Abstract: The disclosed embodiments include a method, apparatus, and computer program product configured to performing automated downhole wellbore trajectory control for correcting between an actual wellbore trajectory path and a planned wellbore trajectory path. For example, in one embodiment, a PID controller is configured to obtain real-time data gathered during the drilling operation, determine whether the actual wellbore trajectory path deviates from the planned wellbore trajectory path, and automatically initiate the downhole wellbore trajectory control to change the actual wellbore trajectory path to a modified correction path that is determined using a minimum incremental wellbore energy method.

Abstract: System and methods for optimizing wellbore tubular design are provided. Design parameters for a wellbore tubular component are determined based on different types of axial loads expected during a downhole operation. The design parameters include load conditions at load points along the tubular component. An equivalent axial load is calculated for each load point, based on the corresponding load conditions. Design limits for the different types of axial loads are determined based on associated design parameters. A counter-load pressure is determined for at least one load point selected for each type of axial load, based on the corresponding equivalent axial load for each load point and a corresponding design limit for each type of axial load. At least one of the design limits is adjusted for the different types of axial loads, based on the counter-load pressure of the selected load point for each type of axial load.

Abstract: A method may include drilling a deviated wellbore penetrating a subterranean formation according to bottom hole assembly parameters and surface parameters; collecting real-time formation data during drilling; updating a model of the subterranean formation based on the real-time formation data and deriving formation properties therefrom; collecting survey data corresponding to a location of a drill bit in the subterranean formation; deriving a target well path for the drilling based on the model of the subterranean formation; deriving a series of trajectory well paths based on the formation properties, the survey data, the bottom hole assembly parameters, and the surface parameters and uncertainties associated therewith; deriving an actual well path based on the series of trajectory well paths; deriving a deviation between the target well path and the actual well path; and adjusting the bottom hole assembly parameters and the surface parameters to maintain the deviation below a threshold.

Abstract: A method for simulating a well system can include providing a well system model, providing a jet pump model, providing at least one calculation engine, inputting an input parameter, defining a mechanical configuration of the well system, integrating a jet pump model into a well system model, computing a solution to a model, and determining at least one production condition of a well system. A computer readable medium can have instructions stored thereon that, when executed by a processor, can cause the processor to perform a method including accessing a well system model, accessing a jet pump model, integrating the jet pump model and the well system model, computing a solution to a combined model, and determining a production condition of a well system.

Abstract: A system provides thermal and stress analysis of complex well operations above the end of the downhole string to meet the analysis needs of downhole operations such as hydraulic fracturing in unconventional oil and gas field development.

Abstract: A method for simulating the effects of rupture disk failure on annular fluid expansion in sealed and open annuli to mitigate annular pressure buildup in a wellbore comprises the steps of: determining whether an internal region or an external region for a pair of casing string annuli is open; and calculating at least one of an adjusted internal annular pressure buildup and an adjusted external annular pressure buildup for at least one of the internal annular region and the external annular region of the casing string annuli.

Abstract: Systems and methods for determining vector-ratio safety factors for wellbore tubular design are provided. Pressure and temperature data for at least one load point along a tubular component of a wellbore are obtained. An effective failure axial load expected at the load point is calculated during a downhole operation to be performed along one or more sections of the wellbore within a subsurface formation, based on the obtained data. An upper boundary and a lower boundary for the effective failure axial load are determined, based on physical properties of the tubular component at the load point. A midpoint of the effective failure axial load is calculated based on the upper and lower boundaries. A critical failure differential pressure is calculated, based on the midpoint of the effective failure axial load. A vector-ratio safety factor is calculated, based on the critical failure differential pressure relative to the effective failure axial load.

Abstract: A method for estimating the wear of a drilling tool is disclosed. The method includes selecting a first incremental distance along a length of a formation. The method further includes determining a first characteristic of the formation along the first incremental distance. The method further includes deriving a first fractional wear factor, y1, for the drilling tool based on the first characteristic of the formation and a first operating condition of the cutting element. The method further includes calculating a first wear function, Wf1, the cutting element based on the first fractional wear factor and estimating an amount of wear of the cutting element during a drilling operation based on the first wear function.

