Hydrocarbon Gas Production System

Provided is hydrocarbon reservoir production system and method that employs a production monitoring system including a well production monitoring system to obtain well production data and gas characteristics of hydrocarbons produced by wells associated with a production region of the reservoir. The production monitoring system adapted to receive selection of modeling parameters, including a selected region and time period, and to generate a set of well performance data including a production data and gas production data for the selected region and time period. A production modeling system adapted to generate, based on the set of well performance data, a model of the performance of the selected region. A production operations system adapted to regulate, based on simulation of the model, operation of wells in the selected region.

FIELD

Embodiments relate generally to developing hydrocarbon reservoirs, and more particularly to operation of hydrocarbon wells based on sales gas production.

BACKGROUND

A rock formation that resides beneath 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 hydrocarbon wells. A hydrocarbon well normally includes a wellbore (or “borehole”) that is drilled into a reservoir to facilitate the extraction (or “production”) of hydrocarbons, such as oil and gas, from the reservoir, the injection of substances into the reservoir, or the evaluation and monitoring of the reservoir.

Development of a hydrocarbon reservoir typically involves multiple phases and 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 a field development plan (FDP) that outlines parameters for extracting hydrocarbons from the reservoir in economical and environmentally responsible manner. An FDP may, for example, specify operating parameters for wells in the reservoir, such as target production rates and pressures, and a reservoir operator may, in turn, operate the wells accordance with the FDP parameters.

SUMMARY

Reservoir simulation can be an important aspect of developing a hydrocarbon reservoir. In many instances, operators rely on simulations to characterize performance of a hydrocarbon reservoir and use the results of the simulations as a basis for developing the reservoir. For example, an operator may conduct simulations of different operating scenarios to generate estimates (or “predictions”) of hydrocarbon production from the reservoir under the different scenarios, select a preferred scenario based on the estimates, and generate and employ a field development plan (FDP) that is consistent with the selected operating scenario. These types of assessments may be completed over the life of a reservoir, sometimes daily or weekly, in an effort to regularly assess and adjust reservoir operations for efficient and effective development of the reservoir.

Simulation of hydrocarbon reservoir production (or “production simulation”) may involve processing (or “simulating”) a model of reservoir production (or “production model”) to predict the reservoir's hydrocarbon production characteristics for a set of operating parameters. A reservoir model is often built using historical reservoir data, and conditions of an operating a scenario are applied to the model to generate a prediction of reservoir performance under that scenario. For example, hydrocarbon reservoir modeling and simulation may involve collecting a set of historical production data for wells in the reservoir, generating a production model based on the historical production data, and conducting a production simulation that involves applying a set of operating parameters to the production model to generate a prediction of production characteristics, such as a predicted production rate, for the set of operating parameters.

Although simulations are a useful tool, they often suffer from limitations that can affect their accuracy, flexibility and usefulness. For example, models and simulations are typically built on a fixed set of set of historical data and may not provide an operator with flexibility to generate models and simulations dynamically, to explore results for custom sets of input data. This can limit an operator's ability to explore different modeling strategies, which can limit the operator's ability to fully understand the impact different reservoir operations on the behavior of the reservoir.

Provided are techniques for monitoring, modeling, simulating and operating a hydrocarbon reservoir based on dynamically defined modeling parameters. In some embodiments, a hydrocarbon reservoir production system includes a production monitoring system having (a) a well production monitoring system that collects well production data for wells in the reservoir and (b) a gas monitoring system having gas production sensors that are associated with a region in the system and operable to sense characteristics of gas in the production of the wells. The production monitoring system can provide for user selection of desired modeling parameters, including a selected region, a selected time period and a selected gas production sensor type, and, in response to receiving such a selection, generate a set of well gas performance data that includes corresponding data. The well gas performance data may include (a) well production data including a subset of the production data for a subset of the wells (i) in the selected region and (ii) measured in the selected time period, and (b) gas production data including gas characteristics sensed by gas production sensors (i) associated with the selected region and of the selected type of gas production sensor and (ii) measured in the selected time period. The gas production sensors may include different types of sensors (e.g., carbon dioxide (CO2) sensors, hydrogen sulfide (H2S) sensors, total dissolved gas (TDG) sensors, or the like), and the selection of one or more types of sensors may provide for gas production data including only gas characteristics (e.g., CO2content, H2S content, total dissolved gas content or the like) sensed by the selected types of sensors. In some embodiments, sensors are tagged (or otherwise associated) with a sensor type, well or region, and a set of well gas performance data includes data obtained from sensors tagged with a sensor type, well or region corresponding to the selected modeling parameters, including sensor type, well or region.

In some embodiments, the hydrocarbon reservoir production system further includes a production modeling system (e.g., a machine learning modeling system) that (1) divides the subset of the production data into (a) a training dataset, (b) a validation dataset, and (c) a testing dataset, (2) generates (using the training dataset) trained models of the performance of the subset of the wells located in the region selected (the models for use in determining predicted sales gas characteristics for the region based on production characteristics of the wells located in the given region), (3) conducts (e.g., by applying the validation dataset to the trained models of the performance of the subset of the wells located in the given region selected) a validation operation to select one of the models as a validated model, and (4) conducts (e.g., by applying the testing dataset to the validated model) a verification operation to verify accuracy of the validated model.

