METHOD FOR MIXING TWO OR MORE LIQUEFIED HYDROCARBON STREAMS

Description

1 / 38 METHOD FOR MIXING TWO OR MORE LIQUEFIED HYDROCARBON STREAMS Field of invention

[001] This descriptive report refers generally to the field of hydrocarbon blending and, more specifically, to processes for blending two or more streams of liquefied hydrocarbons. Background of the invention

[002] This section aims to present various aspects of the technique that may be associated with exemplary embodiments of the present invention. It is believed that this discussion will help provide a framework to facilitate a better understanding of particular aspects of the present invention. Consequently, it should be understood that this section should be read in that context, and not necessarily as admissions of any prior art.

[003] In general, it is commercially important to cryogenically liquefy natural gas in order to produce LNG for more convenient storage and transport. A fundamental reason for liquefying natural gas is that liquefaction results in a reduction in volume, thus making it possible to store and transport large volumes of liquefied gas in low-pressure or even atmospheric pressure containers in an economical manner, and thus provide a technically sound and safe solution in situations where pipeline transport is not practical or economically viable.

[004] The mixing of an LNG product, comprising mainly methane, with another component, such as light hydrocarbons like ethane, propane, or butane, to increase the heating value of LNG to meet market demands is known. For example, document US20140338393 discloses a method for producing a mixed blend of liquefied natural gases to meet particular requirements. Petition 870250092087, dated 08 / 10 / 2025, page 14 / 62 2 / 38 of an operator at a production facility, application site, or supply station mixing a lean liquefied natural gas and a rich liquefied natural gas. In another example, document WO2005093017 discloses compositions comprising mixtures of natural gas and synthetic light hydrocarbons, such as C2 to C5 paraffins, olefins, and mixtures thereof, obtained through hydrocarbon synthesis reactions, which are suitable for use as fuel compositions and particularly for mixtures of such synthetic light hydrocarbons and LNG-derived natural gas produced in an LNG process. In yet another example, document US8381544 discloses altering the heating value of a liquefied natural gas by adding higher heating value components using LNG to cool the higher heating value component stream before combining the higher heating value components with the LNG.

[005] Furthermore, US patent 11416012 discloses the in-line mixing of hydrocarbon liquids from a plurality of containers into a single pipeline, where the hydrocarbon liquids are generally those that exist in a liquid state under atmospheric conditions, such as hydrocarbons that exist as a viscous liquid in underground and surface geological formations, gasoline, crude oils, pyrolysis oil, etc. In this way, this patent reference does not address the challenges of mixing liquefied hydrocarbons.

[006] These disclosures, however, do not address potential challenges associated with mixing two liquefied hydrocarbon streams that have different properties, such as density. As such, it would be desirable to have an improved process for mixing two or more liquefied hydrocarbon streams. These and other objectives will become apparent from the disclosure provided in this document. Summary of the invention Petition 870250092087, dated 08 / 10 / 2025, p. 15 / 62 3 / 38

[007] A method is provided for mixing two or more liquefied hydrocarbon streams in an installation comprising a first storage vessel for storing a first liquefied hydrocarbon, which is optionally liquefied natural gas; a conveying system for sending the first liquefied hydrocarbon to downstream processing equipment, which optionally comprises regasification equipment; and a pipeline network.The pipeline network comprises (i) a first mixing point located downstream of the first storage vessel and upstream of the delivery system, (ii) a first pipeline segment to provide fluid communication between the first storage vessel and the first mixing point, (iii) a second pipeline segment to provide fluid communication between a source of a second liquefied hydrocarbon and the first mixing point, optionally the second liquefied hydrocarbon is selected from a group consisting of liquefied ethane, liquefied butane, liquefied propane and any combination thereof; and (iv) combined pipelines to provide fluid communication between the first mixing point and the delivery system. The combined pipelines comprise a first end valve immediately upstream of an inlet of the delivery system.The method comprises: (a) pumping a first stream of liquefied hydrocarbon from the first storage vessel to the first mixing point through the first pipeline segment; (b) pumping a second stream of liquefied hydrocarbon from the second liquefied hydrocarbon source to the first mixing point through the second pipeline segment; (c) combining the first and second streams of liquefied hydrocarbons at the first mixing point in a volumetric ratio in a range of 1:500, preferably 1:100 and up to 500:1 to provide a combined stream; (d) supplying at least a portion, including all, of the combined stream from the first mixing point to the delivery system through the... Petition 870250092087, dated 08 / 10 / 2025, page 16 / 62 4 / 38 combined conduits, and (e) while the combined stream is between a segment of the combined conduits between the first mixing point and the first end valve, provide the combined stream with an operating pressure above (preferably at least 0.1 bar above, more preferably at least 0.5 bar above, most preferably at least 1.2 bar above) a saturation pressure of the combined stream.

[008] Optionally, in some embodiments, the conduit network further comprises combined return conduits (160) to provide fluid communication between the first mixing point and a storage vessel, optionally the storage vessel is the first storage vessel. The combined return conduits comprise a second end valve immediately upstream of a combined return conduit outlet.In such an embodiment, the method may further comprise supplying at least a portion of the combined stream from a segment of the combined conduits upstream of the first end valve to a storage vessel; while the portion of the combined stream is in a segment of the combined conduits between the first mixing point and the second end valve, supplying the portion of the combined stream with an operating pressure above (preferably at least 0.1 bar above, more preferably at least 0.5 bar above, most preferably at least 1.2 bar above) a saturation pressure of the combined stream.

[009] Optionally, in some embodiments, at least one portion, including the entire combined stream, is not supplied to the storage container.

[0010] Optionally, in some embodiments, the combined conduits additionally comprise a first subsequent mixing point located upstream of the first end valve and downstream of the first mixing point and, optionally, upstream or downstream of Petition 870250092087, dated 08 / 10 / 2025, p. 17 / 62 5 / 38 combined return conduits. In this embodiment, the method may further comprise: (f) supplying a second stream of the first liquefied hydrocarbon from a source of the first liquefied hydrocarbon, optionally the first storage vessel, to the first subsequent mixing point; (g) combining the combined stream and the second stream of the first liquefied hydrocarbon at the first subsequent mixing point in a volumetric ratio in a range of 25:1, preferably 50:1 and up to 500:1, wherein the first stream of the first liquefied hydrocarbon and the stream of the second stream of ethanol liquefied hydrocarbon are combined in a volumetric ratio in a range of 1:500, preferably 1:100 and up to 50:1 at the first mixing point.

[0011] Optionally, in some embodiments, the combined conduits additionally comprise a second subsequent mixing point located downstream of the final valve and upstream of the mixed product storage vessel. In such embodiment, the method may further comprise: (f) providing a third stream of first liquefied hydrocarbon from a first liquefied hydrocarbon source to the second subsequent mixing point, such source being different from the first storage vessel and may optionally comprise a boiling gas management system (150);(g) combining the combined stream and the third stream of the first liquefied hydrocarbon at the second subsequent mixing point in a volumetric ratio in the range of 25:1, preferably 50:1, and up to 150:1, wherein the first LNG stream and the ethane stream are combined in a volumetric ratio in the range of 1:500, preferably 1:100, and up to 50:1 at the first mixing point and wherein the combined stream and the second stream of the first liquefied hydrocarbon are combined in a volumetric ratio in the range of 100:1, preferably 150:1, and up to 500:1 at the first subsequent mixing point. Petition 870250092087, dated 08 / 10 / 2025, page 18 / 62 6 / 38

[0012] Optionally, in some embodiments, the combined conduits also include a subsequent mixing point located downstream of the final valve and upstream of the mixed product storage vessel.In this embodiment, the method may further comprise: (f) providing another stream of the first liquefied hydrocarbon from a second source of the first liquefied hydrocarbon to the subsequent mixing point, optionally such source being different from the first storage vessel, optionally comprising a boiling gas management system; (g) combining the combined stream and the other stream of the first liquefied hydrocarbon at the subsequent mixing point (308) in a volumetric ratio in a range of 25:1, preferably 50:1, and up to 500:1, wherein the first stream of the first liquefied hydrocarbon and the stream of the second liquefied hydrocarbon are combined in a volumetric ratio in a range of 1:500, preferably 1:100, and up to 50:1 at the first mixing point.

