Latest Buzz...
                  

Translate

Showing posts with label Clean Energy Future. Show all posts
Showing posts with label Clean Energy Future. Show all posts

Monday, February 14, 2022

Zero-emission fertiliser production

Production of urea fertiliser with existing technology and natural gas as both a feedstock and fuel creates substantial carbon dioxide emissions and is very expensive due to high fossil fuel energy costs. 

Just one modification can reduce the carbon dioxide emissions to zero - and substitute lower-cost renewable energy: 

Natural gas is reformed with steam into hydrogen and carbon dioxide using solar energy. The technology to use renewable energy for this step was developed by the CSIRO and has been marketed commercially.

This approach of changing natural gas with steam to carbon dioxide and hydrogen is described as Autothermal Reforming. For further reading, see "Difference Between Steam Reforming and Autothermal Reforming".

One tonne of urea fertiliser contains 200 kilograms of carbon. To achieve zero-emissions ONLY just enough natural gas to supply the carbon that will be incorporated into the end product is required: there is no extra carbon that would be emitted as carbon dioxide. 

Natural gas containing 200 kilograms of carbon for one tonne of urea has an energy content of 14.8 gigajoules. At $10 per gigajoule, natural gas costing $148 is sufficient to make one tonne of urea.

Prices to remain high.
(From the ABC article "Farmers turning to alternative growing methods in wake of sky-high fertiliser price")

Analyst Andrew Whitelaw said the huge price hikes in fertiliser all boiled down to one factor: high energy costs.

"I just don't see it [fertiliser prices] falling massively. We don't see it getting back into the A$800 or less mark, by the time we have to buy. We're liable to have high prices for Australia right through to our seeding period."
Andrew Whitelaw from Thomas Elders Markets says fertiliser prices have climbed an extraordinary amount. (ABC News)
Andrew Whitelaw from Thomas Elders Markets says
fertiliser prices have climbed an extraordinary amount. (ABC News)


One tonne of urea can be made in the following steps:

  1. methane + water => hydrogen + carbon dioxide
  2. nitrogen + hydrogen => ammonia
  3. ammonia + carbon dioxide => ammonium carbamate
  4. ammonium carbamate => urea + water

All of the carbon dioxide produced in step 1 is consumed in step 3. 

Half of the water consumed in step 1 is recovered in step 4.

Inputs consumed are the methane and half the water used in step 1 and the nitrogen used in step 2.

The only outputs are one quarter of the hydrogen from step 1 and urea from step 4. 

This method produces zero-emission hydrogen with renewable energy, in parallel with the manufacture of urea. 

Hold that thought.

After considering what seems a novel approach to zero-emissions fertiliser manufacture, (or indeed, any 'novel' idea in any industry) it is always worth doing a patent search to check if the 'novel' idea has in fact been developed by someone else.

And so it is in this case. 

A patent search turns up a patent "Zero emission urea process and plant". The abstract begins: 

"Disclosed is a method for the production of urea allowing a substantial reduction , even down to zero , of the continuous emission of ammonia conventionally resulting from such a process. ..."
The above patent addresses only the reaction of carbon dioxide and ammonia. 

The same inventors also have a patent for the production of the hydrogen and carbon dioxide that are required to make urea, "Process for producing ammonia and urea". The abstract begins:

"Disclosed is a process for the production of ammonia comprising a step wherein synthesis gas is formed in two different ways, viz. by catalytic partial oxidation (31) and by steam reforming, and wherein the combined streams of synthesis gas are subjected to a water gas shift reaction (50). Also disclosed is a process of producing urea, wherein ammonia is formed (90) in a process involving said combined streams and wherein carbon dioxide (110) formed in the same process is reacted with said ammonia so as to form urea."
The assignee of the technology, Stamicarbon, says on its website: 

"As the world market leader in design, licensing and development of urea plants for the fertilizer industry, we apply our expertise, knowledge and experience for many solutions; fertilizer production technologies, emission reduction technologies and all technologies for the integration of urea and adjacent processes."


Wednesday, January 26, 2022

Diesel Locomotives may be powered by Grid-Scale Batteries

The New South Wales Environment Protection Authority commissioned a study in 2014 on the emissions and efficiency of diesel locomotives in use by Pacific National - "DIESEL LOCOMOTIVE Fuel efficiency & Emissions Testing". 

Pacific National Diesel-Electric Locomotive NR121
Pacific National Diesel-Electric Locomotive NR121

 

The test report includes the electric power output of the diesel engines used in the testing program, and the quantity of fuel needed for operating the locomotives between Melbourne and Brisbane. 

This data allows the calculation of the output and storage capacity of a grid scale battery that, if installed in a rail car, would replace the diesel engine, electric generator, and diesel fuel used by Pacific National's diesel locomotives. 

The financial analysis - to choose the time for conversion from diesel to battery power - is a separate matter. When the business case favours the conversion will depend on the falling cost of grid-scale energy storage options and the security of diesel fuel supplies. It is only a matter of time. That is to say it is a question of "when", not "if", the conversion is a good financial proposition. 

