MISO Planning Advisory Committee Briefs

Aiming to prevent claims of preferential treatment under its new competitive transmission process, MISO last week released a formal protocol prohibiting bidders from contacting any MISO staff member directly about requests for proposals.

The rules were released as MISO prepares to receive bids on its first competitive transmission project, the Duff-Coleman 345-kV upgrade. (See MISO Seeks Bids on Duff-Coleman Project.)

Brian Pedersen, MISO’s senior manager of competitive transmission services, said the RTO created a new email address (TDQS@misoenergy.org) so transmission developer applicants wouldn’t contact any MISO staffer.

miso

“We’re moving from a workshop environment to a competitive bid environment … and we want to make sure people know how to communicate appropriately,” Pedersen said. “Once we receive proposals, MISO will only respond to procedural questions. … We’re not going to respond to any substantive questions about the [evaluation] and where we’re at in it.”

MISO said it will publicly post a list of received questions and its responses on the MISO competitive transmission webpage.

Meanwhile, stakeholders will continue working into spring on changes to Business Practice Manual 27 to align it with Tariff changes approved by FERC in November regarding the qualification and selection of competitive developers and the pro forma developer’s agreement (ER15-2657, ER15–2658). Redline changes will be discussed at the March and April Planning Advisory Committee meetings. MISO hopes to make the changes effective by May 1.

BPM Changes Completed for Expedited Project Review

MISO presented stakeholders with BPM changes to replace the out-of-cycle review process with the new expedited review procedure.

MISO will now post all valid expedited requests within two weeks of receipt and notify stakeholders of such requests.

The final BPM language concludes almost a year of discussion on the topic, after stakeholders raised objections to Entergy’s Lake Charles transmission upgrades last February. Some critics questioned whether Entergy was seeking to circumvent the competitive bidding process. (See MISO Seeks Stakeholder Input on Out-of-Cycle Process amid Entergy Controversy.)

“We’ve not had an expedited review of the expedited project review,” joked Matt Tackett, a principal adviser for MISO, during a presentation of the final BPM language.

Sean Brady, Wind on the Wires’ regional policy manager, thanked Tackett for not “rushing” stakeholders through the review process. “I really appreciate that,” he said.

MISO said it would not solicit any further input on the BPM language but would delay posting it until the PAC decides whether to endorse it at its February meeting.

MISO Planning Confidentiality, Notification Changes to Attachment Y Procedure

MISO will require more notification and relax some confidentiality rules concerning generator suspensions and retirements and system support resources planning under Tariff changes outlined to the PAC.

The proposed changes would affect the Attachment Y process, which ensures MISO has time to identify transmission needs resulting from the loss of a generator.

The changes would subject black start units and pseudo-tied generators to Attachment Y requirements that units intending to retire or suspend operations provide at least 26 weeks’ notice.

In addition, information made public by a generator owner will no longer be considered private, and information won’t be confidential after a retirement date has passed.

Some public interest organizations said MISO should make Attachment Y notices public upon their filing, as in PJM. MISO said a 2012 FERC order directed the RTO to keep Attachment Y notices and study results confidential for units that do not qualify as an SSR (ER12-2302).

MISO may also require a new Attachment Y notice 26 weeks prior to the change in status of a SSR unit wishing to retire or alter its agreement, MISO’s Neil Shah said.

Several market participants said that the current 36-month cumulative time limit on generator suspension in a five-year period and the 26-week notice requirement would need to be adjusted under MISO’s proposed switch to a four-month summer and an eight-month winter capacity construct. Shah said that suggestion will be considered only once capacity market changes are finalized.

Generation owners would have to file directly with FERC to determine how much they will be compensated for fixed costs under an SSR and complete either an OASIS posting or a FERC filing to terminate interconnection rights. Suspended generators unable to return to service at the end of suspension period will be considered retired and have their interconnection rights terminated.

Shah said MISO’s decision to change the process is based on experience gained since 2012. Tariff changes will be filed by Feb. 26; MISO is requesting an effective date of May 1.

Work on MTEP17 Futures to Continue Through September

Work on changes to the Transmission Expansion Plan futures process will last through the first three quarters of 2016, Matt Ellis from MISO’s policy studies unit told the PAC. “This is really more a teaser for what’s to come in 2016,” Ellis said of his presentation.

MISO said the new futures process, set to take effect beginning with MTEP17, will use familiar procedures. As with previous MTEPs, final decisions will be made during PAC meetings, while technical details will be hashed out in workshops.

miso

MISO plans to review its resource siting methodology for use in PROMOD models beginning in March and finalize it in July. (See “CPP to Play Role in Reworked Futures Development,” MISO Planning Advisory Committee Briefs.) “We’ve had basically the same siting information for years, so we’ve worked time into the process for re-siting,” Ellis said.

The RTO said it wants to employ a scenario-based analysis with the possibility for many outcomes rather than the least-cost plan under a single scenario. “The scenarios should simulate likely or plausible real-life future system conditions and provide an envelope of outcomes that is significantly broad, rather than a single expected forecast,” MISO wrote.

MISO is hoping to review draft results of the new futures process by the August PAC. “We want to wrap up the whole MTEP17 futures planning process by September,” Ellis said.

Ellis is asking for feedback by Feb. 10 on MISO’s proposed timeline, which he says is subject to change.

