WO2016153334A1 - An integrated system and process for gas recovery in the lng plant - Google Patents

An integrated system and process for gas recovery in the lng plant Download PDF

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Publication number
WO2016153334A1
WO2016153334A1 PCT/MY2016/000014 MY2016000014W WO2016153334A1 WO 2016153334 A1 WO2016153334 A1 WO 2016153334A1 MY 2016000014 W MY2016000014 W MY 2016000014W WO 2016153334 A1 WO2016153334 A1 WO 2016153334A1
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WO
WIPO (PCT)
Prior art keywords
lng
integrated
gas recovery
recovery system
gas
Prior art date
Application number
PCT/MY2016/000014
Other languages
French (fr)
Other versions
WO2016153334A8 (en
Inventor
Amir Hamzah B GHAZALI
M Fadzrul B AHMAD
Wan Ahmad Akram B WAN YAHYA
Amiran B ABDULLAH
Torn NAKAYAMA
Takashi Noda
Original Assignee
Petroliam Nasional Berhad (Petronas)
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Publication date
Application filed by Petroliam Nasional Berhad (Petronas) filed Critical Petroliam Nasional Berhad (Petronas)
Priority to KR1020177030695A priority Critical patent/KR102505938B1/en
Priority to JP2017550109A priority patent/JP7053266B2/en
Publication of WO2016153334A1 publication Critical patent/WO2016153334A1/en
Publication of WO2016153334A8 publication Critical patent/WO2016153334A8/en

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    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/0002—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the fluid to be liquefied
    • F25J1/0022—Hydrocarbons, e.g. natural gas
    • F25J1/0025—Boil-off gases "BOG" from storages
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/0002—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the fluid to be liquefied
    • F25J1/0022—Hydrocarbons, e.g. natural gas
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/02—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen ; Details and kind of the refrigeration system used; Integration with other units or processes; Controlling aspects of the process
    • F25J1/0243—Start-up or control of the process; Details of the apparatus used; Details of the refrigerant compression system used
    • F25J1/0257—Construction and layout of liquefaction equipments, e.g. valves, machines
    • F25J1/0275—Construction and layout of liquefaction equipments, e.g. valves, machines adapted for special use of the liquefaction unit, e.g. portable or transportable devices
    • F25J1/0277—Offshore use, e.g. during shipping
    • F25J1/0278—Unit being stationary, e.g. on floating barge or fixed platform
    • 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
    • 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
    • F25J3/0204—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 feed stream
    • F25J3/0209—Natural gas or substitute natural gas
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • 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
    • F25J3/0233—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 1 carbon atom or more
    • 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
    • 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
    • F25J3/0257—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 nitrogen
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2221/00—Handled fluid, in particular type of fluid
    • F17C2221/03—Mixtures
    • F17C2221/032—Hydrocarbons
    • F17C2221/033—Methane, e.g. natural gas, CNG, LNG, GNL, GNC, PLNG
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2223/00—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel
    • F17C2223/01—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel characterised by the phase
    • F17C2223/0146—Two-phase
    • F17C2223/0153—Liquefied gas, e.g. LPG, GPL
    • F17C2223/0161—Liquefied gas, e.g. LPG, GPL cryogenic, e.g. LNG, GNL, PLNG
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2265/00—Effects achieved by gas storage or gas handling
    • F17C2265/03—Treating the boil-off
    • F17C2265/032—Treating the boil-off by recovery
    • F17C2265/033—Treating the boil-off by recovery with cooling
    • F17C2265/034—Treating the boil-off by recovery with cooling with condensing the gas phase
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2270/00—Applications
    • F17C2270/01—Applications for fluid transport or storage
    • F17C2270/0102—Applications for fluid transport or storage on or in the water
    • F17C2270/0105—Ships
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2270/00—Applications
    • F17C2270/01—Applications for fluid transport or storage
    • F17C2270/0102—Applications for fluid transport or storage on or in the water
    • F17C2270/011—Barges
