CN117365462A - Method and system for inverting hydraulic fracture propagation leading edge by using distributed acoustic sensing - Google Patents
Method and system for inverting hydraulic fracture propagation leading edge by using distributed acoustic sensing Download PDFInfo
- Publication number
- CN117365462A CN117365462A CN202311313986.3A CN202311313986A CN117365462A CN 117365462 A CN117365462 A CN 117365462A CN 202311313986 A CN202311313986 A CN 202311313986A CN 117365462 A CN117365462 A CN 117365462A
- Authority
- CN
- China
- Prior art keywords
- fracture
- dimensionless
- radius
- crack
- strain
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Pending
Links
- 238000000034 method Methods 0.000 title claims abstract description 36
- 238000012544 monitoring process Methods 0.000 claims abstract description 19
- 239000000835 fiber Substances 0.000 claims abstract description 9
- 238000004364 calculation method Methods 0.000 claims description 18
- 238000003860 storage Methods 0.000 claims description 16
- 238000004590 computer program Methods 0.000 claims description 15
- 230000006870 function Effects 0.000 claims description 14
- 239000013307 optical fiber Substances 0.000 claims description 14
- 230000008859 change Effects 0.000 claims description 8
- 230000004069 differentiation Effects 0.000 claims description 5
- 238000004458 analytical method Methods 0.000 claims description 3
- 230000008901 benefit Effects 0.000 abstract description 6
- 238000004422 calculation algorithm Methods 0.000 abstract description 6
- 230000000694 effects Effects 0.000 abstract description 6
- 238000011161 development Methods 0.000 abstract description 4
- 238000013178 mathematical model Methods 0.000 abstract description 2
- 238000010586 diagram Methods 0.000 description 8
- 238000012545 processing Methods 0.000 description 6
- 230000004044 response Effects 0.000 description 4
- 238000005516 engineering process Methods 0.000 description 3
- 239000000243 solution Substances 0.000 description 3
- 230000001427 coherent effect Effects 0.000 description 2
- 238000006073 displacement reaction Methods 0.000 description 2
- 238000002347 injection Methods 0.000 description 2
- 239000007924 injection Substances 0.000 description 2
- 238000005259 measurement Methods 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 230000003287 optical effect Effects 0.000 description 2
- 230000001902 propagating effect Effects 0.000 description 2
- 238000004613 tight binding model Methods 0.000 description 2
- 238000000342 Monte Carlo simulation Methods 0.000 description 1
- 230000002159 abnormal effect Effects 0.000 description 1
- 238000013459 approach Methods 0.000 description 1
- 238000003491 array Methods 0.000 description 1
- 230000007547 defect Effects 0.000 description 1
- 238000009826 distribution Methods 0.000 description 1
- 230000002708 enhancing effect Effects 0.000 description 1
- 239000012530 fluid Substances 0.000 description 1
- 238000011835 investigation Methods 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 230000008569 process Effects 0.000 description 1
- 238000010223 real-time analysis Methods 0.000 description 1
- 230000035945 sensitivity Effects 0.000 description 1
- 238000010206 sensitivity analysis Methods 0.000 description 1
- 238000004088 simulation Methods 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
-
- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
- G06F30/00—Computer-aided design [CAD]
- G06F30/20—Design optimisation, verification or simulation
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
-
- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
- G06F2111/00—Details relating to CAD techniques
- G06F2111/10—Numerical modelling
-
- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
- G06F2119/00—Details relating to the type or aim of the analysis or the optimisation
- G06F2119/14—Force analysis or force optimisation, e.g. static or dynamic forces
Landscapes
- Engineering & Computer Science (AREA)
- Physics & Mathematics (AREA)
- Life Sciences & Earth Sciences (AREA)
- Geology (AREA)
- General Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Theoretical Computer Science (AREA)
- Mining & Mineral Resources (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Evolutionary Computation (AREA)
- Geometry (AREA)
- General Engineering & Computer Science (AREA)
- Computer Hardware Design (AREA)
- Fluid Mechanics (AREA)
- Acoustics & Sound (AREA)
- Remote Sensing (AREA)
- Geophysics (AREA)
- Investigating Or Analyzing Materials By The Use Of Ultrasonic Waves (AREA)
Abstract
The invention discloses a method and a system for inverting a hydraulic fracture propagation front by using distributed acoustic sensing, wherein the method comprises the following steps: distributed fiber optic sensors are deployed in the monitoring well, and the sensors receive and record acoustic signals underground. By means of the signals, the mathematical model and the calculation algorithm, the position of the fracture front edge is rapidly and accurately estimated in real time, and the fracturing effect is estimated. The position of the crack front can be estimated quickly and accurately. The system provides technical basis by monitoring the expansion position of the crack front edge in real time, and prevents occurrence of pressure strings. The invention has the advantages that: quick estimation, accuracy, real-time monitoring, simple and convenient operation and enhanced oil field development benefit, and has important significance for evaluating and adjusting the fracturing scheme of the oil field.
