The Saint Solar facility has been serving SRP commercial customers since the end of 2020 and is one of nine SRP-contracted solar resources delivering more than 650 MW of clean energy to SRP customers. The new battery energy storage system can store enough of the solar facility’s clean energy to provide power to more than 22,500 average-sized homes for four hours.

The Saint Solar facility and the connected battery energy storage system are operated by subsidiaries of NextEra Energy Resources, and solar energy from the site is delivered to 11 SRP commercial customers to help meet their renewable energy goals. The addition of battery energy storage is meant to benefit all SRP energy customers. This new storage will be in addition to SRP’s existing large investment in storage resources, including more than 1,100 MW of battery projects to be online by the end of 2024.

Energy Storage Deployments is an educational track at the POWERGEN International® exhibition and summit, which serves as an education, business and networking hub for electricity generators, utilities, and solution providers engaged in power generation. Join us from January 23-25, 2024, in New Orleans, Louisiana!

The U.S. Energy Information Administration (EIA) recently projected that coal-fired power plants will generate less electricity in 2024 (599 billion kWh) than the combined generation from solar and wind (688 billion kWh) for the first time on record.

Solar is the fastest-growing source of U.S. electric power generation. EIA expects at least 37 GW of new solar generating capacity to come online in 2024, up 39% from 2023. The agency projected 23 GW to come online in 2023, a 33% increase from 2022.

SRP has contracted with NextEra Energy Resources for additional Arizona-based solar and battery energy storage projects. These include the Sonoran Energy Center, an approximately 260-MW solar facility with the ability to charge a 1-GWh battery energy storage system. Located south of Buckeye, Arizona, Sonoran Energy Center will be the largest operational battery project in the state, the companies said. Additionally, SRP has contracted for the output of Storey Energy Center, an 88-MW solar and battery energy storage system operating in Coolidge.

SRP expects a 25% increase in energy demand by 2030. To meet this demand, SRP says its future power system will balance adding more renewables and energy storage resources with flexible natural gas to avoid compromising affordability and reliability. This aligns with SRP’s recently announced Integrated System Plan.

In addition to the battery storage SRP will have in operation in 2024, SRP is prepared to add 1,500 MW of new battery resources and 1,000 MW of long-duration energy storage capacity from pumped hydro by 2035. SRP also plans to add 7,000 MW of new renewable resources, which includes 6,000 MW of new, large-scale solar resources by 2035. This will triple SRP’s current extensive portfolio of solar resources scheduled to come online by the end of 2025.

Originally published in Renewable Energy World.

A subsidiary of NextEra Energy has submitted transmission proposals to support the buildout of offshore wind projects in New York and New Jersey.

NextEra Energy Transmission submitted the New York Renewable Connect and New Jersey Seawind Connector proposals with PJM and NYISO regulators, respectively.

Regulators in New York and New Jersey are expected to select offshore wind transmission proposals in the second half of 2022. New York has a goal of developing 9 GW of offshore wind by 2035, while New Jersey hopes to bring 7.5 GW online over the same period.

"We believe no one in the industry can match our experience and unique skillset and we look forward to participating in this project," Eric Gleason, president of NextEra Energy Transmission, said in a statement.

Earlier this month, PSEG and Ørsted submitted several joint proposals for offshore wind transmission projects in New Jersey, named collectively Coastal Wind Link. The proposals were submitted into the PJM State Agreement Approach Proposal Window.

The U.S. Dept. of Energy will study transmission needs to support the country's burgeoning offshore wind market. The Biden administration wants to deploy 30 GW of offshore wind by 2030. The two-year study will be led by the National Renewable Energy Laboratory and Pacific Northwest National Laboratory.

PA Consulting presented its annual ReliabilityOne top national award to FPL. The analyses by PA includes publicly available information on average interruption duration and frequency.

“Florida Power & Light are industry leaders when it comes to serving their customers in extreme weather situations,” said Gregg Edeson, PA Consulting’s ReliabilityOne program director. “They have implemented innovative technologies to create 24/7 situational awareness of their systems and customers’ status, ensuring that they are quickly able to get the lights back on when storms approach or the power goes out.”

Since the historic storm seasons of 2004 and 2005, FPL has made billions in investments to sustain its grid and enhance customer reliability. It hardened more than 50 percent of main lines serving critical facilities and services, while also installing more than five million smart meters, 120,000 sensors and other intelligent devices to speed up restoration times and clearing trees and vegetation from more than 15,000 miles of line.

