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 when a clean fluid sample may be taken by the downhole fluid sampling tool from at least the pressure test operation and the pumpout operation, and acquiring the clean fluid sample from the wellbore. A system may comprise a downhole fluid sampling tool and an information handling machine. The downhole fluid sampling tool may further comprise one or more probes attached to the downhole fluid sampling tool, one or more stabilizers attached to the downhole fluid sampling tool, and a sensor placed in the downhole fluid sampling tool configured to measure drilling fluid filtrate.

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 data processing method, an image display driving method, a data processing device, a display panel and a computer-readable storage medium are provided. The data processing method includes: based on input RGB grayscale values, calculating a chromaticity coordinate of the input RGB grayscale values on a chromaticity diagram, in which the chromaticity diagram includes a white basic point; calculating to obtain intermediate grayscale values containing a white component, based on the input RGB grayscale values and according to a position relationship between the chromaticity coordinate and the white basic point; and adjusting the intermediate grayscale values to obtain output RGBW grayscale values.

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 and system for estimating clean fluid composition and properties. A method may comprise disposing a downhole fluid sampling tool into a wellbore, wherein the downhole fluid sampling tool comprises optical instrumentation, obtaining a fluid sample with the downhole fluid sampling tool, wherein the fluid sample comprises a reservoir fluid contaminated with a well fluid, identifying input parameters from at least one sensor response on the optical instrumentation, and predicting a clean fluid sample of the reservoir fluid using an asymptote of a dimensional reduction analysis and equation of state. A system may comprise a downhole fluid sampling tool and a processing unit. The downhole fluid sampling tool may further comprise an optical instrumentation operable to obtain fluid samples of a reservoir fluid contaminated with a well fluid while the downhole fluid sampling tool is disposed in a wellbore.

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: The present application provides a multiple primary color conversion method, including: determining color triangles according to color coordinates of a target color; computing grayscale components of l primary colors corresponding to the target color in the color triangles; in step S130, obtaining initial grayscales of l primary colors; in step S140, judging whether there is an overflow grayscale; if yes, then performing step S160, if no, then performing step S150; in step S150, adjusting initial brightness components corresponding to grayscale components of the same primary color as the overflow grayscale, computing grayscale components of l primary colors in color triangles including the primary color of the overflow grayscale, and performing steps S130 and S140; in step S160, determining the initial grayscales of l primary colors as grayscales of l primary colors of the target color.

Abstract: A method may include transforming optical responses for a fluid sample to a parameter space of a downhole tool. The optical responses are obtained using a first operational sensor and a second operational sensor of the downhole tool. Fluid models are applied in the parameter space of the downhole tool to the transformed optical responses to obtain density predictions of the fluid sample. The density predictions of the first operational sensor are matched to the density predictions of the second operational sensor based on optical parameters of the fluid models to obtain matched density predictions. A difference between the matched density predictions and measurements obtained from a densitometer is calculated, and a contamination index is estimated based on the difference.

Abstract: Fingerprints of data portions are distributed in a balanced manner across active controllers of a data storage system, and may be done so in such a manner that, when a new active controller is added to the system, fingerprint ownership and movement between pre-existing active controllers, and active controllers overall, is minimized When a new active controller is added to the system and fingerprints are redistributed, no fingerprint ownership may be re-assigned between pre-existing active controllers and no fingerprints may be moved between pre-existing active controllers, for example, between local memories of the active controller.

Abstract: The present disclosure provides an encoding method and an encoder for a (n, n(n?1), n?1) permutation group code in a communication modulation system, in which 2k k-length binary information sequences are mapped to 2k n-length permutation codeword signal points in a n-dimensional modulation constellation ?n. The constellation ?n with the coset characteristics is formed by selecting 2k n-length permutation codewords from n(n?1) permutation codewords of a code set Pn,xi of the (n, n(n?1), n?1) permutation group code based on coset partition. The constellation ?n is a coset code in which 2k1 cosets are included and each coset includes 2k2 permutation codewords, where k=k1+k2, and 2k?n(n?1). The present disclosure utilizes the coset characteristics to realize one-to-one correspondence mapping of the binary information sequence set to the permutation code constellation, so that the time complexity of executing the encoder is at most the linear complexity of the code length n.