Description
Technical Field
The invention relates to the technical field of oil and gas reservoir development, in particular to a method and a system for quickly estimating the hydraulic fracture expansion front between inversion wells by utilizing low-frequency distributed acoustic sensing strain rate data.
Background
Strain rate measurements generated by interwell low frequency distributed Acoustic sensing (Liu, yongzan, jin, ge, wu, kan, and George moridis), "hydroaulic-fraction-Width Inversion Using Low-Frequency Distributed-objective-Sensing Strain Data-Part I: algorithm and Sensitivity analysis)," SPE j.26 (2021): 359-371.doi: https:// doi.org/10.2118/204225-PA) are useful for characterizing Hydraulic fractures.
Working principle of LF-DAS: LF-DAS is a sensing technology that captures sound waves by optical fibers by collecting and analyzing the sound produced at the surface or downhole. By utilizing the principle of coherent optical time domain reflection measurement, coherent short pulse laser is injected into an optical fiber, when external vibration acts on the optical fiber, the internal structure of the fiber core can be slightly changed due to an elasto-optical effect, so that the change of a back Rayleigh scattering signal is caused, the received reflected light intensity is changed, and the intensity change of the Rayleigh scattering light signal before and after an underground event is detected.
The first prior art (Liu, 2021) proposes an inversion algorithm that quantitatively characterizes fracture geometry by correlating strain data monitored by low frequency distributed acoustic sensing (LF-DAS) with fracture width by Green function. The algorithm adopts a 3D displacement discontinuous method to construct a Green function, utilizes a least square method to solve a linear equation set, and generates a crack width sample through Markov chain Monte Carlo simulation to quantify the uncertainty of inversion width.
The inversion result obtained by the least square method is non-unique and depends heavily on prior regularized information. LF-DAS data shows dominant sensitivity of fracture width near the monitoring well, so fracture width obtained by inversion at the monitoring well location always coincides with the true value. MCMC simulation results confirm that LF-DAS strain data can only impose constraints on fracture sections near the monitoring well. Furthermore, the algorithm is successfully applied to invert the case of near-well width evolution at injection time, except that the average width obtained by inversion near the well is typically the same as the width at the well, except that there is a sharp width change near the fracture tip at an early stage after fracture impingement.
However, the prior art has the following disadvantages:
1. the inversion result obtained by the least square method is non-unique and depends heavily on prior regularized information.
2. The inversion calculation speed is low, and quick estimation and real-time monitoring cannot be achieved.
Disclosure of Invention
The invention provides a method and a system for inverting a hydraulic fracture propagation leading edge by using distributed acoustic sensing aiming at the defects of the prior art. The location of the fracture front was monitored and assessed in real time by LF-DAS. During hydraulic fracturing, understanding of the propagation and rate of the fracture can be aided. In particular, distributed fiber optic sensors are deployed in a monitoring well, which can receive and record acoustic signals from the subsurface. By real-time analysis of these signals, the location of the fracture front can be quickly and accurately estimated. The injection amount and speed of the fracturing fluid can be better controlled by monitoring the position of the front edge of the fracture, so that the optimal fracturing effect can be realized.
In order to achieve the above object, the present invention adopts the following technical scheme:
a method for inverting a hydraulic fracture propagation front using distributed acoustic sensing, comprising the steps of:
1) And deploying a distributed optical fiber sensor in the monitoring well, and using a layout method outside the casing to layout the optical fiber sensor outside the continuous oil pipe, wherein the optical fiber sensor receives and records an underground acoustic signal.
2) Calculating far field strain caused by the radial cracks using an analytical model;
the analytical model is of the formula:
wherein,
wherein P is the net pressure, R is the fracture radius, E is the Young's modulus, v is the Poisson's ratio, η represents the expansion angle, f (v, Z D ,R D ) Representing the crack frontAn estimate of the position of the object,is a function of crack propagation velocity.
