embodiments, the paleobathymetry map 500 may be input into a basin model of the subterranean region of interest 305 to update the basin model by controlling water depth 105a at the time of deposition. In some embodiments, the basin model may also rely, at least in part, on a present-day seismic surface map and lithofacies map. In some embodiments, the basin model may output or display a paleostructure map and/or paleotopography map at each of one or more points in geological time.

FIGS. 7 and 8 each display a paleostructure map 700 in accordance with one or more embodiments. In FIGS. 7 and 8, z is a spatial dimension orthogonal to x and y that indicates depth. FIG. 7 displays the paleostructure map 700 of the present-day subterranean region of interest 305. FIG. 8 displays the paleostructure map 700 of a cross-section of the present-day subterranean region of interest 305. The cross-section is illustrated by the black line in FIG. 7. In some embodiments, the paleostructure map 700 may predict a facies at each location within the present-day subterranean region of interest 305 (i.e., burial depth) as illustrated in FIGS. 7 and 8. Facies may include, without limitation, siltstone, halite, limestone, shale, sandstone, dolomite, and conglomerate. In other embodiments, the paleostructure map 700 may predict the maturation of source rock, migration pathways, and/or paleofetch areas within the subterranean region of interest 305. One or more facies, such as shale, sandstone, and siltstone, among other basin model predictions may be interpreted as indicative of a location of hydrocarbons within the subterranean region of interest 305.

FIG. 9 describes a method in accordance with one or more embodiments. In step 900, a paleoenvironment chart 100 is obtained. In some embodiments, the paleoenvironment chart 100 includes water depths 105a. In some embodiments, one or more of the water depths 105a may be explicitly provided in the paleoenvironment chart 100. In other embodiments, one or more of the water depths 105a may be interpolated from one or more explicitly-provided water depths 105a provided in the paleoenvironment chart 100. In some embodiments, the paleoenvironment chart 100 further includes paleoenvironments 110 and/or fossil information 200. FIGS. 1 and 2 each display a paleoenvironment chart 100 in accordance with one or more embodiments. In some embodiments, the paleoenvironment chart 100 may be obtained or determined from the literature. In some embodiments, the paleoenvironment chart 100 may be indicative of a specific subterranean region.

In step 905, an isopach map 300 of a subterranean region of interest 305 is obtained. The isopach map 300 includes a sedimentary thickness at each position 310 within the subterranean region of interest 305. FIG. 3 displays an isopach map 300 in accordance with one or more embodiments. The isopach map 300 may be determined from and/or calibrated using seismic data, geological data, biostratigraphic data (e.g., well log data, rock core data, and fossil information 200), and/or any combination or portion thereof.

In some embodiments, a GDE map 400 of the subterranean region of interest 305 is also obtained. In some embodiments, the GDE map 400 includes a paleoenvironment 110 at each position 310 within the subterranean region of interest 305. The GDE map 400 may be determined from and/or calibrated using the seismic data, biostratigraphic data, and/or any combination or portion thereof. FIG. 4 displays a GDE map 400 in accordance with one or more embodiments.

In step 910, a paleobathymetry map 500 of the subterranean region of interest 305 is determined. To do so, in some embodiments, the sedimentary thickness at each position 310 within the isopach map 300 is converted to water depth 105a based on the paleoenvironment chart 100. In some embodiments, sedimentary thickness within the isopach map 300 and water depth 105a within the paleoenvironment chart 100 are inversely related. As such, in some embodiments, a simple relationship or calibration curve that quantifies the inverse relationship between sedimentary thickness and water depth 105a based, at least in part, on the paleoenvironment chart 100 may be used for conversion. In some embodiments, the simple relationship between sedimentary thickness and water depth 105a may be quantified as (water depth)=1/(sedimentary thickness). In some embodiments, the simple relationship or calibration curve may interpolate some water depth, sedimentary thickness pairs. However, a person of ordinary skill in the art will appreciate that more complicated relationships may be used. In some embodiments, the simple relationship or calibration curve may be calibrated and/or validated using the seismic data, geological data, biostratigraphic data (e.g., well log data, rock core data, and fossil information 200), and/or any combination or portion thereof. Further, in some embodiments, sedimentary thickness and/or water depth 105a may be normalized such that a normalized simple relationship or calibration curve is determined. In some embodiments, conversion of sedimentary thickness at each position 310 to water depth 105a results in a paleobathymetry map 500.

