US20210340858A1

US20210340858A1 - Systems and Methods for Dynamic Real-Time Hydrocarbon Well Placement

Info

Publication number: US20210340858A1
Application number: US16/861,514
Authority: US
Inventors: Majdi Baddourah; Sulaiman Gannas; Osaid Hajjar
Original assignee: Saudi Arabian Oil Co
Current assignee: Saudi Arabian Oil Co
Priority date: 2020-04-29
Filing date: 2020-04-29
Publication date: 2021-11-04
Also published as: WO2021222608A1

Abstract

Provide are techniques for developing a hydrocarbon reservoir that include identifying a number of wells that can be drilled at a given point in time, providing corresponding parameters to a reservoir simulation process, and when the simulation process reaches simulation of the given point in time, the simulation identifying locations for the wells based on estimated properties for the given point in time, and running subsequent segments of the simulation process in accordance with the wells being drilled and operated in the identified locations.

Description

FIELD

Embodiments relate generally to developing hydrocarbon reservoirs, and more particularly to hydrocarbon reservoir simulation and hydrocarbon well placement.

BACKGROUND

A rock formation that resides under the Earth's surface is often referred to as a “subsurface” formation. A subsurface formation that contains a subsurface pool of hydrocarbons, such as oil and gas, is often referred to as a “hydrocarbon reservoir.” Hydrocarbons are typically extracted (or “produced”) from a hydrocarbon reservoir by way of a hydrocarbon well. A hydrocarbon well normally includes a wellbore (or “borehole”) that is drilled into the reservoir. For example, a hydrocarbon well may include a wellbore that extends into the rock of a reservoir to facilitate the extraction (or “production”) of hydrocarbons from the reservoir, the injection of fluids into the reservoir, or the evaluation and monitoring of the reservoir.
Development of a hydrocarbon reservoir typically involves a series of operations directed to optimizing extraction of the hydrocarbons from the reservoir. For example, a reservoir operator may spend a great deal of time and effort assessing a hydrocarbon reservoir to identify an economical and environmentally responsible plan to extract hydrocarbons from the reservoir, and may engage in corresponding well drilling and production operations to extract hydrocarbons from the reservoir in accordance with the plan. This can include identifying where hydrocarbons are located in the reservoir, generating a field development plan (FDP) that outlines procedures for extracting hydrocarbons from the reservoir, and drilling and operating multiple wells in accordance with the procedures of the FDP. An FDP for a hydrocarbon reservoir may, for example, specify locations, trajectories and operational parameters of production wells, injection wells and monitoring wells that extend into the reservoir.
In many instances, operators rely on simulations to characterize a hydrocarbon reservoir, and the results of the simulations are used as a basis for developing the reservoir. For example, an operator may generate simulations of hydrocarbon reservoir operational scenarios to predict how fluids, such as water and hydrocarbons, will move within the reservoir, and to predict a volume of hydrocarbon production from the reservoir. The operator may, in turn, use the results of the simulations to update the FDP for the reservoir over the course of the development of the reservoir. For example, initial simulations may be used to generate an initial FDP that specifies initial locations and operating parameters for wells before they are drilled, and follow-up simulations may be used to generate updated FDPs that specify revised operating parameters for wells already drilled and locations and operating parameters for additional wells to be drilled.

