Co2 injection well placement

Abstract

This disclosure describes methods and systems for CO2 injection well placement in a target area. The method involves identifying input data associated with the target area, the input data including at least one of core samples or well logs from the target area; generating, based on the input data, a structural depth grid of the target area; generating, based on the structural depth grid, a slope map of the target area; generating, based on the slope map of the target area, a flow direction map for the target area; determining, based on the flow direction map, a fluid flow accumulation and a fluid flow length in the target area; and based on the fluid flow accumulation and the fluid flow length in the target area, selecting at least one position for drilling at least one CO2 injection well in the target area.

Description

Attorney Ref.: 38136-2853WO1CO2 INJECTION WELL PLACEMENTCLAIM OF PRIORITY

[0001] This application claims priority to U.S. Patent Application No. 19 / 015,115 filed on January 9, 2025, the entire contents of which are hereby incorporated by¬ reference.TECHNICAL FIELD

[0002] The present disclosure relates to computer-implemented methods and systems for CO2 injection well placement.BACKGROUND

[0003] CO2 emissions into the atmosphere contribute significantly to climate change, leading to adverse impacts such as global warming, melting ice caps, droughts, and severe storms. To offset or reduce these emissions, methods like storing or sequestering CO2 for long periods have been developed. CO2 can be captured either directly at emission sources or drawn from the atmosphere and then transported to suitable underground sequestration sites. When injected as pure gas into these sites, CO2’s buoyancy relative to in situ water requires specific trapping mechanisms, which are subject to uncertainties like the long-term efficacy of impervious cap rocks. These requirements pose challenges to the widespread adoption of CO2 sequestration.

[0004] Efforts to mitigate CO2 emissions have led to advancements in carbon capture utilization and storage (CCUS) technologies, which offer promising solutions for capturing and storing CO2 in oil and gas reservoirs. CCUS methods are helpful for reducing atmospheric CO2, with the potential for indefinite storage through sequestration. Critical to the success of these methods are the processes of monitoring, measuring, and quantifying CO2 sequestration to ensure effective and secure long-term storage.SUMMARY

[0005] This disclosure describes a CO2-shed analysis tool for strategically placing CO2 injection wells in advantageous locations to reduce fluid movement, like vertical migration assisted fluid movement. To do so, the CO2-shed analysis tool determines the direction of fluid flow to prevent CO2 migration toward an oil or gas field, which could have a damaging impact on the subsurface and surface facilities, and which, inAttorney Ref.: 38136-2853WO1turn, increases the risk of leakage to drinkable aquifers and water bodies. Further, the CO2-shed analysis tool can slow down CO2 fluid migration post injection by determining the placement of CO2 injections wells that slows the pace of fluid movement.

[0006] The disclosed tool achieves better control of the subsurface and mitigates the risk of CO2 leakage into oil and gas fields, regional aquifers, or water bodies (e g., used for farming and irrigation). As described in more detail below, the CO2-shed analysis tool does so by: (1) identifying areas with low dip and the potential for slower fluid (plume) migration, and (2) prioritizing those areas for injection well placement. Examples of such areas include geomorphologically flat basins that prevent CO2 from migrating by gravity / buoyancy movement. Furthermore, the CO2-shed analysis tool can predict a CO2 migration time between two points in the subsurface, which makes it a powerful tool for the exploration screening, development planning, and production monitoring stages of CO2 sequestration.

[0007] One aspect of the subject matter described in this specification may be embodied in a method for CO2 injection well placement in a target area. The method involves identifying input data associated with the target area, the input data including at least one of core samples or well logs from the target area; generating, based on the input data, a structural depth grid of the target area; generating, based on the structural depth grid, a slope map of the target area; generating, based on the slope map of the target area, a flow direction map for the target area; determining, based on the flow direction map, a fluid flow accumulation and a fluid flow length in the target area; and based on the fluid flow accumulation and the fluid flow length in the target area, selecting at least one position for drilling at least one CO2 injection well in the target area.

[0008] The previously described implementation is implementable using a computer-implemented method; a non-transitory. computer-readable medium storing computer-readable instructions to perform the computer-implemented method; and a computer system including a computer memory interoperably coupled with a hardware processor configured to perform the computer-implemented method or the instructions stored on the non-transitory, computer-readable medium. These and other embodiments may each optionally include one or more of the following features.Attorney Ref.: 38136-2853WO1

[0009] In some implementations, the method further involves performing a quality check (QC) on the input data.

[0010] In some implementations, generating the structural depth grid of the target area involves: integrating the input data to generate a structural depth map of the target area; and dividing the structural depth map into a grid of cells, each cell representing a respective portion of the target area.

[0011] In some implementations, generating the slope map of the target area involves performing a dip analysis of the structural depth grid to determine respective inclination range values in respective sub-areas of the target area.

[0012] In some implementations, the respective inclination range values include a maximum and minimum inclination value in a corresponding respective sub-area.

[0013] In some implementations, determining the fluid flow accumulation and the fluid flow length in the target area involves performing, using the flow direction map, a pour point and water-shed analysis in the target area.

[0014] In some implementations, selecting the at least one position for drilling the at least one CO2 inj ection well in the target area involves generating a ranking of a plurality' of candidate drilling locations in the target area, where the ranking ranks the plurality of candidate drilling locations based on at least one of respective fluid movement, fluid flow length, or fluid flow accumulation characteristics of the plurality of candidate drilling locations; and selecting the at least one position based on the ranking of the plurality of candidate drilling locations.

[0015] In some implementations, determining, based on the flow direction map, a fluid flow accumulation and a fluid flow length in the target area: determining, for each of a plurality of testing scenarios, a respective fluid flow accumulation and a respective fluid flow length in the target area, where each of the plurality of testing scenarios includes one or more candidate injection wells.

[0016] In some implementations, selecting the at least one position for drilling the at least one CO2 injection well in the target area involves generating a ranking of the plurality of testing scenarios; and selecting the at least one position for drilling the at least one CO2 injection well based on the ranking.

[0017] The details of one or more embodiments of these systems and methods are set forth in the accompanying drawings and description below. Other features, objects, andAttorney Ref.: 38136-2853WO1advantages of these systems and methods will be apparent from the description, drawings, and claims.BRIEF DESCRIPTION OF DRAWINGS

[0018] FIG. 1 illustrates a CO2-shed analysis workflow, according to some implementations.

[0019] FIG. 2 illustrates a pictorial representation of the CO2-shed analysis workflow, according to some implementations.

[0020] FIG. 3A illustrates an example slope / inclination determination. FIG. 3B illustrates an example flow path accumulation, and FIG. 3C illustrates an example flow distance, according to some implementations.

