+

WO1998053032A1 - Procede et produit de stockage du gaz - Google Patents

Procede et produit de stockage du gaz Download PDF

Info

Publication number
WO1998053032A1
WO1998053032A1 PCT/CA1998/000355 CA9800355W WO9853032A1 WO 1998053032 A1 WO1998053032 A1 WO 1998053032A1 CA 9800355 W CA9800355 W CA 9800355W WO 9853032 A1 WO9853032 A1 WO 9853032A1
Authority
WO
WIPO (PCT)
Prior art keywords
pressure
volume
mixture
temperature
psia
Prior art date
Application number
PCT/CA1998/000355
Other languages
English (en)
Inventor
Ian Morris
Glen Perry
Original Assignee
Jl Energy Transportation Inc.
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Priority claimed from CA002205678A external-priority patent/CA2205678C/fr
Application filed by Jl Energy Transportation Inc. filed Critical Jl Energy Transportation Inc.
Priority to EA199901041A priority Critical patent/EA001951B1/ru
Priority to AU70202/98A priority patent/AU7020298A/en
Publication of WO1998053032A1 publication Critical patent/WO1998053032A1/fr

Links

Classifications

    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
    • C10L3/00—Gaseous fuels; Natural gas; Synthetic natural gas obtained by processes not covered by subclass C10G, C10K; Liquefied petroleum gas
    • C10L3/06—Natural gas; Synthetic natural gas obtained by processes not covered by C10G, C10K3/02 or C10K3/04
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
    • C10L3/00—Gaseous fuels; Natural gas; Synthetic natural gas obtained by processes not covered by subclass C10G, C10K; Liquefied petroleum gas
    • C10L3/003—Additives for gaseous fuels

