# US 11,079,511 B2 · Angular response compensation for DAS VSP

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- Number: US 11,079,511 B2
- Document ID: US11079511B2
- Status: Granted
- Kind: B2
- Application number: 16/077,487
- Filed: 2017-06-28
- Published: 2021-07-01
- Granted: 2021-08-03
- Earliest claimed: 2017-06-28
- Assignees: Halliburton Energy Services, Inc.
- Applicants: Halliburton Energy Services, Inc.
- Inventors: Xiang Wu; Mark Elliot Willis; Andreas Ellmauthaler
- Web page: https://patentgrep.com/patent/US11079511B2

## CPC

- G01V 1/48: Processing data
- G01V 1/50: Analysing data
- E21B 47/00: Survey of boreholes or wells (monitoring pressure or flow of drilling fluid E21B21/08)
- E21B 47/0224: using seismic or acoustic means
- E21B 47/113: using electrical indications; using light radiations
- E21B 47/135: using light waves, e.g. infrared or ultraviolet waves
- G01H 9/004: {using fibre optic sensors (light guides per se G02B6/00, acousto-optical devices specially adapted for gating or modulating in optical wave guides G02F1/125)}
- G01V 1/226: {Optoseismic systems}
- G01V 1/307: {for determining seismic attributes, e.g. amplitude, instantaneous phase or frequency, reflection strength or polarity}
- G01V 1/52: Structural details
- G01V 2210/161: Vertical seismic profiling [VSP]
- G01V 2210/47: Slowness, e.g. tau-pi
- G01V 2210/63: Seismic attributes, e.g. amplitude, polarity, instant phase
- 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
- G01H: MEASUREMENT OF MECHANICAL VIBRATIONS OR ULTRASONIC, SONIC OR INFRASONIC WAVES

## Abstract

A system for processing DAS VSP surveys is provided. The system includes a DAS data collection system coupled to at least one optical fiber at least partially positioned within a wellbore and configured to either activate or passively listen to a seismic source of energy for one or more times. The system further includes an information processing system connected to the DAS data collection system. A seismic dataset is received from the DAS data collection system recorded in a spatiotemporal domain. The seismic dataset is converted into intercept-time ray-parameter domain dataset. Local apparent slope is determined for each seismic signal in the received seismic dataset. Amplitude correction is performed for the received seismic signals by using the slowness profile and the determined local apparent slope in the intercept-time ray-parameter domain dataset. The corrected intercept-time ray-parameter domain dataset is converted back into the spatiotemporal domain.

## Claims

### Claim 1

A system, comprising:
a distributed acoustic sensing (DAS) data collection system coupled to at least one optical fiber at least partially positioned within a wellbore and configured to activate a seismic source of energy or listen to a seismic source of energy for one or more times; and
an information processing system communicatively coupled to the DAS data collection system, the information processing system comprising a processor and a memory device coupled to the processor, the memory device containing a set of instructions that, when executed by the processor, cause the processor to:
receive a seismic dataset from the DAS data collection system recorded in a spatiotemporal domain, the seismic dataset comprising a plurality of seismic data records that are each associated with a different activation of the source by the DAS data collection system to produce a seismic signal;
receive a slowness profile as a function of measured depth within the wellbore from the DAS data collection system or from a VSP processing system;
convert the seismic dataset into intercept-time ray-parameter domain dataset;
determine the local apparent slope for each seismic signal in the received seismic dataset;
perform amplitude correction for the received seismic signals by using the slowness profile and the determined local apparent slope in the intercept-time ray-parameter domain dataset; and
convert the corrected intercept-time ray-parameter domain dataset into the spatiotemporal domain.

### Claim 2 (depends on 1)

The system of claim 1, wherein the set of instructions that cause the processor to convert the seismic dataset into the intercept-time ray-parameter domain dataset further cause the processor to convert the seismic dataset into tau-p domain dataset.

### Claim 3 (depends on 2)

The system of claim 2, wherein the local apparent slope is determined based on arrival time of each seismic signal at the at least one optical fiber.

### Claim 4 (depends on 2)

The system of claim 2, wherein the set of instructions that cause the processor to convert the seismic dataset into the intercept-time ray-parameter domain dataset further cause the processor to divide each seismic data record in the dataset into multiple components, wherein each of the components is associated with a particular depth within the wellbore.

### Claim 5 (depends on 1)

The system of claim 1, wherein the seismic signal comprises a seismic P wave, a seismic S wave, or a combination of them.

### Claim 6 (depends on 5)

The system of claim 5, wherein the set of instructions that cause the processor to convert the seismic dataset into the intercept-time ray-parameter domain dataset further cause the processor to separate seismic signals corresponding to the P-waves from the seismic signals corresponding to the S-waves based upon measured velocity of the seismic signals.

