GB2575283A - Pipeline monitoring system, method, and apparatus - Google Patents

Pipeline monitoring system, method, and apparatus Download PDF

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Publication number
GB2575283A
GB2575283A GB1810975.1A GB201810975A GB2575283A GB 2575283 A GB2575283 A GB 2575283A GB 201810975 A GB201810975 A GB 201810975A GB 2575283 A GB2575283 A GB 2575283A
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Prior art keywords
fluid
hydrogen
monitoring
characteristic
pipeline
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GB201810975D0 (en
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Knight Jeremy
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Orbital Gas Systems Ltd
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Orbital Gas Systems Ltd
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Priority to GB1810975.1A priority Critical patent/GB2575283A/en
Publication of GB201810975D0 publication Critical patent/GB201810975D0/en
Priority to PCT/GB2019/051759 priority patent/WO2020008168A1/en
Publication of GB2575283A publication Critical patent/GB2575283A/en
Withdrawn legal-status Critical Current

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    • C—CHEMISTRY; METALLURGY
    • C01—INORGANIC CHEMISTRY
    • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
    • C01B3/00—Hydrogen; Gaseous mixtures containing hydrogen; Separation of hydrogen from mixtures containing it; Purification of hydrogen
    • C01B3/0005—Reversible uptake of hydrogen by an appropriate medium, i.e. based on physical or chemical sorption phenomena or on reversible chemical reactions, e.g. for hydrogen storage purposes ; Reversible gettering of hydrogen; Reversible uptake of hydrogen by electrodes
    • C—CHEMISTRY; METALLURGY
    • C01—INORGANIC CHEMISTRY
    • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
    • C01B3/00—Hydrogen; Gaseous mixtures containing hydrogen; Separation of hydrogen from mixtures containing it; Purification of hydrogen
    • C01B3/0005—Reversible uptake of hydrogen by an appropriate medium, i.e. based on physical or chemical sorption phenomena or on reversible chemical reactions, e.g. for hydrogen storage purposes ; Reversible gettering of hydrogen; Reversible uptake of hydrogen by electrodes
    • C01B3/001—Reversible uptake of hydrogen by an appropriate medium, i.e. based on physical or chemical sorption phenomena or on reversible chemical reactions, e.g. for hydrogen storage purposes ; Reversible gettering of hydrogen; Reversible uptake of hydrogen by electrodes characterised by the uptaking medium; Treatment thereof
    • C01B3/0021—Carbon, e.g. active carbon, carbon nanotubes, fullerenes; Treatment thereof
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17D—PIPE-LINE SYSTEMS; PIPE-LINES
    • F17D3/00—Arrangements for supervising or controlling working operations
    • F17D3/03—Arrangements for supervising or controlling working operations for controlling, signalling, or supervising the conveyance of several different products following one another in the same conduit, e.g. for switching from one receiving tank to another
    • F17D3/05—Arrangements for supervising or controlling working operations for controlling, signalling, or supervising the conveyance of several different products following one another in the same conduit, e.g. for switching from one receiving tank to another the different products not being separated
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N1/00—Sampling; Preparing specimens for investigation
    • G01N1/02—Devices for withdrawing samples
    • G01N1/10—Devices for withdrawing samples in the liquid or fluent state
    • G01N1/20—Devices for withdrawing samples in the liquid or fluent state for flowing or falling materials
    • G01N1/2035—Devices for withdrawing samples in the liquid or fluent state for flowing or falling materials by deviating part of a fluid stream, e.g. by drawing-off or tapping
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N1/00—Sampling; Preparing specimens for investigation
    • G01N1/02—Devices for withdrawing samples
    • G01N1/22—Devices for withdrawing samples in the gaseous state
    • G01N1/2247—Sampling from a flowing stream of gas
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N25/00—Investigating or analyzing materials by the use of thermal means
    • G01N25/18—Investigating or analyzing materials by the use of thermal means by investigating thermal conductivity
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N27/00—Investigating or analysing materials by the use of electric, electrochemical, or magnetic means
    • G01N27/02—Investigating or analysing materials by the use of electric, electrochemical, or magnetic means by investigating impedance
    • G01N27/04—Investigating or analysing materials by the use of electric, electrochemical, or magnetic means by investigating impedance by investigating resistance
