Abstract: A method of predicting behavior of a drilling assembly includes: generating a mathematical representation of a geometry of each of a plurality of components of a drilling assembly, the plurality of components including a plurality of cutters and one or more additional components configured to at least one of: support the plurality of cutters and operably connect the plurality of cutters to the drill string, the one or more additional components including a drill bit crown; simulating one or more operating conditions incident on the drilling assembly representation, and simulating an interaction between the plurality of components and an earth formation; and predicting physical responses of the drilling assembly representation to the one or more conditions.

Abstract: A method of predicting behavior of a drilling assembly includes: generating a mathematical representation of a geometry of each of a plurality of components of a drilling assembly, the plurality of components including a plurality of cutters and one or more additional components configured to at least one of: support the plurality of cutters and operably connect the plurality of cutters to the drill string, the one or more additional components including a drill bit crown; simulating one or more operating conditions incident on the drilling assembly representation, and simulating an interaction between the plurality of components and an earth formation; and predicting physical responses of the drilling assembly representation to the one or more conditions.

Abstract: A method of predicting behavior of a drilling assembly includes: generating a mathematical representation of a geometry of each of a plurality of components of a drilling assembly, the plurality of components including a plurality of cutters and one or more additional components configured to at least one of: support the plurality of cutters and operably connect the plurality of cutters to the drill string, the one or more additional components including a drill bit crown; simulating one or more operating conditions incident on the drilling assembly representation, and simulating an interaction between the plurality of components and an earth formation; and predicting physical responses of the drilling assembly representation to the one or more conditions.

Abstract: A method for estimating an inclination and azimuth at a bottom of a borehole includes forming a last survey point including a last inclination and a last azimuth; receiving at a computing device bending moment and at least one of a bending toolface measurement and a near bit inclination measurement from one or more sensors in the borehole; and forming the estimate by comparing possible dogleg severity (DLS) values with the bending moment value.

Abstract: A method for estimating a steady state response of a drill string in a borehole includes calculating a first displacement of the drill string in a frequency domain for a first excitation force frequency and a number of multiples of this frequency using an equation of motion of the drill string. The equation of motion has a static force component, an excitation force component, and a non-linear force component with respect to at least one of a deflection and a derivative of the deflection of the drill string. The method further includes: transforming the first displacement from the frequency domain into a time domain; calculating a non-linear force in the time domain; calculating a frequency domain coefficient derived from the calculated non-linear force in the time domain; and calculating a second displacement of the drill string in the frequency domain using the equation of motion and the frequency domain coefficient.

Abstract: A method for estimating a steady state response of a drill string in a borehole includes calculating a first displacement of the drill string in a frequency domain for a first excitation force frequency and a number of multiples of this frequency using an equation of motion of the drill string. The equation of motion has a static force component, an excitation force component, and a non-linear force component with respect to at least one of a deflection and a derivative of the deflection of the drill string. The method further includes: transforming the first displacement from the frequency domain into a time domain; calculating a non-linear force in the time domain; calculating a frequency domain coefficient derived from the calculated non-linear force in the time domain; and calculating a second displacement of the drill string in the frequency domain using the equation of motion and the frequency domain coefficient.

Abstract: A system for estimating downhole parameters includes: at least one parameter sensor disposed along a downhole component and configured to measure a parameter of one or more of a borehole and an earth formation and generate parameter data; and a processor in operable communication with the at least one parameter sensor, the processor configured to receive the parameter data and deformation data relating to deformation of the downhole component. The processor is configured to: generate a mathematical model of the downhole component deformation in real time based on pre-selected geometrical data representing the downhole component and the received deformation data; estimate, in real time, an alignment of the at least one parameter sensor relative to at least one of another parameter sensor and a desired alignment; and in response to estimating a misalignment of the at least one parameter sensor, correct the parameter data based on the misalignment.

Abstract: A method of predicting behavior of a drilling assembly includes: generating a mathematical representation of a geometry of each of a plurality of components of a drilling assembly, the plurality of components including a plurality of cutters and one or more additional components configured to at least one of: support the plurality of cutters and operably connect the plurality of cutters to the drill string, the one or more additional components including a drill bit crown; simulating one or more operating conditions incident on the drilling assembly representation, and simulating an interaction between the plurality of components and an earth formation; and predicting physical responses of the drilling assembly representation to the one or more conditions.

Abstract: A method for estimating an inclination and azimuth at a bottom of a borehole includes forming a last survey point including a last inclination and a last azimuth; receiving at a computing device bending moment and at least one of a bending toolface measurement and a near bit inclination measurement from one or more sensors in the borehole; and forming the estimate by comparing possible dogleg severity (DLS) values with the bending moment value.

Abstract: A method for determining wellbore trajectory includes determining survey parameters in the wellbore; measuring force parameter(s) in the wellbore; and correcting the survey parameters using the measured force parameter(s). The downhole measured force parameters may include forces associated with an operation of a steering device such as an internal reaction force, and/or a bending moment. In variants, the method may include measuring a wellbore temperature; measuring a wellbore parameter in addition to the temperature; and correcting a survey parameter using the measured parameter and the measured temperature. These methods may include correcting survey parameters using measured wellbore diameters. Also, a processor in the wellbore may be programmed to perform the correction while in the wellbore and/or control a steering device using measurements provided by a sensor for measuring internal reaction forces.

Abstract: A method for determining wellbore trajectory includes determining survey parameters in the wellbore; measuring force parameter(s) in the wellbore; and correcting the survey parameters using the measured force parameter(s). The downhole measured force parameters may include forces associated with an operation of a steering device such as an internal reaction force, and/or a bending moment. In variants, the method may include measuring a wellbore temperature; measuring a wellbore parameter in addition to the temperature; and correcting a survey parameter using the measured parameter and the measured temperature. These methods may include correcting survey parameters using measured wellbore diameters. Also, a processor in the wellbore may be programmed to perform the correction while in the wellbore and/or control a steering device using measurements provided by a sensor for measuring internal reaction forces.