— Amanda Durish Cook

January 26, 2016

FERC Outlines Principles for Clean Power Plan Analyses

By Rich Heidorn Jr.

FERC staff last week released a white paper identifying what it called “four guiding principles” that may help RTOs and other transmission planning entities analyze compliance with EPA’s Clean Power Plan.

Although the commission has no direct role in CPP compliance, it may be called on to evaluate the impacts of plant retirements and other responses on reliability.

Staff said modeling of the CPP should address: transparency and stakeholder engagement; study methodology and interactions between studies; study inputs, sensitivities and probabilistic analysis; and tools and techniques. The white paper borrows from a 2015 report by M.J. Bradley & Associates cited by EPA.

clean power plan — Alliant Energy’s coal-burning Edgewater Generating Station (Source: Alliant Energy)

“Incorporating these guiding principles in the modeling of the CPP compliance plans is one way to promote a robust analysis of the reliability impacts of the CPP,” the commission said, adding that it may conduct additional technical conferences on the rule. (See MISO, SPP Stakeholders Developing Trading Plan to Comply with EPA Carbon Rule.)

“State-by-state variations in compliance approaches may add additional uncertainty and complexity, particularly for transmission planning entities that cover multiple states or states with multiple transmission planning entities,” FERC said. “Further, the use of inconsistent models, or inconsistent modeling inputs, may suggest reliability problems where none exist, or may mask problems that do exist. If models and modeling inputs are not transparent, it will be difficult for stakeholders, state commissions, planning authorities or the commission to identify, understand or address potential problems.”

FERC said the impacts of CPP compliance plans can be evaluated through a combination of studies, including resource adequacy, production cost, integrated gas-electric systems simulations and power flow and transient stability analyses.

“Incorporating the results of one study into a subsequent study can result in a more robust analysis,” the white paper says. “For example, the results of a resource adequacy analysis can be used to define the assumptions for the composition of the generation fleet used in a production cost or natural gas infrastructure study. This iterative process can lead to more robust results than using static assumptions.”

It also called for use of new tools to measure the impact of increased renewable and natural gas generation.

January 26, 2016

New England Generators Appeal FERC Capacity Market Orders

The New England Power Generators Association last week asked a federal appeals court to review three FERC orders related to the operation of ISO-NE’s Forward Capacity Market.

FERC in November denied rehearing of complaints made concerning orders related to ISO-NE’s Pay-for-Performance program and the peak energy rent adjustment.

The appeals were filed in the D.C. Circuit Court of Appeals (16-1023, 16-1024).

The first order directed ISO-NE to adopt a modified version of its proposed market design (ER14-1050, EL14-52-001). FERC also denied rehearing on a compliance filing (EL14-52-002).

FERC also denied rehearing of a NEPGA complaint that alleged that the interaction between the penalty factor and ISO-NE’s peak energy rent mechanism is unjust and unreasonable (EL15-25). (See FERC Denies Rehearings on ISO-NE Pay-for-Performance.)

— William Opalka

January 26, 2016

Federal Briefs

The 3rd Annual Grid Modernization Index, a ranking of the progress of states and D.C. toward developing a modernized electric grid, once again scores California on top, followed by Illinois, Texas, Maryland and Delaware.

The rankings by the GridWise Alliance advocacy group are based on survey data from June through October 2015 that tracks grid modernization policies, investment levels and activities.

“Electricity lies at the heart of our economy, and it must evolve to serve the needs of an increasingly low-carbon, always-on, digital economy,” said Steve Hauser, CEO of the GridWise Alliance. “We are pleased to see continued progress across the country this year, but the survey shows that we are just getting started.”

More: GridWise Alliance

Scientists Declare 2015 as Hottest on Record

Scientists said that 2015 was the world’s hottest year on record, breaking 2014’s record, and it was the second-warmest on record for the lower 48 states.

“The globally averaged temperature over land and ocean surfaces for 2015 was the highest among all years since record keeping began in 1880,” said the National Oceanic and Atmospheric Administration’s National Centers for Environmental Information. “During the final month, the December combined global land and ocean average surface temperature was the highest on record for any month in the 136-year record.”

The globally averaged land surface temperature was 2.39 F above the 20th century average, the NOAA report said.

More: The New York Times

EIA Predicts Short-Term Increase in Renewables

The Energy Information Administration said it expects renewable energy sources to increase by about 9.5% in the U.S. in 2016 but said it doesn’t expect much of a boost in subsequent years because of the recently extended energy tax credits.

EIA said that “most plants that will enter service in 2016 are already being developed. Impacts in 2017 depend on how many wind and solar projects are already in the development queue but not yet under construction.”

The report also anticipates a 4.6% increase in hydro generation this year because of increased rainfall, particularly in the Pacific Northwest.

More: Energy Information Administration

Obama Administration Moves to Stop Methane Leaks

The Department of the Interior on Friday unveiled regulations that will mandate that energy companies reduce methane leaks at wells drilled on federal or Native American land. It is yet another attempt by the Obama administration to take steps to combat climate change.

The leaking or venting of methane from federal or Native American land released about 375 billion cubic feet of methane into the atmosphere between 2009 and 2014, according to the government. The new regulations would impact more than 100,000 oil wells that currently produce about 10% of the country’s natural gas.