The energy requirements. 

Two Pacific National diesel locomotives are described in the report for the NSW EPA. 

Each had diesel electric power output of between 3,000 and 3,500 kilowatts - about 3.5 MW. 

The fuel capacity was 12,500 litres of diesel fuel - sufficient for operating from Melbourne to Brisbane without refuelling. 

The fuel consumption was about 210 grams of diesel for each kWh generated. 

Diesel has a density of about 0.85 kilograms per litre.  See "2.3.5 Diesel Fuel".

With a few calculations - 12,500 litres of diesel weigh 10,625 kgs. 

At 210 grams per kWh, 10,625 kgs of diesel can generate a little over 50,000 kWh or 50 MWh of electrical energy. 

A grid-scale energy storage unit able to deliver 4 MW of output power with 50 MWh of storage capacity is in the range of Battery Energy Storage Systems currently being delivered be energy storage manufacturers. 

See for example -  "In New York, a high-level demonstration project is using a 4 MW / 40 MWh battery storage system..." reported in Battery Storage Paves Way For a Renewable-Powered Future

The Business Case.

Pricing information and other details required for a financial analysis and business case for converting Pacific National's diesel locomotives to battery energy storage systems for the time being is not easily obtained. 

Some indicative estimates can be calculated - 

  • 12,500 litres of fuel are loaded for a single trip from Melbourne to Adelaide. At $1 per litre, the fuel costs $12,500. 
  • Electrical energy for the trip is 50 MWh. At $50 per MWh, the energy cost would be $2,500 - a saving of $10,000 per trip. If 200 trips were made each year, the fuel saving would be $2 million per year. 

If it is physically not practical to use a 50 MWh Battery Energy Storage System due to its size and weight, this could explain the interest in development of hydrogen with fuel cell technology for rail transport. See "Coradia iLint™ – the world's 1st hydrogen powered train" -

It was at InnoTrans 2016 in Berlin that Alstom presented the Coradia iLint™ for the first time. The launch of the CO2-emission-free regional train that represents a true alternative to diesel power positioned us as the first railway manufacturers in the world to develop a passenger train based on hydrogen technology. And just two years later, at 2018, the iLint™ entered into commercial service in Germany.

Further Reading.

A recent research paper provides a summary of weight and volume characteristics of energy storage systems for potential application in rail transport - "Energy storage devices in electrified railway systems: A review"

 

 

Sunday, June 14, 2020

Discussion of Hydrogen - Boron 11 fusion

University of New South Wales researchers led by Emeritus Professor Heinrich Hora have made important breakthroughs recently in developing clean nuclear energy technology.
When a proton (a Hydrogen nucleus) fuses with a Boron-11 nucleus it produces 3 alpha particles (Helium nuclei).
That's it. No radioactive fuels. No radioactive waste.

See "Pioneering technology promises unlimited, clean and safe energy" for a recent University of New South Wales report.
Hydrogen Boron-11 fusion
Hydrogen Boron-11 fusion


April 4, 2011: Overturned scientific explanation may be good news for nuclear fusion

"Researchers have been developing reactors to slam hydrogen at high speeds into boron-11, a collision that yields high-energy helium nuclei, or alpha particles. Those alphas then spiral through a tunnel of electromagnetic coils, transforming them into a flow of electrons, or electricity."

June 12, 2020: Ultra-Fast High-Precision Metallic Nanoparticle Synthesis using Laser-Accelerated Protons

The technique of using high-energy lasers to accelerate hydrogen (aka protons) is finding wide application beyond fusion with Boron11.

Friday, January 3, 2020

Phasing-out-fossil-fuels

Scott Morrison has failed to develop a plan for phasing out thermal coal exports and for phasing out vehicles running on fossil fuels.

Simply claiming "you can't shut these down overnight" is a nonsense answer.

IEA - World Energy Outlook, 2019 - Thermal Coal Demise
IEA - World Energy Outlook, 2019 - Thermal Coal Demise


A plan for phasing out both thermal coal exports and vehicles running on fossil fuels is straightforward.

Australia has seen how such plans work. It implemented one in phasing out vehicles that ran on leaded petrol.
  1. Announce a date for the ban on new vehicles that use leaded petrol. 
  2. Announce a date for the ban of the supply of leaded petrol. 
The period to the date of the first ban sees a burst of investment for the supply of fuel and of vehicles to use the new energy source.

The period to the date of the second ban allows for the gradual retirement of all vehicles using the fuel being replaced, and for winding down the supply chain for that fuel.
 
From a paper by Troy Whitford, Fuel Mandates have a History of Success and a Lesson for Bio Fuels Implementation. Australian Policy and History, April 2010.
URL: http://aph.org.au/fuel-mandates-have-a-history-of-success-and-a-lesson-for-bio-fuels-implementation/
"In 1981, Australian state and federal transport ministers met to address pollution problems. Driving the shift towards unleaded petrol were vast environmental and health concerns.

