# US 9,519,073 B2 · Differential phase semblance apparatus, systems, and methods > Agents: this data is available as JSON from the patentgrep API and MCP server — see https://patentgrep.com/llms.txt - Number: US 9,519,073 B2 - Document ID: US9519073B2 - Status: Granted - Kind: B2 - Application number: 14/427,876 - Filed: 2012-11-01 - Published: 2015-09-10 - Granted: 2016-12-13 - Earliest claimed: 2012-11-01 - Assignees: Halliburton Energy Services, Inc. - Applicants: Halliburton Energy Services, Inc. - Inventors: Pradip Kumar Mukhopadhyay; Arthur Cheng - Web page: https://patentgrep.com/patent/US9519073B2 ## CPC - G01V 1/48: Processing data - G01V 1/24: Recording seismic data - G01V 1/32: Transforming one recording into another {or one representation into another} - G01V 1/325: {Transforming one representation into another} - G01V 1/184: {Multi-component geophones} - G01V 1/22: Transmitting seismic signals to recording or processing apparatus - G01V 1/34: Displaying seismic recordings {or visualisation of seismic data or attributes} - G01V 2200/16: Measure-while-drilling or logging-while-drilling - G01V 2210/1299: Subsurface, e.g. in borehole or below weathering layer or mud line - G01V 2210/1429: Subsurface, e.g. in borehole or below weathering layer or mud line - G01V 2210/43: Spectral - G01V 2210/48: Other transforms - G01V 2210/6222: Velocity; travel time - G01V: GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS (means for indicating the location of accidentally buried, e.g. snow-buried, persons A63B29/02) ## Abstract In some embodiments, apparatus and systems, as well as methods, may operate to shift signal data associated with a set of receivers, in time or phase with respect to signal data associated with a receiver reference point, to transform the signal data into shifted data, wherein the signal data corresponds to energy waves propagated through a geological formation before being received by the set of receivers; to multiply the shifted data by a complex conjugate of the signal data associated with the receiver reference point to provide differential phase values; to sum and average the differential phase values to provide differential phase semblance values; and to publish the differential phase semblance values, or information derived from the differential phase semblance values to one of a storage medium, a hardcopy printout, or a display. Additional apparatus, systems, and methods are disclosed. ## Claims ### Claim 1 An apparatus, comprising: a set of receivers arranged as azimuthally separated receiver arrays, each receiver array having front and back receivers to form sum and difference channels; logic to record raw signal data corresponding to energy waves propagated through a geological formation before being received by the set of receivers; and a signal processor to transform the raw signal data into signal data, to shift the signal data associated with the set of receivers in time or phase with respect to the signal data associated with a receiver reference point, to multiply the shifted data by a complex conjugate of the signal data associated with the receiver reference point to provide differential phase values associated with the set of receivers, and to sum and average the differential phase values over the set of receivers at each time of selected times for a given slowness or over the set of receivers at each frequency of selected frequencies for a given slowness to provide differential phase semblance values; and a device operable with the signal processor to publish a slowness time semblance image or a slowness frequency semblance image based on the differential phase semblance values, the device being one of a storage medium, a hardcopy printout device, or a display. ### Claim 2 (depends on 1) The apparatus of claim 1, wherein the apparatus includes a set of transmitters to generate the energy waves in the geological formation. ### Claim 3 (depends on 1) The apparatus of claim 1, further comprising: a telemetry transmitter to communicate the differential phase semblance values to a surface logging facility. ### Claim 4 A system, comprising: a down hole tool; a set of receivers attached to the downhole tool, the set of receivers arranged as azimuthally separated receiver arrays, each receiver array having front and back receivers to form sum and difference channels; logic attached to the downhole tool to record raw signal data corresponding to energy waves propagated through a geological formation before being received by the set of receivers; and a signal processor to transform the raw signal data into signal data, to shift the signal data associated with the set of receivers in time or phase with respect to the signal data associated with a receiver reference point, to multiply the shifted data by a complex conjugate of the signal data associated with the receiver reference point to provide differential phase values associated with the set of receivers, and to sum and average the differential phase values over the set of receivers at each time of selected times for a given slowness or over the set of receivers at each frequency of selected frequencies for a given slowness to provide differential phase semblance values; and a device operable with the signal processor to publish a slowness time semblance image or a slowness frequency semblance image based on the differential phase semblance values, the device being one of a storage medium, a hardcopy printout device, or a display. ### Claim 5 (depends on 4) The system of claim 4, wherein the downhole tool comprises one of a wireline tool or a measurement while drilling tool. ### Claim 6 (depends on 4) The system of claim 4, wherein the signal processor is divided into at least two processors comprising a surface computer and a sub-surface processor communicatively coupled to the surface computer. ### Claim 7 A processor-implemented method to execute on one or more processors that perform the method, comprising: receiving, by a set of receivers arranged as azimuthally