Landmark Graphics Corporation

Other

Halliburton Energy Services, Inc.

Texaco Inc.

Kenneth E Williams

Amit Kumar

Ronald Glen Dusterhoft

Jianfu Ma

Sheldon Burt Gorell

Sheldon B Gorell

Michael Thomas Pelletier

Robert Paul Freese

Avi Lin

Gang Li

Richard Daniel Colvin

Travis S Ramsay

Mamdouh Abdel-Aal Shebl

Matt James Croy

Kevin E Williams

Ray M Jourdan

Systems and methods for generation of in-situ wellbore, core and cuttings information systems. An image and image derivative based property visualization, analysis and enhancement system is provided, which utilizes various types of image data, such as digital rock physics and physical laboratories, petrographic analysis and the in-situ wellbore imaging and derivative products of image segmentation in the construction of a static earth model.

In-situ wellbore, core and cuttings information system

Determining characteristics of a formation. At least some of the illustrative embodiments are methods including determining at least one characteristics of a shale formation. The determining may include: collecting optically interacted electromagnetic radiation from a portion of the shale formation; directing a first portion of the optically interacted electromagnetic radiation from the formation to a first multivariate optical element (MOE), the first MOE creates first modified electromagnetic radiation; applying the first modified electromagnetic radiation to a first detector, the first detector creates a first signal; and determining a first characteristic of the shale formation from the first signal.

Method and system of determining characteristics of a formation

Systems, methods, and software can be used to calculate fracture stratigraphy of a subterranean zone. In some aspects, microseismic event data associated with a fracture treatment of a subterranean zone are received, and the subterranean zone includes multiple subsurface layers. A filter is used to select a subset of the microseismic event data corresponding to fractures in a particular subsurface layer. Fracture stratigraphy is calculated for the particular subsurface layer from fracture planes associated with the selected subset of the microseismic event data.

Analyzing fracture stratigraphy

Modeling hydrocarbon flow, from layered shale formations. At least some of the illustrative embodiments are methods including: modeling movement of hydrocarbons through kerogen-related porosity, the movement through a first model volume; estimating a first permeability of a kerogen-rich layer of a layered shale formation based on the modeling; and modeling hydrocarbon production from the layered shale formation. The modeling hydrocarbon production may include: utilizing the first permeability for the kerogen-rich layer of the layered shale formation; and utilizing a second permeability for a kerogen-poor layer of the layered shale formation, the second permeability different than the first permeability. In various cases the modeling of hydrocarbon production is with respect to a second model volume greater than the first model volume.

Methods and systems of modeling hydrocarbon flow from layered shale formations

Modeling hydrocarbon flow from kerogens in a hydrocarbon bearing formation. At least some of the illustrative embodiments are methods including modeling flow of hydrocarbons through a hydrocarbon bearing formation by: obtaining an indication of kerogen-wet porosity of kerogen within a portion of the formation; obtaining an indication of water-wet porosity within the portion of the formation; modeling hydrocarbon movement through the kerogen-wet porosity; and modeling hydrocarbon movement through the water-wet porosity.

Methods and systems of modeling hydrocarbon flow from kerogens in a hydrocarbon bearing formation

Optimizing well planning scenarios. At least some of the illustrating embodiments include: receiving, by a computer system, a complex fracture model that estimates fractures in a subsurface target; applying the complex fracture model to a reservoir model that estimates geological features between the subsurface target and earth's surface; and determining an earth surface well site and a well path from the earth surface well site to the subsurface target based on the complex fracture model and the geological information, wherein the earth surface well site is offset from the subsurface target.

Methods and systems for well planning based on a complex fracture model

Systems and methods for hydraulic fracture characterization using microseismic event data to identify the orientation spacing and dip for subsurface fractures.

Systems and methods for hydraulic fracture characterization using microseismic event data

A method and apparatus for determining a stress field in a subterranean formation include deploying a stress measurement tool on a tubular string, opening at least three fractures in three different radial directions in the subterranean formation, and closing the at least three fractures. The at least three fractures are reopened while measuring stress and strain conditions. From the reopening, a tangential stress component for each of the at least three fractures is determined. From the tangential stress components and radial directions of the at least three fractures, the stress field of the subterranean formation is determined.

Apparatus and measuring stress in a subterranean formation

The present invention relates to an automated pest control dust applicator device for remote applications, such as bug or bee or hornet spraying in high areas, e.g., trees, overhangs, porch roofs, dormers, eaves, etc. Thus, the automated pest control dust applicator device includes: an elongated support pole having a predetermined length and having a distal end and a proximal end; a dust dispensing nozzle located proximate the distal end of the pole, and connected to a dust reservoir; a conduit and a compressor, with appropriate controls. The dust reservoir is located at the distal end of the elongated support pole. The dust reservoir has an air inlet connected to the conduit, and has an outlet connected to the dust dispensing nozzle for dispersion of the dust. The conduit extends from the dust reservoir a substantial distance in length along the elongated support pole and is connected at its lower end to an air compressor. The automated pest control dust applicator device compressor is a portable compressor, and typically includes a rechargeable power source.

Automated pest control dust applicator device for remote applications

Monofrequency continuous wave signals of long duration are used as inputs form sources of known characteristics and location. These signals are reflected off subterranean features and serve to paint the features for display and evaluation. A primary feature is the use of continuous wave, long duration signals as opposed to the standard short pulse technique.

Method for seismic antenna illumination of subterranean feature for

A system for providing an indication of a glidepath for aircraft using a conventional altimeter having a graduated dial scale and a rotatable pointer includes a plurality of individual indicating lights spaced around the circumference of the dial which are individually controlled by an onboard microcomputer to provide a time dependent, moving indication of a descent rate on the dial scale corresponding to a safe, theoretical glidepath, which indication may be followed by the altimeter pointer to maintain the aircraft on the glidepath. The microcomputer includes a microprocessor control unit, a random access memory for temporary data storage and a read only memory for permanent storage of programmed instructions for computing the glidepath. A manually operable keyboard device permits entry of glidepath data regarding the aircraft's speed, position, etc. into the random access memory for storage therein prior to arrival of the aircraft at a position marking the start of the glidepath whereat the system may be activated by operation of a single push button to produce the visual moving indication of the descent rate corresponding to the desired glidepath.

Growing community of inventors

Houston, TX, United States of America

Kenneth E Williams