Gas compression and transportation system with integrated storage and operation thereof

Abstract

A compression and transportation system for gathering and transporting gas from a gas production plant to gas utilization facilities is disclosed. The system com- prises a gathering and boosting section connected to the gas production plant, a pipe- line system, with an inlet and outlet, at least one operating pipeline sub-system, and a storage and compression station connected to the operating pipeline sub-system. The storage and compression station is adapted to compress gas received from the gather- ing and boosting section and operate in a first mode to store compressed gas within the operating pipeline sub-system when the gas production plant produces gas, and in a second mode to supply stored gas from the operating pipeline sub-system to the gas utilization facilities.

Description

GAS COMPRESSION AND TRANSPORTATION SYSTEM WITH INTEGRATED STORAGE AND OPERATION THEREOFDescriptionTECHNICAL FIELD

[0001] The present disclosure concerns a gas, specifically pure hydrogen or in mixture with other components, compression and transportation system with integrated storage. The present disclosure also concerns the operation method of the compression and transportation system.

[0002] More specifically, the present disclosure relates to hydrogen gathering and pipeline systems, and more particularly to a system and method for gathering green hydrogen from multiple sources, transporting it via pipeline, and storing it to ensure continuous supply for end users.BACKGROUND ART

[0003] Hydrogen is increasingly recognized as a clean and versatile energy carrier with the potential to play a significant role in decarbonizing various sectors of the global economy. Green hydrogen, produced through electrolysis powered by renewable energy sources such as wind and solar, is of particular interest due to its minimal carbon footprint. As the demand for green hydrogen grows, there is a need for efficient systems to gather, transport, and distribute this valuable resource from production sites to end-users.

[0004] Conventional hydrogen production and distribution systems face several challenges when dealing with green hydrogen. The intermittent nature of renewable energy sources leads to fluctuations in hydrogen production, which can result in periods of excess supply or shortages.

[0005] Additionally, hydrogen production facilities are often located far from the endusers, necessitating long-distance transportation. The low volumetric energy density of hydrogen also presents challenges for storage and transportation, requiring high-pressure systems to achieve economically viable energy densities.

[0006] Current hydrogen pipeline systems typically employ a series of compression stations along the pipeline route. These systems are designed for steady-state operation and may struggle to accommodate the variable production rates associated with green hydrogen. Furthermore, the need for large, high-pressure storage facilities at both production and consumption sites increases safety risks and infrastructure costs.

[0007] The transportation of hydrogen over long distances requires careful management of pressure and flow rates to ensure efficient and safe delivery. Existing conventional pipeline configurations may not provide the flexibility needed to handle the dynamic nature of green hydrogen production and consumption patterns. This can lead to inefficiencies in the overall system, potentially limiting the widespread adoption of green hydrogen as an energy carrier.

[0008] It has been appreciated that a smart pipeline configuration for green hydrogen gathering and transmission is needed that overcomes these problems.SUMMARY

[0009] In one aspect, the subject matter disclosed herein concerns a compression and transportation system for gathering gas from a gas production plant and transporting it to one or more gas utilization facilities. The system comprises a gathering and boosting section configured to compress the gas received from the gas production plant to increase its pressure, and a pipeline system having an inlet connected to the gathering section, an outlet connectable to the gas utilization facilities, and at least one operating pipeline sub-system.

[0010] In another aspect, disclosed herein is a storage and compression station connected to the operating pipeline sub-system of the pipeline system. The storage and compression station is adapted to compress the gas coming from the gathering and boosting section and is capable of operating in a first operating mode, during gas production, to store compressed gas within the operating pipeline sub-system, and in a second operating mode, to supply the stored gas to the gas utilization facilities.

[0011] A further aspect of the present disclosure is drawn to a control unit operatively connected to the storage and compression station, which is adapted to operate the station in the first and second operating modes. The system is configured such that thestorage and compression station operates in the second mode when the gas production plant is not operating or is operating below its normal production capacity.

[0012] In another aspect, the subject matter disclosed herein concerns the structure of the storage and compression station, which comprises an inlet and an outlet connected to the operating pipeline sub-system, and a valve group adapted to control and adjust the connection of the inlet and outlet to the pipeline sub-system. The control unit is operatively connected to the valve group to regulate operations.

[0013] A further aspect of the present disclosure is drawn to the inclusion of one or more compressors in the storage and compression station, which are configured to compress the gas for storage in the pipeline sub-system when operating in the first mode. These compressors are deactivated when the system operates in the second mode.

[0014] In another aspect, disclosed herein is a transportation pipeline sub-system, forming part of the operating pipeline sub-system, which is dedicated to transporting gas from the gathering and boosting section to the gas utilization facilities. Additionally, the storage and compression station can include a connection to the transportation pipeline sub-system, enabling gas storage via the valve group.

[0015] A further aspect of the present disclosure is drawn to a storage pipeline subsystem within the operating pipeline sub-system, which is connected to the storage and compression station. The system is configured to store compressed gas in the storage pipeline sub-system during the first operating mode and release it during the second operating mode.

[0016] In another aspect, disclosed herein is the inclusion of first and second compressors in the storage and compression station. In the first operating mode, the first compressor facilitates gas transportation, while the second compressor stores excess gas. In the second operating mode, both compressors work in parallel to introduce stored gas into the transportation pipeline sub-system.

[0017] A further aspect of the present disclosure is drawn to transportation stations along the transportation pipeline sub-system, configured to compress the gas for efficient transport. Each transportation station may include centrifugal or reciprocatingcompressors.

[0018] In another aspect, the subject matter disclosed herein concerns the gathering and boosting section, which includes multiple compressors operating in series and / or parallel, utilizing a combination of centrifugal and reciprocating compressors to manage varying pressure levels and flow rates.

[0019] A further aspect of the present disclosure is drawn to the inclusion of a pressure let-down station at the pipeline system outlet, which reduces pressure to a suitable usage level and includes a pressure control valve, an expander for pressure reduction and energy recovery, and an electric generator.

[0020] In another aspect, disclosed herein is a nitrogen generator connected to the pipeline system inlet, configured to blend nitrogen into the pipeline up to a specified volume percentage.

[0021] A further aspect of the present disclosure is drawn to a compensation tank, interconnected between the gathering and boosting section and the pipeline system inlet, which stabilizes pressure fluctuations.

[0022] In another aspect, the subject matter disclosed herein concerns transportation pressures within a specified range and the suitability of the system for transporting various gases, including hydrogen, helium, nitrogen, ammonia, carbon dioxide, and others.

[0023] A further aspect of the present disclosure is drawn to a method for managing the compression and transportation system, which involves receiving gas from the gas production plant and operating the storage and compression station in different modes depending on production capacity.