3) According to dimensionless parameter Z D And R is D Is defined by the shape of the strain curve, where z D And R is D The dimensionless depth of the fracture front and the fracture radius are shown, respectively.
4) The crack front is tracked using the zero strain location on the LF-DAS waterfall plot. The zero strain position is in one-to-one correspondence with the crack radius, and the change rate of the strain along with the crack radius is calculatedTo estimate the location of zero strain rate.
5) Calculating a numerical differential as follows:
6) Defining a quadratic curve fitting to obtain a dimensionless fracture radius R D And zero strain dimensionless depth z 0D The relation between the following formula:
where the parameters a, b and c are functions of poisson's ratio.
7) Estimating dimensionless fracture radius R at zero strain rate location using curve fitting D 。
8) Determining the closest distance d between the fiber and the crack propagation front f The following formula:
where l and h are the lateral and longitudinal offsets between the fracturing well and the monitoring well, respectively.
Further, the Z D And R is D Is defined as follows:
the z-coordinate and fracture radius R are made dimensionless by dividing them by the hypotenuse of the triangle formed by the lateral and longitudinal offsets to monitor wells l and h.
The invention also discloses a system for inverting the hydraulic fracture propagation leading edge by using the distributed acoustic sensing, which can be used for implementing the method for inverting the hydraulic fracture propagation leading edge by using the distributed acoustic sensing, and concretely comprises the following steps:
an input module: for inputting fracture-related parameters including net pressure, fracture radius, young's modulus, and poisson's ratio.
The calculation module: and calculating far-field strain according to a calculation formula of the analysis model by using the input parameters.
Dimensionless module: the shape of the strain curve is determined according to the defined dimensionless parameters.
And a tracking module: the crack front is tracked using the zero strain location on the LF-DAS waterfall plot. The zero strain position is in one-to-one correspondence with the crack radius, and the zero strain rate position is estimated by calculating the change rate of the strain along with the crack radius.
Numerical differentiation module: and according to the estimated value obtained by the calculation module, determining the relationship between the dimensionless fracture radius and the dimensionless depth of the zero strain through numerical differential calculation.
And a curve fitting module: and (3) according to a quadratic curve fitting method, correlating the parameters with a poisson ratio function to obtain the dimensionless fracture radius.
The nearest distance calculation module: the nearest distance of the optical fiber from the fracture propagation front is calculated from the lateral and longitudinal offset between the fractured and monitor wells.
The invention also discloses a computer device, which comprises a memory, a processor and a computer program stored on the memory and capable of running on the processor, wherein the processor realizes the method for inverting the hydraulic fracture expansion front by using the distributed acoustic sensing when executing the program.
The invention also discloses a computer readable storage medium, on which a computer program is stored, which when executed by a processor implements the method for inverting the hydraulic fracture propagation leading edge by using distributed acoustic sensing.
Compared with the prior art, the invention has the advantages that:
1. and (3) fast estimation: the crack front position can be rapidly estimated by using a mathematical model and a calculation algorithm, so that the time and labor cost are greatly saved.
2. Accuracy: by means of numerical differentiation, curve fitting and other methods, accuracy of an estimation result can be improved, and errors are reduced. Thus, the fracturing effect can be better evaluated, and a reliable technical basis is provided for the fracturing scheme of the oil field.
3. And (3) real-time monitoring: the method can monitor the expansion position of the front edge of the crack in real time and evaluate the fracturing effect, can discover the abnormal expansion condition of the crack in time, and can take measures to adjust and correct in time, thereby avoiding occurrence of pressure strings.
4. The operation is simple and convenient: through input parameters and an operation module, the operation flow is simplified, the use threshold is reduced, and the technology is easier to apply and popularize.
5. Enhancing the development benefit of the oil field: by accurately evaluating the fracturing effect and monitoring the crack expansion position, the oil field development scheme can be optimized, the productivity and the yield can be improved, and higher economic benefit can be realized.
Drawings
FIG. 1 is a diagram of a low frequency distributed acoustic sensor arrangement in accordance with an embodiment of the present invention.
Fig. 2 is a waterfall diagram of an embodiment of the invention LF-DAS.
FIG. 3 is a plot of domain versus fiber for a radial fracture model in accordance with an embodiment of the present invention.
