Iraq still plagued by outages

By International Herald Tribune


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Lack of electricity is still a big problem in Iraq, and there's lots of blame to go around. Much of it goes to the usual suspects: too many insurgent attacks, too few experienced engineers and technicians.

But there's another factor, big and getting bigger, which you probably haven't read about. It's one that Prime Minister Nuri Kamal al-Maliki and his bureaucrats could solve quickly, if they wanted to: Iraq's Ministries of Oil and Electricity are at loggerheads.

While they bicker, Iraqis seethe. During a cold snap this January, I spent a morning interviewing people on the streets of Falluja. Over and over again, I heard variations on two basic themes: appreciation that the coalition had driven the insurgents out of town, and anger over the inability of their government, with American assistance, to provide them with more than an hour or two of electricity each day.

The number of hours may vary, but much the same complaint can be heard just about anywhere in Iraq. Electricity remains a scarce commodity, even though more than $6 billion, mostly in American money, has been devoted to improving supply.

From an encouraging peak of 5,530 megawatts last July 11, typical daily peaks have slipped back to around 4,500 megawatts, according to a recent report by the Special Inspector General for Iraq Reconstruction. That's only about 500 megawatts more than what it was shortly after the start of reconstruction five years ago - before the completion of thousands of American-supported projects. Summer peak demand will be at least 11,000 megawatts, the U.S. State Department estimates.

While the insurgency is a major factor, the heart of the matter is that the oil and electricity ministries have coexisted uneasily ever since they were reconstituted by the Coalition Provisional Authority in 2003. To run its generating plants, the cash-starved Electricity Ministry must beg for whatever fuel the Oil Ministry can spare, while buying as much as it can from places like Kuwait. But charity isn't a priority for Iraq's Oil Ministry - quite the contrary.

Almost all of the Iraqi government's revenues come from oil exports. They totaled $39.8 billion last year, the government says, accounting for about 95 percent of its income. So it is not surprising that the oil minister, Hussain al-Shahristani, has been acting as though every barrel not exported is money wasted.

But that attitude, and the tacit approval of Maliki, is helping to prolong the economic, social and security quagmires that continue to afflict the country. All over Iraq, generating plants sit idle for lack of fuel. The State Department estimates that on a typical day about 1,500 megawatts of power, or one-third of the country's peak output, are unavailable because the Electricity Ministry cannot get enough fuel.

While the Oil Ministry swells the government coffers, hospitals, water-pumping stations and sewage systems function sporadically or not at all. And now countless Iraqis are preparing for yet another summer of sweltering nights and spoiling food.

The Oil Ministry's also refuses to pay for any oil-related projects that do not help the cause of exporting more crude oil. "The Oil Ministry has done zero projects to benefit electricity," an American diplomat in Baghdad told me. "They couldn't care less."

Reconstruction experts at the American Embassy in Baghdad told me of a dozen or so proposed oil projects that could make a big difference in the electricity supply. One is the renovation of the pipeline that brings crude from the southern oil fields to the Doura refinery in Baghdad, which is the nation's largest producer of kerosene and gasoline.

A branch of this pipeline also feeds the Musayyib power plant, south of the capital. Workers there are now finishing a $50 million structure, called a topping unit, to produce diesel fuel for 10 new turbine-generators. Unfortunately, the troubled project to buy and install those generators has dragged on for years and has cost American taxpayers more than $300 million so far. Only four of the generators are ready to operate, but even they sit idle for lack of fuel. A few more generators are expected to be ready in the next couple of months, but the pipeline still won't be capable of delivering enough crude oil for conversion into diesel at the topping unit to run the generators.

To allow this to happen, the pipeline would need an additional pumping station and some general refurbishing. The cost would be very small compared to the money already invested at Musayyib, or compared to alternative fueling schemes like bringing in diesel fuel in convoys of dozens of tanker trucks every day. But the Oil Ministry refuses to modernize the pipeline's pumping system because it wants the oil flowing south for export.

Meanwhile, at the big Qudas power station north of the capital, workers are adding two new generating units to the eight already installed. There's an old oil field literally across the street from Qudas that now pumps enough crude-oil distillate to supply three of the plant's generating units; the other units, however, rely on fuel being trucked in.

It would cost an estimated $50 million to rehabilitate enough of the fields' aging wells and equipment to supply enough an amount of crude, diesel and gas sufficient to fuel 7 of the 10 generating units that Qudas will soon have. Consultants from the American engineering firm Fluor estimate that, given the cost savings from no longer having to truck in the crude, the $50 million would be recouped in about a month. But, here, too, the Oil Ministry isn't interested. "They have no dog in that fight," an embassy official told me. "There's no way for them to make money out of it."

