JP2004530858A5 - - Google Patents
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- JP2004530858A5 JP2004530858A5 JP2003504027A JP2003504027A JP2004530858A5 JP 2004530858 A5 JP2004530858 A5 JP 2004530858A5 JP 2003504027 A JP2003504027 A JP 2003504027A JP 2003504027 A JP2003504027 A JP 2003504027A JP 2004530858 A5 JP2004530858 A5 JP 2004530858A5
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- 239000007788 liquid Substances 0.000 claims description 39
- 239000003345 natural gas Substances 0.000 claims description 37
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims description 31
- 150000002430 hydrocarbons Chemical class 0.000 claims description 24
- 238000001816 cooling Methods 0.000 claims description 19
- 239000004215 Carbon black (E152) Substances 0.000 claims description 16
- 239000007789 gas Substances 0.000 claims description 14
- 238000004821 distillation Methods 0.000 claims 66
- 238000001256 steam distillation Methods 0.000 claims 8
- 239000003949 liquefied natural gas Substances 0.000 claims 6
- ATUOYWHBWRKTHZ-UHFFFAOYSA-N propane Chemical compound CCC ATUOYWHBWRKTHZ-UHFFFAOYSA-N 0.000 description 10
- IJGRMHOSHXDMSA-UHFFFAOYSA-N nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 8
- 239000001294 propane Substances 0.000 description 6
- IJDNQMDRQITEOD-UHFFFAOYSA-N butane Chemical compound CCCC IJDNQMDRQITEOD-UHFFFAOYSA-N 0.000 description 5
- 239000001273 butane Substances 0.000 description 5
- OTMSDBZUPAUEDD-UHFFFAOYSA-N ethane Chemical compound CC OTMSDBZUPAUEDD-UHFFFAOYSA-N 0.000 description 5
- 238000000034 method Methods 0.000 description 5
- 239000000203 mixture Substances 0.000 description 5
- 239000003915 liquefied petroleum gas Substances 0.000 description 4
- 238000004519 manufacturing process Methods 0.000 description 4
- 229910052757 nitrogen Inorganic materials 0.000 description 4
- 239000006227 byproduct Substances 0.000 description 3
- CURLTUGMZLYLDI-UHFFFAOYSA-N carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 description 2
- 239000001569 carbon dioxide Substances 0.000 description 2
- 229910002092 carbon dioxide Inorganic materials 0.000 description 2
- JCXJVPUVTGWSNB-UHFFFAOYSA-N nitrogen dioxide Chemical compound O=[N]=O JCXJVPUVTGWSNB-UHFFFAOYSA-N 0.000 description 2
- OFBQJSOFQDEBGM-UHFFFAOYSA-N pentane Chemical compound CCCCC OFBQJSOFQDEBGM-UHFFFAOYSA-N 0.000 description 2
- 239000003507 refrigerant Substances 0.000 description 2
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 2
- 229910001868 water Inorganic materials 0.000 description 2
- NNPPMTNAJDCUHE-UHFFFAOYSA-N Isobutane Chemical compound CC(C)C NNPPMTNAJDCUHE-UHFFFAOYSA-N 0.000 description 1
- 238000007906 compression Methods 0.000 description 1
- 239000000498 cooling water Substances 0.000 description 1
- 239000012530 fluid Substances 0.000 description 1
- 239000001257 hydrogen Substances 0.000 description 1
- 229910052739 hydrogen Inorganic materials 0.000 description 1
- 125000004435 hydrogen atoms Chemical class [H]* 0.000 description 1
- 239000001282 iso-butane Substances 0.000 description 1
- 239000000047 product Substances 0.000 description 1
- 238000004088 simulation Methods 0.000 description 1
- NINIDFKCEFEMDL-UHFFFAOYSA-N sulfur Chemical compound [S] NINIDFKCEFEMDL-UHFFFAOYSA-N 0.000 description 1
- 229910052717 sulfur Inorganic materials 0.000 description 1
- 239000011593 sulfur Substances 0.000 description 1
Description
天然ガスは通常、地下貯水池に穿孔した井戸から回収される。通常、天然ガスは大部分がメタンであり、則ちメタンが天然ガスの少なくとも50モルパーセントを構成する。特定の地下貯水池に依存して、天然ガスはエタン、プロパン、ブタン、ペンタンなどの比較的少量のメタンより重質の炭化水素類、並びに水、水素、窒素、二酸化炭素及び他のガスも含んでいる。 Natural gas is usually recovered from wells drilled in underground reservoirs. Natural gas is usually predominantly methane, ie methane constitutes at least 50 mole percent of natural gas. Depending on the specific underground reservoir, natural gas also contains relatively small amounts of hydrocarbons, such as ethane, propane, butane, pentane, and heavier hydrocarbons, as well as water, hydrogen, nitrogen, carbon dioxide and other gases. Yes.