Definitions

  • This invention relates to the transfer by pipeline or storage of mixtures which contain methane or natural gas.
  • methane is the largest component of natural gas, and usually accounts for at least 95% by volume of what is known as “transmission specification” natural gas.
  • Other usual components are ethane (usually about 2%), propane (usually about 0.5%), butanes, pentanes and possibly hexanes (altogether amounting to less than about 0.3%), with the balance being nitrogen and carbon dioxide.
  • transmission specification natural gas will be hereinafter called “natural gas”.
  • the natural gas as transmitted through the pipelines of TransCanada Pipeline Limited from Alberta, Canada to Ontario, Canada has typically the following percentage composition by volume:
  • the pressure is in pounds per square inch absolute (psia)
  • the volume is in cubic feet
  • temperature is in degrees R (degrees Fahrenheit plus 460).
  • the Ideal Gas Equation does not give exactly correct results in actual practice, because gases are compressible. Gas molecules, when compressed, pack more tightly together than would be predicted by the Ideal Gas Equation, because of intermolecular forces and molecular shape.
  • an added term, the compressibility factor z can be added to the Ideal Gas Equation. This is a dimensionless factor which reflects the compressibility of the particular gas being measured, at the particular temperature and pressure conditions. At atmospheric pressure or gage pressures of a few hundred pounds, the compressibility factor is sufficiently close to 1.0 so that it can be ignored for most gases, and so that the Ideal Gas Law can be used without the added term z.
  • T the temperature of the gas in degrees
  • T c the critical temperature of the gas in degrees
  • P the pressure of the gas in psia
  • P c the critical pressure of the gas in psia
  • Critical pressures and critical temperatures for pure gases have been calculated, and are available in most handbooks. Where a mixture of gases of known composition is available, a pseudo critical temperature and pseudo critical pressure which apply to the mixture can be obtained by using the averages of the critical temperatures and critical pressures of the pure gases in the mixture, weighted according the percentage of each pure gas present.
  • the compressibility factor z can be found by use of standard charts.
  • One of these is "Compressibility Factors for Natural Gases" by M.D. Standing and D.L. Katz, published in the
  • Natural gas like methane, shows z factor changes with pressure. Under about 1000 psia the dominant variable in the power relationship is the molecular weight of the gas. At this pressure level, addition of further amounts of ethane or propane increases the molecular weight of the gas more rapidly than the z factor decreases. Thus, there is an advantage to removing ethane and propane from the gas.
  • ethane is the additive, enough ethane must be added to methane or natural gas to give a gas composition having a minimum of about 26% ethane for operation at 1,000 psia and normal temperatures (-40°F to +110°F). (All percentages in this document are percentages by volume). Ethane can be added until just before the mixture separates into separate gas and liquid (which occurs at about 40% ethane for a pressure 1,000 psia and a temperature of about 35°F). To reduce the danger of liquefaction if there is inadvertent pressure drop, and to reduce temperature extremes, generally operation at 26-35% ethane and 35°F to +40°F is preferred.
  • ethane as an additive, an amount is added to give a gas which has at least 26%) ethane (but preferably 35% ethane) at 1,000 psia, and at least 6% ethane (but preferably 15% ethane) at 2,200 psia, with the minimum percentage of ethane decreasing smoothly with rise in pressure.
  • Ethylene may be substituted for all or part of the ethane on a 1 : 1 volume basis.
  • pressure indicated is the maximum pressure to which the gas is compressed. In such a compression-rarefaction arrangement, it is preferred that the ratio between the most compressed and the most rarefied pressures of the gas not exceed 1.3:1.
  • C 3 hydrocarbons alone can also be used as the additive.
  • Minimum useable percentage of the total gas mixture vary from a minimum of 5% at 1,000 psia to about 3% at 2,200 psia. Maximum amounts are those which will not cause separation of a liquid phase at the temperature used.
  • the C 3 hydrocarbons may be any of propane, isopropane or propylene, separately or in admixture.
  • One or more C 3 hydrocarbons may also be substituted, preferably on a 1 :3.5 volume basis, for C 2 hydrocarbons, but not to a point where they cause separation of a liquid phase at the pressure and temperature of operation.
  • a 1 :3.5 basis means that each standard volume of C 3 hydrocarbon replaces three and a half standard volumes of C 2 hydrocarbon.
  • the limitation that a liquid phase should not be formed means that not more than about 12%) of C 3 hydrocarbons should be present at 1000 psia and 60°F, and lesser amounts should be used as the pressure or temperature increases.
  • Two or more of the C 2 or C 3 additives can also be used.
  • the use of two or more additives has a synergistic effect in many cases, so that less than the minimum amount of each is needed than would be needed if only one were present, in order to produce a zlv product smaller than that of an equivalent standard volume of natural gas at the pressure and temperature involved.
  • C 4 hydrocarbons do not contribute much to the improvement of the zMschreib product.
  • C 4 hydrocarbons are not additives contemplated by this invention.
  • C 4 hydrocarbons which are already present in the natural gas need not be removed if they are present in insufficient quantity to liquify or to affect the zMschreib, product very adversely.
  • the presence of more than 1% C 4 hydrocarbon in the mixture is not preferred, however, as C 4 hydrocarbons tend to liquify easily at pressures between 1,000 psia and 2,200 psia, and more than 1% C 4 hydrocarbons give rise to increased danger that a liquid phase will separate out.
  • C 4 hydrocarbons also have an unfavourable effect on the mixture's z factor at pressures just under 900 psia, so care should be taken that, during transport through a pipeline, that mixtures according to the invention which contain C 4 hydrocarbons are not allowed to decompress to less than 900 psia, and preferably not to less than 1,000 psia.
  • the z factor falls so much that the zM w product tends to lower values than that of pure methane.
  • the z factor continues to get smaller with increased percentages of ethane, bringing with it a lower zM_, product to the point where further increase of ethane causes separation of a liquid phase (at about 40% ethane at 1,000 psia and 35°F).
  • adding ethane to natural gas so that there is a mixture containing more than 26% ethane at 1,000 psia and 35 °F leads to increased packing of molecules and a decreased zMbun, product, hence decreased pumping costs and more ability to store within a given volume.
  • C 4 hydrocarbons eg butanes and butylenes
  • other components of the natural gas need not be separated out before storing gases according to this invention.