SUMMARY

Reservoir simulation can be an important aspect of developing a hydrocarbon reservoir. In many instances, successful development of a hydrocarbon reservoir relies on generation of accurate and timely simulations of operational scenarios that guide development of the reservoir. For example, a reservoir operator may use a simulation of a hydrocarbon reservoir predict movement of hydrocarbons and other substances, such as injected water, within a hydrocarbon reservoir and to estimate hydrocarbon production. The operator may use that knowledge to generate a corresponding field development plan (FDP) that outlines procedures for extracting hydrocarbons from the reservoir. The FDP may, for example, specify locations, trajectories and operational parameters of production wells, injection wells and monitoring wells that extend into the reservoir.
A simulation of a hydrocarbon reservoir (or a “reservoir simulation”) typically involves processing a model of the reservoir to predict how substances will move within the reservoir under a set of operating parameters. For example, the simulation of a hydrocarbon reservoir may include a prediction of how known pockets of fluids, such as hydrocarbons and water, will move within the reservoir based on locations and operating parameters (e.g., operating flowrates and pressures) of a set of wells in the reservoir, and include an associated estimate of hydrocarbon production from the wells under the parameters. In some instances, multiple simulations are generated based on different sets of parameters to identify an optimal approach for developing the reservoir. For example, a model of a reservoir may be processed (or “run”) for different operational scenarios (e.g., using different combinations of operating flowrates and pressures for wells in the reservoir as inputs to the model) to generate corresponding simulations of the reservoir, one of the simulations that exhibits an efficient production of hydrocarbons from the reservoir may be identified, and the parameters associated with the identified simulation may be employed to produce hydrocarbons from the reservoir.
A model of a reservoir (or a “reservoir model”) typically includes a three-dimensional (3D) set of cells that represent the 3D physical layout of the reservoir. For example, a reservoir model may include a structured 3D grid of cuboid shaped cells arranged in rows and columns, with each of the cells representing a respective volume of the reservoir and being associated with corresponding properties (e.g., permeability, porosity, water saturation or oil saturation) of the volume represented by the cell. Reservoir models often include relatively large grids (e.g., including thousands, millions or billions of cells) and can include an immense amount of information that is processed to generate corresponding reservoir simulations. In view of the processing requirements, reservoir simulation runs often employ multiple processors (e.g., tens, hundreds or thousands of processors) working in parallel to generate a reservoir simulation. In many instances, processors individually process (or “handle”) information for respective subsets of cells of a reservoir model, and the processors exchange information regarding neighboring subsets of cells to account for interactions between the subsets of cells. Accordingly, a reservoir simulation can be computationally complex and consume a great deal of processing resources. In some instances, more and faster processors are employed in an effort to combat the complexity. Even with the implementation of a relatively large number of high-speed processors, however, reservoir simulations can still require a great deal of time (e.g., hours, days, weeks or months) to complete. This can introduce significant delays in generating reservoir simulations (and corresponding FDPs), and can, in turn, delay development of a reservoir. Reservoir simulations are sometimes viewed as costly from the perspective of computing resources and time required. As a result, field operators may forgo generating reservoir simulations due to a lack of resources and time, even though the simulations are beneficial to long-term development of the reservoir.
It can be necessary to run reservoir simulations under multiple scenarios to generate a corresponding set of simulations that can be assessed to identify an optimal FDP for the reservoir. For example, a well operator may run a first simulation based on an initial set of operating parameters for the reservoir, adjust the operating parameters based on the results of the first simulation, and run a second simulation based on the adjusted set of operating parameters. Such an iterative assessment may be repeated until an optimum scenario is identified. Unfortunately, running multiple simulations can increase the computing resources and time required to generate an FDP for a reservoir.
Provided are systems and methods for dynamic real-time well placement based hydrocarbon reservoir simulation. In some embodiments, a number of wells that can be drilled at a given point in time is identified, and corresponding parameters are provided as an input to a reservoir simulation process. When the simulation process reaches simulation of the given point in time, the simulation may identify locations for each of the wells based on estimated properties for the given point in time, and run subsequent segments of the simulation process based on the wells being drilled and operated in the identified locations. For example, where it is determined that four wells can be drilled into a reservoir in 2025 (e.g., based on financial or logistical considerations for developing the reservoir), corresponding “future drilling parameters” may be included with input parameters for a simulation of the reservoir from the year 2020 to the year 2030. A first five-year segment of the simulation process may be run for Jan. 1, 2020 to Dec. 31, 2024 using an “initial” reservoir model that employs the parameters and locations of an “initial” (or “existing”) set of wells that are present on Jan. 1, 2020. The results of the first five-year segment of the simulation process may identify predicted properties of the reservoir on Dec. 31, 2024 based on simulation of the initial reservoir model. At that point, the simulation process may identify locations for each of the four “new” wells based on the predicted properties of the reservoir on Dec. 31, 2024, and generate a corresponding “well-modified” reservoir model that includes the predicted properties of the reservoir on Dec. 31, 2024, as well as the four new wells “inserted” into the model at the identified locations. The simulation process may proceed to run a second five-year segment of the simulation process for Jan. 1, 2025 to Dec. 31, 2030 using the “well-modified” reservoir model. As a result, the reservoir simulation process may dynamically place the “new” wells into the model, in real-time during the simulation run, to generate a simulation that takes into account the “initial” wells and dynamically placed “new” wells.
Provided in some embodiments is a method of developing a hydrocarbon reservoir that includes: generating a dynamic well placement simulation of a hydrocarbon reservoir for a span of time (Δt) defined by a start time (t₁) and end time (t₂), the dynamic well placement simulation including: determining a number (N) of wells to be drilled into the hydrocarbon reservoir at a given point in time (t_w) within the span of time (Δt); determining an initial reservoir model of the hydrocarbon reservoir, the initial reservoir model including cells that represent the hydrocarbon reservoir and a corresponding set of initial properties for each of the cells; conducting, using the initial reservoir model of the hydrocarbon reservoir, a first segment of a simulation of the hydrocarbon reservoir to generate a first segment reservoir properties, the first segment of the simulation of the hydrocarbon reservoir including a simulation of the hydrocarbon reservoir from the start time (t₁) to the given point of time (t_w) that is conducted using the initial reservoir model, the first segment reservoir properties including estimated properties for the cells at the given point of time (t_w) determined based on the first segment of the simulation; identifying, based on the first segment reservoir properties, the number (N) of columns of the cells that have the highest column oil content at the given point of time (t_w) and that do not have a well located in the column at the given point of time (t_w); generating, based on the columns of cells identified, a well-modified model of the hydrocarbon reservoir, the well-modified model including the first segment reservoir properties associated with the cells and a new well located at each column of the columns of the cells identified; conducting, using the well-modified reservoir model of the hydrocarbon reservoir, a second segment of the simulation of the hydrocarbon reservoir to generate second segment reservoir properties, the second segment of the simulation of the hydrocarbon reservoir including a simulation of the hydrocarbon reservoir from the given point of time (t_w) to the end time (t₂) that is conducted using the well-modified reservoir model, the second segment reservoir properties including estimated properties for the cells at the end time (t₂) determined based on the second segment of the simulation; and generating, based on the second segment reservoir properties, a simulation of the hydrocarbon reservoir for the span of time (Δt).
In some embodiments, determining a number (N) of wells to be drilled into the hydrocarbon reservoir at the given point in time (t) includes conducting a financial assessment of the development of the hydrocarbon reservoir to determine the number (N) of wells to be drilled at the point in time (t). In certain embodiments, determining a number (N) of wells to be drilled into the hydrocarbon reservoir at the given point in time (t) includes conducting a logistical assessment of the development of the hydrocarbon reservoir to determine the number (N) of wells to be drilled at the point in time (t). In some embodiments, the method further includes: determining a second number (N₂) of wells to be drilled into the hydrocarbon reservoir at a second given point in time (t_w2) that is later than the given point in time (t) and earlier than the end time (t₂); the second segment of the simulation of the hydrocarbon reservoir including: identifying, based on the second segment reservoir properties and from columns of the cells, the second number (N₂) of columns of the cells that have the highest column oil content at the second given point of time (t_w2) and that do not have a well located in the column at the given point of time (t_w2); conducting, using the well-modified reservoir model of the hydrocarbon reservoir, a third segment of the simulation of the hydrocarbon reservoir to generate third segment reservoir properties, the third segment of the simulation of the hydrocarbon reservoir including a simulation of the hydrocarbon reservoir from the given point in time (t_w) to the second given point of time (t_w2) that is conducted using the well-modified reservoir model, the third segment reservoir properties including estimated properties for the cells at the second given point of time (t_w2) determined based on the third segment of the simulation; identifying, based on the oil content of the cells of the third segment reservoir properties, the number (N₂) of columns of the cells that have the highest column oil content at the second given point of time (t_w2) and that do not have a well located in the column at the second given point of time (t_w2); generating, based on the columns of cells identified, a second well-modified model of the hydrocarbon reservoir, the second well-modified model including the third segment reservoir properties associated with the cells and a new well located at each of the columns of the cells identified for the second given point of time (t_w2); conducting, using the second well-modified reservoir model of the hydrocarbon reservoir, a fourth segment of the simulation of the hydrocarbon reservoir to generate fourth segment reservoir properties, the fourth segment of the simulation of the hydrocarbon reservoir including a simulation of the hydrocarbon reservoir from the second given point of time (t_w2) to the end time (t₂) that is conducted using the second well-modified reservoir model, the fourth segment reservoir properties including estimated properties for the cells at the end time (t₂) determined based on the fourth segment of the simulation, where the second segment of the simulation of the hydrocarbon reservoir includes the third and fourth segments of the simulation of the hydrocarbon reservoir, and the second segment reservoir model corresponds to the fourth segment reservoir model. In certain embodiments, the estimated properties for each of the cells at the given point of time (t_w) include an oil content of the cell at the given point of time (t_w). In some embodiments, the column oil content of each of the columns of the cells at the given point of time (t_w) is defined by a sum of the volume of oil content of the cells in the column at the given point of time (t_w). In certain embodiments, the method further includes generating a field development plan (FDP) for the hydrocarbon reservoir based on the simulation of the hydrocarbon reservoir. In some embodiments, the method further includes: identifying well drilling parameters based on the simulation of the hydrocarbon reservoir; and drilling a well in the hydrocarbon reservoir based on the well drilling parameters. In some embodiments, the method further includes: identifying well operating parameters based on the simulation of the hydrocarbon reservoir; and operating a well in the hydrocarbon reservoir based on the well operating parameters.
