WO2017201630A1 - Système de pipeline multifonctionnel intégré permettant la distribution de mélanges réfrigérés de gaz naturel et de mélanges réfrigérés de gaz naturel et de lgn - Google Patents

Système de pipeline multifonctionnel intégré permettant la distribution de mélanges réfrigérés de gaz naturel et de mélanges réfrigérés de gaz naturel et de lgn Download PDF

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Publication number
WO2017201630A1
WO2017201630A1 PCT/CA2017/050651 CA2017050651W WO2017201630A1 WO 2017201630 A1 WO2017201630 A1 WO 2017201630A1 CA 2017050651 W CA2017050651 W CA 2017050651W WO 2017201630 A1 WO2017201630 A1 WO 2017201630A1
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WIPO (PCT)
Prior art keywords
pipeline
pressure
psig
mixtures
rich gas
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PCT/CA2017/050651
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English (en)
Inventor
Ian Morris
John LAGADIN
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JL Energy Transportation Inc
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JL Energy Transportation Inc
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Priority to CA3024564A priority Critical patent/CA3024564A1/fr
Publication of WO2017201630A1 publication Critical patent/WO2017201630A1/fr
Anticipated expiration legal-status Critical
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Classifications

    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/0002—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the fluid to be liquefied
    • F25J1/0022—Hydrocarbons, e.g. natural gas
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17D—PIPE-LINE SYSTEMS; PIPE-LINES
    • F17D1/00—Pipe-line systems
    • F17D1/08—Pipe-line systems for liquids or viscous products
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17D—PIPE-LINE SYSTEMS; PIPE-LINES
    • F17D1/00—Pipe-line systems
    • F17D1/08—Pipe-line systems for liquids or viscous products
    • F17D1/082—Pipe-line systems for liquids or viscous products for cold fluids, e.g. liquefied gas
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17D—PIPE-LINE SYSTEMS; PIPE-LINES
    • F17D3/00—Arrangements for supervising or controlling working operations
    • F17D3/01—Arrangements for supervising or controlling working operations for controlling, signalling, or supervising the conveyance of a product
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/003—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the kind of cold generation within the liquefaction unit for compensating heat leaks and liquid production
    • F25J1/0032—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the kind of cold generation within the liquefaction unit for compensating heat leaks and liquid production using the feed stream itself or separated fractions from it, i.e. "internal refrigeration"
    • F25J1/0035—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the kind of cold generation within the liquefaction unit for compensating heat leaks and liquid production using the feed stream itself or separated fractions from it, i.e. "internal refrigeration" by gas expansion with extraction of work
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/006—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the refrigerant fluid used
    • F25J1/008—Hydrocarbons
    • F25J1/0082—Methane
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/006—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the refrigerant fluid used
    • F25J1/008—Hydrocarbons
    • F25J1/0085—Ethane; Ethylene
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/02—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen ; Details and kind of the refrigeration system used; Integration with other units or processes; Controlling aspects of the process
    • F25J1/0203—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen ; Details and kind of the refrigeration system used; Integration with other units or processes; Controlling aspects of the process using a single-component refrigerant [SCR] fluid in a closed vapor compression cycle
    • F25J1/0205—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen ; Details and kind of the refrigeration system used; Integration with other units or processes; Controlling aspects of the process using a single-component refrigerant [SCR] fluid in a closed vapor compression cycle as a dual level SCR refrigeration cascade
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/02—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen ; Details and kind of the refrigeration system used; Integration with other units or processes; Controlling aspects of the process
    • F25J1/0228—Coupling of the liquefaction unit to other units or processes, so-called integrated processes
    • F25J1/0232—Coupling of the liquefaction unit to other units or processes, so-called integrated processes integration within a pressure letdown station of a high pressure pipeline system
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2205/00—Processes or apparatus using other separation and/or other processing means
    • F25J2205/60—Processes or apparatus using other separation and/or other processing means using adsorption on solid adsorbents, e.g. by temperature-swing adsorption [TSA] at the hot or cold end
    • F25J2205/66—Regenerating the adsorption vessel, e.g. kind of reactivation gas
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2210/00—Processes characterised by the type or other details of the feed stream
    • F25J2210/06—Splitting of the feed stream, e.g. for treating or cooling in different ways
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2220/00—Processes or apparatus involving steps for the removal of impurities
    • F25J2220/60—Separating impurities from natural gas, e.g. mercury, cyclic hydrocarbons
    • F25J2220/64—Separating heavy hydrocarbons, e.g. NGL, LPG, C4+ hydrocarbons or heavy condensates in general
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2290/00—Other details not covered by groups F25J2200/00 - F25J2280/00
    • F25J2290/60—Details about pipelines, i.e. network, for feed or product distribution

Definitions

  • Embodiments herein relate to high pressure pipeline systems used for delivery of chilled natural gas mixtures to a terminus for subsequent downstream applications such as in LNG, Separation/fractionation facilities and mobile transshipment. More particularly, the new method delivers a chilled product directly from the pipeline providing most, if not all of the chilling energy requirement to meet downstream specification of temperature and pressure for subsequent applications. In support of the processing function the packing characteristics of delivered product under pre-chilled conditions permit the upstream pipeline section to be utilized for containment of stored buffer volumes as suits the flow demands of the processing facilities.
  • the methods herein provide significantly more cost effective chilling and increased pressure energy recovery, thereby reducing/eliminating the need for costly external chilling to meet downstream process demands depending on the application. In particular the method reduces much of the pre-chilling infrastructure involved with LNG processing.
  • methodologies disclosed herein integrated with the needs of the downstream process, delivers these Products for subsequent processing using the greater pressure differential available from an elevated pipeline maximum operating pressure (MOP).
  • MOP maximum operating pressure
  • J-T Joule-Thompson
  • Applicant applies methods for manipulation of gas transport and delivery parameters that result in significant increases in the mass rate of product delivered for a given pipeline. Reductions in capital expense and energy required for both transport and chilling, and savings in trans-shipment infrastructure and expense.