[0013] Optionally, in some embodiments, the combined stream downstream of the first end valve and downstream of any subsequent mixing point, and may optionally also be downstream of the second end valve. In such embodiment, the combined stream may comprise a volumetric ratio of the first liquefied hydrocarbon, preferably LNG, to the second liquefied hydrocarbon, preferably liquefied ethane, of at least 2:1, preferably at least 3:1 and more preferably 4:1.

[0014] Optionally, in some embodiments, the method may additionally comprise providing the pipeline network with a total operating pressure of at least 2 barg.

[0015] Optionally, in some embodiments, the method may further comprise reducing the operating pressure of the combined stream downstream of the second end valve to less than the pressure of Petition 870250092087, dated 08 / 10 / 2025, page 19 / 62 7 / 38 Saturation of the combined stream. In such an embodiment, the method may further comprise reducing the operating pressure of the combined stream downstream of the second end valve to the storage pressure of the storage vessel.

[0016] Optionally, in some embodiments, step (a) is preferably carried out before step (b). In such embodiments, step (a) may comprise circulating the first stream of the first liquefied hydrocarbon from the first storage vessel through the first portion of conduits, the combined conduits, optionally back to the first storage vessel and, optionally, through a boiling gas management system.

[0017] Optionally, in some embodiments, the second liquefied hydrocarbon may be liquefied ethane and the source of liquefied ethane is selected from the group consisting of land-based storage and ethane transport vessels and any combination thereof.

[0018] Optionally, in some embodiments, the installation may include an LNG regasification plant.

[0019] Optionally, in some embodiments, the method may additionally include supplying the contents of the storage container to the shipping system. Brief description of the drawings

[0020] Figure 1 represents a diagram of an exemplary embodiment of a system for use in mixing two or more liquefied hydrocarbon streams according to aspects disclosed in the present disclosure.

[0021] Figure 2 represents a diagram of an exemplary embodiment of another system for use in mixing two or more liquefied hydrocarbon streams according to aspects disclosed in the present disclosure. Petition 870250092087, dated 08 / 10 / 2025, p. 20 / 62 8 / 38

[0022] Figure 3 represents a diagram of an embodiment further exemplifying another system for use in mixing two or more liquefied hydrocarbon streams according to aspects disclosed in the present disclosure.

[0023] Figure 4 represents a diagram of an embodiment further exemplifying another system for use in mixing two or more liquefied hydrocarbon streams according to aspects disclosed in the present disclosure. Detailed description of the invention

[0024] The present invention will now be described in detail with reference to its embodiments, as illustrated in the accompanying drawings. References to “an exclusive embodiment”, “any embodiment”, an “exemplary embodiment”, etc., indicate that the described embodiment may include a specific feature, structure or characteristic, but each embodiment may not necessarily include the specific feature, structure or characteristic. Furthermore, such phrases do not necessarily refer to the same embodiment. Additionally, when a specific feature, structure or characteristic is described in connection with an embodiment, it is understood that it is part of the knowledge of one skilled in the art to affect such feature, structure or characteristic in connection with other embodiments, whether or not explicitly described.Other modifications and adaptations appropriate to the variety of conditions and parameters normally encountered in the field, and which would be evident to those skilled in the art, are within the spirit and scope of the invention.

[0025] Although the description of the present invention provides several specific details that are set forth for a complete understanding of illustrative embodiments, it will be evident to those skilled in the art that the embodiments can be practiced without some or all of these specific details. In other cases, well-defined process steps and / or structures may be used. Petition 870250092087, dated 08 / 10 / 2025, page 21 / 62 9 / 38 known embodiments have not been described in detail so as not to unnecessarily obscure the present invention. The features and advantages of the embodiments can be better understood with reference to the drawings and discussion that follow.

[0026] Furthermore, when similar elements are used in one or more figures, identical reference characters will be used in each figure and a detailed description of the element will be provided only in its first occurrence. Some features or components of the systems or processes described herein may be omitted in certain configurations shown for clarity.

[0027] A general concern when mixing an LNG product with lighter hydrocarbons is the potential formation of stratified liquid layers (or stratification) of different densities in a storage vessel. Typically, heat leaking into the mixed LNG product through the walls of the storage vessel will slowly heat the LNG mixture in contact with the vessel walls and the bottom plate. This warmer mixed LNG has a lower density, which increases its buoyancy, slowly causing the warmer mixed LNG to rise in the bulk LNG inventory. At the top of the liquid column (vapor-liquid interface), the warmer LNG releases excess accumulated heat through vaporization, becoming cooler and denser, which in turn decreases its buoyancy, slowly causing the cooler mixed LNG to descend in the bulk LNG inventory.These conventional natural currents will occur uninterrupted as long as the density difference within the bulk LNG mixture is less than 1%. In situations where the density in the bulk is greater than 1%, different layers of LNG will form, disrupting the natural convection of the bulk LNG. When there is a potential for LNG mixtures with different densities to be introduced into the same vessel... Petition 870250092087, dated 08 / 10 / 2025, page 22 / 62 10 / 38 particularly as in this case at least a 10% difference in density between lean LNG (methane) and liquefied ethane, it is essential to maintain homogeneity and mitigate stratification. Once stratified liquid layers are formed, a rollover can occur when the density difference between the two layers becomes small enough that natural convection currents from the lower layer reach the free surface. The subsequent mixing of these layers is accompanied by a large increase in the normal vaporization rate, which will be proportional to the amount of superheat accumulated in the lower layer. This physical phenomenon associated with the mixing of stratified LNG layers is commonly and descriptively called “rollover”.A high-intensity rollover can, however, result in the release of steam exceeding the container's designed steam handling capabilities and may thus cause overpressure and possibly rupture the storage container.

[0028] Although the present disclosure frequently refers to LNG and ethane as the two liquefied hydrocarbon streams that benefit from the blending methods described herein, it is understood that the principles provided by the present disclosure can be applied to blending other liquefied hydrocarbon streams, such as (i) LNG and liquefied propane, or (ii) LNG and a mixture of liquefied ethane, liquefied propane, liquefied butane and any combination thereof.

[0029] As used in this document, the term “hydrocarbon” has its common meaning, which includes molecules composed of carbon and hydrogen in various combinations and can be of fossil origin (e.g., natural gas) or biogenic origin (e.g., biomethane). The term “liquefied hydrocarbons” refers to hydrocarbons that occur as gases at atmospheric pressure and temperature and, due to a reduction in temperature and / or an increase in pressure, or a combination of both, will change state and become liquids under the new pressure and temperature conditions. Petition 870250092087, dated 08 / 10 / 2025, page 23 / 62 11 / 38 temperature. In some cases (such as natural gas liquefaction), this phase change can also be coupled with a subsequent reduction in operating pressure to meet downstream processes (e.g., atmospheric LNG storage), further reducing the temperature of the liquefied hydrocarbon stream. The specific combination of pressures and temperatures at which gases liquefy varies depending on the type of hydrocarbon. In addition, hydrocarbons can be described as light or heavy according to the number of carbon and hydrogen atoms in a molecule. Examples of liquefied hydrocarbons include alkanes (or paraffins) (such as methane - CH4, ethane - C2H6, propane - C3H8, butanes: normal butane and isobutane - C4H10, natural gasoline or heavier pentanes - C5H12); and alkenes (or olefins) (such as ethylene-C2H44, propylene-C5H6, normal butylene and isobutylene^Hg).

