WO2015076859A1 - Production d'énergie électrique à partir d'un combustible fossile avec une pollution de l'air presque nulle - Google Patents

Production d'énergie électrique à partir d'un combustible fossile avec une pollution de l'air presque nulle Download PDF

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Publication number
WO2015076859A1
WO2015076859A1 PCT/US2014/000213 US2014000213W WO2015076859A1 WO 2015076859 A1 WO2015076859 A1 WO 2015076859A1 US 2014000213 W US2014000213 W US 2014000213W WO 2015076859 A1 WO2015076859 A1 WO 2015076859A1
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Prior art keywords
stage
gas
membrane
compressor
membranes
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PCT/US2014/000213
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English (en)
Inventor
Eliot Gerber
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Eliot Gerber
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 US13/999,746 external-priority patent/US20160256818A1/en
Application filed by Eliot Gerber filed Critical Eliot Gerber
Priority to US14/392,393 priority Critical patent/US20160245126A1/en
Publication of WO2015076859A1 publication Critical patent/WO2015076859A1/fr

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Classifications

    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/22—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by diffusion
    • B01D53/225—Multiple stage diffusion
    • B01D53/226—Multiple stage diffusion in serial connexion
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2256/00—Main component in the product gas stream after treatment
    • B01D2256/10—Nitrogen
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2256/00—Main component in the product gas stream after treatment
    • B01D2256/22—Carbon dioxide
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2257/00—Components to be removed
    • B01D2257/10—Single element gases other than halogens
    • B01D2257/102—Nitrogen
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2257/00—Components to be removed
    • B01D2257/50—Carbon oxides
    • B01D2257/504—Carbon dioxide
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2258/00—Sources of waste gases
    • B01D2258/02—Other waste gases
    • B01D2258/0283—Flue gases
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F05—INDEXING SCHEMES RELATING TO ENGINES OR PUMPS IN VARIOUS SUBCLASSES OF CLASSES F01-F04
    • F05D—INDEXING SCHEME FOR ASPECTS RELATING TO NON-POSITIVE-DISPLACEMENT MACHINES OR ENGINES, GAS-TURBINES OR JET-PROPULSION PLANTS
    • F05D2260/00—Function
    • F05D2260/60—Fluid transfer
    • F05D2260/61—Removal of CO2
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02C—CAPTURE, STORAGE, SEQUESTRATION OR DISPOSAL OF GREENHOUSE GASES [GHG]
    • Y02C20/00—Capture or disposal of greenhouse gases
    • Y02C20/40—Capture or disposal of greenhouse gases of CO2