The Florida utility, part of NextEra Energy, wasn’t alone in its dedication to providing greater customer reliability, according to PA Consulting. Eight other utilities were touted in their respective regions for the same qualities of service delivered by FPL.

These regional winners include:

West Region (Metropolitan) — San Diego Gas & Electric

West Region (Suburban and Rural) — Southern California Edison

Midwest Region (Suburban and Rural) — We Energies

Mid-Atlantic Region (Metropolitan) — Public Service Electric and Gas Company

Northeast Region (Metropolitan) — Consolidated Edison Company of New York

Northeast Region (Suburban and Rural) — Orange and Rockland Utilities

Southeast Region (Metropolitan) — Florida Power & Light Company

Southeast Region (Suburban and Rural) — Gulf Power

Plains Region (Suburban and Rural) — Northern States Power/Xcel Energy

PA Consulting bestowed special ReliabilityOne awards to Public Service Electric and Gas for customer engagement, and San Diego Gas & Electric for outstanding technology, innovation and system resilience.

A higher frequency of major weather events is challenging the nation’s power system, although the utilities touted by PA held their systems together and even improved on ratings for 2019.

Investor owned utilities last year saw slight increases in both average outage frequency and duration compared to 2018. ReliabilityOne award recipients, however, increased their performances year over year, according to PA Consulting.

The owner of Florida Power & Light, Gulf Power and renewables-focused spinoff NextEra Energy Resources, the company first announced its contributions on March 17. Provided by the NextEra Energy Foundation and the Gulf Power Foundation, the emergency funds are being distributed on the front lines of the COVID-19 crisis to provide critical support to the most vulnerable members of our communities.

“Preparing for the unexpected and quickly responding to a crisis is in our DNA and at the very core of our company,” said NextEra Energy Chairman and CEO Jim Robo. “In addition to working tirelessly to deliver the 24/7 electricity that’s powering the COVID-19 response, we remain steadfastly committed to doing everything we can to support the most vulnerable in our communities when they need us most.”  

“NextEra Energy has always been a tremendous partner and a company that cares deeply about the community it serves,” said United Way of Palm Beach County CEO Laurie George. “During this unprecedented time when so many of our neighbors are facing sudden, extraordinary challenges, it’s absolutely critical to have a company like NextEra Energy step up to the plate and lend a helping hand through such generous donations.”

The NextEra Energy family of companies operates in 45 states and includes Florida Power & Light Company, FPL Home, Gulf Power Company and NextEra Energy Resources. Through numerous crises, including hurricanes, major floods, tornadoes and other severe weather events, NextEra Energy has a long-standing track record of helping communities bounce back after a crisis and return to normal.

Florida Power & Light Company, the largest electric utility in Florida, and Gulf Power Company, which serves more than 470,000 customers in northwest Florida, have suspended electric service disconnections and continue to work with customers experiencing hardship in response to COVID-19. Additionally, both companies are seeking approval from the Florida Public Service Commission to pass new fuel savings to customers through a significant one-time bill decrease in May, rather than spread savings out over the remainder of the year as is standard practice in Florida. The companies believe this approach is the fastest way to get much-needed money back in customers’ pockets amid the economic uncertainty.

The U.S. Nuclear Regulatory Commission announced Friday that it has approved Exelon Generation’s application extending the licensing for Peach Bottom Power Stations Units 2 and 3 another 20 years. The renewed licenses now expire in the 2050s, which will be 80 years after the two units became operational.

The 80-year license is uncharted territory for U.S. nuclear power plants. The extensions are seen as a necessity in pro-nuclear corners because the plants offer high capacity, zero carbon and reliable output at a time when only one new facility is being built.

“We are pleased with the NRC’s decision to grant a subsequent license renewal for Peach Bottom Units 2 and 3,” said Bryan Hanson, Exelon Nuclear chief nuclear officer. “This plant is well suited to continue running safely, reliably and efficiently, given the extensive upgrades accomplished over the past seven years.” 

Unit 2 is renewed through August 2053, while Unit 3 to July 2054, according to the NRC. Both units utilize GE boiling water reactors and were commissioned in 1974.

