# US 2016/0259079 A1 · Distributed Acoustic Sensing for Passive Ranging

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- Number: US 2016/0259079 A1
- Document ID: US20160259079A1
- Status: Published application
- Kind: A1
- Application number: 15/029,212
- Filed: 2013-12-17
- Published: 2016-09-08
- Earliest claimed: 2013-12-17
- Assignees: Halliburton Energy Services, Inc.
- Applicants: Halliburton Energy Services Inc.
- Inventors: Glenn A. Wilson; Burkay Donderici
- Web page: https://patentgrep.com/patent/US20160259079A1

## CPC

- G01V 1/42: using generators in one well and receivers elsewhere or vice versa (G01V1/52 takes precedence)
- E21B 7/04: Directional drilling
- E21B 7/06: Deflecting the direction of boreholes
- E21B 47/024: of devices in the borehole (determining slope or direction of the borehole E21B47/022)
- E21B 47/09: Locating or determining the position of objects in boreholes or wells {, e.g. the position of an extending arm}; Identifying the free or blocked portions of pipes
- E21B 47/135: using light waves, e.g. infrared or ultraviolet waves
- 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

A passive system for ranging between two wellbores where a distributed acoustic sensor system is deployed in a first wellbore and a drill bit in a second wellbore being drilled is utilized and an acoustic source to generate an acoustic signal for measurement by the distributed acoustic sensor system. The dynamic strain along the distributed acoustic sensor system is detected with an optical interrogation system and utilized to determine direction and distance between the first wellbore and the second wellbore.

## Claims

### Claim 1

A wellbore ranging system comprising:
an optical waveguide disposed in a first wellbore of a formation; and
an acoustic source disposed in a second wellbore and acoustically coupled with the formation.

### Claim 2 (depends on 1)

The system of claim 1, wherein the optical waveguide is disposed along an axial length of the first wellbore.

### Claim 3 (depends on 1)

The system of claim 1, wherein the optical waveguide is an optical fiber cable disposed along a portion of the axial length of the first wellbore.

### Claim 4 (depends on 3)

The system of claim 3 further comprising a second optical fiber cable disposed along at least the same axial length of the first wellbore as the first optical fiber cable.

### Claim 5 (depends on 3)

The system of claim 3, wherein the optical fiber cable is a distributed acoustic sensor.

### Claim 6 (depends on 1)

The system of claim 1, wherein the optical waveguide spirals around the first wellbore.

### Claim 7 (depends on 1)

The system of claim 1, wherein the first wellbore has a first axial length and the second wellbore has a second axial length and a distal end, wherein the acoustic source in the second wellbore is proximate the distal end.

### Claim 8 (depends on 1)

The system of claim 1, further comprising a plurality of optical waveguides extending along at least a portion of an axial length of the first wellbore.

### Claim 9 (depends on 1)

The system of claim 1, wherein the first wellbore further comprises a casing disposed therein, the casing having an exterior surface, wherein the optical waveguide is disposed adjacent the exterior surface of the casing so as to form an acoustic transmission path between the optical waveguide and the formation.

### Claim 10 (depends on 1)

The system of claim 1, wherein the acoustic source is a drill bit deployed at the end of a drill string as part of bottom hole assembly, wherein the bottom hole assembly further comprises a directional steering system and a power system.

### Claim 11 (depends on 1)

The system of claim 1, further comprising an optical waveguide interrogation system in optical communication with the optical waveguide.

### Claim 12 (depends on 11)

The system of claim 11, further comprising a control system in communication with the optical waveguide interrogation system and a drilling system in communication with the control system, the drilling system further comprising a drill bit disposed in the second wellbore.

### Claim 13

An acoustic ranging system for wellbores, the system comprising:
a first wellbore with a fiber optic ranging system disposed therein; and
an acoustic source disposed to generate an acoustic signal.

### Claim 14 (depends on 13)

The system of claim 13, wherein the fiber optic ranging system comprises an optical waveguide disposed along a portion of the length of the first wellbore.

### Claim 15 (depends on 14)

The system of claim 14, further comprising:
a second wellbore in the formation;
a control system in communication with an optical waveguide interrogation system; and
a drilling system in communication with the control system, the control system disposed to control the drilling system based on measurements from the optical waveguide interrogation system,
wherein:
the first wellbore further comprises a casing disposed therein,
the fiber optic ranging system comprises:
a distributed acoustic sensor disposed along an axial length of the first wellbore adjacent an exterior surface of the casing, and
the optical waveguide interrogation system in optical communication with the distributed acoustic sensor,
the acoustic source is a drill bit deployed on a drill string disposed in the second wellbore, and
the drill string comprises a bottom hole assembly, the bottom hole assembly comprising:
a directional steering system; and
a power system.

### Claim 16

A wellbore ranging method comprising:
deploying a distributed acoustic sensing system in a first wellbore;
utilizing an acoustic source outside of the first wellbore to generate an acoustic signal;
detecting the acoustic signal with the distributed acoustic sensing system; and
determining the position of the first wellbore in a formation based on the detected acoustic signal.

### Claim 17 (depends on 16)

The method of claim 16, further comprising deploying the acoustic source in a second wellbore within the formation.

### Claim 18 (depends on 16)

The method of claim 16, further comprising determining a direction to the first wellbore.

### Claim 19 (depends on 16)

The method of claim 16, wherein deploying comprises positioning an optical waveguide along at least a portion of the length of the first wellbore to acoustically couple the deployed optical waveguide with the formation.

### Claim 20 (depends on 19)

The method of claim 19, further comprising determining a direction to the first wellbore by comparing at least two optical waveguides positioned along the same portion of the length of the first wellbore.

### Claim 21 (depends on 20)

The method of claim 20, wherein one of the optical waveguides is a spiraling optical waveguide disposed along a portion of the length of the first wellbore; and wherein comparing comprises processing differences in the acoustic signal at the portion of the length along which both optical waveguides are disposed.

### Claim 22 (depends on 16)

The method of claim 16, wherein detecting comprises utilizing a light source to drive light along the optical waveguide to detect vibrations along the waveguide based on dynamic strain along the optical waveguide.

### Claim 23 (depends on 16)

The method of claim 16, further comprising:
drilling a second wellbore using a drill bit deployed by a drill string; and
generating the acoustic signal utilizing the drill bit.

### Claim 24 (depends on 23)

The method of claim 23, wherein determining the position of the first wellbore comprises determining a direction and distance between the first wellbore and a second wellbore in which the acoustic source is deployed, and further comprising determining a desired trajectory for a second wellbore relative to a first wellbore based on a drilling plan and, based on the determined position of the first wellbore, adjusting the actual trajectory of the second wellbore.

### Claim 25 (depends on 24)

The method of claim 24, further comprising:
adjusting the trajectory of the second wellbore based on the difference between the desired trajectory and the actual trajectory; and
repositioning a drill bit in the second wellbore to adjust the trajectory of the second wellbore,
wherein drilling of the second wellbore is commenced prior to the step of determining the position of the second wellbore and drilling is continued following repositioning of the drill bit.

### Claim 26 (depends on 23)

The method of claim 23, wherein utilizing, detecting and determining are repeated multiple times during the drilling of the second wellbore.

### Claim 27 (depends on 16)

The method of claim 16, further comprising measuring a characteristic of the first wellbore utilizing the distributed sensing system, wherein the characteristic is selected from the group consisting of temperature, pressure, and vibration.

### Claim 28 (depends on 16)

The method of claim 16, further comprising performing a SAGD operation.