In some embodiments, the hydrocarbon reservoir production system further includes a production operations system that (1) determines (e.g., based on application of predicted well production data for the subset of the wells located in the given region to the validated model) predicted sales gas characteristics for the subset of the wells located in the given region, and (2) regulates (e.g., based on the predicted sales gas characteristics for the region) operation of one or more of the wells located in the given region selected.

Such a hydrocarbon reservoir production system may enable a user to dynamically generate and employ validated production models to predict sales gas characteristics (such as CO2, H2S or TDG content) of a reservoir for different operating scenarios and data inputs, which can be used as a basis for defining and employing well operating parameters for wells in the reservoir.

Provided in some embodiments is a hydrocarbon reservoir production system that includes the following: a production monitoring system including: a well production monitoring system adapted to obtain well production data for wells in a hydrocarbon reservoir, the well production data including measured hydrocarbon production of the wells; and a gas production monitoring system including gas production sensors adapted to sense gas characteristics of hydrocarbons produced by the wells, each of the gas production sensors adapted to sense a characteristic of gas produced by one or more of the wells and being associated with a production region, the gas production monitoring system adapted to generate gas production data including measurements of gas characteristics sensed by the gas production sensors, each of the measurements being associated with a region of the gas production sensor and a time of measurement, the production monitoring system adapted to: receive, by way of a user interface, user selection of modeling parameters including a selected region and a selected time period; and generate, in response to receiving the selection of the modeling parameters, a set of well performance data including: well production data including a subset of the production data for a subset of the wells (i) in the selected region and (ii) measured in the selected time period; and gas production data including gas characteristics sensed by gas production sensors (i) associated with the selected region and (ii) measured in the selected time period; a production modeling system adapted to generate, based on the set of well performance data, a model of the performance of the subset of the wells located in the selected region; and a production operations system adapted to regulate, based on simulation of the model, operation of one or more of the wells in the selected region.

In some embodiments, the well production monitoring system includes production flowrate sensors and the measured hydrocarbon production of the wells includes measurements of flowrate of actual hydrocarbon production of the wells. In certain embodiments, the gas production sensors include different types of gas production sensors, where the modeling parameters include a selection of one or more of the different types of gas production sensors, and where the gas production data includes gas characteristics sensed by gas production sensors (i) associated with the selected region, (ii) measured in the selected time period, and (iii) of a type of gas production sensor selected. In some embodiments, the gas production sensors include carbon dioxide (CO2) content type sensors, hydrogen sulfide (H2S) content type sensors, and total dissolved gas content type sensors, and the modeling parameters includes a selection of one or more of the CO2 content type sensors, H2S content type sensors, and total dissolved gas content type sensors. In some embodiments, the generation of the model includes: dividing the set of well performance data into: a training dataset; a validation dataset; and a testing dataset; generating, using the training dataset, trained models of the performance of the subset of the wells located in the selected region, the models adapted to be used to determine predicted sales gas characteristics for the selected region based on production characteristics of the wells located in the selected region; conducting, by applying the validation dataset to the trained models, a validation operation to select one of the trained models as a validated model; and conducting, by applying the testing dataset to the validated model, a verification operation to verify accuracy of the validated model. In certain embodiments, the regulating of operation of the one or more of the wells in the selected region includes: determining, based on application of predicted well production data for the subset of the wells located in the selected region to the validated model, predicted sales gas characteristics for the subset of the wells located in the selected region; and regulating, based on the predicted sales gas characteristics for the selected region, operation of one or more of the wells in the selected region. In some embodiments, regulating operation of one or more of the wells located in the selected region includes: determining, based on the predicted sales gas characteristics for the region, target production flowrates for the wells in the selected region; and operating the wells in the selected region in accordance with the target production flowrates.

Provided in some embodiments is a method of producing hydrocarbons from a hydrocarbon reservoir, the method including: obtaining, by a well production monitoring system, well production data for wells in a hydrocarbon reservoir, the well production data including measured hydrocarbon production of the wells; sensing, by production sensors of a gas production monitoring system, gas characteristics of hydrocarbons produced by the wells, each of the gas production sensors sensing a characteristic of gas produced by one or more of the wells and being associated with a production region, generating, by the gas production monitoring system, gas production data including measurements of gas characteristics sensed by the gas production sensors, each of the measurements by a gas production sensor being associated with a region of the gas production sensor and a time of measurement; receiving, by way of a user interface of a production monitoring system, user selection of modeling parameters including a selected region and a selected time period; and generating, in response to receiving the selection of the modeling parameters, a set of well performance data including: well production data including a subset of the production data for a subset of the wells (i) in the selected region and (ii) measured in the selected time period; and gas production data including gas characteristics sensed by gas production sensors (i) associated with the selected region and (ii) measured in the selected time period; generating, by a production modeling system and based on the set of well performance data, a model of the performance of the subset of the wells located in the selected region; and regulating, by a production operations system and based on simulation of the model, operation of one or more of the wells in the selected region.