Abstract: A method may include drilling a deviated wellbore penetrating a subterranean formation according to bottom hole assembly parameters and surface parameters; collecting real-time formation data during drilling; updating a model of the subterranean formation based on the real-time formation data and deriving formation properties therefrom; collecting survey data corresponding to a location of a drill bit in the subterranean formation; deriving a target well path for the drilling based on the model of the subterranean formation; deriving a series of trajectory well paths based on the formation properties, the survey data, the bottom hole assembly parameters, and the surface parameters and uncertainties associated therewith; deriving an actual well path based on the series of trajectory well paths; deriving a deviation between the target well path and the actual well path; and adjusting the bottom hole assembly parameters and the surface parameters to maintain the deviation below a threshold.

Abstract: Automated planning, control and/or geosteering assistance for a subterranean drilling operation is performed using an analytical drilling performance model that is a function of a rock brittleness index that is correlated with a corresponding formation property metric which serves as brittleness correlate and for which applicable measurement values are available from log data pertaining to the relevant formation. Correlation between the brittleness index and the brittleness correlate is such that a particular brittleness correlate value indicates a unique corresponding brittleness index value. One embodiment of the drilling performance model expresses rate of penetration as a function of a B4 brittleness index correlated with a sonic log brittleness correlate provided by pressure-wave velocity.

Abstract: Systems and methods for determining vector-ratio safety factors for wellbore tubular design are provided. Pressure and temperature data for at least one load point along a tubular component of a wellbore are obtained. An effective failure axial load expected at the load point is calculated during a downhole operation to be performed along one or more sections of the wellbore within a subsurface formation, based on the obtained data. An upper boundary and a lower boundary for the effective failure axial load are determined, based on physical properties of the tubular component at the load point. A midpoint of the effective failure axial load is calculated based on the upper and lower boundaries. A critical failure differential pressure is calculated, based on the midpoint of the effective failure axial load. A vector-ratio safety factor is calculated, based on the critical failure differential pressure relative to the effective failure axial load.

Abstract: A system provides thermal and stress analysis of complex well operations above the end of the downhole string to meet the analysis needs of downhole operations such as hydraulic fracturing in unconventional oil and gas field development.

Abstract: Systems and methods for simulating the effects of syntactic foam on annular pressure buildup during annular fluid expansion in a wellbore to mitigate annular pressure buildup in the wellbore.

Abstract: System and methods for simulating the effects of rupture disk failure on annular fluid expansion in sealed and open annuli to mitigate annular pressure buildup in a wellbore.

Abstract: A method includes obtaining a relative density of crude oil, and determining an effective molecular weight of the crude oil based on the obtained relative density. The method also includes calculating a crude oil viscosity value as a function of the effective molecular weight. The method also includes storing or displaying the crude oil viscosity value.

Abstract: A method for estimating the wear of a drilling tool is disclosed. The method includes selecting a first incremental distance along a length of a formation. The method further includes determining a first characteristic of the formation along the first incremental distance. The method further includes deriving a first fractional wear factor, y1, for the drilling tool based on the first characteristic of the formation and a first operating condition of the cutting element. The method further includes calculating a first wear function, Wf1, the cutting element based on the first fractional wear factor and estimating an amount of wear of the cutting element during a drilling operation based on the first wear function.

Abstract: Systems and methods for simulating the effects of syntactic foam on annular pressure buildup during annular fluid expansion in a wellbore to mitigate annular pressure buildup in the wellbore.

Abstract: The disclosed embodiments include a method, apparatus, and computer program product configured to performing automated downhole wellbore trajectory control for correcting between an actual wellbore trajectory path and a planned wellbore trajectory path. For example, in one embodiment, a PID controller is configured to obtain real-time data gathered during the drilling operation, determine whether the actual wellbore trajectory path deviates from the planned wellbore trajectory path, and automatically initiate the downhole wellbore trajectory control to change the actual wellbore trajectory path to a modified correction path that is determined using a minimum incremental wellbore energy method.

Abstract: A method for simulating a well system can include providing a well system model, providing a jet pump model, providing at least one calculation engine, inputting an input parameter, defining a mechanical configuration of the well system, integrating a jet pump model into a well system model, computing a solution to a model, and determining at least one production condition of a well system. A computer readable medium can have instructions stored thereon that, when executed by a processor, can cause the processor to perform a method including accessing a well system model, accessing a jet pump model, integrating the jet pump model and the well system model, computing a solution to a combined model, and determining a production condition of a well system.