Abstract: A method and system for determining cement bonding, or other materials attached to a pipe string. A well measurement system for determining cement bonding or other materials attached to a pipe string may comprise an acoustic logging tool, wherein the acoustic logging tool comprises at least one receiver and at least one transmitter. The well measurement system may further comprise an information handling system, wherein the information handling system is configured to broadcast a signal with the transmitter, record the reflected signal with a receiver; and determine an integrity of a cement using a Quintero Wellbore Index.

Abstract: A method for determining the presence and bonding characteristics of elements which may include cement which may be bonded to a pipe string. The method for determining the presence and bonding may comprise disposing an acoustic logging tool in a wellbore, wherein the acoustic logging tool comprises a transmitter and a receiver, broadcasting a pressure pulse with the transmitter into a first material, wherein the pressure pulse reflects off an interface of the first material and a pipe string as a reflected pressure pulse, recording the reflected pressure pulse with a receiver, and determining an integrity of a material using a Quintero Wellbore Index.

Abstract: Methods, systems, and computer program products for characterizing materials in a wellbore having multiple casing strings uses well completion data and instantaneous frequency, instantaneous phase, and/or amplitude attributes, including waveform amplitude or instantaneous amplitude, of an acoustic waveform to determine material densities, acoustic velocities and acoustic travel distances for the materials between the various stages of casings.

Abstract: Methods, systems, and computer program products for characterizing materials in a wellbore having multiple casing strings uses well completion data and instantaneous frequency, instantaneous phase, and/or amplitude attributes, including waveform amplitude and instantaneous amplitude, of an acoustic waveform to determine material densities, acoustic velocities and acoustic travel distances for the materials between the various stages of casings.

Abstract: A method and system for determining cement bonding, or other materials attached to a pipe string. A well measurement system for determining cement bonding or other materials attached to a pipe string may comprise an acoustic logging tool, wherein the acoustic logging tool comprises at least one receiver and at least one transmitter. The well measurement system may further comprise an information handling system, wherein the information handling system is configured to broadcast a signal with the transmitter, record the reflected signal with a receiver; and determine an integrity of a cement using a Quintero Wellbore Index.

Abstract: A method for determining the presence and bonding characteristics of elements which may include cement which may be bonded to a pipe string. The method for determining the presence and bonding may comprise disposing an acoustic logging tool in a wellbore, wherein the acoustic logging tool comprises a transmitter and a receiver, broadcasting a pressure pulse with the transmitter into a first material, wherein the pressure pulse reflects off an interface of the first material and a pipe string as a reflected pressure pulse, recording the reflected pressure pulse with a receiver, and determining an integrity of a material using a Quintero Wellbore Index.

Abstract: Apparatus and methods to investigate a multiple nested conductive pipe structure can be implemented in a variety of applications. A pipe characterization tool obtains first measurements of multiple nested conductive pipes at a first time subsequent to placement of at least one of the multiple nested conductive pipes in a wellbore, and at a second time subsequent to the first time. Processing circuitry calculates a thickness change of the multiple nested conductive pipes between the first time and the second time and predicts future thickness based on this thickness change. Well treatment decisions can be made based on predicted future thickness. Additional apparatus, systems, and methods are disclosed.

Abstract: A distance of a water flow path and a velocity of the water flow are calculated using data obtained from both a pulsed neutron sensor and distributed acoustic sensors. The two distance and velocity values are compared to obtain a first calculated distance and velocity. The distance of the water flow path and the velocity of the water flow are calculated using the Doppler data obtained from distributed Doppler sensors. The distance and velocity values are compared with the first calculated distance and first calculated velocity to obtain a second calculated distance and velocity values. The distance of the water flow path and the velocity of the water flow are calculated using temperature data obtained from distributed temperature sensors. The distance and velocity values are compared with the second calculated distance and velocity to determine a distance of a cement interface, and a velocity of a water flow therein.

