Destroying sewage while producing power

By Orlando Sentinel


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Orlando officials think they've perfected a technology that has flummoxed scientists for decades — one they hope will be used worldwide to turn sewage into electricity and earn the city tens of millions of dollars in royalties.

If city officials and their private-industry partners are right, it could be the biggest thing in sewage treatment since the flush toilet.

"We call it poop to power in five minutes," said project consultant Roy Pelletier.

While the five-year, $8.5 million project has drawn little attention locally, a small, experimental test plant off busy Alafaya Trail near the University of Central Florida has drawn visitors from Mexico, Rio de Janeiro, Abu Dhabi, Canada, Europe and elsewhere in recent weeks.

They have traveled here because they've heard there may be an answer to an intriguing question that has dogged scientists for years: What if you could take sewage and get rid of it cleanly and quickly, without dumping it in rivers or landfills — and generate pollution-free electricity at the same time?

"The technology has the potential to revolutionize how wastewater is processed — the destruction of all organics, the generation of electricity, a completely green footprint," said Don Morgan, CEO of SuperWater Solutions, a Wellington company working with Orlando.

Treated sewage used to be dumped into waterways, but technological advances and tougher regulations ended that practice decades ago.

Orlando treats more than 35 million gallons of sewage a day, essentially by feeding the outflow from the city's toilets and sinks to bacteria. The process produces reclaimed water that's clean enough to be piped to some neighborhoods, golf courses and road medians to irrigate flowers and grass.

But there's another byproduct of the treatment process that's harder to deal with. The bacteria that gobble up the sewage reproduce as they eat, so as the sewage goes away, it's replaced with smelly, mud-like piles of microorganisms. That's sludge, and there's a lot of it.

At Iron Bridge — just one of Orlando's three treatment plants — workers have to get rid of as many as 15 tractor-trailer loads of sludge a day, seven days a week, 365 days a year. The city's disinfected sludge is spread over fields and pastures. Property owners are happy to get it, because they don't have to buy fertilizer.

But sludge can't be spread on land that's wet — a problem during stormy summers — and environmental rules that will further restrict the practice are on the way.

So, what to do with all that sludge?

Orlando inked a deal with SuperWater Solutions to develop a way to treat sludge using a process called "supercritical water oxidation." Several other companies also are testing its use in treating wastewater, as well as industrial and hazardous waste. Plants are now under construction that will use it to destroy the military's stockpiled chemical weapons.

But stubborn technical hurdles have kept it from being commercially viable.

"For 20 years, people at MIT and all around the world have been trying to do this," said Orlando environmental services director David Sloan.

Here's how it works: The sludge is thickened, fed through a grinder and subjected to extremely high pressure. The pressurized mix is pumped through a reactor, along with pure oxygen, where it's heated to more than 700 degrees Fahrenheit.

A strange thing happens to water when it's put under such extreme pressures and temperatures. It's no longer one of the three states — liquid, solid or gas — that kids learn about in school. Rather, it's "supercritical water," a fourth state that's something between a liquid and a gas and is a powerful solvent.

Within the reactor, supercritical water destroys more than 99 percent of organic matter, including sludge. The process leaves behind inorganic salts, clean water and liquid carbon dioxide.

City officials think they can make money from the byproducts. Carbon dioxide could be sold to beverage companies, and the powdery salts are mostly phosphates that could be used by fertilizer manufacturers.

Another byproduct is heat, which can easily be captured and used to power an electrical turbine. Sludge holds about as much energy as coal, and city officials estimate that treating Orlando's 35 tons a day will produce enough electricity to power about 1,183 homes — without pollution or greenhouse gas emissions.

The reactor would use about half the electricity, and the rest could be sold back to the power company — at a "green energy" premium.

The test reactor in a corner of the city's Iron Bridge plant came from a partnership between the city and SuperWater Solutions, which provided the technology. Orlando paid for the development and construction of the system, and city engineers, chemists, mechanics and computer technicians helped figure out how to make it work.

SuperWater Solutions said the technology is now ready to be taken to the commercial market, with the potential for full-size treatment systems built around the world. Orlando will likely be the first customer, with construction of a full-size unit by 2013.

