The disclosure presents processes that utilize collected resistivity data, for example, from an ultra-deep resistivity tool located downhole a borehole. In some aspects, each slice of resistivity data can generate multiple distribution curves that can be overlaid offset resistivity logs. In some aspects, an analysis can be performed to identify trends in the distribution curves that can be used to identify approximate locations of subterranean formation surfaces, shoulder beds, obstacles, proximate boreholes, and other borehole and geological characteristics. As the number of distribution curves generated increase, the confidence in the analysis also increases. In some aspects, the number of distribution curves can be twenty, one hundred, one hundred and one, or other counts of distribution curves. In some aspects, the resistivity data can be used to generate two or more synchronized view perspectives of a specific location along the borehole, where each view perspective uses the same focus area.

The disclosure presents processes that utilize collected resistivity data, for example, from an ultra-deep resistivity tool located downhole a borehole. In some aspects, each slice of resistivity data can generate multiple distribution curves that can be overlaid offset resistivity logs. In some aspects, an analysis can be performed to identify trends in the distribution curves that can be used to identify approximate locations of subterranean formation surfaces, shoulder beds, obstacles, proximate boreholes, and other borehole and geological characteristics. As the number of distribution curves generated increase, the confidence in the analysis also increases. In some aspects, the number of distribution curves can be twenty, one hundred, one hundred and one, or other counts of distribution curves. In some aspects, the resistivity data can be used to generate two or more synchronized view perspectives of a specific location along the borehole, where each view perspective uses the same focus area.

The disclosure presents processes that utilize collected resistivity data, for example, from an ultra-deep resistivity tool located downhole a borehole. In some aspects, each slice of resistivity data can generate multiple distribution curves that can be overlaid offset resistivity logs. In some aspects, an analysis can be performed to identify trends in the distribution curves that can be used to identify approximate locations of subterranean formation surfaces, shoulder beds, obstacles, proximate boreholes, and other borehole and geological characteristics. As the number of distribution curves generated increase, the confidence in the analysis also increases. In some aspects, the number of distribution curves can be twenty, one hundred, one hundred and one, or other counts of distribution curves. In some aspects, the resistivity data can be used to generate two or more synchronized view perspectives of a specific location along the borehole, where each view perspective uses the same focus area.

A method includes obtaining total stresses and pore pressures of each porous medium of a formation, determining a first and second set of effective stresses for the formation, determining an individual collapse and fracturing mud weight for each porous medium of the formation using a first set of associated failure criteria, wherein the first set of associated failure criteria are based on the first set of effective stresses, determining an overall collapse and fracturing mud weight for the formation using a second set of associated failure criteria, wherein the second set of associated failure criteria is based on the second set of effective stresses, determining a mud weight window for the formation using the individual collapse mud weight, the individual fracturing mud weight, the overall collapse mud weight, and the overall fracturing mud weight, and transmitting a command to a drilling system based on the mud weight window.

A method includes obtaining total stresses and pore pressures of each porous medium of a formation, determining a first and second set of effective stresses for the formation, determining an individual collapse and fracturing mud weight for each porous medium of the formation using a first set of associated failure criteria, wherein the first set of associated failure criteria are based on the first set of effective stresses, determining an overall collapse and fracturing mud weight for the formation using a second set of associated failure criteria, wherein the second set of associated failure criteria is based on the second set of effective stresses, determining a mud weight window for the formation using the individual collapse mud weight, the individual fracturing mud weight, the overall collapse mud weight, and the overall fracturing mud weight, and transmitting a command to a drilling system based on the mud weight window.

A method includes installing a measurement device on the injection wellhead, injecting a fluid into the injection well at a plurality of injection rates using a computer processor, measuring an injection bottom hole pressure at each injection rate to determine a plurality of injection bottom hole pressures using the computer processor, determining a relationship between the plurality of injection rates and the plurality of injection bottom hole pressures using the computer processor, and determining an injectivity index of the injection well using the relationship and the computer processor.

A method includes imaging, at an imaging resolution, a core of a subsurface formation to create a core image and iteratively performing the following operations until a defined feature of a rock of the subsurface formation exceeds a viewable image feature threshold: extracting a number of subsamples from the core for a first iteration and from each of the number of subsamples previously extracted for a subsequent iteration; increasing the imaging resolution; and imaging each subsample. The method includes performing the following operations for the subsamples last extracted: determining at least one formation property characteristic; determining a guiding rock property for each voxel of the core image and the number of subsample images; and determining a subsample that is a shortest distance to the voxel based on the number of guiding rock properties; and mapping, for each voxel, the at least one formation property characteristic that is the shortest distance.

This disclosure describes systems, methods, and apparatuses for preventing wireline sticking during hydraulic fracturing operations, the system comprising: a sensor coupled to a fracking wellhead, circulating fluid line, or standpipe of a well and configured to convert acoustic vibrations measured in fracking fluid in the wellhead, fluid line, or standpipe into an electrical signal in a time domain; a memory configured to store the electrical signal; a converter configured to access the electrical signal from the memory and convert the time domain electrical signal into a frequency domain spectrum; a machine-learning system configured to classify the current frequency domain spectrum as associated with increasing wireline friction, the machine-learning system trained on previous frequency domain spectra measured during previous wireline operations and previously classified by the machine-learning system; and a user interface configured to return an indication of the increasing wireline friction to an operator of the hydraulic fracturing operations.

A method of conducting a pressure integrity test for an underground formation includes: whilst fluid is supplied to and/or released and returned from the underground formation under pressure, using an automated monitoring and supervisory system to: monitor the pressure of the fluid being supplied to and/or returned from the underground formation in real-time, monitor a volume of the fluid that is supplied to and/or returned from the underground formation in real-time, determine one or more relationship(s) for the monitored pressure and the monitored volume as the pressure and the volume vary relative to each other and/or with time during the real-time monitoring thereof, and analyze the monitored pressure and volume data using the one or more relationship(s) either in real-time or after completion of the pressure integrity test in order to provide information and/or warnings concerning at least one parameter relating to the underground formation.

A hydrocarbon well includes a wellbore with a surface casing string that couples the wellbore to a wellhead located at the surface and a production casing string that extends through a reservoir within the subsurface. A fluid column is present within the wellbore. The hydrocarbon well also includes a high-frequency tube wave generator that is hydraulically coupled to the wellbore and is configured to generate high-frequency tube waves that propagate within the fluid column. The high-frequency tube waves include a selected waveform containing a specific bandwidth of high-frequency components. The hydrocarbon well further includes a receiver that is hydraulically coupled to the wellbore and is configured to record data corresponding to the generated and reflected high-frequency tube waves propagating within the fluid column, wherein the recorded data relate to characteristics of the wellbore. Moreover, such techniques may also be applied to a pipeline.