EP3612779A1 - Procédé de gnl pour composition de gaz de pipeline variable - Google Patents

Procédé de gnl pour composition de gaz de pipeline variable

Info

Publication number
EP3612779A1
EP3612779A1 EP18787938.2A EP18787938A EP3612779A1 EP 3612779 A1 EP3612779 A1 EP 3612779A1 EP 18787938 A EP18787938 A EP 18787938A EP 3612779 A1 EP3612779 A1 EP 3612779A1
Authority
EP
European Patent Office
Prior art keywords
heavies removal
natural gas
column
demethanizer
distillation column
Prior art date
Legal status (The legal status 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 status listed.)
Pending
Application number
EP18787938.2A
Other languages
German (de)
English (en)
Other versions
EP3612779A4 (fr
Inventor
Attilio J. Praderio
Qi Ma
Wesley R. Qualls
Will T. JAMES
Michael J. Calderon
Paul R. Davies
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
ConocoPhillips Co
Original Assignee
ConocoPhillips Co
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
Application filed by ConocoPhillips Co filed Critical ConocoPhillips Co
Priority claimed from PCT/US2018/027868 external-priority patent/WO2018195013A1/fr
Publication of EP3612779A1 publication Critical patent/EP3612779A1/fr
Publication of EP3612779A4 publication Critical patent/EP3612779A4/fr
Pending legal-status Critical Current

Links

Classifications

    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G5/00—Recovery of liquid hydrocarbon mixtures from gases, e.g. natural gas
    • C10G5/06—Recovery of liquid hydrocarbon mixtures from gases, e.g. natural gas by cooling or compressing
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G70/00—Working-up undefined normally gaseous mixtures obtained by processes covered by groups C10G9/00, C10G11/00, C10G15/00, C10G47/00, C10G51/00
    • C10G70/04—Working-up undefined normally gaseous mixtures obtained by processes covered by groups C10G9/00, C10G11/00, C10G15/00, C10G47/00, C10G51/00 by physical processes
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/10—Feedstock materials
    • C10G2300/1025—Natural gas
    • 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
    • C10L2290/00—Fuel preparation or upgrading, processes or apparatus therefore, comprising specific process steps or apparatus units
    • C10L2290/54—Specific separation steps for separating fractions, components or impurities during preparation or upgrading of a fuel
    • C10L2290/543—Distillation, fractionation or rectification for separating fractions, components or impurities during preparation or upgrading of a fuel
    • 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
    • C10L3/10—Working-up natural gas or synthetic natural gas
    • C10L3/101—Removal of contaminants

