Abstract: Method for acquiring seismic data is described. The method includes determining a non-uniform optimal sampling design that includes a compressive sensing sampling grid. Placing a plurality of source lines or receiver lines at a non-uniform optimal line interval. Placing a plurality of receivers or nodes at a non-uniform optimal receiver interval. Towing a plurality of streamers attached to a vessel, wherein the plurality of streamers is spaced apart at non-uniform optimal intervals based on the compressive sensing sampling grid. Firing a plurality of shots from one or more seismic sources at non-uniform optimal shot intervals. Acquiring seismic data via the plurality of receivers or nodes.

Abstract: A method for 2D seismic data acquisition includes determining source-point seismic survey positions for a combined deep profile seismic data acquisition with a shallow profile seismic data acquisition wherein the source-point positions are based on non-uniform optimal sampling. A seismic data set is acquired with a first set of air-guns optimized for a deep-data seismic profile and the data set is acquired with a second set of air-guns optimized for a shallow-data seismic profile. The data are de-blended to obtain a deep 2D seismic dataset and a shallow 2D seismic dataset.

Abstract: A multi-stage inversion method for deblending seismic data includes: a) acquiring blended seismic data from a plurality of seismic sources; b) constructing an optimization model that includes the acquired blended seismic data and unblended seismic data; c) performing sparse inversion, via a computer processor, on the optimization model; d) estimating high-amplitude coherent energy from result of the performing sparse inversion in c); e) re-blending the estimated high-amplitude coherent energy; and f) computing blended data with an attenuated direct arrival energy.

Abstract: The present invention discloses systems and methods for attenuation of coherent environmental and source-generated noise in a continuously recorded domain of seismic survey testing. Rather than applying universal de-noising techniques to conventional gathers after source de-blending, the system and methods discussed herein focus on estimating and removing noise directly on continuous records by leveraging the noise characteristics in the domain of natural recording. Such techniques may equally be applied to coherent environmental and source-generated noises on seismic data as well as other data and noise types. Driven by the noise types encountered in the field, the methods of noise attenuation may be based upon time-frequency domain rank reduction techniques. Further, to model signal and/or noise, low-rank approximations are employed in conjunction with other techniques such as operator design and unsupervised learning.

Abstract: Disclosed are methods of marine 3D seismic data acquisition that do not require compensation for winds and currents.

Abstract: A silica-based stationary phase for chromatography columns and the methods of preparing such. More particularly, but not by way of limitation, a silica-based stationary phase that is substantially free of polyethers (e.g., polymer glycols). Also, a chromatography column comprising a silica-based stationary phase substantially free of polyethers (e.g., polymer glycols) within its channels as either a thin-film coating and/or a monolith and/or a monolithic coating. More particularly, a micro-electro-mechanical system (MEMS) chromatograph comprising a silica-based monolith substantially free of polyethers (e.g., polymer glycols) as the stationary phase within the micro-channels of the column.

Abstract: Various aspects described herein relate to a machine learning based signal recovery. In one example, a computer-implemented method of noise contaminated signal recovery includes receiving, at a server, a first signal including a first portion and a second portion, the first portion indicative of data collected by a plurality of sensors, the second portion representing noise; performing a first denoising process on the first signal to filter out the noise to yield a first denoised signal; applying a machine learning model to determine a residual signal indicative of a difference between the first signal and the first denoised signal; and determining a second signal by adding the residual signal to the first denoised signal, the second signal comprising (i) signals of the first portion with higher magnitudes than the noise in the second portion, and (ii) signals of the first portion having lower magnitudes than the noise in the second portion.

Abstract: Method for acquiring seismic data is described. The method includes determining a non-uniform optimal sampling design that includes a compressive sensing sampling grid. Placing a plurality of source lines or receiver lines at a non-uniform optimal line interval. Placing a plurality of receivers or nodes at a non-uniform optimal receiver interval. Towing a plurality of streamers attached to a vessel, wherein the plurality of streamers is spaced apart at non-uniform optimal intervals based on the compressive sensing sampling grid. Firing a plurality of shots from one or more seismic sources at non-uniform optimal shot intervals. Acquiring seismic data via the plurality of receivers or nodes.

Abstract: A simultaneous sources seismic acquisition method is described that introduces notch diversity to improve separating the unknown contributions of one or more sources from a commonly acquired set of wavefield signals while still allowing for optimal reconstruction properties in certain diamond-shaped regions. In particular, notch diversity is obtained by heteroscale encoding.

Abstract: A method for separating the unknown contributions of two or more sources from a commonly acquired set of wavefield signals representing a wavefield where the contributions from different sources are both encoded by means of the principles of signal apparition and as well as by means of different source encoding techniques.