    • G01N27/14—Investigating or analysing materials by the use of electric, electrochemical, or magnetic means by investigating impedance by investigating resistance of an electrically-heated body in dependence upon change of temperature
    • G01N27/18—Investigating or analysing materials by the use of electric, electrochemical, or magnetic means by investigating impedance by investigating resistance of an electrically-heated body in dependence upon change of temperature caused by changes in the thermal conductivity of a surrounding material to be tested
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N33/00—Investigating or analysing materials by specific methods not covered by groups G01N1/00 - G01N31/00
    • G01N33/0004—Gaseous mixtures, e.g. polluted air
    • G01N33/0009—General constructional details of gas analysers, e.g. portable test equipment
    • G01N33/0011—Sample conditioning
    • G01N33/0014—Sample conditioning by eliminating a gas
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N33/00—Investigating or analysing materials by specific methods not covered by groups G01N1/00 - G01N31/00
    • G01N33/0004—Gaseous mixtures, e.g. polluted air
    • G01N33/0009—General constructional details of gas analysers, e.g. portable test equipment
    • G01N33/0027—General constructional details of gas analysers, e.g. portable test equipment concerning the detector
    • G01N33/0036—General constructional details of gas analysers, e.g. portable test equipment concerning the detector specially adapted to detect a particular component
    • G01N33/005—H2
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E60/00—Enabling technologies; Technologies with a potential or indirect contribution to GHG emissions mitigation
    • Y02E60/30—Hydrogen technology
    • Y02E60/32—Hydrogen storage

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  • Chemical & Material Sciences (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Health & Medical Sciences (AREA)
  • Immunology (AREA)
  • General Physics & Mathematics (AREA)
  • Biochemistry (AREA)
  • Physics & Mathematics (AREA)
  • General Health & Medical Sciences (AREA)
  • Analytical Chemistry (AREA)
  • Pathology (AREA)
  • Combustion & Propulsion (AREA)
  • Organic Chemistry (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • Food Science & Technology (AREA)
  • Medicinal Chemistry (AREA)
  • Inorganic Chemistry (AREA)
  • Mechanical Engineering (AREA)
  • Electrochemistry (AREA)
  • General Engineering & Computer Science (AREA)
  • Hydrology & Water Resources (AREA)
  • Biomedical Technology (AREA)
  • Molecular Biology (AREA)
  • Materials Engineering (AREA)
  • Nanotechnology (AREA)
  • Investigating Or Analyzing Materials Using Thermal Means (AREA)
  • Investigating Or Analyzing Materials By The Use Of Electric Means (AREA)

Abstract

A pipeline monitoring system 10 for monitoring a transport fluid in a pipeline 12 and which in part contains hydrogen, the system comprises a first fluid flow path, a second fluid flow path, and a hydrogen-separation element 24 positioned on the first fluid path and which separates hydrogen from the transport fluid, monitoring means for monitoring a characteristic of a fluid, which comprises a first detector 20a on the first fluid flow path downstream of the hydrogen-separation element and a second detector 20b on the second fluid flow path, and determining means for determining a hydrogen concentration of the transport fluid based on a difference of the said characteristics monitored by the monitoring means. A method and apparatus relating to the system is also disclosed. The hydrogen separation element may be a metal hydride hydrogen storage element or a solely-hydrogen porous material, such as a nano-material and/or palladium. The nano-material may comprise a nanotube formed from grapheme or grapheme oxide, or a boron nitride. The first and second detectors may be coupled by a Wheatstone bridge circuit as a thermal conductivity sensor.

Description

The present invention relates to a pipeline monitoring system, which is suitable but not necessarily exclusively for monitoring a transport fluid in a pipeline and which in part contains hydrogen. The invention further relates to a method of monitoring a transport fluid in a pipeline which in part contains hydrogen, and also to a transport fluid monitoring apparatus.
There is an increasing move towards a reduction in carbon dioxide emissions globally, and in particular as a result of the combustion of fossil fuels, such as natural gas. One possible option to achieve this is to add hydrogen gas to natural gas within the natural gas grids and networks, since hydrogen gas is carbon-free. Increasing relative percentages of hydrogen gas to natural gas are now used, with an eventual goal of complete decarbonisation of the fuel supply.
