By the Year of 2020, the Amount of Installed Generation Capacity of Hydropower All over China Will Reach 270 Million

Gulf Power renewable energy contract underscores a Florida PSC-approved power purchase from Bay County's municipal solid waste plant, delivering 13.65 MW at a fixed price, boosting fuel diversity, lowering landfill waste, and saving customers money.

Key Points

A fixed-price PPA for 13.65 MW from Bay County's waste-to-energy plant, approved by Florida PSC to cut costs.

✅ Fixed-price purchase; pay only for energy produced.

✅ 13.65 MW from Bay County waste-to-energy facility.

✅ Cuts landfill waste and natural gas dependency.

The Florida Public Service Commission (PSC) approved Tuesday a contract under which Gulf Power Company will purchase all the electricity generated by the Bay County Resource Recovery Facility, a municipal solid waste plant, similar to SaskPower-Manitoba Hydro deal structures seen elsewhere, over the next six years.

“Gulf’s renewable energy purchase promotes Florida’s fuel diversity, further reducing our dependency on natural gas,” PSC Chairperson Julie Brown said. “This renewable energy option also reduces landfill waste, saves customers money, and serves the public interest.”

The contract provides for Gulf to acquire the Panama City facility’s 13.65 megawatts of renewable generation for its customers beginning in July 2017. Gulf will pay a fixed price, aligned with approaches in Alberta's clean electricity RFP programs, and only pays for the energy produced. The contract is expected to save approximately $250,000 and provides security for customers, a contrast to overruns at the Kemper power plant project, because if the plant does not supply energy, Gulf does not have to provide payment.

This contract is the third renewable energy contract between Gulf and Bay County, at a time when the Southern California plant closures may be postponed, continuing agreements approved in 2008 and 2014. In making the decision, the PSC considered Gulf’s need for power and developments such as the Turkey Point license renewal process, as well as the contract’s cost-effectiveness, payment provisions, and performance guarantees, as required by rule.

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Texas Energy Policy Debate centers on ERCOT and PUC directives, fossil fuels vs renewables, grid reliability, energy efficiency, battery storage, and blackout risks, shaping Texas power market rules, conservation alerts, and capacity planning.

Key Points

Policy fight over ERCOT/PUC rules weighing fossil fuels vs renewables and storage to bolster Texas grid reliability.

✅ ERCOT and PUC directives under political scrutiny

✅ Fossil fuel subsidies vs renewable incentives and storage

✅ Focus on grid reliability, efficiency, and blackout prevention

Earlier this week, Governor Abbott released a letter to the Public Utility Commission of Texas (PUC) and the Electric Reliability Council of Texas (ERCOT), demanding electricity market reforms that Abbott falsely claims will "increase power generation capacity and to ensure the reliability of the Texas power grid."

Unfortunately, Abbott's letter promotes polluting, unreliable fossil fuels, attacks safer clean energy options, and ignores solutions that would actually benefit everyday Texans.

"Governor Abbott, in a blatant effort to politicize Texans' energy security, wants to double down on fossil fuels, even though they were the single largest point of failure during both February's blackouts and June's energy conservation alerts," said Cyrus Reed, Interim Director & Conservation Director of the Lone Star Chapter of the Sierra Club.

"Many of these so-called solutions were considered and rejected most recently by the Texas Legislature. Texas must focus on expanding clean and reliable renewable energy, energy efficiency, and storage capacity, as voters consider funding to modernize generation in the months ahead.

"We can little afford to repeat the same mistakes that have failed to provide enough electricity where it is needed most and cost Texans billions of dollars. Instead of advocating for evidence-based solutions, Abbott wants to be a culture warrior for coal and gas, even as he touts grid readiness amid election season, even when it results in blackouts across Texas."

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BC-Alberta Electricity Restrictions spotlight interprovincial energy tensions, limiting power exports and affecting grid reliability, energy sharing, and climate goals, while raising questions about federal-provincial coordination, smart grids, and storage investments.

Key Points

Policies limiting Alberta's power exports to provinces like BC, prioritizing local demand and affecting grid reliability.