Nearly $90 million worth of upgrades were recently completed at the Peach Bottom facility, according to Exelon. Its capacity is around 2,770 MW of carbon-free electricity, enough to power close to 2.7 million homes.

Trump Administration Energy Secretaries Rick Perry and (current) Dan Brouillette both have touted nuclear energy for its carbon-free output and on-site fuel security. In addition to Exelon, Dominion Energy and NextEra Energy have either filed requests or are considering license extensions for some of their nuclear power plants.

— — — — —

Nuclear energy will be part of the Lowering Carbon with Thermal Generation track at POWERGEN International happening December 8-10 in Orlando, Florida.

Santee Cooper Senior Vice President of Nuclear Energy Michael Crosby and Marion Cherry, the utility’s on-site manager for the nuclear project that cost $9 billion and never generated power, reluctantly took an oath to tell the truth at a Senate Finance Committee meeting and then were asked almost no questions.

The committee is deciding Santee Cooper’s future, deciding between bids to let the utility reform itself, sell Santee Cooper to NextEra Energy of Florida or have it managed by Dominion Energy of Virginia.

Senators wanted the men and two former executives to be at a similar meeting Tuesday, but their lawyers advised them not to show up because of criminal investigations into Santee Cooper and its majority partner in the nuclear project, the former SCANA Corp. Senate leadership threatened subpoenas if they didn’t show up.

Through lunch Wednesday, senators asked the men only one question about how much Santee Cooper has spent to protect equipment, material and supplies at the construction site for the reactors north of Columbia since it was abandoned in July 2017. Prompted by Santee Cooper CEO Mark Bonsall, Cherry quietly answered from his seat three rows back that it was $20 million.

The equipment is in limbo as Santee Cooper and the main contractor on the failed nuclear project, Westinghouse Electric Co., have sued each other. Westinghouse declared bankruptcy about three months before the reactors were abandoned.

Cherry and Crosby were mentioned one other time Wednesday by Santee Cooper Board Chairman Dan Ray, who pointed out the men were only a handful of Santee Cooper employees at the abandoned construction site compared to more than 600 SCANA employees.

“They’re good people. And in my opinion, they did their job. But as a litigator mentioned to me last week, they were at the kiddie table,” Ray said.

While the initial refusal of the executives to testify created a small stir, senators spent almost all of Wednesday’s meeting questioning for a second day other Santee Cooper leaders about their bid to stay a public utility.

Through their questions, senators found out Santee Cooper has about $1 billion in potential liabilities with several lawsuits, including the one over the equipment. They also found out the utility has paid $1.7 million for lawyers for its executives for both civil lawsuits and the ongoing criminal investigation, which has not yielded charges.

Santee Cooper officials also said they have shed seven vice presidents in less than three years, but still have 14 vice presidents on the payroll.

The Senate Finance Committee has spent hours meeting each day the Legislature has been in session the past two weeks. They have to make a decision on Santee Cooper’s future and pass it on to the full Senate by mid-March.

The House Ways and Means Committee has a similar assignment and timetable and is holding marathon meetings this week, talking to NextEra and Dominion officials. The Santee Cooper administrators will move across the Statehouse grounds Thursday for their own meeting in the House’s office building.

Santee Cooper is $4 billion in debt mostly because of its debt on the unfinished nuclear reactors. NextEra’s bid of more than $9 billion bid would pay off that debt and offer $940 million in relief on rates for customers who use Santee Cooper’s power.

But NextEra’s offer would cut Santee Cooper’s 1,700-employee workforce by more than 40% and the company could not guarantee rates over the next 20 years below the rates that Santee Cooper proposed.

In its management proposal, Dominion wouldn’t charge a fee to run Santee Cooper. But that bid had fewer details, including no plans on how to handle Santee Cooper’s debt, no names of the executives they would put in place at the South Carolina utility and no details on how much electric rates will increase.

First, the cost of wind turbine installations has dropped by over one-third since 2010 as the capacity of turbines increased. Next, according to Lawrence Berkeley Labs, the average capacity of turbines installed is now 2.32MW, up more than 200% since the late 1990s. The upsizing is mainly due to a drop in the per unit cost of equipment that is of even more advanced technology.

Finally, capacity factors are also rising with an average of 42% reported over the period of 2014 to 2016, a significant increase of 31.5% reported over the period of 2004 to 2011. American Wind Energy Association (AWEA) data reports that there are now over 56,800 wind turbines representing 96,488 MW in service in the U.S., with 5,944MW installed in the fourth quarter of 2018 alone.