The addition of hydrogen gas to the natural gas functions in two ways. Firstly, the burning of hydrogen releases no carbon dioxide, and therefore the addition of hydrogen results in a direct reduction in carbon emissions. There are several ways in which hydrogen can be produced for bulk and continuous contribution to the energy supply.
Secondly, hydrogen is an effective energy storage medium. By converting excessive inconveniently-timed generation of electrical energy from wind and solar processes into hydrogen and inj ecting it into the gas grids allows for the efficient use of the total installed capacity of wind and solar generation means, which are notoriously dependent on environmental conditions to operate. Hydrogen storage allows for the output of the renewable energy sources to be stored without needing to shut down electricity production from conventional power generators in the interim period.
There are, however, issues with the implementation of a hydrogen-doped natural gas supply. At present, it is only safe to add a maximum of 20% concentration of hydrogen within a mixed-gas stream. It is therefore extremely important to be able to safely monitor the hydrogen concentration to ensure that safe operating conditions are maintained.
Furthermore, the addition of hydrogen reduces the calorific value of the natural gas supply per volume. Numerous additional calorific value measurement stations are therefore required to ensure that fair metering and/or billing of energy consumption is maintained across the distribution network according to the hydrogen concentration at the point of delivery.
The measurement of the energy content of natural gas is well-known; however, existing technologies are not capable of functioning accurately once hydrogen has been introduced. As such, additional hydrogen sensors must be provided in order to measure the hydrogen concentration to be able to validate other measurements made on the mixed-gas stream. Such hydrogen measurement devices are slow to operate and expensive, which places a massive strain on the analysis requirements of monitoring the natural gas supply.
The present invention seeks to provide a pipeline monitoring system which removes the need for a dedicated hydrogen probe in order to overcome or obviate the above-referenced problems.
According to a first aspect of the invention, there is provided a pipeline monitoring system for monitoring a transport fluid in a pipeline and which in part contains hydrogen, the system comprising: a first fluid flow path; a second fluid flow path; a hydrogen-separation element positioned on the first fluid path and which removes hydrogen from the transport fluid; monitoring means for monitoring a characteristic of a fluid, the monitoring means comprising a first detector on the first fluid flow path downstream of the hydrogenseparation element and a second detector on the second fluid flow path; and determining means for determining a hydrogen concentration of the transport fluid based on a difference of the said characteristics monitored by the monitoring means.
The ability to monitor a hydrogen concentration of a transport fluid by relative detection of a characteristic of first and second streams, one of which having the hydrogen removed therefrom, advantageously eliminates the need for a dedicated hydrogen probe to be provided in addition to a standard monitoring probe for the bulk transport fluid. A relative comparison of physical characteristics can be executed much more rapidly than an absolute measurement of hydrogen concentration, which allows for analysis of the transport fluid to be undertaken in-line or in real-time.
The term ‘transport fluid’ used herein and throughout in this case is, but not necessarily limited to, an energy-supply gas. An energy-supply gas is intended to preferably, but not necessarily exclusively, mean normal natural gas as found in oil and gas wells, as well as other forms of energy gases and their substitutes such as bio-gas, coal bed methane, synthetic natural gas that may be transported in a conventional natural gas network or network suitable for such transport. These kinds of said gases as well as their substitutes are all defined within the international standards overseen by ISO TCI97, and are incorporated herein by reference.
In one embodiment, the hydrogen-separation element may comprise a metal hydride hydrogen storage element. The hydrogen-separation element may be a soley hydrogenporous material. In this case, the solely Hydrogen-porous material may be a nano-material and/or Palladium, for example. Conveniently, the nano-material may be a carbon nanotube formed from graphene or graphene oxide, or a boron nitride nanotube.
The first and second detectors of the monitoring means may be coupled by a Wheatstone bridge circuit to act as a thermal conductivity gas sensor. Additonally or alternatively, the first and second detectors may be the same detector. In this case, for example, the two fluid flow paths may include a divertor to enable a single detector to effectively act as a detector on each flow path.
