WO1997036139A1 - Aromatics and/or heavies removal from a methane-based feed by condensation and stripping - Google Patents

Aromatics and/or heavies removal from a methane-based feed by condensation and stripping Download PDF

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Publication number
WO1997036139A1
WO1997036139A1 PCT/US1997/004397 US9704397W WO9736139A1 WO 1997036139 A1 WO1997036139 A1 WO 1997036139A1 US 9704397 W US9704397 W US 9704397W WO 9736139 A1 WO9736139 A1 WO 9736139A1
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WO
WIPO (PCT)
Prior art keywords
stream
signal
ofthe
methane
conduit
Prior art date
Application number
PCT/US1997/004397
Other languages
English (en)
French (fr)
Inventor
Jame Yao
Clarence G. Houser
William R. Low
Barnard J. Devers
Original Assignee
Phillips Petroleum Company
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 US08/621,923 external-priority patent/US5669238A/en
Priority claimed from US08/659,732 external-priority patent/US5737940A/en
Application filed by Phillips Petroleum Company filed Critical Phillips Petroleum Company
Priority to JP53448697A priority Critical patent/JP4612122B2/ja
Priority to EA199800856A priority patent/EA000800B1/ru
Priority to AU23351/97A priority patent/AU707336B2/en
Priority to CA002250123A priority patent/CA2250123C/en
Publication of WO1997036139A1 publication Critical patent/WO1997036139A1/en
Priority to NO984488A priority patent/NO309397B1/no

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    • F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification
    • F25J3/02—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream
    • F25J3/0228—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream characterised by the separated product stream
    • F25J3/0242—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream characterised by the separated product stream separation of CnHm with 3 carbon atoms or more
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    • 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
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    • 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
    • F25J2270/00—Refrigeration techniques used
    • F25J2270/60—Closed external refrigeration cycle with single component refrigerant [SCR], e.g. C1-, C2- or C3-hydrocarbons
    • 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
    • F25J2280/00—Control of the process or apparatus
    • F25J2280/02—Control in general, load changes, different modes ("runs"), measurements
    • 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
    • F25J2280/00—Control of the process or apparatus
    • F25J2280/10—Control for or during start-up and cooling down of the installation
    • 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
    • F25J2290/34—Details about subcooling of liquids

