AU2021200537B2 - Subsurface strain estimation using fiber optic measurement - Google Patents

Subsurface strain estimation using fiber optic measurement Download PDF

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Publication number
AU2021200537B2
AU2021200537B2 AU2021200537A AU2021200537A AU2021200537B2 AU 2021200537 B2 AU2021200537 B2 AU 2021200537B2 AU 2021200537 A AU2021200537 A AU 2021200537A AU 2021200537 A AU2021200537 A AU 2021200537A AU 2021200537 B2 AU2021200537 B2 AU 2021200537B2
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strain
well
rock
fiber optic
velocity
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AU2021200537A9 (en
AU2021200537A1 (en
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Kevin John Davies
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Chevron USA Inc
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Chevron USA Inc
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    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
    • G01V1/40—Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging
    • G01V1/52—Structural details
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01B—MEASURING LENGTH, THICKNESS OR SIMILAR LINEAR DIMENSIONS; MEASURING ANGLES; MEASURING AREAS; MEASURING IRREGULARITIES OF SURFACES OR CONTOURS
    • G01B11/00—Measuring arrangements characterised by the use of optical techniques
    • G01B11/16—Measuring arrangements characterised by the use of optical techniques for measuring the deformation in a solid, e.g. optical strain gauge
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V2210/00—Details of seismic processing or analysis
    • G01V2210/60—Analysis
    • G01V2210/66—Subsurface modeling

Abstract

Strain and time-strain measurement in a well enables derivation of a constant that links the two. Knowledge of the constant along with time-strain measurement at another well enables estimation of strain at the other well. 50 10 Processor 11 Machine-Readable Instructions 100 Time-Strain Information Component 102 Velocity-Strain Per Strain Information Component 104 Strain Component 106 Interface 12 Electronic Storage 13 Display 14 FIG. 1 1/4

Description

Processor 11
Machine-Readable Instructions 100
Time-Strain Information Component 102
Velocity-Strain Per Strain Information Component 104
Strain Component 106
Interface 12
Electronic Storage 13 Display 14
FIG. 1
1/4
Australian Patents Act 1990
ORIGINAL COMPLETE SPECIFICATION STANDARDPATENT
Invention Title Subsurface strain estimation using fiber optic measurement
The following statement is a full description of this invention, including the best method of performing it known to me/us:-
[0001]The present disclosure relates generally to the field of estimating strain along a
well using fiber optic measurement.
BACKGROUND
[0002]Strain measurement at a well may be used to perform subsurface analysis, such
as for calibration and verification of mechanical earth models or for well integrity
analysis. The structure of a well may not allow for placement of a fiber optic cable to
perform direct measurement of strain along the well.
[0002A] It is desired to address or ameliorate one or more disadvantages or limitations
associated with the prior art, or to at least provide a useful alternative.
SUMMARY
[0002B] In accordance with the present invention, there is provided a system for
estimating strain along a well, the system comprising:
one or more physical processors configured by machine-readable instructions to:
obtain time-strain information of the well, the time-strain information
characterizing time-strain of the well as a function of distance along the well, the
time-strain of the well measured via a first interior fiber optic cable within a casing
of the well, wherein the well is adjacent to one or more types of rock, the one or
more types of rock including a first type of rock;
obtain velocity-strain per strain information for the well, the velocity-strain per
strain information characterizing one or more values of velocity-strain per strain
corresponding to the one or more types of rock adjacent to the well, the one or
more values of velocity-strain per strain including a first value of velocity-strain
la per strain corresponding to the first type of rock adjacent to the well, wherein the first value of velocity-strain per strain is determined based on fiber optic measurement of time-strain and strain of a calibration well different from the well, the calibration well adjacent to same type of rock as at least one of the one or more types of rock adjacent to the well, the fiber optic measurement of the strain of the calibration well performed via an exterior fiber optic cable of the calibration well positioned outside a casing of the calibration well, the exterior fiber optic cable coupled to the first type of rock adjacent to the calibration well; and estimate the strain of the well as the function of distance along the well based on
(1) the time-strain of the well as the function of distance along the well and (2)
the one or more values of velocity-strain per strain corresponding to the one or
more types of rock adjacent to the well, wherein the strain of the well adjacent to
the first type of rock is estimated based on the time-strain of the well along the
first type of rock and the first value of velocity-strain per strain corresponding to
the first type of rock.
[0002C] The present invention also provides a method for estimating strain along a well,
the method comprising:
obtaining time-strain information of the well, the time-strain information
characterizing time-strain of the well as a function of distance along the well, the
time-strain of the well measured via a first interior fiber optic cable within a casing
of the well, wherein the well is adjacent to one or more types of rock, the one or
more types of rock including a first type of rock; obtaining velocity-strain per strain information for the well, the velocity-strain per strain information characterizing one or more values of velocity-strain per strain corresponding to the one or more types of rock adjacent to the well, the one or more values of velocity-strain per strain including a first value of velocity-strain per strain corresponding to the first type of rock adjacent to the well, wherein the first value of velocity-strain per strain is determined based on fiber optic measurement of time-strain and strain of a calibration well different from the well, the calibration well adjacent to same type of rock as at least one of the one or more types of rock adjacent to the well, the fiber optic measurement of the strain of the calibration well performed via an exterior fiber optic cable of the calibration well positioned outside a casing of the calibration well, the exterior fiber optic cable coupled to the first type of rock adjacent to the calibration well; and estimating the strain of the well as the function of distance along the well based on (1) the time-strain of the well as the function of distance along the well and (2) the one or more values of velocity-strain per strain corresponding to the one or more types of rock adjacent to the well, wherein the strain of the well adjacent to the first type of rock is estimated based on the time-strain of the well along the first type of rock and the first value of velocity-strain per strain corresponding to the first type of rock.
[0002D] The present invention also provides a system for estimating strain along a well,
the system comprising: the well adjacent to one or more types of rock, the one or more types of rock including a first type of rock, the well including a casing; an interior fiber optic cable positioned within the casing of the well to measure time strain of the well; and one or more physical processors configured by machine-readable instructions to: obtain time-strain information of the well, the time-strain information characterizing the time-strain of the well as a function of distance along the well, the time-strain of the well measured via the interior fiber optic cable positioned within the casing of the well; obtain velocity-strain per strain information for the well, the velocity-strain per strain information characterizing one or more values of velocity-strain per strain corresponding to the one or more types of rock adjacent to the well, the one or more values of velocity-strain per strain including a first value of velocity-strain per strain corresponding to the first type of rock adjacent to the well, wherein the first value of velocity-strain per strain is determined based on fiber optic measurement of time-strain and strain of a calibration well different from the well, the calibration well adjacent to same type of rock as at least one of the one or more types of rock adjacent to the well, the fiber optic measurement of the strain of the calibration well performed via an exterior fiber optic cable of the calibration well positioned outside a casing of the calibration well, the exterior fiber optic cable coupled to the first type of rock adjacent to the calibration well; and estimate the strain of the well as the function of distance along the well based on
(1) the time-strain of the well as the function of distance along the well and (2) the one or more values of velocity-strain per strain corresponding to the one or more types of rock adjacent to the well, wherein the strain of the well adjacent to the first type of rock is estimated based on the time-strain of the well along the first type of rock and the first value of velocity-strain per strain corresponding to the first type of rock.
BRIEF DESCRIPTION OF THE DRAWINGS
[0002E] Some embodiments of the present invention are hereinafter described, by way
of example only, with reference to the accompanying drawings, in which:
[0003]FIG. 1 illustrates an example system for estimating strain along a well.
[0004]FIG. 2 illustrates an example method for estimating strain along a well.
[0005]FIG. 3 illustrates an example well in which strain is estimated using values of
velocity-strain per strain for rock types.
[0006]FIG. 4 illustrates an example well from which values of velocity-strain per strain
for rock types are determined.
DETAILED DESCRIPTION
[0007]This disclosure relates to estimating strain along a well. Time-strain information
of a well, velocity-strain per strain information for the well, and/or other information may
be obtained. The time-strain information of the well may characterize time-strain of the
well as a function of distance along the well. The time-strain of the well may be
measured via an interior fiber optic cable within the well. The well may be adjacent to
one or more types of rock, such as a first type of rock and/or other types of rock. The velocity-strain per strain information for the well may characterize one or more values of velocity-strain per strain corresponding to the type(s) of rock adjacent to the well. The value(s) of velocity-strain per strain may include a first value of velocity-strain per strain corresponding to the first type of rock adjacent to the well. The first value of velocity strain per strain may be determined based on fiber optic measurement of time-strain and strain of another well different from the well, and/or other information. The strain of the well as the function of distance along the well may be estimated based on (1) the time-strain of the well as the function of distance along the well, (2) the value(s) of velocity-strain per strain corresponding to the type(s) of rock adjacent to the well, and/or other information. The strain of the well adjacent to the first type of rock may be estimated based on the time-strain of the well along the first type of rock, the first value of velocity-strain per strain corresponding to the first type of rock, and/or other information.
[0008]A system for estimating strain along a well may include one or more electronic
storage, one or more processors and/or other components. The electronic storage may
store information relating to one or more wells, information relating to strain, time-strain
information, information relating to time-strain, information relating to velocity-strain,
velocity-strain information, information relating to velocity-strain per strain, information
relating to one or more types of rock, and/or other information.
[0009]The processor(s) may be configured by machine-readable instructions.
