Turkey agrees to supply Georgia power

By Reuters


Substation Relay Protection Training

Our customized live online or in‑person group training can be delivered to your staff at your location.

  • Live Online
  • 12 hours Instructor-led
  • Group Training Available
Regular Price:
$699
Coupon Price:
$599
Reserve Your Seat Today
Turkey has agreed to a request from neighbour Georgia to supply the country with electricity amid the conflict in the breakaway South Ossetia region, a senior Turkish Energy Ministry source told Reuters.

Russia sent forces into Georgia to repel a Georgian assault on the breakaway region and Georgia's pro-Western president said the two countries were at war.

"Under an agreement, Turkey was receiving electricity from Georgia until the evening of August 7. But after the latest developments Georgia requested 30-40 MW (megawatts) of electricity," the ministry source said.

"We gave a positive response," he said.

Under the power agreement between the two countries, the neighbours supply or receive electricity depending on fluctuating demand.

Turkey and Georgia have limited trade links but last month they launched a railway project together with Azerbaijan, building on links forged by gas and oil piplines across the region.

Related News

Ontario announces SMR plans to four reactors at Darlington

Ontario Darlington SMR Expansion advances four GE Hitachi BWRX-300 reactors with OPG, adding 1,200 MW of baseload nuclear power to support electrification, grid reliability, and clean energy growth across Ontario and Saskatchewan.

 

Key Points

Plan to build four BWRX-300 SMRs at Darlington, delivering 1,200 MW of clean, reliable baseload power under OPG.

✅ Four GE Hitachi BWRX-300 units, 1,200 MW total

✅ Shared infrastructure cuts costs and timelines

✅ Supports electrification, grid reliability, net zero

 

The day after Ontario announced it would be building an additional 4,800 megawatts of nuclear reactors at Bruce Nuclear Generating Station, the province announced it would be dramatically expanding its planned rollout of small modular reactors at its Darlington Nuclear Generating Station, and confirmed plans to refurbish Pickering B as part of its broader strategy.

Ontario Power Generation OPG was always going to be the first to build the GE-Hitachi BWRX-300 small modular reactor SMR, with the U.S.’s Tennessee Valley Authority among others like SaskPower and several European nations following suit. But the OPG was originally going to build just one. On July 7, OPG and the Province of Ontario announced they would be bumping that up to four units of the BWRX-300.

The Ontario government is working with Ontario Power Generation (OPG) to commence planning and licensing for three additional small modular reactors (SMRs), for a total of four SMRs at the Darlington nuclear site. Once deployed, these four units would produce a total 1,200 megawatts (MW) of electricity, equivalent to powering 1.2 million homes, helping to meet increasing demand from electrification and fuel the province’s strong economic growth, the Ontario Ministry of Energy said in a release.

“Our government’s open for business approach has led to unprecedented investments across the province — from electric vehicles and battery manufacturing to critical minerals to green steel,” said Todd Smith, Minister of Energy. “Expanding Ontario’s world-leading SMR program will ensure we have the reliable, affordable and clean electricity we need to power the next major international investment, the new homes we are building and industries as they grow and electrify.”

For the first time since 2005, Ontario’s electricity demand is rising. While the government has implemented its plan to meet rising electricity demand this decade, the experts at Ontario’s Independent Electricity System Operator have recommended the province advance new nuclear generation and pursue life-extension at Pickering NGS to provide reliable, baseload power to meet increasing electricity needs in the 2030s and beyond.

Subject to Ontario Government and Canadian Nuclear Safety Commission (CNSC) regulatory approvals on construction, the additional SMRs could come online between 2034 and 2036. That is the same timeframe that SaskPower is looking at for its first, and possibly second, units.

The initial unit is expected to go online in 2028 following Ontario’s first SMR groundbreaking at Darlington.

The Darlington site, which already hosts four reactors, was originally considered for an expansion of “large nuclear,” which is why OPG was already well on its way for site approvals of additional nuclear power generation. The plan changed to one, singular, SMR. Now that has been updated to four.

The announcement has significant impact on Saskatchewan, and its plans to build four of its own SMRs. The timing would allow Ontario Power Generation to apply learnings from the construction of the first unit to deliver cost savings on subsequent units. This is also the strategy SaskPower is following – allow Ontario to build the first, then learn from that experience.