The oil and gas industry oppose the regulations, which would put new limits on venting and flaring excess natural gas, a practice used to reduce pressure on oil wellheads. The regulations will also call for more frequent inspections to check for leaks. The regulations represent the first major update of such controls in 30 years.

More: The Washington Post

Duke CEO Good Says CPP Will Shift Focus to Nuclear

Duke Energy CEO Lynn Good said the federal Clean Power Plan, with its stringent emissions regulations, is going to force many of the nation’s coal-fired plants to close. Good said she thinks the CPP and carbon limits will eventually shift the spotlight to nuclear energy.

Speaking at the CEO Series of the World Affairs Council of Charlotte, in North Carolina, Good noted that there is a resurgence in nuclear power in China, where 25 reactors are under construction. Five are under construction in the U.S. Most new American power plants use cheap natural gas, which reduces carbon emissions compared to coal, but doesn’t completely eliminate greenhouse gases as nuclear power does.

“I hope nuclear becomes a part of the conversation, at the right time when we recognize the importance of that resource,” she said. “I hope we can work that out as a country and figure out how we are going to put nuclear in the mix.”

More: Charlotte Business Journal

Trans-Peco Pipeline Earns OK in FERC Environmental Study

A FERC environmental assessment has determined that Energy Transfer Partners’ Trans-Peco pipeline, which would deliver natural gas from Texas to Mexico, would have no detrimental effect on the environment.

The natural gas exported to northern Mexico would replace coal as a power plant fuel, but opponents vow they will continue to fight the project. Other state and federal permits are still needed before it can go forward.

“At a personal level, I am outraged over the FERC’s decision,” said Coyne Gibson, a leader in the opposition movement. “At best, this represents a complete and total failure of a federal regulatory agency’s oversight responsibility under the law.”

More: Big Bend Now

FERC Approves 4 Hydro Projects Along Yazoo Basin

FERC has approved licenses for four projects to be built at flood control facilities along the Yazoo River Basin in Mississippi, according to the projects’ developer, FFP New Hydro.

The company, which is a subsidiary of US Renewables Group, said it expects to begin construction in 2017 and have all four units go into operation in 2018. The four facilities would have a capacity of 33.3 MW. They would all be located at dams owned and operated by the U.S. Army Corps of Engineers.

“The development of the Yazoo River Basin hydropower projects will represent an investment of more than $80 million in the state of Mississippi, creating hundreds of jobs during construction, operations and maintenance,” said FFP New Hydro CEO Ramya Swaminathan.

More: Hydroworld

Six Missouri River Dams Yield Tepid Energy Production in 2015

The U.S. Army Corps of Engineers is reporting that electricity generation from the Missouri River’s six dams in the Dakotas, Montana and Nebraska fell below average in 2015. The cause is attributed to a reduced water flow because water is being retained in upstream reservoirs.

According to the corps, the six dams produced 8.5 billion kWh last year, compared to 9.6 billion kWh in 2014. Since 1967, the dams have generated an average 9.3 billion kWh annually. Mike Swenson, a corps engineer in Omaha, said 9.6 billion kWh of electricity production is expected from the dams in 2016 based upon rainwater runoff estimates.

More: The Republic

January 26, 2016

MISO: Mass-Based CPP Plan 1/3 Cost of Rate-Based

By Amanda Durish Cook

CARMEL, Ind. — Mass-based compliance with the Clean Power Plan would cost less than one-third as much as a rate-based method by 2030, according to modeling by MISO.

MISO found that the price disparity between rate-based compliance, which limits emissions in tons per megawatt-hour, and mass-based compliance, which caps emissions in tons per year, increases over time due to the mass-based method’s increased flexibility under emissions trading.

By 2030, production-based compliance costs are expected to reach about $17 billion under a rate-based plan, while mass-based compliance is estimated at about $5 billion, according to the near-term analysis presented at Wednesday’s Planning Advisory Committee meeting. This includes the expense of generation, interchange and emissions, excluding additional transmission and pipeline infrastructure, and other capital costs.

MISO has said that individual states won’t shoulder the burden equally.

MISO Will be Compliant in First Years

Jordan Bakke, policy studies lead at MISO, said rate-based compliance is centered around adding zero-emission resources while mass-based compliance requires also removing emission-heavy generation. Early compliance targets are slated to be met through MISO states’ existing renewable portfolio standards and natural gas’s replacement of coal generation, but additional changes will be needed to continue compliance.

“The planning that has already occurred will only get us so far,” Bakke said. Compliance costs would rise significantly in the “mid- to late 2020s,” he said, after MISO’s existing generation mix fails to carry it through increasingly stringent emissions goals.

The threats to MISO’s coal fleet are less severe in a regional mass-based approach. The analysis forecasts six coal units to be idled by 2030 under mass-based plans, versus nine under rate-based compliance.

With either option, the grid operator said it would need new zero-emission resources to temper the price of CO₂, which is expected to rise from about $20/short ton in 2022 to about $40/short ton by 2030 under mass-based compliance and almost $140/short ton under a rate-based regime.

“Coal unit capacity factors decrease greatly over time under the CPP, more dramatically with a rate-based implementation,” MISO wrote. On the other hand, MISO has suggested that mass-based compliance might require less capital investment because system dispatch won’t have to undergo as many changes. The RTO said the low capacity factors, even using a business-as-usual measurement, show coal units won’t be economically viable by 2022 or 2030.

