Lobbyist spending in Kansas doubles amid coal fight

By Kansas City Star


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Spending by lobbyists doubled in Kansas in the last year due to the dispute over a proposal for two coal-fired power plants.

A report from the state ethics commission said that lobbyist spending totaled more than $1,276,357 from January through August. During the same period in 2007, lobbyist expenditures were $570,038.

The added money was largely spent on efforts to get Kansas residents to pressure lawmakers over Sunflower Electric Power Corp.'s plan to build coal-fired plants in Finney County, the Lawrence Journal-World reported.

The biggest difference was in the areas of communications and mass media, such as television, radio and newspaper ads. Advertising increased more than 11-fold, from $49,577 to $553,356, and communications such as newsletters and mailings increased nearly ninefold, from $31,062 to $260,061. The bulk of those ads and mailings came from groups fighting over the coal project.

Last year, Department of Health and Environment Secretary Rod Bremby denied an air-quality permit for Sunflower's project, citing concerns about global warming, which many scientists link to man-made greenhouse gases.

The Legislature passed three bills allowing the plants, but Gov. Kathleen Sebelius vetoed each one. Supporters of the plants were unable to get the two-thirds majorities to overturn the vetoes.

Both sides expect to continue their efforts — and spending — when the Legislature convenes in January.

According to the ethics commission report, Hays-based Sunflower has spent $176,370 on mass media urging the public to support the project. The company also spent several thousand dollars more on meals for lawmakers.

"It's a matter of trying to get our story out," said Sunflower spokesman Steve Miller.

Sunflower was helped along by several groups backed by coal interests, such as the Alliance for Sound Energy Policy, which spent $106,403 on ads through August; Center for Energy and Economic Development, $44,298; the American Coalition for Clean Coal Electricity, $44,297; and Kansans for Affordable Energy, $11,845. It also received help from some businesses.

On the other side of the issue, Great Plains Alliance for Clean Energy was the group that spent the most, with $128,812 going toward communications and advertising.

"We came into existence because a lot of Kansans felt the need to tell the more broad story," said Scott Allegrucci, the group's executive director.

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Snohomish PUD Hikes Rates Due to Severe Weather Impact

Snohomish PUD rate increase addresses storm recovery after a bomb cyclone and extended cold snap, stabilizing finances and grid reliability while offering assistance programs, payment plans, and energy efficiency for customers.

 

Key Points

Temp 5.8% residential hike in Feb 2025 to recover storm costs, meet cold snap demand, and uphold reliable service.

✅ 5.8% residential increase effective Feb 2025

✅ Driven by bomb cyclone damage and cold snap demand

✅ Aid includes payment plans, efficiency rebates, low income support

 

In early February 2025, the Snohomish County Public Utility District (PUD) announced a temporary increase in electricity rates to offset the financial impact of severe weather events, including a bomb cyclone and an extended cold snap, that occurred in late 2024. This decision aims to stabilize the utility's finances, a pattern seen at other utilities such as Florida Power & Light, which pursued a hurricane surcharge to recover storm costs, while ensuring continued service reliability for its customers.

Background of the Weather Events

In November 2024, the Pacific Northwest experienced a powerful bomb cyclone—a rapidly intensifying storm characterized by a significant drop in atmospheric pressure. This event brought heavy rainfall, strong winds, and widespread power outages across the region. Compounding the situation, a prolonged cold weather period in December 2024 and January 2025 led to increased energy demand, and similar conditions drove up Pennsylvania power rates in the same winter season, as residents and businesses relied heavily on heating systems.

Impact on Snohomish PUD

The combination of the bomb cyclone and the subsequent cold weather placed considerable strain on the Snohomish PUD's infrastructure and financial resources. The utility incurred substantial costs for emergency repairs, restoration efforts, and the procurement of additional electricity to meet the heightened demand during the cold snap. These unforeseen expenses prompted the PUD to seek a temporary rate adjustment to maintain financial stability and continue providing reliable service to its customers.

Details of the Rate Increase

Effective February 2025, the Snohomish PUD implemented a temporary electricity rate increase of 5.8% for residential customers, compared with a 3% BC Hydro increase in the same region for context. This adjustment is designed to recover the additional costs incurred during the severe weather events. The PUD has communicated that this rate increase is temporary and will be reevaluated after a specified period to determine if further adjustments are necessary.

Customer Impact and Assistance Programs

While the rate increase is intended to be temporary, it may still pose a financial burden for some customers, even as some markets expect rates to stabilize in 2025 in other jurisdictions. To mitigate this impact, the Snohomish PUD has outlined several assistance programs:

  • Payment Plans: Customers facing financial hardship can enroll in extended payment plans to spread the cost of the increased rates over a longer period.

