Correlation techniques for passive electroseismic and seismoelectric surveying.

(54) Title: CORRELATION TECHNIQUES FOR ELECTROSISMIC AND PASSIVE SEISMOELECTRIC SURVEY. (54) Title: CORRELATION TECHNIQUES FOR PASSIVE ELECTROSEISMIC AND SEISMOELECTRIC SURVEYING.

(57) Summary

A method for prospecting may include receiving, by a processor, first study data from a first source, the first source comprising a first signal generated by an underground ground reservoir in response to a passive source electromagnetic signal, wherein the electromagnetic signal It is generated by an electrosismic or seismoelectric conversion of the passive source electromagnetic signal. The method may also include receiving, by the processor, second study data from a second source and processing the first study data and second study data to determine one or more properties of an underground land deposit.

(57) Abstract

A method for surveying, may inelude receiving, by a processor, first survey data from a first source, the first source comprising a first signal generated by a subsurface earth formation in response to a passive-source electromagnetic signal, where the electromagnetic signal is generated by an electroseismic or seismoelectric conversion of the passivesource electromagnetic signal The method may also inelude receiving, by the processor, second survey data from a second source and Processing the first survey data and the second survey data to determine one or more properties of a subsurface earth formation.

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Institute

Mexican Property

Industrial

PATENT TITLE NO. 342155 _SE_ sxtttTAKíA οι «« «MIA

Headlines):

Home:

Denomination:

Classification:

Inventor (s):

HUNT ENERGY ENTERPRISES, LLC

1900 N. Akard Street, Dallas, Texas, 75201, USA

CORRELATION TECHNIQUES FOR PASSIVE ELECTROSISMIC AND SEISMOELECTRIC SURVEYING.

Int.CI.8: G01V1 / 28; G01V1 / 36; G01V1 / 38; G01V1 / 48; G01V11 / 00

ARTHUR THOMPSON; ALAN KATZ; ROBERT ENGLAND: MOHAMMAD RAHMAN; NAGA P. DEVINENI

Number

MX / a / 2014/010955

REQUEST

International filing date:

February 2014

Country:

US

PRIORITY

Date:

March 2013

Number:

13/785,106

Validity: Twenty years

Expiration Date: February 28, 2034

The reference patent is granted based on articles 1, 2 fraction V, 6 fraction III, and 59 of the Industrial Property Law.

In accordance with article 23 of the Industrial Property Law, this patent has a non-extendable term of twenty years, counted from the date of filing of the international application and will be subject to the payment of the tartfe to keep the rights.

The undersigned of the present titleholder does so based on the provisions of articles β · fractions lll and 7 ° bis 2 of the Industrial Property Law (Official Gazette of the Federation (B, Q¡F.) Ji7 / Q6 / i99l Amended on 02 / M / 1B84, 10/25/1996, 12/26/1987, 05/17/1999, 01/26/2004, 06/16/2005, 01/25/2306, 05/06/2009, 01/06/2010 06/18/2010. 06/28/2010, 01/27/2012 and 04/09/2012); Articles 1 ?, 3rd fraction V, subsection a), 4th and 12 "sentences I and III of the Regulations of the Mexican Institute of'Mh * MRfad Industrial (DOF 14/12/19991), amended on 07/01/2002, 07/15/2004, 07/28/21 ^ 4 and 09/07/2007); articles 1 ”, 3 °, 4 °, 5” section V subsection a), 16 sections I and lll and 30 of the Organic Statute of the Mextoano Institute of Industrial Property (DOF 12/27/189 », amended on 10/10/2002, 29/97/2004, 08/04/2004 and 09/13/2007); 1, 3 and 5 ”section a) of the Agreement that delegates powers to the Deputy Directors General, Coordinator, Divisional Directors, Holders of Regional Offices, Divisional Deputy Directors, Departmental Coordinators and other subordinates of the Mexican Institute of Industrial Property. (DOF 12/15/1999, amended on 02/04/2000, 07/29/2004, 08/04/2004 and 09/13/2007).

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Arenal Nc. 550, Floor 1.

Coi. Santa Mana Jepepan town. Xochimiico. C P. 16CZ0

Mexico City

Tel.; 55) 53 34 07 00 www.impi gob.mx

Issue Date: September 15, 2016

THE DIVISIONAL DIRECTOR OF PATENTS

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NAHANNY CANAL REYES

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MX / 2016/75266

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CORRELATION TECHNIQUES FOR ELECTRONIC SURVEYING! SMICA AND

PASSIVE SEISMELECTRIC

DESCRIPTION OF THE INVENTION

Conventional geophysical prospecting techniques 5 rely on various prospecting technologies to identify probable regions for drilling or exploration. These conventional prospecting techniques, however, suffer from certain limitations that can prevent a full understanding of the geophysical properties of the probable regions. For example, particular prospecting techniques may require the use of prospecting equipment that is expensive and / or time consuming and methods that may limit the economic feasibility of studying a particular likely region. Furthermore, particular prospecting technologies may be able to provide information regarding one or more geophysical properties of an underground region, but may not be able to provide information about other geophysical properties. Such limitations may lead to the identification of probable regions for drilling or exploration based on an incomplete and / or incorrect understanding of the probable region, which may result in unnecessary time and / or expense being incurred in exploring or drilling regions that do not have the desirable geophysical properties. For example, based on incomplete or incorrect geophysical prospecting, an operation

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IMPI

INSTITUTO MEXICANO DE LA RRCIPIEDAb INDUSTRIAL de drilling may drill a dry hole or drill an underground reservoir that contains less hydrocarbons than expected. As another example, an exploration company may miscalculate the estimated amount of reserves in an underground deposit.

In accordance with the teachings of the present description, disadvantages and problems associated with conventional geophysical prospecting techniques can be reduced and / or eliminated. For example, a prospecting system may be provided using either electro-seismic or seismoelectric passive prospecting techniques. The prospecting system may use passive prospecting data from electronic or seismoelectric passive prospecting and prospecting data from other geophysical prospecting methods to determine one or more properties of an underground land deposit.

In accordance with an embodiment of the present description, a method for prospecting may include receiving, by a processor, first prospecting data from a first source, the first source comprising a first signal generated by an underground land deposit in response to a signal passive source electromagnetic, where the electromagnetic signal is generated by an electrosmic or seismoelectric conversion of the passive source electromagnetic signal. The method may also include receiving, through the processor, second prospecting data from

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INSTITUTO MEXICANO BE THE INDUSTRIAL PROPERTY from a second source and process the first prospecting data and the second prospecting data to determine one or more properties of an underground land deposit.

Technical advantages of certain embodiments of the present invention include the ability to perform passive electro-seismic or seismoelectric prospecting. Such prospecting may be capable of detecting an electromagnetic signal generated in response to an electro-seismic or seismoelectric conversion of the earth's background electric field. Electro-seismic or seismoelectric conversion can be carried out in an underground land deposit. The detected electromagnetic signal may be a vertical signal that is sensitive to a vertical electrical field component of the earth's bottom. Another technical advantage may be the ability to detect a seismic signal generated in response to an electro-seismic or seismic conversion of the earth's background electric field. By using such techniques, a geophysical survey can be conducted without the requirement of costly active sources of electromagnetic or seismic energy, which can improve site safety and reduce any environmental impacts. The reduction in the amount of equipment and energy, together with the corresponding occupied or reduced space at the measurement site, may be an advantage over other systems of

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MEXICAN INSTITUTE &lt;

OF THE PROPERTY

INDUSTRIAL prospecting and methods. From an environmental and health perspective, reduced transportation, site preparation, and high energy sources can improve the overall health and safety of workers operating the equipment.

Furthermore, the earth's naturally occurring electromagnetic field comprises a broad spectrum of frequencies, from sub-hertz frequencies to tens of thousands of hertz frequencies, along with extensive coverage over the earth's surface. The wide spectrum allows a wide range of penetration depths from tens of meters to tens of kilometers. Consequently, the detected electromagnetic and / or seismic signals can be processed to identify various properties of the underground land deposit. Another technical advantage may include the ability to use prospecting data from prospective and electro-seismic or seismic passive survey data from other geophysical prospecting methods to determine one or more properties of an underground land deposit. For example, data from the first study method can be correlated with data from the second study method.

Using data from two or more study methods can allow a more complete and / or reliable understanding of the underground site of interest.

Other technical advantages of the present description will be readily apparent to someone of experience.

mexican institute

DE la raonCDAÓ S&gt; -. 2TÁÍÍ Ordinary industrial pa in the art from the following figures, description and claims. In addition, other specific advantages of particular prospecting techniques and combinations are discussed below. Furthermore, although specific advantages are explained in the present description, various embodiments may include part, all or none of these advantages.

BRIEF DESCRIPTION OF THE DRAWINGS

For a more complete understanding of the present invention and its features and advantages, reference is now made to the following description, taken in conjunction with the accompanying drawings, in which:

FIGURE / a is a perspective diagram illustrating an exemplary system for passive electro-seismic and seismoelectric prospecting;

FIGURE IB is a perspective diagram illustrating an exemplary system for passive electro-seismic and seismoelectric prospecting;

/ FIGURES 2A^Z2C are block diagrams illustrating exemplary sensors for passive electro-seismic and seismoelectric prospecting;

FIGURE 3 is a flow chart illustrating an exemplary method for processing two or more geophysical survey data sources;

FIGURE 4 is a perspective diagram that

The Mexican INSTITUTE of Industrial Property illustrates an exemplary prospecting system that uses passive electrosismic and seismoelectric prospecting techniques and active electrosismic and seismoelectric prospecting techniques, and active seismic prospecting techniques;

FIGURE p is a perspective drawing illustrating an exemplary prospecting system using passive prospecting electro-seismic and seismoelectric prospecting techniques, and source controlled electromagnetic prospecting techniques;

/ FIGURE 6 is a perspective drawing illustrating an exemplary prospecting system utilizing electrosismic and seismoelectric passive prospecting techniques, and magnetotelluric prospecting techniques;

/ FIGURE 71 is a perspective drawing illustrating an exemplary prospecting system using passive prospecting techniques, electrosismic and seismoelectric, and logging techniques; and FIGURE 8 is a flow chart illustrating an exemplary method for correlating data received from various geophysical prospecting methods;

FIGURE 9 is a block diagram illustrating an exemplary computing system suitable for implementing one or more modalities described herein.

Exemplary modalities herein may use passive prospecting techniques that utilize passive sources, such as naturally occurring electromagnetic fields

IMPIOUS:

MEXICAN INSTITUTE ^, - OF LA MONEDAD

INDUSTRIAL and / or seismic waves, and the interactions of electromagnetic or seismic signals generated by these sources and with conversions identify underground reservoirs through electrosismic and / or seismoelectric for characteristics and / or properties of underground terrestrial reservoirs. Such prospecting can be useful for a variety of purposes, including identifying underground water and minerals. Although passive prospecting may be suitable for use as a stand-alone method of geophysical prospecting, passive prospecting in some modalities may be conducted in conjunction with other geophysical prospecting methods to identify properties of underground land sites. The teachings of the present disclosure are intended to encompass modalities that employ passive prospecting as an autonomous prospecting technique as well as modalities that are passive prospecting along with one or more additional methods of geophysical prospecting.

A passive source can be used to provide the energy to generate electrosismic and / or seismoelectric conversions in an underground reservoir or structural feature. For example, the earth's electromagnetic field and / or environmental seismic energy can induce electrosismic or seismoelectric conversions in an underground land deposit that contains hydrocarbons or other minerals. As used herein, a source

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INDUSTRIAL '% ¿£ Tíál __ «5» »' passive can include any source that is not actively initiated by a prospecting operation to actively generate a source of seismic and / or electromagnetic energy. Although a passive source generally includes a natural source of electromagnetic energy and / or seismic energy such as the earth's natural electromagnetic field, other artificial sources of electromagnetic and / or seismic radiation such as power lines or mechanical equipment may also be included as passive sources in particular modalities. Although certain artificial sources can induce an electromagnetic field or seismic wave, they can be distinguished from an active source such as a seismic generator, explosives, electric field generators, and the like that such sources are generally initiated by and / or associated with an operation. Prospecting to facilitate prospecting for an underground site. As used herein, passive prospecting, passive electrosismic prospecting, and passive seismoelectric prospecting may refer to prospecting that uses a passive source compared to an active source. Passive prospecting can detect secondary seismic wave generation through coupling of the electromagnetic source field for various rock formations (electro-seismic effect) and subsequent generations of secondary electromagnetic fields through coupling of the

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DS LA FROPIfDAI INDUSTRIAL seismic waves generated with various rock formations (seismoelectric effect) to probe those formations and the fluids they contain. Alternatively or additionally, passive prospecting can detect the generation of secondary electromagnetic fields through coupling of a seismic source field with various rock formations (seismic effect) and subsequent generations of secondary seismic waves through coupling of electromagnetic fields generated with various rock formations (seismoelectric effect) to probe these formations and the fluids they contain. Generation of tertiary or higher order electromagnetic fields and seismic waves can also result from additional couplings as the fields propagate towards the earth's surface.

Other prospecting techniques such as magnetotelluric prospecting or source controlled electronic prospecting typically reject signals generated by such passively generated conversions as background noise. Using the techniques of the present disclosure, however, electromagnetic and seismic signals generated by seismic and electrosonic conversions in response to a passive energy source can be detected and processed using various data processing techniques to identify properties of the underground land deposit.

For example, a generated seismic signal can be identified by

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frequencies IMο IMPI

MEXICAN INSTITUTE

OF THE PROPERTY

INDUSTRIAL detect the characteristic delay times or associated with the seismic travel time using a selective time method and determine the depth of the seismic signal origin from the selective time method.

Electromagnetic and / or seismic signals generated as a result of electro-seismic or seismic conversions can be detected in any suitable way. For example, various sensors can be used to detect one or more of an electromagnetic signal and a seismic signal that are generated by an underground ground reservoir in response to a passive source electromagnetic or seismic signal, where the electromagnetic signal is generated by a conversion electro-seismic or seismoelectric of the passive source electromagnetic or seismic signal. In some embodiments, sensor arrangements can be used. Data processing can be used to process signals to facilitate the identification of one or more of the properties of the underground land deposit discussed in the foregoing.

Using these techniques, various properties of the underground land deposit can be identified. For example, processing of the detected signal may indicate the presence of fluids such as hydrocarbon and aqueous liquid such as drinking water, fresh water, and brine water in

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¹¹ IMPI

MEXICAN INSTITUTE

OF THE PROPERTY

INDUSTRIAL underground site. In some embodiments, the teachings of the present disclosure can be used to identify additional properties of the underground terrestrial reservoir, including but not limited to the existence of an underground terrestrial reservoir, the depth of the underground reservoir, the porosity and / or permeability of the terrestrial reservoir fluid. underground, the composition of one or more fluids within the underground reservoir, a spatial extension of the underground terrestrial deposit, an orientation of the limits of the underground terrestrial deposit, and the resistivity of the underground terrestrial deposit. Based on the identified properties, models of the underground land deposit can be developed, including three-dimensional structures and time-dependent models. Additionally or alternatively, the techniques of the present description can be used to identify the presence and / or migration of various pollutants, flooding in hydrocarbon production, fault movement, aquifer depth, water use, the presence of and / or magma migration, and hydrofracturing properties.

In some modalities, passive survey data obtained and / or collected as a result of passive prospecting can be processed with geophysical survey data obtained and / or collected using various other techniques, »Λ.

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prospecting. Passive survey data processing and other available sources of geophysical survey data can provide several technical benefits. For example, such processing may allow additional information, more complete information, and / or confirmation of information regarding underground land sites. Such processing can take advantage of the particular resistances of other study methods to establish a baseline for comparison and / or determine particular properties for which those methods are well suited. As a result, passive prospecting techniques combined with other available prospecting techniques can result in a more complete understanding of the underground reservoir that may otherwise be available if individual techniques alone are used.

Although specific benefits have been listed above, various modalities may include all, some, or none of the benefits listed. Modes of the present description and their advantages are better understood by referring to FIGURES 1 to 9, where similar numbers refer to similar and corresponding parts of the various drawings.

FIGURES IA and IB are perspective diagrams illustrating an exemplary system 10 for electro-seismic and seismoelectric passive prospecting; System 10 includes 26 electromagnetic sensors, 28 seismic sensors and system

IMPI

ΙΝϊΤΠΤΤΟ MEXICAN OF INDUSTRIAL PROPERTY

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of computation. FIGURE IA illustrates an embodiment in which system 10 is generally configured to use signals propagated by a passive electromagnetic source 12 of electromagnetic energy to perform geophysical prospecting.

FIGURE IB illustrates an embodiment in which system 10 is generally configured to use signals 20 and / or 22, which can be propagated by a passive seismic source 40.

As illustrated in FIGURE IA, sensors 26 and / or 28 generally detect signals generated by the underground ground reservoir in response to an electromagnetic signal 14 propagated from passive electromagnetic source 12. The computer system 30 can then process the detected signals using various signal processing techniques to identify properties and / or characteristics of the underground land reservoir 16. The system 10 can detect seismic signals 20 generated due to electro-seismic interactions between the electromagnetic signal 14 and the underground reservoir 16, either alone or in combination with detecting the electromagnetic signal 22, which can be generated as a result of seismoelectric conversions of the signals 20 seismic. One or more of the detected seismic signals can then be processed to determine one or more properties of the underground land deposit.

The passive electromagnetic source 12 represents

IMPI

MEXICAN INSTITUTE OR £ LA FRORIÍOAIJ INDUSTRIAL

<img file="MX342155B_D0015.tif" />

any suitable passive source of electromagnetic energy. For example, the passive electromagnetic source 12 may represent the earth's natural electromagnetic field. The passive electromagnetic source 12 propagates the electromagnetic energy towards the earth's surface as electromagnetic signal 14. The electromagnetic signal 14 can represent, for example, an electromagnetic plane wave 14. As the electromagnetic signal 14 propagates through the earth, it may encounter several underground earth deposits 16. The interaction of the electromagnetic signal 14 and the underground terrestrial reservoir 16 can cause an electro-seismic conversion to take place at an edge and / or boundary 18 of the underground reservoir 16. As a result, one or more seismic waves 20 can propagate towards the earth's surface. The electromagnetic signal 22 can be generated as a result of an electro-seismic conversion as the seismic signals 20a propagate to the surface. Electromagnetic sensors 26 can detect electromagnetic signals 22. Seismic sensors 28 can detect seismic signals 20b.

The passive electromagnetic source 12 can represent the naturally occurring electromagnetic field of the earth. Earth's naturally occurring electromagnetic field can include a wide spectrum of frequencies, from sub-hertz frequencies to tens of thousands of

IMPI

MEXICAN INSTITUTE OF INDUSTRIAL PROPERTY

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hertz frequencies, which have wide coverage over the earth's surface. This broad spectrum allows a wide range of depths of penetration of the electromagnetic signal 14 from tens of meters to tens of kilometers. The corresponding frequencies of the electromagnetic signal 14 on earth may result from variations in the passive electromagnetic source 12 due to various natural events such as electromagnetic fluctuations in the ionosphere, electromagnetic discharges of natural origin in the atmosphere such as lightning, and / or other electromagnetic events. In some embodiments, the passive electromagnetic source 12 of the electromagnetic signals 14 may include cultural sources of electromagnetic radiation, which may have frequencies low enough to reach and interact with the underground reservoir 16. As another example, the passive electromagnetic source 12 may include power transmission lines, which can generate electromagnetic signals 14 of resistance and / or frequencies suitable for interacting with the underground reservoir 16.