Under their agreement, if SuperWater Solutions builds plants elsewhere, Orlando will be paid royalties. For every ton of sludge treated anywhere in the world, Orlando will earn $2.50. SuperWater Solutions projects royalty payments of $60 million over the next 20 years.

It's not a sure thing. Other companies are racing to perfect their own technology.

But for Orlando officials, the money isn't the point. They simply want a sustainable way to get rid of their sludge, a chore most residents don't want to think about.

"Putting a man on the moon is sexy, but getting rid of poop is not," City Commissioner Patty Sheehan said.

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Bitcoin consumes 'More electricity than Argentina' - Cambridge

Bitcoin energy consumption is driven by mining electricity demand, with TWh-scale power use, carbon footprint concerns, and Cambridge estimates. Rising prices incentivize more hardware; efficiency gains and renewables adoption shape sustainability outcomes.

 

Key Points

Bitcoin energy consumption is mining's electricity use, driven by price, device efficiency, and energy mix.

✅ Cambridge tool estimates ~121 TWh annual usage

✅ Rising BTC price incentivizes more mining hardware

✅ Efficiency, renewables, and costs shape footprint

 

"Mining" for the cryptocurrency is power-hungry, with power curtailments reported during heat waves, involving heavy computer calculations to verify transactions.

Cambridge researchers say it consumes around 121.36 terawatt-hours (TWh) a year - and is unlikely to fall unless the value of the currency slumps, even as Americans use less electricity overall.

Critics say electric-car firm Tesla's decision to invest heavily in Bitcoin undermines its environmental image.

The currency's value hit a record $48,000 (£34,820) this week. following Tesla's announcement that it had bought about $1.5bn bitcoin and planned to accept it as payment in future.

But the rising price offers even more incentive to Bitcoin miners to run more and more machines.

And as the price increases, so does the energy consumption, according to Michel Rauchs, researcher at The Cambridge Centre for Alternative Finance, who co-created the online tool that generates these estimates.

“It is really by design that Bitcoin consumes that much electricity,” Mr Rauchs told BBC’s Tech Tent podcast. “This is not something that will change in the future unless the Bitcoin price is going to significantly go down."

The online tool has ranked Bitcoin’s electricity consumption above Argentina (121 TWh), the Netherlands (108.8 TWh) and the United Arab Emirates (113.20 TWh) - and it is gradually creeping up on Norway (122.20 TWh).

The energy it uses could power all kettles used in the UK, where low-carbon generation stalled in 2019, for 27 years, it said.

However, it also suggests the amount of electricity consumed every year by always-on but inactive home devices in the US alone could power the entire Bitcoin network for a year, and in Canada, B.C. power imports have helped meet demand.

Mining Bitcoin
In order to "mine" Bitcoin, computers - often specialised ones - are connected to the cryptocurrency network.

They have the job of verifying transactions made by people who send or receive Bitcoin.

This process involves solving puzzles, which, while not integral to verifying movements of the currency, provide a hurdle to ensure no-one fraudulently edits the global record of all transactions.

As a reward, miners occasionally receive small amounts of Bitcoin in what is often likened to a lottery.

To increase profits, people often connect large numbers of miners to the network - even entire warehouses full of them, as seen with a Medicine Hat bitcoin operation backed by an electricity deal.

That uses lots of electricity because the computers are more or less constantly working to complete the puzzles, prompting some utilities to consider pauses on new crypto loads in certain regions.

The University of Cambridge tool models the economic lifetime of the world's Bitcoin miners and assumes that all the Bitcoin mining machines worldwide are working with various efficiencies.

Using an average electricity price per kilowatt hour ($0.05) and the energy demands of the Bitcoin network, it is then possible to estimate how much electricity is being consumed at any one time, though in places like China's power sector data can be opaque.
 

 

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France's nuclear power stations to limit energy output due to high river temperatures

France Nuclear Heatwave Output Restrictions signal reduced reactor capacity along the Rhone River, as EDF curbs output to meet cooling-water rules, balance the grid, integrate solar peaks, and limit impacts on power prices.

 

Key Points

EDF limits reactor output during heat to protect rivers and keep the grid stable under cooling-water rules.

