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November 7, 2024

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NJ Enviros: Heat Pumps Can Cut Building Emissions, Costs

New Jersey could dramatically cut greenhouse gas emissions from buildings – the state’s second largest source of emissions – by replacing fossil-fueled boilers with heat pumps and other electric appliances and beefing up incentives for the equipment, according to a recent report from the New Jersey Conservation Foundation.

Heat pumps can replace furnaces or boilers, and “handle the heating needs of well-insulated homes in the Northeast without backup systems,” according to the report by the Acadia Center, a nonprofit environmental and policy group. Combining heat pumps with other electric appliances and weatherization can result in energy bill saving of almost 50%, the report says.

Often described as air-conditioners in reverse, heat pumps extract heat from outside air, concentrate it and push it into a home. Due to recent improvements in the technology, heat pumps can operate effectively even in sub-zero temperatures, according to the report.

Yet New Jersey’s incentive programs lag behind those of neighboring states, the foundation and other environmental groups said at a press conference Tuesday. They called on state government to develop policies that would offer building owners incentives big enough to reduce the cost of a heat pump, or other electric appliance, to the same cost as a fossil-fuel heater or boiler.

“Just like we have with wind, solar and electric vehicles, New Jersey must be ambitious,” said Eric Miller, New Jersey energy policy director for the Natural Resources Defense Council (NRDC). The state “must design and implement comprehensive building electrification programs that make technologies such as cold climate heat pumps, accessible to the residents and businesses of the state through a coordinated whole of government approach,” Miller said.

“Cold climate heat pumps can work in New Jersey’s climate even on the coldest days,” he said. Heat pumps “can decrease average energy bills for New Jersey’s residents [and] can significantly decrease pollution from New Jersey’s buildings.”

Savings, at a Cost

According to the report, data on New Jersey’s housing stock, weather and utility rates show that the average new home could save about $50 a year if it installed “new efficient cold climate heat pumps” and heat pump water heaters.

If the homeowner also weatherized the house, it would save about $180 a year, and an older, less-efficient house could save $1,300 a year by weatherizing and switching from gas to electric heat and hot water, the report says.

With a typical heat pump costing $4,000 to $7,000, New Jersey previously offered a $2,000 incentive for the purchase of a 5-ton air source heat pump, the report says. But since 2021, the incentives, now handled by utilities, have been cut, with Atlantic City Electric and Jersey Central Power & Light offering rebates of $1,000, while the rebate from PSEG ranges from $390 to $600, according to the report.  

But Rebecca Mazzarella, a spokeswoman for PSEG, said that the company “has incorporated heat pumps for heating, cooling and water heating into our broad effort to help customers save money and energy.”

“Residential heat pumps qualify for rebates up to $750, and customers may be eligible for up to $15,000 in no-interest on-bill repayment to help offset the cost of energy efficient upgrades,” she said, adding that the utility also has  programs offering energy efficiency rebates for commercial customers.

Vermont offers incentives of up to $2,000 for heat pumps, while Connecticut offers between $2,500 and $7,500, according to the New Jersey Conservation Foundation report. New York offers up to $1,600, the report says.

Speakers at the press event dismissed the suggestion, floated by some opponents of electrification, that heat pumps don’t work in cold weather. In response, they cited data that shows annual heat pump sales have surged in New England ― aided by incentives ― from about 70,000 sold in 2016 to close to 180,000 sold in the region in 2020, according to the report.

Maine has set a target of installing 100,000 air source heat pumps by 2025, but had already installed 75,000 by 2021, according to the Efficiency Maine Trust, which is assisting with the installation of heat pumps. New York State is investing $700 million to encourage energy efficiency measures and building electrification, mainly with clean energy heat pump technology. (See NY Pushes Electrification with Heat Pumps.)

New Emissions Rules

Electrification is part of Gov. Phil Murphy’s plan to help New Jersey reach a goal of 100% clean energy by 2050. The state’s 2020 masterplan update sets an GHG emissions reduction goal of 80% by 2050, and on Nov. 10, 2021, Murphy signed an executive order committing the state to a 50% cut in emissions by 2030.