  • Ammonia can also be used as the additive, either in substitution for or in admixture with the hydrocarbon additives.. Approximately 10-12 % by volume NH 3 causes separation of a liquid phase, depending on the pressure and temperature, so the amount added should be below the amount which causes separation of a liquid phase. Any amount of ammonia gives some benefit at the pressures of this invention, but a minimum of 0.5% is preferred in order to get appreciable advantages. Ammonia gives a beneficial effect at even a lower pressure than the other additives, and can be added when storage will take place at any pressure above 800 psia.
  • Carbon monoxide does not have enough economic or heating value to warrant passing it through a pipeline in most cases, even if it reduces the overall energy needed to pump the mixture of itself and natural gas, Similarly, carbon monoxide usually does not have enough economic value to warrant storing it, even when the decrease in zMschreib product causes the mixture of carbon monoxide and natural gas to be stored with lower energy expenditure than natural gas alone.
  • Hydrogen fluoride exhibits a cooling effect analogous to that of ammonia, so that in principle, hydrogen fluoride is also a particular advantageous additive.
  • hydrogen fluoride although it is valuable, is also a highly poisonous and corrosive agent, and its storage and handling need special lines and valves. Usually, the cost of such special lines and valves, and the risks of storing or transporting a highly dangerous product, outweigh any advantage in reduced pumping or compression costs or even refrigeration arising from the mixing of hydrogen fluoride with natural gas in most circumstances.
  • a large supply of hydrogen fluoride is not typically available where natural gas is found.
  • hydrogen fluoride is not as preferred as ammonia in the practice of this invention, although it could be economically useable where sufficient supplies occur with natural gas, and where markets for hydrogen fluoride occur near the downstream end of the pipeline.
  • Two or more of these additives can be used together.
  • the use of two or more additives has a synergistic effect in many cases, so that less than the minimum amount of each is needed than would be needed if only one were present, in order to produce the z factor over that of an equivalent standard volume of natural gas at the pressure and temperature involved.
  • gas “storage” includes the holding of gas in a tank or subterranean cavern or the like, and also the holding of gas in an endless loop of pipeline. All of these types of storage are collectively referred to as a “storage chamber”. Hydrocarbon additives are particularly advantageous for storage as they permit storage of a mixture of methane or natural gas and the hydrocarbon additive in the same storage chamber with less energy expenditure than if the two were stored separately.
  • Ammonia is also a useful additive, as it can be made easily and cheaply from waste hydrogen or natural gas. Thus, a ready supply of ammonia can be made available wherever there is natural gas to store for transport.
  • Ammonia has the property of being a refrigerant, which absorbs heat as it expands.
  • the ammonia cools the mixture as it expands.
  • a minimum of about 4% by volume of ammonia is therefore necessary before the cooling becomes significant. This cooling reduces even further the cost of pumping arising from the effect of ammonia on the z factor.
  • more than 4% by volume of ammonia is preferred.
  • the ammonia can be separated from the natural gas and can be sold, as ammonia is a commercially valuable product.
  • the gas mixture can be made to flow through the pipeline at temperatures not exceeding a particular desired temperature.
  • the line can be designed and the added amount of ammonia adjusted so that the pipeline temperature never exceeds the melting temperature of the permafrost. This makes feasible uninsulated or only slightly insulated pipelines through permafrost, which pipelines do not damage their environment by melting it.
  • Figures 1 A to IE are plots of capacity gain in percent against the content of C 2 hydrocarbons in a mixture of methane and ethane. Each of the plots shows the results at a different pressure.
  • Figures 2 A and 2B are plots of capacity gain versus temperature (in degrees Fahrenheit) for the same gas mixtures at 800 psia and 1,675 psia respectively.
  • Figure 3 is a plot of the z factor for a mixture of methane and various concentrations by volume of ammonia, at different pressures and the same temperature.
  • Figures 4 A and 4B are plots of the horsepower needed to compress natural gas in an idealized pipeline with various amounts of added ammonia.
  • Figure 4A shows the effect of addition of ammonia on gas initially at 1100 psia
  • Figure 4B shows the effect on gas initially at 1900 psia.
  • FIG. 1 A it is seen that, for an 800 psia storage chamber, the best packing occurs when the chamber is filled with pure methane. As ethane is added, the capacity gain percent decreases until there is about 25% ethane in the chamber. After this, the capacity gain begins to increase again, but it does not reach the levels obtained for pure methane.
  • Figure IB shows the effect of addition to methane of ethane for a storage chamber at 1,150 psia.
  • the capacity gain steadily decreases from 0% ethane to about
  • Figure 1C shows that this effect is even more pronounced when the chamber pressure is increased to 1,350 psia.
  • Figure ID shows that at 1,760 psia, the lowest capacity occurs at about 5%, and anything over 12% ethane gives a better capacity gain than is attainable with natural gas or methane alone. For best results, however, at least 15% ethane should be present.
  • Figure IE the addition of about 4% ethane gives a benefit, and the benefit steadily increases all the way up to the point at which the ethane begins to separate out in a liquid phase.
  • at least 12% ethane, and preferably 15% ethane should be present.
  • Figure 2 shows how the effect changes with temperature. Even at 800 psia ( Figure 2A) there is a capacity increase as temperature drops, and the capacity gain is greater the more C 2 that is present. With higher pressure ( Figure 2B) the capacity gain is much greater with temperature, and the improvement in capacity gain becomes still greater as increased amounts of ethane are added.
  • the preferred composition of the gas and preferred conditions for storage when only hydrocarbons is present are the following:
  • Figure 3 shows the effect of 2%, 6% and 10% percentages by volume of ammonia on the z factor, at 30°F. It will be noted that ammonia has a positive effect even at 800 psia, and that increasing percentages of ammonia increase the effect. Increasing pressure also increases the effect, to somewhere between 2000-2200 psia depending on percentage of ammonia, after which further pressure increases do not provide increased benefits.
  • Figure 4 plots, for temperatures of 30 °F and 60 °F, the calculated effect of different amounts of added ammonia to transmission specification natural gas for an idealized 50 mile long pipeline on flat land.
  • the pipeline is assumed to be 36 inches in diameter and to be filled at the input end with gas pressurized to the input pressure. Gas mixtures flow isothermally through the pipeline, and sufficient pumping energy is applied at the input end to give a pressure drop of 150 psia.
  • the gas is initially at 1100 psia
  • Figure 4B the gas is initially at 1900 psia. It will be noted that, in each case, the addition of any amount of ammonia decreases the total horsepower needed for operation of the pipeline at all temperatures and pressures shown.