Definitions

  • This invention concerns a method and associated apparatus for removing benzene
  • cryogenic treatment to separate hydrocarbons having a molecular weight higher than methane
  • component streams for example, C 2 , C 3 , C 4 and C $ +.
  • gas is liquefied by sequentially passing the gas at an elevated pressure through a plurality of
  • Cooling is generally accomplished by heat exchange with
  • refrigerants such as propane, propylene, ethane, ethylene, and methane or a
  • each refrigerant is employed in a closed refrigeration cycle.
  • cooling ofthe liquid is possible by expanding the liquefied natural gas to atmospheric pressure in
  • each stage the liquefied gas is flashed to a lower pressure
  • liquid is recovered and may again be flashed. In this manner, the liquefied gas is further cooled
  • the flashed vapors from the expansion stages are generally collected and
  • removal from natural gas may be accomplished by the same type of cooling used in the
  • aromatics from a methane-based gas stream which is to be liquefied in major portion aromatics from a methane-based gas stream which is to be liquefied in major portion.
  • hydrocarbons from a methane-based gas stream hydrocarbons from a methane-based gas stream.
  • a methane-based gas stream be relatively simple, compact and cost-effective. It still further yet is an object of the present invention that the process employed
  • methane-based gas stream to be liquefied in major portion be compatible with and integrate into
  • Yet still further an object of this is invention is to provide heat exchanger controls
  • Another object of this invention is to provide an improved control method which reduces initial equipment temperature requirements, and costs for heat exchange apparatus.
  • a more specific object is to control heat exchanger temperatures to allow cooling
  • a still further object of this invention is to control the heat exchanger to facilitate
  • benzene and/or other aromatics are removed
  • methane-based gas stream immediately prior to the step wherein a majority of said gas stream is
  • aromatic-rich liquid stream (5) contacting via indirect heat exchange the aromatic-rich liquid
  • hydrocarbons in a methane-based gas stream are removed and concentrated by a process
  • phase stream (2) feeding said two-phase stream into the upper section of a stripping column, (3)
  • the invention is an apparatus
  • conduit connected to said heat exchanger for flow of said gas stream to the heat exchanger.
  • the by-pass conduit is manipulated responsive to the temperature ratio ofthe heat exchange
  • automatic start-up controls include a
  • FIGURE 1 is a simplified flow diagram of a cryogenic LNG production process
  • FIGURE 2 is a simplified flow diagram which illustrates in greater detail the
  • FIGURE 3 is a diagrammatic illustration of a cryogenic separation column
  • FIGURE 4 is a diagrammatic illustration similar to FIGURE 3 for temporarily
  • the technology is also applicable to the generic recovery of such species from methane-
  • aromatics present a unique problem because of their relatively high melting point temperatures.
  • benzene which contains 6 carbon atoms possesses a melting point of 5.5 °C and a
  • Aromatic compounds are aromatic compounds
  • higher molecular hydrocarbon species are those hydrocarbon species possessing,
  • process equipment particularly the heat exchangers employed for condensing said stream, or
  • hydrocarbons from a methane-based gas stream hydrocarbons from a methane-based gas stream.
  • Cryogenic plants have a variety of forms; the most efficient and effective being a
  • LNG liquefied natural gas
  • hydrocarbons of molecular weight greater than methane as a first part thereof, a description of a
  • hydrocarbons from a natural gas stream hydrocarbons from a natural gas stream.
  • invention concerns the sequential cooling of a natural gas stream at an elevated pressure, for
  • propane cycle a multistage ethane or ethylene cycle and either (a) a closed methane cycle
  • feed gas as a source of methane and which includes therein a multistage expansion cycle to
  • the refrigerant having the highest boiling point is utilized first followed by a
  • Pretreatment steps provide a means for removing undesirable components such as
  • composition of this gas stream may vary significantly.
  • a natural gas stream As used herein, a natural gas stream may vary significantly.
  • gas stream is any stream principally comprised of methane which originates in major portion
  • pretreatment steps may be separate steps located either upstream ofthe cooling cycles or located
  • This treatment step is generally performed
  • regenerable molecular sieves Processes employing sorbent beds are generally located
  • the resulting natural gas stream is generally delivered to the liquefaction process
  • 500 psia preferably about 500 to about 900 psia, still more preferably about 550 to about
  • the stream temperature is typically near ambient to slightly above ambient.
  • the natural gas stream at this point is cooled in a plurality of
  • refrigerants preferably three.
  • the overall cooling efficiency for a given cycle improves as the
  • the feed gas is preferably passed through
  • an effective number of refrigeration stages nominally two, preferably two to four, and more
  • refrigerant is preferably comprised in major portion of propane, propylene or
  • refrigerant is preferably comprised in major portion of ethane, ethylene or mixtures thereof, more
  • the refrigerant consists essentially of ethylene.
  • each refrigerant comprises a separate cooling zone.
  • the natural gas feed stream will contain such quantities of C 2 +
  • hydrocarbons from the gas to produce a first gas stream predominating in methane and a second
  • gas/liquid separation means are located at strategic locations downstream of the
  • hydrocarbon stream or streams may be demethanized via a single stage flash or a fractionation
  • the methane-rich stream can be repressurized and recycled or can be
  • the methane-rich stream can be directly returned at pressure
  • hydrocarbon stream may be used as fuel or may be further processed such as by fractionation in
  • stream which is predominantly methane is condensed (i.e., liquefied) in major portion, preferably
  • benzene, other aromatics and/or heavier hydrocarbon removal can be employed.
  • the process pressure at this location is only slightly lower than the pressure of the feed gas to the first stage ofthe first cycle.
  • the liquefied natural gas stream is then further cooled in a third step or cycle by
  • the liquefied natural gas stream is further cooled