Optionally, the determining means may comprise a processor connected to the thermal conductivity gas sensor to determine the hydrogen concentration of the transport fluid.
A Wheatstone bridge circuit is a simple circuit configuration which allows for ready comparison of differing resistances, as produced by the different thermal conductivities detected at the first and second detectors. The relative resistances allow for a rapid calculation to be made which is indicative of the hydrogen concentration in the transport fluid.
The first and second fluid flow paths may be at least in part parallel or substantially parallel to one another.
Parallelization of the flows in the two paths mitigates the effects of unexpected forces being realised in the different flow paths, whilst also maintaining the positioning of the detectors in close proximity to one another. This allows for the creation of a compact detector unit.
Optionally, the second fluid flow path may be coincident with a flow path of the pipeline to be monitored.
It may be desirable to ensure that the relative sensing of the transport fluid be carried out with reference to the bulk fluid in the main pipeline. This may provide the most accurate reading by avoiding any local inconsistencies in the hydrogen concentration in a smaller sample.
The system may further comprise a fluid-characteristic sensor which is positionable on the first fluid flow path downstream of the hydrogen-separation element, the fluidcharacteristic sensor being adapted to monitor at least one further characteristic which is different to the characteristic monitored by the monitoring means.
Optionally, the at least one further characteristic may comprise at least one of: calorific value; Wobbe index; relative density; compression factor; methane number; density; thermal conductivity; primary influencing inert gas; carbon dioxide emission factor; and total concentration.
There are many characterising properties of a transport fluid which may be desirable to monitor, which may otherwise be offset by the presence of hydrogen. It is therefore beneficial to monitor these characteristics in the treated-flow region created downstream of the hydrogen-separation element.
According to a second aspect of the invention, there is provided a method of monitoring a transport fluid in a pipeline which in part contains hydrogen, the method comprising the steps of: a] diverting the transport fluid along first and second fluid flow paths; b] providing a hydrogen-separation element positioned on the first fluid path and which removes hydrogen from the transport fluid; c] monitoring a characteristic of the fluid on the first fluid flow path downstream of the hydrogen-separation element and monitoring the same characteristic of the fluid on the second fluid flow path; and d] determining a hydrogen concentration of the transport fluid based on a difference of the monitored characteristics.
Preferably, the transport fluid may comprise a mixture of an energy-supply gas and hydrogen gas.
Optionally, the monitored characteristic may be thermal conductivity.
The method may further comprise a step e] subsequent to step d] of monitoring at least one further characteristic downstream of the hydrogen-separation element on the first fluid flow path; and step f] of normalising a measurement of the or each further characteristic based on the determined hydrogen concentration.
According to a third aspect of the invention, there is provided a transport fluid monitoring apparatus comprising: a first fluid monitoring conduit adapted to receive or connect to a first detector; a second fluid monitoring conduit adapted to receive or connect to a second detector; and a hydrogen-separation element positioned on the first fluid path for removing hydrogen from a transport fluid.
A dedicated apparatus which can be engaged with existing fluid pipelines and which obviates the need for dedicated hydrogen-concentration probes advantageously improves the ability to monitor the transport fluid to be metered.
The apparatus preferably further comprises a fluid inlet port and a fluid flow splitter for diverting transport fluid from the fluid inlet port into both the first and second fluid monitoring conduits.
The provision of a specific flow splitter ensures that the fluid entering into the two conduits has been received from the same source, and therefore the user can be assured that the hydrogen-depleted fluid is compared with the original transport fluid for accurate comparison.
Optionally, the first and second fluid monitoring conduits may be provided as a unitary component.
The provision of a unitary element having both conduits allows for a compact sensor arrangement to be engaged with an existing pipeline, without needing a plurality of different modifications.
The apparatus may optionally further comprise monitoring means for monitoring a characteristic of a fluid, the monitoring means comprising a first detector on the first fluid monitoring conduit downstream of the hydrogen-separation element and a second detector on the second fluid monitoring conduit; and determining means for determining a hydrogen concentration of the transport fluid based on a difference of the said characteristics monitored by the monitoring means.
