A method includes introducing into a drilling fluid a plurality of tags having a first clay nanoparticle and a first polymer embedded into the clay nanoparticle and circulating the drilling fluid and tags through a well during a drilling operation that creates formation cuttings such that the tags interact with the formation cuttings, creating tagged cuttings. The returned cuttings are collected from the circulating drilling fluid at a surface of the well, and the tags on the returned cuttings are detected to identify the tagged cuttings. The method also includes correlating the tagged cuttings with a drill depth in the well from the drilling operation.

This disclosure presents a process to determine characteristics of a subterranean formation proximate a borehole. Borehole material can be typically pumped from the borehole, though borehole material can be used within the borehole as well. Extracted material of interest can be collected from the borehole material and prepared for analyzation. Typically, the preparation can utilize various processes, for example, separation, filtering, moisture removal, pressure control, cleaning, and other preparation processes. The prepared extracted material can be placed in a photoacoustic device where measurements can be taken, such as a photoacoustic imager or a photoacoustic spectroscopy device. A photoacoustic analyzer can generate results utilizing the measurements, where the results of the extracted material can include one or more of fracture parameters, fracture plane parameters, permeability parameters, porosity parameters, and composition parameters. The results can be communicated to other systems and processes to be used as inputs.

Utilizing multiple rock cores samples obtained while drilling a well to determine the mechanical properties of the rock constituting the wellbore and formation zones within the wellbore. A geomechanical model is created from the samples by nanoindentation testing to provide the raw data from which the geomechanical model is then created.

Solid particles are colored with a cationic dye and at least three calibration standards having different known mass concentrations of the colored particles are prepared. A digital analysis of the images of the calibration standards is carried out based on an additive RGB color model and intensity distribution profiles of red, green and blue colors are obtained for each calibration standard. A single norm function is selected to characterize quantitatively changes in the red, green and blue colors in all calibration standards. A single calibration curve is obtained by comparing values of the selected norm function for each calibration standard with a known mass concentration of the colored particles in this calibration standard. A suspension of the colored solid particles is injected through a porous medium sample and the sample is split into two parts along a suspension flow direction. A digital analysis of an image of the split of the porous medium sample is carried out based on the additive RGB color model and a two-dimensional intensity distribution of red, green and blue colors in the sample split is obtained. Reference intensities of red, green and blue colors are determined and based on the obtained two-dimensional intensity distribution of red, green and blue colors in the obtained image of the sample split, using the reference intensities of red, green and blue colors, the selected norm function and the obtained calibration curve a two-dimensional distribution of the mass concentration of the colored suspension solid particles is determined.

A system for estimating a pore pressure value associated with a depth of a well subject to drilling operations may include a data repository for storing integrated mud gas and pore pressure data associated with one or more existing wells. The data repository may also store a machine learning (ML) engine. The system may also include one or more hardware processors configured to train a ML model using the ML engine and the integrated mud gas and pore pressure data, to estimate, during the drilling operations, the pore pressure value of a formation zone, at the depth of the well, using the trained ML model and mud gas data associated with a depth value that identifies the depth of the well subject to the drilling operations, and to update a drilling program for a production system based on the estimated pore pressure value.

Surface equipment of a cement analysis system (CAS) estimates a first drilling fluid slowness (FSLO) and a first drilling fluid acoustic impedance (ZMUD) based on a type and density of wellbore drilling fluid. A second FSLO is estimated based on a thickness and diameter of wellbore casing and transit time for energy emitted by a downhole tool to travel to and from the casing. An FSLO graphical interface is generated based on the first and second FSLO. A second ZMUD is estimated based on the drilling fluid type and density and one of the first and second FSLO selected utilizing the FSLO graphical interface. A ZMUD graphical interface is generated based on the first and second ZMUD. The downhole tool then obtains log data utilizing at least one parameter selected utilizing the ZMUD graphical interface. The log data includes a final ZMUD measured with respect to wellbore depth.

This disclosure presents a process and system to determine characteristics of a subterranean formation proximate a borehole. Borehole material is typically pumped from the borehole, though borehole material can be used within the borehole as well. Extracted material of interest is collected from the borehole material and prepared for analyzation. Typically, the preparation can be a separation process, a filtering process, a moisture removal process, a pressure control process, a flow control process, a cleaning process, and other preparation processes. The prepared extracted material is placed in a laser dispersion spectroscopy device (LDS) where measurements can be taken. A LDS analyzer can generate results utilizing the measurements, where the results of the extracted material can include one or more of composition parameters, alkene parameters, and signature change parameters. The results can be communicated to other systems and processes to be used as inputs into well site operation plans and decisions.

A probe for identifying and measuring volume fraction constituents of a fluid using time domain analysis and frequency domain analysis to identify individual volume fraction constituents within a pipe on a real time basis and to measure the volume of the individual volume fraction constituents flowing through the pipe on a real time basis.

A method includes taking at least one image of a plurality of returned cuttings from a well using a fluorescent imaging camera, analyzing the at least one image with an imaging processing system to obtain detection data including a calculated percentage of a first emitted fluorescent light to formation cuttings, sending the detection data to an analysis and control program to correlate the returned cuttings with a depth in the well, and automatically controlling at least one drilling parameter for drilling the well based on the detection data.

The disclosure presents processes and methods for utilizing one or more micro-services to generate a calibration of a factor of a borehole operation or to generate an optimization adjustment to the borehole operation. The micro-services selected for execution can be selected by an optimization workflow, where each type of borehole operation can have its own set of micro-services. The micro-services can be part of one or more computing systems, such as a downhole system, a surface system, a well site controller, a cloud service, a data center service, an edge computing system, other computing systems, or various combinations thereof. Also disclosed is a system for implementing micro-services on one or more computing systems to enable a light weight and fast response, e.g., real-time or near real-time response, to borehole operations.