[0021] FIG. 4A illustrates a well based fluid flow analysis of CO2 showing potential CO2 migration pathway using flow streamlines during and post CO2 injection, according to some implementations.

[0022] FIG. 4B illustrates a regional time map showing analysis and location of CO2 injector wells in a mildly inclined topography, according to some implementations.

[0023] FIG. 4C illustrates regional time map showing analysis of CO2 fluid flow migration pathway using flow streamlines, according to some implementations.

[0024] FIG. 5 illustrates an example method, according to some implementations.

[0025] FIG. 6 illustrates a block diagram of an example computer system that can be used to provide computational functionalities associated with described algorithms, methods, functions, processes, flows, and procedures, according to some implementations of the present disclosure.

[0026] FIG. 7 illustrates hydrocarbon production operations that include both one or more field operations and one or more computational operations, which exchange information and control exploration for the production of hydrocarbons, according to some implementations.

[0027] Like reference numbers and designations in the various drawings indicate like elements.DETAILED DESCRIPTION

[0028] This disclosure describes systems and methods for CO2 injection well placement. The disclosed systems and methods identify areas with low dip / inclination for fluid flow as candidate areas for injecting or sequestering of CO2 in the subsurface.Attorney Ref.: 38136-2853WO1The systems and methods can be applied in different environments, such as, saline aquifers or facies-controlled aquifers. Saline aquifers are underground layers of waterbearing rock or sediment that contain saline water. CO2 can be injected into the aquifer where it is trapped by various mechanisms, such as structural trapping, solubility' trapping, and mineral trapping. Facies-controlled aquifers are areas where the distribution and characteristics of the aquifer are strongly influenced by the depositional environment (or facies) of the sedimentary rocks. The term “facies” refers to the distinct characteristics of rock layers that reflect their depositional conditions, such as grain size, composition, and sedimentary' structures.

[0029] When evaluating injection well locations, the systems and methods also determine the direction of fluid flow in the subsurface. This allows the systems and methods to select injection well locations that avoid existing oil and gas operations, mitigate the risk of CO2 leakage, slow down CO2 fluid (plume) migration post injection, and sequestrate large volumes of CO2 in the surface. Additionally, the systems and methods can determine the time and volume of CO2 fluid migration from a point of injection to designated migration points.

[0030] Among other things, the disclosed systems and methods can be used for carbon capture and sequestration. The disclosed systems and methods identify geological storage areas for CO2 sequestration in the subsurface without interfering with existing oil and gas operations, and facilitate storing significant amounts of CO2 in specific locations controlled by underlying subsurface conditions.

[0031] Unlike existing systems, the disclosed systems and methods combine CO2 shed analysis (which utilizes hydraulic subsurface water flow' path, inclination, and facies control) and CO2 flow path to identify a CO2 injection location that minimizes CO2 fluid flow and limits CO2 leakage post injection. Thus, the disclosed systems and methods can strategically place injection wells to mitigate risk of leakage to the surface and to sequester more CO2 volumes by identifying locations with the slow' fluid hydraulic movement.

[0032] FIG. 1 illustrates a CO2-shed analysis workflow 100, according to some implementations. For convenience, workflow 100 will be described as being performed by a system of one or more computers, located in one or more locations, and programmed appropriately in accordance with this specification. FIG. 6 illustrates an example computer system 600, which is described in more detail below.Attorney Ref.: 38136-2853WO1

[0033] At step 102, the computer system selects a target area for performing the CO2 shed analysis. The target area can be a saline aquifer, a facies-controlled aquifer, or another type of geographical formation that can be used for CO2 sequestration. In some examples, the computer system receives a user input indicative of the target area. In these examples, the user input can identify the target area using geographical coordinates defining the area or a unique name assigned to the target area.

[0034] At step 104, the computer system identifies key data for the workflow 100, obtains the data, and quality checks (QC) the data. The data can include core samples obtained from and well logs measured in the target area, including gamma ray logs, seismic logs, resistivity logs, densify logs and / or sonic logs. Additionally, the data can include rock properties, for example, data on porosity, permeability, and fluid saturation derived from the well logs and / or core samples. In some examples, quality checking the data involves data validation (e.g., cross-checking data across different sources), calibration (e.g., depth matching well logs with core samples), anomaly detection (e.g., identifying artifacts in the data), among other quality checks known to a person of ordinary skill in the art.

[0035] At step 106, the computer system integrates the data to create a depth map for the target area. As shown in FIG. 1, creating the depth map involves the integration of multiple geophysical and geological data sources, each of which contributes information for building an accurate subsurface model of the target area. The integrated data includes well ties, well correlation, seismic data, petrophysics, and hydrocarbon (HC) fields. These data sources are explained in more detail below;

[0036] Well ties involve matching geological data from wells with seismic data to create a geological model. This is done by generating seismograms from well logs, w hich are then correlated with actual seismic traces. This step ensures that the depth of geological formations identified in well logs corresponds accurately with their seismic reflections.

[0037] Well correlation involves the analysis and comparison of well logs from multiple wells in the target area. This process helps identify and correlate geological markers, such as formation tops, and continuity of stratigraphic units across the target area. Well correlation is helpful for mapping the spatial distribution of reservoir rocks and understanding the depositional environment.Attorney Ref.: 38136-2853WO1

[0038] Seismic data interpretation involves the creation of time grids that represent the two-way travel time of seismic waves to and from geological interfaces. These time grids are then converted into depth grids. This process uses velocity models derived from well data, seismic velocities, and / or vertical seismic profile (VSP) data to translate time measurements into accurate depth measurements.

[0039] Petrophysics data provides information about reservoir rock properties, such as porosity, permeability, and fluid saturation, which can be derived from well logs and core samples. This information is used for characterizing the target area’s storage and flow capacities. Petrophysical analysis helps identifying sweet spots within the reservoir where hydrocarbon saturation is highest. Integrating petrophysical data into the depth map ensures that the reservoir model includes not just structural details but also the rock property characteristics that impact fluid movement in the target area.

[0040] Hydrocarbon field data includes information on known hydrocarbon accumulations, production history, and / or pressure / temperature conditions. This data is indicative of the behavior reservoirs in the target area, including pressure depletion patterns and water influx.

[0041] As stated, at step 106, the computer system integrates the data to create the depth map for the target area. This step involves, aligning well data with seismic data through well ties, correlating geological markers across wells to establish continuity, using seismic interpretation to convert time maps to depth maps, providing a detailed structural model, incorporating petrophysical properties to add reservoir quality details to the model, and integrating hydrocarbon field data to include reservoir dynamics. In some examples, the resulting final depth map is a three-dimensional (3D) or 2D representation of the target area. The final depth map is indicative of the structural features and reservoir rock properties of the target area, among other characteristics.

