Abstract: Methods and systems for determining one or more ion components. The method may include disposing a fluid sampling tool into a wellbore wherein the fluid sampling tool includes at least one probe to fluidly connect the fluid sampling tool to a formation in the wellbore, and at least one passageway that passes through the at least one probe and into the fluid sampling tool. The method may further comprise drawing a formation fluid, as a fluid sample, through the at least one probe and through the at least one passageway, and analyzing the fluid sample in the fluid sampling tool for one or more ion components.

Abstract: A method and system for correlating two or more logs. The method may include reviewing an openhole log to identify one or more depths within a wellbore for testing, disposing a fluid sampling tool into the wellbore, creating a correlation log with the fluid sampling tool, depth-matching the correlation log to the openhole log to create a relative shift table, and moving the fluid sampling tool to the one or more depths within the wellbore based at least in part on the relative shift table. The system may include a fluid sampling tool disposed in a wellbore to create a correlation log and an information handling system connected to the fluid sampling tool.

Abstract: A method and system for identifying a fluid within a subterranean formation. The method may comprise obtaining one or more pressure measurements at one or more depths with a downhole fluid sampling tool, forming a depth-pressure measurement set form the one or more pressure measurements, creating a solution novelty threshold from at least the depth-pressure measurement set, constraining a solution space with the solution novelty threshold, and finding a solution-space-inscribed simplex within the solution novelty threshold. The method may further comprise generating a simplicial decomposition for a convex hull of the solution-space-inscribed simplex up to the solution novelty threshold, identifying at least one inscribed simplex within the convex hull of the solution-space-inscribed simplex, determining a novel simplex interior with the at least one inscribed simplex, and forming a plurality of solutions with the novel simplex interior.

Abstract: Quality factors associated with formation pressure measurements at various depths in the geologic formation are determined based on one or more well logs of formation properties in a geologic formation. A formation testing tool with two or more probes is positioned in a borehole of the geologic formation based on the quality factors. The two or more probes in the borehole perform respective formation pressure measurements, where each formation pressure measurement is performed at a different depth. The formation pressure measurements and the given distance between the two or more probes indicate a formation pressure gradient.

Abstract: A method comprises receiving a measurement of a pressure in a subsurface formation at a number of depths in a wellbore formed in the subsurface formation across a sampling depth range of the subsurface formation to generate a number of pressure-depth measurement pairs and partitioning the sampling depth range into a number of fluid depth ranges. The method comprises performing a fitting operation over each of the number of fluid depth ranges to determine a fluid gradient for the type of the reservoir fluid for each of the number of fluid depth ranges. The method comprises generating a solution set of one or more solutions based on the fluid gradient of the reservoir fluid for each of the number of fluid depth ranges determined from performing the fitting operation, wherein each solution defines a partitioning of the sampling depth range and the fluid gradient of each fluid depth range.

Abstract: A system to determine a contamination level of a formation fluid, the system including a formation tester tool to be positioned in a borehole, wherein the borehole has a mixture of the formation fluid and a drilling fluid and the formation tester tool includes a sensor to detect time series measurements from a plurality of sensor channels. The system includes a processor to dimensionally reduce the time series measurements to generate a set of reduced measurement scores in a multi-dimensional measurement space and determine an end member in the multi-dimensional measurement space based on the set of reduced measurement scores, wherein the end member comprises a position in the multi-dimensional measurement space that corresponds with a predetermined fluid concentration. The processor also determines the contamination level of the formation fluid at a time point based the set of reduced measurement scores and the end member.

Abstract: The disclosure belongs to the technical field of liquid crystal materials, and specifically relates to a polymerizable compound, a preparation method therefor, and the use thereof. The polymerizable compound has a structure as shown in general formula I. Compared with the existing polymerizable RM, the polymerizable compound has the advantages of a good solubility, a faster polymerization rate, a more complete extent of polymerization, and less residues, thereby improving the problem of poor display to a great extent.

Abstract: A method and system for identifying a fluid sample. The method may comprise disposing a fluid sampling tool into a wellbore. The fluid sampling tool may comprise at least one probe configured to fluidly connect the fluid sampling tool to a formation in the wellbore and at least one passageway that passes through the at least one probe and into the fluid sampling tool. The method may further comprise drawing a wellbore fluid as a fluid sample through the at least one probe and through the at least one passageway, obtaining a fluid measurement of the fluid sample, comparing the fluid measurement to a plurality of fingerprints that populate a database, and identifying the fluid sample based at least in part on one of the plurality of fingerprints.

Abstract: A tunnel automatic monitoring and measuring equipment and method based on fixed-point tour measurement are provided. The equipment includes a monitoring trolley that can move freely in the longitudinal direction of the tunnel, multiple automatic tracking and identification devices are set on the monitoring trolley, the automatic tracking and identification device is connected to the background processing system telecommunication; a monitoring points with reflective markings are arranged on the surface of the tunnel support structure, under the cooperation of the monitoring trolley and the automatic tracking and identification device, the reflective markings set on the tunnel support structure can be automatically measured at the fixed point to obtain the coordinate information of the relevant monitoring points; then, the deformation data of the support structure required in the construction process are extracted by coordinate information calculation.

Abstract: A method includes obtaining a plurality of master sensor responses with a master sensor in a set of training fluids and obtaining node sensor responses in the set of training fluids. A linear correlation between a compensated master data set and a node data set is then found for a set of training fluids and generating node sensor responses in a tool parameter space from the compensated master data set on a set of application fluids. A reverse transformation is obtained based on the node sensor responses in a complete set of calibration fluids. The reverse transformation converts each node sensor response from a tool parameter space to the synthetic parameter space and uses transformed data as inputs of various fluid predictive models to obtain fluid characteristics. The method includes modifying operation parameters of a drilling or a well testing and sampling system according to the fluid characteristics.