    • F17C2270/0113—Barges floating
    • 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
    • F25J2200/00—Processes or apparatus using separation by rectification
    • F25J2200/02—Processes or apparatus using separation by rectification in a single pressure main column system
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2200/00—Processes or apparatus using separation by rectification
    • F25J2200/40—Features relating to the provision of boil-up in the bottom of a column
    • 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
    • F25J2200/00—Processes or apparatus using separation by rectification
    • F25J2200/70—Refluxing the column with a condensed part of the feed stream, i.e. fractionator top is stripped or self-rectified
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2205/00—Processes or apparatus using other separation and/or other processing means
    • F25J2205/30—Processes or apparatus using other separation and/or other processing means using a washing, e.g. "scrubbing" or bubble column for purification purposes
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2205/00—Processes or apparatus using other separation and/or other processing means
    • F25J2205/60—Processes or apparatus using other separation and/or other processing means using adsorption on solid adsorbents, e.g. by temperature-swing adsorption [TSA] at the hot or cold end
    • F25J2205/66—Regenerating the adsorption vessel, e.g. kind of reactivation gas
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2210/00—Processes characterised by the type or other details of the feed stream
    • F25J2210/62—Liquefied natural gas [LNG]; Natural gas liquids [NGL]; Liquefied petroleum gas [LPG]
    • 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
    • F25J2215/00—Processes characterised by the type or other details of the product stream
    • F25J2215/04—Recovery of liquid products
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2220/00—Processes or apparatus involving steps for the removal of impurities
    • F25J2220/60—Separating impurities from natural gas, e.g. mercury, cyclic hydrocarbons
    • F25J2220/64—Separating heavy hydrocarbons, e.g. NGL, LPG, C4+ hydrocarbons or heavy condensates in general
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2230/00—Processes or apparatus involving steps for increasing the pressure of gaseous process streams
    • F25J2230/32—Compression of the product stream
    • 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
    • F25J2245/00—Processes or apparatus involving steps for recycling of process streams
    • F25J2245/02—Recycle of a stream in general, e.g. a by-pass stream
    • 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
    • F25J2245/00—Processes or apparatus involving steps for recycling of process streams
    • F25J2245/90—Processes or apparatus involving steps for recycling of process streams the recycled stream being boil-off gas from storage
    • 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

Definitions

  • This invention relates to an integrated system and process for gas management and recovery. It is in particular, though not exclusively, useful for Boil Off Gas (BOG) recovery in LNG plants.
  • BOG Boil Off Gas
  • Liquefied Natural Gas is the liquid form of natural gas at cryogenic temperature of -160°C. When natural gas is turned into LNG, its volume is reduced. This reduction in volume enables natural gas to be transported economically over long distance.
  • An end-flash unit 35 may be installed downstream of the liquefaction unit 30 for reducing the pressure of the LNG before it is being stored in LNG tanks 55. Further, the end-flash unit 35 has an added advantage of increasing the LNG throughput of the LNG plant 5.
  • the end-flash unit 35 offers expansion cooling to the LNG stream to a desired temperature and allows a warmer LNG stream to escape the liquefaction unit. To this end, the end-flash unit 35 improves heat transfer and reduces the cooling load of the heat exchanger (not shown), which forms part of the end-flash unit 35. As a result, more natural gas is condensed in the heat exchanger which then exits the end-flash unit 35 as primarily sales LNG 45.
  • BOG Boil-Off Gas
  • BOG 60 is routed through a BOG knock-out drum 65 where some BOG is re-liquefied and returned 75 to LNG storage tanks 55, thus recycling and recovering valuable LNG which would otherwise be lost as excess BOG is flared and removed to maintain safe pressure levels.
  • the BOG that remains as vapor is then compressed by a BOG compressor 70 and exported as natural gas 85.
  • An LNG quench line 62 may be included upstream of the BOG knock-out drum 65 for heat exchange.