Detailed Description
The invention will be described in further detail below with reference to the accompanying drawings and by way of examples in order to make the objects, technical solutions and advantages of the invention more apparent.
As shown in fig. 1, a distributed optical fiber sensor is deployed in a monitoring well, the optical fiber sensor is deployed outside a coiled tubing by using a deployment method outside a casing, and the optical fiber sensor receives and records an acoustic signal underground.
Sneddon provides an analytical model for calculating stress and displacement induced by radial cracks in an infinite, homogeneous, linear elastic medium (Sneddon, I.N.1946.The Distribution of Stress in the Neighbourhood of a Crack in an Elastic solid. Proceedings of the Royal Society of London Series A, mathematical and Physical Sciences 187 (1009): 229-260.Http:// www.jstor.org/stable/97970). A model adapted to take into account a fiber optic instrument monitoring well is shown in fig. 3. Figure 3a shows a top view illustrating a radial fracture centered on a fractured well. l and h are the lateral and longitudinal offsets between the fracturing well and the monitoring well, respectively. The closest distance d from the monitoring well to the fracture front f On the diagonal of a triangle formed by the longitudinal and transverse offsets. The side view in fig. 3b depicts the fracture radius R and z coordinates. At the fracture plane, the z-coordinate is zero, and then increases away from the fracture along the measured depth of the well. The direction of the z-coordinate is arbitrary due to symmetry. The wells are vertically parallel and the simulated fractures are lateral.
Far field strain caused by radial cracks with constant net pressure is calculated by equation 1
Here, the
Optical fiber deviceInstalled in the direction of the well bore so epsilon Z Corresponding to the axial strain on the fiber (tensile stress is positive). The parameters in equation 1 include net pressure P, fracture radius R, young's modulus E, and poisson's ratio v. η is the integral variable. The shape of the strain curve is defined by the dimensionless parameter z D And R is D And (5) determining.
The z-coordinate and fracture radius R are made dimensionless by dividing them by the hypotenuse of the triangle formed by the lateral and longitudinal offsets to monitor wells l and h.
Equation 1 provides the basis for the zero strain position approach. For radial cracks, the zero strain location z0 corresponds one-to-one with the crack radius (Leggett, smith, reid, teresa, zhu, ding, and Hill, A.D.2022.Experimental Investigation of Low Frequency Distributed Acoustic Strain-Rate Responses to Propagating Fractures.Proc., SPE Hydraulic Fracturing Technology Conference and Exhibit. Https:// doi. Org/10.2118/209135-MS.). The location of zero strain is extracted from the contour of the converging pattern on the LF-DAS waterfall plot (fig. 2). Sometimes, the strain rate response of the LF-DAS provides a clearer pattern image than the strain response. The following equation provides a basis for a method of tracking the fracture front from the strain rate response. Zero strain rate is defined as:
assume that the crack continues to propagate, i.e., dR/dt is not zero:
thus, the location of zero strain rate can be from dε Z the/dR estimation. Substituting equation 1 into equation 6 can result in:
the left scale term can be eliminated, resulting in:
equation 8 is dimensionless and depends on the dimensionless fracture radius R D Zero strain rate position z without dimension 0D And poisson's ratio. In this work, equation 8 is calculated by numerical differentiation using an integral function and a central difference method. This calculation can be cumbersome and therefore defines a quadratic curve fit to express the dimensionless fracture radius R D And zero strain dimensionless z-coordinate z 0D The relationship between them is as follows:
the parameters a, b and c are functions of poisson's ratio, as shown in the table below.
TABLE 1 zero strain Rate positioning curve fitting coefficients
| z 0D ＞1 | 0.75≤z 0D ≤1 | z 0D ＜0.75 | |
| a | -0.255v-0.789 | -1.83v-1.02 | -1.56v-1.72 |
| b | 0.952v+0.00202 | 1.86v+0.0793 | 1.64+0.914 |
| c | 0.33v+1.05 | -0.136v+1.05 | -0.0891+0.805 |
The difference between the curve fit and the solution using the Sneddon solution is negligible. Thus, this work uses curve fitting to estimate the dimensionless fracture radius at the zero strain rate location. The closest distance df between the fiber and the propagating fracture front can then be determined by:
calculation of the location of the crack propagation front in real time can be achieved using equation 10.