[0030] The present disclosure provides methods for conducting a blending operation of two liquefied hydrocarbon streams to produce liquefied natural gas with the desired composition in an LNG facility that mitigates the risk of stratification. In addition, certain embodiments of the methods of the present disclosure allow routing at least a portion, including all, of the blended product stream to the shipping system, with the option of bypassing, partially or completely, a storage vessel.As used in this document, the term shipping system has its common meaning and generally refers to pumping equipment that sends a stream of liquefied hydrocarbon, such as LNG, for downstream processing, in order to convert the liquefied hydrocarbon stream into vapor to be sent to a pipeline system for use by consumers and / or loading of the liquefied blended product for distribution (including ISO container, tank truck or tanker truck, fueling, etc.). For context, a facility, particularly a regasification facility, typically provides a... Petition 870250092087, dated 08 / 10 / 2025, page 24 / 62 12 / 38 Liquefied hydrocarbon is sent to the shipping system for downstream processing via a storage vessel in fluid communication with said shipping system. The embodiments of the present disclosure provide the option of supplying the blended product to the shipping system without first going with the blended LNG stream through the storage vessel, thus providing operational efficiency improvements. Furthermore, such a bypass of a storage vessel reduces the need to engage the evaporation gas management (BOG) system associated with managing the BOG that is formed from the portion entering the receiving vessel. This is particularly relevant in assets where the BOG management system is an operational constraint, particularly a significant one.Furthermore, such diversion from a storage vessel reduces and even potentially eliminates any risk associated with stratification in the storage vessel and may thus allow a relaxation of the proposed mitigation measures. Embodiments of the present method may provide other additional benefits that are evident to one skilled in the art. In addition, certain embodiments of the methods described in this document may be suitably adapted for blending lean LNG with liquefied ethane to meet desired LNG and / or natural gas specifications (such as Wobbe Index (WI), Lower Heating Value (LHV), Methane Number (MN), or Incomplete Combustion Factor (ICF)) at various LNG installations or sites using the respective site's existing infrastructure.

[0031] Figures 1 to 4 represent various installations comprising a storage vessel 102 for storing a first liquefied hydrocarbon, preferably LNG, and a delivery system 106 for supplying a stream of liquefied hydrocarbon for downstream processing, such as regasification equipment. The installations shown further comprise a network of pipelines in Petition 870250092087, dated 08 / 10 / 2025, page 25 / 62 13 / 38 fluid communication with both storage vessel 102 and delivery system 106. Optionally, LNG installations may further comprise combined return conduits 160 to provide fluid communication between the combined conduit 116 and storage vessel 102. Although Figures 1-4 represent conduits 160 as routing the combined stream from conduits 116 to vessel 102, it is understood that the conduits may alternatively or additionally direct the combined stream from conduits 116 to another suitable storage vessel (on land and / or a vessel), even if not explicitly represented. In general, liquefied natural gas (LNG) is natural gas (predominantly methane) that has been liquefied.It is understood that the figures omit certain portions of the pipeline network, such as recirculation and loading / unloading pipelines, which are not explicitly referenced but are still part of the installation as understood by one skilled in the art. LNG can be stored in vessel 102 and / or 106 at a temperature below -110°C, depending on the application, and more typically below -145°C, such as between -159°C and -162°C. The LNG in vessel 102 is typically lean LNG at the start of mixing operations. In certain embodiments involving routing the combined or mixed stream back to vessel 102, then the LNG composition will be “richer” at the end of the mixing operation compared to the beginning. Generally speaking, “lean” LNG has a relatively lower calorific value, while “rich” LNG contains a higher proportion of heavier hydrocarbons, which gives it a higher calorific value.Low-grade LNG can be further enriched, as by methods described in this document, to meet various market quality specifications, such as the Wobbe Index (WI), Lower Heating Value (LHV), Methane Number (MN), or Incomplete Combustion Factor (ICF).

[0032] The conduit network comprises a first point of Petition 870250092087, dated 08 / 10 / 2025, page 26 / 62 14 / 38 mixing, which may be called an LNG-ethane mixing point 108 in reference to a preferred embodiment, located between the pier and the storage vessel (102). The conduit network further comprises the first conduit segment 110 (which may be called LNG conduits 110 for a preferred embodiment in which the first liquefied hydrocarbon is LNG) and the second conduit segment 112 (which may be called ethane conduits 112 for a preferred embodiment in which the second liquefied hydrocarbon is ethane). The first conduit segment 110 provides fluid communication between the first storage vessel 102 and the first mixing point 108. The second conduit segment 112 provides fluid communication between the storage vessel 114 for the second liquefied hydrocarbon and the first mixing point 108.The vessel 114 may be referred to as the ethane source 114 with reference to a preferred embodiment in which the second liquefied hydrocarbon is ethane. The first mixing point 108 is a fluid conduit junction between the first conduit segment 110 and the second conduit segment 112. Preferably, the first mixing point 108 is a junction at or near the connection between the recirculation line and the discharge line. As can be seen, the mixing point 108 is also upstream of the delivery system 106. The mixing point 108 is a fluid conduit junction known to one skilled in the art. For example, suitable examples of mixing point 108 include a T-junction, Y-junction, a mixing T, a Y-pipe fitting, and any combination thereof.

[0033] In a preferred embodiment, the second liquefied hydrocarbon is ethane. Liquefied ethane can be stored at a temperature below -30°C, depending on the application, and more typically below 75°C, such as between -80°C and -89°C. Although Figure 1 depicts the ethane source 114 as being on a vessel (as an ethane carrier). Petition 870250092087, dated 08 / 10 / 2025, page 27 / 62 15 / 38 liquefied), it is understood that the ethane source 114 may suitably or alternatively be an onshore storage vessel as known to one skilled in the art. The pipeline network further comprises combined pipelines 116 to provide fluid communication between the first mixing point 108 and send the system 106 for downstream processing, so as to convert the liquefied hydrocarbon stream into vapor to be sent to a pipeline system for use by consumers. In specific assets, such as Liquid-in Liquid-Out type LNG assets, the delivery system may include cryogenic distribution piping or, alternatively, LNG pumping equipment and loading facilities for LNG vessels (e.g., supply vessels), LNG tank trucks, LNG railcars and / or LNG ISO containers.

[0034] The proper storage for liquefied hydrocarbons such as LNG, liquefied ethane, and others mentioned herein, is known to those skilled in the art. For example, suitable examples may include simple containment systems that typically have an inner wall or primary vessel that retains the refrigerated liquid and may be self-supporting. The inner vessel may be surrounded by an outer wall, thus forming an annular space, which may contain insulation. The simple containment system may be further insulated, such as the base and roof, and external insulation. Another suitable example includes double containment systems that typically add to the simple containment system a secondary wall that is capable of containing both liquid and vapor.

[0035] A first stream of a first liquefied hydrocarbon, preferably liquefied natural gas (LNG), is pumped through the first pipeline segment 110 (which may be called LNG pipelines 110 in a preferred embodiment), from the storage vessel 102 to the first mixing point 108. With reference to Petition 870250092087, dated 08 / 10 / 2025, p. 28 / 62 16 / 38 Figure 1, the LNG stream can be pumped by at least pumping equipment 120. A stream of liquefied ethane is pumped through ethane conduits 112 from the ethane source 114 to the LNG-ethane mixing point 108. As used herein, the term “liquefied ethane”, “liquid ethane” or “ethane” refers to a liquefied hydrocarbon stream comprising at least 50 mol%, preferably at least 95 mol%, of ethane. As noted elsewhere in the present disclosure, liquefied hydrocarbons other than LNG and liquefied ethane can be mixed using the methods described in this document. For example, if LNG is being mixed with liquefied propane, then the liquefied hydrocarbon stream that is liquefied propane comprises at least 50 mol%, preferably at least 95 mol%, of propane; If liquefied butane, then the stream comprises at least 50 mol% butane, preferably at least 95 mol%.Optionally, if the liquefied hydrocarbon stream does not consist essentially of the component of its namesake (for example, the liquefied ethane stream is not essentially all ethane), the remaining portion of that stream will be selected from a group consisting of ethane, methane, propane, butane, and any combination thereof, as applicable. For example, an example of a liquefied hydrocarbon mixture as defined herein might be LPG, which stands for liquefied petroleum gas, which includes mixtures that are primarily propane, primarily butane, or primarily a mixture of propane and butane.

[0036] With reference to Figure 1, the pumping of the liquefied ethane stream can be done at least by pumping equipment 118. The first LNG stream and the ethane stream are combined at the LNG-ethane mixing point 108 at a volumetric mixing ratio of LNG to ethane in a range of 1:500 and up to 500:1, preferably 1:100 and up to 500:1, and more preferably 1:10 and up to 500:1, to provide a stream Petition 870250092087, dated 08 / 10 / 2025, page 29 / 62 17 / 38 combined. It is understood that a person skilled in the art can select an appropriate flow rate for the first LNG stream and the liquefied ethane stream to achieve a desired mixing ratio within the range described in this document, taking into account various factors such as the specifications and safe operating envelope (SOE) of the equipment and infrastructure involved in the mixing operation (e.g., pipeline network, pumps, storage vessels, valves, etc.). The appropriate number of pumps and pump types to implement the methods as described herein are known to those skilled in the art. Additionally or alternatively, the pumping equipment may be part of the existing infrastructure and equipment of the installation, such as a regasification plant.

