dhelk solutions - presentation 3 v9.pptx

7/27/2019 DHELK Solutions - Presentation 3 v9.pptx

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Presentation Outline Introduction Process Description

Process Modeling

Mass and Energy Balance

Exergetic Analysis Economic Analysis

Sustainability Metrics

Sustainable Development

Questions and Suggestions


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Introduction Enhanced Coal Bed Methane; CSG + CO2 Capture and storage

enhanced methane recovery.

Project Requirements: 250MW ECBM Power Generation Plant.

Zero net Greenhouse Gas emissions.

Focus on power production and CO2 capture techniques. Project Description:

CO2 injection into coal bed to stimulate release of natural gas.

CBM contains 70% CH4 as well as CO2, N2 and water.


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Site Selection

Location: Surat Basin, QLD, Australia (Macalister Coal Seam)Low rank coal except as a shallower depth thus is easier to desorbmethane, resulting in higher recovery fractions

Map Produced from Queensland's IRTM System

The State of Queensland (Department of Natural Resources and Mines) 2009-2012. While every care is taken to ensure the accuracy of this product, the Department of Natural Resources and Mines makes no representations or warranties about its accuracy, reliability,completeness or suitability for any particular purpose and disclaims all responsibility and all liability (including without limitation, liability in negligence) for all expenses, losses, damages (including indirect or consequential damage) and costs which you might incur as aresult of the product being inaccurate or incomplete in any way and for any reason.

SITE Dalby


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CO2 Capture Oxy-fuel, Pre-combustion.

Post-Combustion.


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CO2 Capture Absorber and stripper.

Solvent Monoethanolamine (MEA).


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Power Generation Natural Gas Combined Cycle

High temperature Brayton cycle followed by low temperature Rankine cycle.

Independent steam cycle.


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Boundary Conditions Assumptions:

Complete combustion.

For every mole of CO2 adsorbed, 2.5 additional moles of CH4 isdesorbed.

Reservoir has unlimited storage capacity for CO2.

The design of the following processes has been contracted toFluor:

Subsurface design and ancillary surface equipment.

Brine Treatment.

Solid waste transport and treatment.


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Process Overview


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Model 1 Model Assumptions:

Composition of Coalbed methane = 70mol% CH4

Complete combustion of CH4. No NOx or SOx production. Combustion with 5% excess air.

Simple Design: Rstoic, Separators & Single Turbine Little Heat Integration. Optimisation of Methane & Steam Flow Rate using Design Specs. thermal = 25%.


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Model 2 HP, IP and LP Steam Turbines

Unrealistically high flue gas temperature More heat recovered. Less lost to waste steam.

thermal = 29%


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Model 3 More accurate model of steam heating within boiler. Flue gas at realistic temperature. Used to preheat air and methane.

Multistage compression with intercooling implemented: Reduced work requirements and capture of heat of compression. Capital Expenditure vs Reduced Operating Expenses.

Improved Carbon Capture Model: CO2 combined with cool, lean MEA solution. Heat requirements of MEA reboiler modeled. Heat sourced from compressor intercooling and flue gas excess heat


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Model Comparison

Model 3 most efficient with lowest CO2 emissions.

58g CO2/kWh compared to 570g/kWh for conventional plant.

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ThermalEfficie

ncy(%)

Flow

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Model

Methane in (mol/s) CO2 Emmisions (mol/s) Thermal Efficiency


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Mass and Energy Balance

Stream no. 1 5 7 9 14 16 20 22 23 24 29 48

Description CBM Air Hot Air Flue Gases Water MEA Flue Gas Liquid CO2 Water Fresh Steam Waste Steam Work

From Feed Feed B4 B5 B7 B13 B8 B9 B17 B10 B15 Turbines

To B1 B3 B5 B6 Waste B10 Stack Coal Seam B10 B11 B16 Grid

Phase Mixed Vapor Vapor Vapor Liquid Liquid Vapor Vapor Liquid Vapor Vapor Work

Mole Flow (mol/s) -

CH4 910 - - - - - - - - - - -

H2O 352 - - 1820 1820 1255 - - 5785 5785 5785 -

CO2 5 - - 914 - - 91 823 - - - -

O2 - 1911 1911 91 - - 91 - - - - -

N2 33 7188 7188 7221 - - 7221 - - - - -

MEA - - - - - 1255 - - - - - -

Total Flow (mol/s) 1300 9099 9099 10047 1820 2510 7404 823 5785 5785 5785 -

Temperature (K) 298 298 1123 1773 373 313 393 429 312 873 449 -

Pressure (MPa) 0.1 0.1 3 3 0.1 0.1 0.1 15.3 16.7 16.7 0 -

Enthalpy (kJ/mol) -130.6 0 25.9 -26.4 -281.6 -269.6 -2.1 -391.6 -286.3 -223.9 -236.7 -Enthalpy (MW) -169.8 -0.1 235.5 -264.9 -512.5 -676.8 -15.4 -322.3 -1656.3 -1295.4 -1369.1 -250


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Exergetic Analysis

Exergy Maximum useful work obtainable from a system at a given state.