Definitions

  • TITLE PRODUCTION OF ELECTRIC POWER FROM FOSSIL FUEL WITH ALMOST ZERO AIR POLLUTION
  • the U.S. Energy Information Administration estimates that between 2015 and 2019, 96.65 gigawatts (GW) of new electricity capacity will be added in the U.S.
  • Steam coal (thermal coal) is used in power stations to generate electricity. Generally, the coal is milled to a fine powder, which increases the surface area and allows it to burn more quickly. In these pulverized coal combustion (PCC) systems, the powdered coal is blown into the
  • a generator is mounted at one end of the turbine shaft and consists wire coils. Electricity is generated
  • Natural gas can be used to generate electricity in a variety of ways.
  • the most basic natural gas-fired electric generation consists of a steam generation unit, where fossil fuels are burned in a boiler to heat water and produce steam that then turns a turbine to generate electricity. Natural gas may be used for this process. Typically, only 33 to 35 percent of the thermal energy used to generate the steam is converted into electrical energy in these types of units.
  • Centralized Gas Turbines
  • Gas turbines and combustion engines are also used to generate electricity. In these units' hot gases from burning natural gas spins the turbine and generates electricity. Combined Cycle Units
  • CCGT combined-cycle'
  • the gas turbine operates as a normal gas turbine, using the hot gases released from burning natural gas to turn a turbine and generate electricity.
  • the waste heat from the gas-turbine generates steam, which generates electricity like a steam unit. Because of this efficient use of the heat energy released from the natural gas, combined-cycle plants achieve thermal efficiencies of 50 to 60 percent.
  • each GT (Gas Turbine) has its own associated HRSG, (heat recovery steam generator - a heat exchanger) and multiple HRSGs supply steam to one or more steam turbines.
  • Natural gas is the cleanest of all the fossil fuels, as evidenced in the data comparisons in the chart below. Composed primarily of methane, the main products of the
  • Coal and oil are composed of complex molecules, with a higher carbon ratio and higher nitrogen and sulfur contents. When combusted, coal and oil release higher levels of harmful emissions, including a higher ratio of carbon emissions, nitrogen oxides (Nox), and sulfur dioxide (S02). Coal and fuel oil also release ash particles into the environment, substances that do not burn but instead are carried into the atmosphere and contribute to pollution.
  • FIGS. 1 and 3 are schematic drawings showing the equipment and process flow for the system and method and FIG. 2 shows that the present system is above Robeson's upper bound.
  • a combined cycle electrical generating plant 10 consists of a natural gas fueled turbine 11 and a heat exchange boiler 12 (HRSG).
  • the boiler produces steam which powers a steam turbine 13.
  • the two turbines 11 and 13 may have a common shaft connected to an electrical generator 18.
  • These components are conventional and comprise a combined cycle gas turbine (CCGT) plant 10.
  • CCGT combined cycle gas turbine
  • the exhaust gas from the boiler 12 is generally released to the atmosphere.
  • That exhaust gas contains 2-4% (gas) or 12-14% (coal) of CO2, which is a harmful pollutant.
  • exhaust gas by b'ower/ compressor 19, is to piped to a separation process 14.
  • Process 14 includes a first stage of membrane separators 15 whose permeate (90-99% C02) is piped to by vacuum_pump 20a and compressor 20b to the second stage 16 of membrane separators.
  • the permeate gas from the second stage 16 is piped to vacuum pump 17c and compressor 17b, which
  • the means to transport the various gases are conventional pipes (tubes). They are pipe 11a from turbine 11 to boiler 12, exhaust gas pipe 12a from boiler 12 to first stage 15, steam pipe 12b from boiler 12 to steam turbine 13, pipe 15a from first stage 15 to atmosphere, permate pipe 5b from first stage to second stage 16, permeate pipe 16a from second stage 16 to compressor 17 and pipe 17a from compressor 17 to sequestration or sale.
  • the drive shafts are 11b from the gas turbine and 13b from the steam turbine (both to the generator 18).
  • the volume of gas compressed by compressor 19 is all the exhaust gas from heat exchanger 12. It is a large compressor or blower. However the required compression is relatively low, 0.1-1-3 bar, so the electrical power it uses is also relatively low (pressure ratio to permeate).