Provided in some embodiments is non-transitory computer readable storage medium including program instructions stored thereon that are executable by a processor to perform the following operations for developing a hydrocarbon reservoir: generating a dynamic well placement simulation of a hydrocarbon reservoir for a span of time (Δt) defined by a start time (t₁) and end time (t₂), the dynamic well placement simulation including: determining a number (N) of wells to be drilled into the hydrocarbon reservoir at a given point in time (t_w) within the span of time (Δt); determining an initial reservoir model of the hydrocarbon reservoir, the initial reservoir model including cells that represent the hydrocarbon reservoir and a corresponding set of initial properties for each of the cells; conducting, using the initial reservoir model of the hydrocarbon reservoir, a first segment of a simulation of the hydrocarbon reservoir to generate a first segment reservoir properties, the first segment of the simulation of the hydrocarbon reservoir including a simulation of the hydrocarbon reservoir from the start time (t₁) to the given point of time (t_w) that is conducted using the initial reservoir model, the first segment reservoir properties including estimated properties for the cells at the given point of time (t_w) determined based on the first segment of the simulation; identifying, based on the first segment reservoir properties, the number (N) of columns of the cells that have the highest column oil content at the given point of time (t_w) and that do not have a well located in the column at the given point of time (t_w); generating, based on the columns of cells identified, a well-modified model of the hydrocarbon reservoir, the well-modified model including the first segment reservoir properties associated with the cells and a new well located at each column of the columns of the cells identified; conducting, using the well-modified reservoir model of the hydrocarbon reservoir, a second segment of the simulation of the hydrocarbon reservoir to generate second segment reservoir properties, the second segment of the simulation of the hydrocarbon reservoir including a simulation of the hydrocarbon reservoir from the given point of time (t_w) to the end time (t₂) that is conducted using the well-modified reservoir model, the second segment reservoir properties including estimated properties for the cells at the end time (t₂) determined based on the second segment of the simulation; and generating, based on the second segment reservoir properties, a simulation of the hydrocarbon reservoir for the span of time (Δt).
In some embodiments, determining a number (N) of wells to be drilled into the hydrocarbon reservoir at the given point in time (t) includes conducting a financial assessment of the development of the hydrocarbon reservoir to determine the number (N) of wells to be drilled at the point in time (t). In certain embodiments, determining a number (N) of wells to be drilled into the hydrocarbon reservoir at the given point in time (t) includes conducting a logistical assessment of the development of the hydrocarbon reservoir to determine the number (N) of wells to be drilled at the point in time (t). In some embodiments, the operations further include: determining a second number (N₂) of wells to be drilled into the hydrocarbon reservoir at a second given point in time (t_w2) that is later than the given point in time (t) and earlier than the end time (t₂); the second segment of the simulation of the hydrocarbon reservoir including: identifying, based on the second segment reservoir properties and from columns of the cells, the second number (N₂) of columns of the cells that have the highest column oil content at the second given point of time (t_w2) and that do not have a well located in the column at the given point of time (t_w2); conducting, using the well-modified reservoir model of the hydrocarbon reservoir, a third segment of the simulation of the hydrocarbon reservoir to generate third segment reservoir properties, the third segment of the simulation of the hydrocarbon reservoir including a simulation of the hydrocarbon reservoir from the given point in time (t_w) to the second given point of time (t_w2) that is conducted using the well-modified reservoir model, the third segment reservoir properties including estimated properties for the cells at the second given point of time (t_w2) determined based on the third segment of the simulation; identifying, based on the oil content of the cells of the third segment reservoir properties, the number (N₂) of columns of the cells that have the highest column oil content at the second given point of time (t_w2) and that do not have a well located in the column at the second given point of time (t_w2); generating, based on the columns of cells identified, a second well-modified model of the hydrocarbon reservoir, the second well-modified model including the third segment reservoir properties associated with the cells and a new well located at each of the columns of the cells identified for the second given point of time (t_w2); conducting, using the second well-modified reservoir model of the hydrocarbon reservoir, a fourth segment of the simulation of the hydrocarbon reservoir to generate fourth segment reservoir properties, the fourth segment of the simulation of the hydrocarbon reservoir including a simulation of the hydrocarbon reservoir from the second given point of time (t_w2) to the end time (t₂) that is conducted using the second well-modified reservoir model, the fourth segment reservoir properties including estimated properties for the cells at the end time (t₂) determined based on the fourth segment of the simulation, where the second segment of the simulation of the hydrocarbon reservoir includes the third and fourth segments of the simulation of the hydrocarbon reservoir, and the second segment reservoir model corresponds to the fourth segment reservoir model. In some embodiments, the estimated properties for each of the cells at the given point of time (t_w) include an oil content of the cell at the given point of time (t_w). In certain embodiments, the column oil content of each of the columns of the cells at the given point of time (t_w) is defined by a sum of the volume of oil content of the cells in the column at the given point of time (t_w). In certain embodiments, the operations further include generating a field development plan (FDP) for the hydrocarbon reservoir based on the simulation of the hydrocarbon reservoir. In some embodiments, the operations further include: identifying well drilling parameters based on the simulation of the hydrocarbon reservoir; and drilling a well in the hydrocarbon reservoir based on the well drilling parameters. In some embodiments, the operations further include: identifying well operating parameters based on the simulation of the hydrocarbon reservoir; and operating a well in the hydrocarbon reservoir based on the well operating parameters.
Provided in some embodiments is a hydrocarbon reservoir development system that includes: a hydrocarbon reservoir control system including non-transitory computer readable storage medium including program instructions stored thereon that are executable by a processor to perform the following operations for developing a hydrocarbon reservoir: generating a dynamic well placement simulation of a hydrocarbon reservoir for a span of time (Δt) defined by a start time (t₁) and end time (t₂), the dynamic well placement simulation including: determining a number (N) of wells to be drilled into the hydrocarbon reservoir at a given point in time (t_w) within the span of time (Δt); determining an initial reservoir model of the hydrocarbon reservoir, the initial reservoir model including cells that represent the hydrocarbon reservoir and a corresponding set of initial properties for each of the cells; conducting, using the initial reservoir model of the hydrocarbon reservoir, a first segment of a simulation of the hydrocarbon reservoir to generate a first segment reservoir properties, the first segment of the simulation of the hydrocarbon reservoir including a simulation of the hydrocarbon reservoir from the start time (t₁) to the given point of time (t_w) that is conducted using the initial reservoir model, the first segment reservoir properties including estimated properties for the cells at the given point of time (t_w) determined based on the first segment of the simulation; identifying, based on the first segment reservoir properties, the number (N) of columns of the cells that have the highest column oil content at the given point of time (t_w) and that do not have a well located in the column at the given point of time (t_w); generating, based on the columns of cells identified, a well-modified model of the hydrocarbon reservoir, the well-modified model including the first segment reservoir properties associated with the cells and a new well located at each column of the columns of the cells identified; conducting, using the well-modified reservoir model of the hydrocarbon reservoir, a second segment of the simulation of the hydrocarbon reservoir to generate second segment reservoir properties, the second segment of the simulation of the hydrocarbon reservoir including a simulation of the hydrocarbon reservoir from the given point of time (t_w) to the end time (t₂) that is conducted using the well-modified reservoir model, the second segment reservoir properties including estimated properties for the cells at the end time (t₂) determined based on the second segment of the simulation; and generating, based on the second segment reservoir properties, a simulation of the hydrocarbon reservoir for the span of time (Δt).
In some embodiments, determining a number (N) of wells to be drilled into the hydrocarbon reservoir at the given point in time (t) includes conducting a financial assessment of the development of the hydrocarbon reservoir to determine the number (N) of wells to be drilled at the point in time (t). In certain embodiments, determining a number (N) of wells to be drilled into the hydrocarbon reservoir at the given point in time (t) includes conducting a logistical assessment of the development of the hydrocarbon reservoir to determine the number (N) of wells to be drilled at the point in time (t). In some embodiments, the operations further include: determining a second number (N₂) of wells to be drilled into the hydrocarbon reservoir at a second given point in time (t_w2) that is later than the given point in time (t) and earlier than the end time (t₂); the second segment of the simulation of the hydrocarbon reservoir including: identifying, based on the second segment reservoir properties and from columns of the cells, the second number (N₂) of columns of the cells that have the highest column oil content at the second given point of time (t_w2) and that do not have a well located in the column at the given point of time (t_w2); conducting, using the well-modified reservoir model of the hydrocarbon reservoir, a third segment of the simulation of the hydrocarbon reservoir to generate third segment reservoir properties, the third segment of the simulation of the hydrocarbon reservoir including a simulation of the hydrocarbon reservoir from the given point in time (t_w) to the second given point of time (t_w2) that is conducted using the well-modified reservoir model, the third segment reservoir properties including estimated properties for the cells at the second given point of time (t_w2) determined based on the third segment of the simulation; identifying, based on the oil content of the cells of the third segment reservoir properties, the number (N₂) of columns of the cells that have the highest column oil content at the second given point of time (t_w2) and that do not have a well located in the column at the second given point of time (t_w2); generating, based on the columns of cells identified, a second well-modified model of the hydrocarbon reservoir, the second well-modified model including the third segment reservoir properties associated with the cells and a new well located at each of the columns of the cells identified for the second given point of time (t_w2); conducting, using the second well-modified reservoir model of the hydrocarbon reservoir, a fourth segment of the simulation of the hydrocarbon reservoir to generate fourth segment reservoir properties, the fourth segment of the simulation of the hydrocarbon reservoir including a simulation of the hydrocarbon reservoir from the second given point of time (t_w2) to the end time (t₂) that is conducted using the second well-modified reservoir model, the fourth segment reservoir properties including estimated properties for the cells at the end time (t₂) determined based on the fourth segment of the simulation, where the second segment of the simulation of the hydrocarbon reservoir includes the third and fourth segments of the simulation of the hydrocarbon reservoir, and the second segment reservoir model corresponds to the fourth segment reservoir model. In some embodiments, the estimated properties for each of the cells at the given point of time (t_w) include an oil content of the cell at the given point of time (t_w). In certain embodiments, the column oil content of each of the columns of the cells at the given point of time (t_w) is defined by a sum of the volume of oil content of the cells in the column at the given point of time (t_w). In some embodiments, the operations further include generating a field development plan (FDP) for the hydrocarbon reservoir based on the simulation of the hydrocarbon reservoir. In certain embodiments, the operations further include: identifying well drilling parameters based on the simulation of the hydrocarbon reservoir; and drilling a well in the hydrocarbon reservoir based on the well drilling parameters. In some embodiments, the operations further include: identifying well operating parameters based on the simulation of the hydrocarbon reservoir; and operating a well in the hydrocarbon reservoir based on the well operating parameters.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 is diagram that illustrates a hydrocarbon reservoir environment in accordance with one or more embodiments.