Executing the machine-readable instructions may cause the processor(s) to facilitate
estimating strain along a well. The machine-readable instructions may include one or more computer program components. The computer program components may include one or more of a time-strain information component, a velocity-strain per strain information component, a strain component, and/or other computer program components.
[0010]The time-strain information component may be configured to obtain time-strain
information of a well and/or other information. The time-strain information may
characterize time-strain of the well as a function of distance along the well. The time
strain of the well may be measured via one or more interior fiber optic cables within the
well. The well may be adjacent to one or more types of rock. The type(s) of rock
adjacent to the well may include a first type of rock and/or other types of rock.
[0011]In some implementations, interior fiber optic cable(s) may be positioned within a
casing of the well. In some implementations, the interior fiber optic cable(s) may be
clamped to a tubing of the well. In some implementations, the interior fiber optic
cable(s) may be located within the tubing of the well. In some implementations, the well
may not include an exterior fiber optic cable coupled to the type(s) of rock adjacent to
the well.
[0012]The velocity-strain per strain information component may be configured to obtain
velocity-strain per strain information for the well, and/or other information. The velocity
strain per strain information may characterize one or more values of velocity-strain per
strain corresponding to the type(s) of rock adjacent to the well. The value(s) of velocity
strain per strain may include a first value of velocity-strain per strain corresponding to
the first type of rock adjacent to the well. The first value of velocity-strain per strain may be determined based on fiber optic measurement of time-strain and strain of another well different from the well.
[0013]In some implementations, one or more exterior fiber optic cables may be
positioned outside a casing of the other well. The exterior fiber optic cable(s) may be
coupled to the first type of rock adjacent to the other well. The strain of the other well
may be measured via the exterior fiber optic cable(s). In some implementations, the
exterior fiber optic cable(s) may be coupled to the first type of rock adjacent to the other
well via cementing of the exterior fiber optic cable(s) between the casing of the other
well and the first type of rock adjacent to the other well.
[0014]In some implementations, the time-strain of the other well may be measured via
the exterior fiber optic cable(s) of the other well. In some implementations, the time
strain of the other well may be measured via one or more interior fiber optic cables
within the other well.
[0015]In some implementations, one or more fiber optic strain sensors may be
positioned at one or more locations along the exterior fiber optic cable(s) of the other
well. The fiber optic strain sensor(s) may be configured to measure helical strain at the
location(s) along the exterior fiber optic cable(s).
[0016]The strain component may be configured to estimate the strain of the well as the
function of distance along the well. The strain of the well may be estimated based on
(1) the time-strain of the well as the function of distance along the well, (2) the value(s)
of velocity-strain per strain corresponding to the type(s) of rock adjacent to the well,
and/or other information. The strain of the well adjacent to the first type of rock may be
estimated based on the time-strain of the well along the first type of rock, the first value of velocity-strain per strain corresponding to the first type of rock, and/or other information.
[0017]In some implementations, one or more mechanical earth models may be
calibrated and/or verified for subsurface strain forecasting based on the strain of the
well, and/or other information.
[0018]These and other objects, features, and characteristics of the system and/or
method disclosed herein, as well as the methods of operation and functions of the
related elements of structure and the combination of parts and economies of
manufacture, will become more apparent upon consideration of the following description
and the appended claims with reference to the accompanying drawings, all of which
form a part of this specification, wherein like reference numerals designate
corresponding parts in the various figures. It is to be expressly understood, however,
that the drawings are for the purpose of illustration and description only and are not
intended necessarily as a definition of the limits of the invention. As used in the
specification and in the claims, the singular form of "a," "an," and "the" include plural
referents unless the context clearly dictates otherwise.
[0019]The present disclosure relates to estimating strain along a well. Strain and time
strain measurement in a well enables derivation of a constant that links the two.
Knowledge of the constant along with time-strain measurement at another well enables
estimation of strain at the other well.
[0020]The methods and systems of the present disclosure may be implemented by a
system and/or in a system, such as a system 10 shown in FIG. 1. The system 10 may include one or more of a processor 11, an interface 12 (e.g., bus, wireless interface), an electronic storage 13, a display 14, and/or other components. Time-strain information of a well, velocity-strain per strain information for the well, and/or other information may be obtained by the processor 11. The time-strain information of the well may characterize time-strain of the well as a function of distance along the well. The time strain of the well may be measured via an interior fiber optic cable within the well. The well may be adjacent to one or more types of rock, such as a first type of rock and/or other types of rock. The velocity-strain per strain information for the well may characterize one or more values of velocity-strain per strain corresponding to the type(s) of rock adjacent to the well. The value(s) of velocity-strain per strain may include a first value of velocity-strain per strain corresponding to the first type of rock adjacent to the well. The first value of velocity-strain per strain may be determined based on fiber optic measurement of time-strain and strain of another well different from the well, and/or other information. The strain of the well as the function of distance along the well may be estimated by the processor 11 based on (1) the time-strain of the well as the function of distance along the well, (2) the value(s) of velocity-strain per strain corresponding to the type(s) of rock adjacent to the well, and/or other information. The strain of the well adjacent to the first type of rock may be estimated based on the time-strain of the well along the first type of rock, the first value of velocity-strain per strain corresponding to the first type of rock, and/or other information.
[0021]The electronic storage 13 may be configured to include electronic storage
medium that electronically stores information. The electronic storage 13 may store
software algorithms, information determined by the processor 11, information received remotely, and/or other information that enables the system 10 to function properly. For example, the electronic storage 13 may store information relating to one or more wells, information relating to strain, time-strain information, information relating to time-strain, information relating to velocity-strain, velocity-strain per strain information, information relating to velocity-strain per strain, information relating to one or more types of rock, and/or other information.
[0022]The display 14 may refer to an electronic device that provides visual presentation
of information. The display 14 may include a color display and/or a non-color display.
The display 14 may be configured to visually present information. The display 14 may
present information using/within one or more graphical user interfaces. For example,
the display 14 may present information relating to strain, time-strain, velocity-strain,
velocity-strain per strain, types of rock, mechanical earth models, subsurface strain
forecasting, and/or other information. For instance, the display 14 may present
estimation of strain along a well using time-strain and values of velocity-strain per strain,
and/or subsurface strain forecasted by a mechanical earth model.
[0023]Strain may refer to deformation in and/or change in shape of a material, such as
rock, cement, casing, tubing, fiber-optic cable, and/or other materials. Strain may be
caused due to force/stress being applied to the materials. Examples of strain in rock
include folding, faulting, fracturing, tension, and/or compression of rock. Strain may
include vertical strain, horizontal strain, and/or other strain. Strain may be defined as a
ratio of change in a dimension (e.g., length, volume) to the initial dimension. For
example, vertical strain (zz) may be defined as a ratio of change in vertical dimension of rock to the initial vertical dimension of rock: Ezz = Az/z, where Az is vertical compaction or dilation relative to the original length z.
[0024]Strain in rock may cause the properties of the rock to change (e.g., change in
porosity of rock), which may change the velocity of seismic wave traveling through the
rock to be changed. For example, compression of rock may result in faster seismic
wave velocity through the rock. Where Ezz 0, propagation velocity of seismic wave
may change in the rock, resulting in velocity-strain (Aviv), a ratio of change in velocityAv
to original velocity v. Change in velocity may change seismic wave propagation time
through the rock (time it takes for a seismic wave to move through the rock).
Additionally, strain may change the thickness of the rock (e.g., rock compaction
resulting in thinner rock), further changing the seismic wave propagation time through
the rock. That is, strain may decrease the distance that the seismic wave must travel
through the rock. These changes may result in time-strain (At/t), a ratio of change in
seismic wave propagation time (At) to original seismic wave propagation time (t).
[0025]Subsurface strain estimation may refer to estimation of strain beneath the
surface of the Earth. Subsurface strain estimation may refer to estimation of strain
underground. Subsurface strain estimation may include estimation of subsurface strain
in the past (e.g., using measurements from the past), estimation of current subsurface
strain (e.g., using current measurements), and/or estimation of subsurface strain in the
future (e.g., using a model such as a Mechanical Earth Model (MEM)). Estimation of
subsurface strain in the future may be referred to as subsurface strain forecasting
(SSSF).
[0026]A MEM may represent the mechanical properties of rocks, including elastic
moduli, fractures, stresses, temperatures, pressure conditions, and/or other mechanical
properties of rock. A MEM may include a numerical representation of the state of stress
and rock mechanical properties for a specific stratigraphic section in a field or a basin.
A MEM may include a repository of data-measurements and models-representing
the mechanical properties of rocks and fractures as well as the stresses, pressures, and
temperatures acting on them at depth.
[0027]A MEM may be used to understand subsurface configurations and/or changes in
subsurface configurations. A MEM may be used for analysis of well operations, such as
for oil, gas, and/or C02 sequestration and fluid injection management including
reservoir and overburden. For example, a MEM may be used to understand how rocks
change, in response to drilling, completion, and production operations. Data points in
an MEM may be referenced to its 3D spatial coordinates and time of sample collection.
[0028]MEM calibration and verification may be an imperative part of the SSSF process.
A typical MEM calibration process may comprises modifying the model boundary
conditions, the regional tectonic displacement field, and/or material properties to best fit
observed data. Fiber optic cables may be used to perform direct and/or indirect
measurement of strain. Fiber optic measurement of strain may be used for MEM
calibration and/or verification.