[0024] In another aspect, disclosed herein is the operation of the storage and compression station in the first mode, involving series connection of compressors to transport and store excess gas, and in the second mode, operating compressors in parallel to supply stored gas to the utilization facilities.BRIEF DESCRIPTION OF THE DRAWINGS

[0025] A more complete appreciation of the disclosed embodiments of the invention and many of the attendant advantages thereof will be readily obtained as the same becomes better understood by reference to the following detailed description when considered in connection with the accompanying drawings, wherein:Fig. 1 illustrates a schematic diagram of a system for compressing and transporting the gas according to a first embodiment of the present disclosure;Fig. 2 illustrates a graph of a typical daily hydrogen production of a production plant;Fig. 3 illustrates a graph of pipeline pressure gradient across multiple compression stations of the embodiment of Fig. 1;Fig. 4 illustrates a schematic diagram of a system for compressing and transporting the gas according to a second embodiment of the present disclosure;Fig. 5 illustrates a graph of pipeline pressure gradient across multiple compression stations of the embodiment of Fig. 4;Fig. 6 illustrates an alternative solution of the connection of the compressors of the storage and compression station of the embodiment of Fig. 4;Fig. 7 illustrates a schematic diagram of a system for compressing and transporting the gas according to a third embodiment of the present disclosure;Fig. 8 illustrates a graph of pipeline pressure gradient across multiple compression stations of the embodiment of Fig. 6;Fig. 9 illustrates an alternative solution of the connection of the compressors of the storage and compression station of the embodiment of Fig. 7;Fig. 10 illustrates a flowchart of a method for managing a gas compression and transportation system, according to the present disclosure;Fig. 11 illustrates detailed steps of a first operating mode of the method of Fig.10; andFig. 12 illustrates detailed steps of a second operating mode of the method of Fig. 10.

[0026] Common reference numerals are used throughout the figures to indicate similar features.DETAILED DESCRIPTION OF EMBODIMENTS

[0027] According to one aspect, the present subject matter is directed to a system and method for efficiently gathering, transporting, and storing gases, like hydrogen. The system comprises a network of pipelines, compressors, and storage facilities that work together to manage gas flow from production plants to end-users. The system is adapted to change production levels and demand. When there is excess gas production, the system can store the extra gas in the pipeline network itself or in dedicated storage pipelines. When production is low or demand is high, the system can release the stored gas to maintain a steady supply to users. The system also comprises technical features like pressure control stations and nitrogen blending capabilities to ensure the gas is delivered safely, efficiently and at the right quality. Therefore, the disclosure aims to make the transportation and storage of gases like hydrogen more flexible and efficient, which could be particularly useful in the transition to cleaner energy sources.

[0028] Referring to Fig. 1, it is shown a first embodiment of a compression transportation system 1 of a gas according to the present disclosure.

[0029] The transported gas can be Hydrogen (IL), Helium (He), Nitrogen (N2), Ammonia (NH3), Carbon Di-oxide (CO2), or other gases derived from separation processes or obtained through chemical / thermodynamic processes that use fluids produced from renewable or non-renewable sources, wherein their production is not constant over time. In the following description, without limitation, and only for the purpose of illustration, the gas considered will be the hydrogen.

[0030] Specifically, the compression transportation system 1 shown in Fig. 1 comprises a production plant 2 connected to a gathering section 3, pipeline system 4, connecting the storage gathering section 3 to a gas utilization facility 5, and a compression station 6, connected to the pipeline system 4. In some embodiments, the utilization facility 5 comprises green NH3, Methanol production facilities mainly, and / or otherdifferent hydrogen transformation facilities.

[0031] The hydrogen production plant 2 is of the type comprising different renewable energy sources, such as solar energy production plants, comprising solar panels 21, and wind production plants, comprising wind turbines 22.

[0032] The hydrogen production plant 2 may comprise also other renewable energy sources, not shown in the figures. Inverters 23 are connected to the solar panels 21 or to the wind turbines 22. The hydrogen production plant 2 comprises also electrolyzers 24, which produce hydrogen by splitting water molecules using electricity generated from the above renewable sources. In the embodiment shown, each electrolyzer 24 comprises a relevant buffer tank 25, to collect the hydrogen produced by the relevant electrolyzer 24.

[0033] Since the hydrogen production plant 2 comprises renewable sources, it is subject to relevant production volatility, as can be seen in Fig. 2, where a typical daily hydrogen production of a production plant is shown, wherein in the abscissa the time is reported, and in the ordinate the hydrogen production in percentage of the nominal capacity of a renewable energy production plant. It can be appreciated a typical variation from a percentage of around 25% to 100%.

[0034] For instance, solar panels 21 do not produce energy during the night, while wind turbines do not produce energy in case of no wind. It can be distinguished two operating regimes: a normal energy production regime, when the range production of the hydrogen production plant 2 falls within a range of nominal or normal production capacity, which is usually present when the hydrogen production plant 2 is operating normally (i.e., during the day for the solar panels 21 or during windy days for wind turbines), and a low energy regime, when the hydrogen production plant 2 operates below the range of nominal or normal production capacity.

[0035] The gathering section 3 comprises two compressors 31 and 32, which can be of centrifugal or of reciprocating type, adapted to compress the hydrogen gas received from the hydrogen production plant 2. The number of compressors of the gathering section 3 depends on the number of different thresholds at which hydrogen is produced, the pressure thresholds of the intermediate collectors, and the pressure threshold selected at the output of the gathering station. The number of compressors canrange from zero, if the hydrogen production pressure in the electrolyzers 24 is uniform and equal to or greater than the pressure selected as the output of the gathering station, to n, where n depends on the number of intermediate pressure thresholds, i.e. intermediate collectors, selected.

[0036] The compressors 31 and 32 of the gathering section 3 are connected in series. Also, in some embodiments the compressors are all centrifugal compressors. In some other embodiments, the compressors are all reciprocating compressors. Additionally, in other embodiments, the compressors comprise a mix of the two types of centrifugal and reciprocal compressors, to improve the efficiency and flexibility of Hydrogen compression, due to its low molecular weight. Additionally, in some other embodiments, compression stages are in series since each stage could comprise multiple compressors in parallel if required by the overall capacity.

[0037] The compressors 31 and 32 are driven by a gas turbine fueled by hydrogen turbine 33 or an electric motor.

[0038] The gathering section 3 is configured to compress the gas to a boosting pressure, which is usually set at preferably between 30-60 bar. However, such numbers are only indicative and not limitative.

[0039] The pipeline system 4 extends from a pipeline inlet 41, connected to the gathering section 3, to a pipeline outlet 42 connectable to a utilization facility 5.