In some embodiments, prior to conversion, the isopach map 300 may be aligned to the GDE map 400. Following alignment, a simple relationship or calibration curve may be determined for each paleoenvironment 110 within the GDE map 400 and used to convert each sedimentary thickness within the isopach map 300 to a water depth 105a among the paleoenvironment chart 100.

In some embodiments, the isopach map 300, GDE map 400, paleobathymetry map 500, and/or one or more calibration curves may be smoothed using any smoothing method known to a person of ordinary skill in the art.

In step 915, the paleobathymetry map 500 is input into a basin model of the subterranean region of interest 305 to update the basin model. The basin model may model the evolution of the subterranean region of interest 305 over geological time.

In step 920, a location of hydrocarbons is identified within the subterranean region of interest 305 using the updated basin model. In some embodiments, the updated basin model may output or display a paleostructure map 700 and/or paleotopography map at each of one or more points in geological time. In some embodiments, the paleostructure map 700 may predict a facies at each position 310 within the subterranean region of interest 305 as illustrated in FIGS. 7 and 8. In other embodiments, the paleostructure map 700 may predict the maturation of source rock, migration pathways, and/or paleofetch areas within the subterranean region of interest 305. One or more facies may be interpreted as indicative of a location of hydrocarbons within the subterranean region of interest 305.

Following the identification of the location of hydrocarbons within the subterranean region of interest 305, a wellbore plan may be designed such that a wellbore path penetrates the location of hydrocarbons within the subterranean region of interest 305. The wellbore plan may be additionally informed by the best available information at the time of design. This may include models encapsulating stress conditions of the subterranean region of interest 305, the trajectory of any existing wells 315a, b (which may be desirable to avoid), and the existence of drilling hazards, such as shallow gas pockets, over-pressure zones, and active fault planes.

Returning to the wellbore path, the wellbore path may include a starting surface location of the wellbore, or a subsurface location within an existing wellbore, from which the wellbore may be drilled. The wellbore path may include a terminal location that may intersect with the location of the hydrocarbons. The wellbore path may further still include wellbore geometry information such as wellbore diameter and inclination angle and when each of these change along the depth of the wellbore. If casing is used, the wellbore plan may include casing type and/or casing depths. Furthermore, the wellbore plan may consider other engineering constraints such as the maximum wellbore curvature (“dog-log”) that a drillstring of a drilling system may tolerate and the maximum torque and drag values that the drilling system may tolerate. The wellbore plan may further define associated drilling parameters, such as the planned depths at which casing will be inserted to support the wellbore to prevent formation fluids entering the wellbore and the drilling mud weights (densities) and types that may be used during drilling of the wellbore.

Following the design of the wellbore plan, the wellbore path guided by the wellbore plan may be drilled using a drilling system such that the located hydrocarbons may ultimately be produced to the surface of the earth for use a fuel. The drilling system is further discussed relative to FIG. 11.

Turning to systems, a computer system may be configured to perform steps 900, 905, and 910. FIG. 10 illustrates a computer system 1000 in accordance with one or more embodiments. The computer system 1000 is intended to depict any computing device such as a server, desktop computer, laptop/notebook computer, wireless data port, smart phone, personal data assistant (PDA), tablet computing device, one or more processors within these devices, or any other suitable processing device, including both physical or virtual instances (or both) of the computing device. Additionally, the computer system 1000 may include an input device, such as a keypad, keyboard, touch screen, or other device that can accept user information, and an output device that displays information, including digital data, visual or audio information (or a combination of both), or a graphical user interface (GUI).

The computer system 1000 can serve in a role as a client, network component, server, database, or any other component (or a combination of roles) of a computer system 1000 as required for seismic processing and interpretation. The illustrated computer system 1000 is communicably coupled with a network 1005. In some implementations, one or more components of each computer system 1000 may be configured to operate within environments, including cloud-computing-based, local, global, or other environment (or a combination of environments).

At a high level, the computer system 1000 is an electronic computing device operable to receive, transmit, process, store, and/or manage data and information associated with the disclosed methods. According to some implementations, the computer system 1000 may also include or be communicably coupled with an application server, e-mail server, web server, caching server, streaming data server, business intelligence (BI) server, or other server (or a combination of servers).