Preferably, there may also be provided a fluid-characteristic monitoring device which is engagable with the first fluid monitoring conduit downstream of the first probe, the fluidcharacteristic monitoring device being adapted to monitor at least one further characteristic which is different to the characteristic monitored by the monitoring means.
The invention will now be more particularly described, by way of example only, with reference to the accompanying drawings, in which:
Figure 1 shows a side representation of a first embodiment of a pipeline monitoring system in accordance with the first aspect of the invention; and
Figure 2 shows a side representation of a second embodiment of a pipeline monitoring system in accordance with the first aspect of the invention, utilising a transport fluid monitoring apparatus in accordance with the third aspect of the invention.
Referring to Figure 1, there is shown a pipeline monitoring system, indicated globally at 10, which is suitable for monitoring a transport fluid in a pipeline, the transport fluid being a mixed fluid which in part contains hydrogen, preferably transported in the gas phase. Typically, the transport fluid would be a mixture of natural gas and hydrogen. In this context, natural gas shall mean conventional natural gas, natural gas substitutes, and mixtures incorporating natural gas, including gaseous fuel such as biogas, biomethane, syngas from methanation, coalbed methane, shale gas, and wet gas, as well as natural gas from liquefied natural gas. At present, this arrangement is likely to be restricted to fluids in the gaseous phase.
The pipeline 12 shown has at least two ports 14a, 14b thereon via which monitoring equipment can be engaged. To the first of these ports 14a is attached a referencing pipe
16, from which measurements can be made on the transport fluid having been modified to remove the hydrogen.
The referencing pipe 16 is here provided as a flanged tube having a first flange 18a which is connectable to the first port 14a of the pipeline 12, a second flange 18b which is connectable to a first detector 20a, and a third flange 18c which is connectable to a fluidcharacteristic sensor 22. The referencing pipe 16 therefore defines a first fluid flow path which is different to the flow path of the pipeline 12.
There is provided a hydrogen-separation element 24 in the referencing pipe 16, here proximate the first flange 18a. In other words, the hydrogen-separation element 24 is positionable near to the first port 14a of the pipeline 12 such that a first fluid flow path through the referencing pipe 16 must pass through the hydrogen-separation element 24.
As such, it may be preferred that the hydrogen-separation element 24 be positioned so as to be off-centre within the referencing pipe 16, to thereby create a hydrogen-capture region following the first flange 18a, which in turn leads into a treated-flow region of the referencing pipe 16.
The hydrogen-separation element 24 preferably comprises a metal hydride hydrogen storage element, and/or could comprise a nano-material, such as a carbon nanotube formed from graphene or graphene oxide, or a boron nitride nanotube. The hydrogenseparation element 24 in this case captures the hydrogen, but may ultimately release the hydrogen by venting. The hydrogen-separation element can be considered to be or include a soley hydrogen-porous material, and in addition to the above-mentioned nano-matieral, other materials such as Palladium may be conveniently considered to separate the hydrogen.
A second detector 20b is also provided, and in the depicted embodiment is positionable on the second port 14b to provide a comparable measurement to that produced
The first and second detectors 20a are provided as part of a device which is arranged to be able to detect a characteristic of fluid, from which a hydrogen concentration can be determined comparatively. In this instance, the first detector 20a and second detector 20b together form a thermal conductivity detector, which is able to provide a reading for subsequent measurements which is indicative of the hydrogen concentration in the pipeline 10.
The thermal conductivity detector is preferably formed as an electrically heated filament in a temperature-controlled cell. The first and second detectors 20a, 20b form part of a Wheatstone bridge circuit 26, which allows for accurate adjustment of any subsequent measurements made on the hydrogen-depleted fluid following the hydrogen-separation element 24. Such measurements can be performed by the fluid-characteristic sensor 22.
A processor 28 is provided which is coupled to the thermal conductivity detector, and which is capable of interpreting the output thereof to determine a hydrogen concentration of the transport fluid in the pipeline 12, based on the monitored thermal conductivities. This can then be used to calibrate the fluid-characteristic sensor 22 measurement and/or the hydrogen concentration determined can be used for other purposes, for example, accurate determination of a cost of the transport fluid transported, based on its calorific value.