[0040] In general, the pipeline system 4 comprises at least one operating pipeline subsystem 43, 44, connected to the inlet 41 and the outlet 42.

[0041] As better explained in the following, the compression and transportation system 1 is adapted to store gas within the operating pipeline sub-system 43, 44 of the pipe-line system 4, and to supply the gas stored in the at least one operating pipeline sub-system 43, 44 of the pipeline system 4 to the gas utilization facilities 5.

[0042] The pipeline system 4 comprises, in the present embodiment, a transportation pipeline sub-system 43 for transporting gas from the gathering section 3 to the utilization facility 5. The pipeline system 4 may be distributed even over 300-400 km. In other words, the hydrogen utilization facility 5 may be placed far from the hydrogen production plant 2.

[0043] The storage and compression station 6 is connected to the pipeline system 4 through an inlet 61 and an outlet 62.

[0044] The storage and compression station 6 comprises a first compressor 63, having the relevant driving turbine 631, and a valve group 65 for controlling the hydrogen or gas flow.

[0045] The storage and compression station 6 is adapted to compress the hydrogen coming from the gathering section 3.

[0046] The valve group 65 of the storage and compression station 6 is adapted for controlling the gas flow, having a plurality of valves. Specifically, the valve group 65 is capable of controlling the hydrogen to be compressed and stored into the pipeline system 4 and to be released from the same pipeline system 4. The valves 651 and 652 of the valve group 65, arranged are necessary for isolating the compressor 63, while the horizontally positioned valve 653 ensures the continuity of flow in the pipeline in the event of a compression station shutdown (station bypass). In addition, in general terms, the compression stations 6 comprise, in addition to compressors and associated drivers, process equipment such as filter-separators, cooling elements (e.g., air / water coolers), flow meters, automated and control valves, pressure and temperature protection systems, etc.

[0047] The compression and transportation system 1 comprises also a control unit U, which is operatively connected to the compression station 6 and is configured to manage and coordinate the system’s functionality across multiple operational modes (as better explained below), including but not limited to a first operating mode and a second operating mode.

[0048] Specifically, the control unit U is connected to the valves of the valve group 65 and the first compressor 63 of the storage and compression station 6, allowing for transitions between operating modes.

[0049] By controlling the opening and closing of the valves in valve group 65 and controlling the activation cycles of the first compressors 63, the control unit U optimizes the performance of the compression station 6 based on the operational requirements, as better explained below.

[0050] The control unit U can be implemented using various technologies, depending on the specific requirements of the compression and transportation system 1. One possible implementation involves the use of Application-Specific Integrated Circuits (ASICs), which provide high-performance and energy-efficient solutions tailored to the specific control tasks of the compression station 6.

[0051] Alternatively, the control unit U can be implemented using Field-Programmable Gate Arrays (FPGAs), offering flexibility and reconfigurability that allow for rapid updates and adaptation to evolving system requirements.

[0052] In another embodiment, the control unit U may be constructed with microcontroller units (MCUs) that deliver cost-effective control with sufficient processing power to handle complex valve and compressor coordination tasks.

[0053] Furthermore, the control unit U is equipped with sensors and feedback loops that provide continuous data on pressure levels, temperature, and flow rates within the compression station 6 and the compression and transportation system 1 itself.

[0054] These data are processed to dynamically adjust the operation of the first compressors 63 and the valves of the valve group 65, ensuring that the system operates within safe and efficient parameters. The adaptive nature of the control unit U enhances the reliability and longevity of the compression and transportation system 1. In some embodiments, the control unit U is dedicated to the control of the individual compression station, namely, in the case at issue the compression station 6, but it also interfaces with a higher-level control system, designed to coordinate the operation of all the compression stations, the gathering and boosting section 3, and the electrolyzers 24. This ensures alignment and optimization of the overall functionality of the compression and transportation system 1.

[0055] The control unit U can be programmed to execute pre-set operational routines, enabling automated start-up and shutdown procedures, and responding to external commands or emergency signals. This level of automation contributes to operational safety and minimizes the need for manual intervention, thereby enhancing overall system efficiency.

[0056] The storage and compression station 6 may operate, by means of the controlunit U, in a first operating mode, to store compressed gas within the pipeline system 4, and in a second mode, to supply stored gas to the utilization facility 5, as it will be better explained below.

[0057] More specifically, the compression and transportation system 1 operates in the first operating mode, when the gas production plant 2 is operating in a range of nominal or normal production capacity, the storage and compression station 6 compresses the hydrogen received, to transport through the transportation pipeline sub-system 43, to supply a gas utilization facilities 5, may be with the aid of other transportation means, as better explained below, and, at the same time, to store the compressed hydrogen within the transportation pipeline sub-system 43.

[0058] The transportation pressure within the pipeline system 4 may be maintained during the first operating mode between 50 bar and 60 bar. However, different pressures can be foreseen, without departing from the scope of protection of the disclosure.

[0059] The compression and transportation system 1 operates in the second operating mode when the gas production plant 2 is operating in the in a range below the nominal or normal production capacity, when the gas production plant 2 is operating in a range of nominal or normal production capacity, the first compressor 63 of the storage and compression station 6 stops operating, allowing the release of the hydrogen stored in the transportation pipeline sub-system 43 to supply a gas utilization facilities 5. In general, the storage and compression station 6 reduces initially its capacity in response to the decrease in hydrogen production and may partially operate under partial recycle conditions until it eventually shuts down completely when IL production approaches “zero.”

[0060] The compression transportation system 1 comprises also a plurality of transportation stations 71, ..., 7n connected along the transportation pipeline sub-system 43, series connected. Each transportation station 71, ... , 7n comprises at least one compressor 711,..., 7nl, preferably a centrifugal or reciprocal compressor, for compressing the gas during transport, and a driving turbine 712,..., 7n2, for driving the relevant compressor 711,...,7nl. In general, the type of compressors used for pipelines is centrifugal. The driver is primarily a gas turbine powered by Hydrogen but in some em-bodiments electric motors could also be used, although sometimes they are less convenient due to the infrastructure required to supply high-voltage electrical power.

[0061] In some embodiments, the compression and transportation system 1 also comprises a nitrogen generator 8 is connected to the pipeline inlet 41, to blend nitrogen into the pipeline system 4 up to approximately 10% by volume. The use of the nitrogen increases the average molecular volume of the gas to be transported, especially when the gas is hydrogen.

[0062] In some embodiments, at the pipeline outlet 42, a pressure reduction station 45 is installed. The pressure reduction station 45 comprises a pressure control valve 451, a pressure expander 452, and an electric generator 453 to reduce gas pressure and recover energy before delivery to the utilization facility 5. The energy recovered by the pressure reduction station 45 can be injected in the main power grids or used to supply the compression and transportation system 1 itself, or any other facility.