66 Cases Modeled

Bakke said that the near-term modeling ran 66 cases with differing changes in capacity and either mass- or rate-based compliance: three business-as-usual scenarios in the years 2022, 2025 and 2030; 39 instances of business-as-usual resources but with CPP constraints applied; and 24 runs using alternative resource scenarios combined with CPP constraints. The three business-as-usual cases, which rely heavily on coal generation, would not meet emissions targets, while both categories that use CPP constraints would.

The study assumes a liquid carbon emissions market and that all states choose either mass- or rate-based plans. Bakke said further modeling will be needed if states decide to use a mix of rate-based and mass-based trading.

MISO said it assumed a $4.67/MMBtu natural gas price for 2015. In addition to modeling using its existing generation fleet, the RTO also is including units with signed generation interconnection agreements and projects approved under the 2015 Transmission Expansion Plan.

MISO Wants Reliability Provisions in State Plans

Meanwhile, Kari Bennett, MISO’s senior corporate counsel, said MISO’s comments to the EPA on the federal implementation plan (FIP) will focus on reliability.

In its comments, MISO said it would like EPA to authorize the use of a reliability safety valve in FIPs, similar to that in state implementation plans. MISO said EPA should allow a “meaningful, case-specific review of reliability that is comparable to the state plan requirement.” (See related story, FERC Outlines Principles for Clean Power Plan Analyses.)

Bennett said the comments do not get into the mechanics of how a safety valve would be developed or used.

“As we look at the situation, reliability is often case-specific and a sensitive issue,” she said. “We do think it is prudent for the EPA to include a reliability safety plan in the federal plan as well as state plans.”

January 26, 2016

FERC OKs MISO-SPP Transmission Settlement

By Amanda Durish Cook

FERC on Thursday approved MISO and SPP’s uncontested settlement agreement with a trio of orders governing how MISO transfers power between its North and South regions using SPP transmission.

FERC determined the settlement was “fair and reasonable and in the public interest” (ER14-1174, et al). The commission upheld a Jan. 5 settlement judge’s certification that the agreement was uncontested.

The RTOs agreed in October to the terms of the seven-year settlement, which stipulates north-to-south flows be capped at 3,000 MW and south to north be limited to 2,500 MW. (See SPP, MISO Reach Deal to End Transmission Dispute.) MISO and SPP have 45 days to file Tariff changes with FERC.

Two other orders dismissed all rehearing requests relating to issues prior to the settlement and approved the cancellation of SPP’s hurdle rate mechanism.

Clark Urges Caution

Commissioner Tony Clark wrote a concurring statement, saying the order “leaves the door open as to how the commission would analyze the settlement in the event a challenge is brought.”

Clark said the settlement puts new conditions on MISO’s transmission service because of the transfer limits established between MISO Midwest and MISO South.

“Because these terms could impact more than just the settling parties, including future MISO market participants, I do not think it is appropriate to extend the heightened Mobile-Sierra standard to those third parties or the commission acting [without formal prompting from another party]. Consistent with my prior statements, if we are to preserve the integrity of the Mobile-Sierra standard, we should be judicious in its application.”

The Mobile-Sierra doctrine, named after a pair of Supreme Court rulings, holds that negotiated contracts are presumed to be just and reasonable unless it “seriously harms the public interest” or the parties to the contract agree that the standard should not apply.

MISO, SPP Looking Forward

Jennifer Curran, MISO’s vice president of system planning and seams administration, said MISO was pleased with FERC’s approval. “With this issue behind us, we look forward to continued collaboration across our seams for the benefit of all our customers.”

SPP is “pleased to have the issue resolved,” said David Avery, SPP’s director of corporate communications.

As a result of the settlement, FERC moved to eliminate the $9.57/MWh hurdle rate on flows exceeding the 1,000-MW transfer limit per SPP and MISO’s joint operating agreement (ER16-56). MISO’s proposed Tariff revisions to replace the hurdle rate with a mutual compensation system will become effective Feb. 1.

“As explained by MISO, the substitution of the SPP service agreement with a payment structure for SPP’s and joint parties’ available system capacity obviates any need for the hurdle rate,” FERC said.

However, MISO’s proposed revisions to the commission failed to delete a few mentions of the SPP service agreement, as pointed out by MISO stakeholders. FERC directed MISO to remove the phrase and make a compliance filing in 30 days.

FERC also dismissed as moot requests for rehearing from MISO, MISO transmission owners and Entergy over now obsolete matters in the RTOs’ joint operating agreement (ER14-1174-001, et al).

Having made a one-time, $16 million payment to SPP to fund surplus flow charges over the past two years, MISO is continuing cost allocation talks (ER14-1736).

Beginning next month and continuing until February 2017, MISO will pay SPP $1.33 million per month to cover flows over the 1,000-MW contract path that cross MISO’s North-South interface, but MISO hasn’t yet determined a final cost allocation mechanism that would govern how the cost is split among MISO’s generation owners. (See “MISO to Begin SPP Settlement with $16 Million Payment,” MISO Market Subcommittee Briefs.)

January 26, 2016April 22, 2024

State Briefs

PSC Considering Entergy’s $133M Rate Increase

The Public Service Commission is considering a proposed settlement that would increase Entergy Arkansas rates by more than 8%.