In some embodiments, the well production monitoring system includes production flowrate sensors and the measured hydrocarbon production of the wells includes measurements of flowrate of actual hydrocarbon production of the wells. In certain embodiments, the gas production sensors include different types of gas production sensors, where the modeling parameters includes a selection of one or more of the different types of gas production sensors, and where the gas production data includes gas characteristics sensed by gas production sensors (i) associated with the selected region, (ii) measured in the selected time period, and (iii) of a type of gas production sensor selected. In some embodiments, the gas production sensors include carbon dioxide (CO2) content type sensors, hydrogen sulfide (H2S) content type sensors, and total dissolved gas content type sensors, and the modeling parameters includes selection of one or more of the CO2 content type sensors, H2S content type sensors, and total dissolved gas content type sensors. In certain embodiments, the generation of the model includes: dividing the set of well performance data into: a training dataset; a validation dataset; and a testing dataset; generating, using the training dataset, trained models of the performance of the subset of the wells located in the selected region, the models adapted to be used to determine predicted sales gas characteristics for the selected region based on production characteristics of the wells located in the selected region; conducting, by applying the validation dataset to the trained models, a validation operation to select one of the trained models as a validated model; and conducting, by applying the testing dataset to the validated model, a verification operation to verify accuracy of the validated model. In some embodiments, the regulating of operation of the one or more of the wells in the selected region includes: determining, based on application of predicted well production data for the subset of the wells located in the selected region to the validated model, predicted sales gas characteristics for the subset of the wells located in the selected region; and regulating, based on the predicted sales gas characteristics for the selected region, operation of one or more of the wells in the selected region. In certain embodiments, regulating operation of one or more of the wells located in the selected region includes: determining, based on the predicted sales gas characteristics for the region, target production flowrates for the wells in the selected region; and operating the wells in the selected region in accordance with the target production flowrates.

Provided in some embodiments is a non-transitory computer readable storage medium including program instructions stored thereon that are executable by a processor to perform the following operations for producing hydrocarbons from a hydrocarbon reservoir: obtaining, by a well production monitoring system, well production data for wells in a hydrocarbon reservoir, the well production data including measured hydrocarbon production of the wells; sensing, by way of production sensors of a gas production monitoring system, gas characteristics of hydrocarbons produced by the wells, each of the gas production sensors sensing a characteristic of gas produced by one or more of the wells and being associated with a production region, generating, by the gas production monitoring system, gas production data including measurements of gas characteristics sensed by the gas production sensors, each of the measurements by a gas production sensor being associated with a region of the gas production sensor and a time of measurement; receiving, by way of a user interface of a production monitoring system, user selection of modeling parameters including a selected region and a selected time period; and generating, in response to receiving the selection of the modeling parameters, a set of well performance data including: well production data including a subset of the production data for a subset of the wells (i) in the selected region and (ii) measured in the selected time period; and gas production data including gas characteristics sensed by gas production sensors (i) associated with the selected region and (ii) measured in the selected time period; generating, by a production modeling system and based on the set of well performance data, a model of the performance of the subset of the wells located in the selected region; and regulating, based on simulation of the model, operation of one or more of the wells in the selected region.

In some embodiments, the well production monitoring system includes production flowrate sensors and the measured hydrocarbon production of the wells includes measurements of flowrate of actual hydrocarbon production of the wells. In certain embodiments, the gas production sensors include different types of gas production sensors, where the modeling parameters include a selection of one or more of the different types of gas production sensors, and where the gas production data includes gas characteristics sensed by gas production sensors (i) associated with the selected region, (ii) measured in the selected time period, and (iii) of a type of gas production sensor selected. In some embodiments, the generation of the model includes: dividing the set of well performance data into: a training dataset; a validation dataset; and a testing dataset; generating, using the training dataset, trained models of the performance of the subset of the wells located in the selected region, the models adapted to be used to determine predicted sales gas characteristics for the selected region based on production characteristics of the wells located in the selected region; conducting, by applying the validation dataset to the trained models, a validation operation to select one of the trained models as a validated model; and conducting, by applying the testing dataset to the validated model, a verification operation to verify accuracy of the validated model. In certain embodiments, the regulating of operation of the one or more of the wells in the selected region includes: determining, based on application of predicted well production data for the subset of the wells located in the selected region to the validated model, predicted sales gas characteristics for the subset of the wells located in the selected region; and regulating, based on the predicted sales gas characteristics for the selected region, operation of one or more of the wells in the selected region. In some embodiments, regulating operation of one or more of the wells located in the selected region includes: determining, based on the predicted sales gas characteristics for the region, target production flowrates for the wells in the selected region; and controlling operation of the wells in the selected region in accordance with the target production flowrates.

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. The drawings and the detailed descriptions are not intended to limit the disclosure to the form disclosed, but are intended to disclose modifications, equivalents, and alternatives falling within the scope of the disclosure as defined by the claims.