In yet another embodiment of the present invention, a system for inverting a hydraulic fracture propagation front using distributed acoustic sensing is provided, which can be used to implement the method for inverting a hydraulic fracture propagation front using distributed acoustic sensing described above, specifically including:
an input module: for inputting fracture-related parameters including net pressure, fracture radius, young's modulus, and poisson's ratio.
The calculation module: and calculating far-field strain according to a calculation formula of the analysis model by using the input parameters.
Dimensionless module: the shape of the strain curve is determined according to the defined dimensionless parameters.
And a tracking module: the crack front is tracked using the zero strain location on the LF-DAS waterfall plot. The zero strain position is in one-to-one correspondence with the crack radius, and the zero strain rate position is estimated by calculating the change rate of the strain along with the crack radius.
Numerical differentiation module: and according to the estimated value obtained by the calculation module, determining the relationship between the dimensionless fracture radius and the dimensionless depth of the zero strain through numerical differential calculation.
And a curve fitting module: and (3) according to a quadratic curve fitting method, correlating the parameters with a poisson ratio function to obtain the dimensionless fracture radius.
The nearest distance calculation module: the nearest distance of the optical fiber from the fracture propagation front is calculated from the lateral and longitudinal offset between the fractured and monitor wells.
In yet another embodiment of the present invention, a terminal device is provided, the terminal device including a processor and a memory, the memory for storing a computer program, the computer program including program instructions, the processor for executing the program instructions stored by the computer storage medium. The processor may be a central processing unit (Central Processing Unit, CPU), but may also be other general purpose processors, digital signal processors (Digital Signal Processor, DSP), application specific integrated circuits (Application Specific Integrated Circ uit, ASIC), off-the-shelf Programmable gate arrays (FPGAs) or other Programmable logic devices, discrete gate or transistor logic devices, discrete hardware components, etc., which are the computational core and control core of the terminal adapted to implement one or more instructions, in particular adapted to load and execute one or more instructions to implement a corresponding method flow or a corresponding function; the processor of the embodiment of the invention can be used for inverting the operation of the hydraulic fracture propagation leading edge method by using distributed acoustic sensing.
In a further embodiment of the present invention, the present invention also provides a storage medium, in particular, a computer readable storage medium (Memory), which is a Memory device in a terminal device, for storing programs and data. It will be appreciated that the computer readable storage medium herein may include both a built-in storage medium in the terminal device and an extended storage medium supported by the terminal device. The computer-readable storage medium provides a storage space storing an operating system of the terminal. Also stored in the memory space are one or more instructions, which may be one or more computer programs (including program code), adapted to be loaded and executed by the processor. The computer readable storage medium herein may be a high-speed RAM memory or a non-volatile memory (non-volatile memory), such as at least one magnetic disk memory.
One or more instructions stored in a computer-readable storage medium may be loaded and executed by a processor to implement the respective steps of the methods for rapid estimation in the above embodiments; one or more instructions in a computer-readable storage medium are loaded by a processor and perform the steps of a method of inverting a hydraulic fracture propagation front using distributed acoustic sensing.
It will be appreciated by those skilled in the art that embodiments of the present invention may be provided as a method, system, or computer program product. Accordingly, the present invention may take the form of an entirely hardware embodiment, an entirely software embodiment or an embodiment combining software and hardware aspects. Furthermore, the present invention may take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, and the like) having computer-usable program code embodied therein.
The present invention is described with reference to flowchart illustrations and/or block diagrams of methods, apparatus (systems) and computer program products according to embodiments of the invention. It will be understood that each flow and/or block of the flowchart illustrations and/or block diagrams, and combinations of flows and/or blocks in the flowchart illustrations and/or block diagrams, can be implemented by computer program instructions. These computer program instructions may be provided to a processor of a general purpose computer, special purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, create means for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be stored in a computer-readable memory that can direct a computer or other programmable data processing apparatus to function in a particular manner, such that the instructions stored in the computer-readable memory produce an article of manufacture including instruction means which implement the function specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be loaded onto a computer or other programmable data processing apparatus to cause a series of operational steps to be performed on the computer or other programmable apparatus to produce a computer implemented process such that the instructions which execute on the computer or other programmable apparatus provide steps for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
Those of ordinary skill in the art will appreciate that the embodiments described herein are intended to aid the reader in understanding the practice of the invention and that the scope of the invention is not limited to such specific statements and embodiments. Those of ordinary skill in the art can make various other specific modifications and combinations from the teachings of the present disclosure without departing from the spirit thereof, and such modifications and combinations remain within the scope of the present disclosure.
