Monitoring a fracture in a hydrocarbon well

Hydrocarbon wells that include interrogation devices positioned within a fracture and methods of monitoring at least one property of a fracture. The hydrocarbon wells include a wellbore that extends within a subsurface region and a fracture that extends from the wellbore. The hydrocarbon wells also include a plurality of interrogation devices entrained within a carrier fluid and positioned within the fracture and a downhole communication device positioned within the wellbore and proximal the fracture. The methods include flowing the interrogation devices into the fracture and conveying the excitation signal into the fracture. The methods also include receiving the excitation signal with the interrogation devices and generating a plurality of corresponding resultant signals with the interrogation devices. The methods further include receiving at least a subset of the corresponding resultant signals with a downhole communication device and determining at least one property of the fracture based upon the corresponding resultant signals.

FIELD OF THE DISCLOSURE

The present disclosure relates generally to hydrocarbon wells that include interrogation devices positioned within a fracture and/or to methods of monitoring at least one property of a fracture.

BACKGROUND OF THE DISCLOSURE

During formation and/or completion of hydrocarbon wells, fracture operations may be utilized to fracture a subsurface region within which the hydrocarbon well extends, such as to increase a fluid permeability of the subsurface region. While mechanisms for forming fractures within a subsurface region are well-established, the shape, size, and/or extent of the formed fractures generally is not known. Thus, there exists a need for hydrocarbon wells that include interrogation devices positioned within a fracture and/or for methods of monitoring at least one property of a fracture.

SUMMARY OF THE DISCLOSURE

Hydrocarbon wells that include interrogation devices positioned within a fracture and methods of monitoring at least one property of a fracture are disclosed herein. The hydrocarbon wells include a wellbore that extends within a subsurface region and a fracture that extends from the wellbore. The hydrocarbon wells also include a plurality of interrogation devices entrained within a carrier fluid and positioned within the fracture. The hydrocarbon wells further include a downhole communication device positioned within the wellbore and proximal the fracture. The plurality of interrogation devices is configured to generate a plurality of corresponding resultant signals responsive to receipt of an excitation signal.

The methods include flowing a plurality of interrogation devices within a carrier fluid and from the wellbore into the fracture. The methods also include conveying the excitation signal into the fracture. The methods further include receiving the excitation signal with the plurality of interrogation devices and, responsive to the receiving, generating a plurality of corresponding resultant signals with the plurality of interrogation devices. The methods also include receiving at least a subset of the plurality of corresponding resultant signals from at least a subset of the plurality of interrogation devices with a downhole communication device that is positioned within the wellbore. The methods further include determining at least one property of the fracture based, at least in part, upon the subset of the plurality of corresponding resultant signals.

DETAILED DESCRIPTION AND BEST MODE OF THE DISCLOSURE

FIGS. 1-3provide examples of hydrocarbon wells10, interrogation devices80, and/or methods100, according to the present disclosure. Elements that serve a similar, or at least substantially similar, purpose are labeled with like numbers in each ofFIGS. 1-3, and these elements may not be discussed in detail herein with reference to each ofFIGS. 1-3. Similarly, all elements may not be labeled in each ofFIGS. 1-3, but reference numerals associated therewith may be utilized herein for consistency. Elements, components, and/or features that are discussed herein with reference to one or more ofFIGS. 1-3may be included in and/or utilized with any ofFIGS. 1-3without departing from the scope of the present disclosure. In general, elements that are likely to be included in a particular embodiment are illustrated in solid lines, while elements that are optional are illustrated in dashed lines. However, elements that are shown in solid lines may not be essential and, in some embodiments, may be omitted without departing from the scope of the present disclosure.

FIG. 1is a schematic illustration of examples of a hydrocarbon well10according to the present disclosure, whileFIG. 2is a schematic illustration of examples of an interrogation device80that may be utilized with hydrocarbon wells10and/or methods100, according to the present disclosure. As illustrated inFIG. 1, hydrocarbon wells10include a wellbore20that extends within a subsurface region4. Wellbore20also may be referred to herein as extending between a surface region2and a subterranean formation6that extends within the subsurface region. Hydrocarbon wells10also include at least one fracture30that extends from wellbore20into and/or within the subsurface region. As illustrated schematically by the combination of solid and dashed lines inFIG. 1, hydrocarbon wells10may include a plurality of fractures30. For simplicity's sake, the following discussion frequently will refer to a fracture30, but it is within the scope of the present disclosure that this discussion may apply to more than one fracture30, such as a plurality of fractures30.