  • Energy Efficiency Programs: The PUD offers incentives and resources to help customers reduce energy consumption, potentially lowering their overall bills.

  • Low-Income Assistance: Eligible low-income customers may qualify for additional support through state and federal assistance programs.

The utility encourages customers to contact their customer service department to explore these options and find the best solutions for their individual circumstances.

Community Response and Future Considerations

The announcement of the rate increase has elicited mixed reactions from the community. Some residents express understanding, recognizing the necessity of maintaining infrastructure and service reliability. Others have voiced concerns about the financial impact, particularly among vulnerable populations, a debate also seen with higher BC Hydro rates in nearby British Columbia.

Looking ahead, the Snohomish PUD is committed to enhancing its infrastructure to better withstand future extreme weather events, an approach aligned with other utilities' multi-year rate proposals to fund upgrades. This includes investing in grid modernization, implementing advanced weather forecasting tools, and developing comprehensive emergency response plans. The utility also plans to engage with the community through public forums and surveys to gather feedback and collaboratively develop strategies that balance financial sustainability with customer affordability.

The temporary electricity rate increase by the Snohomish County Public Utility District reflects the financial challenges posed by severe weather events and parallels regional trends, including BC Hydro's 3.75% over two years adjustments, and underscores the importance of proactive infrastructure investment and community engagement. While the rate adjustment aims to stabilize the utility's finances, the PUD remains focused on supporting its customers through assistance programs and ongoing efforts to enhance service reliability and resilience against future climate-related events.

 

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Iran turning thermal power plants to combined cycle to save energy

Iran Combined-Cycle Power Plants drive energy efficiency, cut greenhouse gases, and expand megawatt capacity by converting thermal units; MAPNA-led upgrades boost grid reliability, reduce fuel use, and accelerate electricity generation growth nationwide.

 

Key Points

Upgraded thermal plants that reuse waste heat to boost efficiency, cut emissions, and add capacity to Iran's grid.

✅ 27 thermal plants converted; 160 more viable units identified

✅ Adds 12,600 MW capacity via heat recovery steam generators

✅ Combined-cycle share: 31.2% of 80.509 GW capacity

 

Iran has turned six percent of its thermal power plans into combined cycle plants in order to reduce greenhouse gases and save energy, with potential to lift thermal plants' PLF under rising demand, IRNA reported, quoting an energy official.

According to the MAPNA Group’s Managing Director Abbas Aliabadi, so far 27 thermal power plants have been converted to combined-cycle ones, aligning with Iran’s push to transmit power to Europe as a regional hub.

“The conversion of a thermal power plant to a combined cycle one takes about one to two years, however, it is possible for us to convert all the country’s thermal power plants into combined cycle plants over a five-year period.

Currently, a total of 478 thermal power plants are operating throughout Iran, of which 160 units could be turned into combined cycle plants. In doing so, 12,600 megawatts will be added to the country’s power capacity, supporting ongoing exports such as supplying a large share of Iraq's electricity under existing arrangements.

Related cross-border work includes deals to rehabilitate Iraq's power grid that support future exchanges.

As reported by IRNA on Wednesday, Iran’s Nominal electricity generation capacity has reached 80,509 megawatts (80.509 gigawatts), and it is deepening energy cooperation with Iraq to bolster regional reliability. The country increased its electricity generation capacity by 500 megawatts (MW) compared to the last year (ended on March 20).

Currently, with a total generation capacity of 25,083 MW (31.2 percent) combined cycle power plants account for the biggest share in the country’s total power generation capacity followed by gas power plants generating 29.9 percent, amid global trends where renewables are set to eclipse coal and regional moves such as Israel's coal reduction signal accelerating shifts. EF/MA

 

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Electric Motor Testing Training

Electric Motor Testing Training covers on-line and off-line diagnostics, predictive maintenance, condition monitoring, failure analysis, and reliability practices to reduce downtime, optimize energy efficiency, and extend motor life in industrial facilities.

 

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An instructor-led course teaching on-line/off-line tests to diagnose failures, improve reliability, and cut downtime.

✅ On-line and off-line test methods and tools

✅ Failure modes, root cause analysis, and KPIs

✅ Predictive maintenance, condition monitoring, ROI

 

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Report call for major changes to operation of Nova Scotia's power grid

Nova Scotia Energy Modernization Act proposes an independent system operator, focused energy regulation, coal phase-out by 2030, renewable integration, transmission upgrades, and competitive market access to boost consumer trust and grid reliability across the province.

 

Key Points

Legislation to create an independent system operator and energy regulator, enabling coal phase-out and renewable integration.

✅ Transfers grid control from Nova Scotia Power to an ISO

✅ Establishes a focused energy regulator for multi-sector oversight

✅ Accelerates coal retirement, renewables build-out, and grid upgrades

 

Nova Scotia is poised for a significant overhaul in how its electricity grid operates, with the electricity market headed for a reshuffle as the province vows changes, following a government announcement that will strip the current electric utility of its grid access control. This move is part of a broader initiative to help the province achieve its ambitious energy objectives, including the cessation of coal usage by 2030.

The announcement came from Tory Rushton, the Minister of Natural Resources, who highlighted the recommendations from the Clean Electricity Task Force's report to make the electricity system more accountable to Nova Scotians according to the authors. The report suggests the creation of two distinct entities: an autonomous system operator for energy system planning and an independent body for energy regulation.

Minister Rushton expressed the government's agreement with these recommendations, while the premier had earlier urged regulators to reject a 14% rate hike to protect customers, stating plans to introduce a new Energy Modernization Act in the next legislative session.

Under the proposed changes, Nova Scotia Power, a privately-owned entity, will retain its operational role but will relinquish control over the electricity grid. This responsibility will shift to an independent system operator, aiming to foster competitive practices essential for phasing out coal—currently a major source of the province’s electricity.

Additionally, the existing Utility and Review Board, which recently approved a 14% rate increase despite political opposition, will undergo rebranding to become the Nova Scotia Regulatory and Appeals Board, reflecting a broader mandate beyond energy. Its electricity-related duties will be transferred to the newly proposed Nova Scotia Energy Board, which will oversee various energy sectors including electricity, natural gas, and retail gasoline.

The task force, led by Alison Scott, a former deputy energy minister, and John MacIsaac, an ex-executive of Nalcor Energy, was established by the province in April 2023 to determine the needs of the electrical system in meeting Nova Scotia's environmental goals.

Minister Rushton praised the report for providing a clear direction towards achieving the province's 2030 environmental targets and beyond. He estimated that establishing the recommended bodies would take 18 months to two years, and noted the government cannot order the utility to cut rates under current law, promising job security for current employees of Nova Scotia Power and the Utility and Review Board throughout the transition.

The report advocates for the new system operator to improve consumer trust by distancing electricity system decisions from Nova Scotia Power's corporate interests. It also critiques the current breadth of the Utility and Review Board's mandate as overly extensive for addressing the energy transition's long-term requirements.

Nova Scotia Power's president, Peter Gregg, welcomed the recommendations, emphasizing their role in the province's shift towards renewable energy, as neighboring jurisdictions like P.E.I. explore community generation to build resilience, he highlighted the importance of a focused energy regulator and a dedicated system operator in advancing essential projects for reliable customer service.

The task force's 12 recommendations also include the requirement for Nova Scotia Power to submit an annual asset management plan for regulatory approval and to produce reports on vegetation and wood pole management. It suggests the government assess Ontario's hydro policies for potential adaptation in Nova Scotia and calls for upgrades to the transmission grid infrastructure, with projected costs detailed by Stantec.

Alison Scott remarked on the comparative expense of coal power against renewable sources like wind, suggesting that investments in the grid to support renewables would be economically beneficial in the long run.

 

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Renewables Surpass Coal in India's Energy Capacity Shift

India Renewable Energy Surge 2024 signals coal's decline as solar and wind capacity soar, aided by policy incentives, grid upgrades, energy storage, and falling costs, accelerating decarbonization and clean power growth.

 

Key Points

Q1 2024 saw renewables outpace coal in new capacity, led by cheaper solar, wind, policy support, and storage.

✅ 71.5% of new Q1 capacity came from renewables

✅ Solar and wind expand on falling costs and faster permitting

✅ Grid integration needs storage, skills, and just transition

 

In a landmark shift for the world's second-most populous nation, coal has finally been dethroned as the king of India's energy supply. The first quarter of 2024 saw a historic surge in renewable energy capacity, particularly on-grid solar development across states, pushing its share of power generation past 71.5%. This remarkable feat marks a turning point in India's journey towards a cleaner and more sustainable energy future.

For decades, coal has been the backbone of India's power sector, fueling rapid economic growth but also leading to concerning levels of air pollution. However, a confluence of factors has driven this dramatic shift, even as coal generation surges create short-term fluctuations in the mix. Firstly, the cost of solar and wind power has plummeted in recent years, making them increasingly competitive with coal. Secondly, the Indian government has set ambitious renewable energy targets, aiming for 50% of cumulative power generation capacity from non-fossil fuel sources by 2030. Thirdly, growing public awareness about the environmental impact of coal has spurred a demand for cleaner alternatives.

This surge in renewables is not just about replacing coal. The first quarter of 2024 witnessed a record-breaking addition of 13,669 megawatts (MW) of power generation capacity, with renewables accounting for a staggering 71.5% of that figure, aligning with 30% global renewable electricity milestones seen worldwide. This rapid expansion is driven by factors like falling equipment costs, streamlined permitting processes, and attractive government incentives. Solar and wind energy are leading the charge, and in other major markets renewables are projected to reach one-fourth of U.S. generation in the near term, with large-scale solar farms and wind turbine installations dotting the Indian landscape.

The transition away from coal presents both opportunities and challenges. On the positive side, cleaner air will lead to significant health benefits for millions of Indians. Additionally, India can establish itself as a global leader in the renewable energy sector, attracting investments and creating new jobs, echoing how China's solar PV expansion reshaped markets in the previous decade. However, challenges remain. Integrating such a large amount of variable renewable energy sources like solar and wind into the grid requires robust energy storage solutions. Furthermore, millions of jobs in the coal sector need to be transitioned to new opportunities in the green economy.

Despite these challenges, India's move towards renewables is a significant development with global implications, as U.S. renewable electricity surpassed coal in 2022, underscoring broader momentum. It demonstrates the growing viability of clean energy solutions and paves the way for other developing nations to follow suit. India's success story can inspire a global shift towards a more sustainable energy future, one powered by the sun, wind, and other renewable resources.

Looking ahead, continued government support, technological advancements, and innovative financing mechanisms will be crucial for sustaining India's renewable energy momentum. The future of India's energy sector is undoubtedly bright, fueled by the clean and abundant power of the sun and the wind, as wind and solar surpassed coal in the U.S. in recent comparisons. The world will be watching closely to see if India can successfully navigate this energy transition, setting an example for other nations struggling to balance development with environmental responsibility.

 

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Hitachi freezes British nuclear project, books $2.8bn hit

Hitachi UK Nuclear Project Freeze reflects Horizon Nuclear Power's suspended Anglesey plant amid Brexit uncertainty, investor funding gaps, rising safety regulation costs, and a 300 billion yen write-down, impacting Britain's low-carbon electricity plans.

 

Key Points

Hitachi halted Horizon's Anglesey nuclear plant over funding and Brexit risks, recording a 300 billion yen write-down.

✅ 3 trillion yen UK nuclear project funding stalled

✅ 300 billion yen impairment wipes Horizon asset value

✅ Brexit, safety rules raised costs and investor risk

 

Japan’s Hitachi Ltd said on Thursday it has decided to freeze a 3 trillion yen ($28 billion) British nuclear power project and will consequently book a write down of 300 billion yen.

The suspension comes as Hitachi’s Horizon Nuclear Power failed to find private investors for its plans to build a plant in Anglesey, Wales, where local economic concerns have been raised, which promised to provide about 6 percent of Britain’s electricity.

“We’ve made the decision to freeze the project from the economic standpoint as a private company,” Hitachi said in a statement.

Hitachi had called on the British government to boost financial support for the project to appease investor anxiety, but turmoil over the country’s impending exit from the European Union limited the government’s capacity to compile plans, people close to the matter previously said.

Hitachi had called on the British government to boost financial support for the project to appease investor anxiety, but turmoil over the country’s impending exit from the European Union and setbacks at Hinkley Point C limited the government’s capacity to compile plans, people close to the matter previously said.

Hitachi had banked on a group of Japanese investors and the British government each taking a one-third stake in the equity portion of the project, the people said. The project would be financed one-third by equity and rest by debt.

The nuclear writedown wipes off the Horizon unit’s asset value, which stood at 296 billion yen as of September-end.

Hitachi stopped short of scrapping the northern Wales project. The company will continue to discuss with the British government on nuclear power, it said.

However, industry sources said hurdles to proceed with the project are high considering tighter safety regulations since a meltdown at Japan’s Fukushima nuclear power plant in 2011 drove up costs, even as Europe’s nuclear decline strains energy planning.

Analysts and investors viewed the suspension as an effective withdrawal and saw the decision as a positive step that has removed uncertainties for the Japanese conglomerate.

Hitachi bought Horizon in 2012 for 696 million pounds ($1.12 billion), fromE.ON and RWE as the German utilities decided to sell their joint venture following Germany’s nuclear exit after the Fukushima accident.

Hitachi’s latest decision further dims Japan’s export prospects, even as some peers pursue UK offshore wind investments to diversify.

Toshiba Corp last year scrapped its British NuGen project after its US reactor unit Westinghouse went bankrupt, while Westinghouse in China reported no major impact, and it failed to sell NuGen to South Korea’s KEPCO.

Mitsubishi Heavy Industries Ltd has effectively abandoned its Sinop nuclear project in Turkey, a person involved in the project previously told Reuters, as cost estimates had nearly doubled to around 5 trillion yen.

 

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