  • Figure 2b shows the configuration of the BOG knock-out drum 65 and BOG compressor 70 in greater detail.
  • the invention provides an integrated gas recovery system in an LNG plant comprising: a first inlet for receiving LNG; and a second inlet for receiving boil-off gas, wherein the system is configured to separate natural gas and LNG in the first and second inlets to produce a first outlet of gas stream and a second outlet of LNG.
  • the invention provides a process for gas recovery in an LNG plant by means of an integrated system comprising the steps of: receiving LNG from a first inlet; receiving boil-off gas from a second inlet; and separating natural gas and LNG in the first and second inlets to produce a first outlet of gas stream and a second outlet of LNG.
  • the advantage provided by the integrated gas recovery system is the ability to manage both the LNG throughput of the LNG plant and recover gases generated in the LNG plant, including BOG and End Flash Gas, while maintaining safe working conditions without the need for separate processing units and systems. Safe working conditions may be achieved within the LNG plant by, in one instance, regulating the LNG pressure using the integrated gas recovery system. Accordingly, the integrated gas recovery system in the present invention reduces equipment count, which in turn simplifies the design and construction of the LNG plant. It follows that capital investment and long term operating cost may therefore be reduced.
  • the integrated gas recovery system and LNG plant may be located on an offshore floating vessel or carrier.
  • the integrated gas recovery system may include an integrated compressor train configured to compress the gas stream discharged from the integrated gas recovery system.
  • the integrated compressor train handles the compression load from: i) the BOG generated from the LNG tanks;
  • the conventional LNG plants typically runs with at least two separate compressor trains, namely one for the end-flash unit and the other for the BOG knock-out drum.
  • the drawback of such an arrangement is that the compressors are underutilized more often than not because the compression loads may be divided between the two compressor trains.
  • the integrated gas recovery system may be configured to permit heat exchange between the first and second inlets of the integrated system.
  • the heat exchange between the LNG BOG and LNG rundown from the liquefaction unit improves efficiency of the compressor train by: i) lowering the suction temperature of the first stage compressor to - 160°C; and ii) reducing the compressor suction piping size.
  • the integrated gas recovery system may include a first stage compressor having a suction temperature of between -161°C to -159 °C.
  • Figures 2a and 2b are configuration diagrams of the end-flash unit, BOG knockout drum and their respective compressor trains in Figure 1 ;
  • Figure 3 is a schematic block diagram of an integrated system and process for gas recovery according to one embodiment of the present invention
  • Figure 6 is a configuration diagram of the integrated system and process for gas recovery in Figure 5.
  • the anti-surge line 145 may include one or more shutoff or on and off valves (e.g. KSV) for controlling the supply or flow of compressed gas returning to the flash-drum 95.
  • the valve may be shutoff to stop the compressed gas from returning to the flash-drum 95.
  • the anti-surge line 145 may also include a permissive logic configured to allow compressor start up if and only if the shutoff valve is fully open.
  • further embodiments of the integrated gas recovery system 100 may include a LNG stripping line 155.
  • the LNG stripping line 155 pumps LNG from the LNG tanks 125 for quenching or condensing the BOG 105 from LNG tanks 125 and the vapour return 150 from LNG carriers. It follows that the LNG stripping line 155 serves as a backup in case LNG rundown is unavailable from the liquefaction unit 30.

Abstract

An integrated gas recovery system in an LNG plant comprising: a first inlet for receiving LNG; and a second inlet for receiving boil-off gas, wherein the system is configured to separate natural gas and LNG in the first and second inlets to produce a first outlet of gas stream and a second outlet of LNG.

Description

AN INTEGRATED SYSTEM AND PROCESS FOR GAS RECOVERY IN THE
LNG PLANT
Technical Field
This invention relates to an integrated system and process for gas management and recovery. It is in particular, though not exclusively, useful for Boil Off Gas (BOG) recovery in LNG plants. Background
Liquefied Natural Gas (LNG) is the liquid form of natural gas at cryogenic temperature of -160°C. When natural gas is turned into LNG, its volume is reduced. This reduction in volume enables natural gas to be transported economically over long distance.