separated receiver arrays, each receiver array having front and back receivers to form sum and difference channels, received energy waves, the received energy waves resulting from generated energy waves propagating through a geological formation; shifting signal data associated with the set of receivers, in time or phase with respect to signal data associated with a receiver reference point; multiplying the shifted data by a complex conjugate of the signal data associated with the receiver reference point to provide differential phase values associated with the set of receivers; summing and averaging the differential phase values over the set of receivers at each time of selected times for a given slowness or over the set of receivers at each frequency of selected frequencies for a given slowness to provide differential phase semblance values; and publishing a slowness time semblance image or a slowness frequency semblance image, the differential phase semblance values, to one of a storage medium, a hardcopy printout, or a display. ### Claim 8 (depends on 7) The method of claim 7, further comprising: generating the energy waves using a set of transmitters; and recording raw signal data as a digitized form of the energy waves in a storage medium. ### Claim 9 (depends on 8) The method of claim 8, wherein generating the energy waves further comprises: driving the set of transmitters to generate acoustic waves in the geological formation. ### Claim 10 (depends on 7) The method of claim 7, wherein the shifting comprises shifting the signal data in time, further comprising: transforming analytical signal data in the time domain to frequency domain data, the frequency domain data comprising the signal data. ### Claim 11 (depends on 10) The method of claim 10, further comprising: transforming raw signal data as a digitized form of the energy waves into the analytical signal data. ### Claim 12 (depends on 7) The method of claim 7, wherein the shifting comprises shifting the signal data in time, further comprising: transforming analytical signal data in the time domain to frequency domain data, the frequency domain data comprising the signal data. ### Claim 13 (depends on 7) The method of claim 7, wherein the shifting comprises shifting the signal data in time, further comprising: before the multiplying, converting the shifted data back into the time domain. ### Claim 14 (depends on 7) The method of claim 7, wherein the shifting comprises shifting the signal data in time, and wherein the averaging comprises: averaging the summed differential phase values at selected points in time. ### Claim 15 (depends on 7) The method of claim 7, wherein the shifting comprises shifting the signal data in phase, further comprising: transforming raw signal data as a digitized form of the energy waves in the time domain to frequency domain data, the frequency domain data comprising the signal data. ### Claim 16 (depends on 7) The method of claim 7, wherein the shifting comprises shifting the signal data in phase, and wherein the averaging comprises: averaging the summed differential phase values at selected frequencies. ### Claim 17 (depends on 7) The method of claim 7, wherein the publishing comprises: publishing a phase coherence time semblance image when the shifting comprises shifting the signal data in time. ### Claim 18 (depends on 7) The method of claim 7, further comprising: moving the receiver reference point to a different physical location; repeating the multiplying to provide additional differential phase values for signal data associated with the different physical location; and summing and averaging the differential phase values and the additional differential phase values to provide the differential phase semblance values as stacked values. ### Claim 19 (depends on 7) The method of claim 7, further comprising: selecting a receiver from the set of receivers as a reference receiver located at a location other than the receiver reference point; multiplying to provide additional differential phase values for signal data associated with the reference receiver; and summing and averaging the differential phase values and the additional differential phase values to provide the differential phase semblance values as stacked values. ### Claim 20 An article including a non-transitory, machine-accessible medium having instructions stored therein, wherein the instructions, when executed, result in a machine performing: receiving, by a set of receivers arranged as azimuthally separated receiver arrays, each receiver array having front and back receivers to form sum and difference channels, received energy waves, the received energy waves resulting from generated energy waves propagating through a geological formation; shifting signal data associated with the set of receivers, in time or phase with respect to signal data associated with a receiver reference point; multiplying the shifted data by a complex conjugate of the signal data associated with the receiver reference point to provide differential phase values associated with the set of receivers; summing and averaging the differential phase values over the set of receivers at each time of selected times for a given slowness or over the set of receivers at each frequency of selected frequencies for a given slowness to provide differential phase semblance values; and publishing a slowness time semblance image or a slowness frequency semblance image based on the differential phase semblance values to one of a storage medium, a hardcopy printout; or a display. ### Claim 21 (depends on 20) The article of claim 20, wherein the instructions, when executed, result in the machine performing: prior to the publishing, scaling the differential phase semblance values to provide information derived from the differential phase semblance values. ### Claim 22 (depends on 20) The article of claim 20, wherein the publishing comprises: publishing a phase coherence frequency semblance image when the shifting comprises shifting the signal data in phase.