Analyzing microseismic data from a fracture treatment.

(54) Title: ANALYSIS OF MICROSISMIC DATA OF A FRACTURE TREATMENT.

(54) Title: ANALYZING MICROSEISMIC DATA FROM A FRACTURE TREATMENT.

(57) Summary

Systems, methods, and software can be used to analyze microseismic data from a fracture treatment; In some respects, the data for a new microseismic event come from a fracture treatment of an underground zone; an updated parameter is calculated for a fracture plane; the fracture plane was previously generated based on the data for previous microseismic events; the calculated updated parameter is calculated based on the data for the new microseismic event and the data for the previous microseismic events; A graphical representation of the fracture plane is displayed based on the updated parameter.

(57) Abstract

Systems, methods, and software can be used to analyze microseismic data from a fracture treatment. In some aspects, data for a new microseismic event are from a fracture treatment of a subterranean zone. An updated parameter for a fracture plan is calculated. The fracture plañe was previously generated based on data for prior microseismic events. The updated parameter calculated is calculated based on the data for the new microseismic event and the data for the prior microseismic events. A graphical representation of the fracture plan is displayed based on the updated parameter.

I Μ ΡΙ 'Λ ». *

PATENT TITLE No. 349526

<td>Headlines):</td><td>HALLIBURTON ENERGY SERVICES, INC.</td>

<td>Home:</td><td>10200 Bellaire Boulevard, Houston, Texas, 77072, USA</td>

<td>Denomination:</td><td>ANALYSIS OF MICROSISMIC DATA FROM A FRACTURE TREATMENT.</td>

<td>Classification:</td><td>CIP: G01V1 / 40; G01V1 / 30 CPC: G01V1 / 288; G01V1 / 34; G01V1 / 4O; G01V1 / 301; G01V1 / 345; G01V2210 / 646; G01V2210 / 1234</td>

<td>Inventor (s):</td><td>JIANFU MA; AVI LIN; HAROLD GRAYSON WALTERS</td>

REQUEST

Number:

MX / a / 2015/003997

Country:

US US

International Presentation Date:

October 2013

PRIORITY

Date: Number:

October 2012 61 / 710,582 May 2013 13 / 896,389

Validity: Twenty years

Expiration Date: October 4, 2033

Issue Date: August 2, 2017

The reference patent is granted based on articles 1, 2, section V, 6^or fraction l | l, and 59 of the Industrial Property Law.

In accordance with article 23 of the Industrial Property Law, this patent shall have a validity of twenty years, non-extendable, counted from the date of filing the international application and will be subject to the payment of the fee to keep JOS rights in force.

Whoever signs this title does so based on the provisions of articles 6 · fractions lll and 7 ”bis 2 of the Industrial Property Law (Official Gazette of the Federation (DOF) 06/27/1991, amended on 92 / 98/1994, 10/26/1996, 12/26/1987, 05/17/1999, 01/26/2004, 06/16/2005, 01/25/2006, 05/06/2009, 06/01 / 2010, 18 * 65/2910, 06/28/2010, 01/07/2012 and 04/09/2012); Articles 1, 3 'section V subsection a), 4 and 12 sections I and III of the Regulations of the Mexican Institute of Industrial Property (DOF 12/14/1999, amended on 07/01/2002 «07/15 / 2004, 07/28/2004 and 09/07/2007); items 1^or, 3, 4°, 5^or Section V subsection a), 16 sections I and III and 30 of the Organic Statute of the Mexican Institute of Industrial Property (DOF 12/27/1999, amended on 10/10/2002, 07/29/2004, 08/04/2004 and 09/13/2007), 1. 3 and 5 · subsection a) of the Agreement that delegates powers to the Deputy General Directors, Coordinator. Divisional Directors. Heads of the Regional Offices, Divisional Deputy Directors, Departmental Coordinators and other subordinates of the Mexican Institute of Industrial Property fD.OF 12/15/1999, amended on 02/04/2000, 07/29/2004, 08/04/2004 and 09/13/2007).

This document is signed with an advanced electronic signature (FIEL), based on articles 7 BIS 2 of the Industrial Property Law; 3 of its Regulations, and 1 fraction lll, 2 fraction V, 26 BIS and 26 TER of the Agreement establishing the guidelines for the use of the Payment and Electronic Services Portal (PASE) of the Mexican Institute of Industrial Property, in the procedures indicated.

THE DIVISIONAL DIRECTOR OF PATENTS

NAHANNY CANAL REYES

<img file="MX349526B_D0001.tif" />

Original string:

NAHANNY MARISOL CANAL REYES | 00001000000403252793 | Administration Service

Tax | 1695 || MX / 2017/61531 | MX / a / 2015/003997 | PCT patent title | 1027 | RGZ | Page (s)

1 | / z7NSoByZz7vdW25N96RNcFkGGM =

Digital stamp:

MOD9Yk3nSu7LhvOxuL7W1nvOdWOaLj3faxmDmH3wP2c / TyM8CvaBf9FPA6WNeNwwWMW76KX + Sy2rjMEIa9bn461GVU XfWNfpBcd9bYvCBLD1w4nHdVYmmN5MvH8OTyitCLgYNIEBIJQaHUO3gnzLhyhZ3cM1LO1108QutpOwk8ebN93cmWAF xX / NvbaZrARrYwCdLIU + 7aTZ / qnhzXK3Ahr1 JQVJyvjkerpAegZxAWBtJdg8YoKLJ0 + Cbf8Wn9xHG6JKrCg85MBm0T

7f8RkQnbS + DWzeTTIFKwXIM8KsufYzUX3FY / HV9Bh3TKt3Z5AtbqvJuqKaY2teugq / luEpuQ == iso 1, Pueblo Santa Mana Tepepan, Xochimilco, 16020.

Mexico City

55) 53340700 www.gob.mx/impi

<img file="MX349526B_D0002.tif" />

WZo ......

ANALYSIS OF MICROSMIC DATA FROM A TREATMENT

<img file="MX349526B_D0003.tif" />

BACKGROUND OF THE INVENTION --------—----- This specification refers to the analysis of microsynic data of a fracture treatment. Microscopic data is often acquired in association with hydraulic fracturing treatments applied to an underground formation. Hydraulic fracturing treatments are typically applied to induce artificial fractures in the underground formation, thereby improving the hydrocarbon productivity of the underground formation. The pressures generated by fracture treatment can induce low-amplitude or low-energy seismic events in the underground formation, and the events can be detected by sensors and collected for analysis.

BRIEF DESCRIPTION OF THE INVENTION

In a general aspect, microseismic data from a fracture treatment are analyzed. In some cases, the data can be analyzed in real time, for example, during fracture treatment.

In some respects, the data for a new microseismic event is collected from a fracture treatment of an underground zone. An updated parameter is calculated² ΙΜΡΙ ^ -τ for a fracture plane. The plane of^CEI- ^; ^ ® ^ ir ^ * ^ Ue previously generated based on data for previous microseismic events. The updated, calculated parameter is calculated based on the data for the new microseismic event and the data for the previous available microseismic events. A graphical representation of the fracture plane (or a numerical representation of the fracture plane parameters) is displayed based on the updated parameter.

Implementations can include one or more of the following features. Prior to knowing or estimating possible fracture planes, orientations are used to calculate a parameter of the fracture plane. The graphical representation is continuously updated, for example, as long as new additional microseismic events appear in the input buffer of the system. New microseismic events are collected from fracture treatment before fracture treatment begins, during fracture treatment, after fracture treatment has ended, or any combination of these. The updated parameter is calculated and the graphic representation is displayed in real time during the fracture treatment.

The fracture plane is selected from multiple fracture planes based on the data for the new microseismic event. The new microseismic event is associated with the selected fracture plane. Displaying a graphical representation of the fracture plane includes updating a graphical representation of the fracture planes in real time during fracture treatment. Selecting the fracture plane from the fracture planes includes identifying a distance between the new microseismic event and the selected fracture plane and determining that the distance is less than a threshold distance. The threshold value is a static predefined value. The predefined threshold is calculated by multiplying a coefficient of the standard deviation or uncertainty of the fracture plane. The coefficient can be a predefined constant value, for example between 1 and 2, or another value.

Additionally or alternatively, these and other implementations may include one or more of the following features. Calculating an updated parameter for the fracture plane includes calculating at least one of an updated orientation or an updated area for the fracture plane based on the data for the new microseismic event and the data for the previous microscopic events. Calculate an updated parameter for the plane of

<img file="MX349526B_D0004.tif" />

* IMPI

MEXICAN INSTITUTE, DE LA PROHEDAD fracture includes calculating a distance prdttt ^ 35! T!) Fracture plane for the new event — mi-oiΟΰΓδιήίόο^-- and previous microscopic events. The new microseismic event and the previous microseismic events define a set. In response to the detection that the mean distance is greater than a predefined threshold distance, an updated mean distance is calculated after removing one or more microseismic events from the set.

Additionally or alternatively, these and other implementations may include one or more of the following features. Calculating an updated parameter for the fracture plane includes calculating an updated area for the fracture plane. The updated area for the fracture plane is compared to a previous area for the fracture plane. The new microseismic event is disassociated from the fracture plane in case the updated area for the fracture plane is smaller than the previous area for the fracture plane. The new microseismic event is a first new microseismic event. After displaying the graph based on the first new microseismic event, data is received for a second new microseismic event collected from the fracture treatment. A second updated parameter is calculated for the fracture plane based, in part, on the data for the second event ⁵ ._____ ζ__ _. _ „. . ζ WSTHVtO.MÍXICANO microseismico nuevo. A qrgc KggÍErggra representation. a of the fracture plane is generated based on the updated parameter sAgnndn.

Details of one or more implementations are set forth in the accompanying drawings and the following description. Other features, objectives and advantages will be apparent from the description and drawings as well as from the claims.

BRIEF DESCRIPTION OF THE FIGURES

Figure 1A is a diagram of an exemplary well system; FIG. IB is a diagram of the exemplary computing subsystem 110 of FIG. 1A.

Figures 2A and 2B are graphs showing exemplary fracture planes.

Figures 3A-3F are graphs showing updates for an exemplary fracture plane.

Figure 4 is a flow chart of an exemplary technique for analyzing microseismic data.

Similar reference symbols throughout the various drawings indicate similar elements.

DETAILED DESCRIPTION OF THE INVENTION .