At a typical LNG plant 5, natural gas from gas fields 1 passes through the pre- treatment unit 10, the acid gas removal unit 15, dehydration unit 20, heavy hydrocarbon separation unit 25 and is liquefied in the liquefaction unit 30 where its volume is reduced by a factor of 600. The LNG is then stored in LNG tanks 55. These processing units are illustrated in figures 1 , 2a and 2b.
An end-flash unit 35 may be installed downstream of the liquefaction unit 30 for reducing the pressure of the LNG before it is being stored in LNG tanks 55. Further, the end-flash unit 35 has an added advantage of increasing the LNG throughput of the LNG plant 5. The end-flash unit 35 offers expansion cooling to the LNG stream to a desired temperature and allows a warmer LNG stream to escape the liquefaction unit. To this end, the end-flash unit 35 improves heat transfer and reduces the cooling load of the heat exchanger (not shown), which forms part of the end-flash unit 35. As a result, more natural gas is condensed in the heat exchanger which then exits the end-flash unit 35 as primarily sales LNG 45. The top distillate stream or flashed gas 40 from the end-flash unit 35 may be used as fuel gas for the LNG plant 5. An end-flashed compressor train 50 is employed downstream of the end-flash unit 35 so that the exiting flashed gas 40 may be compressed for use as fuel gas 90 in other processes. Figure 2a shows the configuration of the end-flashed unit 35 and end-flashed compressor train 50 in greater detail.
Sales LNG 45 discharged from the end-flash unit 35 is temporarily stored in LNG tanks 55. Due to heat entering the LNG tanks 55 during storage and transportation, a part of the sales LNG 45 in the tank continuously evaporates and creates a gas called Boil-Off Gas (BOG), which changes the quality of sales LNG 45 over time. The BOG causes the pressure inside the LNG tanks 55 to rise, and must be removed to maintain safe pressure levels. Traditionally, BOG 60 is routed through a BOG knock-out drum 65 where some BOG is re-liquefied and returned 75 to LNG storage tanks 55, thus recycling and recovering valuable LNG which would otherwise be lost as excess BOG is flared and removed to maintain safe pressure levels. The BOG that remains as vapor is then compressed by a BOG compressor 70 and exported as natural gas 85. An LNG quench line 62 may be included upstream of the BOG knock-out drum 65 for heat exchange. Figure 2b shows the configuration of the BOG knock-out drum 65 and BOG compressor 70 in greater detail.
Recently, Floating LNG (F-LNG) has been gaining increasing significance throughout the world. With new technologies which allows for offshore liquefaction, oil producers believe that FLNG can be a cost-effective way of tapping into isolated off-shore natural gas reserves. Moving LNG production to an offshore setting, however, presents a demanding set of challenges. Conventional "on-shore" LNG plants involve considerable processing units and long pipelines that extend beyond the plot space available on FLNG facilities. In terms of the design and construction, every element of a conventional LNG facility needs to fit within the topside of the FLNG facility, whilst maintaining the utmost levels of safety and giving increased flexibility to LNG production.
There remains a need for a cost effective and space efficient system and process for converting natural gas feed to LNG. Summary
In the first aspect, the invention provides an integrated gas recovery system in an LNG plant comprising: a first inlet for receiving LNG; and a second inlet for receiving boil-off gas, wherein the system is configured to separate natural gas and LNG in the first and second inlets to produce a first outlet of gas stream and a second outlet of LNG. In the second aspect, the invention provides a process for gas recovery in an LNG plant by means of an integrated system comprising the steps of: receiving LNG from a first inlet; receiving boil-off gas from a second inlet; and separating natural gas and LNG in the first and second inlets to produce a first outlet of gas stream and a second outlet of LNG.
