Abstract: 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.

Abstract: A method for determining properties of hydraulic fractures from measurements of pressure in a well made after stopping pumping fracturing fluid into the well (shut in) includes determining a first time after shut in whereinafter a decrease in measured pressure is caused by fluid leak off in a fracture. A second time after shut in is determined whereinafter the decrease in pressure is caused by fluid leak off, fracture growth and fluid pressure equilibration in the fracture. A third time after shut in is determined whereinafter the decrease in pressure is caused by fluid leak off, fracture growth, fluid pressure equilibration in the fracture and pressure drop in a near wellbore zone. Values of fluid efficiency, minimum stress and net pressure which are determined result in a calculated pressure with respect to time matching the pressure measurements within a predetermined threshold.

Abstract: A method for determining flowing fluid pressure loss in a well includes moving fluid through a well pipe and perforations in a well pipe at a first rate. A pressure of the fluid moving at the first rate is measured. The rate of moving fluid is changed to a second rate. The rate is changed so as to induce tube waves in the well. Pressure of the fluid moving at the second rate is measured. The measured pressures are used to determine frictional fluid pressure loss in the well pipe and frictional and fluid pressure loss through the perforations. The measured pressures and determined frictional fluid pressure losses are used to determine a fluid pressure outside the perforations.

Abstract: 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.

Abstract: 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.

Abstract: A method for detecting operating anomalies during hydraulic fracturing includes inducing tube waves in a well during pumping a hydraulic fracture treatment. At least one of pressure and time derivative of pressure in the well is measured. The measured at least one of pressure and time derivative of pressure is transformed into the cepstrum domain. An operational anomaly is detected by determining a change in cepstral quefrency corresponding to a two-way travel time of the tube waves and resonances in the well.

Abstract: 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.

Abstract: A method to measure fracture length and geometry/complexity from pressure decay and diffusion and near wellbore conductivity measurements with far-field conductivity estimates.

Abstract: 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.

Abstract: 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.

Abstract: 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 is used to guide RF energy to where that energy is convened to heat in the hydrocarbon bearing strata. The three dimensional underground electromagnetic array 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 legs of the three-dimensional underground electromagnetic array are composed of production well pipe.

Abstract: 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.

Abstract: An embodiment of an apparatus for estimating properties of an earth formation includes a carrier configured to be deployed in a borehole in the earth formation, a nuclear magnetic resonance (NMR) measurement device including a transmitting assembly configured to emit a pulse sequence into a region of a sedimentary earth formation, a receiving assembly configured to detect NMR signals in response to the pulse sequence, and a processor configured to receive the NMR signals and estimate one or more mechanical properties of the region. The processor is configured to perform calculating a size distribution based on the NMR signals, the size distribution including at least one of a pore size distribution and a grain size distribution in the region, estimating a strength of the region based on the size distribution, and performing one or more aspects of an energy industry operation based on the strength.

Abstract: 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.

Abstract: 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.

Abstract: 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.

Abstract: 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.

Abstract: 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.

Abstract: 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.

Abstract: 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.