Monday, June 7, 2021

Snohomish PUD Promoting Smart Technology to Decrease Energy Usage (Everett Herald – Paywall Advisory)

(EVERETT, WA) - - During those frigid winter days, when we all turn up our thermostats, huddle inside and use more energy than normal, the PUD must ensure that it has enough power generation to meet demand.

Preparing for those energy peaks, which usually occur in the early mornings and evenings when people are waking up and getting ready for the day or getting home from work and starting dinner, is critical to the PUD continuing to keep power affordable, reliable and environmentally sustainable.

One way to meet peaks is to build more power plants. But because wind and solar power are not dependable during the winter, that would likely mean adding fossil fuels to the PUD’s power mix, something that would jeopardize the PUD’s ability to meet the state’s clean energy mandates.

Another way to meet those peaks is to not have them in the first place. To do that, the PUD must work hand-in-hand with customers and leverage smart technologies to decrease energy usage during critical time periods in the winter. Innovative technology like advanced meters, smart appliances and connected communication tools give customers more control over their energy consumption and the PUD more information on energy usage.

The PUD’s recently launched FlexEnergy pilots will help guide future plans for incentivizing behaviors that reduce energy usage during peak times. It’s important for the PUD to know how customers respond to time-of-day rate designs, and demand response and critical peak pricing programs and how smart technology can assist them in shifting energy usage away from peak periods.

The pilots are the first of their kind for PUD customers and will introduce PUD customers top the types of tools and programs that they will have the opportunity to join after the Connect Up program rolls out starting in 2023. With more customers taking part, little behavior changes, like scheduling an electric vehicle to charge overnight or changing the time they run laundry or a dishwasher, can help the PUD create a more flexible, clean and reliable power grid.

Residential customers can enroll eligible smart devices as part of the program. Smart thermostats from Google Nest and ecobee and connected EV chargers from ChargePoint and JuiceBox are eligible. Customers who do not register a smart device can join the Customer Choice non-smart tech programs.

The FlexEnergy pilots will focus on three approaches to shifting energy use:

FlexTime: A time-of-day pilot that offers an incentive and employs a new rate design providing customers a chance for costs savings by using energy during discount rate periods.

FlexResponse: A demand response pilot allowing customers to earn incentive payments by leveraging customer-owned smart technologies to lower energy use at certain times.

FlexPeak: A peak pricing pilot that offers incentives and employs a peak-pricing rate design that offers customers a discount rate and peak rate to motivate customers to reduce use at certain times the PUD designates.

Customers who sign up for any of the three pilots will receive bill credit incentives. Customers who enroll in the FlexTime and FlexPeak pilots will also receive discounts on their energy rate during specified times of the day.

The pilots are open to all residential customers who meet limited eligibility requirements, whether they own eligible connected devices or not. Want to enroll in a FlexEnergy pilot program? Visit snopud.com/flexenergy.

Operating since 1949, Snohomish County PUD is a customer-owned, not-for-profit electric and water utility that serves more than 360,000 customers in Snohomish County and Camano Island. For more information on conservation programs, visit www.snopud.com.

 

West Coast Is Facing Power Shortages This Summer - The Pacific Northwest Is Poised to Weather the Storm (The Spokesman-Review, Spokane, WA)

A drought-stricken West is bracing for what is expected to be a hot, dry summer and its strain on a regional power grid that some believe is certain to fall short of demand and leave many in the dark.

The Western Electricity Coordinating Council, which oversees electricity grids throughout the Western U.S. and Canada, estimates Nevada, Utah and Colorado could have a power shortfall equivalent to 34 days this year without power imports from other states. Arizona and New Mexico could be short enough hours to total 17 days. Washington and Oregon could face a shortfall of hours totaling nine days.

There are two reasons behind the power shortfall: Climate change is making it more difficult for utilities and grid managers to forecast demand for electricity, while states aren’t shifting to clean energy fast enough, according to a report by Bloomberg.

Thanks to the region’s surplus of hydroelectric power, Washington and Idaho aren’t facing the blackout risk this summer, but demand is anticipated to increase how much utility companies could pay for electricity.

That’s because Washington is part of the Western Interconnection, a power grid consisting of 136,000 miles of transmission lines that carry power from hydroelectric resources in the Pacific Northwest to California and other states. Utilities routinely import power from out of state, sourcing electricity to where it’s needed across the transmission lines.