  • Applicant enhances delivery conditions for heretofore untapped opportunities for internally-generated chilling Products that is significantly more cost effective than the prior external-generated chilling of Products.
  • the traditional approach having modest delivery pressures and differentials would at most result in chilling during pressure letdown in a range of -10 F degrees to -25 F degrees, the balance to Product conditions being chilled through known exchange methodologies.
  • This new art extends the boundary conditions of pipeline pressure, temperature and NGL constituents of existing technologies for the transportation and optional storage of North.
  • American Spec natural gas mixtures or rich mixtures of natural gas/NGLs, (Products) in a pipeline system for delivery of chilled Products for downstream applications.
  • the new system provides an integrated multi-functional pipeline derived system, for the reduction in energy for both transport and downstream processing of the aforementioned Products by making available a larger deltaP pressure reduction than that normally associated with traditional process considerations.
  • This includes, at the terminus of the last stage high pressure pipeline section, a turbo expander or similar device which reduces pressure and "internally" chills the outflowing Products through the Joule-Thompson effect of their constituent properties.
  • This system can also be retrofitted to existing pipeline systems for certain applications. Recovery of pipeline pressure energy for power generation can also be harnessed if a turbo expander or similar device used for pressure reduction is then employed to generate electricity or shaft power. Process energy/heat transfer normally acquired from "external" sources can then be largely displaced by this form of recovered upstream energy missing in traditional segregation of pipeline and process disciplines.
  • the NGL content carried in such mixtures in a single pipeline eliminates the need for a separate pipeline, or other means for transportation of multiple product streams to markets. Coupled with higher pressure operation the effects of enhanced NGL content results in a reduction in diameter of the pipeline by at least one standard size over that for an equivalent flow of Spec natural gas.
  • Delivery of outlet Products can be set to prescribed temperature and Pressure dependent on downstream application. Substantial overall reduction in energy consumption and associated C02 emissions is thereby achieved through integrated pipeline/processing applications.
  • the method described herein integrated with the needs of a variety of downstream processes, delivers these Products for subsequent processing using the greater pressure differential available from an elevated pipeline maximum operating pressure (MOP) and adjustments to the conveyed mixtures.
  • MOP maximum operating pressure
  • Higher reductions in pressure and temperature are achieved through a turbo expander or similar Joule-Thompson (J-T) device at the terminus of the pipeline, those reductions exceeding those of traditional segregated pipeline/process systems
  • J-T Joule-Thompson
  • the pressure differentials employed substantially increase the benefits of the J-T chilling stage in the range of -60 F degrees to -100 F degrees.
  • the new method provides significantly more cost effective chilling and increased pressure energy recovery, and thereby reduces/eliminates the need for costly external chilling to meet the downstream process demands depending on the application.
  • EMBODIMENTS FOR PROCESSING Applicant controls the pipeline compression cycles, to heretofore higher pressure differentials, and concurrently provides destination storage at new higher pressures. This enables a J-T effect for significant, if not all, process chilling of the product from the storage at the destination. This also enables delivery of a chilled gaseous product at commercial densities for transshipment in lighter lower pressure containment vessels.
  • CHILLING EMBODIMENTS FROM JOULE THOMPSON EFFECT Energy efficiency is enhanced due in part to the ability to drop the pressure of these enhanced mixtures from their high pressure containment levels to destination pressures, thereby.
  • the heretofore unavailable processing pressure differentials efficiently utilize the high refrigerant properties (latent heat of vaporization) from the high levels of constituent NGLs in the Flow-stream as the pressure is permitted to drop to process levels further differentiates this system from other pipeline systems and downstream stream process configurations.
  • the J-T effect caused by forcing the stored gas mixture through the resistance of a J-T valve, chills the gas in an adiabatic manner. This gives a high degree of cooling of the delivered gas without work being added to or done by the system.
  • using a turbo expander at the point of installation of the J-T valve recovers a large part of this pressure energy in the form of generation of electricity or shaft power at the delivery point while the chilling takes place.
  • This power recovery can be substantial, having values in the order of 5,000 to 10,000 kW pre BCF/d of flow on a large installation.
  • the recovered power can be used directly for upstream recompression or more generally for electrical generation exported to the grid or for other process use.
  • the improvement in the gas to steel mass to volume ratio of Rich Gas mixes relative to Standard Specification gas storage is of the order of 50%. This effective reduced use of steel containment can amount to tens of millions of dollar savings in a marine vessel designed for 20,000 tons of Rich Gas capacity, and further add to the economic distance over which such a vessel can deliver its cargo.
  • Recompression can occur at about 1500 psig or at recompression thresholds of between about 1500 to about 1900 psig to attain the hydraulic and compressive power benefits from optimum compressibility Z values and enables reduction in pipe diameters by at least one standard size over those for prior lower pressure designs for reduced capital cost.
  • a pipeline carrying lean North American Spec Gas or NGL Rich Gas that is project specific in volume, by virtue of its entire length and cross sectional area and pipe layout, used for product flow, high pressure storage, and de- pressuring the contents, which operates within the limits of a storage pressure of about 4500 psig reduced down to a low pressure of about 350 psig according to end use for a chilled delivered product.
  • NGL constituents are transported in a single pipeline system, mixed with the natural gas component, the NGLs are transported for a fraction of the cost of building separate pipelines and handling infrastructure.
  • Flowing Rich Mixtures also reduce the complexity of field plants to handle NGLs, and also at the delivery point where economies of scale can be obtained from a single separation/process facility built at that site.
  • Optional storage conditions exist within the pipeline system given the high packing densities of the claimed mixtures. This feature is enabled by the provision of an ultra-high pressure accumulator section of the pipeline generally located immediately upstream of the terminus of the pipeline. Storage configurations within the pipeline system become an optional function of project- specific needs, and can be provided in the form of a number of parallel loops of pipe of predetermined diameters, or a single section of larger diameter.