In some aspects of what is described here, parameters of ₆ IMPI

MEXICAN INSTITUTE J

OE LA riSOrtEDAD tj—, T »_ JR

INDUSTRIAL fracture, dominant fracture orientations, or other data are identified from the microseismic data. In some cases, these or other types of data are identified dynamically, for example, in a real-time manner during a fracture treatment. For many applications and analysis techniques, identification of fracture planes from microseismic events in real time is needed, and individual fracture planes can be displayed to show time evolution and geometric elimination, including location, propagation, growth, reduction or elimination of the fracture planes. Such capabilities can be incorporated into control systems, software, hardware, or other types of tools available to oil and gas field engineers when analyzing potential oil and gas fields, while simultaneously stimulating hydraulic fractures and analyzing fractures. resulting signals. Such tools can provide a reliable and straightforward interface to present and visualize hydraulic fracture dynamics, which can help analyze fracture complexity, fracture network structure, and reservoir geometry. Such tools can help evaluate the effectiveness of hydraulic fracturing treatment, for example, by improving, increasing or optimizing density.⁷ Fracture IMPI and lengths and heights gMiytyES '^. HdsZTg ^ B ^ s improvements in fracture treatment aplir.adn al yarimianto · can improve the production of hydrocarbons or other reservoir resources.

Hydraulic fracturing treatments can be applied in any convenient underground area. Hydraulic fracturing treatments are often applied in tight formations with low-permeability reservoirs, which may include, for example, conventional low-permeability oil and gas reservoirs, resource pieces focused on a continuous basin, and shale gas reservoirs. , or other types of formations. Hydraulic fracturing can induce artificial fractures in the subsurface, which can improve the productivity of the hydrocarbon in a reservoir.

During the application of a hydraulic fracturing treatment, the injection of high pressure fluids can alter stresses, accumulate shear stresses, and cause other effects within geological subsurface structures. In some cases, microseismic events are associated with hydraulic fractures induced by fracturing activities. Acoustic energy or sounds associated with rock stresses, deformations, and fracturing can be detected and collected by

<img file="MX349526B_D0005.tif" />

IMPI

MEXICAN INSTITUTE

OF THE INDUSTRIAL HIOHEUAD SENSORS. In some cases, microseismic events have low energy (for example, with the record value of intensity or moment magnitude less than three), and some uncertainty or precision or measurement error is associated with the event locations. The uncertainty can be described, for example, by an oblong spheroid, where the highest probability is at the center of the spheroid and the lowest probability is at the edge.

Microseismic event mapping can be used to geometrically locate the source point of microseismic events based on the detected compression and shear waves. The detected compression and shear waves (for example p-waves and s-waves) can produce additional information regarding microseismic events, including the location of the source point, the measurement uncertainty of the location and position of the event, the time of occurrence of the event, the momentum magnitude of the event, the direction of particle motion and energy emission spectrum, and possibly others. Microseismic events can be monitored in real time, and in some cases, the events are also processed in real time during fracture treatment. In some cases, after fracture treatment, the microseismic events collected from the treatment are⁹ IMPI ^^

MEXICAN INSTITUTE processed together as post data. ^FROM

The processing of event data. ., jni.cr.Qslsmicojs. ^ collected from a fracture treatment may include fracture matching (also called fracture mapping). Fracture matching processes can identify fracture planes in any zone based on microseismic events collected from the zone. Some exemplary computational algorithms for fracture matching use microseismic event data (e.g., an event location, an event location measurement uncertainty, an event moment magnitude, etc.) to identify individual fractures that are matched with the event. compiled set of microseismic events. Some exemplary computational algorithms can calculate statistical properties of fracture patterns. Statistical properties can include, for example, fracture orientation, fracture orientation trends, fracture size (eg, length, height, area, etc.), fracture density, fracture complexity, fracture network properties, etc. Some computational algorithms consider the uncertainty in event locations using multiple realizations of microseismic event locations. For example, alternative statistical realizations associated with

<img file="MX349526B_D0006.tif" />

₁₀ ΐΝϊΤΓτυτο muicanc DI LA «OHIDAf Monte Carlo techniques can be used“ parS ^ tnw probability distribution defined in a spheroid ~~ u ~~ O'Lrrr type of distribution.

Generally, fracture matching algorithms can operate on real-time data, post data, or any convenient combination of these and other types of data. Some computational algorithms for fracture matching operate only on post data. Algorithms that operate on post data can be used when any subset or several subsets of microseismic data to be processed have been collected from the fracture treatment; such algorithms can access (eg, as an initial input) the complete subset of microseismic events to be processed. In some implementations, the fracture matching algorithms can operate on real-time data. Such algorithms can be used for real-time automatic fracture matching during fracture treatment. Algorithms that operate on real-time data can be used during fracture treatment, and such algorithms can dynamically adapt or update a previously identified fracture model to reflect newly acquired microseismic events. For example, once an event

IMPI

MEXICAN INSTITUTE DE LA EtOninAD INDUSTRIAL microseismic is detected and collected from the treatment field, a real-time automatic fracture matching algorithm can respond to this new event by dynamically identifying and extracting fracture planes from microseismic events already collected in a real time way. Some computational algorithms for fracture matching can operate on a combination of post data and real-time data.

In some cases, fracture mapping algorithms are configured to manipulate conditions that arise in real-time microseismic data processing. For example, various types of challenges or conditions may occur more predominantly in the real-time context. In some cases, real-time processing techniques can be adapted to account for (or reduce or avoid) the lower precision that is sometimes associated with fractures drawn from data sets lacking a sufficient number of microseismic events or lacking a sufficient number of microseismic events in some parts of the domain. Some real-time processing techniques can be adapted to produce fracture data that is consistent with fracture data that can be obtained from post-data processing techniques. For example, some of the processing techniques in

<img file="MX349526B_D0007.tif" />

real time specimens described here

IMPI

MEXICAN INSTITUTE

OF THE PROPERTY haW ^ uprd results that are statistically the Ifl'f S11WS “, - of — actrerde— with the statistical hypothesis test (t test and F test), as results produced by post-data processing techniques on the same data .

In some cases, real-time processing techniques can be adapted to easily provide users (eg instantly from a user's perspective) with the identified fracture data. Such features can allow engineers or field operators to dynamically obtain fracture geometric information and adjust fracture treatment parameters when appropriate (eg, to improve, increase, optimize, or otherwise change treatment). In some cases, the fracture planes are dynamically extracted from microseismic data and displayed for field engineers in real time. Real-time processing techniques can show high-speed performance. In some cases, performance can be improved by using parallel computing technology, distributed computing technology, parallel sequence approaches, fast binary search alqorithms, or a combination of these and other hardware and software solutions that facilitate real-time operations. .

„. . . . IMPT ^^

In some implementations, iNSTiwTdr ^ swfrlde

OF PROHITY

INOUSTRIAL fracture matching can directly present information regarding fracture planes associated with three-dimensional microseismic events. The presented fracture planes can represent fracture networks showing multiple orientations and can activate complex fracture patterns. In some cases, hydraulic fracturing parameters are extracted from a microseismic event data cloud; Such parameters may include, for example, trends in fracture orientation, fracture density, and fracture complexity. Fracture parameter information can be presented to engineers or field operators, for example, in a tabular, numeric, or graphical interface or an interface that combines tabular, numeric, and graphical elements. The graphical interface can be presented in real time and can show the real time dynamics of hydraulic fractures. In some cases, this can help field engineers analyze the complexity of the fracture, the fracture network and the geometry of the reservoir, or it can help them better understand the hydraulic fracturing process as it progresses.

In some implementations, precision confidence values ​​are used to quantify the certainty of the ¹⁴ WICKED

MEXICAN INSTITUTE fracture planes extracted from da1s ^ HteÉ ^ R Precision confidence values ​​piiArlP-η be used to classify fractures into confidence levels. For example, three levels of trust (low trust, medium trust, and high trust) are appropriate for some contexts, while in other contexts a different number may be appropriate (for example, two, four, five, etc. .) of confidence levels. A confidence value of precision of the fracture plane can be calculated based on any appropriate data. In some implementations, a fracture plane precision confidence value is calculated based on the locations of microseismic events and position uncertainties, the magnitude of the moment of individual microseismic events, distances between individual events, and their plane of fracture. of support, the number of support events associated with the fracture plane, and the weight of variation of the fracture orientation, among others.

The precision confidence values ​​can be calculated and the fracture planes can be classified at any appropriate time. In some cases, precision confidence values ​​are calculated and fracture planes are classified in real time during fracture treatment. The fracture planes can be presented to the¹⁵

MEXICAN INSTITUTE user at any appropriate time and in convenient eSg £ gaJUo. In some cases, the fracture planes are presented graphically in a real-time user interface according to the precision confidence values, according to the precision confidence levels, or according to any other type of classification. . In some cases, users can select individual groups or individual sheets (for example, those with high levels of confidence) for visualization or analysis. The fracture planes can be presented to the user in an algebraic format, a numeric format, a graphical format, or a combination of these and other formats.

In some implementations, microseismic events are monitored in real time during hydraulic fracture treatment. As events are monitored, they can also be processed in real time, they can be further processed as post data, or they can be processed using a combination of real time and post data processing. Events can be processed through any convenient technique. In some cases, events are processed individually, at the time and in the order in which they are received. For example, you can use a status of

IMPIAS system S (M, N - 1) to represent the Μ generated from the N - 1 previous events. The new N³™ input event can trigger the S (M, N -1) system. In some cases, upon receipt of the N³™ event, a histogram or distribution of targeting ranges is generated. For example, a probability distribution histogram or Hough transform histogram of degenerate planes in the dip and steering angle domain can be generated to identify the feasible dominant orientations incorporated into the fracture sets.

A ground plan can be generated from a subset of microseismic events. For example, any three non-collinear points in space mathematically define a basic plane. The basic plane defined by three non-collinear microseismic events can be represented by the normal vector (a, b, c). The normal vector (a, b, c) can be calculated based on the three event positions. The orientation of the ground plane can be calculated from the normal vector. For example, dip Θ and direction φ can be given by

Ia²+ b² b (1)

Θ = are tan --------, φ = arctan— ca

The dip angle θ of a fracture plane can represent the angle between the fracture plane and the plane

IMPI

<img file="MX349526B_D0008.tif" />

INSTITUTO MEXICAN · horizontal (for example, the xy plane). The anguld^N,$ £ MSi φ of a fracture plane can represent tíl — angle ¹ enti'ia - a horizontal reference axis (eg, the x-axis) and a horizontal line where the fracture plane crosses the horizontal plane. For example, the direction angle can be defined with respect to north or another horizontal reference direction. A fracture plane can be defined through other parameters, including angular parameters other than steering angle and dip angle.

In general, N events can support P basic planes, where P = N (N - 1) (N-2) / 6, direction angles and dip. A probability histogram can be constructed from the orientation angles. The probability histogram or the enhanced Hough transform histogram can have any convenient configuration. For example, the histogram settings can be based on a fixed cell size (bin) and a fixed number of cells, natural optimal cell size in the direction angle and dip domain, or other types of cells. The histogram can be based on any convenient number of microseismic events (eg, tens, hundreds, thousands, etc.) and any convenient range of orientations. In some cases, multiple discrete cells are defined for the histogram, and each cell represents a discrete range of

IMPI guidelines. From the oatsu planes? ^^ is ^^^ ae to calculate a number of basic planes in each., Discrete range. In some cases, each ground plane orientation falls within the orientation range associated with one of the cells. For example, for N microseismic events, each of the P base planes can be assigned a cell, and the number of base planes assigned to each cell can be calculated. The amount calculated for each cell can be any convenient value. For example, the quantity can be a non-normalized number of base planes, the quantity can be a normalized probability, frequency, or fraction of base planes, or the quantity can be another type of value that is convenient for a histogram. A histogram can be generated to represent the number of base planes assigned to all cells, or to represent the number of base planes assigned to a subset of the cells. Exemplary techniques for generating, updating, and using histograms based on microseismic data are described in US Provisional Application Number 61 / 710,582, filed October 5, 2012.