  • stream is subcooled via passage through an effective number of stages, nominally 2; preferably 2
  • cooling is provided via a third refrigerant having a boiling
  • This refrigerant is preferably
  • liquefied natural gas stream is subcooled via contact with flash gases in a main methane
  • the liquefied gas is further cooled by expansion and
  • the flashed vapor in a closed-cycle system is generally utilized as a fuel.
  • liquefied product is cooled via at least one, preferably two to four, and more preferably three
  • each expansion employs either Joule-Thomson expansion valves or hydraulic expanders followed by a separation ofthe gas-liquid product with a separator.
  • heat exchange means employing said flashed stream to cool the high pressure liquefied stream
  • liquefied stream is generally flashed from process conditions to near-atmospheric pressure in a
  • nitrogen can be any nitrogen concentration in the inlet feed gas.
  • nitrogen concentration in the inlet feed gas is about 1.0 to about 1.5 vol% and an open-cycle is employed, nitrogen can be any nitrogen concentration in the inlet feed gas.
  • the flashed vapor will contain an appreciable concentration of nitrogen and may be subsequently employed as a fuel gas.
  • a typical flash pressure for nitrogen removal at these concentrations is about 400 psia.
  • the flash step may not provide sufficient mtrogen removal. In such event, a nitrogen rejection column will
  • methane stream to the methane economizer is split into a first and second portion.
  • the liquefaction process employs several types of cooling which include but are
  • Indirect heat exchange refers to a process wherein the refrigerant or
  • cooling agent cools the substance to be cooled without actual physical contact between the
  • cooled can vary depending on the demands ofthe system and the type of heat exchanger chosen.
  • refrigerating agent is in a liquid state and the substance to be cooled is in a liquid or gaseous
  • a plate-fin heat exchanger will typically be utilized where the refrigerant is in a
  • the substance to be cooled is liquid or gas and the refrigerant undergoes a phase change from a liquid state to a gaseous state during the heat exchange.
  • Vaporization cooling refers to the cooling of a substance by the evaporation or
  • expansion or pressure reduction cooling refers to cooling which occurs
  • this expansion means is a Joule-Thomson
  • the expansion means is a hydraulic or gas expander.
  • the throttle or expansion valve may not be a
  • the cooling of multiple streams for a given refrigeration stage may occur within a single vessel (i.e., chiller) or within
  • the former is generally preferred from a capital equipment cost perspective.
  • cooling is provided by the compression of a higher
  • boiling point gaseous refrigerant preferably propane
  • heat sink that heat sink generally being the atmosphere, a fresh water source, a salt water source,
  • the main stream is split into at
  • each stream is separately expanded to a designated pressure.
  • Each stream then provides
  • heat transfer means with one or more designated streams, one such stream being the natural gas
  • this embodiment will employ two such expansion cooling/vaporative cooling steps, preferably two to four, and most preferably three.
  • two expansion cooling/vaporative cooling steps preferably two to four, and most preferably three.
  • the refrigerant vapor from each step is returned to the appropriate inlet port at the staged compressor.
  • cascaded cooling This manner of cooling is referred to as "cascaded cooling.”
  • heat energy is pumped from the natural gas stream to be liquefied to a lower
  • refrigerants prior to transfer to the environment via an environmental heat sink (ex., fresh water,
  • the compressed refrigerant vapor is first cooled via indirect heat exchange
  • cooling agents ex., air, salt water, fresh water
  • This cooling may be via inter-stage cooling between compression
  • the second cycle refrigerant preferably ethylene, is preferably first cooled via
  • preferred second and first cycle refrigerants are ethylene and propane, respectively.
  • cooling stages in the first and second cooling cycles which preferably employ propane and
  • this stream is contacted in a sequential manner
  • the first and second cycles are operated in a manner analogous to that set forth for the closed
  • Each vapor stream preferably undergoes significant heat transfer in methane
  • cooling is such that for each stage, the volume of gas generated plus the compressed volume of vapor from the adjacent lower stage results in efficient overall operation of the multi-staged
  • the cooled methane-rich stream is further
  • portion is liquefied (i.e., ethylene condenser).
  • steps are taken to further optimize process
  • economizers are preferably employed to obtain additional cooling from the flashed vapors in the second and third cycles.
  • steps comprise the previously discussed third stage of cooling and will be discussed in greater
  • the contacting can be performed via a series of ethylene
  • stripping column referred to herein as a stripping column performs both stripping and fractionating
  • the process comprises cooling the methane-based gas stream such that 0.1 to 20
  • mol% preferably 0.5 to about 10 mol%, and more preferably about 1.75 to about 6.0 mol% of the total gas stream is condensed thereby forming a two-phase stream.
  • the desired two-phase stream is obtained by cooling the entire
  • the gas stream is first cooled to near the liquefaction temperature and is then split
  • the first stream undergoes additional cooling and partial
  • the two-phase stream is then fed to the upper section of a column wherein the
  • a heavies-rich liquid stream which functions as a reflux stream and a heavies-depleted vapor
  • a methane-rich stripping gas stream is fed to the column.
  • This stream preferably originates from an upstream location where the methane-based gas stream
  • this gas stream is cooled via indirect contact, preferably
  • the methane-rich stripping gas may undergo partial condensation upon cooling and the resulting
  • cooled methane-rich stripping gas containing two phases may be fed directly to the column.
  • the critical temperature and pressure of methane is -116.4°F and 673.3
  • the critical temperature and pressure of propane is 206.2 °F and 617.4 psia and the critical
  • the cooled methane-rich stripping gas be warmer
  • this preferred stream possesses a greater ability to strip
  • composition, temperature, flowrate and liquid to vapor ratio ofthe two-phase stream fed to the upper section ofthe column Such determination is readily within the abilities of one possessing