Abstract: The disclosure discloses an algebraic decoding method and a decoder for a (n, n(n?1), n?1) permutation group code in a communication modulation system. The basic principle of the decoding method is: assuming that two code elements p(r1)=s1 and p(r2)=s2 can be correctly detected in a received real vector with a length of n, including their element values s1, s2 and position indices r1, r2 in the vector, an intermediate parameter w is determined by solving an equation (r1?r2)w=(s1?s2)(mod n); and each code element is calculated by w according to p(i)=(s1+(n?r1+i)w)(mod n), i=1, 2, . . . , n. The decoder is mainly composed of multiple n-dimensional registers, a w calculator, n code element calculators, and a code element buffer. In the disclosure, in a case where a receiver only correctly detects two code elements in a transmitted codeword with a length of n, the codeword can be correctly decoded by using the received information of the two code elements.

Abstract: The subject disclosure provides for a method of optical sensor calibration implemented with neural networks through machine learning to make real-time optical fluid answer product prediction adapt to optical signal variation of synthetic and actual sensor inputs integrated from multiple sources. Downhole real-time fluid analysis can be performed by monitoring the quality of the prediction with each type of input and determining which type of input generalizes better. The processor can bypass the less robust routine and deploy the more robust routine for remainder of the data prediction. Operational sensor data can be incorporated from a particular optical tool over multiple field jobs into an updated calibration when target fluid sample compositions and properties become available.

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.

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: Mutual-complementary modeling and testing methods are disclosed that can enable validated mapping from external oil and gas information sources to existing fluid optical databases through the use of forward and inverse neural networks. The forward neural networks use fluid compositional inputs to produce fluid principal spectroscopy components (PSC). The inverse neural networks apply PSC inputs to estimate fluid compositional outputs. The fluid compositional data from external sources can be tested through forward models first. The produced PSC outputs are then entered as inputs to inverse models to generate fluid compositional data. The degree of matching between reconstructed fluid compositions and the original testing data suggests which part of the new data can be integrated directly into the existing database as validated mapping. The applications of using PSC inputs to reconstruct infrared spectra and estimate oil-based-mud (OBM) contamination with endmember spectral fingerprints are also included.

Abstract: The disclosed embodiments include thin film multivariate optical element and detector combinations, thin film optical detectors, and downhole optical computing systems. In one embodiment, a thin film multivariate optical element and detector combination includes at least one layer of multivariate optical element having patterns that manipulate at least one spectrum of optical signals. The thin film multivariate optical element and detector combination also includes at least one layer of detector film that converts optical signals into electrical signals. The thin film optical detector further includes a substrate. The at least one layer of multivariate optical element and the at least one layer of detector film are deposited on the substrate.

Abstract: Provided are a gate drive circuit and a driving method thereof, a display panel and a display device. The gate drive circuit includes a first sub-circuit group and a second sub-circuit group. The first sub-circuit group can drive the mth row to the first row of pixels of the N rows of pixels in the display panel row by row, and the second sub-circuit group can drive the (m+1)th row to the Nth row of pixels row by row. In addition, m is greater than 1 and less than N.

Abstract: The present disclosure provides a dimming method for an LCD device. The LCD device includes a dimming screen and a display screen. The dimming screen is divided into N×M dimming areas, and the display screen is also divided into N×M display areas. N and M are respectively positive integers greater than or equal to 1. The dimming areas correspond to the display areas in a one-to-one relationship. The dimming method includes determining a regional eigenvalue of each of the dimming areas according to image data, determining a dimming brightness of each of the dimming areas according to each regional eigenvalue, and dimming each of the dimming areas according to each dimming brightness. The present disclosure also provides a dimming screen for use in the dimming method and an LCD device using the dimming method.

Abstract: A method may include collecting measurement data using a first operational sensor and a second operational sensor of a downhole tool, standardizing optical responses of each operational sensor to a master sensor in a tool parameter space to obtain a standardized master sensor response, transforming the standardized master sensor response to a synthetic parameter space response of the master sensor, applying a fluid model with the synthetic parameter space response of the master sensor to predict a fluid characteristic, comparing a first prediction obtained with the fluid model from the first operational sensor with a second prediction obtained with the fluid model from the second operational sensor, determining a fluid characteristic from the first prediction and the second prediction, and optimizing a well testing and sampling operation according to the fluid characteristic.

Abstract: Downhole tools for isolating and analyzing one or more gases include a gas separation assembly in fluid communication with a gas specific analyzer. The gas separation assembly includes a piston disposed within a housing and a separation volume defined between the piston and the housing. The piston is movable to separate a gas component and a liquid component from a downhole formation fluid within the separation volume. The gas specific analyzer is operable to measure one or more properties of the gas component. In some configurations, the gas specific analyzer is an optical assembly containing a light source, an optical detector, and a gas cell that contains an observation volume. The optical assembly is operable to measure one or more properties of the gas component within the observation volume via the light source and the optical detector.