The plan does not suggest a mandate to electrify buildings but calls for the building sector to be “largely decarbonized and electrified” by 2050, with a focus on “new construction and the electrification of oil- and propane-fueled buildings.”

The New Jersey Conservation Foundation report comes as the state’s Department of Environmental Protection (DEP) is evaluating public response to proposed rules that would prohibit the installation of new commercial and industrial fossil fuel-fired boilers in certain circumstances. If the rules were to go into effect, the DEP would not issue a permit for a new fossil-fuel fired boiler of 1-5 MMBTU unless it is “technically infeasible” to use a non-fossil fuel boiler because of “physical, chemical or engineering principles” or because the interruption of the operation of an existing boiler could “jeopardize public health, life or safety.”

Electrification of the state’s building stock, however, does not have universal support. In January, the state Senate voted 35 to 3 in favor of a bill, S4133, that would prevent state agencies from requiring buildings to use electric heating or hot water boilers as part of the state’s carbon reduction efforts. The bill did not advance in the Assembly before the legislative session ended a few days later.

The bill was similar to other “preemption” bills, which were passed in 20 states last year, with broad and active support from the natural gas industry.  (See NJ Legislators Back Alternatives to Electric Heat.) Proponents of the New Jersey bill argued that it is too soon to back electrification as the only solution when alternative fuels could also help cut emissions. Critics also say that heat pumps are expensive.

The New Jersey Conservation Foundation, however, said it is not looking for a mandate that requires the installation of electric appliances and boilers. The goal is to remove any barriers to the adoption of electrical products, provide incentives and advance a widespread understanding of the benefits of electrical heaters and boilers, said Barbara Blumenthal, research director for the foundation.

The incentives “are designed to help spur the innovation and growth and acceptance of the technology, so that as more people become aware, they see that there’s an opportunity and that opportunity becomes more accessible for everyone.”

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Michigan Appeals Court Rules for Wind Turbines near Airport

LANSING, Mich. — In a case that could have statewide implications, Michigan’s Court of Appeals ruled that a Tuscola County Airport board improperly denied variances for eight new wind turbines near the airport, the latest decision in a number of court actions involving the wind farm operated by NextEra Energy Resources’ (NYSE:NEE) Pegasus Wind.

Pegasus operates several wind farms in Michigan’s Thumb region, the location of the greatest concentration of wind farms in the state. Some local governments in the multicounty agricultural region have welcomed wind farms, but others have resisted vigorously. Pegasus’ efforts to locate a wind farm near Tuscola County’s airport have engendered more than a dozen legal cases in both state and federal court, said Heidi Stark, a member of the county’s Planning Commission.

In November 2019, the Tuscola Circuit Court reversed the Tuscola Area Airport Zoning Board of Appeals’ (AZBA) decision rejecting variances for 33 Pegasus turbines, which are now operating. A month before that decision, Pegasus submitted variance applications for eight additional turbines within the airport’s zoning area.

In this case, Pegasus Wind v. Tuscola County and Tuscola County Airport Zoning Board of Appeals (Docket No. 355715), the Tuscola County circuit judge ruled the AZBA had authority to deny the eight variances, although the Federal Aviation Administration and Michigan Department of Transportation (MDOT) had issued “determinations of no hazard.”

But Appeals Judge Michelle Rick, joined by Judge Douglas Shapiro, ruled that the circuit court erred in its ruling and the variances should be granted. Judge Christopher Murray dissented.

‘Practical Difficulty’ vs. ‘Unnecessary Hardship’

The Michigan Airport Zoning Act requires zoning boards of appeals to allow a variance “if a literal application or enforcement of the regulations would result in practical difficulty or unnecessary hardship and the relief granted would not be contrary to the public interest, but would do substantial justice and be in accordance with the spirit of the regulations.”

The Tuscola Area Airport Zoning Ordinance, in contrast, requires the AZBA to grant a variance if a petitioner establishes any one of those factors, as long as the FAA and MDOT’s Aeronautics Commission has found no hazard.

The court said that the circuit court improperly “conflated” the terms “practical difficulty” and “unnecessary hardship.”
It said many of the zoning cases cited by the circuit court and the parties on appeal did not differentiate between practical difficulty and unnecessary hardship because the prior zoning law allowed variances for both reasons.