DETAILED DESCRIPTION

Described are embodiments of novel systems and method monitoring, modeling, simulating and operating a hydrocarbon reservoir based on dynamically defined modeling parameters. In some embodiments, a hydrocarbon reservoir production system includes a production monitoring system having (a) a well production monitoring system that collects well production data for wells in the reservoir and (b) a gas monitoring system having gas production sensors that are associated with a region in the system and operable to sense characteristics of gas in the production of the wells. The production monitoring system can provide for user selection of desired modeling parameters, including a selected region, a selected time period and a selected gas production sensor type, and, in response to receiving such a selection, generate a set of well gas performance data that includes corresponding data. The well gas performance data may include (a) well production data including a subset of the production data for a subset of the wells (i) in the selected region and (ii) measured in the selected time period, and (b) gas production data including gas characteristics sensed by gas production sensors (i) associated with the selected region and of the selected type of gas production sensor and (ii) measured in the selected time period. The gas production sensors may include different types of sensors (e.g., Carbon dioxide (CO2) sensors, Hydrogen Sulfide (H2S) sensors, total dissolved gas (TDG) sensors, or the like), and the selection of one or more types of sensors may provide for gas production data including only gas characteristics (e.g., CO2content, H2S content, total dissolved gas content or the like) sensed by the selected types of sensors.

In some embodiments, the hydrocarbon reservoir production system further includes a production modeling system (e.g., a machine learning modeling system) that (1) divides the subset of the production data into (a) a training dataset, (b) a validation dataset, and (c) a testing dataset, (2) generates (using the training dataset) trained models of the performance of the subset of the wells located in the region selected (the models for use in determining predicted sales gas characteristics for the region based on production characteristics of the wells located in the given region), (3) conducts (e.g., by applying the validation dataset to the trained models of the performance of the subset of the wells located in the given region selected) a validation operation to select one of the models as a validated model, and (4) conducts (e.g., by applying the testing dataset to the validated model) a verification operation to verify accuracy of the validated model.

In some embodiments, the hydrocarbon reservoir production system further includes include a production operations system that (1) determines (e.g., based on application of predicted well production data for the subset of the wells located in the given region to the validated model) predicted sales gas characteristics for the subset of the wells located in the given region, and (2) regulates (e.g., based on the predicted sales gas characteristics for the region) operation of one or more of the wells located in the given region selected.

FIG.1is a diagram that illustrates a reservoir environment100in accordance with one or more embodiments. In the illustrated embodiment, the reservoir environment100includes a reservoir (“reservoir”)102located in a subsurface formation (“formation”)104, and a production system106.

The formation104may include a porous or fractured rock formation that resides beneath the earth's surface (or “surface”)108. The reservoir102may be a hydrocarbon reservoir defined by a portion of the formation104that contains (or that is at least determined or expected to contain) a subsurface pool of hydrocarbons, such as oil and gas. The formation104and the reservoir102may each include layers of rock having varying characteristics, such as varying degrees of permeability, porosity, and fluid saturation.

In the illustrated embodiment, the production system106includes multiple well systems (“wells”)110and a hydrocarbon reservoir production control system (“production control system”)112. Each of the wells110may, for example, be operated as a hydrocarbon production well (or “production well”) that is operable to facilitate the extraction of hydrocarbons (or “production”), such as oil or gas, from the reservoir102. Each of the wells110may include a wellbore114(e.g., created by a drill bit boring through the formation104) having an outlet with a production tree that is connected to a distribution network of midstream facilities122, such as tanks, pipelines or transport vehicles that provide for the that transport production from the well110to downstream facilities124, such as refineries or export terminals.

In some embodiments, the production control system112includes a production monitoring system (or “monitoring system”)130, a production modeling system (or “modeling system”)132, and a production operations system (or “operations system”)134.

In some embodiments, the monitoring system130provides for monitoring of characteristics of production of the wells110(e.g., wells110a-110c) of the production system106. This may include, for example, monitoring rates of production of the wells110and characteristics of gas contained in the production, such as CO2content, H2S content, total dissolved gas (TDG) content or the like.

In the illustrated embodiment, the monitoring system130includes a well monitoring system230and a gas monitoring system232. The well monitoring system230may be operable to obtain well production data240for the production system106and the gas monitoring system232may be operable to obtain gas production data242for the production system106.

In some embodiments, the well production data240includes actual (or “observed”) rates of production from some or all of the wells110. For example, the well production data240may include, for each of the wells110(e.g., for each of wells110a-110c), a record of flowrates measurements of production from the well110over a preceding year (e.g., timeseries data including flowrate measurements recorded every 10 minutes from Feb. 1, 2021-Jan. 31, 2022).

In some embodiments, the gas production data242includes actual (or “observed”) gas characteristics of the production from some or all of the wells110. For example, the gas production data242may include, for each of the wells110(e.g., for each of wells110a-110c), a record of measurements of concentrations of different gases in the production from the well110over a preceding year (e.g., timeseries data including measurements of gas concentration, such as CO2content, H2S content, TDG content or the like, recorded every 10 minutes from Feb. 1, 2021-Jan. 31, 2022). The measured gas concentrations may be used to determine a content of the gas in a volume of the production.