Abstract: A disclosed pressure determination method for tight gas formations includes: obtaining a downhole core sample of a tight gas formation penetrated by a borehole, the core sample having been sealed in a pressure-maintaining core vault during transport out of the borehole; determining an effective pore space of the core sample; deriving the number of moles of gas retrieved with the core sample; and combining the effective pore space and the number of moles together with a downhole temperature to get an estimated formation pressure. A system embodiment includes: a core vault that provides pressure-preserved transport of a core sample from a tight gas formation; a collection chamber that attaches to the core vault to measure volumes of liquid and gas fluids from the core sample; and a processing unit that determines an estimated formation pressure based on said volumes, a downhole temperature, and an effective pore space of the core sample.

Abstract: A disclosed effective porosity determination method for tight gas formations includes: obtaining a core sample sealed in a pressure-maintaining core vault during transport out of the borehole; coupling the core vault to a collection chamber; based at least in part on measured pressure, temperature, and fluid volumes in the collection chamber, deriving the number of moles of gas retrieved with the core sample; and combining the number of moles with a downhole pressure, a downhole temperature, and a downhole core sample volume to determine an effective porosity of the tight gas formation. A system embodiment includes: a coring tool having a core vault with a seal to provide pressure-preserved transport of a core sample from a tight gas formation; a collection chamber that attaches to the core vault to measure volumes of fluids and gas; and a processing unit that responsively determines an effective porosity of the tight gas formation.

Abstract: Sonic data, ultrasonic data, density data, cased-hole neutron data, and open-hole neutron data of the wellbore are obtained. The sonic and ultrasonic data provides the amplitude, frequency, and phase of the altered sonic and ultrasonic waves. The far counts, near counts, and energy spectrum are obtained from density data, cased-hole (CH) neutron data, and open-hole (OH) neutron data. The amplitude, frequency, and phase provide the interface densities of the first, second, and third interfaces. The hydrogen index (HI) of the formation and the cased wellbore are obtained from the CH and OH neutron data. The widths of the second and third interfaces are obtained from the HI's and the densities of the second and third interfaces.

Abstract: A disclosed pressure determination method for tight gas formations includes: obtaining a downhole core sample of a tight gas formation penetrated by a borehole, the core sample having been sealed in a pressure-maintaining core vault during transport out of the borehole; determining an effective pore space of the core sample; deriving the number of moles of gas retrieved with the core sample; and combining the effective pore space and the number of moles together with a downhole temperature to get an estimated formation pressure. A system embodiment includes: a core vault that provides pressure-preserved transport of a core sample from a tight gas formation; a collection chamber that attaches to the core vault to measure volumes of fluids and gas from the core sample; and a processing unit that determines an estimated formation pressure based on said volumes, a downhole temperature, and an effective pore space of the core sample.

Abstract: A disclosed effective porosity determination method for tight gas formations includes: obtaining a core sample sealed in a pressure-maintaining core vault during transport out of the borehole; coupling the core vault to a collection chamber; based at least in part on measured pressure, temperature, and fluid volumes in the collection chamber, deriving the number of moles of gas retrieved with the core sample; and combining the number of moles with a downhole pressure, a downhole temperature, and a downhole core sample volume to determine an effective porosity of the tight gas formation. A system embodiment includes: a coring tool having a core vault with a seal to provide pressure-preserved transport of a core sample from a tight gas formation; a collection chamber that attaches to the core vault to measure volumes of fluids and gas; and a processing unit that responsively determines an effective porosity of the tight gas formation.

Abstract: Sonic data, ultrasonic data, and density data of the annulus are obtained using a sonic tool, an ultrasonic tool, and a density tool, respectively, included in a tool string. A first deconvolution operation is performed to obtain an amplitude, a frequency, and a phase of the modified sonic wave. A first inverse modeling operation results in a first density value of the annular media. A second deconvolution operation is performed to obtain an amplitude, a frequency, and a phase of the modified ultrasonic wave. A second inverse modeling operation results in a second density value of the annular media. A third deconvolution operation is performed to obtain far counts, near counts, and an energy spectrum of gamma rays. A third inverse modeling operation results in a third density value of the annular media.

