Page 1448 – RTO Insider

May 16, 2016

Generators, Tx Operators Spar over Interconnection Processes Before FERC

By Rory Sweeney

Generation developers and transmission operators squared off Friday at a FERC technical conference on interconnection procedures, with developers voicing frustration about delays and a lack of clarity in the processes.

Paul Kelly, NIPSCO - generators transmission operators interconnection ferc — Kelly

Transmission operators pushed back, arguing that high numbers of interconnection requests in small geographical areas create congestion and delay their ability to efficiently review projects.

The conference was prompted by the American Wind Energy Association, which requested that FERC make regulatory and policy changes to interconnection procedures that it argued are outdated, “unduly discriminatory and unreasonable” (RM16-12, RM15-21).

Paul Kelly, director of federal regulatory policy for Northern Indiana Public Service Co., spoke on behalf of MISO transmission owners. He said that risk should be balanced between developers and owners.

“There’s a difference between improving a process and driving efficiencies versus shifting risks onto different parties,” he said. “There are inherent risks for certain business activities, and there can’t be a guaranteed insurance policy.”

Alan McBride, director of transmission strategy and services at ISO-NE, gave Maine as an example of a small region that has experienced a large number of requests. “The problem we do have is in a specific part of the system that is already at its performance limits, we have a significant number of interconnection requests, pretty much exclusively for renewable interconnection,” he said.

The situation is further complicated, transmission operators explained, when projects drop out during the review process, causing a restudy and reshuffling of the queue.

Location, Location, Location

Gosselin - generators transmission operators spar interconnection processes ferc — Gosselin

Developers defended their concentration of requests, saying wind farms’ profitability is dependent on location.

“It matters tremendously in terms of the overall cost per unit of production,” said Dean Gosselin, NextEra Energy’s vice president of business management. “The more windy it is, the lower the cost. Price matters in the marketplace, so clustering usually happens because of that.”

Transmission operators were unified in assuring that they are working on solutions to the delays, but they argued that “speculative” projects are clogging the queue. Developers said all projects can be viable until they’ve gone through studies and received accurate information about the cost and timing of the interconnection.

Omar Martino, director of transmission for EDF Renewable Energy, argued that a 12-month target for completion of studies would solve the issue. He said interconnection customers crowd into the queue “because they understand they will not be able to do anything for the next five to six years.”

Rick Vail, PacifiCorp’s vice president of transmission, said one of the biggest concerns is the time and effort needed to restudy when higher-queue projects drop out.

“A majority of the generation in our system is hundreds, if not many hundreds, of miles away from a load center. So you certainly have different areas where you have transmission constraints, but those also continue to be the areas where developers are requesting to connect to the system,” he said. “A lot of the requests we get seem to [be] a fishing expedition of trying to determine where in the transmission system is the most appropriate place to attach generators.”

Tim Aliff, MISO’s director of reliability planning, said “one size does not fit all for the interconnection queue process,” pointing out, for example, that each of the states in MISO has its own renewable portfolio, which requires flexibility with interconnection requests.

Developer Requests

Developers said more transparency would help them determine the viability of their projects before they apply.

“Better access to cases, both economic cases and the transmissions cases. Better understanding of assumptions, more accurate assumptions in cases. Pretty much any information that can help us make a better decision,” said Jennifer Ayers-Brasher, director of transmission and market analysis for E.ON Climate & Renewables NA. “We feel there should be more commonality across the board.”

They also requested a limit on the number of performance markers projects must meet to stay in the queue. “Introducing more milestones introduces more uncertainty,” Martino said. “Introducing more uncertainty introduces the likelihood of a cascading effect with the cost estimates and schedules because projects affect each other.”

Steven Naumann, Exelon’s vice president of transmission and NERC policy, took a holistic perspective on congestion, saying the entire process needs to be overhauled to forecast and address issues in advance. “There needs to be a serious look at how congestion is dealt with in the interconnection process up front. That is a coordination issue.”

He called for processes to handle risk-inclined developers who don’t want to pay for upgrades that aren’t mandatory even if it affects the reliability of the interconnection. “You’ve got to deal with this fundamental … disconnect between the ‘I will take my chances’ and the big energy market, which doesn’t recognize ‘I will take my chances.’ … This is not an incremental fix. This is something major that has to be set up upfront and done right and thought about how it’s going to be done.”