Building multiple units will also allow common infrastructure such as cooling water intake, transmission connection and control room to be utilized by all four units instead of just one, reducing costs even further, the Ministry said.

“A fleet of SMRs at the Darlington New Nuclear Site is key to meeting growing electricity demands and net zero goals,” said Ken Hartwick, OPG President and CEO. “OPG has proven its large nuclear project expertise through the on-time, on budget Darlington Refurbishment project. By taking a similar approach to building a fleet of SMRs, we will deliver cost and schedule savings, and power 1.2 million homes from this site by the mid-2030s.”

The Darlington SMR project is situated on the traditional and treaty territories of the seven Williams Treaties First Nations and is also located within the traditional territory of the Huron Wendat peoples. OPG is actively engaging and consulting with potentially impacted Indigenous communities, including exploring economic opportunities in the Darlington SMR project such as commercial participation and employment.

The Ministry noted, “Ontario’s robust nuclear supply chain is uniquely positioned to support SMR development and deployment in Ontario, Canada and globally. Building additional SMRs at Darlington would provide more opportunities for Ontario companies and broader economic benefits as suppliers of nuclear equipment, components, and services to make further investments to expand their operation to serve the growing SMR market both domestically and abroad.”

Supporting new SMR development and investing in nuclear power is part of the Ontario government’s larger plan, aligned with a Canadian interprovincial nuclear initiative that brings provinces together, to prepare for electricity demand in the 2030s and 2040s that will build on Ontario’s clean electricity advantage and ensure the province has the power to maintain it’s position as leader in job creation and a magnet for the industries of the future, the Ministry said.

In February, World Nuclear News (WNN) reported that Poland was considering up to 79 small modular reactors of the same design as OPG and SaskPower. And on June 5, it reported, “Canada’s Ontario Power Generation will provide operator services to Poland’s Orlen Synthos Green Energy under a letter of intent signed between the partners, extending their existing cooperation on the deployment of small modular reactors.”

WNN added, “The letter of intent is aimed at concluding future agreements under which OPG and its subsidiaries could provide operator services for SMR reactors to OSGE in connection with the deployment of SMRs in Poland and other European countries. The partnership would include a number of SMR-related activities including: development and deployment; operations and maintenance; operator training; commissioning; and regulatory support.”

 

Related News

View more

EIA: Pennsylvania exports the most electricity, California imports the most from other states

U.S. Electricity Trade by State, 2013-2017 highlights EIA grid patterns, interstate imports and exports, cross-border flows with Canada and Mexico, net exporters and importers, and market regions like ISOs and RTOs shaping consumption and generation.

 

Key Points

Brief EIA overview of interstate and cross-border power flows, ranking top net importers and exporters.

✅ Pennsylvania was the largest net exporter, averaging 59 million MWh.

✅ California was the largest net importer, averaging 77 million MWh.

✅ Top cross-border: NY, CA, VT, MN, MI imports; WA, TX, CA, NY, MT exports.

 

According to the U.S. Energy Information Administration (EIA) State Electricity Profiles, from 2013 to 2017, Pennsylvania was the largest net exporter of electricity, while California was the largest net importer.

Pennsylvania exported an annual average of 59 million megawatt-hours (MWh), while California imported an average of 77 million MWh annually.

Based on the share of total consumption in each state, the District of Columbia, Maryland, Massachusetts, Idaho and Delaware were the five largest power-importing states between 2013 and 2017, highlighting how some clean states import 'dirty' electricity as consumption outpaces local generation. Wyoming, West Virginia, North Dakota, Montana and New Hampshire were the five largest power-exporting states. Wyoming and West Virginia were net power exporting states between 2013 and 2017.

New York, California, Vermont, Minnesota and Michigan imported the most electricity from Canada or Mexico on average from 2013 to 2017, reflecting the U.S. look to Canada for green power during that period. Similarly, Washington, Texas, California, New York, and Montana exported the most electricity to Canada or Mexico, on average, during the same period.

Electricity routinely flows among the Lower 48 states and, to a lesser extent, between the United States and Canada and Mexico. From 2013 to 2017, Pennsylvania was the largest net exporter of electricity, sending an annual average of 59 million megawatthours (MWh) outside the state. California was the largest net importer, receiving an average of 77 million MWh annually.