本発明は、通常、天然ガスを液化すると同時に、メタンより重い炭化水素類から主になる液体ストリーム、たとえばエタン、プロパン、ブタン及びこれらより重質の炭化水素成分から構成される天然ガス液体(NGL)、プロパン、ブタン及びこれらより重質の炭化水素成分から構成される液化石油ガス(LPG)、またはブタン及びこれより重質の炭化水素成分から構成される凝縮物などを副産物として製造することに関する。副産物の液体ストリームの製造には二つの重要な利点：生成したLNGが高メタン純度であること、そして副生成物の液体は、他の多くの目的に関して使用し得る有用な生成物であるという点がある。本発明に従って処理すべき天然ガスストリームの典型的な分析結果は、モル%概算で、約84.2%メタン、7.9%エタン及び他のC2成分、4.9%プロパン及び他のC3成分、1.0%イソブタン、1.1%ノルマルブタン、0.8%ペンタンと、残余は窒素と二酸化炭素であろう。硫黄を含有するガスも含まれることがある。 The present invention typically liquefies natural gas and at the same time a liquid stream composed primarily of hydrocarbons heavier than methane, such as natural gas liquid (NGL) composed of ethane, propane, butane and heavier hydrocarbon components. ), Liquefied petroleum gas (LPG) composed of propane, butane and heavier hydrocarbon components, or a condensate composed of butane and heavier hydrocarbon components as a by-product . Two key advantages for the production of by-product liquid streams: the LNG produced is of high methane purity, and the by-product liquid is a useful product that can be used for many other purposes. There is. Typical analytical results for a natural gas stream to be treated according to the present invention are approximately 84.2% methane, 7.9% ethane and other C 2 components, 4.9% propane and other C 3 components, 1.0% isobutane on a mole percent basis. 1.1% normal butane, 0.8% pentane, with the balance nitrogen and carbon dioxide. Gases containing sulfur may also be included.
ストリーム35と38cの冷却は全て、閉鎖循環式冷却ループによって提供する。このサイクル用の作動流体(working fluid)は炭化水素と窒素との混合物であり、この混合物の組成は、利用可能な冷却媒体を使用して適正な圧力で凝縮させつつ必要な冷媒温度を提供するのに必要に応じて調節される。この場合、冷却水を使用して凝縮すると想定されたので、窒素、メタン、エタン、プロパンとこれらより重質の炭化水素とから構成される冷媒混合物を図１のプロセスのシミュレーションで使用する。ストリームの組成は、おおよそのモルパーセントで、7.5%窒素、41.0%メタン、41.5%エタン及び10.0%プロパンで、残余はこれらより重質の炭化水素である。 All cooling of streams 35 and 38c is provided by a closed circulation cooling loop. The working fluid for this cycle is a mixture of hydrocarbon and nitrogen, and the composition of this mixture provides the required refrigerant temperature while condensing at the proper pressure using available cooling media. Adjusted as needed. In this case, since it is assumed that the water is condensed using the cooling water, a refrigerant mixture composed of nitrogen, methane, ethane, propane and heavier hydrocarbons is used in the process simulation of FIG. The composition of the stream is approximately mole percent, 7.5% nitrogen, 41.0% methane, 41.5% ethane and 10.0% propane, with the remainder being heavier hydrocarbons.
