Baker Hughes Corporation

Geomechanics International, Inc.

Baker Hughes, a Ge Compnay, LLC

Seismos Inc.

Other

Halliburton Energy Services, Inc.

Highland Light Management Corp

Baker Hughes Holdings LLC

Daniel Moos

Colleen A Barton

David A Castillo

Pavel Peska

Daniel T Georgi

Gamal A Hassan

Youli Quan

Chris Ward

Mark David Zoback

John Fabian

Ronald Glen Dusterhoft

Douglas J Patterson

Vladimir Dubinsky

John D Macpherson

Silviu Livescu

Xiao Ming Tang

Stefan Wessling

Yibing Zheng

Jakub Felkl

Junwei Zhang

Preston W Grounds, Iii

Stephan Dankers

Christopher R L Anderson

Donald Ritter

Martin Brudy

Eric M Dunham

Ibrahim Said Abou-Sayed

Hossein Davari Ardakani

Nicola Tisato

Christopher Rl Anderson

A method for determining change in stress in a reservoir formation includes inducing a pressure pulse in a first well hydraulically connected by a fracture to the reservoir formation. A stress-related attribute of the fracture is determined from reflection events detected in pressure measurement made in the first well as a result of the inducing the pressure pulse. The inducing and determining are repeated to estimate changes in the stress-related attribute with respect to time. A method for determining and localizing type of interaction between a treated well and an observation well by monitoring pressure and fracture changes in the observation well.

Method of measuring reservoir and fracture strains, crosswell fracture proximity and crosswell interactions

A method and a system to determine fracture properties during standard operations and injection tests. Fracture compliance, fracture closure pressure, and perforation friction can be determined using a combination of acoustic data, pressure decay data, and wellbore models. A method of automating and adjusting fracture design in real-time. A method and system to recover active, single active pulse data from a background noise dataset.

Determining fracture properties using injection and step-rate analysis, dynamic injection test analysis, extracting pulse-type source signals from noisy data, and measuring friction parameters in a well

A system and method are provided that use RF energy to enhance the extraction of oil and gas from hydrocarbon bearing strata. A three-dimensional underground electromagnetic array of coupled well pipe segments is used to guide RF energy to where that energy is converted to heat in the hydrocarbon bearing strata. The three dimensional underground electromagnetic array of coupled well pipe segments includes a switch to selectively activate coupled well pipe segments and is a guided wave structure, as opposed to an antenna structure, to minimize the unwanted effects of the near fields associated with antennas. In one embodiment, the leas of the three-dimensional underground electromagnetic array are composed of production well pipe.

System and method for electrically selectable dry fracture shale energy extraction

A system and method of applying periodic energy pulses to a portion of a wellbore, fracture(s), and/or near wellbore to interrogate and/or stimulate at least a portion of the wellbore, fracture(s), and/or near wellbore. The system includes a downhole device that is configured to deliver periodic energy pulses to a portion of the wellbore. The downhole device may deliver various energy pulses such as pressure waves, seismic waves, and/or acoustic waves. Sensors may determine properties of a portion of the wellbore and/or fracture based on energy pulses detected within the wellbore. The sensors may be connected to the downhole tool, may be positioned within the wellbore, and/or may be positioned at the surface. The magnitude and/or frequency of the periodic energy pulses may be varied to change the stimulation and/or interrogation of the wellbore.

System and method for using pressure pulses for fracture stimulation performance enhancement and evaluation

The present disclosure is related to methods and apparatuses for acoustic velocity well logging. The method may include estimating a magnitude of a principal horizontal stress in a borehole in a formation. The method may include obtaining a far field stress orientation and making a measurement of near borehole stress orientation. The present disclosure also includes an apparatus configured to be conveyed into a borehole and perform the method. Formation stresses and directions may be estimated.

Predicting hydraulic fracture propagation

A method of predicting a property of an earth formation includes: injecting a fluid into at least one pre-existing feature of the formation at a plurality of constant pressures or flow rates; measuring a response from the at least one pre-existing feature at each of the plurality of constant pressures or flow rates; and estimating at least one property of the at least one pre-existing feature based on the response. An apparatus for predicting a property of an earth formation is also disclosed.