Claims (5)
1. A method for inverting a hydraulic fracture propagation front using distributed acoustic sensing, comprising the steps of:
1) Deploying a distributed optical fiber sensor in a monitoring well, and receiving and recording an underground acoustic signal by the sensor;
2) Calculating far field strain caused by the radial cracks using an analytical model;
the analytical model is of the formula:
wherein,
wherein P is the net pressure, R is the fracture radius, E is the Young's modulus, v is the Poisson's ratio, η represents the expansion angle, f (v, Z D ,R D ) An estimate representing the location of the fracture front,is a crack propagation velocity function;
3) According to dimensionless parameter Z D And R is D Is defined by the shape of the strain curve, where z D And R is D The dimensionless depth and the fracture radius of the fracture front are respectively represented;
4) Tracking the crack front by using the zero strain position on the LF-DAS waterfall graph; the zero strain position is in one-to-one correspondence with the crack radius, and the change rate of the strain along with the crack radius is calculatedTo estimate the location of zero strain rate;
5) Calculating a numerical differential as follows:
6) Defining a quadratic curve fitting to obtain a dimensionless fracture radius R D And zero strain dimensionless depth z 0D The relation between the following formula:
where the parameters a, b and c are functions of poisson's ratio;
7) Estimating dimensionless fracture radius R at zero strain rate location using curve fitting D ；
8) Determining the closest distance d between the fiber and the crack propagation front f The following formula:
where l and h are the lateral and longitudinal offsets between the fracturing well and the monitoring well, respectively.
2. The method of inverting a hydraulic fracture propagation front using distributed acoustic sensing according to claim 1, wherein: the Z is D And R is D Is defined as follows:
the z-coordinate and fracture radius R are made dimensionless by dividing them by the hypotenuse of the triangle formed by the lateral and longitudinal offsets to monitor wells l and h.
3. A system for inverting a hydraulic fracture propagation front using distributed acoustic sensing, characterized by: the system can be used to implement the method of inverting the hydraulic fracture propagation front using distributed acoustic sensing as claimed in claim 1 or 2, comprising in particular:
an input module: for inputting fracture-related parameters including net pressure, fracture radius, young's modulus, and Poisson's ratio;
the calculation module: calculating far-field strain according to a calculation formula of the analysis model by using the input parameters;
dimensionless module: determining the shape of the strain curve according to the defined dimensionless parameters;
and a tracking module: tracking the crack front by using the zero strain position on the LF-DAS waterfall graph; the zero strain positions are in one-to-one correspondence with the crack radius, and the zero strain rate positions are estimated by calculating the change rate of the strain along with the crack radius;
numerical differentiation module: according to the estimated value obtained by the calculation module, the relationship between the dimensionless fracture radius and the dimensionless depth of zero strain is determined through numerical differential calculation;
and a curve fitting module: according to a quadratic curve fitting method, correlating the parameters with a poisson ratio function to obtain a dimensionless fracture radius;
the nearest distance calculation module: the nearest distance of the optical fiber from the fracture propagation front is calculated from the lateral and longitudinal offset between the fractured and monitor wells.
4. A computer device, characterized by: a computer program comprising a memory, a processor and a computer program stored on the memory and executable on the processor, the processor implementing the method of inverting a hydraulic fracture propagation front using distributed acoustic sensing as claimed in claim 1 or 2 when the program is executed.