Definitions

  • the present invention relates generally to a method and apparatus for processing natural gas.
  • methods and apparatus provide stable processing of liquefied natural gas (LNG) across a highly variable and wide range of feed compositions.
  • LNG liquefied natural gas
  • Liquefied Natural Gas (LNG) liquefaction facilities accept feed gas (e.g., methane, ethane, propane, butane, carbon dioxide, nitrogen, etc.) which is converted into a liquefied form through various treatment processes (e.g., impurities removal, multistage cooling, etc.). These facilities are typically designed to accept feed gas compositions that fall within a specified range. Variability of the feed gas composition that exceeds a facility's capabilities can lead to frequent upsetting of the liquefaction process. This excessive variability may be particularly troublesome when liquefying pipeline feed gas.
  • feed gas e.g., methane, ethane, propane, butane, carbon dioxide, nitrogen, etc.
  • treatment processes e.g., impurities removal, multistage cooling, etc.
  • the present invention relates generally to a method and apparatus for processing natural gas.
  • methods and apparatus provide stable processing of liquefied natural gas (LNG) across a highly variable and wide range of feed compositions.
  • LNG liquefied natural gas
  • the invention more particularly relates to a system, method and apparatus for processing natural gas in an LNG facility.
  • a natural gas feed is introduced into a heavies removal unit, wherein the heavies removal system includes a heavies removal column and a distillation column, wherein the heavies removal column and the distillation column are fluidly connected.
  • One or more components of the natural gas feed is purged from the heavies removal column to a methane recycle stream via the purge/recovery line to obtain a specified concentration or concentration range of heavy components feeding into the distillation column.
  • the invention more particularly relates to a system, method and apparatus for processing natural gas feed during natural gas liquefaction.
  • the natural gas feed is introduced into a heavies removal unit, wherein the heavies removal system includes a heavies removal column and a demethanizer, wherein the heavies removal column and the demethanizer are fluidly connected.
  • the heavies removal column is downstream of the demethanizer.
  • the composition of the natural gas feed is determined before it is introduced into the demethanizer.
  • One or more heavy components of the natural gas feed is purged from the heavies removal column to a methane recycle stream via the purge/recovery line to reduce or increase concentration of heavy components feeding into the demethanizer.
  • FIGS. 1A-1B illustrate sample variability in feed gas composition from pipeline.
  • FIG. 1A shows methane mole % during a 3 week window.
  • FIG. IB shows ethane mole % during the same 3 week window.
  • FIG. 2 illustrates a heavies removal unit in accordance with an embodiment of the present invention.
  • the Optimized Cascade Process may use a heavies removal distillation column (heavies removal unit or HRU) to eliminate C6+ hydrocarbons (i.e. heavy components) from the natural gas prior to condensing the gas to LNG.
  • HRU heavies removal unit
  • C6+ hydrocarbons i.e. heavy components
  • gas has already been amine treated and dehydrated prior to heavies removal.
  • Heavies removal is done to prevent freezing from occurring in the liquefaction heat exchangers and to moderate the heating value of the LNG. It also prevents LNG from going off spec due to increased levels of heavy components.
  • FIGS. 1A-1B illustrate an example of variability in methane and ethane composition of natural gas feed in an LNG liquefaction facility during a 3 week period.
  • a first column (demethanizer) within a Heavies Removal Unit may be used to reflux relatively heavy components originating from downstream column overheads.
  • a first column (demethanizer) within a Heavies Removal Unit may be used to reflux relatively heavy components originating from downstream column overheads.
  • lean methane reflux unit may be used.
  • the lean reflux unit is also less than ideal for used at all times (this unit is typically designed for startup) for all feed gas compositions.
  • Equipment for the lean methane reflux as well as the demethanizer are typically not sized for operation at full feed rates but rather at reduced rates until sufficient heavies are cycled up to create a heavies reflux during startup.
  • the present invention provides a method for purging undesirable components present in a gas feed stream to the methane recycle system where the components can be recovered as valuable product.
  • This purge can be accomplished using a purge/recovery line.
  • the rate of purging from the heavies removal system may be adjusted to absorb the compositional variations of the feed gas. Once the heavier components enter the methane recycle stream, the combined stream becomes easier to condense which conserves refrigeration horsepower.
  • the purge/recovery line makes the overall LNG plant stable and more efficient across a wide range of pipeline compositions with high compositional variability.
  • the present invention provides a method for purging undesirable problematic gas components that would otherwise cycle up to the recycle stream. Instead, the purged gas components can be recovered in the LNG stream without concern of freezing.
  • Flow through the purge/recovery line may be adjusted to fix the flow rate recycle to the high pressure demethanizer feed. Since approximately 50% of the liquid in the bottom portion of the high pressure demethanizer are recycled liquids, this greatly stabilizes the high pressure demethanizer operation.
  • the addition of this purge/recovery line also reduces the cycle up of components that otherwise must be fueled and/or flared.
  • the invention provides very stable operation across a highly variable and wide range of feed compositions with minimal operator intervention.
  • the purged problematic components can be efficiently recovered as LNG.
  • the purged components from the heavies removal unit are routed to a methane recycle stream that is condensed with ethylene refrigeration in the optimized cascade process. The introduction of heavier components within the methane recycle makes condensing with ethylene easier which in turn conserves ethylene turbine horsepower requirements.
  • Adjusting the rate of the purge/recovery line allows one to fix a major portion of the heavy components recycled to the high pressure demethanizer feed, thus greatly helping to stabilize the feed across a wide range of compositions. Fixing the portion of overhead from the second column returned to the system and allowing remaining flow to continuously purge to a system where it can be efficiently recovered as valuable LNG product, provides a means to continuously adjust to variable pipeline compositions with minimal operator intervention.
  • the present invention purge/recover line acts as a compositional shock absorber for variable pipeline gas.
  • the invention eliminates the need to route cycled up pentanes and heavier components to fuel, which is less economical than recovering as product. The pentanes and heavier are also problematic in the fuel gas system.
  • the present invention allows a single set of operating conditions over 80% or more of the pipeline rates, compositional variations, allowing minimal operator intervention.
  • the present invention offers the ability to process a wider range of compositions and higher pipeline compositional variations than other current technology available with minimal operator intervention.
  • natural gas feed is introduced into the heavies removal unit 10 (perforated box) via inlet 20.
  • the natural gas feed is then routed to the heavies removal column 30 within the heavies removal unit 10 where it is then separated into light and heavy components.
  • the light components are routed to a demethanizer 100 via a line 50 that connects a top portion of the heavies removal column 30 to a mid/top portion of the demethanizer 100.
  • the heavy components are routed to the demethanizer 100 via a line 60 that connects a bottom portion of the heavies removal column to a mid/bottom portion of the demethanizer 100.
  • the demethanizer 100 is a distillation column.
  • the top portion 110 of the demethanizer 100 is for heavy reflux at full feed rates (but also works acceptably with lean reflux) and may include a condenser, reflux drum, pump, and the like.
  • the bottom portion of the demethanizer 120 is reboiling and may include a reboiler, steam condensate, and the like. As shown, lean reflux is needed for normal operation of the demethanizer 100.
  • the heavies removal unit is relatively simple and easy to operate. It is able to handle a wide range of feed compositions with minimal operator interaction. The unit is also able to operate with minimal, if any, flaring.