FIGS. 2A-2B are diagrams that illustrate a hydrocarbon reservoir model in accordance with one or more embodiments.

FIG. 3 is a flowchart that illustrates a method of hydrocarbon reservoir development in accordance with one or more embodiments.

FIG. 4 is a flowchart that illustrates a method of dynamic real-time well placement reservoir simulation in accordance with one or more embodiments.

FIG. 5 is a diagram that illustrates an example computer system in accordance with one or more embodiments.

While this disclosure is susceptible to various modifications and alternative forms, specific embodiments are shown by way of example in the drawings and will be described in detail. The drawings may not be to scale. It should be understood that the drawings and the detailed descriptions are not intended to limit the disclosure to the particular form disclosed, but are intended to disclose modifications, equivalents, and alternatives falling within the spirit and scope of the present disclosure as defined by the claims.

DETAILED DESCRIPTION

Described are systems and methods for dynamic real-time well placement based hydrocarbon reservoir simulation. In some embodiments, a number of wells that can be drilled at a given point in time is identified, and corresponding parameters are provided as an input to a reservoir simulation process. When the simulation process reaches simulation of the given point in time, the simulation may identify locations for each of the wells based on estimated properties for the given point in time, and run subsequent segments of the simulation process based on the wells being drilled and operated in the identified locations. For example, where it is determined that four wells can be drilled into a reservoir in 2025 (e.g., based on financial or logistical considerations for developing the reservoir), corresponding “future drilling parameters” may be included with input parameters for a simulation of the reservoir from the year 2020 to the year 2030. A first five-year segment of the simulation process may be run for Jan. 1, 2020 to Dec. 31, 2024 using an “initial” reservoir model that employs the parameters and locations of an “initial” (or “existing”) set of wells that are present on Jan. 1, 2020. The results of the first five-year segment of the simulation process may identify predicted properties of the reservoir on Dec. 31, 2024 based on simulation of the initial reservoir model. At that point, the simulation process may identify locations for each of the four “new” wells based on the predicted properties of the reservoir on Dec. 31, 2024, and generate a corresponding “well-modified” reservoir model that includes the predicted properties of the reservoir on Dec. 31, 2024, as well as the four new wells “inserted” into the model at the identified locations. The simulation process may proceed to run a second five-year segment of the simulation process for Jan. 1, 2025 to Dec. 31, 2030 using the “well-modified” reservoir model. As a result, the reservoir simulation process may dynamically place the “new” wells into the model, in real-time during the simulation run, to generate a simulation that takes into account the “initial” wells and dynamically placed “new” wells.
FIG. 1 is a diagram that illustrates a hydrocarbon reservoir environment (“reservoir environment”) 100 in accordance with one or more embodiments. In the illustrated embodiment, the reservoir environment 100 includes a hydrocarbon reservoir (“reservoir”) 102 located in a subsurface formation (“formation”) 104, and a hydrocarbon reservoir development system 106.
The formation 104 may include a porous or fractured rock formation that resides underground, beneath the Earth's surface (“surface”) 108. The reservoir 102 may include a portion of the formation 104 that contains (or that is determined to contain) a subsurface pool of hydrocarbons, such as oil and gas. The formation 104 and the reservoir 102 may each include different layers of rock having varying characteristics (e.g., varying degrees of permeability, porosity, water saturation or oil saturation). The hydrocarbon reservoir development system 106 may facilitate the extraction (or “production”) of hydrocarbons from the reservoir 102.
In some embodiments, the hydrocarbon reservoir development system 106 includes a hydrocarbon reservoir control system (“control system”) 110 and one or more wells 112. In some embodiments, the control system 110 includes a computer system that is the same as or similar to that of computer system 1000 described with regard to at least FIG. 5. Each of the wells 112 may include a wellbore 114 that extends from the surface 108 into a target zone of the formation 104, such as the reservoir 102. The wellbore 114 may be created, for example, by a drill bit boring along a path (or “trajectory”) through the formation 104 and the reservoir 102.
In some embodiments, the control system 110 controls operations for developing the reservoir 102. For example, the control system 110 may control logging operations used to acquire data for the reservoir 102, and may control processing that generates models and simulations (e.g., based on the data for the reservoir 102) that characterize the reservoir 102. In some embodiments, the control system 110 determines drilling parameters for the wells 112 in the reservoir 102, determines operating parameters for the wells 112 in the reservoir 102, controls drilling of the wells 112 in accordance with drilling parameters, or controls operating the wells 112 in accordance with the operating parameters. This can include, for example, the control system 110 determining drilling parameters (e.g., determining well locations and trajectories) for the reservoir 102, controlling drilling of the wells 112 in accordance with the drilling parameters (e.g., controlling a well drilling system of the hydrocarbon reservoir development system 106 to drill the wells 112 at the well locations and with the wellbores 114 following the trajectories), determining operating parameters (e.g., determining production rates and pressures for “production” wells 112 and injection rates and pressure for “injections” wells 112), and controlling operations of the wells 112 in accordance with the operating parameters (e.g., controlling a well operating system of the hydrocarbon reservoir development system 106 to operate the production wells 112 to produce hydrocarbons from the reservoir 102 in accordance with the production rates and pressures determined for the respective wells 112, and controlling the injection wells 112 to inject substances, such as water, into the reservoir 102 in accordance with the injection rates and pressures determined for the respective wells 112). In some embodiments, the control system 110 determines monitoring parameters or controls operations of “monitoring” wells 112. For example, the control system 110 may determine wellbore logging parameters for monitoring wells 112, and control logging tools and sensors within the wellbores 114 of the monitoring wells 112 in accordance with the wellbore logging parameters for the monitoring wells 112.
In some embodiments, the control system 110 stores in a memory, or otherwise has access to, reservoir data 126. The reservoir data 126 may include data that is indicative of properties of the reservoir 102. In some embodiments, the reservoir data 126 includes one or more models of the reservoir 102 (or “reservoir models” or “models”) 130, one or more simulations of the reservoir 102 (or “reservoir simulations” or “simulations”) 132, or well drilling forecast for the reservoir 102 (or “well forecast”) 134. As described here, the simulations 132 may include “dynamic real-time well placement” type reservoir simulations.
A reservoir model 130 may include a three-dimensional (3D) grid of cells (or “grid cells”) representing a portion of the reservoir 102. Each of the cells may include a cuboid cell (or similar shaped cell) that represents a corresponding volume within the reservoir 102. Each of the cells may be associated with properties of the volume represented by the cell. The properties may include properties of the volume itself (e.g., permeability, porosity, water saturation, or oil saturation of the rock located in volume represented by the cell) or properties of interfaces with adjacent cells (e.g., fluid fluxes that represent fluid interchange between the volume represented by cell and respective ones of other volumes represented by cells directly adjacent to the cell). The properties of each of the cells may be determined based on data acquired for the reservoir 102, such as data of seismic logs of the reservoir 102, data of downhole logs of wells drilled into the reservoir 102, data acquired by way of assessment core samples extracted from the reservoir 102, or data recorded for another reservoir having characteristics that are the same or similar to those of the reservoir 102.
A simulation of the reservoir 102 (or “reservoir simulation”) 132 may include data that represents predicted movement of fluids, such as water or hydrocarbons, within the reservoir 102 or the production of fluids, such as hydrocarbons, from the reservoir 102, over time. In some embodiments, a simulation of the reservoir 102 is generated based on a reservoir model 130. For example, a reservoir simulation 132 may include a snapshot of where fluid is expected to be within the reservoir 102 one year from now, and a volume of hydrocarbons to be produced from the reservoir 102 over the year, based on a reservoir model 130 that indicates present characteristics of the reservoir 102 (e.g., a modeling of the current location of water and hydrocarbons in the reservoir 102) and expected operating parameters for the reservoir 102 over the next year (e.g., a predicted set operating flowrates and pressures for the wells 112 over the next year). In some embodiments, a reservoir simulation 132 includes a sequence of snapshots over time that demonstrates the predicted movement of fluids within the reservoir 102 and hydrocarbon production at different times (e.g., at year one, at year two, and year three). The reservoir simulations 132 may be used to determine how to develop the reservoir 102. For example, a reservoir simulation 132 may be used to determine drilling or operating parameters that are employed at the wells 112 in the reservoir 102.