  • the resulting increased densities of the current Standard Spec Gas and Rich Gas mixtures under lowered temperatures can more effectively be contained at lower pressures than previously possible:
  • the mixtures can be shipped in less expensive, lighter wall containers.
  • the Rich Gas chilled products can be stored at 1300 psig and match the transport volume of Standard Transmission specification gas shipped under the much higher pressures at 1800 psig plus levels.
  • the improvement in the gas to steel mass to volume ratio particularly of Rich Gas mixes relative to Standard Specification gas storage is of the order of 50%. This effective reduced use of steel containment can amount to tens of millions of dollar savings in a marine vessel designed for 20,000 tons of Rich Gas capacity, and further add to the economic distance over which such a vessel can deliver its cargo.
  • EMBODIMENTS OF ENERGY INTENSITY High pressure cycles in the transmission system and the selection of the NGL constituents allow for the inclusion of Rich Gas mixtures with an upper value of MW of about 23.2 adapted to an appropriately designed pipeline. Energy levels of the order of about 1500 BTU/ft3 for the higher heating value (HHV) of the delivered Rich Gas mixtures can result. This favourably compares to the HHV value of 1050 BTU/ft3 for a typical North American Standard Transmission specification gas delivered in today's pipeline network.
  • HHV heating value
  • EMBODIMENTS REGARDING DOWNSTREAM PROCESSING the delivered gas can now be customized to both optimal temperature and pressures of specified downstream process applications such as LNG, separation and fractionation facilities.
  • the internally generated chilling can replace first stage or even second stage process chilling trains of the prior art.
  • the energy of the high pressure pipeline section results in coupled with the high degree of "internal" chilling. Harnessing the behavior of the refrigeration properties of the flowing products within a pipeline adds a new dimension to energy savings in the processing of natural gas mixtures.
  • the customary requirement for refrigeration of process products of natural gas mixtures that has been normally provided externally from energy intensive infrastructure can now be minimized or eliminated with the integration of high pressure pipeline and process design. This can be built into the design of new projects or installed as a retrofit to existing infrastructure.
  • the last compressor station for storage or preparatory for chilling, is used to increase pressure prior to conditioning of the product by chilling of the gas through a J-T device, the chilling optionally conducted through a downstream turbo-expander for generation of recovery power for other applications.
  • Storage pressure created by this last compressor is customized and designed for a specific downstream application.
  • One can retrofit existing pipeline systems for existing gas processes and LNG facility applications. Recovered power from the J-T device can be used for additional power needs, fractionation or sold to the electric grid system.
  • Applicant has advanced the known pipeline systems by providing a method of accelerating the onset of lower compressibility (Z) factors in natural gas pipelines, implementing broader pressure, temperature, and range of constituents within Rich Gas mixtures for yielding a new array of transportation benefits including: a wider band of low flow resistance in pipelines over prior art otherwise restricted by lower maximum operating pressures; increases in storage densities resulting from these lowered Z factors; and an ability to take advantage of high levels of NGLs within the new gas mixtures and their behavior within the broader pipeline pressure differentials (sitting within 3500 psig and 900 psig),
  • the pipeline differentials that result enable effective use of the J-T effect for "internal" chilling to occur from within the product transported by the pipeline, without a need for added external energy,.
  • Applicant delivers a pre-chilled product by pipeline that alleviates this energy and environmental demand on the industry. Further, when provided via turbo expander, Applicant's system recovers pipeline energy otherwise lost in the custody transfer between segregated pipeline and end process disciplines.
  • this disclosure sets forth a method of accelerating the onset of, and access to, lower compressibility (Z) factors in natural gas pipelines such that flow resistance and storage density are improved.
  • the properties of the Rich Gas mixtures and higher operating/storage pressures involved are such that internal chilling within the transported medium can then take place through the Joule-Thompson effect, making a lower pressure delivery of a Rich Gas Product direct from the pipeline.
  • the subsequent delivery of a chilled product using recovered pipeline energy can replace a substantial amount of chilling otherwise externally created for many downstream applications
  • Figure 1 is a schematic of one embodiment of a pipeline system disclosed herein with expanded storage staging section and transshipment facilities to precondition flow for downstream processing and facilities for loading land, marine or air vessels.
  • embodiments of storage and transmission behavior is simply provided herein using two component mixtures of methane with each of the primary NGLs of ethane, propane, and butane.
  • Figure 1 A shows a pressure trace at corresponding points of flow in Fig. 1 , against the backdrop of the phase envelope of the transmitted gas-based on a re-injected ethane-rich gas mixture from natural gas produced in Alaska;
  • Figure 1 B shows a temperature trace at corresponding points of flow in Figs. 1 and 1A;
  • Figure 1 C illustrates the pressure temperature trace of the gas flow in the pipeline relative to the phase envelope of the flow mixture. Three staging steps are covered from the normal pipeline section flow between compressor stations, to the high pressure storage containment, to the delivery pressure drop with chilling specified for Product delivery.
  • Figure 2B illustrates the compressibility factors of typical of an example Rich Gas mixture, a catenary trace for Z Factor values for selective temperatures.
  • the path traced by gas flow in the current pipeline staging sections at high to low pressures is shown as A-B-C;
  • Figures 3 through 5 illustrate the chilling abilities available for downstream deliveries for three progressively richer gas mixtures containing a blend of constituents C1 , C2, C3 ... C6+.
  • the mixtures are distinguished by HHV (high heat Values) in USBTU/ft3 units given in the title block of each of the Figures ..