  • diameter is greater than six (6) ft.
  • FIGURES 1 and 2 The flow schematic and apparatus set forth in FIGURES 1 and 2 is a preferred
  • FIGURES 1-4 are
  • controllers additional temperature and pressure controls, pumps, motors, filters, additional heat exchangers, valves, etc. These items would be provided in accordance with standard engineering
  • conduits which contain the refrigerant ethylene or optionally, ethane. Items numbered 300 thru
  • FIGURE 1 the numbering system employed in FIGURE 1 has been employed in FIGURES 2, 3,
  • FIGURE 1 Items numbered 400 thru 499 correspond to additional flow lines or
  • numbered 600 thru 799 generally concern the process control system, exclusive of control
  • valves and specifically includes sensors, transducers, controllers and setpoint inputs.
  • FIGURES 1 through 4 lines designated as signal lines are depicted as dash
  • the signals provided from any transducer are electric in form. However, the signals provided
  • gaseous propane is compressed in multistage compressor
  • each stage of compression may be a separate unit and
  • the units mechanically coupled to be driven by a single driver Upon compression, the
  • compressed propane is passed through conduit 300 to cooler 20 where it is liquefied.
  • separation vessel be located downstream of cooler 20 and upstream of a pressure reduction
  • Such vessels may be comprised of a single-stage gas-liquid separator or may
  • absorber section the latter two of which may be continuously operated or periodically brought
  • conduit 302 to a pressure
  • expansion valve 12 wherein the pressure ofthe liquefied propane
  • conduit 304 then flows through conduit 304 into high-stage propane chiller 2 wherein gaseous methane
  • ethylene refrigerant introduced via conduit 202 are respectively cooled via indirect heat exchange
  • the gas in conduit 154 is fed to main methane economizer 74 which will be discussed in greater detail in a subsequent section and wherein the stream is cooled via indirect
  • conduit 158 is then combined with the heavies depleted vapor stream in conduit 120 from the
  • the propane gas from chiller 2 is returned to compressor 18 through conduit 306.
  • conduit 308 the pressure further reduced by passage through a pressure reduction
  • expansion valve 14 means, illustrated as expansion valve 14 , whereupon an additional portion ofthe liquefied
  • the cooled feed gas stream from chiller 2 flows via
  • conduit 102 to a knock-out vessel 10 wherein gas and liquid phases are separated.
  • conduit 104 removed via conduit 104 and then split into two separate streams which are conveyed via
  • conduits 106 and 108 The stream in conduit 106 is fed to propane chiller 22.
  • the stream in conduit 106 is fed to propane chiller 22.
  • conduit 108 becomes the feed to heat exchanger 62 and is ultimately the stripping gas to the
  • heavies removal column 60 Ethylene refrigerant from chiller 2 is introduced to chiller 22 via
  • the feed gas stream also referred to herein as a methane-rich stream
  • chiller 22 is removed via conduit 314, flashed across a pressure reduction means, illustrated as
  • refrigerant stream flows from the intermediate-stage propane chiller 22 to the low-stage propane
  • FIGURE 1 illustrates cooling of streams provided
  • conduits 110 and 206 to occur in the same vessel, the chilling of stream 110 and the cooling
  • cooling steps wherein multiple streams were cooled in a common vessel may be
  • the former arrangement is a preferred embodiment because ofthe
  • refrigerant exits the low-stage propane chiller 28 via conduit 208 and is preferably fed to a
  • ethylene is removed via conduit 210.
  • the separation vessel is analogous to the vessel earlier
  • single-stage gas-liquid separator or may be a multiple stage operation which provides greater
  • ethylene refrigerant via conduit 210 then flows to the ethylene economizer 34
  • refrigerant is flashed to a preselected temperature and pressure and fed to the high-stage ethylene
  • ethylene economizer 34 wherein the vapor functions as a coolant via indirect heat exchange means 46.
  • the ethylene vapor is then removed from the ethylene economizer via conduit 216
  • expansion valve 52 whereupon the resulting two-phase product is introduced into
  • conduit 118 to the benzene/aromatics/heavies removal column 60.
  • methane-rich stream in conduit 104 was split so as to flow via conduits 106 and 108.
  • conduit 108 which is referred to herein as the methane-rich stripping gas is first fed to
  • conduit 117 the stream delivered by conduit 117 provides cooling capabilities via indirect heat exchange
  • the stream in conduit 119 is rich in benzene, other aromatics and/or other heavier
  • This stream is subsequently separated into liquid and vapor portions
  • conduit 123 is produced via conduit 123 and a
  • stage condenser is produced via conduit 122.
  • conduit 234 low-stage side is removed via conduit 234, cooled via inter-stage cooler 71 and returned to
  • conduit 236 for injection with the high-stage stream present in conduit 216.
  • the two-stages are a single module although they may each be a separate module and
  • the compressor is routed to a downstream cooler 72 via conduit 200.
  • cooler flows via conduit 202 and is introduced, as previously discussed, to the high-stage
  • the liquefied stream in conduit 122 is generally at a temperature of about -125°F
  • conduit 124 and its pressure is reduced by a pressure reduction means which is illustrated as
  • expansion valve 78 which of course evaporates or flashes a portion ofthe gas stream.
  • the flashed stream is then passed to methane high-stage flash drum 80 where it is separated into a gas
  • conduit 128 where it is combined with the gas stream delivered by conduit 121.
  • the liquid phase in conduit 130 is passed through a second methane economizer
  • the cooled liquid exits the second methane economizer 87 via conduit 132 and is
  • expansion valve 91 expanded or flashed via pressure reduction means illustrated as expansion valve 91 to further
  • a pressure reduction means illustrated as a
  • conduit 146 which is connected to the first methane economizer
  • conduit 148 which is connected to the low pressure port
  • the liquefied natural gas product from flash drum 94 which is at approximately
  • conduits 144, 146, or 148 either conduits 144, 146, or 148; the selected conduit being based on a desire to match vapor
  • each stage may exist as a separate unit where
  • the units are mechanically coupled together to be driven by a single driver.
  • compressed gas from the intermediate stage of compressor 83 is passed through an inter-stage