During the 1980s, automobile associations were critical of the introduction of unleaded fuel. The RACV opposed the implementation believing it was too costly. The oil industry was cynical, too, arguing the introduction of unleaded fuel did not follow from a technological breakthrough but rather a decision by ministers. Without doubt, the position taken by oil companies, automobile associations and other stakeholders regarding unleaded fuel changed over time.

Despite opposition to unleaded fuel, the Transportation Council adopted a program to mandate unleaded petrol by 1985. The implementation policy for unleaded fuel was undertaken in stages. Initially, regulations were made calling for all new motor vehicles made after January 1986 (manufactured within Australia or imported) to meet the new fuel requirements. The policy then called for a complete phase out of leaded fuel by 2002. Prior to the national mandate, states had led the way on unleaded fuel of which NSW took the lead. The decision to mandate was essential for implementing unleaded fuel. It forced car manufacturers, oil producers and consumers to make the transition."

Saturday, February 23, 2019

Successful transition from old to new technology

The transition from leaded to unleaded transport fuels begun in 1981 with a target end-date of 2002 is a good example of how the adoption of a long-term policy simplifies the making of investment decisions of stakeholders for new plant and equipment.

From a paper by Troy Whitford, Fuel Mandates have a History of Success and a Lesson for Bio Fuels Implementation. Australian Policy and History, April 2010.
URL: http://www.aph.org.au/fuel-mandates-have-a-history
"In 1981, Australian state and federal transport ministers met to address pollution problems. Driving the shift towards unleaded petrol were vast environmental and health concerns.

During the 1980s, automobile associations were critical of the introduction of unleaded fuel. The RACV opposed the implementation believing it was too costly. The oil industry was cynical, too, arguing the introduction of unleaded fuel did not follow from a technological breakthrough but rather a decision by ministers. Without doubt, the position taken by oil companies, automobile associations and other stakeholders regarding unleaded fuel changed over time.

Despite opposition to unleaded fuel, the Transportation Council adopted a program to mandate unleaded petrol by 1985. The implementation policy for unleaded fuel was undertaken in stages. Initially, regulations were made calling for all new motor vehicles made after January 1986 (manufactured within Australia or imported) to meet the new fuel requirements. The policy then called for a complete phase out of unleaded fuel by 2002. Prior to the national mandate, states had led the way on unleaded fuel of which NSW took the lead. The decision to mandate was essential for implementing unleaded fuel. It forced car manufacturers, oil producers and consumers to make the transition."
Both renewable and fossil fuel investments for generating and distributing electricity can be utilised at close to full capacity to provide electricity for recharging electric battery powered vehicles.

Both of these investments can also be used to manufacture hydrogen for fuel-cell powered electric vehicles.

Vehicle manufacturers at present face considerable uncertainty in predicting which of the emerging clean fuel transport systems will win out in the long run.

Fuel cell electric vehicle with battery for short trips
Fuel cell electric vehicle with battery for short trips

Adopting a policy for the introduction of electric vehicles would reduce that uncertainy. Allowance can still be made for competing technologies that are quickly evolving. Fuel cells for instance that produce electric power from, say, hydrogen, are not that dissimilar from batteries that store and recharge electrolyte in situ. Vehicles using either, or both, of these energy supply systems are powered by electric motors regardless of which these two evolving technologies provides the electricity. One version of electric vehicles might use a battery for short trips and activate a hydrogen fuel cell on longer trips after the battery charge is depleted.

This plan would encourage continuing expansion and technological advances in renewable energy without the need to immediately write off substantial capital invested in fossil fuel power plants.

Saturday, September 1, 2018

Energy transition


Final Report Summary - HELMETH (Integrated High-Temperature Electrolysis and Methanation for Effective Power to Gas Conversion), 25 July 2018

A highly efficient Power-to-Gas process has been realized by the European research project HELMETH. It has the potential to be the most efficient storage solution for renewable energy utilizing the existing natural gas grid without capacity limitations and to be a source for “green” Substitute Natural Gas (SNG) to avoid fossil carbon dioxide emissions.

The objective of the HELMETH project is the proof of concept of a highly efficient Power-to-Gas process by realizing the first prototype that combines a pressurized high temperature steam electrolysis with a CO2-methanation module.

The demonstration plant was assembled at the sunfire facility in Dresden. The methanation unit, developed and built by KIT in Karlsruhe, was set up inside a container and transported to sunfire to perform combined operational tests.

The steam outlet from the methanation cooling circuit is fed to the electrolyser and the hydrogen output from the electrolyser is fed to the methanation unit. The steam is converted to hydrogen in the electrolyser.
Coupled Power-to-Gas plant (left container: methanation; right container: electrolyser)
Coupled Power-to-Gas plant (left container: methanation; right container: electrolyser)

The efficiency is significantly increased by using the heat of reaction from the exothermic methanation reaction to produce steam for the high temperature electrolysis.