Perhaps the biggest waste of all in Iraq involves not oil but natural gas, an enormous resource that is literally squandered all the time. It comes out of the ground along with oil, and is simply burned off, or "flared," to prevent it from exploding. Yet several studies have concluded that if the gas from the southern oil fields alone were used to generate electricity, it could provide 4,100 megawatts, nearly doubling Iraq's total capacity. Nevertheless, the Oil Ministry has pushed back on every Electricity Ministry proposal over the past five years aimed at capturing and delivering the gas to generating plants.

Not only the two ministries are at odds, their leaders are as well, American diplomats tell me. The oil minister, Shahristani, was trained as a chemical engineer, worked as a nuclear specialist and spent years in Saddam Hussein's prisons - but he had no experience in the oil industry before his appointment.

He is, however, well connected with the Supreme Council for the Islamic Revolution in Iraq, the country's dominant Shiite political party. Meanwhile, the electricity minister, Karim al-Hasan, holds a Ph.D. in electrical engineering and came up through the ranks of the ministry, which gives him great expertise but little political sway.

Efforts to bring coherence and compromise to Iraq's energy ministries have been sparse and fruitless. A multi-ministry "energy-fusion cell" was set up nearly a year ago to work with the Pentagon and State Department on an integrated energy plan, but this has gone nowhere.

One promising note: The Iraqi government's new agreement on sharing oil resources among regions apparently has language mandating that the government stop flaring its natural gas and start capturing and using it.

Iraq has some of the world's largest known oil reserves, but it spent nearly $1 billion - maybe twice that - importing refined oil products last year. That's not the only paradox. Iraqis are experiencing the unfortunate results of America's failure to anticipate the fuel requirements of the three dozen generating units it installed early during reconstruction.

Sadly, thanks to bureaucratic infighting and an obsession with export revenue, their own government is now on a path to institutionalize and perpetuate those energy problems indefinitely.

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Taiwan's economic minister resigns over widespread power outage

Taiwan Power Blackout disrupts Taipei and commercial hubs after a Taoyuan natural gas plant error, triggering nationwide outage, grid failure, elevator rescues, power rationing, and the economic minister's resignation, as CPC Corporation restores supply.

 

Key Points

A nationwide Taiwan outage from human error at a Taoyuan gas plant, triggering rationing and a minister's resignation.

✅ Human error disrupted natural gas supply at Taoyuan plant

✅ 6.68 million users affected; grid failure across cities

✅ Minister Lee resigned; President Tsai ordered a review

 

Taiwan's economic minister resigned after power was knocked out in many parts of Taiwan, with regional parallels such as China power cuts highlighting grid vulnerabilities, including capital Taipei's business and high-end shopping district, due to an apparent "human error" at a key power plant.

Economic Affairs minister Lee Chih-kung tendered his resignation verbally to Premier Lin Chuan, United Daily News reported, citing a Cabinet spokesman. Lin accepted the resignation, the spokesman said according to the daily.

As many as 6.68 million households and commercial units saw their power supply cut or disrupted on Tuesday after "human error" disrupted natural gas supply at a power plant in northern Taiwan's Taoyuan, the semi-official Central News Agency reported, citing the government-controlled oil company CPC Corporation as saying.

The company added that power at the plant, Taiwan's biggest natural gas power plant, resumed two minutes later.

In New Taipei City, there were at least 27,000 reported cases of people being stuck in lifts. Photos in social media also showed huge crowds stranded in lift lobby in Taipei's iconic 101-storey Taipei 101 building.

Power rationing was implemented beginning 6pm, and, as seen in the National Grid short supply warning in other markets, such steps aim to stabilize supply, Central News Agency said. Power supply was gradually being restored beginning at about 9:40pm. news reports said.

President Tsai Ing-wen apologised for the blackout, noting parallels with Japan's near-blackouts that underscored grid resilience, and said that she has ordered all relevant departments to produce clear report in the shortest time possible.

"Electricity is not just a problem about people's livelihoods but also a national security issue. A comprehensive review must be carried out to find out how the electric power system can be so easily paralysed by human error," said Ms Tsai in a Facebook post.