[0029]Measurement and/or estimation of strain along a well may be used for analysis of
well and/or well operations. For example, measurement and/or estimation of strain
along a well may be used to calibrate and/or verify a MEM. As another example, measurement and/or estimation of strain along a well may be used to determine the integrity of the well. Other uses of strain measurement and estimation are contemplated.
[0030]Strain along a well may refer to/include strain of the well. Strain along a well may
refer to/include strain in the well. Strain along a well may refer to/include strain in
materials/media around the well. Strain along a well may refer to/include strain in
materials/media adjacent to the well. For example, strain along a well may refer to
strain in rock, cement, and/or other materials around/adjacent to the well. Strain along
a well may refer to values of strain at different positions along the well. For example, for
a vertical well, strain along a well may refer to values of strain at different depths along
the well. Strain along a well may include a vertical component, a lateral component,
and/or other directional components.
[0031]A well may refer to a hole or a tunnel in the ground. A well may be drilled in one
or more directions. For example, a well may include a vertical well, a horizontal well, a
deviated well, and/or other type of well. A well may be drilled in the ground for
exploration and/or recovery of natural resources in the ground. For example, a well
may be drilled in the ground to aid in extraction and/or production of hydrocarbons. As
another example, a well may be drilled in the ground for fluid injection. Application of
the present disclosure to other types of wells and wells drilled for other purposes are
contemplated.
[0032]A well may be drilled into a subsurface region using practically any drilling
technique and equipment known in the art, such as geosteering, directional drilling, etc.
Drilling a wellbore may include using a tool, such as a drilling tool that includes a drill bit
and a drill string. Drilling fluid, such as drilling mud, may be used while drilling in order
to cool the drill tool and remove cuttings. Other tools may also be used while drilling or
after drilling, such as measurement-while-drilling (MWD) tools, seismic-while-drilling
(SWD) tools, wireline tools, logging-while-drilling (LWD) tools, and/or other downhole
tools. After drilling to a predetermined depth, the drill string and the drill bit may be
removed, and then the casing, the tubing, and/or other equipment may be installed
according to the design of the well. The equipment to be used in drilling a well may be
dependent on the design of the well, the subsurface region, the hydrocarbons, and/or
other factors.
[0033]A well may include a plurality of components, such as, but not limited to, a
casing, a liner, a tubing string, a heating element, a sensor, a packer, a screen, a gravel
pack, artificial lift equipment (e.g., an electric submersible pump (ESP)), tubing, and/or
other components. If a wellbore is drilled offshore, the wellbore may include one or
more of the previous components plus other offshore components, such as a riser. A
wellbore may also include equipment to control fluid flow into the wellbore, control fluid
flow out of the wellbore, or any combination thereof. For example, a well may include a
wellhead, a blowout preventer (BOP), a choke, a valve, and/or other control devices.
These control devices may be located on the surface, under the surface (e.g., downhole
in the well), or any combination thereof. In some embodiments, same control devices
may be used to control fluid flow into and out of a well. In some embodiments, different
control devices may be used to control fluid flow into and out of a well. In some
embodiments, the rate of flow of fluids through a well may depend on the fluid handling capacities of the surface facility that is in fluidic communication with the well. The equipment to be used in controlling fluid flow into and out of a well may be dependent on the well, the subsurface region, the surface facility, and/or other factors. Moreover, sand control equipment and/or sand monitoring equipment may also be installed (e.g., downhole and/or on the surface). A well may also include any completion hardware that is not discussed separately. The term "well" may be used synonymously with the terms
"borehole," "wellbore," or "well bore." The term "well" or "wellbore" is not limited to any
description or configuration described herein.
[0034]FIG. 3 illustrates an example well 300. The well 300 may be adjacent to (e.g.,
surrounded by) different types of rock, such as Rock A, Rock B, and Rock C. The well
300 may include a casing 312, a tubing 314 within the casing 312, and/or other
components. The volume between the casing 312 and the adjacent rock may be filled
with cement 320. The cement 320 may physically/rigidly couple the casing 312 to the
adjacent rock. Use of other materials between the casing 312 and the adjacent rock is
contemplated.
[0035]A fiber optic cable outside a casing may be referred to as an exterior fiber optic
cable. A fiber optic cable within a casing may be referred to as an interior fiber optic
cable. The well 300 may not include exterior fiber optic cables that are positioned to
directly measure strain along the well 300. For example, no exterior fiber optic cables
may exist between the casing 312 and the rock adjacent to the casing 312. No exterior
fiber optic cables may be cemented between the casing 312 and the rock adjacent to
the casing 312. Thus, the well 300 may not include any exterior fiber optic cables coupled to the rock adjacent to the well 300. In some implementations, the well 300 may be a well in which no exterior fiber optic cables were installed during well completion. For example, the well 300 may be an existing well or a legacy well.
[0036]It may be impractical/impossible to install an exterior fiber optic cable to directly
measure strain along the well 300. For example, it may be too costly and/or time
consuming to change the well 300 by inserting an exterior fiber optic cable between the
well 300 and the rock adjacent to the well. On the other hand, it may be possible to
insert one or more interior fiber optic cables within the casing 312. For example, the
well 300 may include an interior fiber optic cable 324 within the casing 312. The interior
fiber optic cable 324 may run along the length of the well 300. In some
implementations, the interior fiber optic cable 324 may be attached to the tubing 314.
The interior fiber optic cable 324 may be attached to the tubing 314 from outside, within,
or inside the tubing. For example, the interior fiber optic cable 324 may be clamped to
the tubing 314 (at one or more locations along the tubing 314) or built into the tubing
314. Other attachment of the interior fiber optic cable 324 to the tubing 314 is
contemplated. In some implementations, the interior fiber optic 324 cable may not be
attached to the tubing 314. For example, the interior fiber optic cable 324 may hang
inside the casing 312 without touching the tubing 314. The interior fiber optic cable 324
may hang inside the tubing 314 without touching the tubing 314.
[0037]The interior fiber optic cable 324 may be used to measure time-strain of the well
300. The strain along the well 300 (e.g., the strain in the rock adjacent to the well 300
and/or in the cement 320) may cause seismic wave propagation time to change along
the well 300 (e.g., through the rock and/or the cement 320). Seismic wave may be propagated near/within the well 300 using a seismic source 330. A seismic source may refer to a device that generates seismic energy. A seismic source may refer to a device that propagates seismic wave through one or more materials.
[0038]The change in seismic wave propagation time (difference in seismic wave
propagation times before and after strain) may be measured via the interior fiber optic
cable 324 using an interrogator 328. The interior fiber optic cable 324 may change its
shape (e.g., move, flex, vibrate, be squeezed) when it is hit by a seismic wave, and the
change in the shape of the interior fiber optic cable 324 (e.g., causing change in
refractive index properties) may be detected by the interrogator 328.
[0039]The interrogator 328 may be an optoelectronic instrument that acquires data
using fiber optic cables. The interrogator 328 may include a source of light and a
receiver of light. The light transmitted into a fiber optic cable by the interrogator 328
may be received by the interrogator 328. The interrogator 328 may use the
characteristic of the received light to generate sensor data, such as how, when, and/or
where the shape of the fiber optic cable changed, which may be used to determine
when and/or where seismic wave hit the fiber optic cable. This information may be used
to determine seismic wave propagation time, change in seismic wave propagation time,
and/or time-strain. The interrogator 328 may measure time-strain at different positions
along the interior fiber optic cable 324, which results in measurement of time-strain at
different positions along the well 300. Thus, the interrogator 328 may measure time
strain of the well 300 as a function of distance along the well 300 (e.g., measure time
strain of the well 300 at different depths). The interior fiber optic cable 324 and the
interrogator 328 may be used to perform time-strain monitoring of the well 300. An example fiber optic system that enables time-strain measurement is Distributive
Acoustic Sensing. Use of other fiber optic system to measure time-strain is
contemplated. In some implementations, measurement of seismic wave propagation
time and/or change in seismic wave propagation time may be used to determine
seismic wave velocity and/or velocity-strain.
[0040]The extent to the measured seismic wave propagation time, the measured
change in seismic wave propagation time, and/or the measured time-strain is indicative
of strain of the well 300 may depend on the proximity of the seismic source 330 to the
well 300. If the seismic source 330 is laterally close to the well 300, then the seismic
wave propagated by the seismic source 330 may travel over small lateral distance
before hitting/being measured by the interior fiber optic cable 324, and the measured
seismic wave propagation time, the measured change in seismic wave propagation
time, and/or the measured time-strain may be indicative of strain of materials within a
small lateral area adjacent to the well 300 (e.g., small aperture around the well 300,
small lateral area between the seismic source 330 and the well 300, small area/volume
over which the seismic wave traveled before hitting/being measured by the interior fiber
optic cable 324). If the seismic source 330 is laterally farther from the well 300, then the
seismic wave propagated by the seismic source 330 may travel over large lateral
distance before hitting/being measured by the interior fiber optic cable 324, and the
measured seismic wave propagation time, the measured change in seismic wave
propagation time, and/or the measured time-strain may be indicative of strain of
materials within a large lateral area adjacent to the well 300 (e.g., large aperture around
the well 300, large lateral area between the seismic source 330 and the well 300, large area/volume over which the seismic wave traveled before hitting/being measured by the interior fiber optic cable 324).