LNG製造プロセス効率は、通常、全冷却圧縮動力対全液体製造速度の比である、必要な「比動力消費(specific power consumption)」を使用して比較する。LNGを製造するための従来プロセスに関し比動力消費の公開情報では、0.168HP-Hr/Lb[0.276kW/-時間/kg]〜0.182HP-Hr/Lb[0.300kW/-時間/kg]の範囲を示しており、これはLNG製造プラントの年間340日の操業因子に基づくものと考えられる。これと同一ベースで、本発明の図１の態様の比動力消費は0.161HP-Hr/Lb[0.265kW/-時間/kg]であり、これは従来プロセスよりも４〜13%も効率が改良している。さらに、従来プロセスの比動力消費は、本発明のこの実施例で示されているようにNGL(C2及びこれより重質の炭化水素)液体ストリームではなく、比較的低い回収レベルでLPG(C3及びこれより重質の炭化水素)または凝縮物(C4及びこれより重質の炭化水素）液体ストリームだけを同時に製造することをベースとしていることに留意しなければならない。従来プロセスは、LPGストリームまたは凝縮物ストリームの代わりにNGLストリームを同時に製造するためにかなりの冷却動力が必要である。 LNG production process efficiencies are typically compared using the required “specific power consumption”, which is the ratio of the total cooling compression power to the total liquid production rate. Specific power consumption public information regarding conventional processes for producing LNG ranges from 0.168HP-Hr / Lb [0.276kW / -hr / kg] to 0.182HP-Hr / Lb [0.300kW / -hr / kg] This is thought to be based on an operating factor of 340 days per year for the LNG production plant. On this same basis, the specific power consumption of the embodiment of FIG. 1 of the present invention is 0.161 HP-Hr / Lb [0.265 kW / -hour / kg], which is 4 to 13% more efficient than the conventional process. is doing. Furthermore, the specific power consumption of the conventional process is not an NGL (C 2 and heavier hydrocarbons) liquid stream as shown in this embodiment of the invention, but LPG (C 3 and which heavier hydrocarbons) or condensate (C 4 and only needs to be noted that the base to be manufactured simultaneously hydrocarbons) liquid streams which heavier. Conventional processes require significant cooling power to simultaneously produce NGL streams instead of LPG streams or condensate streams.
Claims (6)
(a)前記天然ガスストリームを加圧下で冷却してその少なくとも一部を凝縮させて凝縮ストリームを形成する；及び
(b)前記凝縮ストリームを膨張させて低圧とし前記液化天然ガスストリームを形成する、
前記方法において、
(1)前記天然ガスストリームを一つ以上の冷却段階で処理する；
(2)前記冷却化天然ガスストリームを膨張させて中間圧力とし、その後蒸留カラムの中間カラム供給材料位置に方向付け、ここで前記ストリームは、より揮発性の高い蒸気蒸留ストリームと、前記メタンより重質の炭化水素成分の大部分を含有する比較的揮発性の低い画分とに分離する；
(3)蒸気蒸留ストリームを前記膨張させた冷却化天然ガスストリームより下の前記蒸留カラムの領域から抜き出し、その少なくとも一部を凝縮させるのに十分に冷却し、それによって蒸気ストリームと液体ストリームとを形成する；
(4)前記液体ストリームの一部を前記蒸留カラムへのもう一つの供給材料として、前記蒸気蒸留ストリームが抜き出されるのと実質的に同一領域の供給位置で前記蒸留カラムに供給する；
(5)前記膨張させた冷却化天然ガスストリームの少なくとも一部を、前記蒸留カラム中で前記液体ストリームの残余部分の少なくなくとも一部と完全に接触させる；及び
(6)前記蒸気ストリームを前記より揮発性の高い蒸気蒸留ストリームと混合して、前記メタンの大部分と軽質成分とを含有する揮発性残渣ガス画分を形成する；及び
(7)前記揮発性残渣ガス画分を加圧下で冷却してその少なくとも一部を凝縮させて、前記凝縮ストリームを形成する
ことを改良点とする。 A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) cooling the natural gas stream under pressure to condense at least a portion thereof to form a condensed stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating the natural gas stream in one or more cooling stages;
(2) The cooled natural gas stream is expanded to an intermediate pressure and then directed to the intermediate column feed position of the distillation column, where the stream is heavier than the more volatile vapor distillation stream and the methane. Separating into relatively less volatile fractions containing the majority of quality hydrocarbon components;
(3) A vapor distillation stream is withdrawn from the area of the distillation column below the expanded cooled natural gas stream and cooled sufficiently to condense at least a portion thereof, thereby allowing the vapor and liquid streams to Form;
(4) supplying a portion of the liquid stream to the distillation column as another feed to the distillation column at a supply location in substantially the same region as the vapor distillation stream is withdrawn;
(5) contacting at least a portion of the expanded cooled natural gas stream with at least a portion of the remaining portion of the liquid stream in the distillation column; and
(6) mixing the vapor stream with the more volatile vapor distillation stream to form a volatile residue gas fraction containing a majority of the methane and light components; and
(7) The volatile residue gas fraction is cooled under pressure to condense at least a part thereof to form the condensed stream.