[0042] At step 108, the computer system performs grid / raster analysis on the final depth map to generate a structural depth grid. This step involves dividing the target area into a grid of cells or pixels, each representing a portion of the subsurface. Each cell includes specific data values for various attributes, such as depth, porosity, permeability, and / or fluid saturation.

[0043] At step 110, the computer system uses the structural depth grid to generate a slope map of the target area. In some examples, the computer system identifies areas with loosely spaced contours in the structural depth grid. Loosely spaced contoursAttorney Ref.: 38136-2853WO1indicate regions where the measured attribute, such as depth or elevation, changes gradually over a larger distance, signifying a gentle gradient, slope, or topography. These contours, which appear as spaced lines or contours on a map, suggest a more homogeneous area compared to regions with tightly spaced contours that indicate rapid changes. This step helps identify areas that are topographically flat or without steep slopes.

[0044] In some implementations, the computer system performs a dip / azimuth analysis of the structural depth grid, e.g., in the areas with loosely spaced contours, to determine dip / inclination in the target area. Dip, or inclination, refers to the angle at which a geological layer or fault plane deviates from the horizontal plane. It can be measured in degrees and indicates the steepness and of the inclined layer or fault. Azimuth specifies the compass direction in which the geological layer or fault plane is inclined. More specifically, the computer system can determine the dip / inclination of subsurface reservoir seal pairs, where a reservoir / seal pair refers to potential reservoir and seal rocks overlying the primary’ injection reservoir and its top seal. In some examples, the computer system determines dip / inclination ranges by determining minimum and maximum values in different sub-areas within the target area, e.g., 0-2 degrees, 2-4 degrees, 4-6 degrees, etc.

[0045] At step 112, the computer system identifies derisking areas in the target area based on the slope map. In particular, the computer system identifies areas with low dip / inclination, e.g., 0-2 degrees, and selects those areas as derisking areas in which there is a lower risk of placing CO2 injection wells. In some examples, the computer system selects at least one area with the lowest dip / inclination range as the derisking area(s).

[0046] At step 114, the computer system generates a flow direction map in the target area. A flow direction map is a geospatial representation that illustrates the direction, e.g., using graphical arrows or vectors, in which fluids move through the subsurface. In some examples, the computer system generates the flow direction map based on the slope map and / or the structural depth grid. In particular, the computer system uses characteristics of the target reservoir, such as topography (e.g., the slope map) and subsurface permeability, to generate the flow direction map.

[0047] At steps 116a and 116b, the computer system determines a flow accumulation and flow length in one or more derisking areas. More specifically, the computer systemAttorney Ref.: 38136-2853WO1performs a pour point and water-shed analysis for the one or more derisking areas. The pour point analysis is conducted to determine how fluid will flow at a particular location. This is done with the knowledge of the facies and salinity as these characteristics control the pace of fluid movement in the water-shed and pour point zones. In some examples, the computer system performs the pour point analysis by alternating the injection rate, e.g., 1 million Tons, 4 million Tons, 6 million Tons, and 8 million Tons, in different testing scenarios, where each testing scenario is defined by a number and location of testing wells. Water-shed analysis is performed to understand the behavior of water at different topographic inclinations, for example, considering the density and viscosities of the different phases. Using this information, the computer system determines the flow accumulation and flow length for the different testing scenarios.

[0048] More specifically, the computer system tests a scenario by placing one or more injection wells at one or more corresponding locations in the target area and performing a CO2 shed analysis. The CO2 shed analysis predicts the flow direction, migration time from the injection point to a marked location, and accumulation / concentration of CO2 as it migrates within the subsurface. Additionally, the CO2 shed analysis provides an understanding of the flow of the different phases of CO2 considering density, viscosity, facies, and / or inclinations. Note that migration timing of CO2 fluid serves as a risk assessment tool. For example, the computer system can quantify the risk of the CO2 injected in a well migrating quickly to a location identified as risky, e.g., having significant environmental impact or could cause earthquake due to fault reactivation. As another example, the computer system can determine the CO2 migration time between an aquifer used for drinking or domestic activities to injection well or even a leakage point or surface. Thus, the migration time provides an understanding of the potential CO2 risk of leakage or interference.

[0049] At step 118, the computer system determines CO2 injection well placement. In particular, the computer system compares the results from the different testing scenarios (e.g., number and location of injection wells) to determine which scenarios have results that are favorable for CO2 injection well placement. The favorable results include the slowest fluid movement, shortest flow length, and / or least spread flow accumulation. Additionally, the computer system compares the dissolution, residual and solubility trapping for each of the testing scenarios. Dissolution trapping occurs when CO2 dissolves into the formation water (brine) present in the geological reservoir. ThisAttorney Ref.: 38136-2853WO1process reduces the buoyancy of CO2, making it less likely to migrate upwards and escape the storage site. Residual trapping is when CO2 gets trapped in pore spaces due to capillary forces, immobilizing small clusters of CO2. Solubility trapping is when CO2 dissolves chemically into brine, forming carbonic acid and its dissociation products, enhancing stability.

[0050] In some implementations, the computer system generates a ranking of the candidate areas for CO2 injection well placement in order of most favorable results for CO2 injection well placement. The computer system then selects one or more of the candidate areas as areas for placing one or more CO2 injection wells. In other implementations, the computer system generates a ranking of the different testing scenarios, each of which represents a different combination of number of wells and locations, in order of most favorable results for CO2 injection well placement. The computer system then selects the top ranked testing scenario as the number / location of wells to implement.

[0051] FIG. 2 illustrates a pictorial representation 200 of the CO2 shed analysis workflow, according to some implementations. FIG. 2 illustrates the stages of CO2 shed analysis from the structural map formation to dip / inclination analysis. At the stage of determining the slope, the dip / inclination of the subsurface reservoir seal pairs is defined by areas with specified ranges of slope, e.g., 0-2 degrees, 2-4 degrees, etc. A flow direction analysis is conducted after determining the slope and a CO2 / water-shed spatial analysis is produced. In particular, the flow accumulation and flow length analyses are conducted with different testing scenarios (e.g., different CO2 injection amounts, different areas with different slopes, and / or different subsurface properties, e.g., salinity and facies). These analyses when combined with facies and salinity’ are indicative of the areas where CO2 wells will be effective for dissolution, residual and solubility trapping.