[0041]If the interior fiber optic cable 324 is attached to the tubing 314, the
characteristics of the light received by the interrogator 328 may be used to measure
strain of the tubing 314. That is, the strain of the tubing 314 may be directly measured
via the interior fiber optic cable 324. The strain of the tubing 314 may be compared to
the strain of the well 300 estimated using the time-strain of the well 300 to determine
whether the strain of the tubing 314 may be used as a substitute for the strain of the
well 300. The strain of the tubing 314 may be compared to the strain of the well 300
estimated using the time-strain of the well 300 to determine whether they are or are not
consistent with each other. An example fiber optic system that enables strain
measurement is Distributive Strain Sensing and/or Direct Strain Sensing. Use of other
fiber optic system to measure strain is contemplated. I
[0042]FIG. 4 illustrates an example well 400. The well 400 may be adjacent to (e.g.,
surrounded by) different types of rock, such as Rock A, Rock B, and Rock C. The well
400 may include a casing 412, a tubing 414 within the casing 412, and/or other
components. The volume between the casing 412 and the adjacent rock may be filled
with cement 420. The cement 420 may physically/rigidly couple the casing 412 to the
adjacent rock. Use of other materials between the casing 412 and the adjacent rock is
contemplated.
[0043]The well 400 may include one or more exterior fiber optic cables that are
positioned to directly measure strain along the well 400. For example, an exterior fiber
optic cable 422 may exist between the casing 412 and the rock adjacent to the casing
412. The exterior fiber optic cable 422 may be cemented between the casing 412 and
the rock adjacent to the casing 412. Thus, the well 400 may include the exterior fiber
optic cable 422 coupled to the rock adjacent to the well 400. In some implementations,
the well 400 may be a well in which exterior fiber optic cable(s) were installed during
well completion. For example, the well 400 may be a new well.
[0044]The exterior fiber optic cable 422 may be used to directly measure strain along
the well 400. Coupling between the exterior fiber optic cable 422 and the rock adjacent
to the well 400 may cause strain in the rock adjacent to well 400 to appear in the
exterior fiber optic cable 422. Strain in the rock adjacent to the well 400 may cause
strain in the cement 420, which may cause strain in the exterior fiber optic cable 422.
Thus, measurement of strain along the exterior fiber optic cable 422 may be used as
measurement of strain along the well 400. The strain along the exterior fiber optic cable
422 may be measured by an interrogator 426 without a seismic source as the change in
shape of the exterior fiber optic cable 422 is caused by the strain in the cement 420.
The interrogator 426 may measure strain at different positions along the exterior fiber
optic cable 422, which results in measurement of strain at different positions along the
well 400. Thus, the interrogator 426 may measure strain of the well 400 as a function of
distance along the well 400 (e.g., measure strain of the well 400 at different depths).
The exterior fiber optic cable 422 and the interrogator 426 may be used to perform
strain monitoring of the well 400.
[0045]In some implementations, the exterior fiber optic cable 422 may be used to
measure time-strain of the well 400. The strain in the rock adjacent to the well 400
and/or in the cement 420 may cause seismic wave propagation time to change through the rock and/or the cement 420. Seismic wave may be propagated near/within the well
400 using a seismic source 430. The change in seismic wave propagation time
(difference in seismic wave propagation times) may be measured via the exterior fiber
optic cable 422 using the interrogator 426. The exterior fiber optic cable 422 may
change its shape (e.g., move, flex, vibrate, be squeezed) when it is hit by a seismic
wave, and the change in the shape of the exterior fiber optic cable 422 may be detected
by the interrogator 426.
[0046]The interrogator 426 may measure time-strain at different positions along the
exterior fiber optic cable 422, which results in measurement of time-strain at different
positions along the well 400. Thus, the interrogator 426 may measure time-strain of the
well 400 as a function of distance along the well 400 (e.g., measure time-strain of the
well 400 at different depths). The exterior fiber optic cable 422 and the interrogator 426
may be used to perform time-strain monitoring of the well 400. In some
implementations, measurement of seismic wave propagation time and/or change in
seismic wave propagation time may be used to determine seismic wave velocity and/or
velocity-strain.
[0047]In some implementations, the well 400 may include one or more interior fiber
optic cables within the casing 412. For example, the well 400 may include an interior
fiber optic cable 424 within the casing 412. The interior fiber optic cable 424 may run
along the length of the well 400. In some implementations, the interior fiber optic cable
424 may be attached to the tubing 414. For example, the interior fiber optic cable 424
may be clamped to the tubing 414 or built into the tubing 414. Other attachment of the interior fiber optic cable 424 to the tubing 414 is contemplated. In some implementations, the interior fiber optic cable 424 may not be attached to the tubing
414. For example, the interior fiber optic cable 424 may hang inside the casing 412
without touching the tubing 414.
[0048]The interior fiber optic cable 424 may be used to measure time-strain of the well
400. The strain in the rock adjacent to the well 400 and/or in the cement 420 may
cause seismic wave propagation time to change through the rock and/or the cement
420. Seismic wave may be propagated near/within the well 400 using the seismic
source 430. The change in seismic wave propagation time (difference in seismic wave
propagation times) may be measured via the interior fiber optic cable 424 using the
interrogator 428. The interior fiber optic cable 424 may change its shape (e.g., move,
flex, vibrate, be squeezed) when it is hit by a seismic wave, and the change in the
shape of the interior fiber optic cable 424 may be detected by the interrogator 428.
[0049]The interrogator 428 may measure time-strain at different positions along the
interior fiber optic cable 424, which results in measurement of time-strain at different
positions along the well 400. Thus, the interrogator 428 may measure time-strain of the
well 400 as a function of distance along the well 400 (e.g., measure time-strain of the
well 400 at different depths). The interior fiber optic cable 424 and the interrogator 428
may be used to perform time-strain monitoring of the well 400. In some
implementations, measurement of seismic wave propagation time and/or change in
seismic wave propagation time may be used to determine seismic wave velocity and/or
velocity-strain.
[0050]In some implementations, time-strain of the well 400 may be measured via both
the exterior fiber optic cable 422 and the interior fiber optic cable 424. These
measurements may be compared to determine whether they are or are not consistent
with each other. The measurements may be compared to determine whether one or
more time-strain measurements should be adjusted when being used for strain
estimation. For example, there may be differences between time-strain measured by
the exterior fiber optic cable 422 and the interior fiber optic cable 424. Time-strain
measured via the exterior fiber optic cable 422 may provide more accurate estimation of
strain along the well 400 than time-strain measured via the interior fiber optic cable 424.
Differences between time-strain measured via the exterior fiber optic cable 422 and the
interior fiber optic cable 424 may be used to adjust the time-strain measured via the
interior fiber optic cable 424, and the adjusted time-strain measurement may be used to
estimate strain along the well 400 more accurately.
[0051]If the interior fiber optic cable 424 is attached to the tubing 414, the interior fiber
optic cable 424 may be used by the interrogator 428 to measure strain of the tubing
414. That is, the strain of the tubing 414 may be directly measured via the interior fiber
optic cable 424. The strain of the tubing 414 may be compared to the strain of the well
400 measured via the exterior fiber optic cable 422 to determine whether the strain of
the tubing 414 may be used as a substitute for the strain of the well 400. The strain of
the tubing 414 measured via the interior fiber optic cable 424 may be compared to the
strain of the well 400 measured via the exterior fiber optic cable 422 to determine
whether they are or are not consistent with each other.
[0052]In some implementations, one or more fiber optic strain sensors may be
positioned along one or more fiber optic cables. For example, one or more fiber optic
strain sensors may be positioned at one or more locations along the exterior fiber optic
cable 422. A fiber optic strain sensor may include one or more fiber optic cables
wrapped around in a helical manner (e.g., in a spiral). The fiber optic strain sensor(s)
may be configured to measure helical strain at corresponding location(s) along the fiber
optic cable(s). Helical strain may include lateral/side-way strain. The fiber optic strain
sensor(s) may be configured to measure strains in three component directions (e.g., x,
y, z).
[0053]Measurement of strain and time-strain (and/or velocity-strain) of a well may
enable determination of value(s) of velocity-strain per strain corresponding to type(s) of
rock adjacent to well. That is, fiber optic measurement of strain and time-strain of a well
may be used to calculate values of velocity-strain per strain corresponding to type(s) of
rock adjacent to well. Values of velocity-strain per strain may vary over rock type.
Velocity-strain per strain may be referred to as R-factor (R). R-factor is described in
Hatchell, P. & Bourne, S., "Rocks under strain: Strain-induced time-lapse time shifts are
observed for depleting reservoirs," The Leading Edge, 24, 1222-1225 (2005). A value
of velocity-strain per strain corresponding to a type of rock may be a constant that links
strain and time-strain for the type of rock. Knowledge of the value of velocity-strain per
strain corresponding to a type of rock may enable strain estimation at a well adjacent to
the same type of rock based on time-strain measurement at the well.
[0054]Values of velocity-strain per strain (R) may be equal to a negative ratio of
velocity-strain (Av/v) to strain (E): R = -(Av/v)/. Velocity-strain (Av/v) may be defined in terms of velocity-strain per strain (R) as negative of velocity-strain per strain (R) multiplied by strain (E): Av/v = -RE. Time-strain (At/t) may be defined in terms of velocity strain per strain (R) as one plus velocity-strain per strain (R), multiplied by strain (E):AtIt
= (1+R)E.
