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Houston, TX, United States

Apache Corporation is an American independent oil and gas corporation. It is headquartered in 1 Post Oak Central in the Uptown district of Houston, Texas.Apache has become a large multinational company, with regional offices and operations in the United States, Argentina, Australia, Canada, Egypt and UK North Sea.The company's proved reserves at year-end 2010 totaled 2.95 billion barrels of oil equivalent, roughly half oil and half natural gas. Wikipedia.

Smith T.M.,Apache Corporation
Leading Edge (Tulsa, OK) | Year: 2011

A quick scan of the SEG web site shows that the phrase "seismic petrophysics" has been used explicitly in the title of a paper or abstract six times, the earliest of which was by Williams et al. in 1996 ("The Hugoton cross-well survey; A direct look at stratigraphy, seismic petrophysics and shale anisotropy"). However, the first attempt at a definition and an expanded description of "seismic petrophysics" was published by Wayne Pennington in The Leading Edge in 1997 ("Seismic petrophysics: An applied science for reservoir geophysics"). He defines seismic petrophysics as follows: "⋯the purposeful application of rock physics theory, as calibrated by laboratory and well measurements, to the interpretation of seismic data⋯" © 2011 Society of Exploration Geophysicists.

Monk D.J.,Apache Corporation
Geophysics | Year: 2010

The concept of the Fresnel zone has been explored by many workers; most commonly, their work has involved examining the Fresnel zone in the limiting case of zero offset and constant velocity. I have examined the shape of the Fresnel zone for nonzero offset and in the situation of constant velocity gradient. Finite-offset Fresnel zones are not circular but are elliptical and may be many times larger than their zero-offset equivalents. My derivation takes a largely geometric approach, and I suggest a useful approximation for the dimension of the Fresnel zone parallel to the shot-receiver azimuth. The presence of a velocity gradient (velocity increasing with depth) in the subsurface leads to an expansion of the Fresnel zone to an area that is far larger than may be determined through a more usual straight-ray determination. © 2010 Society of Exploration Geophysicists.

Apache Corporation | Date: 2013-07-18

A wave glider system includes a float having geodetic navigation equipment for determining a geodetic position and heading thereof. The glider includes an umbilical cable connecting the float to a sub. The sub has wings operable to provide forward movement to the float when lifted and lowered by wave action on the surface of a body of water. At least one geophysical sensor streamer is coupled to the sub. The at least one geophysical sensor streamer has a directional sensor proximate a connection between the sub and one end of the at least one geophysical sensor streamer to measure an orientation of the streamer with respect to a heading of the float.

A method for detemining an optimum spacing of seismic energy sources based on mutual admittance includes deploying a plurality of seismic energy sources along a source line, separated by a selected spacing. Seismic receivers are deployed along a receiver line orthogonal to the source line. Seismic energy is simultaneously transmitted from each of the plurality of seismic energy sources while recording signals from the seismic receivers. The transmitting and recording of signals is repeated for a plurality of different spacings between the energy sources. Seismic energy in the recorded signals is determined in separate time windows selected to represent reflected body wave signal, and source generated ground roll noise, respectively. A signal-to-noise ratio with respect to the spacing of the seismic energy sources is calculated and the optimum spacing between energy sources is selected based on the signal-to-noise ratio.

A method for characterizing subsurface formations penetrated by a wellbore includes accepting as input to a computer measurements of a physical parameter of the formations made over a selected axial interval of the wellbore. At least one attribute of the measurements is determined from a change in the measurements over the selected axial interval. At least one characteristic of the formations in the selected axial interval using the at least one attribute.

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