Apparatus and Method for Positioning a Measurement Device at a Subsurface Location to Conduct In-Situ Monitoring of Hydrogen Levels

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.

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.

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.

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.

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 cmare 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.

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.

is a schematic diagram illustrating a measurement devicein a retracted state according one or more example implementations of the present disclosure. As illustrated in, measurement devicecomprises a pair of installation mechanism portions-and-at respective proximal and distal ends. In one or more example implementations, installation mechanism portions-and-incorporate respective liner hangers-and-that are expandable to engage and grip an interior liner of a wellbore (in) for installing measurement deviceat a location down the wellbore. Hangers-and-are shown in retracted states infor when measurement deviceis lowered into a wellbore (see). Accordingly, installation mechanism portion-is detachably coupled to cablingfor lowering measurement devicedown a wellbore (in). In certain embodiments, one or more connections via cablingcan be established to one or more surface apparatuses, such as an operator console (in) and the like, for communications with the surface.

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

As illustrated in, measurement devicefurther comprises a cartridge portionand a measurement portion. In one or more example implementations, measurement portionembodies a sonde or probe that includes the components described and shown with reference to. 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 devicehas 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. In the deployed state illustrated in, hangers-and-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 portionhosts the power and communication instrumentations of measurement deviceand measurement portionincorporates 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, measurement portionincorporates a plurality of centralizer armsthat are coupled at their respective upper/proximal and lower/distal portions to measurement portion—for example, a central shaft elementof measurement portion.

Accordingly, in certain embodiments, measurements taken by the instrumentation at measurement portioncan be recorded at cartridge portion, transmitted from memory and/or streamed in real time via cabling (e.g.,) and/or a wireless communication (e.g.in) for interpretation. Acquisition and interpretation software can be executed to process the raw data received from measurement deviceand 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—for example, processor(s)in cartridge portionin. In certain embodiments, at least portions of the software can be executed by one or more processors (not shown) incorporated in measurement portion.

is a schematic diagram illustrating the operating components of cartridge portionaccording to one or more example implementations of the present disclosure. As illustrated in, cartridge portionincorporates a power module, one or more processor devices, a memory, and a communication interface/telemetry recorder.

Power moduleis a power source for other operating components of cartridge portion. In certain embodiments, power modulecan be a power source for the overall measurement device, including operating components of measurement portion. According to one or more example implementations, power moduleincorporates a power generation mechanism that captures and stores energy using one or more flowmeters, as discussed in further detail with reference to. In certain embodiments, power modulecan 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)and memoryare embodied by a field programmable gate array (FPGA) based processing unit to record, process, and transfer the data recorded by measurement deviceto 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. 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)and/or memory device(s), 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)comprise one or more graphics processing units (GPUs) for the computation and analysis of data obtained by measurement device. Correspondingly, memorycan 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)can operate in a memory mode or a streaming mode. In the memory mode, the GPU, processor(s), stores raw and processed data in memory, and transmits interpreted information via the telemetry system. In the streaming mode, the GPU, processor(s), discards the raw and processed data, and transmits solely the interpreted results via the telemetry system. A difference between the streaming mode and the memory mode is that the streaming mode significantly reduces data storage requirements of memoryand, hence, is able to operate longer as compared to the memory mode based on power consumption. In certain embodiments, processor(s)determines between operating in the streaming and memory modes based on a remaining power available at power module, an expected remaining operating time of measurement device, a communication status with a surface computing device (and/orin), a power generation rate of power module, available memory storage in memory, a scheduled maintenance time, to name a few.

Communication interface/telemetry recorderincorporates electronics adapted to relay data obtained by measurement deviceto the surface—for example, one or more computing apparatuses (in) operating at the surface and in communication with measurement device. In embodiments, communication interfacecan include any suitable hardware (e.g., hardware for wired and/or wireless connections) and/or software interface among the operating components of measurement deviceand one or more computing apparatuses (in) at the surface. According to one or more example implementations, communication interfaceincludes interconnections between the sensors of measurement deviceand processor(s)and memoryfor relaying, processing, and recording the data from the sensors. In embodiments, communication interfacecan further include wired and/or wireless connections for relaying raw and/or processed data to one or more apparatuses (in) at the surface. In one or more example implementations, communication interface/telemetry recorderis in wireless communication with a surface interface module (in) for recording and/or relaying data obtained by measurement deviceto a surface terminal device (in). In certain embodiments, one or more signal repeaters (not shown) can be deployed along a wellbore (in) to relay signals between communication interface/telemetry recorderand its surface interface module (in). Data obtained by measurement devicecan be received by a surface terminal device (in) via wired or wireless communications with surface interface module (in).

is a schematic diagram illustrating operating components of measurement portionaccording to one or more example implementations of the present disclosure. As illustrated in, measurement portionincorporates one or more pressure probes, one or more temperature probe(s), one or more gradiomanometers, and a Raman/optical probe and flowmeter assembly.