(a)前記天然ガスストリームを加圧下で冷却してその少なくとも一部を凝縮させて凝縮ストリームを形成する；及び
(b)前記凝縮ストリームを膨張させて低圧とし前記液化天然ガスストリームを形成する、
前記方法において、
(1)前記天然ガスストリームを一つ以上の冷却段階で処理して部分的に凝縮させる；
(2)前記部分的に凝縮させた天然ガスストリームを分離して、第一の蒸気ストリームと第一の液体ストリームとを提供する；
(3)前記第一の蒸気ストリームと前記第一の液体ストリームとを膨張させて中間圧力とする；
(4)前記膨張させた第一の蒸気ストリームと前記膨張させた第一の液体ストリームとを蒸留カラムの中間カラム供給材料位置に方向付け、ここで前記ストリームをより揮発性の高い蒸気蒸留ストリームと、前記メタンより重質の炭化水素成分の大部分を含有する比較的揮発性の低い画分とに分離する；
(5)蒸気蒸留ストリームを、前記膨張させた第一の蒸気ストリームより下の前記蒸留カラムの領域から抜き出し、その一部を凝縮させるのに十分に冷却し、それによって第二の蒸気ストリームと第二の液体ストリームとを形成する；
(6)前記蒸気蒸留ストリームを抜き出すのと実質的に同一領域の供給位置で、前記第二の液体ストリームの一部を前記蒸留カラムへのもう一つの供給材料として前記蒸留カラムに供給す
る；
(7)前記膨張させた第一の蒸気ストリームの少なくとも一部を、前記蒸留カラム中で前記第二の液体ストリームの残余部分の少なくとも一部と完全に接触させる；
(8)前記第二の蒸気ストリームを前記より揮発性の高い蒸気蒸留ストリームと混合して、前記メタンの大部分と軽質成分とを含有する揮発性残渣ガス画分を形成する；及び
(9)前記揮発性残渣ガス画分を加圧下で冷却してその少なくとも一部を凝縮させ、それによって前記凝縮ストリームを形成する
ことを改良点とする。 A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) cooling the natural gas stream under pressure to condense at least a portion thereof to form a condensed stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating said natural gas stream in one or more cooling stages to partially condense;
(2) separating the partially condensed natural gas stream to provide a first vapor stream and a first liquid stream;
(3) expanding the first vapor stream and the first liquid stream to an intermediate pressure;
(4) directing the expanded first vapor stream and the expanded first liquid stream to an intermediate column feed position of a distillation column, wherein the stream is a more volatile vapor distillation stream; Separating into a relatively less volatile fraction containing the majority of the hydrocarbon components heavier than the methane;
(5) A steam distillation stream is withdrawn from the area of the distillation column below the expanded first steam stream and cooled sufficiently to condense a portion thereof, thereby producing a second steam stream and a second steam stream. Forming two liquid streams;
(6) supplying a portion of the second liquid stream to the distillation column as another feed to the distillation column at a feed location substantially in the same region as withdrawing the vapor distillation stream;
(7) at least a portion of the expanded first vapor stream is in full contact with at least a portion of the remaining portion of the second liquid stream in the distillation column;
(8) mixing the second vapor stream with the more volatile vapor distillation stream to form a volatile residue gas fraction containing a majority of the methane and light components; and
(9) The volatile residue gas fraction is cooled under pressure to condense at least a portion thereof, thereby forming the condensed stream.