✅ Cuts likely at midday/weekends when solar peaks

✅ Bugey, Saint Alban maintain minimum grid output

✅ France net exporter; price impact expected small

 

The high temperature warning has come early this year but will affect fewer nuclear power plants, amid a broader France-Germany nuclear dispute over atomic power policy that shapes regional energy flows.

High temperatures could halve nuclear power production at plants along France's Rhone River this week, as European power hits records during extreme heat. 

Output restrictions are expected at two nuclear plants in eastern France due to high temperature forecasts, nuclear operator EDF said, which may limit energy output during heatwaves. It comes several days ahead of a similar warning that was made last year but will affect fewer plants.

The hot weather is likely to halve the available power supply from the 3.6 GW Bugey plant from 13 July and the 2.6 GW Saint Alban plant from 16 July, the operator said.

However, production will be at least 1.8 GW at Bugey and 1.3 GW at Saint Alban to meet grid requirements, and may change according to grid needs, the operator said.

Kpler analyst Emeric de Vigan said the restrictions were likely to have little effect on output in practice. Cuts are likely only at the weekend or midday when solar output was at its peak so the impact on power prices would be slim.

During recent lockdowns, power demand held firm in Europe, offering context for current price dynamics.

He said the situation would need monitoring in the coming weeks, however, noting it was unusually early in the summer for such restrictions to be imposed.

Water temperatures at the Bugey plant already eclipsed the initial threshold for restrictions on 9 July, underscoring France's outage risks under heat-driven constraints. They are currently forecast to peak next week and then drop again, Refinitiv data showed.

"France is currently net exporting large amounts of power – single nuclear units' supply restrictions will not have the same effect as last year," Refinitiv analyst Nathalie Gerl said.

The Garonne River in southern France has the highest potential for critical levels of warming, but its Golfech plant is currently offline for maintenance until mid-August, the data showed, highlighting how Europe is losing nuclear power during critical periods.

"(The restrictions were) to be expected and it will probably occur more often," Greenpeace campaigner Roger Spautz said.

"The authorities must stick to existing regulations for water discharges. Otherwise, the ecosystems will be even more affected," he added.

 

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Global oil demand to decline in 2020 as Coronavirus weighs heavily on markets

COVID-19 Impact on Global Oil Demand 2020 signals an IEA forecast of declining consumption as travel restrictions curb transport fuels, disrupt energy markets, and shift OPEC and non-OPEC supply dynamics amid economic slowdown.

 

Key Points

IEA sees first demand drop since 2009 as COVID-19 curbs travel, weakening transport fuels and unsettling energy markets.

✅ IEA base case: 2020 demand at 99.9 mb/d, down 90 kb/d from 2019.

✅ Travel restrictions hit transport fuels; China drives the decline.

✅ Scenarios: low -730 kb/d; high +480 kb/d in 2020.

 

Global oil demand is expected to decline in 2020 as the impact of the new coronavirus (COVID-19) spreads around the world, constricting travel and broader economic activity, according to the International Energy Agency’s latest oil market forecast.

The situation remains fluid, creating an extraordinary degree of uncertainty over what the full global impact of the virus will be. In the IEA’s central base case, even as global CO2 emissions flatlined in 2019 according to the IEA, demand this year drops for the first time since 2009 because of the deep contraction in oil consumption in China, and major disruptions to global travel and trade.

“The coronavirus crisis is affecting a wide range of energy markets – including coal-fired electricity generation, gas and renewables – but its impact on oil markets is particularly severe because it is stopping people and goods from moving around, dealing a heavy blow to demand for transport fuels,” said Dr Fatih Birol, the IEA’s Executive Director. “This is especially true in China, the largest energy consumer in the world, which accounted for more than 80% of global oil demand growth last year. While the repercussions of the virus are spreading to other parts of the world, what happens in China will have major implications for global energy and oil markets.”

The IEA now sees global oil demand at 99.9 million barrels a day in 2020, down around 90,000 barrels a day from 2019. This is a sharp downgrade from the IEA’s forecast in February, which predicted global oil demand would grow by 825,000 barrels a day in 2020.