Since the produced SNG is fully compatible with the existing natural gas grid and storage infrastructure, practically no capacity limitations apply to store energy from fluctuating renewable energy sources.


Steam Hydrogasification

By replacing the CO2 methanation module in the Power-to-Gas process realized by the HELMETH research project with a lignite methanation module, Australia can manufacture 50% renewable methane. That is, synthetic natural gas containing 50% renewable energy (as hydrogen) and 50% fossil fuel (from low-cost wet lignite).

This can fuel dispatchable generators in conjunction with renewable intermittent generators to provide 100% reliable electricity generation: the intermittent renewable generators supplying 50% of electricity and dispatchable generators powered by 50% renewable methane providing the other 50%.

The lignite methanation module has been developed in the U.S.

Steam Hydrogasification in a hydrogen environment

Making synthetic natural gas from hydrogen and a variety of waste streams and coal has been researched for some time.

For example:

UC Riverside researchers receive two grants to advance steam hydrogasification reaction for waste-to-fuels, 15 September 2011

Researchers at the University of California, Riverside’s Center for Environmental Research and Technology (CERT) at the Bourns College of Engineering have received two grants to further explore a steam hydrogasification process they developed...

A $650,000 grant from the California Energy Commission (CEC) extends its commitment to $2 million to CERT for the patented steam hydrogasification reaction (SHR), which can turn any carbonaceous material into transportation fuels or natural gas. The CEC grant will allow for the completion of a process demonstration unit at CERT that will provide data needed before a proposed pilot plant is built at the city of Riverside’s waste water treatment facility.

Synthetic natural gas made from wet carbonaceous feedstock such as lignite
Synthetic natural gas made from wet carbonaceous feedstock such as lignite

Wednesday, August 22, 2018

A carbon policy thread


Cr Philip Penfold blocks advisor - too much advice
Cr Philip Penfold blocks advisor - too much advice


Maitland City Council

ORDINARY MEETING AGENDA 10 JULY 2012


17.2 REDUCTION OF METHANE GAS AT MT VINCENT WASTE SITE

NOTICE OF MOTION SUBMITTED BY CLR RAY FAIRWEATHER
File No: P44197
Attachments: Nil
Responsible Officer: David Evans - General Manager

Bernie Mortomore - Executive Manager Planning, Environment and Lifestyle


Clr Ray Fairweather has indicated his intention to move the following Notice of Motion at the next Council Meeting being held on Tuesday 10 July 2012:

THAT

  1. The General Manager provide a report to council on all possible options available to council for the reduction of methane gas at the Mt Vincent Waste Site;
  2. What are those options and if council can implement any of those options to reduce the huge carbon tax cost impost on our ratepayers ($2.2 million dollars in 2012/2013 budget);
  3. The report expand on the possible sale of methane gas to generate power for electricity grid and if such a venture would benefit council financially;
  4. The opportunity if one exists for the calling of tenders for the extraction of methane gas for commercial uses; and
  5. What is involved in the 'burning option' of reducing methane gas and carbon tax payments.

NOTES BY CLR RAY FAIRWEATHER

The $2.2 million cost of the carbon tax is a huge impost on ratepayers (though it is yet to be properly costed) that needs urgent investigation on all options available to reduce those costs and if economically beneficial should be given urgent priority.

RESPONSE BY EXECUTIVE MANAGER PLANNING, ENVIRONMENT AND LIFESTYLE

A reduction of methane gas emissions from any landfill can be made by reducing the quantity of organic matter buried at the site as methane gas generation is a product of decomposition of organic materials that are subject to anaerobic conditions. These conditions are found in a landfill.
In the landfill context if methane is being generated then a landfill gas extraction system can be installed to capture the gas, pass it through a flare to convert it to carbon dioxide and hence reduce the carbon footprint of the site. If there is sufficient and constant gas production the gas can be used to power a generator which will create electricity that can be either exported to the grid or used sacrificially on site.
Alternatively organic waste can be processed in aerobic conditions so that it does not convert the waste to methane. It will generate other gases but because methane is said to be more than 21 times more problematic than carbon dioxide the greenhouse gas outputs are reduced. Aerobic waste processing of total organic waste streams utilises some form of technology to control and manage the processes. Council will recall that a waste technology solution was explored through the HIR partnership prior to the project being abandoned.
Council has a contract in place to install a gas extraction system at the Mt Vincent Rd Waste Facility. This contract with LMS Energy was entered into on the basis that infrastructure costs and ongoing management of the system was borne by LMS Energy in return for the carbon credits generated minus a royalty payment to Council. The contract remains in place and commercial in confidence. The system is to be installed within the next 3 months and gas capture should commence towards the end of the year. At this stage the reduction effect on Council's carbon liability remains unknown. It will however reduce the gas emissions from the site.
Whether there will be sufficient gas generation from the site to generate power will be known once the system is commissioned. Given the system is being retrofitted the efficiencies of the gas capture are difficult to model.
A further detailed report can be provided to Council as required.