[0052] FIG. 3A illustrates an example slope / inclination determination, FIG. 3B illustrates an example flow path accumulation, and FIG. 3C illustrates an example flow distance, according to some implementations. As described previously, the slope, flow' accumulation, and flow’ distance are determined from a depth structural map of the target reservoir. These figures enable determining areas with minimum slope, flow' accumulation, and / or flow distance for CO2 injection well placement.Attorney Ref.: 38136-2853WO1

[0053] FIG. 4A illustrates a well based fluid flow analysis of CO2 showing potential CO2 migration pathway using flow streamlines during and post CO2 injection, according to some implementations. At this stage, after the wells are placed based on the results from the analysis of slope, flow accumulation, and flow distance, observations are made during and after CO2 injection to determine the behavior of fluid migration pattern in the subsurface.

[0054] FIG. 4B illustrates a regional time map showing analysis and location of CO2 injector wells in a mildly inclined topography, according to some implementations. FIG.4C illustrates regional time map showing analysis of CO2 fluid flow migration pathway¬ using flow streamlines, according to some implementations. Superimposing the results of the analysis on depth structural maps re-enforces the importance of CO2 shed analysis and the role inclination plays in the migration of CO2 fluids within the subsurface when facies and salinity are integrated into the workflow.

[0055] FIG. 5 illustrates an example process 500 for CO2 injection well placement in a target area. For convenience, process 500 will be described as being performed by a computer system having one or more computers located in one or more locations and programmed appropriately in accordance with this specification. An example of the computer system is the computing system 600 illustrated in FIG. 6 and described below.

[0056] At 502, a computer system identifies input data associated with the target area, the input data comprising core samples and well logs from the target area.

[0057] At 504, the computer system generates, based on the input data, a structural depth grid of the target area;

[0058] At 506, the computer system generates, based on the structural depth grid, a slope map of the target area;

[0059] At 508, the computer system generates, based on the slope map of the target area, a flow direction map for the target area;

[0060] At 510, the computer sy stem determines, based on the flow direction map, a fluid flow accumulation and a fluid flow length in the target area.

[0061] At 512, the computer system, based on the fluid flow accumulation and the fluid flow length in the target area, selecting at least one position for drilling at least one CO2 injection well in the target.

[0062] In some implementations, the method further involves performing a quality¬ check (QC) on the input data.Attorney Ref.: 38136-2853WO1

[0063] In some implementations, generating the structural depth grid of the target area involves: integrating the input data to generate a structural depth map of the target area; and dividing the structural depth map into a grid of cells, each cell representing a respective portion of the target area.

[0064] In some implementations, generating the slope map of the target area involves performing a dip analysis of the structural depth grid to determine respective inclination range values in respective sub-areas of the target area.

[0065] In some implementations, the respective inclination range values include a maximum and minimum inclination value in a corresponding respective sub-area.

[0066] In some implementations, determining the fluid flow accumulation and the fluid flow length in the target area involves performing, using the flow direction map, a pour point and water-shed analysis in the target area.

[0067] In some implementations, selecting the at least one position for drilling the at least one CO2 inj ection well in the target area involves generating a ranking of a plurality of candidate drilling locations in the target area, where the ranking ranks the plurality of candidate drilling locations based on at least one of respective fluid movement, fluid flow length, or fluid flow accumulation characteristics of the plurality' of candidate drilling locations; and selecting the at least one position based on the ranking of the plurality of candidate drilling locations.

[0068] In some implementations, determining, based on the flow direction map, a fluid flow accumulation and a fluid flow length in the target area: determining, for each of a plurality of testing scenarios, a respective fluid flow accumulation and a respective fluid flow length in the target area, where each of the plurality' of testing scenarios includes one or more candidate injection wells.

[0069] In some implementations, selecting the at least one position for drilling the at least one CO2 injection well in the target area involves generating a ranking of the plurality' of testing scenarios; and selecting the at least one position for drilling the at least one CO2 injection well based on the ranking.

[0070] FIG. 6 is a block diagram of an example computer system 600 that can be used to provide computational functionalities associated with described algorithms, methods, functions, processes, flows, and procedures, according to some implementations of the present disclosure. In some implementations, the computer system performing process 100 or 500 can be the computer system 600, include the computer system 600, or theAttorney Ref.: 38136-2853WO1computer system performing process 100 or 500 can communicate with the computer system 600.

[0071] The illustrated computer 602 is intended to encompass any computing device such as a server, a desktop computer, an embedded computer, a laptop / notebook computer, a wireless data port, a smart phone, a personal data assistant (PDA), a tablet computing device, or one or more processors within these devices, including physical instances, virtual instances, or both. The computer 602 can include input devices such as keypads, keyboards, and touch screens that can accept user information. Also, the computer 602 can include output devices that can convey information associated with the operation of the computer 602. The information can include digital data, visual data, audio information, or a combination of information. The information can be presented in a graphical user interface (UI) (or GUI). In some implementations, the inputs and outputs include display ports (such as DVI-I+2x display ports), USB 3.0, GbE ports, isolated DI / O, SATA-III (6.0 Gb / s) ports, mPCIe slots, a combination of these, or other ports. In instances of an edge gateway, the computer 602 can include a Smart Embedded Management Agent (SEMA), such as a built-in ADLINK SEMA 2.2, and a video sync technology, such as Quick Sync Video technology7supported by ADLINK MSDK+. In some examples, the computer 602 can include the MXE-5400 Series processor-based fanless embedded computer by ADLINK, though the computer 602 can take other forms or include other components.

[0072] The computer 602 can serve in a role as a client, a network component, a server, a database, a persistency, or components of a computer system for performing the subject matter described in the present disclosure. The illustrated computer 602 is communicably coupled with a network 630. In some implementations, one or more components of the computer 602 can be configured to operate within different environments, including cloud-computing-based environments, local environments, global environments, and combinations of environments.

[0073] At a high level, the computer 602 is an electronic computing device operable to receive, transmit, process, store, and manage data and information associated with the described subject matter. According to some implementations, the computer 602 can also include, or be communicably coupled with, an application server, an email server, a web server, a caching server, a streaming data server, or a combination of servers.Attorney Ref.: 38136-2853WO1

[0074] The computer 602 can receive requests over network 630 from a client application (for example, executing on another computer 602). The computer 602 can respond to the received requests by processing the received requests using software applications. Requests can also be sent to the computer 602 from internal users (for example, from a command console), external (or third) parties, automated applications, entities, individuals, systems, and computers.

[0075] Each of the components of the computer 602 can communicate using a system bus 603. In some implementations, any or all of the components of the computer 602, including hardware or software components, can interface with each other or the interface 604 (or a combination of both), over the system bus. Interfaces can use an application programming interface (API) 612. a service layer 613, or a combination of the API 612 and service layer 613. The API 612 can include specifications for routines, data structures, and object classes. The API 612 can be either computer-language independent or dependent. The API 612 can refer to a complete interface, a single function, or a set of APIs 612.