“We are basically tied to what happens in the Western electric grid. It’s a big machine. It stretches a lot of distance,” said Ben Kujala, director of power planning for the Northwest Power and Conservation Council, a regional organization that develops and maintains a regional power plan, as well as a fish and wildlife program. “There can be small local issues that have very limited effects. But, if it becomes a shortage or they’re looking for energy around the entire West, it’s something that will have impacts. Now, those impacts are not that the lights are going to go out. Generally, it’s that the power is more expensive.”

At the Palo Verde hub in Arizona, prices have nearly quadrupled since last summer’s outages, while prices have tripled at the Pacific Northwest’s Mid-Columbia hub, one of eight electricity trading hubs in the Western U.S., according to Bloomberg.

“People are kind of anticipating similar challenges (to last year) and so there’s some very high prices showing up in the summer right now … If (utilities) have to go out and buy power in the market, they’ll be looking at a premium for that power,” Kujala said. “Because there’s a lot of people in California that are buying power, hoping to not have a repeat of the circumstances they saw last time.”

Jason Thackston, senior vice president of energy resources at Avista Corp., echoed that prices for the summer are higher compared to prior years.

“We’re already seeing market prices for the summer higher than we would normally expect to see them as a result of a couple of things,” Thackston said. “One is the drought conditions that California and the Southwest are experiencing. And we’ve seen a drier than normal spring, so we’re seeing less hydro generation predicted across the Western U.S. Then, what we saw happening in California last year with rolling blackouts is probably having an impact on prices, power this summer as well.”

Nearly two-thirds of Washington’s power is generated from hydroelectric resources.

“I look at how much hydro generation we are looking at this year, and we’re seeing kind of average-ish, fairly normal stuff,” Kujala said. “So this is not a year that I would be waving a flag around saying, ‘we’re in deep trouble in the Northwest.’”

Avista is constantly evaluating snowpack over the winter to forecast hydroelectric generation for the summer. If there’s a predicted shortfall of hydroelectric generation, it will supplement it with other types of power, Thackston said.

“For example, we might increase our expectations around our natural gas generation that’s available to serve our customers. We will, at times, go into the market to fill a need that we have if that’s more economic in serving our customers,” Thackston said. “But we do that in advance. We’re looking out into the future months and buying power, or increasing our generation expectations, or adjusting our generation expectations based on the conditions that we’re forecasting so that by the time we get to the month, we really have taken all that into consideration and are ready for serving our customers.”

Inland Power and Light Co., a cooperative that purchases power from Bonneville Power Administration, serves 12 counties in Eastern Washington and North Idaho and is anticipating enough supply for its customers, Inland Power spokesman Andy Barnes said.

“It’s a low water year so far, but we have no alerts saying we have a power supply shortage,” Barnes said. “Washington state is fortunate because we have such a megasupplier and producer in the hydrosystem, which is really beneficial.”

Kieran Connolly, vice president of generation asset management for Bonneville Power Administration, said there’s a long history of interregional supply and demand in the Western Interconnection.

“In general, we still expect California to import power this summer, though the volumes from the Northwest will likely be lower due to reduced surplus hydropower arising from lower-than-average water supply,” Connolly said in an email.

The Bonneville Power Administration is a federal nonprofit agency that markets power generated by 31 hydroelectric projects in the Northwest, one nonfederal nuclear plant and several small nonfederal power plants.

Connolly added power shortages elsewhere in the Western Interconnection should have minimal impact on Northwest customers.

“While each situation is unique, reliability standards and Bonneville’s operating procedures are designed to limit the risk that challenges elsewhere in the grid would spill onto the Bonneville system,” he said.

Planning for the Future

In the Northwest, each utility creates its own load forecast and is responsible for its own resource needs, according to a report from the Pacific Northwest Utilities Conference Committee’s 2021 forecast.

The Northwest PowerPool Corp., a voluntary association of Pacific Northwest-based utilities, is developing a regional resource adequacy program to evaluate future capacity needs and pool resources to serve demand during stressed grid or market conditions. The program is slated to launch in late 2023 or early 2024.