[0063] Fig. 3 illustrates a graph of the pipeline pressure gradient across the compression transportation system 1. On the abscissa the pipeline length is reported, while on the ordinate the pipeline pressure gradient is reported.

[0064] The graph shows pressure profiles for the first and the second operating conditions, respectively indicated in the figure with the curves A and B.

[0065] More specifically, the solid line represents the pressure gradient during normal operation, where each transportation station 71, 72, 73, 7n increases the gas pressure to maintain flow through the system. The dashed line indicates an alternative operating mode where the pressure gradient is primarily due to fluid transportation without significant compression at intermediate stations.

[0066] The pressure gradient graph demonstrates how the compression and transportation system 1 can adapt to varying production and demand conditions. When the production plant 2 operates within or above the range of nominal or normal production capacity, the compression and transportation system 1 may utilize all transportation stations 71, 72, 73, 7n to maintain higher pressures throughout the pipeline length. Conversely, when production is below the range of nominal or normal production capacity, or during periods of lower demand, the compression and transportation system1 may operate with reduced compression at intermediate stations, resulting in a more gradual pressure decline along the pipeline length, or stopped and by-passed the compression station along the pipelines.

[0067] This flexible operation allows the compression and transportation system 1 to efficiently handle variations in gas production, which may occur due to the use of renewable energy sources such as wind and solar for hydrogen production at the production plant 2.

[0068] The area S enclosed by curves A and B is the pressure gradient preserved along pipeline system 4 during the first operating mode and released during the second operating mode.

[0069] As it can be seen, each transportation station 71, 72, 73, 7n increases the pressure within the transportation pipeline sub-system 43.

[0070] The dashed line C represents the pressure variation along the pipeline under the extreme condition where the compression stations (initial and intermediate, i.e., from the first transportation station 71 and at the outlet 42 of the pipeline system 4) are shut down, resulting in “no incoming hydrogen JL from gathering. This is due to both the reduction in accumulated mass and pressure losses in the fluid flow, which occur as a result of the pressure energy accumulated during the day.

[0071] Still referring to Fig. 1, a compensation storage tank 9 is positioned between the gathering section 3 and the pipeline inlet 41 of the pipeline system 4. The compensation tank 9 is adapted to stabilize the pressures in case of fluctuations in the hydrogen gathering / production system.

[0072] In the present embodiment, the gathering section 3 performs the initial hydrogen compression by the two (or more) compressors 31 and 32. The compressed hydrogen can be directed to the compensation tank 9 or directly to the pipeline system 4, depending on the current operating conditions and storage requirements.

[0073] Referring to Fig. 4, a second embodiment of the compression and transportation system 1 is shown. The compression and transportation system 1 of Fig. 4 comprises additional components to enhance its storage and operational capabilities. In particular, the pipeline system 4 comprises, in addition to the transportation pipelinesub-system 43, a storage pipeline sub-system 44, for storing compressed hydrogen.

[0074] The storage pipeline sub -system 44 is connected to the storage and compression station 6, allowing for the storage and release of gas as needed.

[0075] Also, the storage and compression station 6 is connected to the pipeline system 4 and still comprises an inlet 61, an outlet 62, connected to the transportation pipeline sub-system 43. The storage and compression station 6 comprises in the present embodiment a first compressor 63, a second compressor 64, along with the valve group 65 for controlling gas flow.

[0076] The control unit U is connected also to the second compressor 64, to control its operation.

[0077] Also in the present embodiment, the storage and compression station 6 can operate in two operating modes.

[0078] In the first operating mode, typically during periods of high production of the gas production plant 2, or low demand of the gas utilization facilities 5, the storage and compression station 6 compresses gas and stores it in the storage pipeline subsystem 44.

[0079] In said first operating mode the compressor 63 compresses the gas flow received from the gathering and boosting section 3 to the minimum pressure required for the transport through pipeline 44. The transported flow corresponds to the demand of the gas utilization facilities 5. The following compression stations 71...711 are used only for the transportation of the gas. Any excess flow compressed by compressor 63 is directed to compressor 64, which increases its pressure and stores it in pipeline 45. In such a first operating mode, the compressors 62 and 63 operate in parallel.

[0080] In a second operating mode, usually during periods of low production of the gas production plant 2 or high demand of the gas utilization facilities 5, the storage and compression station 6 releases the gas stored in the storage pipeline sub-system 44 to supply the utilization facility 5.

[0081] More specifically, during the first operating mode, the valve group 65 is configured to connect the first compressor 63 and the second compressor 64 of the storageand compression station 6 in series. Alternatively, in some other embodiments, the compressor 64 could be connected with compressor 63 either in series or in parallel, while maintaining their distinct functions and discharge pressures, whereas the suction pressures remain the same (from the gathering and boosting section 3).

[0082] Also, the valve group 65 is configured so that the first compressor 63 of the storage and compression station 6 supplies the utilization facility 5, which is also transported by the aid of the transportation stations 71, ..., 7n positioned along the transportation pipeline sub-system 43; and the second compressor 64 partially directs the hydrogen to the storage pipeline sub-system 44.

[0083] During the night (second operating mode), when production may be lower, the valve group 65 is configured to connect the first compressor 63 and the second compressor 64 of the storage and compression station 6 in parallel. Also, the valve group 65 is configured so that the first compressor 63 of the storage and compression station 6 supplies the utilization facility 5, and the second compressor 64 allows the hydrogen stored into the storage pipeline sub-system 44 to flow toward the gas utilization facilities 5.

[0084] In this way, compared to the first embodiment, this compression and transportation system 1 prevents the first compressor 63 to be switched off when operating in the second operating mode. It is, in fact, well known that frequent switching-off of compressors can cause problems. Hydrogen, due to its low molecular weight and high diffusivity, can lead to embrittlement of critical components within the compressor during periods of inactivity. This phenomenon, often worsened by temperature fluctuations, can cause microcracking and degradation of seals, valves, and internal surfaces. Additionally, the repeated pressurization and depressurization cycles introduce mechanical fatigue, which reduces the overall lifespan of the equipment and increases the likelihood of leaks or mechanical failure. Such issues not only compromise the efficiency and reliability of the hydrogen transport system but also elevate maintenance costs and pose potential safety risks.

[0085] Then, the storage and compression station 6 operates in a cyclic mode, typically ON during the day for compression and storage, and at low regime, but not shut down during the night when stored gas is being released. This cyclic operation allows thecompression transportation system 1 to efficiently manage fluctuations in gas production and demand.