Hydrocarbon wells10further include a plurality of interrogation devices80. Interrogation devices80may be entrained within a carrier fluid. Additionally or alternatively, at least a subset of interrogation devices80may be positioned within fracture30and/or within the plurality of fractures30. Interrogation devices80may be configured to produce and/or generate a plurality of corresponding resultant signals98responsive to receipt of an excitation signal70. Hydrocarbon wells10also include a downhole communication device50. Downhole communication device50may be positioned within wellbore20and/or may be proximal fracture30.

During operation of hydrocarbon wells10, such as during the examples of methods100, that are discussed in more detail herein, interrogation devices80may flow into fracture30. Subsequently excitation signal70may be generated and/or conveyed into the fracture and received by interrogation devices80. Responsive to receipt of the excitation signal, interrogation devices80may produce and/or generate the plurality of corresponding resultant signals98, at least a subset of which may be received with and/or by downhole communication device50. At least one property of fracture30then may be calculated, established, and/or determined based, at least in part, on the subset of the plurality of corresponding resultant signals98received by the downhole communication device. As such, and as discussed in more detail herein with reference to methods100ofFIG. 3, hydrocarbon wells10according to the present disclosure may permit and/or facilitate actual, direct, and/or in situ determination of the at least one property of the fracture, examples of which are disclosed herein with reference to methods100.

In some examples, downhole communication device50may include a communication device receiver54. The communication device receiver, when present, may be configured to receive resultant signals98, or a subset of the plurality of corresponding resultant signals98, from interrogation devices80.

In some examples, downhole communication device50may include a communication device excitation signal transmitter56. The communication device excitation signal transmitter, when present, may be configured to generate excitation signal70and/or to provide excitation signal70to interrogation devices80. In these examples, excitation signal70may include and/or be a radio frequency excitation signal. The radio frequency excitation signal may have and/or may define any suitable signal frequency. Examples of the signal frequency include signal frequencies of at least 10 kilohertz (KHz), at least 20 KHz, at least 30 KHz, at least 40 KHz, at least 50 KHz, at least 75 KHz, at least 100 KHz, at least 250 KHz, at least 500 KHz, at least 1 megahertz (MHz), at least 50 MHz, at least 100 MHz, at least 250 MHz, at least 500 MHz, at least 1 GHz, at least 2 GHz, at most 5 GHz, at most 4 GHz, at most 3 GHz, at most 2.5 GHz, at most 2 GHz, at most 1.5 GHz, at most 1 GHz, at most 500 MHz, at most 100 MHz, at most 500 KHz, and/or at most 100 KHz.

In some examples, downhole communication device50may form a portion of a downhole assembly40. Downhole assembly40, when present, additionally may include one or more of a perforation gun42, a downhole pressure pulse generator44, and/or a downhole electric field generator46. Perforation gun42, when present, may be configured to generate one or more perforations within a casing26that may line wellbore20thereby permitting and/or facilitating formation of fractures30. Downhole pressure pulse generator44, when present, may be configured to generate excitation signal70in the form of a pressure pulse excitation signal within carrier fluid60. Downhole electric field generator46, when present, may be configured to generate excitation signal70in the form of an electric field excitation signal.

As illustrated in dashed lines inFIG. 1, downhole communication device50may include a communication device data transmitter52. Communication device data transmitter52, when present, may be configured to transmit a data signal53to surface region2. Data signal53may include information regarding, may be based upon, and/or may be representative of the at least one property of the fracture.

The data signal may be transmitted to the surface region in any suitable manner. As an example, the hydrocarbon well may include an electrical conductor22that may extend between the downhole communication device and the surface region. In this example, the downhole communication device may be configured to transmit the data signal via the electrical conductor. As another example, an optical fiber may extend between the downhole communication device and the surface region. In this example, the hydrocarbon well also may include one or more optical encoders and/or optical decoders that may provide an optical signal to the optical fiber and/or that may receive the optical signal from the optical fiber.