In some embodiments, the well production data240is obtained by way of well production sensors250operable to measure production flow from the wells110. For example, each of the wells110(e.g., each of wells110a-110c) may have one or more well production sensors250(e.g., respective sensors250a-250c) operable to measure the flowrate of production produced by the well110, and the midstream facilities122may include one or more well production sensors250(e.g., sensor250d) operable to measure the flow rate of comingled production produced by the wells110(e.g., comingled production from wells110a-110c). A well production sensor250may include, for example, a flowrate sensor coupled to a production path (e.g., a production flowline) that measures the flowrate of production flowing in the path.

In some embodiments, the gas production data242is obtained by way of gas production sensors252operable to measure gas characteristics of production from the wells110. For example, each of the wells110(e.g., each wells110a-110c) may have one or more gas production sensors252(e.g., respective sensors252a-252c) operable to measure the gas content of production produced by the wells110, and the midstream facilities122may include one or more gas production sensors252(e.g., sensor252d) operable to measure the gas content of comingled production produced by the wells110(e.g., comingled production from wells110a-110c). A gas production sensor252may include, for example, a gas content sensor (e.g., a CO2content sensor, H2S content sensor, total dissolved gas content sensor, or the like) coupled to a production flow path (e.g., production flowline or the like) that measures concentrations of gas(es) (e.g., CO2content, H2S content, total dissolved gas content or the like) in the production flowing in the path. The gas production sensors252a,252b,252cand252dmay include, for example, a CO2content sensor, a H2S content sensor, a CO2content sensor and a CO2content sensor, respectively.

In some embodiments, portions of the well production data240obtained by way of a production sensor250are associated with the production sensor250or one or more wells110associated with the production sensor250. For example, flowrate data obtained from a flowrate type production sensor250ameasuring production from an outlet of the first well110amay be “tagged” (or otherwise associated) with the first well110a, a flowrate type sensor, and a corresponding region (e.g., its physical location or “region 1”). As a further example, flowrate data obtained from a flowrate type production sensor250dmeasuring comingled production from the wells110a-110cflowing in a midstream flowline may be “tagged” (or otherwise associated) with the wells110a-110c, a flowrate type sensor, and a corresponding region (e.g., its physical location or “region 1”). The region may be, for example, a geographic location (e.g., latitude and longitude coordinates of the first well110aor the sensor250a) or a defined region within the production system106. In the illustrated embodiment, example defined regions include “region 1” including the first well110a, the first production sensor250a, and the first gas production sensor252a, “region 2” including the second well110b, the second production sensor250b, and the second gas production sensor252b, “region 3” including the third well110c, the third production sensor250c, and the third gas production sensor252c, and “region 4” including the fourth production sensor250dand the fourth gas production sensor252d.

In some embodiments, portions of the gas production data242obtained by way of a production sensor250are associated with the production sensor250or one or more wells110associated with the production sensor250. For example, CO2content data obtained from a CO2type content sensor252ameasuring concentration of CO2in the production from an outlet of the first well110amay be “tagged” (or otherwise associated) with the first well110a, a CO2type content sensor, and “region 1.” As a further example, H2S content data obtained from a H2S type content sensor250dmeasuring H2S content of the comingled production from the wells110a-110cflowing in a midstream flowline may be “tagged” (or otherwise associated) with the wells110a-110c(based on them being the source of the production being measured), a H2S type content sensor, and a corresponding region (e.g., its physical location or “region 4”).

In some embodiments, the monitoring system130provides for selection of modeling parameters that define a dataset to be used as a basis for modeling performance of the production system106. For example, the monitoring system130may enable user selection of modeling parameters and generate, from the well production data240and the gas production data242, a set of well performance data260that corresponds to the selected modeling parameters. For example, the monitoring system130may provide for presentation of an interactive user interface element (e.g., by way of a graphical user interface display) that enables a user to select modeling parameters including some or all of the following: one or more regions (e.g., geographic location(s), geographic area(s), or defined region(s)), one or more gas sensor types (e.g., CO2content sensor, H2S content sensor, or TDG content sensor), and one or more time periods (e.g., Jan. 1, 2022-Jan. 31, 2022).

In response to receiving selection of the modeling parameters (e.g., selection of the modeling parameters by a user using the interactive user interface), the monitoring system130may filter the well production data240and the gas production data242in accordance with the selected modeling parameters to generate a set of well performance data260that includes well production data240for the selected region(s), gas sensor type(s), and the time period(s). For example, in response to receiving selection of modeling parameters including: “region 1” and “region 2”; “CO2content sensor type” and “H2S content sensor type”; and “1/1/2022 to 1/31/2022”, the monitoring system130may return a well performance data260that includes (a) a subset of the well production data240including flowrate measurements obtained by way of flowrate sensor(s) in region 1 and 2 (e.g., from production sensors250aand250b) and being associated with (e.g., having timestamps falling within) the timeframe of Jan. 1, 2022-Jan. 31, 2022, and (b) a subset of the gas production data242including measurements obtained by way of the CO2content sensor(s) and H2S content sensor(s) in regions 1 and 2 (e.g., CO2content sensor252aand H2S content sensor252b) and being associated with (e.g., having timestamps falling within) the timeframe of Jan. 1, 2022-Jan. 31, 2022. As another example, in response to receiving selection of modeling parameters including: “region 1”, “region 2”, and “region 4”; “CO2content sensor type”; and “1/1/2022 to 1/31/2022”, the monitoring system130may return a well performance data260that includes (a) a subset of the well production data240including flowrate measurements obtained by way of the flowrate sensors in regions1,2and4(e.g., from production sensors250a,250band250d) and being associated with (e.g., having timestamps falling within) the timeframe of Jan. 1, 2022-Jan. 31, 2022, and (b) a subset of the gas production data242including measurements obtained by way of CO2content sensor(s) in regions1,2and4(e.g., CO2content sensors252aand252d) and being associated with (e.g., having timestamps falling within) the timeframe of Jan. 1, 2022-Jan. 31, 2022.

