module 14. “life cycle assessment (lca)”

PIECEPIECEProgram for North American Mobility In Higher EducationProgram for North American Mobility In Higher Education

MODULE 14. “Life Cycle Assessment (LCA)”MODULE 14. “Life Cycle Assessment (LCA)”4 steps of LCA, approaches, software, databases, 4 steps of LCA, approaches, software, databases, subjectivity, sensitivity analysis, application to a classic subjectivity, sensitivity analysis, application to a classic example. example.

Module 14 – Life Cycle Assessment 22

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Tier IIIOpen-ended problem


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What are the prerequisites for this tier?What are the prerequisites for this tier?

It is further assumed that students already have an It is further assumed that students already have an introductory-level background in Life Cycle Assessment introductory-level background in Life Cycle Assessment (LCA) (from Tier I and Tier II) and the basic knowledge in (LCA) (from Tier I and Tier II) and the basic knowledge in petrochemical processes, such as would normally be part petrochemical processes, such as would normally be part of any undergraduate engineering curriculum.of any undergraduate engineering curriculum.

Prerequisites for tier IIIPrerequisites for tier III


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What is the purpose of this module?What is the purpose of this module?Open-Ended Design ProblemOpen-Ended Design Problem. Is comprised of an . Is comprised of an open-ended problem to solve real-life application open-ended problem to solve real-life application of LCA to the oil and gas sector. The global aim of LCA to the oil and gas sector. The global aim of that problem is to quantify the total of that problem is to quantify the total environmental benefits and drawback of a environmental benefits and drawback of a process. process.

Statement of intentStatement of intent

ANTONIO

"to solve a" instead of "of a solve"


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Spath and Mann. (2001) Spath and Mann. (2001) ”Life Cycle Assessment of Hydrogen Production via ”Life Cycle Assessment of Hydrogen Production via

Natural Gas Steam Reforming“. National Renewable Energy Laboratory.Natural Gas Steam Reforming“. National Renewable Energy Laboratory.

Spath and Mann. (1999) “Life Cycle Assessment of Coal-fired Power Spath and Mann. (1999) “Life Cycle Assessment of Coal-fired Power

Production”. National Renewable Energy Laboratory.Production”. National Renewable Energy Laboratory.Mann and Spath. (1997) “Life Cycle Assessment of Biomass Gasification Mann and Spath. (1997) “Life Cycle Assessment of Biomass Gasification

Combined-Cycle System”. National Renewable Energy Laboratory.Combined-Cycle System”. National Renewable Energy Laboratory.Rojey A., Minkkinen A., Arlie J.P. and Lebas E. “Combined Production of Rojey A., Minkkinen A., Arlie J.P. and Lebas E. “Combined Production of

Hydrogen, Clean Power and Quality Fuels”. Institut Français du Pétrole (IFP).Hydrogen, Clean Power and Quality Fuels”. Institut Français du Pétrole (IFP).

ReferencesReferences


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D. Gray, G. Tomlinson, “Opportunities For Petroleum Coke Gasification Under D. Gray, G. Tomlinson, “Opportunities For Petroleum Coke Gasification Under

Tighter Sulfur Limits For Transportation Fuels,” Presented at the Gasification Tighter Sulfur Limits For Transportation Fuels,” Presented at the Gasification

Technologies Conference, San Francisco, California, October 8–11, 2000Technologies Conference, San Francisco, California, October 8–11, 2000H. Baumann, A.M. Tillman(2004). ‘’The hitch Hicker’s Guide to LCA. An H. Baumann, A.M. Tillman(2004). ‘’The hitch Hicker’s Guide to LCA. An

orientation in life cycle assessment methodology and application’’. orientation in life cycle assessment methodology and application’’.

Studentlitteratur AB. Lund, Sweden Studentlitteratur AB. Lund, Sweden

The Environmental Foundation Bellona :The Environmental Foundation Bellona : http://www.bellona.no/en/energy University of Newbrunswick (Canada) (University of Newbrunswick (Canada) (Petroleum and Natural Gas Processing):Petroleum and Natural Gas Processing):

http://www.unb.ca/che/che5134/smr.htm

ReferencesReferences

http://www.bellona.no/en/energy



http://www.unb.ca/che/che5134/smr.htm


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Tier III is broken in six parts:Tier III is broken in six parts:

• Description of the context: Hydrogen production via natural Description of the context: Hydrogen production via natural gas steam reforminggas steam reforming

• Problem statementProblem statement• Statement of the intentStatement of the intent• Report StructureReport Structure• RecommendationsRecommendations• IndexIndex

Unlike the previous two sections, this section does not have Unlike the previous two sections, this section does not have a quiz. The student must interpret the results of the above a quiz. The student must interpret the results of the above work and elaborate a succinct project report (15 - 20 pages).work and elaborate a succinct project report (15 - 20 pages).

Tier III: ContentTier III: Content


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Metric units of measure are used. Therefore, material consumption is Metric units of measure are used. Therefore, material consumption is reported in units based on the gram (e.g., kilogram or metric tonne), reported in units based on the gram (e.g., kilogram or metric tonne), energy consumption based on the joule (e.g., kilojoule or megajoule), energy consumption based on the joule (e.g., kilojoule or megajoule), and distance based on the meter (e.g., meter). When it can contribute to and distance based on the meter (e.g., meter). When it can contribute to the understanding of the analysis, the English system equivalent is stated the understanding of the analysis, the English system equivalent is stated in parenthesis. The metric units used for each parameter are given below, in parenthesis. The metric units used for each parameter are given below, with the corresponding conversion to English units.with the corresponding conversion to English units.

Mass:Mass: kilogram (kg) = 2.205 poundskilogram (kg) = 2.205 poundsMetric tonne (T) = 1.102 ton (t)Metric tonne (T) = 1.102 ton (t)

Distance: Distance: Meter (m) = 6200 mile = 3281 feetMeter (m) = 6200 mile = 3281 feetArea: Area: hectare (ha) = 10,000 m2 = 2.47 acreshectare (ha) = 10,000 m2 = 2.47 acresVolume: Volume: cubic meter (mcubic meter (m33) = 264.17 gallons) = 264.17 gallons

normal cubic meters (Nmnormal cubic meters (Nm33) = 0.02628 standard cubic feet (scf) ) = 0.02628 standard cubic feet (scf) at a standard at a standard temperature & pressure of 15.6°C (60°F) and 101.4 kPa temperature & pressure of 15.6°C (60°F) and 101.4 kPa (14.7 psi), (14.7 psi), respectivelyrespectively

Tier III: Units of measure Tier III: Units of measure

ANTONIO

megagram?meter instead of kmwhat is 1 x 106 g?