As another example, communication device data transmitter52may include and/or be a wireless communication device data transmitter configured to wirelessly transmit the data signal to the surface region. In this example, hydrocarbon well10may include a downhole wireless network24that may extend within the wellbore and/or that may be configured to convey the data signal between the downhole communication device and the surface region. Examples of the wirelessly transmitted data signal include an electromagnetic data signal, a radio frequency data signal, and/or an acoustic data signal that may be conveyed along and/or within wellbore20, casing26, and/or carrier fluid60.

Turning toFIG. 2, interrogation devices80may include any suitable structure that may be positioned within the fracture, that may be entrained within the carrier fluid, and/or that may generate the corresponding resultant signals. In addition, interrogation devices80may generate corresponding resultant signals98in any suitable manner.

As an example, interrogation devices80may include a plurality of passive interrogation devices82. Passive interrogation devices82may be configured to passively interact with excitation signal70and/or to passively generate resultant signal98. An example of passive interrogation devices82includes a plurality of radio frequency identification (RFID) interrogation devices. RFID interrogation devices may receive excitation signal70and may passively interact with, or modify, the excitation signal to generate the resultant signal.

As another example, interrogation devices80may include a plurality of active interrogation devices84. Active interrogation devices84may be configured to actively generate resultant signal98. As an example, active interrogation devices84may include at least one sensor86. Sensor86may be configured to collect data related to the at least one property of the fracture. Examples of the data include an absolute location of each interrogation device relative to the downhole communication device, a relative location of each interrogation device relative to at least one other interrogation device, a pressure acting on each interrogation device, and/or a temperature of each interrogation device.

Active interrogation devices84additionally or alternatively may include energy harvesting structures88. Energy harvesting structures88may be configured to generate electrical energy responsive to receipt of excitation signal70and/or responsive to fluid contact with carrier fluid60, such as to power one or more other components of the active interrogation device.

Examples of energy harvesting structures88include an electromagnetic energy harvesting structure, such as an RFID structure, configured to generate electrical energy responsive to receipt of an electromagnetic excitation signal, a pressure energy harvesting structure, such as a piezoelectric element, configured to generate electrical energy responsive to receipt of a pressure pulse excitation signal, and/or an electric field energy harvesting structure, such as an inductive coil, configured to generate electrical energy responsive to receipt of an electric field excitation signal. Additional or alternative examples of energy harvesting structures88include structures that react with carrier fluid60and/or that otherwise generate electrical energy responsive to fluid contact with the carrier fluid. As an example, energy harvesting structures88may form a battery via contact with, or utilizing, the carrier fluid. As another example, and as discussed in more detail herein, the carrier fluid may include and/or be an electrically conductive carrier fluid, and energy harvesting structures88may receive the electric current from the electrically conductive carrier fluid.

Interrogation device80additionally or alternatively may include one or more interrogation device transmitters90. Interrogation device transmitters90may be configured to generate resultant signals98, such as may be responsive to receipt of excitation signal70. Interrogation devices80additionally or alternatively may include interrogation device receivers94. Interrogation device receivers94may be configured to receive a corresponding resultant signal70from another interrogation device in the plurality of interrogation devices, such as to permit and/or to facilitate device-to-device communication among two or more interrogation devices80.

As illustrated in dashed lines inFIG. 2, interrogation devices80may include an encapsulating material96. Such interrogation devices may be referred to herein as encapsulated interrogation devices. An example of encapsulating material96includes a proppant material. In such a configuration, interrogation devices80additionally may be configured to function as, or may be, a proppant within the fractures of the hydrocarbon well and may be spherical, or at least substantially spherical, in shape.

FIG. 3is a flowchart depicting examples of methods100of monitoring at least one property of a fracture that extends from a wellbore of a hydrocarbon well and within a subsurface region, according to the present disclosure. Methods100may include providing a plurality of interrogation devices to the wellbore at105, forming a fracture at110, and/or drilling the wellbore at115. Methods100include flowing the plurality of interrogation devices at120and may include generating an excitation signal at125. Methods100include conveying the excitation signal at130and receiving the excitation signal at135. Methods100also may include powering the plurality of interrogation devices at140and/or collecting data at145, and methods100also may include generating a plurality of corresponding resultant signals at150and receiving at least a subset of the plurality of corresponding resultant signals at155. Methods100further may include transmitting a data signal at160, determining a property of the fracture at165, and repeating at least a portion of the methods at170.

Providing the plurality of interrogation devices to the wellbore at105may include providing the plurality of interrogation devices to the wellbore and/or positioning the plurality of interrogation devices within the wellbore in any suitable manner. As an example, the providing at105may include injecting, or flowing, the plurality of interrogation devices into the wellbore from a surface region and/or within a carrier fluid, such as carrier fluid60ofFIG. 1. Examples of the plurality of interrogation devices are disclosed herein with reference to interrogation devices80ofFIGS. 1-2.

The providing at105may include selectively providing the plurality of interrogation devices to the wellbore based upon and/or responsive to a supply criteria. As an example, the selectively providing may include selectively providing at a predetermined time. As another example, the selectively providing may include repeated and selectively providing on a predetermined schedule, or time interval. As additional examples, the selectively providing may include selectively providing based upon a fluid type of the carrier fluid, based upon a flow rate of the carrier fluid, and/or based upon an operational sequence for the hydrocarbon well. Additionally or alternatively, the providing at105may include continuously providing the plurality of interrogation devices to the wellbore, at least during a predetermined providing time interval.

In these examples, methods100may include forming the fracture at110, such as via flow of the carrier fluid into the subsurface region and/or via pressurization of the subsurface region with the carrier fluid. In these examples, methods100also may include propping the fracture with, via, and/or utilizing the plurality of interrogation devices. Stated another way, the plurality of interrogation devices may function both as a proppant and as a mechanism via which methods100may determine the at least one property of the fracture.

The forming at110may be accomplished in any suitable manner and/or as part of any suitable operation of and/or within the hydrocarbon well. As an example, the carrier fluid may include and/or be a fracture fluid that may be configured to fracture the subsurface region, such as during a fracture stimulation operation and/or during completion of the hydrocarbon well. In this example, methods100may permit and/or facilitate monitoring of the at least one property of the fracture during the fracture stimulation operation.

As another example, the carrier fluid may include and/or be a cuttings re-injection fluid that includes drill cuttings that may be injected as part of a cuttings injection operation. In this example, the forming at110may include forming the fracture via flow of the cuttings re-injection fluid into and/or within the subsurface region, and methods100may permit and/or facilitate monitoring of the at least one property of the fracture during the cuttings injection operation.

As yet another example, the carrier fluid may include and/or be water, such as produced water, that may be injected as part of a water re-injection operation. In this example, the forming at110may include forming the fracture via flow of the produced water into and/or within the subsurface region, and methods100may permit and/or facilitate monitoring of the at least one property of the fracture during the water re-injection operation.

Drilling the wellbore at115may include utilizing a drill bit to drill the wellbore and/or to extend a length of the wellbore, such as during a drilling operation. As an example, the drilling at115may be performed prior to a remainder of the steps of methods100, such as to establish and/or define the wellbore. As another example, the drilling at115may be performed at least partially concurrently with one or more steps of methods100. As a more specific example, and during the drilling at115, the carrier fluid may include a drilling mud, and the drilling at115may include drilling with, via, and/or utilizing the drilling mud. In this example, methods100may be utilized to monitor for fracture formation within the subsurface region and/or to monitor for lost returns due to fracture formation during the drilling operation.

Flowing the plurality of interrogation devices at120may include flowing the plurality of interrogation devices within the carrier fluid, from the wellbore, and/or into the fracture. This may include flowing the plurality of interrogation devices from the surface region, within the wellbore, and/or to the fracture. As discussed, the plurality of interrogation devices also may be, or may function as, a proppant for the fracture. With this in mind, the flowing at120further may include propping the fracture with, via, and/or utilizing the plurality of interrogation devices.

Generating the excitation signal at125may include generating the excitation signal in any suitable manner. As an example, the generating at125may include generating the excitation signal with, via, and/or utilizing a downhole communication device, such as downhole communication device50ofFIG. 1. As another example, the generating at125may include generating the excitation signal with, via, and/or utilizing a downhole pressure pulse generator, such as downhole pressure pulse generator44ofFIG. 1. As yet another example, the generating at125may include generating with, via, and/or utilizing a downhole electric field generator, such as downhole electric field generator46ofFIG. 1. Examples of the excitation signal are disclosed herein with reference to excitation signal70ofFIG. 1.

Conveying the excitation signal at130may include conveying the excitation signal into the fracture. This may include conveying the excitation signal within carrier fluid, conveying the excitation signal via the carrier fluid, and/or conveying the excitation signal through the carrier fluid.

Receiving the excitation signal at135may include receiving the excitation signal with the plurality of interrogation devices. This may include receiving the excitation signal from the carrier fluid, receiving the excitation signal via the carrier fluid, receiving the excitation signal from the downhole communication device, and/or receiving the excitation signal from another interrogation device in the plurality of interrogation devices.

Powering the plurality of interrogation devices at140may include powering the plurality of interrogation devices in any suitable manner. As an example, the powering at140may include powering with, via, and/or utilizing an energy storage device of each interrogation device of the plurality of interrogation devices. As another example, the powering at140may include powering with, via, and/or utilizing the excitation signal. In this example, the powering at140further may include powering with, via, and/or utilizing an energy harvesting structure of each interrogation device of the plurality of interrogation devices. Examples of the energy harvesting structure are disclosed herein with reference to energy harvesting structure88ofFIG. 2.

Collecting data at145may include collecting data with, via, and/or utilizing the plurality of interrogation devices and/or with, via, and/or utilizing a sensor of each interrogation device of the plurality of interrogation devices. Examples of the sensor are disclosed herein with reference to sensor86ofFIG. 2. The data may include and/or be any suitable data that may be collected by the plurality of interrogation devices. As examples, the data may include spatial information regarding each interrogation device of the plurality of interrogation devices, scalar information regarding each interrogation device, absolute distance information regarding a distance between each interrogation device and the downhole communication device, relative distance information regarding a distance between each interrogation device and at least one other interrogation device of the plurality of interrogation devices, pressure information regarding a pressure exerted upon each interrogation device, and/or temperature information regarding a temperature of each interrogation device.

Generating the plurality of corresponding resultant signals at150may include generating the plurality of corresponding resultant signals with the plurality of interrogation devices and may be responsive to the receiving at135. Stated another way, each interrogation device of the plurality of interrogation devices that receives the excitation signal during the receiving at135may, responsive to receipt of the interrogation signal, generate a corresponding resultant signal. Examples of the resultant signal and/or of mechanisms via which the plurality of interrogation devices perform the generating at150are discussed in more detail herein.

Receiving at least the subset of the plurality of corresponding resultant signals at155may include receiving the subset of the plurality of corresponding resultant signals from at least a subset of the plurality of interrogation devices. Additionally or alternatively, the receiving at155may include receiving with, via, and/or utilizing a downhole communication device that may be positioned with the wellbore, such as downhole communication device50ofFIG. 1.

It is within the scope of the present disclosure that the subset of the plurality of interrogation devices may include interrogation devices that are within a threshold distance range of the downhole communication device. Examples of the threshold distance range include distances of at least 0.01 meters, at least 0.05 meters, at least 0.1 meters, at least 0.25 meters, at least 0.5 meters, at least 0.75 meters, at least 1 meter, at least 2 meters, at most 10 meters, at most 8 meters, at most 6 meters, at most 5 meters, at most 4 meters, at most 3 meters, at most 2.5 meters, at most 2 meters, at most 1.5 meters, and/or at most 1 meter.

Transmitting the data signal at160may include transmitting any suitable data signal, which may be based upon the plurality of resultant signals, to the surface region. The transmitting at160may be subsequent to and/or responsive to the receiving at155. Stated another way, subsequent to receipt of the subset of the plurality of corresponding resultant signals during the receiving at155, methods100may include performing the transmitting at160.

The transmitting at160may be accomplished in any suitable manner. As an example, the transmitting at160may include transmitting a wired data signal. As a more specific example, an electrical conductor, such as electrical conductor22ofFIG. 1, may extend within the wellbore and/or between the downhole communication device and the surface region; and the transmitting at160may include transmitting with, via, and/or utilizing the electrical conductor. As another example, the transmitting at160may include wirelessly transmitting the data signal. As more specific examples, the transmitting at160may include transmitting via an acoustic signal that is propagated within the wellbore, transmitting via an electromagnetic signal that is propagated within the wellbore, and/or transmitting via a downhole wireless network, such as downhole wireless network24ofFIG. 1, that extends within the wellbore.

Determining the property of the fracture at165may include calculating, establishing, estimating, and/or otherwise defining at least one property of the fracture based, at least in part, on the subset of the plurality of corresponding resultant signals received during the receiving at155. Examples of the at least one property of the fracture include a one-dimensional measure of fracture size as a function of distance from the wellbore, a two-dimensional measure of fracture size as a function of distance from the wellbore, a fracture width, a fracture height, a fracture length, and/or a three-dimensional measure of fracture geometry within the subsurface region.

In a specific example, the subset of the plurality of corresponding resultant signals may include distance information regarding a distance between the downhole communication device and each interrogation device of the subset of the plurality of interrogation devices. In this example, the determining at165may include determining the at least one property of the fracture based, at least in part, on the distance information. Additionally or alternatively in this example, the at least one property of the fracture may include fracture size as a function of distance from the downhole communication device.

In another specific example, the subset of the plurality of corresponding resultant signals may include absolute spatial information regarding a location of each interrogation device of the subset of the plurality of interrogation devices relative to the downhole communication device. In this example, the determining at165may include determining the at least one property of the fracture based, at least in part, on the absolute spatial information. Additionally or alternatively in this example, the at least one property of the fracture may include fracture size as a function of location within the subsurface region.

As yet another more specific example, the subset of the plurality of corresponding resultant signals may include relative spatial information regarding a location of each interrogation device of the subset of the plurality of interrogation devices relative to at least one other interrogation device in the plurality of interrogation devices. In this example, the determining at165may include determining the at least one property of the fracture based, at least in part, on the relative spatial information. Additionally or alternatively in this example, the at least one property of the fracture may include fracture size as a function of location within the subsurface region.

In another more specific example, a combination of the above determining steps may be performed. As an example, the distance between the downhole communication device and each interrogation device of the subset of the plurality of interrogation devices may be determined, such as via an elapsed time between the generating at125and the receiving at135. In addition, relative spatial information regarding a location of each interrogation device of the subset of the plurality of interrogation devices relative to at least one other interrogation device in the plurality of interrogation devices also may be determined, such as via interrogation device-to-interrogation device communication. The combination of these two pieces of information then may be utilized to generate a 2-dimensional or 3-dimensional map of particle location within the subsurface region, and this map of particle location then may be utilized to determine, to establish, and/or to infer fracture geometry and/or morphology within the subsurface region.

It is within the scope of the present disclosure that the determining at165additionally or alternatively may include determining one or more other properties of the subsurface region and/or of the fracture. As an example, the subset of the plurality of corresponding resultant signals may include temperature information regarding a temperature proximal each interrogation device of the subset of the plurality of interrogation devices. In this example, the at least one property of the fracture may include a temperature distribution within the fracture.

As another example, the subset of the plurality of corresponding resultant signals may include pressure information regarding a pressure proximal and/or acting upon each interrogation device of the subset of the plurality of interrogation devices. In this example, the at least one property of the fracture may include a pressure distribution within the fracture.

Repeating at least the portion of the methods at170may include repeating any suitable portion and/or portions of methods100in any suitable order and/or for any suitable purpose. As an example, the repeating at170may include repeatedly performing the conveying at130, the generating at150, the receiving at155, and the determining at165during a monitoring timeframe. Such methods may permit and/or facilitate determination of the at least one property of the fracture as a function of time. This may, for example, permit and/or facilitate determination of flow kinetics of the plurality of interrogation devices into the fracture and/or determination of growth kinetics of the fracture.

As discussed herein with reference to the forming at110, the carrier fluid may include and/or be a fracture fluid utilized during a fracture stimulation operation. In this example, the repeating at170may include repeating to measure and/or monitor fracture growth, fracture size, fracture volume, fracture extent, and/or fracture shape during the fracture stimulation operation.

As also discussed herein with reference to the forming at110, the carrier fluid may include and/or be a cuttings re-injection fluid that includes drill cuttings utilized during a cuttings re-injection operation. In this example, the repeating at170may include repeating to measure and/or monitor fracture growth during the cuttings re-injection operation.

As also discussed herein with reference to the forming at110, the carrier fluid may include and/or be produced water utilized during a water re-injection operation. In this example, the repeating at170may include repeating to measure and/or monitor fracture growth during the water re-injection operation.

As discussed herein with reference to the drilling at115, the carrier fluid may include a drilling mud utilized during a drilling operation. In this example, the repeating at170may include repeating to monitor for, or to detect, lost returns due to fracture formation during the drilling operation.

Regardless of the nature of the carrier fluid, methods100may be utilized to form a plurality of fractures, such as during a single instance of the forming at110and/or by repeating the forming at110. Additionally or alternatively, methods100may be utilized to monitor geometry and/or growth of the plurality of factures, such as by repeating the flowing at120, the conveying at130, the receiving at135, the generating at150, the receiving at155, and/or the determining at165. It is within the scope of the present disclosure that hydrocarbon wells10and/or methods100may include and/or utilize a significant number of variants and/or variations. More specific but still illustrative, non-exclusive examples of these variants and/or variations of hydrocarbon wells10and/or of methods100are disclosed below. It is within the scope of the present disclosure that any structure, function, and/or step of any of these variants and/or variations may be utilized with any hydrocarbon well10and/or method100, according to the present disclosure.

In a first example, the plurality of interrogation devices may include and/or be a plurality of passive interrogation devices, such as a plurality of radio frequency identification (RFID) interrogation devices. In this example, the generating at125may include generating the excitation signal with the downhole communication device and/or the receiving at135may include receiving the excitation signal from the downhole communication device. In addition, the generating at150may include modifying the excitation signal to generate the plurality of corresponding resultant signals. The modifying may include resonating the plurality of interrogation devices at a frequency of the excitation signal to disrupt the excitation signal and/or to generate the plurality of corresponding resultant signals.

In a second example, the plurality of interrogation devices may include and/or be a plurality of active interrogation devices. In this example, methods100may include the powering at140; and responsive to the powering at140, methods100may include the collecting at145. Stated another way, the plurality of active interrogation devices may be powered with, via, and/or utilizing the excitation signal, such as is disclosed herein with reference to the powering at140. In addition, and responsive to receipt of power from the excitation signal, the plurality of active interrogation devices may collect data, such as is disclosed herein with reference to the collecting at145. In this example, the generating at150may include generating the plurality of corresponding resultant signals based, at least in part, on the data collected during the collecting at145.

It is within the scope of the present disclosure that each interrogation device in the plurality of interrogation device may include and/or define a unique identifier. In such a configuration, the generating at150additionally or alternatively may include generating the plurality of corresponding resultant signals based, at least in part, on the unique identifier. Stated another way, each interrogation device of the plurality of interrogation devices may generate a corresponding resultant signal that includes a corresponding unique identifier and/or may transmit the corresponding unique identifier to the downhole communication device. Such a configuration may permit and/or facilitate identification of individual interrogation devices of the plurality of interrogation devices and/or association of data transmitted by a given interrogation device with the given interrogation device.

In some implementations of this second example, the receiving at155may include receiving the subset of the plurality of corresponding resultant signals directly from the subset of the plurality of interrogation devices. Stated another way, the conveying at130may include directly conveying each corresponding resultant signal from a corresponding interrogation device to the downhole communication device.

In other implementations of this second example, the subset of the plurality of corresponding resultant signals may be a first subset of the plurality of corresponding resultant signals, and the subset of the plurality of interrogation devices may be a first subset of the plurality of interrogation devices. In these implementations, methods100further may include receiving a second subset of the plurality of corresponding resultant signals with the first subset of the plurality of interrogation devices. The second subset of the plurality of corresponding resultant signals may be received from a second subset of the plurality of interrogation devices, and the first subset of the plurality of corresponding resultant signals may be based, at least in part, on the second subset of the plurality of corresponding resultant signals. Stated another way, the second subset of the plurality of interrogation devices may communicate to, or with, the first subset of the plurality of interrogation devices; and information conveyed from the first subset of the plurality of interrogation devices to the downhole communication device may include information conveyed from the second subset of the plurality of interrogation devices to the first subset of the plurality of interrogation devices. Stated yet another way, methods100may include forming and/or utilizing a network of interrogation devices that may be configured for interrogation device-to-interrogation device communication. Such a configuration may permit and/or facilitate downhole communication over larger distances than otherwise may be feasible and/or may permit and/or facilitate determination of relative location and/or spatial information among the interrogation devices.

In one variation of the second example, the excitation signal, which may be conveyed during the conveying at130and/or received during the receiving at135, may include and/or be a radio frequency excitation signal. In this variation, the powering at140may include powering with, via, and/or utilizing the radio frequency excitation signal, which may be generated during the generating at125and/or by the downhole communication device. Also in this variation, the plurality of interrogation devices may include a plurality of radio frequency identification (RFID) interrogation devices configured to generate a plurality of corresponding RFID power outputs responsive to receipt of the radio frequency excitation signal, and the RFID power outputs may be utilized to power the interrogation devices.

In another variation of the second example, the excitation signal, which may be conveyed during the conveying at130and/or received during the receiving at135, may include and/or be a pressure pulse within the carrier fluid. In this variation, the powering at140may include powering with, via, and/or utilizing the pressure pulse. The pressure pulse may be generated during the generating at125, such as utilizing the downhole communication device, a perforation gun attached to a downhole assembly that includes the downhole communication device, a downhole pressure pulse generator positioned within the wellbore, and/or an uphole pressure pulse generator positioned in a surface region.

Also in this variation, the powering at140may include powering with, via, and/or utilizing the pressure pulse. As an example, the plurality of interrogation devices may include a plurality of piezoelectric interrogation devices configured to generate a plurality of corresponding piezoelectric power outputs responsive to receipt of the pressure pulse, and the piezoelectric power outputs may be utilized to power the interrogation devices.

In yet another variation of the second example, the excitation signal, which may be conveyed during the conveying at130and/or received during the receiving at135, may include and/or be an electric field conveyed within the carrier fluid. In this variation, the powering at140may include powering with, via, and/or utilizing the electric field, which may be generated during the generating at125. To facilitate the conveying at130, the carrier fluid may include an electrically conductive carrier fluid, an ionic carrier fluid, and/or an electrolytic carrier fluid that may be configured to convey the excitation signal. Also in this variation, the plurality of interrogation devices may include a plurality of energy harvesting interrogation devices configured to generate a plurality of corresponding harvested power outputs responsive to receipt of the electric field, and the harvested power outputs may be utilized to power the interrogation devices.

In the present disclosure, several of the illustrative, non-exclusive examples have been discussed and/or presented in the context of flow diagrams, or flow charts, in which the methods are shown and described as a series of blocks, or steps. Unless specifically set forth in the accompanying description, it is within the scope of the present disclosure that the order of the blocks may vary from the illustrated order in the flow diagram, including with two or more of the blocks (or steps) occurring in a different order and/or concurrently.

As used herein, “at least substantially,” when modifying a degree or relationship, may include not only the recited “substantial” degree or relationship, but also the full extent of the recited degree or relationship. A substantial amount of a recited degree or relationship may include at least 75% of the recited degree or relationship. For example, an object that is at least substantially formed from a material includes objects for which at least 75% of the objects are formed from the material and also includes objects that are completely formed from the material. As another example, a first length that is at least substantially as long as a second length includes first lengths that are within 75% of the second length and also includes first lengths that are as long as the second length.

INDUSTRIAL APPLICABILITY

The systems and methods disclosed herein are applicable to the oil and gas industries.