Page (270)

Friday, August 3, 2018

Transition from thermal coal exports

Australia exports 200 million tonnes of thermal coal each year.

Japan is the largest importer, importing 80 million tonnes per year. In planning to eliminate its reliance on fossil fuel imports, Japan is looking to CO2-free hydrogen to replace its imports of coal and LNG, used primarily for electricity generation, and oil, used primarily for road transport.

One step in the 20-year transition timetable is to invest in large solar PV installations in Saudi Arabia and construction of a 'hydrogen pipeline" to deliver hydrogen produced by electrolysis to Japan.

Another step is the construction of combined-cycle gas turbine power stations that have integrated gasification plants to convert imported coal to gas to fuel them. These plants can later run on hydrogen when sufficient supply is available.

Australia and Japan could co-ordinate projects in this transition of Japan's energy systems.
One of the benefits of co-ordination is that Australia's industry and workforce has a planned transition in how it prepares energy for export, adapting employment skills and infrastructure as the plan progresses.

Another of the benefits is that part of the infrastructure development is undertaken by Australia, sharing the effort so that Japan can focus its investments on the most efficient technology to use the energy it imports.

The long-term transition would see Australia's coal export terminals replaced with hydrogen export facilities and the fleet of bulk ore carriers replaced with specialised hydrogen shipping vessels. The coal mining workforce would gradually be replaced with a workforce that constructs and operates hydrogen production plants.

During the early years of the transition it may be beneficial to convert hydrogen and coal to methane and make use of existing natural gas pipelines, LNG export terminals and LNG tankers to transport the hydrogen to Japan's existing LNG import facilities.

One benefit for Japan would be to avoid the time and cost of building integrated coal-gasifiers with new combined-cycle gas turbine power stations and fuel cell generators. The gasification can be carried out in Australia before exporting the coal with hydrogen as LNG.

Large-scale solar farms are currently built with inverters that are a significant part of the cost.
The inverters change direct-current electricity produced by the solar panels into alternating-current electricity for distribution on the electricity grid.

Inverters aren't needed when the goal is to produce hydrogen by electrolysis with the electricity generated.

A second income-stream from renewable electricity production will assist farmers struggling with drought near coal-mining regions. Solar PV installations could be designed to be "stock-friendly" for Australian livestock producers, and not copies of European installations where fields are covered with closely-spaced solar panels just above ground level.

Cattle and solar PV systems
Cattle and solar PV systems


The renewable energy generated would be fed to electrolysis units creating hydrogen.
The hydrogen is to be transferred into methanation units that have pulverised coal handling equipment where the hydrogen and coal is transformed into methane, ready for transfer to LNG export terminals.

Thyssenkrupp coal handling system
Thyssenkrupp coal handling system
Gasification technologies
Gasification technologies


See Thyssenkrupp Australia - "Power-to-gas: Storing wind and sun [energy] in natural gas"

Power-to-gas: storing wind and sun renewable energy in natural gas

The 2015 Japanese government report "Overview of Assessment by Power Generation Cost Verification Working Group", Institute of Energy Economics, Japan (IEEJ) explained that renewable energy costs are higher in Japan than in other countries, and showed Australia has a comparative advantage in large-scale wind and solar installations.
"Unit construction costs for solar PV and wind power generation systems in Japan are higher than in other countries. ...Apparent factors behind the cost gap include higher personnel costs, complex topography and FIT scheme introduction backgrounds in Japan." (at pages 8-9)

International comparison of unit construction costs for solar PV generation systems

Related posts:

Australian energy exports

Keeping waste plastic out of landfill

 


Thursday, July 26, 2018

Consumerism in an ecosystem

Rain forests are centres of great activity that depend on quite small reserves of nutrients.

Plants continuously absorbing sunlight transform water and carbon dioxide into polymers, mainly cellulose, and release oxygen.

On the rain forest floor, a myriad of animals and insect munch their way through fallen leaves and branches, breaking the polymers into water and carbon dioxide. Their waste releases the very small nutrient reserves back into the thin soil layer where they are once again available to the plant community.

Caterpillar eating a leaf
Caterpillar eating a leaf

A productive rain forest ecosystem harboring a great variety of living organisms is a stark contrast to a desert landscape in which far fewer living things eek out a sparse existence.

Human activity might be viewed as damaging and harmful to the environment, and though this is sometime a reasonable observation, it does not have to be.

Consumers supporting producers and discarding obsolete items provide a level of economic activity to engage people and allow their participation in economic and social life.

That discarded items accumulate and are not reprocessed is a problem that can be solved.

Steel and aluminium can be reprocessed more or less indefinitely. Demand for new steel and aluminium eventually declines in economies as the accumulated volume being recycled meets more and more of demand.


Collecting municipal waste, then sorting, recycling and reprocessing at large central plants has been a fairly universal approach for some time. New technology may allow for some waste material to be reprocessed at or near the point of origin, reducing the cost and complexity of large-scale collection and sorting.


Many waste items that are compounds of only carbon, hydrogen and oxygen can be completely decomposed into a gaseous fuel and may be substituted for natural gas in space heaters and hot water systems.

There is no need for waste materials to accumulate and degrade the environment. Creative solutions can be found. Many creative solution exist but simply aren't well known, hence the word "found" rather than "developed".

Energy in the Future


One creative solution that does not exist but may be developed is a business model and technology for virtually unlimited energy at little or no cost.

One possibility is a process to transform materials from one nuclear structure to another that is commercially viable and that generates energy as a byproduct. The energy byproduct can be distributed for a nominal charge.Transforming nuclear waste into safe, naturally occurring and valuable isotopes is a possible additional benefit.

Wednesday, July 18, 2018

Australian energy exports

Japan intends to establish a "hydrogen pipeline" to replace its existing imports of energy from Australia and elsewhere.
Hydrogen is the key to energy security and the fight against global warming

To speed up the development of a "hydrogen pipeline" for Japan, Australia may be able to adapt existing energy infrastructure for the purpose.

Hydrogen produced by renewable energy creates a number of challenges for special-purpose overland transport and shipping. An interim processing strategy can skip over these challenges and re-use existing infrastructure, saving time and money. A little chemistry explains how this can work...

When hydrogen is combined with carbon dioxide to form methane and water, the energy content in the methane is about the same as the energy that was present in just the hydrogen:

CO2 + 4H2 → CH4 + 2H2O

In the above reaction half of the hydrogen combines with oxygen from the carbon dioxide to form water. The other half of the hydrogen combines with the carbon from the carbon dioxide to form methane. This is known as the "Sabatier reaction". It is used commercially by Audi to create "e-gas" for its Compressed Natural Gas vehicles.



Natural gas is essentially methane with smaller amounts of other gases such as carbon monoxide and ethane. Methane made from hydrogen can be transported through natural gas pipelines and shipped as LNG - liquefied natural gas - from Australia to Japan using existing LNG terminals and LNG tankers.

When methane is combined with water to form hydrogen and carbon dioxide, the energy content in the hydrogen is about the same as the energy that was present in just the methane:

CH4 + 2H2O → 4H2 + CO2

In the above reaction oxygen from the water combines with carbon from the methane to form carbon dioxide. All the hydrogen that was part of both the methane and water is separated. This is known as "Steam Methane Reforming". It is widely used in industry to manufacture hydrogen from natural gas.


The carbon dioxide produced in the above reaction may be liquefied in Japan and returned to Australia on the empty LNG ships that delivered the methane.

This allows the carbon dioxide to be re-used indefinitely in Australia to convert hydrogen to methane for shipping to Japan using existing natural gas pipelines, LNG terminals and tankers.



Saturday, June 23, 2018

National Energy Guarantee and known pitfalls

A Japanese study released in October 2017 warns of costly European policy mistakes when investment in renewable energy is increasing.

Though details of the National Energy Guarantee policy are still under discussion, the Japanese study is worth checking so that Australia doesn't fall into any of the pitfalls it warns of.

This is an extract with some of the warnings in the Japanese study.


The Ways Forward for Japan EPCOs in the New Energy Paradigm
October 2017
Renewable Energy Institute, The Ways Forward for Japan EPCOs in the New Energy Paradigm (Tokyo: REI, 2017), 76 pp.
Executive Summary
Japan electric power companies(EPCOs) have essentially been focusing on their domestic market so far. Yet, business opportunities also exist overseas. ... Critical to successful internationalization of Japan EPCOs business will be their ability to deploy cost efficient Renewable Energy (RE).
To make their way through this new energy paradigm, Japan EPCOs have the chance to learn critical lessons from their European peers.
European EPCOs have already faced similar challenges to those Japan EPCOs are now confronted with. And European EPCOs have failed to adapt quickly. Japan is lagging behind, and that is not necessarily a bad thing. Indeed, it means that Japan EPCOs may benefit from their European peers painful experiences.
Struggling, several European EPCOs posted record losses and saw their market capitalization collapse in recent years. They were victims of low wholesale electricity prices resulting from sluggish electricity demand and dramatic expansion of wind and solar power with lower marginal cost, leading to overcapacity and pushing fossil power plants out in the competitive market merit order. (page 1)
Key Challenges Faced by Japan’s EPCOs
Global Annual Change in Electricity Generation 2010-2016
In the past two years RE accounted for the majority of new power capacity globally driven by dramatic cost reductions in wind and solar, and globally for the past three years the increase in RE electricity generation has been higher than the increase in fossil electricity generation. (Page 15)
European EPCOs Failed to Adapt Quickly
These overall negative performances result from the European EPCOs failure to quickly adapt to the energy transition, at the generation level especially. While electricity consumption stagnated, significant expansion of close to zero marginal cost wind and solar power, in which European EPCOs did not sufficiently invest, took place in Europe. The latter helped lowering wholesale electricity prices due to the merit order effect. At the same time, conventional power capacity did not significantly decrease which combined with stagnating electricity consumption and the expansion of RE resulted in overcapacity further reducing wholesale electricity prices (Chart 31). European EPCOs conventional power plants were thus outcompeted due to their higher marginal costs and suffered from low wholesale electricity prices, thus significantly affecting European EPCOs profitability. (page 26-27)
In Europe, several EU Member States including France, Germany, Italy, Spain, and the UK, notably, have introduced rewards for making capacity available, in the form of capacity mechanisms. However, capacity mechanisms are considered problematic because they risk distorting electricity markets. Inappropriate designs of mechanisms may for instance result in existing uneconomic power plants receiving financial support and disturbing the transition to a low-carbon economy – a failure. 31  The UK and Germany offer telling examples of far from perfect capacity mechanisms. (page 28)
In Germany, from this year 2.7GW of largely inflexible and high-emitting lignite capacity will be placed into an emergency stand-by reserve, only to be used as back-up when required for a period of four years, after which these plants will be permanently retired. 33  This comes at an estimated cost of €1.6 billion to the German government to compensate for lost revenues from the electricity market during these years of security stand-by. 34
These flawed designs are unsurprising insofar as it has been found that many of EU Member States did not adequately assess the need or cost-effectiveness before introducing such mechanisms. 35
In addition, it has also been recognized that capacity mechanisms implementation must be accompanied by appropriate market reforms. 36
Thus, before adding gigawatts of new conventional power plants and/or pushing for the implementation of a capacity mechanism in Japan, Japan EPCOs should thus be well aware of these painful lessons learnt in Europe (page 29)
ENDNOTES
31   European Parliament, “Capacity mechanisms for electricity – May 2017” (accessed 28 August 2017)  
33   The Economist Intelligence Unit, “Is Germany’s Energiewende cutting GHG emissions? – 20 March 2017” (accessed 31 August 2017)
34   Overseas Development Institute, Rethinking Power Markets: Capacity mechanisms and decarbonisation (London, United Kingdom: ODI, 2016), 46 pp
35   European Parliament, op. cit. note 31
36   Ibid.

Friday, December 22, 2017

Snowy Hydro 2.0 has competition

There are many ways to store renewable energy.

A problem with Snowy Hydro 2.0 is that it won't work without a large investment in additional 'poles and wires'. This is needed to move renewable energy to the centralised storage facility and to deliver it to consumers when needed. This very large outlay will add to already high electricity prices in Australia.

Another option reduces the need for spending on 'poles and wires' and cuts electricity prices: installing energy storage along-side solar PV systems owned by electricity consumers. See Affordable reliable electricity the easy way for a discussion on this option.

A different option for energy storage has even more advantages...

The Australian Government and other coal lobbyists express concerns with a fifty percent renewable energy target such as the one proposed by the Australian Labor Party:
"50% Renewable Energy by 2030 ...The Climate Change Authority has found that for Australia to achieve its bipartisan agreement to limit global warming by less than 2°C, renewable energy will need to comprise at least half of Australia’s electricity generation by 2030." 
Opponents make claims such as:
"Labor’s energy policy to deliver $200 bill shock ...Labor’s policy of a 50 per cent ­renewable energy target by 2030 would require the closure of 75 per cent of existing coal-fired power in Australia."
It's not as challenging a problem as some people think. Instead of using renewable energy to pump water uphill in a Snowy Hydro 2.0, it can be converted to despatchable fuel in two steps:
  1. Produce hydrogen by electrolysis of water.
  2. Use the hydrogen from the first step to manufacture methane from brown coal. 
The resulting fuel contains 50% renewable energy and 50% fossil fuel energy. If biomass was gasified in place of the coal, the fuel would be 100% renewable, despatchable energy.

The advantages include:
  • There is no need for fracking to produce coal seam gas.
  • There is no shortage of natural gas for the domestic market.
  • Inefficient old brown coal power stations that produce over 1,100 kilograms of carbon dioxide per megawatt-hour are replaced by efficient combined-cycle gas turbine power stations that produce only 330 kilograms of carbon dioxide per megawatt-hour. 
The reduction in carbon dioxide emissions from over 1,100 kilograms to just 330 kilograms per megawatt-hour points to a fairly remarkable benefit:
  • For Snowy Hydro 2.0 only about 2 megawatt-hours of renewable energy are returned for each 3 megawatt-hours of renewable energy that are stored... 
  • Carbon in brown coal is only being converted into electricity at an efficiency of about 25% in existing coal-fired power stations.
  • After this carbon is used to make methane with hydrogen from renewable energy, it is converted into electricity with an efficiency of 60% in combined cycle gas turbine power stations. 
  • This change means the amount of coal needed for the same amount of electricity is cut by over 70%. Output is increased, not reduced in this option.
E.on launches power-to-gas plant
E.on launches power-to-gas plant
The unit uses wind power to run electrolysis equipment that transforms water into hydrogen

The conversion of coal and biomass into high energy synthetic gases suitable for use as fuels focused attention on the hydrogasification reaction: C + 2H2 ⇄ CH4.