As discussed, conventional LNG plants optimize LNG throughput and maintain safe working conditions within the LNG plant using separate systems, namely the end-flash unit, the BOG knock-out drum and their respective or dedicated compressor trains.
Compared to conventional LNG plants, the advantage provided by the integrated gas recovery system according to one embodiment of the invention is the ability to manage both the LNG throughput of the LNG plant and recover gases generated in the LNG plant, including BOG and End Flash Gas, while maintaining safe working conditions without the need for separate processing units and systems. Safe working conditions may be achieved within the LNG plant by, in one instance, regulating the LNG pressure using the integrated gas recovery system. Accordingly, the integrated gas recovery system in the present invention reduces equipment count, which in turn simplifies the design and construction of the LNG plant. It follows that capital investment and long term operating cost may therefore be reduced.
In one embodiment, the integrated gas recovery system and LNG plant may be located on an offshore floating vessel or carrier. In alternative embodiments, the integrated gas recovery system may include an integrated compressor train configured to compress the gas stream discharged from the integrated gas recovery system. Advantageously, the integrated compressor train handles the compression load from: i) the BOG generated from the LNG tanks;
ii) vapour return during transportation;
iii) the flashed gas stream from the LNG rundown or integrated gas recovery system; or
iv) a combination thereof.
As discussed, the conventional LNG plants typically runs with at least two separate compressor trains, namely one for the end-flash unit and the other for the BOG knock-out drum. The drawback of such an arrangement is that the compressors are underutilized more often than not because the compression loads may be divided between the two compressor trains.
By providing an integrated compressor train, the invention therefore provides a means for improving the overall economics for running the offshore LNG plant. This is achieved by reducing the number of compressor trains necessary for running the LNG plant, thus reducing the upfront capital investment and on-going operating cost. In one embodiment, the integrated gas recovery system may include a compressor train comprising a two-stage compressor.
In another embodiment, the integrated gas recovery system may be configured to permit heat exchange between the first and second inlets of the integrated system. To this end, the heat exchange between the LNG BOG and LNG rundown from the liquefaction unit improves efficiency of the compressor train by: i) lowering the suction temperature of the first stage compressor to - 160°C; and ii) reducing the compressor suction piping size.
In another embodiment, the first outlet of the integrated gas recovery system may have an operating temperature of between -161°C to -159 °C.
In another embodiment, the integrated gas recovery system may include a first stage compressor having a suction temperature of between -161°C to -159 °C.
Brief Description of Drawings
Embodiments of the invention will now be described, by way of non-limiting example only, with reference to the accompanying drawings in which:
Figure 1 is a schematic block diagram illustrating the systems and processes involved in a conventional LNG plant;
Figures 2a and 2b are configuration diagrams of the end-flash unit, BOG knockout drum and their respective compressor trains in Figure 1 ; Figure 3 is a schematic block diagram of an integrated system and process for gas recovery according to one embodiment of the present invention;
Figure 4 is a configuration diagram of the integrated system and process for gas recovery in Figure 3;
Figure 5 is a schematic block diagram of an integrated system and process for gas recovery according to another embodiment of the present invention; and
Figure 6 is a configuration diagram of the integrated system and process for gas recovery in Figure 5.
Detailed Description of Embodiments The present invention relates to an integrated gas recovery system and process for managing the LNG, BOG and End-flash gas throughput of the LNG plant. In particular, the integrated system and process involves managing safe working conditions such as pressure levels downstream of the liquefaction unit.
Figure 3 shows a schematic block diagram of an integrated gas recovery system 100 for an LNG plant 130 according to one embodiment of the present invention. It will be appreciated that the integrated gas recovery system 100 may be a flash drum 95 comprising structured packing, liquid distributors, random packing or a combination thereof. Figure 4 shows the configuration of the integrated gas recovery system 100 in Figure 3.