In some examples, the histogram is presented as a three-dimensional bar graph, a three-dimensional surface map, or other convenient graph in an appropriate coordinate system. The peaks in the histogram graph

<img file="MX349526B_D0009.tif" />

¹⁹ WIlWl can indicate dominant orientations example, along an axis, the hi stog branch —— &lt;* uei Jtt represent direction angles of 0^or at 360 ° (or other range), and the steering angles can be divided into any convenient number of tanks; Along another axis, the histogram can represent dip angles from 60 ° to 90 ° (or another range), and the dip angles can be divided into any convenient number of cells. The quantity (for example, probability) for each cell can be plotted along a third axis in the histogram. The resulting graph can show the local highs (peak). Each local maximum (peak) may indicate a respective direction angle and a respective dip angle representing a dominant orientation of the fracture. For example, the local maximum of the histogram may indicate that more basic planes are aligned along this direction (or range of directions) than along neighboring directions, and these basic planes are either in a closely parallel position. or substantially in the same plane.

The orientation range represented by each cell in the histogram can be determined through any appropriate technique. In some cases, each cell represents a predetermined range of orientations. For example, the fixed cell size method can be used. In some cases, the range or size for each cell is calculated based on the data to be represented by the histogram. For example, the natural optimal cell size method can be used. In some cases, the ground plane orientations are classified, and groupings of classified orientations are identified. For example, all addresses can be sorted in descending or ascending order and then grouped into groupings; Similarly, all dip values ​​can be sorted in descending or ascending order and then grouped into groupings. Clusters can be associated with a two-dimensional grid, and the number of basic planes in each grid cell can be counted. In some cases, this technique can generate adaptive and dynamic groupings, leading to highly accurate values ​​for the dominant orientations. This technique and associated refinements can be implemented with computational complexity N³log {N). In some cases, the cell sizes for both direction and dip are fixed, and each base plane location grid cell can be explicitly determined through the dip and direction associated with a computational complexity N³.

Fracture planes associated with a set of events ²¹ ΙΜΡΙ «^. ,, WSTITUTO MEXICANO microseismic can be extracted from dominants incorporated in the histogram data. Basic planes that support the dominant orientation (θ, φ), can be either almost parallel or in the same plane. Basic planes located within the same plane can be fused together, forming a new fracture plane with stronger support (for example, representing a greater number of microseismic events). Any convenient technique can be used to fuse the fracture planes. In some cases, for each dominant orientation (θ, φ), a normal to the plane vector is constructed with the components (sine Θ cosine φ, sine θ, sine φ, cosine 9). In some cases, the results are insensitive to the location of the plane, and without loss of generality, the plane can be constructed from this normal vector (for example, assuming the origin is in the plane). The plane can be described by

X sine Θ cosine φ + y sine Θ, sine φ + z cosine 9 = 0. The normal signed distance of each event (x₀, Y₀, z₀) from a basic plane to the built plane can be represented d =

- (x₀ sine 9 cosine φ + y₀ sine 9 sine φ + x or cosine 9). In this representation events with opposite signs of d are located on opposite sides of the plane.

In some cases, microseismic events are grouped into clusters based on their distance from the plane of ²² IMPI ^^

MEXICAN INSTITUTE fracture built. For example, a groupSMX ^ I®, ^ d ^^^ D ^ os can contain the most important group of events to a constructed fracture plane. As such, each cluster of microseismic events can support a particular fracture plane. Cluster size refers to the number of events that the cluster contains. In some cases, user input or other program data may designate a minimum number of events in a sustained grouping. The minimum cluster size may depend on the number of microseismic events in the data. In some cases, the minimum cluster size should be greater than or equal to three. For example, clusters that have a size greater than or equal to the minimum cluster size can be considered legitimate fracture planes. A location fit algorithm and location uncertainty values ​​for the events in each cluster can be applied to find their corresponding fracture plane.

Any convenient technique can be used to identify a fracture plane from a set of microseismic events. In some cases, the Chi-square fitting technique is used. Given the K observed microseismic events, the locations can be represented (xí, yi, z¿), and their measurement uncertainty can be represented (oí,_x, Oi,_Y, Oi,_z), where 1 i K.

₂₃ ΙΜΡΙ ^% Mexican rísrrruTO of the INDUSTRIAL property r 'the parameters of the plane model z = ax + by + c can be calculated, for example, by minimizing the Chi-square merit function.

X²(a, b, c) κ (ζ, -αχ, -δγ, -ο)^{2 , = l}to²z + a²to²x + b²to²_Y (2)

The Chi-square merit function can be solved by any convenient technique. In some cases, a solution can be obtained by solving three equations, which are partial derivatives of X²(a, b, c) with respect to its variables, where each partial derivative is zeroed. In some cases, there is no analytical solution for this nonlinear mathematical system of equations. Numerical methods (for example, Newton's numerical method, Newton Rafson method, conjugate gradient method, or another technique) can be applied to solve the parameters a, b and c, and the direction and dip angles can be calculated (for example, using equation (1) above). The orientation of the dominant fracture plane calculated from microseismic events may be the same as, or it may be slightly different from, the dominant fracture orientation identified from the histogram.

In some implementations, an algorithm iterates over all dominant possible orientations to expand all possible fracture planes. In some cases, the

IMPIé ^

MEXICAN INSTITUTE

DELAMOPIEBaD algorithm iterates over a literate subset of possible dominant orientations. LcFB iTétaolo'nes can converge on planes. Some planes may be exactly the same as each other and some may be close to each other. Two planes can be considered close to each other, for example, when the average distance of the events of one plane from another plane is less than a certain threshold. The threshold distance can be designated, for example, as a control parameter. The algorithm can merge nearby planes together and the support events of one plane can be associated with the support events of the other merged planes.

In some cases, constraints are imposed on the fracture planes identified from the microseismic data. For example, in some cases, the residual event distance must be less than a certain tolerance distance. The tolerance distance can be designated, for example, as a control parameter. In some cases, the identified fracture planes need to be appropriately truncated to represent the finite size of fractures. The truncated plane limit can be calculated from the position of the supporting events and the uncertainty of the event location measurement. New finite size fracture planes can be

<img file="MX349526B_D0010.tif" />

IMPI iNSTnvr · Mexican DE LA r * On »A · INBUSntlAL fusing with the already identified fractures.

In some cases, a new N³The entry microseismic event is associated with the already identified fracture planes based on the previous N-1 microseismic events. When associating the new event with an existing fracture, an algorithm can be used to update the existing fracture. For example, updating the fracture may change the geometry, location, orientation, or other parameters of the fracture. By choosing one of the previously identified fracture planes, the distance of the fracture plane from the new event can be calculated. If the distance is less than or equal to the distance control parameter, the new event can be added to the support event set for the fracture plane. If the distance is greater than the distance control parameter, other previously identified fracture planes can be selected (eg, iteratively or recursively) until a plane is found within the threshold distance. After the new event is added to an established support for a fracture plane, new dip and direction values ​​can be evaluated and, if necessary, recalculated (for example, using the Chi-square fit method, or other statistical or deterministic technique) for the

IMPI

6 MEXICAN INSTITUTE

OF THE PROPERTY

INDUSTRIAL * fracture. Typically, recalculating the fracture parameters causes a limited change in orientation due to conditional distance control.

In some cases, when a new microseismic event is associated with a fracture plane, one or more parameters can be modified or optimized (for example, residual distance, area, etc.). The distance residual r from the plane can represent the average distance from the supporting events to the plane. If the distance residual is less than the provided residual tolerance T, the new event can be labeled for the associated events set for the plane. In some cases, an additional process, through which other associated events from the support set are removed from the list, is launched and is terminated when the distance residual r falls within the determined T. An area of ​​the fracture plane can represent the size of the fracture plane. Experience shows that generally a new event causes the fracture plane to propagate in length, grow in height, or both. Therefore, computational processes can be constrained by an area condition that does not decrease, whereby the area of ​​the new plane should grow larger than or remain equal to that of the original plane (rather than shrink) when the new event is added to the plane.

ΙΜΡΙ ^ § ινϊτγπ, γγοmuican · —Ot LA FRBMtDA »inoustmal

The orientation of a fracture plane can represent the angle of the fracture plane. For example, a normal vector, direction and dip angles, or other convenient parameters can be used to represent the orientation of the fracture plane. A change in the orientation of a fracture plane (or other changes to a fracture plane) may cause certain associated support events to be removed from the associated event list to the unassociated event list based on their distance from the Updated fracture plan. Additionally or alternatively, a change in an orientation of the fracture plane may cause some previously unassociated events to be assigned to the fracture plane based on its proximity to the updated fracture plane. Additionally, some events associated with nearby planes can also be associated with the current plane. If a new event is associated with two fracture planes, the fracture planes can cross each other. In some cases, intersecting planes can be merged. If the new event does not belong to an existing fracture plane, it can be assigned to the list of unassociated events.

The N accumulated microseismic events can be considered at any point as a subset of the

2θ IMPI ^

MEXICAN INSTITUTE

OF THE PROPERTY set of final post data events. In dich¿r £^or^ a^Lsos7 ~ ST · histogram or distribution of orientations based on the first N events may be different from the histogram or distribution of orientations constructed from the final post data. Some fracture planes extracted from the N microseismic events may not be precise, and this imprecision may decrease as time increases and as more events accumulate. As an example, the accuracy and confidence may be lower at an initial time when the detected fracture planes are associated with microseismic events located near the borehole. Such data may indicate fracture planes that are nearly parallel to the borehole, even if those planes do not represent actual fractures.

Fracture precision confidence can be used as a measure for the certainty associated with the fracture planes identified from the microseismic data. In some cases, accuracy confidence is identified in real time during fracture treatment. The precision confidence can be determined from any suitable data using any suitable calculations. In some cases, the precision confidence value for a fracture plane is influenced by the number of associated microseismic events.

<img file="MX349526B_D0011.tif" />

with the fracture plane. For example, the trust value

IMPI

MEXICAN INSTITUTE OF INDUSTRIAL PROPERTY can scale (for example, linearly, non-linearly, exponentially, polynomially, etc.) with the number of microseismic events according to a function. The number of microseismic events associated with a fracture plane can be incorporated (eg, as a weight, an exponent, etc.) into an equation to calculate precision confidence. In some cases, a fracture plane has a higher confidence value when the fracture plane is supported by a larger number of microseismic data points (or a lower confidence value when the fracture plane is supported by a smaller number microseismic data points).