Because this reaction is highly exothermic and requires the presence of hydrogen, it has been suggested that it be integrated with endothermic hydrogen-producing reactions such as the steam/carbon gasification reaction, C + H20 ⇄ C0 + H2, and the methane/steam reforming reaction, CH4 + H20 ⇄ C0 + 3H2, to conserve heat and reduce the amount of hydrogen which must be provided.

It has been found that this can be done by reacting the coal or other carbonaceous material with steam and hydrogen in a hydrogasification zone to produce a methane-rich gas, passing at least a portion of this gas stream through a methane reforming zone where it is contacted with steam to reduce part of the methane and form hydrogen, and then recycling hydrogen and carbon monoxide recovered from the steam reformer overhead gas to the hydrogasification zone.

Coal char or other carbonaceous solids are circulated between the hydrogasification and reforming zones to provide heat integration.

Wednesday, December 20, 2017

Gas Vision 2050 by 2025

Gas Vision 2050 is an Energy Networks Australia report produced on December 18, 2017. Australia’s peak gas industry bodies prepared it to "demonstrate how gas may continue to provide Australians with reliable and affordable energy in a low carbon energy future."

The scope of the report is to "outline how Australia’s gas supply and infrastructure can be a national advantage as our energy mix continues to evolve."


The reports author's missed the option being explored across Europe: make us of Australia’s gas supply and infrastructure as an energy storage system.

This new purpose for Australia’s gas supply and infrastructure has the potential to make a substantial contribution to the economy. For instance, a proposal for a multi-billion dollar development of pumped hydro energy storage "Snowy Hydro 2.0" is years away from becoming a reality. The gas supply infrastructure can begin providing this function almost immediately.

The report describes three technologies under the heading "Decarbonisation Pathways" -
  • Biogas production – Biogas consists of methane and is already produced from municipal solid waste.
  • Hydrogen: Hydrogen can be produced from natural gas or through electrolysis. Hydrogen creates opportunities for clean energy for households, businesses or transport and can also generate zero emissions electricity using fuel cells or gas turbines.
  • Carbon capture and storage (CCS) refers to the process of producing decarbonised hydrogen from gas, coal, or biogas to remove carbon dioxide from the carbon cycle.
There is a fourth technology that has significant potential to accelerate decarbonisation of Australia's gas supply. So much so that the goal the report sets for 2050 may be achieved much sooner.

Biogas can be produced from a great many carbon-containing materials such as farm crop waste, municipal waste, sewage sludge, animal waste and timber waste. In each case about half the carbon combines with hydrogen from water in the mixture to form methane and the remaining carbon combines with the oxygen "left over" from the creation of methane to form carbon dioxide.

The result is a gas that is about 50/50 methane and carbon dioxide. The carbon dioxide needs to be removed before the methane is suitable for injection into gas supply pipelines.

Hydrogen can be produced using surplus renewable energy to split water by electrolysis. This is a method of energy storage. Hydrogen may be injected directly into gas supply lines, but the proportion can be no more than 10 percent by volume.
The fourth technology that isn't mentioned in the Gas Vision 2050 report tackles both of the above issues:
Waste materials containing carbon can be reacted with hydrogen. In this process ALL the carbon is converted into methane and NO carbon dioxide is created. So there is nothing to separate from the biogas before it can be injected into natural gas pipelines. The 10 percent limit on the proportion of hydrogen that can be safely mixed with natural gas is no longer an issue...
The biomethane produced via this pathway is achieving two purposes:
  • It is replacing natural gas with carbon-neutral biogas. 
  • It is storing renewable energy in the form of methane for use as required.
Production of Biogas/Methane by Biomass Hydrogasification


This needn't be a permanent part of a zero-emission energy system. While battery capacity investment is ramping up, excess wind and solar power can be stored and distributed as hydrogen and/or methane in the existing natural gas system.

Burning natural gas in heating appliances will eventually be discontinued, but for now, a large number of these appliances are being used. It will be some time before they are all replaced.

Small distributed gas-fueled electricity generation can be up to 60% efficient. These do the job that batteries and pumped hydro will eventually do - when enough of them have been built.

Farmers can replace coal seam gas industry by manufacturing methane from crop waste that is combined with hydrogen made to store  renewable energy.

When there are enough batteries and pumped hydro storage to eliminate the need for natural gas energy resources in Australia, this bio-methane can be used as feed stock in chemical industries to replace coal seam gas. It can also be exported as LNG, substituting for Australia's coal and coal seam gas energy exports.