[0037] In one embodiment, the combined stream may be supplied to the mixed product storage shipping system 106 via at least combined conduits 116 from the first mixing point 108, with or without being returned to the container 102 via conduits 160 and / or to another suitable storage container. In certain embodiments, if the combined stream is directed back to the container 102, the product in the container 102 may also be directed to the shipping system 106, typically using the existing infrastructure (not shown) of a particular facility, such as an LNG import facility.Preferably, the flow rate of the LNG stream and the flow rate of the ethane stream, through their respective pumps, provide adequate force to move the combined stream to the delivery system 106 or to the LNG storage vessel 102 (or other storage vessel (not shown)), without the need for additional pumping equipment.

[0038] The conduit network may comprise a plurality of valves as known to one skilled in the art for controlling the flow of various streams. For example, referring to Figure 1, optionally, the LNG conduits 110 may comprise a valve 122 for controlling the Petition 870250092087, dated 08 / 10 / 2025, page 30 / 62 18 / 38 flow of the first LNG stream flowing from storage vessel 102 to the LNG-ethane mixing point 108. Optionally, the ethane pipelines 112 comprise valve 124 to control the flow of the liquefied ethane stream flowing from the ethane source 114 to the LNG-ethane mixing point 108. In embodiments that include combined pipelines with return 160, the pipelines 160 may comprise valve 162 to control the flow from the combined pipelines 116 to vessel 102 (and / or other suitable storage vessel (not shown)). Valve 162 can be manipulated or controlled to allow the combined stream to partially or completely bypass container 102. Regardless of the number of valves positioned along the pipeline network, such as LNG pipelines 110, ethane pipelines 112, and combined pipelines 160 and 116, to control the flow of the respective stream, the pipeline network comprises an end valve 126.The end valve 126 is the last valve through which the combined stream flows before being introduced into the delivery system 106. That is, the end valve 126 is the valve immediately upstream of an inlet of the mixed product storage container delivery system 106. For embodiments that also include combined return conduits 160, the valve 162 is also considered another end valve before the combined product is introduced into the container 102.

[0039] At least during the mixing operation, the combined conduits 116 and, optionally, the conduits 160, have an operating pressure due at least to the force exerted by the flow of the combined stream through the respective combined conduits 116, as well as any flow control devices available in the conduits, such as the end valve 126 and, optionally, the valve 162.While the combined stream is being delivered to its destination, whether to the shipping system 106 and / or to the container 102 (or other container), the portion of the respective combined conduits, 116 and / or 160, between the mixing point of... Petition 870250092087, dated 08 / 10 / 2025, p. 31 / 62 19 / 38 LNG-ethane 108 and upstream of the respective end valve, 126 and / or 162, is provided with an operating pressure that is greater than the saturation pressure of the combined stream, preferably at least 0.1 bar, more preferably at least 0.5 bar and, most preferably, at least 1.2 bar above the saturation pressure of the combined stream. An operating pressure at least 1.2 bar greater than the saturation pressure of the combined stream is more preferable because it provides a more preferential buffer to accommodate fluctuations in pressure conditions along the conduits 116, although embodiments with a lower operating pressure that is greater than the saturation pressure of the combined stream may still provide the benefits described herein. The saturation pressure of the combined stream may change as it moves through the conduits 116 to the mixed product storage vessel 106, at least due to heat transfer from the environment and / or equipment.Generally, the saturation pressure of the combined stream increases as it moves through the combined conduits 116 towards the vessel 106. Or the operating pressure of the combined conduits 116 between the LNG-ethane mixing point 108 and the end valve 126 is frequently adjusted, preferably in response to monitoring, to accommodate the increase in saturation pressure and / or the saturation pressure of the combined stream may be reduced to ensure that the operating pressure remains higher than the saturation pressure of the combined stream as the saturation pressure changes.In addition to other benefits described elsewhere in this disclosure, by providing an operating pressure equal to or greater than the saturation pressure of the combined stream in the combined conduit portion 116 between the mixing point 108 and the end valve 126, the methods described herein mitigate the formation of two-phase flow in that combined conduit portion 116 (whether the two-phase flow formation is localized or sustained). Thus, the methods described herein... Petition 870250092087, dated 08 / 10 / 2025, page 32 / 62 20 / 38 document can minimize operational disturbances and damage to equipment (e.g., cavitation-induced valve erosion) as known to one skilled in the art. The term “saturation pressure” has its common meaning and includes the definition of the pressure at which the fluid exists as both vapor and liquid, and the rate of evaporation is equal to its rate of condensation for a given temperature. In this scenario, the saturation pressure of the combined stream is the pressure at which the combined stream exhibits a vapor and liquid phase, which are in thermodynamic equilibrium at the temperature of the combined stream. The saturation pressure of the combined stream while in the respective combined conduits, 160 and / or 116, between the LNG-ethane mixing point 108 and a respective end valve, 126 and / or 162 can be adequately determined by one skilled in the art, based on the temperature of the combined stream and mixing ratio (both of which can be measured by sensors).The conduit network may comprise suitable sensors known to one skilled in the art to provide the relevant data for implementing the methods as described herein. Examples of suitable sensors include hydrometers, gravimeters, densitometers, density measuring sensors, gravity measuring sensors, pressure transducers, temperature sensors, flow meters, mass flow meters, Coriolis meters, other measuring sensors for determining a density, gravity, or other variable as will be understood by those skilled in the art, or some combination thereof. The determination of the saturation pressure of the combined stream may be made manually or autonomously using a computer or other similar process control systems, so that subsequent corrective action (e.g., increasing the operating pressure of the system, increasing the mixing ratio, or otherwise) may be implemented as desired.The methods described in this document provide an operating pressure in the respective combined conduits, 116. Petition 870250092087, dated 08 / 10 / 2025, p. 33 / 62 21 / 38 and / or 160, between the LNG-ethane mixing point 108 and a respective end valve, 126 or 162, which is greater than the saturation pressure of the combined stream, preferably at least 0.1 bar, more preferably at least 0.5 bar, and most preferably at least 1.2 bar above the saturation pressure of the combined stream. Providing such an operating pressure that is greater than the saturation pressure of the combined stream allows the combined stream to remain in the liquid phase while flowing through these conduit segments, despite varying pressure conditions along such conduit segments.

[0040] Appropriately, the operating pressure of the combined stream in the combined conduits, as well as other parts of the conduit network, can be monitored as is known by one of the common abilities, such as by sensors. Monitoring can allow continuous monitoring of the operating conditions of the combined stream to ensure that the operating pressure in the combined conduits 116 remains above (preferably at least 0.1, 0.5 or 1.2 bar above) the saturation pressure of the combined stream. Optionally and preferably, an operating pressure of the combined stream upstream of a respective end valve, 126 or 162, which is greater than the saturation pressure of the combined stream can be provided by adjusting the percentage opening of a respective end valve, 162 or 126, to provide the desired operating pressure upstream of the respective end valve.The percentage of opening of the final valve 126 can be continuously adjusted as needed during mixing operation to provide the desired operating pressure equal to or greater than the saturation pressure of the combined stream, as described in this document.