The electromagnetic signal 14 represents an electromagnetic wave, electromagnetic plane wave, or other suitable electromagnetic signal that propagates to Earth from the passive electromagnetic source 12. For example, in response to the Earth's electromagnetic field, the signal

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MEXICAN INSTITUTE&gt;

FROM THE rfl '? L »IEDAt&gt;

INDUSTRIAL electromagnetic can propagate to Earth as electromagnetic modulation that, unlike an acoustic wave, travels at the speed of an electromagnetic wave in the subsoil. The speed of an electromagnetic wave in the subsoil can generally be less than the speed of an electromagnetic wave in a vacuum or air. The electromagnetic signal 14 can typically travel underground to the earth at a speed of approximately one hundred times more than the speed of propagation of an acoustic wave in the seismic frequency band of approximately 1-100 Hz. Due to the relative speed of the electromagnetic signal 14 when compared to a seismic signal, the travel time of the electromagnetic signal to the subsurface land field, in some embodiments, can be ignored when processing the detected electromagnetic field 22 and / or the seismic signals detected. Although illustrated as a static field, it should be noted that the electromagnetic signal 14 can be a time varying field.

The electromagnetic signal 14 may propagate to the earth's subsoil, as an approximate plane wave, including over the subsoil reservoir 16 of interest. The term plane wave can refer to a wave with a substantially uniform amplitude in a normal plane at a velocity vector of the electromagnetic signal 14. The velocity vector can generally be vertical, although not

IMPI O? '

MEXICAN INSTITUTE Dí LA MONEDAD industrial

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it is necessarily perpendicular to the surface of the Earth above the underground earth deposit 16. For example, a velocity vector may be substantially vertical although it may appear to be tilted with respect to a vertical axis on the surface where the surface is at an incline, such as on a hillside or other incline.

As a result of the electro-seismic and / or seismic effect, the seismic signals 20 and / or the electromagnetic signals 22 resulting from the electromagnetic signals 14 can be generated substantially and uniformly through the subsoil 16. As a result, the seismic signals 20 and / or electromagnetic signals 22 can each form a substantially vertical plane wave traveling to the Earth's surface.

Subsoil land deposit 16 represents any subsoil land deposit of interest to

<td>purposes</td><td>of</td><td colspan="2">geophysical prospecting. The</td><td>site 16</td>

<td>land</td><td>of the</td><td>subsoil can</td><td>represent</td><td>a deposit</td>

<td>geological</td><td>than</td><td>contains one or</td><td>more fluid</td><td>In some</td>

<td>modalities</td><td>, the</td><td>site 16</td><td>land</td><td>underground</td>

<td>It represents</td><td>a</td><td>rock formation</td><td colspan="2">porous capable of containing</td>

fluids. A porous rock formation, for example, may include a portion of solid rock interspersed with channel-like porous spaces. A porous rock formation, for example, can include a terrestrial substance that contains a volume

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no soil or porous space, and may include, but is not limited to, consolidated, poorly consolidated, or unconsolidated earth materials. The fluids contained by the underground terrestrial reservoir 16 may be hydrocarbons such as oil and gas, water (including fresh, salt, potable, or brine water), helium, carbon dioxide, minerals, or other terrestrial fluids. In some embodiments, the underground ground reservoir 16 may represent a reservoir containing contaminants, magma, or molten material. Subterranean earth deposit 16 may represent a geological layer, a stratigraphic trap, a fault, a belt of folds and thrusts, or other geographic formation of interest. Subterranean reservoir 16 may represent a probable or potential area of ​​interest for exploration and / or drilling operations.

The underground terrestrial reservoir 16 may include a polarizable fluid that includes one or more fluid dipoles 114 associated with a fluid in the underground terrestrial reservoir 16. As a result, an electrochemical interaction can be formed between the polarizable fluid and the solid rock portions at boundary 18. The electrochemical interaction is represented by the + symbol in the fluid portion and the symbol in the solid rock portion. Electromagnetic signals 14 can meet and / or interact with fluid dipoles 114 from underground terrestrial reservoir 16.

IMPI

MEXICAN INSTITUTE OF INDUSTRIAL PROPERTY

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In particular, electromagnetic signals 14 can cause a change in the polarization of dipoles 114 in the porous fluid, which in turn can cause a pulse

118 pressure is generated. For example, electromagnetic signals 14 can modify electrochemical bonds or move charges of fluid dipoles 114, thereby effectively creating pressure pulse 118 where interactions are distorted. Pressure pulse 118 may represent a change in pressure and / or fluid flow that produces a time varying pressure gradient, which can then propagate and / or be transmitted to the land (or rock) formation at boundary 18, from the 16th underground site. Electromagnetic signals 14 exist throughout the fluid area and can primarily affect the charges of dipoles 114 that are at or near the boundary 18 of the rock. The pressure gradient produced by the pressure pulse 118 can propagate to the surface as a seismic signal 20. It should be noted that the solid rock portion may have an existing natural surface load on at least a portion of the rock surface. Electrochemical interaction can result in a local porous fluid dipole 114 causing a local background electromagnetic field. However, the singo of the background electromagnetic field or the direction of field polarity depends on the surface charge on the solid and the ijviri

MEXICAN INSTITUTE

DF THE PROPERTY '

INDUSTRIAL how the fluid filters that load. For example, for clay layers, the load is typically as shown and illustrated. In other materials such as carbonates, however, the charge can be reversed. In this way, a suitable subsoil 16 can be an underground source of seismic energy.

Boundary 18 may represent a suitable edge, boundary, fluid surface, or interconnection between the underground ground reservoir 16 and other portions of the subsoil. Boundary 18 may represent the boundary of a hydrocarbon deposit, stratigraphic trap, fold and thrust belt, geological rock layer, or other geological formation that contains or is likely to contain fluids and other minerals of interest. Boundary 18 can represent a boundary between any two types of subsoil materials.

Electrosismic energy conversion can occur between the boundary 18 between two types of rock. For example, the conversion of electrosismic energy can occur at the boundary 18 between the productive rock and the sealing and / or confining rock. Alternatively, the conversion of electrosismic energy can occur at an interface 18 between porous fluids, eg, between oil and water. At rock and / or fluid interconnects 18, there may be a gradient in chemical potential. For example in

<img file="MX342155B_D0021.tif" />

IMPI

INSTITUTO MHXIGANO Ot LA FROHEDAP INDUSTRIAL the boundary 18 between a silicate rock and a carbonate rock, a chemical reaction can occur in the mixed porous fluids. For example, silicate can dissolve carbonate, and silicate ions in solution can react with carbonate ions in solution. The general reaction can be driven by a gradient in chemical potential at interconnection 18. The reaction product between positive and negative ions in solution is electrically neutral and can precipitate out of solution. When a precipitate forms, the deposition resulting from the precipitate hardens the rock, increases its hardness, and increases the electrical resistivity of the interconnect. During reactions in porous spaces, charged ion concentration gradients can be created within porous fluids. These concentration gradients can produce an electrochemical potential gradient that can manifest itself as a macroscopic electrical potential gradient. Gradients of internal electrical potential at interconnects can create internal voltages, and the interaction of the ground electromagnetic field 14 with the gradient of electrochemical potential can change these internal voltages. Due to natural modulations in the ground electromagnetic field 14, internal stresses can be modulated, justifying conversions

IMPI

MEXICAN INSTITUTE

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DE LA FROFIEDA D .1¾)

INDUSTRIAL nonlinear electrosismics that can be measured and used by the system 10.

The seismic signals 20 represent any seismic signals and / or seismic waves generated by the electro-seismic effect in response to the electromagnetic signal 14.

As noted above, the seismic signals 20 can represent a substantially vertical plane wave traveling to the earth's surface. The seismic signals 20 can generate subsequent secondary electromagnetic fields and seismic waves through various combinations of seismic and electroelectric effects as the seismic signals 20 propagate to the surface. For example, as illustrated, the seismic wave 20a can be converted by the seismoelectric effect, into an electromagnetic signal 22, into an immediate subsoil deposit 24. In some embodiments, the seismic signals 20 may represent secondary seismic signals generated as a result of various seismic and / or electro-seismic conversions of the seismic signals 20 as they propagate to the surface. The seismic signals 20 can represent any mechanical seismic wave propagating in the subsoil of the earth and can include, but are not limited to P and S waves.

Electromagnetic signals 22 represent any electromagnetic signals, fields

IMPIOUS#

MEXICAN INSTITUTE

PROPERTY 2

INDUSTRIAL electromagnetic, or electromagnetic waves generated by the seismoelectric effect in response to seismic signals.

the one signals 22 flat wave

As stated above, electromagnetic can represent substantially vertical traveling to the Earth's surface. Electromagnetic signals 22 can generate subsequent secondary seismic signals and electromagnetic signals such as electromagnetic signals 22 propagated to the surface. The electromagnetic signals 22 may represent secondary electromagnetic signals generated as a result of various seismoelectric and / or electro-seismic conversions of the seismic signals 20 as they propagate to the surface. In some embodiments, electromagnetic signals 22 can detect Earth's immediate subsoil and / or at a certain distance above Earth's surface. Furthermore, the electromagnetic signals 22 can represent a varying time electromagnetic field resulting from the seismoelectric effect. Electromagnetic signals 22 can modulate an electromagnetic field within the Earth, such as immediate subsoil 24, and thus can be referred to as a modulation signal. Modulation, or modulation can refer to frequency modulation, phase modulation, and / or amplitude modulation. For example, seismic signals 20 can travel in the immediate subsoil 24 and directly modulate a

<img file="MX342155B_D0023.tif" />

IMPI

MEXICAN INSTITUTE OF INDUSTRIAL PROPERTY electromagnetic field within immediate subsoil 24. Seismic signals 20 may cause a change in electrical impedance in immediate subsoil 24, which may result in a time dependent variation of electromagnetic signals 22 and / or the passage of seismic signals 20 can interact with a fluid or rock boundary in the immediate subsoil 20 to produce electromagnetic signals 20.

Electrosismic conversions can also produce nonlinear electromagnetic conversions. The seismoelectric and electro-seismic effects generate harmonic responses where the coupling of the electromagnetic signals 22 and the seismic signals 20 create new frequency modulations that are harmonic of the electromagnetic signals and the seismic signals 20. Accordingly, electromagnetic signals 22 and seismic signals can represent one or more nonlinear electromagnetic responses. Nonlinear electrosismic conversions can produce useful signals during processing. In some embodiments, nonlinear harmonic signals, having frequency components at higher frequency harmonics than the fundamental frequency of the passive electromagnetic source 12, such as those frequencies present in the ground electromagnetic field of the ground, may be detected as a result of the

IMPI

MEXICAN INSTITUTE A

OF THE PROPERTY

INDUSTRIAL electromagnetic signal distortions 14 that interact with the underground terrestrial reservoir 16 when they contain at least one fluid. Harmonic signals can be processed alone or in conjunction with the fundamental frequencies of seismic signals 20 and / or electromagnetic signals 22 to determine one or more properties of the subsurface land field. In some embodiments, system 10 can be used to detect and / or isolate harmonic signals that can occur in both electromagnetic signals 22 and seismic signals 20.

Underground reservoir 16 can generate seismic signals 20 and / or electromagnetic signals 22 particularly when the fluid occurs in a porous reservoir, such as high permeability reservoirs. Accordingly, seismic signals 20 and / or electromagnetic signals 22 can indicate the presence of that fluid and / or can be used by system 20 to potentially locate and / or locate particular fluids, such as hydrocarbons, water, or other types of fluids as described above. Furthermore, when conventional seismic reflection boundaries 18 exist between the subsoil reservoir 16 and the surface, seismic reflections can occur and can be detected by seismic sensors 20.

The immediate subsoil deposit 24 represents an underground deposit in or in the immediate subsoil of the

IMPI ~

MEXICAN INSTITUTE OF INDUSTRIAL PROPERTY

<img file="MX342155B_D0024.tif" />

Earth. The immediate subsoil reservoir 24, for example, can represent a water table or another layer of porous rock. The seismic signals 20 can interact with fluid in the pores of the immediate subsoil reservoir 24. As a result, the charges within the pore can be modified. For example, the pore may contain fresh water as it occurs in the water table. The resulting modification of the charges can generate an alternating current field, which can drive the emission of electromagnetic signals 22 through the seismic effect.

Electromagnetic sensors 26 represent any suitable combination of detection elements capable of detecting and / or measuring at least a certain portion of electromagnetic signals 22. The electromagnetic sensors can be communicatively coupled with the computer system 30 and / or configured to produce signals detected in the computer system 30. In some embodiments, sensors 26 can be configured to detect and / or isolate the vertical component of electromagnetic signals 22. As indicated above, electromagnetic signals can be emitted on the earth's surface as a detectable electromagnetic field. It should also be noted that an electromagnetic field generally includes an electric field and a magnetic field. Accordingly, the electromagnetic sensor 26 may be able to detect signals

IMPI

MEXICAN INSTITUTE OF MOMFDAD industrial

<img file="MX342155B_D0025.tif" />

electromagnetic, an electrical portion of the electromagnetic signals 22 and / or a magnetic portion of the electromagnetic signals 22. In some embodiments, the electromagnetic sensor 26 can represent a magnetic field detector capable of detecting a magnetic field. In some embodiments, electromagnetic sensors 26 can be configured to attenuate and / or reject horizontal electromagnetic signals.

The electromagnetic sensors 26 can be arranged in one arrangement and / or in a variety of patterns. Any suitable number of electromagnetic sensors 26 can be arranged in the arrangement or pattern. For example, an arrangement of electromagnetic sensors 26 can include any of two to thousands of sensors. In some embodiments, the electromagnetic sensors 26 may represent a set of sensors that includes one or more magnetic field detectors, one or more electric field detectors, and one or more electromagnetic field detectors, which can be used at particular locations for passive prospecting. . The arrangement can be configured to arrange electromagnetic sensors, such as sensor 26a, and 26b, separated by any suitable lateral distance. For example, sensors 26a and 26b can be located anywhere from several centimeters (inches) to several kilometers (miles) apart.

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Sensors 26 may comprise any type of sensor capable of measuring the vertical electric field component of electromagnetic signals 22 in the immediate subsoil 24 of Earth. In some embodiments, additional or alternative signals may also be measured including the bottom vertical portion of the electromagnetic signals 14, the passive electromagnetic source 12 of electromagnetic radiation, one or more components of the magnetic field, one or more horizontal components, of the signal electromagnetic and / or one or more components of the seismic amplitude. In some embodiments, one or more electromagnetic field detectors can be configured to measure a horizontal component of the earth's electromagnetic field in one or more dimensions. For example, sensors 26 may include pairs of electrodes arranged in a horizontal alignment to measure one or more horizontal components of electromagnetic signals 22 and / or electromagnetic signals 14. In some embodiments, sensor 26 can be configured to measure various components of electromagnetic signals 22 and / or 14. For example, sensor 26 may represent a two axis electromagnetic field detector and / or a three axis electromagnetic field detector.

The sensors 26 can be arranged above the Earth's surface and / or within the Earth. In some embodiments, sensor 26 can be placed in or on the

<img file="MX342155B_D0026.tif" />

Earth's surface or at any distance above the Earth's surface. For example, electromagnetic sensors 26 can be arranged anywhere from one to thirty point forty-eight meters (one hundred feet) above Earth, depending on the relative amplification capabilities of sensors 26 and the attenuation of electromagnetic signals 22 . In some embodiments, sensors 26 may be disposed above and / or below the water table, above and / or below subsurface land reservoir 16, and / or any suitable combinations of locations and depths. Sensors 26 can be held in one location for one period of detection of particular electromagnetic signals 22 and / or can be moved subsequently to provide another period of detection. Additionally or alternatively, a plurality of sensors 26, such as an arrangement, can be used to provide several simultaneous measurements at various locations. For example, electromagnetic sensors 26 can be arranged within a probe. Alternatively or additionally, an arrangement of electromagnetic sensors 26 may be provided in the area above and / or surrounding the borehole to facilitate drilling and / or exploration of perforated fields. A more detailed discussion of an exemplary operation of such modalities is discussed below with respect to FIGURE 7. More detailed examples of the

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MEXICAN INSTITUTE OF PROPERTY

INDUSTRIAL sensors 26 are illustrated in FIGURES 2A, 2B, and 2C.

Seismic sensors 28 represent any suitable combination of detection elements capable of detecting and / or measuring at least a portion of seismic signals 20. For example, sensors 26 can be configured to detect the vertical component of seismic signals 20. The seismic sensors 28 can be communicatively coupled with the computing system 30 and / or configured to produce signals detected in the computing system 30.

Seismic sensors 28, may include, but are not limited to, geophones, hydrophones, and / or accelerometers, including digital accelerometers. Sensors 28 can represent a single component geophone, a two component geophone, or a three component geophone. Sensors 28 can also represent a single axis accelerometer, a two axis accelerometer, or a three axis accelerometer. In some embodiments, seismic sensors 28 may represent one or more three-component accelerometers. Additionally or alternatively, sensors 28 may represent any suitable combinations of these types of seismic sensors. For example, various types of sensors 28 can be used by system 10 to detect seismic signals 20. Seismic sensors 28 can measure a seismic wave in various directions, for example in one or two directions parallel to the earth's surface, in one

<img file="MX342155B_D0027.tif" />

IMPÍ

INSTITUTO MEXICANO DI LA PROPIEDAD INDUSTRIAL direction perpendicular to the earth's surface, and / or in a vertical direction.

The seismic sensors 28 can be arranged in any arrangement and / or in a variety of patterns. For example, seismic sensors 26 may be arranged and / or located in similar ways and locations as discussed above with respect to sensors 26. Any suitable number of seismic sensors 28 may be arranged in the arrangement or pattern. For example, seismic sensors 28 can be arranged in a similar manner as discussed above with respect to electromagnetic sensors 26. The seismic sensors 28 can be separated laterally by less than about half the wavelength of the highest frequency surface seismic wave expected to be detected. This may include frequencies higher than those expected to be produced by the electrosismic effect within the underground land deposit. Seismic sensors 28 can be configured to attenuate and / or reject surface and / or horizontal seismic signals. Such signals can be caused by various sources including heavy equipment, vehicular traffic, and / or natural sources such as earthquakes and / or thunder.

In some embodiments, a pattern and / or arrangement of electromagnetic sensors 26 may overlap with a pattern or arrangement of seismic sensors 28. The detected signals

<img file="MX342155B_D0028.tif" />

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MEXICAN INSTITUTE of coldness r% Z “5;

INDUSTRIAL by sensors 26 and / or 28 can be transmitted to computer systems 30. In some embodiments, the signals can be properly recorded, for example using a conventional seismic field record. Additionally or alternatively, each sensor can have its own recording device, and each recording device can be internal or external to the seismic sensor. It should be noted that although illustrated as including sensors 26 and 28, system 10 may include only sensors 28 or only sensors 28 as appropriate for particular embodiments. Accordingly, any suitable combination of sensors 26 and / or sensors 28 can be used.

Sensors 26 and / or 28 can form all or a portion of a long-term facility, which can be used for long-term passive prospecting. Signals 20 and / or 22 can be detected multiple times over a period of time, which can be periods of days, weeks, months, or years. Long-term studies can provide a time-based indication of various properties of the underground terrestrial reservoir 16, including any changes to the reservoir during the time period in which the signals are detected. The system 10 can thus be used to monitor the development and / or reduction of the hydrocarbon field and / or water well or aquifer during production periods.

The computer system 30 represents any

<img file="MX342155B_D0029.tif" />

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MEXICAN INSTITUTE

DE LA FROPIEDAC industrial appropriate combination of hardware, software, signal processors, and control logic to process, store, and / or analyze electromagnetic signals 22 and / or 20 seismic signals, received from sensors 26 and / or 28. The system 30 Computing can include one or more processors, memory, and / or interfaces. The computer system 30, for example, can include an interface that can operate to communicate with and / or receive information from the sensors 26 and / or 28. The computer system 20 can be operative to receive and / or process passive survey data from sensors 26 and

28. Passive survey data may include, for example, representative data from signals 20 and / or 22. The computing system 30 may include one or more analog-to-digital converters suitable for digitizing signals 20 and / or 22 for signal processing. digital. Alternatively or additionally, sensors 26 and / or 28 may include suitable analog-to-digital converters. The computer system 30 may include a recording and / or storage device capable of operating to receive and store data received from sensors 26 and 28. The computer system 30 may include, for example, digital and / or analog recording devices and / or non-transitory means. In some embodiments, the computing system 30 may be able to process the detected seismic signal 20 and the detected electromagnetic signal 22 in real time without first registering the signals in a non-transient medium.

<img file="MX342155B_D0030.tif" />

IMPI

MEXICAN INSTITUTE Dt LA MONEDAD INDUSTRIAL

The computing system 30 can form all or a portion of a recording vehicle, a housing structure, or a weather resistant enclosure located near the sensors 26 and / or 28. In some embodiments, the computing system 30 can enclose yourself at least partially in a weather-resistant enclosure. Accordingly, the computer system 30 may be able to record passive study data for days up to weeks without human intervention. As shown below with respect to FIGURES 4-6, a computing system 30 can be locked in a dedicated recording vehicle. In addition, although illustrated as external to sensors 26 and / or 28, computing system 30 may be internal or external to a housing of one or more sensors 26 and / or 28. In addition, computing device 30 may be one of a plurality of computing devices 30 used to record one or more electrical and / or seismic signals. The computing device 30 may be able to communicate with other computing devices 30 or other data processing servers over a network (not shown). The network can be a wired or wireless communication network. In this way, any of the data processing techniques described herein may be performed by one or more computing devices 30 and / or may be performed by a remote data processing server, which may be capable of processing and correlating data. from several

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INDUSTRIAL 30 computing devices. An exemplary embodiment of the computing system is discussed in greater detail below with respect to FIGURE 9.

As illustrated in FIGURE IB, the passive seismic source 40 represents any suitable passive source of seismic energy. For example, the passive source 40 can represent the earth's natural seismic energy. The passive source 40 propagates the seismic energy to the earth's subsoil as seismic signal 42. The seismic signal 42 may represent, for example, a seismic plane wave 42. When the seismic signal 42 propagates to the earth, it may encounter several underground earth deposits 16. The interaction of the seismic signal 42 and the underground terrestrial reservoir 16 may cause a seismic conversion to take place at an edge and / or boundary 18 of the underground reservoir 16. As a result, one or more electromagnetic signals 22 and / or seismic signals 20 can propagate towards the earth's surface. The electromagnetic signal 22 as a result can be generated from a seismic conversion as the seismic signals 20 propagate to the surface electromagnetic. Sensors can detect electromagnetic signals. Seismic sensors 28 can detect seismic signals 20. In some embodiments, seismic sensors can detect seismic signals, the

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INSTITUTO MEXICANO DE LA PROPIEDAD industrial which can be used as a reference to detect a modulation of signals 20 and / or 22 by the underground ground reservoir 16.

The passive seismic source 40 can represent the seismic energy that occurs naturally from the earth. Each seismic energy that occurs naturally from the earth can include a wide spectrum of frequencies, from sub-hertz frequencies to tens of thousands of hertz frequencies, which have a wide coverage over the earth's surface. This broad spectrum allows a wide range of depths of penetration of the seismic signal 42 from tens of meters to tens of kilometers, the corresponding frequencies of the seismic signal 42 on the ground may result from variations in the passive source 40 due to various events such as earthquakes, tides, tectonic events, volcanic activity, thunder, and atmospheric pressure fluctuations. In some embodiments, the passive source 40 of seismic signals 42 may include cultural sources of seismic waves, which may have frequencies low enough to reach and interact with underground reservoir 16. As another example, the passive source 40 may include well drilling activities, pumping fluids, automobile noise, compressor noise, farm noise, and manufacturing noise, which can generate seismic signals 42 of adequate resistance.

<img file="MX342155B_D0031.tif" />

and / or frequency to interact with the underground site 16.

FIGURE IB includes several examples of passive seismic source 40, including passive seismic sources 40a-40e. Passive seismic source 40a may represent a source of seismic energy resulting from a drilling operation. The passive seismic source 40a can represent a drilling event located at a particular depth (such as, for example, the head of a drill bit or the drilling apparatus that interacts with subsurface) and / or can represent vibrations from drilling activities along a section of the hole and casing. Passive seismic source 40b can represent a source of seismic energy that results from horizontal drilling activities such as fracturing, hydrofracturing, or other drilling operations. Additionally or alternatively, the passive seismic source 40b may represent seismic energy caused by the fluid moving through the pore spaces in the rock (which may be the result of hydrofracturing). Passive seismic sources 40c and 40d may represent sources of seismic energy that result from the earth's natural seismic activity and / or a micro-earthquake or other natural event, as described above. The passive seismic source 40a may represent a source of seismic energy resulting from a

<img file="MX342155B_D0032.tif" />

IMPI

MEXICAN INSTITUTE OF INDUSTRIAL PROPERTY immediate subsoil or surface event. Accordingly, the passive seismic source 40 can include any suitable source of seismic energy and / or can be located in any suitable relationship with the underground land reservoir 16 including above, below, behind or in the underground land reservoir 16. Additionally or alternatively, the passive seismic source 40 may include seismic energy caused by a drill bit, fracturing rock, fluid moving through pore spaces in the rock, wells where drilling or pumping activity occurs, and / or or by polluting fluids that migrate through the subsoil.

The seismic signal 42 represents a seismic wave, a seismic plane wave, or other suitable seismic signal that propagates to Earth from the passive source 40. Accordingly, the seismic signal 42 can emanate from any suitable passive seismic source 40, including those originating from the Earth's surface and / or located at a certain suitable depth below the surface. For example, seismic signals 42a-42e may respectively originate from passive seismic sources 40a-40e.

It should be understood that the various signs illustrated in the

FIGURES IA and IB are represented in different figures for clarity only. Consequently, particular modalities of system 10 may be able to use signals 20 and / or

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MEXICAN INSTITUTE Al

OF THE PROPERTY ^{Λ Γ} &lt;'industrial propagated by the passive electromagnetic source 12 and / or by the passive seismic source 40. Furthermore, system 10 can be configured to use signals 20 and / or 22 from passive electromagnetic source 12 at particular times while using signals 20 and / or 22 from passive seismic source 40 at other particular times and / or You can use the signals at the same time. For example, passive electro-seismic / seismoelectric prospecting using passive seismic sources and / or passive electromagnetic sources 12 may be collected during drilling or fracturing or enhanced oil recovery to acquire information on hydrocarbons and / or other fluids. Study data from passive electromagnetic sources 12 can be collected, for example, when passive seismic sources 40 are attenuated. For example, the drilling operation may be paused and / or terminated. As another example, the computing system 30 can perform passive prospecting during drilling, fracturing, and / or enhanced oil recovery to acquire information on hydrocarbons and / or other fluids.

In operation, system 10 detects, stores, and / or analyzes electromagnetic signals 22 and / or seismic signals 20. Sensors 26 and 28 respectively can detect electromagnetic signals 22 and seismic signals 20. Each sensor can transmit the detected signals to the device

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for storage and / or processing. The «« lll.u kl A. I »·.

computing device 30 can record the resulting electromagnetic signals 22 and / or seismic signals 20. The computing device 30 can process the electromagnetic signals 22 and / or the seismic signals 20 to identify various properties associated with the underground reservoir 16.

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electromagnetic propagated from the passive seismic source 40. The computer system 30 can then process the detected signals using various signal processing techniques to identify properties and / or characteristics of the underground land reservoir 16. Thus, the techniques discussed in the present description can be used to analyze the signals 20 and / or 22 generated as a result of the passive electromagnetic source 12 and / or the passive seismic source 40. Certain examples of the operation of the system 10 provided below can be discussed with respect to a passive electromagnetic source 12, but it should be noted that the teachings of the present disclosure apply similarly and / or the same as the signals generated by the passive seismic source 40.

The system 10 can process the signals to determine the existence of a fluid in the reservoir 16

MEXICAN INSTITUTE OF INDUSTRIAL PROPERTY

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underground and / or other properties of the underground reservoir, such as the existence of the underground terrestrial reservoir 16, and / or an indication that it contains a fluid, a depth of the underground reservoir 16, a porosity of the underground reservoir 16, a permeability to fluid from underground land reservoir 16, a composition and / or type of at least one fluid within underground ground reservoir 16, a spatial extension of the underground land reservoir 16, an orientation of the boundaries of the underground land reservoir 16, a resistivity of the underground land reservoir 16, or any combination thereof. Fluids that can be detected and / or identified by system 10 can include an aqueous fluid (such as water), a hydrocarbon, petroleum, carbon dioxide, carbon monoxide, acid gases, helium, nitrogen, other underground minerals. System 10 may also be able to identify and / or track the migration of fluids, contaminants, magma, and other underground fluids.

System 10 can be moved during a measurement to detect signals 20 and / or 22 at various locations. In this way, system 10 may be able to generate and analyze passive study data across large study areas.

The mobile system 10 can provide useful information for a classification or a first glance over an area of

MEXICAN INSTITUTE

DF THE PROPERTY. L.lJLlÍ '

INDUSTXIAL and. / Interest. In some embodiments, system 10 can be arranged in a mobile vehicle. For example, sensors 26 can be installed in a pattern on a mobile device to facilitate movement of the arrangement. For example, sensors 26 may be arranged on a trailer, frame, or cargo carrier that can be connected to a mobile vehicle such as a truck or van. Sensors 26 may alternatively be installed in a land vehicle, watercraft, or aircraft. System 10 can record and / or store signals 20 and / 22 detected by sensors 26 and / or 28, as described in greater detail herein. In a certain embodiment, system 10 can continuously and / or repeatedly detect signals 20 and / or 22 while moving.

The computer system 30 can record signals 20 and / or 22 for various periods of time when appropriate.

The computer system 30 can use sampling techniques to ensure an adequate representation of the detected signals. A minimum sampling rate can be determined based on the frequency of the sampled signals. In general, the sampling ratio for analog to digital conversion should be at least twice the highest frequency of interest to adequately represent the recorded waveform. However, higher order sampling can be used, including various oversampling techniques. Higher record times

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OS INDUSTRIAL PROPERTY

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they can allow better signal to noise ratios (SNR) and therefore can increase the reliability of the detected signals.

The computing system 30 can process the detected signals and / or 22 to determine particular properties of the underground land deposit, including any one or more of the properties discussed above. The computing system 30 can process the signals at substantially the same time as the time the signals are detected and / or can store the signals to process the signals at a later time. The computer system 30 can be configured to apply various digital signal processing techniques to the detected signals.

For example, the computing system 30 can apply a series of pre-processing steps to the detected signals, including applying various calculated filtering techniques to remove noise and / or isolate the signals of interest from the detected signals. After preprocessing, the computer system 30 can determine from the processed data various properties of the underground terrestrial reservoir 16. The computer system 30, for example, can correlate the processed data to identify the properties of the underground land deposit 16. Each of these stages are discussed in greater detail below.

Pre-Processing of 20 and / or 22 Detected Signals

The computer system 30 can apply various

IMPI

MEXICAN INSTITUTE OF EROEIEOAD

INDUSTRIAL

<img file="MX342155B_D0037.tif" />

pre-processing techniques to the data received from sensors 26 and / or 28 to identify and / or isolate signals 20 and / or 22 from other sources of electromagnetic signals that may be received by sensors 26 and / or 28. For example , to isolate the electromagnetic signals 22, the computing system 30 can apply a noise reduction scheme using a generated reference signal that is detected and / or demodulated to identify and / or isolate the electromagnetic signals 20. The computing system 30 can also apply other noise reduction techniques, such as isolation of direct current components of the signal, digital sampling techniques, and / or analog and / or digital band-pass filtering.

Coherent noise refers to cyclic signals 20 and / or 22 that have an approximately constant frequency during a predetermined measurement period. Many coherent electromagnetic noise sources can be found in a typical measurement setup and can be accounted for through various processing techniques. For example, the 60 Hertz (Hz) power line frequency can generate a high-amplitude electromagnetic signal that can propagate on the ground, where the resulting amplitude in one or more electromagnetic sensors 26 can be hundreds or thousands of times greater that the background electromagnetic field

IMPI

INST1TUT MEXICANO Dt LA MONEDAD

INDUSTRIAL

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desired within the earth. Similarly, unbalanced power lines can generate 180Hz of noise and motors can generate 400Hz of noise. As a further example, cathodic protection circuits may introduce poorly rectified alternating current (AC) signals at various frequencies resulting in electromagnetic noise at one or more electromagnetic sensors 26.

The computer system 30 can apply various noise reduction techniques, including a technique that can use a generated reference signal that is demodulated to identify and / or isolate electromagnetic signals 22. The noise reduction scheme can be used to generate a signal that can have an increased signal-to-noise ratio with respect to the entire aspect of electromagnetic field 14. For example, a reference signal may be generated by a reference signal generator and input to the nearby surface 24 of the

Land. The reference signal generator can transmit the reference signal on the ground from a location close to the ground. Electromagnetic signals 22 can modulate the reference signal in the same way as the vertical portion of electromagnetic signals 22. After detecting the modulated reference signal with sensor 26, the computing system 30 can then compare the detected signal with the known reference signal and isolate the

<img file="MX342155B_D0039.tif" />

IMPI

MEXICAN INSTITUTE OF THE WOPIEDAr;

INDUSTRIAL 22 electromagnetic signals for further processing. The detected modulated reference signal, in some embodiments, can be filtered or otherwise pre-processed before comparing and isolating the electromagnetic signal 22. For example, a blocking amplifier can be used to isolate the electromagnetic signal 22 from the detected signal. The reference signal generator can be coupled to the blocking amplifier 804 or can be part of the blocking amplifier. The reference signal and the detected modulation signal can be input to the blocking amplifier. The blocking amplifier can produce a signal comprising the electromagnetic signal 22 with an improved signal to noise ratio compared to the signal detected by the sensor 26. The existence of a modulation of the reference signal can be taken as an indication that coupling has occurred due to the interaction of the reference signal with the electromagnetic signals 22. Electromagnetic signals 22 can then be isolated based on the fact that electromagnetic signals 22 may have a narrower band-frequency spectrum than the reference signal and / or may have recognizable and removable characteristics. The signal produced can then be sent to one or more additional processing stages, before being passed for further analysis.

Depending on the type of sensors 26 and / or 28

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INDUSTRIAL used to detect the signal, electromagnetic signals and / or seismic signals can include an alternating current (AC) portion and a direct current (DC) portion. The CD portion of the signal may result from detection of one or more portions of the earth's electromagnetic field 14, and may not be representative of electromagnetic signals 22 or seismic signals 20. Accordingly, the CD portion can represent noise that can be filtered prior to analysis of signals 20 and / or 22. The CD portion can be filtered and / or removed using any suitable techniques, such as using a capacitive filter and other elements of the sensor 26 and / or design 28 and / or use a digital filter implemented in software.

Digital sampling techniques that include data reduction can be used to limit and / or filter the data to be processed. Reduction may refer to a suitable technique to reduce the effective sampling rate. To the appropriate degree, reduction can reduce the amount of data that is processed in the analysis stages, which can reduce processing times. Signal data typically can be reduced to an effective sampling rate approaching twice the highest frequency of interest while allowing for identification of the frequency characteristics in the data. Greater reduction ratios can be used, for example, when

<img file="MX342155B_D0040.tif" />

<img file="MX342155B_D0041.tif" />

you want a quicker, and possibly less accurate, first look. In some embodiments, signals 20 and / or 22 can be oversampled and / or averaged over one or more frequencies and / or frequency ranges to reduce the effects of momentary fluctuations in electromagnetic field 14 and / or signals 20 and / or 22 . For example, the signal amplitude may be selected to be averaged by the computing system 30 at one or more fixed frequencies present in the detected seismic signal 20 and / or the electromagnetic signal 22. It should also be noted that seismic signals 20 may require certain characteristic propagation times for a seismic wave originating from the underground ground reservoir 16 to reach the Earth's surface. The averaging process may include identifying the characteristic seismic propagation times of the underground reservoir. The averaging process may include and / or sample the signal amplitude for a duration of time, which may be more than twice the oscillation period, and average the signal amplitude during the detection time period.

Various filtering techniques can be used to isolate signals 20 and / or 22, reduce noise, and / or increase SNR. For example, signals 20 and / or 22 can be filtered with a bandpass filter to isolate one or more frequency bands of interest. Noise can be filtered using a high pass filter, a low pass filter,

IMPI ® MLXJCANC INSTITUTE OF INDUSTRIAL PROPERTY

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wideband frequency filter, and / or 'S'OKTSBefci'S.SSBVBfc · * narrowband frequency filter, or other suitable noise filter.

In some embodiments, environmental and / or naturally-occurring sources of electromagnetic radiation, such as electromagnetic signals 14 and / or passive electromagnetic source 12, can be used to determine the frequency range, amplitude range, and / or other parameters of a desired noise filter.

Coherent noise sources may not have an exactly constant frequency for a predetermined measurement period. These imperfections may be due to phase changes in the coherent noise sources. For example, the electromagnetic noise generated by power lines may experience some variations in power line voltage. The computer system 30 can monitor the phase of the coherent noise source to adjust the start times to correspond to the phase of the coherent noise for each interval. The coherent noise source may also experience amplitude variations over time, which may result in partial noise cancellation consistent with the sum of the intervals. In one embodiment, the computing system 30 can apply a frequency filter, such as a frequency notch filter, to the detected electromagnetic signals 22 to further improve the signal-to-noise ratio and / or

<img file="MX342155B_D0043.tif" />

IMPI

INSTITUTO MEXICANO OS LA PROPERTY INDUSTRIAL reduce a portion of the coherent noise in a background electromagnetic field.

The techniques used to remove at least a portion of the coherent noise from the detected electromagnetic signals 22 can also be applied to the detected seismic signals 20. Various sources of coherent seismic noise can occur in a typical measurement configuration, including, for example, engine noise and industrial equipment. It should be noted that the start time and duration for each corresponding interval of the detected electromagnetic signals 22 and the detected seismic signals 20 can be the same to improve cross-correlation of the signals. In some embodiments, the start time and duration can be selected to allow cancellation of at least a portion of the coherent noise in the detected electromagnetic signals 22 and the detected seismic signals 20.

The horizontal components of the electromagnetic signals 22 and / or the seismic signals 20 can be rejected in any suitable way. For example, various electromagnetic sensors 26 can be arranged in one arrangement and can be used to detect one more horizontal and / or vertical components of the electromagnetic signal 22. Similarly, horizontal seismic noise can also be rejected in seismic signals.

MEXICAN INSTITUTE OF PROPERTY

INDUSTRIAL detected. In particular, the detected seismic signals 20 can be filtered in the spatial domain to reject surface waves traveling horizontally through the seismic sensors 28. One or more seismic sensors 28 can be configured to measure a horizontal component of seismic signals 22, which can be used to generate the horizontal components used in the spatial filter. Accordingly, a horizontal component of the electromagnetic signal 22 and / or the seismic signal 20 can be used as a prediction filter to remove noise from the vertical component of the electromagnetic signal 22 and / or the seismic signal 20. The prediction filter can use horizontal components detected by one or more electromagnetic sensors 26 and / or sensors 28.

Spatial filters can also be applied to reject local seismic noise that can be detected by seismic sensors 28. In some embodiments, local noise waves can propagate through the plurality of seismic sensors 28 in expected propagation patterns, which can be analogous to water waves in a pond. Propagation noise waves can be eliminated by determining the direction of travel and velocity, and by applying a spatial filter that makes use of the propagation symmetry of the noise wave. The spatial filter can eliminate local noise from the seismic signals detected by each sensor

<img file="MX342155B_D0044.tif" />

<img file="MX342155B_D0045.tif" />

28. In some embodiments, a prediction filter can be used to predict the arrival and amplitude of the local noise wave in a seismic sensor and to remove the local noise wave during generation of the detected seismic signal.

As indicated above, one or more seismic sensors 28 can be configured to measure a horizontal component of the seismic wave. These seismic sensors 28 can also be used to determine the propagation geometry of the local noise wave. The spatial filter can then be applied to each of the plurality of seismic sensors 28, including those that may not be configured to measure a horizontal component of the seismic wave. In some embodiments, one or more additional seismic sensors 28 used for local noise rejection may be implemented at a separation distance from the seismic sensors 28 that measure the seismic signals 20. The ability to measure the local noise wave at a distance from other seismic sensors 28 can provide better prediction of the local noise wave and an improvement in local noise wave reduction in the detected seismic signal.

To improve spatial continuity through seismic sensors 28, seismic signals 20 detected by various seismic sensors 28 can be cross-correlated and / or summed. The summed seismic signals 20 can be used as a prediction filter to improve the

IMPI

MEXICAN INSTITUTE OF PROPERTY

INDUSTRIAL

<img file="MX342155B_D0046.tif" />

spatial continuity. The summed seismic signals 20 can result in an increase in the amplitude of the seismic waves arriving at the same time, for example, from a plane wave. The summed seismic signals 20 may tend to cancel out local noise sources and / or seismic signal components 20 that do not travel as a plane wave. In some embodiments, an immersion filter can be used to reject noise. For example, the fact that the seismic signals resulting from one or more electronic conversions may be plane wave can be used to remove at least a portion of a signal. noise level of the seismic signal detected. In particular, an immersion filter can be used to reject the detected seismic signals 20 that arrive at a non-normal angle to the seismic sensors 28. In some embodiments, the immersion filter can be applied after cross-correlating the seismic signals detected from two or more of the seismic sensors.

Processing of Signals 20 and / or 22

After any of the above optional pre-processing steps are performed, the resulting filtered and / or signals 20 can be processed to determine one or more properties of the underground land reservoir 16. Processing may include extracting an envelope from filtered signals 20 and / or 22, applying various processing steps and / or frequency domain analysis, and others

<img file="MX342155B_D0047.tif" />

processing techniques as explained in more detail below. The existence of hydrocarbons in a reservoir can be indicated by the existence of a modulation in signals 20 and / or 22. In terms of signal analysis described in this section, the modulation can be identified by the computer system 30 by demodulating a portion of signals 20 and / or 22 detected to determine if an envelope can be identified. If no envelope is found that can be distinguished from white noise, for example, or some other suitable reference signal, then this result can be taken as evidence that there are no hydrocarbons in the underground reservoir 16. If a suitable envelope is identified, then the analysis described herein can be carried out to identify the spectral properties of the envelope and correlate the results with the presence of various fluids as well as a time and / or frequency-depth function. In some modalities, other studies as described below may be performed when an envelope is identified.

The pre-processed signals 20 and / or 22 can pass to a signal envelope extraction stage in which the computing system 30 determines a signal envelope in the band of interest. The signal envelope can refer to the shape of the signal modulation. The modulation and therefore the envelope, may comprise one or more than one

<img file="MX342155B_D0048.tif" />

INDUSTRIAL frequency modulation, a phase modulation, or an amplitude modulation. An envelope detector used to extract the envelope from the signal can be implemented in hardware or software. The envelope detector can demodulate signals 20 and / or 22 to determine and / or extract the signal envelope. Various demodulation techniques can be used to extract the signal envelope, including the Hilbert transform method.

If a signal envelope has been obtained, the computer system can analyze the envelope to calculate one or more spectral properties. Spectral properties can include amplitude and frequency characteristics of a signal and / or envelope, as well as other signal and / or envelope characteristics, such as phase characteristics. The determination of spectral properties can allow the computing system 30 to compare the envelope with one or more additional envelopes for additional signal bands. Spectral properties can be determined in the frequency domain by calculating the Fourier Transform and / or the power spectral density. For example, the power spectral density for various frequency bands can be calculated to provide the power carried by the envelope expressed in power units per frequency. Alternatively or in addition to the power spectral density, a Fourier Transform (FT), such as a

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Fast Fourier Transform (FFT) and / or a complex FFT, can provide an indication of various envelope frequency characteristics, including frequency distribution. Furthermore, the power spectral density and FT calculations can provide relative amplitudes of each of the identified frequencies. The calculation of the spectral properties can be implemented in hardware and / or software. In some embodiments, the computing system 30 can determine one or more spectral properties using a blocking amplifier and / or a spectrum analyzer.

Once the spectral properties have been calculated, the computing system 30 can compare corresponding values ​​in certain frequency bands with the corresponding spectral properties in other frequency bands. Based on the comparison, the computing system 30 can generate one or more ratios of spectral properties, such as ratios of power spectral densities, FFT amplitudes, and / or phases. A particular detected signal 20 and / or 22 that includes various portions of white noise can be used as a base set of spectral properties that can be used as bases for comparison. For example, the base spectral properties can be used to normalize other calculated relationships. It should be noted, however, that other mathematical transformations can be used to produce

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<img file="MX342155B_D0051.tif" />

similar results.

The computer system 30 can analyze and correlate the spectral property relationships as a function of the bandpass frequencies of the original signals 20 and / or 22 and / or as a function of the frequency band of the extracted envelopes. Based on the analysis, the computing system 30 can determine the information on the frequency characteristics of the modulation signal and / or the correlation of amplitude with respect to the resistance of the modulation signal for each frequency. Variations within the analysis can be used as feedback to adjust the analysis criteria such as increasing the bandwidth of the bandpass filters, which can be expected and increasing the amplitude of the ratio of the power spectral properties. The analysis properties can be designed based on the quality and quantity of data obtained, the type of signals present and interact with a reservoir of interest, and a desired processing cost rate.

The computer system 30 can process the power spectral density obtained by not trending the power spectral density and / or integrating the power spectral density. The computer system 30 can then perform a detected electromagnetic field correlation analysis in the time domain, the frequency domain, or

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<img file="MX342155B_D0052.tif" />

both of them. For example, after trend elimination and integration, the computing system 30 can determine an FT of the power spectral density. The FT of the power spectral density can produce correlations between the source electromagnetic field 14, and the secondary electromagnetic fields 22 generated by the seismic signals 20 by the seismoelectric effect in the immediate subsoil field 24. Analysis properties can be designed based on the quality and quantity of data obtained, the type of signals present and interaction with a reservoir of interest, and a desired processing cost rate. In such modalities, the computing system 30 can determine the existence of hydrocarbons in the underground terrestrial reservoir 16 that can be indicated based on the existence of strong correlations between the source electromagnetic signal 14 and the secondary electromagnetic signals 22 generated by the seismic signals 20 through the seismoelectric effect in the immediate subsoil deposit 24. The seismic signals 20 can be generated by electrosismic effects in the underground terrestrial reservoir 16 at correlation moments that may correspond to the known seismic transit time between the hydrocarbon reservoirs and the earth's surfaces.

Seismic transit times can be explicitly obtained from seismic data obtained in the area of

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<img file="MX342155B_D0053.tif" />

interest or can be estimated based on the acoustic properties of the rock.

The correlation of spectral properties of the envelope and the presence of various fluids in underground pore spaces can be based on a variety of classification methodologies. For example, statistical regression analysis, and statistical classifiers such as neural networks, decision trees, classifiers

Bayesians, fuzzy logic classifiers, and conventional statistical classifiers can all be used to determine a time-depth and / or frequency-depth relationship. For example, analysis can be performed with the system and methods described herein at locations with known properties and reservoir characteristics to train and / or determine correlation parameters. Once the parameters have been determined, such complete adequate training in a neural network, the computer system 30 can repeat the analysis in a new location.

Additionally or alternatively, the computing system 30 can perform power spectral analysis and obtain relative power ratios of the modulation signal 20 and / or 22 with respect to a background signal to determine the frequency characteristics of the modulation signal. Time and / or frequency characteristics can be used to derive depth information and

<img file="MX342155B_D0054.tif" />

location on the source and resistance of the modulation signal, thereby revealing information on the location and / or depth of an underground land deposit 16. A variety of models can be used to correlate the results of the spectral analysis with the depth of the modulation signal. For example, the depth of the underground reservoir 16 can be determined based on a time-depth function and / or a frequency-depth function. Although a correlation generally exists between the frequencies of modulation signals 20 and / or 22 and the depth at which those signals originate, the exact correlation may or may not be apparent from analysis of the signal detected by sensors 26 and / or 28. Accordingly, a time-depth function and / or frequency-depth function can be established using known or predetermined locations, parameters and / or calculations. Depth values ​​for similar locations can be determined based on those predetermined characteristics once the spectral characteristics of the signals are analyzed and determined. The time-depth and / or frequency-depth ratio for signals 20 and / or 22 may depend on the resistivity of the Earth, the reservoir properties, the types of components present, and / or the various electrical properties of a particular geological area . Therefore,

IMPI inuttuto mexicana • I THE INDUSTRIAL «ΟΗΪΒΑ»

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New and / or modified time-depth and / or frequency-depth functions can be determined and / or applied as the computer system 30 moves from one location to another. In some modalities, a function of time depth and / or frequency-depth for one area can provide a suitable estimate for another area depending on the relative characteristics of these areas. The time-depth and / or frequency-depth functions can be derived from pre-existing empirical data obtained from previous geographic studies and / or exploration. Other suitable data sources for determining a frequency-depth function can be considered, such as conventional surface effect conductivity analyzes. Based on a function of time-depth and / or frequency-depth and particular signals 20 and / or 22, the computing system 30 can derive the depth information associated with the underground ground reservoir 16.

The computing system 30 can use various correlation techniques, which can be used to identify particular properties of the underground reservoir 16. In some embodiments, passive prospecting can be performed by sequentially detecting and / or separately processing electromagnetic signals 22 and seismic signals 20. For example, detection of electromagnetic signals 22 and seismic signals 20 can

<img file="MX342155B_D0056.tif" />

IMPI Mexican Institute OF THE rtOFIEDAC IN »uSt» ial occur at different times and / or locations. In some embodiments, detection can occur during overlapping time periods and / or at the same locations. The two types of signals can be cross-correlated to determine various properties of the underground land deposit 16.

Cross correlation, which can also be referred to as conjoint processing, can be used to identify features in common with the data from both signals. For example, electro-seismic and seismoelectric signals can originate from the same physical conversion mechanism at limits 18 between dissimilar rocks or limits 18 between different fluids in rock pore spaces. Sensors 26 and 28, however, may not be equally sensitive to rapid signal changes or small differences in signal amplitude. In this way, the processed electromagnetic signals 22 and the seismic signals 20 may be similar but may not be identical. Cross-correlation by the computing system 30 can improve and / or isolate the common information from the data sets. The cross correlation can be carried out at a variety of points in the analysis of each signal · as described above with respect to the processing of electromagnetic signals 22 and seismic signals 20, either together or individually.

In some modalities, the computer system 30

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<img file="MX342155B_D0057.tif" />

it can cross-correlate the detected electromagnetic signals 22 with the detected seismic signals 20 to isolate at least a portion of the detected seismic signal 22. For example, electrosismic conversion can generate a seismic response in a time dependent electromagnetic field with a corresponding time dependency. Consequently, the resulting seismic signals 20 can have the same time dependency as electromagnetic signals 14, delayed by the seismic travel time. The electromagnetic signal travel time can be rejected because the downtime of electromagnetic propagation in the reservoir can be much shorter than the seismic travel time to the surface. This result can be used to eliminate at least a portion of the noise signal that does not possess the expected time dependency between the detected electromagnetic signals 22 and the detected seismic signals 20.

One or more harmonic signals can be detected and / or isolated on the detected seismic signal using a variety of methods. In some embodiments, the detected seismic signal can be cross-correlated with the detected electromagnetic field. A frequency analysis of the data resulting from the cross correlation can be used

<img file="MX342155B_D0058.tif" />

to identify frequencies in the detected seismic signal that are higher than those presented in the detected electromagnetic field. The frequencies present in the detected electromagnetic signal 22 can then be used to remove at least a portion of the corresponding frequencies, including fundamental frequencies, from the detected seismic signal 20 using, for example, filtering techniques as discussed above. The frequencies can also be used by the computer system 30 to detect and / or isolate one or more harmonic signals that may include coherent harmonic signals.

The computing system 30, in some embodiments, can detect and / or isolate the harmonic signals by partially rectifying the detected seismic signal 20 and / or the detected and / or isolated harmonic signals from the detected seismic signal 20. Harmonic signals may appear to be a partially rectified sine wave, which may be asymmetric at approximately zero amplitude. In some modalities, the positive amplitudes may be greater than the negative amplitudes. The resulting symmetry can be used by arbitrarily reducing the positive portions of the source waveform before cross-correlating. In some modalities, negative amplitudes may be greater than positive amplitudes. The resulting skewness can be used by arbitrarily reducing the portions - - - - * · - '¿i

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INDUSTRIAL t ** -S&gt; ^ negative of the source waveform before cross-correlation. Signal measurement and processing can be used to determine which portion of the amplitude, such as the positive amplitude portion or the negative amplitude portion, if any, is greater. Any of the aforementioned pre-processing techniques can be applied before the computing system 30 cross-correlates the detected harmonic signals in the detected seismic signal 20 with the detected electromagnetic signals 22 and / or one or more harmonic signals in the signals 22 electromagnetic detected. An auto-correlation of the detected electromagnetic signals 22 may have lower frequency components than the auto-correlation of the detected seismic signals 20. In some embodiments, the detected seismic signal 20 can be bandpass filtered to eliminate frequencies below the fundamental frequencies present in the detected electromagnetic signals 22, which can be used to identify harmonic signals. The filter can be applied before processing the detected seismic signal and the detected electromagnetic field. In some embodiments, the detected harmonic signals can be processed with the detected electromagnetic signals 22 to determine at least one property of the underground land reservoir 16. In some modalities the processing of harmonic signals

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detected with the detected electromagnetic signals 22 may comprise cross-correlation of the detected harmonic signals with the detected electromagnetic signals 22.

The computer system 30 can detect and / or isolate one or more non-linear signals using any suitable technique. Nonlinear signals in the detected electromagnetic field, which may include harmonic signals, can result from the conversion of electromagnetic energy in the electromagnetic field at the bottom of the earth into seismic energy, as described in greater detail above. This conversion point can also result in a frequency shift or time delay in electromagnetic energy in the electromagnetic field at the bottom of the earth generating non-linear signals. At least a portion of the resulting nonlinear signals can be detected by electromagnetic field detectors and used to determine at least one property of the underground land deposit.

In some embodiments, the interconnect 18 where the electro-seismic conversions occur can be modeled as a charged capacitor comprising a high resistance flat region and an existing internal electromagnetic field. The interconnection can then be understood as having a resistance-capacitor time constant (RC). The RC time constant can vary over a

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considerable range of values ​​depending on the resistance of the rock interconnection 18 and the internal electric field.

The RC time constant can also have the effect of smoothing out a portion of the above electromagnetic field 14, which can be detected by one or more of the electromagnetic sensors 26. In some embodiments, the degree of smoothing resulting from the electromagnetic field 14 can be used during processing to determine at least one property of the underground land deposit. The bottom electromagnetic field 14 can be modified depending on the orientation of the background electromagnetic field 14 with respect to interconnection 18. When the background electromagnetic field 14 is parallel to the internal field at interconnection 18, the internal field and internal voltage can not be significantly modified. In this orientation, interconnect 18 behaves as a high value single resistor with moving fluids in the pore space, and the RC time constant may not significantly affect the background electromagnetic field 14. However, part of the electric power field energy can be converted to seismic energy in the electrosismic response.

When the background electromagnetic field 14 is antiparallel to the internal field at the interconnect

18, internal chemical reactions can be temporarily stopped, stresses and effective resistance

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<img file="MX342155B_D0060.tif" />

they can be reduced, and the net electric field can decrease.

In this orientation, the applied field can be rectified at least partially to a reduced value and the change in internal stresses can produce a seismic response. In terms of the general underground terrestrial reservoir, the ground electromagnetic field can be partially rectified from the boundaries between the rock masses. As a result, the ground electromagnetic field 14 that interacts with a charged dipole layer where an electrosonic conversion occurs can be altered, and the disturbances can be detected by one or more sensors 26 configured to detect the electromagnetic field 14 of background. In some embodiments , the partial rectification of the bottom electromagnetic field 14 can be used to determine an orientation, resistivity, or both of at least one interconnect 18 in the underground ground reservoir 16. The apparent subsoil resistivity may depend on the background electromagnetic field polarization. In a polarity of the background electromagnetic field 14, the conversion surface appears as a simple resistance. In the opposite polarity, it appears to be a capacitor with a large Earth time constant. This time constant can at least partially smooth out a polarity of the source signal, resulting in a polarity that has an observable induced polarization while the

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opposite polarity cannot. The degree of polarization induced can act as an indicator of the interconnect resistivity, and the determination of the polarity that is affected can act as an indicator of the interconnection orientation of rock.

The properties of the background electromagnetic field 14 may be partially dependent, allowing a determination of the lateral degree of the underground ground reservoir 16. The extent of lateral variation in induced polarization and the generation of nonlinear signals can be reduced due to the long wavelengths present in the electromagnetic field 14 of the earth background. As a result, the detected electromagnetic field may have a limited resolution with respect to the edges 18 of the reservoir.

In some embodiments, low-frequency measurements, such as frequency measurements below 1 Hz, the electromagnetic field 14 of the earth's bottom can be useful in measuring the polarity dependence of induced polarization. In the measurements of the seismic signals resulting from the electro-seismic conversions, the

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IMPI

INSTITUTO MEXICANO DI LA EROPIEDAD INDUSTRIAL important characterizations. In some embodiments, frequency and time information can be determined by integrating the amplitudes of different polarities in the detected electromagnetic field and the detected seismic signal from one or more seismic sensors.

The non-linear signals in the detected electromagnetic signals 22 resulting from the conversions at the interconnections of the underground land deposit can be detected using a variety of methods. In some embodiments, the positive and negative polarities of the ground electromagnetic field 14 may have different amplitudes of different frequency spectra after they are affected by the interconnect. These differences can be used to determine the non-linear components of the detected electromagnetic signals 22. The resulting linear electronic response can be detected from the seismic signal detected on one or more simic sensors. Through a cross correlation, the linear components resulting from the detected electromagnetic signals 22 can be determined and isolated by the computer system 30. Using linear components as a filter, nonlinear components can be isolated from the detected electromagnetic field. The filtered electromagnetic signals 22 can further be processed to identify the non-linear components or reduce any noise signals

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present in the detected electromagnetic field after they are filtered. For example, additional filters can be applied and / or autocorrelations can be performed.

In some embodiments, the detected electromagnetic signals 22 can be compared to the electromagnetic field 14 of the bottom of the earth measured at a distant location. The detected electromagnetic field can have harmonic frequencies and low frequencies that are not present in a measured signal at a distant point. In this embodiment, the detected electromagnetic signals 22 on a remote electromagnetic sensor 26 can be used to filter the detected electromagnetic signals 22 above the underground ground reservoir 16. The remaining signal present after applying the filter may contain the various harmonic, nonlinear, and / or bass frequencies of interest. These signals can also be processed or filtered, for example, to eliminate one or more noise signals.

In some modes, any harmonic, nonlinear, and / or low frequencies present in the detected electromagnetic field above the underground ground reservoir of interest can be detected by comparing the detected electromagnetic field measured on earth with those measured in the atmosphere. If modulation of the electromagnetic field 14 from the bottom of the earth creates a seismic response, then the surface when the

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INDUSTRIAL

<img file="MX342155B_D0064.tif" />

Energy conversion can behave as a source of electromagnetic radiation since there is a finite region of the modulated electromagnetic field and charge separation. The electromagnetic field at the bottom of the earth within the Earth by itself can occupy a character that reflects non-linear conversion. The resulting electromagnetic radiation can manifest itself as a change in boundary conditions on the earth's surface. Specifically, the resulting electromagnetic radiation can create a vertical electric field that may not be continuous across the earth / atmosphere boundary. The use of a detected electromagnetic field above the earth's surface can be used to filter the detected electromagnetic field within the earth. The remaining signal present after applying the filter may contain the various harmonic, nonlinear, and / or bass frequencies of interest. These signals can also be processed or filtered, for example, to eliminate one or more noise signals.

GENERATION OF MODELS OF THE 16 SUBTERRANEAN LAND FIELD

Various properties of the underground reservoir can be used to develop a geological model of the underground land reservoir 16. Various modeling programs can be used to develop the underground reservoir model and can provide results

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OF INDUSTRIAL PROPERTY planned based on the model. The expected results can then be compared to the detected signals 20 and / or 22 to determine if the model is accurate. When a discrepancy is detected, the geological model can be altered and the process repeated. Such a process may result in a correlation between the geological model and the detected signal, thereby providing one or more properties of the underground reservoir 16. The computer system 30 may be capable of generating various models of the underground terrestrial reservoir 16, including three-dimensional models and time-dependent or four-dimensional models. Four-dimensional models can be generated based on signals 20 and / or 22 detected over time. Four-dimensional models in this way can illustrate the time-dependent properties of underground reservoir 16, including amounts of fluids produced from reservoir 16, changes in reservoir 16 over time, effects of hydrofracturing, migration of contaminants, and / or magma, and other time dependent properties.

Accordingly, the detection and analysis steps can be repeated by the computing system 30 any number of times. For example, multiple measurements can be made in one location over multiple time periods. The results can be statistically analyzed to

<img file="MX342155B_D0065.tif" />

IMPI

INSTITUTO MEXICANO DI LA PROPIEDAD INDUSTRIAL provide a correlation and / or study of. improved precision. Furthermore, one or more samples can be taken at several locations sequentially in time or concurrently in time using one or more sensors 26 and / or 28. For example, various measurements can be made at various locations around a site of interest. Various grid patterns and / or random sample locations can be selected to generate a plurality of measurements across an area. For example, the grid and / or detector arrangement described above can be used to generate a plurality of detected signals for use with the processing techniques described herein. The various measurements can be performed sequentially or concurrently at a single location, and / or the measurements can be performed sequentially and / or concurrently at various locations around a site of interest, when a plurality of locations is used to measure the signal of interest. The resulting hydrocarbon indications and the resulting depth measurements can be used to generate a two-dimensional, three-dimensional, and / or time-dependent model of the underground terrestrial reservoir 16 and / or one or more fluids contained therein. In some embodiments, the computing system 30 may be able to generate models using any suitable combination of study data obtained from any one or more.

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of the study techniques discussed below with respect to FIGURE 3.

The two-dimensional, three-dimensional, and / or time-dependent model may include one or more images and / or maps of the underground terrestrial reservoir 16. For example, the computer system 30 can use passive seismoelectric and / or electro-seismic data to develop a dimensional or three-dimensional map of the subsoil and / or underground areas. Various study data from any of the techniques in the present description can be correlated to identify particular characteristics of a particular portion of the image and / or map. For example, study data that is particularly reliable in identifying particular characteristics can be used as a baseline for comparison with other study data. As another example, study data for a particular coordinate and / or location in the model may be available from a first study method but not available from a second study method. Alternatively or in addition, the computing system 30 may be able to determine the reliability and / or accuracy of the particular study data and may determine whether it uses a first portion of the geological data of a methodology over a second portion of the geological data of another methodology. In addition, in some modalities, system 30 of

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The MIXICAN INSTITUTE OF INDUSTRIAL PROPERTY computation may be able, based on reliability determinations, to use a particular reliable data point from a first study technique as an assumption when processing and / or interpreting data from another study technique. For example, resistivity information determined from Controlled Source Electromagnetic Prospecting (CSEM) and / or Active Source Prospecting Depth information can be used as assumptions when interpreting passive source electro-seismic and / or seismoelectric survey data. Accordingly, information from various study methodologies can be interleaved, intrapolated, extrapolated, and / or combined as appropriate to form the image and / or map of the underground land site 16.

FIGURES 2A, 2B, and 2C are block diagrams illustrating exemplary sensors 26 for passive seismic and electroseismic prospecting. As illustrated in FIGURE 2A, sensor 260 may be a particular embodiment of sensor 26 that includes one or more conductor elements 202 and 204, coupling network 210, amplifier 208, and signal processing unit 209. Sensor 260 may be capable of detecting electro-seismic signals 22, as previously discussed with respect to sensor 26.

Sensor 260 can produce a signal representing the detected electromagnetic signals 22. Sensor 260 can

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MEXICAN INSTITUTE OF INDUSTRIAL PROPERTY installed and / or arranged in any suitable housing, including waterproof housing, moving vehicles, and / or permanent installations, as discussed above with respect to sensor 26, sensor 260 generally operates to comparing a stable reference voltage with a voltage radiation sensitive to electromagnetic signals radiated from the ground. Accordingly, sensor 260 can be configured to detect variations in the terrestrial signal, which can be fully or partially comprised of electromagnetic signals 22, compared to a reference voltage.

Conductive elements 202 and 204 are generally capable of measuring electromagnetic signals radiated from the earth. As illustrated, conductive element 202 measures a stable reference voltage, while conductive element 204 is generally capable of measuring the vertical component of electromagnetic signals 22. Conductive elements 202, 204 may represent any conductive and / or suitable conductive layers or other sensing elements. As illustrated, the elements 202 and 204 conductors are capacitive plates that are arranged parallel to the Earth's surface. An arrangement generally parallel to the Earth's surface can allow the conducting element 204 to respond to and / or measure the vertical component of electromagnetic signals 22, which can

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INDUSTRIAL represent a vertical electric field. Similarly, conductive element 202 can be protected from and / or configured not to measure the vertical component of electromagnetic signals 22. In some modalities, elements 202,

204 conductors can form a capacitor. The elements

202, 204 conductors can be a conductive metal such as copper, aluminum, or stainless steel. Particular modes of conductive elements 202, 204 may have an area of ​​from several square centimeters (square inches) to approximately several square meters (square feet). As illustrated, conductive elements 202, 204 can be separated from Earth by a distance x. The distance x can be any suitable distance at which the conductive elements 202, 204 may be able to respond to electromagnetic signals 22 transmitted in the air as a vertical electric field. Conductive elements 202, 204 can be configured relatively close to the ground. For example, capacitive plates 202, 204 can be separated from Earth by approximately 10-12 inches (25.40-30.41 centimeters) in particular embodiments. It should be noted, however, that although particular distances are discussed as an example, any distance can be used at which conductive elements 202, 204 are capable of detecting electromagnetic signals 22. The elements 202, 204 conductors can each be connected to

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the inputs of the amplifier 208. The conductive element 202 or the conductive element 204 can also be grounded.

It should be understood, however, that although a particular embodiment of conductive elements 202 and 204 is discussed herein, any suitable conductive elements may be used. For example, conductive element 202 may represent a flat conductive plate arranged near conductive element 204, which may be an antenna.

Suitable antennas may include flat conductive plates at predetermined distances and / or grounded, concave conductive plates above ground, various conductive plates with geometry to concentrate the signal, metal mesh or wire mesh in any shape and / or geometry. suitable, monopole wire extending up from the ground, loop wire around a ferrite or steel core, or any other suitable structure capable of being used as an antenna. Furthermore, conductive elements 202 and 204 can represent any suitable conductive elements arranged geometrically to maximize capacitance itself. Also, although illustrated as two components, conductive elements 202 and 204 can be implemented as a single component. For example, conductive elements 202 and 204 can be implemented using a monopole wire extending upward from the ground and / or a battery arrangement. In some

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INSTITUTO MEXICANO K LA PROPIEDAD INDUSTRIAL modalities, elements 202 and / or 204 conductors can represent a conductive sphere.

Amplifier 208 represents any amplification circuit operable to compare the signals generated by capacitive board 204 with the reference signals generated by capacitive board 202. Amplifier 208, for example, can represent an operational amplifier. In some embodiments, amplifier 208 may include any circuits and / or components that condition the signal. For example, amplifier 208 may be capable of performing any one or more of the preprocessing or processing steps discussed above with respect to FIGURE 1. Amplifier 208 may include suitable inputs and outputs. As illustrated, capacitive plates 202, 204 are connected to the inputs. The output can be connected to the computer system 30. For example, amplifier 208 may be capable of producing the electromagnetic signals 22 detected in computer system 30. Amplifier 208, in some embodiments, may include suitable analog-to-digital converters for digitizing the detected electromagnetic signals 22.

Signal processing unit 209 represents any suitable combination of hardware, software, and other components that can operate to process the output of amplifier 208. For example, processing unit 209

DE L * "OP1EDA" INDWm "IAl signal may be capable of íiTipIprnAnt-ir nnniqniora gives one or more of the processing steps discussed above with respect to FIGURE 1. Signal processing unit 209 may be a portion implemented by hardware of sensor 260 and / or can form a portion of computer system 30. Signal processing unit 209 may include one or more notch filters, low pass filters, high pass filters, clamping circuits, sample and hold circuits, or any other suitable signal conditioning circuits.

Coupling network 210 represents any suitable network of components that can operate to couple conductive elements 202, 204 to amplifier 208. As illustrated, coupling network 210 includes a capacitor Cl, inductor LI, capacitor C2 and a resistor R arranged like a pi filter. The pi filter can generally operate to select a desired frequency band for amplifier 208 and to exclude frequencies that may otherwise saturate amplifier 208. The resistance can be any suitable resistance, and in some modes, can be selected to set the constant of time of the input circuitry of electromagnetic signals 22.

The resistor R can be connected through the input of the amplifier 208 in parallel. Furthermore, although a particular embodiment of the coupling network 210 is illustrated,

<img file="MX342155B_D0071.tif" />

any suitable network components can be used.

For example, coupling network 210 may include a correlation resistor, a pi filter, a transformer, a resonant network, or any combination and number of these components.

Protection 212 represents any suitable electromagnetic protection. Shield 212 can be configured to attenuate and / or prevent horizontal components of electromagnetic fields from reaching conductive element 214. Shield 212 can be configured to surround all or a portion of conductive elements 202 and 204. For example, as illustrated, shield 212 may comprise a structure that surrounds the top and sides of conductive elements 202 and 204. The guard 212, for example, may be a vertically arranged cylindrical structure that can be closed at least at one end. just like the top end. Alternatively, guard 212 may represent a box or other suitable enclosure. Shield 212 may be formed of any suitable material that can operate to attenuate and / or prevent electromagnetic signals from propagating through the material. For example, shield 212 may be formed of Mu-metal, conductive plates or foil, wire mesh, aluminized Mylar material, supplied statically charged insulating plates, and / or conductive plastic. Metal Mu

<img file="MX342155B_D0072.tif" />

<img file="MX342155B_D0073.tif" />

It can refer to one or more classes of nickel-iron alloys that are characterized by high magnetic permeability. Shield 212 can protect against static or slow-moving electromagnetic fields that may otherwise interfere with the detection of electromagnetic signals 22. Shield 212 can be electrically connected and / or coupled to input on amplifier 208. Furthermore, it should also be understood that in the particular modalities, protection 212 may or may not be adequate and / or necessary.

In operation, the electromagnetic signals 22 can be a time varying vertical electric field.

Interaction of electromagnetic signals 22 with capacitive plate 204 can produce a load on the elements

204 conductors. The other board 202 can be protected from electromagnetic signals 22. Accordingly, the signals generated by the board 202 can be interpreted as the reference voltage. Accordingly, a capacitive load across the conductive elements 202 and 204 may turn out to correspond to the electromagnetic signals 22. In some embodiments, a resistor can be coupled in series with the charged conducting element 202. At suitable times, the charged conductive plate 202 can be unloaded and therefore allow a time variation field representative of electromagnetic signals 22 to be measured,

<img file="MX342155B_D0074.tif" />

<img file="MX342155B_D0075.tif" />

processed, and / or registered by the computer system 30. By using the parallel conductor elements 202, 204, sensor 260 can detect only the vertical components of electromagnetic signals 22 or other electromagnetic signals. Accordingly, the parallel plate design can be configured not to respond to the horizontal components of the electromagnetic signals 22. Although two conductive elements 202, 204 are shown, sensor 260 may include a single plate properly grounded through one or more resistance devices and coupled to computer system 30.

FIGURE 2B illustrates sensor 262, which may be a particular embodiment of sensor 26 that includes the network

211 coupling, shield 212, conductive element 214, electrode 216, amplifier 218, and unit

219 signal processing. Like sensor 260, a sensor 262 may be capable of detecting electro-seismic signals 22, as previously discussed with respect to sensor 26. Sensor 260 can also produce a signal representing the detected electromagnetic signals 22. Sensor 260 can be installed and / or arranged in any suitable housing, including waterproof housing, moving vehicles, and / or permanent installations, as discussed above with respect to a sensor 26.

Coupling network 211 represents any network

IMPI

MEXICAN INSTITUTE »t THE INDUSTRIAL PROPERTY

<img file="MX342155B_D0076.tif" />

of components that can buy or couple the conductive elements 202, 204 with the amplifier 208. As illustrated, the mating includes a resistor R of a suitable resistance, which can be selected to establish the time constant of the input of electromagnetic signals 22. The resistor R can be connected through the inputs to the amplifier 208 in parallel. Furthermore, although a particular embodiment of the coupling network 211 is illustrated, any suitable network components can be used. For example, the coupling network 211 may include a correlation resistor, a pi filter, a transformer, a resonant network, or any combination and number of these components.

Protection 212 represents any suitable electromagnetic protection, as discussed above with respect to FIGURE 2A. Shield 212 can be configured to surround all or a portion of conductive element 214. For example, as illustrated, shield 212 may comprise a structure that surrounds the top and sides of conductive element 214. Shield 212 can be electrically connected and / or coupled to an input on amplifier 218. As indicated above, it should be understood that in particular modalities, protection 212 may or may not be adequate and / or necessary.

The conductive element 214 represents any

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INSTITUTO MEXICANC ^ «ήΜκίΐϋιι PE LA TRONEDA 0

INDUSTRIAL suitable conductive element operable to generate a stable reference signal protected against one or more vertical and / or horizontal components of electromagnetic signals 22. The conductive element 214 may represent a conductive plate. As illustrated, the conductive element 214 is a conductive plate that includes multiple folds that form multiple parallel portions of the conductive element 214. The conductive element 214 folded into multiple folded portions can allow the conductive element 214 to fit within a much smaller volume while also having an area large enough to detect electromagnetic signals 22. Additionally or alternatively, the element

214 Conductor may include a conductive base portion that forms a main structure or connection for multiple conductive fins. Conductive element 214 may be electrically connected and / or coupled to an input in amplifier 218. The distance y represents any suitable distance separating conductive element 214 from the Earth's surface. For example, in a particular embodiment, the distance may be approximately 60.96 centimeters (24 inches). In some embodiments, the distance y can be relatively larger than the distance z.

Electrode 216 represents any suitable electrical component configurable to form a connection to

<img file="MX342155B_D0077.tif" />

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INSTITUTO MEXICANO DE EA PROPIEDAD INDUSTRIAL the Earth and / or detect one or more vertical portions of the electromagnetic signals 22. Electrode 216 is configured to form electrical contact with Earth and can be disposed within Earth. For example, electrode 216 may be arranged in a hole drilled in the Earth that varies from several centimeters (inches) to approximately 3.04 meters (10 feet) to approximately 4.57 meters (15 feet). Additionally or alternatively, electrode 216 may be disposed within Earth at various depths as needed to form an electrical coupling with the

Land. In some embodiments, electrode 216 represents a porous vessel electrode. Porous glass electrodes can include a suitable saline and / or aqueous solution to form an electrical coupling with the Earth, suitable useful salts with the electrodes can include, but are not limited to, copper sulfate, silver chloride, cadmium chloride , mercury chloride, lead chloride, and any combination thereof. In some embodiments, electrode 216 may include a conductive electrode such as grounding rods and / or metal sheets, mesh sheets, and / or wires buried in trenches or shallow pits. Electrode 216 can be manufactured from a variety of conductive materials including, but not limited to, copper, stainless steel, aluminum, gold, galvanized metal, iron, lead, brass, graphite, steel, alloys of the

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MEXICAN INSTITUTE OF RROPISUaD industrial

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themselves, and combinations thereof. Electrode 216 may be electrically connected and / or coupled to shield 212 and an input to amplifier 218. Electrode 216 may represent a porous vessel, a conducting cell, a buried length of wire, a buried wire mesh, and / or a group of or combination of the aforementioned components.

Amplifier 218 and signal processing unit 219 may be similar to amplifier 208 and signal processing unit 209. As illustrated, one input on amplifier 218 connects to shield 212 and another input connects to conductive element 214. Network

211 The coupling includes a resistor R connected through the inputs of amplifier 218. Electrode 216 also connects to the input connected to shield 212.

In operation, the electromagnetic signals 22 can be a time varying vertical electric field. The interaction of electromagnetic signals 22 with conducting element 216 can cause and / or induce an electrical response to be conducted and / or transmitted to the input into amplifier 218. Shield 212 can attenuate and / or prevent horizontal electromagnetic signals reach the conductive element 214. Accordingly, the signals detected by the conductor element 214 can represent a stable reference voltage while the detected signals

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INSTITUTO MEXICANO Di LA nORUDAI) INDUSTRIA 1

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by the conductive element 216 they can represent and correspond to the electromagnetic signals 22. Amplifier 218 can perform appropriate signal processing and produce the electromagnetic signals 22 detected in computing system 30. By using the conductive element 214 and shield 212, sensor 262 can detect only the vertical components of electromagnetic signals 22. Accordingly, the design of sensor 262 may be such that sensor 262 does not respond to horizontal components of electromagnetic signals 22 or other electromagnetic signals.

FIGURE 2C illustrates current sensor 264, which may be a particular embodiment of sensor 26 including shield 212, electrode 216, mating 213, resistor 226, amplifier 228, signal conditioning unit 229 , and battery 230. Sensor 264 may be capable of detecting electro-seismic signals 22 that may be capable of detecting signals 22 as current through a detection resistor 226. Sensor 260 can also produce a signal representing detected electromagnetic signals 22. Sensor 260 can be installed and / or arranged in a suitable housing, including waterproof housing, moving vehicles, and / or permanent installations, as discussed above with respect to sensor 26.

<img file="MX342155B_D0080.tif" />

IMPI

MEXICAN INSTITUTE OF INDUSTRIAL PROPERTY

Protection 212 represents any suitable electromagnetic protection, as discussed above with respect to FIGURE 2A. Shield 212 may be configured to surround all or a portion of battery 230. For example, as illustrated, shield 212 may comprise a structure that surrounds the top and sides of battery 230. Shield 212 may be connected electrically and / or coupled to the input on amplifier 228. In particular embodiments, guard 212 may additionally or alternatively surround all or a portion of mating network 213. As illustrated, shield 212 surrounds detection resistor 224 of mating network 213. As indicated above, it should be understood that in particular modalities, protection 212 may or may not be adequate and / or necessary.

The coupling network 213 can include any suitable components that can operate to couple the battery 230 to the amplifier 218. The coupling network 213 can include similar components as discussed above with respect to FIGURES 2A and 2B. As illustrated, the coupling network 213 includes the current sensor 222 and the detection resistor 224, the current sensor 222 represents any suitable current sensor, operable to detect a current I generated by electrode 216.

As illustrated, the current sensor 222 is a

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MEXICAN INSTITUTE OF INDUSTRIAL PROPERTY

<img file="MX342155B_D0081.tif" />

current transformer that detects the current as a voltage drop across a detection resistor 224. The current transformer can be a start transformer with, for example, up to 1000 times gain or more.

Current sensor 222 can represent any suitable current sensing technologies, including Hall effect sensors, a senseFET, or other suitable current sensor.

Battery 230 represents any suitable voltage source that can operate to allow current to flow from the ground through sense resistor 224. The 230 battery can have great self-capacitance. The charge may leak from the ground and attempt to charge battery 230. Battery 230 may have a capacitance and / or resistance between the battery and ground, which may represent the capacitance and / or resistance of the air. Electrode 216 can be connected to one terminal of resistor 224. Resistor 224 can be connected between terminals of current sensor 222. A terminal of resistor 224 can be connected to a battery terminal

230. Resistor 226 can be connected in parallel to battery 230. The outputs of current sensor 222 can be connected to inputs of amplifier 228, which can provide an output representing electromagnetic signals 22. Amplifier 228 and unit 229

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Signal conditioning may be similar to amplifier 208 and signal processing unit 209. It should be noted that in some embodiments, the battery 230 may additionally or alternatively comprise a capacitor. It should also be noted that in some embodiments, a current amplifier may additionally or alternatively perform the functions of the current sensor 222, the detection resistor 224, and the amplifier

228.

In operation, variations in ground potential caused by electromagnetic signals 22 and electromagnetic field 14 at the bottom of the Earth can induce a current I through the detection resistor 224 to be detected by current sensor 222. Amplifier 228 and / or signal conditioning unit 229 can perform proper signal processing and produce the electromagnetic signals 22 detected in computing system 30.

It should be noted, however, that although FIGURES 2A, 2B, and 2C illustrate particular modalities of the sensors

26, sensors 26 may include any suitable number and combination of components that can operate to detect portions of electromagnetic signals 22, such as various antennas or other detection elements. Suitable antennas may include, but are not limited to, a

IMPI

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Mexican institute of IA INDUSTRIAL PROPERTY parallel plate capacitor comprising two or more parallel conduction plates; a plate capacitor antenna comprising an electrode electrically coupled to the ground; a monopole antenna comprising a conducting element, a dipole antenna comprising two conducting elements; a multi-pole antenna comprising a plurality of conducting elements; a directional antenna comprising conducting elements arranged to increase a signal amplitude in a particular direction, and a coil antenna comprising one or more coils of wire, and / or any combination of protection antennas. In some embodiments, sensor 26 may represent a concentric electrical dipole (CED). The CED can include two electrodes in a concentric configuration. For example, the electrodes may be generally circular dipoles with an inner circular electrode arranged concentrically within an outer circular electrode. The electrodes can generally be aligned in a plane that is parallel to the plane of the earth's surface. The CED can then preferentially detect the vertical portion of the electromagnetic signals 22 that are substantially perpendicular to the plane of the CED. The vertical portion of the electromagnetic signals 22 can create a detectable potential difference between the two electrodes.

In some embodiments, sensor 26

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INDUSTRIAL T electromagnetic can comprise a pair of electrodes in contact with the earth and arranged inside the earth. For example, a first electrode can be arranged in a hole drilled in the ground that varies from about 3.04 meters (10 feet) to about 4.57 meters (15 feet). A second electrode can be arranged within about 0.30 meters (1 foot) to about 0.91 meters (3 feet) from the earth's surface, and the pair of electrodes can be electrically coupled. In some embodiments, the pair of electrodes can be disposed within the earth at various depths as needed to form an electrical coupling with the earth. In some embodiments, the electrodes may take the form of porous vessel electrodes or other electrodes, such as electrode 216. In some embodiments, the electrodes may comprise a conductive electrode in contact with the ground and electrically coupled to a porous vessel electrode. .

FIGURE 3 is a flow chart illustrating an exemplary method 700 for processing two or more geophysical survey data sources. Geophysical survey data sources include passive seismic and electronic prospecting 702, active seismic prospecting 704, microseismology 706, source-controlled electromagnetic prospecting 708, magnetotelluric prospecting 710, magnetic prospecting 714,

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INSTITUTO MEXICANO DT LA PROPIEDAD industrial

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induced 716 polarization, 718 ground penetrating radar, and various charting technologies including 720 charting (including SP and / or acoustic charting), aerial 722 prospecting, 724 electroseismic and seismoelectric prospecting, sludge charting, measurement during 728 drilling, 730 geophysical and / or geological models, 732 seismic and passive microelectric seismic prospecting, and 734 surface radioactivity profiling. in general, the computing system 30 may be able to process and / or cross-correlate two or more available sources of geophysical survey data in step 736. Processing of two or more available geophysical data sources may allow the computer system 30 to determine a more accurate and / or complete identification of various properties of the underground reservoir 16 that may otherwise be available by processing a single source of ground data. geophysical study. For example, the computing system 30 may be able to use particular study methods that have particular resistances to identify particular properties, and use these properties as a baseline for comparison and / or correlation with data from other study methods.

Passive electro-seismic prospecting 702 may include the electro-seismic and seismoelectric prospecting method discussed above with respect to the

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MEXICAN INSTITUTE OF INDUSTRIAL ΕΜΟΡΙΕΟΑΠ

FIGURE 1. As described in greater detail below, the passive study data detected, for example, by sensors 26 and / or 28, can be processed and / or correlated with computing system 30 to determine and / or confirm the properties of the 16 underground land deposit.

The active seismic survey 704 can include any form of seismic survey that uses an active source of seismic energy to determine one or more properties of the underground terrestrial reservoir 16. Active sources of seismic energy can include explosives, shock coils, and other man-made artificial forms of seismic energy. Active seismology typically produces information indicative of geological structures. Seismic prospecting techniques generally involve the use of an active seismic energy source and set of receivers propagated along or near the earth's surface to detect reflected seismic signals from underground geological boundaries, such as the boundary 18 illustrated in FIGURE 1. These signals are recorded as a function of time. The computer system 30 can subsequently process these signals to reconstruct a suitable image of the underground ground reservoir 16.

In active seismic prospecting 704, seismic energy can travel from the active source to Earth, reflected from a particular geological layer in a contrast of

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INSTITUTO MEXICANO 06 LA MOPÍEDAO industrial seismic impedance, and return to the receiver as a reflected seismic wave. The seismic energy can be the waves called

<td>cutting</td><td>(waves</td><td>S) o</td><td>the</td><td>waves called</td><td>of</td><td>compression</td>

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<td>differ</td><td colspan="2">with respect to</td><td>their</td><td>speeds, angles</td><td>of</td><td>reflection,</td>

vibration directions, and / or to some degree, the types of information that can be obtained from their respective types of seismic data. However, both types of waves undergo similar attenuation by underground reservoir. Underground terrestrial reservoirs 16 tend to attenuate relatively higher frequency components and allow relatively lower frequency components to pass through the earth with relatively little attenuation. For deeper reservoirs, the low-frequency content of the reflected seismic energy may represent information about the underlying underground 16 terrestrial reservoirs. Due to the low frequency of detected reflected seismic energy, however, the resolution of the reflected seismic energy may be insufficient to allow detection of relatively thin geological layers. Passive microseismology 706, or micro-seismic prospecting, can refer to any suitable study technology that detects microseismic energy to determine one or more properties of an underground terrestrial reservoir 16. Microseismology

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MEXICAN INSTITUTE OF INDUSTRIAL PROPERTY is generally based on small localized seismic events generated on land by naturally occurring land movements or well drilling operations. Microseismology then is a form of passive seismic prospecting because the seismic energy source is not specifically generated for prospecting purposes. Such seismic events can be generated and / or caused by tectonic forces, ocean tides and / or other natural phenomena. Seismic waves can also be created when drilling or conducting ground fracturing operations in hydrocarbon exploration, production, or in water well services. These natural and artificial events can be termed microseismic events. Generally, microseismic prospecting produces qualitative information about the location of underground structures or position information about drilling operations. In this study methodology, the location of the seismic source may be imperfectly known. Accordingly, microseismology can be useful for generating high-level information regarding the underground terrestrial reservoir 16, although it may also be less useful for generating high resolution images and / or data on the underground terrestrial reservoir 16. In some modalities, microseismology can locate the source of fracturing events such as those found in deposits of

MEXICAN IMPIINSTITUTO I heard THE INDUSTRIAL PROPERTY fracturing.

The Controlled Source Electromagnetic Survey (CSEM) 708 may include any suitable prospecting methodology that uses an electromagnetic source of energy and determines one or more properties of the underground land deposit 16. CSEM 708 is particularly useful for providing electrical resistivity information that indirectly indicates the presence of hydrocarbons. Using data from the CSEM survey 708 and the passive electroseismic / seismic survey 702, the computing system 30 may be able to determine fluid and structural property information associated with the underground terrestrial reservoir 16. Controlled source electromagnetic prospecting 708 involves the use of an electrical power source and a set of electromagnetic receivers. These electromagnetic receivers can be deployed at the bottom of the sea in deep water, although terrestrial applications are also possible. Although CSEM survey 708 can be conducted on land or in shallow water, recent work finds particularly useful applications in deep water. In prospecting

708 From CSEM, an energy source can excite an electrical current in the earth that passes through the various underground rock formations. The electric current follows a path of low electrical resistance through the

100

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more conductive rocky masses. Hydrocarbon tanks contain insulating gas or petroleum fluids. Consequently, the applied electric current tends to flow around the resistant reservoir structures. The deflection of the current around the deposits is detected as a change in the electromagnetic response in electromagnetic detectors. The measured signal properties can be processed by the computer system 30 to determine the presence of resistant structures that can indicate the presence of hydrocarbons.

In controlled source seismoelectric prospecting, generally a seismic source which can be dynamite or a seismic vibrator, creates a seismic wave that propagates into the subsoil where its seismic energy is partially converted into an electric field at a boundary between rock types or fluid interconnects. The electric field then propagates to the earth's surface where it is detected with electric and / or magnetic field sensors.

In controlled source electrosismic prospecting, a source of electrical energy is connected to electrodes in contact with the earth's surface. The voltage applied to the electrodes causes the electric current to flow underground. When that stream passes through a rocky boundary or fluid interconnect, a

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INSTITUTE ΜΕΧ ICA NO

From the industrial PROPERTY portion of the electrical energy can be converted into seismic energy. The resulting seismic energy can then propagate to the earth's surface where it is detected with seismic detectors that can be selected from geophones, accelerometers, or hydrophones.

Both seismoelectric and electro-seismic conversion amplitudes depend on the presence of hydrocarbon fluids so that methods that produce information on the fluid content of the rock that is used in the exploration and production of hydrocarbons. Both methods also produce high-resolution images of rock formations that are typical of seismic surveys. High-energy sources that can be used by CSEM prospecting 708 and by active seismic and electroseismic prospecting 722 are typically expensive. As a result, the costs of these active source study methods may tend to limit the commercial viability of the CSEM survey 708 and the active source seismoelectric and electro-seismic survey 722 in both environments.

The magnetotelluric prospecting 710 can include any suitable prospecting methodology that uses the earth's background electromagnetic fields to determine the Earth's underground electrical conductivity. Magnetotelluric prospecting 710 can use suitable electromagnetic sensors, such as sensors 26, to

IMPI

MEXICAN INSTITUTE

DE LA TROPIEDAU r

INDUSTRIAL field frequency

102

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detect the electromagnetic low portion of the earth's bottom. Based on the detected low frequency signals, the computing system 30 can estimate the underground electrical conductivity.

Magnetotelluric prospecting 710 may be useful in determining electrical conductivity, which may be indicative of the types of materials in the underground reservoir 16, but may be less useful in determining the detailed location or shape properties of the underground terrestrial reservoir 16. Detected natural electromagnetic fields using the 710 magnetotelluric survey generally originate from the earth's atmosphere. Electromagnetic fields of natural origin typically propagate underground, where they find rock formations of different electrical conductivity.

When electromagnetic fields make contact with a low conductivity reservoir, as is typical of hydrocarbon deposits, the electromagnetic field measured on the earth's surface changes. Spatially dependent electromagnetic fields measured at the earth's surface can be used to indicate the presence of low conductivity reservoirs that may contain hydrocarbons. The magnetotelluric prospecting 710 has several limitations when used alone. Only in low frequency electromagnetic stimulation, the length

103

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INSTITUTO MEXICANO DI LA INDUSTRIAL property long wave can reach prospecting deposits because high frequency electromagnetic fields are quickly attenuated by conductive earth. Long wavelength electromagnetic waves limit the spatial resolution of magnetotherapeutic energy which makes delineation of the deposit difficult. Additionally, magnetoteiuric prospecting only provides information on the electrical conductivity of the reservoir and does not produce data that reveals information on the porosity, permeability, or structure of the deposit.

Magnetic prospecting 712 can include any suitable prospecting methodology that uses magnetic field detection devices to measure the earth's magnetic field and determine one or more properties of the underground land deposit 16. Magnetic prospecting 712 may be particularly suitable for aircraft prospecting. Magnetic prospecting 712 can be based on the fact that hydrocarbon deposits and mineral deposits, such as an iron mine, can alter the magnetic field of the local earth. Accordingly, the computing system 30 can process data received from the magnetic field detection devices in combination with the passive electro-seismic and seismic survey 702 to determine the presence of deposit structure and / or the presence of hydrocarbons and other minerals. Magnetic prospecting 712

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INDUSTRIAL can have several limitations when used alone. Magnetic prospecting 712 may be less useful for determining and / or measuring properties related to the spatial extent of the deposit and the structure of the underground terrestrial reservoir 16. Magnetic prospecting 712 may also not be able to identify particular fluids and / or minerals or fluid flow properties.

Gravity survey 714 can include any of the appropriate survey methodologies that use gravity detectors to determine one or more properties of the underground land deposit 16. Deposits such as the underground land deposit 16 typically have a smaller mass density than non-producing rock. A gravity meter of sufficient sensitivity may be able to detect the difference in mass density of the underground terrestrial reservoir 16 compared to the surrounding reservoirs. The computer system 30 can determine the presence of the underground ground reservoir 16 based on the receipt of data from a gravity meter indicating a minimum of local gravity acceleration on the underground ground reservoir 16.

The 714 gravity survey can have several limitations when used alone. For example, local gravity values ​​reflect an average of the mass densities of all materials at the periphery of the

105

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gravity. Therefore, although low-density deposits reduce measured gravity acceleration, the presence of high-density rock can increase measured gravity acceleration. In this way, the presence of high-density rock can reduce the spatial resolution of the measurement and therefore obscure the presence of a low-density reservoir. In addition, the spatial resolution of gravity measurements can generally be limited to length scales comparable to the depth and lateral grade of the deposit. The amplitude to identify the gravity signature depends on the volume of the tank. Gravity survey 714 may also be less useful in determining properties such as reservoir structure, pore fluid properties, or permeability. 712 and / or 714 gravity and magnetic prospecting can be particularly useful for studying large areas, such as all geological basins.

The induced polarization survey 716 can include any suitable methodology for using an induced potential field on Earth to determine one or more properties of the underground terrestrial reservoir 16. Measuring the induced potential field can allow the computing system 30 to determine the carrying capacity and resistivity of the underground terrestrial reservoir 16. One or more transmission electrodes can be used to drive and / or induce current in the ground, which can induce a potential field.

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MEXICAN INSTITUTE OF PROPERTY

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INDUSTRIAL

One or more sensors, such as potentiometers, can measure the induced potential field. There are several techniques for IP 716 prospecting, including time domain based IP prospecting and frequency domain based IP prospecting, in time domain based prospecting, transmission electrodes can drive a load on the

Earth for a specific amount of time. The sensors measure the potential field during the on and off period of the transmission electrodes. Based on the peak voltage measurements at time, the apparent resistivity of the underground terrestrial reservoir 16 can be calculated by the computer system 30. Based on the measurements of the transient voltage drop during the disconnection time of the transmission electrodes, the computing system 30 can calculate the load capacity.

The ground penetrating radar survey 718 can include any suitable survey methodology that uses ground penetrating radio waves to determine one or more properties of the underground ground reservoir 16. Radio waves can be electromagnetic waves in the microwave band of the radio spectrum. Transmitters can generate high-frequency radio waves and transmit radio waves on Earth.

Suitable antennas or detection elements can detect a reflected return signal from the terrestrial deposit 16

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Underground. When the generated radio wave hits an object or boundary, such as boundary 18 with different dielectric constants, the receiving antenna receives variations in the reflected return signal. Those variations can be processed by the computer system 30 to identify structural characteristics of the subsoil. The depth of penetration of the GPR survey 718 can generally be limited by the electrical conductivity of the ground under the transmit signal. As conductivity decreases, the signal depth may increase. Accordingly, the GPR 718 survey can be particularly useful for low conductivity land types, such as ice, dry sandy soils, granite, lime, and concrete, in high conductivity land types, the 718 GPR survey can only penetrate a few meters. Even in low conductivity materials, prospecting

718 With GPR it can be particularly useful for identifying features that are only up to several hundred meters deep. Accordingly, the GPR survey 718 can be used by the computer system 30 to identify properties of the immediate subsoil reservoir 24, such as objects, changes in materials, cavities, cracks, and the presence and amount of groundwater and other fluids. GPR prospecting 718 can also be helpful in identifying and / or tracking contaminants and impurities.

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The 720 scan may include any suitable scanning technique, including acoustic and / or spontaneous potential. The 720 scan may include passive imaging techniques such as spontaneous potential (SP) imaging to measure the resistivity and / or conductivity of the surrounding reservoir. In particular, SP Plot 720 can include any suitable prospecting methodology that uses passive measurements to determine electrical potentials between various depths in a borehole. SP Imaging 720 is a technique that can generally be used by well-imaging systems during drilling operations. One or more sensors, such as potentiometers, can measure electrical potentials between depths in a probe and a voltage to ground at the surface. Changes in electrical potential can be caused by a build-up of charge on the borehole walls. The probe may include conductive fluids to facilitate an SP response. SPs can occur when two aqueous solutions having different ionic concentrations are brought into contact through a porous, semipermeable membrane. Ions tend to migrate from high to low ionic concentrations. In the case of the SP 720 plot, two or more aqueous solutions may be the conductive fluid in the borehole, such as drilling mud, and the water in an onshore reservoir 16

109 Mexican institute.

SAY THE PROPERTY · -, -. · '.

INDUSTRIAL &lt;aj

IMPI underground. If the conductive fluid contains more or fewer ions than reservoir water it can cause the SP to drift in the opposite way to a permeable underground terrestrial reservoir 16. SP measurements can be used by the computer system 30 to detect the presence of hydrocarbons, which can reduce the response on an SP plot due to reduced contact between the conductive fluid in the borehole and contact with reservoir water. SP Plot 720 can be used to determine locations and / or depths of the pervious underground land deposit 16. The boundaries of the underground land deposit 16, the resistivity of the reservoir water, and other properties. SP measurements can be used in computing the computing system 30 to determine the location of potential gradients where electrosismic and / or seismoelectric conversions are likely to occur. The computer system 30 can then determine the depths where signals 20 and / or signals 22 correlate with the amplitudes of SP. Diagram 720 may additionally or alternatively include active source diagrams. For example, active source imaging can use an active source such as a nuclear source and an associated sensor. An exemplary nuclear source can include thorium or other gamma-emitting materials.

Other 720 logging methods may include

110

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IMPI INNRruro Mexicana de la RMORIEE'AD INDUSTRIAL conductivity chart, acoustic chart, dielectric constant chart, gamma ray chart, reservoir tester chart, micro-resistivity or imaging chart, density, neutron porosity, sonic, calibrator, and nuclear magnetic resonance imaging. Generally, the computing system 30 can use logging data individually and / or correlatively to determine underground rock and fluid properties. In combination with passive seismic and electro-seismic detection 702, the single-scan plot data, or in combination with multiple or many 720 plots, computer 30 can determine the structural and fluid properties of underground reservoirs, particularly those containing hydrocarbons.

Aerial survey 722 can include any suitable survey methodology that uses airplanes, helicopters, or lighter than air means to implement geophysical survey detectors. Detectors may include, but are not limited to, gravity, electric field, magnetic field, electromagnetic field, video, infrared, ultraviolet, and other sensors in the electromagnetic spectrum. Aerial 722 surveys can generally cover large areas of the Earth's surface. Consequently, particular aerial survey methods 722 can achieve only lll resolution.

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MEXICAN INSTITUTE M INDUSTRIAL PROPERTY

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lower spatial compared to other study methods.

Such studies are generally not used for detailed analysis of deposit properties but can guide locations where high resolution studies such as seismology and electrosismology may be useful. Accordingly, another study, such as a passive electro-seismic / seismic study 702, may be initiated in response to information on the underground reservoir 16 obtained from the aerial survey 722.

The 726 sludge plot can include any suitable methodology to detect the properties of drilling sediments created during drilling a hole during hydrocarbon exploration or other purposes. Sludge 726 plots can determine the type of rock penetrated by the drill bit, the presence of hydrocarbons or water in the sediments, radio activity that is an indicator of hydrocarbons or shales, and the microscopic rock properties related to porosity and permeability.

Measurement during 728 drilling can include any suitable methodology for detecting underground properties near the drill bit and / or changes in underground reservoirs caused by drilling operations such as fracturing and fluid flow. These properties may include but are not limited to

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acoustic properties, electrical properties, fracture properties, location of the drill bit, reservoir pressure, porosity, and permeability.

Geological and geophysical 730 models can include information generated by studying geological history, present day settings, analogies to nearby sites, and measurement experience at many geological sites. Such models can offer guidance to reduce the risk of finding and developing underground resources.

The passive microselectric and microelectroseismic survey 732 can include any suitable methodology to detect electromagnetic and / or seismic emanations from seismic and / or electromagnetic sources of natural and / or passive artificial energy below the Earth's surface. Microseismology 706 can detect seismic events originating at a depth as discussed above, while microelectric and passive microelectrosismic survey 732 can take advantage of the combined use of the electromagnetic field and seismic energy generated by underground events. For example, earthquakes, wave movements, and tectonic forces generate electromagnetic and seismic energy sources. Such events are known to generate seismic and electromagnetic energy. These events can also generate signals

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INSTITUTO MEXICANA DE LA MONEDAD INDUSTRIAL electromagnetic and secondary seismic caused by electro-seismic and seismoelectric conversions. Microseismic events created during well drilling operations, reservoir fracturing, fluid production, and fluid migration are of particular importance in hydrocarbon production and exploration, and in aquifer development. Reservoir fracturing and subsoil fluid flow are known to create seismic events that are used to locate the drill bit, analyze fracture development, and detect fluid migration. Microseismic monitoring 706 may be limited by an uncertain location of the source signal and by uncertainty in the seismic properties of the subsoil, particularly the speed of seismic waves in the subsoil. Microelectroseismology and microselectric 732 methods can overcome these limitations on microseismology.

In one embodiment, drill bit noise and fracture events generated during drilling and / or hydraulic fracturing can generate seismic waves and electromagnetic energy that propagates to the earth's surface and / or to the location of the wells. Electromagnetic propagation is known to travel at a speed that is much greater than the seismic wave. Detecting the arrival of the EM wave before the seismic wave can then allow

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MEXICAN INSTITUTE OF INDUSTRIAL PROPERTY

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seismic travel time analysis and can allow a more precise determination of the depth at the origin of the seismic signal. The detection of such electromagnetic and seismic energies can be carried out on the surface of the earth, in shallow holes or in wells. Detection means can be seismic detectors such as geophones, well hydrophones, accelerometers, digital accelerometers as well as antennas designed to detect electromagnetic energy.

In another embodiment, the seismic and / or electromagnetic waves generated by drilling and / or fracturing activities can also generate secondary electromagnetic and seismic energies through electro-seismic and / or seismoelectric conversions. Detecting these secondary EM and seismic fields can advantageously improve the analysis of the location of the underground structures 16 as well as the location and probable identity of the porous fluids. The computer system 30 can process microelectroseismic and microselectric data concurrently or in sequence with the passive electroseismic and seismoelectric data to locate the microseismic events within structure 16 of greatest interest.

In another embodiment, seismic and / or electromagnetic waves generated by drilling and / or fracturing activities can also generate electromagnetic energy

<img file="MX342155B_D0102.tif" />

115

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and secondary seismic through conversions

- ·· ——— —__ electro-seismic and / or seismoelectric that propagate to additional geological structures at greater depth or at distances away from the origin of the signal. For example, a seismic wave created by drilling and / or fracturing activity can propagate to a greater depth where seismic reflection and / or seismic conversion occurs. The secondary event then generated can spread to the surface or to a well location where it can be detected. The secondary wave field can then be useful in creating an image of the deep structure.

Alternatively or in addition, the secondary conversion event may occur at a location distant from the source event at a depth similar to the source depth or slightly shallower than the source event. Such secondary conversions can advantageously generate signals useful for identifying additional structures 15 and / or can, after signal processing in computer 30, identify fluids such as hydrocarbon fluids.

The surface radioactivity profile 734 can include any suitable surface radioactivity profile technique, such as surface gamma ray prospecting. For example, certain underground underground sites 16 may show a chimney effect in which

116

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MEXICAN INSTITUTE DL LA MONEDAD INDUSTRIAL

<img file="MX342155B_D0104.tif" />

fluids or minerals can seep to the surface. This leak can cause radioactive changes in the surface that can be detected through the use of the profile

734 of surface radioactivity.

The computer system 30, at step 736, can process the survey data from two or more geological survey data sources, including two or more passive electroseismic survey 702, active seismic survey 704, microseismology 706, electromagnetic survey 708 controlled source, magnetotelluric survey 710, magnetic survey 712, gravity survey 714, induced polarization 716, ground penetration radar 718,

<td>720 slide,</td><td>studios 722</td><td>aerial,</td><td>prospecting</td><td> 724</td>

<td>electrosismic and</td><td>seismoelectric</td><td>active,</td><td>Diagram 726</td><td>by</td>

<td>sludge measurement</td><td colspan="2">during drilling</td><td>728, modeling</td><td> 730</td>

geological, passive 732 microselectric and microelectroseismic prospecting, and 734 surface radioactivity profile. For example, by using passive electrosismic prospecting 702 data in conjunction with data from various other study methods, disadvantages and limitations of the other study methods can be reduced and / or eliminated.

In some modalities, more information about the underground reservoir area can be obtained by conducting one or more additional studies before, after, or during any of the 702 prospecting techniques.

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MEXICAN INSTITUTE 'tÍL — C-1 &lt;Λ DE LA RROPIEDAD J

INDUSTRIAL passive electro-seismic described herein to be carried out. For example, an active seismological study 704, a microseismic study 706, CSEM study 708, a gravity study 714, magnetic study 712, IP study 716, and / or GPR study 718 may be conducted based on an indication of a fluid present in the underground site of interest. Alternatively or additionally, passive electrosismic prospecting 702 may be performed based on data from any of the study methods described herein that are processed by the computer system 30 to identify a property of the underground ground reservoir 16 of interest for exploration and / or or additional prospecting. Passive electroseismic prospecting 702 in this manner can be used as a precursor to additional prospecting methodologies to provide initial analysis · to identify regions of interest for further prospecting. Additionally or alternatively, passive prospecting 702 can be used after those methodologies are employed to obtain more detailed information about a region of interest studied using another technique. In some embodiments, passive electrosismic prospecting 702 can be used during the same prospecting operation in conjunction with other study methods. Passive electro-seismic prospecting 702 can be used at the same time and / or during intervals in which other study methods do not

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INDUSTRIAL are used. For example, passive electro-seismic prospecting 702 may be able to detect signals 20 and / or 22 during periods in which a response signal generated by an active source of seismic energy is reduced and / or attenuated during an active seismic prospecting operation 704 . Alternatively or in addition, the computing system 30 may be able to filter active seismic energy resources and detect signals 20 and / or 22 during active seismic survey 702 operations. The additional passive electrostatic study 702 can provide more data on a larger number of sensors and / or detectors to obtain more quality information on the underground land deposit 16 than other study methods. In this way, method 700 can be used by computing system 30 as described herein in combination with other prospecting techniques to provide information on an underground land deposit 16. Particular modalities and correlation techniques for combinations of various study methodologies are discussed below with respect to FIGURES 4-7. In some embodiments, passive electro-seismic survey 702 can be used alone or in conjunction with other study methods to determine a location at which to drill and / or start one or more soundings in the underground terrestrial deposit 16. For example, the computing system 30, as described above, can detect an envelope

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ue LA RROFJFDAD ÍV '· J ¡' - 'J INDUSTRIAL using 702 passive electro-seismic prospecting that indicates the presence of one or more hydrocarbons in the underground land deposit 16, based on the envelope, the computer system can determine a drilling operation it can or should be carried out in a particular location with respect to the underground land deposit 16. Additionally or alternatively, passive electro-seismic prospecting 702 may be used alone or in conjunction with other study methods to determine locations at which to begin any other suitable mining operation to recover the particular type of ore, which may also be based on depth, characteristics of geological surface, and / or surrounding deposits in the subsoil.

FIGURE 4 is a perspective diagram illustrating an exemplary prospecting system 400 utilizing passive electro-seismic and seismic prospecting techniques 702 and active seismic prospecting techniques 704, which are explained above, may include electro-seismic and seismoelectric prospecting techniques. active. As illustrated, system 400 includes electromagnetic sensors 26, seismic sensors 28, computing system 30 which has been described above with respect to FIGURE 1 and can operate in a similar manner as described above with respect to system 10. In addition, system 400 may include one or more active seismic generators 42 and sensors

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<img file="MX342155B_D0106.tif" />

they may be able to additionally and / or alternatively detect a seismic response generated by the active seismic sensor. In addition, one or more active sources of electromagnetic energy may be located at the periphery of a prospecting operation. Accordingly, electromagnetic sensors 26 and / or sensors 28 may be capable of detecting one or more signals 20, 22, as discussed above, and may additionally or alternatively be capable of detecting one or more electromagnetic signals generated in response to the electromagnetic source as a result of an electro-seismic or seismoelectric conversion in underground ground 16. In general, system 400 may be capable of using any one or more of the passive seismic and electroseismic prospecting techniques 702 and / or the active seismic prospecting techniques 704 described above. In addition, the computing system 30 may be able to correlate data from passive electrosismic prospecting 702 with data detected by prospecting method 704.

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artificial or other electromagnetic energy that can be detected by electromagnetic sensors 36 and / or seismic sensors 28. The electromagnetic source may include a source

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<img file="MX342155B_D0107.tif" />

electromagnetic energy capable of generating an electromagnetic response signal 20 or seismic signal 22 in a similar manner as discussed above with respect to the passive electromagnetic source 12.

The active seismic source 42 can represent any suitable active source of seismic energy 44 including shock coils, dynamite, vibrators, or other sources of artificial seismic energy. Seismic sensors 28 can be configured to detect active response signals generated by active seismic source 42. In some embodiments, seismic sensors 28 may be able to detect both response signals from active seismic source 42 and signals 20. Alternatively, particular seismic sensors 28 can be configured to detect one type of signal or the other.

In operation, the computer system 30 may be able to use the active seismic sources 42 and seismic sensors to perform active seismic prospecting 704.

In addition, the computing system 30 can use sensors 26 and / or sensors 28 to conduct passive seismic and electroselectric prospecting 702. The computer system 30 may be able to use these techniques in any suitable way.

For example, the computer system 30 may primarily use active seismic survey 704 to detect seismic data that may reveal structure, depth, and

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IMPI

MEXICAN INSTITUTE OE LA PROWEOAO INDUSTRIAL location of the underground site 16. During the periods in which the response signals generated by the active source are reduced and / or attenuated, the computer system 30 can receive signals 20 and / or 22 detected by sensors 26 and / or 28. For example, system 30 It can use sensors 26 and / or 28 between the seismic events generated by the active seismic source 42.

Additionally or alternatively, the computing system may be capable of detecting signals 20 and 22 at substantially the same time or at overlapping times during which the active source 42 generates seismic signals 44. In such embodiments, the computing system 30 may include suitable filters to remove the signals generated by the active seismic source 42 using any suitable technique including predictive filtering in a similar manner as discussed above. In such modalities, the passive seismic or electronic data may treat the signals generated by the seismic source 42 as noise.

Accordingly, these signals can be filtered from this data while a separate processing task can actively process the response signals generated as a result of the signals 44 from the active source 42 to determine the various properties of the underground land reservoir 16 based on these active seismic signals.

123

The computer system 30 can

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»RnvntUAU LY * .T» '· * J industrial be able to correlate data received as a result of passive electro-seismic or seismic survey 702 and / or data received as a result of seismic survey 704. For example, the seismic data may be analyzed by the computer system 30 to determine a depth of a specific boundary 18 or other characteristic of the underground reservoir 18. Once such characteristics are identified, these characteristics can be used as a baseline in the analysis of the passive study data. Depth information from active seismic survey, in some modalities, is used as a depth assumption when you use passive seismic survey. For example, depth information obtained as a result of seismic survey 704 can be used in the frequency depth function discussed above with respect to FIGURE 1 to determine a reference line depth from which other depths and / or other characteristics of the underground reservoir 16 using the passive prospecting technique 702 can be determined.

Alternatively or additionally, the data from both study techniques can be formatted and / or integrated into a single data set and the combined data can be analyzed to identify the properties of the underground reservoir 16.

As a result of using various techniques of

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OF THE PROPERTY YVu'i'J--. INDUSTRIAL prospecting, additional information can be obtained from

702 Passive electroseismic underground terrestrial prospecting to subsoil 16 which may otherwise be available using active 704 seismic prospecting alone. For example, seismological technique 702 can provide structural information regarding reservoir 16 while it can provide structural and electrical properties related to the presence of hydrocarbons. The data from both techniques may be able to confirm the presence of hydrocarbons or other minerals.

In addition, the combination of the two study techniques may provide the ability to easily identify more stratigraphic traps, meandering currents, and another irregular underground land deposit 16 that may contain hydrocarbons or other minerals of interest.

FIGURE 5 is a perspective drawing illustrating an exemplary prospecting system 500 utilizing passive seismic and electroseismic prospecting techniques 702 and magnetotelluric prospecting 710. As illustrated, system 500 includes electromagnetic sensors 26, seismic sensors 28, computing system 30, which are described above with respect to FIGURE 1 and can operate in a manner similar to that described above with respect to system 10. As illustrated, system 500 may also include electromagnetic sensors 64 that may be capable

125

IMPI

MEXICAN INSTITUTE

DF ΙΑ ΡΒΠΡΙΕΠΑη V *³. ^. ““ Tl: '· item 3

OF PROPERTY 9

INDUSTRIAL detecting magnetotelluric signals, which are described operates above with respect to FIGURE 3. Although not illustrated, in some embodiments, system 600 may also include a controlled source of electromagnetic radiation that can be generated by vehicle 50 and / or generated by various electrodes that can be arranged at the bottom of the ocean or in another suitable place. System 500 may additionally or alternatively include components suitable for performing IP survey 716.

The electromagnetic sensor 64 may be able to detect the magnetotelluric signal 62. The electromagnetic sensor 64 can be similar to any of the sensor modalities 26 discussed above and discuss how to detect the signal for electromagnetic. The sensor 64 can be configured for field detection are useful for detecting electromagnetic horizontal components of the ground that processing by the computing system 30 in the prospecting 710 magnetotelluric.

In operation, system 500 can utilize magnetotelluric prospecting 710, passive seismic and electroseismic prospecting 702 and / or CSEM 708 in order to determine the properties of the underground ground reservoir 16. Additionally or alternatively, various correlation techniques can be used to correlate the data

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IMPIS

MEXICAN INSTITUTE *.

OF INDUSTRIAL PROPERTY among the different study methods. For example, the magnetotelluric prospecting 710 can be used by the computer system 30 to confirm electrical conductivity, which may be indicative of the types of materials in the underground reservoir 16. Passive electrosismic prospecting 702 can provide well-proven geometry. The data from both techniques may be able to confirm the presence of hydrocarbons or other minerals.

In addition, the combination of the two study techniques may provide the ability to more easily identify stratigraphic traps, meandering currents, and another underground land deposit 16 which may contain hydrocarbons or other minerals of interest.

FIGURE 6 is a perspective drawing illustrating an exemplary prospecting system 600 using passive seismic and electro-seismic prospecting techniques 702 and CSEM 708. As illustrated, system 600 includes a vehicle 50 that may be capable of operating in water, including deep water operations. Vehicle 50 may be able to tow or pull electrodes 52, sensors 26, and / or sensors 64. The sensors 26 may be able to detect electromagnetic signals generated by the underground reservoir 16, which may be located some distance below the bottom of the body of water. Sensors 64 may be capable of detecting magnetotelluric signals 62. In some

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MEXICAN INSTITUTE DF. THE PROPERTY

INDUSTRIAL modalities, the sensors 26 may additionally or alternatively be arranged at the bottom of the sea and / or at the bottom of a body of water. Electromagnetic sensors 64 and / or sensors may be able to transmit information wirelessly to system 30, which can be located in vehicle 50. Additionally or alternatively, sensors 64 and / or sensors 26 can store information locally and / or can recovered by vehicle 50. Electrodes 52 can be used to generate a high current signal that can be transmitted to Earth through the body of water. The computer system 30 can be housed in the vehicle 50 or other structure capable of containing the power transformers and other power generation equipment capable of generating the adequate amount of current required to penetrate the

Earth using electrodes 52.

Electrodes 52 can include positive 52Ά electrode and negative 52B electrode. Electrodes 52 can be of any suitable length and are arranged in any suitable shape with respect to Earth capable of generating a current source that can penetrate Earth. For example, a current can be induced to flow to Earth from negative 52B electrode and back from Earth to positive 52A electrode. The stream can be modulated by underground reservoir 16. Accordingly, sensors 26 may be able to detect modulation caused by the

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IMPI

MEXICAN INSTITUTE (A

OF THE VUjÍ PROPERTY and

INDUSTRIAL __ underground reservoir 16 within the signals returned to electrode 52A.

In operation, the computer system 30 may be able to use electrodes 52 to perform the survey

708 CSEM. In addition, the computing system 30 can use sensors 26 and / or sensors 28 to perform passive electro-seismic and seismic prospecting 702. The computer system 30 may be able to use these techniques in any suitable way. For example, the computing system 30 may primarily use CSEM Survey 708 to detect electromagnetic survey data.

During the periods in which the response signals from the electrodes 52 are reduced and / or attenuated, the computing system 30 can receive signals 20 and / or 22 detected by the sensors 26 and / or 28. For example, the system 30 It can use sensors 26 and / or 28 between the times in which the currents are generated by electrodes 52.

The computer system 30 may be able to correlate and process the study data received as a result of CSEM techniques 708 and passive seismic and electroselectric prospecting 702. In some embodiments, the computing system 30 may additionally be able to correlate and process data received as a result of prospecting 710 magnetotelluric. Therefore, by using multiple prospecting techniques, it can be obtained

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Additional information about the '16 subsoil than would otherwise be available using CSEM 708 techniques or 710 magnetotelluric prospecting only. For example, the CSEM survey 708 can be used by the computing system 30 to confirm high electrical resistivity which can be used to indicate the presence of the underground land deposit 16. Passive electro-seismic prospecting 702 can provide well-proven geometry. The data from both techniques may be able to confirm the presence of hydrocarbons or other minerals. In addition, the combination of the two study techniques may provide the ability to more easily identify stratigraphic traps, meandering currents, and another underground land deposit 16 which may contain hydrocarbons or other minerals of interest.

FIGURE 7 is a perspective drawing illustrating an exemplary prospecting system 700 using passive seismic and electroseismic prospecting techniques 702 and SP logging techniques 720. As illustrated, system 700 includes sensors 26 and 28, logging facility 50, and potentiometer 72 which can be arranged in a borehole drilling operation 70.

The logging facility 50 may include the computer system 30 and other suitable equipment for mapping the drilling operation 70, including the

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IMPI

MEXICAN INSTITUTE or THE INDUSTRIAL PROPERTY capacity to process the signals received from the

72. Study data received as result 15? SP imaging when detecting potentiometer 72 can be correlated with passive study data received by sensors 26 and / or 28. For example, the SP log data can provide very reliable depth and / or resistivity information for the underground terrestrial reservoir 16 that can be used as a reference line to process the signals received from sensors 26 and / or 28 in accordance with 702 passive study methods. The data from both techniques may be able to confirm the presence of hydrocarbons or other minerals. In addition, the combination of the two study techniques may provide the ability to more easily identify stratigraphic traps, meandering currents, and another underground land deposit 16 which may contain hydrocarbons or other minerals of interest.

FIGURE 8 is a flowchart illustrating an exemplary method 800 for correlating data received from various geophysical survey methods. Method 800 begins at step 802 where the first signals from the first sensor elements are received. For example, signals 20 and / or 22 can be detected by sensors 26 and / or 28 and transmitted to computing system 30. In step 804, the computing system 30 can process the signals according

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IMPI 'ΝΓΓΙΤυΤΟ MEXICANO DE LA FROFIEDAD INDUSTRIAL with the 700 passive study method that uses any of the techniques discussed above. In step 806, the computing system 30 can receive additional signals from second sensor elements. For example, the computing system 30 may receive signals generated as a result of any of the aforementioned study techniques including one or more of the study methods described above with respect to FIGURE 3.

In step 808, the computing system 30 can process those signals according to the particular study method associated with those signals. In step 810, the computing system 30 can determine if additional data from the study method is available and can then use those additional methods to receive the additional signals from other sensor elements in the step

806 after those signals can be processed at the stage

808. Accordingly, the computing system 30 may be able to proactively use the available study methods when configured to use those methods. For example, during an active study operation 704, the computing system 30 may be configured to automatically initiate the signals received from the sensors 26 and / or 28 during periods when the active study signals from the active source 42 are attenuated and / or are insignificant, as discussed above.

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132

INDUSTRIAL

At step 812, the computing system 30 may be able to correlate any of the received signals according to any of the above study methods, including any of the correlation techniques mentioned in the above discussed with respect to the

FIGURES 1-7. In step 814, various subsoil properties can be determined based on the individual study methods alone and / or based on the correlation of the received signals performed in step 812. After step 814 is performed, the computing system 30 it can perform any other suitable computing tasks, such as generating and / or updating the three-dimensional, four-dimensional, or two-dimensional models of the underground ground reservoir 16. For example, the computer system 30 may gradually move over time in order to take large amounts of data, samples, or particular areas that may be very large compared to the extent of the area that is capable of being examined by an arrangement. sensors in any location.

FIGURE 9 illustrates an exemplary computing system 30 suitable for implementing one or more modalities described herein. The computer system 30 includes a processor 982 (which may be referred to as a central processor unit or CPU) that is in communication with the memory devices including storage 984

IMPIOS

133

Secondary MEXICAN INDUSTRIAL COMPANY WTTTUTO, 986 read-only memory (ROM), 988 random access memory (RAM), 990 input / output (I / O) devices, and 992 network connectivity devices. The processor can be implemented as one or more CPU chips.

It is understood that by programming and / or loading executable instructions in the computer system 30, at least one of the CPU 982, RAM 988, and ROM 986 is changed, transforming the computer system 30, in part, into a machine or apparatus particular having the novel functionality taught by the present description. It is critical to the arts of electrical engineering and software engineering that the functionality that can be implemented by loading executable software onto a computer can be converted to a hardware implementation by known design rules. The decisions between implementing a concept in software versus hardware typically revolve around considerations of design stability and the number of units to be produced rather than the problems involved in the transition from the software domain to the hardware domain. Generally, a design that is still subject to frequent changes may be preferred to be implemented in software, because reusing a hardware implementation is more expensive than reusing a software design. Generally, it may be preferred that a design that is stable and will be produced in high volume be implemented in

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IMPI 'NSTITUTO MEXICANO DELA PROPIEDAD INDUSTRIAL hardware, for example, in a specific application integrated circuit (ASIC), because large production batches of the hardware implementation may be less expensive than the software implementation. Often, a design can be developed and tested in software form, and then transformed, by well-known design rules, into an equivalent hardware implementation on an application-specific integrated circuit that implements the software instructions. In the same way that a machine controlled by a new ASIC is a particular machine or device, likewise, a computer that has been programmed and / or loaded with executable instructions can be seen as a particular machine or device.

Secondary storage 984 typically consists of one or more disk drives or tape drives and is used for non-volatile data storage and as an overflow data storage device if the

RAM 988 is not large enough to hold all the job data. Secondary storage 984 can be used to store programs that are loaded into RAM 988 when such programs are selected for execution. ROM 986 is used to store instructions and perhaps data that is read during program execution. ROM

6 it is a non-volatile memory device that normally has a small memory capacity in relation to the largest

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MEXICAN INSTITUTE OF INDUSTRIAL IROHIBAD

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984 secondary storage memory capacity. RAM 988 is used to store volatile data and perhaps to store instructions. Access to both 986 ROM and 988 RAM is typically faster than secondary 984 storage. Secondary storage 984, RAM 988, and / or ROM 986 may in some contexts be referred to as computer readable storage medium and / or non-transient computer readable media.

990 I / O devices can include printers, video monitors, liquid crystal displays (LCDs), touch screens, keyboards, alphanumeric keyboards, switches, dial disks, mice, trackballs, voice recognizers, card readers , paper tape readers, or other well-known input devices.

922 network connectivity devices can take the form of modems, modem banks, memory cards

Ethernet, Universal Serial Bus (USB) Interface Cards, Serial Interfaces, Ring Network Cards, Fiber Distributed Data Interface Cards (FDDI), Wireless Local Area Network (WLAN) Cards, Transceiver Cards radio such as code division multiple access (CDMA), global system for mobile communication (GSM), long-term evolution (LTE), global interoperability for microwave access (WiMAX), and / or other cards

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'ΝΪΤΐΤυΤσ MEXICAN M THE FROPIEÜAD of radio transceiver ínéerfá protocol ^ T ^ T other well-known network devices. These y97 network connectivity devices can allow the 982 processor to communicate with the Internet or one or more intranets. With such a network connection, it is contemplated that processor 982 may receive information from the network, or may produce information on the network in the course of performing the steps of the method described above. Such information, which is often represented as a sequence of instructions that is executed using processor 982, can be received from and produced on the network, for example, in the form of a computer data signal embedded in a carrier wave.

Such information, which may include data or instructions to be executed using the 982 processor for example, may be received from and produced over the network, for example, in the form of a computer database band signal or signal embedded in a wave. carrier. The baseband signal or signal embedded in the carrier wave generated by network connectivity devices 992 can propagate on or over the surface of electrical conductors, in coaxial cables, in waveguides, in an optical conduit, for example a fiber optic, or in the air or free space. The information contained in the band signal or the signal incorporated in the carrier wave can be arranged according to different sequences, according to

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you want to either process or generate the information or transmit or receive the information. The 'bas'e' band signal or the signal incorporated in the carrier wave, or other types of signals currently used or developed in the future, can be generated according to various methods well known to one skilled in the art. The baseband signal and / or the signal embedded in the carrier wave may in some contexts be referred to as a transient signal.

The 982 processor executes instructions, codes, computer programs, scripts that are accessed from the hard disk, floppy disk, optical disk (these various disk-based systems can be considered as secondary storage 984), ROM 986, RAM 988, or 992 network connectivity devices. Although only one 982 processor is shown, multiple processors may be present. Thus, although the instructions may be discussed as being executed by one processor, the instructions may be executed simultaneously, serially, or otherwise executed by one or more processors. Instructions, codes, computer programs, scripts, and / or data that can be accessed from secondary 984 storage, for example, hard drives, floppy disks, optical disks, and / or other devices, ROM 986, and / or RAM 988 may be referred to in some contexts as non-transient instructions and / or non-transient information.

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MEXICAN INSTITUTE OF INDUSTRIAL PROPERTY

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In some embodiments, the computer system 30 may comprise two or more computers in communication with each other, collaborating to perform a task. For example, but not by way of limitation, an application may be divided in such a way as to allow simultaneous and / or parallel processing of the application's instructions.

Alternatively, the data processed by the application can be divided in such a way as to allow simultaneous and / or parallel processing of different

10 'portions of a data set by two or more computers.

In some embodiments, display software may be employed by the computer system 30 to provide the functionality of a number of servers that are not directly linked to the number of computers in the computer system 30. For example, visualization software can provide twenty virtual servers on four physical computers. In some embodiments, the functionality described above may be provided by running the application and / or applications in a cloud computing environment. Cloud computing can comprise providing computing service delivery over a network connection using dynamically scalable computing resources. Cloud computing can be supported, at least in part, by virtualization software. A cloud computing environment can be established by a company

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MEXICAN INSTITUTE \

OF THE PROPERTY ^F *

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and / or can be contracted on an as needed basis from a third party provider. Some cloud computing environments may include cloud computing resources owned and operated by the company, as well as cloud computing resources contracted and / or leased from a third-party provider.

In some embodiments, some or all of the functionality described above may be provided as a computer program product. The computer program product may comprise one or more computer readable storage media that has programming code that can be used by a computer represented therein for. implement the functionality described above. The computer program product may comprise data structures, executable instructions, and other computer-usable programming code. The software product may be represented on removable computer storage media and / or non-removable computer storage media. The removable computer-readable storage medium may comprise, without limitation, a paper tape, a magnetic tape, magnetic disk, an optical disc, a solid-state memory chip, for example, analog magnetic tape, memory-only discs. read-disk

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IMPI

Mexican INSTITUTE Dí LA PROPIEDAD INDUSTRIAL compact (CD-ROM), floppy disks, drives i

miniature storage, digital cards, multimedia cards, among others. The computer program product may be suitable to load, by the computer system 30, at least portions of the content of the computer program product for secondary storage 984 into the ROM

986, in RAM 988, and / or in other non-volatile memory and the volatile memory of the computing system 30. Processor 982 can process executable instructions and / or data structures in part by direct access to the computer program product, for example, by reading a CD-ROM disk inserted into a peripheral disk drive of computer system 30. Alternatively, processor 982 can process executable instructions and / or data structures by remotely accessing the computer program product, for example, by downloading executable instructions and / or data structures from a remote server using the 922 devices of network connectivity. The computer program product may comprise instructions that promote the loading and / or copying of data, data structures, files, and / or executable instructions for secondary storage 984, in ROM 986, in RAM 988, and / or in other non-volatile memory and volatile memory of the computing system 30.

In some contexts, a baseband signal and / or

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IMPI

INSTITUTO MEXICANO DE LA FROFIEDAD INDUSTRIAL a signal incorporated in a carrier wave can be called a transient signal. In some contexts, secondary storage 984, ROM 986, and RAM 988 may be referred to as nontransient computer-readable media or computer-readable storage media. A modality of dynamic RAM of RAM 988, likewise, can be termed as a non-transient computer readable medium since while dynamic RAM receives electrical power and

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<td colspan="2">find it on</td><td colspan="2">and it is operational,</td><td>the</td><td colspan="2">Dynamic RAM stores</td>

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Processor 982 may comprise internal RAM, internal ROM, cache memory, and / or other internal non-transient storage blocks, sections, or components, which may be referred to in some contexts as non-transient computer-readable media or as human-readable storage media. computer.

Herein, or is inclusive and not exclusive, unless expressly stated otherwise or otherwise indicated by context. Therefore, A or B herein means A, B, or both, unless expressly stated otherwise or otherwise indicated by context. On the other hand, and at the same time it is solidarity, unless expressly stated otherwise or

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otherwise indicated by context. Therefore, A and B herein means A and B, jointly or individually unless expressly stated otherwise or otherwise indicated by context.

This description encompasses all changes, substitutions, variations, alterations, and modifications to exemplary modalities herein which may be understood by a person having ordinary skill in the art.

Likewise, where applicable, the appended claims encompass all changes, substitutions, variations, alterations, and modifications to exemplary embodiments herein which may be comprised of a person of ordinary skill in the art. Furthermore, the reference in the appended claims to an apparatus or system or a component of an apparatus or system that is adapted for, provides for, capable of, configures for, enables for, operates for, or operates to perform a particular function covers apparatus , system, component, whether or not that particular function is activated, turned on, or unlocked, as long as that device, system, or component is adapted, available, capable of, configured, activated, operated, or operated in this manner.

Any of the steps, operations, or processes described herein can be performed or implemented with one or more hardware or software modules, alone or in combination with other devices. In one modality, a

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MEXICAN INSTITUTE df. The INDUSTRIAL proprietary software module is implemented with a computer program product comprising a medium containing computer readable computer program code, which may be executed by a computer processor to perform any or all of the steps, operations or processes described.

Modalities of the invention may also relate to an apparatus for performing the operations herein. This apparatus may be specially constructed for the required purposes, and / or may comprise a general-purpose computing device selectively activated or reconfigured by a computer program stored in the computer. Such a computer program may be stored on a tangible and computer-readable storage medium or any type of means suitable for storing electronic instructions, and coupled to a computer system bus. Furthermore, any computing system mentioned in the specification can include a single processor or can be architectures that employ multiple processor designs for increased computing capacity.

Although the present invention has been described in various embodiments, many changes, variations, alterations, transformations, and modifications may be suggested by someone skilled in the art, and the present invention is intended to encompass such changes, variations,

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alterations, transformations and modifications that fall within the scope of the appended claims. Furthermore, although the present disclosure has been described with respect to various embodiments, it is fully expected that the teachings of the present disclosure may be combined into a single embodiment as appropriate.

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