Because processing and interpretation may not be sequential, the computer system 1000 can receive requests over network 1005 from other computer systems 1000 or another client application and respond to the received requests by processing the requests appropriately. In addition, requests may also be sent to the computer system 1000 from internal users (for example, from a command console or by other appropriate access method), external or third-parties, other automated applications, as well as any other appropriate entities, individuals, systems, or computer systems 1000.

Each of the components of the computer system 1000 can communicate using a system bus 1010. In some implementations, any or all of the components of each computer system 1000, both hardware or software (or a combination of hardware and software), may interface with each other or the interface 1015 (or a combination of both) over the system bus 1010 using an application programming interface (API) 1020 or a service layer 1025 (or a combination of the API 1020 and service layer 1025. The API 1020 may include specifications for routines, data structures, and object classes. The API 1020 may be either computer-language independent or dependent and refer to a complete interface, a single function, or even a set of APIs. The service layer 1025 provides software services to each computer system 1000 or other components (whether or not illustrated) that are communicably coupled to each computer system 1000. The functionality of each computer system 1000 may be accessible for all service consumers using this service layer 1025. Software services, such as those provided by the service layer 1025, provide reusable, defined business functionalities through a defined interface. For example, the interface may be software written in JAVA, C++, or other suitable language providing data in extensible markup language (XML) format or another suitable format. While illustrated as an integrated component of each computer system 1000, alternative implementations may illustrate the API 1020 or the service layer 1025 as stand-alone components in relation to other components of each computer system 1000 or other components (whether or not illustrated) that are communicably coupled to each computer system 1000. Moreover, any or all parts of the API 1020 or the service layer 1025 may be implemented as child or sub-modules of another software module, enterprise application, or hardware module without departing from the scope of this disclosure.

The computer system 1000 includes an interface 1015. Although illustrated as a single interface 1015 in FIG. 10, two or more interfaces 1015 may be used according to particular needs, desires, or particular implementations of each computer system 1000. The interface 1015 is used by each computer system 1000 for communicating with other systems in a distributed environment that are connected to the network 1005. Generally, the interface 1015 includes logic encoded in software or hardware (or a combination of software and hardware) and operable to communicate with the network 1005. More specifically, the interface 1015 may include software supporting one or more communication protocols associated with communications such that the network 1005 or interface's hardware is operable to communicate physical signals within and outside of the illustrated computer system 1000.

The computer system 1000 includes at least one computer processor 1030. Generally, a computer processor 1030 executes any instructions, algorithms, methods, functions, processes, flows, and procedures as described above. A computer processor 1030 may be a central processing unit (CPU) and/or a graphics processing unit (GPU).

The computer system 1000 also includes a memory 1035 that stores data and software for the computer system 1000 or other components (or a combination of both) that can be connected to the network 1005. Although illustrated as a single memory 1035 in FIG. 10, two or more memories may be used according to particular needs, desires, or particular implementations of the computer system 1000 and the described functionality. While memory 1035 is illustrated as an integral component of each computer system 1000, in alternative implementations, memory 1035 can be external to the computer system 1000.

The application 1040 is an algorithmic software engine providing functionality according to particular needs, desires, or particular implementations of the computer system 1000, particularly with respect to functionality described in this disclosure. For example, application 1040 can serve as one or more components, modules, applications, etc. Further, although illustrated as a single application 1040, the application 1040 may be implemented as multiple applications 1040 on each computer system 1000. In addition, although illustrated as integral to each computer system 1000, in alternative implementations, the application 1040 can be external to each computer system 1000.

There may be any number of computer systems 1000, such as computer clusters, associated with, or external to, a seismic processing system and an interpretation workstation, where each computer system 1000 communicates over network 1005. Further, the term “client,” “user,” and other appropriate terminology may be used interchangeably as appropriate without departing from the scope of this disclosure. Moreover, this disclosure contemplates that many users may use the computer system 1000, or that one user may use multiple computer systems 1000.

A basin modeling system may be configured to perform step 915. An interpretation workstation may be configured to perform step 920. A wellbore planning system may be configured to design the wellbore plan based on the location of hydrocarbons determined in step 920. In some embodiments, the basin modeling system, interpretation workstation, and/or wellbore planning system may include a computer system 1000. A drilling system may be configured to drill the wellbore path guided by the wellbore plan.

FIG. 11 illustrates a drilling system 1100 in accordance with one or more embodiments. In some embodiments, the drilling system 1100 may be configured to drill a wellbore 1105 within the subterranean region of interest 305 guided by the wellbore plan, which includes a wellbore path 1110. In some embodiments, the wellbore path 1110 is designed to penetrate the location of hydrocarbons (e.g., a reservoir 1115) within the subterranean region of interest 305.