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Pressure: Pressure: kilopascals (kPa) = 0.145 pounds per square inchkilopascals (kPa) = 0.145 pounds per square inch

Energy:Energy: kilojoule (kJ) = 1,000 Joules (J) = 0.9488 Btukilojoule (kJ) = 1,000 Joules (J) = 0.9488 BtuGigajoule (GJ) = 0.9488 MMBtu (million Btu)Gigajoule (GJ) = 0.9488 MMBtu (million Btu)Terajoule (Tj) = 1.0 x 10Terajoule (Tj) = 1.0 x 1099 Joules (J) Joules (J)kilowatt-hour (kWh) = 3,414.7 Btukilowatt-hour (kWh) = 3,414.7 BtuGigawatt-hour (GWh) = 3.4 x 109 BtuGigawatt-hour (GWh) = 3.4 x 109 Btu

Power: Power: megawatt (MW) = 1 x 106 J/smegawatt (MW) = 1 x 106 J/s

Temperature:Temperature: °C = (°F - 32)/1.8°C = (°F - 32)/1.8

Hydrogen Equivalents:Hydrogen Equivalents:

1 kg H1 kg H22 = 423.3 scf gas = 11.126 Nm = 423.3 scf gas = 11.126 Nm33 gas gas

Tier III: Units of measure Tier III: Units of measure

ANTONIO

tera joule instead of tetra--


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Btu - Btu - British thermal unitsBritish thermal unitsCO2-equivalence- CO2-equivalence- Expression of the GWP in terms of CO2 for the following three Expression of the GWP in terms of CO2 for the following three

components CO2, CH4, N2O, based on IPCC weighting factorscomponents CO2, CH4, N2O, based on IPCC weighting factorsEIA - EIA - Energy Information AdministrationEnergy Information AdministrationGWP - GWP - global warming potentialglobal warming potentialHHV - HHV - higher heating valuehigher heating valueHTS - HTS - high temperature shifthigh temperature shiftIPCC- IPCC- Intergovernmental Panel on Climate ChangeIntergovernmental Panel on Climate ChangekWh - kWh - kilowatt-hour (denotes energy)kilowatt-hour (denotes energy)LCA - LCA - life cycle assessmentlife cycle assessmentLHV - LHV - lower heating valuelower heating valueLTS - LTS - low temperature shiftlow temperature shiftMMSFCD - MMSFCD - million standard cubic feet per daymillion standard cubic feet per dayMW - MW - megawatt (denotes power)megawatt (denotes power)N2O - N2O - nitrous oxidenitrous oxideNm3 - Nm3 - normal cubic metersnormal cubic metersNMHCs - NMHCs - non-methane hydrocarbonsnon-methane hydrocarbonsNOx - NOx - nitrogen oxides, excluding nitrous oxide (N2O)nitrogen oxides, excluding nitrous oxide (N2O)NREL - NREL - National Renewable Energy LaboratoryNational Renewable Energy LaboratoryPSA - PSA - pressure swing adsorptionpressure swing adsorptionSMR - SMR - steam methane reformingsteam methane reformingSOx - SOx - sulfur oxides, including the most common form of airborne sulfur, SO2sulfur oxides, including the most common form of airborne sulfur, SO2Stressor - Stressor - A term that collectively defines emissions, resource consumption, and A term that collectively defines emissions, resource consumption, and

energy use; a substance or activity that results in a change to the energy use; a substance or activity that results in a change to the natural natural environmentenvironment

Stressor category - Stressor category - A group of stressors that defines possible impactsA group of stressors that defines possible impactswt% - wt% - percentage by weightpercentage by weight

Tier III: Abbreviations and TermsTier III: Abbreviations and Terms


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1. Description of the context: Hydrogen production via natural gas steam reforming

2. Problem statement3. Statement of the intent

a. System boundariesb. Major assumptionsc. Data

4. Report Structure5. Recommandations6. Index

Tier III: OutlineTier III: Outline


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1.1. Description of the context: Hydrogen production via natural gas steam Description of the context: Hydrogen production via natural gas steam reformingreforming



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1.1. Description of the context: Hydrogen Description of the context: Hydrogen production via natural gas steam reformingproduction via natural gas steam reforming

1.1. Hydrogen (H1.1. Hydrogen (H22))Hydrogen is used in a number of industrial applications, with today’s largest Hydrogen is used in a number of industrial applications, with today’s largest consumers being ammonia production facilities (40.3 %), oil refineries consumers being ammonia production facilities (40.3 %), oil refineries (37.3%), and methanol production plants (10.0%). Because such large (37.3%), and methanol production plants (10.0%). Because such large quantities of hydrogen are required in these instances, the hydrogen is quantities of hydrogen are required in these instances, the hydrogen is generally produced by the consumer, and the most common method is generally produced by the consumer, and the most common method is steam reforming of natural gas. The figure below shows a simplified steam reforming of natural gas. The figure below shows a simplified flowsheet of the process utilised in this context for hydrogen production.flowsheet of the process utilised in this context for hydrogen production.

ANTONIO

Number, not numeralWe need a diagram to complement the explanation, like the one in page 24


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1.2. The process1.2. The processHydrogen can be produced from natural gas, oil or coal. Synthesis gas Hydrogen can be produced from natural gas, oil or coal. Synthesis gas production is a key step, as it gives access to a wide range of options. production is a key step, as it gives access to a wide range of options. Synthesis gas which is formed mainly by a mixture of CO and H2 is obtained Synthesis gas which is formed mainly by a mixture of CO and H2 is obtained either by steam-reforming, in the case of natural gas or by partial oxidation. either by steam-reforming, in the case of natural gas or by partial oxidation. Steam methane reforming is the most common and least expensive method Steam methane reforming is the most common and least expensive method of producing hydrogen. About half of the world's hydrogen is produced from of producing hydrogen. About half of the world's hydrogen is produced from SMR (Gaudernack, 1998). The process can be used also with other light SMR (Gaudernack, 1998). The process can be used also with other light hydrocarbon feedstocks, such as ethane and naphtha. The process is hydrocarbon feedstocks, such as ethane and naphtha. The process is endothermic and synthesis gas is typically produced in a tubular reformer endothermic and synthesis gas is typically produced in a tubular reformer furnace.furnace.


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Inlet temperatures are within the range 450-650°C and the product gas Inlet temperatures are within the range 450-650°C and the product gas leaves the reformer at 700-950°C, depending on the applications (Rostrup-leaves the reformer at 700-950°C, depending on the applications (Rostrup-Nielsen, 1993). The desulphurized feedstock is mixed with process steam Nielsen, 1993). The desulphurized feedstock is mixed with process steam and reacted over a nickel based catalyst contained in high alloy steel tubes. and reacted over a nickel based catalyst contained in high alloy steel tubes. Although the plant requires some stream for the reforming and shift Although the plant requires some stream for the reforming and shift reactions, the highly exothermic reactions results in an excess amount of reactions, the highly exothermic reactions results in an excess amount of steam produced by the plant. Due to the high operating temperature in the steam produced by the plant. Due to the high operating temperature in the reformer, the reformer effluent contains about 10-15 vol % CO (dry basis). reformer, the reformer effluent contains about 10-15 vol % CO (dry basis). A high-temperature shift (HTS) operating at an inlet temperature of 343 to A high-temperature shift (HTS) operating at an inlet temperature of 343 to 371°C makes possible to convert about 80 to 90% of the CO. This step uses 371°C makes possible to convert about 80 to 90% of the CO. This step uses a catalyst which is typically composed of copper oxide-zinc oxide on a catalyst which is typically composed of copper oxide-zinc oxide on alumina. A Pressure Swing Adsorption unit (PSA) is used for removing CO alumina. A Pressure Swing Adsorption unit (PSA) is used for removing CO and other contaminants present with hydrogen. and other contaminants present with hydrogen.


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If the CO2 which is present typically at the level of 15-20% has to be If the CO2 which is present typically at the level of 15-20% has to be recovered, it may be more appropriate to use a specific step for separating recovered, it may be more appropriate to use a specific step for separating CO2 from hydrogen by solvent scrubbing. An amine solvent is typically used CO2 from hydrogen by solvent scrubbing. An amine solvent is typically used for such a separation step. The hydrogen thus obtained, can be exported. for such a separation step. The hydrogen thus obtained, can be exported. Refining is presently the main consumer of hydrogen. It can be used also in Refining is presently the main consumer of hydrogen. It can be used also in a combined cycle for generating electricity. a combined cycle for generating electricity. Such a scheme provides therefore an attractive option for producing Such a scheme provides therefore an attractive option for producing electricity, without emitting CO2. Synthesis gas produced during the initial electricity, without emitting CO2. Synthesis gas produced during the initial step, can also be used for producing liquid hydrocarbon fuels, through step, can also be used for producing liquid hydrocarbon fuels, through Fischer-Tropsch synthesis. Thus, it is possible to transform any fossil fuel or Fischer-Tropsch synthesis. Thus, it is possible to transform any fossil fuel or biomass into hydrogen, electricity and liquid fuels.biomass into hydrogen, electricity and liquid fuels.


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2.2. Problem statementProblem statement



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2.2. Problem StatementProblem Statement

An oil & gas plant seeks to modernize by looking at 3 process options: An oil & gas plant seeks to modernize by looking at 3 process options: improving the environmental aspects, improving the performance of some improving the environmental aspects, improving the performance of some units of production to maximize the hydrogen production and finaly to install units of production to maximize the hydrogen production and finaly to install a better system of electronic control of the process. Your are the process a better system of electronic control of the process. Your are the process engineer in this firm. Your boss, the plant manager, wants you to do a study engineer in this firm. Your boss, the plant manager, wants you to do a study on the the total environmental aspects (quantification and analysis) of on the the total environmental aspects (quantification and analysis) of producing 48 MMscfd of hydrogen via natural gas steam reforming for the producing 48 MMscfd of hydrogen via natural gas steam reforming for the intern study. In recognition of the fact that upstream processes required for intern study. In recognition of the fact that upstream processes required for the operation of the Steam Methane Reforming (SMR) plant also produce the operation of the Steam Methane Reforming (SMR) plant also produce pollutant and consume energy and natural resources.pollutant and consume energy and natural resources.

The data colletion and validation have already been done by another The data colletion and validation have already been done by another engineer. engineer.

ANTONIO

not very clear..., which are the 3 options, etc


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2. Problem statement3.3. Statement of the intentStatement of the intent



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2.2. Problem statementProblem statement3.3. Statement of the intent Statement of the intent

a.a. System boundariesSystem boundaries



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3.3. Statement of the intentStatement of the intent

3.1. System boundaries3.1. System boundariesThis LCA should be performed in a cradle-to-grave manner, for this reason, This LCA should be performed in a cradle-to-grave manner, for this reason, natural gas production and distribution, as well as electricity generation, natural gas production and distribution, as well as electricity generation, were included in the system boundaries. The steps associated with were included in the system boundaries. The steps associated with obtaining the natural gas feedstock are drilling/extraction, processing, and obtaining the natural gas feedstock are drilling/extraction, processing, and pipeline transport. The next figure shows the System Boundaries for pipeline transport. The next figure shows the System Boundaries for Hydrogen Production via Natural Gas Steam Reforming.Hydrogen Production via Natural Gas Steam Reforming.

Raw material extraction

Raw material extraction

Production& distributionof electricity

Production& distributionof electricity

Constructionof equipmentConstructionof equipment

Production& distributionof natural gas


Hydrogenproduction

plant

Hydrogenproduction

plant



Natural gasboiler

Natural gasboiler

RecyclingRecycling

LandfillingLandfilling

x x x x

XX

EE

E

E

E

E

E

-E

-E

-RM

-Em

RM

RM

RM

RM

RMRM

-RM

-Em

Em

Em

Em

EmEm

Em

Em

M

E = energyEm = emissionsM = materialsRM = raw materials

Avoided operations


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3.3. Statement of the intentStatement of the intent 3.1. System boundaries3.1. System boundaries

For this study, the plant life was set at 20 years with 2 years of construction. For this study, the plant life was set at 20 years with 2 years of construction. In year one, the hydrogen plant begins to operate; plant construction takes In year one, the hydrogen plant begins to operate; plant construction takes place in the two years prior to this (years negative two and negative one). In place in the two years prior to this (years negative two and negative one). In year one the hydrogen plant is assumed to operate only 45% (50% of 90%) year one the hydrogen plant is assumed to operate only 45% (50% of 90%) of the time due to start-up activities. In years one through 19, normal plant of the time due to start-up activities. In years one through 19, normal plant operation occurs, with a 90% capacity factor. During the last year the operation occurs, with a 90% capacity factor. During the last year the hydrogen plant is decommissioned. Therefore, the hydrogen plant will be in hydrogen plant is decommissioned. Therefore, the hydrogen plant will be in operation 67.5% (75% of 90%) of the last year.operation 67.5% (75% of 90%) of the last year.


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a. System boundariesb.b. Major assumptionsMajor assumptions



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3.2. Major assumptions3.2. Major assumptions

A pretreatment on the natural gas is necessary to avoid emposoinment of A pretreatment on the natural gas is necessary to avoid emposoinment of the catalysts with the sulphur. The H2S is removed in a hydrogenation the catalysts with the sulphur. The H2S is removed in a hydrogenation reactor and then in a ZnO bed. After pretreatment, the natural gas and 2.6 reactor and then in a ZnO bed. After pretreatment, the natural gas and 2.6 MPa steam are fed to the steam reformer. The resulting synthesis gas is MPa steam are fed to the steam reformer. The resulting synthesis gas is then fed to high temperature shift (HTS) and LTS reactors where the water then fed to high temperature shift (HTS) and LTS reactors where the water gas shift reaction converts 92% of the CO into H2.gas shift reaction converts 92% of the CO into H2.

HydrogenationZnO BedCatalyticSteam Reforming

HighTemperatureShift

LowTemperatureShift

PressureSwing

Adsorption

Natural gas feedstock

Naturalgas fuel

Off-gas

steam

H2 product slipstream

H2

Hydrogen Plant Block Flow Hydrogen Plant Block Flow DiagramDiagram

ANTONIO

not very clear


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)(6.2)(8.4

requiredenergysteamMPayelectricitenergygasnaturalportedexenergysteamMPahydrogenproductinenergy

The hydrogen is purified (to 99.9% mol.) using a pressure swing adsorption The hydrogen is purified (to 99.9% mol.) using a pressure swing adsorption (PSA) unit. The reformer is fueled primarily by the PSA off-gas, but a small (PSA) unit. The reformer is fueled primarily by the PSA off-gas, but a small amount of natural gas is used to supply the balance of the reformer duty. amount of natural gas is used to supply the balance of the reformer duty. The PSA off-gas is comprised of CO2 (47.06 mol%), H2 (24.26 mol%), CH4 The PSA off-gas is comprised of CO2 (47.06 mol%), H2 (24.26 mol%), CH4 (19.59 mol%), CO (7.8 mol%), N2 (0.55 mol%), and some water vapor. The (19.59 mol%), CO (7.8 mol%), N2 (0.55 mol%), and some water vapor. The steam reforming process produces 4.8 MPa steam. Electricity is purchased steam reforming process produces 4.8 MPa steam. Electricity is purchased from the grid to operate the pumps and compressors. from the grid to operate the pumps and compressors.

The hydrogen plant energy efficiency is defined as the total energy The hydrogen plant energy efficiency is defined as the total energy produced by hydrogen plant divided by the total energy into the plant, produced by hydrogen plant divided by the total energy into the plant, determines by the following formula:determines by the following formula:

The base case of this analysis assumed that 1.4% of the natural gas that is The base case of this analysis assumed that 1.4% of the natural gas that is produced is lost to the atmosphere due to fugitive emissions. produced is lost to the atmosphere due to fugitive emissions.

ANTONIO

overall spelling, determined instead of determineschange font of formula, nor readable


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a.a. System boundariesSystem boundariesb. Major assumptionsc.c. DataData

Construction material RequirementConstruction material Requirement



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3.4.1. Construction material 3.4.1. Construction material requirement: requirement:

Construction Plant Materials Construction Plant Materials Requirements Requirements and pipelineand pipelineThe next table list materials requirements used for the plant in this study. A The next table list materials requirements used for the plant in this study. A

sensitivity analysis was performed how changing these numbers would sensitivity analysis was performed how changing these numbers would affect the results.affect the results.

Material Amount required(Mg)

Concrete 9504.6

Steel 3036.4

Aluminum 25.06

Iron 37.12

Hydrogen Plant Material Requirement (Base Case)Hydrogen Plant Material Requirement (Base Case)


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To move the natural gas from the oil or gas wells to the hydrogen plant, we To move the natural gas from the oil or gas wells to the hydrogen plant, we use pipelines. Because the main pipeline is shared by many users, only a use pipelines. Because the main pipeline is shared by many users, only a portion of the material requirement was allocated for the natural gas portion of the material requirement was allocated for the natural gas combined-cycle plant. For this analysis, the total length of pipeline transport combined-cycle plant. For this analysis, the total length of pipeline transport for the natural gas combined-cycle plant is assumed to be 425 km, it was for the natural gas combined-cycle plant is assumed to be 425 km, it was sized so that the total pressure drop in the pipe is of 0.05 psi/100 feet sized so that the total pressure drop in the pipe is of 0.05 psi/100 feet (0.001 MPa/100 meters). The pipe has a diameter of 31 inches assuming a (0.001 MPa/100 meters). The pipe has a diameter of 31 inches assuming a wall thickness of 1 inch. The steel used for the pipe construction has a wall thickness of 1 inch. The steel used for the pipe construction has a density of 7700 kg/m3. density of 7700 kg/m3.


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3.4.1. Air Emissions due to materials’ 3.4.1. Air Emissions due to materials’ constructionconstruction

Air emission g of emission/Kg of H2 produced

Benzene(C6H6) 1.4

CO2 1614.3

CO 5.46

CH4 50.3

NO2 6.86

N2O 0.0150

NMHCs 15.08

Particulate 0.504

SO2 6.48

The construction of materials The construction of materials requirements also produce a lot of requirements also produce a lot of air emissions. Because of lack of air emissions. Because of lack of data, we will suppose that those data, we will suppose that those constructions emit 2.8652 ton of constructions emit 2.8652 ton of particulate/hectare of the mill/month particulate/hectare of the mill/month of activity. of activity. You can suppose that NMHCs = 50% mass. benzene + 50% mass. You can suppose that NMHCs = 50% mass. benzene + 50% mass.

Toluene.Toluene.

Air emissions due to the plant constructionAir emissions due to the plant construction

ANTONIO

Air emissions are not "construction material", better to say emission due to constructing the materials, or similar


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a.a. System boundariesSystem boundariesb.b. Major assumptionsMajor assumptionsc.c. DataData

Construction material Requirement Natural gas composition and lostNatural gas composition and lost



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3.4.2. Natural gas composition and 3.4.2. Natural gas composition and loss loss

While natural gas is generally though of as methane, about 5-25% of the While natural gas is generally though of as methane, about 5-25% of the volume is comprised of ethane, propane, butane, hydrogen sulfide, and volume is comprised of ethane, propane, butane, hydrogen sulfide, and inerts (nitrogen, CO2 and helium). The relative amounts of these inerts (nitrogen, CO2 and helium). The relative amounts of these components can vary greatly depending on the location of the wellhead. The components can vary greatly depending on the location of the wellhead. The next table gives the composition of the natural gas feedstock use in this next table gives the composition of the natural gas feedstock use in this analysis, as well as typical pipeline and wellhead compositions. The analysis, as well as typical pipeline and wellhead compositions. The composition used in this study (first column) assumes that the natural gas composition used in this study (first column) assumes that the natural gas has undergo a pretreatment before entering the desulphurization reactor. has undergo a pretreatment before entering the desulphurization reactor. The natural gas feedstock contains up to 7 ppmv total sulfur, max. 5 ppmv The natural gas feedstock contains up to 7 ppmv total sulfur, max. 5 ppmv in the form of hydrogen sulphide (H2S) and max. 2 ppmv organic sulfur as in the form of hydrogen sulphide (H2S) and max. 2 ppmv organic sulfur as mercaptane. mercaptane.

ANTONIO

what is "lost" here?, maybe loss?


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Natural Gas CompositionNatural Gas CompositionNatural gas feedstock used in

analysisTypical range of wellhead components

(mol%)

Component Mol % (dry) Low value High value

Methane (CH4) 83.59 75 99

Ethane (C2H6) 10.19 1 15

Propane (C3H8) 1.15 1 10

Nitrogen (N2) 1.00 0 15

Carbon Dioxide (CO2) 0.78 0 10

Iso-butane (C4H10) 0.11 0 1

N-butane (C4H10) 0.17 0 2

Pentanes (C5+) 0.04 0 1

N-pentane 0.03 0 ----

N- +(C6) 0.03 0 ----

Hydrogen (H2) 2.91 0 ----


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In extracting, process, transmitting, storing and distributing natural gas, In extracting, process, transmitting, storing and distributing natural gas, some is lost to the atmosphere. Over the past two decades, the natural gas some is lost to the atmosphere. Over the past two decades, the natural gas industry and others have tried to better quantify the losses. There is a industry and others have tried to better quantify the losses. There is a general consensus that fugitive emissions are the largest source, accounting general consensus that fugitive emissions are the largest source, accounting for about 38% of the total, and that nearly 90% of the fugitive emissions are for about 38% of the total, and that nearly 90% of the fugitive emissions are a result of leaking compressor components. The second largest source of a result of leaking compressor components. The second largest source of methane emissions comes from pneumatic control devices, accounting for methane emissions comes from pneumatic control devices, accounting for approximately 20% of the total losses. approximately 20% of the total losses.

The majority of the pneumatic losses happen during the extraction step. The majority of the pneumatic losses happen during the extraction step. Engine exhaust is the third largest source of methane emissions due to Engine exhaust is the third largest source of methane emissions due to incomplete combustion in reciprocating engines and turbines used in incomplete combustion in reciprocating engines and turbines used in moving the natural gas through the pipeline. These three sources make up moving the natural gas through the pipeline. These three sources make up nearly 75 % of the overall estimated methane emissions. The remaining nearly 75 % of the overall estimated methane emissions. The remaining 25% come from sources such as dehydrators, purging of 25% come from sources such as dehydrators, purging of transmissions/storage equipment, and meter and pressure regulating transmissions/storage equipment, and meter and pressure regulating stations in distribution lines. stations in distribution lines.


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2. Problem statement3.3. Statement of the intent Statement of the intent

a. System boundariesb. Major assumptionsc.c. DataData

Construction material Requirement Natural gas composition and lost Production and distribution of electricityProduction and distribution of electricity



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3.4.3. production and distribution of 3.4.3. production and distribution of electricity electricity

Electricity is purchased from the grid to operate the pumps and Electricity is purchased from the grid to operate the pumps and compressors. The production was assumed to be the generation mix of coal, compressors. The production was assumed to be the generation mix of coal, lignite (hard coal), oil and fuel/natural gas. The process consume approx. lignite (hard coal), oil and fuel/natural gas. The process consume approx. 129,104 Mj/day. Each fuel provide respectively 3%, 2%, 72% and 23% of the 129,104 Mj/day. Each fuel provide respectively 3%, 2%, 72% and 23% of the total energy needed by the process. The stressors associated with this mix total energy needed by the process. The stressors associated with this mix should also determined in a cradle-to-grave manner. should also determined in a cradle-to-grave manner. The table below presents the quantity (in kg) of air emissions for each fossil The table below presents the quantity (in kg) of air emissions for each fossil fuel used for electricity production. Those data relate to a functional unit of fuel used for electricity production. Those data relate to a functional unit of 1 Tj net electricity delivered from the power plant.1 Tj net electricity delivered from the power plant.

Coal Fuel gas Oil Lignite

CO2 275833 245831 229380 370979

CO 56.6 81.97 75.15 45.1

NOx 451.7 408.44 488 12.6

SO2 1062.07 58.29 2359.4 3623.53

Particulates 321.59 16.13 96.87 257.66

N2O 1.79 1.5 5.53 1.8

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in kg


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2. Problem statement3.3. Statement of the intent Statement of the intent

a. System boundariesb. Major assumptionsc.c. DataData

Construction material Requirement Natural gas composition and lost Production and distribution of electricity HH22 Production plant Production plant




3.4.4. H3.4.4. H22 Production plant Production plant Hydrogenation and Hydrogenation and

DesulphurizationDesulphurizationAs the reformer catalyst is sensitive to poisoning from sulfur, sulfur in the As the reformer catalyst is sensitive to poisoning from sulfur, sulfur in the natural gasis processed in a Hydrogenation Reactor. Sulfur is totaly natural gasis processed in a Hydrogenation Reactor. Sulfur is totaly converted to hydrogen sulfide in this Hydrogenation reactor and will be converted to hydrogen sulfide in this Hydrogenation reactor and will be absorbed on the zinc oxide by conversion of ZnO to ZnS in the absorbed on the zinc oxide by conversion of ZnO to ZnS in the desulphurization reactor. Natural gas leaving the reactor will have a residual desulphurization reactor. Natural gas leaving the reactor will have a residual sulfur content of less than 0.2 ppmv.sulfur content of less than 0.2 ppmv.The total adsorption capacity of the desulphurization catalyst, based on total The total adsorption capacity of the desulphurization catalyst, based on total 7 ppmv sulfur in the feedstock will be for minimum 2 years of uninterrupted 7 ppmv sulfur in the feedstock will be for minimum 2 years of uninterrupted operation.operation.A small amount of hydrogen, which is recycled from the product stream, is A small amount of hydrogen, which is recycled from the product stream, is used in the Hydrogenation step to adjust the pressure in the reactor. The used in the Hydrogenation step to adjust the pressure in the reactor. The table below gives the caractheristics of the inflow of the hydrogenation table below gives the caractheristics of the inflow of the hydrogenation reactor.reactor. The flow in

Kg/h Kmol/h

Natural gas feedstock 17222 962

Hydrogen (H2) 57 28

Inflows to the hydrogenation reactorInflows to the hydrogenation reactor

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pressure


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3.4.4. H3.4.4. H22 Production plant Production plant Steam reformingSteam reforming

In the steam reforming, the mixture of desulphurized natural gas and In the steam reforming, the mixture of desulphurized natural gas and process steam (3358 kmol/h at 2.6 MPa (380 psi)) is reformed under process steam (3358 kmol/h at 2.6 MPa (380 psi)) is reformed under application or external heat. The principle chemical reactions taking place application or external heat. The principle chemical reactions taking place in the steam reformer are as follows:in the steam reformer are as follows:

Steam reformingSteam reforming heatHmnnCOOnHHC mn 22 )2/(

Water-gas Shift reaction (which is highly exothermic)Water-gas Shift reaction (which is highly exothermic)heatHCOOHCO 222

The effluent contains besides the products CO2 and residual CH4 and H2O. The effluent contains besides the products CO2 and residual CH4 and H2O. The reformed gas leaves the SR at 810ºC and approx. 25 kg/cm2 abs.. All The reformed gas leaves the SR at 810ºC and approx. 25 kg/cm2 abs.. All reactions take place simultaneously at about 560ºC. However, the reaction reactions take place simultaneously at about 560ºC. However, the reaction as a whole is endothermic. Those reactions take place over a nickel-based as a whole is endothermic. Those reactions take place over a nickel-based catalyst.catalyst.

The waste heat contained in the furnace flue gas is utilized for superheating The waste heat contained in the furnace flue gas is utilized for superheating of the reformer feedstock, generating of medium pressure steam, of the reformer feedstock, generating of medium pressure steam, superheating of the medium pressure steam and preheating of the superheating of the medium pressure steam and preheating of the combustion air. Those gases leave the reformer at approx. 1000ºC.combustion air. Those gases leave the reformer at approx. 1000ºC.


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Components % mol.

CO2 6.2

H2 43.73

N2 0.16

C1 4.75

C2 0

C3 0

i-C4 0

N-C4 0

i-C5 0

N-C5 0

N-C6 0

H2O 38.07

CO 7.08

The reformed gas compositionThe reformed gas composition


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The combustion air given is based on 5% excess air and enters the burner The combustion air given is based on 5% excess air and enters the burner at 380ºC and approx. 1.2 kg/cm2, at a rate of 123488 kg/h. It is composed at 380ºC and approx. 1.2 kg/cm2, at a rate of 123488 kg/h. It is composed of 20.4% mol. O2, 76.77% mol. N2 and 2.83% of H2O.of 20.4% mol. O2, 76.77% mol. N2 and 2.83% of H2O.Waste heat is recovered from the flue gas as well as from the reformed gas Waste heat is recovered from the flue gas as well as from the reformed gas to preheat and superheat process streams and for steam production. to preheat and superheat process streams and for steam production.

The natural gas utilized as fuel for the burner contains 5 ppmv of H2S and 2 The natural gas utilized as fuel for the burner contains 5 ppmv of H2S and 2 ppmv of mercaptane and has the following composition and ppmv of mercaptane and has the following composition and characteristics:characteristics:

Molar mass (kg/mol) 18.38

Flow in kmol/h 26.4

Pression (kg/cm2) 2

Temperature (ºC) 20


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Components % mol.

CO2 0.8

N2 1.02

C1 86.1

C2 10.5

C3 1.18

i-C4 0.11

N-C4 0.17

i-C5 0.04

N-C5 0.04

N-C6 0.04

The table below presents the The table below presents the composition of the flue gas at the composition of the flue gas at the outlet of the burners.outlet of the burners.

Components % mol.

CO2 19.28

O2 1.05

N2 60.28

H2O 19.38

Molar composition of of the natural gas used in the Molar composition of of the natural gas used in the burnerburner


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3.4.4. H3.4.4. H22 Production plant Production plant High Temperature Shift (HTS)High Temperature Shift (HTS)

The carbon monoxide, which is produced in the steam reformer, is The carbon monoxide, which is produced in the steam reformer, is converted by means of water vapor on a catalyst in a HTS reactor to converted by means of water vapor on a catalyst in a HTS reactor to hydrogen and carbon dioxide, according to the following reaction:hydrogen and carbon dioxide, according to the following reaction:

This reaction is highly exothermic, which leads to temperature rise of about This reaction is highly exothermic, which leads to temperature rise of about 50ºC. The CO-content at the outlet of the Shift reactor is less than 2 mol-%. 50ºC. The CO-content at the outlet of the Shift reactor is less than 2 mol-%. Subsequently the shifted gas is cooled down in different exchangers to Subsequently the shifted gas is cooled down in different exchangers to approx. 36ºC. Process condensate is separated in multiple liquid-gas approx. 36ºC. Process condensate is separated in multiple liquid-gas separators. The gas is then routed to the PSA Unit.separators. The gas is then routed to the PSA Unit.

heatHCOOHCO 222


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3.4.4. H3.4.4. H22 Production plant Production plant SeparatorsSeparators

The outflow gas from the HTS passes by different exchangers and liquid-The outflow gas from the HTS passes by different exchangers and liquid-gas separators. At the outlet of the last separator, we obtain two flows. On gas separators. At the outlet of the last separator, we obtain two flows. On flow of 481 kg/h of liquid water at 35ºC and a gaseous flow principally flow of 481 kg/h of liquid water at 35ºC and a gaseous flow principally composed of hydrogen (H2) and carbon dioxide (CO2) at a rate of 43186 composed of hydrogen (H2) and carbon dioxide (CO2) at a rate of 43186 kg/h (3945 kmol/h). The table bellow gives the molar composition of this kg/h (3945 kmol/h). The table bellow gives the molar composition of this gaseous flow:gaseous flow:

Component % mol.

CO2 16.92

CO 2.8

H2 72.7

H2O 0.27

N2 0.24

CH4 7.07

Molar composition of the gaseous outflow of the last Molar composition of the gaseous outflow of the last separator before the PSA unitseparator before the PSA unit



3.4.4. H3.4.4. H22 Production plant Production plant Pressure Swing absorption Pressure Swing absorption

(PSA)(PSA)For final purification a Pressure Swing Adsorption process is used. The For final purification a Pressure Swing Adsorption process is used. The reminder of undesired components are removed from the bulk of hydrogen reminder of undesired components are removed from the bulk of hydrogen by means of adsorption on molecular sieves using a PSA. The purification of by means of adsorption on molecular sieves using a PSA. The purification of hydrogen is based on selective adsorption of gas components such as CH4, hydrogen is based on selective adsorption of gas components such as CH4, CO, CO2, N2 and H2O. Hydrogen does not absorb and leaves the PSA unit CO, CO2, N2 and H2O. Hydrogen does not absorb and leaves the PSA unit as a product gas with high purity. Subsequently the pure hydrogen product as a product gas with high purity. Subsequently the pure hydrogen product is compressed and a small amount is recycled to upstream of the is compressed and a small amount is recycled to upstream of the Hydrogenation Reactor. Hydrogenation Reactor.

The adsorbed gases in the PSA are released and routed as off-gases to the The adsorbed gases in the PSA are released and routed as off-gases to the off gas which ensures a stable and constant supply of fuel gas to the off gas which ensures a stable and constant supply of fuel gas to the burners of the reformer.burners of the reformer.

The Hydrogen (H2) obtained from the PSA has a 99% molar purity. It leaves The Hydrogen (H2) obtained from the PSA has a 99% molar purity. It leaves the PSA Unit at 40ºC at 5149 kg/h (2525 kmol/h).the PSA Unit at 40ºC at 5149 kg/h (2525 kmol/h).


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3.4.4. H3.4.4. H22 Production plant Production plant Steam Generation SystemSteam Generation System

Waste heat from the process is utilized for steam generation. As the main Waste heat from the process is utilized for steam generation. As the main source of energy, the sensible heat of the reformed gas downstream Steam source of energy, the sensible heat of the reformed gas downstream Steam Reformer is used for steam production in Reformed Gas Waste Heat Boiler. Reformer is used for steam production in Reformed Gas Waste Heat Boiler. An other source of heat for steam generation is the waste heat of the flue An other source of heat for steam generation is the waste heat of the flue gas leaving the steam reformer. Here additional steam is produced in Flue gas leaving the steam reformer. Here additional steam is produced in Flue Gas Waste Heat Boiler.Gas Waste Heat Boiler.


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3.4.4. H3.4.4. H22 Production plant Production plant Shut downShut down

The process is shuted down for 24 hours every 2 years to change the The process is shuted down for 24 hours every 2 years to change the catalysts. Duringcatalysts. During start-up of the process or PSA Unit failure, we use a start-up of the process or PSA Unit failure, we use a burners’ fuel (for the SR) composed in majority of natural gas (12.88 the burners’ fuel (for the SR) composed in majority of natural gas (12.88 the mole rate of the natural gas used in normal operation case) completed with mole rate of the natural gas used in normal operation case) completed with Raffinery fuel. The mole ratio of thoses two fuels is 8.5.Raffinery fuel. The mole ratio of thoses two fuels is 8.5.

ANTONIO

spelling, what is thoses


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2. Problem statement3. Statement of the intent

a. System boundariesb. Major assumptionsc. Data

4.4. Report structureReport structure



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4.1. Questions for discussion4.1. Questions for discussion

1- Quantify the environmental loads - resource use and pollutant air 1- Quantify the environmental loads - resource use and pollutant air emissions - of the system.emissions - of the system.2- Make the results more environmentally relevant by translating the 2- Make the results more environmentally relevant by translating the emissions using environmental themes method. Identify and evaluate the emissions using environmental themes method. Identify and evaluate the environmental impacts of the process by making an impact assessment by environmental impacts of the process by making an impact assessment by calculating the total impact. The index list is in the Index towards the end calculating the total impact. The index list is in the Index towards the end of the problem.of the problem.


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4.1. Questions for discussion4.1. Questions for discussion

3- Make a sensitivity study and identify the most important parameters 3- Make a sensitivity study and identify the most important parameters toward their influence on the results of this study.toward their influence on the results of this study.4- Examine the net emission of greenhouse gases, as well as the major 4- Examine the net emission of greenhouse gases, as well as the major environmental consequences.environmental consequences.5- Substitutions scenarios: What possible improvements on the system 5- Substitutions scenarios: What possible improvements on the system could we do ?could we do ?7- Make a cost-benefit Analysis, typically involves an economic ROI study.7- Make a cost-benefit Analysis, typically involves an economic ROI study.8- Since Risk is another matter not dealt with in LCA, we won’t ask you 8- Since Risk is another matter not dealt with in LCA, we won’t ask you about it but you should write a short paragraph about the Ecological Risk about it but you should write a short paragraph about the Ecological Risk Assessment (ERA) related to this process.Assessment (ERA) related to this process.


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4.2. Suggestion for Report Table of 4.2. Suggestion for Report Table of ContentsContents

1.1. Executive summuryExecutive summury2.2. IntroductionIntroduction3.3. ObjectivesObjectives4.4. Summury of resultsSummury of results5.5. Sensitivity AnalysisSensitivity Analysis6.6. Impact AssessmentImpact Assessment7.7. Impovement OpportunitiesImpovement Opportunities8.8. ConclusionsConclusions


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2.2. Problem statementProblem statement3.3. Statement of the intentStatement of the intent

a.a. System boundariesSystem boundariesb.b. Major assumptionsMajor assumptionsc. Data

4. Report structure5.5. RecommendationsRecommendations



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5.5. RecommendationsRecommendations

1.1. When reporting the final results of your work it is important to When reporting the final results of your work it is important to thoroughly describe the methodology used in this analysis. The thoroughly describe the methodology used in this analysis. The report should explicitly define the system analyzed and the report should explicitly define the system analyzed and the boundaries that were set.boundaries that were set.

2.2. All assumptions or decisions made in performing the work All assumptions or decisions made in performing the work should be clearly explained and reported along side the final should be clearly explained and reported along side the final results of this project.results of this project.

3.3. The results should not be oversimplified solely for the purposes The results should not be oversimplified solely for the purposes of presentation.of presentation.

4.4. All the environnemental data needed to do this work are given All the environnemental data needed to do this work are given towards the end of the problem (in the Index).towards the end of the problem (in the Index).

5.5. You should respect the international standards for LCA (ISO You should respect the international standards for LCA (ISO 14040-14043) when performing the different steps of the 14040-14043) when performing the different steps of the analyze.analyze.


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End of Tier IIIEnd of Tier III

• This is the end of Module 14. Please submit your report to your professor This is the end of Module 14. Please submit your report to your professor for grading. for grading.

• We are always interested in suggestions on how to improve the course. We are always interested in suggestions on how to improve the course. You may contact us atYou may contact us at www.namppimodule.org

http://www.namppimodule.org/


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INDEX


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To meet the needs of this study, categorization and less-is-better approaches To meet the needs of this study, categorization and less-is-better approaches have been taken. The next table summarizes the stressors categories and main have been taken. The next table summarizes the stressors categories and main stressors from the natural gas steam reforming, hydrogen production system. stressors from the natural gas steam reforming, hydrogen production system.

Impact Impact CategoriesCategories

Substance Static reserve life (years)

Natural gas 0.0187 kg Sbeq/m3.

Hard coal 0.0134 kg Sbeq/kg

Soft coal 0.00671 kg Sbeq/kg

Fossil energy 4.81 x 10-4 kg Sbeq/Mj

1. Depletion of abiotic resources1. Depletion of abiotic resources

Depletion equivalents for abiotic Depletion equivalents for abiotic resources, expressed relative to resources, expressed relative to

antimony (Sb) and based on ultimate antimony (Sb) and based on ultimate reserves.reserves.


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2. Global warming2. Global warming

Trace gas GWP 100 years(kg CO2 eqv/kg)

CO2 1

CH4 25

N2O 310

NO2 320

3. Acidification3. Acidification

Substance AP (g SO2 eqv/g)

SO2 1

NOx 0.7

Global warning potentials for Global warning potentials for 100 years expressed in 100 years expressed in

relative to CO2relative to CO2

Generic acidification equivalents expressed relative to SO2 (CML/NOH 1992;

in CML 2002)


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4. Photochemical ozone creation potential (contribution to smog)4. Photochemical ozone creation potential (contribution to smog)

Substance High NOx POCPs (kg ethylene/kg)

CO 0.027

NO2 0.028

Methane 0.006

Ethane 0.123

Propane 0.176

N-butane 0.352

N-pentane 0.395

N-C6 0.495

Benzene 0.218

Toluene 0.637

Photochemical ozone creation potentials (POCPs) for high NOx background

concentrations expressed relative to ethylene (CML 2002)


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5. Human toxicity5. Human toxicityHuman toxicity potentiels, HTPinf, for infinite horizon and global scale. The indicators Human toxicity potentiels, HTPinf, for infinite horizon and global scale. The indicators are expressed relative to 1,4-dichlorobenzeneare expressed relative to 1,4-dichlorobenzene

6. Eutrophication6. EutrophicationGeneric eutrophication equivalents for emissions to air, water and soil. Indicators are Generic eutrophication equivalents for emissions to air, water and soil. Indicators are expressed relative to PO3-4 (CML/NOH 1992; CML 2002).expressed relative to PO3-4 (CML/NOH 1992; CML 2002).

Substance HTP for emissions to air

NO2 1.2

SO2 0.096

Benzene 1900

Toluene 0.33

Substance (g PO3-4 /g)

PO3-4 1

H3 PO4 0.97

P 3.06

NH3 0.35

NH4+ 0.33

N 0.42


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Impacts Associated with Stressor CategoriesImpacts Associated with Stressor Categories

L, RH, ECatalysts, coal

ash (indirectly), flue gas clean up waste (indirectly)

Solid waste

R, GEFossil fuels,

water, minerals and ores

Resource depletion

LH, ENMHCs, benzeneOther stressors with toxic effectsLESO2, H2S, H2OContributors to corrosion

L, RH, ESO2, NOx, CO2Acidification precursorsL, RH, ENOx, VOCsPhotoquemicalContributors to smog

L, RH, EParticulates

R, GH, ECO2, CH4, N2O,

CO and NOx (indirectly), water vapor

GreenhouseGasesClimate change

R, GH, ENOOzone depletion compoundsMinorMajor

Area impacted L=local (country) R=regional (state)

G=global

Major Impact category

H=human health E=ecological health

StressorsStressors categories

L, RH, ECatalysts, coal

ash (indirectly), flue gas clean up waste (indirectly)