The majority of Northwest utilities’ generating resources acquired last year and those under development are wind and solar projects. Biomass, hydropower, batteries and imports make up the rest.

More than 2,000 megawatts of coal-fired generation have been retired in the Pacific Northwest. By 2029, only four coal units will remain in operation in the region.

For a variety of reasons, including meeting power demand as well as the state’s decarbonization policies and goals, utilities are exploring adding nearly 7,500 megawatts of potential new supply-side resources over the next decade, in addition to 1,800 megawatts of resources slated to be in operation in the next few years, according to PNUCC’s forecast.

Avista has started in “a really good place with respect to clean energy,” with more than half of its power generation already carbon-free. The company’s power generation is mostly hydroelectric but also includes wind, solar and biomass, Thackston said.

Avista, a co-owner of Units 3 and 4 at the Colstrip, Montana coal-fired plant, is planning to exit ownership by 2025.

Avista and other utility companies in the state will no longer be allowed to distribute electricity from coal-fired generation after 2025 due to the Washington Clean Energy Transformation Act.

“Two years ago, we announced aspirational goals to serve our customers with 100%, clean electricity by 2045 and a carbon-neutral supply of electricity by the end of 2027,” Thackston said. “We believe that as the costs of renewable generation and storage technology continue to drop, and the technologies continue to mature, that we can move toward those goals in a way that for sure balances, affordability and reliability.”

The NPCC, which was created in 1980 after Congress passed the Pacific Northwest Electric Power Planning and Conservation Act, is releasing a draft of its 2021 Northwest Power Plan in August, followed by a public hearing. The 2021 power plan will include a 20-year electricity demand forecast and a portfolio of resources to meet anticipated demand.

Kujala, of the NPCC, said the organization is examining how the power system is adapting to solar resources in the West as utilities are retiring more thermal resources. Some utilities are looking at adding storage into renewable projects to meet demand, he added.

“I guess the question is, ‘are plants actually capturing the sort of investments you need to make to make sure that is a reliable system?’ We are definitely in the process of exploring that, and a lot of work is about that exact question,” Kujala said.

Looking to the future, there might be short periods or hours when electricity is stretched thin, but outages spanning days are not likely in the Northwest, barring some event outside of normal operations, Kujala said.

Kujala emphasizes the power outages that occurred in California and Texas last year were different in the cause and impact.

In a report released in January, California utility regulators determined the Golden State’s rolling blackouts last year resulted from inadequate supply and demand planning, as well as market issues.

The Texas Interconnection is maintained as a separate grid – a key difference compared with the Northwest, which is part of the Western Interconnection.

“I think a lot of people look at what happened in Texas, and that’s their fear. But we have a lot of advantages being tied to that larger grid,” Kujala said. “The costs can impact us, and if something happens in the desert Southwest or California, it can impact our utilities. But it also helps us be able to ride through circumstances like that in a much different way than what happened in Texas.”

 

Offshore Wind Farms Show What Biden’s Climate Plan Is Up Against (NY Times - Build It. We Dare You)

A constellation of 5,400 offshore wind turbines meet a growing portion of Europe’s energy needs. The United States has exactly seven.

With more than 90,000 miles of coastline, the country has plenty of places to plunk down turbines. But legal, environmental and economic obstacles and even vanity have stood in the way.

President Biden wants to catch up fast — in fact, his targets for reducing greenhouse gas emissions depend on that happening. Yet problems abound, including a shortage of boats big enough to haul the huge equipment to sea, fishermen worried about their livelihoods and wealthy people who fear that the turbines will mar the pristine views from their waterfront mansions. There’s even a century-old, politically fraught federal law, known as the Jones Act, that blocks wind farm developers from using American ports to launch foreign construction vessels.

Offshore turbines are useful because the wind tends to blow stronger and more steadily at sea than onshore. The turbines can be placed far enough out that they aren’t visible from land but still close enough to cities and suburbs that they do not require hundreds of miles of expensive transmission lines.

The Biden administration wants up to 2,000 turbines in the water in the next eight and a half years. Officials recently approved a project near Martha’s Vineyard that languished during the Trump administration and in May announced support for large wind farms off California’s coast. The $2 trillion infrastructure plan that Mr. Biden proposed in March would also increase incentives for renewable energy.