Pressure probe(s)and temperature probe(s)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 deviceis deployed. In embodiments, pressure probe(s)and temperature probe(s)can be oriented to detect localized pressure and temperature parameters in cooperation with one or more of the other sensors of measurement device—for example, for determining the flow characteristics and/or concentration of hydrogen in the subsurface environment.

Gradiomanometer(s)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 (in). Thus, a fluid density at a subsurface location can be determined by measurement device.

In certain embodiments, measurement portioncan 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 (in). In certain embodiments, measurement portioncan 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 (in).

is a cross-sectional view along line B in theA-A direction inshowing a first portionof Raman/optical probe and flowmeter assemblyin measurement portion.is a cross-sectional view along line B in theB-B direction inshowing a second portionof Raman/optical probe and flowmeter assemblyin measurement portion. Referring to, bandmarks a location from the upper/proximal end of centralizer armsthat is about one quarter (¼) to one third (⅓) of the total length spanning centralizer armsalong a central longitudinal axis “A” of measurement portion. Correspondingly, bandinmarks a location from the lower/distal end of centralizer armsthat is about one quarter (¼) to one third (⅓) of the total length spanning centralizer armsalong a central longitudinal axis “A” of measurement portion. Thus,provides an upward (or proximal) interior view of an upper (or proximal) portion of measurement portionanda downward (or distal) interior view of a lower (or distal) portion of measurement portion. In accordance with one or more example implementations of the present disclosure, measurement portionhas 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—of centralizer arms.

As illustrated in, measurement portioncomprises, consists essentially of, or consists of twelve (12) bowspring centralizer arms-, . . . ,-that are coupled to measurement portionat their respective upper/proximal and bottom/distal portions. According to one or more example implementations and as illustrated in, centralizer armsare coupled at their upper/proximal portions to a central shaft portion, which can be coupled to cartridge portion, and, as illustrated in, centralizer armsare coupled and at their lower/distal portions to a central shaft portion. Centralizer armsthereby form an expanded interior space in measurement portion. 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, central shaft portionextends along an entire length of the interior space formed by centralizer arms. In certain embodiments, central shaft portioncan be disconnected between the upper/proximal and lower/distal portions.

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

According to one or more example implementations, flowmeters-,-, and-are disposed proximate to—for example, mounted on-interior surfaces of centralizer arms-,-, and-, respectively. Correspondingly, as illustrated in, three (3) flowmeters-,-, and-are disposed across a lower or distal portion of an expanded interior space formed by centralizer arms, for example, at bandin. According to one or more example implementations, flowmeters-,-, and-are disposed proximate to—for example, mounted on-interior surfaces of centralizer arms-,-, and-, respectively. As shown in, flowmeters-,-, and-are disposed around an interior perimeter at about one half (½) to about three quarters (¾) diameter of the diameter of outer circumference-of measurement portion, for example, at bandof. According to one or more example implementations, outer circumference-has a diameter of about 12.1 cm (or about 4¾ inches), or the OD at line “B” in. Correspondingly, as shown in, flowmeters-,-, and-are disposed around an interior perimeter at about one half (½) to about three quarters (¾) diameter of the diameter of outer circumference-of measurement portion, for example, at bandof. According to one or more example implementations, outer circumference-has a diameter of about 12.1 cm (or about 4¾ inches), or the OD at line “B” in. Thus, flowmetersare disposed in an expanded interior space formed by centralizer armsat locations that are away from the maximum outer circumference of the interior space—for example, at line “B” shown in. As such, flowmetersare 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, flowmeterscan be disposed at different locations on interior and/or exterior portions of measurement portionwithout departing from the spirit and scope of the present disclosure. In certain embodiments, flowmeterscan 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-,-,-,-,-, and-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, six (6) fiber optic Raman probes-, . . . ,-are disposed around an interior perimeter at about one half (½) to about three quarters (¾) diameter of the outer circumference diameter-of measurement portion, for example, at bandof. According to one or more example implementations, probes-, . . . ,-are disposed proximate to—for example, mounted on-interior surfaces of respective arms-,-,-,-,-, and-as shown in. In other words, Raman probes-, . . . ,-are disposed in an upper or proximal portion of an expanded interior space formed by centralizer armsand at locations that are away from the maximum outer circumference of the interior space, or the outer circumference-, for example, at line “B” shown in. Accordingly, probeswould be disposed away from a wellbore wall when measurement portionis deployed. Probes, as arranged in, provide coverage around an interior perimeter of measurement portion, with a probedisposed every 60 degrees around the interior perimeter. In certain embodiments, more or fewer probescan be disposed at regular or irregular intervals, or at particular positions depending upon the deployment environment of measurement device.