The integrated gas recovery system 100 comprises a flash drum 95 with inlets 105, 110 and outlets 1 15, 120. LNG from the liquefaction unit 30 is fed to inlet 110 of the integrated gas recovery system 100. Separately, BOG from the LNG tanks 125 is routed to inlet 105 of the integrated gas recovery system 100.
In addition, the flash drum 95 according to one embodiment of the present invention may include heat exchange or transfer between the LNG from inlet 110 and the BOG from inlet 105. In the process of heat exchange, the LNG from inlets 105, 110 quenches, condenses, which then settles at the bottom of the flash drum 95 and exits through outlet 115. The LNG 1 15 is then returned and stored in LNG tanks 125. BOG which remained in its vapour phase rises, together with a relatively small mixture of vaporized or flashed gases like nitrogen and ethane, etc. from inlet 110, and exits from the top of the flash drum 95 through outlet 120.
The operating temperature of gases at outlet 120, according to any embodiment of the present invention, may be maintained or varied via control valves by changing the amount of LNG supplied to inlet 110 and/or the amount of BOG supplied to inlet 105. In the embodiment shown in Figures 3 and 4, the operating temperature of the gases at outlet 120 may be maintained between -161 °C to - 159°C under all operating scenarios barring process disturbances and control noises. The internals and pipelines of the integrated gas recovery system 100, according to any embodiment of the present invention, may be reasonably sized for achieving optimum space efficiency and LNG throughput for the LNG plant 130. In one embodiment, flash-drum 95 may include more complex internals to accommodate the equipment required for a desirable amount of heat and mass transfer between the LNG and the BOG.
The mixture of gases from outlet 120, according to any embodiment of the present invention, may be compressed using an integrated compressor train 135 and routed to a fuel gas system 143 for FLNG power generation. Alternatively, the compressed gas discharged from the compressor train 135 may be used to power auxiliary engines, gas turbines, gas diesel engines and/or vaporizers in the LNG plant 130.
In one embodiment of the present invention, the integrated compressor train 135 may comprise a two-stage compressor (first and second stage) for handling of compression load from: the BOG generated 105 from the LNG tanks 125, vapour return 150 during transportation from the LNG carrier, the gas stream 120 from the flash drum 95, and a combination thereof. The compression load may vary between offloading and holding modes. Relative to the compression load during holding modes, the compression load of the compressor train 135 is significantly increased during LNG offloading operation as vapour from the LNG carrier is being returned 105 to the integrated gas recovery system 100. Depending on design requirements, additional compressors may be added to increase the capacity or load of the compressor train 135 in the LNG plant 130.
The flash drum 95, according to any embodiment of the present invention, may include continuous heat exchange between the BOG from inlet 105 and LNG rundown 0 from the liquefaction unit 30. In this case, the continuous heat exchange reduces the cooling load of the compressor train 135 thereby increasing the efficiency of the compressor train 135. Advantageously, the suction temperature of the first stage compressor may be maintained between - 161 °C to -159 °C, which is significantly lower compared to the range of -100°C to -140°C in traditional LNG plants. As gases contract at a lower temperature, the suction piping size of the integrated compressor train 135 may be reduced to capture even more cost and operational savings. It will be appreciated that the integrated compressor trains 135 may be designed and made of materials to endure low temperature conditions.
In one embodiment of the present invention, an anti-surge line 145 may be installed for safe operation of integrated compressor train 135 as shown in Figures 4 and 6. The anti-surge line 145 returns or recycles the compressed gas discharged from compressor train 135 to the flash-drum 95. To this end, the antisurge line 145 prevents the compressor train 135 from surging and handles pressure and flow transitions during start-up and shutdown of the LNG plant 130, LNG load transfer and power interruption.