[0076] The service layer 613 can provide software services to the computer 602 and other components (whether illustrated or not) that are communicably coupled to the computer 602. The functionality' of the computer 602 can be accessible for all service consumers using this service layer 613. Software services, such as those provided by the service layer 613, can provide reusable, defined functionalities through a defined interface. For example, the interface can be software written in JAVA, C++, or a language providing data in extensible markup language (XML) format. While illustrated as an integrated component of the computer 602, in alternative implementations, the API 612 or the service layer 613 can be stand-alone components in relation to other components of the computer 602 and other components communicably coupled to the computer 602. Moreover, any or all parts of the API 612 or the service layer 613 can be implemented as child or sub-modules of another software module, enterprise application, or hardware module without departing from the scope of the present disclosure.

[0077] The computer 602 can include an interface 604. Although illustrated as a single interface 604 in FIG. 6, two or more interfaces 604 can be used according to particular needs, desires, or particular implementations of the computer 602 and the described functionality. The interface 604 can be used by the computer 602 forAttorney Ref.: 38136-2853WO1communicating with other systems that are connected to the network 630 (whether illustrated or not) in a distributed environment. Generally, the interface 604 can include, or be implemented using, logic encoded in software or hardware (or a combination of software and hardware) operable to communicate with the network 630. More specifically, the interface 604 can include software supporting one or more communication protocols associated with communications. As such, the network 630 or the interface's hardware can be operable to communicate physical signals within and outside of the illustrated computer 602.

[0078] The computer 602 includes a processor 605. Although illustrated as a single processor 605 in FIG. 6, two or more processors 605 can be used according to particular needs, desires, or particular implementations of the computer 602 and the described functionality. Generally, the processor 605 can execute instructions and manipulate data to perform the operations of the computer 602, including operations using algorithms, methods, functions, processes, flows, and procedures as described in the present disclosure.

[0079] The computer 602 can also include a database 606 that can hold data for the computer 602 and other components connected to the network 630 (whether illustrated or not). For example, database 606 can be an in-memory, conventional, or a database storing data consistent with the present disclosure. In some implementations, the database 606 can be a combination of two or more different database types (for example, hybrid in-memory and conventional databases) according to particular needs, desires, or particular implementations of the computer 602 and the described functionality. Although illustrated as a single database 606 in FIG. 6, two or more databases (of the same, different, or combination of types) can be used according to particular needs, desires, or particular implementations of the computer 602 and the described functionality. While database 606 is illustrated as an internal component of the computer 602, in alternative implementations, database 606 can be external to the computer 602.

[0080] The computer 602 also includes a memory 607 that can hold data for the computer 602 or a combination of components connected to the network 630 (whether illustrated or not). Memory 607 can store any data consistent with the present disclosure. In some implementations, memory 607 can be a combination of two or more different types of memory (for example, a combination of semiconductor and magnetic storage)Attorney Ref.: 38136-2853WO1according to particular needs, desires, or particular implementations of the computer 602 and the described functionality. Although illustrated as a single memory 607 in FIG. 6, two or more memories 607 (of the same, different, or combination of types) can be used according to particular needs, desires, or particular implementations of the computer 602 and the described functionality. While memory 607 is illustrated as an internal component of the computer 602, in alternative implementations, memory 607 can be external to the computer 602.

[0081] An application 608 can be an algorithmic software engine providing functionality according to particular needs, desires, or particular implementations of the computer 602 and the described functionality'. For example, an application 608 can serve as one or more components, modules, or applications 608. Multiple applications 608 can be implemented on the computer 602. Each application 608 can be internal or external to the computer 602.

[0082] The computer 602 can also include a power supply 614. The power supply 614 can include a rechargeable or non-rechargeable battery that can be configured to be either user- or non-user-replaceable. In some implementations, the power supply 614 can include power-conversion and management circuits, including recharging, standby, and power management functionalities. In some implementations, the power-supply 614 can include a power plug to allow the computer 602 to be plugged into a wall socket or a power source to, for example, power the computer 602 or recharge a rechargeable battery.

[0083] There can be any number of computers 602 associated with, or external to, a computer system including computer 602, with each computer 602 communicating over network 630. Further, the terms “client”, “user”, and other appropriate terminology can be used interchangeably without departing from the scope of the present disclosure. Moreover, the present disclosure contemplates that many users can use one computer 602 and one user can use multiple computers 602.

[0084] FIG. 7 illustrates hydrocarbon production operations 700 that include both one or more field operations 710 and one or more computational operations 712, which exchange information and control exploration for the production of hydrocarbons. In some implementations, outputs of techniques of the present disclosure can be performed before, during, or in combination with the hydrocarbon production operations 700, specifically, for example, either as field operations 710 or computational operations 712,Attorney Ref.: 38136-2853WO1or both.

[0085] Examples of field operations 710 include forming / drilling a wellbore, hydraulic fracturing, producing through the wellbore, injecting fluids (such as water) through the wellbore, to name a few. In some implementations, methods of the present disclosure can trigger or control the field operations 710. For example, the methods of the present disclosure can generate data from hardware / s oft ware including sensors and physical data gathering equipment (e.g., seismic sensors, well logging tools, flow meters, and temperature and pressure sensors). The methods of the present disclosure can include transmitting the data from the hardware / software to the field operations 710 and responsively triggering the field operations 710 including, for example, generating plans and signals that provide feedback to and control physical components of the field operations 710. Alternatively or in addition, the field operations 710 can trigger the methods of the present disclosure. For example, implementing physical components (including, for example, hardware, such as sensors) deployed in the field operations 710 can generate plans and signals that can be provided as input or feedback (or both) to the methods of the present disclosure.

[0086] Examples of computational operations 712 include one or more computer systems 720 that include one or more processors and computer-readable media (e.g., non-transitory computer-readable media) operatively coupled to the one or more processors to execute computer operations to perform the methods of the present disclosure. The computational operations 712 can be implemented using one or more databases 718, which store data received from the field operations 710 and / or generated internally within the computational operations 712 (e.g., by implementing the methods of the present disclosure) or both. For example, the one or more computer systems 720 process inputs from the field operations 710 to assess conditions in the physical world, the outputs of which are stored in the databases 718. For example, seismic sensors of the field operations 710 can be used to perform a seismic survey to map subterranean features, such as facies and faults. In performing a seismic survey, seismic sources (e.g., seismic vibrators or explosions) generate seismic waves that propagate in the earth and seismic receivers (e g., geophones) measure reflections generated as the seismic waves interact with boundaries between layers of a subsurface formation. The source and received signals are provided to the computational operations 712 where they are stored in the databases 718 and analyzed by the one or more computer systems 720.Attorney Ref.: 38136-2853WO1

[0087] In some implementations, one or more outputs 722 generated by the one or more computer systems 720 can be provided as feedback / input to the field operations 710 (either as direct input or stored in the databases 718). The field operations 710 can use the feedback / input to control physical components used to perform the field operations 710 in the real world.