Repowering existing wind turbine sites with taller towers and longer blades is perhaps the most notable current industry trend. A repowered wind farm not only extends the life of the facility but leverages rising capacity factors found with modern technology along with more efficient power generation. One midwestern energy company, for example, has announced plans to spend upwards of $1 billion to repower 700 existing wind turbines with the promise of 19 to 28% more generation, depending on site. In fact, 15 repowering projects accounted for 2,136MW of the about 7,000 MW added to the grid in 2017, according to AWEA. The National Renewable Energy Laboratory (NREL), as reported by the EIA,  has predicted that investment in repowering of existing wind turbine sites has the potential to grow to $25 billion by 2030.

Not all existing wind farm owners have the balance sheet or site factors that would encourage a full or partial repowering. Instead, those owners often pursue a more incremental approach to improving the reliability and capacity factor of their wind turbines. One approach is to consider an optimized blade replacement, typically at sites characterized by low wind speeds. Development of more reliable and efficient gearboxes has also been the desire of many wind farm owners and the Department of Energy has invested heavily in their development. NREL has also helped develop many new wind turbine components for increased turbine reliability. However, turbine blade pitch control valves, well known within the industry as having a limited life, continues to weigh down wind turbine reliability and capacity factor.

Controlling Blade Pitch

Blade pitch controlled is a critical function within the overall wind turbine control system. Wind turbines operate at constant rotational speed, usually about 15-20rpm for large turbines. The gearbox increases the shaft speed to about 1,000—1,800rpm to match the generator rotational speed requirements, typically producing 60-cycle AC electricity at about 700V. The turbine controller starts the turbine when the wind reaches a given speed, usually about 8-16mph. A yaw drive keeps the turbine pointed into the wind to maximize electricity production.

The pitch control system, located within the turbine hub, rotates the three variable-pitch turbine blades in unison to precisely control the generator speed based on a feedback signal from the generator. On hydraulically controlled units there is one pitch control proportional valve per blade on a turbine so, for example, there are three valves used on a three blade turbine. The pitch system also “stalls” the blades so that there is no lift generated by the rotating blades thus shutting the turbine down when the wind speed reaches about 55mph to protect the turbine from damage (Figure 1). A brake is usually engaged when the blades cease rotation.

Figure 1. The anatomy of a typical wind turbine. Source: Parker Hannifin

The pitch control system operates in a very demanding environment and the proportional control valve, one per blade, is arguably the device exposed to the harshest operating environment. Failure of only one of the three valves will force the wind turbine out of service. Data from operators confirm this observation with many field reports of pitch control valve failure within weeks of its first operation, with an unexpectedly large number of failures occurring within six months of service. Upon failure, a maintenance technician must travel to the turbine site and replace the pitch control valve in the hub. Performing this service can take one or more days, depending on the site location, technician availability, and weather conditions. Often the cause of the failure has been traced to circuit board failure due to inadequate vibration protection or the circuit board enclosure design does not prevent dirt and moisture ingress. The cost of a replacement pitch control valve is secondary to the cost of maintenance replacement evolution and the loss of energy generation.

A pitch control valve must be designed to operate 24/7 in an extremely rugged environment. First, most pitch control valves are located in the turbine ub which rotates and thus exposed to heavy vibration, shock, and rotational forces (up to 50G on three axes). The valves are also subject to lightning strikes so the valve electronics must be electrically isolated from the turbine nacelle. Also, the pitch control valve must be capable of withstanding ambient temperatures, ranging from -40C (Minnesota in the winter) to 85C (West Texas in the summer) in which wind turbines are installed.  Finally, it stands to reason that the pitch control valve should be designed to comply with IP65 standards for protection against dirt, grease, and moisture (Figure 2).

Figure 2.  A well-designed pitch control valve will not only ensure stable turbine performance over its load range but will be designed to operate reliably in extreme cold and heat and will not allow dust or moisture intrusion, a known cause of valve failure. Source: Parker Hannifin Corp.