[0086] Comparing the first embodiment (shown in Fig. 1) and the second embodiment (shown in Fig. 4), all the compression stations are affected by production volatility, both in terms of flow rates and pressure thresholds, making all compression stations generally (over the time) inefficient. In the second embodiment, however, the compression stations for transport are not affected by production volatility and are therefore generally more efficient. The storage and compression station 6, on the other hand, will be affected by volatility of the gas production likewise in the first embodiment of compression and transportation system 1. Therefore, a better efficiency is achieved with the second embodiment of compression and transportation system 1.

[0087] Continuing referring to Fig. 4, the second embodiment of the compression and transportation system 1 also comprises a nitrogen generator 8, connected to the pipeline system 4 via a nitrogen blending pipe 81. The nitrogen blending pipe 81 allows for the introduction of nitrogen into the gas stream, which can be used to adjust the gas composition or for purging purposes.

[0088] The transportation stations 71, ... , 7n of the compression transportation system 1 are connected to the transportation pipeline sub-system 43, to maintain pressure and flow throughout the system.

[0089] At the downstream end, a pressure reduction station 45 is installed, comprising a pressure control valve 451, a pressure expander 452, and an electric generator 453. This configuration allows for pressure reduction before delivery to the utilization facility 5 while also enabling energy recovery. It is noted that the pressure reduction station 45 is installed at the end of the storage pipeline sub-system 44 to recover energy before sending the gas to the pipeline system 4. Normally, the gas injected into storage pipeline sub-system 44 is recompressed using the compressors 63 and 64. Only in the event of a full or partial shutdown of the storage and compression station 6 during the night, the pressure reduction station 45 can be used as a backup to supply the gas utilization facilities 5 without interruptions.

[0090] The solution allows to store the hydrogen to equalize / dampen production flue-tuations, reducing or eliminating them at the user’s baseline. This simplifies the operations of the gas utilization facilities 5.

[0091] Also, only a portion of the hydrogen volume is at higher pressure. Specifically, the hydrogen to be transported will be compressed to an optimal pressure threshold, taking into account parameters such as compression power and pipeline size. For transport, it is not necessary to reach particularly high pressures. The hydrogen to be stored is compressed to a significantly higher-pressure threshold compared to the transport pipeline. Storing hydrogen at high pressure makes pressure variability less critical, thus reducing the pressure head variability for which the machinery must be designed, making the storage process much more efficient. In the first embodiment of the compression and transportation system 1 as shown in Fig. 1, it would be necessary to compress the entire volume / mass to higher pressures to dampen head variations.

[0092] Also, having higher-pressure storage allows not only for material storage, but also energy storage. That is, part of the energy used to elevate hydrogen to a higher pressure can be recovered (usually via turboexpanders).

[0093] The storage pipeline sub-system 44 can also function as fuel storage and / or supply for remote recompression stations powered by gas turbines.

[0094] The parallel storage pipeline effectively acts as a bypass to the main transport pipeline. In the event of a trip at any of the recompression stations, it is possible, for limited periods, to draw hydrogen directly from the storage instead of from the upstream pipeline, thereby preventing the users from running out of supply and being forced into a shutdown.

[0095] In some embodiments, in the case of long transportation pipelines 43 with multiple recompression stations, if the n-th transportation station 71, 72,...,7n, it will be possible to supply the (n+l)-th recompression station from the parallel pipeline, ensuring that the recompression, stations from (n+1) onward do not need to shut down. This could allow for restarting the upstream recompression stations, if possible, and realigning the entire system. If the last transportation station 71, 72,..., 7n encounters issues, it will be possible to supply hydrogen to the user directly from the storage pipeline sub-system 44, until it is depleted.

[0096] Fig. 5 illustrates the graph of the pipeline pressure gradient across the compression transportation system 1. Like in Fig. 3, on the abscissas the pipeline length is reported, while on the ordinate the pipeline pressure gradient is reported.

[0097] As it can be seen, each transportation station 71, 72, 73, 7n increases the gas pressure to maintain flow through the system.

[0098] The area S enclosed by curves A and B is the pressure gradient preserved along pipeline system 4 during the first operating mode and released during the second operating mode. The larger the area S, the greater the quantity of hydrogen stored in the pipeline system 4, although this distance should not be excessively increased.

[0099] With reference to Fig. 6, an alternative solution of the connection of the compressors 63 and 64 of the storage and compression station 6 is shown, where the second compressor 64 is connected in parallel to the first compressor 63. The operation of the storage and compression station 6 of Fig. 6 is analogous to that of Fig. 4.

[0100] With reference to Fig. 7, a third embodiment of the compression and transportation system 1 is shown. The compression transportation system 1 comprises a pipeline system 4 having only the storage pipeline sub-system 44, which is closed with pig launcher / receiver 441 and 442, used for the periodic cleaning of each pipeline. As an alternative, caps can be used.

[0101] In the embodiment, the gas utilization facility 5 is close to the gas production plant 2. For this reason, there is not the transportation pipeline sub-system 43. Also, the nitrogen generator 8 is directly connected to the gas utilization facility 5.

[0102] The compensation tank 9 is positioned between the gathering section 3 and the pipeline inlet 41.

[0103] The valve group 65 controls the routing of gas between the various components, allowing for different operating modes of compression and storage. The first compressor 63 and the second compressor 64 in the storage and compression station 6 can be configured to operate in series or parallel depending on system requirements and the first or second operating modes. Also in this embodiment, in said first operating mode the compressor 63 compresses the gas flow received from the gathering and boosting section 3 to the minimum pressure required for the transport through pipeline 44. The transported flow corresponds to the demand of the gas utilization facilities 5. Any excess flow compressed by com-pressor 63 is directed to compressor 64, which increases its pressure and stores it in pipeline 45. In such a first operating mode, thecompressors 62 and 63 operate in parallel.

[0104] In a first operating mode, typically when the production plant 2 is operating at or above the range of nominal or normal production capacity, the control unit U operates valve group 65 so that the first compressor 63 and the second compressor 64 are parallel connected. The first 63 and second 64 compressors are currently considered as two stages within a single casing, but in some embodiments, it is possible to have a single-casing solution with multiple impellers needed to achieve the storage pressure. The presence of two separate stages might be necessary if an intermediate cooling system is included.

[0105] Also, the control unit U operates the first compressor 63 so that it compresses the hydrogen for supply the gas utilization facility 5, and the second compressor 64 for it to compress and store excess gas in the storage pipeline sub-system 44.

[0106] In a second operating mode, typically when the production plant 2 is operating below the range of nominal or normal production capacity, the control unit U controls both the first compressor 63 and the second compressor 64 to operate in parallel to move stored gas from the storage pipeline sub-system 44 towards the gas utilization facility 5, ensuring its consistent supply.