  • HHV high heat Values
  • Figures 6A through 8C illustrate the storage aspects attainable within the pipeline system simplified as 2-component Rich Gas mixes, and quantified as ratios of Mass-of-Gas to Mass-of-Containment Steel
  • Figure 6A illustrates storage characteristics of pipe containment ethane- based rich gas mixtures showing regions of optimal net volume ratio of ethane- based mixtures compared to CNG volume ratios under same storage conditions, wherein comparable mass of gas to mass of containment steel pipe ratios are listed;
  • Figure 6B illustrates gas storage characteristics of ethane-based rich gas, with tabulated data of concentration of ethane for densest mixture under stated conditions of temperature and pressure, wherein resulting maximum volume ratio of mixture under stated conditions of temperature and pressure exceeds those of Standard Transmission specification mixture, and lower storage pressures reflect with lower m/m mass ratio for containment;
  • Figure 6C further illustrates regions and limitations of the ethane-based rich gas of Fig. 6B for illustrating preferred V/V and M/M ratios over those of standard transmission gas and limitations where rich gas mixtures could stray into the liquid phase;
  • Figure 7A shows storage characteristics of pipe containment propane- based rich gas mixtures, showing regions and limitations for optimal net volume ratio of propane-based mixtures compared to CNG volume ratios under same storage conditions, where comparable mass of gas to mass of containment steel pipe ratios are listed;
  • Figure 7B illustrates gas storage characteristics of propane-based rich gas, with tabulated data of concentration of propane for densest mixture under stated conditions of temperature and pressure, wherein resulting maximum volume ratio of mixture under stated conditions of temperature and pressure exceeds those of Standard Transmission specification mixture, and lower storage pressures reflect with lower m/m mass ratio for containment;
  • Figure 7C further illustrates regions and limitations of the propane-based rich gas of Fig. 7B for illustrating preferred V/V and M/M ratios over those of standard transmission gas and limitations where rich gas mixtures could stray into the liquid phase;
  • Figure 8A shows storage characteristics of pipe containment butane- based rich gas mixtures, showing regions and limitations for optimal net volume ratio of butane-based mixtures compared to CNG volume ratios under same storage conditions, wherein comparable mass of gas to mass of containment steel pipe ratios are listed;
  • Figure 8B illustrates gas storage characteristics of propane-based rich gas, with tabulated data of concentration of butane for densest mixture under stated conditions of temperature and pressure, wherein resulting maximum volume ratio of mixture under stated conditions of temperature and pressure exceeds those of Standard Transmission specification mixture, and lower storage pressures reflect with lower m/m mass ratio for containment;
  • Figure 8C further illustrates regions and limitations of the butane-based rich gas of Fig. 8B for illustrating preferred V/V and M/M ratios over those of standard transmission gas and limitations where rich gas mixtures could stray into the liquid phase;
  • FIG. 6 illustrate the internal chilling aspects now available from contained gas behavior under the claimed operating and storage conditions for the pipeline. For the most part the Joule Thompson effect kicks in at a pressure of 3200 psig. Higher pressures generally occur from operational storage considerations and can be further utilized downstream of the pipeline.
  • Figure 9A shows a comparison between a conventional pipeline system and the transmission system of Fig. 1 ; illustrating benefits in deliverable heat value, reduction in pipe mass, compression power, fuel and C02 emissions;
  • Figure 9B shows a selection of values of the heat of vaporization of outgoing CFC refrigerants and those similar values of NGLs operating from an initial temperature of 80°F;
  • Fig. 9C is a schematic illustrating the replacement of a first stage propane section of a cascaded propane-ethylene-methane process for LNG production, external chilling at the first stage of an LNG plant being replaced by an internally chilled mixture emerging from the pipeline.
  • the Rich Gas pipeline flow is separated into an NGL stream and a lean gas feedstock for the LNG process.
  • FIG. 1 the system 100 is illustrated for moving a product of mixtures of natural gas and NGLs through a series of compression/recompression cycles 1 12 from a source 1 10 to a destination 126.
  • FIGs. 1A and 1 B pressure and temperature traces respectively are shown for the operating scenario of Fig. 1A, that transmits and stores the natural gas mixture in the dense phase mode, and are arranged to correspond with the steps of system 100.
  • the operating scenario is overlaid on the backdrop of the phase envelope of the gas being transmitted and stored according to Fig. 1 .
  • the pipeline system 100 comprises several transmission staging sections, including a transmission or pipeline staging section 102 for moving rich gas from the source 1 12 to the destination 126, a storage staging section 104 for storing the transmitted rich gas at or near the destination, and a trans-shipment staging section 106 having necessary facilities for delivering rich gas to downstream applications.
  • a transmission or pipeline staging section 102 for moving rich gas from the source 1 12 to the destination 126
  • a storage staging section 104 for storing the transmitted rich gas at or near the destination
  • a trans-shipment staging section 106 having necessary facilities for delivering rich gas to downstream applications.
  • NGLs or make up methane gas may be injected into the pipeline 1 12 or storage pipes at points m/1 18 for adjusting the rich gas therein.
  • the pipeline transmission staging section 102 comprises one or more pipelines 1 12 for moving natural gas mixture, and one or more compressors 1 14 for recompression of the natural gas mixture at each section to a higher pressure.
  • the pipeline staging section 102 transmits natural gas mixture within desired pressure and temperature ranges.
  • the natural gas mixture is a Standard Gas mixture Rich Gas mixture, formulated by additive or subtractive processing, and comprising: from 40% to 98% by molar volume (mol volume) of methane, from trace to 35% by mol volume of ethane, from trace to 22% by mol volume of propane, from trace to 9% by mol volume of butane, and trace elements of C5+ (i.e., C5, C6, ... ) hydrocarbons not exceeding 0.25% by mol volume; and the total of (a) to (e) being 100%, and such mixture being completely gaseous or dense phase (supercritical) with no liquid phase at the temperature and pressure of operation.
  • C5+ i.e., C5, C6, ...
  • the pipeline extends from the source to the destination, through a series of recompression cycles.
  • One or more, or all of recompressions raise the Rich Gas to a maximum operating pressure (MOP), having a Rich Gas mixture adjusted to avoid liquid fallout.