Irreversibility Exergy destroyed during a process

Dead State 298.15K and 1 atm

Compressors and Gas Turbine major areas of irreversibility.

Future optimisation to further improve overall process efficiency

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Economic Analysis High variability in electricity and gas prices

Potential shortage of domestic natural gas in Queensland

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Price($/MWh)

QLD Wholesale Electricity Prices

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Price($/GJ)

QLD Gas Prices - 2012/13

An uncertain future for the Carbon Tax

Switch to Emissions Trading Scheme in 2016 $12.10 per tonne CO2e

May be gone as soon as September


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Economic Analysis

Sources: National State Economic Forecasts to 2034 - (NIEIR, 2012)

Australian Energy Market Operator Historical Prices

Carbon Capture Approaches for NGCC Systems (NETL, 2010)

Carbon Tax Conditions: Floating price in FY16 forecast to drop to $12.10

Free permits issued for 95% of CO2 sequestered.

CurrentAnnual Growth Rate

To FY16 To FY43

Electricity ($/MWh) 56.60 5.50% 3.30%

Natural Gas ($/GJ) 4.95 4.10% 4.00%

Carbon Tax ($) 23 $24.15 , $25.40 $122.50

Capital Cost ($) 257,972,802 - -

Plant Life 30 years - -

Discount Rate (%) 10% - -

Gas Consumed (kmol/y) 28,695,002

Gas Consumed (GJ/y) 23,023,148

Power Produced (MWh/y) 2,190,000

CO2 emissions (t/y) 126,918

CO2 sequestered (t/y) 1,142,258

Cost Forecasts Yearly Plant Data


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Discounted Payback Period

-$300M

-$250M

-$200M

-$150M

-$100M

-$50M

$M

$50M

$100M

$150M

$200M

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NPV($million

s)

Year

Discounted Payback Period = 12.8 years

Undiscounted Payback Period = 7.5 years

Discounted Payback Period = 12.8 yrs


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Internal Rate of Return

Internal rate of return = 15.4%

Borderline commercial viability

May require government incentives such as CCS Flagships program

-$400M

-$200M

$M

$200M

$400M

$600M

$800M

$1000M

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NPV($m

illions)

Discount Rate (%)

NPV = $162,399,076

IRR = 15.4%


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Sustainable Development

AusPlume Modeling


Social/Political Drivers

Compliance with Sustainable Development


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AusPlume

Model CO2 and N2 release rates to evaluate effects onsurrounding receptors

Site3km

3km

D(-8, -8)

C(8, -5)

A(10, 6) B

(15, 5)

N

S

EW

Kogan

Tara


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Emission rates

AusPlume

Worst case scenario for emissions spread


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AusPlume


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a measure of sustainability performance of an operating unit- Quantifies the benefit of implementing sustainability

Emissions

Environmental Burden


))(( ,1

NiN

ni

ii PFWEB


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Land Use- 3 km2 occupied by the site including a buffer zone for OHS

- Land rehabilitation for use by the Traditional Owners

- Infrastructure removal, treatment of contaminated areas andrevegetation.



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Social and Political Drivers Inextricably linked! Social Political Drivers. Currently, Society is unimpressed by CSG.

Increase strength of local economy.

Cultural Heritage; Barunggam tribe

Political Drivers; using legislation, tax and incentives. Mining and Carbon Tax.

Incentives; for clean, efficient energy or renewable. Clean Energy Finance Corporation; $10 billion.

Clean Technology Innovation Program; $200 million.

How will a change in governmentaffect this?

Source; The Telegraph 2010 (ABC 2013)


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Sustainable Development Compliance

ECBM is the most sustainable fossil fuel due to efficientuse of resources and zero net carbon emissions.

However, not sustainable since it uses a finite resource.

Lifecycle Assessment should be performed.

Some examples show that ECBM falls short onAcidification, Ozone Layer Depletion and Fossil FuelDepletion.

development that meets the

needs of the present without

compromising the ability of future

generations to meet their own

needs (Vesilind 2009)


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Switched on to a brighter future

dhelk solutions - presentation 3 v9.pptx

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