  • cooler 84 and is combined with the high pressure gas in conduit 140 prior to the third-stage of
  • the compressed gas is discharged from the high-stage methane compressor
  • conduit 150 is cooled in cooler 86 and is routed to the high pressure propane chiller via
  • FIGURE 1 depicts the expansion of the liquefied phase using expansion valves
  • expansion valve and separate flash drum might be employed prior to the flow of either the
  • FIGURE 1 With regard to the compressor/driver units employed in the process, FIGURE 1
  • compression train comprising two or more compressor/driver combinations in parallel in lieu of
  • FIGURE 2 Presented in FIGURE 2 is a preferred embodiment ofthe benzene, other aromatic
  • phase stream is obtained by cooling and partially condensing a portion ofthe stream in conduit
  • the stream delivered via conduit 116 is split into a first
  • conduit 532 flows through an optional valve 532, preferably a hand control valve, to conduit 454
  • second stream in conduit 452 flows through a valve 530, preferably a control valve, into conduit
  • conduit 118 should be sufficient to insure adequate mixing
  • two-phase stream in conduit 118 is preferably controlled via maintaining the streams at a desired
  • thermocouple situated in conduit 118
  • the controller 682 responds
  • conduit 116 which is situated in a conduit wherein flows the portion ofthe stream delivered via conduit 116
  • the transmitted signal 680 is scaled to be representative of the position ofthe control valve 530 required to
  • chiller 54 delivered via conduit 118 to the upper section of column 60 and the methane-rich
  • stripper gas delivered via conduit 108 Although depicted in FIGURE 1 as originating from the
  • this stream can originate from any one of the feed gas stream from the first stage of propane cooling, this stream can originate from any one of the feed gas stream from the first stage of propane cooling, this stream can originate from any one of the feed gas stream from the first stage of propane cooling, this stream can originate from any one of the feed gas stream from the first stage of propane cooling, this stream can originate from any one of the feed gas stream from the first stage of propane cooling, this stream can originate from any one of the feed gas stream from the first stage of propane cooling, this stream can originate from any one of the feed gas stream from the first stage of propane cooling
  • Effluent streams from this inventive process step are the heavies-depleted gas stream from column 60 produced via
  • conduit 120 and the warmed heavies-rich stream produced via conduit 119. As illustrated in
  • FIGURE 2 a heavy-rich stream is produced from column 60 and undergoes warming in heat
  • conduit 114 cools the stripping gas fed to the column via conduit 109.
  • composition ofthe feedstreams to the column Generally, two (2) to fifteen (15) theoretical
  • stages will be required.
  • the preferred number of stages is three (3) to ten (10), still more
  • the upper section of column wherein the two-phase stream in conduit 1 18 is fed is designed to facilitate gas/liquid separation.
  • This means is to be located between the point of entry of conduit 118 and the point of exit of
  • conduit 119 as a warmed heavies-rich stream.
  • cooling ability of this stream can be enhanced by flashing to a lower
  • the stream is fed to a demethanizer 67.
  • the flowrate of heavies-rich liquid from column 60 may be controlled via various
  • FIGURE 2 is a preferred apparatus and is comprised of a level controller device 600, also a
  • the controller 600 establishes an output signal 602 that either
  • transducer 604 operably located in conduit 114 establishes an output signal 606 that typifies the
  • the flow measurement device is preferably located
  • Signal 602 is provided
  • Signal 614 is provided to control valve 97 and valve 97
  • a setpoint signal (not illustrated) representative of a
  • level controller 600 may be manually inputted to level controller 600 by an operator or in
  • the controller 608 provides an output signal 614 which is responsive
  • This signal is scaled so as to the difference between the respective input and setpoint signals.
  • stripping gas stream is routed to the heat exchanger via conduit 117.
  • the entire methane-rich stripping gas stream is fed to the entire methane-rich stripping gas stream.
  • the heat exchanger and the degree of cooling controlled by such parameters controlled by such parameters as the amount of
  • conduit 108 flows through control valve 500 into conduit 400 whereupon the stream is split and transferred via conduits 402 and 403.
  • the stream flowing through conduit 403 ultimately
  • FIGURE 2 The means illustrated in FIGURE 2 are simple hand control valves, designated 502 and
  • heavies-bearing stream may be substituted for one or both ofthe hand control valves.
  • valves are operated such that the temperature approach difference ofthe streams in
  • conduits 117 and 404 to heat exchanger 62 does not exceed 50 °F whereupon damage to the heat
  • conduit 407 thereby forming the cooled methane-rich stripping gas stream which is delivered to
  • conduit 109 Operably located in conduit 109 is a flow transducing device 616 which in
  • a process variable input to a flow controller 620 is provided as a process variable input to a flow controller 620. Also provided either manually or
  • controller then provides an output signal 624 which is responsive to the difference between the
  • thermocouple operably located in conduit 117
  • calculator 700 is also provided with a second temperature signal 706 representative ofthe
  • thermocouple 702 whose output signal 706 is responsive to a sensing element such as a thermocouple operably
  • ratio calculator 700 In response to signals 706 and 708 ratio calculator 700 provides an
  • Ratio controller 712 is also provided with a set point
  • ratio controller 712 Responsive to signals 710 and 714, ratio controller 712 provides an
  • control valve 534 which is operably located in by-pass conduit 718, required to maintain the desired ratio represented by set point signal 714.
  • Control valve 534 is manipulated responsive to signal 716.
  • temperature controller 722 is desirably set at a temperature compatible with the liquid in
  • valve 536 to close and not allow flow ofthe warm dry gas to a cryogenic separation column 60
  • temperature controller 722 Responsive to signals 706 and 724 temperature controller 722 provides an output
  • Signal 726 responsive to the difference between signals 706 and 724.
  • Signal 726 is scaled to be
  • control valve 536 which is operably located in conduit 108