Tuscola County Airport Variance map (Michigan Court of Appeals) Alt FI.jpgThis “variance map” included in the court’s ruling shows numerous wind turbines (blue rocket shapes) around the Tuscola County Airport (center). | Michigan Court of Appeals

That changed with the 2006 Michigan Zoning Enabling Act, which said only a showing of practical difficulty — and not unnecessary hardship — is required to justify the grant of “nonuse” variances, which are concerned with the area, height and setback requirements of structures.

“Because there appears to be confusion between the requirements of practical difficulty and unnecessary hardship, we use this case as an opportunity to distinguish those requirements in the application of variances,” the court said. “The law is clear that practical difficulty and unnecessary hardship are two separate things, and being unique to or inherent in the property is a requirement of hardships, not practical difficulty.

“The question is whether Pegasus has any use for this land under the current zoning — it does not — and whether entering into the agreements with knowledge that the land was subject to the zoning ordinance rendered these hardships self-created — also no,” the court continued. “Accordingly, none of the AZBA’s three stated reasons for concluding that Pegasus failed to establish a practical difficulty is supported by the record, let alone supported by substantial evidence, and the circuit court misapplied the practical difficulty standard.”

Public Interest

The court said the circuit court also erred by affirming the AZBA’s determination that the variances would be contrary to the public interest and protection of the airport’s approach.

The AZBA said the turbines would require a 300-foot increase in minimum descent altitude and that there was no evidence that the energy generated by the project is needed or would be used in the surrounding community.

The court said, however, that there are already numerous turbines “in and around the airport.”

“The record does not contain any evidence supporting a finding that the addition of these eight turbines would or could create risks and situations different from what is already happening as a result of the numerous wind turbines already built.”

While the case deals directly with Tuscola County, many local governments in Michigan have adopted zoning ordinances to effectively block development of wind and solar farms. The AZBA ordered the case published, which means the ruling must be followed in similar cases unless a higher court overturns it.

Pegasus could not be reached for comment. Lawyers for the county could not be reached for comment on whether it will appeal to the state Supreme Court. The Supreme Court refused to hear an earlier case involving Pegasus and Tuscola County.

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Report: Microsoft, PepsiCo Earn Top Marks on Net-zero Progress

Microsoft (NASDAQ:MSFT) and PepsiCo (NASDAQ:PEP) took the No. 1 and 2 spots in a new ranking of 55 large U.S. companies for their work on net-zero targets and greenhouse gas emission reductions and disclosures.

“The good news is that progress is being made,” said Danielle Fugere, president and chief counsel of the nonprofit As You Sow and co-author of the report “Road to Zero Emissions,” released Thursday.

An examination of the top five U.S. corporations in each of 11 major sectors showed 50 companies are disclosing some of their climate emissions, Fugere said during a webinar on the report.

While the number of companies that adopt net-zero targets is increasing, the term “net zero” is not well defined and often does not align with the goal to limit global warming to a 1.5-degree Celsius increase, she said. Companies, she added, don’t always demonstrate whether they are reducing emissions directly or using carbon offsets, and few companies disclose emissions from, or set targets that cover, their value chains.

Value-chain emissions come from sources not directly associated with company operations or the energy that companies purchase or consume. They are difficult to track and can include, for example, companies’ franchise and investment activities or use of the products they sell.

About half of the companies in the report are achieving emissions reductions related to direct operations and energy, but their value-chain emissions represent “the vast majority of total emissions,” according to David Shugar, ESG and climate data analyst at As You Sow and co-author of the report.

Companies analyzed for the report received scores based on GHG emission reductions, disclosures and targets, with reductions showing the “greatest room for improvement,” he said.

Microsoft and Pepsi were among a group of six companies to earn the highest marks on GHG reductions by decreasing emissions at a rate necessary to meet a 1.5-C, net-zero by 2050 goal. There were 43 companies, however, that earned the lowest marks for either not disclosing emissions or not reducing direct and value-chain emissions in line with 1.5 C.