Based on the share of total consumption within each state, the District of Columbia, Maryland, Massachusetts, Idaho, and Delaware were the five largest power-importing states between 2013 and 2017. Wyoming, West Virginia, North Dakota, Montana, and New Hampshire were the five largest power-exporting states. States with major population centers and relatively less generating capacity within their state boundaries tend to have higher ratios of net electricity imports to total electricity consumption, as utilities devote more to electricity delivery than to power production in many markets.

Wyoming and West Virginia were net power exporting states (they exported more power to other states than they consumed) between 2013 and 2017. Customers residing in these two states are not necessarily at an economic disadvantage or advantage compared with customers in neighboring states when considering their electricity bills and fees and market dynamics. However, large amounts of power trading may affect a state’s revenue derived from power generation.

Some states also import and export electricity outside the United States to Canada or Mexico, even as Canada's electricity exports face trade tensions today. New York, California, Vermont, Minnesota, and Michigan are the five states that imported the most electricity from Canada or Mexico on average from 2013 through 2017. Similarly, Washington, Texas (where electricity production and consumption lead the nation), California, New York, and Montana are the five states that exported the most electricity to Canada or Mexico, on average, for the same period.

Many states within the continental United States fall within integrated market regions, referred to as independent system operators or regional transmission organizations. These integrated market regions allow electricity to flow freely between states or parts of states within their boundaries.

EIA’s State Electricity Profiles provide details about the supply and disposition of electricity for each state, including net trade with other states and international imports and exports, and help you understand where your electricity comes from more clearly.

 

Related News

View more

High Natural Gas Prices Make This The Time To Build Back Better - With Clean Electricity

Build Back Better Act Energy Savings curb volatile fossil fuel heating bills by accelerating electrification and renewable electricity, insulating households from natural gas, propane, and oil price spikes while cutting emissions and lowering energy costs.

 

Key Points

BBBA policies expand clean power and electrification to curb volatility, lower bills, and cut emissions.

✅ Tax credits for renewables, EVs, and efficient all-electric homes

✅ Shields households from natural gas, propane, and heating oil spikes

✅ Cuts methane, lowers bills, and improves grid reliability and jobs

 

Experts are forecasting serious sticker shock from home heating bills this winter. Nearly 60 percent of United States’ households heat their homes with fossil fuels, including natural gas, propane, or heating oil, and these consumers are expected to spend much more this winter because of fuel price increases.

That could greatly burden many families and businesses already operating on thin margins. Yet homes that use electricity for heating and cooking are largely insulated from the pain of volatile fuel markets, and they’re facing dramatically lower price increases as a result.

Projections say cost increases for households could range anywhere from 22% to 94% more, depending on the fuel used for heating and the severity of the winter temperatures. But the added expenditures for the 41% of U.S. households using electricity for heating are much less stark—these consumers will see only a 6% price increase on average. The projected fossil fuel price spikes are largely due to increased demand, limited supply, declining fuel stores, and shifting investment priorities in the face of climate change.

The fossil fuel industry is already seizing this moment to use high prices to persuade policymakers to vote against clean energy policies, particularly the Build Back Better Act (BBBA). Spokespeople with ties to the fossil fuel industry and some consumer groups are trying to pin higher fuel prices on the proposed legislation even before it has passed, even as analyses show the energy crisis is not spurring a green revolution on its own, let alone begun impacting fuel markets. But the claim the BBBA would cost Americans and the economy is false.

The facts tell a different story. Adopting smart climate policies and accelerating the clean energy transition are precisely the solutions to counter this vicious cycle by ending our dependance on volatile fossil fuels. The BBBA will ensure reliable, affordable clean electricity for millions of Americans, in line with a clean electricity standard many experts advocate—a key strategy for avoiding future vulnerability. Unlike fossil fuels subject to the whims of a global marketplace, wind and sunshine are always free. So renewable-generated electricity comes with an ultra-low fixed price decades into the future.

By expanding clean energy and electric vehicle tax credits, creating new incentives for efficient all-electric homes, and dedicating new funding for state and local programs, the BBBA provides practical solutions that build on lessons from Biden's climate law to protect Americans from price shocks, save consumers money, and reduce emissions fueling dangerous climate change.