The commissioners will vote in February on a settlement that would give Entergy an increase of $133.6 million, 20% less than the $167 million increase the utility originally sought. The settlement was reached between the utility and several entities, including the attorney general’s office and Entergy’s major commercial customers.

Entergy said the increase is needed because of improvements to its electrical infrastructure and its $237 million purchase of an interest in a gas-fired generation plant. The settlement would allow Entergy a 9.75% return on equity.

More: Arkansas Democrat-Gazette

CONNECTICUT

Rooftop Solar Program Praised by Governor

Gov. Dannel Malloy showed up as a booster for a public-private partnership that brings solar panels and lower electricity bills to the state’s residents. The Solar for All initiative links residents with PosiGen Solar and Energy Efficiency, a solar system installation company.

The company offers solar panel installation under a 20-year agreement at an introductory price of $20/month for the first year if more than 50 households sign up. After the first year, the basic charge goes up to $79/month for a 6-kW system. The program is subsidized by a $5 million investment by the state’s Green Bank program as part of a way to lower greenhouse gas emissions in the state.

More: New Haven Register; PosiGen

INDIANA

Wind Turbine Shrinks School District’s Power Bill

The Shenandoah School District reported it had a zero balance on its December electricity bill, thanks to a wind turbine it installed two years ago.

According to school officials, the 900-kW turbine is intended to supply 85% of the power used by the elementary, middle and high schools. District Business Manager Julia Miller said the district pays between $105,000 and $112,000 annually for electricity, about half its bill before the turbine went into service.

Shenandoah School District used government bonds to finance the $2.6 million turbine, which is expected to pay for itself within 10 years.

More: News-Sentinel

KANSAS

Legislators Blast $20M Deal for Capitol Grounds’ Power Plant

Legislators are upset Gov. Sam Brownback’s administration signed a $20 million lease-purchase for construction of a new state power plant in Topeka that they say sidesteps legislative oversight.

Members of the House and Senate expressed frustration with the 15-year contract executed Dec. 29 because the total cost was millions of dollars higher than previously disclosed, the first payment wasn’t included in Brownback’s budget and the arrangement had not been approved by the state’s joint building committee.

In October, the Department of Administration said the heating and cooling plant to be located one block north of the Capitol would cost about $12 million. The previous estimate shared with legislators monitoring state building projects was $9 million.

More: The Topeka Capital-Journal

Bill Killing Tx Authority Criticized by Wind Advocates

A bill that would terminate the funding for the Electric Transmission Authority, which was formed a decade ago because it was thought utilities were not developing sufficient transmission lines, is being seen as a threat to future wind projects in the state.

Sen. Robert Olson, chairman of the Senate Utilities Commission, said transmission planning is now largely done by SPP and the transmission authority is unnecessary. But wind energy advocates say the state-centric transmission authority stimulated the growth of wind energy by developing a robust transmission system in Kansas.

More: Midwest Energy News

MICHIGAN

PSC Launches Investigation into Consumers’ Estimates

The Public Service Commission is investigating the way Consumers Energy estimates bills after about 300 customers last year complained about inaccurate bill estimates. The commission has asked the company to file a report by Feb. 18 detailing its staffing levels and its communications process with customers on billing estimates, along with an accounting of the number of bills that were underestimated or overestimated.

“One of the issues that has come up in our meetings is the algorithm the software uses in calculating and estimating what a bill would be,” said Judy Palnau, a PSC spokesperson. “Is it possible the algorithm needs adjusting?”

A company spokesman said it estimates bills when it is unable to read a customer’s meter.

More: Mlive

MISSOURI

Ameren to Help Noranda Smelter, Asks for Regulation Changes

Ameren Missouri said it is working with lawmakers to change utility regulations to help Noranda Aluminum, a smelter that buys 10% of the utility’s power. The smelter has threatened to shut down if it cannot reduce its energy costs.

The St. Louis utility wants regulations modeled on those in neighboring Illinois, where “near-automatic” annual rate increases are offered in return for more grid investment. The change would reduce the Public Service Commission’s authority in utilities’ rate structure and rate adjustments.

Noranda has said it will lay off almost 500 of the 850 smelter workers by February and will wind down operations by March 12 unless it can “secure a substantially more sustainable power rate for the smelter,” according to the St. Louis Post-Dispatch. The announcement was prompted by a power outage that shut down two of the smelter’s three aluminum production lines.

More: St. Louis Post-Dispatch

MONTANA

CPP Rules Threaten Coal Plant, Economy Officials Say

Shutting down one or more units at Colstrip’s 40-year-old coal-fired power plant complex would devastate the state’s economy through possible job losses and higher power bills, state elected officials and industry backers said Jan. 18 in Billings.

The discussion centered on concerns that EPA’s proposed Clean Power Plan, which calls for the state to reduce its carbon emissions by 47%, will have an adverse impact on Colstrip, where four power units produce 2,094 MW and employ about 350 workers. The plants are the state’s biggest producers of greenhouse gases.

The Colstrip plant has six owners: NorthWestern Energy, Talen Energy, Portland General Electric, Puget Sound Energy, Avista and PacifiCorp. The latter four market power in Washington and Oregon, where legislators are proposing new laws this year to cut cross-state purchases of coal power.

More: Billings Gazette

NEBRASKA

Local Utilities Rejecting NPPD’s 20-Year Wholesale Contracts

A dozen towns and one regional power provider have spurned Nebraska Public Power District’s demands for 20-year wholesale electric contracts.

NPPD’s current 20-year contracts expire at the end of 2021, but the utility asked its customers to commit to new contracts now to protect its bond rating. NPPD has inked new contracts with 62 of its 75 wholesale customers, which include rural public power districts and municipal buyers that made up 92% of the district’s revenue in 2014.

But some wholesale customers have opted to shop around SPP for competitive suppliers. For most of NPPD’s wholesale customers, this is the first contract negotiation in which it has been feasible to look for alternative suppliers in the RTO’s broader market.

More: Lincoln Journal Star

NEW HAMPSHIRE

Jury Slams ENH Power for Stealing Customer Info

A Superior Court jury ordered the parent company of the state’s largest competitive supplier of electricity, ENH Power, to pay more than $500,000 in damages to a smaller competitor for stealing confidential customer lists, sales leads and other proprietary information.

The Rockingham County jury found that ENH officials convinced an employee of Freedom Companies to steal the information and give it to them. An attorney for ENH vowed to appeal.

More: New Hampshire Union Leader

Anti-Pipeline Bills Reviewed by Lawmakers

Two bills introduced to impede efforts to build a natural gas pipeline through the state came under review by lawmakers, but some legislators questioned whether they have the ability to regulate interstate projects, which typically come under federal jurisdiction.

The legislation was introduced in response to Kinder Morgan’s plan to build the $5 billion Northeast Energy Direct pipeline to deliver shale gas from Pennsylvania through Massachusetts and part of New Hampshire. One bill would levy a tax on gas transported through the state, and the second would prohibit passing any of the construction charges to state residents.

Kinder Morgan has vowed to oppose the legislation. “We believe that at a time when New Hampshire residents are paying among the highest energy rates in the country, that it would be inappropriate to potentially increase those costs through a new tax,” said spokeswoman Susan Geiger.

More: New Hampshire Union Leader

NEW JERSEY

Environmental Group Fights Proposed Power Plant

The Sierra Club is protesting a Massachusetts company’s proposal to build a natural gas-fired power plant on 423 acres in Hillsborough.

Jeff Tittel of the Sierra Club said the site is environmentally sensitive because of its proximity to the Delaware and Raritan Canal and it contains wetlands.

Genesis Power’s $1 billion Amwell Energy Center would generate enough electricity to power 700,000 homes.

More: myCentralJersey.com

NEW MEXICO

Town Gets Solar Farm, New Wholesale Power Contract

Guzman Energy has struck a seven-year agreement with the city of Aztec that supplies the city with power at a substantial savings from the current municipal supplier.

Guzman agreed to build a 1-MW solar farm that will generate about 8% of the city’s electricity and supply the remainder of the power from Guzman’s other assets. The new contract sets the price at 5 cents/kWh.

The agreement will replace Aztec’s expiring 10-year deal with Public Service Company of New Mexico that started out at 7.5 cents/kWh and included yearly increases based on natural gas futures, the city said. Those yearly increases mean the city is actually paying PNM closer to 8 cents/kWh.

More: The Daily Times

NEW YORK

NYC Launches Pilot to Switch Food Trucks to Solar

New York City has started a pilot program to convince mobile food vendors to switch to clean energy by subsidizing food carts that are equipped with solar panels and battery storage systems.

MOVE Systems, a New York firm that has developed carts with solar panels on their roofs, hopes the PV carts would reduce vendors’ energy costs by 20%, and could also cut greenhouse gas emissions from the city’s estimated 8,000 food trucks and carts by 60%. The carts would also have backup propane generators.

Most of the vendors now use propane or diesel generators.

More: International Business Times

NORTH DAKOTA

PSC Sets Hearing for Wind Farm, Tx Project

The Public Service Commission scheduled a public hearing for March to consider a proposed wind energy project and transmission line in Stark County.

Brady Wind, a subsidiary of NextEra Energy Resources, proposes to erect as many as 87 wind turbines to generate 150 MW of electricity at an estimated cost of $235 million. The company is also looking to build a 19-mile 230-kV transmission line from the project.

It’s the second attempt for NextEra to build a wind farm in the area. The Stark County Commission in May rejected a conditional use permit for a project of similar size, which was planned for a 61-square-mile area in eastern Stark County between Gladstone and Richardton.

More: The Bismarck Tribune

OKLAHOMA

PSO Enacts Interim Rate Increase While it Awaits Ruling

Public Service Company of Oklahoma said it will put an interim electric rate increase into effect that will generate $75 million while it awaits a final decision from the Corporation Commission on its formal $169 million rate-increase request.

Under state law, utilities are allowed to implement interim rates if they don’t get a final decision from the commission within six months. The interim rates are subject to refund if the commission doesn’t grant PSO’s full request.

The utility said that customers will actually pay less under the new rate structure because the higher rates are more than offset by lower electricity costs attributed to cheap natural gas prices. PSO said a typical residential customer using about 1,100 kW of electricity a month should see bills fall by $2.44.

More: The Oklahoman

PENNSYLVANIA

UGI Utilities Requesting Distribution Rate Increase

UGI Utilities is asking for a distribution rate increase now that a settlement with the Public Utilities Commission barring it from doing so has expired.

After a 2011 gas explosion killed five people in Allentown, the company agreed to expedite its replacement of old natural gas distribution lines, improve leak detection and pay a $500,000 civil penalty. The settlement also prohibited UGI from imposing a distribution system improvement charge for two years.

Filing for a base rate increase is a prerequisite to adding a system-improvement charge. The requested hike would raise an average residential customer’s bill by about 19.7% and a commercial consumer’s bill by about 7.4%.

More: The Morning Call

State Orders Crackdown on Methane Emissions

Gov. Tom Wolf announced a state-directed crackdown on methane emissions from shale gas wells and pipelines last week, in an attempt to address the problem of releases of the gas that had so far been unregulated. The four-part plan will involve a new permitting process for shale gas wells, a new permitting process for pipeline compressor stations and gas processing facilities, leak limits at existing gas and oil facilities, and establishment of best practices to address leaks.

Methane has 84 times the heat-trapping capabilities of carbon dioxide, another greenhouse gas that gets more attention.

“These regulations will improve our air, address the urgent crisis of climate change and help businesses reclaim product that is now wasted,” Wolf said. “The best companies understand the business case for reducing methane leaks. Methane that doesn’t leak into the atmosphere can be used for energy production.”

More: Pittsburgh Post-Gazette

VIRGINIA

Draining of Dominion Coal Ash Ponds Months Away

Dominion Resources says it needs to complete design work before it begins to drain two coal ash ponds into the Potomac and James rivers.

The State Water Control Board granted Dominion permission to “dewater” its coal ash retention ponds at its Possum Point and Bremo Bluff stations. Possum Point is on the Potomac River and Bremo Bluff is on the James River. Several environmental groups, and at least one state agency, say they plan to appeal the board’s decision.

Dominion is also investigating remediating ash impoundments at two other plants.

More: Bay Journal

January 26, 2016

FERC to Investigate Rates of 4 Natural Gas Pipeline Cos.

By Suzanne Herel

FERC on Thursday called for an investigation into four interstate natural gas pipelines that it believes might be charging shippers in PJM, ISO-NE, NYISO and CAISO too much.

The pipelines — Empire Pipeline (RP16-300-000), Iroquois Gas Transmission System (RP16-301-000), Columbia Gulf Transmission (RP16-302-000) and Tuscarora Gas Transmission (RP16-299-000) — have been ordered to file a cost and revenue study within 75 days and appear before an administrative law judge for evidentiary hearings.

The ’ earnings were flagged in a FERC review of annual reports filed by 129 pipeline companies for 2013 and 2014. The analysis found returns on equity for the four pipelines ranged from 15.8% (Empire, 2013) to 24.9% (Tuscarora, 2014). The industry average ROE is a little more than 12%.

“These estimated levels of returns led staff to believe that these four pipelines are over-recovering their costs of service and may be charging rates that are no longer just and reasonable,” James Sarikas, of FERC’s Office of Energy Market Regulation, said in a presentation to the commission. “In addition, none of these pipelines have an existing settlement with its customers that places a currently effective moratorium on existing rates, or requires it to file a new general [Natural Gas Act] Section 4 rate case in the future.”

First Probes Since 2013

The probes are the first in two years to be conducted under Section 5 of the NGA, designed to protect consumers from excessive rates and charges.

FERC in 2009 began a regular, in-depth review of the cost and revenue information filed by large pipelines and in 2011 expanded its focus to include smaller operations.

In that time, the commission initiated 10 proceedings to determine if the pipelines’ transportation and storage rates might not be just and reasonable. Eight of those investigations ended in settlement agreements, and two were terminated.

Dena Wiggins, president of the Natural Gas Supply Association, which represents gas producers and marketers, said her group was pleased that FERC had opened the investigations, adding that they underscore a need for revisions to Section 5.

“Legislation that reforms Section 5, granting FERC the authority to award refunds to shippers in cases where pipelines are determined to have overcharged, would further enhance consumer protections, since currently FERC can only order an overearning pipeline to lower its rates going forward from the date of the commission’s order,” she said in a statement. “Now that FERC has adopted a new modernization surcharge policy that grants interstate pipelines new opportunities to recover costs outside of a general rate case, Section 5 reform is more important than ever.”

Pipelines Span the Country

FERC’s orders outlined their concerns over the companies’ earnings:

Empire, an affiliate of National Fuel Gas, received authorization in 2011 to construct the Tioga County Extension Project, which enables it to transport natural gas south from Canada and product from the Marcellus shale north from Pennsylvania. It had not filed a rate case since 2006. The commission’s review found Empire earned $24.6 million after income taxes in 2013, an ROE of 15.8%, and $28.6 million (20.2%) the following year.
Iroquois, which owns pipelines from the Canadian border through New York and western Connecticut, has not adjusted its rates since 2004. FERC said it had an after-tax return of $54 million (16.2%) in 2013 and $55.6 million (16.3%) in 2014.
Columbia Gulf operates about 3,400 miles of pipeline located primarily in Louisiana, Mississippi, Tennessee and Kentucky. Its current rates are the result of a 2011 settlement agreement, which barred it from seeking to modify rates before April 1, 2014. The company earned $21.9 million (17.3%) for 2013 and $26.4 million (18.2%) for 2014.
Tuscarora, which operates a 229-mile pipeline in Nevada and northwestern California, had not had a rate examination since a 2012 settlement with the Nevada Public Utilities Commission. FERC’s review indicated earnings of $9.7 million (23.6%) for 2013 and $9.6 million (24.9%) for 2014.

January 26, 2016

ATC to Separate Legacy Assets from Development Arm

American Transmission Co. won permission from FERC last week for a corporate reorganization that will split its existing transmission assets from its development partnership with Duke Energy.

ATC said the separation was driven by its owners — utilities, co-operatives and municipalities — who were unwilling or unable to take part in projects outside of the company’s 9,500 miles of “existing core transmission” in Wisconsin, Michigan, Illinois and Minnesota.

FERC approved the creation of a new holding company, ATC Holdco LLC, which will assume most of ATC’s 50% share in Duke-American Transmission Co., which is seeking development opportunities in PJM, MISO and SPP (EC16-47).

ATC’s owners can remain invested in the legacy transmission only or exchange their interests for shares in the development arm.

The companies pledged to not pass on any transaction-related costs to customers for five years, but FERC reminded them that the commission doesn’t allow rate recovery to finance transactions.

“Regardless of the terms of applicants’ hold-harmless commitment, we remind applicants that the commission historically has not permitted rate recovery of acquisition premiums,” FERC wrote in the order, issued Wednesday. “If applicants seek recovery of any acquisition premium associated with the transaction, they must be able to demonstrate in a subsequent proceeding … that its acquisition was ‘prudent and provides measurable, demonstrable benefits to ratepayers.’”

No comments were filed opposing the transaction. Wisconsin Electric Power Co. and Wisconsin Public Service Corp. submitted their written support.

— Amanda Durish Cook

January 26, 2016

FERC: Entergy not Required to Buy from Large QFs

By Tom Kleckner

Entergy’s operating companies don’t have to sign new purchase power agreements with most qualifying facilities above 20 MW, FERC ruled last week (QM14-3-000).

Because of their membership in MISO, the commission said, the Entergy companies had met their “statutory standard” under a 2006 order in which the commission revised its regulations implementing the Public Utility Regulatory Policies Act.

In a separate order, the commission granted Arkansas Electric Cooperative Corp. (AECC) similar relief based on the 2006 order, which said that QFs with net capacity above 20 MW were presumed to have “nondiscriminatory access” to wholesale markets in RTOs such as MISO.

The commission denied Entergy’s request for relief regarding one QF, Dow Chemical’s Plaquemine facility south of Baton Rouge, La., which it said faced transmission constraints.

Excluding the Dow facility, FERC said MISO provides all “over-20 QFs” in Entergy’s territories “nondiscriminatory access to independently administered, auction-based day-ahead and real-time wholesale markets for the sale of electric energy and to wholesale markets for long-term sales of capacity and electric energy.”

Entergy’s request was supported by the Louisiana Public Service Commission but protested by several industrial customers with QFs.

The Louisiana PSC said QFs in Entergy’s service territory have nondiscriminatory access to MISO’s markets and noted the company’s request “was made in part to satisfy the Louisiana commission’s requirements — which included removing the PURPA ‘put’ obligation — in approving MISO membership for Entergy Gulf States Louisiana and Entergy Louisiana.”

Justice Department Investigation

Protests by Occidental Chemical and Formosa Plastics cited an open Department of Justice antitrust investigation into Entergy’s transmission practices. Formosa said FERC should deny Entergy’s application pending a resolution of the investigation, noting that the department sought to have Entergy divest its transmission system. Occidental said that MISO had not approved transmission improvements to relieve the Amite South load pocket.

The commission said that because Amite South is import constrained, Occidental’s Taft QF was not prevented from selling energy outside the load pocket, and noted that LMPs at the plant are higher than average LMPs in MISO.

“Moreover, as Entergy points out, any energy which the Taft QF sells to load-serving entities outside the Amite South load pocket, including through the sub-regional power balance constraint to load-serving entities in MISO Midwest would, therefore, most often relieve congestion caused by the constraint, rather than be barred by it, and would instead receive congestion credits,” FERC said.

In contrast, FERC said, Dow’s 1,491-MW Plaquemine QF is located in a generation pocket, which is export constrained and subject to lower LMPs than the rest of MISO.

Entergy told FERC that transmission upgrades are scheduled to go in service around the Dow facility in December 2018. FERC said Entergy will be able to file for termination of its obligation to the Dow QF once the upgrades are completed.

The commission emphasized that granting Entergy’s application “does not relieve Entergy of its obligation to abide by its existing agreements.”

Entergy told FERC it would honor existing contracts “pending satisfaction of applicable contract termination requirements” and said it would not “seek to terminate any existing agreements effective prior to 120 days” after its request was accepted. FERC’s order was effective Oct. 23, 2015, the date of Entergy’s filing.

AECC Request Approved

In a related order, FERC also granted AECC’s request to terminate its PURPA obligations for “over-20” QFs in MISO (QM15-3-000).

AECC made the request in April on behalf of itself and its 17 members, 14 of which are in MISO, but later amended the application so that it applied solely to the cooperative. The commission agreed with AECC that it relies on Entergy Arkansas’ transmission system to serve its members’ load.