Abstract:
Methods, systems, and devices for determining an acoustic parameter of a downhole fluid using an acoustic assembly. Methods include transmitting a plurality of pulses; measuring values for at least one wave property measured for reflections of the plurality of pulses received at at least one acoustic receiver, including: a first value for a first reflection traveling a first known distance from a first acoustically reflective surface having a first known acoustic impedance, a second value for a second reflection traveling a second known distance substantially the same as the first known distance from a second acoustically reflective surface having a second known acoustic impedance, and a third value for a third reflection traveling a third known distance from a third acoustically reflective surface having a third known acoustic impedance substantially the same as the second acoustic impedance; and estimating the acoustic parameter using the values.
Abstract:
In one aspect, the disclosure provides an apparatus that includes an acoustic transducer, and a backing coupled to the transducer, wherein the backing includes solid grains with fluid between the grains.
Abstract:
An electrode includes a structure comprising a porous material and an electrically-conductive liquid covering at least a portion of the porous material, wherein the electrode is configured to be immersed in fluids of interest, the electrically-conductive liquid being immiscible in the fluids of interest.
Abstract:
Systems and sensor elements for indirect monitoring of cumulative damage to downhole components having a sensor body defining an internal cavity, at least one electrical wear element located within the sensor body, wherein a portion of the at least one electrical wear element electrically extends from the internal cavity, through the sensor body, and to an exterior of the sensor body, and an abrasive substance located within the internal cavity, the abrasive substance moveable within the internal cavity to contact and erode material of the at least one electrical wear element, wherein erosion of the at least one electrical wear element causes a resistance of the at least one electrical wear element to increase.
Abstract:
An apparatus for sensing a chemical of interest in a fluid of interest includes: a tube permeable to the chemical of interest, having a polymer, and configured to be disposed into the fluid of interest; and a reactant disposed in a hollow portion of the tube and configured to react with the chemical of interest causing a change to transmissiveness of light. The apparatus further includes: a light source configured to illuminate the reactant; a photodetector configured to detect light traversing the reactant; a processor coupled to the photodetector and configured to determine a rate of change of detected light in response to the chemical of interest reacting with the reactant in order to sense the chemical of interest; and a reactant purging system in fluid communication with the hollow portion and configured to purge out pre-existing reactant present in the hollow portion with new unreacted reactant.
Abstract:
A fiber optic sensor to determine a property in an environment with a temperature exceeding 150 degrees Celsius includes a light source to emit broadband light, an etendue of the light source being less than 1000 square micro meter-steradians (μm2 sr), and an optical fiber to carry incident light based on the broadband light and a reflection resulting from the incident light. A photodetector detects a resultant light based on the reflection and outputs an electrical signal, and a processor processes the electrical signal from the photodetector to determine the property.
Abstract:
An in situ method of mining is disclosed. In one non-limiting embodiment, the method includes: defining an ore volume; drilling a large number of vertical boreholes; forming lateral boreholes from at least some of the vertical boreholes; transporting the ore cut during drilling of the vertical and lateral boreholes to a surface location; and separating the ore received at the surface from other materials. Additional ore may be extracted fracturing and/or leaching the formation surrounding the drilled boreholes. The residual ore at the surface may be disposed by pumping it into already drilled boreholes or underground storage facilities.
Abstract:
An apparatus for estimating an ambient environment at which inorganic scale will form in a downhole fluid includes a stress chamber disposed in a borehole in a production zone at a location within a specified range of maximum pressure and configured to receive a sample of the fluid from the production zone and to apply an ambient condition to the sample that causes the formation of inorganic scale. An inorganic scale sensor is configured to sense formation of inorganic scale within the chamber and an ambient environment sensor is configured to sense an ambient environment within the chamber at which the formation of inorganic scale occurs. The apparatus further includes a processor configured to receive measurement data from the inorganic scale sensor and the ambient environment sensor and to identify the ambient environment at which the formation of inorganic scale occurs.
Abstract:
An apparatus and method are described to estimate a fraction of carbon dioxide present in a downhole fluid. The apparatus includes a carrier configured to be conveyed through a borehole penetrating the earth. The apparatus also includes a pressure sensor disposed at the carrier and configured to measure an ambient pressure of the downhole fluid and an ambient temperature sensor disposed at the carrier and configured to measure a temperature of the downhole fluid. A processor of the apparatus receives the ambient pressure and the ambient temperature measurements and solves for the fraction of carbon dioxide in the downhole fluid using a correlation function with the ambient pressure and the ambient temperature as inputs to the correlation function.
Abstract:
An apparatus, method and computer-readable medium for detecting a gas influx event in a borehole fluid during a drilling operation is disclosed. A measurement of an acoustic velocity of the borehole fluid is obtained at an acoustic sensor disposed in a borehole. A measurement of temperature of the borehole fluid is obtained at a temperature sensor disposed in the borehole. A process compares the measurement of the acoustic velocity of the borehole fluid to the measurement of the temperature of the borehole fluid to detect the gas influx event.