Abstract: A method for producing an opaque polymeric film comprises: (a) extruding a base layer comprising a polymeric matrix and at least one cavitating agent; (b) coextruding at least one additional layer on at least one side of the base layer; (c) cooling the coextruded multi-layer film; and then (d) orienting the film in at least the machine direction (MD); wherein at least said base layer contains polybutylene terephthalate (PBT) and polycarbonate.

Abstract: A laminated multilayer film substrate for use in the production of banknotes having an oriented polypropylene core layer and at least one high density polyethylene layer on each side of the oriented polypropylene layer. The core layer may contain microcavities formed by the addition of a cavitating agent. The outer surfaces of the multilayer film substrate are coated with one or more epoxy layers, filed or unfilled, and one or more antistatic layers. The resultant films exhibit good embossability, dead-fold characteristics and other properties, making them highly suited for the production of bank notes and other security documents.

Abstract: The invention discloses methods of improving blocking resistant properties and reducing the coefficient of friction of a multilayer film comprising providing at least one layer of an ethylene-propylene impact copolymer having from about 3% to about 30% by weight ethylene, wherein said copolymer has no more than two peaks in the melting curve within the range from about 110° C. to about 165° C., and wherein said layer is non-heat sealable, to a multilayer film having a core layer comprising polypropylene, high density polyethylene (HDPE) or linear low density polyethylene (LLDPE), whereby anti-blocking and coefficient of friction characteristics of said film is improved without necessity of adding an antiblock or slip agent.

Abstract: A process for constructing a three-dimensional geologic model of a subsurface earth volume in which the positions of geologic interfaces within the model are adjusted as the model is being constructed. The resulting geologic model should be consistent with all available geologic and geophysical information regarding the subsurface earth volume, including information regarding the spatial attributes of geologic interfaces within said subsurface earth volume.

Abstract: The present invention relates to multilayer laminates having controlled directional tearing in both the machine direction (MD) and the transverse direction (TD). It is desirable to have controlled tearing for use in connection with pouches or other packages having a reclose device. The laminate is made up of a biaxially oriented inner layer containing linear low density polyethylene (LLDPE) and having a tensile elongation to break of less than 200% in the MD and less than 150% in the TD, an outer layer having a heat distortion temperature of at least 10° C. higher than the inner layer and a tensile longation to break of less than 200% in the MD and less than 150% in the TD, and an adhesive layer containing an adhesive polymer sandwiched between the inner and outer layers and adhering the two layers to each other.

Abstract: A method for controlled-amplitude prestack time migration of seismic data traces. According to the inventive method, common-offset gathers of the prestack seismic data traces are 3-D Fourier transformed from the space-time domain to a preselected alternate data domain, such as the frequency-wavenumber domain, the wavenumber-time domain, or the slant-stack domain. A migration operator that substantially preserves the seismic amplitudes of the original data traces is computed in the {right arrow over (p)}−z domain. This migration operator is applied to the transformed data traces in the alternate data domain, an imaging condition is applied, and the resulting migrated data traces are then transformed back to the space domain.

Abstract: A method of sparse hyperbolic inversion is used to suppress multiples in marine seismic data. By explicitly including the two-way water-bottom reflection traveltime and water-bottom reflection coefficient as part of an augmented model domain, the inversion may be successfully carried out even for intermediate water depths and sloping water bottoms. Linear noises can also be suppressed by appropriate definition of the model. The invention also has the capability of handling time-varying wavelets or several different wavelets simultaneously. This latter capability is useful in suppressing dispersive ground roll on land seismic data.

Abstract: The disclosed invention provides a method for recovering hydrocarbons from a subterranean formation by injecting an emulsion, comprising oil and water, into the formation. More specifically, the emulsion is stabilized using undissolved solid particles, which are preferably at least partially oleophilic. The solids-stabilized emulsion may be used either as a drive fluid for displacing hydrocarbons from the formation or to produce a barrier for diverting flow of fluids in the formation. Such solid particles may be either formation solid particles (i.e., indigenous to the formation) or nonformation solid particles (i.e., obtained from outside the formation). Nonformation solid particles may either be naturally occurring or synthetic. Some preferred solids include clays, quartz, feldspar, gypsum, coal dust, asphaltenes, and polymers.

Abstract: A method for reconstructing a selected seismic wavefield at a designated common midpoint and offset location from a set of prestack seismic data traces. The method uses actual data traces from other common midpoint and offset locations to reconstruct the selected wavefield at the designated reconstruction location. The method may be used to reconstruct any selected wavefield, including both primary reflection wavefields and secondary wavefields such as water-bottom multiple wavefields, and may be used with both 2-D and 3-D seismic data. If the reconstructed wavefield is a secondary wavefield, it may be subtracted from the prestack seismic data traces to eliminate interference between wavefields. The method may also be used to reconstruct data from missing shots to avoid spatial aliasing problems in other data processing operations.

Abstract: A method for enhancing zero-phase seismic data traces so that subtle geologic features are easier to identify and interpret. In a first embodiment, the method comprises enhancing the amplitudes of at least the peaks and troughs in the zero-phase seismic data traces. This enhancement can be accomplished in a variety of ways. In a second embodiment, the negative second difference is calculated at each sample point along the zero-phase seismic data trace to enhance bends or kinks in the data, as well as peaks and troughs.