The well forecast 134 may include data that identifies wells that are expected to be drilled over the course of development of the reservoir 102. For example, the well forecast 134 may include a listing of “new” wells to be drilled into the reservoir 102 and corresponding times at which each of the new wells can be drilled. In some embodiments, the well forecast 134 is determined based on a financial or logistical assessment of the development of the reservoir. For example, if each well costs five million dollars to drill, it is determined that twenty-five million dollars will be made available on Jan. 1, 2020 for developing the reservoir 102 and another twenty million dollars will be made available on Jan. 1, 2025 for developing the reservoir 102, then a financial assessment may determine that five wells can be drilled on or after Jan. 1, 2020 and that four wells can be drilled on or after Jan. 1, 2025, and the well forecast 134 may be updated to include data that forecast drilling five wells in the reservoir 102 on or after Jan. 1, 2020 and drilling four wells in the reservoir 102 on or after Jan. 1, 2025. As another example, if drilling of each well requires a drilling rig, it is determined that five drilling rigs will be made available on Jan. 1, 2020 for developing the reservoir 102, and four drilling rigs will be made available on Jan. 1, 2025 for developing the reservoir 102, then a logistical assessment may determine that five wells can be drilled on or after Jan. 1, 2020 and that four wells can be drilled on or after Jan. 1, 2025, and the well forecast 134 may be updated to include data that forecast drilling five wells in the reservoir 102 on or after Jan. 1, 2020 and drilling four wells in the reservoir 102 on or after Jan. 1, 2025. In some embodiments, the well forecast 134 is developed based on a combination of financial and logistical assessments. For example, the well forecast 134 may forecast drilling wells at times when both of financial and logistical requirements are satisfied.
As described here, a reservoir model 130 may be processed in accordance with a dynamic real-time well placement based hydrocarbon reservoir simulation technique to generate a reservoir simulation 132. In some embodiments, a number of wells that can be drilled at a given point in time is identified (e.g., based on the well forecast 134) and corresponding parameters are provided as an input to a reservoir simulation process. When the simulation process reaches simulation of the given point in time, the simulation may identify locations for each of the wells based on the estimated properties of the reservoir at the given point in time, and run subsequent segments of the simulation process based on the wells being drilled and operated in the identified locations. For example, where it is determined that four wells can be drilled into the reservoir 102 in 2025 (e.g., based on the well forecast 134), corresponding “future drilling parameters” may be included with input parameters for a simulation of the reservoir 102 from the year 2020 to the year 2030. A first five-year segment of the simulation process may be run for Jan. 1, 2020 to Dec. 31, 2024 using an “initial” reservoir model 140 that includes parameters and locations of an “initial” (or “existing”) set of five wells that are present on Jan. 1, 2020. The results of the first five-year segment of the simulation process may identify predicted properties of the reservoir 102 on Dec. 31, 2024 based on simulation of the parameters and locations of the existing set of wells. At that point, the simulation process may identify locations for each of the four “new” wells based on the predicted properties, and generate a corresponding “well-modified” reservoir model 142 that includes the predicted properties of the reservoir on Dec. 31, 2024, as well as the four new wells inserted at the identified locations. The simulation process may, then, proceed to run a second five-year segment of the simulation process for Jan. 1, 2025 to Dec. 31, 2030 using the well-modified reservoir model 142 to generate a “complete” reservoir simulation 132 for Jan. 1, 2020 to Dec. 31, 2029. Accordingly, the reservoir simulation process may dynamically place the “new” wells into optimal locations within the reservoir model 130, in real-time during the simulation run, to generate a reservoir simulation 132 that takes into account the “initial” wells and dynamically placed “new” wells.
FIG. 2A is a diagram that illustrates an initial reservoir model 140 for a first point in time, in accordance with one or more embodiments. The initial reservoir model 140 is defined by a 3D grid of cells 202, which is formed of multiple cells 204. The 3D grid of cells 202 is formed of seven horizontally oriented 2D grids of cells (or “layer of cells”) 206 (e.g., including the layers of cells 206 a-g) stacked atop one another. Each layer of cells 206 is formed of horizontally oriented rows and columns of cells 204. The cells 204 of the various layers of cells 206 stacked atop one another form respective vertically oriented columns of cells (or “vertical columns of cells”) 210. For example, a first vertical column of cells 210 a may be defined by a cell 204 a of the “top” layer of cells 206 a and the “underground” cells 204 b-204 g, which are located directly beneath the cell 204 a. The top layer cell 206 a may represent a portion of a relatively shallow layer of the formation 104 located at or near the surface 108. Each of the lower layer cells 206 a-206 g may represent a portion of a relatively deep layer of the formation 104 located below the top layer cell 206 a. The initial reservoir model 140 further includes hydrocarbon wells 112 h, 112 i, 112 j, 112 k and 1121 located at respective top cells 204 h, 204 i, 204 j, 204 k and 2041 of top layer of layer of cells 206 a. Each of the wells 112 h-1121 may be defined by a respective wellbore that penetrates the respective top cells 204 h, 204 i, 204 j, 204 k and 2041 and one more of the cells 204 located directly there beneath. For example, the well 112 a located at the cell 204 h may have a wellbore 114 that penetrates the top cell 204 h and some or all of the six underground cells 204 located directly beneath the cell 204 h. In such an embodiment, the initial reservoir model 140 may be defined by the 3D grid of cells 202, a set of properties for each of the cells 204 corresponding to the first point in time, the locations of the wells 112 h-1121 (and the trajectories of the wellbores of the wells 112 h-1121), and set of operating parameters for the wells 112 h-1121. The set of properties for each of the cells may include, for example, an oil content of each of the cells 204.
FIG. 2B is a diagram that illustrates a well-modified reservoir model 142 for a second point in time, in accordance with one or more embodiments. The well-modified reservoir model 142 is similar to the initial reservoir model 140 of FIG. 2A, but includes additional (or “new”) wells 112 m, 112 n, 112 o and 112 p located at respective top cells 204 m, 204 n, 204 o and 204 p of top layer of layer of cells 206 a. The locations of the new wells 112 m-112 p may be determined, for example, based on a first simulation of the reservoir from the first point in time to the second point in time, using the initial reservoir model 140. Each of the new wells 112 m-112 p may be defined by a respective wellbore that penetrates the respective top cells 204 m, 204 n, 204 o and 204 p and one more of the underground cells 204 located directly there beneath. In such an embodiment, the well-modified reservoir model 142 may be defined by the 3D grid of cells 202, a set of properties for each of the cells 204 corresponding to the second point in time, the locations of the wells 112 a-112 p (and the trajectories of the wellbores the wells 112 a-112 p) and a set of operating parameters for the wells 112 a-112 p.
With reference to FIGS. 2A and 2B, in some embodiments, the initial reservoir model 140 of FIG. 2A is determined for Jan. 1, 2020, which defines parameters and locations of the “initial” (or “existing”) set of wells 112 h-1121 that are present on Jan. 1, 2020, and it is determined that four wells can be drilled into the reservoir 102 in 2025 based on the well forecast 134. The initial reservoir model 140 and “future drilling parameters” indicating that four wells can be drilled into the reservoir 102 in 2025 are included with input parameters for a simulation of the reservoir 102 from the year 2020 to the year 2030. A first five-year segment of the simulation process is run for Jan. 1, 2020 to Dec. 31, 2024 using the initial reservoir model 140 and the results of the first five-year segment of the simulation process are used to predict properties of the reservoir 102 on Dec. 31, 2024. The simulation process identifies locations for each of the four new wells 112 m-112 p based on the predicted properties, and generates the corresponding well-modified reservoir model 142 (which includes the predicted properties of the reservoir on Dec. 31, 2024, as well as the four new wells 112 m-112 p inserted at the respective cells 204 m, 204 n, 204 o and 204 p of top layer of layer of cells 206 a). The simulation process, then, proceeds to run the next five-year segment of the simulation process for Jan. 1, 2025 to Dec. 31, 2029 using the well-modified reservoir model 142 to generate a “complete” reservoir simulation 132 for Jan. 1, 2020 to Dec. 31, 2029.