  • Signal selector 728 is also provided with a control signal 742
  • conduit 119 in conduit 119 substantially equal to the desired temperature represented by signal 740.
  • Level controller 600 senses the level and its output opens valve 97 responsive to
  • valve 536 is initially opened by
  • the start-up controls assist the operator in providing a smooth safe start-up and reduce the
  • the warmed heavies-rich liquid stream from heat exchanger 62 is fed via conduit
  • rectifying and stripping sections may contain distinct stages (e.g., trays, plates) or may provide
  • column packing eg., saddles, racking rings, woven wire
  • a column packing e.g., saddles, racking rings, woven wire
  • packing is preferred for columns possessing a diameter
  • the stripping or lower section contains 4 to 20 theoretical stages, more
  • the upper or rectifying section ofthe column preferably contains 4 to 20 theoretical stages, more preferably 8 to 13 theoretical stages, and most preferably about 10 theoretical
  • a conventional reboiler 524 is provided at the bottom to provide stripping vapor.
  • demethanizer is provided to the reboiler via conduit 428 wherein said fluid is heated via an
  • indirect heat transfer means 525 with a heating medium delivered via conduit 440 and returned
  • conduit 442 which is connected to flow control valve 526 which is in turn connected to
  • conduit 444 Vapor from the reboiler is returned to the demethanizer column via conduit 430
  • conduit 432 may
  • conduit 436 optionally be combined in conduit 436 with a second liquids stream produced from the bottom of
  • a means for controlling liquid flow is inserted into one or
  • control valve 522 which is inserted between conduits 438 and 123.
  • control valve 522 is manipulated by a flow controller 632 which is responsive to
  • controller 626 may be provided via operator or computer algorithm input. Output from the
  • controller 632 is signal 634 which is scaled to be representative of the position ofthe control
  • valve 522 required to maintain the desired flowrate in conduit 438 to maintain the desired level in 67.
  • thermocouple situated in conduit 430 provides an input signal 638 to a thermocouple
  • the controller 642 responds to the differences in the two
  • conduits 440 or 444 containing the heating medium, preferably conduits 440 or 444, most preferably conduit 444 as
  • the transmitted signal 644 is scaled to be representative of the position ofthe control valve 526 required to maintain the flowrate necessary to obtain the desired temperature in
  • a novel aspect ofthe demethanizer column is the manner in which reflux liquids
  • conduit 410 whereupon at least a portion of said stream is partially condensed upon
  • the heavies-rich liquid product from the heavies removal column 60 is heavies-rich liquid product from the heavies removal column 60.
  • heavies-rich liquid product is first employed for cooling of at least a portion ofthe overhead
  • designated streams occurs in a countercurrent manner. In one embodiment, the entire stream
  • the overhead vapor product in conduit 410 is split into streams flowing in conduits 412 and 414.
  • the stream in conduit 414 is cooled in heat exchanger 62 by flowing said stream through indirect
  • conduit 418 The relative flowrates ofthe vapor streams in conduits 412 and 414 or 418 are
  • a flow control means preferably a flow control valve through which overhead
  • vapor may flow without flowing through the heat exchanger thereby avoiding the control ofa
  • Vapor flowing in conduit 412 flows through flow control means 512 and is
  • conduit 416 Conduits 416 and 418 are then joined thereby resulting in a combined cooled two-phase stream which flows through conduit 420. Situated in conduit 420 is
  • a temperature transducing device 646 in combination with a temperature sensing device
  • thermocouple preferably a thermocouple, provides a signal 648 representative of the actual temperature ofthe
  • a desired temperature 650 is also
  • controller 652 inputted to the controller 652 either manually or via a computational algorithm. Based on a
  • the preceding methodology is employed but the heavies-rich stream in
  • conduit 1 17 is first employed for cooling ofthe stream delivered via conduit 414 prior to cooling
  • conduit 121 can be returned to the open methane cycle for subsequent liquefaction.
  • pressure ofthe demethanizer and associated equipment is controlled by automatically manipulating control valve 518 responsive to a pressure transducer device 656 operably located
  • control valve is connected on the inlet side to conduit 422 and on the outlet
  • conduit 121 which preferably is directly or indirectly connected to the low pressure inlet
  • a sensing device provides a signal 658 to a pressure controller 660 which is representative ofthe
  • a set point pressure signal 662 is also provided as input to the
  • the controller then generates a response signal 664 representative of the
  • valve 664 is scaled in such a manner as to activate the valve 518 according for approach and
  • the pressure sensing transducer 656 are embodied in a single device commonly called
  • the flowrate of reflux is controlled via input from a level control device 666 which
  • Controller is responsive to a sensing device located in the lower section ofthe separator 514.
  • signal 668 is provided as a setpoint input to flow controller 670 to
  • control valve 519 which is representative ofthe difference in signals and scaled to provide for appropriate liquids flow through the flow control valve 519
  • control such as proportional, proportional-integral, or proportional-integral-derivative (PID).
  • PID proportional-integral-derivative
  • FIGURE 4 depicted in FIGURE 4 for calculating the required control signals based on measured process
  • FIGURES 2, 3, and 4 can utilize the various modes of control such as proportional, proportional-
  • the output of a controller can be scaled to represent any desired factor
  • the controller output might be a signal representative of a flow rate ofa
  • control gas necessary to make the desired and actual temperatures equal.
  • controller output can range from 0-10 units, then the controller
  • output signal could be scaled so that an output having a level of 5 units corresponds to 50%
  • the transducing means used to measure parameters which characterize a process in the various signals generated thereby may
  • control elements of this system can be
  • Selective control loops are used in a variety of process situations for selecting an
  • control signal that has a higher priority in the event of certain process conditions. For example,