What’s really causing the gas price spikes?
The U.S. Energy Information Administration’s winter 2021 energy price forecasts project that homes heated with natural gas, fuel oil, and propane will see average price increases of 30%, 43%, and 54%, respectively. Those who heat their homes with electricity, on the other hand, should expect a modest 6% increase. At the pump, drivers are seeing some of the highest gas prices in nearly a decade as the U.S. energy crisis ripples through electricity, gas, and EV markets today. And the U.S. is not alone. Countries around the globe are experiencing similar price jumps, including Britain's high winter energy costs this season.

A closer look confirms the cause of these high prices is not clean energy or climate policies—it’s fossil fuels themselves.  

First, the U.S. (and the world) are just now feeling the effects of the oil and gas industry’s reduced fuel production and spending due to the pandemic. COVID-19 brought the world’s economies to a screeching halt, and most countries have not returned to pre-COVID economic activity. During the past 20 months, the oil and gas industry curtailed its production to avoid oversupply as demand fell to all-time lows. Just as businesses were reopening, stored fuel was needed to meet high demand for cooling during 2021’s hottest summer on record, driving sky-high summer energy bills for many households. February’s Texas Big Freeze also disrupted gas distribution and production.

The world is moving again and demand for goods and services is rebounding to pre-pandemic levels. But even with higher energy demand, OPEC announced it would not inject more oil into the economy. Major oil companies have also held oil and gas spending flat in 2021, with their share of overall upstream spending at 25%, compared with nearly 40% in the mid-2010s. And as climate change threats loom in the financial world, investors are reducing their exposure to the risks of stranded assets, increasingly diversifying and divesting from fossil fuels. 

Second, despite strong and sustained growth for renewable energy, energy storage, and electric vehicles, the relatively slow pace to adopt fossil fuel alternatives at scale has left U.S. households and businesses tethered to an industry well-known for price volatility. Today, some oil drillers are using profits from higher gas prices to pay back debt and reward shareholders as demanded by investors, instead of increasing supply. Rising prices for a limited commodity in high demand is generating huge profits for many of the world’s largest companies at the expense of U.S. households.

Because 48% of homes use fossil gas for heating and another 10% heat with propane and fuel oil, more than half of U.S. households will feel the impact of rising prices on their home energy bills. One in four U.S. households continues to experience a high energy burden (meaning their energy expenses consume an inordinate amount of their income), including risks of pandemic power shut-offs that deepen energy insecurity, and many are still experiencing financial hardships exacerbated by the pandemic. Those with inefficient fossil-fueled appliances, homes, and cars will be hardest hit, and many families with fixed- and lower-incomes could be forced to choose between heat or other necessities.

We have the solutions—the BBBA will unlock their benefits for all households

Short-term band-aids may be enticing, but long-term policies are the only way out of this negative feedback loop. Clean energy and building electrification will prevent more costly disasters in the future, but they’re the very solutions the fossil fuel industry fights at every turn. All-electric homes and vehicles are a natural hedge against the price spikes we’re experiencing today since renewables are inherently devoid of fuel-related price fluctuations.

RMI analysis shows all-electric single-family homes in all regions of the country have lower energy bills than a comparable mixed fuel-homes (i.e., electricity and gas). Electric vehicles also save consumers money. Research from University of California, Berkeley and Energy Innovation found consumers could save a total of $2.7 trillion in 2050—or $1,000 per year, per household for the next 30 years—if we accelerate electric vehicle deployment in the coming decade.

The BBBA would help deliver these consumer savings by expanding and expediting clean energy, while ensuring equitable adoption among lower-income households and underserved communities. Extending and expanding clean energy tax credits; new incentives for electric vehicles (including used electric vehicles); and new incentives for energy efficient homes and all-electric appliances (and electrical upgrades) will reduce up-front costs and spur widespread adoption of all-electric homes, buildings, and cars.

A combination of grants, incentives, and programs will promote private sector investments in a decarbonized economy, while also funding and supporting state and local governments already leading the way. The BBBA also allocates dedicated funding and makes important modifications (such as higher rebate amounts and greater point-of-purchase availability) to ensure these technologies are available to low-income households, underserved urban and rural communities, tribes, frontline communities, and people living in multifamily housing.