Abstract: A distance of a water flow path and a velocity of the water flow are calculated using data obtained from both a pulsed neutron sensor and distributed acoustic sensors. The two distance and velocity values are compared to obtain a first calculated distance and velocity. The distance of the water flow path and the velocity of the water flow are calculated using the Doppler data obtained from distributed Doppler sensors. The distance and velocity values are compared with the first calculated distance and first calculated velocity to obtain a second calculated distance and velocity values. The distance of the water flow path and the velocity of the water flow are calculated using temperature data obtained from distributed temperature sensors. The distance and velocity values are compared with the second calculated distance and velocity to determine a distance of a cement interface, and a velocity of a water flow therein.

Abstract: A distance of a water flow path and a velocity of the water flow is calculated using data obtained from both a pulsed neutron sensor and distributed acoustic sensors. The two distance and velocity values are compared to obtain a first calculated distance and velocity. The distance of the water flow path and the velocity of the water flow are calculated using the Doppler data obtained from distributed Doppler sensors. The distance and velocity values are compared with the first calculated distance and first calculated velocity to obtain a second calculated distance and velocity values. The distance of the water flow path and the velocity of the water flow are calculated using temperature data obtained from distributed temperature sensors. The distance and velocity values are compared with the second calculated distance and velocity to determine a distance of a cement interface, and a velocity of a water flow therein.

Abstract: A distance of a water flow path and a velocity of the water flow is calculated using pulsed neutron data and noise data. The two distance and velocity values are compared with each other to obtain a first calculated distance and a first calculated velocity. The distance of the water flow path and the velocity of the water flow are calculated using Doppler data. The distance and velocity values are compared with the first calculated distance and first calculated velocity to obtain a second calculated distance and velocity values. The distance of the water flow path and the velocity of the water flow are calculated using temperature data. The distance and velocity values are compared with the second calculated distance and velocity to determine a distance of a cement interface and a velocity of a water flow in the cement interface.

Abstract: A gas presence and distance thereof are calculated using pulsed neutron data. A distance of a gas flow path and a velocity of the gas flow therein are calculated using distributed acoustic sensors. The gas saturation and distance, and gas velocity and distance obtained from the noise data are correlated to obtain a first calculated distance and velocity values. The distance and the velocity of the gas flow are calculated using distributed Doppler sensors. The distance and velocity values are compared with the first calculated distance and velocity values to obtain a second calculated distance and velocity values. The distance of the gas flow and the velocity of the gas flow are calculated using distributed temperature sensors. The distance and velocity values are compared with the second calculated distance and velocity values to determine a distance of a cement interface, and a velocity of a gas flow therein.

Abstract: A gas presence and distance thereof are calculated using pulsed neutron data. A distance of a gas flow path and a velocity of the gas flow therein are calculated using distributed acoustic sensors. The gas saturation and distance, and gas velocity and distance obtained from the noise data are correlated to obtain a first calculated distance and velocity values. The distance and the velocity of the gas flow are calculated using distributed Doppler sensors. The distance and velocity values are compared with the first calculated distance and velocity values to obtain a second calculated distance and velocity values. The distance of the gas flow and the velocity of the gas flow are calculated using distributed temperature sensors. The distance and velocity values are compared with the second calculated distance and velocity values to determine a distance of a cement interface, and a velocity of a gas flow therein.

Abstract: A distance of a gas flow path and a velocity of the gas flow therein are calculated using pulsed neutron data and noise data. The gas saturation and distance to flow path obtained from the pulsed neutron data and gas velocity and distance to flow path obtained from the noise data are compared with each other to obtain a first calculated distance and a first calculated velocity. The distance and the velocity of the gas flow are calculated using Doppler data. The distance and velocity values are compared with the first calculated distance and first calculated velocity to obtain a second calculated distance and velocity values. The distance and the velocity of the gas flow are calculated using temperature data. The distance and velocity values are compared with the second calculated distance and velocity to determine a distance of a cement interface and a velocity of a gas flow therein.