Taiwan has been at risk of a power shortage after a recent typhoon knocked down a power transmission tower in Hualien county along the eastern coast of Taiwan, rather than a demand-driven slowdown like the China power demand drop during pandemic factory shutdowns. This reduced the electricity supply by 1.3million kilowatts, or about 4 per cent of the operating reserve.

That was followed by the breakdown of a power generator at Taiwan's largest power plant, which further reduced the operating reserve by 1.5 per cent.

The situation is worsened by the ongoing heatwave that has hit Taiwan, with temperatures soaring to 38 degrees Celsius over the past week.

As a result, the government had imposed the rationing of electricity, and, highlighting how regional strains such as China's power woes can ripple into global markets, switched off all air-conditioning in many of its Taipei offices, a move that drew some public backlash.

 

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Germany should stop lecturing France on nuclear power, says Eon boss

EU Nuclear Power Dispute strains electricity market reform as Germany resists state aid for French reactors, while Eon urges cooperation to meet the energy transition, low-carbon goals, renewables integration, and cross-border power trade.

 

Key Points

A policy standoff between Germany and France over nuclear energy's role, state aid, and electricity market reforms.

✅ Germany opposes state aid for existing French nuclear plants.

✅ Eon CEO urges compromise to advance market reform and decarbonization.

✅ Cross-border trade shows reliance on French nuclear amid renewables push.

 

Germany should stop trying to impose its views on nuclear power on the rest of the EU, the head of one of Europe’s largest utilities has warned, as he stressed its importance in the region’s clean energy transition.

Leonhard Birnbaum, chief executive of German energy provider Eon, said Berlin should accept differences of opinion as he signalled his desire for a compromise with France to break a deadlock amid a nuclear power dispute over energy reforms.

Germany this year shut down its final three nuclear power plants as it followed through on a long-held promise to drop the use of the energy source, effectively turning its back on nuclear for now, while France has made it a priority to modernise its nuclear power plants.

The differences are delaying reforms to the region’s electricity market and legislation designed to meet greenhouse gas emissions targets.

One sticking point is Germany’s refusal to back French moves to allow governments to provide state aid to existing power plants, which could enable Paris to support the French nuclear fleet.

The Eon chief, whose company has 48mn customers across Europe, said it would be “better for everyone” if the two countries could approach the dispute with the mindset that “everyone does their part”, even as Germany has at times weighed a U-turn on the nuclear phaseout in recent debates.

“Neither the French will be able to persuade us to use nuclear power, nor we will be able to persuade them not to. That’s why I think we should take a different approach to the discussion,” he added.

Birnbaum said Germany “would do well to be a bit cautious about trying to impose our way on everyone else”. This approach was unlikely to be “crowned with success”.

“The better solution will not come from opposing each other, but from working together.”

Birnbaum made the comments at a press conference announcing Eon’s second-quarter results.

The company raised its profit outlook, predicting adjusted net income of €2.7bn to €2.9bn, and promised to reduce bills for customers as it hailed “diminishing headwinds” following the energy crisis caused by the war in Ukraine.

Birnbaum, whose company owned one of the three German nuclear plants shut down this year, pointed out that French nuclear energy was helping the conversion to a system of renewable energy in Germany at a time when Europe is losing nuclear power just when it needs energy.

This was a reference to Europe’s shared power market that allows countries to buy and sell electricity from one another. 

Germany has been a net importer of French electricity since shutting down its own nuclear plants, which last month prompted the French energy minister Agnès Pannier-Runacher to accuse Berlin of hypocrisy. 

“It’s a contradiction to massively import French nuclear energy while rejecting every piece of EU legislation that recognises the value of nuclear as a low-carbon energy source,” Pannier-Runacher told the German business daily Handelsblatt.

She also criticised Berlin’s drive to use new gas-fired power plants as a “bridge” to its target of being carbon neutral by 2045, even as some German officials contend that nuclear won’t solve the gas issue in the near term, arguing that it created a “credibility problem” for Germany: “Gas is a fossil fuel.”

Berlin officials responded by pointing out that Germany was a net exporter of electricity to France over the winter when its nuclear power stations were struggling to produce because of maintenance problems. 

They added that the country only imported French power because it was cheaper, not because their country was suffering shortages.

Berlin argues that renewable energy is cleaner and safer than nuclear, despite renewable rollout challenges linked to cheap Russian gas and grid expansion, and accuses France of seeking to protect the interests of its nuclear industry.

In Paris, officials see Germany’s resistance to nuclear energy as wrong-headed given the need to fight climate change effectively, and worry it is an attempt to undercut a key aspect of French industrial competitiveness.
 