The short-term outlook for the oil market will ultimately depend on how quickly governments move to contain the coronavirus outbreak, how successful their efforts are, and what lingering impact the global health crisis has on economic activity.

To account for the extreme uncertainty facing energy markets, the IEA has developed two other scenarios for how global oil demand could evolve this year. In a more pessimistic low case, global measures fail to contain the virus, and global demand falls by 730,000 barrels a day in 2020. In a more optimistic high case, the virus is contained quickly around the world, and global demand grows by 480,000 barrels a day.

“We are following the situation extremely closely and will provide regular updates to our forecasts as the picture becomes clearer,” Dr Birol said. “The impact of the coronavirus on oil markets may be temporary. But the longer-term challenges facing the world’s suppliers are not going to go away, especially those heavily dependent on oil and gas revenues. As the IEA has repeatedly said, these producer countries need more dynamic and diversified economies in order to navigate the multiple uncertainties that we see today.”

The IEA also published its medium-term outlook examining the key issues in global demand, supply, refining and trade to 2025, as well as the trajectory of the global energy transition now shaping markets. Following a contraction in 2020 and an expected sharp rebound in 2021, yearly growth in global oil demand is set to slow as consumption of transport fuels grows more slowly and as national net-zero pathways, with Canada needing more electricity to reach net-zero influencing power demand, according to the report. Between 2019 and 2025, global oil demand is expected to grow at an average annual rate of just below 1 million barrels a day. Over the period as whole, demand rises by a total of 5.7 million barrels a day, with China and India accounting for about half of the growth.

At the same time, the world’s oil production capacity is expected to rise by 5.9 million barrels a day, with more than three-quarters of it coming from non-OPEC producers, the report forecasts. But production growth in the United States and other non-OPEC countries is set to lose momentum after 2022, amid shifts in Wall Street's energy strategy linked to policy signals, allowing OPEC producers from the Middle East to turn the taps back up to help keep the global oil market in balance.

The medium-term market report, Oil 2020, also considers the impact of clean energy transitions on oil market trends. Demand growth for gasoline and diesel between 2019 and 2025 is forecast to weaken as countries around the world implement policies to improve efficiency and cut carbon dioxide emissions – and as solar power becomes the cheapest electricity in many markets and electric vehicles increase in popularity. The impact of energy transitions on oil supply remains unclear, with many companies prioritising short-cycle projects for the coming years.

“The coronavirus crisis is adding to the uncertainties the global oil industry faces as it contemplates new investments and business strategies,” Dr Birol said. “The pressures on companies are changing, with European oil majors turning electric to diversify. They need to show that they can deliver not just the energy that economies rely on, but also the emissions reductions that the world needs to help tackle our climate challenge.”

 

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Experts warn Albertans to lock in gas and electricity rates as prices set to soar

Alberta Energy Price Spike signals rising electricity and natural gas costs; lock in fixed rates as storage is low, demand surged in heat waves, and exports rose after Hurricane Ida, driving volatility and higher futures.

 

Key Points

An anticipated surge in Alberta electricity and natural gas prices, urging consumers to lock fixed rates to reduce risk.

✅ Fixed-rate gas near $3.79/GJ vs futures approaching $6/GJ

✅ Low storage after heat waves and U.S. export demand

✅ Switch providers or plans; UCA comparison tool helps

 

Energy economists are warning Albertans to review their gas and electricity bills and lock in a fixed rate if they haven't already done so because prices are expected to spike in the coming months.

"I have been urging anyone who will listen that every single Albertan should be on a fixed rate for this winter," University of Calgary energy economist Blake Shaffer said Monday. "And I say that for both natural gas and power."

Shaffer said people will rightly point out energy costs make up only roughly a third of their monthly bill. The rest of the costs for such things as delivery fees can't be avoided. 

But, he said, "there is an energy component and it is meaningful in terms of savings." 

For example, Shaffer said, when he checked last week, a consumer could sign a fixed rate gas contract for $3.79 a gigajoule and the current future price for gas is nearly $6 a gigajoule.

A typical household would use about 15 gigajoules a month, he said, so a consumer could save $30 to $45 a month for five months. For people on lower or fixed incomes, "that is a pretty significant saving."