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)
  • Separation By Low-Temperature Treatments (AREA)

Abstract

L'invention concerne un système, un procédé et un appareil de traitement de gaz naturel dans une installation de GNL. Une alimentation en gaz naturel est introduite dans une unité d'élimination de minéraux lourds. Le système d'élimination de minéraux lourds comprend une colonne d'élimination de minéraux lourds et une colonne de distillation. La colonne d'élimination de minéraux lourds et la colonne de distillation sont reliées par l'intermédiaire d'une ligne de purge/récupération. Un ou plusieurs composants de l'alimentation en gaz naturel sont purgés de la colonne d'élimination de minéraux lourds à la colonne de distillation par l'intermédiaire de la ligne de purge/récupération pour obtenir une concentration spécifiée ou une plage de concentration de composants lourds alimentant la colonne de distillation.
EP18787938.2A 2017-04-19 2018-04-17 Procédé de gnl pour composition de gaz de pipeline variable Pending EP3612779A4 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US201762487170P 2017-04-19 2017-04-19
PCT/US2018/027868 WO2018195013A1 (fr) 2017-04-19 2018-04-17 Procédé de gnl pour composition de gaz de pipeline variable

Publications (2)

Publication Number Publication Date
EP3612779A1 true EP3612779A1 (fr) 2020-02-26
EP3612779A4 EP3612779A4 (fr) 2020-04-01

Family

ID=69172176

Family Applications (1)

Application Number Title Priority Date Filing Date
EP18787938.2A Pending EP3612779A4 (fr) 2017-04-19 2018-04-17 Procédé de gnl pour composition de gaz de pipeline variable

Country Status (1)

Country Link
EP (1) EP3612779A4 (fr)

Family Cites Families (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6367286B1 (en) * 2000-11-01 2002-04-09 Black & Veatch Pritchard, Inc. System and process for liquefying high pressure natural gas
EP1695951B1 (fr) * 2003-07-24 2014-08-27 Toyo Engineering Corporation Procede et appareil de separation d'hydrocarbures
CN101815915B (zh) * 2007-08-14 2014-04-09 氟石科技公司 用于改进的天然气液回收的配置和方法

Also Published As

Publication number Publication date
EP3612779A4 (fr) 2020-04-01

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