[0107] In particular, the first compressor 63 will suck the hydrogen from storage pipeline sub-system 44. As mentioned, the first 63 and the second 64 will work in parallel. The compression stations 63 and 64 will supply 100% of the hydrogen to the gas utilization facility 5 or the residual part of the hydrogen (not handled by the gathering and boosting section). The compressors 63 and 64 suction pressure may be quite constant by a Pressure Control Valve (PCV) valve or the pressure let-down station 5.

[0108] The Pressure Control Valve (PCV) is a pressure reduction valve with a dual function: providing protection against overpressure (in addition to standard protection systems such as PSHH or PSV) to limit the pipeline pressure; and allowing supply to the gas utilization facility 5, when the storage compression station or the gathering system is in partial or total shutdown. Therefore, the pipeline system 4 enables storage for nighttime operation and potentially daily storage to compensate for temporary shutdowns of the compression and transportation system 1.

[0109] These solutions allow to mitigate instability by dynamically adjusting the pressure levels within the compression and transportation system 1, ensuring that the compressors operate within its designed performance parameters.

[0110] As it can be seen, the compressors 63 and 64 of the storage and compression station 6 of the present embodiment operates in cyclic mode: series during days and parallel during nights.[OHl] The compressors 63 and 64 are currently considered as two stages within a single casing, but in some variants, there could be a single-casing solution with multiple impellers required to achieve the storage pressure. The presence of two separate stages might be necessary if an intermediate cooling system is included.

[0112] Fig. 8 illustrates a graph showing the storage pipeline sub-system 44 pressure gradient versus the storage pipeline sub-system 44 length for the compression transportation system 1 of Fig. 7. Specifically, the graph depicts the pressure profile along the storage pipeline sub-system 44, with the vertical axis representing pipeline pressure gradient and the horizontal axis representing pipeline length.

[0113] The operation of the first compressor 63 and of the second compressor 64 are shown at the bottom of the figure. The storage and compression station 6 can operate the first compressor 63 and the second compressor 64 in series / parallel mode and are schematically shown at the beginning of the storage pipeline sub-system 44, positioned between the production plant 2 and the utilization facility 5.

[0114] The pressure gradient shows an initial increase at the compression station location followed by a gradual decline along the pipeline length, represented by two different slope lines indicating different operating conditions. The upper broken curve represents the pressurization / storage phase with compressors 63 and 64 operating in series. The lower broken curve, on the other hand, represents the compression condition toward the user during the night, with the pressure variation caused by pressure losses along the pipeline system 4, pressure reduction through the expander / PCV, and compression toward the gas utilization facilities 5. Also, in the present embodiment, the compressors 63 and 64 operate continuously day and night without cyclic stops.

[0115] With reference to Fig. 9, an alternative solution of the connection of the compressors 63 and 64 of the storage and compression station 6 is shown. Specifically, Fig. 9 shows a single stage storage and compression station 6, comprising then only one compressor 63 is connected in parallel to the first compressor 63. The operation of the storage and compression station 6 of Fig. 6 is analogous to that of Fig. 4.

[0116] The compression transportation system 1 can be operated according to a method 100 as illustrated in Figures 10, 11 and 12. The method 100 is designed to allow the operation of the compression and transportation system 1 particularly when connected to a hydrogen production plant 2 operating at different pressures and flow rates, to transport or supply the gas to one or more gas utilization facilities 5.

[0117] The method 100 (Fig. 10) starts with a step 110 of receiving hydrogen from the gas production plant 2. The gas production plant 2 is able to operate in a range of nominal or normal production capacity. Based on the capacity production, the method 100 branches into two operating modes.

[0118] When the capacity production is equal to, or above the nominal range, the method 100 proceeds to a first operating mode 120.

[0119] As shown in Fig. 11, the first operating mode 120 comprises a step 121 of connecting the first compressor 63 and second compressor 64 of the storage and compression station 6 in series. This is followed by a step 122 of compressing the gas, to allow its transportation through the transportation pipeline sub-system 43, by means of the first compressor 63. The first operating mode 120 also comprises a step 123 of storing the excess gas in the storage pipeline sub-system 44, by means of the second compressor 64.

[0120] When the capacity production is below the range of nominal or normal production capacity, the method 100 proceeds to a second operating mode 130. As illustrated in Fig. 12, the second operating mode 130 comprises a step 131 of connecting the first compressor 63 and the second compressor 64 of the storage and compression station 6 in parallel. This is followed by a step 132 of introducing the hydrogen stored in the storage pipeline sub-system 44 into the transportation pipeline sub-system 43 to supply the gas to the gas utilization facilities 5.

[0121] The method 100 allows the compression transportation system 1 according to any one of the embodiments disclosed, to adapt its operation based on the current hydrogen production capacity, switching between different operating modes to manage gas compression and transportation efficiently, handling a possible volatility of the gas production. In other words, this flexibility enables the system to handle variations in gas production and demand, ensuring a consistent supply to the gas utilization facilities 5.ADVANTAGES

[0122] An advantage of the present invention is that it allows for efficient gathering, compression, storage, and transportation of gas from production plants to utilization facilities. The system’s ability to operate in two modes enables it to manage fluctuations in gas production and demand, ensuring a stable supply to end-users.

[0123] Another advantage of the present invention is that it can adapt to varying production levels, ensuring continuous gas supply even during periods of low or no production from the gas production plant. This flexibility is particularly beneficial for managing the intermittent nature of green hydrogen production from renewable energy sources.

[0124] It is also an advantage of the present invention that it provides precise control over gas flow within the system, optimizing the storage and release of gas as needed, by a valve group and its connection to the control unit allows for switching between operating modes based on production and demand conditions.

[0125] An additional advantage is the continuous operation of some embodiments, is that the compressors operate without daily start-stop cycles, which can cause mechanical fatigue and increase the operational complexity of the entire pipeline.

[0126] Another advantage of the present invention is that it allows the transportation pipeline to serve a dual purpose as both a transport and storage medium, maximizing the system’s efficiency and storage capacity. This dual functionality reduces the need for large, separate storage facilities, thereby improving safety and reducing infrastructure costs.

[0127] It is also an advantage of the present invention the incorporation in the systemof energy recovery capabilities at the pressure let-down station, improving the energy efficiency of the system by converting excess pressure into usable electricity. This feature reduces operational costs.

[0128] Another advantage of the present invention is that it allows to blend nitrogen into the gas stream, allowing for precise control of gas composition. This feature can be important for certain end-use applications or for safety reasons, enhancing the versatility of the system.

[0129] While aspects of the invention have been described in terms of various specific embodiments, it will be apparent to those of ordinary skill in the art that many modifications, changes, and omissions are possible without departing form the spirt and scope of the claims. In addition, unless specified otherwise herein, the order or sequence of any process or method steps may be varied or re-sequenced according to alternative embodiments.