In some embodiments, the production modeling system132uses the well performance data260as a basis for modeling performance of the production system106. For example, the production modeling system132may generate (e.g., using machine learning) a “validated” production model (or “validated model”)262that can be used in a simulation operation to generate estimated (or “simulated” or “predicted”) characteristics of production of the production system106. The validated production model262may include, for example, a model to which sets of production parameters (e.g., including flowrate parameters) can be applied to determine corresponding sets of estimated (or “predicted”) gas characteristics264of production of the production system106(e.g., such as predicted CO2content, H2S content, or TDG content of the production). The gas produced in production may be referred to as “sales gas” and the gas characteristics264may be referred to as “sales gas characteristics.”

In some embodiments, the production modeling system132identifies subsets of the well performance data260and performs certain modeling operations using respective ones of the subsets to determine the validated production model262. In some embodiments, the production modeling system132conducts a division operation to identify three subsets of the well performance data260. For example, the production modeling system132may divide the well performance data260into three discrete subsets including a training dataset272(e.g., including the data associated with a first portion (e.g., 70%) of the time period represented by the well performance data260), a validation dataset274(e.g., including the data associated with a second portion (e.g., 15%) of the time period represented by the well performance data260), and a testing dataset276(e.g., including the data associated with a third portion (e.g., 15%) of the time period represented by the well performance data260).

In some embodiments, the production modeling system132conducts a training operation using the training dataset272to generate a plurality of trained models280. For example, in an instance where the production modeling system132generates ten trained models280, the production modeling system132may identify ten different portions of the training dataset272and conduct a training operation on each of the ten different portions to generate ten respective trained models280. The training may include machine learning that uses historical data inputs (e.g., the well production data240in the training dataset272) and corresponding historical data outputs (e.g., the gas production data242in the training dataset272) to generate one or more “trained” models that can be used to estimate (or “predict”) outputs (e.g., production gas characteristics) for a given set of inputs (e.g., production flowrate). In some embodiments, the training operation includes conducting linear regression, polynomial regression, decision tress, Nearest Neighbor, support vector machines (SVM), or the like operations on the training dataset272to generate the trained models280.

In some embodiments, the production modeling system132conducts a validation operation to select a given one of the trained models280as a validated model262. For example, the production modeling system132may conduct a validation operation that includes, for each of the trained models280, applying the well production data240(e.g., production flowrates) of validation dataset274to the trained models280to generate a respective set of simulation results (e.g., estimated values of gas characteristics), and comparing the respective set of simulation results to the “observed” gas production data242of the validation dataset274to determine an amount of error between the respective set of simulation results and the “observed” gas production data242of the validation dataset274, and selecting a trained model280having the smallest error as the validated model262.FIG.3is diagram300that illustrates results of a model validation operation in accordance with one or more embodiments. The diagram300illustrates differences between observed (or “actual”) gas characteristics and predicted gas characteristics and associated errors therebetween. In some embodiments, error between observed and predicted gas characteristics are determined by way of Mean Squared Error (MSE), Root Mean Squared Error (RMSE), Mean Absolute Error (MAE), or the like techniques.

In some embodiments, the production modeling system132conducts a verification operation to verify that the validated model262provides acceptable results. For example, the production modeling system132may conduct a verification operation that includes applying the well production data240(e.g., production flowrates) of testing dataset276to the validated model262to generate a respective set of simulation results (e.g., estimated values of gas characteristics), and comparing the respective set of simulation results to the “observed” gas production data242of the testing dataset276to determine an amount of error between the respective set of simulation results (generated by simulating the validated model262) to the “observed” gas production data242of the testing dataset276, where the validated model262is verified responsive to determining that the amount of error satisfies a threshold (e.g., the error is at or below 3%) and is not verified responsive to determining that the amount of error does not satisfy the threshold (e.g., the error is above 3%). In some embodiments, the amount of error is determined by way of Mean Squared Error (MSE), Root Mean Squared Error (RMSE), Mean Absolute Error (MAE), or the like techniques.