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  • Engineering & Computer Science (AREA)
  • Physics & Mathematics (AREA)
  • Mechanical Engineering (AREA)
  • Thermal Sciences (AREA)
  • General Engineering & Computer Science (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Chemical & Material Sciences (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
  • Separation By Low-Temperature Treatments (AREA)
  • Organic Low-Molecular-Weight Compounds And Preparation Thereof (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
  • Treating Waste Gases (AREA)
PCT/US1997/004397 1996-03-26 1997-03-19 Aromatics and/or heavies removal from a methane-based feed by condensation and stripping WO1997036139A1 (en)

Priority Applications (5)

Application Number Priority Date Filing Date Title
JP53448697A JP4612122B2 (ja) 1996-03-26 1997-03-19 凝縮及びストリッピングによるメタンを主とした供給物からの芳香族及び（又は）重質物の除去
EA199800856A EA000800B1 (ru) 1996-03-26 1997-03-19 Способ извлечения конденсацией и отгонкой ароматических и/или высокомолекулярных углеводородов из сырья на основе метана и устройство для его осуществления
AU23351/97A AU707336B2 (en) 1996-03-26 1997-03-19 Aromatics and/or heavies removal from a methane-based feed by condensation and stripping
CA002250123A CA2250123C (en) 1996-03-26 1997-03-19 Aromatics and/or heavies removal from a methane-based feed by condensation and stripping
NO984488A NO309397B1 (no) 1996-03-26 1998-09-25 Fremgangsmåter for fjerning av aromatiske og/eller tyngre hydrokarbonkomponenter fra en metanbasert gasström ved kondensasjon og stripping, samt apparat for utförelse av samme

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
US08/621,923 US5669238A (en) 1996-03-26 1996-03-26 Heat exchanger controls for low temperature fluids
US08/621,923 1996-03-26
US08/659,732 US5737940A (en) 1996-06-07 1996-06-07 Aromatics and/or heavies removal from a methane-based feed by condensation and stripping
US08/659,732 1996-06-07

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AR (1) AR006440A1 (ko)
AU (1) AU707336B2 (ko)
CA (1) CA2250123C (ko)
CO (1) CO5090917A1 (ko)
EA (1) EA000800B1 (ko)
ID (1) ID17331A (ko)
IN (1) IN191375B (ko)
MY (1) MY123833A (ko)
NO (1) NO309397B1 (ko)
OA (1) OA11014A (ko)
SA (1) SA97180452B1 (ko)
TR (1) TR199801906T2 (ko)
TW (1) TW426665B (ko)
WO (1) WO1997036139A1 (ko)

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WO2007045364A2 (de) * 2005-10-20 2007-04-26 Linde Aktiengesellschaft Rückgewinnungssystem für die weiterverarbeitung eines spaltqasstroms einer ethylenanlage
US8127938B2 (en) 2009-03-31 2012-03-06 Uop Llc Apparatus and process for treating a hydrocarbon stream
CN102893108A (zh) * 2009-09-30 2013-01-23 国际壳牌研究有限公司 分馏烃流的方法及其设备
US9920985B2 (en) 2011-08-10 2018-03-20 Conocophillips Company Liquefied natural gas plant with ethylene independent heavies recovery system
WO2020047056A1 (en) * 2018-08-31 2020-03-05 Uop Llc Gas subcooled process conversion to recycle split vapor
WO2021067562A3 (en) * 2019-10-02 2021-06-24 Saudi Arabian Oil Company Natural gas liquids recovery process
US11402155B2 (en) 2016-09-06 2022-08-02 Lummus Technology Inc. Pretreatment of natural gas prior to liquefaction
CN115317947A (zh) * 2022-08-30 2022-11-11 山东神驰石化有限公司 一种丙烯生产用高效精馏塔
US11905480B1 (en) 2022-10-20 2024-02-20 Saudi Arabian Oil Company Enhancing H2S specification in NGL products