(a)前記天然ガスストリームを加圧下で冷却してその少なくとも一部を凝縮させて凝縮ストリームを形成する；及び
(b)前記凝縮ストリームを膨張させて低圧とし前記液化天然ガスストリームを形成する、
前記方法において、
(1)前記天然ガスストリームを一つ以上の冷却段階で処理する；
(2)前記冷却化天然ガスストリームを膨張させて中間圧力とし、その後蒸留カラムの中間カラム供給材料位置に方向付け、ここで前記ストリームを、より揮発性の高い蒸気蒸留ストリームと、前記メタンより重質の炭化水素成分の大部分を含有する比較的揮発性の低い画分とに分離する；
(3)蒸気蒸留ストリームを前記膨張させた冷却化天然ガスストリームより下の前記蒸留カラムの領域から抜き出し、その少なくとも一部を凝縮させるのに十分に冷却し、それによって蒸気ストリームと液体ストリームとを形成する；
(4)前記膨張させた冷却化天然ガスストリームの少なくとも一部を前記蒸留カラム中で前記液体ストリームの少なくとも一部と完全に接触させる；
(5)前記液体蒸留ストリームを、前記蒸気蒸留ストリームを抜き出す前記領域より上の位置から抜き出し、ここで前記液体蒸留ストリームを加熱し、その後前記蒸気蒸留ストリームを抜き出す領域より下の位置で前記蒸留カラムへのもう一つの供給材料として前記蒸留カラムに再び方向付ける；
(6)前記蒸気ストリームを前記より揮発性の高い蒸気蒸留ストリームと混合して、前記メタンの大部分と軽質成分とを含有する揮発性残渣ガス画分を形成する；及び
(7)前記揮発性残渣ガス画分を加圧下で冷却してその少なくとも一部を凝縮させて、前記凝縮ストリームを形成する
ことを改良点とする。 A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) cooling the natural gas stream under pressure to condense at least a portion thereof to form a condensed stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating the natural gas stream in one or more cooling stages;
(2) The cooled natural gas stream is expanded to an intermediate pressure and then directed to the intermediate column feed position of the distillation column, where the stream is heavier than the more volatile vapor distillation stream and the methane. Separating into relatively less volatile fractions containing the majority of quality hydrocarbon components;
(3) A vapor distillation stream is withdrawn from the area of the distillation column below the expanded cooled natural gas stream and cooled sufficiently to condense at least a portion thereof, thereby allowing the vapor and liquid streams to Form;
(4) contacting at least a portion of the expanded cooled natural gas stream with at least a portion of the liquid stream in the distillation column;
(5) The liquid distillation stream is withdrawn from a position above the region from which the vapor distillation stream is withdrawn, wherein the liquid distillation stream is heated and then the distillation column at a position below the region from which the vapor distillation stream is withdrawn. again the distillation column as another feed to orient;
(6) mixing the vapor stream with the more volatile vapor distillation stream to form a volatile residue gas fraction containing a majority of the methane and light components; and
(7) The volatile residue gas fraction is cooled under pressure to condense at least a part thereof to form the condensed stream.