In some cases, the precision confidence value for a fracture plane is influenced by the uncertainty of the location for microseismic events associated with the fracture plane. For example, the precision confidence value can scale (eg, linearly, nonlinearly, exponentially, polynomially, etc.) with the uncertainty of the location of the microseismic event according to a function. The uncertainty of the location of the microseismic event can be incorporated (for example, as a weight, an exponent, or any decaying function of the distance, etc.) into an equation to calculate the confidence

<img file="MX349526B_D0012.tif" />

precision. In some cases, a fracture plane has a

IMPI

MEXICAN INSTITUTE »E LA PROPERTY INDUSTRIAL Higher confidence value when the fracture plane is supported by microseismic data points that have a lower uncertainty (or a lower confidence value when the fracture plane is supported by microseismic data points that have a greater uncertainty).

In some cases, the precision confidence value for a fracture plane is influenced by the magnitude of the moment for microseismic events associated with the fracture plane. For example, the precision confidence value can be scaled (eg, linearly, nonlinear, exponential, polynomial, etc.) with the magnitude of the moment of the microseismic event according to a function. The magnitude of the moment of the microseismic event can be incorporated (eg, as a weight, an exponent, etc.) into an equation to calculate the precision confidence. The magnitude of the moment for a microseismic event can refer to the energy or intensity (sometimes proportional to the square of the amplitude) of the event. For example, the magnitude of the moment for a microseismic event can be a logarithmic scale value of the energy or intensity, or another type of value that represents the intensity of the energy. In some cases, a fracture plane has a higher confidence value when the fracture plane is

IMPI ^:

MEXICAN INSTITUTE

O-ι OF THE PROPERTY ΥΛτ ^ -rycjL

O 1 INDUSTRIAL&gt; is supported by microseismic data points than a higher intensity (or a lower confidence value when the fracture plane is supported by microseismic data points that have a lower intensity).

In some cases, the precision confidence value for a fracture plane is influenced by the distance between the fracture plane and the microseismic events associated with the fracture plane. For example, the precision confidence value can be scaled (eg, linearly, nonlinearly, exponentially, polynomial, etc.) with the average distance between the fracture plane and the microseismic events that support the fracture plane. Average distance can be incorporated (for example, as a weight, as an exponent, etc.) into an equation to calculate precision confidence. In some cases, a fracture plane has a higher confidence value when the fracture plane is supported by microseismic data points that are, on average, closer to the fracture plane (or a lower confidence value when the fracture plane is fracture is supported by microseismic data points that are, on average, further from the fracture plane).

In some cases, the precision confidence value for a fracture plane is influenced by the orientation of the fracture plane with respect to a dominant orientation trend in the set of 'INDUSTRIAL

For example, the precision confidence value can be scaled (for example, linearly, nonlinearly, exponentially, polynomial, etc.) with the angular difference between the orientation of the fracture plane and a dominant orientation trend in the data. microseismic. Orientation angles can include direction, dip, or any relevant combination (eg, a three-dimensional spatial angle). The orientation can be incorporated (for example, as a weight, an exponent, etc.) into an equation to calculate the precision confidence. A microseismic data set may have one dominant orientation trend or it may have multiple dominant orientation trends. Dominant orientation trends can be classified, for example, as primary, secondary, etc. In some cases, a fracture plane has a higher confidence value when the fracture plane is aligned with a dominant orientation trend in the microseismic data set (or a lower confidence value when the fracture plane is deviated from the trend). dominant orientation in the microseismic data set).

A weighting value called the fracture orientation variation weight can represent the

IMPI Mexican institute DE LA MONEDAD Angular difference between the orientation of the plSRVí ^ 'fe fracwra and a dominant orientation trend in microseismic data. The fracture orientation variation weight can be a scalar value that is a maximum when the fracture plane is aligned with a dominant orientation trend. The fracture orientation variation weight may be a minimum for fracture orientations that are maximally separated from a dominant fracture orientation trend. For example, when there is a single dominant fracture orientation trend, the fracture orientation variation weight can be zero for fractures that are perpendicular (or normal) to the dominant fracture orientation. As another example, when there are multiple dominant fracture orientation trends, the fracture orientation variation weight can be zero for fractures that have orientations between the dominant fracture orientations. The weight of variation of the fracture orientation can be the ratio of the orientation of the calculated plane and the orientation reflected by the homogeneous case.

In some cases, when there are multiple dominant fracture orientation trends, the fracture orientation variation weight has the same maximum value for each dominant fracture orientation trend. In some cases, when there are multiple dominant fracture orientations, the fracture orientation variation weight has a different local maximum value for each dominant fracture orientation. For example, the fracture orientation variation weight can be 1.0 for fractures that are parallel to a first dominant fracture orientation trend, 0.8 for fractures that are parallel to a second dominant fracture orientation trend, and 0.7 for fractures. that are parallel to a third dominant fracture orientation trend. The weight of variation of the fracture orientation can decrease to the local minima between the trend of dominant fracture orientations. For example, the weight of fracture orientation variation between each neighboring pair of dominant fracture orientations may define a local minimum in the middle between the dominant fracture orientations or at another point between the dominant fracture orientations.

The precision confidence parameter can be influenced by the uncertainty of the location of the supporting microseismic events, the magnitude of the moment of the supporting microseismic events, the distance between the supporting microseismic events and the fracture plane, the number of support events associated with plane, weight

<img file="MX349526B_D0013.tif" />

IMPI, other values, or variation of the fracture orientation "I 1 · * S ¹ Ί 1 any appropriate combination of one or more of these. In some general models, the confidence increases as the magnitude of moment is larger, and as the variation of the fraction orientation becomes larger, and the number of support events is larger, and its precision in its location is larger, as the weight variation as a function of distance is larger. Those factors can be used as inputs to define the weight in an equation for precision confidence. For example, in some models, the weights are linear or non-linear functions of these factors and the weight of variation of the fracture orientation may appear with a higher weight when it influences the plane confidence. In some examples, the precision confidence is calculated as:

Confidence = (fracture orientation variation weight) * evenroi ((p_that location uncertainty) * (moment magnitude weight) * (distance variation weight)). (3)

Other equations or algorithms can be used to calculate confidence.

The identified fracture planes can be classified into confidence levels based on the values ​​of

<img file="MX349526B_D0014.tif" />

³⁶ IMPI MEXICAN INSTITUTE confidence in the precision of frac ¥ tf® ^ ™ planes In cases, three levels are used: low ñivo! de — eon-fF-an-zeT— medium confidence level and high confidence level. Any convenient number of confidence levels can be used. In some examples, when a new event is added to the support assembly associated with an existing fracture plane, its associated fracture confidence parameter can be increased, which can cause the fracture plane to drift from its current confidence level. to a higher one, if any. As another example, if a fracture orientation deviates from the orientation trends shown by the microseismic event post data, as microseismic events gradually accumulate, a decrease in fracture confidence can be induced, mainly by the weight of variation of the orientation of the fracture, causing the plane to decrease its level to a lower confidence level, if it exists. This can particularly apply to fractures created at the initial moment of hydraulic fracturing treatment; this may also apply to other types of fractures in other settings.

Users (for example, field engineers, operational engineers and analysts, as well as others) can be provided with a graphical display of the construction drawings.

MEXICAN INSTITUTE DE LA MONEDAD fracture identified from the data 'WKTosisrñTcos. In some cases, the graphic screen allows the user to view the identified plans in real time, in graphic panels that present the confidence levels. For example, three graphical panels can be used to separately display the low confidence level, medium confidence level and the high confidence level of the fracture planes. In some cases, the lower confidence level fracture planes are created early in the fracture treatment. In some cases, higher confidence level fracture planes propagate in time in the direction almost perpendicular to the borehole. Ά As new microseismic events gradually accumulate over time, the graphic display can be updated to allow users to dynamically observe the association of fracture planes between confidence levels associated with graphic panels.

The confidence level groups can be presented as graphs of the fracture planes, or the confidence level groups can be presented in another format. Confidence level groups can be presented in algebraic form, for example by showing algebraic parameters (for example, parameters for the equation of a

<img file="MX349526B_D0015.tif" />

IMPI®

MEXICAN INSTITUTE OF PROPERTY „_Ί___,. ____. x -____ __ INDUSTRIAL plane) of the fracture planes in each group. Confidence level groups can be presented in numerical form, for example, showing the numerical parameters (eg direction, dip, area, etc.) of the fracture planes in each group. The confidence level groups can be presented in a tabular form, for example by presenting a table of the algebraic parameters or numerical parameters of the fracture planes in each group. In addition, a fracture plane can be graphically represented in three-dimensional space, two-dimensional space, or another space. For example, a fracture plane can be represented in a rectilinear coordinate system (for example, x, y, z coordinates) in a polar coordinate system (for example, r, θ, φ coordinates), or another coordinate system . In some examples, a fracture plane can be represented as a line at the intersection of the fracture plane with another plane (for example, a line in the xy plane, a line in the xz plane, a line in the yz plane, or a line in any arbitrary plane or surface).

In some cases, a graphical display allows users to track and visualize the spatial and temporal evolution of specific fracture planes, including their generation, propagation, and growth. For example, a user can observe stages of a spatial evolution and

IMPIAS

9 MEXICAN INSTITUTE J

DE LA MOHEDAL »¿J * ¿-y

INDUSTRIAL time of the specific fracture plane such as, for example, initially identifying the fracture plane based on three microseismic events, a new event that changes the orientation of the plane, a new event that causes the area of ​​the planes to grow (for for example, vertically, horizontally, or both) or other stages in the evolution of a fracture plane. The spatial and temporal evolution of the fracture planes can present the displacement trajectories of stimulated fluids and support agents injected into the rock matrix. Visualizing the dynamics of fracture planes can help users better understand the hydraulic fracturing process, analyze fracture complexity more accurately, evaluate hydraulic fracturing effectiveness, or improve well performance.

Although this application describes examples involving microseismic event data, the techniques and systems described in this application can be applied to other types of data. For example, the techniques and systems described here can be used to process data sets that include data elements that are not related to microseismic events, which may include other types of physical data associated with an underground area. In some respects, this application provides a framework for the

<img file="MX349526B_D0016.tif" />

processing of large volumes of data

IMPI

INSTITUTO MEXICAN · DF LA PROPERTY industrial the framework can be adapted for various applications that are not specifically described here. For example, the techniques and systems described here can be used to analyze spatial coordinates, orientation data, or other types of information collected from any source. As an example, soil or rock samples can be collected (eg during drilling) and the concentration of a given compound (eg a certain salt) can be identified as a function of location. This can help geophysicists and operators evaluate geolayers in the ground.