In some embodiments, the placement of wells at a given point in time within a simulation is based on the cumulative volume of hydrocarbons estimated to be contained at different locations within the reservoir at the given point in time. For example, wells may be placed in columns of cells that both (a) do not already have a well located in the column of cells at the point in time and (b) have a relatively high oil content at the point in time (e.g., in comparison to the other columns of cells that do not already have a well located therein). For example, referring to FIGS. 2A and 2B and continuing with the above example, upon the simulation reaching Dec. 31, 2024, an estimate of oil content for each of the “non-well containing” columns of cells 210 (e.g., for each column of cells 210 other than the “well-containing” columns of cells 210 h-2101, which include cells 204 h-1 that have wells 112 h-1 located therein) may be determined, the columns of cells 210 m-210 p may be determined to have the four highest oil contents of the “non-well containing” columns of cells 210, and the four new wells 112 m-112 p may be inserted at the respective top cells 204 m, 204 n, 204 o and 204 p to generate the well-modified reservoir model 142 for use in the next five-year segment of the simulation process, from Jan. 1, 2025 to Dec. 31, 2029.
In some embodiments, the cumulative amount of oil contained in a column of cells (or “column oil content” is determined as an aggregate of the amount of oil contained in the cells of the column of cells. For example, an estimate of oil content for each of the “non-well containing” columns of cells 210 may include a sum of the oil content for each of the cells 204 contained in the column of cells 210. Referring to the first column of cells 210 a, for example, if the cells 204 a-204 g are estimated to have an oil content of about 0 barrels of oil, 500 barrels of oil, 1,000 barrels of oil, 1,500 barrels of oil, 1,000 barrels of oil, 1,500 barrels of oil, and 500 barrels of oil, respectively, on Dec. 31, 2024 based a first segment of a reservoir simulation from Jan. 1, 2025 to Dec. 31, 2029, then the first column of cells 210 a may be determined to have an estimated oil content of about 6,000 barrels of oil on Dec. 31, 2024.
FIG. 3 is a flowchart that illustrates a method of hydrocarbon reservoir modeling, simulation and development in accordance with one or more embodiments. Some or all of the procedural elements of method 300 may be performed, for example, by the control system 110 or another reservoir operator.
In some embodiments, the method 300 includes determining a well forecast for a hydrocarbon reservoir (block 302). Determining a well forecast for a hydrocarbon reservoir may include identifying wells that are expected to be drilled over the course of development of the reservoir. For example, the well forecast 134 for the reservoir 102 may include data that forecasts drilling five wells into the reservoir 102 on or after Jan. 1, 2020 and drilling four wells into the reservoir 102 on or after Jan. 1, 2025. In some embodiments, the well forecast 134 is developed based on financial or logistical assessments, as described herein.
In some embodiments, the method 300 includes conducting a dynamic real-time well placement simulation, based on the well forecast, to generate a reservoir simulation (block 304). Conducting a dynamic well placement simulation based on the well forecast to generate a reservoir simulation may include identifying a number of wells that can be drilled into the reservoir at a given point in time, based on the well forecast, and providing the number of wells and the given point in time as a “well forecast” input to a reservoir simulation process. As described, in some embodiments, when the simulation process reaches simulation of the given point in time, the simulation process may dynamically identify locations for each of the wells based on the estimated properties of the reservoir for the given point in time, and run subsequent segments of the simulation process based on wells being drilled and operated in the identified locations, to generate a simulation for the reservoir.
FIG. 4 is a flowchart that illustrates a method 400 of conducting a dynamic real-time well placement simulation based on the well forecast to generate a reservoir simulation in accordance with one or more embodiments. In some embodiments, the method 400 includes identifying an initial reservoir model for the reservoir (block 402). Identifying an initial reservoir model for the reservoir may include identifying an initial model of the reservoir that includes properties of the reservoir at or near the starting point in time for the simulation. For example, where the simulation is for Jan. 1, 2020 to Dec. 31, 2029, this may include identifying the initial reservoir model 140 of FIG. 2A determined for Jan. 1, 2020. The initial reservoir model 140 may be defined, for example, by the 3D grid of cells 202, a set of properties for each of the cells 204 corresponding to Jan. 1, 2020, the locations of the wells 112 h-1121 (and the trajectories of the wellbores of the wells 112 h-1121), and set of operating parameters for the wells 112 h-1121 for Jan. 1, 2020 forward.
In some embodiments, the method 400 includes conducting a segment of the reservoir simulation based on the current reservoir model to identify segment reservoir properties (block 404). Conducting a segment of the reservoir simulation based on the current reservoir model to identify segment reservoir properties may include identifying a next point in time at which additional wells can be drilled, and conducting a simulation from the current point in time of the simulation to the next point in time using the current reservoir model to identify segment reservoir properties that include estimated properties for the reservoir at the next point in time, identifying locations for each of the “new” wells to be drilled at the next point in time based on the predicted properties of the segment reservoir properties, and generating a corresponding “well-modified” reservoir model that includes the predicted properties of the reservoir at the next point in time, as well as the new wells (e.g., including well trajectories) inserted at the identified locations. For example, where it is determined that four wells can be drilled into the reservoir 102 in 2025 based on the well forecast 134, corresponding “future drilling parameters” may be included with input parameters for a simulation of the reservoir 102 from the year 2020 to the year 2030. A first five-year segment of the simulation process may be run for Jan. 1, 2020 to Dec. 31, 2024 using the “initial” reservoir model 140 that includes parameters and locations of an “initial” (or “existing”) set of five wells that are present on Jan. 1, 2020. The results of the first five-year segment of the simulation process may identify segment reservoir properties that include predicted properties of the reservoir 102 on Dec. 31, 2024, which are based on simulation of the parameters and locations of the initial five wells.
In some embodiments, the method 400 includes determining whether the reservoir simulation includes an additional segment (block 406). If it is determined that the reservoir simulation includes an additional segment, then the method 400 may proceed to identifying locations for additional wells based on the well forecast and current segment reservoir properties (block 408) and generating a well-modified reservoir model based on the identified locations for the additional wells (block 410). The simulation process of method 400 may, then, proceed to conduct a next segment of the simulation using the well-modified reservoir model (at block 404). If it is determined that the reservoir simulation includes an additional segment, then the method 400 may proceed to generating a reservoir simulation based on the segment reservoir properties (block 412). Accordingly, the cycle of simulating a segment of the simulation and dynamically placing wells between the simulations of the segments may continue until all segments of the simulation have been completed.
Continuing with the prior example, after simulating the segment from Jan. 1, 2020 to Dec. 31, 2024, it may be determined that the simulation includes an additional segment from Jan. 1, 2025 to Dec. 31, 2029. In response to this determination, the simulation process may identify the respective locations for each of the four new wells 112 m-112 p based on the predicted properties of the segment reservoir properties for the reservoir 102 on Dec. 31, 2024 determined in the “first” simulation segment, and generate the corresponding well-modified reservoir model 142 (which includes the predicted properties of the reservoir on Dec. 31, 2024, as well as parameters of the four new wells 112 m-112 p inserted at the respective top cells 204 m, 204 n, 204 o and 204 p of the top layer of layer of cells 206 a). A next iteration of the simulation process may proceed to run a second five-year segment of the simulation process for Jan. 1, 2025 to Dec. 31, 2030 using the well-modified reservoir model 142. The results of the second five-year segment of the simulation process may identify segment reservoir properties that include predicted properties of the reservoir 102 on Dec. 31, 2030 based on simulation of the parameters and locations of the wells 112 a-112 p. A reservoir simulation 132 for Jan. 1, 2020 to Dec. 31, 2029 may be generated using the segment reservoir properties for each of the segments simulated. For example, a reservoir simulation 132 for Jan. 1, 2020 to Dec. 31, 2029 may identify the predicted location of water and hydrocarbons within the reservoir 102, and a volume of hydrocarbons produced from the reservoir 102, based on the segment reservoir properties for Dec. 31, 2029.