The fluid-characteristic sensor 22 is preferably provided as a combined sensor which is able to monitor at least one, and preferably a plurality of different characteristics and/or physical or chemical properties of the hydrogen-depleted transport fluid. These further characteristics may include any or all: calorific value; Wobbe index; relative density; compression factor; methane number; density; thermal conductivity; primary influencing inert gas; carbon dioxide emission factor; and total concentration.
In operation, transport fluid flows through the pipeline 12, typically being a mixture of natural gas and hydrogen, though it will be appreciated that the present arrangement could readily be implemented for any transport fluid comprising a hydrogen component. Indeed, it may be that the present invention could substitute the hydrogen-separation element 24 for a capture element of a different component of the transport fluid, in order to provide calibrated measurements of the remaining fluid.
The transport fluid then flows into the first port 14a and the second port 14b as offshoots from the main pipeline 12. The transport fluid flowing through the first port 14a enters the referencing pipe 16 and passes across the hydrogen-separation element 24. Hydrogen is then removed from the transport fluid, preferably being completely removed therefrom, by capture at the hydrogen-separation element 24, for example, by complexation, absorption or adsorption.
It is preferred that the first and second ports 14a, 14b be in continuous fluid communication with the pipeline 12, since the structure of thermal conductivity detectors is such that the absence of a fluid flow can result in damage to the relevant filament. However, it may be possible to provide a sealing valve to be able to isolate the first and second detectors 20a, 20b and/or the fluid-characteristic sensor 22 from the pipeline 12.
The hydrogen-depleted flow which is then produced downstream of the hydrogenseparation element 24 can be measured by the first detector 20a and/or the fluidcharacteristic sensor 22. Simultaneously, the transport fluid can be measured by the second detector 20b, having entered through the second port 14b, the transport fluid having physical properties which correspond with those of the bulk flow of transport fluid. In this sense, either the pipeline 12 and/or the second port 14b can be considered to be a second fluid flow path along which untreated transport fluid can flow, and subsequently be detected by the second detector 20b.
The comparison between the physical properties of the transport fluid as detected by the second detector 20b, and the hydrogen-depleted flow detected by the first detector 20a, can be analysed by the processor 28. The operation of the Wheatstone bridge circuit 26 is based on the fact that the properties of the natural gas in a hydrogen-depleted state are known, and therefore the comparative measurement of the thermal conductivity, which creates a differential resistance within the Wheatstone bridge circuit 26, allows for the determination of the hydrogen concentration of the transport fluid.
Using this arrangement, the hydrogen concentration is determinable for metering and/or billing purposes. The calorific value, for example, of the hydrogen-depleted natural gas can be determined by the fluid-characteristic sensor 22, and then a calibration can be made based on the determined difference in the hydrogen concentration in the bulk flow of the transport fluid in the pipeline 12. As such, this arrangement creates an effective inline monitoring solution for a natural gas and hydrogen supply, without the need to include additional and cumbersome hydrogen monitoring probes.
An alternative arrangement is illustrated in Figure 2. Identical or similar features to those described in respect of the first embodiment will be referenced using identical or similar reference numerals, and further detailed description will be omitted for brevity.
The pipeline monitoring system 110 includes a pipeline 112 having a single access port 114, to which is connected a transport fluid monitoring apparatus 130. In this arrangement, the transport fluid monitoring apparatus 130 is provided as a unit which can be engaged simply with the access port 114.
The transport fluid monitoring apparatus 130 comprises a referencing unit 116 having a first fluid monitoring conduit 132 and a second fluid monitoring conduit 134 which preferably extend in parallel to one another away from a connector flange 118a which is engagable with the access port 114, downstream of a flow splitter 136. Forming the referencing unit 116 as a unitary component having both of the first and second fluid monitoring conduits 132, 134 simplifies the engagement of the transport fluid monitoring apparatus 130 with the pipeline 112, which limits downtime of the transport fluid flow for installation.
Preferably the first and second monitoring conduits 132, 134 have an identical or uniform bore, to ensure that there are no minor discrepancies therebetween which may affect the accuracy of the measurements made, and are preferably positioned so as to be parallel to one another, so that the fluid flow along the respective first and second fluid flow paths is unidirectional.