[0055]Thus, knowledge of two of strain, time-strain, and velocity-strain per strain
enables determination (e.g., calculation, estimation) of the third. For example,
knowledge of strain and time-strain for a rock type enables determination of the value of
velocity-strain per strain corresponding to the rock type. Knowledge of time-strain and
value of velocity-strain per strain for a rock type enables determination of strain in the
rock type. Similarly, knowledge of two of strain, velocity-strain, and velocity-strain per
strain enables determination of the third. For example, knowledge of strain and
velocity-strain for a rock type enables determination of the value of velocity-strain per
strain corresponding to the rock type. Knowledge of velocity-strain and value of
velocity-strain per strain for a rock type enables determination of strain in the rock type.
Values of velocity-strain per strain determined for rock types adjacent to a well may be
used to determine strain at another well using time-strain measurements at the other
well.
[0056]For example, referring to FIG. 4, fiber optic measurement of strain (E) of the well
400 along Rock A (via the exterior fiber optic cable 422) and fiber optic measurement of
time-strain (At/t) of the well 400 along Rock A (via the exterior fiber optic cable 422
and/or the interior fiber optic cable 424) may be used to determine value of velocity
strain per strain (RA) corresponding to Rock A. Fiber optic measurement of strain (E) of
the well 400 along Rock B and fiber optic measurement of time-strain (At/t) of the well
400 along Rock B may be used to determine value of velocity-strain per strain (RB)
corresponding to Rock B. Fiber optic measurement of strain (E) of the well 400 along
Rock C and fiber optic measurement of time-strain (At/t) of the well 400 along Rock C
may be used to determine value of velocity-strain per strain (Rc) corresponding to Rock
C. Thus, fiber optic measurement of strain and time-strain of the well 400 may be used
to determine values of velocity-strain per strain corresponding to types of rock adjacent
to the well 400. A well from which values of velocity-strain per strain for rock types are
determined, such as the well 400, may be referred to as an R-factor calibration
well/strain calibration well/calibration well.
[0057]One or more of the values of velocity-strain per strain determined from a R-factor
calibration well may be used in one or more other wells to estimate strain at the other
well(s). The value(s) of velocity-strain per strain may be used in combination with fiber
optic measurement of time-strain (and/or velocity-strain) at the other well(s) to estimate
strain of the other well(s). Values of velocity-strain per strain for rock types may enable
fiber optic measurement of time-strain (and/or velocity-strain) of a well to be used to
back-calculate strain of the well. Values of velocity-strain per strain may be used to
perform strain estimation for well in which direct fiber optic measurement of strain is not
possible. The values of velocity-strain per strain from R-factor calibration wells may be
combined with fiber optic measurement of time-strain (and/or velocity-strain) to enable
strain estimation in wells that have same/similar types of rock as the R-factor calibration
wells.
[0058]For example, referring to FIG. 3, direct fiber optic measurement of strain along
the well 300 may not be possible due to lack of exterior fiber optic cable between the casing 312 and the rock adjacent to the well 300. However, the types of rock adjacent to the well 300 may be the same types of rock adjacent to the well 400. Values of velocity-strain per strain (RA, RB, RC) determined using fiber optic measurement of strain and time-strain of the well 400 may be used to estimate strain along the well 300. For example, strain of the well 300 adjacent to Rock A may be estimated based on time strain of the well 300 along Rock A (measured via the interior fiber optic cable 324) and the value of velocity-strain per strain (RA) corresponding to Rock A. Strain of the well
300 adjacent to Rock B may be estimated based on time-strain of the well 300 along
Rock B and the value of velocity-strain per strain (RB) corresponding to Rock B. Strain
of the well 300 adjacent to Rock C may be estimated based on time-strain of the well
300 along Rock C and the value of velocity-strain per strain (Rc) corresponding to Rock
C. A well in which strain is estimated using time-strain measurement (and/or velocity
strain measurement) and values of velocity-strain per strain, such as the well 300, may
be referred to as a strain-estimation well. A strain-estimation well may be linked to one
or more R-factor calibration wells based on types of rock adjacent to the
wells/corresponding values of velocity-strain per strain.
[0059]Values of velocity-strain per strain for a strain-estimation well may be determined
from one or more R-factor calibration wells. For example, a strain-estimation well may
be adjacent to three types of rock, such as the well 300. An R-factor calibration well
may be adjacent to the same three types of rock, such as the well 400. Values of
velocity-strain per strain for the well 300 may be determined from the well 400. As
another example, values of velocity-strain per strain for the well may be determined
from multiple R-factor calibration wells. For instance, a value of velocity-strain per strain for one type of rock may be determine from one R-factor calibration well (adjacent to the same one type of rock) while values of velocity-strain per strain for the other two types of rock may be determined from another R-factor calibration well (adjacent to the same two types of rock). Alternative, a value of velocity-strain per strain for individual types of rock may be determine from different R-factor calibration wells.
[0060]In some implementations, a value of velocity-strain per strain for a particular type
of rock may be determined from multiple R-factor calibration wells. For example,
separate values of velocity-strain per strain for a particular type of rock may be
determined from multiple R-factor calibration wells (each adjacent to the same type of
rock), and the separate values may be combined (e.g., averaged) for use in strain
estimation at a strain-estimation well. As another example, none of the R-factor
calibration wells may be adjacent to the same type of rock as the rock adjacent to the
strain-estimation well. Values of velocity-strain per strain for different types of rock from
the multiple R-factor calibration wells may be combined to estimate the value of
velocity-strain per strain for the rock adjacent to the strain-estimation well. That is, the
value of velocity-strain per strain for the rock adjacent to the strain-estimation well may
be estimated by combining values of velocity-strain corresponding to different types of
rock. For instance, averaged properties of two different types of rock may match the
properties of the rock adjacent to the strain-estimation well. The values of velocity
strain per strain for the two different types of rock may be combined to estimate the
value of velocity-strain per strain for the rock adjacent to the strain-estimation well.
Other combination of velocity-strain per strain is contemplated.
[0061]Placement and number of components shown in FIGS 3 and 4 are merely
provided as examples and are not meant to be limiting. The present disclosure may be
applied to wells with different components and/or different component placement. For
example, while the seismic sources 330, 430 are shown in FIGS. 3 and 4 as being
located at the surface, a seismic source may be located partially or totally under the
surface. For example, a seismic source may be located downhole, within, or below a
well. For instance, a well may include an open-well and a seismic source may be
located below the open well.
[0062]Referring back to FIG. 1, the processor 11 may be configured to provide
information processing capabilities in the system 10. As such, the processor 11 may
comprise one or more of a digital processor, an analog processor, a digital circuit
designed to process information, a central processing unit, a graphics processing unit, a
microcontroller, an analog circuit designed to process information, a state machine,
and/or other mechanisms for electronically processing information. The processor 11
may be configured to execute one or more machine-readable instructions 100 to
facilitate estimating strain along a well. The machine-readable instructions 100 may
include one or more computer program components. The machine-readable
instructions 100 may include a time-strain information component 102, a velocity-strain
per strain information component 104, a strain component 106, and/or other computer
program components.
[0063]The time-strain information component 102 may be configured to obtain time
strain information of a well and/or other information. The well for which time-strain
information is obtained may include a well at which strain is to be estimated using time strain measurement (and/or velocity-strain measurement) and value(s) of velocity-strain per strain. The well for which time-strain information is obtained may include a strain estimation well, such as an existing well or a legacy well. The well may be adjacent to one or more types of rock. For example, referring to FIG. 3, the types of rock adjacent to the well may include Rock A, Rock B, Rock, C, and/or other types of rock.
[0064]Obtaining time-strain information may include one or more of accessing,
acquiring, analyzing, determining, examining, identifying, loading, locating, opening,
receiving, retrieving, reviewing, selecting, storing, and/or otherwise obtaining the time
strain information. The time-strain information component 102 may obtain time-strain
information from one or more locations. For example, the time-strain information
component 102 may obtain time-strain information from a storage location, such as the
electronic storage 13, electronic storage of a device accessible via a network, and/or
other locations. The time-strain information component 102 may obtain time-strain
information from one or more hardware components (e.g., a computing device) and/or
one or more software components (e.g., software running on a computing device).
[0065]The time-strain information may characterize time-strain of the well as a function
of distance along the well. For example, for a vertical well, the time-strain information
may characterize time-strain of the well at different depths along the well. The time
strain information may characterize time-strain of the well over the entire length of the
well (e.g., from top to bottom) or for one or more portions of the well.
[0066]The time-strain information may characterize the time-strain of the well by
describing, defining, and/or otherwise characterizing the time-strain of the well. The time-strain information may characterize the time-strain of the well by including information that describes, delineates, defines, identifies, is associated with, quantifies, reflects, sets forth, and/or otherwise characterizes one or more of value, property, quality, quantity, attribute, feature, and/or other aspects of the time-strain of the well.
For example, the time-strain information may characterize the time-strain of the well by
including information that specifies values of time-strain at different locations along the
well and/or information that may be used to determine the values of time-strain at
different locations along the well. Other types of time-strain information are
contemplated.
[0067]The time-strain of the well (characterized by the time-strain information) may be
measured via one or more interior fiber optic cables within the well. For example,
referring to FIG. 3, the time-strain of the well 300 may be measured via the interior fiber
optic cable 324. Other measurements of time-strain of the well are contemplated.
[0068]In some implementations, interior fiber optic cable(s) of the well may be
positioned within a casing of the well. For example, referring to FIG. 3, the interior fiber
optic cable 324 may be positioned within the casing 312 of the well 300. In some
implementations, the interior fiber optic cable(s) may be clamped to a tubing of the well.