Solid waste

R, GEFossil fuels,

water, minerals and ores

Resource depletion

LH, ENMHCs, benzeneOther stressors with toxic effectsLESO2, H2S, H2OContributors to corrosion

L, RH, ESO2, NOx, CO2Acidification precursorsL, RH, ENOx, VOCsPhotoquemicalContributors to smog

L, RH, EParticulates

R, GH, ECO2, CH4, N2O,

CO and NOx (indirectly), water vapor

GreenhouseGasesClimate change

R, GH, ENOOzone depletion compoundsMinorMajor

Area impacted L=local (country) R=regional (state)

G=global

Major Impact category

H=human health E=ecological health

StressorsStressors categories


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Economic dataEconomic data

The reactorThe reactor The catalystThe catalyst DescriptionDescription Quantity Quantity (m(m33))

PricePrice

Desulphurisation Desulphurisation reactorreactor

Zinc Oxide Zinc Oxide Desulphurisation Catalyst Desulphurisation Catalyst

(ZnODs)(ZnODs)

Zinc Oxide based catalyst Zinc Oxide based catalyst having specific physical having specific physical and textural properties and textural properties blended with suitable blended with suitable binders in the form of binders in the form of pelletspellets

16.516.5 3.5 3.5 US/lbUS/lb

SRSR Nickel BasedNickel Based A nickel based catalyst on A nickel based catalyst on alpha alumina carrier or alpha alumina carrier or calcium aluminate calcium aluminate compound in the form of compound in the form of rings/high geometric rings/high geometric surface rings.surface rings.

23.623.6 3.237 3.237 US/LUS/L

HTSHTS Copper Oxide-Zinc Oxide Copper Oxide-Zinc Oxide on Alumina on Alumina

An iron chrome and An iron chrome and copper promoted iron copper promoted iron chrome based catalyst.chrome based catalyst.

36.536.5 5.198 5.198 US/LUS/L

Hydrogenation Hydrogenation reactorreactor

------------------------------------------ ------------------------------------------ 7.27.2 ----------

CatalystsCatalysts

Due to lack of data, we suppose that all these catalysts have the same Due to lack of data, we suppose that all these catalysts have the same density than water.density than water.


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Equipment Description/Utility Quantity

VesselVessel For waterFor water 11CompressorCompressor Centrifugal; Emotor; Isentropic; Combustion Air Centrifugal; Emotor; Isentropic; Combustion Air

FanFan33

CompressorCompressor Centrifugal; Emotor; Isentropic; Flue gas FanCentrifugal; Emotor; Isentropic; Flue gas Fan 22CompressorCompressor H2 compressor, Reciprocating, IsentropicH2 compressor, Reciprocating, Isentropic 22DrumDrum Steam condensateSteam condensate 11DrumDrum Tank and deaeratorTank and deaerator 11DrumDrum For flare gasFor flare gas 11DrumDrum Gas separatorGas separator 11DrumDrum Shifted gas separatorShifted gas separator 11DrumDrum Shifted gas separatorShifted gas separator 11DrumDrum For fuel gasFor fuel gas 11Shell- tube Shell- tube HEHE

Feed preheaterFeed preheater 11

EquipmentEquipment


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Economic dataEconomic dataShell- tube Shell- tube HEHE

BFW-PreheaterBFW-Preheater 11

Shell- tube Shell- tube HEHE

Reformed gas final coolerReformed gas final cooler 11

Plate HEPlate HE Blow down coolerBlow down cooler 11Air CoolerAir Cooler Reformed gas air coolerReformed gas air cooler 11Static MixerStatic Mixer At the feedAt the feed 11PumpsPumps Centrifugal; team turbineCentrifugal; team turbine 22PumpsPumps Flare condensate; Drum pumpFlare condensate; Drum pump 22ReactorReactor Hydrogenation with jacketHydrogenation with jacket 11ReactorReactor Desulphurization, jacketDesulphurization, jacket 11ReactorReactor HTSHTS 11SteamturbineSteamturbine For BFW pump; back-pressure turbineFor BFW pump; back-pressure turbine 11SteamturbineSteamturbine Turbine for Fluegas Fan; back-pressure turbineTurbine for Fluegas Fan; back-pressure turbine 22

TOTALTOTAL

2525Also consider that you need 3 feeds for the alimentation and the effluents and that you have 2 purges.Consider also that we use a Straightline depreciation during 10 years with a resale price of 0$.


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Economic dataEconomic dataHH22 price price

Gray and Tomlinson (2000) Gray and Tomlinson (2000) proposed equations to calculate the hydrogen proposed equations to calculate the hydrogen costs based on the prices of fuels in the world-wide market, in these costs based on the prices of fuels in the world-wide market, in these equations it is assumed that the value of hydrogen is equal to the cost of equations it is assumed that the value of hydrogen is equal to the cost of producing it from reformation. Based on this the cost of sale of hydrogen is producing it from reformation. Based on this the cost of sale of hydrogen is given by:given by: CSH = 0.45•CGN + 0.76 CSH = 0.45•CGN + 0.76 Where:Where:

CSH = Cost of Hydrogen CSH = Cost of Hydrogen DutyDuty ($/MPCSD) ($/MPCSD)CGN = Cost of Natural Gas ($/MMBtu)CGN = Cost of Natural Gas ($/MMBtu)

Gray y Tomlinson (2000)Gray y Tomlinson (2000) also established a simple equation to estimate the also established a simple equation to estimate the cost of the natural gas in function of the price of petroleum in the world, cost of the natural gas in function of the price of petroleum in the world, which is:which is:

CGN = 0.13CGN = 0.13••PPM PPM Where:Where:

PPM = Price of the Petrol in the World ($/BBL)PPM = Price of the Petrol in the World ($/BBL)

Most of the hydrogen produced at the present time is consumed in its site of Most of the hydrogen produced at the present time is consumed in its site of production. When it is sold in the market, to its production cost is added the production. When it is sold in the market, to its production cost is added the cost of liquefying it and of transporting it.cost of liquefying it and of transporting it.

ANTONIO

why those equation numbers?, same in next pages


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Electricity costElectricity costIn order to calculate the cost of the electricity used to produce hydrogen, In order to calculate the cost of the electricity used to produce hydrogen, Gray and Tomlinson (2000) assumed that the value of the electricity is Gray and Tomlinson (2000) assumed that the value of the electricity is determined by the cost of producing it with a advanced plant of combined determined by the cost of producing it with a advanced plant of combined cycle of natural gas. It was assumed that the cost of capital of this type of cycle of natural gas. It was assumed that the cost of capital of this type of plants is of $494/kw and an amount of specified energy of 6.396 BTU/KW. plants is of $494/kw and an amount of specified energy of 6.396 BTU/KW. Based on these estimations the sale price required of the electricity it is Based on these estimations the sale price required of the electricity it is given by the following equation:given by the following equation:

CEPH = 0.0064•CGN + 0.0116CEPH = 0.0064•CGN + 0.0116 Where: Where:

CEPH = Cost of electricity for produce hydrogen ($/KWh)CEPH = Cost of electricity for produce hydrogen ($/KWh)

...the end....the end.

module 14. “life cycle assessment (lca)”

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