Furthermore, each of the first and second monitoring conduits 132, 134 may be provided having a vent portion 138 to permit venting of fluid therefrom, should there be, for any reason, a pressurised build-up of fluid inside the transport fluid monitoring apparatus 130.
A hydrogen-separation element 124 is engaged within the first fluid monitoring conduit 132, preferably proximate an end of the first fluid monitoring conduit 132 which is proximate the flow splitter 136 or connector flange 118a, thereby defining a treated-flow region downstream of the hydrogen-separation element 124.
The first detector 20a can then be positioned on the first fluid flow path of the first fluid monitoring conduit 132 downstream of the hydrogen-separation element, whilst the second detector 20b can be positioned on the second fluid monitoring conduit 134 which is in fluid communication with the pipeline 12. As per the previous embodiment, the first and second detectors 20a, 20b can be set up as part of a Wheatstone bridge circuit 26 to form a thermal conductivity detector. Again, a Wheatstone bridge 26 is merely one convenient circuit design for monitoring the difference between the physical properties of the flows, and other arrangements are possible.
In addition, the fluid-characteristic sensor 22 may also be provided so as to be connectable to the first fluid monitoring conduit 132, again, to permit monitoring of the transport fluid following the removal of hydrogen.
The method of using the present invention can therefore be summarised as follows. Transport fluid can be diverted along first and second fluid flow paths, with a hydrogenseparation element being positioned on the first fluid path to remove hydrogen from the transport fluid. A characteristic of the fluid on the first fluid flow path can then be monitored downstream of the hydrogen-separation element, and the same characteristic of the fluid on the second fluid flow path is monitored for comparison. A hydrogen concentration of the transport fluid is then determined based on a difference of the monitored characteristics.
This is most applicable where the transport fluid comprises a mixture of energy-supply gas, such as natural gas, along with hydrogen gas, and also where the monitored characteristic is thermal conductivity. At least one further characteristic can then be monitored downstream of the hydrogen-separation element on the first fluid flow path, and a measurement of the or each further characteristic normalised based on the determined hydrogen concentration.
It will be appreciated that other physical properties of a fluid may be affected by the presence of hydrogen therein, and therefore whilst the embodiments described above refer to the use of a thermal conductivity detector, other appropriate detectors could be considered which measure other physical properties, such as density, or compression factor.
It is therefore possible to provide a pipeline monitoring system for determining a hydrogen concentration of a transport fluid, so as to be able to calibrate or reference further measurements taken from the transport fluid. This has the advantage of allowing for monitoring the composition of the transport fluid as it is metered, in particular with 5 regards to the calorific value thereof, without the need to provide a dedicated and slow hydrogen probe.
The words ‘comprises/comprising’ and the words ‘having/including’ when used herein with reference to the present invention are used to specify the presence of stated features, integers, steps or components, but do not preclude the presence or addition of one or more 10 other features, integers, steps, components or groups thereof.
It is appreciated that certain features of the invention, which are, for clarity, described in the context of separate embodiments, may also be provided in combination in a single embodiment. Conversely, various features of the invention which are, for brevity, described in the context of a single embodiment, may also be provided separately or in 15 any suitable sub-combination.
The embodiments described above are provided by way of examples only, and various other modifications will be apparent to persons skilled in the field without departing from the scope of the invention as defined herein.

Claims (20)

1. A pipeline monitoring system for monitoring a transport fluid in a pipeline and which in part contains hydrogen, the system comprising:
a first fluid flow path;
a second fluid flow path;
a hydrogen-separation element positioned on the first fluid path and which separates hydrogen from the transport fluid;
monitoring means for monitoring a characteristic of a fluid, the monitoring means comprising a first detector on the first fluid flow path downstream of the hydrogen-separation element and a second detector on the second fluid flow path; and determining means for determining a hydrogen concentration of the transport fluid based on a difference of the said characteristics monitored by the monitoring means.
2. A pipeline monitoring system as claimed in claim 1, wherein the hydrogenseparation element comprises a metal hydride hydrogen storage element.
3. A pipeline monitoring system as claimed in claim 1 or claim 2, wherein the hydrogen-separation element comprises a soley hydrogen-porous material.