  • the second compressor 20a acts on a smaller volume of gas (2-4 % or 12-14%) of the volume acted on by the first compressor. It uses higher
  • the first stage membrane has a high permeance (greater than 800) and low C02/N2 -selectivity (10-100, preferably 10-30).
  • the pressure is greater (6-15) bar and the membrane has a lower permeance (10-50) and higher C02/N2 selectivity (greater than 20 and preferably over 100).
  • the membranes used in the first stage have a permeance of at least 800 and preferably over 2000 and most preferably over 4000. This is an important feature of the system for a number of reasons:
  • the same gas flow is obtainable, for carbon dioxide (CO2), with a membrane of permeance for CO2 of 100 and membrane area of 100m2 and a membrane of permeance for CO2 of 1000 and membrane area of 10m2.
  • CO2 carbon dioxide
  • the selectivity of the membrane of the first stage may be as low as 10 (selectivity CO2/N2).
  • the high permeance permits lower compression (b»ower) pressure.
  • the volume of exhaust gas blown into the first stage is large.
  • the membranes of the first stage separate all the exhaust gas from the boiler.
  • the lower pressure means a smaller compressor (blower) may be used.
  • the power used may be less.
  • raising the permeance from 200 to 400 means that the required pressure may be reduced, the compressor may be 1 ⁇ 2 the size and only 1 ⁇ 2 the is power used.
  • the preferred permeance for the first stage membranes is over 2000 and most preferred is over 4000.
  • the first separation stage because it uses high permeance membranes, requires only a small membrane area and a small "footprint" (fewer modules) and less area for modules).
  • the membranes of the second separator stage should have selectivity which is higher than the first set of membranes, preferably selectivity of at least 20 and most preferably 50-1000.
  • the volume of gas processed through the second stage is only a small portion of the volume of exhaust gas processed by the first stage.
  • the second stage may have a higher compression and still be low in cost since the volume of gas is low. This higher compression permits membranes having lower permeance
  • MTR Membrane Technology and Research Inc.
  • MTR Newark, CA tested a CO2 separation and capture system using its MTR "Polaris” 1 membrane with a coal gasification exhaust flume.
  • the PolarisTM membrane system is said to use a CO2-selective polymeric membrane (micro-porous films which act as semi-permanent barriers to separate two different mediums).
  • the membrane material is formed into modules and captures CO2 from a plant's flue gas. See Journal of Membrane Science: "Power plant post-combustion carbon dioxide capture: An opportunity for membranes"; Tim C. Merkel et.al.
  • the permeance of Polaris 3 may be 2000-4000.
  • molecular sieves microporous solids known as "molecular sieves.”
  • the turm molecular sieve refers to a particular property of these materials, i.e., the ability to selectively sort molecules based primarily on a size exclusion process. This is due to a very regular pore structure of molecular dimensions.
  • the maximum size of the molecular or ionic species that can enter the pores of a zeolite is controlled by the dimensions of the channels. These are conventionally defined by the ring size of the aperture, where, for example, the term “8- ring” refers to a closed loop that is built from eight tetrahedrally coordinated silicon (or aluminium) atoms and 8 oxygen atoms.
  • TFC thin film composite
  • PIM-1 Polymer of intrinsic microporosity PIM-1 having a CO2 barrier of 5500 gpu and a barrier of 398 for N2. PIM-1 was prepared from 5,5_,6,6_-tetrahydroxy-3,3,3_,3_- tetramethyl-1 ,1_-spirobisindane and tetrafluoroterephthalonitrile. See Budd PM et al. Journal of Membrane science 2005;251 :263e9. "Gas separation membranes from polymers of intrinsic microporosity" and US Pat.Appl.20120264589 & 2013/0145931.
  • the driving force across a gas-separation membrane is the pressure differential between the feed side and the permeate side. Creating this driving force accounts for most of the cost for membrane separation since flue gases are at or slightly above atmospheric pressure. It is conventional to compress the feed gas to a higher pressure (15 to 20 bar) and set the permeate stream at atmospheric pressure