[0088] For example, the computational operations 712 can process the seismic data to generate three-dimensional (3D) maps of the subsurface formation. The computational operations 712 can use these 3D maps to provide plans for locating and drilling exploratory wells. In some operations, the exploratory’ wells are drilled using logging-while-drilling (LWD) techniques which incorporate logging tools into the drill string. LWD techniques can enable the computational operations 712 to process new information about the formation and control the drilling to adjust to the observed conditions in real-time.

[0089] The one or more computer systems 720 can update the 3D maps of the subsurface formation as information from one exploration well is received and the computational operations 712 can adjust the location of the next exploration well based on the updated 3D maps. Similarly, the data received from production operations can be used by the computational operations 712 to control components of the production operations. For example, production well and pipeline data can be analyzed to predict slugging in pipelines leading to a refinery and the computational operations 712 can control machine operated valves upstream of the refinery to reduce the likelihood of plant disruptions that run the risk of taking the plant offline.

[0090] In some implementations of the computational operations 712, customized user interfaces can present intermediate or final results of the above-described processes to a user. Information can be presented in one or more textual, tabular, or graphical formats, such as through a dashboard. The information can be presented at one or more on-site locations (such as at an oil well or other facility), on the Internet (such as on a webpage), on a mobile application (or app), or at a central processing facility.

[0091] The presented information can include feedback, such as changes in parameters or processing inputs, that the user can select to improve a production environment, such as in the exploration, production, and / or testing of petrochemical processes or facilities. For example, the feedback can include parameters that, when selected by the user, can cause a change to. or an improvement in. drilling parametersAttorney Ref.: 38136-2853WO1(including drill bit speed and direction) or overall production of a gas or oil well. The feedback, when implemented by the user, can improve the speed and accuracy of calculations, streamline processes, improve models, and solve problems related to efficiency, performance, safety, reliability, costs, downtime, and the need for human interaction.

[0092] In some implementations, the feedback can be implemented in real-time, such as to provide an immediate or near-immediate change in operations or in a model. The term real-time (or similar terms as understood by one of ordinary skill in the art) means that an action and a response are temporally proximate such that an individual perceives the action and the response occurring substantially simultaneously. For example, the time difference for a response to display (or for an initiation of a display) of data following the individual’s action to access the data can be less than 1 millisecond (ms), less than 1 second (s), or less than 5 s. While the requested data need not be displayed (or initiated for display) instantaneously, it is displayed (or initiated for display) without any intentional delay, taking into account processing limitations of a described computing system and time required to, for example, gather, accurately measure, analyze, process, store, or transmit the data.

[0093] Events can include readings or measurements captured by downhole equipment such as sensors, pumps, bottom hole assemblies, or other equipment. The readings or measurements can be analyzed at the surface, such as by using applications that can include modeling applications and machine learning. The analysis can be used to generate changes to settings of downhole equipment, such as drilling equipment. In some implementations, values of parameters or other variables that are determined can be used automatically (such as through using rules) to implement changes in oil or gas well exploration, production / drilling, or testing. For example, outputs of the present disclosure can be used as inputs to other equipment and / or systems at a facility. This can be especially useful for systems or various pieces of equipment that are located several meters or several miles apart, or are located in different countries or other jurisdictions.

[0094] Implementations of the subject matter and the functional operations described in this specification can be implemented in digital electronic circuitry, in tangibly embodied computer software or firmware; in computer hardware, including the structures disclosed in this specification and their structural equivalents; or inAttorney Ref.: 38136-2853WO1combinations of one or more of them. Software implementations of the described subject matter can be implemented as one or more computer programs. Each computer program can include one or more modules of computer program instructions encoded on a tangible, non-transitory, computer-readable computer-storage medium for execution by, or to control the operation of, data processing apparatus. Alternatively, or additionally, the program instructions can be encoded in / on an artificially generated propagated signal. For example, the signal can be a machine-generated electrical, optical, or electromagnetic signal that is generated to encode information for transmission to a suitable receiver apparatus for execution by a data processing apparatus. The computer-storage medium can be a machine-readable storage device, a machine-readable storage substrate, a random or serial access memory’ device, or a combination of computer-storage mediums.

[0095] The terms ‘'data processing apparatus”, “computer”, and “electronic computer device” (or equivalent as understood by one of ordinary skill in the art) refer to data processing hardware. For example, a data processing apparatus can encompass all kinds of apparatuses, devices, and machines for processing data, including by way of example, a programmable processor, a computer, or multiple processors or computers. The apparatus can also include special purpose logic circuitry’ including, for example, a central processing unit (CPU), a field programmable gate array (FPGA), or an application specific integrated circuit (ASIC). In some implementations, the data processing apparatus or special purpose logic circuitry’ (or a combination of the data processing apparatus and special purpose logic circuitry ) can be hardware- or softwarebased (or a combination of both hardware- and software-based). The apparatus can optionally include code that creates an execution environment for computer programs, for example, code that constitutes processor firmware, a protocol stack, a database management system, an operating system, or a combination of execution environments. The present disclosure contemplates the use of data processing apparatuses with or without conventional operating systems, for example, Linux, Unix, Windows, Mac OS, Android, or iOS.

[0096] A computer program, which can also be referred to or described as a program, software, a software application, a module, a software module, a script, or code can be written in any form of programming language. Programming languages can include, for example, compiled languages, interpreted languages, declarative languages, orAttorney Ref.: 38136-2853WO1procedural languages. Programs can be deployed in any form, including as stand-alone programs, modules, components, subroutines, or units for use in a computing environment. A computer program can, but need not, correspond to a file in a file system. A program can be stored in a portion of a file that holds other programs or data, for example, one or more scripts stored in a markup language document; in a single file dedicated to the program in question; or in multiple coordinated files storing one or more modules, sub programs, or portions of code. A computer program can be deployed for execution on one computer or on multiple computers that are located, for example, at one site or distributed across multiple sites that are interconnected by a communication network. While portions of the programs illustrated in the various figures may be shown as individual modules that implement the various features and functionality through various objects, methods, or processes; the programs can instead include a number of sub-modules, third-party7services, components, and libraries. Conversely, the features and functionality of various components can be combined into single components as appropriate. Thresholds used to make computational determinations can be statically, dynamically, or both statically and dynamically determined.