[0041] Optionally, additionally or alternatively, the saturation pressure of the combined stream can be reduced by adjusting the volumetric ratio of the first LNG and liquefied ethane stream at the point of Petition 870250092087, dated 08 / 10 / 2025, page 34 / 62 22 / 38 LNG-ethane mixing 108 and / or along the combined conduits 116 providing additional mixing points. In general, the additional mixing point(s) allow more LNG to be added to the combined stream, which reduces the saturation pressure of the combined stream, thus providing another option to ensure that a combined stream operating pressure is obtained that is greater than the saturation pressure of the combined stream. For example, referring to Figure 2, the combined conduits 116 additionally comprise the subsequent mixing point 208 located upstream of valve 162, if present, and upstream of the final valve 126 and downstream of the LNG-ethane mixing point 108.As can be seen in Figure 2, the pipeline network further comprises another pipeline segment 216 (which may be referred to as second LNG pipelines 216 in a preferred embodiment) to provide fluid communication between storage vessel 102 (or a suitable second LNG source, not shown in Figure 2) and subsequent mixing point 208. In scenarios where the second LNG stream comes from storage vessel 102, the second LNG pipelines 216 may provide fluid communication between the subsequent mixing point 208 and vessel 102 via a connection to LNG pipelines 110 or may connect directly to vessel 102. When desired, a second stream of the first liquefied hydrocarbon, preferably LNG, may be supplied to the subsequent mixing point 208 from storage vessel 102 (or a second LNG source) via second LNG pipelines 216.Optionally and preferably, the second LNG conduits 216 may additionally comprise valve 222 to control the flow of the second LNG stream through the second LNG conduits 216. For example, valve 222 may be closed when mixing at the subsequent mixing point 208 is not desired and opened when mixing of LNG in addition to the combined stream is desired. Petition 870250092087, dated 08 / 10 / 2025, p. 35 / 62 23 / 38 The opening of valve 222 can be adjusted to achieve a desired mixing ratio at the subsequent mixing point 208. In Figure 2, the combined stream and the second LNG stream are combined at a ratio in a range of 25:1, preferably 50:1, and up to 500:1 at the subsequent mixing point 208, and the first LNG stream and ethane stream are combined at a ratio in a range preferably of 1:100 and up to 50:1 at the LNG-ethane mixing point 108. As an additional mixing point is provided, the LNG-ethane ratio at the LNG-ethane mixing point 108 can be lower than if there were only a single mixing point (i.e., 108).For example, in a single mixing point scenario, the LNG to ethane ratio at the LNG-ethane mixing point is in the range of 1:500 and up to 500:1 versus a multiple mixing point scenario as depicted in Figure 2, the ratio is in the range of 1:500, preferably 1:100, and up to 50:1 of LNG to ethane at the LNG-ethane mixing point 108 and 25:1, preferably 50:1, and up to 500:1 of combined stream to second LNG stream at the subsequent mixing point 208. The mixing ratio ranges provided, for a multiple mixing point scenario, may be extended or altered to meet specific asset and / or process requirements, as understood by one skilled in the art. For example, the first mixing points may have a mixing ratio of 1:1, while the second mixing point may have a mixing ratio of 47:1.

[0042] Optionally, additionally or alternatively, there may be a different mixing point downstream of the end valve 126. For example, referring to Figure 3, the combined conduits 116 additionally comprise the subsequent mixing point 308 located downstream of the end valve 126 and upstream of the delivery system 106. Optionally and alternatively, the subsequent mixing point 308 may be located upstream of the end valve 126, depending on the particular arrangement of the Petition 870250092087, dated 08 / 10 / 2025, p. 36 / 62 24 / 38 existing plant infrastructure where the mixing operation is performed. The pipeline network may further comprise BOG pipelines 148 which provide fluid communication between storage vessel 102 (and / or the vapor space of other vessels, both onshore and on vessels, available in the LNG asset, although not shown in the figures provided) and the evaporating gas management (BOG) system 150. During the operation of the LNG plant 100, including while LNG is stored in vessel 102, BOG is produced in vessel 102 (and / or others available in the LNG asset, although not shown in the figures provided), at least due to heat leakage from the environment and / or energy input from the discharge pumps and evaporated vapors due to the pressure difference between the LNG carrier and storage vessel 106.The BOG (in the vapor phase) is typically removed from storage vessel 102 (and / or others available in the LNG asset, although not shown in the figures provided) to mitigate the impacts of pressure buildup if the BOG is left in vessel 102. The BOG management system 150 typically comprises an evaporating gas compressor and a condenser column to condense (although other options and technical configurations may apply) and recover the BOG as LNG, which is provided to send to system 116A via return lines 316.

[0043] As can be seen in Figure 3, the pipeline network further comprises a third LNG pipeline 316 to provide fluid communication between a source of the first liquefied hydrocarbon, such as LNG (whose source may be different from the container 102, optionally the BOG management system 150 as represented) and subsequent mixing point 308. When desired, another LNG stream may be supplied to the subsequent mixing point 308 from the BOG management system 150 via third LNG pipelines 316. Although not Petition 870250092087, dated 08 / 10 / 2025, page 37 / 62 25 / 38 represented, it is understood that the third LNG conduits 316 may additionally comprise a valve to control the flow of the LNG stream through it. In Figure 3, the combined stream and the LNG stream from the BOG management system 150 are combined in a ratio in a range of 25:1, preferably 50:1 and up to 500:1 at the subsequent mixing point 208 and the first LNG stream and ethane stream are combined in a ratio in a range preferably of 25:1, preferably 50:1 and up to 500:1 at the LNG-ethane mixing point 108.For a multi-mixing-point scenario represented in Figure 3, the LNG-to-ethane mixing ratio at LNG-ethane mixing point 108 is in the range of 1:500, preferably 1:100 and up to 50:1, and at the subsequent mixing point 308, the ratio of the combined stream to the BOG management system LNG stream 150 is in the range of 25:1, preferably 50:1 and up to 500:1 at mixing point 308.

[0044] With reference to Figures 3 and 4, the conduit network may optionally comprise conduits 152, downstream of mixing point 108 and mixing point 208, if present, to provide fluid communication between the combined conduits 116 and the BOG management system 150. At least a portion of the combined flow may be supplied to the BOG management system 150 for the purpose of recondensing the BOG flow 148 (and / or other BOG flows originating from other LNG storage vessels or processes on site, although not disregarded in the figures provided) as standard in recondenser-based BOG management systems. The LNG mixing conduit 152 may further comprise a valve (not shown) to allow control over the amount of combined stream, if any, to be supplied to the BOG management system 150.Optionally, alternatively, or additionally, the mixed LNG 152 stream can serve another purpose within or outside the system. Petition 870250092087, dated 08 / 10 / 2025, page 38 / 62 26 / 38 BOG 150 management, not shown in the figures provided.

[0045] Optionally, additionally or alternatively, both additional mixing points may be present together with the LNG-ethane mixing point 108. For example, referring to Figure 4, the combined conduits 116 comprise both the subsequent mixing point 208 and the subsequent mixing point 308, as described in Figures 2 and 3, respectively. For the multiple mixing point scenario represented in Figure 4, the mixing ratio of (i) LNG to ethane at the LNG-ethane mixing point 108 is in a range of 1:500, preferably 1:100 and up to 50:1, (ii) the combined stream to the second LNG stream at the subsequent mixing point 208 is in a range of 25:1, preferably 50:1 and up to 150:1, and (iii) the combined stream to the BOG management system LNG stream 150 at the subsequent mixing point 308 is in a range of 100:1, preferably 150:1 and up to 500:1.Depending on the particular configuration of the asset implementation of this mixing process, the conduit network may comprise more than three mixing points represented in the figures (such as 108, 208, and 308) to achieve the desired operating pressure, which is greater than the saturation pressure of the combined stream. The mixing ratio ranges provided, for a multi-mixing-point scenario, may be extended or altered to meet specific asset and / or process requirements, as understood by one skilled in the art. For example, the first mixing point (such as 108) may have a mixing ratio of the first liquefied hydrocarbon stream to the second liquefied hydrocarbon stream of 1:1, while subsequent mixing points (such as 208 and / or 308) may have a mixing ratio of 47:1 of the combined stream to the first liquefied hydrocarbon stream.

[0046] Optionally and preferably, various mixing scenarios (such as single or multiple mixing points) and mixing ratios within the Petition 870250092087, dated 08 / 10 / 2025, page 39 / 62 27 / 38 ranges provided can be selected to achieve a volumetric LNG to ethane mixing ratio of at least 2:1, preferably at least 3:1, more preferably at least 4:1, in the combined stream that is downstream of the final valve 162 and / or the final valve 126 (for a scenario involving a single mixing point and / or multiple mixing points with the subsequent mixing point 208) or downstream of the subsequent mixing point 308 (for scenarios that include the mixing point 308).

[0047] It is understood that the BOG 150 management system may be present in other figures, such as Figure 1, even if not represented, where BOG 148 conduits are present to provide fluid communication between storage vessel 102 (or other vessels or vessels present on site) and the BOG 150 management system to manage BOG accumulation in storage vessel 102 (or other vessels or vessels present on site), as described in this document and known to one skilled in the art, including as part of the existing LNG plant infrastructure. The BOG 150 management system may be bypassed during mixing operation, as shown at least in Figures 1 and 2.