  • pressurized feed/atmospheric permeate mode (designated as pressurized feed/atmospheric permeate mode).
  • the feed-gas and the post-separation compressors account for over 50% of the capital and operating costs.
  • the present approach is to compress the feed gas at the first stage, at a lower pressure i.e. 0.1to 1.1 bar.
  • the first separation stage because it uses high permeance membranes, requires only a small membrane area and a small "footprint" (fewer modules and less area for modules).
  • the membranes of the second separator stage should have selectivity which is higher than the first stage of membranes, preferably selectivity of at least 20 and most preferably 40-200.
  • the volume of exhaust gas processed through the first stage and transported to the second stage is mostly CO2.
  • the first stage cuts out over 85 percent of the total volume of the exhaust from the plant and releases it to the atmosphere.(gas plant).
  • the second stage's volume is that remaining percent.
  • the second stage has a higher compression and is low in cost since the volume of gas is low. This higher compression permits membranes having lower permeance i.e. 20-100 and higher selectivity (20-1000) and preferably above 30.
  • membranes suitable for the second separation stage 1.
  • MTR Membrane Technology and Research Inc.
  • Polaris 1 has a lower permeance, of 1000, and a higher selectivity of 50 compared to Polaris 3.
  • the volume of gas which passes through the first stage and is processed by the second stage is only a small part of original exhaust gas volume.
  • the compressor (blower) size and its running electrical power for the second stage may be 1/6 the compressor size and power of the first stage. Due to the high separation property of the second stage membrane the resulting purity of the final CO2 is 98%-99.9%.
  • U S tax law 26 USC ⁇ 45Q, provides a $10 or $20 c r edit per ton CO2 for geological sequestration.
  • the amount of the credit depends on the type of storage.
  • Emissions trading (“cap and trade”) is a market-based system to reduce air pollution by paying money for reductions in emissions.
  • a government sets a limit (cap) on the volume of a pollutant that may be emitted. This cap is allocated or sold to firms
  • the CO2 content is about 13% of the flue gas i.e. 11 ,000 ton CO2 per day.
  • the flue gas is at atmospheric pressure.
  • the flue gas contains other pollutents, see page 7.
  • SO2 and particulate matter is removed before the flue gas is vented to the atmosphere.
  • the first stage uses a blower 19, a vacuum pump 20a, a compressor 20b, a second vacuum pump 17c, a compressor 17b and a membrane area of 0.55 MM X 10 6 m2. Merkel 1
  • the first blower 19 must blow all the exhaust fumes, for example 500 M3/s
  • blowers 1 ,8000,000 CMH- 1 ,059,000 CFM). It is suggested that five blowers be used, four on Line all the time (8750 hours/year) and one in reserve.
  • the prefered blowers are rated at 291 ,400 CFM each, and are preferably airfoil centrifugal fans 89 inch wheel diameter and 11 HP, 0.1 Bar. Their cost is about 0.65 million each (about 2.6 million for 4 ). Their total running cost is about $12,000 per year. This type of fan is available from Twin City, Minneapolis, MN.( model BCS). It would seem less costly to obtain a desired pressure ratio by a vacuum at the first stage, using a fan with little compression, then to use a compressor for all the exhaust gas.
  • the volume of gas separated by the first stage is only about 13% of the volume of the exhaust gas.
  • a vacuum for the first stage.
  • large fans of the type used in wind tunnels. For example, two fans rated at 2000kW (total) ,cost about 2 million, running cost $700,000 per year. (Witt & Sohn, Germany).
  • Another alternative is a two-stage fan (FlaktWoods).
  • the vacuum pump 20a is preferably a group of booster vacuum pumps, such as ten Tuthill M-D Model 1248 using a 200 HP motor.
  • the total cost is estimated at 1.1 million dollars and yearly running cost would be about 1.3 million dollars. It acts upon the C02 gas from stage one which is about 138,000 CFM with a vacuum of 100 torr (.13 Bar).
  • Compressor 20b may be a centrifugal compressor, such as GE type D (0.9 bar inlet vacuum). It would cost about 4 million dollars and be driven by a 8,000 HP motor whose running cost per year would be about 5 million dollars.