[0130] Reference has been made in detail to embodiments of the disclosure, one or more examples of which are illustrated in the drawings. Each example is provided by way of explanation of the disclosure, not limitation of the disclosure. In fact, it will be apparent to those skilled in the art that various modifications and variations can be made in the present disclosure without departing from the scope or spirit of the disclosure. Reference throughout the specification to "one embodiment" or "an embodiment" or “some embodiments” means that the particular feature, structure or characteristic described in connection with an embodiment is included in at least one embodiment of the subject matter disclosed. Thus, the appearance of the phrase "in one embodiment" or "in an embodiment" or "in some embodiments" in various places throughout the specification is not necessarily referring to the same embodiment(s). Further, the particular features, structures or characteristics may be combined in any suitable manner in one or more embodiments.

[0131] When elements of various embodiments are introduced, the articles “a”, “an”, “the”, and “said” are intended to mean that there are one or more of the elements. The terms “comprising”, “including”, and “having” are intended to be inclusive and mean that there may be additional elements other than the listed elements.

[0132] The subject matter described herein can be implemented in digital electroniccircuitry, or in computer software, firmware, or hardware, including the structural means disclosed in this specification and structural equivalents thereof, or in combinations of them. The subject matter described herein can be implemented as one or more computer program products, such as one or more computer programs tangibly embodied in an information carrier (e.g., in a machine-readable storage device), or embodied in a propagated signal, for execution by, or to control the operation of, data processing apparatus (e.g., a programmable processor, a computer, or multiple computers). A computer program (also known as a program, software, software application, or code) can be written in any form of programming language, including compiled or interpreted languages, and it can be deployed in any form, including as a stand-alone program or as a module, component, subroutine, or other unit suitable for use in a computing environment. A computer program does not necessarily correspond to a file. A program can be stored in a portion of a file that holds other programs or data, in a single file dedicated to the program in question, or in multiple coordinated files (e.g., files that store one or more modules, sub-programs, or portions of code). A computer program can be deployed to be executed on one computer or on multiple computers at one site or distributed across multiple sites and interconnected by a communication network.

[0133] The processes and logic flows described in this specification, including the method steps of the subject matter described herein, can be performed by one or more programmable processors executing one or more computer programs to perform functions of the subject matter described herein by operating on input data and generating output. The processes and logic flows can also be performed by, and apparatus of the subject matter described herein can be implemented as, special purpose logic circuitry, e.g., an FPGA (field programmable gate array) or an ASIC (application-specific integrated circuit).

[0134] Processors suitable for the execution of a computer program include, by way of example, both general and special purpose microprocessors, and any one or more processors of any kind of digital computer. Generally, a processor will receive instructions and data from a read-only memory, or a random access memory, or both. The essential elements of a computer are a processor for executing instructions and one or more memory devices for storing instructions and data. Generally, a computer will also include, or be operatively coupled to receive data from or transfer data to, orboth, one or more mass storage devices for storing data, e.g., magnetic, magneto-optical disks, or optical disks. Information carriers suitable for embodying computer program instructions and data include all forms of non-volatile memory, including by way of example semiconductor memory devices, (e.g., EPROM, EEPROM, and flash memory devices); magnetic disks, (e.g., internal hard disks or removable disks); magneto-optical disks; and optical disks (e.g., CD and DVD disks). The processor and the memory can be supplemented by, or incorporated in, special purpose logic circuitry.

[0135] To provide for interaction with a user, the subject matter described herein can be implemented on a computer having a display device, e.g., a CRT (cathode ray tube) or LCD (liquid crystal display) monitor, for displaying information to the user and a keyboard and a pointing device, (e.g., a mouse or a trackball), by which the user can provide input to the computer. Other kinds of devices can be used to provide for interaction with a user as well. For example, feedback provided to the user can be any form of sensory feedback, (e.g., visual feedback, auditory feedback, or tactile feedback), and input from the user can be received in any form, including acoustic, speech, or tactile input.

[0136] The techniques described herein can be implemented using one or more modules. As used herein, the term “module” refers to computing software, firmware, hardware, and / or various combinations thereof. At a minimum, however, modules are not to be interpreted as software that is not implemented on hardware, firmware, or recorded on a non-transitory processor readable recordable storage medium (i.e., modules are not software per se). Indeed “module” is to be interpreted to always include at least some physical, non-transitory hardware such as a part of a processor or computer. Two different modules can share the same physical hardware (e.g., two different modules can use the same processor and network interface). The modules described herein can be combined, integrated, separated, and / or duplicated to support various applications. Also, a function described herein as being performed at a particular module can be performed at one or more other modules and / or by one or more other devices instead of or in addition to the function performed at the particular module. Further, the modules can be implemented across multiple devices and / or other components local or remote to one another. Additionally, the modules can be moved from one device and added to another device, and / or can be included in both devices.

[0137] The subj ect matter described herein can be implemented in a computing system that includes a back-end component (e.g., a data server), a middleware component (e.g., an application server), or a front-end component (e.g., a client computer having a graphical user interface or a web browser through which a user can interact with an implementation of the subject matter described herein), or any combination of such back-end, middleware, and front-end components. The components of the system can be interconnected by any form or medium of digital data communication, e.g., a communication network. Examples of communication networks include a local area network (“LAN”) and a wide area network (“WAN”), e.g., the Internet.

Claims

CLAIMS1. A compression and transportation system for gathering a gas from a gas production plant, and for transporting the gas to one or more gas utilization facilities, the com-pression and transportation system comprising:a gathering and boosting section, connectable to the gas production plant, configured to compress the gas received from the gas production plant for increasing the pressure of the gas;a pipeline system havingan inlet, connected to the gathering section,an outlet, connectable to the one or more gas utilization facilities, and at least one operating pipeline sub-system, connected to the inlet and the outlet;wherein the compression and transportation system further comprises a stor-age and compression station connected to the at least one operating pipeline sub-system of the pipeline system, wherein the storage and compression station is adapted to compress the gas coming from the gathering and boosting section, andwherein the storage and compression station is capable of operating in a first operating mode, when the gas production plant produces gas, to store compressed gas within the at least one operating pipeline sub-system of the pipeline system, and in a second operating mode, to supply the gas stored in the at least one operating pipeline sub-system of the pipeline system to the gas utilization facilities.

2. The compression and transportation system of claim 1, comprising a control unit operatively connected to the compression station, and adapted to operate storage and compression station in the first and second operating modes.

3. The compression and transportation system of claim 1, wherein the gas production plant is configured to operate in a range of nom-inal or normal production capacity, andwherein the storage and compression station operates in the second operat-ing mode when the gas production plant is not operating or it is operating at capacity production below the range of nominal or normal capacity.