[0048] Optionally and preferably, the first LNG stream is pumped to the LNG-ethane mixing point 108 at a volumetric flow rate and pressure, which can be adjusted throughout the mixing operation to meet the relevant process requirements. Although the flow rate and pressure of the first LNG stream pumped to the mixing point 108 can be adjusted, it is preferable to minimize the rate of change in the operation of the first LNG stream to a reasonable and / or practical extent. Meanwhile, the volumetric flow rate and pressure of the liquefied ethane stream in the ethane conduits 112 can be suitably adjusted, as known to one skilled in the art, to meet the desired mixing ratio at the LNG-ethane mixing point 108, within a range of Petition 870250092087, dated 08 / 10 / 2025, page 40 / 62 28 / 38 1:500, preferably 1:100 to 500:1 of LNG to liquefied ethane, for a single mixing point, or the various mixing ratio ranges at other mixing points in scenarios that include multi-mixing points as described in this document.

[0049] The embodiments described in this disclosure provide options for implementation, such as a selection between a single-point mixing operation or a multi-point process, to allow consideration of various factors in optimizing the mixing operation as desired. For example, in an installation with hydraulic limitations in a conduit segment that is upstream of the first mixing point 108 (such as at least a portion of conduits 110 leading to the first mixing point having a reduced internal diameter, such as one that is 12 inches or less or one that is smaller than the diameter of conduits 116 and / or conduits 112).A multi-point mixing operation may be more suitable for such a scenario because such limitations can restrict a single-point mixing operation, such as in terms of flow rate and mixing ratio possibilities (including a reduction in the amount of second liquefied hydrocarbon that can be mixed) and higher operating costs. Furthermore, a multi-point mixing operation allows for improved control and flexibility of the overall operation.

[0050] With reference to Figures 1 to 4, the combined conduits 116 continue through the end valve 126 to supply the combined stream (which may be from single or multiple mixing point(s)) that sends to system 106, which is downstream of end valve 126. Optionally and preferably, the operating pressure of the combined stream is increased by the sending system 106 to generate a pressurized combined stream to supply the stream to a downstream LNG vaporizer system to produce a regasified natural gas stream that has adequate pressure for Petition 870250092087, dated 08 / 10 / 2025, p. 41 / 62 29 / 38 enter a fluidly connected natural gas electrical network. Suitable means or equipment for increasing the pressure in the delivery system 106 are provided elsewhere in this disclosure and may be selected by one skilled in the art based on particular conditions and parameters of a given installation or equipment.

[0051] Optionally, additionally or alternatively, the operating pressure of the combined stream in the respective combined conduits 116 (including 116A) and / or 160 and 116A may also be influenced by operating conditions of downstream systems in communication with the conduits located downstream of a respective end valve 162 or 126, as understood by one skilled in the art.

[0052] Optionally, the mixing operation can be further improved, such as by reducing the amount of time to complete the mixing operation, by providing a receiving storage vessel (a storage vessel to which the combined stream is being supplied, such as vessel 102) with an operating pressure that is higher than the saturation pressure of the combined stream. It is understood that the higher operating pressure is subject to limitations imposed by the safety operating parameters of the respective storage vessel. Preferably, the operating pressure of the vessel receiving the combined stream is at least 5% higher, more preferably at least 50%, and most preferably at least 100% higher than the saturation pressure of the combined stream.A suitable way to provide such a vessel with an operating pressure greater than the saturation pressure of the combined stream is to adjust the BOG pressure setpoint as known to one skilled in the art.

[0053] The option of providing a receiving storage vessel with an operating pressure higher than the saturation pressure of the combined stream is subject to limitations imposed by Petition 870250092087, dated 08 / 10 / 2025, pages 42 / 62 30 / 38 safety operating parameters of the respective storage vessel, is not typical in standard operating practice (primarily storage of liquefied hydrocarbon for transport) for these storage vessels and may be applied as desired. If employed, the higher operating pressure is temporarily supplied to the respective storage vessel during part or all of the mixing operation, or even maintained after the mixing operation, as desired.

[0054] In general, for storage, it is desirable to maintain a relatively low operating pressure, preferably as low as possible within the relevant technical and contractual constraints, to keep the product temperature in the storage vessel correspondingly low, thus optimizing the volumetric capacity of the storage vessel and reducing BOG formation. In the long term, the lower operating pressure is even more desirable because it can help minimize changes in LNG quality over time. It is understood that the standard practice of maintaining a low operating pressure for the receiving storage vessel is also available as an option for selection during part or all of the mixing operation.Achieving a desired operating pressure for a specific receiving vessel is primarily accomplished by managing the BOG (Blood-Off Gas) of the respective vessel, typically through the associated BOG management system. By providing the applicable storage vessel(s) with a higher operating pressure during mixing, the intermittency of the combined stream as it enters the respective storage vessel is reduced or potentially eliminated, minimizing or even eliminating the boiling gas formation rate associated with mixing. A minimal or zero BOG formation rate during mixing relaxes the... Petition 870250092087, dated 08 / 10 / 2025, page 43 / 62 31 / 38 restrictions on boiling gas management, which reduces operating time. Once the mixing operation is complete, the operating pressure of the respective vessel can be reduced to return it to the standard operating pressure or, optionally, maintained in accordance with the relevant technical and contractual restrictions imposed on the vessel and its cargo. The BOG can be managed using standard operating procedures after the mixing operation, thus allowing the mixing operation to proceed without time delays associated with BOG management.

[0055] The methods of the present disclosure address certain negative impacts of tank mixing of two different liquefied hydrocarbons, such as stratification, by promoting in-line mixing of two different liquefied hydrocarbons in a conduit under an operating pressure that is greater than the saturation pressure of the combined stream. Since the saturation pressure of the combined stream can vary along its path from mixing point 108 to its destination, such as back to vessel 102, the reference to “saturation pressure of the combined stream” is generally in the context of a particular segment of conduits.Adjusting mixing ratios and / or providing additional mixing points, as described in this document, are some suitable ways to manipulate the operating pressure of a relevant pipeline segment and / or influence the saturation pressure of the combined stream in the relevant segment to achieve the desired operating pressure level that is greater than the saturation pressure of the combined stream to ensure that it remains in the liquid state.

[0056] In addition, the methods described in this document also provide an option to minimize BOG management requirements during mixing operations, thereby decreasing the operating time of the mixing operation, by providing the respective receiving storage vessel with an operating pressure that is greater than the saturation pressure. Petition 870250092087, dated 08 / 10 / 2025, page 44 / 62 32 / 38 of the combined stream to minimize intermittency of the combined stream as it enters the respective storage container.

[0057] As mentioned in this disclosure, the methods in this document can be employed to conduct a blending operation of two liquefied hydrocarbon streams, such as LNG and liquefied ethane, particularly in existing facilities using infrastructure already being used in standard operations, such as LNG regasification. For example, an LNG facility that supplies LNG or natural gas to downstream users aims to supply “rich” LNG to downstream users, although it is limited by the lean LNG input from global markets, the methods described in this document can be used to add liquefied ethane (or other lighter hydrocarbon or light hydrocarbon blend) to the facility’s LNG using existing infrastructure such as pump equipment, pipelines and valves, etc. When blending is desired, certain operational parameters of the facility may be altered to implement the methods described in this document.

[0058] During standard operation, the LNG import facility is operated under its standard parameters to allow for LNG regasification. When blending LNG with another liquefied hydrocarbon is desired, the methods described in this document can be employed with minimal changes to existing infrastructure and ease of transition between blending mode and normal plant operation mode, such as shipment for downstream processing. Before the start of blending operation, the product in storage vessel 102 is typically lean LNG which can be further enriched with another liquefied hydrocarbon. Before combining the lean LNG with another liquefied hydrocarbon, such as ethane, the lean LNG from storage vessel 102 is sent to the LNG pier and back to the LNG storage vessel (such as from vessel 102 to blending point 108 via pipelines 110 (or other pipelines)). Petition 870250092087, dated 08 / 10 / 2025, page 45 / 62 33 / 38 similar) back to container 102 (or another container) through conduits 160, passing through the BOG management system 150 (partially or completely as shown in Figures 3 and 4) and to the shipping system 106 or bypassing the BOG management system 150 completely (as shown in Figures 1 and 2)).