Figure 1A shows a schematic diagram of an exemplary well system 100 with a computing subsystem 110. The exemplary well system 100 includes a treatment well 102 and an observation well 104. The observation well 104 can be located away from the treatment well 102, near treatment well 102, or at any convenient location. Well system 100 may include one or more additional treatment wells, observation wells, or other types of wells. The computing subsystem 110 may include one or more computing devices or systems located in the treatment well 102, in the observation well 104, or other locations. The

IMPI

INSTITUTO MEXICAN · Di LA FROMEDAD, INDUSTRIAL computing subsystem 110 or any of its components can be located separately from the other components shown in figure 1A. For example, computing subsystem 110 may be located in a data processing center, computing facility, or other convenient location. Well system 100 may include additional or different features, and the well system features can be accommodated as shown in Figure 1A or in any other convenient configuration.

The exemplary treatment well 102 includes a borehole 101 in an underground zone 121 below the surface 106. The underground zone 121 can include one or less of one rock formation, or the underground zones 121 can include more than one rock formation. In the example shown in Figure 1A, the underground zone includes various subsoil layers 122. The subsoil layers 122 can be defined by geological or other properties of the underground zone 121. For example, each of the subsoil layers 122 may correspond to a particular lithology, a particular fluid content, a particular pressure or stress profile, or any other desirable characteristic. In some cases, one or more of the subsurface layers 122 may be a fluid reservoir.⁴²MEXICAN INSTITUTE DE LA PROPIEDAD Ό ** 3ρ * &amp; Ρ containing hydrocarbons or other types of fTtíTObs r * dz ^ r '⁼'UNDERGROUND ZONE 121 may include any convenient' TOT'oSS ^ ​​T ^ TSTfRSüTOT. For example, one or more of the subsoil layers 122 may include sandstone, carbonate materials, shale, coal, shale clay, granite, or other materials.

Exemplary treatment well 102 includes injection treatment subsystem 120, which includes instrument trucks 116, pump trucks 114, and other equipment. The injection treatment subsystem 120 may apply an injection treatment to the underground zone 121 through the borehole 101. The injection treatment can be a fracture treatment that fractures the underground zone 121. For example, injection treatment can initiate, propagate, or open fractures in one or more of the subsoil layers 122. A fracture treatment can include a mini-fracture trial treatment, a regular or complete fracture treatment, a follow-up fracture, a re-fracture treatment, a final fracture treatment, or another type of fracture treatment.

Fracture treatment can inject a treatment fluid into underground zone 121 at any convenient fluid pressures and flow rates of

IMPI

INSTITUTO mar, κι.INSTITUTO MtXICAHC of Fluid Industrial Currency. Fluids may be injected above, below, or below a fracture initiation pressure, above7 at or below a fracture closure pressure, or in any suitable combination of these and other fluid pressures. The fracture initiation pressure for a formation is the minimum fluid injection pressure that can initiate or propagate artificial fractures in the formation. The application of a fracture treatment may or may not initiate or propagate artificial fractures in the formation. The fracture closure pressure for a formation is the minimum fluid injection pressure that can expand existing fractures in the underground formation. The application of a fracture treatment may or may not dilate natural or artificial fractures in the formation.

A fracture treatment can be applied through any appropriate system, using any convenient technique. Pump trucks 114 may include mobile vehicles, immovable installations, skids, hoses, tubes, fluid tanks or reservoirs, pumps, valves, or other suitable structures and equipment. In some cases, truck pumps 114 are coupled to a workstring placed in borehole 101. During operation, pump trucks 114 can pump fluid through the string ₄₄

MEXICAN INSTITUTE

OF THE PROPERTY

INDUSTRIAL 'work and within underground zone 121. The pumped fluid may include a filler, holding agents, a flushing fluid, additives or other materials.

Fracture treatment can be applied at a single fluid injection location or multiple fluid injection locations in an underground area, and the fluid can be injected over a single time period or over multiple different time periods. In some cases, a fracture treatment may use multiple different fluid injection locations in a single borehole, multiple fluid injection locations in multiple different boreholes, or any suitable combination. Furthermore, the fracture treatment can inject fluid through any convenient type of borehole, such as, for example, vertical boreholes, inclined boreholes, horizontal boreholes, curved boreholes, or any suitable combination. of these and others.

A fracture treatment can be controlled through any appropriate system, using any convenient technique. Instrument trucks 116 can include mobile vehicles, immovable facilities, or other convenient structures. Instrument trucks 116 may include an injection control system that

ΙΜΡΙ6 ^

MEXICAN INSTITUTE

OF PROPERTY Ομμμ ^^ Μ · * industrial 7 ^ - monitors and controls the fracture treatment applied by the injection treatment subsystem 120. In some implementations, the injection control system can communicate with other equipment to monitor and control injection treatment. For example, instrument trucks 116 can communicate with pump truck 114, subsurface instruments, and monitoring equipment.

Fracture treatment, as well as other activities and natural phenomena, can generate microseismic events in underground zone 121, and microseismic data can be collected from underground zone 121. For example, microseismic data can be collected by one or more sensors 112 associated with observation well 104, or microseismic data can be collected by other types of systems. The microseismic information detected in the well system 100 can include acoustic signals generated by natural phenomena, acoustic signals associated with a fracture treatment applied through the treatment well 102, or other types of signals. For example, sensors 112 can detect acoustic signals generated by rock slides, rock movements, rock fractures, or other events in underground zone 121. In some cases, the locations of individual microseismic events can be determined

<img file="MX349526B_D0017.tif" />

IMPI iNSTmrro Mexicano t&gt; E INDUSTRIAL PROPERTY based on microseismic data.

Microseismic events in underground zone 121 can occur, for example, along or near induced hydraulic fractures. Microseismic events can be associated with pre-existing natural fractures or hydraulic fracture planes induced by fracturing activities. In some environments, most detectable microseismic events are associated with shear rock fracturing. Such events may or may not correspond to hydraulic induced stress fractures that have significant width generation. The orientation of a fracture can be influenced by the stress regime, the presence of fracture systems that were generated at various times in the past (for example, under the same stress orientation or a different stress orientation). In some environments, older fractures can be cemented to close geologic time, and remain as planes of weakness in the rocks in the subsurface.

The observation well 104 shown in FIG. 1A includes a test well 111 in an underground region below the surface 106. The observation well 104 includes sensors 112 and other equipment that can be used to detect microseismic information. Sensors 112

MEXICAN INSTITUTE DE LA INDUSTRIAL may include geophones or other types of listening equipment. Sensors 112 may be located in a variety of positions in well system 100. In FIG. 1A, sensors 112 are installed on surface 106 and below surface 106 in borehole 111. Additionally or alternatively, the sensors can be placed at other locations above or below surface 106, at other locations within borehole 111, or within another borehole. Observation well 104 may include additional equipment (eg, workstring, packers, casing, or other equipment) not shown in FIG. 1A. In some implementations, microseismic data is detected by sensors installed in treatment well 102 or surface 106 without use of an observation well.

In some cases, all or part of the computing subsystem 110 may be contained in a technical command center at the well site, in a real-time operations center at a remote location, at another appropriate location, or any suitable combination of these. Well system 100 and computer system 110 may include or have access to any convenient communication infrastructure. For example, well system 100 may include multiple separate communication links or

<img file="MX349526B_D0018.tif" />

a network of interconnected communication links. The

IMPI

MEXICAN INSTITUTE DE LA RWOMÍDAD INDUSTRIAL Communication links may include wired or wireless communication systems. For example, sensors 112 can communicate with instrument trucks 116 or computing subsystem 110 through links or wired or wireless networks, or instrument trucks 116 can communicate with computing subsystem 110 through links. or wired or wireless networks. Communication links may include a public data network, a private data network, satellite links, dedicated communication channels, telecommunications links, or any suitable combination of these and other communication links.

Computing subsystem 110 can analyze microseismic data collected in borehole system 100. For example, computing subsystem 110 can analyze microseismic event data from a fracture treatment from an underground zone 121. Microseismic data from a fracture treatment They may include data collected before, during, or after fluid injection. The computing subsystem 110 can receive the microseismic data at any convenient time. In some cases, the computing subsystem 110 receives the microseismic data in real time (or substantially in time

MEXICAN INSTITUTE Di LA FROREDAD INDIFSTWAL real) during fracture treatment. For example, microseismic data can be sent to computing subsystem 110 immediately upon detection by sensors 112. In some cases, computing subsystem 110 receives some or all of the microseismic data after fracture treatment has been completed. . The computing subsystem 110 can receive the microseismic data in any convenient format. For example, the computing subsystem 110 may receive the microseismic data in a format produced by microseismic sensors or detectors, or the computing subsystem 110 may receive the microseismic data after the microseismic data has been formatted, packaged, or otherwise processed. The computing subsystem 110 may receive the microseismic data through any convenient means. For example, the computing subsystem 110 may receive microseismic data over a wired or wireless communication link, over a wired or wireless network, or through one or more disks or other tangible media.

The computing subsystem 110 can be used to perform fracture mapping in real time during a fracture treatment. For example, the computing subsystem 110 may receive microseismic data as a

MEXICAN INSTITUTE)

DI LA FROFIEDAC. , INDUSTRIAL U &gt;&gt; time series of individual microseismic events as fracture treatment is applied. At any given time, the computing subsystem 110 can identify fracture planes based on the microseismic data that has accumulated up to that point. When a new microseismic event is detected, the computing subsystem 110 can update the previously generated fracture planes based on the new microseismic event. For example, computing subsystem 110 may identify a previously generated fracture plane that is most likely associated with the new microseismic event. The previously generated fracture plane can be identified, for example, based on spatial proximity or other considerations. The new microseismic event can be combined with other microseismic events associated with the previously generated fracture plane, and the combined set of microseismic events can be fitted to one plane. Various revisions can be performed, for example, to improve the accuracy of the results. In some cases, the updated fracture plane can be displayed to a user in real time, to allow the user to view the growth, propagation or evolution of fractures in the underground zone.

Some of the techniques and operations described here are

<img file="MX349526B_D0019.tif" />

IMPI

MEXICAN INSTITUTE

OF THE PROPERTY, INDUSTRIAL can be implemented through a computing subsystem configured to provide the described functionality. In various embodiments, a computing device can include any of several types of devices, including, but not limited to, personal computer systems, desktops, laptops, notebooks, mainframe systems, handheld computers, workstations, tablets. , application servers, storage devices, or any type of electronic or computing device.

Figure IB is a diagram of the exemplary computing subsystem 110 of Figure 1A. Exemplary computing subsystem 110 may be located in or near one or more wells of well system 100 or at a remote location. All or part of the computing subsystem 110 can operate independently of the well system 100 or independently of any of the other components shown in FIG. 1A. Exemplary computing subsystem 110 includes a processor 160, memory 150, and input / output controllers 170 communicatively coupled via bus 165. The memory may include, for example, random access memory (RAM), a memory device. storage (for example, a write-read-only memory (ROM) or others), a hard disk, or other

IMPI

MEXICAN INSTITUTE 5 2 θΕ L * PROPERTY

INDUSTRIAL type of storage medium. The computing subsystem 110 can be pre-programmed or it can be programmed (and reprogrammed) by loading a program from another source (for example, from a CD-ROM, from another computer device over a data network, or otherwise ). The input / output controller 170 is coupled to input / output devices (eg, a monitor 175, a mouse, keyboard, or other input / output devices) and to a communication link 180. The input / output devices they receive and transmit data in analog or digital form over communication links such as a serial link, a wireless link (for example, infrared, radio frequency, or others), a parallel link, or another type of link.