Although the drilling system 1100 shown in FIG. 11 is used to drill the wellbore 1105 on land, the drilling system 1100 may be a marine wellbore drilling system. Further, although the drilling system 1100 shown in FIG. 11 is used to drill a new wellbore 1105, the wellbore 1105 being drilled may be a sidetrack wellbore or an offset wellbore. As such, the example of the drilling system 1100 shown in FIG. 11 is not meant to limit the present disclosure.

As shown in FIG. 11, the wellbore 1105 may be drilled using a drill rig that may be situated on a land drill site, an offshore platform, such as a jack-up rig, a semi-submersible, or a drill ship. The drill rig may be equipped with a hoisting system, such as a derrick 1120, which can raise or lower the drillstring 1125 and other tools required to drill the wellbore 1105. The drillstring 1125 may include one or more drill pipes connected to form conduit and a bottom hole assembly 1130 (BHA) disposed at the distal end of the drillstring 1125. The BHA 1130 may include a drill bit 1135 to cut into rock 1140, including cap rock 1140a. The BHA 1130 may further include measurement tools, such as a measurement-while-drilling (MWD) tool and logging-while-drilling (LWD) tool. MWD tools may include sensors and hardware to measure downhole drilling parameters, such as the azimuth and inclination of the drill bit 1135, the weight-on-bit, and the torque. The LWD measurements may include sensors, such as resistivity, gamma ray, and neutron density sensors, to characterize the rock 1140 surrounding the wellbore 1105. Both MWD and LWD measurements may be transmitted to the surface of the earth 1145 using any suitable telemetry system known in the art, such as a mud-pulse or by wired-drill pipe.

To start drilling, or “spudding in,” the wellbore 1105, the hoisting system lowers the drillstring 1125 suspended from the derrick 1120 of the drill rig towards the planned surface location of the wellbore 1105. An engine, such as a diesel engine, may be used to supply power to the top drive 1150 to rotate the drillstring 1125 via the drive shaft 1155. The weight of the drillstring 1125 combined with the rotational motion enables the drill bit 1135 to bore the wellbore 1105.

The near-surface rock 1140 of the subterranean region of interest 305 is typically made up of loose or soft sediment or rock, so large diameter casing 1160 (e.g., “base pipe” or “conductor casing”) is often put in place while drilling to stabilize and isolate the wellbore 1105. At the top of the base pipe is the wellhead, which serves to provide pressure control through a series of spools, valves, or adapters (not shown). Once near-surface drilling has begun, water or drill fluid may be used to force the base pipe into place using a pumping system until the wellhead is situated just above the surface of the earth 1145.

Drilling may continue without any casing 1160 once deeper or more compact rock 1140 is reached. While drilling, a drilling mud system 1165 may pump drilling mud from a mud tank on the surface of the earth 1145 through the drill pipe. Drilling mud serves various purposes, including pressure equalization, removal of rock cuttings, and drill bit cooling and lubrication.

At planned depth intervals, drilling may be paused and the drillstring 1125 withdrawn from the wellbore 1105. Sections of casing 1160 may be connected, inserted, and cemented into the wellbore 1105. Casing string may be cemented in place by pumping cement and mud, separated by a “cementing plug,” from the surface of the earth 1145 through the drill pipe. The cementing plug and drilling mud force the cement through the drill pipe and into the annular space between the casing 1160 and the wall of the wellbore 1105. Once the cement cures, drilling may recommence. The drilling process is often performed in several stages. Therefore, the drilling and casing cycle may be repeated more than once, depending on the depth of the wellbore 1105 and the pressure on the walls of the wellbore 1105 from surrounding rock 1140.

Due to the high pressures experienced by deep wellbores 1105, a blowout preventer (BOP) may be installed at the wellhead to protect the rig and environment from unplanned oil or gas releases. As the wellbore 1105 becomes deeper, both successively smaller drill bits 1135 and casing 1160 may be used. Drilling deviated or horizontal wellbores 1105 may require specialized drill bits 1135 or drill assemblies.