### Claim 7 (depends on 6)

The system of claim 6, wherein the set of instructions that cause the processor to perform amplitude correction further cause the processor to separately perform the amplitude correction for the seismic signals corresponding to the P-waves and for the seismic signals corresponding to the S-waves.

### Claim 8 (depends on 1)

The system of claim 1, wherein the set of instructions that cause the processor to convert the seismic dataset into the intercept-time ray-parameter domain dataset further cause the processor to perform one of slant stack depth-varying tau-p transform and depth-varying sparse tau-p transform.

### Claim 9 (depends on 1)

The system of claim 1, wherein the DAS data collection system comprises a data interrogation device communicatively coupled to one end of the at least one optical fiber and positioned at a surface of the earth.

### Claim 10 (depends on 6)

The system of claim 6, wherein the slowness profile value is associated with S-waves or the slowness profile value is associated with P-waves and wherein the slowness profile is obtained using a zero offset, check shot VSP survey, or a sonic log.

### Claim 11

A method for processing DAS VSP surveys to perform amplitude correction in real-time or offline, the method comprising:
activating a seismic source of energy or listening to a seismic source of energy by a distributed acoustic sensing (DAS) data collection system coupled to at least one optical fiber at least partially positioned within a wellbore;
sending an acquired seismic dataset from the DAS data collection system to an information processing system communicatively coupled to the DAS data collection system, the seismic dataset comprising a plurality of seismic data records that are each associated with a different activation of the source by the DAS data collection system to produce a seismic signal;
sending a slowness profile as a function of measured depth within the wellbore from the DAS data collection system or from a VSP processing system to an information processing system;
converting, by the information processing system, the seismic dataset into intercept-time ray-parameter domain dataset;
determining, by the information processing system, local apparent slope for each seismic signal in the received seismic dataset;
performing, by the information processing system, amplitude correction for the received seismic signals by using the slowness profile and the determined local apparent slope in the intercept-time ray-parameter domain dataset; and
converting, by the information processing system, the corrected intercept-time ray-parameter domain dataset into the spatiotemporal domain.

### Claim 12 (depends on 11)

The method of claim 11, wherein the DAS data collection system comprises a data interrogation device communicatively coupled to one end of the at least one optical fiber and positioned at a surface of the earth.

### Claim 13 (depends on 11)

The method of claim 11, wherein converting the seismic dataset into the intercept-time ray-parameter domain dataset comprises converting the seismic dataset into tau-p domain dataset.

### Claim 14 (depends on 13)

The method of claim 13, wherein the local apparent slope is determined based on arrival time of each seismic signal at the at least one optical fiber.

### Claim 15 (depends on 13)

The method of claim 13, wherein converting the seismic dataset into the intercept-time ray-parameter domain dataset comprises dividing each seismic data record in the dataset into multiple components, wherein each of the components is associated with a particular depth within the wellbore.

### Claim 16 (depends on 11)

The method of claim 11, wherein the seismic signal comprises a combined seismic P-wave and seismic S-wave.

### Claim 17 (depends on 16)

The method of claim 16, wherein converting the seismic dataset into the intercept-time ray-parameter domain dataset comprises separating seismic signals corresponding to the P-waves from seismic signals corresponding to the S-waves based upon measured velocity of the seismic signals.

### Claim 18 (depends on 17)

The method of claim 17, wherein performing amplitude correction comprises separately performing the amplitude correction for the seismic signals corresponding to the P-waves and for the seismic signals corresponding to the S-waves.

### Claim 19

An information processing system communicatively coupled to a distributed acoustic sensing (DAS) data collection system, the information processing system comprising a processor and a memory device coupled to the processor, the memory device containing a set of instruction that, when executed by the processor, cause the processor to:
receive an acquired seismic dataset from the DAS data collection system, the seismic dataset comprising a plurality of seismic data records that are each associated with a different activation time of a source or with a different listen time of a source by the DAS data collection system to produce a seismic signal;
receive slowness profile as a function of measured depth within the wellbore from the DAS data collection system or from a VSP processing system;
convert the seismic dataset into intercept-time ray-parameter domain dataset;
determine local apparent slope for each seismic signal in the received seismic dataset;
perform amplitude correction for the received seismic signals by using the slowness profile and the determined local apparent slope in the intercept-time ray-parameter domain dataset; and
convert the corrected intercept-time ray-parameter domain dataset into the spatiotemporal domain.

### Claim 20 (depends on 19)

The information processing system of claim 19, wherein the set of instructions that cause the processor to convert the seismic dataset into the intercept-time ray-parameter domain dataset further cause the processor to convert the seismic dataset into tau-p domain dataset.