Abstract: The disclosed invention provides a method for recovering hydrocarbons from a subterranean formation by injecting an emulsion, comprising oil and water, into the formation. More specifically, the emulsion is stabilized using undissolved solid particles, which are preferably at least partially oleophilic. The solids-stabilized emulsion may be used either as a drive fluid for displacing hydrocarbons from the formation or to produce a barrier for diverting flow of fluids in the formation. Such solid particles may be either formation solid particles (i.e., indigenous to the formation) or nonformation solid particles (i.e., obtained from outside the formation). Nonformation solid particles may either be naturally occurring or synthetic. Some preferred solids include clays, quartz, feldspar, gypsum, coal dust, asphaltenes, and polymers.

Abstract: Apparatus and method for determining the location of the source of seismic energy around a well are provided. Multiple seismic receivers, each receiver having orthogonal seismic sensors, are axially spaced on a tool which is capable of sending real-time seismic signals to the surface. A method for calculating the location with respect to the receivers is also provided.

Abstract: The disclosed invention is a solids-stabilized emulsion and method for making same for use in recovering hydrocarbons from a subterranean formation. More specifically, the emulsion comprises oil and water and is stabilized using undissolved solid particles, which are preferably at least partially oleophilic. Carbon dioxide or another gas is added to the emulsion to adjust the emulsion's viscosity to the desired level. The solids-stabilized emulsion may be used either as a drive fluid for displacing hydrocarbons from the formation or to produce a barrier for diverting flow of fluids in the formation. Such solid particles may be either formation solid particles (i.e., indigenous to the formation) or nonformation solid particles (i.e., obtained from outside the formation). Nonformation solid particles may either be naturally occurring or synthetic. Some preferred solids include clays, quartz, feldspar, gypsum, coal dust, asphaltenes, and polymers.

Abstract: A method for quantitatively measuring lateral continuity at a specified subsurface location from seismic data. The seismic data trace nearest to the specified location is designated as the reference trace. Next, all data traces falling within a specified distance from the reference trace are extracted from the data, and one or more statistics which measure the similarity between each trace and the reference trace are calculated. Only the portions of the traces falling within the target formation are considered. Preferably, the statistics should permit comparison of both the temporal and atemporal behaviors of the traces. The results are compared to objective significance tests to determine whether each trace is the same as or different from the reference trace.

Abstract: A method for analyzing seismic intervals and predicting subsurface petrophysical properties through the use of a new set of attributes known as Linear Shape Attributes (LSAs). The Linear Shapes form an orthogonal basis set derived directly from the seismic data traces for the interval in question. Collectively, the LSAs capture substantially all of the useful information contained in the input data set. The input data set may include all or a selected portion of the seismic data traces for the prospect. Petrophysical information obtained from well logs and/or pseudo-well logs may be used to calibrate the LSAs. The calibrated LSAs may then be used for a variety of purposes, such as predicting subsurface petrophysical properties at other locations or determining the location of a new well.

Abstract: Features of subsurface earth reservoirs of interest are made available for analysis and evaluation by forming three-dimensional, geologic block models based on field data. The field data include geological observations, such as lithofacies and porosity values obtained from well data and other sources, as well as geophysical data, usually from seismic surveys. The geologic models representative of subsurface reservoirs so obtained are optimized to match as closely as feasible geologic constraints known or derived from observed geologic data. The models also conform to geophysically based constraints indicated by seismic survey data. The modeled geologic lithofacies and porosity are converted into acoustic velocity and bulk density values, which are then formulated as a seismic response which is then compared with actual seismic data.

Abstract: A method for attenuating source-generated surface wavetrains in a set of seismic data traces. According to the method, the seismic data traces are Fourier transformed with respect to time to determine the frequency components of the surface wavetrain. A phase matching operation is then performed using estimates of the wavenumbers for each of the frequency components to approximately align the surface wavetrain in the seismic data traces. Next, a spatial low-pass filter is used to remove the approximately aligned surface wavetrain. Finally, the phase matching is removed and an inverse Fourier transformation is performed to return the seismic data traces to the time domain.

Abstract: A method for deriving reservoir lithology and fluid content for a target location from pre-stack seismic reflection data. The method uses inversion of pre-stack seismic reflection data for both the target location and a calibration location having known subsurface lithology and fluid content to derive the subsurface lithology and fluid content at the target location. The inversion process is preferably a viscoelastic inversion to account for the effects of friction on seismic wave propagation. The results of the inversion process are a set of subsurface elastic parameters for both the target and calibration locations. Relative magnitudes of these subsurface elastic parameters are compared, together with the known subsurface lithology and fluid content at the calibration location, to derive the subsurface lithology and fluid content at the target location.

Abstract: A method and apparatus are disclosed for detecting seismic waves and electromagnetic waves at the same location in making geophysical measurements. A seismic wave is generated at a first location and the seismic wave and electromagnetic waves generated by said seismic wave are detected at a spaced-apart second location. The seismic wave may be detected by a single apparatus that also detects the magnetic field. Alternatively, the seismic wave may be detected by two spaced-apart apparatus that also measures the magnetic field at the two spaced-apart locations as well as measuring the electric field between the two apparatus.

Abstract: A method for removing non-geologic amplitude variations from seismic data. The method is based on the premise that lateral amplitude variations with spatial wavelengths shorter than the width of the Fresnel zone, a known wave propagation effect, for the target cannot be caused by changes in the reflectivity of the target and must, therefore, be due to non-geologic causes. The method permits these non-geologic amplitude effects to be identified and removed from the seismic data. The method may be implemented either manually or automatically by a computer.