  • MOP maximum operating pressure
  • the re-compression pressure is raised of over about 2250 psig and in further embodiments between MOP of about 2250 to about 2850 psig.
  • recompression can occur at about 1500 psig or at recompression thresholds of between about 1500 to about 1900 psig to attain the described hydraulic and compressive power benefits from optimum compressibility Z values.
  • the volumetric efficiency of the Rich Gas mixture is improved, one can reduce in pipe diameters by at least one standard size over those for prior lower pressure designs for reduced capital cost whilst moving the same mass of Rich Gas.
  • the pipeline staging section 102 operates with a maximum operating pressure (MOP) of 2500 psig and recompression at 1300 psig, utilizing a range of low compressibility factors Z range, Point A to Point B to Point C of Fig. 2B, and at temperatures between about 50°F and about 120°F.
  • MOP maximum operating pressure
  • Transmission pipeline compressors are shown as “C” types.
  • Cx stepped compressors
  • D-E head for decompression
  • This drop in pressure at the exit of the storage section reduces the storage temperature via Joule-Thompson effect on the flowing products to -45F as shown here.
  • much lower temperatures in accordance with downstream Application can be provided.
  • the Phase Envelope for a Rich NGL-laden Alaska gas mixture is noted alongside the pipeline pressure/temperature trace.
  • the trace C-D is representative of pipeline section flow
  • the trace D to E is the high pressure lift to storage
  • E to F is the drop of pressure and temperature through a simple Joule-Thompson valve to a condition suited to gas separation or chilled Compressed Natural Gas (CNG) storage.
  • CNG Compressed Natural Gas
  • a pipeline carrying above described rich gas mixture can run between 2500 psia, Point A, through the prior known low Z value at 2100 psia at Point B, and even lower down to a pressure of about 1300 psia to 1500 psia in the region of Point C before recompression.
  • the recompression point depends on station spacing and pipe diameter relative to pipeline flow rate. This wider recompression pressure cycle, or wider operating pressure range, also permits longer distances between compressor stations for reduced capital expenditure.
  • the operation of the rich gas pipeline at the new higher MOP towards Point A can result in a 12% increase in flow for less power per unit of gas over the performance of the earlier designs with a MOP at Point B.
  • Applicant found new operating efficiencies that outweigh the required increase in pipe wall thickness demanded by the higher MOP.
  • the average Z value drops from 0.705 to 0.682, and the compressor station spacing increases by 15%, easily removing one complete compressor station from the infrastructure of a typical 1000 mile longdistance pipeline. For example, conventional spacing of one station per 100 miles might be increased to one station per 120 miles, further reducing capital cost and complexity.
  • compaction of the natural gas mixture in the standard-diameter pipeline sections 1 12 between compressor stations 1 14 acts as a line pack accumulator 122.
  • the amount of gas stored in the accumulator portion(s) 104 permits a correctly designed dense phase pipeline to operate at normal flow for several days in the event of a station outage before the new steady state, lower flow conditions dictated by the outage set in place.
  • FIG. 1 C With reference to Fig. 1 C the performance characteristics of the high pressure accumulator performance is illustrated against the backdrop of the Phase Envelope for a Rich NGL laden Alaska gas mixture, noted alongside the pipeline pressure/temperature trace.
  • the trace C-D (176-174) is representative of pipeline section flow
  • the trace D to E (174-178) is the high pressure lift to storage
  • E to F (178-180) is the drop of pressure and temperature through a simple Joule- Thompson valve to a condition suited to gas separation or chilled Compressed Natural Gas (CNG) storage.
  • the operating conditions lie in the Dense Phase/Supercritical zone above and to the right of the Critical Point of the Gas, point 170.
  • compression is shown from point 174 to point 178 at about 3250 psig where the mixture can be held under conditions of high density.
  • Point 176 marks the Maximum Operating Pressure (MOP) to which the gas is compressed in a mainline segment to 2500 psig.
  • MOP Maximum Operating Pressure
  • the gas would be compressed back to MOP level at 2500 psig and the cycle begin again.
  • the accumulator or storage staging section 104 usually located at the destination, comprises one or more storage pipes 122, and a Joule-Thomson (J-T) expander 132 (described later) for transmitting rich gas from the storage pipes to the trans-shipment staging section 106.
  • J-T Joule-Thomson
  • a high, and last stage, pressure booster compressor station 1 16 can be located between staging sections 102 and 104 and has a high head capability to lift the pressure up from above described, normal operating pressures to a desired elevated storage pressure in the storage pipes 122.
  • each of the storage pipes 122 is a pipe having a longer section length and a larger diameter ("A" to "B" of Fig. 1 B) to provide required storage volume.
  • the storage pipe(s) 122 operate at a higher pressure to act as an accumulator for storage purposes.
  • the high storage pressure set at the upper level of where the Joule Thomson (J-T) effect is activated in the transmitted gas mixture, also provides the differential from the high pressure (at the storage pipes 122) to low pressure (after passing through the J-T expander 132), which is required to obtain the internal gas chilling in the trans-shipment staging section 106 via the J-T cooling effect (described later).
  • the Rich Gas mixture disclosed herein may be contained in the storage pipes 122 at pressures between about 3250 psig and about 3500 psig, depending on liquid fallout limits of the particular gas mixture, and preferably at ambient/ground temperatures.
  • About 1 10°F has been noted in modeling summer operations where limitations of air cooling and residence times in the pipeline have not proved to be prohibitive to in-pipe storage.
  • temperate zone winter conditions about 75°F or lower is the norm for flow emerging from storage. This lower temperature is the basis for J-T chilling summarized for Standard Specification and Rich Gas mixes in Figs. 3, 4 and 5.
  • An optional temperature trimming system is incorporated within or downstream of the storage compressors to condition the gas flow to optimal temperature or density conditions for process applications downstream of the invention.