The cost of offshore wind turbines has fallen about 80 percent over the last two decades, to as low as $50 a megawatt-hour. While more expensive per unit of energy than solar and wind farms on land, offshore turbines often make economic sense because of lower transmission costs.

“Solar in the East is a little bit more challenging than in the desert West,” said Robert M. Blue, the chairman and chief executive of Dominion Energy, a big utility company that is working on a wind farm with nearly 200 turbines off the coast of Virginia. “We’ve set a net-zero goal for our company by 2050. This project is essential to hitting those goals.”

The slow pace of offshore wind development highlights the trade-offs between urgently addressing climate change and Mr. Biden’s other goals of creating well-paying jobs and protecting local habitats. The United States could push through more projects if it was willing to repeal the Jones Act’s protections for domestic shipbuilding, for example, but that would undercut the president’s employment promises.

These difficult questions can’t simply be solved by federal spending. As a result, it could be difficult or impossible for Mr. Biden to eliminate greenhouse gas emissions from the power sector by 2035 and reach net-zero emissions across the economy by 2050, as he would like.

“I think the clear fact that other places got a jump on us is important,” said Amanda Lefton, the director of the Bureau of Ocean Energy Management, the agency that leases federal waters to wind developers. “We are not going to be able to build offshore wind if we don’t have the right investments.”

Europe’s head start means it has established a thriving complex of turbine manufacturing, construction ships and an experienced work force. That’s why the United States could have to rely on European components, suppliers and ships for years.

Installing giant offshore wind turbines — the largest one, made by General Electric, is 853 feet high — is difficult work. Ships with cranes that can lift more than a thousand tons haul large components out to sea. At their destinations, legs are lowered into the water to raise the ships and make them stationary while they work. Only a few ships can handle the biggest components, and that’s a big problem for the United States.

A 1,600-Mile Round Trip to Canada.

Lloyd Eley, a project manager, helped build nuclear submarines early in his career and has spent the last eight years at Dominion Energy. None of that quite prepared him for overseeing the construction of two wind turbines off the Virginia coast.

Mr. Eley’s biggest problem was the Jones Act, which requires ships that travel from a U.S. port to anywhere within the country, including its waters, to be made and registered in the United States and owned and staffed by Americans.

The largest U.S.-built ships designed for doing offshore construction work are about 185 feet long and can lift about 500 tons, according to a Government Accountability Office report published in December. That is far too small for the giant components that Mr. Eley’s team was working with.

So, Dominion hired three European ships and operated them out of the Port of Halifax in Nova Scotia. One of them, the Vole au Vent from Luxembourg, is 459 feet (140 meters) long and can lift 1,654 tons.

Mr. Eley’s crew waited weeks at a time for the European ships to travel more than 800 miles each way to port. The installations took a year. In Europe, it would have been completed in a few weeks. “It was definitely a challenge,” he said.

The U.S. shipping industry has not invested in the vessels needed to carry large wind equipment because there have been so few projects here. The first five offshore turbines were installed in 2016 near Block Island, R.I. Dominion’s two turbines were installed last year.

Had the Jones Act not existed — it was enacted after World War I to ensure that the country had ships and crews to mobilize during war and emergencies — Dominion could have run European vessels out of Virginia’s ports. The law is sacrosanct in Congress, and labor unions and other supporters argue that repealing it would eliminate thousands of jobs at shipyards and on boats, leaving the United States reliant on foreign companies.

Demand for large ships could grow significantly over the next decade because the United States, Europe and China have ambitious offshore wind goals. Just eight ships in the world can transport the largest turbine parts, according to Dominion.

Dominion is spending $500 million on a ship, being built in Brownsville, Texas, that can haul large wind equipment. Named after a sea monster from Greek myth, Charybdis, the ship will be 472 feet (144 meters) long and able to lift 2,200 tons. It will be ready at the end of 2023. The company said the ship, which it will also rent to other developers, would let it affordably install roughly 200 more turbines by 2026. Dominion spent $300 million on its first two but hopes the others will cost $40 million each.

Fishermen Fear for Their Livelihoods.

For the last 24 years, Tommy Eskridge, a resident of Tangier Island, has made a living catching conchs and crabs off the Virginia coast.

