Elster to take lead on KCBPU smart grid

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The Kansas City Board of Public Utilities KCBPU has selected Elster for their smart grid deployment, choosing the EnergyAxis Smart Grid solution to streamline business and operational processes and provide cost-effective services to its customer base.

"Our customers and their unique needs were our primary consideration in awarding Elster this contract — we needed a Smart Grid technology partner that understood these needs and could meet our unique geographic and technology requirements for both electricity and water," said Don Gray, general manager, KCBPU.

"Elster has demonstrated global success in challenging conditions with multi-utilities in electricity and water, making us very confident that their EnergyAxis system will enable our customers to realize the benefits of the Smart Grid," Gray added.

Google recently announced its selection of Kansas City, Kansas, as the location for its ultra-high-speed fiber project. This network is expected to be 100 times faster than most broadband connection speeds.

With Elster's proven technologies, which include advanced metering infrastructure AMI, KCBPU will install Ethernet-connected Rex3 Smart Meters and replace outdated control systems and infrastructure. This will enable the utility to roll out valuable new services such as outage management, time-of-use TOU rates, remote connect and disconnect service, flexible billing and leak detection capabilities to its customers.

As part of its Smart Grid plan, KCBPU plans to deploy more than 69,000 of Elster's smart electric meters and 55,000 Elster smart water meters over the next few years.

"KCBPU is dedicated to providing the highest quality of electric and water services at the lowest possible cost to its customers, and, through this partnership with Elster, they will be able to achieve this mission with even greater success," said David Green, executive vice president, customers and markets, North America, Elster.

"By investing in the Elster EnergyAxis Smart Grid solution and replacing its aging water and electric infrastructure, KCBPU is also enhancing its abilities to support the changing needs of its customers," Green added.

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N.S. approves new attempt to harness Bay of Fundy's powerful tides

Bay of Fundy Tidal Energy advances as Nova Scotia permits Jupiter Hydro to test floating barge platforms with helical turbines in Minas Passage, supporting renewable power, grid-ready pilots, and green jobs in rural communities.

 

Key Points

A Nova Scotia tidal energy project using helical turbines to generate clean power and create local jobs.

✅ Permits enable 1-2 MW prototypes near Minas Passage

✅ Floating barge platforms with patented helical turbines

✅ PPA at $0.50/kWh with Nova Scotia Power

 

An Alberta-based company has been granted permission to try to harness electricity from the powerful tides of the Bay of Fundy.

Nova Scotia has issued two renewable energy permits to Jupiter Hydro.

Backers have long touted the massive energy potential of Fundy's tides -- they are among the world's most powerful -- but large-scale commercial efforts to harness them have borne little fruit so far, even as a Scottish tidal project recently generated enough power to supply nearly 4,000 homes elsewhere.

The Jupiter application says it will use three "floating barge type platforms" carrying its patented technology. The company says it uses helical turbines mounted as if they were outboard motors.

"Having another company test their technology in the Bay of Fundy shows that this early-stage industry continues to grow and create green jobs in our rural communities," Energy and Mines Minister Derek Mombourquette said in a statement.

The first permit allows the company to test a one-megawatt prototype that is not connected to the electricity grid.

The second -- a five-year permit for up to two megawatts -- is renewable if the company meets performance standards, environmental requirements and community engagement conditions.

Mombourquette also authorized a power purchase agreement that allows the company to sell the electricity it generates to the Nova Scotia grid through Nova Scotia Power for 50 cents per kilowatt hour.

On its web site, Jupiter says it believes its approach "will prove to be the most cost effective marine energy conversion technology in the world," even as other regional utilities consider initiatives like NB Power's Belledune concept for turning seawater into electricity.

The one megawatt unit would have screws which are about 5.5 metres in diameter.

The project is required to obtain all other necessary approvals, permits and authorizations.

It will be located near the Fundy Ocean Research Center for Energy in the Minas Passage and will use existing electricity grid connections.

A study commissioned by the Offshore Energy Research Association of Nova Scotia says by 2040, the tidal energy industry could contribute up to $1.7 billion to Nova Scotia's gross domestic product and create up to 22,000 full-time jobs, a transition that some argue should be planned by an independent body to ensure reliability.

Last month, Nova Scotia Power said it now generates 30 per cent of its power from renewables, as the province moves to increase wind and solar projects after abandoning the Atlantic Loop.

The utility says 18 per cent came from wind turbines, nine per cent from hydroelectric and tidal turbines and three per cent by burning biomass across its fleet.

However, over half of the province's electrical generation still comes from the burning of coal or petroleum coke, even as environmental advocates push to reduce biomass use in the mix. Another 13 per cent come from burning natural gas and five per cent from imports.

 

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More Polar Vortex 2021 Fallout (and Texas Two-Step): Monitor For ERCOT Identifies Improper Payments For Ancillary Services

ERCOT Ancillary Services Clawback and VOLL Pricing summarize PUCT and IMM actions on load shed, real-time pricing adders, clawbacks, and settlement corrections after the 2021 winter storm in the Texas power grid market.

 

Key Points

Policies addressing clawbacks for unprovided AS and correcting VOLL-based price adders after load shed ended in ERCOT.

✅ PUCT ordered clawbacks for ancillary services not delivered.

✅ IMM urged price correction after firm load shed ceased.

✅ ERCOT's VOLL adder raised costs by $16B during 32 hours.

 

Potomac Economics, the Independent Market Monitor (IMM) for the Electric Reliability Council of Texas (ERCOT), filed a report with the Public Utility Commission of Texas (PUCT) that certain payments were made by ERCOT for Ancillary Services (AS) that were not provided, even as ERCOT later issued a winter reliability RFP to procure capacity during subsequent seasons.

According to the IMM (emphasis added):

There were a number of instances during the operating days outlined above in which AS was not provided in real time because of forced outages or derations. For market participants that are not able to meet their AS responsibility, typically the ERCOT operator marks the short amount in the software. This causes the AS responsibility to be effectively removed and the day-ahead AS payment to be clawed back in settlement. However, the ERCOT operators did not complete this task during the winter event, echoing issues like the Ontario IESO phantom demand that cost customers millions, and therefore the "failure to provide" settlements were not invoked in real time.

Removing the operator intervention step and automating the "failure to provide" settlement was contemplated in NPRR947: Clarification to Ancillary Service Supply Responsibility Definition and Improvements to Determining and Charging for Ancillary Service Failed Quantities; however, the NPRR was withdrawn in August 2020 amid ongoing market reform discussions because of the system cost, some complexities related to AS trades, and the implementation of real-time co-optimization.

Invoking the "failure to provide" settlement for all AS that market participants failed to provide during the operating days outlined above will produce market outcomes and settlements consistent with underlying market principles. In this case, the principle is that market participants should not be paid for services that they do not provide, even as a separate ruling found power plants exempt from providing electricity in emergencies under Texas law, underscoring the distinction between obligations and settlements. Whether ERCOT marked the short amount in real-time or not should not affect the settlement of these ancillary services.

On March 3, 2021, the PUCT ordered (a related press release is here) that:

ERCOT shall claw back all payments for ancillary service that were made to an entity that did not provide its required ancillary service during real time on ERCOT operating days starting February 14, 2021 and ending on February 19,2021.

On March 4, 2021, the IMM filed another report and recommended that:

the [PUCT] direct ERCOT to correct the real-time prices from 0:00 February 18,2021, to 09:00 February 19, 2021, to remove the inappropriate pricing intervention that occurred during that time period.

The IMM approvingly noted the PUCT's February 15, 2021 order, which mandated that real-time energy prices reflect firm load shed by setting prices at the value of lost load (VOLL).1

According to the IMM (emphasis added):

This is essential in an energy-only market, like ERCOT's, where the Texas power grid faces recurring crisis risks, because it provides efficient economic signals to increase the electric generation needed to restore the load and service it reliably over the long term.

Conversely, it is equally important that prices not reflect VOLL when the system is not in shortage and load is being served, and experiences in capacity markets show auction payouts can fall sharply under different conditions. The Commission recognized this principle in its Order, expressly stating it is only ERCOT's out-of-market shedding firm load that is required to be reflected in prices. Unfortunately, ERCOT exceeded the mandate of the Commission by continuing to set process at VOLL long after it ceased the firm load shed.

ERCOT recalled the last of the firm load shed instructions at 23:55 on February 17, 2021. Therefore, in order to comply with the Commission Order, the pricing intervention that raised prices to VOLL should have ended immediately at that time. However, ERCOT continued to hold prices at VOLL by inflating the Real-Time On-Line Reliability Deployment Price Adder for an additional 32 hours through the morning of February 19. This decision resulted in $16 billion in additional costs to ERCOT's market, prompting legislative bailout proposals in Austin, of which roughly $1.5 billion was uplifted to load-serving entities to provide make-whole payments to generators for energy that was not needed or produced.

However, at its March 5, 2021, open meeting (related discussion begins around minute 20), although the PUCT acknowledged the "good points" raised by the IMM, the PUCT was not willing to retrospectively adjust its real-time pricing for this period out of concerns that some related transactions (ICE futures and others) may have already settled and for unintended consequences of such retroactive adjustments.  

 

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Biden calls for 100 percent clean electricity by 2035. Here’s how far we have to go.

Biden Clean Energy Plan 2035 accelerates carbon-free electricity with renewables, nuclear, hydropower, and biomass, invests $2T in EVs, grid and energy efficiency, and tightens fuel economy standards beyond the Clean Power Plan.

 

Key Points

A $2T U.S. climate plan for carbon-free power by 2035, boosting renewables, nuclear, EVs, efficiency, and grid upgrades.

✅ Targets a zero-carbon electric grid nationwide by 2035

✅ Includes renewables, nuclear, hydropower, and biomass in standard

✅ Funds EVs, grid modernization, weatherization, and fuel economy rules

 

This month the Democratic presumptive presidential nominee, Joe Biden, outlined an ambitious plan, including Biden’s solar plan to expand clean energy, for tackling climate change that shows how far the party has shifted on the issue since it controlled the White House.

President Barack Obama’s Clean Power Plan had called for the electricity sector to cut its carbon pollution 32 percent by 2030, and did not lay out a trajectory for phasing out oil, coal or natural gas production.

This year, Democratic 2020 hopefuls such as Sen. Bernie Sanders (I-Vt.) went much further, suggesting the United States should derive all of its electricity from renewable sources by 2030, moving to 100% renewables as part of a $16.3 trillion plan to wean the nation away from fossil fuels. Many other congressional Democrats have embraced the Green New Deal — the nonbinding resolution calling for a carbon-free power sector by 2030 and more energy efficient buildings and vehicles, along with a massive investment in electric vehicles and high-speed rail.

Last year, 38 percent of U.S. electricity generated came from clean sources, according to a Washington Post analysis of data from the U.S. Energy Information Administration, and in April renewables hit a record 28% nationwide.

Biden’s new plan, which carries a price tag of $2 trillion, would eliminate carbon emissions from the electric sector by 2035, impose stricter gas mileage standards, fund investments to weatherize millions of homes and commercial buildings, and upgrade the nation’s transportation system. To reach its 2035 carbon-free electricity goal, the campaign includes wind, solar and several forms of energy, acknowledging why the grid isn’t yet 100% renewable while balancing reliability, that are not always counted in state renewable portfolio standards, such as nuclear, hydropower and biomass.

“A great appeal of the Biden proposal is that it is much closer to targeting carbon directly, which is the ultimate enemy, and plays fewer favorites with particular technologies,” said Michael Greenstone, who directs the University of Chicago’s Energy Policy Institute. “This will reduce the costs to consumers and give more carbon bang for the buck.”

But some environmentalists, such as Friends of the Earth President Erich Pica, question the idea of including more controversial carbon-free technologies. “There is no role for nuclear in a least-cost, low carbon world. Including these dinosaurs in a clean energy standard is going to incentivize industry efforts to keep aging, dangerous facilities online,” Pica said in an email.

Hydropower, which relies on a system of moving water that constantly recharges, is defined as renewable by the Environmental Protection Agency. Biomass is often considered as carbon neutral because even though it releases carbon dioxide when it is burned, the plants capture nearly the same amount of CO2 while growing.


Both forms of energy have come under fire for their environmental impacts, however. Damming streams and rivers can destroy fish habitat and make it more difficult for them to spawn, and it also seems unlikely that hydropower will expand its current 6 percent share of the nation’s electrical grid.

Many experts argue that classifying biomass energy as carbon neutral provides an incentive to cut down trees that would otherwise remain standing and sequester carbon. “If burning this wood were good for the climate, then we should not recycle paper, we should burn it,” noted Tim Searchinger, a research scholar at the Princeton School of Public and International Affairs.

Illinois lead the nation in the amount of electricity generated from nuclear power

More than half of the country — 30 states, Washington, and three territories — have adopted a renewable portfolio standard (RPS), according to the National Conference of State Legislatures, and seven states and one territory have set renewable energy goals. While 14 states, along with the District, Puerto Rico and the Virgin Islands, have established requirements of 50 percent or more carbon-free electricity, nearly as many have set theirs at 15 percent or less.

Maine Gov. Janet Mills (D), who has called for 100% renewable electricity in the state, has pushed clean electricity aggressively since taking office in 2019, lifting a wind energy moratorium imposed by her predecessor and signing bills aimed at expanding the state’s carbon-free energy sources. Biomass accounts for a quarter of the state’s electricity, more than any other state.

New York has one of the country’s most ambitious climate targets, which it scaled up last year. It aims to obtain 70 percent of its power from renewable sources within a decade, a period when renewables surpassed coal in U.S. generation, and eliminate carbon altogether by 2040, even as the state is in the process of shutting down a major nuclear plant near New York City, Indian Point, which is slated to cease operating on April 30, 2021.

... while other states are weakening theirs

Last year, Ohio weakened its renewable energy standard from a target of 12.5 percent in 2027 to 8.5 percent by 2026, even as renewables topped coal nationwide for the first time in over a century, without setting any future goals, and jettisoned its energy efficiency standard. West Virginia — which established modest renewable requirements in 2009 — repealed them altogether in 2015, the year they were set to take effect.

 

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'Pakistan benefits from nuclear technology'

Pakistan Nuclear Energy advances clean power with IAEA guidance, supporting SDGs via electricity generation, nuclear security, and applications in healthcare, agriculture, and COVID-19 testing, as new 1,100 MW reactors near grid connection.

 

Key Points

Pakistan Nuclear Energy is the nation's atomic program delivering clean electricity, SDGs gains, and IAEA-guided safety.

✅ Two 1,100 MW reactors nearing grid connection

✅ IAEA-aligned safety and nuclear security regime

✅ Nuclear tech supports healthcare, agriculture, COVID-19 tests

 

Pakistan is utilising its nuclear technology to achieve its full potential by generating electricity, aligning with China's steady nuclear development trends, and attaining socio-economic development goals outlined by the United Nations Sustainable Development Goals.

This was stated by Pakistan Atomic Energy Commission (PAEC) Chairperson Muhammad Naeem on Tuesday while addressing the 64th International Atomic Energy Agency (IAEA) General Conference (GC) which is being held in Vienna from September 21, a forum taking place amid regional milestones like the UAE's first Arab nuclear plant startup as well.

Regarding nuclear security, the PAEC chief stated that Pakistan considered it as a national responsibility and that it has developed a comprehensive and stringent safety and security regime, echoing IAEA praise for China's nuclear security in the region, which is regularly reviewed and upgraded in accordance with IAEA's guidelines.

Many delegates are attending the event through video link due to the novel coronavirus (Covid-19) pandemic.

On the first day of the conference, IAEA Director General Rafael Mariano Grossi highlighted the role of the nuclear watchdog in the monitoring and verification of nuclear activities across the globe, as seen in Barakah Unit 1 at 100% power milestones reported worldwide.

He also talked about the various steps taken by the IAEA to help member states contain the spread of coronavirus such as providing testing kits etc.

In a recorded video statement, the PAEC chairperson said that Pakistan has a mutually beneficial relationship with IAEA, similar to IAEA assistance to Bangladesh on nuclear power development efforts. He also congratulated Ambassador Azzeddine Farhane on his election to become the President of the 64th GC and assured him of Pakistan's full support and cooperation.

Naeem stated that as a clean, affordable and reliable source, nuclear energy can play a key role, with India's nuclear program moving back on track, in fighting climate change and achieving the Sustainable Development Goals (SDGs).

The PAEC chief informed the audience that two 1,100-megawatt (MW) nuclear power plants are near completion and, like the UAE grid connection milestone, are expected to be connected to the national grid next year.

He also highlighted the role of PAEC in generating electricity through nuclear power plants, while also helping the country achieve the socio-economic development goals outlined under the United Nations SDGs through the application of nuclear technology in diverse fields like agriculture, healthcare, engineering and manufacturing, human resource development and other sectors.

 

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More red ink at Manitoba Hydro as need for new power generation looms

Manitoba NDP Energy Financing Strategy outlines public ownership of renewables, halts private wind farms, stabilizes hydroelectric rates, and addresses Manitoba Hydro deficits amid drought, export revenue declines, and rising demand for grid reliability.

 

Key Points

A plan to fund public renewables, pause private wind, and stabilize Manitoba Hydro rates, improving utility finances.

✅ Public ownership favored over private wind contracts

✅ Focus on rate freeze and Manitoba Hydro debt management

✅ Addresses drought impacts, export revenue declines, rising demand

 

Manitoba's NDP administration has declared its intention to formulate a strategy for financing new energy ventures, following a decision to halt the development of additional private-sector wind farms and to extend a pause on new cryptocurrency connections amid grid pressures. This plan will accompany efforts to stabilize hydroelectric rates and manage the financial obligations of the province's state-operated energy company.

Finance Minister Adrien Sala, overseeing Manitoba Hydro, shared these insights during a legislative committee meeting on Thursday, emphasizing the government's desire for future energy expansions to remain under public ownership, even as Ontario moves to reintroduce renewable energy projects after prior cancellations, and expressing trust in Manitoba Hydro's governance to realize these goals.

This announcement was concurrent with Manitoba Hydro unveiling increased financial losses in its latest quarterly report. The utility anticipates a $190-million deficit for the fiscal year ending in March, marking a $29 million increase from its previous forecast and a significant deviation from an initial $450 million profit expectation announced last spring. Contributing factors to this financial downturn include reduced hydroelectric power generation due to drought conditions, diminished export revenues, and a mild fall season impacting heating demand.

The recent financial update aligns with a period of significant changes at Manitoba Hydro, initiated by the NDP government's board overhaul following its victory over the former Progressive Conservative administration in the October 3 election, and comes as wind projects are scrapped in Alberta across the broader Canadian energy landscape.

Subsequently, the NDP-aligned board discharged CEO Jay Grewal, who had advocated for integrating wind energy from third-party sources, citing competitive wind power trends, to promptly address the province's escalating energy requirements. Grewal's approach, though not unprecedented, sought to offer a quicker, more cost-efficient alternative to constructing new Manitoba Hydro dams, highlighting an imminent energy production shortfall projected for as early as 2029.

The opposition Progressive Conservatives have criticized the NDP for dismissing the wind power initiative without presenting an alternate solution, warning about costly cancellation fees seen in Ontario when projects are halted, and emphasizing the urgency of addressing the predicted energy gap.

In response, Sala reassured that the government is in the early stages of policy formulation, reflecting broader electricity policy debates in Ontario about how to fix the power system, and criticized the previous administration for its inaction on enhancing generation capacity during its tenure.

Manitoba Hydro has named Hal Turner as the acting CEO while it searches for Grewal's successor, following controversies such as Solar Energy Program mismanagement raised by a private developer. Turner informed the committee that the utility is still deliberating on its approach to new energy production and is exploring ways to curb rising demand.

Expressing optimism about collaborating with the new board, Turner is confident in finding a viable strategy to fulfill Manitoba's energy needs in a safe and affordable manner.

Additionally, the NDP's campaign pledge to freeze consumer rates for a year remains a priority, with Sala committing to implement this freeze before the next provincial election slated for 2027.

 

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Relief for power bills in B.C. offered to only part of province

BC Hydro COVID-19 Relief offers electricity bill credits for laid-off workers and small business support, announced by Premier John Horgan, while FortisBC customers face deferrals and billing arrangements across Kelowna, Okanagan, and West Kootenay.

 

Key Points

BC Hydro COVID-19 Relief gives bill credits to laid-off residents; FortisBC offers deferrals and payment plans.

✅ Credit equals 3x average monthly bill for laid-off BC Hydro users

✅ Small businesses on BC Hydro get three months bill forgiveness

✅ FortisBC waives late fees, no disconnections, offers deferrals

 

On April 1, B.C. Premier John Horgan announced relief for BC Hydro customers who are facing bills after being laid-off during the economic shutdown due to the COVID-19 epidemic, while the utility also explores time-of-use rates to manage demand.

“Giving people relief on their power bills lets them focus on the essentials, while helping businesses and encouraging critical industry to keep operating,” he said.

BC Hydro residential customers in the province who have been laid off due to the pandemic will see a credit for three times their average monthly bill and, similar to Ontario's pandemic relief fund, small businesses forced to close will have power bills forgiven for three months.

But a large region of the province which gets its power from FortisBC will not have the same bail out.

FortisBC is the electricity provider to the tens of thousands who live and work in the Silmikameen Valley on Highway 3, the city of Kelowna, the Okanagan Valley south from Penticton, the Boundary region along the U.S. border. as well as West Kootenay communities.

“We want to make sure our customers are not worried about their FortisBC bill,” spokesperson Nicole Brown said.

FortisBC customers will still be on the hook for bills despite measures being taken to keep the lights on, even as winter disconnection pressures have been reported elsewhere.

Recent storm response by BC Hydro also highlights how crews have kept electricity service reliable during recent atypical events.

“We’ve adjusted our billing practices so we can do more,” she said. “We’ve discontinued our late fees for the time being and no customer will be disconnected for any financial reason.”

Brown said they will work one-on-one with customers to help find a billing arrangement that best suits their needs, aligning with disconnection moratoriums seen in other jurisdictions.

Those arrangement, she said, could include a “deferral, an equal payment plan or other billing options,” similar to FortisAlberta's precautions announced in Alberta.

Global News inquired with the Premier’s office why FortisBC customers were left out of Wednesday’s announcement and were deferred to the Ministry of Energy, Mines and Petroleum Resources.

The Ministry referred us back to FortisBC on the issue and offered no other comment, even as peak rates for self-isolating customers remained unchanged in parts of Ontario.

“We’re examining all options of how we can further help our customers and look forward to learning more about the program that BC Hydro is offering,” Brown said.

Disappointed FortisBC customers took to social media to vent about the disparity.

 

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