(a)前記天然ガスストリームを加圧下で冷却してその少なくとも一部を凝縮させて凝縮ストリームを形成する；及び
(b)前記凝縮ストリームを膨張させて低圧とし前記液化天然ガスストリームを形成する、
前記方法において、
(1)前記天然ガスストリームを一つ以上の冷却段階で処理して部分的に凝縮させる；
(2)前記部分的に凝縮させた天然ガスストリームを分離して、第一の蒸気ストリームと第一の液体ストリームとを提供する；
(3)前記第一の蒸気ストリームと前記第一の液体ストリームとを膨張させて中間圧力とする；
(4)前記膨張させた第一の蒸気ストリームと前記膨張させた第一の液体ストリームを蒸留カラムの中間カラム供給材料位置に方向付け、ここで前記ストリームをより揮発性の高い蒸気蒸留ストリームと、前記メタンより重質の炭化水素成分の大部分を含有する比較的揮発性の低い画分とに分離する；
(5)蒸気蒸留ストリームを、前記膨張させた第一の蒸気ストリームより下の前記蒸留カラムの領域から抜き出し、その少なくとも一部を凝縮させるのに十分に冷却し、それにより第二の蒸気ストリームと第二の液体ストリームとを形成する；
(6)前記膨張させた第一の蒸気ストリームの少なくとも一部を、前記蒸留カラム中、前記第二の液体ストリームの少なくとも一部と完全に接触させる；
(7)前記蒸気蒸留ストリームを抜き出す前記領域より上の位置で液体蒸留ストリームを前記蒸留カラムから抜き出し、ここで前記液体蒸留ストリームを加熱し、その後前記蒸気蒸留ストリームを抜き出す領域よりも下の位置で蒸留カラムへのもう一つの供給材料として前記蒸留カラムに再び方向付ける；
(8)前記第二の蒸気ストリームを前記より揮発性の高い蒸気蒸留ストリームと混合して、前記メタンの大部分と軽質成分とを含有する揮発性残渣ガス画分を形成する；及び
(9)前記揮発性残渣ガス画分を加圧下で冷却してその少なくとも一部を凝縮させ、それにより前記凝縮ストリームを形成する
ことを改良点とする。 A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) cooling the natural gas stream under pressure to condense at least a portion thereof to form a condensed stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating said natural gas stream in one or more cooling stages to partially condense;
(2) separating the partially condensed natural gas stream to provide a first vapor stream and a first liquid stream;
(3) expanding the first vapor stream and the first liquid stream to an intermediate pressure;
(4) directing the expanded first vapor stream and the expanded first liquid stream to an intermediate column feed position of a distillation column, wherein the stream is a more volatile vapor distillation stream; Separating into a relatively less volatile fraction containing the majority of the hydrocarbon components heavier than methane;
(5) A steam distillation stream is withdrawn from the area of the distillation column below the expanded first steam stream and cooled sufficiently to condense at least a portion thereof, thereby providing a second steam stream and Forming a second liquid stream;
(6) at least a portion of the expanded first vapor stream is in full contact with at least a portion of the second liquid stream in the distillation column;
(7) A liquid distillation stream is withdrawn from the distillation column at a position above the region from which the steam distillation stream is withdrawn, wherein the liquid distillation stream is heated and then at a position below the region from which the steam distillation stream is withdrawn. again directing said distillation column as another feed to the distillation column;
(8) mixing the second vapor stream with the more volatile vapor distillation stream to form a volatile residue gas fraction containing a majority of the methane and light components; and
(9) The volatile residue gas fraction is cooled under pressure to condense at least a part thereof, thereby forming the condensed stream.
(a)前記天然ガスストリームを加圧下で冷却してその少なくとも一部を凝縮させて凝縮ストリームを形成する；及び
(b)前記凝縮ストリームを膨張させて低圧とし前記液化天然ガスストリームを形成する、
前記方法において、
(1)前記天然ガスストリームを一つ以上の冷却段階で処理する；
(2)前記冷却化天然ガスストリームを膨張させて中間圧力とし、その後蒸留カラムの中間カラム供給材料位置に方向付け、ここで前記ストリームは、より揮発性の高い蒸気蒸留ストリームと、前記メタンより重質の炭化水素成分の大部分を含有する比較的揮発性の低い画分とに分離する；
(3)前記膨張させた冷却化天然ガスストリームより下の前記蒸留カラムの領域から蒸気蒸留ストリームを抜き出し、その少なくとも一部を凝縮させるのに十分に冷却し、それによって蒸気ストリームと液体ストリームとを形成する；
(4)前記液体ストリームの一部を前記蒸留カラムへのもう一つの供給材料として、前記蒸気蒸留ストリームが抜き出されるのと実質的に同一領域の供給位置で前記蒸留カラムに供給する；
(5)前記膨張させた冷却化天然ガスストリームの少なくとも一部を、前記蒸留カラム中で前記液体ストリームの残余部分の少なくなくとも一部と完全に接触させる；
(6)前記蒸気ストリームを前記蒸気蒸留ストリームが抜き出される領域より上の位置で前記蒸留カラムから抜き出し、そこで前記液体蒸留ストリームを加熱し、その後前記蒸気蒸留ストリームが抜き出される領域より下の位置で前記蒸留カラムへのもう一つの供給材料として前記蒸留カラムに再び方向付ける；
(7)前記蒸気ストリームを前記より揮発性の高い蒸気蒸留ストリームと混合して、前記メタンの大部分と軽質成分とを含有する揮発性残渣ガス画分を形成する；及び
(8)前記揮発性残渣ガス画分を加圧下で冷却してその少なくとも一部を凝縮させて、前記凝縮ストリームを形成する