Up Your Turbine Game

One pitch control valve that has proven itself in multiple wind turbine applications is the Parker Hannifin D1FC (nominal size: NG06, 5gpm flow rate) and the D3FC (nominal size NG10, 16gpm flow rate) direct operated proportional DC valve with position feedback. The control valves receive an input signal (either 4-20ma or +/-10VDC) from the main turbine controller based on its monitoring of the generator output. Valve flow and performance specifications have been matched to the system requirements of the turbine so as to be compatible with the existing control parameters and co-exist with valves on the other axis.

In addition to IP65 designation, which inhibits moisture and dust infiltration, the D1FC and D3FC units are designed to meet IEC 68-2-6, -7 and -36 vibration standards so that sinus, random noise, and shock loads, respectively, are well accounted for in the design, unlike OEM pitch control valves The electronic driver card is installed with anti-shock mounting technology which minimize vibrational effects. Unlike other OEM valves, all fasteners are thread locked to guard against vibration as an additional measure of safety.

Field service reports often cite mating connectors as the root cause of a turbine forced outage. The connectors used on OEM pitch control valves do not have locking connectors so vibration can cause the connectors to disengage. The D1FC and D3FC valve assemblies use locking mating connectors much like those found in the automotive industry that is exceptionally vibration resistant. Other important design characteristics of the D1FC and D3FC pitch control valves are illustrated in Figure 3.

Figure 3. The Parker Hannifin pitch control valves are designed to meet the most demanding performance specifications and are configured to be “plug and play” when replacing OEM control valves. Source: Parker Hannifin Corp.

Exceptional Operating Report

It is not unusual for plant owners to inquire about the operating record of any new component proposed as an OEM replacement, particularly one that serves such a critical function as the pitch control valves. Potential suppliers expect those questions. A potential user should begin by investigating the track record of the supplier. Parker Hannifin is certainly recognized as a global provider of motion and control technologies, particularly hydraulic controls, for a century. Control of hydraulics has been its stock in trade for almost as long.

What about the track record of the proposed replacement components? Parker Hannifin pitch control valves have been in service in wind turbine applications since 2016, without a single failure attributed to the valve assembly. NextEra Energy Resources, for example, recently purchased D1FC valve assemblies as a replacement for problematic OEM pitch control valves that were the root cause of turbine forced outages. D1FC valves were selected because of its field track record but also because they are a direct replacement and required no tuning prior to use. Replacement of a valve by a technician requires only about 20 minutes.

There is a further advantage for cost-conscience owners: a single replacement D1FC valve may be used in conjunction with two existing OEM valves, thereby allowing an incremental replacement program. This approach may be preferable for those owners who would rather replace with upgraded components as repeated failures occur over time. Other owners may determine that changing all three valves may be most cost-effective solution when the technician labor cost for multiple repairs and lost generation costs are considered in the analysis.

About the authors: Tom Ulery is industrial applications manager with Parker Hannifin. He has worked in the coming about 20 years as a supervisor and product sales manager.

Mark Riley is manager, global business development power generation markets, at Parker Hannifin. He worked 10 years including as a market development manager. Riley also worked for Honeywell Aerospace and AT&T.

¨

On the surface, 2019 for power generators looked pretty routine compared to recent history within the industry. Coal-fired and nuclear plants were retired, while combined cycle gas turbine facilities proliferated. Wind and solar rose dramatically. Nuclear got older.

The stories that readers of Power Engineering flocked to, however, defied those easy and misleading categories. The faithful clicked on pieces about technologies that “trendmakers” consider doomed, unlikely or struggling at best. They wanted to read about peers moving up or moving out or, worse, gone.

This is not a top 10 list of the most read stories on our website. Instead, each entry is a catch-all for a particular type of story which gained wide traction in Power Engineering in 2019.

All in all, perhaps this offers insights into what our readers are thinking, concerned about or anticipating. They are worth another look.

1. The future of nuclear is unknown, but we are clearly eager to know more

Of the top 10 pages opened by our readers, four were about nuclear energy technologies on projects. Whether it was a “what if” column on the possibility of thorium as a fuel for the future, or updates on Georgia Power’s tenacious effort to get the Vogtle 3 and 4 reactors built, nuclear seemed to capture the most attention.

2. Turbine sector is getting ready…and getting more competitive

It seems like nearly all of the major players have struggled. GE already had split off that part of its business–while Siemens announced its own impending split. Meanwhile, a longtime EPC and services firm, Doosan Heavy Industries of South Korea, revealed plans for its own large gas turbine, possibly sending it into top-line competition with the Big Four that includes Mitsubishi Hitachi Power Systems, Ansaldo Energia, GE and Siemens. All four of these players also are considering futures utilizing hydrogen in the fuel mix.