One area he works is where Dominion plans to place its turbines. Federal regulators have adjusted spacing between turbines to one nautical mile to create wider lanes for fishing and other boats, but Mr. Eskridge, 54, worries that the turbines could hurt his catch.

The area has yielded up to 7,000 pounds of conchs a day, though Mr. Eskridge said a typical day produced about half that amount. A pound can fetch $2 to $3, he said.

Mr. Eskridge said the company and regulators had not done enough to show that installing turbines would not hurt his catch. “We just don’t know what it’s going to do.”

Annie Hawkins, executive director of the Responsible Offshore Development Alliance, which includes hundreds of fishing groups and companies, worries that the government is failing to scrutinize proposals and adequately plan.

“What they’re doing is saying, ‘Let’s take this thing we’ve really never done here, go all in, objectors be damned,’” Ms. Hawkins said. “Coming from a fisheries perspective, we know there is going to be a massive-scale displacement. You can’t just go fish somewhere else.”

Fishing groups point to recent problems in Europe to justify their concerns. Orsted, the world’s largest offshore wind developer, for example, has sought a court injunction to keep fishermen and their equipment out of an area of the North Sea set for new turbines while it studies the area.

Orsted said that it had tried to “work collaboratively with fishermen” but that it had sought the order because its work was complicated by gear left in the area by a fisherman it could not identify. “To safely conduct the survey work and only as a last resort, we were left with no choice but to secure the right to remove this gear,” the company said in a statement.

When developers first applied in 2001 for a permit for Cape Wind, a project between Cape Cod, Martha’s Vineyard and Nantucket, resistance was fierce. Opponents included Senator Edward M. Kennedy, the Massachusetts Democrat who died in 2009, and William I. Koch, an industrialist.

Neither wanted the turbines marring the views of the coast from their vacation compounds. They also argued that the project would obstruct 16 historical sites, disrupt fishermen and clog up waterways used by humpback, pilot and other whales.

After years of legal and political battles, the developer of Cape Wind gave up in 2017. But well before that happened, Cape Wind’s troubles terrified energy executives who were considering offshore wind.

Projects up and down the East Coast are mired in similar fights. Residents of the Hamptons, the wealthy enclave, opposed two wind development areas, and the federal government shelved the project. On the New Jersey shore, some homeowners and businesses are opposing offshore wind because they fear it will raise their electricity rates, disrupt whales and hurt the area’s fluke fishery.

Energy executives want the Biden administration to mediate such conflicts and speed up permit approval.

“It’s been artificially, incrementally slow because of some inefficiencies on the federal permitting side,” said David Hardy, chief executive of Orsted North America.

Renewable-energy supporters said they were hopeful because the country had added lots of wind turbines on land — 66,000 in 41 states. They supplied more than 8 percent of the country’s electricity last year.

Ms. Lefton, the regulator who oversees leasing of federal waters, said future offshore projects would move more quickly because more people appreciated the dangers of climate change.

“We have a climate crisis in front of us,” she said. “We need to transition to clean energy. I think that will be a big motivator.”

 

2020 Wildfires Left Precious Endangered Species Habitat in Central Washington ‘Nothing But Ash & Dust’ (Seattle Times, WA – Paywall Advisory)

(SAGEBRUSH FLAT WILDLIFE AREA, Douglas County, WA) - - It is a sound like something from the beginning of the world, that begins in the darkness just before dawn. Sage grouse, intent on attracting the interest of a mate, have begun to dance.

Their call at first light is a sound of the wild in the shrubsteppe of Central Washington, a landscape of sagebrush, flowers and native grasses precious and rare — now much more so since the wildfires of 2020.

Of the 802,000 acres that burned in Washington in 2020, some 725,000 were scorched within the boundaries of the Columbia plateau, including around 600,000 acres of shrubsteppe habitat — an area nearly three times the size of Mount Rainier National Park. That was a lot to burn in a landscape already reduced by half from the original 10 million or so acres in Washington, lost in conversion to farmland and development.

The acreage that just burned isn’t “lost” in the same sense as ground permanently converted to other uses. It will recover, in different ways and in different places over time. Just what that recovery looks like is something the state Department of Fish and Wildlife is still working to understand.

But what is beyond doubt is that the fires that wrought so much destruction and suffering for people also were punishing for wildlife — and apocalyptic for already rare species.