 

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Is tidal energy the surge remote coastal communities need?

BC Tidal Energy Micro-Grids harness predictable tidal currents to replace diesel in remote Indigenous coastal communities, integrating marine renewables, storage, and demand management for resilient off-grid power along Vancouver Island and Haida Gwaii.

 

Key Points

Community-run tidal turbines and storage deliver reliable, diesel-free electricity to remote B.C. coastal communities.

✅ Predictable power from tidal currents reduces diesel dependence

✅ Integrates storage, demand management, and microgrid controls

✅ Local jobs via marine supply chains and community ownership

 

Many remote West Coast communities are reliant on diesel for electricity generation, which poses a number of negative economic and environmental effects.

But some sites along B.C.’s extensive coastline are ideal for tidal energy micro-grids that may well be the answer for off-grid communities to generate clean power, suggested experts at a COAST (Centre for Ocean Applied Sustainable Technologies) virtual event Wednesday.

There are 40 isolated coastal communities, many Indigenous communities, and 32 of them are primarily reliant on diesel for electricity generation, said Ben Whitby, program manager at PRIMED, a marine renewable energy research lab at the University of Victoria (UVic).

Besides being a costly and unreliable source of energy, there are environmental and community health considerations associated with shipping diesel to remote communities and running generators, Whitby said.

“It's not purely an economic question,” he said.

“You've got the emissions associated with diesel generation. There's also the risks of transporting diesel … and sometimes in a lot of remote communities on Vancouver Island, when deliveries of diesel don't come through, they end up with no power for three or four days at a time.”

The Heiltsuk First Nation, which suffered a 110,000-litre diesel spill in its territorial waters in 2016, is an unfortunate case study for the potential environmental, social, and cultural risks remote coastal communities face from the transport of fossil fuels along the rough shoreline.

A U.S. barge hauling fuel for coastal communities in Alaska ran aground in Gale Pass, fouling a sacred and primary Heiltsuk food-harvesting area.

There are a number of potential tidal energy sites near off-grid communities along the mainland, on both sides of Vancouver Island, and in the Haida Gwaii region, Whitby said.

Tidal energy exploits the natural ebb and flow of the coast’s tidal water using technologies like underwater kite turbines to capture currents, and is a highly predictable source of renewable energy, he said.

Micro-grids are self-reliant energy systems drawing on renewables from ocean, wave power resources, wind, solar, small hydro, and geothermal sources.

The community, rather than a public utility like BC Hydro, is responsible for demand management, storage, and generation with the power systems running independently or alongside backup fuel generators — offering the operators a measure of energy sovereignty.

Depending on proximity, cost, and renewable solutions, tidal energy isn’t necessarily the solution for every community, Whitby noted, adding that in comparison to hydro, tidal energy is still more expensive.

However, the best candidates for tidal energy are small, off-grid communities largely dependent on costly fossil fuels, Whitby said.

“That's really why the focus in B.C. is at a smaller scale,” he said.

“The time it would take (these communities) to recoup any capital investment is a lot shorter.

“And the cost is actually on a par because they're already paying a significant amount of money for that diesel-generated power.”

Lisa Kalynchuk, vice-president of research and innovation at UVic, said she was excited by the possibilities associated with tidal power, not only in B.C., but for all of Canada’s coasts.

“Canada has approximately 40,000 megawatts available on our three coastlines,” Kalynchuk said.

“Of course, not all this power can be realized, but it does exist, so that leads us to the hard part — tapping into this available energy and delivering it to those remote communities that need it.”

Challenges to establishing tidal power include the added cost and complexity of construction in remote communities, the storage of intermittent power for later use, the economic model, though B.C.’s streamlined regulatory process may ease approvals, the costs associated with tidal power installations, and financing for small communities, she said.

But smaller tidal energy projects can potentially set a track record for more nascent marine renewables, as groups like Marine Renewables Canada pivot to offshore wind development, at a lower cost and without facing the same social or regulatory resistance a large-scale project might face.

A successful tidal energy demo project was set up using a MAVI tidal turbine in Blind Channel to power a private resort on West Thurlow Island, part of the outer Discovery Islands chain wedged between Vancouver Island and the mainland, Whitby said.

The channel’s strong tidal currents, which routinely reach six knots and are close to the marina, proved a good site to test the small-scale turbine and associated micro-grid system that could be replicated to power remote communities, he said.

The mooring system, cable, and turbine were installed fairly rapidly and ran through the summer of 2017. The system is no longer active as provincial and federal funding for the project came to an end.