On-site power was also adapting gas-fired technologies, as reciprocating engines were being deployed to offer load following and stabilization services in areas where renewable energy concentration was heaviest.

3. Forgive us if we’re old-fashioned…but chillers still thrill us

We’ll play it cool when it comes to this part of the best-read content 2019 in Power Engineering. Some pieces focused on condenser performance monitoring or cooling tower heat transfer. Either way, Power Engineering readers are a smart lot who want to learn more on the inside workings of the modern power plant. Our contributors are happy and more than able to oblige.

4. Energy storage is still a question mark, but a lot of people are asking

A January 2019 webcast on “The Growth of Battery Storage for the Off-grid/Mini-grid Market” drew exceptional readership interest up to and following the broadcast itself. Bloomberg, HOMER Energy and Trojan Battery looked at statistics affirming the growth of energy storage and exploring the way forward.

Utilities are stepping tentatively but unmistakably into the battery sector. Dominion and Duke Energy both have projects going forward, Key Capture Energy completed the largest installation in New York.

The utility-scale battery option, however, is expensive and requires serious safety oversights. An Arizona Public Service, AES joint venture facility exploded earlier this year, injuring four firefighters. This search for safeguards also resulted in an important energy storage breakthroughs session at POWERGEN International this November in New Orleans.

And the Energy Storage Breakthroughs Summit at POWERGEN was that event’s most well-attended track.

5. Entergy Corp. building big-time gas-fired capacity

Many utilities are building new CCGT plants globally, but for some reason the stories surrounding Entergy’s new projects proved extremely popular. The New Orleans-based utility announced it was adding 4 GW of new gas-fired capacity in coming years, including the recently completed St. Charles Power Station in nearby Montz. With its Montgomery County project, Entergy also is building its first new Texas capacity in several decades.

6. Are you tired of our gas? Apparently not

Haha, forgive us a little levity with a (very small) joke, but the expansion in gas-fired power generation capacity both in the U.S. and globally was no laughing matter. It’s official: the U.S. Energy Information Agency has confirmed that domestic combined-cycle capacity now exceeds coal-fired, 264 GW to 243.

Companies like MHPS, Siemens and beyond are also supplying CCGT plants all around the world. And IHS Markit reported that U.S. gas production was reaching an astounding 90 billion cubic feet per day.

Now put those last two facts together, and you have the makings for our Number 7.

7. The ETA for LNG is now

This past year marked a turning point for approval, construction and commissioning of liquefied natural gas export terminals along the U.S. coasts. Utilities, conventional oil and gas firms and startups are all vying for space to take some of that excess U.S. gas, freeze it for stable shipping and send it to power generation markets around the world.

The Natural Gas Knowledge Hub at POWERGEN19, which offered numerous sessions on LNG ventures, was one of the most popular content offerings there.

8. C&I Customers want wind and solar in the market

We’re talking just a few companies here, little names like ….Amazon, Google, Microsoft, AT&T and Facebook. They may not off-take clean energy directly, but they want renewables in the grid. Corporate power purchase agreements help finance utility-scale wind and solar projects.

Michael Terrell, head of energy market development at Google, told Power Engineering back in January that zero-carbon energy made great business sense for long-term investment. Clean energy, fixed-price contracts are very attractive. Since 2010, the internet giant has signed to offset the cost of more than 30 solar and wind projects across the Americas and Europe.

New virtual PPAs signed by AT&T recently pushed that company’s clean energy investment to more than 1.5 GW.

9. And let us not forget coal

Sure, Trump Administration energy regulators have worried about the pace of coal-fired plant retirements. Nonetheless, coal still generates nearly 30 percent of the U.S. and global electricity mixes.

And while nothing new is planned in the U.S. and Europe, major projects are going forward mainly in Asia. Coal is going to be around for a while. A long while.

10. In Memorium

We could have put this one much higher, but felt it was an appropriate way to end this story. Power Engineering readers value the contributions of those who give their time and energies into this industry, so we all read with sadness on the death of Christopher McCallum, a principal consultant at Lummus and member of the POWERGEN International advisory committee.