Balancing Accuracy and Speed

Tony-Dobbins, FERC - generators transmission operators spar interconnection processes ferc — Dobbins

Throughout the conference, developers pushed for both greater accuracy in estimates and faster delivery of results. MISO’s Aliff said the situation is a tradeoff: Transmission operators can’t provide the requested level of accuracy until later phases of the study, but they can’t start the studies earlier because they don’t know which projects will drop out. He said he wasn’t aware of any projects that withdrew because the process was taking too long.

At CAISO, it’s a two-phase process that takes two years, said Stephen Rutty, the ISO’s director of grid assets.

NextEra’s Gosselin said developers need to know about the overloaded transmission elements that need to be upgraded. “We have a saying in our world of development, which is ‘time kills all projects.’ The longer it takes, the more unlikely it is the project will be valid and go to fruition,” he said.

ISO-NE’s McBride said preparing construction estimates is a time-consuming process. “It takes weeks, if not months. [It] involves site surveys and getting bids from equipment suppliers and those kinds of endeavors.”

“One of the responsibilities as a transmission provider is to make sure we’re not passing on some of the costs to the connected generation, especially if it’s not required for load service,” Vail said.

At PJM, cost also plays into the timeliness of studies, explained David Egan, the RTO’s manager of interconnection projects. Egan said PJM found through its stakeholder process that generators preferred having upgrade costs “socialized” between all of the projects in the queue that caused it, not just leaving the last one to pay.

“The problem is that now you have to wait for the queue to close to be able to study everyone,” Egan said. “Where before, the smaller generators could have been moved along quicker … now you are bundled together. It is a clash of cost-sharing versus timeliness, at least on the smaller distributed generators.”

Connection Disputes

FERC staff asked about the prevalence of disputes between developers and transmission owners.

Kelly said the parties often work with the RTO, but he noted that there are dispute-resolution procedures available inside the interconnection processes.

Aliff said that MISO doesn’t see many disputes, but when they occur, the RTO plays an important role. “The fact that we don’t have a dog in the fight is a reason we should play a part,” he said. “We are making sure the reliability of the system is maintained. … If you start allowing individual interconnection customers to deviate from planning standards, you end up with a previous customer built to a level that a later customer did not build to … which could have a reliability impact down the road. Also, from an efficiency standpoint, building substations that have future ability to expand may be a cheaper alternative down the road for all other customers.”

That didn’t sit well with Gosselin, who described an incident in which NextEra and the transmission owner had different cost estimates because the owner expected the generator to prepare land for the owner’s potential future expansion. “There is a gap in expectations right there. … When we are building it, we are building it for us and only us and our future,” he said. “Ultimately, we resolved that piece of it fairly simply by saying we will option the rights for the land for them if want to expand in the future, and it’s their cost, not ours.”

Estimating Inconsistencies

Developers acknowledged that estimate overruns are rare but can be devastating when they happen.

“We have had several epic fails where the actual costs came in multiples of what the estimate was,” Gosselin said. “If we make a decision and that changes it significantly on subsequent restudies, we have either made a bad decision or we got lucky. Neither are good.”

“I have to say, they are rare, but they do happen,” Martino said. “On one particular occasion, we saw cost deviations of almost 100%.”

Energy Storage

In the final panel of the day, participants discussed energy storage.

“It’s a very creative market right now,” Rutty said. “Lots to look forward to.”

Transmission operators said they need a way to control how much power each resource is withdrawing to store or injecting into the grid. “What we would want is that they would install a power relay to limit the output,” Egan said. “The problem you have is, if you … exceed the thermal capabilities we’ve studied, you could cause damage.”

Developers urged regulators to look at storage differently and not try to wedge it into an existing group.

“Storage is very much its own asset class that touches just about every other asset class that hits the grid,” said John Fernandes, the director of policy and market development for RES Americas. “Let’s stop talking about storage as generation storage, storage as negative gen. I get it, but those are still dangerous semantics. … If we really want to be able to accommodate storage at a large scale five or 10 years from now, those rules need to start going into place now.”