Abstract: Methods for separating the unknown contributions of two or more sources from a commonly acquired set of wavefield signals based on varying parameters at the firing time, location and/or depth of the individual sources in a lateral 2D plane.

Abstract: Methods for separating the unknown contributions of two or more sources from a commonly acquired set of wavefield signals based on varying parameters at the firing time, location and/or depth of the individual sources in a lateral 2D plane.

Abstract: A method of monitoring the drilling of a wellbore having a drilling fluid that circulates in the wellbore during drilling, comprises: Extracting a plurality of gaseous compounds from a sample of drilling fluid exiting the wellbore, Measuring a quantity y(i) of at least a group of compounds, each group comprises comprising at least one extracted gaseous compound, Determining, from the measured quantity y(i) and an extraction coefficient ?(i) associated to each group, the content x(i) of each group of gaseous compounds present in the sample of drilling fluid, Deriving a drilling indicator from the content x(i) of at least one group of gaseous compounds.

Abstract: A mud gas analyzer and a well-site system using the mud gas analyzer are described. The mud gas analyzer includes at least one degasser adapted to extract gas from drilling mud passing through a flow path formed at least partially by a drill string within a well and an annulus positioned between an exterior surface of the drill string and a formation surrounding the well at a well-site, at least one gas analyzer adapted to interact with the gas extracted from the drilling mud. The gas analyzer determines an isotopic composition of a gas liberated from the drilling mud and generates a sequence of signals indicative of ratios of isotopes of a gas species liberated from the drilling mud.

Abstract: Safety device (10) for a fluid production well, comprising a valve (58) used to seal a passage, and which can move between an open position of the passage (52) and a closed position of the passage (52); and connecting biasing means (92) for permanently biasing the valve (58) towards the closed position thereof. The device comprises holding means (42) for holding the valve (58) in its open position against permanent biasing means (92), and actuating means (42, 44) which are configured to actuate the holding means (42), on reception of a maintenance signal, to generate: *a first displacement of the movement element (98) from the active valve biasing position to an intermediate valve biasing position, in which the valve (58) remains in its open position; and *a subsequent second return displacement of the movement element (58) from the intermediate valve biasing position to the active valve biasing position.

Abstract: The present disclosure concerns a method for detecting gain or loss of drilling fluid in a drilling installation, said drilling installation comprising a drilling pipe, drilling fluid pits and a hydraulic connection between the pits and the drilling pipe.

Abstract: Gas-extraction device (152) for extracting at least one gas contained in a drilling mud, the device comprising: —an enclosure (162), —an equipment (164) for supplying the drilling mud to the enclosure (162), —an equipment (170) for introducing a carrier gas into the enclosure (62; 162), wherein the device comprises a flow regulator (204) able to regulate the flow rate of a gas flow containing at least carrier gas, and a pressure controller situated downstream of the enclosure (162) configured for locally setting a pressure lower than the pressure of the enclosure (162), wherein the flow, regulator (204) is interposed between the pressure controller and the enclosure (162).

Abstract: Levels of kerogen and bitumen are computed in a sample of rock from DRIFTS measurements on the sample. The DRIFTS spectrum of a rock sample is measured, resulting in an estimate of bitumen and kerogen. Bitumen is then washed from the rock and DRIFTS is re-measured, resulting in an estimate of kerogen. Bitumen quantity is calculated by subtracting the washed sampled results from first DRIFTS measurements.

Abstract: A device (118) for automatically calibrating an analyzer (112) used for mud gas or fluid logging, comprising: a cabinet (140) having a plurality of dedicated reception slots (144), each slot (144) being configured for the insertion of a canister (148) containing a known calibration mixture, the cabinet (140) containing: a main line (174) to be connected to the analyzer (112), a connection assembly able to selectively connect each reception slot (144) to the main line (174), a control unit (151) for controlling the connection assembly to successively connect at least two successive slots (144) to the main line (174).

Abstract: A method and system for prospecting for gas hydrates and gas hydrates over free gas is disclosed. The method includes using well log data to form a rock physics model to generate synthetic seismic representing hydrate and hydrate-over-gas models. Spectral decomposition is applied to the synthetic seismic and to field seismic from the prospecting area, forming low frequency narrow band data sets. From mapped potential sands in the field data, compare positive amplitude dominated event in the narrow band field data to the narrow band synthetics for gas hydrates. Compare negative amplitude dominated event in the narrow band field data to the narrow band synthetics for gas or gas hydrate-over gas. From these comparisons, perform modeling to determine saturation and thickness for hydrates and hydrates-over-gas.