For example, referring to FIG. 3, the interior fiber optic cable 324 may be clamped to the
tubing 314 of the well 300. In some implementations, the interior fiber optic cable(s)
may be located within the tubing of the well. For example, the interior fiber optic
cable(s) may be built into the tubing 314. In some implementations, the well may not
include an exterior fiber optic cable coupled to the rock adjacent to the well. For example, referring to FIG. 3, no exterior fiber optic cable may be located between the casing 312 and the rock adjacent to the well 300 (e.g., no exterior fiber optic cable cemented between the casing 312 and the rock adjacent to the well 300). Direct fiber optic measurement of strain along the well 300 may not be possible due to the lack of an exterior fiber optic cable.
[0069]The velocity-strain per strain information component 104 may be configured to
obtain velocity-strain per strain information for the well, and/or other information. The
well for which velocity-strain per strain information is obtained may include a well at
which strain is to be estimated using time-strain measurement (and/or velocity-strain
measurement) and value(s) of velocity-strain per strain. The well for which velocity
strain information is obtained may include a strain-estimation well, such as an existing
well or a legacy well.
[0070]Obtaining velocity-strain per strain information may include one or more of
accessing, acquiring, analyzing, determining, examining, identifying, loading, locating,
opening, receiving, retrieving, reviewing, selecting, storing, and/or otherwise obtaining
the velocity-strain per strain information. The velocity-strain per strain information
component 104 may obtain velocity-strain per strain information from one or more
locations. For example, the velocity-strain per strain information component 104 may
obtain velocity-strain per strain information from a storage location, such as the
electronic storage 13, electronic storage of a device accessible via a network, and/or
other locations. The velocity-strain per strain information component 104 may obtain
velocity-strain per strain information from one or more hardware components (e.g., a computing device) and/or one or more software components (e.g., software running on a computing device).
[0071]The velocity-strain per strain information may characterize one or more values of
velocity-strain per strain corresponding to the type(s) of rock adjacent to the well. The
velocity-strain per strain information may characterize value(s) of velocity-strain per
strain corresponding to different types of rock adjacent to the well. For example,
referring to FIG. 3, the value(s) of the velocity-strain per strain may include the value of
velocity-strain per strain (RA) corresponding to Rock A, the value of velocity-strain per
strain (RB) corresponding to Rock B, and the value of velocity-strain per strain (Rc)
corresponding to Rock C.
[0072] The velocity-strain per strain information may characterize the value(s) of
velocity-strain per strain corresponding to rock type(s) by describing, defining, and/or
otherwise characterizing the value(s) of velocity-strain per strain corresponding to the
rock type(s). The velocity-strain per strain information may characterize the value(s) of
velocity-strain per strain corresponding to rock type(s) by including information that
describes, delineates, defines, identifies, is associated with, quantifies, reflects, sets
forth, and/or otherwise characterizes one or more of value, property, quality, quantity,
attribute, feature, and/or other aspects of the value(s) of velocity-strain per strain
corresponding to the rock type(s). For example, the velocity-strain per strain
information may characterize the value(s) of velocity-strain per strain corresponding to
rock type(s) by including information that specifies values of velocity-strain per strain
corresponding to different rock types and/or information that may be used to determine the values of velocity-strain per strain corresponding to different rock types. Other types of velocity-strain per strain information are contemplated.
[0073]The value(s) of velocity-strain per strain (characterized by the velocity-strain per
strain information) may be determined based on fiber optic measurement of time-strain
and strain of one or more other wells different from the well. The value(s) of velocity
strain per strain may be determined based on fiber optic measurement of time-strain
and strain of one or more R-factor calibration wells, such as a well in which one or more
exterior fiber optic cable are cemented between the rock and the well during well
completion. For example, values of velocity-strain per strain RA, RB, and Re may be
determined based on fiber optic measurement of time-strain and strain of the well 400
shown in FIG. 4.
[0074]In some implementations, one or more exterior fiber optic cables may be
positioned outside a casing of the other well(s) (R-factor calibration well(s)). For
example, referring to FIG. 4, the exterior fiber optic cable 422 may be positioned outside
the casing 412 of the well 400. The exterior fiber optic cable(s) may be coupled to the
rock of one or more types adjacent to the other well. For example, referring to FIG. 4,
the exterior fiber optic cable 422 may be coupled to Rock A, Rock B, and Rock C. The
strain of the other well may be measured via the exterior fiber optic cable(s). For
example, referring to FIG. 4, strain of the well 400 may be measured via the exterior
fiber optic cable 422.
[0075]In some implementations, the exterior fiber optic cable(s) may be coupled to the
rock of one or more types adjacent to the other well via cementing of the exterior fiber optic cable(s) between the casing of the other well and the rock of one or more types adjacent to the other well. For example, referring to FIG. 4, the exterior fiber optic cable
422 may be coupled to Rock A, Rock B, and Rock C via cementing of the exterior fiber
optic cable 422 between the casing 412 of the well 400 and the rock adjacent to the well
400. Cementing may result in physical/rigid coupling between the exterior fiber optic
cable 422 and the Rock A, Rock B, and Rock C. Use of other technique/materials to
create coupling between the exterior fiber optic cable(s) and the rock adjacent to the
other well are contemplated.
[0076]In some implementations, the time-strain of the other well may be measured via
the exterior fiber optic cable(s) of the other well. For example, referring to FIG. 4, the
time-strain of the well 400 may be measured via the exterior fiber optic cable 422. In
some implementations, the time-strain of the other well may be measured via one or
more interior fiber optic cables within the other well. For example, referring to FIG. 4,
the time-strain of the well 400 may be measured via the interior fiber optic cable 424.
[0077]The strain component 106 may be configured to estimate strain of the well
(strain-estimation well). Strain of the well may refer/include to strain along the well.
Strain of the well may refer to strain in the well. Strain of the well may refer to/include
strain in materials/media around the well. Strain of the well may refer to/include strain in
materials/media adjacent to the well. Estimating strain of a well may include
ascertaining, approximating, calculating, determining, establishing, finding, identifying,
obtaining, quantifying, and/or otherwise estimating the strain of the well. The strain of
the well may be estimated as the function of distance along the well. For example, for a
vertical well, the strain of the well may be estimated for different depths along the well.
[0078]The strain of the well may be estimated based on (1) the time-strain of the well
as the function of distance along the well, (2) the value(s) of velocity-strain per strain
corresponding to the type(s) of rock adjacent to the well, and/or other information. For
example, for a vertical well, strain of the well may be estimated for different depths
along the well based on (1) time-strain of the well at different depths along the well, and
(2) the values of velocity-strain per strain corresponding to type(s) of rock adjacent to
the well at different depths along the well. The strain of the well adjacent to a particular
type of rock may be estimated based on the time-strain of the well along the particular
type of rock, the value of velocity-strain per strain corresponding to the particular type of
rock, and/or other information.
[0079]For example, referring to FIG. 3, the strain of the well 300 at different depths
along Rock A may be estimated based on (1) the time-strain of the well 300 at different
depths along Rock A (measured via the interior fiber optic cable 324) and (2) the value
of velocity-strain per strain (RA) corresponding to Rock A. The strain of the well 300 at
different depths along Rock B may be estimated based on (1) the time-strain of the well
300 at different depths along Rock B (measured via the interior fiber optic cable 324)
and (2) the value of velocity-strain per strain (RB) corresponding to Rock B. The strain
of the well 300 at different depths along Rock C may be estimated based on (1) the
time-strain of the well 300 at different depths along Rock C (measured via the interior
fiber optic cable 324) and (2) the value of velocity-strain per strain (Rc) corresponding to
Rock C. In some implementations, estimation of the strain of the well using time-strain
measurement may include estimation of the strain of the well using velocity-strain
measurement. Thus, fiber optic measurements from within the well may be used to estimate strain of materials/media outside the well, enabling strain monitoring in wells that do not have exterior fiber optic cables to directly measure strain outside the well.
[0080]In some implementations, one or more mechanical earth models may be
calibrated and/or verified for subsurface strain forecasting based on the strain of the
well, and/or other information. Strain estimated using the time-strain of the well and the
value(s) of velocity-strain per strain may be used to calibrate and/or verify the MEM(s).
The MEM(s) may predict (forecast) values of strain of the well in the future (e.g., values
of strain at different locations around the well at different times). The MEM(s) may
predict (forecast) changes in strain of the well at different locations and/or at different
times.
[0081]Calibration of a MEM may refer to setting up the MEM for subsurface strain
forecasting. Calibration of a MEM using strain estimation may include setting and/or
adjusting parameters of the MEM using strain values that were estimated using the
time-strain of the well and the value(s) of velocity-strain per strain. For example,
beginning conditions for the MEM may be set for subsurface strain forecasting using the
strain of a well estimated for a particular time point/time period.
[0082]Verification of a MEM using strain estimation may include checking whether the
strain predicted/forecasted by the MEM matches the strain estimated using the time
strain of the well and the value(s) of velocity-strain per strain. For example, the MEM
may be used to predict/forecast strain of the well at a future time point/time period.
Time-strain of the well and the value(s) of velocity-strain per strain at the future time
point/time period may be used to estimate the strain of the well, and the estimated strain may be compared with the strain output by the MEM to determine whether or not the two values match. The parameters of the MEM may be adjusted based on differences between (1) the forecasted strain output by/determined from the MEM and (2) the strain estimated using the time-strain of the well and the value(s) of velocity-strain per strain.
