A method to estimate and model all or at least two parameters of hydraulic fracture geometry in predominantly horizontal or nearly horizontal wells, by use of inter-well electromagnetic recordings. In aspects, resistivity of the fracturing fluid is used in the modeling process.

Methods and systems for quantifying an uncertainty in at least one porosity compaction model parameter are disclosed. The method includes obtaining a first sequence of depth-porosity duplets from a sedimentary layer and generating a plurality of alternate sequences of depth-porosity duplets based, at least in part, on resampling the first sequence. The method further includes estimating a plurality of values for the porosity compaction model parameter based on fitting a porosity compaction model to the first sequence and each alternate sequence. The method further includes quantifying the uncertainty in the porosity compaction model parameter based on determining the value of a parameter of probability density function fit to a histogram of the plurality of values for the porosity compaction model parameter.

Techniques for determining an operator position for a hydrocarbon production area include identifying an entity name; determining a plurality of land areas associated with the entity name based on at least one public data set, at least one of the land areas including a hydrocarbon-bearing land area; determining a position associated with the entity name for each of the plurality of land areas based on the at least one public data set and at least one private data set, the position including an operator position or a non-operator position; determining at least a portion of the plurality of land areas in which the determined position associated with the entity name includes the operator position; aggregating the determined portion of the plurality of land areas to generate an operator land area for the entity name; and generating a graphical representation of the generated operator land area to present to a user.

Techniques for determining an operator position for a hydrocarbon production area include identifying an entity name; determining a plurality of land areas associated with the entity name based on at least one public data set, at least one of the land areas including a hydrocarbon-bearing land area; determining a position associated with the entity name for each of the plurality of land areas based on the at least one public data set and at least one private data set, the position including an operator position or a non-operator position; determining at least a portion of the plurality of land areas in which the determined position associated with the entity name includes the operator position; aggregating the determined portion of the plurality of land areas to generate an operator land area for the entity name; and generating a graphical representation of the generated operator land area to present to a user.

An affixable device can include a locking mechanism, a force-limiting mechanism, and a sensing mechanism. The locking mechanism can include an engagement component configured to disable the locking mechanism. The force-limiting mechanism can be configured to limit a locking force of the locking mechanism. The sensing mechanism can be coupled to the engagement component, and can be configured to determine that the force-limiting mechanism has limited the locking force of the locking mechanism. In response to determining the force-limiting mechanism limiting the locking force, the sensing mechanism can cause the engagement component to disable the locking mechanism.

A system includes different types of downhole sensing tools deployed in a borehole, wherein the different types of downhole sensing tools are optimized to identify a downhole condition based on a predetermined downhole evaluation plan that accounts for sensing tool availability and performance constraints. The system also includes at least one processing unit configured to analyze measurements collected by the different types of downhole sensing tools, wherein the collected measurements are analyzed together to identify the downhole condition. The system also includes at least one device that performs an operation in response to the identified downhole condition.

A system includes different types of downhole sensing tools deployed in a borehole, wherein the different types of downhole sensing tools are optimized to identify a downhole condition based on a predetermined downhole evaluation plan that accounts for sensing tool availability and performance constraints. The system also includes at least one processing unit configured to analyze measurements collected by the different types of downhole sensing tools, wherein the collected measurements are analyzed together to identify the downhole condition. The system also includes at least one device that performs an operation in response to the identified downhole condition.

A system for drilling a wellbore into an earth formation includes a logging tool in the wellbore having at least one near-range measurement sensor, and a processor. The processor is configured to receive, at each depth along the wellbore, near-range measurement data and reference data related to a density of the formation, determine one or more near-range earth models that include a density model of a layer at each depth based on the near-range data constrained by the reference data, receive surface gravitational data from multiple surface locations, determine a mid-range or far-range formation model based on the near-range earth model and the surface gravitational data, and provide the mid-range or far-range formation model to a well driller for geosteering a drill bit into the earth formation.

Embodiments of the present disclosure provide a ferromagnetic object detection device and a method for detecting a tubing coupling. The ferromagnetic object detection device includes a support tube, a magnetic field generating device and a magnetic detection device. The support tube includes a space penetrating in a first direction; the magnetic field generating device is located on an outer sidewall of the support tube and configured to generate a magnetic field; the magnetic field detection device includes a first magnetic field detection element, a second magnetic field detection element and a third magnetic field detection element.

Embodiments of the present disclosure provide a ferromagnetic object detection device and a method for detecting a tubing coupling. The ferromagnetic object detection device includes a support tube, a magnetic field generating device and a magnetic detection device. The support tube includes a space penetrating in a first direction; the magnetic field generating device is located on an outer sidewall of the support tube and configured to generate a magnetic field; the magnetic field detection device includes a first magnetic field detection element, a second magnetic field detection element and a third magnetic field detection element.