  • the permate from the second stage is about 138,000 CFM. It is acted upon by the same type of devices as the devices after the first stage. That is; the the gas is pulled by vacuum booster pump 17c, which is the same type as booster pump 20a, to obtain a vacuum of 100 torr . It acts upon the CO2 gas from stage two and that gas is then compressed by compressor 17b to 14 Bar for transport or sale .
  • the cost of carbon capture alone is about $8.6 /ton .Even with an additional cost of $9/ton for further treatment of the C02 the total cost of about $17.6 a ton is less than the amount received of about $21.5 /ton._A profit of about 5 million dollars per year for the carbon capture and sequestration.
  • the vacuum pumps 17c,20a each need only move gas at 42,000 CFM.
  • the 2 compressors 20b, 17b should have a cost of $350,000 each and a running cost each of about 1.5 million each.
  • the compressor 17b compresses the gas to 14 bar ( 203 psi) which is below its final compression.
  • the total yearly cost would be 19 million dollars.
  • the tons of C02 captured per year would be at least 1.23 million tons of C02 for a tax credit (USA) of 24.6 million.
  • the 19 million of costs is a deduction for tax purposes. I.i US that 19 million of costs has a value of ' about 6.6 million dollars ( 35% rate), without consideration of state corporate income tax.- for example California rate is 8.8% and New York is 7.1%.
  • the total of the tax credit and value of the 6.6 million Federal tax deduction is 31.2 million , which is more than the costs of 21 million. This is a profit of about 10 million dollars.
  • the European cap-and-trade system had a decline in allowance spot prices from over $25 per metric ton of carbon dioxide (June 2008) to about $3 (May 2013). However, even at $3 per ton the utility of this example could receive 3.7 million for its sale of credits. Its net cost per year would be about 15.3 million dollars, without any tax credit. It should be able to be recover that cost in a rate adjustment. For a large electrical utility this would be about 3% of its generating plant cost, a small price to pay for helping save the planet.
  • the CO2 concentration is ⁇ 13 mol %. According to one calculation , although not others, the minimum theoretical energy requirement is -5% of the output of the coal power plant, see Guest Blog "Post-Combustion C02 Capture to Mitigate climate Change: Separation Costs Energy " Cory Simon, March 7,
  • This separation system may be retro-fitted and adapted to gas fueled steam generation units, centralized gas turbines, and combined cycle units.
  • CCS systems must compress CO2 to a supercritical state for transportation and/or storage.
  • Storage pressure local to the power plant will require a nominal 1 ,600 psia, while the current pipeline specification is 2,215 psia.
  • a fabric filter is often used to collect PM on the surfaces of fabric bags. Most of the particles are captured on already collected particles that have formed a dust layer. The fabric material itself can capture particles that have penetrated the dust layers. According to EPA, a fabric filter on a coal-fired power plant can capture up to 99.9 percent of total particulate emissions and 99.0 to 99.8 percent of PM 2.5. Thirty-five percent of coal-fired power plants in the U.S. have already installed fabric filters, according to environmental Health and Engineering. The blower 19, in Fig.1 , can be used to blow exhaust gas to the fabric bags ("bag house"). In that way the PM will not clog or foul the first stage membrane.
  • This proposed system uses natural gas, or coal, as its fuel, separates the
  • this system uses a conventional coal burning power generating plant and retrofits it with a carbon capture two-stage
  • this system uses a separation facility with a gas burning plant.
  • That facility can be retrofitted to existing plants to separate C02 for the $20 tax credit.
  • the system is above " Robeson's upper bound", although the membranes are within that bound.
  • the cascade may have a permeance of 5500 and a selectivity to CO2/N 2 of 200, which are not now obtainable in a single membrane.
  • the pressure ratio across the membranes of the first stage is relatively low, for example 3-6, and the pressure ratio across the membranes of the second stage is relatively higher, for example 10-20.