ことを改良点とする。 A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) cooling the natural gas stream under pressure to condense at least a portion thereof to form a condensed stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating the natural gas stream in one or more cooling stages;
(2) The cooled natural gas stream is expanded to an intermediate pressure and then directed to the intermediate column feed position of the distillation column, where the stream is heavier than the more volatile vapor distillation stream and the methane. Separating into relatively less volatile fractions containing the majority of quality hydrocarbon components;
(3) withdrawing a steam distillation stream from the region of the distillation column below the expanded cooled natural gas stream and cooling sufficiently to condense at least a portion thereof, thereby consolidating the vapor and liquid streams. Form;
(4) supplying a portion of the liquid stream to the distillation column as another feed to the distillation column at a supply location in substantially the same region as the vapor distillation stream is withdrawn;
(5) at least a portion of the expanded cooled natural gas stream is in full contact with at least a portion of the remaining portion of the liquid stream in the distillation column;
(6) The vapor stream is withdrawn from the distillation column at a position above the area from which the vapor distillation stream is withdrawn, where the liquid distillation stream is heated, and then the position below the area from which the vapor distillation stream is withdrawn. in again directing the distillation column as another feed to the distillation column;
(7) mixing the vapor stream with the more volatile vapor distillation stream to form a volatile residue gas fraction containing a majority of the methane and light components; and
(8) The volatile residue gas fraction is cooled under pressure to condense at least a part thereof to form the condensed stream.
(a)前記天然ガスストリームを加圧下で冷却してその少なくとも一部を凝縮させて凝縮ストリームを形成する；及び
(b)前記凝縮ストリームを膨張させて低圧とし前記液化天然ガスストリームを形成する、
前記方法において、
(1)前記天然ガスストリームを一つ以上の冷却段階で処理して部分的に凝縮させる；
(2)前記部分的に凝縮させた天然ガスストリームを分離して、第一の蒸気ストリームと第一の液体ストリームとを提供する；
(3)前記第一の蒸気ストリームと前記第一の液体ストリームとを膨張させて中間圧力とする；
(4)前記膨張させた第一の蒸気ストリームと前記膨張させた第一の液体ストリームとを蒸留カラムの中間カラム供給材料位置に方向付け、ここで前記ストリームをより揮発性の高い蒸気蒸留ストリームと、前記メタンより重質の炭化水素成分の大部分を含有する比較的揮発性の低い画分とに分離する；
(5)前記膨張させた第一の蒸気ストリームより下の前記蒸留カラムの領域から蒸気蒸留ストリームを抜き出し、その少なくとも一部を凝縮させるのに十分に冷却し、これによって第二の蒸気ストリームと第二の液体ストリームとを形成する；
(6)前記蒸気蒸留ストリームを抜き出すのと実質的に同一領域の供給位置で、蒸留カラムへのもう一つの供給材料として前記蒸留カラムに前記第二の液体ストリームの一部を供給する；
(7)前記膨張させた第一の蒸気ストリームの少なくとも一部を、前記蒸留カラム中、前記第二の液体ストリームの残余部分の少なくとも一部と完全に接触させる；
(8)前記蒸気蒸留ストリームを抜き出す領域より上の位置で前記蒸留カラムから液体蒸留ストリームを抜き出し、ここで前記液体蒸留ストリームを加熱し、その後前記蒸気蒸留ストリームを抜き出す領域より下の位置で蒸留カラムへのもう一つの供給材料として前記蒸留カラムに再び方向付ける；
(9)前記第二の蒸気ストリームを前記より揮発性の高い蒸気蒸留ストリームと混合して、
前記メタンの大部分と軽質成分とを含有する揮発性残渣ガス画分を形成し；及び
(10)前記揮発性残渣ガス画分を加圧下で冷却し、その少なくとも一部を凝縮させ、それによって前記凝縮ストリームを形成する
ことを改良点とする。 A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) cooling the natural gas stream under pressure to condense at least a portion thereof to form a condensed stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating said natural gas stream in one or more cooling stages to partially condense;
(2) separating the partially condensed natural gas stream to provide a first vapor stream and a first liquid stream;
(3) expanding the first vapor stream and the first liquid stream to an intermediate pressure;
(4) directing the expanded first vapor stream and the expanded first liquid stream to an intermediate column feed position of a distillation column, wherein the stream is a more volatile vapor distillation stream; Separating into a relatively less volatile fraction containing the majority of the hydrocarbon components heavier than the methane;
