Abstract: Fluid holdups within a downhole sampling tool are identified by comparing high- and low-resolution measurements of fluid samples.

Abstract: A method including generating integrated computational element (ICE) models and determining a sensor response as the projection of a convolved spectrum associated with a sample library with a plurality of transmission profiles determined from the ICE models. The method includes determining a regression vector based on a multilinear regression that targets a sample characteristic with the sensor response and the sample library and determine a plurality of regression coefficients in a linear combination of ICE transmission vectors that results in the regression vector. The method further includes determining a difference between the regression vector and an optimal regression vector. The method may also include modifying the ICE models when the difference is greater than a tolerance, and fabricating ICEs based on the ICE models when the difference is within the tolerance. A device and a system for optical analysis including multiple ICEs fabricated as above, are also provided.

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: The present disclosure is directed to systems and methods for synthesizing a spidroin. In some embodiments, the methods comprise synthesizing a monomer in vivo in a heterologous host, the monomer comprising an N-terminus IntC domain and a C-terminus IntN domain, and post-translationally polymerizing the synthesized monomer via in vitro split-intein mediated polymerization.

Abstract: A method and system for performing a pressure test. The method may comprise inserting a formation testing tool into a wellbore to a first location within the wellbore, identifying one or more tool parameters of the formation testing tool, performing a first pre-test with the pressure transducer when the pressure has stabilized to identify formation parameters, inputting the formation parameters and the one or more tool parameters into a forward model, changing the one or more tool parameters to a second set of tool parameters; performing a second pre-test with the second set of tool parameters; and comparing the first pre-test to the second pre-test. A system may comprise at least one probe, a pump disposed within the formation testing tool, at least one stabilizer, a pressure transducer disposed at least partially in the at least one fluid passageway, and an information handling system.

Abstract: The present disclosure provides a heat exchange system, air conditioning apparatus and control method for air conditioning apparatus. The heat exchange system including a compressor; a four-way valve; a first heat exchanger; a throttle device; a second heat exchanger; a fluid reservoir, including a first communication port and a second communication port, and the first communication port is communicated with the suction port, and the second communication port is communicated with one end of the second heat exchanger; a first valve body, being arranged on a flow path between the fluid reservoir and the compressor; a second valve body, being arranged on a flow path between the second communication port of the fluid reservoir and the throttle device; and a detection device, being used to detect the refrigerant amount for heat exchange cycle in the heat exchange system.

Abstract: A system comprising (i) thin film optical element comprising substrate and thin film stack (?2 film layers; uniform thickness—variation of less than ±5% in any 10 mm2 stack) deposited on substrate's first side; (ii) holder comprising at least one opening; wherein holder has inner side and outer side having beveled edge extending into lip having flat side and beveled edge side; wherein beveled edge/beveled edge side of lip form angle <45° with flat side of lip/first side; wherein flat side of lip and holder inner side define socket receiving substrate; wherein opening exposes first side to deposition plume; wherein first side contacts flat side of lip, thereby allowing film stack deposition on first side; wherein beveled edge side/beveled edge provide film uniformity, and (iii) deposition source providing plume traveling towards first side perpendicular to flat side of lip/first deposition side; and wherein beveled edge side faces plume.

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: 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 may comprise positioning a downhole fluid sampling tool into a wellbore; performing a pressure test operation within the wellbore; performing a pumpout operation within the wellbore; identifying one or more formation parameters at least in part from the at least one pressure test operation or the at least one pumpout operation; building a correlation model that relates a pumpout trend to the one or more formation parameters; determining a time when the downhole fluid sampling tool takes a clean fluid sample utilizing at least the correlation model; and acquiring the clean fluid sample with the downhole fluid sampling tool from the wellbore. Additionally, a system may comprise a downhole fluid sampling tool configured to: perform a pressure test operation within a wellbore; and perform a pumpout operation within the wellbore; and.