For GHG disclosures, most of the companies report their direct emissions, but Shugar said only 20 report their value-chain emissions. Microsoft, PepsiCo, Alphabet (NASDAQ:GOOGL), Johnson & Johnson (NYSE:JNJ) and Facebook (NASDAQ:FB) earned the highest marks for their disclosures, while Tesla (NYSE:TSLA) and Berkshire Hathaway (NYSE:BRK.A) earned the lowest marks. Only 11 companies, he said, report the number of offsets they are purchasing to meet their targets.

Looking at the companies’ GHG targets, 36 have set a GHG reduction goal, but some of the goals are not 1.5 C aligned, Shugar said. And Microsoft and Apple (NASDAQ:AAPL) were the only companies with targets for their value-chain emissions that address a 1.5-C goal, he said.

Energy Companies

Of the five energy companies that made the report, only Southern Co. (NYSE:SO) earned what the report described as a passing mark, ranking No. 8 overall. Southern scored well for disclosing its emissions, but it is among the companies that is not addressing its value-chain emissions.

While Dominion Energy (NYSE:D), Duke Energy (NYSE:DUK) and NextEra Energy (NYSE:NEE) also scored well for their emissions disclosures, none have set carbon-neutral goals for 2050 that cover direct or value-chain emissions, according to the report.

Berkshire Hathaway, parent company of MidAmerican Energy and PacifiCorp, took the lowest spot on the list, having not met any of the criteria in the report for GHG disclosures, targets and reductions.

To support companies that believe the report does not accurately represent their net-zero programs, Fugere said that As You Sow is creating an online reporting tool so companies can update the nonprofit’s database in real time. Future rankings will reflect the updates submitted to the database, she said.

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DC Circuit Upholds FERC on Transmission Cost Allocation in PJM

The D.C. Circuit Court of Appeals on Friday denied Linden VFT’s and the Long Island Power Authority’s (LIPA) petitions for review of a settlement that allocated transmission costs in PJM.

But the court did agree with Linden’s argument that FERC “erroneously” assigned costs based on a “flawed interpretation” of the settlement, remanding the commission’s decision for further proceedings.

The dispute was over a settlement the commission approved between PJM and members in May 2018 regarding how the RTO would allocate the costs of transmission projects above 500 kV approved between April 19, 2007 — when FERC determined the RTO’s existing violation-based distribution factor (DFAX) or “postage stamp” method was unjust and unreasonable, requiring a new load-ratio share method — and Feb. 1, 2013, when FERC approved PJM’s new hybrid method, combining both the DFAX and load-ratio methods. (See FERC Rebuffs Challenges to PJM Tx Cost Allocation.)

FERC approved the settlement over the objection of Linden and LIPA, both of which export electricity from PJM to New York; they argued they would pay about $30 million more for the “vintage projects” approved between 2007 and 2013 than under a pure DFAX method.

After the commission denied rehearing of the settlement orders, Linden and LIPA petitioned for judicial review.

“The question is difficult because high-voltage projects afford two different kinds of benefits — local benefits that accrue primarily to utilities close to the project at issue, and regional benefits that accrue throughout the grid,” the court said in its ruling. “The 7th Circuit has twice set aside cost allocations that ignored the local benefits, and we have set aside cost allocations that ignored the regional benefits.”

Arguments

Linden and LIPA contended that FERC’s approval of the settlement, and the allocations it implemented, were arbitrary, but the court disagreed, saying that the commission can approve an agreement when the “overall result of the settlement is just and reasonable,” even if “individual aspects” of it “may be problematic.”

“FERC adequately justified its approval of each formula,” the court said. “Start with the going-forward formula, which allocates costs through a mix of the postage-stamp and flow-based methods. FERC approved the formula based on reasoning in its 2013 compliance order, which had approved the same formula for future high-voltage transmission projects. Doing so was not arbitrary.”

Linden and LIPA also contended that the settlement violated a requirement of a cost-benefit analysis to quantify the benefits of a project, citing the 7th Circuit Court of Appeals’ rejection of the postage-stamp methodology in 2014. But the D.C. Circuit said that ruling was narrow, in that it found FERC weighed regional benefits over local benefits. “‘Nothing in those decisions casts doubt on’ FERC’s view that high-voltage projects have substantial regionwide benefits,” it said, quoting itself from a previous ruling.

The court also said FERC “reasonably concluded” in its orders that Linden or LIPA would not have found a more favorable decision on the settlements by going through litigation in the courts.

“The challengers do their best to obscure this point, but what they seek is application of a pure postage-stamp method — or at least a hybrid formula with a more heavily weighted postage-stamp component,” the court said. “The 7th Circuit has twice set aside a pure postage-stamp formula for the vintage projects. We have little doubt that, if faced once again with a pure or almost pure postage-stamp formula, it would call strike three.”

TEC Adjustments

The 2018 settlement made a series of adjustments for the “vintage project” costs incurred before 2016, which PJM previously had allocated under the DFAX method. FERC said the adjustments were made to bring the allocations in line with “what would have been credited or paid” if PJM had adopted the going-forward formula from the start.

The formula imposed monthly transmission enhancement charge (TEC) adjustments beginning in January 2016 and continuing through December 2025.

Linden argued that it did not need to make any of the payments created in the formula because it surrendered its firm transmission withdrawal rights on Jan. 1, 2018, about five months before FERC approved the settlement. PJM agreed that Linden did not need to pay TEC adjustments for 2018 to 2025, but they disagreed over TEC adjustments for 2016 and 2017.

Regarding TEC adjustments, the PJM tariff states, “If all responsible customers in a zone or merchant transmission facility are no longer subject to transmission enhancement charges under the PJM tariff during the period in which transmission enhancement charge adjustments are collected, then, during the portion of that period that such responsible customers are not subject to transmission enhancement charges, the payments from or credits to such responsible customers shall cease.”

Linden is the only responsible customer in its merchant facility, and it argued that the “period in which [TEC] adjustments are collected” began when FERC approved the settlement, because PJM “did not and could not collect any payments before then.”

FERC said that TEC adjustments began to accrue and were “collected” as soon as the settlement became effective in January 2016.

“The plain meaning of ‘collected’ unambiguously supports Linden,” the court ruled. “FERC has not identified a single example, in a dictionary or otherwise, where ‘collect’ means to accrue liability. Nor have we found any. This strongly suggests that ‘collect’ simply cannot bear that meaning.”

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ERCOT, Brazos Agree to Mediation in Dispute

ERCOT and Brazos Electric Power Cooperative agreed last week to enter mediation over the amount of money the bankrupt cooperative owes the Texas grid operator’s market.

The agreement paused a two-week proceeding in Houston before the U.S. Bankruptcy Court for the Southern District of Texas and followed testimony Thursday by Kenan Ögelman, ERCOT’s vice president of commercial operations.

Ögelman explained to the presiding judge that ERCOT is a nonprofit, “invoice-in, payment-out” manager of the state’s electric market. Defaults on any power purchases would be uplifted to its participants, he said.

“How does ERCOT pay? They’re a clearinghouse. What assets do they have?” Chuck Gibbs, an attorney representing Brazos’ largest member, said last month during an Infocast ERCOT Market Summit. (See ERCOT’s Legal Issues Continue to Mount.)

U.S. Bankruptcy Judge David Jones suggested the two sides reach an agreement over their differences “to make this all work. ERCOT … [is] a lifeblood for everybody that lives in this state.”

ERCOT and Brazos will mediate their dispute before Judge Marvin Isgur, the court’s other presiding judge. The bankruptcy proceeding is expected to resume in April.

At issue is $1.9 billion in market charges ERCOT assigned to Brazos during last February’s winter storm, when regulators ordered prices be kept at $9,000/MWh over four days. The cooperative is not disputing how much energy it bought to compensate for its own plants that did not run, but it argues it should owe about $800 million (21-03863).

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MISO Winter Fuel Security Surveys Now Permanent

With winter largely behind it, MISO staff last week told stakeholders that winter fuel security surveys will become an annual fixture.  

The RTO rolled out the weekly surveys to its fossil fuel generation fleet’s owners in early December, despite some members saying it was a burdensome task. At the time, MISO said it was receiving concerning reports about possible fuel scarcities ahead of the winter. The mandatory surveys ended last month.  (See MISO Sounds Alarm on Potential Winter Fuel Scarcity.)

During a Reliability Subcommittee meeting Thursday, staff’s J.T. Smith said the grid operator will refine the format to make sure it’s efficient and easier to use by next winter.  