Comparable savings can also be achieved with electricity, he said.

Shaffer said research has shown households that are least able to afford sharp increases in gas and electrical bills are less likely to pick up the phone and call their energy provider and either negotiate a lower fixed rate contract or jump to a new provider. 

But, he said, it is definitely worth the time and effort, particularly as Calgary electricity bills are rising across the city. Alberta's Utilities Consumer Advocate has a handy cost comparison tool on its website that allows consumers to conduct regional price comparisons that will assist in making an informed decision.

"Folks should know that for most providers you can change back to a floating rate any time you want," Shaffer said.

Summer heat wave affected natural gas supply
Why are energy prices set to spike in Alberta, which is a major producer of natural gas?

Sophie Simmonds, managing director of the brokerage firm Anova Energy, said Alberta is now generating the majority of its power using natural gas. 

The heat wave in June and July created record electrical demand. Normally, natural gas is stored in the summer for use in the winter. But this year, there was much greater gas consumption in the summer and so less was stored. 

Alberta also set a new electricity usage record during a recent deep freeze, underscoring system stress.

On top of that, Alberta has been exporting much more natural gas to the United States since August and September because Hurricane Ida knocked out natural gas assets in the Gulf of Mexico.

"So what this means is we are actually going into winter with very, very low storage numbers," Simmonds said.

Why natural gas prices have surged to some of their highest levels in years
Canadians to remain among world's top energy users even as government strives for net zero
Consultant Matt Ayres said he believes rising electricity prices also are being affected by Alberta's transition from carbon-intensive fuel sources to less carbon-intensive fuel sources.

"That transition is not always smooth," said Ayres, who is also an adjunct assistant professor at the University of Calgary's School of Public Policy. 

"It is my view that at least some of the price increases we are seeing on electricity comes down to difficulties imposed by that transition and also by a reduction in competition amongst generators, as well as power market overhaul debates shaping policy." 

In 2019, under the leadership of Premier Jason Kenney the UCP government removed the former NDP government's rate cap on electricity at the time.

The NDP has called for the government to reinstate the cap but the UCP government has dismissed that as unsustainable and unrealistic.

 

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Russian Strikes on Western Ukraine Cause Power Outages

Ukraine Energy Grid Attacks intensify as missile strikes and drone raids hit power plants, substations, and transmission lines, causing blackouts, disrupted logistics, and humanitarian strain during winter, despite repairs, air defense, and allied aid.

 

Key Points

Missile and drone strikes on Ukraine's power grid to force blackouts, strain civilians, and disrupt military logistics.

✅ Targets: power plants, substations, transmission lines

✅ Impacts: blackouts, heating loss, hospital strain

✅ Goals: erode morale, disrupt logistics, force aid burdens

 

Russia’s continued strikes on Ukraine have taken a severe toll on the country’s critical infrastructure, particularly its energy grid, as Ukraine continues to keep the lights on despite sustained bombardment. In recent months, Western Ukraine has increasingly become a target of missile and drone attacks, leading to widespread power outages and compounding the challenges faced by the civilian population. These strikes aim to cripple Ukraine's resilience during a harsh winter season and disrupt its wartime operations.

Targeting Energy Infrastructure

Russian missile and drone assaults on Ukraine’s energy grid are part of a broader strategy to weaken the country’s morale and capacity to sustain the war effort. The attacks have primarily focused on power plants, transmission lines, and substations. Western Ukraine, previously considered a relative safe haven due to its distance from front-line combat zones, is now experiencing the brunt of this campaign.

The consequences of these strikes are severe. Rolling blackouts and unplanned outages have disrupted daily life for millions of Ukrainians, though authorities say there are electricity reserves that could stabilize supply if no new strikes occur, leaving homes without heating during freezing temperatures, hospitals operating on emergency power, and businesses struggling to maintain operations. The infrastructure damage has also affected water supplies and public transportation, further straining civilian life.