5. A computer-readable storage medium, characterized by: a computer program stored thereon, which when executed by a processor, implements the method of inverting a hydraulic fracture propagation front using distributed acoustic sensing as claimed in claim 1 or 2.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202311313986.3A CN117365462A (en) | 2023-10-11 | 2023-10-11 | Method and system for inverting hydraulic fracture propagation leading edge by using distributed acoustic sensing |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202311313986.3A CN117365462A (en) | 2023-10-11 | 2023-10-11 | Method and system for inverting hydraulic fracture propagation leading edge by using distributed acoustic sensing |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN117365462A true CN117365462A (en) | 2024-01-09 |
Family
ID=89407012
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202311313986.3A Pending CN117365462A (en) | 2023-10-11 | 2023-10-11 | Method and system for inverting hydraulic fracture propagation leading edge by using distributed acoustic sensing |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN117365462A (en) |
Citations (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN112576245A (en) * | 2020-12-09 | 2021-03-30 | 中国石油大学(华东) | Distributed optical fiber strain monitoring method based on crack propagation simulation |
| CN113216947A (en) * | 2021-05-17 | 2021-08-06 | 中国石油大学(华东) | Horizontal well fracturing process crack height determination method based on monitoring well distributed optical fiber strain monitoring |
| CN115749762A (en) * | 2022-12-09 | 2023-03-07 | 中国石油大学(北京) | Distributed optical fiber-based multi-crack parameter inversion method and device |
-
2023
- 2023-10-11 CN CN202311313986.3A patent/CN117365462A/en active Pending
Patent Citations (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN112576245A (en) * | 2020-12-09 | 2021-03-30 | 中国石油大学(华东) | Distributed optical fiber strain monitoring method based on crack propagation simulation |
| CN113216947A (en) * | 2021-05-17 | 2021-08-06 | 中国石油大学(华东) | Horizontal well fracturing process crack height determination method based on monitoring well distributed optical fiber strain monitoring |
| CN115749762A (en) * | 2022-12-09 | 2023-03-07 | 中国石油大学(北京) | Distributed optical fiber-based multi-crack parameter inversion method and device |
Non-Patent Citations (3)
| Title |
|---|
| SMITH LEGGETT等: "Experimental Investigation of Low-Frequency Distributed Acoustic Strain-Rate Responses to Propagating Fractures", 《SPE JOURNAL》, 31 December 2022 (2022-12-31), pages 3814 - 3828 * |
| 任伟建;宋成坤;霍凤财;杨迪;姜淑环;孙宝翔;王春蕾;李鹏娜;: "基于多平台的油田业务管理系统关键技术研究", 《化工自动化及仪表》, no. 08, 10 August 2016 (2016-08-10) * |
| 马国旗;曹丹平;尹教建;朱兆林;: "分布式声传感井中地震信号检测数值模拟方法", 《石油地球物理勘探》, no. 02, 31 December 2019 (2019-12-31) * |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| AU2017230716B2 (en) | DAS method of estimating fluid distribution | |
| US10030511B2 (en) | Systems, methods, and computer medium to provide entropy based characterization of multiphase flow | |
| US11686194B2 (en) | Low frequency DAS well interference evaluation | |
| US11467308B2 (en) | Fibro: a fiber optic data processing software for unconventional reservoirs | |
| US11753918B2 (en) | Method for multilayer hydraulic fracturing treatment with real-time adjusting | |
| US20150241582A1 (en) | Methods and systems for using known source events in seismic data processing | |
| CA3008438A1 (en) | Method for evaluating and monitoring formation fracture treatment using fluid pressure waves | |
| US20170234999A1 (en) | Reducing Microseismic Monitoring Uncertainty | |
| CN105452903A (en) | Multi-frequency inversion of modal dispersions for estimating formation anisotropy constants | |
| WO2020068326A1 (en) | Wavelet transform-based coherent noise reduction in distributed acoustic sensing | |
| CN110426739B (en) | Geological exploration detection method and device and storage medium | |
| RU2009139867A (en) | AUTOMATED ASSESSMENT OF DRILL SLOW SLOWNESS | |
| CN109490947B (en) | High-temperature medium seismic wave propagation simulation method | |
| CN109709602B (en) | Remote detection sound wave offset imaging method, device and system | |
| US9982527B2 (en) | Apparatus and method for a matrix acoustic array | |
| KR101459388B1 (en) | Speed information derivation method of underground | |
| TW201907869A (en) | Motion information acquisition method and device | |
| CN117365462A (en) | Method and system for inverting hydraulic fracture propagation leading edge by using distributed acoustic sensing | |
| GB2581633A (en) | Method and system for analyzing a borehole using passive acoustic logging | |
| Moldovan et al. | Fixed point automatic interpretation of bender-based G0 measurements | |
| EP3012669A2 (en) | System and method for predicting the front arrival time in reservoir seismic monitoring | |
| US11448066B2 (en) | Locating passive seismic events in a wellbore using distributed acoustic sensing | |
| US20210364669A1 (en) | Multi-well interference control and mitigation | |
| US11939863B2 (en) | Distributed acoustic sensing systems and methods with dynamic gauge lengths | |
| Mjehovich et al. | Quantitative analysis of HFTS-2 completion designs using cross-well strain measurement |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination |