Objection Filed Against Con Edison Request for Rate Increase

The basis for Con Edison’s request for a rate increase is substantially that it wants to build lots of new infrastructure, like additional cables, substations and transformers, to deliver incremental power to support widespread electrification of vehicles and buildings as part of New York State’s goal of “net zero” greenhouse gas emissions.

Aerial view of a city skyline featuring wind turbines in the foreground with skyscrapers and a waterfront in the background.

From The Manhattan Contrarian

By Francis Menton

As I have mentioned here on a couple of occasions, I have joined with two colleagues to intervene in the regulatory proceeding where our local electric utility, Con Edison, has made its most recent request for a large rate increase. My colleagues in this enterprise are Roger Caiazza, who blogs as the Pragmatic Environmentalist of New York, and Richard Ellenbogen, a Cornell-trained engineer who as his day job runs a factory in Westchester County.

After a “deregulation” that took place in the 1990s, Con Edison almost entirely got out of the business of generating electricity, so this case is about the rates for delivery of the electricity, rather than generation. The basis for Con Edison’s request for a rate increase is substantially that it wants to build lots of new infrastructure, like additional cables, substations and transformers, to deliver incremental power to support widespread electrification of vehicles and buildings as part of New York State’s goal of “net zero” greenhouse gas emissions. That idea might make some sense if there were large amounts of zero-emissions electricity ready to be sent to New York City to be used for electrifying the buildings and vehicles. But in fact, it is the opposite: a very large majority of the electricity that Con Edison delivers is generated by natural gas — which means that electrifying buildings and vehicles doesn’t reduce GHG emissions at all and probably increases the emissions. New York State’s “climate” plans to generate lots of zero emissions electricity for New York City are almost completely dead. Its big program for off-shore wind generation in the waters off Long Island has been nixed by the federal government; and while the State continues to promote onshore wind and solar facilities in upstate New York, its plan to bring that power to New York City died, at least for now, in November 2024 when the new $11 billion Clean Path transmission line got canceled as uneconomic.

It’s actually great that these projects have died, because if they had gone forward they could have multiplied our electricity rates by at least double (before even getting started on huge costs of energy storage as penetration of intermittent renewables on the grid increased). Meanwhile, the death of the generation and transmission projects has made the whole idea of building and vehicle electrification useless, and indeed counterproductive (in terms of reducing GHG emissions, if you should happen to care about that). It doesn’t take an engineering genius to understand that burning natural gas on-site to heat a building uses less natural gas than burning it at a power plant, generating electricity, transmitting the electricity to a house, and then using the electricity at the house to make heat. But Con Edison — egged on by advocates ranging from environmental crazies to the religiously-committed New York City itself — soldiers on to try to build expensive new infrastructure to receive mythical zero-emissions electricity that does not exist and is in fact nothing but regular-old natural gas electricity.

The concept of Messrs. Caiazza, Ellenbogen and myself has been to see if we can inject some rationality into the process to prevent entirely futile and wasteful (and even counterproductive) spending in pursuit of the infeasible “net zero” goals. None of the three of us are being compensated in any way for this work. Basically, we are doing it as a hobby, to see if we can save New Yorkers from their own folly.

On Wednesday (November 26) we filed a document setting forth our position, titled “Statement of Independent Intervenors Roger Caiazza, Richard Ellenbogen, and Francis Menton In Opposition to the Joint Proposal.” To view our Statement, go to this link to the docket of the proceeding before the New York Public Service Commission, and click on Document Number 214.

Some procedural history on where we are: Con Edison started this rate proceeding back in January 2025, by requesting rate increases of about 10% each year for the years 2026, 2027 and 2028. Anybody with an interest in the matter (like a ratepayer) was allowed to intervene, and shortly there were about 100 parties, three of them being Messrs. Caiazza, Ellenbogen and myself. Other parties range from New York City, Westchester County, Amtrak, the MTA, and various advocacy and environmental groups, to state legislators and individual ratepayers.

In June the State Department of Public Service paused the proceedings to begin settlement negotiations. My colleagues and I opted to join those, but as the price of joining we were sworn to confidentiality as to the discussions. And thus I have had nothing to report for about five months. However, the settlement negotiations ended at the beginning of November when all the big players entered into what they call their “Joint Proposal.,” often abbreviated “JP.” The JP got filed on November 5, and is Item 183 on the Public Service Commission docket. The JP itself is some 300+ pages long, and I would not recommend trying to read it; however, a Summary of the Joint Proposal, 6 pages long, was filed the next day on November 6. It is item 185 on the docket.

The good news about the JP, I suppose, is that Con Edison has been induced to reduce its request for a rate increase from about 10% per year to about 3% per year. (My own inference from watching the process is that Con Edison always knew that 3% was the most it could get, and only put up the 10% number at the beginning to have something to back off from.). The bad news is that there is still lots of spending in the Proposal to support “climate” things like building and vehicle electrification, and worse, they refuse to break out which of the spending is for these “climate” purposes versus the main job of assuring safe and reliable electricity.

So with that background, here are some choice excerpts from our submission. From the introductory section:

The Independent Intervenors object to the JP because it seeks to implement large rate increases for projects not necessary for or germane to reliability and safety of the electrical system and that are instead intended to support extraneous goals that are impossible and infeasible. The bases for the objections of the Independent Intervenors include:

• The JP supports spending for purposes of building electrification and vehicle electrification, but there is not enough zero-emissions electricity generation capacity available to the downstate region to accomplish those goals reliably, and therefore any spending on Company delivery infrastructure for these purposes is wasteful. The Independent Intervenors object to spending ratepayer money supposedly for the delivery of electricity, when the electricity does not in fact exist.

• Spending by the Company to support building and vehicle electrification is actually counterproductive for Climate Leadership & Community Protection Act (CLCPA) goals because there is and will be little zero-emission generation available to the Company service territory during and after the JP period. Therefore, building and vehicle electrification will increase rather than decrease GHG emissions.

And from the concluding sections:

THE JP IS UNJUST, UNREASONABLE, AND CONTRARY TO THE PUBLIC INTEREST

There is nothing “just” or “reasonable” in:

• Imposing on the ratepayers billions of dollars of costs for purposes having nothing to do with system reliability or safety, and instead supporting goals that are infeasible (as admitted by the State itself) and impossible to achieve such that the public’s funds will be completely wasted.

• Imposing huge costs on ratepayers to build new infrastructure for the delivery of new zero-emissions electricity that in fact does not exist and will not exist in this state during the time period of this rate case and for many years thereafter.

• Hiding and concealing potentially billions of dollars of costs in a rate increase that have nothing to do with system reliability and safety and instead are going for infeasible and impossible goals.

• Providing potentially billions of dollars of ratepayer funds to support electrification projects supposedly to reduce GHG emissions, but that will instead increase GHG emissions because of the characteristics of the system that cannot be changed in any relevant time frame.

In the intervening sections between the introduction and conclusion, should you be interested, there is lots of detail about such things as failure to get zero-emission generators or transmission lines constructed, and actual emissions data from the downstate electricity system showing that you actually increase emissions by banning natural gas heat.

I do not know if the objections of myself and my colleagues will get much if any traction in this proceeding. And even if we do get some traction, this proceeding is somewhat peripheral to the central goals of New York’s “climate leadership” initiative of generating lots of zero-emissions electricity (and, supposedly, showing the world how that can be done). Still, we may get at least some of the vast collection of New York energy bureaucrats to look critically at one corner of this ridiculous situation. Maybe.

BP abandons UK green energy plant in blow to Miliband

BP has shelved plans to build a major hydrogen project in Teesside in a fresh blow to Ed Miliband’s net zero plans.

A close-up image of a gas pipe featuring a valve and pressure gauge, with a visible 'H2' marking, alongside the BP logo on a dark background.

Oil giant withdraws application for major hydrogen project in Teesside

BP has shelved plans to build a major hydrogen project in Teesside in a fresh blow to Ed Miliband’s net zero plans. The Telegraph has the story.

The oil giant withdrew its request to the Government on Monday to build the project after it clashed with separate plans backed by Sir Keir Starmer to construct the largest data centre in Europe.

It comes after Downing Street selected a former steel site in Teesside as the home for its second AI Growth Zone, with Labour banking on the technology to help turbocharge the economy.

The two proposed sites were earmarked on overlapping plots of land, pitting the Energy Secretary – who was relying on the BP project to meet his net zero ambitions – against the Prime Minister and Peter Kyle, the Business Secretary.

BP said a decision by the Labour-led Redcar and Cleveland council to throw its weight behind the data centre ultimately made its project unviable.

In a letter to the Energy Department, a spokesman for the BP-backed H2Teesside project insisted its decision had “not been taken lightly”.

It said it still believed hydrogen had “an important role to play in the future energy market”.

A spokesman for BP also blamed “material changes in circumstances” including “a planning application being granted locally for a data centre on the same piece of land” for its decision to withdraw from the project.

Sir Keir has claimed that AI will help the Government deliver a “decade of national renewal”, with plans for the new AI growth zone now expected to be announced before Christmas.

Tensions between the Energy Department and Mr Kyle over the competing projects escalated to such an extent that the Business Secretary even explored legal routes to attempt to influence Mr Miliband’s decision.

Mr Miliband had already twice delayed a decision on whether to grant the development consent order (DCO) to start producing “blue” hydrogen from natural gas, and then capture and store the carbon emissions.

A decision was due on Thursday Dec 4, but it is understood that BP has withdrawn its application for the DCO ahead of an announcement in order to make way for the data centre to be built.

Read the full story here.

Time to take down industrial wind turbines

Wind turbines are environmentally destructive, causing serious problems to people and wildlife alike.

Silhouettes of wind turbines against a vibrant sunset over the ocean.

From CFACT

By Tom Harris

Wind turbines are environmentally destructive, causing serious problems to people and wildlife alike.

And for what?

A tiny amount of expensive power that only generates energy when the wind blows in a narrow range.

With the climate scare finally dying, it is time to take down these useless machines!

AND, despite claims by activists, the real KWH cost is about 5X the cost of conventional electricity sources!

Money for nothing, indeed!

Trump Admin, States Beef It Out Over Massive Offshore Drilling Unveiling

The Department of the Interior (DOI) unveiled its proposal Thursday to open broad swaths of coastal waters to oil and gas drilling in a move that has drawn bipartisan resistance.

A brightly lit offshore oil rig at night, illuminated against a dark sky, with a full moon visible above.

Watts Up With That?

From THE DAILY CALLER

Daily Caller News Foundation

Audrey Streb
DCNF Energy Reporter

The Department of the Interior (DOI) unveiled its proposal Thursday to open broad swaths of coastal waters to oil and gas drilling in a move that has drawn bipartisan resistance.

The DOI directed Bureau of Ocean Energy Management (BOEM) Thursday to take the “necessary steps” to eliminate former President Joe Biden’s 2024-2029 oil and gas leasing scheme. The Trump approved “expansive” replacement plan seeks to develop 1.27 billion acres of viable extraction sites.

After the Biden administration imposed a broad offshore drilling ban and set a record-low leasing schedule, the Trump administration is now pushing to restart development across federal lands and waters. The new proposal seeks to explore drilling off the coasts of Alaska, California and Florida.

Democratic California Gov. Gavin Newsom has staunchly opposed the idea of drilling in Golden State waters, and even some Florida republicans have also come out against the proposal, according to E&E News.

“Offshore oil and gas production does not happen overnight. It takes years of planning, investment, and hard work before barrels reach the market,” DOI Secretary Doug Burgum said Thursday. “The Biden administration slammed the brakes on offshore oil and gas leasing and crippled the long-term pipeline of America’s offshore production. By moving forward with the development of a robust, forward-thinking leasing plan, we are ensuring that America’s offshore industry stays strong, our workers stay employed, and our nation remains energy dominant for decades to come.” 

(RELATED: EXCLUSIVE: Trump Admin Torpedoing Biden’s Oil And Gas Crackdown)

The Golden State may soon be facing a gas crisis as multiple major refineries prepare to shutter and more stringent regulations on the oil and gas industries take effect.

Florida Republicans including Sen. Rick Scott, Sen. Ashley Moody, Rep. Gus Bilirakis and Rep. Vern Buchanan told E&E News they wanted the state to remain off limits to offshore oil and gas lease expansion. Scott and Bilirakis stopped short of condemning the DOI proposal, while Buchanan and Moody remain firmly opposed to any drilling off Florida’s beaches.

“The new maps released today by @SecretaryBurgum and @Interior outlining potential new offshore oil drilling sites in the Gulf of America are HIGHLY concerning — and we will be engaging directly with the department on this issue,” Moody wrote on X on Thursday.

President Donald Trump signed a day one executive order to “unleash American energy” and declared a national energy emergency. The One Big Beautiful Bill Act (OBBBA) went further, instructing the DOI and the Bureau of Land Management (BLM) to open more domestic energy exploration opportunities and “immediately resume onshore quarterly lease sales in specified states.”

Trump has emphasized boosting conventional energy sources, which contrasts with Biden’s stifling of the oil and gas industry. Biden froze liquified natural gas (LNG) exports, blocked the major Keystone XL pipeline and halted BLM lease approvals on his first day as president, instead championing a green energy agenda to the tune of billions in subsidies, loans and grants.

Energy sector insiders like American Petroleum Institute (API) President and CEO Mike Sommers celebrated the plan, stating that “after years of delay in federal leasing, this is a historic step toward unleashing our nation’s vast offshore resources.”

All content created by the Daily Caller News Foundation, an independent and nonpartisan newswire service, is available without charge to any legitimate news publisher that can provide a large audience. All republished articles must include our logo, our reporter’s byline and their DCNF affiliation. For any questions about our guidelines or partnering with us, please contact licensing@dailycallernewsfoundation.org.

An illuminated offshore oil drilling platform at dusk, with cranes and structures visible against a colorful sky and calm water.

Green Subsidies Set to Rocket Under Miliband

The OBR have now published their full Economic & Fiscal Outlook, following the new Budget.

A distressed man screaming in front of a burning industrial site, with a caption that reads 'British Net Zero Industrial Collapse'.

From NOT A LOT OF PEOPLE KNOW THAT

By Paul Homewood

 The OBR have now published their full Economic & Fiscal Outlook, following the new Budget.

As usual, there is a table showing Environmental Levies, which are costs imposed on energy bills as a direct consequence of Government policy.

Table showing environmental levies and forecasts for the UK government from 2024 to 2030, detailing costs associated with renewable energy obligations, contracts for difference, and other related expenses in billions.
https://obr.uk/efo/economic-and-fiscal-outlook-november-2025/

One way or another, these are all effectively subsidies for renewable energy. Most are directly paid to wind farms and the like, including Renewables Obligations and Contracts for Difference. Capacity Market payments are an indirect subsidy, in the sense that intermittent generation cannot work without reliable generation on standby.

Warm Homes Discount is a rebate for poorer household on benefits, such as Pension Credit and Universal Benefit. It is worth £150 a year and is funded from everybody else’s energy bills. However, this rebate would not be necessary if energy prices were not already inflated by Net Zero policies.

I’ll do a separate post on Sizewell C shortly.

Overall, the cost of what are euphemistically called “policy costs” will increase from £11.8bn last year to £18.6 in 2031/31. (Note – OBR show a cost of £10.5bn for 2024/25. But as they point out, this does not include Capacity Market.)

This is bad enough, but the OBR do not show the full costs imposed on our energy bills by Net Zero. My table below offers a more complete view of things:

Table showing Environmental Levies costs forecasted from 2024 to 2031, detailing various subsidies for renewable energy, including Renewables Obligation, Contracts for Difference, and Warm Home Discount.

When other relevant costs are included, the bill rises to £31.8 billion in 2030/31. This is equivalent to over £1100 per household.

A few notes may be useful:

1) Feed in Tariffs are subsidies to smaller renewable generators. These were always included in Environmental Levies by the OBR, until a few years ago when they were taken out for plainly political reasons. The costs shown are the official numbers supplied by OFGEM for 2023/24.

2) Climate Change Levy, which also adds to energy bills, is shown elsewhere by the OBR.

3) The costs of the Emissions Trading Scheme, ETS, are sourced from John Constable’s review earlier this year:

https://www.ref.org.uk/ref-blog/390-uk-renewable-electricity-subsidy-totals-2002-to-the-present-day

4) System Balancing costs also come from the same John Constable analysis, itself based on official OFGEM data. As with ETS, it is assumed, optimistically, that these costs won’t rise from existing levels.

Even this does not reflect all of the costs imposed on energy bills by Net Zero. It does not attempt to measure the impact on bills of the £80 billion upgrade of the electricity transmission network, which is needed to meet Net Zero requirements.

For years, the crippling cost of Net Zero has been hidden from the public. But it is now getting so big to hide much longer.

 More Evidence NE China Is Not Cooperating with the Alarmist Global Warming Narrative

In a new study, scientists have determined that northeastern China’s droughts were far more frequent and intense during the Little Ice Age (LIA) than in the 1950-2021 era of supposedly “alarming” global warming. During the LIA, which the study clarifies as spanning from 1568 to 1850, there were 59 extreme dry events (droughts) in this region, whereas from 1850 to 2021, there were only 8.

Aerial view of terraced farmland in northeastern China, showcasing alternating layers of green crops and brown earth, illustrating agricultural practices in a hilly landscape.
Chinese Loess Plateau

From No Trick Zone

By Kenneth Richard

Northeastern China was at least 5°C (and up to 9°C) warmer than today and droughts (and floods) were far more extreme when CO2 levels were a “safe” 265 ppm.

In a new study, scientists have determined that northeastern China’s droughts were far more frequent and intense during the Little Ice Age (LIA) than in the 1950-2021 era of supposedly “alarming” global warming. During the LIA, which the study clarifies as spanning from 1568 to 1850, there were 59 extreme dry events (droughts) in this region, whereas from 1850 to 2021, there were only 8.

The authors further assert the frequency of extreme dry events have long been associated with cold periods in paleoclimate reconstructions, whereas extreme wet events (floods) are linked to warm periods.

“Our results demonstrate that Northeast Asia was relatively dry during cold periods and comparatively wet during warm periods. … For example, Northeast Asia experienced a wet MWP [Medieval Warm Period], which was the latest warm period.”

Interestingly, the relative humidity of northeast China during the last 40 years was more similar to the levels during the cold LIA than during the 1850 to 1950 period, when there were frequent extreme wet events and almost no extreme dry events.

In sum, the “mild drought from the 1950s to the present day does not exceed natural variability” when considering the context of the past 454 years.

“…long-term hydroclimate records indicate that both the frequency and intensity of recent drought episodes fall well within the range of natural variability observed during the LIA.”

A detailed scientific chart depicting summer hydroclimate variations in Northeast China from 1568 to 2021, showing trends in relative humidity and the frequency of extreme dry and wet events across different historical periods.
Image Source: Liu et al. 2025

Several other studies lend support to the conclusion that a warmer climate is a wetter climate. A paleoclimate reconstruction study utilizing the known limiting temperature for rice agriculture suggests not only that summer temperatures were 5-7°C warmer than present (>26°C vs. 20-21°C today) during the Early Holocene, but “summer rainfall was about 30% higher than modern between about 10,000 and 6,000 cal yr BP” (Dodson et al., 2021).

“The current mean July temperatures are about 20–21°C, however, these are estimated to be above 26°C between 8,500 and 4,200 cal yr BP.”

A scientific article discussing the impacts of climate variations on agriculture in China, focusing on temperature and rainfall changes over time.
Image Source: Dodson et al., 2021

A study published last year (Guo et al., 2024) indicates today’s Loess Plateau mean annual air temperature (MAAT) is 9.86°C, with a mean annual precipitation of 531 mm. From ~2,700 years ago until about 300 years ago the MAAT was 17.02°C (>7°C warmer) and yearly precipitation averaged 903 mm.

Graph depicting the quantitative reconstruction of temperature and precipitation in the Huangling region of the Chinese Loess Plateau during the Middle and Late Holocene.
Image Source: Guo et al., 2024

The modern era of “alarming” global warming is actually 5-7°C and up to 7-9°C colder in northeastern China (Zheng et al., 2018) than it was during the much warmer Early Holocene, when CO2 was a “safe” 265 ppm.

“…mean annual air temperatures [MAAT] in NE China during the early Holocene were 5-7°C higher than today.”

“MAAT records from the Chinese Loess Plateau also suggested temperature maxima 7-9°C higher than modern during the early Holocene”

Graph comparing reconstructed temperature changes based on proxies from Gushantun peat in Northeast China, showing mean annual air temperatures during the early Holocene were 5-7°C higher than today.
Image Source: Zheng et al., 2018

Northern China was also much warmer than today throughout much of the last 10,000 years. Using the known growth temperature limit for Ceratopteris as evidence, scientists have determined the mean January temperature in northern China was “7.7°C higher than today” throughout the Mid Holocene (Zhang et al., 2022).

Map showing the spatial distribution of Ceratopteris in East China during the mid-Holocene, indicating regions with warmer climate conditions and the northern boundary of the species.
Image Source: Zhang et al., 2022

In sum, there is nothing even remotely unusual about the modern temperatures or precipitation in northeastern Asia that would suggest humans are responsible for warming the climate or intensifying rainfall.

How to Cut the Electricity Price in Australia

Australia’s retail electricity price has gone through the roof and is still climbing. This is a proposal for how to bring it down again. Something like this proposal already operates in many other countries, so this is not a step into the unknown. Actually, I would claim that over the last few years the Australian system has been forced further and further into a dark hole, and this proposal is for a large step into the light. Although large, the step is simple, rational, and inexpensive.

A group of kangaroos standing in a golden field during sunset, with wind turbines in the background.

From Watts Up With That?

Mike Jonas,

Australia’s retail electricity price has gone through the roof and is still climbing. This is a proposal for how to bring it down again. Something like this proposal already operates in many other countries, so this is not a step into the unknown. Actually, I would claim that over the last few years the Australian system has been forced further and further into a dark hole, and this proposal is for a large step into the light. Although large, the step is simple, rational, and inexpensive.

The Basic Principle

The basic principle behind this proposal is:

The purpose of the electricity grid is to meet demand at minimal cost.

This is very important, and the present disastrous situation is in large part because this basic principle has been discarded. Note that there is no mention in the basic principle of any need to pander to the needs, wishes and vagaries of electricity suppliers. The suppliers’ only purpose is to meet demand profitably, and the proposed system’s only purpose is to enable that at minimal overall cost.

The Present System

The present system uses an auction mechanism to match supply to demand. Each supplier submits bids to supply certain amounts of electricity to given regions for upcoming 5-minute trading intervals. The Australian Electricity Market Operator (AEMO) runs a dispatch auction every 5 minutes and accepts bids cheapest first until they have enough to match expected demand. From this, they set a spot price for all accepted suppliers and all users. This system is known as the National Electricity Market (NEM).

As currently operated, bids can be submitted day-ahead (or earlier) but remain re-biddable up to dispatch. This fuels volatility, because effectively there is just one short-term 5-minute-based system. It has been observed that: “… regional electricity markets in Australia are characterized by relatively low levels of annual, weekly and intra-daily seasonal patterns, but are by far the most volatile markets in this study.” [1].

The Proposed System

The proposed system is based on the fact that most demand is fairly well known in advance – AEMO know roughly what tomorrow’s demand will be, they just don’t know exactly how it will pan out minute by minute. So if AEMO can cater for most of the demand in advance, then they only need to be flexible for the relatively small part of demand that varies. The proposal is: There should be a binding day-ahead auction, by region, for specified quantities of electricity for specified periods of the following day.  The specified periods would range from an hour to the full 24 hours. In other words, AEMO can work out its expected requirement by region for each part of the following day, and lock supply in for most of that. The next day’s 5-minute auctions then only need to deal with variations in demand, not the whole of demand.

Variations of this proposed Day Ahead Market (DAM) system are used by many countries [2], and significantly reduce volatility – “We also find that electricity markets organized as day-ahead markets exhibit a significantly lower overall price variation compared to markets with real-time trading.” [1]. For suppliers, a day-ahead market also increases certainty. Businesses can plan better with certainty, and this factor alone will, in time, reduce overall cost [3].

The present system already has mechanisms for handling situations like a successful supply bidder failing to deliver, expected demand failing to materialise, and organisations trying to game the system by eg. cartel operation or withholding supply. All of these mechanisms can continue. Some new provisions might be needed for the day-ahead market, such as deviation charges [4] and ‘gross’ bidding [5]. The present system also allows suppliers to have backup arrangements with each other, and these can continue too. So, for example, a solar company could put in a bid for several hours’ supply to a nominated region for the next day and protect themselves by having a backup agreement with a gas company in case there are more clouds than expected.

The point of this proposed system is that it matches the market mechanisms more closely to the patterns of demand. In other words, it aligns the market with the basic principle as stated above.  No kind of supply is favoured or penalised. Wind and solar companies, for example, whose supply is unpredictable, can still participate fully by getting backup agreements. The main difference from the present system is that suppliers become more responsible for variations in supply, allowing the market operator to concentrate more on meeting demand.

The processing logic for the day-ahead auction is far from simple, but it isn’t new – it has already been done. The USA’s PJM, for example, optimises diverse bids into a least-cost 24-hour plan [6], and typically clears about 95% of the next day’s demand. This forward-clearing approach has delivered estimated 10-20 % system-cost savings through better planning and lower volatility.

Oh, and one more thing: there are no government subsidies or mandates in the proposed system. Removal of those, in time, cuts overall cost too.

Implementation

It really should not take long to get the proposed system up and running.

AEMO already uses linear programming (LP) for security-constrained economic dispatch (SCED). Extending it to a day-ahead market should not be all that difficult. In any case, equivalent commercial software – like GE’s PROBE or Hitachi’s Network Manager EMS – is readily available and licensed to other operators. At $A20-30M, the cost pales into insignificance beside Snowy 2.0’s overruns. But it could make sense for one state or region to pilot it first before national rollout.

With the greater understanding that should come from using a day-ahead system, it should be possible to improve the long-term planning (“Capacity Market”). In future, will a nuclear plant be cheaper in total than more renewables, for example? Certainly, Australia should use much more of its own gas and coal [2].

Acknowledgement. Grok helped a lot with finding information, reviewing the article, and suggesting improvements. Please note that any errors are mine alone – I still have to check everything.

References and Notes

[1] Electricity markets around the world – Klaus Mayer & Stefan Trück (2018), Journal of Commodity Markets.

[2] Countries using a version of DAM include Canada, Norway, Finland and USA (‘PJM’ states). Their electricity prices are mostly lower than Australia’s, and less volatile. Norway and Finland do have the advantage of plentiful hydro, but Australia has the advantage of cheap domestic gas and coal. It is noteworthy that Finland and the PJM states have some nuclear power, which is competitive in a DAM. See also [3].

[3] Some countries that use a DAM have higher electricity prices than Australia, so some other things have to be in place (or absent) as well. Grok pointed out that these countries’ high prices typically stem from external factors like high taxes, heavy renewables subsidies/mandates, and gas import dependence.

[4] Imbalance settlement price – This example is from France. A price is applied to deviations from agreed supply. Note that there can be rewards as well as penalties.

[5] PJM Operating Agreement §1.10.01(b) (FERC Docket ER24-1234, filed Jan. 30, 2024: https://elibrary.ferc.gov/eLibrary/document/20240130/5073). “Each Generation Owner shall offer into the Day-Ahead Energy Market all of the output of each of its Generation Capacity Resources up to the Economic Maximum for such Generation Capacity Resource for each hour of the Operating Day, unless such Generation Capacity Resource is on a planned outage or derated for maintenance or other reasons.“. NB. I am assured that this citation and quote are correct, but I couldn’t check them because I couldn’t open the link. I could find Energy Market Must Offer Requirements for Generation Capacity Resources which does show that suppliers must bid all their available capacity. This is called ‘gross’ bidding.

[6] PJM Fact Sheet – Understanding PJM’s Markets (2024)

Why is My Energy Bill Even Higher?

Ofgem recently announced the price cap for the first quarter of 2026 and, despite gas prices falling, the overall price cap has gone up. The Budget has made some small changes to reduce energy bills, but the change to Renewables Obligations is simply moving the cost around not tackling the root cause. I am giving a talk later this week on why our energy bills are so high, so it is time to update the figures on the real causes of high energy bills.

Offshore wind turbines operating in the ocean, with a platform structure visible in the foreground against a dark sky.

The Daily Sceptic

By David Turver

Ofgem recently announced the price cap for the first quarter of 2026 and, despite gas prices falling, the overall price cap has gone up. The Budget has made some small changes to reduce energy bills, but the change to Renewables Obligations is simply moving the cost around not tackling the root cause. I am giving a talk later this week on why our energy bills are so high, so it is time to update the figures on the real causes of high energy bills.

Energy Prices in Context

The latest data from the IEA show the UK had the highest industrial electricity prices in the world in 2024 and the second highest domestic electricity prices, see Figure A.

Graph comparing international industrial and domestic electricity prices (p/kWh) from 1998 to 2024 for various countries, including the UK, France, Germany, Canada, Korea, and the USA.
Figure A – International Gas and Electricity Prices (per IEA and DESNZ)

UK gas prices are competitive with continental Europe, so contrary to popular belief, it cannot be gas driving our high electricity prices. Although we should note that gas prices in the UK and EU are much higher than key competitors like the USA and Canada (see Figure B).

Line graph depicting international industrial gas prices per kilowatt-hour from 1998 to 2024, showing price trends for countries including France, Germany, the UK, Canada, Korea, and the USA.
Figure B – International Industrial Gas Prices per IEA and DESNZ (p per kWh)

More recent data for the first half of 2025 for EU countries plus the UK show a similar story. High energy prices represent an existential threat to the economy, so it is vital that we properly understand the causes of high prices so we can formulate the right policy responses.

Role of Gas

It is true that the cost of gas sets the wholesale electricity price most of the time. However, this is not the whole story. According to DUKES (Table 5.6A), in 2024 we used 178.8 TWh of gas to produce electricity. According to TradingView, the average price of gas in 2024 was 89.67p per therm. Working through the arithmetic, this gas would have cost us about £5.5 billion. Remember that number when we start looking at the cost of renewables subsidies.

Carbon Taxes

The price of gas-fired electricity is inflated by the addition of carbon taxes in the form of the Carbon Price Support Mechanism (CPS) and the Emissions Trading Scheme (ETS) – the latter is not strictly a Carbon Tax but nevertheless is an extra cost. As shown in Figure C, Ember now produces an interesting chart breaking down the fuel costs and carbon costs of gas-fired electricity.

A line graph illustrating the impact of gas costs on electricity prices in the UK, showing electricity price, fuel cost, and carbon cost over time from January 2018 to October 2025.
Figure C – Impact of Gas and Carbon Costs on Wholesale Electricity Prices

In October 2025, it estimates fuel costs of £53.88 per MWh and carbon costs of £27.31 per MWh or 33.6% of the total. It is worth noting that carbon costs have risen 37.7% from £19.84 per MWh in January of this year. This is because the Prime Minister has signed us up to the EU Emissions Trading Scheme, where carbon costs were much higher than the UK. This has the effect of pushing up our costs of electricity.

Removing these carbon costs would immediately reduce the wholesale price of electricity and bring down bills. A welcome side-effect is that the revenue for renewables generators funded by Renewables Obligation Certificates (ROCs) would also be cut as they receive the wholesale price plus their certificates on top. Moreover, wind and solar farms operating on a merchant basis would also see a reduction in revenue, leading to an even bigger reduction in bills.

According to DESNZ statistics, the UK power sector emitted about 37.5 MtCO2e in 2024. The CPS cost £18 per tonne and the average carbon cost in the ETS was about £38 per tonne, so the total added to our bills from these costs was about £2.1 billion. Emissions are falling but ETS costs are rising, so it is difficult to say quite how this cost would move in the future. For the average electricity bill of 2,700 kWh, the annual saving would be about £70.

Renewables Subsidies Driving High Electricity Prices

We are often told that renewables are cheap and if we could only get rid of all that pesky gas then our electricity bills will fall. In fact, Ed Miliband incorrectly blamed the recent rise in the Ofgem price cap on fossil fuel markets and was on the receiving end of a community note as a result. However, the flaw in the ‘cheap renewables’ argument is that advocates only compare marginal costs of generation, not the full costs. So, while it is true that the wind and the sun are free, wind turbines, solar panels and the equipment required to connect them to the grid are not. By looking at the actual cost of subsidies, we can see the actual cost of renewables, shown in Figure D.

Bar chart showing the basic cost of electricity by technology and subsidy scheme in pounds per megawatt-hour (£/MWh). Categories include Gas, Offshore Wind, Onshore Wind, Solar, Nuclear, and Biomass, with corresponding fuel, carbon costs, and subsidies represented in different colors.
Figure D – Basic Cost of Electricity by Technology and Subsidy Scheme

Starting with gas, using the Ember data, the cost of gas-fired electricity has been about £81 per MWh in October this year made up of roughly £54 per MWh fuel costs and £27 per MWh carbon costs.

Moving now to offshore wind that is subsidised by both CfDs and Renewable Obligation Certificates (ROCs). The weighted average strike price for CfD-funded Offshore Wind from April to October 2025 has been about £155 per MWh, with £93 per MWh or 60% of revenue coming from subsidies and the balance of £62 coming from the market. The strike price has been increased by the inflation indexing at the beginning of April and the Neart na Gaoithe (NNG) wind farm recently activating its CfD at a current price of £162.82 per MWh. The basic cost of CfD-funded offshore wind is almost double gas-fired electricity. ROC-funded offshore wind is even more expensive. These windfarms receive the market price for their output (assumed to be the same as for CfD-funded generators) plus an average of 1.9 ROCs per MWh of output. Ofgem has set the buyout price for these certificates at £67.06 per MWh for 2025-26. This puts the current cost of ROC-funded offshore wind at £190 per MWh, with £127 per MWh or 67% of revenue coming from subsidies.

A similar story can be seen for onshore wind with the basic cost being more expensive than gas. Several new solar farms have come on stream recently so the basic cost of CfD-funded solar is lower than gas including carbon costs, but more expensive than the raw cost of gas-fired electricity. However, ROC and Feed-in-Tariff funded solar is much more expensive.

New offshore wind was awarded contracts at £85 per MWh at 2025 prices in AR6, but the main project, Hornsea 4 has been cancelled as uneconomic. There were many projects awarded contracts at cheap prices in AR4, about £49 per MWh at 2025 prices. On the face of it, this basic cost is lower than even the raw price of gas-fired electricity, but these projects have either been cancelled or partially rebid at higher prices.

New offshore contracts are on offer in AR7 at £117 per MWh, index-linked for 20 years, again the basic cost is much more expensive than the fully-loaded cost of gas-fired electricity. The prices on offer have also risen for onshore wind and solar compared to AR6 contract awards.

Renewables Subsidies

Let us have a look at the total cost of all these subsidies. Renewables are subsidised by three subsidy schemes: Renewable Obligations Certificates (ROCs), Contracts for Difference (CfDs) and Feed-in-Tariffs (FiTs).

ROC-funded generators are awarded certificates for each unit of electricity generated in addition to the market price they receive for their output. Accordingly, electricity from these generators will always be more expensive than market rates, often set by gas. Even though this scheme is closed to new participants, the OBR (March 2025 detailed forecast tables: receipts) shows us the RO scheme cost £7.8 billion in 2024-25 and the cost is forecast to rise to £8.5 billion in 2026-27.

Feed-in-Tariffs (FiT) are paid mostly to small solar installations. FiT generators are paid a fixed amount to generate electricity plus a smaller amount for the power they export (or are deemed to export) to the grid. Again, this scheme is closed to new entrants, however analysis of Ofgem’s latest report into the FiT scheme shows it cost nearly £1.9 billion in 2023-24, or around £221 per MWh which is nearly three times higher than market rates today (October 13th 2025) of about £82 per MWh. We might expect the cost of the FiT scheme to continue to rise in line with inflation.

Finally we have the Contract for Difference (CfD) scheme used for the now annual renewables auctions. Here, generators receive a fixed amount for the power they generate. They receive the market value for their power and are then paid a top-up to the strike price of their contract. If market prices are above the strike price, they must pay back the difference. Analysis of data published by the Low Carbon Contract Company shows the CfD scheme cost a record £2.4 billion in subsidies during calendar year 2024. The cost of this scheme is likely to rise, considering the high prices being offered on new 20-year index-linked contracts in the current Allocation Round 7 (AR7) auction of new capacity.

All prices are much higher than the current price of gas-fired electricity unencumbered by carbon costs.

The total cost of these subsidy schemes amounts to over £12 billion per year or more than twice the amount spent on gas for electricity, see Figure E.

Table showing the annual costs of renewable energy subsidy schemes in the UK, detailing expenditures for Renewables Obligation Certificates (ROCs), Contracts for Difference (CfDs), and Feed-in Tariffs (FiTs), with a total cost of £12.1 billion.
Figure E – Annual Cost of Renewables Subsidies (£bn)

In the latest Ofgem price cap, ROCs add over £89 to our electricity bills, CfDs £33 and FiTs over £19, for a total of over £141 for a typical household using 2,700kWh of electricity per year. This amounts to about 16% of the ex-VAT total electricity bill of £902.

Extra Costs of Renewables

However, subsidies do not represent the full cost of renewables. First, because wind and solar are intermittent their output can fluctuate significantly so that sometimes they produce less than expected. At other times can produce more than demand or more than the grid can handle and we pay wind farms to curtail their output. The grid needs to be always balanced so we also pay gas generators to fire up to compensate. NESO produce Monthly Balancing Services Summary reports and the data for 2024-25 shows the cost of this service was £2.7 billion. In addition, we pay for backup through the capacity market and the OBR shows this cost us £1.3bn in 2024-25. Grid balancing adds about £48 to the typical electricity bill and the Capacity Market adds about £24.

If we attribute these costs to intermittent renewables (allowing an inflation adjusted £750m for the cost of balancing before renewables) we can see the full cost of renewables, see Figure F.

Bar chart depicting the total cost of electricity by technology and subsidy scheme in £/MWh, showing comparisons for gas, offshore wind, onshore wind, solar, nuclear, and biomass, along with components such as fuel costs, carbon costs, and subsidies.
Figure F – Full Cost of Electricity by Technology and Subsidy Scheme

The cost of grid balancing adds about £20 to the cost of intermittent renewables and backup from the capacity market about £13, together adding £33 per MWh. The full cost of active CfDs for offshore wind rises to £188 per MWh, onshore wind £150 per MWh and solar £103 per MWh, all much more expensive than gas, even with a carbon tax added. The full cost of new capacity in AR6 and AR7 is also much higher than gas power.

These extra costs are only going to get worse. NESO forecasts balancing costs to rise to £6.4-£8.3 billion by 2030 and OBR forecasts Capacity Market costs to rise to £4.4 billion per year in 2030-31. We can therefore expect these extra costs of renewables to rise to £10-12 billion by 2030, again roughly twice the current cost of gas used for electricity.

In addition, because renewables are geographically dispersed, they need extra spending on transmission lines to connect them to the grid. Ofgem has recently approved an initial £8.9 billion of spending on the high-voltage electricity network. They claim this is the first step of an £80 billion programme to boost the electricity network capacity. They estimate this will add a further £74 to electricity bills.

Other Policy Costs

All these costs of renewables make electricity extremely expensive, particularly for the poorest households, so the Government has introduced schemes like the Warm Homes Discount (WHD) and the Energy Company Obligation (ECO) to try to help. WHD provides a £150 discount for the poorest households and ECO obliges energy companies to install insulation measures to some homes. The cost of these schemes is paid for by everyone else and together these add about £47 to electricity bills.

If electricity prices were lower, these schemes would be largely unnecessary and the cost of supporting the poorest would fall dramatically.

Latest Price Cap January to March 2026

Gas prices have fallen from £31.37 per MWh last time to £28.33 per MWh in the latest price cap. As expected, this has led to a reduction in gas bills, although the £38 reduction in fuel costs is partly offset by a £3 increase in policy costs driven by an expansion in the WHD. After some other minor charges, the net change in gas bills is a £35 reduction (ex-VAT)

However, despite the reduction in gas prices, the fuel costs of electricity have gone up because of the increase in carbon costs. Overall electricity bills are up £38 (ex-VAT) since last time driven by the expansion of WHD, carbon costs and core operating costs of suppliers. We should also mention the cost of Sizewell C through the Nuclear Regulated Asset Base (nRAB) scheme has been added to policy costs, adding £13 (ex-VAT) to the typical electricity bill.

Despite gas prices falling, combined gas and electricity bills are £65 higher (ex-VAT) than the April-June 2024 period just before Labour came to power, promising to cut our bills by £300.

How to Reduce Bills

The high cost of energy means we face a version of the Trolley Problem. This is where you face a dilemma of whether to divert a runaway trolley bus to kill one person instead of five. In our version of the problem we must sacrifice either society or the Green Blob, see Figure G.

Figure G – Net Zero Trolley Problem

If we continue down the current Net Zero path, our economy and wider society faces an existential threat from high energy prices. We must face the unpalatable truth that moving onto the path to prosperity will require measures that will be painful for some, most notably what can be loosely termed the Green Blob.

The Reform Party has committed to end Net Zero and the Tories have recently pledged to repeal the Climate Change Act, disband the Climate Change Committee, eliminate carbon costs and end ROCs early. These new Tory policies reflect some of the ideas discussed in earlier articles. Reform has committed to striking down any contracts agreed in the current Allocation Round 7 (AR7) auction of new renewables capacity.

In the Budget, Labour has abolished the Energy Company Obligation, cutting about £60 from energy bills. It will also temporarily move about 75% of the cost of the Renewables Obligation from bills and into general taxation

If the Government has an epiphany about energy costs, it could also consider cutting VAT on energy bills, delivering an immediate cut of 5%. Other measures could be considered including cutting curtailment charges and ending the spending on grid expansion.

Taken together, these measures would reduce energy bills, meaning the WHD could also be cut, reducing bills further.

On the supply side, the Energy Profits Levy on oil and gas producers should be cut and the ban on offshore and onshore drilling should also be lifted. Increasing supply ought to reduce prices and of course we might also earn export revenues. In the medium term we need to build more gas-fired generators and massively expand out nuclear fleet after streamlining nuclear regulations.

Conclusions

We face an existential crisis from high energy prices. The Net Zero project should be abandoned and be replaced by a project with the sole aim of delivering cheap and abundant energy. There are many measures that could be taken in the short term to cut bills. Fixing the supply side will take longer and work on that should start now.

It is encouraging that opposition parties have started to challenge the Net Zero orthodoxy. The Green Blob should be left in no doubt that the trolley bus has been diverted and it is coming for it. Time to get out of the way.

David Turver writes the Eigen Values Substack page, where this article first appeared.

Two Hot Spots Slow Arctic Ice Recovery November 2025

The polar vortex is pronounced this year, resulting in warmer temperature over the Arctic ocean, and slowing the normal sea ice recovery.  Dr. Judah Cohen at AER Arctic Oscillation blog provides information like the chart above.

A research vessel navigating through a vast expanse of Arctic sea ice under clear blue skies.

From Science Matters

By Ron Clutz

Two weather forecast maps showing GPH and temperature anomalies for the Northern Hemisphere. The left map illustrates the 1-5 day forecast, while the right shows the 11-15 day forecast.
Figure 12. (a) Predicted 10 mb geopotential heights (dam; contours) and temperature anomalies (°C; shading) across the Northern Hemisphere averaged for 25 Nov to 29 Nov 2025. (b) Same as (a) except forecasted averaged from 05 Dec to 09 Dec 2025. The forecasts are from the 00Z 24 November 2025 GFS model ensemble.

The polar vortex is pronounced this year, resulting in warmer temperature over the Arctic ocean, and slowing the normal sea ice recovery.  Dr. Judah Cohen at AER Arctic Oscillation blog provides information like the chart above.

After a pattern of solidly growing sea ice extent in October, a slowdown occurred in November, coincidental with the warm spots shown above.  The graph below shows 2025 compared to the 19 year average (2006 to 2024 inclusive), to SII (Sea Ice Index) and some notable years.

Line graph displaying November Arctic ice extents in million square kilometers, comparing 2025, 2024, 2020, 2007, and 19-year averages.

According to MASIE. the average November adds ~2.5M km2 of sea ice extent, which is matched also by 2007.  2024 started below average, but gained steadily to close the gap.  2025 started at the same level, but the refreezing slowed down, ending November in deficit by 1.1M km2.  SII shows even lower ice extents (the last two days not yet reported.)

A cartoon depicting a polar bear next to an out-of-order ice maker, expressing concern about ice levels while a person in winter attire holds a sign stating 'The Earth has a fever.'

The table below shows the distribution of ice in the Arctic Ocean basins, suggesting two places where ice recovery is lagging.

Region2025334Day 334 Ave.2025-Ave.20073342025-2007
 (0) Northern_Hemisphere978403710880420-109638311009948-1225911
 (1) Beaufort_Sea107107010696231447105887212198
 (2) Chukchi_Sea87908279120787875687829191253
 (3) East_Siberian_Sea10871371083943319410820155122
 (4) Laptev_Sea89784589782421897613232
 (5) Kara_Sea565299792107-226808826319-261020
 (6) Barents_Sea28050242740-214690216525-188474
 (7) Greenland_Sea55041353968710726618844-68431
 (8) Baffin_Bay_Gulf_of_St._Lawrence412284664437-252153708497-296212
 (9) Canadian_Archipelago85493185343115008502494682
 (10) Hudson_Bay188797543322-354525751382-562585
 (11) Central_Arctic30376373193296-1556593183072.72-145436
 (12) Bering_Sea145331138776655572644.6272687
 (13) Baltic_Sea42264452-22504226
 (14) Sea_of_Okhotsk5828861277-2989530525236

Overall ice extent was 1.1M km2 below average or 10%.  About half the deficit comes from the European Atlantic basins, Kara and Barents seas.  The other half is mostly from N. America’s Hudson and Baffin bays. Ice in these regions operate on the LIFO principle, last in and first out.

Map of the Arctic region showing various seas and countries including the United States, Canada, Greenland, and Russia.

At this point in the year, Arctic ice has grown back to 65% of last March maximum with 2.5 months to catch up.   AER  suggests that things may shift again in December:

Map showing temperature anomalies from November 24 to December 9, 2025, with warmer temperatures indicated in red and cooler temperatures in blue across North America and parts of Europe and Asia.
Figure 9. Forecasted surface temperature anomalies (°C; shading) from 05 Dec to 09 Dec 2025. The forecasts are from the 00Z 24 Nov 2025 GFS ensemble.
Map showing the GEFS 11-15 Day Forecast of Snow Water Equivalent (SNOD) change from November 24 to December 9, 2025, with regions highlighted in blue indicating snowfall increase and red indicating decrease.
Figure 10. Forecasted snowfall (mm/day; shading) from 05 Dec to 09 Dec 2025. The forecasts are from the 00Z 24 Nov 2025 GFS ensemble.

Illustration by Eleanor Lutz shows Earth’s seasonal climate changes. If played in full screen, the four corners present views from top, bottom and sides. It is a visual representation of scientific datasets measuring ice and snow extents.