Aimed at Civilian and Military Impact

Russia’s targeting of Ukraine’s power grid has dual purposes. On one hand, it aims to undermine civilian morale by creating hardships during the cold winter months, even as Ukraine works to keep the lights on this winter through contingency measures. On the other, it seeks to hinder Ukraine’s military logistics and operations, which heavily rely on a stable energy supply for transportation, communications, and manufacturing of military equipment.

These attacks coincide with a broader strategy of attritional warfare, where Moscow hopes to exhaust Ukraine’s resources and diminish its ability to continue its counteroffensive operations. By disrupting critical infrastructure, Russia increases pressure on Ukraine's allies to step up humanitarian and military aid, stretching their capacities.

Humanitarian Consequences

The impact of these power cuts on the civilian population is profound. Millions of Ukrainians are enduring freezing temperatures without consistent access to electricity or heating. Vulnerable populations, such as the elderly, children, and those with disabilities, face heightened risks of hypothermia and other health issues.

Hospitals and healthcare facilities are under immense strain, relying on backup generators that cannot sustain prolonged use. In rural areas, where infrastructure is already weaker, the effects are even more pronounced, leaving many communities isolated and unable to access essential services.

Humanitarian organizations have ramped up efforts to provide aid, including distributing generators, warm clothing, and food supplies, while many households pursue new energy solutions to weather blackouts. However, the scale of the crisis often outpaces the resources available, leaving many Ukrainians to rely on their resilience and community networks.

Ukraine's Response

Despite the challenges, Ukraine has demonstrated remarkable resilience in the face of these attacks. The government and utility companies are working around the clock to repair damaged infrastructure and restore power to affected areas. Mobile repair teams and international assistance have played crucial roles in mitigating the impact of these strikes.

Ukraine’s Western allies have also stepped in to provide support. The European Union, the United States, and other countries have supplied Ukraine with energy equipment, financial aid, and technical expertise to help rebuild its energy grid, though recent decisions like the U.S. ending support for grid restoration complicate planning and procurement. Additionally, advanced air defense systems provided by Western nations have helped intercept some of the incoming missiles and drones, though not all attacks can be thwarted.

Russia’s Escalation Strategy

Russia’s focus on Western Ukraine reflects a shift in its strategy. Previously, attacks were concentrated on front-line areas and major urban centers in the east and south. However, by targeting the western regions, Moscow seeks to disrupt the relatively stable zones where displaced Ukrainians and critical supply chains are located.

Western Ukraine is also a hub for receiving and distributing international aid and military supplies. Striking this region not only undermines Ukraine’s internal stability but also sends a message to its allies about Russia’s willingness to escalate the conflict further.

Broader Implications

The attacks on Ukraine’s energy grid have broader geopolitical implications. By targeting infrastructure, Russia intensifies the pressure on Ukraine’s allies to continue providing support, even as Kyiv has at times helped Spain amid blackouts when capacity allowed, testing their unity and resolve. The destruction also poses long-term challenges for Ukraine’s post-war recovery, as rebuilding a modern and resilient energy system will require significant investments and time.

Moreover, these attacks highlight the vulnerability of civilian infrastructure in modern warfare, echoing that electricity is civilization amid winter conditions. The deliberate targeting of non-combatant assets underscores the need for international efforts to strengthen the protection of critical infrastructure and address the humanitarian consequences of such tactics.

The Russian attacks on Western Ukraine's power grid are a stark reminder of the devastating human and economic costs of the ongoing conflict. While Ukraine continues to demonstrate resilience and adaptability, the scale of destruction underscores the need for sustained international support. As the war drags on, the focus must remain on mitigating civilian suffering, rebuilding critical infrastructure, and pursuing a resolution that ends the violence and stabilizes the region.

 

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Are Norwegian energy firms ‘best in class’ for environmental management?

CO2 Tax for UK Offshore Energy Efficiency can accelerate adoption of aero-derivative gas turbines, flare gas recovery, and combined cycle power, reducing emissions on platforms like Equinor's Mariner and supporting net zero goals.

 

Key Points

A carbon price pushing operators to adopt efficient turbines, flare recovery, and combined cycle to cut emissions.