In another embodiment of the present invention, the anti-surge line 145 may include one or more shutoff or on and off valves (e.g. KSV) for controlling the supply or flow of compressed gas returning to the flash-drum 95. For instance, during compressor failure or maintenance of the compressor train, the valve may be shutoff to stop the compressed gas from returning to the flash-drum 95. This arrangement isolates the compressor train 135 and anti-surge line 145 from the integrated gas recovery system 100 in preparation for maintenance or inspection work. In a further embodiment of the present invention, the anti-surge line 145 may also include a permissive logic configured to allow compressor start up if and only if the shutoff valve is fully open.
As seen in figures 3 to 6, further embodiments of the present invention may be provided with a flare stack 140 downstream of the flash-drum 95 to allow safe disposal of gases in the event of an emergency, power or equipment failure, equipment maintenance, or other plant upset conditions. In case of extreme turndown or emergency conditions, LNG rundown from the liquefaction unit 30 could continue and BOG could be generated in quantities which exceed the capacity of the flash-drum 95. In this case, the mixture of BOG and flashed gases in the flash drum 95 will be sent to the atmosphere through flaring or venting.
Referring to Figures 5 and 6, further embodiments of the integrated gas recovery system 100 may include a LNG stripping line 155. The LNG stripping line 155 pumps LNG from the LNG tanks 125 for quenching or condensing the BOG 105 from LNG tanks 125 and the vapour return 150 from LNG carriers. It follows that the LNG stripping line 155 serves as a backup in case LNG rundown is unavailable from the liquefaction unit 30.
The integrated gas recovery system 100 according to another embodiment of the present invention may include using the compressed gases from the integrated compressor train 135 as regeneration gas 160 for upstream units like the dehydration unit and heavy HC separation unit.

Claims

1. An integrated gas recovery system in an LNG plant comprising:
a first inlet for receiving LNG; and
a second inlet for receiving boil-off gas,
wherein the system is configured to separate natural gas and LNG in the first and second inlets to produce a first outlet of gas stream and a second outlet of LNG.
2. An integrated gas recovery system according to claim 1 , wherein the system condenses natural gas in the first and second inlets by means of a flash drum.
3. The integrated gas recovery system according to claim 1 or 2, wherein the system further comprises an integrated compressor train configured to compress the gas stream from the first outlet to discharge a compressed gas stream.
4. The integrated gas recovery system according to any one of the preceding claims, wherein the system is configured to permit heat exchange between the first and second inlets.
5. The integrated gas recovery system according to any one of the preceding claims, wherein the LNG plant is located on an offshore floating vessel.
6. The integrated gas recovery system according to any one of the preceding claims, wherein the system further comprises a flare stack for flaring the gas stream from the first outlet.
7. The integrated gas recovery system according to any one of the preceding claims, wherein the system further comprises a line for returning the compressed gas stream to the integrated gas recovery system.
8. The integrated gas recovery system according to claim 7, wherein the line comprises one or more shutoff valves for controlling the flow of compressed gas stream returning to the integrated gas recovery system.
9. The integrated gas recovery system according to any one of the preceding claims, wherein the operating temperature of the first outlet is between -161°C to -159 °C.
10. The integrated gas recovery system according to claim 3, wherein the integrated compressor train comprises a first and second stage compressor.
11. The integrated gas recovery system according to claim 10, wherein the suction temperature of the first stage compressor is between -161°C to - 159 °C.
12. The integrated gas recovery system according to any one of the preceding claims, wherein the system further comprises a third inlet for receiving LNG from a stripping line.
13. A process for gas recovery in an LNG plant by means of an integrated system comprising the steps of:
receiving LNG from a first inlet;
receiving boil-off gas from a second inlet; and
separating natural gas and LNG in the first and second inlets to produce a first outlet of gas stream and a second outlet of LNG.
14. The process according to claim 13, wherein the process further comprises the step of heat exchange between the first and second inlets.
15. The process according to claim 13 or 14, wherein the process further comprises the step of compressing the gas stream from the first outlet to discharge a compressed gas stream.
PCT/MY2016/000014 2015-03-25 2016-03-24 An integrated system and process for gas recovery in the lng plant WO2016153334A1 (en)

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