[0059] Before the second stream of liquefied hydrocarbon is supplied to the first mixing point 108, lean LNG from storage vessel 102 is preferably first supplied to mixing point 108 and at least to send to system 106 via pipelines 116 and optionally back to vessel 102 (both may be as part of the normal shipping operation) and to 106, to ensure cooling of the mixing pathway for at least the combined stream. After circulation of the first liquefied hydrocarbon is established, the second stream of liquefied hydrocarbon may be pumped from the second vessel 114 in accordance with aspects described in this disclosure to initiate the mixing operation. This includes supplying the combined stream to shipping system 106 at an operating pressure that is greater than the saturation pressure of the combined stream.Additional benefits of LNG recirculation (under various circulation scenarios) (i) before the addition of the second liquefied hydrocarbon (such as liquefied ethane) and (ii) during the mixing operation include keeping the various pipelines cool to minimize vapor formation, particularly at mixing point 108, and to facilitate mixing. Furthermore, if desired and equipment available, LNG circulation supplies LNG to the BOG management system 150, enabling BOG recondensation upstream of the LNG delivery system 106. Lean LNG circulation, as described, can be suitably facilitated by various pumping equipment, such as pumps 118 and 120. Once lean LNG recirculation has been established, if it is not already being done, the liquefied ethane stream can be pumped from the source. Petition 870250092087, dated 08 / 10 / 2025, pp. 46 / 62 34 / 38 of ethane 114 according to aspects described in the present disclosure to initiate the mixing operation. That is, the first LNG stream is pumped into the pipeline network before the liquefied ethane stream.

[0060] The combined stream may be supplied back to vessel 102 or another vessel as part of the circulation or recirculation route, provided it has an operating pressure greater than the saturation pressure of the combined stream at least in the portion of conduits 116 between the mixing point 108 and the end valve 162. Additionally or alternatively, certain embodiments of the methods described in this document provide an option to partially or completely pass through a storage vessel, such as vessel 102, routing the combined stream to send to system 106 without any being supplied to a vessel, such as 102, through conduits 160, under an operating pressure greater than the saturation pressure of the combined stream at least in the portion of conduits 116 between the mixing point 108 and the end valve 126.The operating pressure of the combined stream is increased by the delivery system 106 to generate a pressurized combined stream to supply a downstream LNG vaporizer system to produce a regasified natural gas stream that has a suitable pressure to enter a connected natural gas power grid in a fluid manner. Suitable means or equipment for increasing the pressure in the delivery system 106 are provided elsewhere in this disclosure and may be selected by one skilled in the art based on particular conditions and parameters of a given installation or equipment.

[0061] The operating parameters of the mixing operation, as described in this document, affect the operating pressure of the pipeline network compared to the standard operating parameters. Optionally and preferably, the pipeline network is supplied with an operating pressure of at least 2 bar g (bar gauge) to accommodate the Petition 870250092087, dated 08 / 10 / 2025, p. 47 / 62 35 / 38 impacts of the mixing operation while meeting operational parameters. Suitable methods for supplying the pipeline network with such operating pressure are known to those skilled in the art. Once the mixing operation is completed, such as when the desired quantity of the second liquefied hydrocarbon, such as liquefied ethane, has been mixed, the liquefied ethane stream is reduced and stopped. Standard operation is resumed, including the return of the pipeline network operating pressure to its standard parameters. The properties of the regasified mixed product downstream of the delivery system 106, preferably “rich” LNG relative to the LNG before mixing, can be constantly monitored (e.g., Wobbe index) to ensure that the natural gas supplied to the power grid meets certain specifications, such as quality, flow rate, and pressure.During the mixing operation, information on the quality of the regasified blended product (e.g., Wobbe index) is preferably provided to the mixing operation to allow adjustment of the mixing ratio between the two liquefied hydrocarbon streams to ensure that the regasified blended product stream meets the desired product quality specifications. The same philosophy applies to applications where the LNG blend is supplied to other downstream users, as is the case in Liquid-in Liquid-Out type terminals (as described in

[0031] . For embodiments where the operating pressure of the respective storage vessel, such as 102, has been increased to be above the saturation pressure of the combined stream, the operating pressure of the respective vessel may also be reduced to its standard parameters.After the mixing operation, the mixed product in container 102 can be stored as inventory, or otherwise managed, such as distribution in accordance with contractual obligations.

[0062] In applications where the combined stream can be recirculated or distributed between multiple storage containers (not Petition 870250092087, dated 08 / 10 / 2025, pp. 48 / 62 36 / 38 shown) so that at least a portion, including the entire combined stream, is supplied to a mixing point as if it were lean LNG, accumulation of the second liquefied hydrocarbon (such as liquefied ethane) can occur. That is, as the mixing operation is carried out over a period of time, the first liquefied hydrocarbon stream that is pumped to the first mixing point 108 comprises an increasing amount of the second liquefied hydrocarbon over time. Such accumulation can be accounted for by adjusting the mixing ratio at the LNG-ethane mixing point 108. LNG plants typically include equipment to continuously monitor the properties of the LNG flowing through the pipeline network, including sensors (e.g., flow). Continuous monitoring allows for continuous adjustment of the flow of the respective streams, preferably the liquefied ethane stream, to achieve the desired mixing ratios.

[0063] Optionally and preferably, the flow of the combined stream in the part of the combined conduits 160 and 116 upstream of valve 162 and the end valve 126 is preferably carried out under turbulent flow regime.

[0064] Although not represented, it is understood that the principles described in this document can be applied to provide blending between a liquefied ethane carrier and a floating storage and regasification unit (FSRU), which typically comprises an LNG storage vessel, a BOG management system, and a shipping system.

[0065] The methods provided in this document, which include the in-line mixing of the first LNG stream and the liquefied ethane stream, particularly under turbulent flow regime, can maximize the mixing of LNG and liquefied ethane in the combined stream, thus allowing the combined stream to exhibit a composition and characteristics Petition 870250092087, dated 08 / 10 / 2025, pp. 49 / 62 37 / 38 homogeneous (e.g., density), so that it can be supplied to storage vessel 102 (or other vessels, either on-site or on a vessel) and / or shipping system 106 in homogeneous condition, which mitigates the risk of fluid stratification or commercial problems at the point of custody transfer (e.g., natural gas network injection point). In-line mixing operations, however, can introduce partial vaporization with two-phase flow formation due to the difference in specific enthalpy of lean LNG and liquid ethane streams, which can lead to the undesirable risk of excessive pipeline vibrations leading to pipe stress and fatigue. The methods described in this document address potential two-phase flow formation by maintaining the operating pressure in the combined stream to be greater than the combined stream saturation pressure.

[0066] Although not shown, it is understood that a computer program may be used to control and / or implement some, including all, aspects of the methods described in this document. Such a computer program may be called a controller. For example, the computer program may be used to control the pump discharge pressure and flow, the system operating pressure by manipulating the percentage of opening of the flow control valve, among others. A suitable computer program includes one that is executed by a data processor. As used herein, the reference to a computer program is intended to be equivalent to a reference to a program element and / or to a computer-readable medium containing instructions for controlling a computer system to coordinate the performance of the method described above.The computer program can be implemented as computer-readable instruction code using any suitable programming language, such as JAVA or C++, and can be stored on computer-readable media (removable disk, etc.). Petition 870250092087, dated 08 / 10 / 2025, pages 50 / 62 38 / 38 volatile or non-volatile memory, embedded memory / processor, etc.). The instruction code is operable to program a computer or any other programmable device to perform the intended functions. The computer program may be available on a network, such as the World Wide Web, from which it can be downloaded. The various aspects described herein may be performed by means of computer program software, respectively; however, they may also be performed by means of one or more specific electronic circuits, respectively hardware. Furthermore, the invention may also be carried out in a hybrid form, i.e., in a combination of software modules and hardware modules. Additionally or alternatively, any or all aspects of the methods described in this document may be performed manually by one or more human operators with relevant operational knowledge of the installation.