[0083]In some implementations, the MEM(s) may be calibrated and/or verified using
direct fiber optic measurement of strain of the well (e.g., such as the strain of the well
400 measured via the exterior fiber optic cable 422). That is, if a well has one or more
exterior fiber optic cables, the direct strain measurement via the exterior fiber optic
cable(s) may be used to calibrate and/or verify the MEM(s).
[0084]Strain estimation/measurement via fiber optic cable may provide enhanced
subsurface strain sampling, such as more accurate subsurface strain sampling and/or
more frequent subsurface strain sampling. Strain estimation/measurement via fiber
optic cable may be used to increase the reliability/accuracy of the MEM in subsurface
strain forecasting. In some implementations, the time-strain and/or strain of the well
may be periodically/continuously monitored to provide periodic/continuous MEM
updating. For example, the estimated and/or measured strain of the well may be used
to adjust parameters of the MEM periodically/continuously and/or to verify the output of
the MEM periodically/continuously.
[0085]In some implementations, strain estimation/measurement via fiber optic cable
may be used to analyze one or more operations of the well. For example, strain
estimation/measurement via fiber optic cable may be used to monitor, determine, and/or
adjust well operation parameters. In some implementations, strain estimation/measurement via fiber optic cable may be used to analyze one or more conditions of the well. For example, strain estimation/measurement via fiber optic cable may be used to monitor or determine the integrity of the well. Periodic/continuous strain estimation/measurement via fiber optic cable may be used to provide periodic/continuous well integrity monitoring. Other uses of strain estimation/measurement via fiber optic cable are contemplated.
[0086]Implementations of the disclosure may be made in hardware, firmware, software,
or any suitable combination thereof. Aspects of the disclosure may be implemented as
instructions stored on a machine-readable medium, which may be read and executed
by one or more processors. A machine-readable medium may include any mechanism
for storing or transmitting information in a form readable by a machine (e.g., a
computing device). A machine-readable medium may include non-transitory computer
readable medium. For example, a tangible computer-readable storage medium may
include read-only memory, random access memory, magnetic disk storage media,
optical storage media, flash memory devices, and others, and a machine-readable
transmission media may include forms of propagated signals, such as carrier waves,
infrared signals, digital signals, and others. Firmware, software, routines, or instructions
may be described herein in terms of specific exemplary aspects and implementations of
the disclosure, and performing certain actions.
[0087]In some implementations, some or all of the functionalities attributed herein to the
system 10 may be provided by external resources not included in the system 10.
External resources may include hosts/sources of information, computing, and/or processing and/or other providers of information, computing, and/or processing outside of the system 10.
[0088]Although the processor 11, the electronic storage 13, and the display 14 are
shown to be connected to the interface 12 in FIG. 1, any communication medium may
be used to facilitate interaction between any components of the system 10. One or
more components of the system 10 may communicate with each other through hard
wired communication, wireless communication, or both. For example, one or more
components of the system 10 may communicate with each other through a network.
For example, the processor 11 may wirelessly communicate with the electronic storage
13. By way of non-limiting example, wireless communication may include one or more
of radio communication, Bluetooth communication, Wi-Fi communication, cellular
communication, infrared communication, or other wireless communication. Other types
of communications are contemplated by the present disclosure.
[0089]Although the processor 11, the electronic storage 13, and the display 14 are
shown in FIG. 1 as single entities, this is for illustrative purposes only. One or more of
the components of the system 10 may be contained within a single device or across
multiple devices. For instance, the processor 11 may comprise a plurality of processing
units. These processing units may be physically located within the same device, or the
processor 11 may represent processing functionality of a plurality of devices operating
in coordination. The processor 11 may be separate from and/or be part of one or more
components of the system 10. The processor 11 may be configured to execute one or
more components by software; hardware; firmware; some combination of software, hardware, and/or firmware; and/or other mechanisms for configuring processing capabilities on the processor 11.
[0090]It should be appreciated that although computer program components are
illustrated in FIG. 1 as being co-located within a single processing unit, one or more of
computer program components may be located remotely from the other computer
program components. While computer program components are described as
performing or being configured to perform operations, computer program components
may comprise instructions which may program processor 11 and/or system 10 to
perform the operation.
[0091]While computer program components are described herein as being
implemented via processor 11 through machine-readable instructions 100, this is merely
for ease of reference and is not meant to be limiting. In some implementations, one or
more functions of computer program components described herein may be
implemented via hardware (e.g., dedicated chip, field-programmable gate array) rather
than software. One or more functions of computer program components described
herein may be software-implemented, hardware-implemented, or software and
hardware-implemented.
[0092]The description of the functionality provided by the different computer program
components described herein is for illustrative purposes, and is not intended to be
limiting, as any of computer program components may provide more or less functionality
than is described. For example, one or more of computer program components may be
eliminated, and some or all of its functionality may be provided by other computer program components. As another example, processor 11 may be configured to execute one or more additional computer program components that may perform some or all of the functionality attributed to one or more of computer program components described herein.
[0093]The electronic storage media of the electronic storage 13 may be provided
integrally (i.e., substantially non-removable) with one or more components of the system
and/or as removable storage that is connectable to one or more components of the
system 10 via, for example, a port (e.g., a USB port, a Firewire port, etc.) or a drive
(e.g., a disk drive, etc.). The electronic storage 13 may include one or more of optically
readable storage media (e.g., optical disks, etc.), magnetically readable storage media
(e.g., magnetic tape, magnetic hard drive, floppy drive, etc.), electrical charge-based
storage media (e.g., EPROM, EEPROM, RAM, etc.), solid-state storage media (e.g.,
flash drive, etc.), and/or other electronically readable storage media. The electronic
storage 13 may be a separate component within the system 10, or the electronic
storage 13 may be provided integrally with one or more other components of the system
(e.g., the processor 11). Although the electronic storage 13 is shown in FIG. 1 as a
single entity, this is for illustrative purposes only. In some implementations, the
electronic storage 13 may comprise a plurality of storage units. These storage units
may be physically located within the same device, or the electronic storage 13 may
represent storage functionality of a plurality of devices operating in coordination.
[0094]FIG. 2 illustrates method 200 for estimating strain along a well. The operations
of method 200 presented below are intended to be illustrative. In some implementations, method 200 may be accomplished with one or more additional operations not described, and/or without one or more of the operations discussed. In some implementations, two or more of the operations may occur substantially simultaneously.
[0095]In some implementations, method 200 may be implemented in one or more
processing devices (e.g., a digital processor, an analog processor, a digital circuit
designed to process information, a central processing unit, a graphics processing unit, a
microcontroller, an analog circuit designed to process information, a state machine,
and/or other mechanisms for electronically processing information). The one or more
processing devices may include one or more devices executing some or all of the
operations of method 200 in response to instructions stored electronically on one or
more electronic storage media. The one or more processing devices may include one
or more devices configured through hardware, firmware, and/or software to be
specifically designed for execution of one or more of the operations of method 200.
[0096] Referring to FIG. 2 and method 200, at operation 202, time-strain information of a
well may be obtained. The time-strain information of the well may characterize time
strain of the well as a function of distance along the well. The time-strain of the well
may be measured via an interior fiber optic cable within the well. The well may be
adjacent to one or more types of rock, such as a first type of rock and/or other types of
rock. In some implementation, operation 202 may be performed by a processor
component the same as or similar to the time-strain information component 102 (Shown
in FIG. 1 and described herein).
[0097]At operation 204, velocity-strain per strain information for the well may be
obtained. The velocity-strain per strain information for the well may characterize one or
more values of velocity-strain per strain corresponding to the type(s) of rock adjacent to
the well. The value(s) of velocity-strain per strain may include a first value of velocity
strain per strain corresponding to the first type of rock adjacent to the well. The first
value of velocity-strain per strain may be determined based on fiber optic measurement
of time-strain and strain of another well different from the well, and/or other information.
In some implementation, operation 204 may be performed by a processor component
the same as or similar to the velocity-strain per strain information component 104
(Shown in FIG. 1 and described herein).
[0098]At operation 206, the strain of the well as the function of distance along the well
may be estimated based on (1) the time-strain of the well as the function of distance
along the well, (2) the value(s) of velocity-strain per strain corresponding to the type(s)
of rock adjacent to the well, and/or other information. The strain of the well adjacent to
the first type of rock may be estimated based on the time-strain of the well along the first
type of rock, the first value of velocity-strain per strain corresponding to the first type of
rock, and/or other information. In some implementation, operation 206 may be
performed by a processor component the same as or similar to the strain component
106 (Shown in FIG. 1 and described herein).
[0099]At operation 208, information relating to the strain of the well may be presented
on a display. The information relating to the strain of the well may include the strain
itself (e.g., visual representation of the strain) and/or information determined based on the strain. For example, information relating to the strain of the well may include subsurface strain forecasting by a mechanical earth model using the strain of the well.
For instance, the strain of the well may be used to calibrate and/or verify the mechanical
earth model for subsurface strain forecasting, and information relating to the subsurface
strain forecasting may be presented on the display. In some implementation, operation
208 may be performed using a component the same as or similar to the display 14
(Shown in FIG. 1 and described herein).
[0100]Although the system(s) and/or method(s) of this disclosure have been described
in detail for the purpose of illustration based on what is currently considered to be the
most practical and preferred implementations, it is to be understood that such detail is
solely for that purpose and that the disclosure is not limited to the disclosed
implementations, but, on the contrary, is intended to cover modifications and equivalent
arrangements that are within the spirit and scope of the appended claims. For example,
it is to be understood that the present disclosure contemplates that, to the extent possible,
one or more features of any implementation can be combined with one or more features
of any other implementation.