Abstract: A method and a system for measuring downhole fluid properties. The downhole fluid sampling tool may comprise at least one probe and at least one passageway that passes through the at least one probe and into the downhole sampling tool. The method may comprise drawing a wellbore fluid through the at least one probe and through the at least one passageway, obtaining a first channel measurement of the wellbore fluid, obtaining at least a second channel measurement, clustering channel data from a plurality of channel measurements comprising the first channel measurement and the at least second channel measurement, and measuring a phase through a plurality of channels. The method may further comprise separating a plurality of phase signals based on the phase measured through the plurality of channels, labeling the wellbore fluid, assigning the plurality of phase signals to specific phases of a multi-phase fluid, and estimating a fluid property.

Abstract: Embodiments of the present disclosure provide a method and system for training a model by using training data. The training data includes a plurality of samples, each sample includes N features, and features in the plurality of samples form N feature columns, and the method includes: determining an importance value of each of the N feature columns; determining whether the importance value of each of the N feature columns satisfies a threshold condition; performing a dimension reduction on M feature columns to generate P feature columns in response to the determination that the importance values of the M feature columns do not satisfy the threshold condition, wherein M<N and P<M; merging (N?M) feature columns having importance values that satisfy the threshold condition and the generated P feature columns to obtain (N?M+P) feature columns; and training the model based on the training data including the (N?M+P) feature columns.

Abstract: Disclosed herein are examples embodiments of a progressive modeling scheme to enhance optical sensor transformation networks using both in-field sensor measurements and simulation data. In one aspect, a method includes receiving optical sensor measurements generated by one or more downhole optical sensors in a wellbore; determining synthetic data for fluid characterization using an adaptive model and the optical sensor measurements; and applying the synthetic data to determine one or more physical properties of a fluid in the wellbore for which the optical sensor measurements are received.

Abstract: Disclosed are systems and methods for performing a contamination estimation of a downhole sample comprising at least a formation fluid and/or a filtrate. A plurality of downhole signals are obtained from the downhole sample and one or more of the signals are conditioned. At least two of the conditioned signals or downhole signals are fused into a multivariate dataset. From optical and density properties of the formation fluid and/or of the filtrate, a multivariate calculation is performed to generate concentration profiles of the formation fluid and the filtrate.

Abstract: An integrated computing element for an optical computing device includes a flexible optical substrate. The integrated computing element also includes at least one optical thin film deposited on a first surface of the flexible optical substrate. The at least one optical thin film is configured to selectively pass fractions of electromagnetic radiation at different wavelengths.

Abstract: A method includes receiving fluid property data of a fluid and receiving material property data for materials in the fluid. The method includes detecting material sensor data from at least one sensor and applying an inverse model and a forward model to the fluid property data and the material property data to provide at least in part synthetic spectral channel data for the materials.

Abstract: A downhole tool is positioned in a borehole of a geological formation at a given depth. A formation property is determined at the given depth. The positioning and determining is repeated to form data points of a data set indicative of formation properties at various depths in the borehole. One or more outlier data points is removed from the data set based on first gradients to form an updated data set. One or more properties associated with a reservoir compartment are determined based on second respective gradients associated with the updated data set.

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 present disclosure provides methods and an apparatuses for building a data identification model. One exemplary method for building a data identification model includes: performing logistic regression training using training samples to obtain a first model, the training samples comprising positive and negative samples; sampling the training samples proportionally to obtain a first training sample set; identifying the positive samples using the first model, and selecting a second training sample set from positive samples that have identification results after being identified using the first model; and performing Deep Neural Networks (DNN) training using the first training sample set and the second training sample set to obtain a final data identification model. The methods and the apparatuses of the present disclosure improve the stability of data identification models.

Abstract: A method comprises determining an adaptive fluid predictive model calibrated with a plurality of types of sensor data, wherein the plurality of types of sensor responses comprise a first type of sensor response associated with a synthetic parameter space and a second type of sensor response associated with a tool parameter space. The method comprises applying the adaptive fluid predictive model to one or more fluid samples from field measurements obtained from a tool deployed in a wellbore formed in a subterranean formation and determining a value of a fluid answer product prediction with the applied adaptive fluid predictive model. The method comprises facilitating a wellbore operation with the tool based on the value of the fluid answer product prediction.