4. The compression and transportation system of claim 1, wherein the storage and compression station comprisesan inlet, connected to the at least one operating pipeline sub-system of the pipeline system,an outlet, connected to the at least one operating pipeline sub-system of the pipeline system, anda valve group, adapted to control and adjust the connection of the inlet and the outlet of the storage and compression station to the at least one operating pipeline sub-system of the pipeline system, andwherein the control unit is operatively connected to the valve group, to operate the storage and compression station in the first and second operating modes.

5. The compression and transportation system of claim 1, wherein the storage and compression station comprises one or more first compressors, for compressing the gas to allow the storage of the gas into the at least one operating pipeline sub-system of the pipeline system when operating in the first mode.

6. The compression and transportation system of claim 1, wherein the at least one first compressor is stopped when the storage and compression station operates in the second operating mode.

7. The compression and transportation system of claim 1, wherein the at least one operating pipeline sub-system of the pipeline system comprises at least one transportation pipeline sub-system for transporting the gas from the gathering and boosting section to one or more gas utilization facilities.

8. The compression and transportation system of claim 5, wherein the one or more one compressors of the storage and compression station is connected to the transportation pipeline sub-system, and wherein, in the first operating mode, the gas compressed by the one or more compressors of the storage and compression station, is stored in the transportation pipeline sub-system by means of the valve group.

9. The compression and transportation system of claim 1,wherein the at least an operating pipeline sub-system of the pipeline system comprises a storage pipeline sub-system, connected to the storage and compression station,wherein, in the first operating mode, the storage and compression station is operated so that the gas compressed by the storage and compression station is stored in the storage pipeline sub-system, andwherein, in the second operating mode, the storage and compression station is operated so that the gas stored in the storage pipeline sub-system is released to supply the gas utilization facilities.

10. The compression and transportation system of claim 5, wherein the storage and compression station comprises one or more second compressors,wherein, when the compression and transportation system operates in the first operating mode, the one or more first compressors compresses the gas, to allow its transportation through the transportation pipeline sub-system, and one or more second compressors is connected in series with the at least one first compressor, to compresses and store the excess gas in the storage pipeline sub-system, and wherein, when the compression and transportation system operates in the second operating mode, the one or more first compressors and one or more second compressors operate in parallel to introduce the gas stored in the storage pipeline sub-system into the transportation pipeline sub-system.

11. The compression and transportation system of claim 7, comprising one or more transportation stations configured for compressing the gas along the transportation pipeline sub-system of the pipeline system to transport the gas from the inlet to the outlet, to supply the gas utilization facilities.

12. The compression and transportation system of claim 11, wherein each transportation station comprises at least one compressor, preferably a centrifugal or a reciprocal compressor.

13. The compression and transportation system of claim 1, wherein the gathering and boosting section comprises at least oneor more compressors, operating in series and / or in parallel, configured to compress the gas to a boosting pressure,wherein the gathering and boosting section comprises a combination of cen-trifugal compressors and reciprocating compressors configured to operate in series or parallel to manage different inlet pressure levels and flow rates, and wherein the boosting pressure is preferably comprised within 30-60 bar.

14. The compression and transportation system of claim 1, wherein the pipeline system further comprises a pressure let-down station at the outlet, wherein the pressure let-down station, to reduce the pressure of the pipeline system at a usage pressure, suitable for the gas utilization facilities, wherein the pressure let-down station comprises:a pressure control valve,an expander configured to reduce pressure, to allow the and recover energy, andan electric generator, connected to the expander, to generate current.

15. The compression and transportation system of claim 1, further comprising a nitrogen generator, connected by a blending nitrogen connecting pipe to the inlet of the pipeline system, wherein the nitrogen generator is configured to blend nitrogen (N2) into the pipeline system up to a percentage of the volume r.

16. The compression and transportation system of claim 15, wherein percentage of the volume r is less or equal to 10% vol..

17. The compression and transportation system of claim 1, further comprising a compensation tank interconnected between the gathering and boosting section and the inlet of the pipeline system,wherein the compensation tank is adapted to stabilize the pressures in case of fluctuations of the gathering and boosting section and / or the gas production plant.

18. The compression and transportation system of claim 1, wherein the transportation pressure is comprised between 50 bar and 60 bar.

19. The compression and transportation system of claim 1, wherein the gas is Hydrogen (JL), Helium (He), Nitrogen (N2), Ammonia (NH3), Carbon Dioxide (CO2), or other gases derived from separation processes or obtained through chemi-cal / thermodynamic processes that use fluids produced from renewable or non-renew-able sources, wherein their production is not constant over time.

20. A method of managing a compression and transportation system connected to a gas production plant operating at different pressures and flow rates, to transport the gas to one or more gas utilization facilities, wherein the compression and transportation system comprises:a gathering and boosting section, connectable to the gas production plant, configured to compress the gas received from the gas production plant for increasing the pressure of the gas;a pipeline system having an inlet, connected to the gathering section, an outlet, connectable to the one or more gas utilization facilities, and at least one operating pipeline sub-system, connected to the inlet and the outlet; wherein the compression and transportation system further comprises a storage and compression station connected to the at least one operating pipeline sub-system of the pipeline system, wherein the storage and compression station is adapted to compress the gas coming from the gathering and boosting section, and wherein the storage and compression station is capable of operating in a first operating mode, when the gas production plant produces gas, to store compressed gas within the at least one operating pipeline sub-system of the pipeline system, and in a second operating mode, to supply the gas stored in the at least one operating pipeline sub-system of the pipeline system to the gas utilization facilities,wherein the gas production plant is able to operate in a nominal or normal production capacity, the method comprising the step of:receiving gas from the gas production plant;operating the storage and compression station in the first operating mode, when the gas production plant is operating at capacity production within or above than the range of nominal or normal capacity; andoperating the storage and compression station in the second operating mode, when the gas production plant is operating at capacity production below the range of nominal or normal capacity.

21. The method of claim 20,wherein the step of operating the storage and compression station in the first operating mode comprises the sub-steps of:connecting the at least one first compressor and the second compressor of the storage and compression station in series;compressing the gas, to allow its transportation through the transportation pipeline sub-system, by means of the at least one first compressor; and storing the excess gas in the storage pipeline sub-system, by means of the second compressor.

22. The method of claim 20,wherein the step of operating the storage and compression station in the sec-ond operating mode comprises the sub-steps of:connecting the at least one first compressor and the second compressor of the storage and compression station in parallel; andintroducing the gas stored in the storage pipeline sub-system into the trans-portation pipeline sub-system to supply the gas to the gas utilization facilities.

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