Landscapes

  • Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Engineering & Computer Science (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
  • Organic Chemistry (AREA)
  • Filling Or Discharging Of Gas Storage Vessels (AREA)

Abstract

Pour le stockage du gaz naturel à des pressions supérieures à 1000 lb/po2, il est avantageux d'ajouter au gaz un additif qui est un composé à base d'hydrocarbures C¿2?-C3 ou un mélange de composés de ce type. Au-dessus d'une limite inférieure (qui varie en fonction de l'additif ajouté et de la pression), on obtient ainsi une diminution de la puissance nécessaire pour comprimer le mélange. Pour le stockage ou le transport par pipeline du gaz naturel à des pressions supérieures à 800 lb/po?2¿, il est avantageux d'ajouter au gaz de l'ammoniac, en une quantité telle que ce dernier ne génère pas de phase liquide à la température et à la pression utilisées. Le mélange ammoniac-gaz naturel peut être comprimé ou pompé avec une consommation d'énergie inférieure à celle qui serait nécessaire pour un volume équivalent de gaz naturel seul. Quand la quantité d'ammoniac présent est supérieure à 4 % en volume, le pompage par pipeline est également facilité par l'effet réfrigérant de l'ammoniac, qui diminue la température du gaz transporté. A la place de l'ammoniac, on peut ajouter au gaz naturel du fluorure d'hydrogène ou du monoxyde de carbone, mais ceux-ci sont moins préférés que l'ammoniac.
PCT/CA1998/000355 1997-05-16 1998-04-16 Procede et produit de stockage du gaz WO1998053032A1 (fr)

Priority Applications (2)

Application Number Priority Date Filing Date Title
EA199901041A EA001951B1 (ru) 1997-05-16 1998-04-16 Способ хранения газа и продукт хранения
AU70202/98A AU7020298A (en) 1997-05-16 1998-04-16 Gas storage method and product

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
CA2,205,678 1997-05-16
CA002205678A CA2205678C (fr) 1996-11-18 1997-05-16 Methode de stockage du gaz naturel et produit

Publications (1)

Publication Number Publication Date
WO1998053032A1 true WO1998053032A1 (fr) 1998-11-26

Family

ID=4160685

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/CA1998/000355 WO1998053032A1 (fr) 1997-05-16 1998-04-16 Procede et produit de stockage du gaz

Country Status (3)

Country Link
AU (1) AU7020298A (fr)
EA (1) EA001951B1 (fr)
WO (1) WO1998053032A1 (fr)

Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO1990000589A1 (fr) * 1988-07-11 1990-01-25 Mobil Oil Corporation Procede de liquefaction d'hydrocarbures gazeux
US5315054A (en) * 1990-10-05 1994-05-24 Burnett Oil Co., Inc. Liquid fuel solutions of methane and liquid hydrocarbons
WO1997019152A1 (fr) * 1995-11-17 1997-05-29 665976 Alberta Ltd. Melanges conçus pour le stockage et le transport par pipeline de gaz