Finally, the BBBA proposes to make oil and gas polluters pay for the harm they are causing to people’s health and the climate through a methane fee. This fee would cost companies less than 1% of their revenue, meaning the industry would retain over 99% of its profits. In return return we’d see substantial reductions of a powerful greenhouse gas and a healthier environment in communities living near fossil fuel production. These benefits also come with a stronger economy—Energy Innovation analysis shows the methane fee would create more than 70,000 jobs by 2050 and boost gross domestic product more than $250 billion from 2023 to 2050.

The facts speak for themselves. Gas prices are rising because of reasons totally unrelated to smart climate and clean energy policies, which research shows actually lower costs. For the first time in more than a decade, America has the opportunity to enact a comprehensive energy policy that will yield measurable savings to consumers and free us from oil and gas industry control over our wallets.

The BBBA will help the U.S. get off the fossil fuel rollercoaster and achieve a stable energy future, ensuring that today’s price spikes will be a thing of the past. Proving, once and for all, that the solution to our fossil fuel woes is not more fossil fuels.

 

Related News

View more

Canadian power crews head to Irma-hit Florida to help restore service

Canadian Power Crews Aid Florida after Hurricane Irma, supporting power restoration for Tampa Electric and Florida Power & Light. Hydro One and Nova Scotia Power teams provide mutual aid to speed outage repairs across communities.

 

Key Points

Mutual aid effort sending Canadian utility crews to restore power and repair outages in Florida after Hurricane Irma.

✅ Hydro One and Nova Scotia Power deploy line technicians

✅ Support for Tampa Electric and Florida Power & Light

✅ Goal: rapid power restoration and outage repairs statewide

 

Hundreds of Canadian power crews are heading to Florida to help restore power to millions of people affected by Hurricane Irma.

Two dozen Nova Scotia Power employees were en route Tampa on Tuesday morning. An additional 175 Hydro One employees from across Ontario are also heading south. Tuesday to assist after receiving a request for assistance from Tampa Electric.

Nearly 7½ million customers across five states were without power Tuesday morning as Irma — now a tropical storm — continued inland, while a power outage update from the Carolinas underscored the regional strain.

In an update On Tuesday, Florida Power & Light said its "army" of crews had already restored power to 40 per cent of the five million customers affected by Irma in the first 24 hours.

FPL said it expects to have power restored in nearly all of the eastern half of the state by the end of this coming weekend. Almost everyone should have power restored by the end of day on Sept. 22, except for areas still under water.Jason Cochrane took a flight from Halifax Stanfield International Airport along with 19 other NSP power line technicians, two supervisors and a restoration team lead, drawing on lessons from the Maritime Link first power project between Newfoundland and Nova Scotia. "It's different infrastructure than what we have to a certain extent, so there'll be a bit of a learning curve there as well," Cochrane said. "But we'll be integrated into their workforce, so we'll be assisting them to get everything put back together."

The NSP team will join 86 other Nova Scotians from their parent company, Emera, who are also heading to Tampa. Halifax-based Emera, whose regional projects include the Maritime Link, owns a subsidiary in Tampa.

"We're going to be doing anything that we can to help Tampa Electric get their customers back online," said NSP spokesperson Tiffany Chase. "We know there's been significant damage to their system as a result of that severe storm and so anything that our team can do to assist them, we want to do down in Tampa."

Crews have been told to expect to be on the ground in the U.S. for two weeks, but that could change as they get a better idea of what they're dealing with.

'It's neat to have an opportunity like this to go to another country and to help out.'- Jason Cochrane, power line technician

"It's neat to have an opportunity like this to go to another country and to help out and to get the power back on safely," said Cochrane.

Chase said she doesn't know how much the effort will cost but it will be covered by Tampa Electric. She also said Nova Scotia Power will pull its crews back if severe weather heads toward Atlantic Canada, as utilities nationwide work to adapt to climate change in their planning.

 

Related News

View more

Altmaier's new electricity forecast: the main driver is e-mobility

Germany 2030 Electricity Demand Forecast projects 658 TWh, driven by e-mobility, heat pumps, and green hydrogen. BMWi and BDEW see higher renewables, onshore wind, photovoltaics, and faster grid expansion to meet climate targets.