  • an operating condition, upper temperature limit of 150°F is specified to maintain flow in gaseous state when the pipeline is installed in cold environments having high heat losses along the sectional length(s).
  • Such an accumulator storage system takes advantage of the available conventional pipeline installation equipment, techniques and inspection and quality control aspects implemented for the pipelines 1 12 in the pipeline staging section 102.
  • three (3) parallel 36" pipes can be used as the storage pipes 122 between the last compressor station 1 16 and the trans-shipment staging section 106.
  • the storage staging section 104 ahead of the shipping point can now incorporate a large volume by means of pipes 122.
  • the pipes 1 12 may be a mix of pipes of different lengths and/or diameters for holding this strategically determined volume.
  • the increased diameter(s)/cross-section(s) or combined diameter(s)/cross-section(s) of the storage pipes 122 in the storage staging section 104 further reduce the hydraulic pressure loss that may be experienced by the conventional pipeline system during normal operating conditions.
  • the natural gas mixture in the storage pipes 122 first passes through the molecular sieve/J-T expander 132 coupled downstream of the high pressure accumulator 122 to reduce the pressure thereof and to chill the natural gas mixture.
  • the J-T expander 132 reduces adiabaticaly the pressure of the natural gas mixture, or in one embodiment the rich gas mixture, from the high storage pressure (about 3250 to 3500 psig) to approximately 1300 psig. Such a pressure drop at the J-T expander 132 results in J-T cooling to the natural gas mixture passing therethrough for trans-shipment at optimal conditions illustrated in Figs. 6A, 7A and 8A.
  • the J-T expander acts as an internal chiller that, dependent on the destination demands, may be all the chilling that is required.
  • the J-T expander 132 may be any gas expander and ancillary equipment suitable for reducing the pressure of the natural gas mixture and for chilling the natural gas mixture using the Joule- Thomson effect (i.e., internal, or self-chilling).
  • the J-T expander 132 is a pressure reduction valve; in another embodiment and more efficiently, the J-T expander 132 is an energy recovering turbo expander.
  • the Joule-Thomson effect refers to the phenomenon that, with no heat exchange with the environment, the temperature of a gas changes when it is forced through a flow restrictor.
  • the J-T expander 132 uses the J-T effect to chill the natural gas mixture to a low temperature suitable for trans-shipment without liquid fallout, e.g., in some embodiments to between about -20°F and about -30°F for Rich Gas Mixtures, or in other embodiments to between about -10°F and about - 80°F for Standard Specification Gas.
  • a low temperature suitable for trans-shipment without liquid fallout e.g., in some embodiments to between about -20°F and about -30°F for Rich Gas Mixtures, or in other embodiments to between about -10°F and about - 80°F for Standard Specification Gas.
  • carbon steels are generally limited in service to -55°F, utilizing these lower temperatures is dependent upon the materials of construction with lower limits such as nickel steels, aluminum and stainless steel.
  • Alternative pre-chilled feed stock can be provided from header 134 shown in Fig.1 for a variety of process/transportation technologies that can benefit from reductions in chilled front end energy needs and lowered C02 emissions when coupled with the pipeline system 100 in this manner.
  • Typical but not exhaustive technologies applicable as downstream destinations for pre-chilled flow include separation and fractionation 142, CNG processing 144, NGL processing feedstock 146, first stage liquefied natural gas (LNG) processing 148, and compressed LNG for emerging market 150.
  • the storage staging section 104 and the trans-shipment staging section 106 may be alternatively located at other locations such as intermediate locations or spur-lines anywhere along the pipeline 1 12.
  • the storage pipes 122 can operate at a high pressure up to 4500 psig for increasing process storage density. At such high pressures the J-T effect on the contained Products is minimal, an external trimming cooler system is coupled to the J-T expander to reduce the discharged natural gas mixture to optimal temperature for colder temperature downstream applications.
  • Standard Transmission specification gases may be transmitted in the high-pressure pipelines 1 12 operating between an MOP of about 2750 psig and recompression at 1650 psig or 1700 psig for transmitting the Standard Transmission specification gases at a low Z factor for improved gas transmission efficiency.
  • an external trimming cooler system can also be coupled to the J-T expander 132 to reduce the discharged natural gas mixture to optimal temperature or density conditions for alternate specified downstream applications.
  • Figs. 6A, 7A and 8A show comparative values for the volumetric compression of the methane constituent in progressively richer mixes against Standard Transmission specification mixtures under the same conditions. Areas of best performance are shown as side-by-side graphs. As a commercial measure, one compares the mass of gas mixture to containment steel to show the effectiveness of this mode of storage.
  • Figs. 6A to 8C show the benefits of a Rich Gas mixture having ethane (C2) added as the compression constituent.
  • Figs. 7A to 7C show the benefit of a Rich Gas mixture having propane (C3) added and
  • Figs. 8A to 8C show the benefit of Rich gas mixture having butane (C4) added as the compression constituent..
  • Fig. 7A shows the benefits in storage of Rich Gas mixtures (for the NGL constituent represented by propane (C3) over standard Standard Transmission specification / CNG mixes.
  • the Rich Gas is modeled as a two component propane / methane mix, and net V/V ratios are for the solo methane component, to make a comparison to the CNG case under the same storage conditions.
  • Rich Gas mixture benefits are shown as mass of gas to mass of containment steel ratios on a lb/lb basis, especially important when high tonnage of materials are involved in storage vessels.
  • Fig. 8A shows the benefits in storage of Rich Gas mixtures (using C4) over standard CNG transmission mixtures.
  • the rich gas is modeled as a two component butane / methane mixture, and net V/V ratios are for the methane component only to make a comparison to the CNG case under the same storage conditions.
  • Rich gas mixure benefits are shown as mass of gas to mass of containment steel ratios on a lb/lb basis, especially important when high tonnage of materials are involved in storage vessels.