Patent Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO1990000589A1 (fr) * 1988-07-11 1990-01-25 Mobil Oil Corporation Procede de liquefaction d'hydrocarbures gazeux
US5315054A (en) * 1990-10-05 1994-05-24 Burnett Oil Co., Inc. Liquid fuel solutions of methane and liquid hydrocarbons
WO1997019152A1 (fr) * 1995-11-17 1997-05-29 665976 Alberta Ltd. Melanges conçus pour le stockage et le transport par pipeline de gaz
WO1997019151A1 (fr) * 1995-11-17 1997-05-29 665976 Alberta Ltd. Melanges pour le transport de gaz par pipelines

Also Published As

Publication number Publication date
EA199901041A1 (ru) 2000-06-26
AU7020298A (en) 1998-12-11
EA001951B1 (ru) 2001-10-22

Similar Documents

Publication Publication Date Title
US7418822B2 (en) Method and substance for refrigerated natural gas transport
US6217626B1 (en) High pressure storage and transport of natural gas containing added C2 or C3, or ammonia, hydrogen fluoride or carbon monoxide
KR102244172B1 (ko) 이중 목적의 액화 천연가스/액화 질소 저장 탱크를 퍼징하는 방법
EP0500355A1 (fr) Transport de gaz à pétrole non-traité
US6201163B1 (en) Pipeline transmission method
WO2008009930A2 (fr) Appareil et procédés pour le transport et le traitement de gaz naturel
US20080110181A1 (en) Residual boil-off gas recovery from lng storage tanks at or near atmospheric pressure
AU2002231519A1 (en) Method and substance for refrigerated natural gas transport
WO1990000589A1 (fr) Procede de liquefaction d'hydrocarbures gazeux
Janusz et al. Hydrogen-natural gas mixture compression in case of transporting through high-pressure gas pipelines
CN1102215C (zh) 生产富甲烷液体的方法
WO1997019152A1 (fr) Melanges conçus pour le stockage et le transport par pipeline de gaz
AU747206B2 (en) Pipeline transmission method
WO1998053032A1 (fr) Procede et produit de stockage du gaz
KR20220031150A (ko) 액화가스 운반선의 연료공급시스템 및 방법
Reynolds et al. Pipeline transportation of hydrogen
CA2904486A1 (fr) Methode et systeme de traitement et liquefaction de gaz naturel
CN113677942B (zh) 冷却蒸发气体的方法和用于该方法的装置
CA2443200C (fr) Procede et substance utiles pour transporter du gaz naturel refrigere
CA2205678C (fr) Methode de stockage du gaz naturel et produit
JP7198294B2 (ja) 液化天然ガスタンクからのボイルオフガスを再凝縮させるためのシステムおよび方法
US11243026B2 (en) Method and device for liquefaction of methane
JP7204888B2 (ja) 天然ガス液化プラントにおけるボイルオフガス再循環サブシステム
CA2205670C (fr) Methode de transport par pipeline

Legal Events

Date Code Title Description
AK Designated states

Kind code of ref document: A1

Designated state(s): AL AM AT AU AZ BA BB BG BR BY CH CN CU CZ DE DK EE ES FI GB GE GH GM GW HU ID IL IS JP KE KG KP KR KZ LC LK LR LS LT LU LV MD MG MK MN MW MX NO NZ PL PT RO RU SD SE SG SI SK SL TJ TM TR TT UA UG US UZ VN YU ZW

AL Designated countries for regional patents

Kind code of ref document: A1

Designated state(s): GH GM KE LS MW SD SZ UG ZW AM AZ BY KG KZ MD RU TJ TM AT BE CH CY DE DK ES FI FR GB GR IE IT LU MC NL PT SE BF BJ CF CG CI CM GA GN ML MR NE SN TD TG

DFPE Request for preliminary examination filed prior to expiration of 19th month from priority date (pct application filed before 20040101)
121 Ep: the epo has been informed by wipo that ep was designated in this application
WWE Wipo information: entry into national phase

Ref document number: 199901041

Country of ref document: EA

NENP Non-entry into the national phase

Ref document number: 1998549728

Country of ref document: JP

REG Reference to national code

Ref country code: DE

Ref legal event code: 8642

122 Ep: pct application non-entry in european phase
点击 这是indexloc提供的php浏览器服务，不要输入任何密码和下载