The drilling system 1100 may be disposed at and communicate with other systems in the wellbore environment, such as the wellbore planning system 1170. The drilling system 1100 may control at least a portion of a drilling operation by providing controls to various components of the drilling operation. In one or more embodiments, the system may receive data from one or more sensors arranged to measure controllable parameters of the drilling operation. As a non-limiting example, sensors may be arranged to measure weight-on-bit, drill rotational speed (RPM), flow rate of the mud pumps (GPM), and rate of penetration of the drilling operation (ROP). Each sensor may be positioned or configured to measure a desired physical stimulus. Drilling may be considered complete when a drilling target 1175 with the reservoir 1115 is reached or the presence of hydrocarbons is established.

FIG. 12 describes a system 1200 in accordance with one or more embodiments. The system 1200 may include at least two of a seismic acquisition system 1205, well logging system 1210, computer system 1000, basin modeling system 1215, interpretation workstation 1220, wellbore planning system 1170, and drilling system 1100. Each part of the system 1200 may be communicably coupled with any other part of the system 1200 via the network 1005 (not shown in FIG. 12). In some embodiments, the seismic acquisition system 1205, well logging system 1210, basin modeling system 1215, interpretation workstation 1220, wellbore planning system 1170, and/or drilling system 1100 may include a computer system 1000. In other embodiments, the basin modeling system 1215 and/or wellbore planning system 1170 may be stored on a memory 1035 of a computer system 1000.

In some embodiments, the seismic acquisition system 1205 may be configured to obtain seismic data from the subterranean region of interest 305. The seismic acquisition system 1205 may include a seismic source configured to emit seismic waves along and into the subterranean region of interest 305. The seismic acquisition system 1205 may further include seismic receivers configured to detect and record the seismic waves. The seismic data may be transferred to, stored on, and processed by a seismic processing system (not shown) prior to being transferred to and stored on the computer system 1000.

The well logging system 1210 may be configured to collect well log data among the biostratigraphic data. The well logging system 1210 may be configured to collect the well log data by being deployed downhole within one or more wells 315a, b within the subterranean region of interest 305. The well log data may be transferred to and stored on the computer system 1000.

In some embodiments, the seismic data may be used to determine the isopach map 300. In some embodiments, the seismic data and/or biostratigraphic data may be used to determine the GDE map 400.

Once the computer system 1000 receives the paleoenvironment chart 100, the computer system 1000 may be configured to perform step 910 as described relative to FIG. 9 to determine the paleobathymetry map 500 of the subterranean region of interest 305. The paleobathymetry map 500 may be determined using the paleoenvironment chart 100 and the isopach map 300 (and, in some embodiments, the GDE map 400).

The paleobathymetry map 500 may be transferred to and stored on the basin modeling system 1215. In some embodiments, the basin modeling system 1215 may be configured to perform step 915 as described relative to FIG. 9 to update a basin model. A paleostructure map 700 or paleotopography map output or displayed from the updated basin model may be transferred to and stored on the interpretation workstation 1220. In some embodiments, the interpretation workstation 1220 may be configured to perform step 920 as described relative to FIG. 9 to identify a location of hydrocarbons within the subterranean region of interest 305 based on the updated basin model.

In some embodiments, the location of hydrocarbons may be transferred to and stored on the wellbore planning system 1170. In some embodiments, the wellbore planning system 1170 may be or include a computer system 1000 or reside on the memory 1035 of a computer system 1000. Further, in some embodiments, the computer system 1000 may include specific software used for wellbore planning. The wellbore planning system 1170 may be configured to design a wellbore plan based, at least in part, on the location of hydrocarbons. The wellbore path within the wellbore plan may be designed to penetrate the location of hydrocarbons within the subterranean region of interest 305.

In some embodiments, the wellbore plan may be transferred to and stored on the drilling system 1100. The drilling system 1100 may be configured to drill a wellbore 1105 within the subterranean region of interest 305 guided by the wellbore plan as illustrated in FIG. 11.

In summary, the disclosed methods may rely on a paleoenvironment chart 100, isopach map 300, and, in some embodiments, GDE map 400 to determine a paleobathymetry map 500 input into a basin model. The disclosed methods may rely on the idea that sedimentary thickness and water depth 105a are inversely related. The updated basin model may be used to predict a location of hydrocarbons within the subterranean region of interest 305 at the present time.

Although only a few example embodiments have been described in detail above, those skilled in the art will readily appreciate that many modifications are possible in the example embodiments without materially departing from this invention. Accordingly, all such modifications are intended to be included within the scope of this disclosure as defined in the following claims.