“We know that this was a very ad-hoc, quick move,” Smith said of last year’s abrupt rollout. He said staff will examine whether the RTO is “asking the right questions or not.”

He admitted that not all generation owners responded to the survey after it was introduced. MISO has said some operators were “hit and miss” in filling out the weekly surveys.

“By the time we started to get decent information, it wasn’t as relevant anymore,” Smith said.

MISO said the survey results showed “healthy” fuel stockpiles this winter. It said the mild winter weather also contributed to the positive fuel management. Some operators reported slower train deliveries because of supply chain issues, labor shortages and harsh weather.

The RTO also delivered a refresher on how it positions itself for extreme weather. (See NERC Cold Weather Project Moves Forward.)

MISO’s Trevor Hines said each extreme weather event is different and the RTO prepares differently across heatwaves, arctic blasts, hurricanes or tornadoes.

He said the bulk of preparations rely on members’ most up-to-date offer data available. “We’re only as good as the information provided to us,” Hines said.

He said staff considers an extreme weather event’s unique risk before committing generation in advance. Hines said control room operators will monitor storm paths to anticipate what resources could become unavailable and will order early start times if it becomes too cold for generators to start up normally. MISO often dispatches additional units to account for forced outage risk, he said.

MISO is considering using extreme weather historical data to influence its decision-making, Hines said. He said going forward, staff might use past load data and generation- and transmission-failure data to predict response during unfolding events.

The RTO will also remove the “other” option when generation owners input data into the outage scheduler.

Senior engineer David Schoon said MISO suspects the generic option is overused as a cause code in the outage tickets that market participants submit for outages. In its place, staff will add several new outage explanation selections.

Staff said it’s important they understand why generation outages are occurring. MISO said it hasn’t meaningfully updated its outage-cause codes since 2014.

Some stakeholders said it isn’t immediately clear what causes generation to trip. They added that MISO’s outage ticket system is rigid and doesn’t allow members to retroactively modify their entries.

Staff said they would investigate why members can’t seem to edit outage notices.

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Nonprofits: NorthWestern’s Net-zero Goal Not Enough

Dozens of Montana organizations are demanding that NorthWestern Energy decarbonize by 2035, years ahead of its midcentury target for net-zero emissions.

More than 30 groups, including environmental nonprofits, public consumer advocates, health care professionals, consultants and a Montana State University professor, sent a letter Thursday to NorthWestern Board Chair Dana Dykhouse. The organizations demanded the utility decarbonize its fleet no later than 2035, saying the plan should be based on science and contain benchmarks.

The letter also said NorthWestern, which serves 753,600 customers across Montana, South Dakota and Nebraska in SPP and MISO, should model multiple scenarios that “eliminate the utility’s dependence on fossil fuels.”

“We urge you, as a fiduciary of NorthWestern Energy, to exercise your responsibility in a manner that guarantees the company’s long-term financial well-being,” the letter urged Dykhouse. “That can only be accomplished by requiring the company to adopt a meaningful climate strategy that will make it more resilient and prepared for the clean energy future.”

The same day, NorthWestern set a goal of achieving net-zero carbon emissions by 2050. Montana’s largest utility called it an “achievable target” in a press release.

“NorthWestern Energy begins this transition to an even cleaner energy future building on the considerable progress we have already made,” Energy CEO Brian Bird said. “We have the tremendous honor to be the stewards of this critical energy infrastructure that delivers safe and reliable energy to our region. Now is the time to raise the bar and start the transition to net zero by 2050.”

Northwestern said that last year, 56% of its electricity was generated from carbon-free resources, better than the electricity industry’s 40% average. It pointed out that its 10 hydroelectric facilities supplied 33% of the utility’s load.

Montana Environmental Information Center Co-Director Anne Hedges, one of the letter’s signatories, blasted the 2050 goal as a “PR move to improve lackluster” environment, social and governance perception. She said the target allows NorthWestern to raise emissions through 2035 by building more fossil fuel generation and pipelines.

“There are no benchmarks for reaching its 2050 goal in the electricity section of its business. Until we see NorthWestern actually plan for a clean energy future with benchmarks and actions that decrease its reliance on fossil fuels instead of increasing its reliance, it’s hard to take its proposal seriously,” Hedges said in an email to RTO Insider. “Anything short of meaningful planning and implementation is just more of the same from this laggard utility.”

She said NorthWestern’s largest financial investors have “raised concerns about companies that fail to plan for a lower carbon future” and added that financial analyst Moody’s has recently given the utility poor environmental and social scores. She said NorthWestern’s 2050 net-zero goal is only a “small step” and about decade behind other utilities in the region.

“Increased fossil fuel dependency means increased costs for customers, more expensive stranded assets and a failure to decarbonize according to the latest scientific research,” Hedges said.

NorthWestern did not respond to a request for comment.

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MISO, SPP Finalize JTIQ Results with MISO Transmission Duplicates

MISO and SPP on Friday announced that they have completed their Joint Targeted Interconnection Queue (JTIQ) study, though two of the project proposals might not proceed under the interregional planning effort.

The final study report’s portfolio includes seven projects, costing about $1.65 billion, designed to foster more generator interconnections and unclog the RTOs’ queues. If approved, the transmission projects could resolve 48 reliability constraints and deliver about $724 million in adjusted production costs savings to MISO and $247 million to SPP.

However, two of the JTIQ’s portfolio projects are also included in MISO’s long-range transmission portfolio. The transmission lines, in North Dakota and from South Dakota to Minnesota, could invalidate or seriously alter the RTOs’ plans for similar projects. (See MISO Stakeholders Uneasy Over Long-range Tx, JTIQ Overlap.)

MISO stakeholders have asked that SPP load bear some of the two projects’ costs, even if SPP’s benefits are shown to be small. Both projects are in the MISO footprint.

MISO planners have been firm that their long-range planning takes priority over the JTIQ study. Staff have also said the RTO’s benefits on the two projects eclipse SPP’s, and they have pointed out that the grid operators haven’t yet delved into meaningful cost-allocation negotiations.

According to the JTIQ study, the $424.5 million South Dakota-Minnesota line yields a $487 million APC benefit to MISO and a $32 million benefit to SPP. The $165 million North Dakota line results in $405 million in benefits to MISO and $56 million in SPP benefits.

The JTIQ study began in late 2020 and evaluated 59 project ideas. MISO kicked off its long-range planning in mid-2020.

In a joint statement accompanying the study’s release, MISO CEO John Bear and SPP CEO Barbara Sugg said the need to build transmission to accommodate increasing renewable energy requests “transcends boundaries.”

They said a lack of new transmission projects along their seam caused generation projects in both footprints “to drop out of the study process because costly network upgrades are triggered.”

MISO’s interconnection queue currently contains 127.1 GW of proposed generation. SPP has 97 GW worth of new generation in its queue. Both are overwhelmingly tipped toward renewable energy and storage projects.Their analysis shows the JTIQ portfolio could support a range of 28 to 53 GW worth of new generation along their seam.

“Both MISO and SPP have existing planning processes, and the JTIQ partnership allowed us to focus on future reliability risks based on the trends in our generation portfolios,” Antoine Lucas, SPP vice president of engineering, said in a press release. “The resulting portfolio of projects fully resolves the set of transmission constraints evaluated in the study, providing considerable reliability benefits to both RTO regions.”

The RTOs said they’re after an “equitable cost allocation mechanism between interconnection customers and load in MISO and SPP.” They expect cost-allocation discussions to continue “well into 2022.”

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NYISO Launches 2022 Grid Planning Study

NYISO on Wednesday presented stakeholders with a plan to clarify by year-end what increasing amounts of renewable energy mean for the grid over the next decades.

“I want to look at the evolution of load and net load shapes over time, i.e., load net of wind and solar, both behind the meter and in front of the meter, because that is really what the rest of the resources have to respond to,” Nicole Bouchez, principal economist for market design, told the Installed Capacity/Market Issues Working Group.

The multiphase study will first dive into the ISO’s Climate Change Phase I report from 2020 and follow with two studies coming this year that will have additional information.

The first new analysis planned is the Outlook study, followed by the Reliability Needs Assessment (RNA), which could possibly be leveraged for the Grid in Transition effort. (See NYISO Updates Grid in Transition Work and Plan for 2022.)

NYISO will examine “things like the distribution of hourly ramps over time, because in many ways that is what we are anticipating will be changing and what California has seen changing,” Bouchez said. “We’re also going to be looking at periods with low wind and solar and what that implies for these net energy and hourly ramps.”

Several stakeholders said that while some previous studies identified the dispatchable emission-free resource capacity that New York will likely need in the future, there is not much information available on the duration and magnitude of wind and solar lulls.

“It’s not just the energy amount, but how long and how often do we have a one-week lull; how many times do we have a two-day lull; and how many times do we have an hour or two lull — [in order] to understand what kind of pallet of dispatchable emission-free resources would most appropriately apply to the system conditions that we’re likely to see,” said David Clarke of Long Island Power Authority.

Accurate forward weather forecasting will become increasingly important, and the duration and frequency of wind lulls directly impact other resource requirements and other technology requirements as planners start to look out over a 10- or 20-year period, said Chris Wentlent of the Municipal Electric Utilities Association.

“So if we’re seeing a two- or three- or four-day lull, that creates a certain requirement as we think about storage going forward and storage capability,” Wentlent said. “Same thing with zero-carbon resources and the amount that we might need as backup in in those type of events.”

In terms of forward weather forecasting, Bouchez said she didn’t know of any studies specific enough to say at exactly what time of the year lulls will change, but that the second phase of the climate change study looked at historical data, and what scenarios could happen.

NYISO System Energy Forecast (NYISO) Content.jpgNYISO system energy forecast shows the Policy Case is lower as additional EE savings and PV adoption outweigh gains from electric vehicles and electrification. After 2030, CLCPA forecast is significantly higher than the Reference Case, largely driven by aggressive statewide electrification. | NYISO

 

NYISO commissioned Analysis Group to perform the Phase II study, which examined the potential impacts on reliability based on the electricity demand projections for 2020-2050 developed in the initial climate change study. Those include the impacts on load and resource availability from more frequent and severe storms and extended heat waves and cold snaps.

“We can definitely go back and re-leverage that information and look to see what we can leverage in terms of wind lulls, especially when we’re looking at periods of multiday potentially low solar,” Bouchez said. “We’ll see what we can pull to make those as realistic as possible, given what is expected in the future.”

The ISO plans to present the Phase I analysis in March and April in terms of market design and then the policy case from the Outlook study in the third quarter, Bouchez said. The RNA study would be presented in the fourth quarter.

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MISO to Loosen Some Interconnection Requirements

MISO said it will alter some interconnection rules so that generation owners can more easily replace generation at the same point of interconnection or share a single point of interconnection with other owners.

The RTO will remove the requirement that transmission owners must sign off on a shared facilities agreement among interconnection customers, saying there was never a need for transmission owners to be signatories to agreements for shared interconnection facilities.

During a March 1 Planning Advisory Committee, MISO’s Jackson Evans said that after the RTO’s shared network upgrade process was introduced in 2019, multiple disputes arose between interconnection customers and transmission owners over who has ownership rights to interconnection facilities and who would be responsible for their maintenance.

“It almost led to multiple withdrawals” in the interconnection queue, Evans said.

MISO will still require interconnection customers wishing to share interconnection facilities to submit a shared facilities agreement upon filing their request. However, that agreement will no longer be tied to the transmission owners’ interconnection facilities.

Customized Energy Solutions’ Ginger Hodge thanked MISO for the changes and ending a year of “delays, disagreements and frustrations.”

The grid operator said it will prepare a FERC filing for either April or May. The revised process would apply to entrants in the generator interconnection queue’s next cycle

The RTO also said it will make it easier for generation owners to replace units, allowing generators to request longer-term suspension reliability studies with the replacement requests. Previously, the grid operator granted reliability assessments only for the gap period between winding down generator operations at the outgoing unit and the replacement unit’s startup.

MISO added that it will reduce its decision time to approve suspensions for units set to be demolished and replaced. It also said it can shorten a required 26-week notice period to 30 days for generator suspensions in certain replacement situations.

The RTO intends to file the replacement generation process changes with FERC sometime in May.