Apparatus and method for predicting properties of earth formations

A method of processing data generated from an energy industry or oilfield operation includes: receiving a data set representing parameter values generated during at least a portion of the operation, the parameter values including values of a plurality of parameters relating to the operation; dividing the data set into a plurality of data subsets, each data subset including values for multiple parameters; determining a measure of similarity between data in each subset relative to data in one or more other subsets; displaying a map of the data set in at least two dimensions, the map including a visual representation of each subset positioned relative to a visual representation of the one or more other subsets based on the measure of similarity; and analyzing the map to estimate a condition associated with the operation.

System and method for well data analysis

A method for estimating a property of an earth formation penetrated by a borehole includes: performing a borehole integrity test at a pressure less than a fracture gradient pressure of the formation to provide leakage data; injecting a fluid into the formation at a first pressure greater than the fracture gradient pressure during a first injection time interval using a fluid injector; measuring pressure versus time using a pressure sensor and a timer during a first test time interval to provide first pressure data; injecting a fluid into the formation at a second flow rate greater than the first flow rate during a second injection time interval using the fluid injector; measuring pressure versus time using the pressure sensor and the timer during a second test time interval to provide second pressure data; and estimating the property using the first pressure data, the second pressure data, and the leakage data.

Natural fracture injection test

A method of processing parameter data includes: receiving at least one alarm value for a selected interval, the at least one alarm value generated based on a comparison of estimated parameter values at one or more respective interval points with limits at the respective interval points; performing, by a processor, a statistical analysis of the at least one alarm value over the selected interval; and generating an alarm indication associated with the selected interval, the alarm indication corresponding to a result of the statistical analysis.

System and method for generating profile-based alerts/alarms

A system, method and computer-readable medium for developing an earth formation is disclosed. A tool conveyed in a borehole induces a stress in the earth formation proximate a borehole. A sensor assembly obtains a measurement of a physical property of the borehole at a plurality of azimuthal locations in the borehole. The values of the physical property are indicative of the induced stress in the formation. A processor forms an image of the borehole using the obtained measurements of the physical property, estimates an azimuthal variation with borehole depth of the induced stress in the formation from the formed image, and alters an operational parameter of a device for developing the earth formation using the estimated azimuthal variation with depth of the induced stress in the formation.

System and method for stress field based wellbore steering

Stress in formations from azimuthal variation in acoustic and other properties

A method for modeling flow properties over a series of time increments of a reservoir in an earth formation having a plurality of fractures is disclosed. The method includes: building a three-dimensional stress field representing stresses in the reservoir; building a three-dimensional discrete fracture network (NFM) having fracture flow properties using information obtained from a tool or changes to the stress field; running a flow simulation of the reservoir for a time increment using the NFM to model the flow properties of the reservoir for that time increment; computing a latest change in the three-dimensional stress field from the flow simulation; and incrementing the time increment and iterating the building the NFM using the latest change in the stress field, the running of the flow simulation using the latest NFM, and the computing a latest change in the stress field from the latest running of the flow simulation.

Method to improve reservoir simulation and recovery from fractured reservoirs

A system and method for the geomechanical steering of the orientation of a wellbore is disclosed. In one embodiment, any available a priori data regarding the stress characteristics of a region of interest are used to develop a preliminary stress model for the region. A geosteered drilling operation is thereafter commenced, with the trajectory being steered in a direction relative to the stress model of the region. While drilling, real-time data is obtained from conventional down-hole instrumentation. The real-time data is used to refine the stress model for the region, such that the trajectory can be guided on an ongoing basis to achieve an optimal relationship with the measured stress characteristics of the region.

Cross-dipole measurements are obtained in a borehole. By estimating a direction of polarization of the fast shear mode at low and high frequencies and comparing the estimated distances, a cause of anisotropy is established. Formation stresses and directions may be estimated.

Identification of stress in formations using angles of fast and slow dipole waves in borehole acoustic logging

Pre-drill pore pressure and fracture gradient predictions obtained from seismic velocity data are used in well design taking into account uncertainties in the velocity estimation and in the models that use the velocities to determine pore pressure. Using geological constraints, limits are established on hydrocarbon column height. It is also possible to predict the relative number of casings required to reach target reservoirs.

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Palo Alto, CA, United States of America

Daniel Moos