[0097] The methods, processes, or logic flows described in this specification can be performed by one or more programmable computers executing one or more computer programs to perform functions by operating on input data and generating output. The methods, processes, or logic flows can also be performed by, and apparatus can also be implemented as, special purpose logic circuitry, for example, a CPU, an FPGA, or an ASIC.

[0098] Computers suitable for the execution of a computer program can be based on one or more of general and special purpose microprocessors and other kinds of CPUs. The elements of a computer are a CPU for performing or executing instructions and one or more memory devices for storing instructions and data. Generally, a CPU can receive instructions and data from (and write data to) a memory. A computer can also include, or be operatively coupled to, one or more mass storage devices for storing data. In some implementations, a computer can receive data from, and transfer data to, the mass storage devices including, for example, magnetic, magneto optical disks, or optical disks. Moreover, a computer can be embedded in another device, for example, a mobile telephone, a personal digital assistant (PDA), a mobile audio or video player, a gameAttorney Ref.: 38136-2853WO1console, a global positioning system (GPS) receiver, or a portable storage device such as a universal serial bus (USB) flash drive.

[0099] Computer readable media (transitory or non-transitory, as appropriate) suitable for storing computer program instructions and data can include all forms of permanent / non-permanent and volatile / non-volatile memory, media, and memory devices. Computer readable media can include, for example, semiconductor memory’ devices such as random access memory (RAM), read only memory (ROM), phase change memory (PRAM), static random access memory (SRAM), dynamic random access memory' (DRAM), erasable programmable read-only memory (EPROM), electrically erasable programmable read-only memory' (EEPROM), and flash memory' devices. Computer readable media can also include, for example, magnetic devices such as tape, cartridges, cassettes, and intemal / removable disks. Computer readable media can also include magneto optical disks, optical memory' devices, and technologies including, for example, digital video disc (DVD), CD ROM, DVD+ / -R, DVD-RAM, DVD-ROM, HD-DVD, and BLURAY. The memory can store various objects or data, including caches, classes, frameworks, applications, modules, backup data, jobs, web pages, web page templates, data structures, database tables, repositories, and dynamic information. Types of objects and data stored in memory' can include parameters, variables, algorithms, instructions, rules, constraints, and references. Additionally, the memory can include logs, policies, security or access data, and reporting files. The processor and the memory can be supplemented by, or incorporated in, special purpose logic circuitry'.

[0100] Implementations of the subject matter described in the present disclosure can be implemented on a computer having a display device for providing interaction with a user, including displaying information to (and receiving input from) the user. Types of display' devices can include, for example, a cathode ray' tube (CRT), a liquid crystal display (LCD), a light-emitting diode (LED), or a plasma monitor. Display devices can include a keyboard and pointing devices including, for example, a mouse, a trackball, or a trackpad. User input can also be provided to the computer through the use of a touchscreen, such as a tablet computer surface with pressure sensitivity or a multi-touch screen using capacitive or electric sensing. Other kinds of devices can be used to provide for interaction with a user, including to receive user feedback, for example, sensory' feedback including visual feedback, auditory feedback, or tactile feedback. Input fromAttorney Ref.: 38136-2853WO1the user can be received in the form of acoustic, speech, or tactile input. In addition, a computer can interact with a user by sending documents to, and receiving documents from, a device that is used by the user. For example, the computer can send web pages to a web browser on a user's client device in response to requests received from the web browser.

[0101] The term “graphical user interface,” or “GUI,” can be used in the singular or the plural to describe one or more graphical user interfaces and each of the displays of a particular graphical user interface. Therefore, a GUI can represent any graphical user interface, including, but not limited to, a web browser, a touch screen, or a command line interface (CLI) that processes information and efficiently presents the information results to the user. In general, a GUI can include a plurality’ of user interface (UI) elements, some or all associated with a web browser, such as interactive fields, pulldown lists, and buttons. These and other UI elements can be related to or represent the functions of the web browser. Implementations of the subject matter described in this specification can be implemented in a computing system that includes a back end component, for example, as a data sen’ er, or that includes a middleware component, for example, an application server. Moreover, the computing system can include a frontend component, for example, a client computer having one or both of a graphical user interface or a Web browser through which a user can interact with the computer. The components of the system can be interconnected by any form or medium of wireline or wireless digital data communication (or a combination of data communication) in a communication network. Examples of communication networks include a local area network (LAN), a radio access network (RAN), a metropolitan area network (MAN), a wide area network (WAN). Worldwide Interoperability for Microwave Access (WIMAX), a wireless local area network (WLAN) (for example, using 802.11 a / b / g / n or 802.20 or a combination of protocols), all or a portion of the Internet, or any other communication system or systems at one or more locations (or a combination of communication networks). The network can communicate with, for example, Internet Protocol (IP) packets, frame relay frames, asynchronous transfer mode (ATM) cells, voice, video, data, or a combination of communication types between network addresses.

[0102] The computing system can include clients and servers. A client and server can generally be remote from each other and can typically interact through a communicationAttorney Ref.: 38136-2853WO1network. The relationship of client and server can arise by virtue of computer programs running on the respective computers and having a client-server relationship.

[0103] Cluster file systems can be any file system type accessible from multiple servers for read and update. Locking or consistency tracking may not be necessary since the locking of exchange file system can be done at application layer. Furthermore, Unicode data files can be different from non-Unicode data files.

[0104] While this specification contains many specific implementation details, these should not be construed as limitations on the scope of what may be claimed, but rather as descriptions of features that may be specific to particular implementations. Certain features that are described in this specification in the context of separate implementations can also be implemented, in combination, or in a single implementation. Conversely, various features that are described in the context of a single implementation can also be implemented in multiple implementations, separately, or in any suitable sub-combination. Moreover, although previously described features may be described as acting in certain combinations and even initially claimed as such, one or more features from a claimed combination can, in some cases, be excised from the combination, and the claimed combination may be directed to a sub-combination or variation of a sub-combination.

[0105] Particular implementations of the subject matter have been described. Other implementations, alterations, and permutations of the described implementations are within the scope of the following claims as will be apparent to those skilled in the art. While operations are depicted in the drawings or claims in a particular order, this should not be understood as requiring that such operations be performed in the particular order shown or in sequential order, or that all illustrated operations be performed (some operations may be considered optional), to achieve desirable results. In certain circumstances, multitasking or parallel processing (or a combination of multitasking and parallel processing) may be advantageous and performed as deemed appropriate.