The placement of wells at a given point in time within a simulation may be based on the cumulative volume of hydrocarbons estimated to be contained at different locations within the reservoir at the given point in time. For example, wells may be placed in columns of cells that both (a) do not already have a well located in the column of cells at the point in time and (b) have a relatively high oil content at the point in time (e.g., in comparison to the other columns of cells that do not already have a well located therein). For example, referring to FIGS. 2A and 2B and continuing with the above example, upon the simulation reaching Dec. 31, 2024, an estimate of oil content for each of the “non-well containing” columns of cells 210 (e.g., for each column of cells 210 other than the “well-containing” columns of cells 210 h-2101, which include cells 204 h-1 that have wells 112 h-1 located therein) may be determined, the columns of cells 210 m-210 p may be determined to have the four highest oil contents of the “non-well containing” columns of cells 210, and the four new wells 112 m-112 p may be inserted at the respective top cells 204 m, 204 n, 204 o and 204 p to generate the well-modified reservoir model 142 for use in the next five-year segment of the simulation process, from Jan. 1, 2025 to Dec. 31, 2029.
The cumulative amount of oil contained in a column of cells (or “column oil content” may be determined as an aggregate of the amount of oil contained in the cells of the column of cells. For example, an estimate of oil content for each of the “non-well containing” columns of cells 210 may include a sum of the oil content for each of the cells 204 contained in the column of cells 210. Referring to the first column of cells 210 a, for example, if the cells 204 a-204 g are estimated to have an oil content of about 0 barrels of oil, 500 barrels of oil, 1,000 barrels of oil, 1,500 barrels of oil, 1,000 barrels of oil, 1,500 barrels of oil, and 500 barrels of oil, respectively, on Dec. 31, 2024 based a first segment of a reservoir simulation from Jan. 1, 2025 to Dec. 31, 2029, then the first column of cells 210 a may be determined to have an estimated oil content of about 6,000 barrels of oil on Dec. 31, 2024.
Referring again to FIG. 3, in some embodiments, the method 300 includes developing the reservoir based on the reservoir simulation (block 306). Developing the reservoir based on the reservoir simulation may include defining or conducting various operations for development of the reservoir based on the “dynamic real-time well placement” simulation of the reservoir. For example, this may include the control system 110 or (another operator of the reservoir 102) determining drilling parameters or operating parameters for wells 112 in the reservoir 102 based on the “dynamic real-time well placement” simulation 132, or controlling drilling or operating of the wells 112 in accordance with the drilling or operating parameters. In some embodiments, a field development plan (FDP) may be generated for the reservoir 102 based on the on the reservoir simulation. For example, the control system 110 or (another operator of the reservoir 102) may generate a FDP that specifies parameters for developing the reservoir 102, such as the drilling parameters or operating parameters for wells 112 in the reservoir 102, based on the on the estimate of production of the reservoir 102 over the given period of time and the movement of fluids within the reservoir 102 over the given period of time provided by the “dynamic real-time well placement” simulation 132. The control system 110 or (another operator of the reservoir 102) may control drilling or operating of the wells 112 in accordance with the respective drilling parameters or operating parameters of the FDP.
FIG. 5 is a diagram that illustrates an example computer system (or “system”) 1000 in accordance with one or more embodiments. The system 1000 may include a memory 1004, a processor 1006 and an input/output (I/O) interface 1008. The memory 1004 may include non-volatile memory (e.g., flash memory, read-only memory (ROM), programmable read-only memory (PROM), erasable programmable read-only memory (EPROM), electrically erasable programmable read-only memory (EEPROM)), volatile memory (e.g., random access memory (RAM), static random access memory (SRAM), synchronous dynamic RAM (SDRAM)), or bulk storage memory (e.g., CD-ROM or DVD-ROM, hard drives). The memory 1004 may include a non-transitory computer-readable storage medium having program instructions 1010 stored on the medium. The program instructions 1010 may include program modules 1012 that are executable by a computer processor (e.g., the processor 1006) to cause the functional operations described, such as those described with regard to the control system 110, or the methods 300 or 400.
The processor 1006 may be any suitable processor capable of executing program instructions. The processor 1006 may include one or more processors that carry out program instructions (e.g., the program instructions of the program modules 1012) to perform the arithmetical, logical, or input/output operations described. The processor 1006 may include multiple processors that can be grouped into one or more processing cores that each include a group of one or more processors that are used for executing the processing described here, such as the independent parallel processing of partitions (or “sectors”) by different processing cores to generate a simulation of a reservoir. The I/O interface 1008 may provide an interface for communication with one or more I/O devices 1014, such as a joystick, a computer mouse, a keyboard, or a display screen (e.g., an electronic display for displaying a graphical user interface (GUI)). The I/O devices 1014 may include one or more of the user input devices. The I/O devices 1014 may be connected to the I/O interface 1008 by way of a wired connection (e.g., an Industrial Ethernet connection) or a wireless connection (e.g., a Wi-Fi connection). The I/O interface 1008 may provide an interface for communication with one or more external devices 1016, such as sensors, valves, pumps, motors, computers or communication networks. In some embodiments, the I/O interface 1008 includes an antenna or a transceiver.
Further modifications and alternative embodiments of various aspects of the disclosure will be apparent to those skilled in the art in view of this description. Accordingly, this description is to be construed as illustrative only and is for the purpose of teaching those skilled in the art the general manner of carrying out the embodiments. It is to be understood that the forms of the embodiments shown and described here are to be taken as examples of embodiments. Elements and materials may be substituted for those illustrated and described here, parts and processes may be reversed or omitted, and certain features of the embodiments may be utilized independently, all as would be apparent to one skilled in the art after having the benefit of this description of the embodiments. Changes may be made in the elements described here without departing from the spirit and scope of the embodiments as described in the following claims. Headings used here are for organizational purposes only and are not meant to be used to limit the scope of the description.
It will be appreciated that the processes and methods described here are example embodiments of processes and methods that may be employed in accordance with the techniques described here. The processes and methods may be modified to facilitate variations of their implementation and use. The order of the processes and methods and the operations provided may be changed, and various elements may be added, reordered, combined, omitted, modified, and so forth. Portions of the processes and methods may be implemented in software, hardware, or a combination thereof. Some or all of the portions of the processes and methods may be implemented by one or more of the processors/modules/applications described here.
As used throughout this application, the word “may” is used in a permissive sense (meaning having the potential to), rather than the mandatory sense (meaning must). The words “include,” “including,” and “includes” mean including, but not limited to. As used throughout this application, the singular forms “a,” “an,” and “the” include plural referents unless the content clearly indicates otherwise. Thus, for example, reference to “an element” may include a combination of two or more elements. As used throughout this application, the term “or” is used in an inclusive sense, unless indicated otherwise. That is, a description of an element including A or B may refer to the element including one or both of A and B. As used throughout this application, the phrase “based on” does not limit the associated operation to being solely based on a particular item. Thus, for example, processing “based on” data A may include processing based at least in part on data A and based at least in part on data B, unless the content clearly indicates otherwise. As used throughout this application, the term “from” does not limit the associated operation to being directly from. Thus, for example, receiving an item “from” an entity may include receiving an item directly from the entity or indirectly from the entity (e.g., by way of an intermediary entity). Unless specifically stated otherwise, as apparent from the discussion, it is appreciated that throughout this specification discussions utilizing terms such as “processing,” “computing,” “calculating,” “determining,” or the like refer to actions or processes of a specific apparatus, such as a special purpose computer or a similar special purpose electronic processing/computing device. In the context of this specification, a special purpose computer or a similar special purpose electronic processing/computing device is capable of manipulating or transforming signals, typically represented as physical, electronic or magnetic quantities within memories, registers, or other information storage devices, transmission devices, or display devices of the special purpose computer or similar special purpose electronic processing/computing device.