Wildlife managers estimate the population of 775 sage grouse in 2020 is now reduced to 699 birds, and 500 in three years would not be surprising — a dangerously low population. Sharp-tailed grouse numbered about 870 in 2020 and now are down by nearly a quarter to 660.

Department biologists confirmed a minimum of 164 pygmy rabbits in Washington 2020, but the fires burned through the area occupied by 70 of those rabbits — a 43% loss.

The Cold Springs fire started near Omak on Sept. 6. A 1-year-old child died in that fire, which burned 189,923 acres. The fire was determined to be human-caused, but is still under investigation. Then, on Sept. 7, winds pushed the fire in Okanogan County into Douglas County, burning some 30 miles, all the way to Highway 2. Combined, the Cold Springs and Pearl Hill fires burned 337,000 acres.

This is country that knows fire. But not fire so hot it destroys plants deep into the subsoil over hundreds of thousands of acres — and jumps not only fire breaks, but a half-mile of the Columbia River, to keep right on burning. Then, after the fire, came more wind, scouring the soil from burned roots. Then came a punishing spring drought — the fourth driest spring on record.

Wildlife and conservation experts now confront what in some places were burned over moonscapes, bereft even of common animals that had enlivened the land.

In parts of the Douglas County Wildlife Area Complex, outside Bridgeport, after the fires there were no white-tailed jack rabbits, no badgers. And so many dead porcupines. They climbed trees, trying to get away from the fire. Then the trees burned.

Jon Gallie, pygmy rabbit biologist for the WDFW, returned after the fires to the location of the enclosure where he and other department staff were raising pygmy rabbits for release to the wild. He hoped, that as in previous fires, the animals had toughed it out in their burrows as the fire danced past.

Not this time. The rabbits had asphyxiated as the fire in its fury devoured oxygen from the atmosphere.

“There was nothing but ash and dust,” Gallie said. “No movement, no footprints. There was no chance anything survived.”

Dan Peterson, manager for the Douglas County Wildlife Area Complex, remembered being in his house in Bridgeport, Douglas County, the night the fires were burning.

“I thought, ‘There goes 20 years of work,'” he said.

Deep Loss

Wade Troutman’s family came to this wide open landscape four generations ago. Born on the family ranch named Open Heart for the shape of its heirloom cattle brand, he never left. Even after the fires, he still doesn’t want to live anywhere but on the family ranch.

He likes the peace and the quiet, and the agrarian culture of a place where people take care of the land and one another. It’s changing here, as everywhere. But this is still a place where, when people see smoke, they run to the fire. To help.

“That’s your neighbor,” Troutman said.

He’s seen fire all his life, Troutman said. But nothing like the freak east wind that Labor Day weekend, that turned the blaze into a blast furnace. “It rolled through here like an atomic bomb went off,” Troutman said. “Everything was on fire.”

He fought the fire until there was nothing left — not even his house. Not far from where he spoke, tulips bloomed next to a car melted to the chassis.

The first days after the fire were a fog of dislocation. “I like my breakfast. I don’t have any frying pan. Or spatula. I don’t have nothing to cook it on. It goes on like that forever,” Troutman said. He is starting completely over, at 70, he said.

Troutman said he feels for the animals he has so long enjoyed living with, and feels a kinship with their struggle. Burned out of his home, he is now living in a travel trailer. “By God, it’s tough, and this wildlife is in the same predicament,” Troutman said.

“The sage grouse numbers were not great to begin with. A hundred years ago, there was probably somewhere else to go when they came back after a fire. Just like I need a house, they need habitat.”

Now, right as the land and all who rely on it need to heal, comes this cruel spring drought. “There is no damn rain, no damn rain,” Troutman said. “It just slows everything down.”

Troutman waves away concern saying, “Oh, we’ll be fine,” — perhaps a habit among those who endure in this landscape, shaped by cataclysm since its beginning.

A Rare, Ancient Habitat

Ancient floods and glaciers carved this land. It is too rocky to farm in many places, and the good ground mostly too small in area to bother grazing. Even after the arrival of settlers, much of this landscape was left to itself, as elsewhere farmers and ranchers established wheat farms and grazed horses, cattle and sheep.

The result, explains sage grouse expert and WDFW biologist Michael Schroeder, was that Douglas County was by 2020 still home to some of the finest shrubsteppe landscape left anywhere in western North America. Here remained a rugged, delicate beauty to be savored under open skies, accompanied by the song of meadowlarks. Some of the best of what was left of what had been a rolling inland sea of sere, sage green.

The plants of this now rare ecosystem are adapted to rainfall as scant as 6 inches a year, roasting sun and drying winds. Their stems and leaves are specially adapted to conserve moisture, and their root systems can pull water from down deep.

This landscape also is one of the last stands for some of the few species that can turn sagebrush into nutritious protein: the sage grouse, and the pygmy rabbit, native animals that have been part of this landscape for thousands of years.

As the shrubsteppe they depend on for food and cover has been lost to farming and grazing, both sage grouse and pygmy rabbit have declined in numbers. Losses that the WDFW among others, have been working to reverse by putting shrubsteppe into conservation, and even launching a breeding program to rebuild pygmy rabbit populations. 

Now comes the sad but necessary task, still underway, of assessing the setbacks to those programs and the damage to state wildlife lands.

Peterson, the wildlife area manager, walked through water birch groves blackened by the fire. Some were resprouting at the base of their charred trunks. But what, he wondered out loud, would the sharp-tailed grouse that love to roost in these trees, eating seeds and buds, live on this coming winter? And what of the sage grouse now without sagebrush?

These were not losses state wildlife managers had confronted on this scale before.

A Long, Uncertain Recovery

First light was just a smudge at dawn when Schroeder, the sage grouse expert, whispered in the still morning air, still cool and dewy from the night.

“Hear that?” Schroeder said. “They are here.”

What he had heard was a sound that is a signature of the West, a bubbling call made by strutting male sage grouse as they dance for a potential mate.

Tangerine and lemon streaked the sky as the growing light revealed sage grouse urgently pumping their chest up and down, as they pirouetted and paraded. They fanned their tails in a corona of spiky plumage meant to impress.

Theirs is a mating dance like none other, and sage grouse won’t dance just anywhere; they have parade grounds they return to year after year. As Schroeder watched through a telescope, he wondered aloud what will happen to the state’s sage grouse.

The birds weren’t killed outright by the fire; they likely flew miles away, Schroeder said. But they have come back to these places where they have always danced and nested. Theirs is a home they won’t leave, and so must start over. Like Troutman.

Schroeder expects sage grouse numbers will plummet at least at first in the years to come, as females forego nesting in favor of survival. Beyond that?

These birds have proven resilient, even learning to dance and eat in wheat fields. But what comes next is unknown. He hopes for a slow rebuilding — but this is a bird already isolated in a tiny breeding population. That adds to the risk of extinction.

Like Schroeder, Gallie is starting over with the task of rebuilding a population of an already rare animal. The fires wiped out a decade’s worth of infrastructure and work on behalf of pygmy rabbits, a state endangered species.

Gallie walked a remaining breeding enclosure in an unburned area, where adult pygmy rabbits produce young that WDFW staff release to the wild. The baby pygmy rabbits, just a few weeks old, were so small and so fast they were hard to spot in the sagebrush. For each brown, tiny-eared fuzz ball seen scooting to its burrow, Gallie figured there were 10 more not spotted.

No wonder, even the chunkiest adults are no bigger than an adult’s fist. 

Hannah Anderson, wildlife diversity division manager for the WDFW, said she was grateful the Legislature stepped in this past session with nearly $4 million urgently needed to help fund restoration and recovery of the state’s shrubsteppe wild lands, and the rare animals that depend on them. Private landowners who lost so much in the fires also received some help for essentials such as restocking hay supplies.

But recovery will still be a long and slow process — with many unknowns.

On a recent spring day, Peterson, the wildlife area manager, looked over burned ground that the WDFW had replanted in the Bridgeport unit of the state Sagebrush Flat Wildlife Area of Douglas County.

Dust puffed from behind his boots as he walked the charred ground. A few brave spears of grass shivered in a hard wind. Lupine was making a start, its purple flowers a jolt against the gray ground.

“I would be hesitant to use the word restore,” Peterson said of the work underway here. “When people talk about restoration, I say I can’t do in two years what nature took eons to create.”