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US7484385B2 (en) 2003-01-16 2009-02-03 Lummus Technology Inc. Multiple reflux stream hydrocarbon recovery process
US6742357B1 (en) * 2003-03-18 2004-06-01 Air Products And Chemicals, Inc. Integrated multiple-loop refrigeration process for gas liquefaction
CN100565061C (zh) * 2003-10-30 2009-12-02 弗劳尔科技公司 柔性液态天然气工艺和方法
US7866184B2 (en) 2004-06-16 2011-01-11 Conocophillips Company Semi-closed loop LNG process
US20070012072A1 (en) * 2005-07-12 2007-01-18 Wesley Qualls Lng facility with integrated ngl extraction technology for enhanced ngl recovery and product flexibility
KR102367522B1 (ko) * 2014-03-14 2022-02-25 루머스 테크놀로지 엘엘씨 액화 전 희박 천연 가스로부터의 중질 탄화수소 제거를 위한 공정 및 장비
DE102015002164A1 (de) * 2015-02-19 2016-08-25 Linde Aktiengesellschaft Verfahren zum Verflüssigen von Erdgas
KR102291922B1 (ko) * 2015-04-28 2021-08-20 대우조선해양 주식회사 천연가스를 이용하여 중질탄화수소를 생산하는 ｆｌｎｇ 및 ｆｌｎｇ에서 천연가스를 이용하여 중질탄화수소를 생산하는 방법

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US3413816A (en) * 1966-09-07 1968-12-03 Phillips Petroleum Co Liquefaction of natural gas
US4142876A (en) * 1975-05-22 1979-03-06 Phillips Petroleum Company Recovery of natural gas liquids by partial condensation
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* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2007045364A2 (de) * 2005-10-20 2007-04-26 Linde Aktiengesellschaft Rückgewinnungssystem für die weiterverarbeitung eines spaltqasstroms einer ethylenanlage
WO2007045364A3 (de) * 2005-10-20 2007-06-07 Linde Ag Rückgewinnungssystem für die weiterverarbeitung eines spaltqasstroms einer ethylenanlage
US8127938B2 (en) 2009-03-31 2012-03-06 Uop Llc Apparatus and process for treating a hydrocarbon stream
CN102893108A (zh) * 2009-09-30 2013-01-23 国际壳牌研究有限公司 分馏烃流的方法及其设备
CN102893108B (zh) * 2009-09-30 2014-12-24 国际壳牌研究有限公司 分馏烃流的方法及其设备
US9920985B2 (en) 2011-08-10 2018-03-20 Conocophillips Company Liquefied natural gas plant with ethylene independent heavies recovery system
US11402155B2 (en) 2016-09-06 2022-08-02 Lummus Technology Inc. Pretreatment of natural gas prior to liquefaction
WO2020047056A1 (en) * 2018-08-31 2020-03-05 Uop Llc Gas subcooled process conversion to recycle split vapor
US11473837B2 (en) 2018-08-31 2022-10-18 Uop Llc Gas subcooled process conversion to recycle split vapor for recovery of ethane and propane
WO2021067562A3 (en) * 2019-10-02 2021-06-24 Saudi Arabian Oil Company Natural gas liquids recovery process
US11326116B2 (en) 2019-10-02 2022-05-10 Saudi Arabian Oil Company Natural gas liquids recovery process
CN115317947A (zh) * 2022-08-30 2022-11-11 山东神驰石化有限公司 一种丙烯生产用高效精馏塔
CN115317947B (zh) * 2022-08-30 2023-08-11 山东神驰石化有限公司 一种丙烯生产用高效精馏塔
US11905480B1 (en) 2022-10-20 2024-02-20 Saudi Arabian Oil Company Enhancing H2S specification in NGL products

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CA2250123C (en) 2004-01-27
TW426665B (en) 2001-03-21
OA11014A (en) 2003-03-06
CA2250123A1 (en) 1997-10-02
JP2000512724A (ja) 2000-09-26
JP4612122B2 (ja) 2011-01-12
SA97180452B1 (ar) 2006-10-30
TR199801906T2 (xx) 1999-01-18
AU2335197A (en) 1997-10-17
AR006440A1 (es) 1999-08-25
IN191375B (ko) 2003-11-29
CO5090917A1 (es) 2001-10-30
ID17331A (id) 1997-12-18
MY123833A (en) 2006-06-30
NO984488D0 (no) 1998-09-25
EA199800856A1 (ru) 1999-04-29
EA000800B1 (ru) 2000-04-24
NO309397B1 (no) 2001-01-22
NO984488L (no) 1998-11-26
AU707336B2 (en) 1999-07-08

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