✅ Prioritizes Alberta load over interprovincial power exports

✅ Risks to BC peak demand support and outage resilience

✅ Pressures for federal-provincial coordination and smart-grid investment

In a move that underscores the complexities of Canada's interprovincial energy relationships, the government of British Columbia (B.C.) has formally expressed concerns over recent electricity restrictions imposed by Alberta after it suspended electricity purchase talks with B.C., amid ongoing regional coordination challenges.

Background: Alberta's Electricity Restrictions

Alberta, traditionally reliant on coal and natural gas for electricity generation, has been undergoing a transition towards more sustainable energy sources as it pursues a path to clean electricity in the province.

In response, Alberta introduced restrictions on electricity exports, aiming to prioritize local consumption and stabilize its energy market and has proposed electricity market changes to address structural issues.

B.C.'s Position: Ensuring Energy Reliability and Cooperation

British Columbia, with its diverse energy portfolio and commitment to sustainability, has historically relied on the ability to import electricity from Alberta, especially during periods of high demand or unforeseen shortfalls. The recent restrictions threaten this reliability, prompting B.C.'s government to take action amid an electricity market reshuffle now underway.

B.C. officials have articulated that access to Alberta's electricity is crucial, particularly during outages or times when local generation does not meet demand. The ability to share electricity among provinces ensures a stable and resilient energy system, benefiting consumers and supporting economic activities, including critical minerals operations, that depend on consistent power supply.

Moreover, B.C. has expressed concerns that Alberta's restrictions could set a precedent that might affect future interprovincial energy agreements. Such a precedent could complicate collaborative efforts aimed at achieving national energy goals, including sustainability targets and infrastructure development.

Broader Implications: National Energy Strategy and Climate Goals

The dispute between B.C. and Alberta over electricity exports highlights the absence of a cohesive national energy strategy, as external pressures, including electricity exports at risk, add complexity. While provinces have jurisdiction over their energy resources, the interconnected nature of Canada's power grids necessitates coordinated policies that balance local priorities with national interests.

This situation also underscores the challenges Canada faces in meeting its climate objectives. Transitioning to renewable energy sources requires not only technological innovation but also collaborative policies that ensure energy reliability and affordability across provincial boundaries, as rising electricity prices in Alberta demonstrate.

Potential Path Forward: Dialogue and Negotiation

Addressing the concerns arising from Alberta's electricity restrictions requires a nuanced approach that considers the interests of all stakeholders. Open dialogue between provincial governments is essential to identify solutions that uphold the principles of energy reliability, economic cooperation, and environmental sustainability.

One potential avenue is the establishment of a federal-provincial task force dedicated to energy coordination. Such a body could facilitate discussions on resource sharing, infrastructure investments, and policy harmonization, aiming to prevent conflicts and promote mutual benefits.

Additionally, exploring technological solutions, such as smart grids and energy storage systems, could enhance the flexibility and resilience of interprovincial energy exchanges. Investments in these technologies may reduce the dependency on traditional export mechanisms, offering more dynamic and responsive energy management strategies.

The tensions between British Columbia and Alberta over electricity restrictions serve as a microcosm of the broader challenges facing Canada's energy sector. Balancing provincial autonomy with national interests, ensuring equitable access to energy resources, and achieving climate goals require collaborative efforts and innovative solutions. As the situation develops, stakeholders across the political, economic, and environmental spectrums will need to engage constructively, fostering a Canadian energy landscape that is resilient, sustainable, and inclusive.

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Small Modular Reactors in Canada are advancing through provincial collaboration, offering nuclear energy, clean power and carbon reductions for grids, remote communities, and mines, with factory-built modules, regulatory roadmaps, and pre-licensing by the nuclear regulator.

Key Points

Compact, factory-built nuclear units for clean power, cutting carbon for grids, remote communities, and industry.

✅ Provinces: Ontario, Saskatchewan, New Brunswick collaborate

✅ Targets coal replacement, carbon cuts, clean baseload power

✅ Modular, factory-made units; 5-10 year deployment horizon

The premiers of Ontario, Saskatchewan and New Brunswick have committed to collaborate on developing nuclear reactor technology in Canada. 

