A method may comprise measuring during a survey operation a gravitational field data using a survey accelerometer and magnetic field data using a survey magnetometer and determining during a drilling operation an azimuth of a wellbore based on the gravitational field data and the magnetic field data obtained during the survey operation. A system may comprise a drilling rig; a pipe string attached to the drilling rig; a bottom hole assembly attached to the pipe string, wherein the bottom hole assembly comprises at least one sensor; a drill bit, wherein the at least one sensor measure a revolutions-per-minute (RPM) of the drill bit; and a computing subsystem.

A method may comprise measuring during a survey operation a gravitational field data using a survey accelerometer and magnetic field data using a survey magnetometer and determining during a drilling operation an azimuth of a wellbore based on the gravitational field data and the magnetic field data obtained during the survey operation. A system may comprise a drilling rig; a pipe string attached to the drilling rig; a bottom hole assembly attached to the pipe string, wherein the bottom hole assembly comprises at least one sensor; a drill bit, wherein the at least one sensor measure a revolutions-per-minute (RPM) of the drill bit; and a computing subsystem.

Disclosed are an apparatus for measuring a position of a probe for an inclinometer, and a probe. The apparatus for measuring a position of a probe for an inclinometer comprises: a probe connection unit; a cable connection unit; a storage unit; a power supply unit; a magnetic field generator; a rotational number calculation unit, and a probe position calculation unit.

A depth positioning method to position a production logging tool (1) and a measurement log in a hydrocarbon well (3) in production obtained by means of the tool, the depth positioning method comprises: generating (S1, S2, S3, S1′, S2′, S3′, S11, S12, S13) a set of magnetic measurements (MAG1, MAG) of a depth portion of the hydrocarbon well from a first passive magnetic sensor along the depth portion of the hydrocarbon well, the set of magnetic measurements comprising magnitude and/or direction measurements of the magnetic field that forms a characteristic magnetic field pattern representative of a surrounding magnetic environment of the hydrocarbon well all along the depth portion; comparing (S4, S4′, S14) the set of magnetic measurements (MAG1, MAG) to another set of magnetic measurements (MAG_R, MAG2), the other set of magnetic measurements being a reference set of magnetic measurements generated either by a same or similar passive magnetic sensor deployed and run in the hydrocarbon well earlier, or by a second passive magnetic sensor spaced from the first passive magnetic sensor from a defined distance (DS) deployed and run in the hydrocarbon well simultaneously; and determining (S4, S4′, S14) the maximum of correlation between the set of magnetic measurements (MAG1, MAG) and the reference set of magnetic measurements (MAG_R, MAG2), the maximum being related to identifiable characteristic magnetic field pattern over a part of the depth portion.

A disclosed borehole curvature logging system includes: a drill string having a bottomhole assembly (BHA) with sensors providing actual deformation and bending moment measurements as a function of BHA position at spaced-apart intervals on the BHA; a processing system that retrieves said actual measurements and responsively generates a log of borehole curvature; and a user interface that displays the borehole curvature log. The processing system implements a method that generates the log by: providing an estimated borehole trajectory; deriving predicted deformation and bending moment measurements based on the estimated borehole trajectory; determining an error between the predicted measurements and the actual measurements; updating the estimated borehole trajectory to reduce the error; repeating said deriving, determining, and updating to refine the estimated borehole trajectory; and converting the estimated borehole trajectory into a borehole curvature log.

A disclosed borehole curvature logging system includes: a drill string having a bottomhole assembly (BHA) with sensors providing actual deformation and bending moment measurements as a function of BHA position at spaced-apart intervals on the BHA; a processing system that retrieves said actual measurements and responsively generates a log of borehole curvature; and a user interface that displays the borehole curvature log. The processing system implements a method that generates the log by: providing an estimated borehole trajectory; deriving predicted deformation and bending moment measurements based on the estimated borehole trajectory; determining an error between the predicted measurements and the actual measurements; updating the estimated borehole trajectory to reduce the error; repeating said deriving, determining, and updating to refine the estimated borehole trajectory; and converting the estimated borehole trajectory into a borehole curvature log.

A system and method for uncertainty estimation of reservoir parameters in unconventional reservoirs using a physics-guided convolutional neural network to generate a plurality of reservoir models, a data analysis step, and an uncertainty step is disclosed. The method is a computationally efficient method to estimate uncertainties in models of unconventional reservoirs.

A system and method for uncertainty estimation of reservoir parameters in unconventional reservoirs using a physics-guided convolutional neural network to generate a plurality of reservoir models, a data analysis step, and an uncertainty step is disclosed. The method is a computationally efficient method to estimate uncertainties in models of unconventional reservoirs.

Method for obtaining a directional survey in a rotating downhole component include acquiring and generating, while rotating, sets of raw data having 3-axis magnetic field data and 3-axis gravity field data. A set of rotationally-invariant data is obtained for each of the sets of raw data to generate a first number of sets of rotationally-invariant data. An earth property value is calculated from each of the sets. An accuracy indicator is estimated for each of the sets using a respective earth property value, an earth property reference value, and an error model, to generate a plurality of accuracy indicators. A set of mean values is determined using the plurality of sets of rotationally-invariant data using a second number of sets of rotationally-invariant data of the plurality of sets of rotationally-invariant data. The directional survey is estimated and used to control the downhole component.

Method for obtaining a directional survey in a rotating downhole component include acquiring and generating, while rotating, sets of raw data having 3-axis magnetic field data and 3-axis gravity field data. A set of rotationally-invariant data is obtained for each of the sets of raw data to generate a first number of sets of rotationally-invariant data. An earth property value is calculated from each of the sets. An accuracy indicator is estimated for each of the sets using a respective earth property value, an earth property reference value, and an error model, to generate a plurality of accuracy indicators. A set of mean values is determined using the plurality of sets of rotationally-invariant data using a second number of sets of rotationally-invariant data of the plurality of sets of rotationally-invariant data. The directional survey is estimated and used to control the downhole component.