# US 11,994,642 B2 · Method and apparatus for geophysical formation evaluation measurements behind casing > Agents: this data is available as JSON from the patentgrep API and MCP server — see https://patentgrep.com/llms.txt - Number: US 11,994,642 B2 - Document ID: US11994642B2 - Status: Granted - Kind: B2 - Application number: 17/628,611 - Filed: 2019-08-30 - Published: 2022-08-25 - Granted: 2024-05-28 - Earliest claimed: 2019-08-30 - Assignees: Halliburton Energy Services, Inc. - Applicants: Halliburton Energy Services, Inc. - Inventors: Kristoffer Thomas Walker; John Philip Granville; Chung Chang - Web page: https://patentgrep.com/patent/US11994642B2 ## CPC - G01V 1/50: Analysing data - E21B 47/005: Monitoring or checking of cementation quality or level - E21B 47/107: using acoustic means - E21B 49/00: Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells - G01V 1/46: Data acquisition - G01V 1/48: Processing data - G01V 1/52: Structural details - 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 2210/1425: Land surface - G01V 2210/1429: Subsurface, e.g. in borehole or below weathering layer or mud line - G01V 2210/32: Noise reduction - G01V: GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS (means for indicating the location of accidentally buried, e.g. snow-buried, persons A63B29/02) - E21B: EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS ## Abstract Apparatus, methods, and systems for determining acoustic velocity behind casing or tubing in a subterranean wellbore. A method may include obtaining a plurality of waveform data sets corresponding to a plurality of propagation path regimes and obtaining a total wavefield across the receiver array. The method may also include determining a Green's function representing each of the plurality of propagation path regimes and determining a noise wavefield by convolving the Green's functions and a known transmitted pressure signal corresponding to the plurality of waveform data sets. The method may also include generating a reduced-noise wavefield by subtracting the noise wavefield from the total wavefield and estimating the acoustic velocity of a formation behind the casing or tubing from the reduce-noise wavefield. ## Claims ### Claim 1 A method of determining acoustic velocity behind casing or tubing in a subterranean wellbore, the method comprising: obtaining, using an acoustic logging tool at a wellbore depth corresponding to a target subterranean formation zone, a plurality of waveform data sets, the plurality of waveform data sets comprises a first waveform data set corresponding to a first propagation path regime and a second waveform data set corresponding to a second propagation path regime; obtaining, using the acoustic logging tool, a total wavefield across a receiver array of the acoustic logging tool at the wellbore depth; determining a first Green's function based on the first waveform data set and a second Green's function based on the second waveform data set, the first Green's function representing the first propagation path regime and the second Green's function representing the second propagation path regime; determining a noise wavefield by convolving the first Green's function, the second Green's function, a known transmitted pressure signal corresponding to the first waveform data set and a known transmitted pressure signal corresponding to the second waveform data set; and generating a reduced-noise wavefield by subtracting the noise wavefield from the total wavefield. ### Claim 2 (depends on 1) The method according to claim 1, wherein the reduced-noise wavefield corresponds to a wavefield associated with a refracted compressional wave transiting the target subterranean formation zone. ### Claim 3 (depends on 1) The method according to claim 1, further comprising estimating, using the reduced-noise wavefield, a formation compressional wave speed for the target subterranean formation zone. ### Claim 4 (depends on 1) The method according to claim 1, wherein the acoustic logging tool comprises one or more acoustic or ultrasonic transmitters configured to sample different propagation paths between a transmitter source and an array of acoustic receivers. ### Claim 5 (depends on 1) The method according to claim 1, wherein determining the first Green's function and the second Green's function further comprises deconvolving a known transmitted pressure signal from a recording of the first waveform data set and the second waveform data set. ### Claim 6 (depends on 1) The method according to claim 1, wherein the first propagation path regime comprises a high-angle of incidence regime and the second propagation path regime comprises a low-angle of incidence regime. ### Claim 7 (depends on 6) The method according to claim 6, wherein the acoustic logging tool comprises a first low-incidence angle directional acoustic transmitter configured to transmit a source waveform such that it impacts the casing or tubing at a low-incidence angle and a second high-incidence angle directional acoustic transmitter configured to transmit a source waveform such that it impacts the casing or tubing at a high-incidence angle. ### Claim 8 (depends on 7) The method according to claim 7, wherein obtaining a total wavefield comprises firing the first low-incidence angle directional acoustic transmitter and the second high-incidence angle directional acoustic transmitter simultaneously. ### Claim 9 (depends on 7) The method according to claim 7, further comprising: firing simultaneously the first low-incidence angle