In some embodiments, the production operations system134generates predicted gas characteristics264using the validated model262and uses the predicted gas characteristics264as a basis for operating the production system106. For example, the production operations system134(or another operator of the production system106) may, responsive to the accuracy of the model262being verified, conduct simulations of the validated model262for different sets of potential production parameters to generate respective sets of estimated (or “predicted”) gas characteristics264of production of the production system106(e.g., by applying each of the sets of production parameters to the validated model262to generate the respective sets of estimated (or “predicted”) gas characteristics264of production of the production system106), assess the sets of estimated (or “predicted”) gas characteristics264of production of the production system106to determine a given one of the sets of estimated (or “predicted”) gas characteristics264that satisfies sales gas criteria (e.g., the set of estimated (or “predicted”) gas characteristics264that has a lowest CO2, H2S or TDG content, or a CO2, H2S or TDG content that satisfies a corresponding content threshold value, determine the set of production parameters (e.g., production flowrate for the wells110) corresponding to the given set of estimated (or “predicted”) gas characteristics264, generate a FDP290that includes production operating parameters292consistent with the set of production parameters (e.g., including flowrate parameters for the wells110that correspond to the production flowrate for the wells110of the set of production parameters), and operate the production system106in accordance with the production operating parameters292of the FDP290(e.g., operate the wells110in accordance with the flowrate parameters of the FDP290). In some embodiments, threshold values (e.g., for CO2, H2S or TDG) are determined based on one or more production factors, such as plant design or reservoir characteristics. For example, a dome-type plant may be designed to handle a relatively high H2S concentration and, as a result, have a relatively high H2S threshold (e.g., in the range of about 3-4%). In contrast, another type of plant may be designed to handle a relatively low H2S concentration and, as a result, have a relatively low H2S threshold (e.g., in the range of about 2-3%).

In some embodiments, the production control system112is operable to execute the operations described herein, including control of various operations of the production system106, including well production operations. The production control system112may include a production system memory and a production system processor that are operable to perform some or all the various processing and control operations of the production control system112described here. In some embodiments, the production control system112includes a computer system that is the same as or similar to that of computer system1000described with regard to at leastFIG.5.

FIG.2is a flowchart that illustrates a method of operating a reservoir (e.g., including assessing and controlling production operations) in accordance with one or more embodiments. In some embodiments, some or all the operations described with regard to operating the reservoir may be executed or controlled by the production control system112(or another operator of the reservoir102).

In some embodiments, method200includes obtaining production data (block202). This may include obtaining historical well production data for a hydrocarbon reservoir production system (e.g., including production flowrate data for one or more wells in a reservoir over a preceding period of time) and historical gas production data (e.g., including gas characteristics of production from the one or more wells in a reservoir over the preceding period of time) for the production system, as described. For example, obtaining production data may include the well monitoring system230obtaining the well production data240for the production system106, including, for each of the wells110(e.g., for each of wells110a-110c) and midstream facilities122, a record of flowrates measurements of production from the well110over a preceding year (e.g., timeseries data including flowrate measurements recorded every 10 minutes from Feb. 1, 2021-Jan. 31, 2022 by well production sensors250a-250d), and for each of the wells110(e.g., for each of wells110a-110c) and midstream facilities122, a record of measurements of concentrations of different gases in the associated production streams over a preceding year (e.g., timeseries data including measurements of gas concentration, such as CO2content, H2S content, total dissolved gas content or the like, recorded every 10 minutes from Feb. 1, 2021-Jan. 31, 2022 by gas production sensors252a-252d).

In some embodiments, method200includes receiving selection of model parameters (block204). This may include receiving selection of modeling parameters that define a dataset to be used as a basis for modeling performance of the production system, as described. For example, receiving selection of model parameters may include the monitoring system130presenting an interactive user interface element (e.g., by way of a graphical user interface display) that enables a user to select modeling parameters including some or all of the following: one or more regions (e.g., geographic location(s), geographic area(s), or defined region(s)), one or more gas sensor types (e.g., CO2content sensor, H2S content sensor, or TDG content sensor), and one or more time periods (e.g., Jan. 1, 2022-Jan. 31, 2022), and receiving user selection of modeling parameters including: “region 1” and “region 2”; “CO2content sensor type” and “H2S content sensor type”; and “1/1/2022 to 1/31/2022”.

In some embodiments, method200includes generating well performance data (block206). This may include, in response to receiving selection of modeling parameters, generating (from the well production data and the gas production data) a set of well performance data260that corresponds to the selected modeling parameters, as described. For example, generating well performance data may include, in response to receiving selection of modeling parameters including: “region 1” and “region 2”; “CO2content sensor type” and “H2S content sensor type”; and “1/1/2022 to 1/31/2022”, the monitoring system130generating well performance data260that includes (a) a subset of the well production data240including flowrate measurements obtained by way of flowrate sensor(s) in region 1 and 2 (e.g., from production sensors250aand250b) and being associated with (e.g., having timestamps falling within) the timeframe of Jan. 1, 2022-Jan. 31, 2022, and (b) a subset of the gas production data242including measurements obtained by way of the CO2content sensor(s) and H2S content sensor(s) in regions1and2(e.g., CO2content sensor252aand H2S content sensor252b) and being associated with (e.g., having timestamps falling within) the timeframe of Jan. 1, 2022-Jan. 31, 2022.