May 16, 2016

CPP Panel Exposes Western Divide

By Robert Mullin

SANTA MONICA, Calif. — Dawn Wilson, director of environmental policy and affairs at Southern California Edison, said the company was disappointed with the Supreme Court’s stay of EPA’s Clean Power Plan in February.

Ray Williams, PGE - Clean Power Plan (CPP) - western divide — Williams © *RTO Insider*

“We are specifically engaged with a coalition of energy sector entities that are engaged in litigation in support of the plan,” she said during a panel discussion on the potential impact of the rule on California and the West at the Infocast California Energy Summit.

Ray Williams, director of long-term energy policy for Pacific Gas and Electric, said his company also supported the EPA plan.

“Basically, we say we’re a utility in the business of assembling a clean portfolio,” Williams said. “This is — from a business perspective — something that is doable.”

Travis Kavulla, NARUC Pres - Clean Power Plan (CPP) - western divide — Kavulla © *RTO Insider*

Travis Kavulla, vice chairman of the Montana Public Service Commission and president of the National Association of Regulatory Utility Commissioners, brought an inland West perspective to the discussion. Montana’s attorney general joined the lawsuit against the regulations, although the state’s governor and Department of Environmental Quality are preparing for implementation.

Kavulla contended that the Clean Power Plan differs from previous federal air quality regulations by going beyond the “fence line” of the power plant to impose requirements on entire states.

“You have a de facto renewables mandate for the entire nation,” Kavulla said.

Kavulla also pointed out the economic impact of the rule on his state and region.

“Montana, Wyoming and Utah have entire communities built around big central coal stations,” he said. “These are influential but also tied to livelihood. We’re looking to understand what the transition [away from coal] may look like.”

Dawn Wilson, SCE, Amber Mahone, E3, Shawn Elicegui, NV-Energy, Travis Kavulla, NARUC - Clean Power Plan (CPP) - western divide — Left to right: Wilson, Mahone, Shawn Elicegui of NV Energy and Kavulla © *RTO Insider*

Amber Mahone, director of climate policy analysis at Energy+Environmental Economics, pointed to the other forces working against coal, including regional haze rules and low natural gas prices.

“The writing is on the wall,” Mahone said. “It’s not a question of if — it’s when these plants retire.”

“We have to believe as a society that we won’t unabatedly burn coal,” she said.

May 16, 2016

SPP Forecast Report Focuses on ‘Big Events’

By Tom Kleckner

Boston Pacific’s 2016 “Looking Forward” report to SPP’s Board of Directors focuses on “big events.”

Dr. Roach presenting ©RTO Insider — Dr. Roach presenting © *RTO Insider*

“What’s surprising is the number of big events that have occurred here in just the past year,” said Boston Pacific founder and director Craig Roach, who presented the report to the board last month.

The firm’s sixth annual report for SPP focuses on “broad market and regulatory events” that could significantly impact its markets or require the board’s attention:

The shale gas “revolution”;
EPA policies;
Federal-state jurisdiction disputes;
Challenges to the utility business model;
Industry consolidation; and
Electric vehicles.

Shale Gas Risk Narrowed

Roach cited as one “big event” EPA’s June 2015 draft assessment, which found no evidence that fracking was having a “widespread, systemic impact on drinking water resources.”

The report represented a “significant narrowing of risk” for shale gas supplies, Roach said. “The question is whether that abundance will continue in the future.”

Assuming continued technological advances, Boston Pacific believes it will, noting U.S. Energy Information Administration forecasts that shale gas production in the continental U.S. will increase by 73% by 2040, accounting for 55% of total U.S. natural gas production.

Gas is important to SPP, Roach said, because gas-fired power often sets the price in the RTO’s energy markets and because the flexibility of combined cycle power plants complements intermittent wind and solar generation.

Boston Pacific categorized the risks facing gas supplies as “above-ground” (regulatory) and “underground” (extraction). In other words, Roach asked: “Is the gas there? Can it be recovered at a reasonable cost?”

EPA’s ‘Environmental Campaign’

A second big event, Roach said, was the Supreme Court’s February stay of the Clean Power Plan. The report refers to EPA’s “continued environmental campaign,” saying it has “pushed along multiple fronts to drive the electricity business to reduce a broad range of air pollution emissions and other environmental impacts.”

Boston Pacific said the high court’s stay gives SPP’s board, members and states an opportunity to “collaborate” on their views. “The SPP markets have been, and will continue to be, the path to cost-effective reductions in carbon dioxide emissions,” the report says.

State-Federal Jurisdiction

Roach also took note of the Supreme Court’s April ruling rejecting Maryland regulators’ attempt to subsidize a power plant. (See Supreme Court Rejects MD Subsidy for CPV Plant.)

Based on the court’s January ruling upholding FERC’s jurisdiction over demand response compensation, Roach said he expected the court to support the state’s contract-for-differences with Competitive Power Ventures’ combined cycle plant.

“If the Supreme Court took the same principles as it did in the [DR] ruling … it would have reversed the lower court and restored state rights,” he said. “The Supreme Court did nothing like that. It said, ‘We’re going to rule very narrowly.’”

The report says the Maryland decision could result in state programs being “pre-empted under similar reasoning.”

Distributed Resources

Boston Pacific Managing Director Vincent Musco said the company hasn’t changed its view on the impact of distributed energy resources on the utility business model. “Consistent with the past, we see no evidence” that DER will displace the grid and centralized generation, he said.

The report notes that residential rooftop solar is much more expensive than utility-scale solar. “If costs alone drove technology choice, utility-scale would win,” it said. “Notably, utilities have made considerable investments in utility-scale solar and wind resources and are projected to continue to do so.”

Transmission Costs

The report points to customer pushback over growing transmission costs, citing complaints challenging the earnings of SPP members American Electric Power and Westar Energy.

Calling for “substantial grid investment,” the report says the challenge will be allocating expansion projects in a manner “considered fair.”

Industry Consolidation

The one new topic added in this year’s report is industry consolidation, which it said is being driven by the search for “growth and increasing operational efficiency through scale.”

The report says the number of investor-owned utilities has dropped by 52% over the last two decades, from 100 in 1994 to 48 in 2014. Average market capitalization has increased from $9.4 billion in 2004 to $16.2 billion in 2014 (measured in 2014 dollars).

“If there are fewer competitors, that can impact the competitiveness of the market,” Musco said. “It can affect governance, with fewer people around the table and fewer and [weaker] voices.”

May 16, 2016

Utilities Seek OK for Gas Releases to Generators at Technical Conference

By William Opalka

Electric and gas utilities tried to convince FERC at a technical conference last week that targeted release of natural gas capacity to generators would alleviate supply constraints and help lower prices.

Other participants said the proposal is premature, ill-defined, discriminatory and interferes with the wholesale power market.

The May 9 conference was scheduled in response to Algonquin Gas Transmission’s petition asking FERC to allow exemptions from its capacity release bidding requirements (RP16-618).

The proposed changes to the company’s tariff would permit “prearranged releases” of firm capacity to utilities or generation owners. The company is one of the partners in the proposed Access Northeast pipeline that would expand capacity by 900,000 dekatherms per day into New England. (See FERC to Consider Electric Utility Purchases of Gas Pipeline Capacity.)

Electric distribution companies in Maine, New Hampshire, Massachusetts, Connecticut and Rhode Island have asked state regulators to approve cost recovery from their ratepayers for access to expanded pipelines.

Richard Kruse vice president, regulatory for Algonquin’s parent, Spectra Energy, told FERC the region is vulnerable to gas and electric price volatility.

“Every time this issue comes up, the rest of the country says ‘New England needs to get its act together,’” he said. The market has not solved the issue. “We have not seen generators sign up for pipeline capacity. We’ve held multiple open seasons and it has not materialized.”

Generators have commitments for about 80,000 dekatherms per day of firm capacity, but Kruse said that has dropped in recent years.

“We thought this would create a clear line of sight between the cost causation to the customer and the benefit [through lower electric rates],” said James Daly, vice president of energy supply for Eversource Energy, another partner in Access Northeast.

Algonquin said its waiver request is consistent with FERC policy exempting releases for state-regulated retail access programs from bidding requirements.

But critics said programs to benefit the electric distributors don’t yet exist.

“To a suspicious mind, any program that any state asserts would advance reliability would fall under the ambit of the program,” said former FERC Chairman Joseph Kelliher, now vice president for federal regulatory affairs at NextEra Energy. “Here the commission would be writing a blank check to the states that any program you stick the reliability label on would be permitted.”

Kruse said Algonquin would welcome guidance from the commission.

May 16, 2016

Federal Briefs

In a surprise move, the D.C. Circuit Court of Appeals on Monday decided to skip its scheduled three-judge hearing on the Clean Power Plan and proceed directly to en banc review, meaning a much larger roster of judges will review EPA’s regulations.

The Clean Power Plan, the centerpiece of the Obama administration’s efforts to combat climate change, was challenged by numerous states and stayed by the Supreme Court until its legality was resolved. The D.C. Circuit’s decision means that oral arguments will be postponed from June 2 to Sept. 27 and appeals would go directly to the Supreme Court, potentially speeding up the overall process. After a ruling by a three-judge panel, appeals are heard en banc before going to the Supreme Court.

The court’s decision appears to be sua sponte (on the court’s own initiative), as there is no record of any party to the case asking the court to hear the case en banc in the first instance.

More: The Washington Post; The Wall Street Journal

EIA Excludes CPP, Paris Agreement from Projections

The Energy Information Agency did not include the effects of the Clean Power Plan, the Paris climate agreement or any federal policy changes when it projected a 33.9% worldwide increase of CO₂ emissions between 2012 and 2040, even though nearly 200 countries have resolved to cut greenhouse gas emissions.

EIA Administrator Adam Sieminski said that the agency’s projections shouldn’t be considered actual predictions, saying it doesn’t “have a huge amount of confidence what those endpoint numbers are.” Changes are coming too fast to predict future energy use and technological advances, he said.

“We’re going to have the wrong economic numbers,” Sieminski said. “We’re not going to get the climate policies thing right. The technology — something is going to happen with batteries in the year 2030 that we didn’t expect, that we didn’t build into this. Something is going to happen in Iraq.”

More: Morning Consult

Yucca Mountain Opponents Question NRC Impact Statement

nevadaroberthalsteadsourcegov — Halstead

Native American tribes and officials from the Nevada Commission on Nuclear Projects are questioning the Nuclear Regulatory Commission’s environmental impact statement on the now-suspended Yucca Mountain underground repository project. The commission recently issued the environmental report, concluding that it would be safe to store spent fuel in the mountain.

While the commission determined that the release of radioactivity from a spent fuel dump there would be minimal, Nevada scientists believe it would violate the so-called 1 million-year standard after 2,000 years and contaminate groundwater used by the Timbisha Shoshone tribe.

Nevada’s Agency for Nuclear Projects Executive Director Robert Halstead said the NRC report is flawed because it is based on unverified computer calculations.

More: Las Vegas Review-Journal

Feds Label 2013 Texas Plant Explosion as Arson

Federal investigators have determined that the 2013 explosion at a Texas fertilizer plant was an act of arson. About 30 tons of ammonium nitrate exploded at the West Fertilizer Co. facility, killing 15 people, injuring 160 and laying waste to much of the town of West.

After ruling out other causes, investigators of the Bureau of Alcohol, Tobacco and Firearms determined the blast must have been intentionally set. “The only hypothesis that could not be eliminated is incendiary,” an ATF agent said. ATF did not say whether they had any suspects.

More: The Hill

TVA Files Application For Clinch River SMRs

The Tennessee Valley Authority has filed an early site permit application with the Nuclear Regulatory Commission to determine the potential to build and operate small modular nuclear reactors at its Clinch River site near Oak Ridge, Tenn.

It is the first time such a permit has been filed with the intention of building small modular reactors, which are seen as a way to keep down costs and provide “cookie-cutter” designs that could be used at many different sites.

“It’s a significant event for us as we continue exploring potential SMR technology as a way of expanding our diverse portfolio to ensure a safe, reliable supply of energy for those we serve,” TVA Chief Nuclear Officer Joe Grimes said. NRC will use the permit to examine the site’s safety, environmental conditions and emergency preparedness if TVA decides to go forward.

More: TVA

DOE Suspends Funding For Texas CCS Project

The Energy Department has pulled back from another carbon capture and storage project. The department stripped the $240 million it had pledged to the Texas Clean Energy Project and asked that the money be put toward other research and development projects.

Project developer Summit Texas Clean Energy was denied an $11 million advance earlier this year. A department audit also criticized the project’s shaky financing.

The Obama administration has invested $4.8 billion in six CCS storage projects. Four of those projects have been cancelled or suspended.

More: Inside Climate News

Power Generation Emissions Lowest Since 1993

Carbon emissions from U.S. electricity generation are at their lowest levels since 1993, according to the Energy Department.

The department attributes the decrease to the retirement of coal units, replaced by renewable energy and cleaner-burning natural gas.

Carbon emissions in 2015 totaled 1,925 million metric tons, the lowest since 1993 and down 21% from 2005 levels, the department said. It also noted that in the past 10 years, generation from coal dropped from 51% of the nation’s total to 34%. In the same 10 years, natural gas’ share rose from 18% to 32%. While nuclear remained steady at 20%, renewables rose from 8% to 13%.

More: FuelFix Blog

May 16, 2016

New York Demands Probe of Tree Cutting on Pipeline Route

By William Opalka

New York Attorney General Eric Schneiderman on Friday demanded that FERC investigate Constitution Pipeline for alleged tree cutting and other construction activities in defiance of a commission order (CP13-499).

Schneiderman successfully petitioned FERC in January to delay construction along the New York segment of the 124-mile route until state environmental officials had issued a water quality permit. That permit, required under Section 401 of the federal Clean Water Act, was denied last month. (See New York Environmental Department Rejects Constitution Pipeline.)

The pipeline is intended to bring shale gas from the Marcellus region of Pennsylvania into the New York and New England markets.

“My office has found compelling evidence that Constitution not only ignored widespread, unpermitted construction along its pipeline right-of-way corridor, but even authorized, encouraged or condoned it. Constitution also did not report this activity to FERC or to the state. FERC must take strong enforcement action against Constitution to ensure that pipeline companies know they can’t simply thumb their nose at laws that protect New York’s landowners, communities and environment,” Schneiderman said in a statement.

Schneiderman called for an investigation and an enforcement action by FERC for alleged violations of the Natural Gas Act that could subject the pipeline developers to fines of up to $1 million per day. He also asked for a stay of the FERC order from December 2014 that approved the pipeline.

In a two-month investigation, the attorney general’s office said it collected evidence of widespread clear-cutting, road building and heavy equipment use adjacent to state-protected streams and wetlands along the pipeline’s right of way in three counties. State environmental officials said the pipeline route includes about 250 stream crossings, dozens of which are critical to protecting trout.

Constitution spokesman Tom Droege denied the allegations in a statement and suggested landowners may have cut trees on their own.

“Constitution received the complaint late Friday and is undertaking a careful review of the allegations made by the New York attorney general. Constitution intends to vigorously defend its actions in connection with the project, as such actions were conducted within the bounds of applicable laws and regulations,” he wrote. “Constitution did not cut any trees in New York without permits, as FERC confirmed after it conducted an investigation of reports that trees were being cut. Constitution never advised nor encouraged landowners to cut trees on their properties. Landowners retain the right to use their properties after Constitution obtains easements, and Constitution only obtains the right to construct and operate its facilities.”

On Jan. 29, FERC delayed tree cutting in New York, but Schneiderman said the developer did not inform landowners of that fact. Instead, it told them the following day that it intended to begin construction in the spring, “leading some New York landowners to reasonably conclude that pipeline construction on the right of way in New York was imminent and prompting them to prematurely harvest timber within the right of way on their property in order to save the timber’s monetary value.”

Constitution is a partnership of Williams Partners and its co-developers, Cabot Oil & Gas, Piedmont Natural Gas and WGL Holdings. The developers have said they intend to file a legal challenge to the denial of the water quality permit.

May 16, 2016

SPP Asks for Clarification on MISO Settlement Order

By Tom Kleckner

SPP asked FERC last week to resolve a “Catch-22” situation facing the RTO regarding the handling of settlement revenue stemming from a dispute with MISO (ER16-791).

A March FERC order conditionally accepted SPP’s proposal to distribute to its members $16 million in funds reached in a settlement with MISO over the latter’s use of SPP’s transmission system to transfer power freely between its North and South regions. The order also set the docket for hearing and settlement procedures to resolve factual issues in dispute. (See “MISO Settlement Funds Held Up,” SPP RSC Briefs.)

SPP said it has begun distributing settlement revenue to members with its May invoices, but only to those members who signed on to the settlement agreement. At issue, the RTO says, is what to do with transmission-owning members not subject to FERC jurisdiction that have not agreed to a voluntary refund commitment as part of the commission’s final order on allocation.

The RTO asked FERC to confirm it can hold those members’ “allocated shares” until the hearing and settlement procedures end. It also requested the commission clarify SPP will not owe interest on any revenues not distributed to any non-jurisdictional TO that has not signed the refund commitment.

The clarification, it said, “will resolve the ‘Catch-22’ facing SPP, whereby SPP cannot … disburse funds to entities over which the commission cannot order refunds in the event of overpayment by SPP; yet, on the other hand, SPP lacks any explicit authority to hold funds on behalf of these entities.”

SPP said “many, but not all” of its impacted TOs have provided the requested voluntary refund commitment. The proceeding’s first settlement conference was held April 21, with a second scheduled June 16.

May 16, 2016

Integrated Resource Planning on the Horizon for Calif.

By Robert Mullin

SANTA MONICA, Calif. — Ed Randolph, energy division director at the California Public Utilities Commission, does not care if his state meets its 50% renewable mandate by 2030.

Ed Randolph, California PUC - integrated resource planning — Randolph © *RTO Insider*

That statement, delivered at the Infocast California Energy Summit last week, came with an important qualifier: “Let me be clear — we will meet the 50% RPS.”

The more pressing concern for the PUC, Randolph said, is reforming the agency’s long-term planning process (LTPP) to ensure California will meet its ambitious greenhouse gas reduction goals for 2050. In 2005, Gov. Arnold Schwarzenegger issued an executive order establishing the state’s objective to reduce 2050 GHG emissions to 80% below 1990 levels. Gov. Jerry Brown reinforced that measure through a 2015 order creating an interim target of a 40% reduction by 2030. [Editor’s Note: An earlier version of this article incorrectly reported that the 80% cut was the product of state legislation.]

The State Senate last year passed legislation to codify both standards, but the bill stalled in the State Assembly. Still, the state Air Resources Board intends to include both targets in an updated version of its GHG scoping plan, which defines the state’s climate change goals and lays the groundwork for achieving them.

The state’s load-serving entities — which include the three investor-owned utilities, electric service providers and community-choice aggregators — will play a key role in the effort.

The problem: The current LTPP, which emphasizes reliability, does not provide a blueprint for achieving GHG reductions.

Other state objectives further muddle the planning picture. Randolph pointed out that efforts aimed at improving energy efficiency and increasing the use of demand response rely on their own cost methodologies.

“I really don’t think we’re doing integrated resource planning yet,” said Randolph.

That will change in 2017 when the commission adopts a process requiring each of California’s LSEs to file an IRP that prioritizes emission reductions alongside other — more standard — requirements, such as resource diversity, reliability and cost-effectiveness.

Among the most fundamental steps to getting there: “We need to determine what the GHG metrics are going to be,” said Randolph, referring to the need to determine each LSE’s share of emissions reductions. “What’s the savings target?

“We know what it is for the economy,” he added, referring to the 80% target. “We need to know what it is for the energy sector.”

The IRP process will also require that the PUC produce its own long-term load forecasts, a capability the agency needs to develop. Randolph said the PUC has requested additional funding from the legislature to create an in-house modeling unit.

IRP implementation could follow one of a few approaches, according to Randolph.

Under a “CPUC-centric” IRP, the commission would set GHG targets for each of the LSEs and determine the resource portfolios that would meet them.

An “LSE-centric” approach would have the PUC establish reliability needs and GHG targets for the LSEs, while allowing them to develop their own resource mixes.

A third choice: a hybrid of the two.

With those options now on the table for next year, Randolph reminded attendees that — for now — it is still business as usual at his agency.

“Anyone who’s a fan of the CPUC’s current proceedings, they’re not going away quite yet,” he said.

May 16, 2016

SPP Sets Z2 Review Session for June 28-29

SPP will hold a two-day review session for the Attachment Z2 credit-settlement system June 28-29 at its Little Rock headquarters. The session will run 9 a.m. to 4:30 p.m. each day.

The review session was initially planned for late May, but conflicts with a number of stakeholder meetings pushed the date back.

The Z2 settlement system is being used to help resolve years of incorrect credits for transmission upgrades; the Board of Directors last month approved a payment plan that will begin in November. (See “Board Approves Z2 Level Payment Plan,” SPP Board of Directors Briefs.)

Staff said attendees will gain an understanding of how the settlement system was designed and built and how its calculations are performed.

SPP is asking attendees to complete the Z2 online course on SPP’s Learning Center, review a Z2 white paper and sign a nondisclosure agreement, which will be sent after registering for the review session.

– Tom Kleckner

May 16, 2016

Overheard at IPPNY Spring Conference

Albany, N.Y. — More than 120 people attended the Independent Power Producers of New York’s annual spring conference at the Desmond Hotel and Conference Center. Here are some highlights.

John Reese, Eastern Generation IPPNY Spring Conference — Reese © *RTO Insider*

John Reese, IPPNY chairman and senior vice president at Eastern Generation, mused about the conference’s theme, “Bolstering New York’s Energy Markets in a Changing Landscape.”

“The New York landscape changes so often it should be made of Play-Doh,” he said, noting that both the former state Senate majority leader and the former Assembly speaker were sentenced to prison this month on corruption charges.

In addition, a former aide to Gov. Andrew Cuomo is the subjects of a wide-ranging federal influence peddling probe that has ensnared both SolarCity and Competitive Power Ventures. “We have every major energy agency in the state under subpoena by the U.S. attorney: the New York Power Authority, NYSERDA [New York State Energy Research and Development Authority] and the Public Service Commission,” Reese said.

Sen. Joseph Griffo, chairman of the Senate Committee on Energy and Telecommunications, said the Senate will be considering “reset legislation” for the state’s energy service companies while monitoring PSC proceedings on the issue. (See Retailers Ask for Rehearing of NY Guaranteed Savings Order.)

“We’re looking at things designed to protect customers, to weed out some of the bad actors, establish a more robust, legitimate ESCO market,” Griffo said.

Assemblywoman Amy Paulin, chairman of the Assembly Committee on Energy, said she is backing legislation that would give electric vehicle owners discounted rates for charging their cars during off-peak times. She said she also supports a tax credit for farmers leasing land to solar developers and noted that a fuel cell sales tax exemption was included in the state budget.

Scott Weiner, NY PSC IPPNY - Spring Conference — Weiner © *RTO Insider*

Scott Weiner, deputy for markets and innovation at the New York Department of Public Service, said he initially thought the Supreme Court’s ruling last month rejecting Maryland regulators’ attempt to subsidize a combined cycle plant through a contract-for-differences was “very narrow.” (See Supreme Court Rejects MD Subsidy for CPV Plant.)

“Nothing in this opinion should be read to foreclose Maryland and other states from encouraging production of new or clean generation through measures ‘untethered to a generator’s wholesale market participation,’” the court said.

But after rereading the order, Weiner said, he changed his mind.

“There will be a lot of lawyers spending a lot of time defining ‘tethering,’” he said. “There’s a lot that the order didn’t say. That leaves white space for all of us to work our way through.”

New York Clean Energy Standard — Bay © *RTO Insider*

FERC Chairman Norman Bay gave his thoughts on continuing state-federal jurisdictional battles over the electric industry and calls for reregulation in states with retail choice.

“At FERC we clearly don’t have the authority to tell a state that it can’t be vertically integrated. We don’t have the authority to tell a state that, if it chooses to do so, that it can’t reregulate,” he said. “The case to be made for a market-based approach to further important public policies has to be made. And I think that case is being made in RTOs and ISOs across the country.”