Doug Ford, Scott Moe and Blaine Higgs made the announcement and signed a memorandum of understanding on Sunday in advance of a meeting of all the premiers. 

They will be working on the research, development and building of small modular reactors as a way to help their individual provinces reduce carbon emissions and move away from non-renewable energy sources like coal. 

Small modular reactors are easy to construct, are safer than large reactors and are regarded as cleaner energy than coal, the premiers say. They can be small enough to fit in a school gym. 

SMRs are actually not very close to entering operation in Canada, though Ontario broke ground on its first SMR at Darlington recently, signaling early progress. Natural Resources Canada released an "SMR roadmap" last year, with a series of recommendations about regulation readiness and waste management for SMRs.

In Canada, about a dozen companies are currently in pre-licensing with the Canadian Nuclear Safety Commission, which is reviewing their designs.

"Canadians working together, like we are here today, from coast to coast, can play an even larger role in addressing climate change in Canada and around the world," Moe said.  

Canada's Paris targets are to lower total emissions 30 per cent below 2005 levels by 2030, and nuclear's role in climate goals has been emphasized by the federal minister in recent remarks. Moe says the reactors would help Saskatchewan reach a 70 per cent reduction by that year.

The provinces' three energy ministries will meet in the new year to discuss how to move forward and by the fall a fully-fledged strategy for the reactors is expected to be ready.

However, don't expect to see them popping up in a nearby field anytime soon. It's estimated it will take five to 10 years before they're built. 

Ford lauds economic possibilities
The provincial leaders said it could be an opportunity for economic growth, estimating the Canadian market for this energy at $10 billion and the global market at $150 billion.

Ford called it an "opportunity for Canada to be a true leader." At a time when Ottawa and the provinces are at odds, Higgs said it's the perfect time to show unity. 

"It's showing how provinces come together on issues of the future." 

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No other premiers have signed on to the deal at this point, but Ford said all are welcome and "the more, the merrier."

But developing new energy technologies is a daunting task. Higgs admitted the project will need national support of some kind, though he didn't specify what. The agreement signed by the premiers is also not binding. 

About 8.6 per cent of Canada's electricity comes from coal-fired generation. In New Brunswick that figure is much higher — 15.8 per cent — and New Brunswick's small-nuclear debate has intensified as New Brunswick Premier Blaine Higgs has said he worries about his province's energy producers being hit by the federal carbon tax.

Ontario has no coal-fired power plants, and OPG's SMR commitment aligns with its clean electricity strategy today. In Saskatchewan, burning coal generates 46.6 per cent of the province's electricity.

How would it work?
The federal government describes small modular reactors (SMRs) as the "next wave of innovation" in nuclear energy technology, and collaborations like the OPG and TVA partnership are advancing development efforts, and an "important technology opportunity for Canada."

Traditional nuclear reactors used in Canada typically generate about 800 megawatts of electricity, and Ontario is exploring new large-scale nuclear plants alongside SMRs, or enough to power about 600,000 homes at once (assuming that 1 megawatt can power about 750 homes).

The International Atomic Energy Agency (IAEA), the UN organization for nuclear co-operation, considers a nuclear reactor to be "small" if it generates under 300 megawatts.

Designs for small reactors ranging from just 3 megawatts to 300 megawatts have been submitted to Canada's nuclear regulator, the Canadian Nuclear Safety Commission, for review as part of a pre-licensing process, while plans for four SMRs at Darlington outline a potential build-out pathway that regulators will assess.

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Such reactors are considered "modular" because they're designed to work either independently or as modules in a bigger complex (as is already the case with traditional, larger reactors at most Canadian nuclear power plants). A power plant could be expanded incrementally by adding additional modules.

Modules are generally designed to be small enough to make in a factory and be transported easily — for example, via a standard shipping container.

In Canada, there are three main areas where SMRs could be used:

Traditional, on-grid power generation, especially in provinces looking for zero-emissions replacements for CO2-emitting coal plants.
Remote communities that currently rely on polluting diesel generation.
Resource extraction sites, such as mining and oil and gas.
 

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Spain Electricity Demand April 2020 saw a 17.3% year-on-year drop as COVID-19 lockdown curbed activity; renewables and wind power lifted the emission-free share, while combined cycle plants dominated islands, per REE data.

Key Points

A 17.3% y/y decline amid COVID-19 lockdown, with 47.9% renewables and wind at 21.3% of the national power mix.

✅ Mainland demand -17%; Balearic -27.6%; Canary -20.3%.

✅ Emission-free share: 49.7% on the peninsula in April.

✅ Combined cycle led islands; coal absent in Balearics.

Demand for electricity in Spain dropped by 17.3% year-on-year to an estimated 17,104 GWh in April, aligning with a 15% global daily demand dip during the pandemic, while the country’s economy slowed down under the national state of emergency and lockdown measures imposed to curb the spread of COVID-19.

According to the latest estimates by Spanish grid operator Red Electrica de Espana (REE), the decline in demand was registered across Spain’s entire national territory, similar to a 10% UK drop during lockdown. On the mainland, it decreased by 17% to 16,191 GWh, while on the Balearic and the Canary Islands it plunged by 27.6% and 20.3%, respectively.

Renewables accounted for 47.9% of the total national electricity production in April, echoing Britain’s cleanest electricity trends during lockdown. Wind power production went down 20% year-on-year to 3,730 GWh, representing a 21.3% share in the total power mix.

During April, electricity generation in the peninsula was mostly based on emission-free technologies, reflecting an accelerated power-system transition across Europe, with renewables accounting for 49.7%. Wind farms produced 3,672 GWh, 20.1% less compared to April 2019, while contributing 22% to the power mix, even as global demand later surpassed pre-pandemic levels in subsequent periods.

In the Balearic Islands, electricity demand of 323,296 MWh was for the most part met by combined cycle power plants, even as some European demand held firm in later lockdowns, which accounted for 78.3% of the generation. Renewables and emission-free technologies had a combined share of 6.4%, while coal was again absent from the local power mix, completing now four consecutive months without contributing a single MWh.

In the Canary Islands system, demand for power decreased to 558,619 MWh, even as surging demand elsewhere strained power systems across the world. Renewables and emission-free technologies made up 14.3% of the mix, while combined cycle power plants led with a 45.3% share.

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Sustainable Marine tidal energy delivers in-stream power to Nova Scotia's grid from Grand Passage, proving low-impact, renewable generation and advancing a floating tidal array at FORCE and Minas Passage in the Bay of Fundy.

Key Points

The first in-stream tidal project supplying clean power to Nova Scotia's grid, proven at Grand Passage.

✅ First to deliver in-stream tidal power to Canada's grid

✅ Demonstration at Grand Passage informs FORCE deployments

✅ Low-impact design and environmental monitoring validated

Sustainable Marine has officially powered up its tidal energy operation in Canada and is delivering clean electricity to the power system in Nova Scotia, on the country’s Atlantic coast, as the province moves to increase wind and solar projects in the years ahead. The company’s system in Grand Passage is the first to deliver in-stream tidal power to the grid in Canada, following provincial approval to harness Bay of Fundy tides that is spurring further development.

The system start-up is the culmination of more than a decade of research, development and testing, including lessons from Scottish tidal projects in recent years and a powerful tidal turbine feeding onshore grids, managing the technical challenges associated with operating in highly energetic environments and proving the ultra-low environmental impact of the tidal technology.

Sustainable Marine is striving to deliver the world’s first floating tidal array at FORCE (Fundy Ocean Research Centre for Energy). This project will be delivered in phases, drawing upon the knowledge gained and lessons learned in Grand Passage, and insights from offshore wind pilots like France’s first offshore wind turbine in Europe. In the coming months the company will continue to operate the platform at its demonstration site at Grand Passage, gradually building up power production, while New York and New England clean energy demand continues to rise, to further prove the technology and environmental monitoring systems, before commencing deployments in the Minas Passage – renowned as the Everest of tidal energy.

The Bay of Fundy’s huge tidal energy resource contains more than four times the combined flow of every freshwater river in the world, with the potential to generate approximately 2,500 MW of green energy, underscoring why independent electricity planning will be important for integrating marine renewables.

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