directional acoustic transmitter and the second high-incidence angle directional acoustic transmitter using a short impulse drive pulse to obtain a total wavefield; and firing the second high-incidence angle directional acoustic transmitter using a longer drive pulse to obtain a second waveform data set corresponding to the high-angle of incidence regime; wherein determining the second Green's functions comprises applying deconvolution to the second waveform data set. ### Claim 10 (depends on 1) The method according to claim 1, wherein the acoustic logging tool comprises an ultrasonic transmitter configured to transmit a source wave at ultrasonic frequencies greater than about 20 KHz. ### Claim 11 (depends on 1) The method according to claim 1, wherein the acoustic logging tool comprises a broadband transmitter configured to transmit a source wave at acoustic frequencies of from about 20 Hz to about 20 KHz and ultrasonic frequencies greater than 20 KHz. ### Claim 12 (depends on 1) The method according to claim 1, further comprising: disposing an acoustic logging tool in a subterranean wellbore comprising casing or tubing, the acoustic logging tool having a receiver array and one or more directional acoustic or ultrasonic transmitters configured to sample different propagation paths between the one or more directional acoustic or ultrasonic transmitters and the receiver array; and actuating the one or more directional acoustic or ultrasonic transmitters so as to acquire a plurality of waveform data sets at a wellbore depth corresponding to a target subterranean formation zone. ### Claim 13 (depends on 12) The method according to claim 12, wherein the acoustic logging tool is lowered to a wellbore depth corresponding to a cased portion of the wellbore or adjacent to tubing. ### Claim 14 (depends on 1) The method according to claim 1, wherein the acoustic logging tool comprises a narrow-beam transmitter configured to perform a sweep of firings through a range of incidence angles. ### Claim 15 (depends on 1) The method according to claim 1, wherein the plurality of waveform data sets and the total wavefield are obtained using an acoustic logging tool having a transmitter configured to transmit in an ultrasonic frequency range of from about 50 kHz to about 200 kHz. ### Claim 16 A system comprising: an acoustic logging tool having a receiver array and one or more directional acoustic or ultrasonic transmitters configured to sample different propagation paths between the one or more directional acoustic or ultrasonic transmitters and the receiver array, the acoustic logging tool configured to acquire a plurality of waveform data sets at a wellbore depth corresponding to a target subterranean formation zone adjacent to casing or tubing, wherein the plurality of waveform data sets comprises a first waveform data set corresponding to a first propagation path regime and a second waveform data set corresponding to a second propagation path regime; at least one processor in communication with the acoustic logging tool, wherein the at least one processor is coupled with a non-transitory computer-readable storage medium having stored therein instructions which, when executed by the at least one processor, causes the at least one processor to: determine a total wavefield across the receiver array of the acoustic logging tool at the wellbore depth; generate a first Green's function based on the first waveform data set and a second Green's function based on the second waveform data set, the first Green's function representing the first propagation path regime and the second Green's function representing the second propagation path regime; determine a noise wavefield by convolving the first Green's function, the second Green's function, a known transmitted pressure signal corresponding to the first waveform data set and a known transmitted pressure signal corresponding to the second waveform data set; and generate a reduced-noise wavefield by subtracting the noise wavefield from the total wavefield. ### Claim 17 (depends on 16) The system according to claim 16, wherein the non-transitory computer-readable storage medium further contains a set of instructions that when executed by the at least one processor, further causes the at least one processor to estimate, using the reduced-noise wavefield, a formation compressional wave speed for the target subterranean formation zone. ### Claim 18 (depends on 17) The system according to claim 17, wherein the acoustic logging tool comprises a first low-incidence angle directional acoustic transmitter configured to transmit a source waveform such that it impacts the casing or tubing at a low-incidence angle and a second high-incidence angle direction acoustic transmitter configured to transmit a source waveform such that it impacts the casing or tubing at a high-incidence angle; and wherein the first propagation path regime comprises a high-angle of incidence regime and the second propagation path regime comprises a low-angle of incidence regime. ### Claim 19 (depends on 16) The system according to claim 16, wherein the acoustic logging tool comprises at least one ultrasonic transmitter configured to transmit a source wave at ultrasonic frequencies greater than about 20 KHz. ### Claim 20 (depends on 16) The system according to claim 16, wherein the acoustic logging tool comprises at least one broadband transmitter configured to transmit a source wave at acoustic frequencies of from about 20 Hz to about 20 KHz and ultrasonic frequencies greater than 20 KHz.