✅ Aero-derivative turbines beat industrial units on efficiency

✅ Flare gas recovery cuts routine flaring and fuel waste

✅ Combined cycle raises efficiency and lowers emissions

 

By Tom Baxter

The recent Energy Voice article from the Equinor chairman concerning the Mariner project heralding a ‘significant point of reference’ for growth highlighted the energy efficiency achievements associated with the platform.

I view energy efficiency as a key enabler to net zero, and alongside this the UK must start large-scale storage to meet system needs; it is a topic I have been involved with for many years.

As part of my energy efficiency work, I investigated Norwegian practices and compared them with the UK.

There were many differences, here are three;


1. Power for offshore installations is usually supplied from gas turbines burning fuel from the oil and gas processing plant, and even as the UK's offshore wind supply accelerates, installations convert that to electricity or couple the gas turbine to a machine such as a gas compressor.

There are two main generic types of gas turbine – aero-derivative and industrial. As the name implies aero-derivatives are aviation engines used in a static environment. Aero-derivative turbines are designed to be energy efficient as that is very import for the aviation industry.

Not so with industrial type gas turbines; they are typically 5-10% less efficient than a comparable aero-derivative.

Industrial machines do have some advantages – they can be cheaper, require less frequent maintenance, they have a wide fuel composition tolerance and they can be procured within a shorter time frame.

My comparison showed that aero-derivative machines prevailed in Norway because of the energy efficiency advantages – not the case in the UK where there are many more offshore industrial gas turbines.

Tom Baxter is visiting professor of chemical engineering at Strathclyde University and a retired technical director at Genesis Oil and Gas Consultants


2. Offshore gas flaring is probably the most obvious source of inefficient use of energy with consequent greenhouse gas emissions.

On UK installations gas is always flared due to the design of the oil and gas processing plant.

Though not a large quantity of gas, a continuous flow of gas is routinely sent to flare from some of the process plant.

In addition the flare requires pilot flames to be maintained burning at all times and, while Europe explores electricity storage in gas pipes, a purge of hydrocarbon gas is introduced into the pipes to prevent unsafe air ingress that could lead to an explosive mixture.

On many Norwegian installations the flare system is designed differently. Flare gas recovery systems are deployed which results in no flaring during continuous operations.

Flare gas recovery systems improve energy efficiency but they are costly and add additional operational complexity.


3. Returning to gas turbines, all UK offshore gas turbines are open cycle – gas is burned to produce energy and the very hot exhaust gases are vented to the atmosphere. Around 60 -70% of the energy is lost in the exhaust gases.

Some UK fields use this hot gas as a heat source for some of the oil and gas treatment operations hence improving energy efficiency.

There is another option for gas turbines that will significantly improve energy efficiency – combined cycle, and in parallel plans for nuclear power under the green industrial revolution aim to decarbonise supply.

Here the exhaust gases from an open cycle machine are taken to a separate turbine. This additional turbine utilises exhaust heat to produce steam with the steam used to drive a second turbine to generate supplementary electricity. It is the system used in most UK power stations, even as UK low-carbon generation stalled in 2019 across the grid.

Open cycle gas turbines are around 30 – 40% efficient whereas combined cycle turbines are typically 50 – 60%. Clearly deploying a combined cycle will result in a huge greenhouse gas saving.

I have worked on the development of many UK oil and gas fields and combined cycle has rarely been considered.

The reason being is that, despite the clear energy saving, they are too costly and complex to justify deploying offshore.

However that is not the case in Norway where combined cycle is used on Oseberg, Snorre and Eldfisk.

What makes the improved Norwegian energy efficiency practices different from the UK – the answer is clear; the Norwegian CO2 tax.

A tax that makes CO2 a significant part of offshore operating costs.

The consequence being that deploying energy efficient technology is much easier to justify in Norway when compared to the UK.

Do we need a CO2 tax in the UK to meet net zero – I am convinced we do. I am in good company. BP, Shell, ExxonMobil and Total are supporting a carbon tax.

Not without justification there has been much criticism of Labour’s recent oil tax plans, alongside proposals for state-owned electricity generation that aim to reshape the power market.

To my mind Labour’s laudable aims to tackle the Climate Emergency would be much better served by supporting a CO2 tax that complements the UK's coal-free energy record by strengthening renewable investment.

 

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