(5) withdrawing the steam distillation stream from the area of the distillation column below the expanded first steam stream and cooling it sufficiently to condense at least a portion thereof, thereby providing a second steam stream and a second steam stream. Forming two liquid streams;
(6) supplying a portion of the second liquid stream to the distillation column as another feed to the distillation column at a feed position substantially in the same region as withdrawing the vapor distillation stream;
(7) at least a portion of the expanded first vapor stream is in full contact with at least a portion of the remaining portion of the second liquid stream in the distillation column;
(8) A liquid distillation stream is withdrawn from the distillation column at a position above the region from which the steam distillation stream is withdrawn, where the liquid distillation stream is heated and then the distillation column at a position below the region from which the steam distillation stream is withdrawn. again the distillation column as another feed to orient;
(9) mixing the second vapor stream with the more volatile vapor distillation stream;
Forming a volatile residue gas fraction containing a majority of the methane and light components; and
(10) The volatile residue gas fraction is cooled under pressure to condense at least a portion thereof, thereby forming the condensed stream.
Applications Claiming Priority (3)
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| US29684801P | 2001-06-08 | 2001-06-08 | |
| US60/296,848 | 2001-06-08 | ||
| PCT/US2002/017675 WO2002101307A1 (en) | 2001-06-08 | 2002-06-04 | Natural gas liquefaction |
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| JP2009037799A Division JP5847371B2 (en) | 2001-06-08 | 2009-02-20 | Natural gas liquefaction |
| JP2012076611A Division JP2012189315A (en) | 2001-06-08 | 2012-03-29 | Natural gas liquefaction |
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|---|---|
| JP2004530858A JP2004530858A (en) | 2004-10-07 |
| JP2004530858A5 true JP2004530858A5 (en) | 2012-06-14 |
| JP5041650B2 JP5041650B2 (en) | 2012-10-03 |
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| JP2009037799A Expired - Fee Related JP5847371B2 (en) | 2001-06-08 | 2009-02-20 | Natural gas liquefaction |
| JP2012076611A Withdrawn JP2012189315A (en) | 2001-06-08 | 2012-03-29 | Natural gas liquefaction |
| JP2015102737A Pending JP2015166670A (en) | 2001-06-08 | 2015-05-20 | natural gas liquefaction |
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| JP2009037799A Expired - Fee Related JP5847371B2 (en) | 2001-06-08 | 2009-02-20 | Natural gas liquefaction |
| JP2012076611A Withdrawn JP2012189315A (en) | 2001-06-08 | 2012-03-29 | Natural gas liquefaction |
| JP2015102737A Pending JP2015166670A (en) | 2001-06-08 | 2015-05-20 | natural gas liquefaction |
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| JP (4) | JP5041650B2 (en) |
| KR (1) | KR100877029B1 (en) |
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| AR (1) | AR034457A1 (en) |
| AU (1) | AU2008200409B2 (en) |
| BR (1) | BR0210928B1 (en) |
| CA (2) | CA2448884C (en) |
| EA (1) | EA005326B1 (en) |
| HK (1) | HK1071423A1 (en) |
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| NO (1) | NO20035423D0 (en) |
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| SA (1) | SA02230280B1 (en) |
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| UA (1) | UA76750C2 (en) |
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-
2008
- 2008-01-25 AU AU2008200409A patent/AU2008200409B2/en not_active Ceased
-
2009
- 2009-02-20 JP JP2009037799A patent/JP5847371B2/en not_active Expired - Fee Related
-
2012
- 2012-03-29 JP JP2012076611A patent/JP2012189315A/en not_active Withdrawn
-
2015
- 2015-05-20 JP JP2015102737A patent/JP2015166670A/en active Pending
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