McCallum died in Boston at the age of only 44. Prior to Lummus he had worked for NextEra Energy Resources and had been operations manager and chief engineer of a 300-MW combined cycle in New England.

The industry also mourned the passing of Ron Nichols, most recently president of Southern California Edison. Nichols served in a career that spanned SCE, Los Angeles Department of Water and Power, Navigant Consulting and Resource Management International.

Here’s looking forward to a happier, more productive and powerful 2020.

Thank you.

The Clarion Energy Content Directors of Power Engineering

Work on the Chicot Solar Energy Center is expected to last about 11 months. Florida-based NextEra Energy Resources will build and operate the site, while Entergy Arkansas will buy the power under a 20-year power purchase agreement.

Once completed, the 825-acre Chicot site near Lake Village will be the biggest solar power facility in Arkansas. It will supersede the Stuttgart Solar Energy Center, which came online last year.

 “Entergy Arkansas is already the largest solar provider in the state, and this project allows us to increase what we can provide for our customers,” said Laura Landreaux, president and CEO of Entergy Arkansas. “Large-scale, universal solar allows us to provide the benefits of renewable energy to all of our 700,000 customers at an economic price.”

The facility will feature approximately 350,000 photovoltaic solar panels that convert the sun’s energy into electricity. The solar energy center will have a capacity to generate 100 megawatts of electricity, or enough to power more than 18,000 homes.

 “This project will bring good jobs, tax benefits and affordable, renewable energy to the state for decades to come,” said John Ketchum, president and CEO of NextEra Energy Resources. “We are pleased to continue to work with our partners at Entergy Arkansas to bring economic, renewable energy to customers and introduce another universal solar project of this scale in Arkansas.”

The project will create up to 150 jobs during the construction phase.

Entergy Corp. Chief Operating Officer Paul Hinnenkamp was one of the keynote speakers at POWERGEN International two weeks ago in New Orleans. During the keynote and afterward, Hinnenkamp elaborated on Entergy’s long-term plan to add as much 3 or 4 GW of renewable energy resources to its generation mix over the next 11 years.

“Our customers, our stakeholders are just more and more interested in seeing those types of generation,” he said during a post-keynote interview at POWERGEN. “Our emissions in 2030 will be 50 percent less than they were in 2000, on a per-unit basis…in order to accomplish that we have to do more on the renewable front.”

Click here to see a video of the Paul Hinnenkamp interview.

The 81-MW Stuttgart Solar Energy Center was completed by NextEra Energy Resources in January 2018. Entergy Arkansas also has signed a 20-year power purchase agreement for the power.

The Phoenix-based public utility confirmed that the Navajo Generating Station (pictured) will officially shut down within days, if not already. The 2,250-MW coal-fired plant has been targeted for closure because of its age, operational economics and an original lease running out, according to reports.

Meanwhile, SRP announced it was making big investments in two solar and storage projects. These include the Sonoran Energy Center and the Storey Energy Center, which will combine for more than 300 MW in solar-storage combined capacity.

“These integrated solar and storage plants will allow SRP to meet its summer peak demand, reduce carbon emissions, and provide clean energy to our customers while optimizing energy output using state-of-the-art battery technology,” said SRP CEO Mike Hummel. “In addition, these plants will get SRP more than 60 percent toward our goal of adding 1,000 MW of new utility-scale, solar energy to its system by the end of fiscal year 2025.”

Sonoran Energy Center will be an approximately 250-MW system with the solar array charging a 1 GWh energy storage system and will be built in Little Rainbow Valley, south of Buckeye.

The Storey Energy Center will be an approximately 88-MW solar and energy storage system and is scheduled to be built south of Coolidge.

The projects were chosen as the result of an open “All-Source” solicitation for resources and will help serve SRP’s summer peak load. Both plants are scheduled to be online by June 2023 and will be owned and operated by subsidiaries of NextEra Energy Resources, LLC.

The Navajo Generating Station closure could displace close to 500 workers, according to reports. SRP, however, is relocating more than half of those to other facilities.

The coal-fired plant in the Navajo Nation has been in operation since the mid-1970s. Several entities, including the tribe, had explored options to acquire it but eventually declined.

(Rod Walton is content director for Power Engineering and POWERGEN International, happening next week in New Orleans. POWERGEN will feature dozens of content sessions on the future of coal-fired generation, solar power and energy storage.