Communication link 180 can include any type of communication channel, connector, data communication network, or other link. For example, communication link 180 may include a wired or wireless network, a Local Area Network (LAN), a Wide Area Network (WAN), a Private Network, a Public Network (such as the Internet), a network WiFi, a network that includes a satellite link, or another type of data communication network. Memory 150 can store instructions (eg, computer code) associated with an operating system,

............ IB ₅₃ IMPI

MEXICAN INSTITUTE »E LA PROPERTY ..., INDUSTRIAL computer applications, and other resources.

Memory 150 may also store application data and data objects that can be interpreted by one or more applications or virtual machines running on computing subsystem 110. As shown in Figure IB, exemplary memory 150 includes microseismic data. 151, geological data 152, fracture data 153, other data 155, and applications 156. In some implementations, a memory of a computing device includes additional or different information.

Microseismic data 151 can include information on the locations of microseisms in an underground area. For example, microseismic data may include information based on acoustic data detected at observation well 104, surface 106, treatment well 102, or other locations. Microseismic data 151 may include information collected by sensors 112. In some cases, microseismic data 151 have been combined with other data, reformatted, or otherwise processed. Microseismic event data can include any convenient information related to microseismic events (locations, magnitudes, uncertainties, times, etc.). Event data

<img file="MX349526B_D0020.tif" />

Microseismics may include data collected from one or

IMPI

MEXICAN INSTITUTE plus fracture treatments, which may include data collected before, during, or after a fluid injection.

Geological data 152 may include information on the geological properties of the underground zone 121. For example, geological data 152 may include information on subsurface layers 122, information on boreholes 101, lll or information on other attributes of the underground zone 121. In some cases, geological data 152 includes information on the lithology, fluid content, stress profile, pressure profile, spatial extent, or other attributes of one or more rock formations in the underground zone. Geological data 152 may include information collected from well logs, rock samples, rock outcrops, microseismic imaging, or other data sources.

Fracture data 153 may include information on fracture planes in an underground zone. Fracture data 153 can identify the locations, sizes, shapes, and other properties of fractures in a model of an underground zone. Fracture data 153 can include information on natural fractures, hydraulically induced fractures, or any other type of

<img file="MX349526B_D0021.tif" />

IMPI r r- MEXICAN INSTITUTE

3 OF THE PROPERTY

INDUSTRIAL discontinuity in underground zone 121. Fracture data 153 may include fracture planes calculated from microsymal data 151. For each fracture plane, the fracture data 153 may include information (eg, steering angle, dip angle, etc.) identifying an orientation of the fracture, information identifying a shape (eg, curvature, gap, etc. .,) of the break, information that identifies the limits of the break, or any other suitable information.

Applications 156 may include software applications, texts, programs, functions, executables, or other modules that are interpreted or executed by processor 160. Such applications may include machine-readable instructions for executing one or more of the operations depicted in the figure. Four. Applications 156 may include machine-readable instructions for generating a user interface or graph, such as, for example, those depicted in Figures 2A, 2B, 3A, 3B, 3C, · 3D, 3E, and 3F. Applications 156 can obtain input data, such as microseismic data, geological data, or other types of input data from memory 150, from another local source, or from one or more remote sources (for example, via the link of

IMPI

MEXICAN INSTITUTE DB LA PROPIEDAD communication 180). Applications 156 can output and store Oe S'cL'l'tdU data in the¹memory 150, on another local medium, or on one or more remote devices (eg, by sending the output data over communication link 180).

Processor 160 may execute instructions, for example, to generate output data based on the data inputs. For example, processor 160 can run applications 156 by executing or interpreting software, texts, programs, functions, executables, or other modules contained in applications 156. Processor 160 may execute one or more of the operations depicted in Figure 4 or may generate one or more of the interfaces or graphics shown in Figures 2A, 2B, 3A, 3B, 3C, 3D, 3E, and 3F. The input data received by processor 160 or the output data generated by processor 160 may include any of microseismic data 151, geological data 152, fracture data 153, or other data 155.

Figures 2A and 2B are graphs showing exemplary fracture planes. Figure 2a includes a graph 200a showing an initial fracture plane 208a, an updated fracture plane 208b, and a microseismic event 206a. Graph 200a shows the effect of updating the parameters of the initial fracture plane 208a based on the new

IMPI ^ J

FT MEXICAN INSTITUTE 'DI LA FROriEDAD kVaWSLaÍ INDUSTRIAL microseismic event 206a. In particular, updating the parameters of the initial fracture plane 208a generates the updated fracture plane 208b.

A fracture plane can be plotted in any convenient coordinate system (eg, spherical coordinates, rectangular coordinates, etc.). Graph 200a shows the fracture planes in a three-dimensional rectilinear coordinate system. In graph 200a, the coordinate system is represented by the vertical axis 204a and two horizontal axes 204b and 204c. Vertical axis 204a represents a range of depths in an underground zone; horizontal axis 204b represents an east-west coordinate range; and the horizontal axis 204c represents a range of north-south coordinates (all in units of feet).

The initial fracture plane 208a and updated fracture plane 280b are represented by two-dimensional, rectangular bodies that extend through three-dimensional space. A fracture plane can have any other convenient geometry, such as, for example, triangular, ellipsoidal, trapezoidal, irregular geometry, or other geometry.

Graph 200a shows an example of how the parameters of a fracture plane can be updated based on a single microseismic event. As shown₅₈ IMPIc ^

FROM INDUSTRIAL EROHEBAD - comparing the two fracture planes in figure 2A, updating the initial fracture plane 208a based on microseismic event 206a causes the fracture plane to grow in height and length; the updated fracture plane 208b has a greater vertical and horizontal extent than the initial fracture plane 208a. Consequently, the updated fracture plane 208b has a larger area than the initial fracture plane 208a. In some cases, updating a fracture plane changes the fracture plane in another way.

Figure 2B includes another graph 200b showing an initial fracture plane 208c, an updated fracture plane 208d, and a microseismic event 206b. The graphic

200b shows the effect of updating the parameters of the initial fracture plane 208c based on the new microseismic event 206b. In particular, updating the parameters of the initial fracture plane 208c generates the updated fracture plane 208d.

Graph 200b shows the fracture planes in a three-dimensional rectilinear coordinate system represented by the vertical axis 204d and two horizontal axes 204c and 204f. The axes in graph 200b represent the same parameters as the axes in graph 200a, on a different scale. The initial fracture plane 208c and the

IMPI

MEXICAN INSTITUTE oe LA INDUSTRIAL PROPERTY updated fracture plane 208d are represented by two-dimensional, rectangular areas that extend in the three-dimensional coordinate system.

As shown by comparing the two fracture planes in Figure 2B, updating the initial fracture plane 208c based on microseismic event 206b causes the fracture plane to rotate to a new orientation. For example, the updated fracture plane 208d has a different orientation than the initial fracture plane 208c, with respect to the vertical and horizontal axes in graph 200b. Accordingly, the updated fracture plane 208d and the initial fracture plane 208c define normal vectors that have different orientations (ie, pointing in directions not parallel in space).

Figures 3A-3F are graphs showing updates for an exemplary fracture plane. The graphs show an exemplary time sequence for the fracture plane. Figure 3A shows a graph 300a of an initial fracture plane 308a; each later graph in the time sequence shows the fracture plane as updated based on a new microseismic data point. Figure 3B shows a graph 300b of an updated first fracture plane 308b; Figure 3C shows a graph 300c of a second fracture plane⁶⁰ IMPI

INWf'-ΠΌ updated 308c; the 3D figure shows a WW »jwUS-« and an updated third fracture plane, 3.084 ^ —1 * —Fi-yurs¹ A graph 300e of an updated fourth fracture plane 308e is shown; Figure 3F shows a graph 300f of an updated fifth fracture plane 308f. In each graph, the previous version of the fracture plane is shown 'for comparison. The graphs in Figures 3A-3F also show borehole 310 and microseismic events 306.

Each of the graphs 300a, 300b, 300c, 300d, 300e, and 300f show the respective fracture planes in a three-dimensional rectilinear coordinate system represented by the vertical axis 304a and two horizontal axes 304b and 304c. Vertical axis 304a represents a range of depths in an underground zone; horizontal axis 304b represents an east-west coordinate range; and the horizontal axis 304c represents a range of north-south coordinates (all in foot units). As shown in the figures, the axes are scaled for each respective graph. In the examples shown in Figures 3A-3F, the fracture planes are represented by two-dimensional rectangular areas that extend in the three-dimensional coordinate system. The fracture planes can have other spatial geometries.

The initial fracture plane 308a and the planes of

<img file="MX349526B_D0022.tif" />

6i IMPI MEXICAN INSTITUTE OS LA PROMSOAD updated fracture 308b, 308c, 308d, represent the growth and evolution of an individual iradLLlidr over time. In the example shown, the starting fracture plane 308a is identified when 40 is received.^avo microseismic event; the 87^avo microseismic event triggers an update algorithm. For example, process 430 shown in Figure 4 (or another process) can be used to update a fracture plane based on a new microseismic event. Figure 3B shows that updating the fracture plane based on 87^avo microseismic event changes the orientation of the fracture plane. In particular, the update of the initial fracture plane 308a based on the 87^av0 Microseismic event causes the fracture plane to rotate to a new orientation, and the updated first fracture plane 308b has a different orientation than the initial fracture plane 308a. The remaining updates shown in Figures 3C-3F cause the fracture plane to propagate, and the graphs show how the area of ​​the fracture plane increases as time progresses.

Figure 3C shows an update based on 89^avo microseismic event received. The updated fracture foreground update 308b based on 89^av0microseismic event causes the fracture plane to grow

MEXICAN INSTITUTE DE LA PROPIEDAD vertically, and the second plane of fracTOy ^^ ctuSTÍzado 308c is higher than the foreground of — fidULÚfS updated 308b. The 3D figure shows an update based on the 130^avo microseismic event received. The updated fracture second plane update 308C based on the 130^avo Microseismic event causes the fracture plane to grow vertically, and the updated third fracture plane 308d is higher than the updated second fracture plane 308C. Figure 3E shows an update based on the 152^avo microseismic event received. The updated third fracture plane update 308d based on the 152^avThe microseismic event causes the fracture plane to grow horizontally (to the left in the figure), and the updated fourth fracture plane 308e is longer than the updated third fracture plane 308d. Figure 3F shows an update based on 157^avomicroseismic event received. The updated third fracture plane update 308d based on the 157^avo Microseismic event causes the fracture plane to grow horizontally (to the right in the figure) and vertically, and the updated fifth fracture plane 308f is longer and higher than the updated fourth fracture plane 308e.