Abstract: Light from a light source that has interacted with a sample of downhole fluid provided in a downhole optical tool is sequentially passed through a plurality of groups of light filters, each of the groups of light filters including of one or more light filters, to generate a data set for each of the groups of light filters, also referred to as a simultaneous channel group. The data generated for each of the simultaneous channel groups is then analyzed to determine if the data from that simultaneous channel groups is effective in providing information useful for the analysis of the sample of downhole fluid.

Abstract: A method comprises receiving a measurement of a pressure in a subsurface formation at a number of depths in a wellbore formed in the subsurface formation across a sampling depth range of the subsurface formation to generate a number of pressure-depth measurement pairs and partitioning the sampling depth range into a number of fluid depth ranges. The method comprises performing a fitting operation over each of the number of fluid depth ranges to determine a fluid gradient for the type of the reservoir fluid for each of the number of fluid depth ranges. The method comprises generating a solution set of one or more solutions based on the fluid gradient of the reservoir fluid for each of the number of fluid depth ranges determined from performing the fitting operation, wherein each solution defines a partitioning of the sampling depth range and the fluid gradient of each fluid depth range.

Abstract: A method may comprise forming a data matrix, extracting chromatographs of a mud filtrate and a formation fluid, extracting concentration profiles of the mud filtrate and the formation fluid, and decomposing a data set on an information handling machine using a bilinear model. A system may comprise a downhole fluid sampling tool and an information handling tool. The downhole fluid sampling tool may comprise one or more multi-chamber sections, one or more fluid module sections, one or more gas chromatographers, wherein the one or more gas chromatographers are disposed in the one or more fluid module sections, and an information handling system.

Abstract: A method and system for performing a pressure test. The method may include inserting a formation testing tool into a wellbore to a first location within the wellbore based at least in part on a figure of merit. The formation testing tool may include at least one probe, a pump disposed within the formation testing tool and connect to the at least one probe by at least one probe channel and at least one fluid passageway, and at least one stabilizer disposed on the formation testing tool. The method may further include activating the at least one stabilizer, wherein the at least one stabilizer is activated into a surface of the wellbore and performing the pressure test and determining at least one formation property from the pressure test.

Abstract: A method includes receiving first material property data for a first material in one or more second materials, detecting material sensor data from at least one sensor, and applying an inverse model and a forward model to the first material property data to provide, at least in part, synthetic sensor measurement data for the one or more second materials.

Abstract: A method and system for determining fluid contamination. The method may comprise monitoring a fluid sample, wherein the fluid sample comprises a reservoir fluid contaminated with a well fluid, and obtaining input parameters, wherein the input parameters comprise fluid properties obtained from measurement of the fluid sample and mud filtrate composition. The method may further comprise representing a mud composition as a Gaussian distribution, selecting a plurality of input data during a pumpout, determining calculated fluid properties of the reservoir fluid using an equation of state filtrate analysis, and further obtaining updated values of iterative parameters for use in a mole fraction distribution function.

Abstract: The present invention provides an interpretable power load prediction method, system and terminal machine, relating to the field of power load prediction. The method comprises: initializing three factors—seasonal factor, trend factor, and smoothing factor, denoted as S1, T1, and I1 respectively; calculating states of the three factors for time t+1 in a current DeepES unit; outputting the three factors St+1, Tt+1, and It+1 to a next DeepES unit; repeating until a n-th DeepES unit completes its operation; calculating a predicted value Y based on the three factors that are outputted from a final DeepES unit. In power load prediction, constructing an interpretable prediction model enables users to understand the inference process of the model, therefore helps enhance the credibility of the model.

Abstract: Embodiments of a device, system and method are disclosed herein. In one embodiment, a device comprises a sample cell configured to interact a fluid sample with an ion selective substrate to modify an optical characteristic of the ion selective substrate according to an ion concentration of the fluid sample, wherein the sample cell is also configured to optically interact an illumination light with the ion selective substrate to generate a sample light; an optical element configured to interact with the sample light to provide a modified light that has a property of the fluid sample; and a detector that receives the modified light and provides an electrical signal proportional to the property of the fluid sample indicated by the modified light; and wherein the ion selective substrate comprises a membrane, the membrane configured to change an optical property in a selected wavelength range, according to the property of the fluid sample.

Abstract: A method includes identifying, by pre-set criteria, a first plurality of optical channels and a second plurality of optical channels using optical data generated from a plurality of optical filters of a tester tool. The method also includes determining, from the optical data, a first plurality of fluid types detected by each channel in the first plurality of optical channels using a bootstrap fluid identification technique and determining, from the optical data and the first plurality of fluid types, a second plurality of fluid types detected by each channel in the second plurality of optical channels using a guided fluid identification technique. Further, the method includes generating a spectral signature indicating fluid types for each channel within the tester tool based on the first plurality of fluid types and second plurality of fluid types.

Abstract: A method and system for identifying a fluid sample. The method may comprise disposing a fluid sampling tool into a wellbore. The fluid sampling tool may comprise at least one probe configured to fluidly connect the fluid sampling tool to a formation in the wellbore and at least one passageway that passes through the at least one probe and into the fluid sampling tool. The method may further comprise drawing a wellbore fluid as a fluid sample through the at least one probe and through the at least one passageway, obtaining a fluid measurement of the fluid sample, comparing the fluid measurement to a plurality of fingerprints that populate a database, and identifying the fluid sample based at least in part on one of the plurality of fingerprints.