  • Each graph illustrates the maximum gas storage values of rich gas-vs-std specification gas for gases enriched with ethane, propane and butane respectively.
  • rich mix gases higher m/m values are shown in grey tone and are subject to moderate reduction in peak NGL concentration to avoid two-phase or liquid state storage conditions.
  • the Y-axis represents V/V, being (Volume of Natural Gas at Std. Conditions) / (Volume of Natural Gas at Storage Conditions).
  • the corresponding Y-axis M/M Gross Mass of Contained Mixture/Mass of steel in Containment System.
  • the contained natural gas in Rich Gas Mix is net value of natural gas component within the Mix.
  • Performance for storage of the gaseous Rich Gas mixture (for the NGL constituent represented by ethane (C2), measured against the Standard Transmission specification mixture, appears in the 1 100 to 1400 psig range of pressures at temperatures in the -30°F to -20°F window, balancing increased compressed volume ratio against mass ratio.
  • Rich Gas mixtures offer 50% or better Mass Ratio figures for storage of the methane constituent (essentially Standard Transmission specification gas) under selected conditions of storage than is attainable from Standard Transmission Specification mixtures under these moderate levels of pressure and temperature.
  • Fig. 6C shows clearly where Rich Gas mixtures are superior to Standard Transmission specification mixtures under storage conditions and where the technology must respect the onset of undesirable liquid phase above certain concentrations of the NGL constituent.
  • Fig. 7A shows the benefits in storage of Rich Gas mixtures (for the NGL constituent represented by propane (C3) over Standard Transmission specification / CNG mixes.
  • the Rich Gas is modeled as a two component propane / methane mix, and net V/V ratios are for the solo methane component, to make a comparison to the CNG case under the same storage conditions.
  • Fig. 7C shows clearly where Rich Gas mixtures are superior to Standard Transmission specification mixtures under storage conditions and where the technology must respect the onset of the liquid phase.
  • Fig. 8A shows the benefits in storage of Rich Gas mixtures using butane (C4) over standard CNG transmission mixtures.
  • Fig. 8C shows clearly where Rich Gas mixtures are superior to Standard Transmission specification gas/CNG mixtures under these storage conditions and where the technology must respect the onset of undesirable liquid phase.
  • Fig. 9A shows a comparison between a conventional pipeline system and the high pressure transmission system 200 disclosed herein.
  • the conventional pipeline system (column 102) is operated at a pressure of about 1440 psig, transmitting a Standard Transmission gas mixture with Molecular Weight (MW) of 16.75.
  • the high pressure transmission system 200 (column 202) is operated at a pressure of about 2250 psig, transmitting a rich gas mixture with Molecular Weight (MW) of 19.93.
  • system 200 The smaller diameter of system 200 is not restricted to the comparative inlet flow rate of 1.0 billion ft3/day used here for comparative purposes and can achieve a still higher daily heat value delivery per US ton steel.
  • system 201 which is essentially system 200 subjected to a higher flow rate and velocity restrictions, the delivered heat value ratio is seen to increase by the order of +30%, depending a higher flow rate and velocity limitations). See system 201.
  • Fig. 9A also shows that the compressor stations of system 200 also require less power than those of the conventional system 100 to deliver the set volume of gas at the rate of 1.0 bcf/d.
  • the move to a higher flow rate of system 300 shows a prorated increase in overall compressor power and C02 emissions over that of the lower pressure system 100.
  • Fig. 9B shows a selection of values of the enthalpies of vaporization of CFC refrigerants for external chilling and those of NGLs operating from an initial temperature of 80°F. It will be noted that the efficacy of NGLs are comparable alongside the more typical R21 CFC refrigerant, which is amongst those being withdrawn from the market out of environmental concerns of damage to the ozone layer of the atmosphere. Given the chilling ability of constituent hydrocarbons in a Rich Gas mixture, and the elevated levels of storage , the opportunity exist here for those skilled in the art to design the delivery of chilled product as the gas exits the pipeline beyond those promised for Standard Specification gas mixtures. In other contexts where less emphasis is placed on storage and hydraulics a system could be designed to achieve greater temperature reductions for Standard Specification gas mixtures, in particular the retrofit of existing LNG systems.
  • Fig. 9C shows the replacement of the first stage propane section of a cascaded propane-ethylene-methane process for LNG production.
  • the cold gas is first used to provide maximum temperature differential to the LNG process prior to becoming feedstock for an NGL separation plant. Methane and residual ethane from this separation plant is then introduced back as feedstock into the LNG process.
  • the gas stream leaves the pipeline/storage system via the turbo expander 132 that both chills the gas as its pressure drops and generates shaft power that can be converted into electricity W.
  • the flowrate is monitored at a custody transfer point C.
  • An opportunity here also exists for an auxiliary process chilling flow C-V of product to be withdrawn.
  • the main pipeline delivery flow destined for the LNG plant passes into the first stage chiller LNG1 at point D where all or most of the chilling normally supplied by a propane refrigeration plant is replaced by the pipeline outflow. This unit chills the LNG plant feedstock passing through the heat exchanger from point H to point K.
  • Point E From Point E the flow goes to Point F where it enters a separation tower SP1 where NGL liquids are extracted (departing the tower at Point J) leaving behind a lean gas stream of mostly methane and some ethane that forms the basis of the LNG feedstock.
  • This product flows from point G to the inlet of the first stage chiller LNG 1 at point H. It will generally not require any intermediate processing with correct operation of the separation tower SP1 that is ideally specified as an absorbent process.
  • the separation unit SP1 has a loop for regeneration of adsorbent fluid through a process skid RG1 .
  • the previously mentioned chilled side-stream of pipeline outflow of cold rich gas CV is used in the chiller section of this skid.
  • the chilling stream enters the RG1 unit at W, leaving at X to rejoin intercept at point V and reunite with the mainstream flow EF emerging from the Chiller LNG 1 .