In some embodiments, method200includes determining a validated model of gas production (block208). This may include, determining a validated model of gas production based on well performance data, as described. For example, determining a validated model of gas production may include the production modeling system132identifying subsets of the well performance data260and performing certain modeling operations using respective ones of the subsets to determine the validated production model262. As described here, in some embodiments, the production modeling system132may divide the well performance data260into three discrete subsets including a training dataset272, a validation dataset274, and a testing dataset276, conduct a training operation (using the training dataset272) to generate a plurality of trained models280, conduct a validation operation (using the validation dataset274) to select a given one of the trained models280as a validated model262, and conduct a verification operation (using the testing dataset276) to verify that the validated model262provides acceptable results. The validated production model262may include, for example, a model to which sets of production parameters (e.g., including production flowrate parameters of the wells110) can be applied to determine corresponding sets of estimated (or “predicted”) gas characteristics264(e.g., such as CO2content, H2S content, or TDG content) of production of the production system106.

In some embodiments, method200includes determining predicted gas characteristics (block210). This may include generating predicted gas characteristics using the validated model, as described. For example, determining predicted gas characteristics may include the production operations system134(or another operator of the production system106), responsive to the accuracy of the model262being verified, conducting simulations of the validated model262for different sets of potential production parameters to generate respective sets of estimated (or “predicted”) gas characteristics264of production of the production system106(e.g., by applying each of the sets of production parameters to the validated model262to generate the respective sets of estimated (or “predicted”) gas characteristics264of production of the production system106). In some embodiments, the estimated gas characteristics264are used to identify production characteristics of certain ones of the wells110. For example, the estimated gas characteristics264may be used to identify relative production characteristics between the wells110, including “high” and “low” contributors (e.g., well with the greatest and least amount of sales gas contributions to production of the production system106).

In some embodiments, method200includes operating the production system (block212). This may include operating the production system based on the estimated (or “predicted”) gas characteristics, as described. For example, operating the production system may include the production operations system134(or another operator of the production system106) assessing the sets of estimated (or “predicted”) gas characteristics264of production of the production system106to determine a given one of the sets of estimated (or “predicted”) gas characteristics264that satisfies a sales gas criteria (e.g., the set of estimated (or “predicted”) gas characteristics264that has a lowest CO2, H2S or dissolved gas content, or a CO2, H2S or dissolved gas content that satisfies a corresponding threshold value), determining the set of production parameters (e.g., production flowrate for the wells110) corresponding to the given set of estimated (or “predicted”) gas characteristics264, generating a FDP290that includes production operating parameters292consistent with the set of production parameters (e.g., including flowrate parameters for the wells110that correspond to the set of production parameters (e.g., to the production flowrate for the wells110of the set of production parameters), and operating the production system106in accordance with the production operating parameters292of the FDP290(e.g., operating the wells110in accordance with the flowrate parameters of the FDP290). This may include controlling valves/chokes or similar mechanisms of the production system106used to regulate the flow of production from the wells110in accordance with “target” flowrate parameters of the FDP290.

The techniques describe here may provide for an operator dynamically generating and employ validated production models to predict sales gas characteristics (such as CO2, H2S or TDG content) of a reservoir for different operating scenarios and data inputs, which can, in turn, be used as a basis for defining and employing well operating parameters for wells in the reservoir. This may provide for generation and use of production model that can generate predicted sales gas characteristics that closely track actual (or “observed” or “measured”) sales gas characteristics for a set of operating conditions.FIG.4is a diagram400that illustrates a low variance of sales gas characteristics (e.g., predicted using the described techniques) relative to actual (or “observed” or “measured”) sales gas characteristics, which illustrates the effectiveness of the described assessment, modeling, and operating techniques.

FIG.5is a diagram that illustrates an example computer system (or “system”)1000in accordance with one or more embodiments. In some embodiments, the system1000is a programmable logic controller (PLC). The system1000may include a memory1004, a processor1006and an input/output (I/O) interface1008. The memory1004may 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 memory1004may include a non-transitory computer-readable storage medium having program instructions1010stored thereon. The program instructions1010may include program modules1012that are executable by a computer processor (e.g., by the processor1006) to cause the functional operations described, such as those described with regard to the production system106, the production control system112, the monitoring system130, the modeling system132, the operations system134, or the method200.

The processor1006may be any suitable processor capable of executing program instructions. The processor1006may include a central processing unit (CPU) that carries out program instructions (e.g., the program instructions of the program modules1012) to perform the arithmetical, logical, or input/output operations described. The processor1006may include one or more processors. The I/O interface1008may provide an interface for communication with one or more I/O devices1014, such as a joystick, a computer mouse, a keyboard, or a display screen (for example, an electronic display for displaying a graphical user interface (GUI)). The I/O devices1014may include one or more of the user input devices. The I/O devices1014may be connected to the I/O interface1008by way of a wired connection (e.g., an Industrial Ethernet connection) or a wireless connection (e.g., a Wi-Fi connection). The I/O interface1008may provide an interface for communication with one or more external devices1016. In some embodiments, the I/O interface1008includes one or both of an antenna and a transceiver. The external devices1016may include, for example, devices of the production system106, such as the well production sensors250, the gas production sensors252and valves/chokes or similar mechanisms used to regulate production flow from the wells110.

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 of software and hardware. Some or all 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 (that is, meaning having the potential to), rather than the mandatory sense (that is, 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 (for example, 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.