WO2016081718A1

WO2016081718A1 - Sensor system

Info

Publication number: WO2016081718A1
Application number: PCT/US2015/061567
Authority: WO
Inventors: David Thomas CHAPMAN; Endre IVARRUD; Mehdi RAFIEE; Walter Joseph TRYBULA
Original assignee: Board Of Regents, The University Of Texas System
Priority date: 2014-11-19
Filing date: 2015-11-19
Publication date: 2016-05-26

Abstract

Instrumented carriers for performing in-wellbore and/or in-fracture measurements of physical parameters are injected into a wellbore within a subterranean formation. The carriers each contain one or more sensor systems, which include a capability to communicate results of the measurements to an external device. The carriers may be configured as frac balls.

Description

SENSOR SYSTEM

Cross -Reference to Related Application

This application claims priority to U.S. Provisional Patent Application Serial No. 62/081,863, which is hereby incorporated by reference herein.

Technical Field

This invention relates in general to a reusable, electronically instrumented carrier for performing a variety of in-wellbore and/or in-fracture physical and/or chemical measurements for oil and/or gas operations, which are not currently possible due to inaccessibility of these areas with existing tooling.

Background Information

This section is intended to introduce various aspects of the art, which may be associated with exemplary embodiments of the present disclosure. This discussion is believed to assist in providing a framework to facilitate a better understanding of particular aspects of the present disclosure. Accordingly, it should be understood that this section should be read in this light, and not necessarily as admissions of prior art.

In certain wellbore operations, various treatment fluids may be pumped into the well and eventually into the subterranean formation to restore or enhance the productivity of the well. For example, a non-reactive fracturing, or "frac," fluid may be pumped into the wellbore to initiate and propagate fractures in the formation, thus providing flow channels to facilitate movement of the hydrocarbons to the wellbore so that the hydrocarbons may be pumped from the well. In such fracturing operations, the fracturing fluid is hydraulically injected into a wellbore penetrating the subterranean formation and is forced against the formation strata by pressure. The formation strata is forced to crack and fracture, and a proppant is placed in the fracture by movement of a viscous fluid containing proppant into the crack in the rock. The resulting fracture, with proppant in place, provides improved flow of the recoverable fluid, e.g., oil, gas, and/or water, into the wellbore.

In certain wells (e.g., horizontal or lateral wells) with multiple production zones, it may be necessary to treat various formations in a multi-stage operation requiring repeated "trips" downhole. Each trip generally includes isolating a single production zone and then delivering the treatment fluid to the isolated zone. Since multiple trips downhole are required to isolate and treat each zone, the completion operation may be very time consuming and expensive. Wellbores are historically characterized using measurement equipment lowered or pulled into wellbores that are tethered to the surface with mechanical and electrical cables (often referred to as wireline logging techniques). Wireline logging requires significant surface infrastructure, operator labor, and production downtime, and thus significant cost to the well operator to obtain the wellbore data. A lower cost of obtaining wellbore measurements might be achieved by attaching or embedding microelectronic sensors into the sidewall of low cost, flexible polymer tubing, or as a bottom hole attached device, such as a well clean out nozzle.

Brief Description of the Drawings

FIG. 1 illustrates a schematic of a wellbore in which embodiments of the present invention are injected.

FIG. 2 illustrates an example of a sensor system carrier configured in accordance with embodiments of the present invention.

FIG. 3 illustrates a block diagram of a sensor system configured in accordance with various embodiments of the present invention.

FIG. 4 illustrates a flow diagram configured in accordance with embodiments of the present invention.

Detailed Description

Aspects of the present invention provide multiple miniaturized electronic sensor systems distributed over the surface of a carrier, which comprises the instrumentation and enables direct measurements in above and/or below ground locations that are currently difficult or impossible to access (e.g., pipelines, subsea tubulars, pumping stations, drill strings, wellbores, and natural and induced fractures) and/or with higher resolution. Within embodiments of the present invention, including those that are recited within the claims, the term "wellbore" may include any portion of piping utilized within the exploration, production, and transportation of hydrocarbons (e.g., pipelines, subsea tubulars, pumping stations, drill strings, wellbores into subterranean formations).

Embodiments of the present invention implement such a carrier in the form of a frac ball. Embodiments of the present invention may be implemented within a fracturing sensor system and/or a wellbore sensor system.

Referring to FIG. 1, to overcome the disadvantages with multi-trip zone isolation and treatment within wellbore operations, a series of sleeves and/or valves 101 and isolation packers 103 are inserted and spaced along the length of the lateral wellbore 105, allowing the isolation of multiple zones and their selective fracturing in a continuous operation. For example, one method for creating multiple fractures in a formation 100 along a wellbore 105 is the use of frac ports and sliding sleeves implemented within a completion string placed inside the wellbore 105. Open hole packers 103, which isolate different sections of the wellbore 105, are actuated by mechanical, hydraulic, or chemical mechanisms. In order to activate each sleeve 101, one or more properly sized fracture stage balls ("frac balls") (not shown in FIG. 1) are injected (e.g., pumped) along with a fracturing fluid 120 from an injection well 110 into the wellbore 105. Each frac ball is smaller than the opening of all of the previous sleeves, but larger than the sleeve it is intended to open. Seating of the frac ball exerts pressure at the end of the sliding sleeve assembly, causing it to slide and open the frac ports. Once the port is opened, the fluid 120 is diverted into the open hole space 100 outside of the completion assembly, causing the formation 100 to fracture. At the completion of each fracturing stage, the next larger frac ball is injected into the wellbore 105, which opens the next sleeve, and so on, until all of the sleeves are opened and multiple fractures are created in the formation 100.

It would be further desirable to be able to perform measurements of various physical and chemical properties present within the wellbore 105 and/or in the fractures in the formation 100.

FIG. 2 depicts an exemplary instrumented carrier 200 (also simply referred to as a "carrier" herein), covered with one or more attached sensor systems 201, which may be distributed in a desired manner on a surface 203 of the carrier 200 (which may be implemented in the form of a fracture stage ball ("frac ball") as further described herein). One or more sensor systems 201 may be attached to the surface 203 of the carrier 200 in a permanent or semipermanent manner, and may be recoverable, attached to the carrier 200 or separately from the carrier 200.

In embodiments of the present invention, the instrumented carrier 200 may include circuitry (further described with respect to FIG. 3) configured to obtain multiple measurements utilizing one or more sensors 320 within diverse sensor systems 201 located on the carrier 200, which can provide unique opportunities to evaluate scenarios where different portions of the carrier 200 may experience different environments. Such an instrumented carrier 200 can provide previously unavailable unique insights into the production environment (e.g., the wellbore 105 and/or the subterranean formation 100).

In embodiments of the present invention, one or more of the sensor systems 201 include one or more sensors (which may include associated sensor circuitry) that make one or more measurements (including in real-time) of physical parameters (which may include physical and/or chemical conditions (e.g., temperature, pressure, and resistivity)) associated with the wellbore 105 and/or the formation fractures 100, and store information associated with such measurements (including in a time-stamped and/or geolocated manner) to an associated memory 314 (see FIG. 3).

Referring again to FIG. 1, the instrumented carrier 200 may be retrieved (e.g., using well-known techniques) to the surface of the subterranean formation 100 from the wellbore 105 and/or directly from the subterranean formation 100 (e.g., through a recovery well 112), where the sensor system(s) 201 may be recharged (e.g., wirelessly) and the memory 314 interrogated (e.g., by a separate computer system 114 (e.g., wirelessly)). The information from each of the sensor systems 201 may be utilized to create data tables of the measured variables' profiles over time, which may be used to characterize well treatment processes. The comparison and correlation of the data from various sensor systems 201 on the carrier 200 can thus provide information previously unobtainable.

The carriers 200 may be manufactured using any suitable material for utilization within a wellbore (e.g., wellbore 105) and/or subterranean formation (e.g., formation 100), including, but not limited to, metal and/or plastic. The sensor systems 201 may be attached (e.g., embedded or mounted) on a surface 203 of the carrier 200 using any suitable means, including with an adhesive. Any number of the sensor systems 201 may be implemented on a particular carrier 200, and such sensor systems 201 may be implemented to measure any desired chemical and/or physical property of the environment in which they are injected (e.g., the wellbore 105 and/or the subterranean formation 100). Though FIG. 2 shows a plurality of the sensor systems 201 distributed in a relatively uniform manner over a surface 203 of the carrier 200, such sensor systems 201 may be implemented on a carrier 200 in any desired distribution pattern. Note that embodiments of the present invention are not limited to the carrier 200 only taking the form of a frac ball.

Furthermore, one or more of the sensor systems 201 may be engineered (configured) to be released from a surface 203 of a carrier 200 in response to a predetermined stimuli, such as a threshold temperature or pressure, and then the released sensors 201 may continue to obtain measurements of their specified chemical and/or physical properties. For example, the adhesive utilized to attach the sensor system(s) 201 to the surface 203 may comprise a material that deteriorates upon encountering a certain threshold parameter within the wellbore 105 and/or subterranean formation 100 to thereby release the sensor system(s) 201 from the carrier 200. Within embodiments of the present invention, certain one or more sensor system(s) 201 may be further encapsulated with a material that deteriorates upon encountering a certain threshold parameter within the wellbore 105 and/or subterranean formation 100 so that such sensor system(s) 201 do not perform their associated measurement(s) until after deterioration of the encapsulant. Such adhesives and encapsulants are well-known in the art, and not shown for the sake of simplicity. The released sensor system(s) 201 may then be retrieved to the surface of the formation 100 for further analysis, including retrieval of information pertaining to the measurements.

With reference now to FIG. 3, a block diagram illustrating a system 300 is depicted in which aspects of embodiments of the invention may be implemented. For example, the system 300 may be utilized for implementing one or more of the sensor systems 201. The system 300 may employ a local bus architecture 312. The bus architecture 312 may permit communication between a microcontroller or microprocessor 310 with a (volatile and/or non volatile) memory 314, an I/O adaptor 318, and a communication adapter 334. An optional power source 302 may be included within the system 300 for providing power to the system 300. An I/O adapter 318 may be provided in order to communicate with one or more sensor circuits 320 (which each include one or more sensors), which have been described herein with examples. The communication adapter 334 may communicate with a transmitter/receiver 336, which may be utilized to permit transfer of data and information between the system 300 and any external systems, such as equipment 114 utilized to retrieve the measurements obtained by the sensor circuits 320 by the system 300. The transmitter/receiver 336 may include any suitable communication means, which includes wireless, such as Bluetooth.

The sensor system(s) 201 may each operate autonomously from each other, or may coordinate and/or communicate with each other to obtain measurements of a particular parameter. The sensor system(s) 201 may store such information in the memory 314, which may be stored in the memory 314 as data tables that correlate the measured parameter(s) to other measured parameters and/or a geolocation and/or time. Such parameters may include time, temperature, pressure, pH, resistivity, and ion charge. Though the sensor system(s) 201 may be powered by an included (optional) power source 302, one or more sensor systems 201 may also be passive devices that provide information without the utilization of a power source, such as with RFID devices.

Though one or more of the sensor systems 201 on a carrier 200 may be autonomous in that they operate autonomously from each other, one or more sensor systems 201 may be implemented to communicate with each other using such a transmitter/receiver 336, or some sort of wired connection between such sensor systems 201. Furthermore, an optional power source 302 may be implemented for each of the powered sensor systems 201, or a single power source may be implemented on or in the carrier 200 for powering a plurality of the sensor systems 201. Furthermore, though the sensor systems 201 have been described herein as being mounted to or embedded within the surface 203 of the carrier 200, certain sensor system(s) 201 may be implemented further within the material comprising the carrier 200. Furthermore, hollow carriers (e.g., frac balls) 200 may be utilized in which electronic circuitry (e.g., system 300) for sensor systems 201 and/or power sources 302 may be implemented inside the carrier 200.

Geolocation of the carrier 200 may be obtained through the use of embedded geolocation circuitry 340 (e.g., circuitry that includes a gyroscope, accelerometer, compass, acoustic means, magnetic means, or 9-axis motion tracking means).

Referring again to FIG. 1, a wireless base station 116 may be inserted down the wellbore 105, which is in wired communication with equipment 114 on the surface of the formation 100. Such a wireless base station 116 may be able to perform wireless communications with the sensor system(s) 201 on the carrier(s) 200, or may perform communications with one or more short-range wireless sensor read-out nodes 118 embedded within the completion string and/or wellbore 105, wherein these sensor node(s) 118 then are in wireless communication with the sensor system(s) 201 on the carrier(s) 200.

Embodiments of the present invention may utilize an existing non-dissolving (e.g., chemically resistant) instrumented frac stage isolation ball ("frac ball") as the carrier 200, such as for utilization within sliding sleeves 101 of a wellbore 105 for hydraulic fracturing. Such an instrumented frac ball 200 may be covered with one or more sensor systems 201, such as illustrated in FIG. 2.

Such frac balls may range from about 0.8 to 5.75 inches in diameter and may be used at pressures and temperatures as high as 11,000 psi and 400°F. The sensor systems 201 can be manufactured to survive these conditions for durations (e.g., up to a week), and may be millimeter to nanometer in scale, enabling the implementation of a plurality (e.g., tens to hundreds) of sensor systems 201 per carrier 200.

In accordance with some embodiments of the present invention, since frac balls 200 are often utilized to close perforated holes in the wellbore 105, the sensor systems 201 may be distributed on a surface 203 of a frac ball 200 so that when the frac ball 200 plugs a perforation, one or more sensor systems 201 on one side of the frac ball 200 obtain measurements from the fractures and/or subterranean environment 100, while one or more sensor systems 201 on another side of the frac ball 200 obtain measurements from the environment within the wellbore 105.

In today's multistage hydraulic fracturing jobs, a single horizontal wellbore (e.g., wellbore 105) can have as many as 30-50 fracture stages, with a stage-to- stage variation in production as great as 100%, where some stages produce nothing, and other stages produce millions of cubic feet of oil and/or gas equivalent, the reason for which is not currently understood, because measurements are not available. This configuration, which is presented as one possible example of such a carrier 200, is able to measure profiles (in both the upstream and downstream sides of the hydraulically isolating instrumented frac ball) simultaneously, during the hydraulic fracturing of the upstream stage.

Measuring pressure versus time during multistage hydraulic fracturing, via pressure sensor-studded frac stage balls (e.g., carriers 200) in the stage isolation wellbore zones can provide information on hydraulic communication between fracture stages. This knowledge would provide the producer the opportunity to compensate for the communication between each frac stage in the well plan to enhance production and reserves, for example, by adjusting fracking pressure, stage spacing, and/or depth in the current and subsequent stages.

Having this information, operating companies can engineer a schedule for fracturing by which one can redesign the fluid to reduce the friction and so the excessive horsepower needed to generate the required injection rates. Accurate estimation of temperature would help in understanding the perforation efficiency along the lateral as the ball passes by each of the perforation clusters. Changes in temperature from the flowing intervals would give an understanding of how successful was the frac job in that stage/interval. These intervals can be treated at a later time if identified.

Since the location of the frac ball seat in a sliding sleeve is well known, this data can be also geolocated within the subsurface formation 100. Such an instrumented frac ball 200 may be recovered to the surface of the formation 100 when the well is brought back on line, after all stages are complete. The frac ball 200 may be recovered via a coarse screening grid and then interrogated as disclosed herein. Another option for recovery is the use of a sacrificial layer of dissolvable frac stage ball material on top of the non-dissolving instrumented ball. The dissolvable layer releases the ball, and produces the data containing core to the surface.

Another embodiment of the present invention may include wire or fiber infrastructure 130 within the casing and sliding sleeve to communicate to equipment 114 on the surface of the formation 100, enabling real-time data acquisition from the instrumented carrier(s) 200 during fracturing operations.

FIG. 4 illustrates a flow diagram configured in accordance with embodiments of the present invention. As has been described in examples herein, in step 401, one or more sensor systems 201 are attached to a carrier 200. In step 402, a fluid 120 containing one or more such carriers 200 is injected into a wellbore 105, a formation 100, etc., such as through an injection well 110 utilizing well-known injection (pumping) equipment. In step 403, the sensor systems 201 collect measurements of physical parameters of the environment (e.g., the wellbore 105, the formation 100, etc.) utilizing there embedded sensor circuits 320, as described herein. In step 404, the measurements are then retrieved from the sensor systems 201 utilizing any one of the techniques described herein. Such techniques may include wireless communications of the measurements from the individual sensor systems 201 on the carriers 200 to a wireless base station 116 or node 118, which is in communication 130 with the equipment 114 on the surface of the formation 100. Alternatively, one or more of the carriers 200 may be retrieved from the formation 100 through a recovery well 112, and then interrogated by the equipment 114.

As will be appreciated by one skilled in the art, aspects of the present invention may be embodied as a system, method, and/or program product. For example, the sensor systems and any technique for retrieving the information from the sensor systems may be embodied within a system as generally illustrated with respect to FIG. 3. Accordingly, aspects of the present invention may take the form of an entirely hardware embodiment, an entirely software embodiment (including firmware, resident software, micro-code, etc.), or embodiments combining software and hardware aspects that may all generally be referred to herein as a "circuit," "circuitry," "module," or "system." Furthermore, aspects of the present invention may take the form of a program product embodied in one or more computer readable storage medium(s) having computer readable program code embodied thereon. (However, any combination of one or more computer readable medium(s) may be utilized. The computer readable medium may be a computer readable signal medium or a computer readable storage medium.)

A computer readable storage medium may be, for example, but not limited to, an electronic, magnetic, optical, electromagnetic, infrared, biologic, atomic, or semiconductor system, apparatus, controller, or device, or any suitable combination of the foregoing. More specific examples (a non-exhaustive list) of the computer readable storage medium may include the following: an electrical connection having one or more wires, a portable computer diskette, a hard disk, a random access memory (RAM), a read-only memory (ROM), an erasable programmable read-only memory (EPROM or Flash memory), an optical fiber, a portable compact disc read-only memory (CD-ROM), an optical storage device, a magnetic storage device, or any suitable combination of the foregoing. In the context of this document, a computer readable storage medium may be any non-transitory and/or tangible medium that can contain or store a program for use by or in connection with an instruction execution system, apparatus, controller, or device. Program code embodied on a computer readable signal medium may be transmitted using any appropriate medium, including but not limited to wireless, wire line, optical fiber cable, RF, etc., or any suitable combination of the foregoing.

A computer readable signal medium may include a propagated data signal with computer readable program code embodied therein, for example, in baseband or as part of a carrier wave. Such a propagated signal may take any of a variety of forms, including, but not limited to, electro-magnetic, optical, or any suitable combination thereof. A computer readable signal medium may be any computer readable medium that is not a computer readable storage medium and that can communicate, propagate, or transport a program for use by or in connection with an instruction execution system, apparatus, controller, or device.

Any flowcharts and block diagrams in the figures illustrate architecture, functionality, and operation of possible implementations of systems, methods and program products according to various embodiments of the present invention. In this regard, each block in the flowcharts or block diagrams may represent a module, segment, or portion of code, which comprises one or more executable program instructions for implementing the specified logical function(s). It should also be noted that, in some implementations, the functions noted in the blocks may occur out of the order noted in the figures. For example, two blocks shown in succession may, in fact, be executed substantially concurrently, or the blocks may sometimes be executed in the reverse order, depending upon the functionality involved.

Modules implemented in software for execution by various types of processors may, for instance, comprise one or more physical or logical blocks of computer instructions which may, for instance, be organized as an object, procedure, or function. Nevertheless, the executables of an identified module need not be physically located together, but may comprise disparate instructions stored in different locations which, when joined logically together, comprise the module and achieve the stated purpose for the module. Indeed, a module of executable code may be a single instruction, or many instructions, and may even be distributed over several different code segments, among different programs, and across several memory devices. Similarly, operational data may be identified and illustrated herein within modules, and may be embodied in any suitable form and organized within any suitable type of data structure. The operational data may be collected as a single data set, or may be distributed over different locations including over different storage devices. The data may provide electronic signals on a system or network.

These program instructions may be provided to a processor and/or controller of a general purpose computer, special purpose computer, or other programmable data processing apparatus (e.g., controller) to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, create means for implementing the functions/acts specified in the flowchart and/or block diagram block or blocks.

It will also be noted that each block of the block diagrams and/or flowchart illustration, and combinations of blocks in the block diagrams and/or flowchart illustration, can be implemented by special purpose hardware-based systems that perform the specified functions or acts, or combinations of special purpose hardware and computer instructions. For example, a module may be implemented as a hardware circuit comprising custom VLSI circuits or gate arrays, off-the-shelf semiconductors such as logic chips, transistors, controllers, or other discrete components. A module may also be implemented in programmable hardware devices such as field programmable gate arrays, programmable array logic, programmable logic devices or the like.

Computer program code, i.e., instructions, for carrying out operations for aspects of the present invention may be written in any combination of one or more programming languages, including an object oriented programming language such as Java, Smalltalk, C++ or the like and conventional procedural programming languages, such as the "C" programming language or similar programming languages. The program code may execute entirely on the user's computer, partly on the user' s computer, as a stand-alone software package, partly on the user' s computer and partly on a remote computer or entirely on the remote computer or server. In the latter scenario, the remote computer may be connected to the user's computer through any type of network, including a local area network (LAN) or a wide area network (WAN), or the connection may be made to an external computer (for example, through the Internet using an Internet Service Provider).

These program instructions may also be stored in a computer readable storage medium that can direct a computer, other programmable data processing apparatus, controller, or other devices to function in a particular manner, such that the instructions stored in the computer readable medium produce an article of manufacture including instructions which implement the function/act specified in the flowchart and/or block diagram block or blocks.

The program instructions may also be loaded onto a computer, other programmable data processing apparatus, controller, or other devices to cause a series of operational steps to be performed on the computer, other programmable apparatus or other devices to produce a computer implemented process such that the instructions which execute on the computer or other programmable apparatus provide processes for implementing the functions/acts specified in the flowchart and/or block diagram block or blocks.

Reference throughout this specification to "one embodiment," "embodiments," or similar language means that a particular feature, structure, or characteristic described in connection with the embodiments is included in at least one embodiment of the present invention. Thus, appearances of the phrases "in one embodiment," "in an embodiment," "embodiments," and similar language throughout this specification may, but do not necessarily, all refer to the same embodiment. Furthermore, the described features, structures, aspects, and/or characteristics of the invention may be combined in any suitable manner in one or more embodiments. Correspondingly, even if features may be initially claimed as acting in certain combinations, one or more features from a claimed combination can in some cases be excised from the combination, and the claimed combination can be directed to a sub-combination or variation of a sub-combination.

In the descriptions herein, numerous specific details are provided, such as examples of programming, software modules, user selections, network transactions, database queries, database structures, hardware modules, hardware circuits, hardware chips, controllers, etc., to provide a thorough understanding of embodiments of the invention. One skilled in the relevant art will recognize, however, that the invention may be practiced without one or more of the specific details, or with other methods, components, materials, and so forth. In other instances, well-known structures, materials, or operations may be not shown or described in detail to avoid obscuring aspects of the invention.

Benefits, advantages and solutions to problems have been described above with regard to specific embodiments. However, the benefits, advantages, solutions to problems, and any element(s) that may cause any benefit, advantage, or solution to occur or become more pronounced may be not to be construed as critical, required, or essential features or elements of any or all the claims. Those skilled in the art having read this disclosure will recognize that changes and modifications may be made to the embodiments without departing from the scope of the present invention. It should be appreciated that the particular implementations shown and described herein may be illustrative of the invention and its best mode and may be not intended to otherwise limit the scope of the present invention in any way. Other variations may be within the scope of the following claims.

While this specification contains many specifics, these should not be construed as limitations on the scope of the invention or of what can be claimed, but rather as descriptions of features specific to particular implementations of the invention. Headings herein may be not intended to limit the invention, embodiments of the invention or other matter disclosed under the headings.

As used herein, the terms "comprises," "comprising," or any other variation thereof, may be intended to cover a non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements does not include only those elements but may include other elements not expressly listed or inherent to such process, method, article, or apparatus. Further, no element described herein is required for the practice of the invention unless expressly described as essential or critical.

Herein, the term "or" may be intended to be inclusive, wherein "A or B" includes A or B and also includes both A and B.

The terminology used herein is for the purpose of describing particular embodiments only and is not intended to be limiting of the invention. As used herein, the singular forms "a," "an," and "the" may be intended to include the plural forms as well, unless the context clearly indicates otherwise. It will be further understood that the terms "comprises" and/or "comprising," when used in this specification, which may include the claims herein below, specify the presence of stated features, integers, steps, operations, elements, and/or components, but do not preclude the presence or addition of one or more other features, integers, steps, operations, elements, components, and/or groups thereof.

The corresponding structures, materials, acts, and equivalents of all means or step plus function elements in the claims below may be intended to include any structure, material, or act for performing the function in combination with other claimed elements as specifically claimed.

The description of the present invention has been presented for purposes of illustration and description, but is not intended to be exhaustive or limited to the invention in the form disclosed. Many modifications and variations will be apparent to those of ordinary skill in the art without departing from the scope and spirit of the invention. The embodiment was chosen and described in order to best explain the principles of the invention and the practical application, and to enable others of ordinary skill in the art to understand the invention for various embodiments with various modifications as may be suited to the particular use contemplated.

Claims

What is Claimed is:

1. A frac ball carrier comprising one or more sensor systems attached to a surface of the frac ball carrier, wherein the one or more sensor systems each comprise a sensor configured to measure a physical parameter of an environment in proximity to the frac ball carrier.

2. The frac ball carrier as recited in claim 1, wherein the one or more sensor systems each comprise a memory configured to store information pertaining to the measured physical parameter.

3. The frac ball carrier as recited in claim 2, further comprising communications circuitry configured to externally communicate the measured physical parameter from the one or more sensor systems.

4. The frac ball carrier as recited in claim 1, wherein the frac ball carrier is a frac stage isolation ball configured for utilization within sliding sleeves of a wellbore for hydraulic fracturing.

5. The frac ball carrier as recited in claim 1, wherein a first one of the one or more sensor systems is attached to the surface of a first side of the frac ball carrier, and wherein a second one of the one or more sensor systems is attached to the surface of a second side of the frac ball carrier, wherein the first and second sides of the frac ball carrier are located on opposite sides of the frac ball carrier from each other, and wherein the first one of the one or more sensor systems is configured to measure a different physical parameter than the second one of the one or more sensor systems.

6. The frac ball carrier as recited in claim 1, wherein the one or more sensor systems comprise geolocation circuitry configured to determine a location of the frac ball carrier.

7. A system comprising:

one or more carriers, wherein each carrier comprises one or more sensor systems attached to a surface of the carrier, wherein the one or more sensor systems each comprise a sensor configured to measure a physical parameter of an environment in proximity to the carrier; communications circuitry configured to retrieve information from the one or more sensor systems, wherein the information pertains to the measured physical parameter;

a fluid containing the one or more carriers; and

injection equipment configured to inject the fluid into a wellbore.

8. The system as recited in claim 7, wherein the carrier is a frac stage isolation ball configured for utilization within sliding sleeves of the wellbore for hydraulic fracturing.

9. The system as recited in claim 8, further comprising hydraulic fracturing equipment configured to fracture a subterranean formation in proximity to the wellbore.

10. The system as recited in claim 9, whereby the fracturing of the subterranean formation by the hydraulic fracturing equipment results in a passage of the fluid containing the one or more carriers into the subterranean formation from the wellbore.

11. The system as recited in claim 10, wherein the one or more sensor systems comprise geolocation circuitry configured to determine a location of the one or more carriers in relation to each other within the wellbore or the subterranean formation.

12. The system as recited in claim 7, wherein the communications circuitry further comprises circuitry configured to externally communicate the measured physical parameter from the one or more sensor systems.

13. The system as recited in claim 12, wherein the circuitry configured to externally communicate the measured physical parameter from the one or more sensor systems comprises RFID circuitry.

14. The system as recited in claim 12, wherein the circuitry configured to externally communicate the measured physical parameter from the one or more sensor systems comprises a wireless node configured for location within the wellbore.

15. The system as recited in claim 10, further comprising equipment configured to recover from the subterranean formation at least some of the fluid containing one or more of the sensor systems through a recovery well.

16. A method comprising:

injecting a fluid containing a plurality of carriers into a wellbore, wherein each of the plurality of carriers comprises sensor systems attached to a surface of the carrier, wherein the sensor systems each comprise a sensor for measuring a physical parameter of an environment in proximity to the carrier; and

retrieving information from the sensor systems, wherein the information pertains to the measured physical parameter.

17. The method as recited in claim 16, wherein the retrieving of the information from the sensor systems comprises wireless communications of the information from the sensor systems to wireless communications equipment.

18. The method as recited in claim 16, wherein the retrieving of the information from the sensor systems comprises recovering at least a portion of the plurality of the carriers through a recovery well.

19. The method as recited in claim 16, wherein each of the plurality of the carriers is a frac stage isolation ball configured for utilization within sliding sleeves of the wellbore for hydraulic fracturing.

20. The method as recited in claim 19, further comprising hydraulic fracturing of a subterranean formation in proximity to the wellbore, whereby the fracturing of the subterranean formation results in a passage of the fluid containing the plurality of carriers into the

subterranean formation from the wellbore.