“But as a proof of concept, we think it was very successful,” Whitby said, adding micro-grid tidal power is still in the early stages of development.

Ideally, the project will be revived with new funding, so it can continue to act as a test site for marine renewable energy and to showcase the system to remote coastal communities that might want to consider tidal power, he said.

In addition to harnessing a local, renewable energy source and increasing energy independence, tidal energy micro-grids can fuel employment and new business opportunities, said Whitby.

The Blind Channel project was installed using the local supply chain out of nearby Campbell River, he said.

“Most of the vessels and support came from that area, so it was all really locally sourced.”

Funding from senior levels of government would likely need to be provided to set up a permanent tidal energy demonstration site, with recent tidal energy investments in Nova Scotia offering a model, or to help a community do case studies and finance a project, Whitby said.

Both the federal and provincial governments have established funding streams to transition remote communities away from relying on diesel.

But remote community projects funded federally or provincially to date have focused on more established renewables, such as hydro, solar, biomass, or wind.

The goal of B.C.’s Remote Community Energy Strategy, part of the CleanBC plan and aligned with zero-emissions electricity by 2035 targets across Canada, is to reduce diesel use for electricity 80 per cent by 2030 by targeting 22 of the largest diesel locations in the province, many of which fall along the coast.

The province has announced a number of significant investments to shift Indigenous coastal communities away from diesel-generated electricity, but they predominantly involve solar or hydro projects.

A situation that’s not likely to change, as the funding application guide in 2020 deemed tidal projects as ineligible for cash.

Yet, the potential for establishing tidal energy micro-grids in B.C. is good, Kalynchuk said, noting UVic is a hub for significant research expertise and several local companies, including ocean and river power innovators working in the region, are employing and developing related service technologies to install and maintain the systems.

“It also addresses our growing need to find alternative sources of energy in the face of the current climate crisis,” she said.

“The path forward is complex and layered, but one essential component in combating climate change is a move away from fossil fuels to other sources of energy that are renewable and environmentally friendly.”

 

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Energy groups warn Trump and Perry are rushing major change to electricity pricing

DOE Grid Resilience Pricing Rule faces FERC review as energy groups challenge an expedited timeline to reward coal and nuclear for reliability in wholesale markets, impacting natural gas, renewables, baseload economics, and grid pricing.

 

Key Points

A DOE proposal directing FERC to compensate coal and nuclear plants for reliability attributes in wholesale markets.

✅ Industry coalition seeks normal FERC timeline and review

✅ Impacts wholesale pricing, baseload economics, reliability

✅ Request for 90-day comments and reply period

 

A coalition of 11 industry groups is pushing back on Energy Secretary Rick Perry's efforts to quickly implement a major change to the way electric power is priced in the United States.

The Energy Department on Friday proposed a rule that stands to bolster coal and nuclear power plants by forcing the regional markets that set electricity prices to compensate them for the reliability they provide. Perry asked the Federal Energy Regulatory Commission to consider and finalize the rule within 60 days, including a 45-day period during which stakeholders can issue comments.

On Monday, groups representing petroleum, natural gas, electric power and renewable energy interests including ACORE urged FERC to reject the expedited process, as well as the Department of Energy's request that the regulatory commission consider putting in place an interim rule.

They say the time frame is "aggressive" and the department didn't provide adequate justification for fast-tracking a process that could have huge impacts on wholesale electricity markets.

"This is one of the most significant proposed rules in decades related to the energy industry and, if finalized, would unquestionably have significant ramifications for wholesale markets under the Commission's jurisdiction," the groups said in the motion filed with FERC.

"The Energy Industry Associations urge the Commission to reject the proposed unreasonable timelines and instead proceed in a manner that would afford meaningful consideration of public comments and be consistent with the normal deliberative process that it typically affords such major undertakings," they said.

The groups are requesting a 90-day comment period, as well as another period for reply comments. FERC, which has authority to regulate interstate transmission and sale of electricity and natural gas, is not required to decide in favor of the rule but, amid a recent FERC decision that drew industry criticism, must consider it.

Expediting the process or imposing an interim rule is generally limited to emergencies, the groups said. The Energy Department's letter to FERC does not even attempt to establish that an immediate threat to U.S. electricity reliability exists, they allege.