 

Key Points

A BMWi outlook to 658 TWh by 2030, led by e-mobility, plus demand from heat pumps, green hydrogen, and industry.

✅ Transport adds ~70 TWh; cars take 44 TWh by 2030

✅ Heat pumps add 35 TWh; green hydrogen needs ~20 TWh

✅ BDEW urges 70% renewables and faster grid expansion

 

Gross electricity consumption in Germany will increase from 595 terawatt hours (TWh) in 2018 to 658 TWh in 2030. That is an increase of eleven percent. This emerges from the detailed analysis of the development of electricity demand that the Federal Ministry of Economics (BMWi) published on Tuesday. The main driver of the increase is therefore the transport sector. According to the paper, increased electric mobility in particular contributes 68 TWh to the increase, in line with rising EV power demand trends across markets. Around 44 TWh of this should be for cars, 7 TWh for light commercial vehicles and 17 TWh for heavy trucks. If the electricity consumption for buses and two-wheelers is added, this results in electricity consumption for e-mobility of around 70 TWh.

The number of purely battery-powered vehicles is increasing according to the investigation by the BMWi to 16 million by 2030, reflecting the global electric car market momentum, plus 2.2 million plug-in hybrids. In 2018 there were only around 100,000 electric cars, the associated electricity consumption was an estimated 0.3 TWh, and plug-in mileage in 2021 highlighted the rapid uptake elsewhere. For heat pumps, the researchers predict an increase in demand by 35 TWh to around 42 TWh. They estimate the electricity consumption for the production of around 12.5 TWh of green hydrogen in 2030 to be just under 20 TWh. The demand at battery factories and data centers will increase by 13 TWh compared to 2018 by this point in time. In the data centers, there is no higher consumption due to more efficient hardware despite advancing digitization.

The updated figures are based on ongoing scenario calculations by Prognos, in which the market researchers took into account the goals of the Climate Protection Act for 2030 and the wider European electrification push for decarbonization. In the preliminary estimate presented by Federal Economics Minister Peter Altmaier (CDU) in July, a range of 645 to 665 TWh was determined for gross electricity consumption in 2030. Previously, Altmaier officially said that electricity demand in this country would remain constant for the next ten years. In June, Chancellor Angela Merkel (CDU) called for an expanded forecast that would have to include trends in e-mobility adoption within a decade and the Internet of Things, for example.

Higher electricity demand
The Federal Association of Energy and Water Management (BDEW) is assuming an even higher electricity demand of around 700 TWh in nine years. In any case, a higher share of renewable energies in electricity generation of 70 percent by 2030 is necessary in order to be able to achieve the climate targets and to address electricity price volatility risks. The expansion paths urgently need to be increased and obstacles removed. This could mean around 100 gigawatts (GW) for onshore wind turbines, 11 GW for biomass and at least 150 GW for photovoltaics by 2030. Faster network expansion and renovation will also become even more urgent, as electric cars challenge grids in many regions.
 

 

Related News

View more

Trump's Oil Policies Spark Shift in Wall Street's Energy Strategy

Wall Street Fossil Fuel Pivot signals banks reassessing ESG, net-zero, and decarbonization goals, reviving oil, gas, and coal financing while recalibrating clean energy exposure amid policy shifts, regulatory rollbacks, and investment risk realignment.

 

Key Points

A shift as major U.S. banks ease ESG limits to fund oil, gas, coal while rebalancing alongside renewables.

✅ Banks revisit lending to oil, gas, and coal after policy shifts.

✅ ESG and net-zero commitments face reassessment amid returns.

✅ Renewables compete for capital as risk models are updated.

 

The global energy finance sector, worth a staggering $1.4 trillion, is undergoing a significant transformation, largely due to former President Donald Trump's renewed support for the oil, gas, and coal industries. Wall Street, which had previously aligned itself with global climate initiatives and the energy transition and net-zero goals, is now reassessing its strategy and pivoting toward a more fossil-fuel-friendly stance.

This shift represents a major change from the earlier stance, where many of the largest U.S. banks and financial institutions took a firm stance on decarbonization push, including limiting their exposure to fossil-fuel projects. Just a few years ago, these institutions were vocal supporters of the global push for a sustainable future, with many committing to support clean energy solutions and abandon investments in high-carbon energy sources.