[0067] Although specific embodiments have been described herein, it is understood that such descriptions are not intended to limit the embodiments described. Instead, any combination of the features and elements provided above, whether or not related to different embodiments, is envisioned for implementing and practicing the contemplated embodiments. Furthermore, although the embodiments disclosed herein may achieve advantages over other possible solutions or the state of the art, whether or not a specific advantage is achieved by a particular embodiment does not limit the scope of the present disclosure. Thus, the aspects, features, embodiments, and advantages described herein are merely illustrative and are not considered elements or limitations of the appended claims, except where explicitly mentioned in a claim (or claims). Petition 870250092087, dated 08 / 10 / 2025, pp. 51 / 62

Claims

1 / 6 CLAIMS 1. A method for mixing two or more streams of liquefied hydrocarbons in an installation, characterized in that it comprises: - a first storage vessel (102) for storing a first liquefied hydrocarbon, optionally the first liquefied hydrocarbon is liquefied natural gas, - a delivery system (106) for sending the first liquefied hydrocarbon to downstream processing equipment, optionally the downstream processing equipment comprises regasification equipment, and - a conduit network comprising i. a first mixing point (108) located downstream of the first storage vessel (102) and upstream of the delivery system (106), ii. a first conduit segment (110) for providing fluid communication between the first storage vessel (102) and the first mixing point (108),iii. a second conduit segment (112) to provide fluid communication between a source of a second liquefied hydrocarbon (114) and the first mixing point (108), optionally the second liquefied hydrocarbon is selected from a group consisting of liquefied ethane, liquefied butane, liquefied propane and any combination thereof; iv. combined conduits (116) to provide fluid communication between the first mixing point (108) and the delivery system (106), the combined conduits (116) comprising a first end valve (126) immediately upstream of an inlet of the delivery system (106), Petition 870250092087, dated 08 / 10 / 2025,pg. 52 / 62 2 / 6 wherein the method comprises: (a) pumping a first stream of liquefied hydrocarbon from the first storage vessel (102) to the first mixing point (108) through the first conduit segment (110); (b) pumping a second stream of liquefied hydrocarbon from the second liquefied hydrocarbon source (114) to the first mixing point (108) through the second conduit segment (112); (c) combining the first and second streams of liquefied hydrocarbons at the first mixing point (108) at a volumetric ratio in a range of 1:500, preferably 1:100 and up to 500:1 to provide a combined stream; and (d) providing at least a portion, including all, of the combined stream from the first mixing point (108) to the delivery system (106) through the combined conduits (116),and (e) while the combined stream is in a segment of the combined conduits (116) between the first mixing point (108) and the first end valve (126), provide the combined stream with an operating pressure above (preferably at least 0.1 bar above, more preferably at least 0.5 bar above, most preferably at least 1.2 bar above) a saturation pressure of the combined stream.

2. Method according to claim 1, characterized in that the conduit network further comprises combined return conduits (160) to provide fluid communication between the first mixing point (108) and a storage vessel, optionally wherein the storage vessel is the first storage vessel (102), wherein the combined return conduits (160) comprise a second end valve immediately upstream of a combined return conduit outlet, wherein the method further comprises: Petition 870250092087, dated 08 / 10 / 2025, p.53 / 62 3 / 6 supply at least a portion of the combined stream from a segment of the combined conduits upstream of the first end valve (126) to a storage vessel while the portion of the combined stream is between a segment of the combined conduits (116) between the first mixing point (108) and the second end valve (126), supply the portion of the combined stream with an operating pressure above (preferably at least 0.1 bar above, more preferably at least 0.5 bar above, most preferably at least 1.2 bar above) a saturation pressure of the combined stream.

3. Method according to claim 2, characterized in that at least a portion, including the whole, of the combined stream is not supplied to the storage container (102).

4. Method according to any of the preceding claims, characterized in that the combined conduits (116) further comprise a first subsequent mixing point (208) located upstream of the first end valve (126) and downstream of the first mixing point (108) and, optionally, upstream or downstream of the combined return conduits (160), the method further comprising: (f) supplying a second stream of the first liquefied hydrocarbon from a source of the first liquefied hydrocarbon, optionally the first storage vessel (102), to the first subsequent mixing point (208);(g) combine the combined stream and the second stream of the first liquefied hydrocarbon at the first subsequent mixing point (208) in a volumetric ratio in a range of 25:1, preferably 50:1 and up to 500:1, wherein the first stream of the first liquefied hydrocarbon and the stream of the second stream of liquefied hydrocarbon ethane Petition 870250092087, dated 08 / 10 / 2025, page 54 / 62 4 / 6 are combined in a volumetric ratio in a range of 1:500, preferably 1:100 and up to 50:1 at the first mixing point (108).; 5. Method according to claim 4, characterized in that the combined conduits (116) further comprise a second subsequent mixing point (308) located downstream of the final valve (126) and upstream of the mixed product storage vessel (102), wherein the method comprises: (f) providing a third stream of the first liquefied hydrocarbon from a source of the first liquefied hydrocarbon to the second subsequent mixing point (308), optionally wherein said source is different from the first storage vessel (102) and optionally comprising a boiling gas management system (150);(g) combining the combined stream and the third stream of the first liquefied hydrocarbon at the second subsequent mixing point (308) in a volumetric ratio in a range of 25:1, preferably 50:1, and up to 150:1, wherein the first liquefied hydrocarbon stream and the second liquefied hydrocarbon stream are combined in a volumetric ratio in a range of 1:500, preferably 1:100, and up to 50:1 at the first mixing point (108) and wherein the combined stream and the second stream of the first liquefied hydrocarbon are combined in a volumetric ratio in a range of 100:1, preferably 150:1, and up to 500:1 at the first subsequent mixing point (208).

6. Method according to claim 1, characterized in that the combined conduits (116) further comprise a subsequent mixing point (308) located downstream of the final valve (126) and upstream of the mixed product storage vessel (102), wherein the method comprises: (f) supplying another stream of the first liquefied hydrocarbon from a source of the first liquefied hydrocarbon to the point of Petition 870250092087, dated 08 / 10 / 2025, page.55 / 62 5 / 6 subsequent mixing (308), optionally wherein said source is different from the first storage vessel (102) and optionally comprising an evaporation gas management system (150); (g) combining the combined stream and the other stream of the first liquefied hydrocarbon at the subsequent mixing point (308) in a volumetric ratio in a range of 25:1, preferably 50:1, and up to 500:1, wherein the first stream of the first liquefied hydrocarbon and the stream of the second liquefied hydrocarbon are combined in a volumetric ratio in a range of 1:500, preferably 1:100, and up to 50:1 at the first mixing point (108).

7. Method according to any of the preceding claims, characterized in that the combined stream downstream of the first end valve (126) and downstream of any subsequent mixing point (308) and, optionally, downstream of the second end valve (162), comprises a volumetric ratio of the first liquefied hydrocarbon, preferably LNG, to the second liquefied hydrocarbon, preferably liquefied ethane, of at least 2:1, preferably at least 3:1 and more preferably 4:

1.

8. A method according to any of the preceding claims, characterized in that it further comprises: providing the pipeline network with a total operating pressure of at least 2 barg.

9. Method according to any of the preceding claims, characterized in that it further comprises: reducing the operating pressure of the combined stream downstream of the second end valve (162) to less than the saturation pressure of the combined stream.

10. Method according to claim 9, characterized in that it further comprises reducing the operating pressure of the combined stream downstream of the second end valve (162) to the storage pressure of the storage container (102).

11. Method according to any of the preceding claims, characterized in that step (a) is performed before step (b).

12. Method according to claim 11, characterized in that step (a) comprises circulating the first stream of the first liquefied hydrocarbon from the first storage vessel (102) through the first portion of conduits (110), the combined conduits (116), optionally back to the first storage vessel (102) and, optionally, through a boiling gas management system (150).

13. A method according to any of the preceding claims, characterized in that the second liquefied hydrocarbon is liquefied ethane and the source of liquefied ethane is selected from the group consisting of land-based storage and vessel-based transport of ethane and any combination thereof.

14. A method according to any of the preceding claims, characterized in that the installation comprises an LNG regasification plant.

15. Method according to any of the preceding claims, characterized in that it further comprises supplying the contents of the storage container (102) to the shipping system (106). Petition 870250092087, dated 08 / 10 / 2025, pp. 57 / 62

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