Figure 4 is a flow chart of a process

IMPI Mexican institute OF INDUSTRIAL PROPERTY specimen 430 to analyze data mi r.rosí smi ros. Some or all of the operations in process 430 may be implemented by one or more computing devices. In some implementations, the process 430 may include additional operations, fewer operations, or different operations executed in the same or different order. Additionally, one or more of the individual operations or subsets of the operations in process 430 can be performed in isolation or in other contexts. Output data generated by process 430, including output generated by intermediate operations, may include information stored, displayed, printed, transmitted, communicated, or processed.

In some implementations, some or all of the operations in process 430 are performed in real time during a fracture treatment. An operation can be executed in real time, for example, by executing the operation in response to receiving data, (for example, from a sensor or monitoring system) without substantial delay. An operation can be executed in real time, for example, by executing the operation while monitoring additional microseismic data from the fracture treatment. Some real-time operations can receive an input and produce an output during a fracture treatment; in

MEXICAN INSTITUTE

OWNERSHIP In some cases, the output is made available to a user within a time frame that allows an operator to respond to the output, for example by modifying the fracture treatment.

In some cases, some or all of the operations in process 430 are performed dynamically during a fracture treatment. An operation can be executed dynamically, for example by iteratively or repeatedly executing the operation based on additional inputs, for example, as inputs are made available. In some cases, dynamic operations are performed in response to receiving data for a new microseismic event (or in response to receiving data for a number of new microseismic events, etc.).

At 400 microseismic data are received for a new microseismic event. For example, microseismic data can be obtained by reading microseismic data from memory, receiving microseismic data from a remote device, or in a different way. Microseismic data may include information about the measured location of the new microseismic event, information about a measured magnitude of the new microseismic event, information about an uncertainty associated with the new microseismic event, or information about a time associated with the new microseismic event.

<img file="MX349526B_D0023.tif" />

₆₅ IMPI

MEXICAN INSTITUTE nt la noptEDAo INDUSTRIAL new microseismic event, etc. Microseismic data is collected from a fracture treatment. For example, microseismic event data can include microseismic data collected at an observation well, a fracture treatment well, at the surface, or at other locations in a well system. Microseismic data from a fracture treatment can include data for microseismic events detected before, during, or after the fracture treatment is applied. For example, in some cases, microseismic monitoring begins before fracture treatment is applied, ends after fracture treatment is applied, or both.

At 401, a previously generated fracture plane is selected. In this example, the fracture plane is previously generated in the sense that it was generated before the data for the new microseismic event was received. In some implementations, the parameters of a previously generated fracture plane are the parameters that were identified from the microseismic data collected before the new microseismic event was detected. The previous data from the previous microseismic event and the new microseismic event can be part of a microseismic data set from the same underground zone fracture treatment. In some cases, the data

MEXICAN INSTITUTE DE LA ΡΒΟΓΙΕΰΑΓ)

INDUSTRIAL ^w the previous microseismic event and the new microseismic event are from different fracture treatments.

Fracture planes (eg, the previously generated fracture plane selected at 401) can be identified from microseismic data by any convenient operation, process, or algorithm. A fracture plane can be identified by calculating the fracture plane parameters, for example, from the locations and other parameters of the measured microseismic events. In some cases, the fracture planes are identified in real time during fracture treatment. Exemplary techniques for identifying fracture planes from microseismic data are described in U.S. Provisional Application Serial Number 61 / 710,582, filed October 5, 2012.

In some cases, when data is received at 400, several fracture planes have already been generated. For example, tens or hundreds of fracture planes may already have been identified from previously received microseismic data. As such, in some cases, a particular fracture plane is selected from multiple fracture planes previously generated at 401. For example, the particular fracture plane can be selected from a list of previously generated fracture planes based on

<img file="MX349526B_D0024.tif" />

. 67 an index, selection criteria or other information.

At 402 the distance between the new microseismic event and the selected fracture plane is calculated. The distance can be calculated, for example, based on the spatial coordinates of the new microseismic event and the parameters of the selected fracture plane. In a certain case, the distance calculation can be considered for the uncertainty in the location of the microseismic event, the uncertainty in the location of the fracture plane, or both. Other information can be considered when calculating the distance.

At 403, the distance between the new microseismic event and the selected fracture plane is compared to a control parameter. The control parameter can be a threshold value to determine if the selected fracture plane is close enough to the new microseismic event, for example, to consider the new microseismic event as a support event for the selected fracture plane. The control parameter can be a pre-designated threshold value (eg, a system constant). The control parameter can be a dynamically calculated value. For example, the control parameter can be calculated based on the parameters of the selected fracture plane, parameters of other planes of

MEXICAN INSTITUTE Λ

OF THE PROPERTY Fracture previously generated, or with ¿&gt; a ^? '^{TO THE} erF ^ ecra information. ----- If the distance between the new microseismic event and the selected fracture plane is not less than the control parameter, process 430 advances to operation 450. At 450, if there are other previously generated fracture planes that are not have been selected, process 430 advances to operation 401. Accordingly, in some cases operations 400, 402, 403, 450 and 401 cause process 430 to select multiple different, previously generated fracture planes in sequence.

Process 430 can use any convenient algorithm or technique to systematically advance through previously generated fracture planes. For example, an indexed list of previously generated fracture planes can be created. The list may be classified, for example, based on the size, confidence, time, or other parameters of the fracture planes, or the list may not be classified. A stored index can be used to systematically select a different previously generated fracture plane from the list each time operation 401 is executed.

In some cases, the previously generated fracture planes are selected in sequence until the planes have been

INSTITUTO MEXICAN * '0F' .A PROPERTY selected all generated. At 450, if all previously generated fracture planes have been selected, the new microseismic event is designated as an unassociated event at 460. As such, the new microseismic event can be labeled, marked, or otherwise designated as not supporting any fracture plane.

In some cases, previously generated fracture planes are selected in sequence until the distance between a selected fracture plane and the new microseismic event is less than the control parameter. At 403, if the distance between the new microseismic event and the selected fracture plane is not less than the control parameter, process 430 advances to step 415. At 415, the selected fracture plane is updated based on the new microseismic event. The operations on the dashed box in Figure 4 represent an exemplary technique for updating a fracture plane based on a new microseismic event. Other techniques can be used.

At 404, parameters of the selected fracture plane are calculated. In the example shown, the orientation, area and distance residual of the fracture plane are calculated. The area of ​​the fracture plane indicates the two-dimensional size of the fracture plane. The residual away

MEXICAN INSTITUTE

DE IA PROPERTY of a fracture plane indicates the distance to the fracture plane and the events of SOpCTTS — Clél pld'HU of fracture.

The orientation of the fracture plane indicates the angle of the fracture plane, for example, in a specified coordinate system. Orientation can be specified, for example, through particular values ​​of dip angle and steering angle. At 404, new direction and dip values ​​can be calculated using a Chi-square fitting technique or other techniques. In some cases, the change in orientation is small, for example due to the conditional control of distance.

The selected fracture plane parameters can be calculated based on the new microseismic event and other microseismic events. For example, the other microseismic events may be previous microseismic events that occurred or were detected (or both) before the new microseismic event. In some cases, the other microseismic events are the set of supporting microseismic events that were used to calculate the previously generated fracture plane (i.e., the fracture plane that was selected in 401).

At 405, the distance residual is compared to a tolerance value. The tolerance value can be a threshold value to determine if the microseismic events that were used to update the fracture plane are (on average) close enough to the updated fracture plane, for example, to consider the new microseismic event as a support event for the updated fracture plane. The tolerance value can be a pre-designated threshold value (for example, a system constant). The tolerance value can be a dynamically calculated value.

At 405, if the distance residual is less than the control parameter, process 430 advances to step 410. At 410 the updated fracture plane can be stored and the new microseismic event is associated with the updated fracture plane.

At 405 if the distance residual is not less than the control parameter, process 430 advances to operation 406. At 406, the distance residual can be reduced by disassociating one or more microseismic events from the selected fracture plane. For example, one or more microseismic events that are the greatest distance from the updated version of the selected fracture plane can be disassociated from the fracture plane.

In 407 new parameters of the plane of

IMPI MEXICAN INSTITUTE DE LA PROPIEDAD ΐΛ ^^ Γ, Λ fracture from microsísmi'oSS events *¹reftiarients after one or more microseismic events TuérCIl disassociated in 406. If the distance residual has not been reduced or if the distance residual has not been reduced by an acceptable amount (for example, less than the tolerance value or some other threshold), then process 430 advances to step 460. At 460, the new microseismic event is designated as an unassociated event at 460. As such, the microseismic event can be labeled, marked, or otherwise designated as not supporting some plane of fracture. In some cases, the selected fracture plane can be restored to its previously generated parameters. In other words, if the new microseismic event is designated as unassociated, the updated parameters for the calculated fracture plane at 404 can be discarded.

In some cases, process 430 improves or optimizes the residual distance and area when the selected fracture plane is updated at 415. For example, when the residual distance from the updated fracture plane is less than the tolerance value at 405, the new microseismic event is associated with the fracture plane at 410. Otherwise, other microseismic events in the support assembly can be disassociated until the residual of

IMPI distance falls within the threshold value. In some rsan ^ ,. changing the orientation or size of the fracture plane causes some microseismic events to be disassociated from the fracture plane. In some cases, changing the orientation or size of the fracture plane causes some microseismic events to be associated with the fracture plane. In some cases, a microseismic event can be associated with multiple fracture planes. The association of a microseismic event with multiple fracture planes may indicate that the fracture planes intersect.

If the distance residual has been reduced by an acceptable amount at 407, then process 430 advances to step 408. At 408 the updated fracture plane area is calculated (after disassociating one or more microseismic events at 406). The area could be the size of the fracture plane generated from the microseismic events still associated with the fracture plane after the events were disassociated in 406. If the size of the fracture plane is not larger than the previous area of ​​the fracture plane, then process 430 advances to operation 460 (described above). As such, the review performed at 408 can ensure that the association of the new microseismic event with the fracture plane does not cause the fracture plane to shrink. This review can be₇₄ IMPI »?

MEXICAN INSTITUTE oe property .j

INDUSTRIAL ““ -T * executed, for example, to incorporate physical or geological constraints in a fracture-matching algorithm. For example, the review may be performed to reflect the knowledge that fractures tend to grow (rather than shrink) during fracture treatment. Experience shows that new microseismic events are typically associated with a fracture that spreads in length or grows in height. As such, the non-diminishing area condition can be imposed to ensure that an area of ​​the updated fracture plane is greater than or equal to that of the original plane. Other assumptions are used in some environments.

At 408, if the size of the fracture plane is greater than the previous area of ​​the fracture plane, then process 430 advances to operation 410. At 410, the new microseismic event is associated with the fracture plane. If any microseismic event was disassociated in 406, those microseismic events can be designated as unassociated, or they can be handled in a different way. Exemplary techniques for handling disassociated microseismic events are described in United States Provisional Application Serial Number 61 / 710,582 filed October 5, 2012. In some cases, updated fracture plane parameters (i.e.