[0106] Moreover, the separation or integration of various system modules and components in the previously described implementations should not be understood as requiring such separation or integration in all implementations; and it should be understood that the described program components and systems can generally be integrated together in a single software product or packaged into multiple software products.Attorney Ref.: 38136-2853WO1

[0107] Accordingly, the previously described example implementations do not define or constrain the present disclosure. Other changes, substitutions, and alterations are also possible without departing from the spirit and scope of the present disclosure.

[0108] Furthermore, any claimed implementation is considered to be applicable to at least a computer-implemented method; a non-transitory, computer-readable medium storing computer-readable instructions to perform the computer-implemented method; and a computer system comprising a computer memory interoperably coupled with a hardware processor configured to perform the computer-implemented method or the instructions stored on the non-transitory. computer-readable medium.

Claims

Attorney Ref.: 38136-2853WO1CLAIMSWe Claim:

1. A computer-implemented method for C02 injection well placement in a target area, the computer-implemented method comprising:identifying input data associated with the target area, the input data comprising core samples and well logs from the target area;generating, based on the input data, a structural depth grid of the target area; generating, based on the structural depth grid, a slope map of the target area; generating, based on the slope map of the target area, a flow direction map for the target area;determining, based on the flow direction map, a fluid flow accumulation and a fluid flow length in the target area; andbased on the fluid flow accumulation and the fluid flow length in the target area, selecting at least one position for drilling at least one CO2 injection well in the target area.

2. The computer-implemented method of claim 1, further comprising:performing a quality check (QC) on the input data.

3. The computer-implemented method of claim 1 , wherein generating the structural depth grid of the target area comprises:integrating the input data to generate a structural depth map of the target area; anddividing the structural depth map into a grid of cells, each cell representing a respective portion of the target area.

4. The computer-implemented method of claim 1, wherein generating the slope map of the target area comprises:performing a dip analysis of the structural depth grid to determine respective inclination range values in respective sub-areas of the target area.Attorney Ref.: 38136-2853WO15. The computer-implemented method of claim 1, wherein the respective inclination range values comprise a maximum and minimum inclination value in a corresponding respective sub-area.

6. The computer-implemented method of claim 1, wherein determining the fluid flow accumulation and the fluid flow length in the target area comprises:performing, using the flow direction map, a pour point and water-shed analysis in the target area.

7. The computer-implemented method of claim 1 , wherein selecting the at least one position for drilling the at least one CO2 injection well in the target area comprises: generating a ranking of a plurality of candidate drilling locations in the target area, wherein the ranking ranks the plurality7of candidate drilling locations based on at least one of respective fluid movement, fluid flow length, or fluid flow accumulation characteristics of the plurality of candidate drilling locations; andselecting the at least one position based on the ranking of the plurality of candidate drilling locations.

8. The computer-implemented method of claim 1, wherein determining, based on the flow direction map, a fluid flow accumulation and a fluid flow length in the target area:determining, for each of a plurality of testing scenarios, a respective fluid flow accumulation and a respective fluid flow length in the target area, wherein each of the plurality of testing scenarios comprises one or more candidate injection wells.

9. The computer-implemented method of claim 1 , wherein selecting the at least one position for drilling the at least one CO2 injection well in the target area comprises: generating a ranking of the plurality of testing scenarios; andselecting the at least one position for drilling the at least one CO2 injection well based on the ranking.

10. A system comprising:Attorney Ref.: 38136-2853WO1one or more processors configured to perform operations for CO2 injection well placement in a target area, the operations comprising:identifying input data associated with the target area, the input data comprising core samples and well logs from the target area;generating, based on the input data, a structural depth grid of the target area;generating, based on the structural depth grid, a slope map of the target area;generating, based on the slope map of the target area, a flow direction map for the target area;determining, based on the flow direction map, a fluid flow accumulation and a fluid flow length in the target area; andbased on the fluid flow accumulation and the fluid flow length in the target area, selecting at least one position for drilling at least one CO2 injection well in the target area.

11. The system of claim 10, wherein generating the structural depth grid of the target area comprises:integrating the input data to generate a structural depth map of the target area; anddividing the structural depth map into a grid of cells, each cell representing a respective portion of the target area.

12. The system of claim 10. wherein generating the slope map of the target area comprises:performing a dip analysis of the structural depth grid to determine respective inclination range values in respective sub-areas of the target area.

13. The system of claim 10, wherein the respective inclination range values comprise a maximum and minimum inclination value in a corresponding respective sub-area.

14. The system of claim 10, wherein determining the fluid flow accumulation and the fluid flow length in the target area comprises:Attorney Ref.: 38136-2853WO1performing, using the flow direction map, a pour point and water-shed analysis in the target area.

15. The system of claim 10, wherein selecting the at least one position for drilling the at least one CO2 injection well in the target area comprises:generating a ranking of a plurality of candidate drilling locations in the target area, wherein the ranking ranks the plurality of candidate drilling locations based on at least one of respective fluid movement, fluid flow length, or fluid flow accumulation characteristics of the plurality of candidate drilling locations; andselecting the at least one position based on the ranking of the plurality of candidate drilling locations.

16. The system of claim 10, wherein determining, based on the flow direction map, a fluid flow accumulation and a fluid flow length in the target area:determining, for each of a plurality of testing scenarios, a respective fluid flow accumulation and a respective fluid flow length in the target area, wherein each of the plurality of testing scenarios comprises one or more candidate injection wells.

17. The system of claim 10, wherein selecting the at least one position for drilling the at least one CO2 injection well in the target area comprises:generating a ranking of the plurality of testing scenarios; andselecting the at least one position for drilling the at least one CO2 injection well based on the ranking.

18. A non-transitory computer storage medium encoded with instructions that, when executed by one or more computers, cause the one or more computers to perform operations for CO2 injection well placement in a target area, the operations comprising:identifying input data associated with the target area, the input data comprising core samples and well logs from the target area;generating, based on the input data, a structural depth grid of the target area; generating, based on the structural depth grid, a slope map of the target area; generating, based on the slope map of the target area, a flow direction map for the target area;Attorney Ref.: 38136-2853WO1determining, based on the flow direction map, a fluid flow accumulation and a fluid flow length in the target area: andbased on the fluid flow accumulation and the fluid flow length in the target area, selecting at least one position for drilling at least one CO2 injection well in the target area.

19. The non-transitory computer storage medium of claim 18, wherein generating the structural depth grid of the target area comprises:integrating the input data to generate a structural depth map of the target area; anddividing the structural depth map into a grid of cells, each cell representing a respective portion of the target area.

20. The non-transitory computer storage medium of claim 18, wherein generating the slope map of the target area comprises:performing a dip analysis of the structural depth grid to determine respective inclination range values in respective sub-areas of the target area.

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