Conocophillips Company

Shearwater Geoservices Software Inc.

Charles Clinton Mosher

Joel D Brewer

Peter M Eick

Chengbo Li

Frank D Janiszewski

Jun Cao

Laurence S Williams

Ge Jin

Baishali Roy

Kyle R Krueger

Robert G Keys

Ali Can Tura

Sam T Kaplan

Dana M Jurick

Frank P Filice

Yu Zhang

Herbert W Swan

Michael Paul Davidson

Feng Chen

Jianxing Hu

Roman Kazinnik

Aaron L Janssen

Ronnie B Darnell

Yunqing Shen

Zhengxue Li

Yong Ma

Bradley Bankhead

Jon Anderson

Jeffrey Malloy

Method for acquiring seismic data is described. The method includes obtaining undersampled seismic data acquired from a non-uniform sampling grid. Attenuating multiples from the undersampled seismic data.

Offshore application of non-uniform optimal sampling survey design

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.

Non-uniform optimal survey design principles

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.

Use NUOS technology to acquire optimized 2D data

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

3D seismic acquisition

Use nuos technology to acquire optimized 2D data

A workflow using techniques for improving signal-to-noise ratio and decreasing interferences for Low-Frequency Distributed Acoustic Sensing is described.

Low-frequency DAS SNR improvement

The invention relates to DAS observation has been proven to be useful for monitoring hydraulic fracturing operations. While published literature has shown focus on the high-frequency components (&#x3e;1 Hz) of the data, this invention discloses that much of the usable information may reside in the very low frequency band (0-50 milliHz). Due to the large volume of a DAS dataset, an efficient workflow has been developed to process the data by utilizing the parallel computing and the data storage. The processing approach enhances the signal while decreases the data size by 10000 times, thereby enabling easier consumption by other multi-disciplinary groups for further analysis and interpretation. The polarity changes as seen from the high signal to noise ratio (SNR) low frequency DAS images are currently being utilized for interpretation of completions efficiency monitoring in hydraulically stimulated wells.

Low frequency distributed acoustic sensing

Method and system for ongoing monitoring for underground structure at or near a production wellpad is provided. The system includes a sparse acquisition grid and utilizes information obtained from Rayleigh waves to monitor subsurface structures.

Surface wave tomography using sparse data acquisition

A method of monitoring hydraulic fracturing using DAS sensors in a treatment well and/or observation well is described. The raw data is transformed using a low pass filter (&#x2264;0.05 Hz) and down-sampled to show the signal as the stimulation progresses. The resulting data can be used to optimize the hydraulic fracturing or improve reservoir models for other reservoirs.

Hydraulic fracture monitoring by low-frequency das

Computer-implemented method for determining optimal sampling grid during seismic data reconstruction includes: a) constructing an optimization model, via a computing processor, given by min&#x2225;Su&#x2225;s.t. &#x2225;Ru&#x2212;b&#x2225;&#x2266;&#x3c3; wherein S is a discrete transform matrix, b is seismic data on an observed grid, u is seismic data on a reconstruction grid, and matrix R is a sampling operator; b) defining mutual coherence as wherein C is a constant, S is a cardinality of Su, m is proportional to number of seismic traces on the observed grid, and n is proportional to number of seismic traces on the reconstruction grid; c) deriving a mutual coherence proxy, wherein the mutual coherence proxy is a proxy for mutual coherence when S is over-complete and wherein the mutual coherence proxy is exactly the mutual coherence when S is a Fourier transform; and d) determining a sample grid r=arg min&#x3bc;(r).

Compressive sensing

The invention relates to continuously or near continuously acquiring seismic data where at least one pulse-type source is fired in a distinctive sequence to create a series of pulses and to create a continuous or near continuous rumble. In a preferred embodiment, a number of pulse-type seismic sources are arranged in an array and are fired in a distinctive loop of composite pulses where the returning wavefield is source separable based on the distinctive composite pulses. Firing the pulse-type sources creates an identifiable loop of identifiable composite pulses so that two or more marine seismic acquisition systems with pulse-type seismic sources can acquire seismic data concurrently, continuously or near continuously and the peak energy delivered into the water will be less, which will reduce the irritation of seismic data acquisition to marine life.

Continuous composite relatively adjusted pulse

The invention relates to seismic imaging where complex geologies are likely to create data that is confusing or ambiguous for a conventional matrix of acquisition source points and receiver locations. With some understanding of the geological substructure, the acquisition source points and receiver locations that optimize the imaging may be found by using a reciprocal two-way wave equation propagation method coupled with a quality geologic model. With this, the acquisition source points and receiver locations that optimize the imaging may be selected and used to better resolve the substructure and avoid the inclusion of data that obscures understanding of the substructure.

Growing community of inventors

Houston, TX, United States of America

Charles Clinton Mosher