However, with the change in administration and the resurgence of support for traditional energy sectors under Trump’s policies, these same banks are now rethinking their strategies. Financial institutions are increasingly discussing the possibility of lifting long-standing restrictions that limited their investments in controversial fossil-fuel projects, including coal mining, where emissions drop as coal declines, and offshore drilling. The change reflects a broader realignment within the energy finance sector, with Wall Street reexamining its role in shaping the future of energy.

One of the most significant developments is the Biden administration’s policy reversal, which emphasized reducing the U.S. carbon footprint in favor of carbon-free electricity strategies. Under Trump, however, there has been a renewed focus on supporting the traditional energy sectors. His administration has pushed to reduce regulatory burdens on fossil-fuel companies, particularly oil and gas, while simultaneously reintroducing favorable tax incentives for the coal and gas industries. This is a stark contrast to the Biden administration's efforts to incentivize the transition toward renewable energy and zero-emissions goals.

Trump's policies have, in effect, sent a strong signal to financial markets that the fossil-fuel industry could see a resurgence. U.S. banks, which had previously distanced themselves from financing oil and gas ventures due to the pressure from environmental activists and ESG (Environmental, Social, and Governance) investors, as seen in investor pressure on Duke Energy, are now reconsidering their positions. Major players like JPMorgan Chase and Goldman Sachs are reportedly having internal discussions about revisiting financing for energy projects that involve high carbon emissions, including controversial oil extraction and gas drilling initiatives.

The implications of this shift are far-reaching. In the past, a growing number of institutional investors had embraced ESG principles, with the goal of supporting the transition to renewable energy sources. However, Trump’s pro-fossil fuel stance appears to be emboldening Wall Street’s biggest players to rethink their commitment to green investing. Some are now advocating for a “balanced approach” that would allow for continued investment in traditional energy sectors, while also acknowledging the growing importance of renewable energy investments, a trend echoed by European oil majors going electric in recent years.

This reversal has led to confusion among investors and analysts, who are now grappling with how to navigate a rapidly changing landscape. Wall Street's newfound support for the fossil-fuel industry comes amid a backdrop of global concerns about climate change. Many investors, who had previously embraced policies aimed at curbing the effects of global warming, are now finding it harder to reconcile their environmental commitments with the shift toward fossil-fuel-heavy portfolios. The reemergence of fossil-fuel-friendly policies is forcing institutional investors to rethink their long-term strategies.

The consequences of this policy shift are also being felt by renewable energy companies, which now face increased competition for investment dollars from traditional energy sectors. The shift towards oil and gas projects has made it more challenging for renewable energy companies to attract the same level of financial backing, even as demand for clean energy continues to rise and as doubling electricity investment becomes a key policy call. This could result in a deceleration of renewable energy projects, potentially delaying the progress needed to meet the world’s climate targets.

Despite this, some analysts remain optimistic that the long-term shift toward green energy is inevitable, even if fossil-fuel investments gain a temporary boost. As the world continues to grapple with the effects of climate change, and as technological advancements in clean energy continue to reduce costs, the transition to renewables is likely to persist, regardless of the political climate.

The shift in Wall Street’s approach to energy investments, spurred by Trump’s pro-fossil fuel policies, is reshaping the $1.4 trillion global energy finance market. While the pivot towards fossil fuels may offer short-term gains, the long-term trajectory for energy markets remains firmly in the direction of renewables. The next few years will be crucial in determining whether financial institutions can balance the demand for short-term profitability with their long-term environmental responsibilities.

 

Related News

View more

Sign Up for Electricity Forum’s Newsletter

Stay informed with our FREE Newsletter — get the latest news, breakthrough technologies, and expert insights, delivered straight to your inbox.

Electricity Today T&D Magazine Subscribe for FREE

Stay informed with the latest T&D policies and technologies.
  • Timely insights from industry experts
  • Practical solutions T&D engineers
  • Free access to every issue

Live Online & In-person Group Training

Advantages To Instructor-Led Training – Instructor-Led Course, Customized Training, Multiple Locations, Economical, CEU Credits, Course Discounts.

Request For Quotation

Whether you would prefer Live Online or In-Person instruction, our electrical training courses can be tailored to meet your company's specific requirements and delivered to your employees in one location or at various locations.