<img file="MX349526B_D0025.tif" />

fracture plane based on microsynic events that remain associated after 406) are stored as the updated fracture plane.

Exemplary process 430 includes revisions that can improve the accuracy of a fracture matching algorithm. For example, some or all of the comparisons in 403, 405, 407, and 408 can help improve confidence that the updated fracture plane corresponds to a physical fracture in the underground zone. Comparisons can be adjusted for a particular environment, as appropriate. In some cases, additional or different comparisons can be made. For example, in some cases, a precision confidence value is used to determine whether a new microseismic event is associated with a plane. Exemplary techniques for calculating a precision confidence value for a fracture plane are described in U.S. Provisional Application Serial Number 61 / 710,582 filed October 5, 2012.

In some implementations, a graphical representation of the updated fracture planes is generated. The graphical representation can be displayed, for example, to present the fracture plane updated in real time during the fracture treatment. The graphical representation can include a single plane of

<img file="MX349526B_D0026.tif" />

go IMPI

MEXICAN INSTITUTE DE LA FROFIEDAD _,. . INDUSTRIAL fracture or multiple fracture planes. The graphical representation may include a three-dimensional representation of the fracture plane, a three-dimensional representation of the microseismic events associated with the fracture plane, or a combination of these and other characteristics. Examples of a representation of a fracture plane are shown in Figures 2A, 2B, 3A, 3B, 3C, 3D, 3E, and 3F. Other types of graphical representations can be used.

The graphical representation can be displayed on a monitor, screen, or other type of display device. In some cases the screen is updated. For example, the displayed graphical representation can be updated based on additional microseismic event data from the fracture treatment. The display (and in some cases, the update) of the graphical representation can allow a user to see the dynamic behavior associated with a fracture treatment. In some cases, a fracture plane may be updated as additional microseismic data accumulates, and updates may cause the fracture plane to grow or change orientation.

Some modalities of subject matter and operations described in this specification can be implemented in digital electronic circuits, or the software of ₇₇

MEXICAN INSTITUTE or LA PROPERTY Oraú'-JiLT®! ' , INDUSTRIAL&gt; ».».

computer, firmware, or hardware, including the structures disclosed in this specification and their structural equivalents, or in combination of one or more thereof. Some modalities of subject matter described in this specification may be implemented as one or more computer programs, that is, one or more modules of computer program instructions, encoded on a computer storage medium for execution by, or for control. of the operation of the data processing apparatus. A computer storage medium may be, or may be included in, a computer-readable storage device, a computer-readable storage substrate, a serial or random access memory array or device, or a combination of one or more of the same. Furthermore, although a computer storage medium is not a propagated signal, a computer storage medium can be a source or destination of computer program instructions encoded in an artificially generated propagated signal. The computer storage medium can also be, or can be included in, one or more separate physical media or components (eg, multiple CDs, discs, or other storage devices).

The term data processing apparatus encompasses

<img file="MX349526B_D0027.tif" />

₇₈ IMPI ' ⁰ MEXICAN INSTITUTE

RE IA INDUSTRIAL PROPERTY all types of apparatus, devices and machines to process data, including by way of example a programmable processor, a computer, a system on a chip, or multiple of these, or combinations of the above. The apparatus may include special purpose logic circuits, for example, an FPGA (Field Programmable Gate Array) or an ASIC (Application Specific Integrated Circuit). The apparatus may also include, in addition to hardware, a code that creates an execution environment for the computer program in question, for example, a code that constitutes processor firmware, a protocol stack, a database management system. , an operating system, an uptime environment across the platform, a virtual machine, or a combination of one or more of them. The appliance and the runtime environment can realize various different structures of the computing model, such as Web services, computing infrastructures and distributed grid computing.

A computer program (also known as a program, software, software application, text, or code) can be written in any form of programming language, including compiled or interpreted languages, declarative, or procedural languages. A₇₉ IMPI ^^ ^J MEXICAN INSTITUTE Jk

Dt THE CURRENCY

INDUSTRIAL program can be stored in a part of a file that holds other programs or data (for example, one or more texts stored in a markup language document), in a single file dedicated to the program in question, or in multiple coordinated files (for example, files that store one or more modules, applets, or pieces of code). A computer program can be deployed to run on one computer or on multiple computers that are located at one site or distributed across multiple sites and interconnected through a communication network.

Some of the processes and logical flows described in this specification can be executed through one or more programmable processors that execute one or more computer programs to execute the actions operating on incoming data and generating an output. Processes and logic flows can also be executed by, and the apparatus can also be implemented as special purpose logic circuits, for example, an FPGA (Field Programmable Gate Array) or an ASIC (Application Specific Integrated Circuit).

Processors suitable for executing a computer program include, by way of example, general and special purpose microprocessors, and ₈₀ ° ^OR MEXICAN INSTITUTE UTj ^ J

DF. THE PROFITY M

INDUSTRIAL processors of any type of digital computer.

Generally, a processor will receive instructions and data from read-only memory or random access memory or both. A computer includes a processor for executing actions according to instructions and one or more memory devices for storing instructions and data. A computer may also include, or may be operably coupled to receive data from or transfer data to, or both, one or more mass storage devices for storing data, eg, magnetic discs, magneto-optical discs, or optical discs. However, a computer does not need to have such devices. Convenient devices for storing computer program instructions and data include all forms of non-volatile memory, memory devices, and media, including by way of example semiconductor memory devices (e.g., EPROM, EEPROM, flash memory devices, and others), magnetic discs (eg, internal hard drives, removable discs, and others), magneto-optical discs, and CD ROM and DVD ROM discs. The processor and memory can be supplemented by, or incorporated into, special purpose logic circuits.

To allow interaction with a user, operations can be implemented on a computer that has a

IMPI

MEXICAN INSTITUTE

HEARD THE PROPERTY

INDUSTRIAL a monitor, or another

<img file="MX349526B_D0028.tif" />

display device (for example type of display device) to display information to the user and a keyboard and pointing device (for example, a mouse, ball, tablet, touch screen, or other type of display device). pointer) through which the user can provide input to the computer. Other types of devices can be used to allow interaction with a user as well; for example, the feedback provided to the user can be any form of sensory feedback, eg, visual feedback, auditory feedback, or tactile feedback; and input from the user can be received in any form, including acoustic, voice, or tactile input. Furthermore, a computer can interact with a user by sending documents to and receiving documents from a device that is used by the user; for example, by sending web pages to a web browser on a user's client device in response to requests received from the web browser.

A client and server are generally far from each other and typically interact through a communication network. Examples of communication networks include a local area network (LAN) and a wide area network (WAN), an inter-network (for example, the Internet), a network that

IMPI comprises a satellite link, and peer-to-peer networks (eg ad hoc peer-to-peer networks). The client and server relationship arises by virtue of the computer programs that run on the respective computers and that have a client-server relationship with each other.

In some aspects of what has been described here, dominant orientations incorporated into fracture sets associated with microseismic events can be dynamically identified during fracture treatment. For example, fracture planes can be extracted from real-time microseismic events collected from the field. Fracture planes can be identified based on information from microseismic events including: event locations, event location measurement uncertainties, magnitudes of event timing, event occurrence times, and others. At each point in time, the data can be associated with previously calculated basic planes, including the supporting set of microseismic events.

In some aspects of what has been described here, a probability histogram or basic plane distribution can be constructed from the collected microseismic events, and the histogram or distribution can be used to derive the fracture orientations.

Q 3 Mexican Institute ^υ OF THE PROPERTY Vjxee ^ -VyF

INDUSTRIAL -dominant. The fractures extracted along the dominant orientations, in some cases, can provide an optimal match with the microseismic events in real time. The histogram or distribution and the dominant orientations may have a not inconsiderable sensitivity to the new incoming microseismic event. As such, some planes identified during the time microseismic data is assimilated may be inaccurate when compared to the post-data outcome of microseismic events. Exemplary techniques for generating, updating, and using histograms based on microseismic data are described in US Provisional Application Number 61 / 710,582, filed October 5, 2012.

In some aspects of what has been described here, a precision confidence parameter can provide a measure for the precision of identified planes in real time. Factors that impact the precision confidence of a plane can include the intrinsic properties of an event, the relationship between support events and the plane, and weight that reflect the fracture orientation trends of post microseismic data. In some cases, high confidence fracture planes at the end of the hydraulic fracturing treatment that were identified in a real-time manner are consistent.

MEXICAN INSTITUTE OS LA PROPERTY GT —FINDUSTRIAL ------ with those obtained from post-event data.

In some aspects, some or all of the features described herein can be combined or implemented separately in one or more software programs for automated real-time fracture mapping. The software can be implemented as a computer program product, a setup application, a client-server application, an Internet application, or any other convenient type of software. In some cases, a real-time automated fracture mapping program can dynamically show users the spatial and temporal evolution of identified fracture planes in real time as microseismic events gradually accumulate. The dynamics may include, for example, the generation of new fractures, the propagation and growth of existing fractures, or other dynamics. In some cases, a real-time automated fracture mapping program can provide users with the ability to view the identified fracture planes in real-time at multiple levels of confidence. In some cases, users can observe a spatial and temporal evolution of high-confidence fractures, which can show the dominant trends for all microseismic event data. In some cases, an automated fracture mapping program

<img file="MX349526B_D0029.tif" />

as IMPI

MEXICAN INSTftVTO

DE LA NONEDAO in real time can assess the confidence of _P^ m^ori fracture, for example, to measure the certainty of identified fracture planes. Precision confidence values, for example, can help users better understand and analyze changes in a probability histogram or orientation distribution, which can vary continuously with the real-time accumulation of microseismic events. In some cases, a real-time automated fracture mapping program can provide results that are consistent with post-data fracture mapping. For example, at the end of the hydraulic fracture treatment, the results produced by the real-time automated fracture mapping program may be statistically consistent with those obtained by a post-data automated fracture mapping program operating on the same data. Such fractures can enable field engineers, operators, and analysts to dynamically view and monitor the spatial and temporal evolution of hydraulic fractures, analyze fracture complexity and reservoir geometry, evaluate the effectiveness of hydraulic fracture treatment, and improve performance. from the well.

Although this specification contains many details, these should not be construed as limitations on the

<img file="MX349526B_D0030.tif" />

IMPI

MEXICAN INSTITUTE Dk THE PROPERTY scope of which can be claimed, but γΗ8 '^^τ** £ Μ descriptions of specific features — for — particular erjwplUS. Some features that are described in this specification in the context of separate implementations can also be combined. In contrast, various features that are described in the context of a single implementation can also be implemented in multiple modes separately or in any suitable sub-combination.

A number of modalities have been described. However, it will be understood that various modifications can be made. Accordingly, other embodiments are within the scope of the following claims.

<img file="MX349526B_D0031.tif" />

IMPI tWSWVfO MEXICANO Dt LA WOHÍOAD inwjítiial