4. A pipeline monitoring system as claimed in claim 3, wherein the solely Hydrogenporous material is at least one of a nano-material and/or Palladium.
5. A pipeline monitoring system as claimed in claim 4, wherein the nano-material comprises a carbon nanotube formed from graphene or graphene oxide, or a boron nitride nanotube.
6. A pipeline monitoring system as claimed in any one of the preceding claims, wherein the first and second detectors of the monitoring means are coupled by a Wheatstone bridge circuit to act as a thermal conductivity gas sensor.
7. A pipeline monitoring system as claimed in claim 6, wherein the determining means comprises a processor connected to the thermal conductivity gas sensor to determine the hydrogen concentration of the transport fluid.
8. A pipeline monitoring system as claimed in any one of the preceding claims, wherein the first and second fluid flow paths are at least in part parallel or substantially parallel to one another.
9. A pipeline monitoring system as claimed in any one of the preceding claims, wherein the second fluid flow path is coincident with a flow path of the pipeline to be monitored.
10. A pipeline monitoring system as claimed in any one of the preceding claims, further comprising a fluid-characteristic sensor which is positionable on the first fluid flow path downstream of the hydrogen-separation element, the fluid-characteristic sensor being adapted to monitor at least one further characteristic which is different to the characteristic monitored by the monitoring means.
11. A pipeline monitoring system as claimed in claim 10, wherein the at least one further characteristic comprises at least one of: calorific value; Wobbe index; relative density; compression factor; methane number; density; thermal conductivity; primary influencing inert gas; carbon dioxide emission factor; and total concentration.
12. A method of monitoring a transport fluid in a pipeline which in part contains hydrogen, the method comprising the steps of:
a] diverting the transport fluid along first and second fluid flow paths;
b] providing a hydrogen-separation element positioned on the first fluid path and which separates hydrogen from the transport fluid;
c] monitoring a characteristic of the fluid on the first fluid flow path downstream of the hydrogen-separation element and monitoring the same characteristic of the fluid on the second fluid flow path; and
d] determining a hydrogen concentration of the transport fluid based on a difference of the monitored characteristics.
13. A method as claimed in claim 12, wherein the transport fluid comprises a mixture of energy-supply gas and hydrogen gas.
14. A method as claimed in claim 12 or claim 13, wherein the monitored characteristic is thermal conductivity.
15. A method as claimed in any one of claims 12 to 14, further comprising a step e] subsequent to step d] of monitoring at least one further characteristic downstream of the hydrogen-separation element on the first fluid flow path; and step f] of normalising a measurement of the or each further characteristic based on the determined hydrogen concentration.
16. A transport fluid monitoring apparatus comprising:
a first fluid monitoring conduit adapted to receive or connect to a first detector;
a second fluid monitoring conduit adapted to receive or connect to a second detector; and a hydrogen-separation element positioned on the first fluid path for separating hydrogen from a transport fluid.
17. A transport fluid monitoring apparatus as claimed in claim 16, further comprising a fluid inlet port and a fluid flow splitter for diverting transport fluid from the fluid inlet port into both the first and second fluid monitoring conduits.
18. A transport fluid monitoring apparatus as claimed in claim 16 or claim 17, wherein the first and second fluid monitoring conduits are provided as a unitary component.
19. A transport fluid monitoring apparatus as claimed in any one of claims 16 to 18, further comprising monitoring means for monitoring a characteristic of a fluid, the monitoring means comprising a first detector on the first fluid monitoring conduit downstream of the hydrogen-separation element and a second detector on the second fluid monitoring conduit; and determining means for determining a hydrogen concentration of the transport fluid based on a difference of the said characteristics monitored by the monitoring means.
20. A transport fluid monitoring apparatus as claimed in any one of claims 16 to 19, further comprising a fluid-characteristic monitoring device which is engagable with the first fluid monitoring conduit downstream of the first probe, the fluid-characteristic monitoring device being adapted to monitor at least one further characteristic which is 5 different to the characteristic monitored by the monitoring means.
GB1810975.1A 2018-07-04 2018-07-04 Pipeline monitoring system, method, and apparatus Withdrawn GB2575283A (en)

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