  • This disclosure discusses a method of accelerating the onset of, and access to, lower compressibility (Z) factors in natural gas pipelines covering embodiments of broader pressure, temperature, and constituents within Rich Gas mixtures yielding a new array of transportation benefits.
  • a wider band of low flow resistance in pipelines over that in the prior art which restricted by lower maximum operating pressures. Storage density is improved.
  • the properties of the Rich Gas mixtures and higher operating/storage pressures involved are such that internal chilling within the transported medium can then take place through the Joule- Thompson effect and making a chilled, lower pressure delivery of product direct from the pipeline.
  • embodiments include a method of bringing about the chilling of Natural Gas and Natural Gas/NGL mixtures delivered from a pipeline system such that the resulting mixture also exhibits internal chilling behavior during its transport, storage, and withdrawal from the system that is associated with behavior properties of the constituents of the conveyed product.
  • Such mixtures can be formulated by additive or subtractive processing of the natural gas and NGL constituents. Operational conditions where these effects occur can be between 3500 psig and 500 psig and 120F and -120F. The low temperature range being reserved for the lightest mixtures not exhibiting liquid fall out.
  • the method replaces or reduces the need for externally provided chilling traditionally applied in downstream processing of the delivered products. Notwithstanding the types of process here include but are not limited to pre chilling for LNG production, chilling for separation and fractionation, and chilling for enhanced storage of CNG.
  • a method of high pressure pipeline transmission and systems of storage for Natural Gas mixtures and Natural Gas/NGL enhanced mixtures is provided, the mixtures formulated with the objective of lowering compressibility (Z) factors under Maximum Operating conditions (MOP) between above about 2150 psig and up to about 4500 psig.
  • Such mixtures can be formulated by additive or subtractive processing of the natural gas and NGL constituents.
  • range of effective gas mixtures applicable comprise: from 40% to 98% by mol volume of methane, from trace to 35% by mol volume of ethane; from trace to 22% by mol volume of propane; from trace to 9% by mol volume of butane; residual amounts of N2 not exceeding 2% by mol volume; trace elements of C5+ (ie C5, C6 ... ) hydrocarbons not exceeding 0.25% of mol volume; and the total being 100%, wherein the operating conditions of the mixture is completely gaseous or in the supercritical-dense phases with no liquid phase.
  • the mol% of any of the Light Hydrocarbons (ethane, propane, butane) given here can also lie within the 0 to specified minimum % mol range as shown, where the stand alone % mol of remaining Light Hydrocarbons is sufficient to bring about the reduction in Z factor value and dense phase flow/storage behavior and/or chilling effects.
  • Such stand alone values are 6% for ethane, 1 .5% for propane and 0.5% for butanes for Rich Gas mixtures : and 2% for ethane, 1 % for propane and 0.25% for butanes in the 2500 psig or higher pressure Standard Transmission specification mixtures.
  • a high pressure staged section of the pipeline that is project specific in volume by virtue of length and cross sectional area, can be used for high pressure storage, product flow and de-pressuring of the pipeline contents, which operates within the limits of 3500 psig and 800 psig according to end use for the delivered product.
  • Such as system can also be operated within the limits of 4500 psig and 800 psig according to end use for the delivered product.
  • a pressure and temperature reducing device such as a J-T valve or Turbo Expander is located at the exit points of the pipe sections that will bring about the refrigeration effect within the transmitted gas mixture subjected to the pressure drop.
  • a turbo expander system is employed that permits shaft or electrical recovery of pipeline energy from the high pressure storage.
  • an optional temperature trimming system incorporated within or downstream of the storage compressors to condition the gas flow to optimal temperature or density conditions for process applications downstream of the invention.
  • an upper temperature limit of 150F is claimed for operating conditions to maintain flow in gaseous state when the pipeline is installed in cold environments with high heat losses along the sectional length(s).
  • a pipeline can be configured to carry lean North American Spec Gas or NGL Rich Gas , that is project specific in volume, by virtue of its entire length and cross sectional area and pipe layout, used for product flow, high pressure storage, and de-pressuring the contents, which operates within the limits of 4500 psig and 350 psig according to end use for a chilled delivered product.

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Abstract

L'invention concerne des constituants de pression, de température et de LGN de pipeline qui sont manipulés pour le transport et le stockage facultatif dans un système de pipeline de mélanges de gaz naturel ou de mélanges riches pour la distribution de produits réfrigérés pour des applications en aval. La réduction de pression à partir d'une dernière section de compression fourni des produits réfrigérés intérieurement, permettant une réduction des coûts d'investissement et de fonctionnement. Un poste de compression à haute portance, avant l'extrémité de pipeline, fournit un différentiel de pression pour le refroidissement Joule-Thompson des contenus de pipeline. L'étape de refroidissement peut être adaptée aux systèmes de pipeline existants, et l'étape de refroidissement peut comprendre un turbodétendeur ou analogue pour la récupération d'énergie de pression de pipeline pour la génération d'énergie. Par exemple, avec cette opération de pression plus élevée, les effets de teneur améliorée en LGN entraînent une réduction du diamètre du pipeline d'au moins une taille standard. On obtient ainsi une réduction globale importante de la consommation d'énergie et des émissions de CO2 associées par l'intermédiaire d'applications de pipeline et de traitement intégrées.
PCT/CA2017/050651 2016-05-27 2017-05-29 Système de pipeline multifonctionnel intégré permettant la distribution de mélanges réfrigérés de gaz naturel et de mélanges réfrigérés de gaz naturel et de lgn Ceased WO2017201630A1 (fr)

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EP4264153A4 (fr) * 2020-12-18 2024-12-04 JL Energy Transportation Inc. Procédé de gnl utilisant une charge d'alimentation en tant que fluide frigorigène primaire
CN116263235A (zh) * 2021-12-14 2023-06-16 中国石油工程建设有限公司 一种超临界co2管道检修工况下管存介质减排系统与方法

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