[0101]Throughout this specification and the claims which follow, unless the context
requires otherwise, the word "comprise", and variations such as "comprises" and
"comprising", will be understood to imply the inclusion of a stated integer or step or
group of integers or steps but not the exclusion of any other integer or step or group of
integers or steps.
[0102]The reference in this specification to any prior publication (or information derived
from it), or to any matter which is known, is not, and should not be taken as an
acknowledgment or admission or any form of suggestion that that prior publication (or
information derived from it) or known matter forms part of the common general
knowledge in the field of endeavor to which this specification relates.

Claims (19)

The claims defining the invention are as follows:
1. A system for estimating strain along a well, the system comprising:
one or more physical processors configured by machine-readable instructions to:
obtain time-strain information of the well, the time-strain information
characterizing time-strain of the well as a function of distance along the well, the
time-strain of the well measured via a first interior fiber optic cable within a casing
of the well, wherein the well is adjacent to one or more types of rock, the one or
more types of rock including a first type of rock;
obtain velocity-strain per strain information for the well, the velocity-strain
per strain information characterizing one or more values of velocity-strain per
strain corresponding to the one or more types of rock adjacent to the well, the
one or more values of velocity-strain per strain including a first value of velocity
strain per strain corresponding to the first type of rock adjacent to the well,
wherein the first value of velocity-strain per strain is determined based on fiber
optic measurement of time-strain and strain of a calibration well different from the
well, the calibration well adjacent to same type of rock as at least one of the one
or more types of rock adjacent to the well, the fiber optic measurement of the
strain of the calibration well performed via an exterior fiber optic cable of the
calibration well positioned outside a casing of the calibration well, the exterior
fiber optic cable coupled to the first type of rock adjacent to the calibration well;
and
estimate the strain of the well as the function of distance along the well
based on (1) the time-strain of the well as the function of distance along the well and (2) the one or more values of velocity-strain per strain corresponding to the one or more types of rock adjacent to the well, wherein the strain of the well adjacent to the first type of rock is estimated based on the time-strain of the well along the first type of rock and the first value of velocity-strain per strain corresponding to the first type of rock.
2. The system of claim 1, wherein the exterior fiber optic cable is coupled to the first
type of rock adjacent to the calibration well via cementing of the exterior fiber optic cable
between the casing of the calibration well and the first type of rock adjacent to the
calibration well.
3. The system of claim 1, wherein the time-strain of the calibration well is measured
via the exterior fiber optic cable.
4. The system of claim 1, wherein the time-strain of the calibration well is measured
via a second interior fiber optic cable within the calibration well.
5. The system of claim 1, wherein one or more fiber optic strain sensors are
positioned at one or more locations along the exterior fiber optic cable, the one or more
fiber optic strain sensors configured to measure helical strain at the one or more
locations along the exterior fiber optic cable.
6. The system of claim 1, wherein the first interior fiber optic cable is clamped to a
tubing of the well.
7. The system of claim 1, wherein a mechanical earth model is calibrated or verified
for subsurface strain forecasting based on the strain of the well.
8. The system of claim 1, wherein the well does not include an exterior fiber optic
cable coupled to the one or more types of rock adjacent to the well.
9. A method for estimating strain along a well, the method comprising:
obtaining time-strain information of the well, the time-strain information
characterizing time-strain of the well as a function of distance along the well, the time
strain of the well measured via a first interior fiber optic cable within a casing of the well,
wherein the well is adjacent to one or more types of rock, the one or more types of rock
including a first type of rock;
obtaining velocity-strain per strain information for the well, the velocity-strain per
strain information characterizing one or more values of velocity-strain per strain
corresponding to the one or more types of rock adjacent to the well, the one or more
values of velocity-strain per strain including a first value of velocity-strain per strain
corresponding to the first type of rock adjacent to the well, wherein the first value of
velocity-strain per strain is determined based on fiber optic measurement of time-strain
and strain of a calibration well different from the well, the calibration well adjacent to
same type of rock as at least one of the one or more types of rock adjacent to the well, the fiber optic measurement of the strain of the calibration well performed via an exterior fiber optic cable of the calibration well positioned outside a casing of the calibration well, the exterior fiber optic cable coupled to the first type of rock adjacent to the calibration well; and estimating the strain of the well as the function of distance along the well based on (1) the time-strain of the well as the function of distance along the well and (2) the one or more values of velocity-strain per strain corresponding to the one or more types of rock adjacent to the well, wherein the strain of the well adjacent to the first type of rock is estimated based on the time-strain of the well along the first type of rock and the first value of velocity-strain per strain corresponding to the first type of rock.
10. The method of claim 9, wherein the exterior fiber optic cable is coupled to the first
type of rock adjacent to the calibration well via cementing of the exterior fiber optic cable
between the casing of the calibration well and the first type of rock adjacent to the
calibration well.
11. The method of claim 9, wherein the time-strain of the calibration well is measured
via the exterior fiber optic cable.
12. The method of claim 9, wherein the time-strain of the calibration well is measured
via a second interior fiber optic cable within the calibration well.
13. The method of claim 9, wherein one or more fiber optic strain sensors are
positioned at one or more locations along the exterior fiber optic cable, the one or more
fiber optic strain sensors configured to measure helical strain at the one or more
locations along the exterior fiber optic cable.
14. The method of claim 9, wherein the first interior fiber optic cable is clamped to a
tubing of the well.
15. The method of claim 9, wherein a mechanical earth model is calibrated or verified
for subsurface strain forecasting based on the strain of the well.
16. A system for estimating strain along a well, the system comprising:
the well adjacent to one or more types of rock, the one or more types of rock
including a first type of rock, the well including a casing;
an interior fiber optic cable positioned within the casing of the well to measure
time-strain of the well; and
one or more physical processors configured by machine-readable instructions to:
obtain time-strain information of the well, the time-strain information
characterizing the time-strain of the well as a function of distance along the well,
the time-strain of the well measured via the interior fiber optic cable positioned
within the casing of the well;
obtain velocity-strain per strain information for the well, the velocity-strain
per strain information characterizing one or more values of velocity-strain per strain corresponding to the one or more types of rock adjacent to the well, the one or more values of velocity-strain per strain including a first value of velocity strain per strain corresponding to the first type of rock adjacent to the well, wherein the first value of velocity-strain per strain is determined based on fiber optic measurement of time-strain and strain of a calibration well different from the well, the calibration well adjacent to same type of rock as at least one of the one or more types of rock adjacent to the well, the fiber optic measurement of the strain of the calibration well performed via an exterior fiber optic cable of the calibration well positioned outside a casing of the calibration well, the exterior fiber optic cable coupled to the first type of rock adjacent to the calibration well; and estimate the strain of the well as the function of distance along the well based on (1) the time-strain of the well as the function of distance along the well and (2) the one or more values of velocity-strain per strain corresponding to the one or more types of rock adjacent to the well, wherein the strain of the well adjacent to the first type of rock is estimated based on the time-strain of the well along the first type of rock and the first value of velocity-strain per strain corresponding to the first type of rock.
17. The system of claim 1, wherein:
the first value of velocity-strain per strain is determined further based on the fiber
optic measurement of the time-strain and the strain of one or more other calibration
wells different from the calibration well.
18. The system of claim 1, wherein:
the one or more types of rock that are adjacent to the well further include a
second type of rock different from the first type of rock;
the one or more values of velocity-strain per strain characterized by the velocity
strain per strain information further include a second value of velocity-strain per strain
corresponding to the second type of rock adjacent to the well; and
the second value of velocity-strain per strain is determined based on the fiber
optic measurement of the time-strain and the strain of another calibration well different
from the calibration well.
19. The system of claim 1, wherein:
the one or more types of rock that are adjacent to the well further include a
second type of rock different from the first type of rock;
the one or more values of velocity-strain per strain characterized by the velocity
strain per strain information further include a second value of velocity-strain per strain
corresponding to the second type of rock adjacent to the well;
no calibration well is adjacent to the second type of rock; and
multiple values of velocity-strain per strain for different types of rock from multiple
calibration wells are combined to estimate the second value of velocity-strain per strain
corresponding to the second type of rock adjacent to the well.
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Non-Patent Citations (5)

* Cited by examiner, † Cited by third party
Title
Becker, M. W., et al., ‘Distributed Acoustic Sensing as a Distributed Hydraulic Sensor in Fractured Bedrock’, 2020, Water Resources Research, 56.9, e2020WR028140. *
Davies, K., et al., ‘Fiber Optics for Sub-Surface Strain Forecasting’, 2020, First EAGE Workshop on Fibre Optic Sensing. Vol. 2020. No. 1. *
Hatchell, P. et al., ’Rocks under strain: Strain-induced time-lapse time shifts are observed for depleting reservoirs’, 2005, The Leading Edge, 24.12, pages 1222-1225. *
Holt, R. M., et al., ‘R-From laboratory data to 4D seismic interpretation’, 2009, SEG Technical Program Expanded Abstracts 2009, pages 1960-1964. *
Li, M., et al., ‘Current and future applications of distributed acoustic sensing as a new reservoir geophysics tool’, 2015, The Open Petroleum Engineering Journal, 8.1, pages 272-281. *

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