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  • Chemical & Material Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Analytical Chemistry (AREA)
  • General Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • Separation Using Semi-Permeable Membranes (AREA)

Abstract

La présente invention concerne un système permettant la séparation et l'élimination non polluante du dioxyde de carbone issu de la combustion d'un combustible fossible, ledit système comprenant un système de séparation de gaz qui comprend : un premier étage de séparateurs de CO2 à membranes; des moyens destinés à acheminer l'effluent gazeux vers le premier étage, le premier étage séparant le CO2 des autres gaz présents dans l'effluent gazeux, un second étage de séparateurs de CO2 à membranes, et des moyens destinés à acheminer le perméat gazeux traversant les membranes du premier étage vers le second étage, le second étage produisant un perméat de CO2 d'une pureté supérieure à 90 %.
PCT/US2014/000213 2013-11-22 2014-11-17 Production d'énergie électrique à partir d'un combustible fossile avec une pollution de l'air presque nulle WO2015076859A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
US14/392,393 US20160245126A1 (en) 2013-11-22 2014-11-17 Production of electric power from fossil fuel with almost zero pollution

Applications Claiming Priority (8)

Application Number Priority Date Filing Date Title
US201361907406P 2013-11-22 2013-11-22
US61/907,406 2013-11-22
US201461966170P 2014-02-18 2014-02-18
US61/966,170 2014-02-18
US201461950300P 2014-03-10 2014-03-10
US61/950,300 2014-03-10
US13/999,746 2014-03-19
US13/999,746 US20160256818A1 (en) 2014-03-19 2014-03-19 Production of electric power from fossil fuel with almost zero air pollution

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Cited By (4)

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Publication number Priority date Publication date Assignee Title
WO2016196056A1 (fr) * 2015-05-29 2016-12-08 Ohio State Innovation Foundation Procédés pour la séparation de co2 d'un flux gazeux
CN112762424A (zh) * 2021-01-07 2021-05-07 中国船舶重工集团新能源有限责任公司 一种基于储热和压缩式热泵相结合的太阳能热电解耦系统及其运行方法
CN116579546A (zh) * 2023-04-15 2023-08-11 浙江容大电力工程有限公司 一种基于园区的智能化用电数据分析及管理系统
CN117180928A (zh) * 2023-09-28 2023-12-08 中国船舶集团有限公司第七一一研究所 一种气体捕集储存系统及方法

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US6579331B1 (en) * 1997-08-01 2003-06-17 Exxonmobil Research And Engineering Company CO2-Selective membrane process and system for reforming a fuel to hydrogen for a fuel cell
US20110052466A1 (en) * 2009-05-21 2011-03-03 Battelle Memorial Institute Catalyzed co2-transport membrane on high surface area inorganic support
US20110262328A1 (en) * 2010-09-13 2011-10-27 Membrane Technology And Research, Inc. Process for separating carbon dioxide from flue gas using sweep-based membrane separation and absorption steps

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US4597777A (en) * 1983-02-15 1986-07-01 Monsanto Company Membrane gas separation processes
US6579331B1 (en) * 1997-08-01 2003-06-17 Exxonmobil Research And Engineering Company CO2-Selective membrane process and system for reforming a fuel to hydrogen for a fuel cell
US6216441B1 (en) * 1997-09-17 2001-04-17 General Electric Co Removal of inert gases from process gases prior to compression in a gas turbine or combined cycle power plant
US6428606B1 (en) * 2001-03-26 2002-08-06 Membrane Technology And Research, Inc. Membrane gas separation process with compressor interstage recycle
US20110052466A1 (en) * 2009-05-21 2011-03-03 Battelle Memorial Institute Catalyzed co2-transport membrane on high surface area inorganic support
US20110262328A1 (en) * 2010-09-13 2011-10-27 Membrane Technology And Research, Inc. Process for separating carbon dioxide from flue gas using sweep-based membrane separation and absorption steps

Cited By (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2016196056A1 (fr) * 2015-05-29 2016-12-08 Ohio State Innovation Foundation Procédés pour la séparation de co2 d'un flux gazeux
CN107708840A (zh) * 2015-05-29 2018-02-16 俄亥俄州创新基金会 从气体流分离co2的方法
US11358093B2 (en) 2015-05-29 2022-06-14 Ohio State Innovation Foundation Methods for the separation of CO2 from a gas stream
CN107708840B (zh) * 2015-05-29 2022-12-20 俄亥俄州创新基金会 从气体流分离co2的方法
CN112762424A (zh) * 2021-01-07 2021-05-07 中国船舶重工集团新能源有限责任公司 一种基于储热和压缩式热泵相结合的太阳能热电解耦系统及其运行方法
CN112762424B (zh) * 2021-01-07 2022-10-18 中国船舶重工集团新能源有限责任公司 一种基于储热和压缩式热泵相结合的太阳能热电解耦系统及其运行方法
CN116579546A (zh) * 2023-04-15 2023-08-11 浙江容大电力工程有限公司 一种基于园区的智能化用电数据分析及管理系统
CN116579546B (zh) * 2023-04-15 2023-12-12 浙江容大电力工程有限公司 一种基于园区的智能化用电数据分析及管理系统
CN117180928A (zh) * 2023-09-28 2023-12-08 中国船舶集团有限公司第七一一研究所 一种气体捕集储存系统及方法

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