Claims

What is claimed is:

1. A method of developing a hydrocarbon reservoir, the method comprising:

generating a dynamic well placement simulation of a hydrocarbon reservoir for a span of time (Δt) defined by a start time (t₁) and end time (t₂), the dynamic well placement simulation comprising:

determining a number (N) of wells to be drilled into the hydrocarbon reservoir at a given point in time (t_w) within the span of time (Δt);

determining an initial reservoir model of the hydrocarbon reservoir, the initial reservoir model comprising cells that represent the hydrocarbon reservoir and a corresponding set of initial properties for each of the cells;

conducting, using the initial reservoir model of the hydrocarbon reservoir, a first segment of a simulation of the hydrocarbon reservoir to generate a first segment reservoir properties, the first segment of the simulation of the hydrocarbon reservoir comprising a simulation of the hydrocarbon reservoir from the start time (t₁) to the given point of time (t_w) that is conducted using the initial reservoir model, the first segment reservoir properties comprising estimated properties for the cells at the given point of time (t_w) determined based on the first segment of the simulation;

identifying, based on the first segment reservoir properties, the number (N) of columns of the cells that have the highest column oil content at the given point of time (t_w) and that do not have a well located in the column at the given point of time (t_w);

generating, based on the columns of cells identified, a well-modified model of the hydrocarbon reservoir, the well-modified model comprising the first segment reservoir properties associated with the cells and a new well located at each column of the columns of the cells identified;

conducting, using the well-modified reservoir model of the hydrocarbon reservoir, a second segment of the simulation of the hydrocarbon reservoir to generate second segment reservoir properties, the second segment of the simulation of the hydrocarbon reservoir comprising a simulation of the hydrocarbon reservoir from the given point of time (t_w) to the end time (t₂) that is conducted using the well-modified reservoir model, the second segment reservoir properties comprising estimated properties for the cells at the end time (t₂) determined based on the second segment of the simulation; and

generating, based on the second segment reservoir properties, a simulation of the hydrocarbon reservoir for the span of time (Δt).

2. The method of claim 1, wherein determining a number (N) of wells to be drilled into the hydrocarbon reservoir at the given point in time (t) comprises conducting a financial assessment of the development of the hydrocarbon reservoir to determine the number (N) of wells to be drilled at the point in time (t).

3. The method of claim 1, wherein determining a number (N) of wells to be drilled into the hydrocarbon reservoir at the given point in time (t) comprises conducting a logistical assessment of the development of the hydrocarbon reservoir to determine the number (N) of wells to be drilled at the point in time (t).

4. The method of claim 1, further comprising:

determining a second number (N₂) of wells to be drilled into the hydrocarbon reservoir at a second given point in time (t_w2) that is later than the given point in time (t) and earlier than the end time (t₂);

the second segment of the simulation of the hydrocarbon reservoir comprising:

identifying, based on the second segment reservoir properties and from columns of the cells, the second number (N₂) of columns of the cells that have the highest column oil content at the second given point of time (t_w2) and that do not have a well located in the column at the given point of time (t_w2);

conducting, using the well-modified reservoir model of the hydrocarbon reservoir, a third segment of the simulation of the hydrocarbon reservoir to generate third segment reservoir properties, the third segment of the simulation of the hydrocarbon reservoir comprising a simulation of the hydrocarbon reservoir from the given point in time (t_w) to the second given point of time (t_w2) that is conducted using the well-modified reservoir model, the third segment reservoir properties comprising estimated properties for the cells at the second given point of time (t_w2) determined based on the third segment of the simulation;

identifying, based on the oil content of the cells of the third segment reservoir properties, the number (N₂) of columns of the cells that have the highest column oil content at the second given point of time (t_w2) and that do not have a well located in the column at the second given point of time (t_w2);

generating, based on the columns of cells identified, a second well-modified model of the hydrocarbon reservoir, the second well-modified model comprising the third segment reservoir properties associated with the cells and a new well located at each of the columns of the cells identified for the second given point of time (t_w2); and

conducting, using the second well-modified reservoir model of the hydrocarbon reservoir, a fourth segment of the simulation of the hydrocarbon reservoir to generate fourth segment reservoir properties, the fourth segment of the simulation of the hydrocarbon reservoir comprising a simulation of the hydrocarbon reservoir from the second given point of time (t_w2) to the end time (t₂) that is conducted using the second well-modified reservoir model, the fourth segment reservoir properties comprising estimated properties for the cells at the end time (t₂) determined based on the fourth segment of the simulation,

where the second segment of the simulation of the hydrocarbon reservoir comprises the third and fourth segments of the simulation of the hydrocarbon reservoir, and the second segment reservoir model corresponds to the fourth segment reservoir model.

5. The method of claim 1, wherein the estimated properties for each of the cells at the given point of time (t_w) include an oil content of the cell at the given point of time (t_w).

6. The method of claim 1, wherein the column oil content of each of the columns of the cells at the given point of time (t_w) is defined by a sum of the volume of oil content of the cells in the column at the given point of time (t_w).

7. The method of claim 1, further comprising generating a field development plan (FDP) for the hydrocarbon reservoir based on the simulation of the hydrocarbon reservoir.

8. The method of claim 1, further comprising:

identifying well drilling parameters based on the simulation of the hydrocarbon reservoir; and

drilling a well in the hydrocarbon reservoir based on the well drilling parameters.

9. The method of claim 1, further comprising:

identifying well operating parameters based on the simulation of the hydrocarbon reservoir; and

operating a well in the hydrocarbon reservoir based on the well operating parameters.

10. A non-transitory computer readable storage medium comprising program instructions stored thereon that are executable by a processor to perform the following operations for developing a hydrocarbon reservoir:

11. The medium of claim 10, wherein determining a number (N) of wells to be drilled into the hydrocarbon reservoir at the given point in time (t) comprises conducting a financial assessment of the development of the hydrocarbon reservoir to determine the number (N) of wells to be drilled at the point in time (t).

12. The medium of claim 10, wherein determining a number (N) of wells to be drilled into the hydrocarbon reservoir at the given point in time (t) comprises conducting a logistical assessment of the development of the hydrocarbon reservoir to determine the number (N) of wells to be drilled at the point in time (t).

13. The medium of claim 10, the operations further comprising:

the second segment of the simulation of the hydrocarbon reservoir comprising:

14. The medium of claim 10, wherein the estimated properties for each of the cells at the given point of time (t_w) include an oil content of the cell at the given point of time (t_w).

15. The medium of claim 10, wherein the column oil content of each of the columns of the cells at the given point of time (t_w) is defined by a sum of the volume of oil content of the cells in the column at the given point of time (t_w).

16. The medium of claim 10, the operations further comprising generating a field development plan (FDP) for the hydrocarbon reservoir based on the simulation of the hydrocarbon reservoir.

17. The medium of claim 10, the operations further comprising:

18. The medium of claim 10, the operations further comprising:

19. A hydrocarbon reservoir development system comprising:

a hydrocarbon reservoir control system comprising non-transitory computer readable storage medium comprising program instructions stored thereon that are executable by a processor to perform the following operations for developing a hydrocarbon reservoir:

20. The system of claim 19, wherein determining a number (N) of wells to be drilled into the hydrocarbon reservoir at the given point in time (t) comprises conducting a financial assessment of the development of the hydrocarbon reservoir to determine the number (N) of wells to be drilled at the point in time (t).

21. The system of claim 19, wherein determining a number (N) of wells to be drilled into the hydrocarbon reservoir at the given point in time (t) comprises conducting a logistical assessment of the development of the hydrocarbon reservoir to determine the number (N) of wells to be drilled at the point in time (t).

22. The system of claim 19, the operations further comprising:

the second segment of the simulation of the hydrocarbon reservoir comprising:

23. The system of claim 19, wherein the estimated properties for each of the cells at the given point of time (t_w) include an oil content of the cell at the given point of time (t_w).

24. The system of claim 19, wherein the column oil content of each of the columns of the cells at the given point of time (t_w) is defined by a sum of the volume of oil content of the cells in the column at the given point of time (t_w).

25. The system of claim 19, the operations further comprising generating a field development plan (FDP) for the hydrocarbon reservoir based on the simulation of the hydrocarbon reservoir.

26. The system of claim 19, the operations further comprising:

27. The system of claim 19, the operations further comprising: