APPARATUS AND METHOD FOR POSITIONING A MEASUREMENT DEVICE AT A SUBSURFACE LOCATION TO CONDUCT IN-SITU MONITORING OF HYDROGEN LEVELS

Description

CROSS-REFERENCE TO RELATED APPLICATIONS

This application is a divisional of and claims the benefit of U.S. patent application Ser. No. 18/636,015, filed Apr. 15, 2024, the entire contents of which are incorporated by reference herein.

FIELD OF THE DISCLOSURE

The present disclosure generally relates to energy storage and extraction and, more specifically, to a tool for positioning at a subsurface location, such as a natural resource reservoir, to conduct in-situ determinations of hydrogen levels.

BACKGROUND OF THE DISCLOSURE

With continued developments in seeking energy sources with reduced carbon output, there is growing interest in hydrogen as a low-carbon fuel. Key challenges for using hydrogen as a viable energy medium are its storage and transportation. The present disclosure addresses hydrogen storage by providing a heretofore unavailable hydrogen monitoring tool usable for storage applications.

SUMMARY OF THE DISCLOSURE

Hydrogen produced from excess energy supply can be stored in large quantities and used later. Accordingly, subsurface hydrogen storage is becoming increasingly important due to its large scale capacity, which makes it technically and economically feasible. For many years, depleted hydrocarbon reservoirs and saline aquifers have been successfully used as subsurface storages for natural gas. However, unlike natural gas storage, hydrogen interactions with reservoir fluid and rock are not well understood and reactions may occur via different mechanisms.

With the continued developments in using and storing hydrogen, there is an ongoing need for downhole tools that can monitor hydrogen productions. Production logging is a well-known technique used in conventional hydrocarbon extraction operations to determine flow and fluid properties based on velocity, density, pressure and temperature measurements in a reservoir. Although these measurements provide for differentiating gas, oil, and water, they are not designed to detect hydrogen. In other words, there are no existing tools capable of detecting and quantifying hydrogen flow potential from subsurface storages. This is vitally important in order to assess the subsurface hydrogen storages in terms of delivery rate and working capacity.

The present disclosure generally relates to an in-situ hydrogen monitoring apparatus and method to ascertain hydrogen behavior in subsurface reservoirs and to, thereby, assess the performance of intermediate-to-long-term subsurface storage reservoirs. More specifically, in view of the developed field of conventional production logging, the present disclosure is directed to a new logging tool that is compatible with existing infrastructure and that is capable of detecting hydrogen presence in subsurface reservoirs, quantifying flow potential, and detecting any changes in produced hydrogen compositions.

According to one or more example implementations consistent with the present disclosure, a measurement device adapted for positioning at a subsurface location and for determining one or more parameters related to hydrogen at the subsurface location, comprises: one or more hangers adapted to affix the measurement device to the subsurface location; a plurality of centralizer arms forming an interior space having a proximal portion and a distal portion; a plurality of fiber optic Raman probes each disposed at the proximal portion or the distal portion of the interior space and proximate to a respective one of the plurality of centralizer arms, said plurality of fiber optic Raman probes being adapted to measure a hydrogen concentration in a downhole measurement; and a plurality of optical probes each disposed at another of the distal portion or the proximal portion of the interior space and proximate to a same or different one of the plurality of centralizer arms, said plurality of optical probes being adapted to measure downhole local gas holdup.

In one or more example implementations, the measurement device further comprises one or more flowmeters disposed at the proximal portion or the distal portion of the interior space.

In one or more example implementations, the measurement device further comprises another one or more flowmeters disposed at another of the proximal portion or the distal portion of the interior space.

In one or more example implementations, the one or more flowmeters and the another one or more flowmeter are rotationally offset from each other in relation to a longitudinal axis along the measurement device.

In one or more example implementations, the measurement device further comprises: one or more power generators coupled to the one or more flowmeters; and one or more energy storage devices coupled to the one or more power generators, wherein said one or more energy storage devices are adapted to store power generated by the one or more power generators via the one or more flowmeters and adapted to supply the stored power to the measurement device.

In one or more example implementations, the measurement device further comprises one or more graphical processing units (GPUs) adapted to process at least signal data obtained from the plurality of fiber optic Raman probes.

In one or more example implementations, the measurement device further comprises a communication interface adapted to transmit interpretation data from the one or more GPUs to a surface computing apparatus.

In one or more example implementations, the measurement device further comprises a memory, wherein the one or more GPUs are adapted to operate in one of a first mode and a second mode, the first mode comprises storing, in the memory, raw and processed data used for generating the interpretation data, and the second mode comprises discarding the raw and processed data.

In one or more example implementations, the plurality of fiber optic Raman probes and the plurality of optical probes are disposed at respective interior perimeters having diameters that are fractions of respective outer circumference diameters formed by the plurality of centralizer arms.

In one or more example implementations, the plurality of fiber optic Raman probes are disposed proximate to same ones of the plurality of centralizer arms as the plurality of optical probes.

In one or more example implementations, the plurality of fiber optic Raman probes are disposed proximate to different ones of the plurality of centralizer arms from the plurality of optical probes.

In one or more example implementations, the plurality of centralizer arms are bowspring centralizer arms.

In one or more example implementations, the plurality of fiber optic Raman probes are adapted to detect signal bands of hydrogen molecules.

In one or more example implementations, the plurality of fiber optic Raman probes are adapted to detect signal spectra with wavenumbers at about 4,100-4,175 cm⁻¹.

In one or more example implementations, the measurement device further comprises a temperature probe and a pressure probe, wherein the detected signal with wavenumbers at about 4,125-4,165 cm⁻¹ are processed based on one or more of a temperature determined using the temperature probe and a pressure determined using the pressure probe.

In one or more example implementations, the plurality of centralizer arms comprise at least six (6) bowspring centralizer arms, and the fiber optic Raman probes comprise six (6) fiber optic Raman probes that are disposed proximate to respective ones of the at least six (6) centralizer arms at 60 degrees from one another around an interior perimeter of the measurement device.

In one or more example implementations, the plurality of optical probes comprise six (6) optical probes that are disposed proximate to respective ones of the at least six (6) centralizer arms at 60 degrees from one another around another interior perimeter of the measurement device.

According to one or more example implementations consistent with the present disclosure, a method for determining one or more parameters related to hydrogen at a subsurface location, comprises: affixing a measurement device to the subsurface location with one or more hangers; and receiving data from the measurement device, wherein the measurement device comprises: a plurality of centralizer arms forming an interior space having a proximal portion and a distal portion; a plurality of fiber optic Raman probes each disposed at the proximal portion of the interior space and proximate to a respective one of the plurality of centralizer arms, said plurality of fiber optic Raman probes being adapted to measure a hydrogen concentration in a downhole measurement; and a plurality of optical probes each disposed at the distal portion of the interior space and proximate to a same or different one of the plurality of centralizer arms, said plurality of optical probes being adapted to measure downhole local gas holdup.

In one or more example implementations, the data received from the measurement device comprises interpretation data generated using one or more graphical processing units (GPUs) disposed in the measurement device.

In one or more example implementations, the one or more GPUs are adapted to operate in one of a first mode and a second mode, the first mode comprises storing, in a memory, raw and processed data used for generating the interpretation data, and the second mode comprises discarding the raw and processed data.

BRIEF DESCRIPTION OF THE DRAWING FIGURES

Various example implementations of this disclosure will be described in detail, with reference to the following figures, wherein:

FIG. 1A is a schematic diagram illustrating a measurement device in a retracted state according one or more example implementations of the present disclosure.

FIG. 1B is a schematic diagram illustrating the measurement device of FIG. 1A in an expanded, deployment state.

FIG. 2 is a schematic diagram illustrating the operating components of a cartridge portion in the measurement device of FIGS. 1A and 1B according to one or more example implementations of the present disclosure.

FIG. 3 is a schematic diagram illustrating operating components of a measurement portion in the measurement device of FIGS. 1A and 1B according to one or more example implementations of the present disclosure.

FIG. 4A is a cross-sectional view along line B in the 4A-4A direction in FIG. 1A showing a first portion of a Raman/optical probe and flowmeter assembly of FIG. 3.

FIG. 4B is a cross-sectional view along line B in the 4B-4B direction in FIG. 1A showing a second portion of a Raman/optical probe and flowmeter assembly of FIG. 3.

FIG. 5 is a schematic diagram showing a power module of FIG. 2 according to one or more example implementations of the present disclosure.

FIG. 6 is a flow diagram for a process of determining between operating modes for the measurement device of FIGS. 1A and 1B according to one or more example implementations of the present disclosure.

FIG. 7 is a schematic diagram illustrating two (2) Raman/optical probe and flowmeter assemblies in a tandem configuration according to one or more example implementations of the present disclosure.

FIG. 8A is a schematic diagram showing a deployment of the measurement device of FIG. 1A according to one or more example implementations of the present disclosure.

FIG. 8B is a schematic diagram showing an installed measurement device of FIG. 1B in use according to one or more example implementations of the present disclosure.

DETAILED DESCRIPTION OF CERTAIN EMBODIMENTS OF THE DISCLOSURE

As an overview, the present disclosure generally concerns energy storage and extraction and, more specifically, directed to techniques involving the use of depleted hydrocarbon reservoirs for energy storage—as an example, for storing hydrogen as an energy storage medium.

Optimizing hydrogen injection and withdrawal from depleted hydrocarbon reservoirs requires an enhanced understanding of the production and injection profiles. Existing production logging techniques lack specific hydrogen detection capabilities that are required to effectively monitor the hydrogen injections and withdrawals.

The present disclosure is directed to an innovative permanently or semi-permanently installed measurement device, subsurface sensing system, and downhole logging tool and method for in-situ hydrogen monitoring to quantify flow potential and the changes in produced hydrogen compositions from subsurface hydrogen storages.

According to example implementations of the present disclosure, miniature downhole Raman sensors are integrated with production/flow logging sensors for hydrogen monitoring and surveillance. Raman spectroscopy is capable of providing structural fingerprints for different molecules in a sample, including homonuclear diatomic molecules such as hydrogen.

FIG. 1A is a schematic diagram illustrating a measurement device 100 in a retracted state according one or more example implementations of the present disclosure. As illustrated in FIG. 1A, measurement device 100 comprises a pair of installation mechanism portions 105-1 and 105-2 at respective proximal and distal ends. In one or more example implementations, installation mechanism portions 105-1 and 105-2 incorporate respective liner hangers 107-1 and 107-2 that are expandable to engage and grip an interior liner of a wellbore (805 in FIGS. 8A and 8B) for installing measurement device 100 at a location down the wellbore. Hangers 107-1 and 107-2 are shown in retracted states in FIG. 1A for when measurement device 100 is lowered into a wellbore (see FIG. 8A). Accordingly, installation mechanism portion 105-1 is detachably coupled to cabling 109 for lowering measurement device 100 down a wellbore (805 in FIGS. 8A and 8B). In certain embodiments, one or more connections via cabling 109 can be established to one or more surface apparatuses, such as an operator console (810 in FIG. 8B) and the like, for communications with the surface.

FIG. 1B is a schematic diagram illustrating measurement device 100 with liner hangers 107-1 and 107-2 both in an expanded, deployment state. Thus, hangers 107-1 and 107-2 in the illustrated deployment state grips an interior liner of a wellbore to affix measurement device 100 to a location. In certain embodiments, hangers 107-1 and 107-2 can be set hydraulically or mechanically, or can be other types of installation mechanisms for affixing measurement device 100 to a location.

As illustrated in FIGS. 1A and 1B, measurement device 100 further comprises a cartridge portion 110 and a measurement portion 115. In one or more example implementations, measurement portion 115 embodies a sonde or probe that includes the components described and shown with reference to FIGS. 4A-5 and 7. As used herein, a sonde refers to an instrument probe that automatically transmits information about its surroundings from an inaccessible location, such as underground or underwater. According to one or more example implementations, measurement device 100 has a total length of about 2.2 meters (m) (or about 1.5 m to about 3 m) and an outer diameter (OD) of about 3.4 centimeters (cm) (or about 3.0 cm to about 5.0 cm) in the retracted state illustrated in FIG. 1A. In the deployed state illustrated in FIG. 1B, hangers 107-1 and 107-1 has an OD or a width of about 12 cm to about 12.5 cm, or about 12.1 cm to about 12.3 cm (or about 4¾ inches), to engage an inner surface of a wellbore with a corresponding dimension.

According to one or more example implementations, cartridge portion 110 hosts the power and communication instrumentations of measurement device 100 and measurement portion 115 incorporates instrumentation for logging measurements, such as pressure, temperature, fluid density, depth, to name a few, as well as for advanced measurements, including specific measurements for in-situ evaluations related to hydrogen. In example implementations, the advanced measurements can include fluid flow velocity, Raman signals, and local gas holdup. As illustrated in FIG. 1B, measurement portion 115 incorporates a plurality of centralizer arms 405 that are coupled at their respective upper/proximal and lower/distal portions to measurement portion 115—for example, a central shaft element 125 of measurement portion 115.

Accordingly, in certain embodiments, measurements taken by the instrumentation at measurement portion 115 can be recorded at cartridge portion 110, transmitted from memory and/or streamed in real time via cabling (e.g., 109) and/or a wireless communication (e.g. 810 in FIG. 8B) for interpretation. Acquisition and interpretation software can be executed to process the raw data received from measurement device 100 and to analyze dynamic well performance, as well as the productivity and injectivity from subsurface reservoirs used for hydrogen storage. In embodiments, at least portions of such software can be executed by one or more onboard processors incorporated in measurement device 100—for example, processor(s) 210 in cartridge portion 110 in FIG. 2. In certain embodiments, at least portions of the software can be executed by one or more processors (not shown) incorporated in measurement portion 115.

FIG. 2 is a schematic diagram illustrating the operating components of cartridge portion 110 according to one or more example implementations of the present disclosure. As illustrated in FIG. 2, cartridge portion 110 incorporates a power module 205, one or more processor devices 210, a memory 215, and a communication interface/telemetry recorder 220.

Power module 205 is a power source for other operating components of cartridge portion 110. In certain embodiments, power module 205 can be a power source for the overall measurement device 100, including operating components of measurement portion 115. According to one or more example implementations, power module 205 incorporates a power generation mechanism that captures and stores energy using one or more flowmeters 410, as discussed in further detail with reference to FIG. 5. In certain embodiments, power module 205 can comprise any suitable heat and pressure resistant battery—for example, lithium-ion batteries or the like.

In one or more example implementations of the present disclosure, processor(s) 210 and memory 215 are embodied by a field programmable gate array (FPGA) based processing unit to record, process, and transfer the data recorded by measurement device 100 to the surface for interpretation and processing. The FPGA includes configurable logic blocks and embedded components for data processing adapted to the signal data detected via the various sensors of measurement device 100. According to one embodiment, the FPGA contains a 48-bit adder with an accumulator and enables efficient monitoring and processing of the data within the subsurface environment. In embodiments, one or more additional processor(s) 210 and/or memory device(s) 215, such as a microcontroller or the like, can be incorporated to handle the data recording, processing, and communication tasks.

According to one or more example implementations processor(s) 210 comprise one or more graphics processing units (GPUs) for the computation and analysis of data obtained by measurement device 100. Correspondingly, memory 215 can comprise any volatile or non-volatile memory device(s) suitable for operation in downhole environments to store raw measurement data and/or processed data. In one or more embodiments, processor(s) (GPU) 210 can operate in a memory mode or a streaming mode. In the memory mode, the GPU, processor(s) 210, stores raw and processed data in memory 215, and transmits interpreted information via the telemetry system 220. In the streaming mode, the GPU, processor(s) 210, discards the raw and processed data, and transmits solely the interpreted results via the telemetry system 220. A difference between the streaming mode and the memory mode is that the streaming mode significantly reduces data storage requirements of memory 215 and, hence, is able to operate longer as compared to the memory mode based on power consumption. In certain embodiments, processor(s) 210 determines between operating in the streaming and memory modes based on a remaining power available at power module 205, an expected remaining operating time of measurement device 100, a communication status with a surface computing device (810 and/or 807 in FIG. 8B), a power generation rate of power module 205, available memory storage in memory 215, a scheduled maintenance time, to name a few.

Communication interface/telemetry recorder 220 incorporates electronics adapted to relay data obtained by measurement device 100 to the surface—for example, one or more computing apparatuses (810 in FIG. 8B) operating at the surface and in communication with measurement device 100. In embodiments, communication interface 220 can include any suitable hardware (e.g., hardware for wired and/or wireless connections) and/or software interface among the operating components of measurement device 100 and one or more computing apparatuses (810 in FIG. 8B) at the surface. According to one or more example implementations, communication interface 220 includes interconnections between the sensors of measurement device 100 and processor(s) 210 and memory 215 for relaying, processing, and recording the data from the sensors. In embodiments, communication interface 220 can further include wired and/or wireless connections for relaying raw and/or processed data to one or more apparatuses (810 in FIG. 8B) at the surface. In one or more example implementations, communication interface/telemetry recorder 220 is in wireless communication with a surface interface module (807 in FIG. 8B) for recording and/or relaying data obtained by measurement device 100 to a surface terminal device (810 in FIG. 8B). In certain embodiments, one or more signal repeaters (not shown) can be deployed along a wellbore (805 in FIG. 8B) to relay signals between communication interface/telemetry recorder 220 and its surface interface module (807 in FIG. 8B). Data obtained by measurement device 100 can be received by a surface terminal device (810 in FIG. 8B) via wired or wireless communications with surface interface module (807 in FIG. 8B).

FIG. 3 is a schematic diagram illustrating operating components of measurement portion 115 according to one or more example implementations of the present disclosure. As illustrated in FIG. 3, measurement portion 115 incorporates one or more pressure probes 305, one or more temperature probe(s) 310, one or more gradiomanometers 325, and a Raman/optical probe and flowmeter assembly 330.

Pressure probe(s) 305 and temperature probe(s) 310 can include any suitable pressure and temperature sensors that are used, for example, in production logging for determining the pressure and temperature of the subsurface environment at which measurement device 100 is deployed. In embodiments, pressure probe(s) 305 and temperature probe(s) 310 can be oriented to detect localized pressure and temperature parameters in cooperation with one or more of the other sensors of measurement device 100—for example, for determining the flow characteristics and/or concentration of hydrogen in the subsurface environment.

Gradiomanometer(s) 325 derives a fluid density in a wellbore by, according to one or more example implementations, incorporating a differential transducer to measure a differential pressure over the length of a column of fluid within the wellbore (805 in FIGS. 8A and 8B). Thus, a fluid density at a subsurface location can be determined by measurement device 100.

In certain embodiments, measurement portion 115 can include a depth matching and correlation detector (not shown), which can be based on gamma ray, optical, sonic, photoelectric factor, or the like, for matching well logs—for example, raw logging-while-drilling (LWD) logs, electrical-wireline-logging (EWL) logs, or the like—and matching depth information of a wellbore (805 in FIGS. 8A and 8B). In certain embodiments, measurement portion 115 can further include a casing collar locator (CCL) (not shown), for example, with a coil and magnetic assembly and a downhole amplifier for detecting a magnetic flux caused by an enlarged collar of a metallic casing of a wellbore (805 in FIGS. 8A and 8B).

FIG. 4A is a cross-sectional view along line B in the 4A-4A direction in FIG. 1 showing a first portion 330a of Raman/optical probe and flowmeter assembly 330 in measurement portion 115. FIG. 4B is a cross-sectional view along line B in the 4B-4B direction in FIG. 1 showing a second portion 330b of Raman/optical probe and flowmeter assembly 330 in measurement portion 115. Referring to FIG. 1B, band 130 marks a location from the upper/proximal end of centralizer arms 405 that is about one quarter (¼) to one third (⅓) of the total length spanning centralizer arms 405 along a central longitudinal axis “A” of measurement portion 115. Correspondingly, band 135 in FIG. 1 marks a location from the lower/distal end of centralizer arms 405 that is about one quarter (¼) to one third (⅓) of the total length spanning centralizer arms 405 along a central longitudinal axis “A” of measurement portion 115. Thus, FIG. 4A provides an upward (or proximal) interior view of an upper (or proximal) portion of measurement portion 115 and FIG. 4B a downward (or distal) interior view of a lower (or distal) portion of measurement portion 115. In accordance with one or more example implementations of the present disclosure, measurement portion 115 has a total length of about 1.5 meters (m) to about 3.0 m and a maximum outer diameter (OD) of about 12.1 cm (or about 4¾ inches) across a middle portion—e.g., at line “B” in FIG. 1—of centralizer arms 405.

As illustrated in FIGS. 4A and 4B, measurement portion 115 comprises, consists essentially of, or consists of twelve (12) bowspring centralizer arms 405-1, . . . , 405-12 that are coupled to measurement portion 115 at their respective upper/proximal and bottom/distal portions. According to one or more example implementations and as illustrated in FIG. 4A, centralizer arms 405 are coupled at their upper/proximal portions to a central shaft portion 125, which can be coupled to cartridge portion 110, and, as illustrated in FIG. 4B, centralizer arms 405 are coupled and at their lower/distal portions to a central shaft portion 125. Centralizer arms 405 thereby form an expanded interior space in measurement portion 115. In embodiments, different types and numbers of centralizers can be used without departing from the spirit and scope of the present disclosure. As illustrated in FIG. 1B, central shaft portion 125 extends along an entire length of the interior space formed by centralizer arms 405. In certain embodiments, central shaft portion 125 can be disconnected between the upper/proximal and lower/distal portions.

According to one or more example implementations, six (6) of the centralizer arms 405 (or half of the total number of centralizer arms 405) incorporate respective mini spinner flowmeters 410 to provide fluid velocity measurements. As illustrated in FIG. 4A, three (3) flowmeters 410-1, 410-2, and 410-3 are disposed across an upper or proximal portion of an expanded interior space formed by centralizer arms 405, for example, at band 130 in FIG. 1B.

According to one or more example implementations, flowmeters 410-1, 410-2, and 410-3 are disposed proximate to—for example, mounted on-interior surfaces of centralizer arms 405-3, 405-7, and 405-11, respectively. Correspondingly, as illustrated in FIG. 4B, three (3) flowmeters 410-4, 410-5, and 410-6 are disposed across a lower or distal portion of an expanded interior space formed by centralizer arms 405, for example, at band 135 in FIG. 1B. According to one or more example implementations, flowmeters 410-4, 410-5, and 410-6 are disposed proximate to—for example, mounted on-interior surfaces of centralizer arms 405-1, 405-5, and 405-9, respectively. As shown in FIG. 4A, flowmeters 410-1, 410-2, and 410-3 are disposed around an interior perimeter at about one half (½) to about three quarters (¾) diameter of the diameter of outer circumference 4c-a of measurement portion 115, for example, at band 130 of FIG. 1B. According to one or more example implementations, outer circumference 4c-a has a diameter of about 12.1 cm (or about 4¾ inches), or the OD at line “B” in FIG. 1B. Correspondingly, as shown in FIG. 4B, flowmeters 410-4, 410-5, and 410-6 are disposed around an interior perimeter at about one half (½) to about three quarters (¾) diameter of the diameter of outer circumference 4c-b of measurement portion 115, for example, at band 135 of FIG. 1B. According to one or more example implementations, outer circumference 4c-b has a diameter of about 12.1 cm (or about 4¾ inches), or the OD at line “B” in FIG. 1B. Thus, flowmeters 410 are disposed in an expanded interior space formed by centralizer arms 405 at locations that are away from the maximum outer circumference of the interior space—for example, at line “B” shown in FIG. 1B. As such, flowmeters 410 are adapted to determine the characteristics of a main flow within a wellbore by being place substantially away from the sidewalls (not shown) of the wellbore. In certain embodiments, flowmeters 410 can be disposed at different locations on interior and/or exterior portions of measurement portion 115 without departing from the spirit and scope of the present disclosure. In certain embodiments, flowmeters 410 can also determine water holdup, water/hydrocarbon bubble count, and include relative bearing measurements, to name a few. In certain embodiments, alternative types and arrangements of flowmeters can be implemented, such as a full bore spinner, continuous spinner, or the like.

According to one or more example implementations, the same centralizer arms 405-1, 405-3, 405-5, 405-7, 405-9, and 405-11 are also used as sensing elements to provide caliper measurements from the movement of the respective bowsprings for measuring one or more inclinations of a wellbore via a physical caliper.

As illustrated in FIG. 4A, six (6) fiber optic Raman probes 415-1, . . . , 415-6 are disposed around an interior perimeter at about one half (½) to about three quarters (¾) diameter of the outer circumference diameter 4c-a of measurement portion 115, for example, at band 130 of FIG. 1B. According to one or more example implementations, probes 415-1, . . . , 415-6 are disposed proximate to—for example, mounted on-interior surfaces of respective arms 405-2, 405-4, 405-6, 405-8, 405-10, and 405-12 as shown in FIG. 4A. In other words, Raman probes 415-1, . . . , 415-6 are disposed in an upper or proximal portion of an expanded interior space formed by centralizer arms 405 and at locations that are away from the maximum outer circumference of the interior space, or the outer circumference 4c-a, for example, at line “B” shown in FIG. 1B. Accordingly, probes 415 would be disposed away from a wellbore wall when measurement portion 115 is deployed. Probes 415, as arranged in FIG. 4A, provide coverage around an interior perimeter of measurement portion 115, with a probe 415 disposed every 60 degrees around the interior perimeter. In certain embodiments, more or fewer probes 415 can be disposed at regular or irregular intervals, or at particular positions depending upon the deployment environment of measurement device 100.

As such, probes 415 are adapted to determine the characteristics of a main flow within a wellbore by being place substantially away from the sidewalls (not shown) of a wellbore when measurement portion 115 is deployed. In certain embodiments, Raman probes 415 can be disposed at different locations on interior and/or exterior portions of measurement portion 115 without departing from the spirit and scope of the present disclosure.

Raman probes 415 operate to detect Raman signals of a fluid in a subsurface location of measurement device 100—for example, a wellbore. In one or more example implementations, Raman probes 415 are adapted to detect signal spectra with wavenumbers in a range of about 100-4,325 cm⁻¹. Accordingly, vibrational bands of hydrogen molecules—including their spin isomers, for example, ortho-hydrogen and para-hydrogen—in ranges of about 4,100-4,175 cm⁻¹ are processed based on the in-situ pressure and temperature detected by pressure probe(s) 305 and temperature probe(s) 310. According to one example embodiment, signal bands in ranges of about 4,125-4,165 cm⁻¹ are detected and processed based on temperature and pressure conditions at the subsurface location with the wavenumbers being adjusted based on these conditions—for example, 0-400° C. (Celsius) and 0-40 MPa (Mega-Pascal). In certain embodiments, Raman probes 415 can also be adapted to detect rotational bands of hydrogen molecules in ranges of about 300-1,200 cm⁻¹. In certain embodiments, signal processing techniques, such as Fourier transform, wavelet transform, data processing and/or correction algorithms, to name a few, can be used to identify and process the relevant signal bands.

According to one or more example implementations, data collected by probes 415 is processed by processor(s) 210—for example, in relation to data collected by the probes and detectors of measurement portion 115, such as flowmeters 410 and/or probes 420—and forwarded to a surface computing apparatus (810 and/or 807 in FIG. 8B) for interpretation and/or further processing. According to one or more example implementations, in a memory mode, a GPU comprised in processor(s) 210 stores raw data from probes 415 (and/or flowmeters 410, probes 420, etc.) and processed data in memory 215, and transmits interpreted information via the telemetry system 220 to a surface computing apparatus (810 and/or 807 in FIG. 8B). In a streaming mode, the GPU comprised in processor(s) 210 discards the raw and processed data, and transmits solely the interpreted results via the telemetry system 220 to a surface computing apparatus (810 and/or 807 in FIG. 8B). A difference between the streaming mode and the memory mode is that the streaming mode significantly reduces data storage requirements of memory 215 and, hence, is able to operate longer as compared to the memory mode based on power consumption. In certain embodiments, raw data collected by probes 415 can be relayed to a surface computing apparatus (810 and/or 807 in FIG. 8B) for processing and interpretation in real time. In certain embodiments, one or more processing devices (not shown) can be incorporated in measurement portion 115 for processing data signals from probes 415.

Referring now to FIG. 4B, six (6) optical probes 420-1, . . . , 420-6 are disposed around an interior perimeter at about one half (½) to about three quarters (¾) diameter of the outer circumference diameter 4c-b of measurement portion 115, for example, at band 135 of FIG. 1B. According to one or more example implementations, probes 420-1, . . . , 420-6 are disposed proximate to—for example, mounted on-interior surfaces of respective arms 405-2, 405-4, 405-6, 405-8, 405-10, and 405-12 as shown in FIG. 4B. In other words, optical probes 420-1, . . . , 420-6 are disposed in a lower or distal portion of an expanded interior space formed by centralizer arms 405 and at locations that are away from the maximum outer circumference of the interior space—for example, at line “B” shown in FIG. 1B. Accordingly, probes 420 would be disposed away from a wellbore wall when measurement portion 115 is deployed. Probes 420, as arranged in FIG. 4B, provide coverage around an interior perimeter of measurement portion 115 (or the expanded interior space thereof), with a probe 420 disposed every 60 degrees around the interior perimeter. In the illustrated implementation, probes 420 are vertically aligned with probes 415 by being disposed proximate to the same centralizer arms 405. In certain embodiments, more or fewer probes 420 can be disposed at regular or irregular intervals, or at particular positions, including positions that are vertically offset from probes 415, depending upon the deployment environment of measurement device 100.

As such, probes 420 are adapted to determine the characteristics of a main flow within a wellbore by being place substantially away from the sidewalls (not shown) of the wellbore (805 in FIGS. 8A and 8B) when measurement portion 115 is deployed. In certain embodiments, optical probes 420 can be disposed at different locations on interior and/or exterior portions of measurement portion 115 without departing from the spirit and scope of the present disclosure.

According to one or more example implementations, probes 420 are Gas Holdup Optical Sensor Tool (“GHOST”) probes that operate to measure local gas holdup in a subsurface location of measurement device 100—for example, a wellbore. In certain embodiments, probes 420 can also include gas/liquid bubble count, caliper, and relative bearing measurements, to name a few.

According to one or more example implementations, data collected by probes 420 is processed by processor(s) 210—for example, in relation to data collected by the probes and detectors of measurement portion 115, flowmeters 410, and/or probes 415—and forwarded to a surface computing apparatus (not shown) for interpretation and/or further processing. According to one or more example implementations, in a memory mode, a GPU comprised in processor(s) 210 stores raw data from probes 420 (and/or flowmeters 410, probes 415, etc.) and processed data in memory 215, and transmits interpreted information via the telemetry system 220 to a surface computing apparatus (810 and/or 807 in FIG. 8B). In a streaming mode, the GPU comprised in processor(s) 210 discards the raw and processed data, and transmits solely the interpreted results via the telemetry system 220 to a surface computing apparatus (810 and/or 807 in FIG. 8B). A difference between the streaming mode and the memory mode is that the streaming mode significantly reduces data storage requirements of memory 215 and, hence, is able to operate longer as compared to the memory mode based on power consumption. In certain embodiments, raw data collected by probes 420 can be relayed to a surface computing apparatus (810 and/or 807 in FIG. 8B) for processing and interpretation in real time. In certain embodiments, one or more processing devices (not shown) can be incorporated in measurement portion 115 for processing data signals from probes 420.

As illustrated in FIGS. 1B, 4A, and 4B, centralizer arms 405 form an expanded interior space—for example, a prolate spheroid—with a maximum outer circumference at about a middle line—for example, line “B” in FIG. 1B-between an upper/proximal point and a bottom/distal point of each centralizer arm 405. According to one or more example implementations, each centralizer arm 405 is a bowspring coupled to a central shaft element 125 of measurement portion 115 at the respective upper/proximal and lower/distal points. As illustrated in FIG. 1B, the upper/proximal point can be coupled to cartridge portion 110. In certain embodiments, different types of centralizer arms 405 adapted for forming a centered interior space from a borehole wall (not shown) can be incorporated in measurement portion 115 without departing from the spirit and scope of the present disclosure.

Referring back to FIGS. 4A and 4B, the probes 415/420 and flowmeters 410 are disposed at a middle portion within the expanded interior space formed by centralizer arms 405 proximate to the upper/proximal and lower/distal positions, which are indicated, for example, by bands 130 and 135 in FIG. 1B, respectively. Thus, advantageously, the probes 415/420 and flowmeters 410 are disposed sufficiently away from a borehole wall circumferentially to capture a main flow of a well. Additionally, accounting for the lower density of hydrogen, probes 415 are arranged on an upper (or proximal) portion of measurement portion 115 in relation to probes 420 for measurements in vertical wellbores. In certain embodiments, probes 415 and probes 420 can be offset from one another by being disposed on different centralizer arms 405 from one another at respective upper (or proximal) portions and lower (or distal) portions. In certain embodiments, probes 415 and 420 and be disposed at different positions—for example, probe 415 at a distal portion of measurement portion 115 or probe 420 at a proximal portion of measurement portion 115—depending upon the deployment environment of measurement device 100.

As further illustrated in FIGS. 4A and 4B, flowmeters 410-1, 410-2, and 410-3 are arranged on centralizer arms 405-3, 405-7, and 405-11 between respective pairs of probes 415-1 and 415-2, 415-3 and 415-4, and 415-5 and 415-6, respectively, and flowmeters 410-4, 410-5, and 410-6 are rotationally offset from flowmeters 410-1, 410-2, and 410-3 in relation to a central longitudinal axis along measurement portion 115—see, for example, axis “A” in FIGS. 1A, 1B, 4A, and 4B—by being arranged on centralizer arms 405-1, 405-5, and 405-9 between the other pairs of probes 420-2 and 420-3, 420-4 and 420-5, and 420-6 and 420-1. As shown in FIGS. 4A and 4B, the offset is about 60 degrees. In certain embodiments, the rotational offset can be between 1-59 degrees or 61-119 degrees. Thus, flow characteristics, or any differences, between the upper/proximal and lower/distal portions of measurement portion 115 can be determined based on the offset arrangement of flowmeters 410. This arrangement also provides for circumferential coverage in flow characteristic determinations. In certain embodiments, flowmeters 410-1, 410-2, and 410-3 can be vertical or horizontally aligned with flowmeters 410-4, 410-5, and 410-6. In certain embodiments, different numbers of centralizer arms 405, flowmeters 410, and/or probes 415/420 can be used with attendant alignments and/or offsets without departing from the spirit and scope of the present disclosure.

In certain embodiments, measurement device 100 can be used for measurements in horizontal deployments with flowmeters 410, probes 415, and probes 420 encircling an interior perimeter of measurement portion 115 away from the outermost circumference of arms 405, or a borehole wall.

FIG. 5 is a schematic diagram showing power module 205 according to one or more example implementations of the present disclosure.

As illustrated in FIG. 5, power module 205 comprises an energy storage 505 and one or more generator elements 510 that is coupled to one or more of the flowmeters 410 in measurement portion 115. Thus, in certain embodiments, generator element(s) 510 can be embodied in measurement portion 115 and coupled to one or more of the flowmeters 410. As flowmeters 410 are driven by the fluid flow in a well, generator element(s) 510 coupled to the driven element(s) of a corresponding flowmeter(s) 410 captures electrical energy for storage in energy storage 505. Energy storage can be any suitable heat and pressure resistant energy storage device or battery—for example, rechargeable lithium-ion batteries or the like. Thus, the energy generation and storage of power module 205 provides for extended operations of measurement device 100 while deployed.

Correspondingly, in certain embodiments, processor(s) 210 can determine between a memory mode and a streaming mode for optimizing power consumption of measurement device 100. FIG. 6 is a flow diagram for a process 600 of determining between such operating modes for measurement device 100 according to one or more example implementations of the present disclosure.

As shown in FIG. 6, process 600 starts with step s601 of receiving a data request. In one or more example implementations, the data request is received from a surface computing apparatus (810 and/or 807 in FIG. 8) that has established a communication connection with measurement device 100. Such a communication connection can be a wired or wireless connection to a surface interface module (807 in FIG. 8) and/or one or more signal repeaters (not shown) deployed along a wellbore (805 in FIG. 8), or the like. Upon receiving the data request, process 600 proceeds to step s602, where processor(s) 210 determines whether there is sufficient power at power module 205 and/or available memory storage at memory 215 to operate in a memory mode. According to one or more example implementations, processor(s) 210 determines whether energy storage 505 exceeds a low state of charge (SOC) threshold of about 20% to about 30% and/or a memory capacity at memory 215 of about 10% to about 60%. In certain embodiments, processor(s) 210 can account for the rate of power generation via generator(s) 510 and/or an estimated power consumption from operating in the memory mode for an expected duration based on the requested data. For example, the decision can be based on an estimated SOC at energy storage 505 and/or memory capacity at memory 215 upon completing a transmission of the requested data in the memory mode. In certain embodiments, processor(s) 210 can further base the decision at step s602 upon an expected remaining operating time of measurement device 100, a communication status with a surface computing device (810 and/or 807 in FIG. 8B), a scheduled maintenance time, to name a few.

Upon determining that there is sufficient power at power module 205 and/or available memory storage at memory 215 (“Yes”), processor(s) 210 proceeds to step s603 and transmits requested data in the memory mode—in other words, processor(s) 210 stores raw and processed data in memory 215, and transmits the requested data comprising interpreted information via the telemetry system 220. In certain embodiments, the raw and processed data stored in memory 215 can be obtained through the memory mode and/or the streaming mode of process 600 as the requested data or upon retrieval of measurement device 100.

Upon determining that there is not sufficient power at power module 205 and/or available memory storage at memory 215 (“No”), processor(s) 210 proceeds to step s604 and transmits requested data in the streaming mode—in other words, processor(s) 210 discards the raw and processed data, and transmits solely the requested data comprising interpreted results via the telemetry system 220. In certain embodiments, if the requested data is previously stored raw and processed data, such previously stored data is transmitted at steps s603 and s604.

Next, at step s605, processor(s) 210 determines whether data transmission is completed. If so (“Yes”), process 600 ends. If not (“No”), process 600 returns to step s602 to determine, again, whether there is sufficient power at power module 205 and/or available memory storage at memory 215 to operate in the memory mode. In certain embodiments, processor(s) 210 can execute s605 based upon one or more of an elapsed time, an amount of data transmitted, an amount of energy consumed from power module 205, or the like, upon initiating data transmission at steps s603 and s604. In certain embodiments, step s605 can follow only step s603 to allow for switching from the memory mode to the streaming mode upon reaching or surpassing a low energy storage threshold at power module 205 and step s604 can be executed until process 600 ends upon completion of the data transmission. In certain embodiments, a user control can be provided to a surface computing apparatus (810 and/or 807 in FIG. 8B) to determine operations in either the memory mode or the streaming mode, and a low power alert can be transmitted to the surface computing apparatus (810 and/or 807 in FIG. 8B), for example, for retrieval and maintenance, upon determining that a low energy storage threshold (SOC), e.g., about 5%, has been reached or surpassed.

According to one or more example implementations of the present disclosure, installation mechanism portions 105, cartridge portion 110, and measurement portion 115 are connected to one another via threaded connections for convenient replacements and rearrangements—for example, using a modular structure. In case more measurements are required, dual configurations of measurement portion 115 can be deployed.

FIG. 7 is a schematic diagram illustrating two (2) Raman/optical probe and flowmeter assemblies 330-1 and 330-2 in a tandem configuration according to one or more example implementations of the present disclosure. In certain embodiments, the tandem configuration can be arranged by coupling respective measurement portions 115 to one another via a threaded connection. As illustrated in FIG. 7, an additional Raman/optical probe and flowmeter assembly 330-2 can be connected to the lower end of Raman/optical probe and flowmeter assembly 330-1. Such a dual configuration of the assemblies 330-1 and 330-2 is capable of acquiring further fluid information from the borehole. In certain embodiments, the respective portions 105, 110, and 115 of measurement device 100, as illustrated in FIGS. 1A and 1B, can be rearranged in different configurations without departing from the spirit and the scope of the present disclosure. As one example, an additional measurement portion 115 embodying assembly 330-2 can be disposed between installation mechanism portion 105-1 and cartridge portion 110. According to one or more example implementations, assemblies 330-1 and 330-2 are rotationally offset from each other in relation to a longitudinal axis along measurement device 100—see, for example, axis “A” in FIGS. 1A and 1B. Such a rotational offset provides for circumferential coverage among the flowmeters 410, probes 415, and probes 420 of these assemblies 330-1 and 330-2. According to one or more example implementations, the offset is about 30 degrees. In certain embodiments, the rotational offset can be between 1-119 degrees. These values and ranges correspond to the example implementation illustrated in FIGS. 4A and 4B. Other values and ranges can be implemented based on the number of respective centralizer arms 405, corresponding probes 415/420, and/or flowmeters 410 without departing from the spirit and scope of the present disclosure. In certain embodiments, further additional sonde portions 115-x (x>2; or x<=4) can be deployed.

There are numerous issues related to hydrogen storage using subsurface formations. For example, the biogeochemical changes due to high microbial activity or contamination by other gases, such as hydrogen sulfide and methane, can impact the quality of stored hydrogen. Additionally, the presence of high cushion gas can affect storage performance in terms of delivery rate and working capacity. Advantageously, Raman/optical probe and flowmeter assembly 330 and measurement portion 115 of the present disclosure provides for a specific tool usable with existing infrastructure for hydrogen-specific measurements. FIGS. 8A and 8B are schematic diagrams of measurement device 100 incorporating Raman/optical probe and flowmeter assembly 330 in use according to one or more example implementations of the present disclosure. As illustrated in FIG. 8A, measurement device 100 can be lowered near reservoir region 800 down wellbore 805 in the retracted configuration shown in FIG. 1A. Next, upon reaching a target depth and/or position in wellbore 805, measurement device 100 is affixed against the inner wall of wellbore 805 by expanding installation mechanism portions 105 as illustrated in FIG. 8B. In one or more example implementations, hangers 107 are expanded to exert friction force on a liner (not shown) of the inner wall of wellbore 805. As shown in FIG. 8B, centralizer arms 405 are expanded to a deployment configuration of Raman/optical probe and flowmeter assembly 330. Once measurement device 100 is properly installed, cabling 109 can be detached and withdrawn. Thus, during hydrogen injection to or extraction from reservoir region 800, which can include a depleted hydrocarbon reservoir, enclosed subsurface structural formation, or the like, measurement device 100 with Raman/optical probe and flowmeter assembly 330 is capable of measuring hydrogen flow parameters, concentrations, to name a few. In certain embodiments, measurement portion 115 can be a self-contained tool (sonde) that is lowered to a subsurface location for hydrogen-related measurements. Thus, according to one or more example implementations, a method for determining hydrogen-related parameters-concentration, flow parameters, quantity, to name a few—in a subsurface location, such as a wellbore, comprises deploying and affixing measurement portion 115 to the subsurface location, establishing a communication connection to measurement device 100 using a computing apparatus 810 (and/or interface module 807), and executing process 600 to request and obtain signal data from measurement portion 115 and/or processed/interpreted data from processor(s) 210. Hydrogen injection or extraction can be initiated or terminated before, during, or after each of these steps.

In certain embodiments, measurement portion 115 and Raman/optical probe and flowmeter assembly 330 can be incorporated in a wireline downhole measurement tool for hydrogen monitoring at a subsurface location. A wireline downhole monitoring tool incorporating features of measurement portion 115 and Raman/optical probe and flowmeter assembly 330 is described in commonly-owned and co-pending U.S. patent application Ser. No. 18/635,909 filed on Apr. 15, 2024 under Attorney Docket No. 00501/012187-US0, the entire contents of which are incorporated by reference herein.

According a first example implementation consistent with the present disclosure, a measurement device adapted for positioning at a subsurface location and for determining one or more parameters related to hydrogen at the subsurface location, comprises: one or more hangers adapted to affix the measurement device to the subsurface location; a plurality of centralizer arms forming an interior space having a proximal portion and a distal portion; a plurality of fiber optic Raman probes each disposed at the proximal portion or the distal portion of the interior space and proximate a respective one of the plurality of centralizer arms, said plurality of fiber optic Raman probes being adapted to measure a hydrogen concentration in a downhole measurement; and a plurality of optical probes each disposed at another of the distal portion or the proximal portion of the interior space and proximate a same or different one of the plurality of centralizer arms, said plurality of optical probes being adapted to measure downhole local gas holdup.

In a second example implementation, the measurement device further comprises one or more flowmeters disposed at the proximal portion or the distal portion of the interior space.

In a third example implementation, the measurement device further comprises another one or more flowmeters disposed at another of the proximal portion or the distal portion of the interior space.

In a fourth example implementation, the one or more flowmeters and the another one or more flowmeter are rotationally offset from each other in relation to a longitudinal axis along the measurement device.

In a fifth example implementation, the measurement device of any of the third through fourth example implementations further comprises: one or more power generators coupled to the one or more flowmeters; and one or more energy storage devices coupled to the one or more power generators, wherein said one or more energy storage devices are adapted to store power generated by the one or more power generators via the one or more flowmeters and adapted to supply the stored power to the measurement device.

In a sixth example implementation, the measurement device of any of the preceding example implementations further comprises one or more graphical processing units (GPUs) adapted to process at least signal data obtained from the plurality of fiber optic Raman probes.