 

  • A coalition of energy industry groups asked regulators to reject a rule proposed by the U.S. Department of Energy on Friday.
  • The rule would bolster coal-fired and nuclear power plants by requiring wholesale markets to compensate them for certain attributes.
  • The groups say the Energy Department proposed "unreasonable timelines" for stakeholders to offer feedback on a rule with "significant ramifications for wholesale markets."

 

The groups cite a recent Energy Department report on grid reliability that concluded: "reliability is adequate today despite the retirement of 11 percent of the generating capacity available in 2002, as significant additions from natural gas, wind, and solar have come online since then."

The Department of Energy did not return a request for comment.

The Energy Department's rule marks a flashpoint in the battle between natural gas-fired and renewable energy and so-called baseload power sources like coal and nuclear.

Separately, coal and business groups have supported the EPA in litigation over the Affordable Clean Energy rule, as documented in legal challenges brought during the rule's defense.

Gas, wind and solar power have eaten into coal and nuclear's share of U.S. electric power generation in recent years. That is thanks to a boom in U.S. gas production that has pushed down prices, the rapid adoption of subsidized renewable energy and President Barack Obama's efforts to mitigate emissions from power plants, which the Trump administration has sought to replace with a tune-up as policies shift.

Electric power is priced in deregulated, wholesale markets in many parts of the country. Utilities typically draw on the cheapest power sources first.

Some worry that the retirement of coal-fired and nuclear power plants undermines the nation's ability to reliably and affordably deliver electricity to households and businesses.

President Donald Trump has vowed to revive the ailing coal industry, declaring an end to the 'war on coal' in public remarks. Trump, Perry and other administration officials reject the consensus among climate scientists that carbon emissions from sources like coal-fired plants are the primary cause of global warming.

 

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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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Plan to End E-Vehicle Subsidies Sparks Anger in Germany

Germany EV Subsidy Cut triggers budget-crisis fallout in the automotive industry, after a constitutional court ruling; EV incentives end, threatening electromobility adoption, manufacturer competitiveness, 2030 targets, and demand amid Chinese competition and weak global growth.

 

Key Points

A sudden end to Germany's EV incentives due to a budget shortfall after a court ruling, hurting automakers and adoption.

✅ Ends buyer rebates amid budget crisis ruling

✅ Risks 2030 EV targets and industry competitiveness

✅ Weak demand and China competition intensify

 

The German government has faced a backlash after abruptly ending an electric car subsidy scheme in a blow to the already struggling automotive industry.

The scheme is one of the casualties of a budget crisis caused by a shock constitutional court ruling in November that upended the government's spending plans.

The economy ministry said Saturday that Sunday would be the last day prospective buyers could apply for the scheme, which paid out thousands of euros per customer to partially cover the cost of buying an electric car today.

A spokesman for the ministry admitted it was an "unfortunate situation" for consumers who had been hoping to take advantage of the subsidy, but it had no choice "because there is no longer enough money available."

Analyst Ferdinand Dudenhoeffer from the Center for Automotive Research warned the decision could have dramatic consequences amid a Europe EV slump already pressuring demand.

"The competitiveness of [auto] manufacturers will now be severely damaged," Dudenhoeffer told the Rheinische Post newspaper.

The Handelsblatt business daily had already warned that scrapping the scheme risked jeopardizing Germany's plans to get 15 million electric cars on the road by 2030, even though the EU EV share grew during lockdowns earlier in the pandemic.

"This goal was already considered extremely unrealistic. Now it seems completely illusory," it wrote.

In the UK, analysts warn that electric cars could cost more if a post-Brexit deal is not reached, underscoring wider market uncertainties.

A total of around 10 billion euros ($1.1 billion) has been paid out since 2016 under the scheme for around 2.1 million electric vehicles, according to the economy ministry.

Germany's flagship automotive industry, including Volkswagen, has been struggling with the transition to electromobility due to a weak global economy and low levels of demand.

In addition, it is facing a serious challenge from homegrown rivals in China, one of its most important markets, as France moves to discourage Chinese EVs with new rules.

"The Chinese are massively expanding their car industry because they have customers. Our manufacturers no longer have any," Dudenhoeffer said, as France's incentive rules make the market tougher for Chinese brands.

Germany's highest court decided last month that the government had broken a constitutional debt rule when it transferred 60 billion euros earmarked for pandemic support to a climate fund.

The bombshell ruling blew a huge hole in spending plans and plunged Chancellor Olaf Scholz's three-way coalition into turmoil.

After adopting an emergency budget for 2023, Scholz and his junior coalition partners battled for weeks before finally finding an agreement for 2024.

 

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