In a seventh example implementation, the measurement device of the sixth example implementation further comprises a communication interface adapted to transmit interpretation data from the one or more GPUs to a surface computing apparatus.

In an eighth example implementation, the measurement device of the seventh example implementation further comprises a memory, wherein the one or more GPUs are adapted to operate in one of a first mode and a second mode, the first mode comprises storing, in the memory, raw and processed data used for generating the interpretation data, and the second mode comprises discarding the raw and processed data.

In a ninth example implementation, the plurality of fiber optic Raman probes and the plurality of optical probes of any of the preceding example implementations are disposed at respective interior perimeters having diameters that are fractions of respective outer circumference diameters formed by the plurality of centralizer arms.

In a tenth example implementation, the plurality of fiber optic Raman probes of any of the preceding example implementations are disposed proximate same ones of the plurality of centralizer arms as the plurality of optical probes.

In an eleventh example implementation, the plurality of fiber optic Raman probes of any of the preceding example implementations are disposed proximate different ones of the plurality of centralizer arms from the plurality of optical probes.

In a twelfth example implementation, the plurality of centralizer arms of any of the preceding example implementations are bowspring centralizer arms.

In a thirteenth example implementation, the plurality of fiber optic Raman probes of any of the preceding example implementations are adapted to detect signal bands of hydrogen molecules.

In a fourteenth example implementation, the plurality of fiber optic Raman probes of the thirteenth example implementation are adapted to detect signal spectra with wavenumbers at about 4,100-4,175 cm⁻¹.

In a fifteenth example implementation, the measurement device of the fourteenth example implementation further comprises a temperature probe and a pressure probe, wherein the detected signal with wavenumbers at about 4,125-4,165 cm⁻¹ are processed based on one or more of a temperature determined using the temperature probe and a pressure determined using the pressure probe.

In a sixteenth example implementation, the plurality of centralizer arms of any of the first through eleventh and thirteenth through fifteenth example implementations comprise at least six (6) bowspring centralizer arms, and the fiber optic Raman probes of any of the first through eleventh and thirteenth through fifteenth example implementations comprise six (6) fiber optic Raman probes that are disposed proximate respective ones of the at least six (6) centralizer arms at 60 degrees from one another around an interior perimeter of the measurement device.

In a seventeenth example implementation, the plurality of optical probes of the sixteenth example implementation comprise six (6) optical probes that are disposed proximate respective ones of the at least six (6) centralizer arms at 60 degrees from one another around another interior perimeter of the measurement device.

According an example implementation consistent with the present disclosure, method for determining one or more parameters related to hydrogen at a subsurface location, comprises: affixing a measurement device to the subsurface location with one or more hangers; and receiving data from the measurement device, wherein the measurement device comprises: a plurality of centralizer arms forming an interior space having a proximal portion and a distal portion; a plurality of fiber optic Raman probes each disposed at the proximal portion of the interior space and proximate a respective one of the plurality of centralizer arms, said plurality of fiber optic Raman probes being adapted to measure a hydrogen concentration in a downhole measurement; and a plurality of optical probes each disposed at the distal portion of the interior space and proximate a same or different one of the plurality of centralizer arms, said plurality of optical probes being adapted to measure downhole local gas holdup.

In one or more example implementations, the data received from the measurement device comprises interpretation data generated using one or more graphical processing units (GPUs) disposed in the measurement device.

In one or more example implementations, the one or more GPUs are adapted to operate in one of a first mode and a second mode, the first mode comprises storing, in a memory, raw and processed data used for generating the interpretation data, and the second mode comprises discarding the raw and processed data.

Portions of the methods described herein can be performed by software or firmware in machine readable form on a tangible (e.g., non-transitory) storage medium. For example, the software or firmware can be in the form of a computer program including computer program code adapted to cause the system to perform various actions described herein when the program is run on a computer or suitable hardware device, and where the computer program can be embodied on a computer readable medium. Examples of tangible storage media include computer storage devices having computer-readable media such as disks, thumb drives, flash memory, and the like, and do not include propagated signals. Propagated signals can be present in a tangible storage media. The software can be suitable for execution on a parallel processor or a serial processor such that various actions described herein can be carried out in any suitable order, or simultaneously.

The headings used herein are for organizational purposes only and are not meant to be used to limit the scope of the description or the claims. As used throughout this application, the words “may” and “can” are used in a permissive sense (i.e., meaning having the potential to), rather than the mandatory sense (i.e., meaning must). To facilitate understanding, like reference numerals have been used, where possible, to designate like elements common to the figures. In certain instances, a letter suffix following a dash ( . . . -b) denotes a specific example of an element marked by a particular reference numeral (e.g., 210-b). Description of elements with references to the base reference numerals (e.g., 210) also refer to all specific examples with such letter suffixes (e.g., 210-b), and vice versa.

It is to be further understood that like or similar numerals in the drawings represent like or similar elements through the several figures, and that not all components or steps described and illustrated with reference to the figures are required for all embodiments or arrangements.

The terminology used herein is for the purpose of describing particular embodiments only and is not intended to be limiting of the disclosure. As used herein, the singular forms “a,” “an,” and “the” are intended to include the plural forms as well, unless the context clearly indicates otherwise. It will be further understood that the terms “contains”, “containing”, “includes”, “including,” “comprises”, and/or “comprising,” and variations thereof, when used in this specification, 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, and are meant to encompass the items listed thereafter and equivalents thereof as well as additional items.

Terms of orientation are used herein merely for purposes of convention and referencing and are not to be construed as limiting. However, it is recognized these terms could be used with reference to an operator or user. Accordingly, no limitations are implied or to be inferred. In addition, the use of ordinal numbers (e.g., first, second, third) is for distinction and not counting. For example, the use of “third” does not imply there is a corresponding “first” or “second.” Also, the phraseology and terminology used herein is for the purpose of description and should not be regarded as limiting.

While the disclosure has described several example implementations, it will be understood by those skilled in the art that various changes can be made, and equivalents can be substituted for elements thereof, without departing from the spirit and scope of the disclosure. In addition, many modifications will be appreciated by those skilled in the art to adapt a particular instrument, situation, or material to embodiments of the disclosure without departing from the essential scope thereof. Therefore, it is intended that the disclosure not be limited to the particular embodiments disclosed, or to the best mode contemplated for carrying out this disclosure, but that the disclosure will include all embodiments falling within the scope of the appended claims.

The subject matter described above is provided by way of illustration only and should not be construed as limiting. Various modifications and changes can be made to the subject matter described herein without following the example embodiments and applications illustrated and described, and without departing from the true spirit and scope encompassed by the present disclosure, which is defined by the set of recitations in the following claims and by structures and functions or steps which are equivalent to these recitations.