#ColoradoRiver Negotiators Are Nearly Out of Time and #Snowpack — Jake Bolster and Wyatt Myskow (InsideClimateNews.org) #COriver #aridification

Ruh roh. Not looking good out there. Source: NASA.

Click the link to read the article on the Inside Climate News website (Jake Bolster and Wyatt Myskow):

February 4, 2026

With another federal deadline only weeks away and record-low snowfall further drying out the watershed, states have begun talking about whether they are prepared for litigation

Time and water are running low on the Colorado River.

Amid one of the driest winters on record, representatives from seven Western states have less than two weeks to meet an already-delayed federal deadline to find a new way to share the dwindling Colorado River—one that recognizes the megadrought and overconsumption plaguing the basin.

The current guidelines for implementing drought contingencies expire later this year, but as the Feb. 14 deadline looms, basin states, particularly Arizona and Colorado, have begun discussing the prospect of settling their disputes in court, suggesting that a deal is far from guaranteed. And while a meeting last week in Washington, D.C. between the Interior Department and all seven basin states brought some hope, state negotiators have again dug in their heels.

“I’ll certainly own whatever failure attaches [to me for] not having a seven-state agreement,” said Tom Buschatzke, the director of the Arizona Department of Water Resources and the state’s lead negotiator, in a meeting among the state’s stakeholders on Monday. “The only real failure for me, when I look in that mirror, is if I give away the state of Arizona’s water supply for the next several generations. That ain’t gonna happen, and I won’t see that as failure if we can’t come to a collaborative outcome. To me, that’s successfully protecting the state of Arizona.”

Those who hoped for a repeat of the winter of 2022-2023, when heavy snowfall across the West temporarily and partially replenished critical reservoirs, easing pressure on negotiators, are out of luck. With 2026’s winter about halfway over, it would take record amounts of snowfall for the Colorado River basin to climb back to merely average snowpack levels, said Eric Kuhn, the retired general manager of the Colorado River District and an author on Colorado River issues.

“People are mobilizing for potential litigation, and the question is, is somebody gonna pull a trigger?” Kuhn asked. “Hydrology may be the driving force. It may not be human action. It may be nature that forces us into litigation.”

The Colorado River basin spans parts of Arizona, California, Colorado, New Mexico, Nevada, Utah and Wyoming, and serves over 40 million people across the seven states, 30 tribes and Mexico. It contains dozens of watersheds, all but one of which—the Green River basin in Wyoming and slivers of Colorado and Utah—have experienced below-average or well below-average precipitation since October, when the new water year begins.

A storm in mid-January, which started in the West and brought several inches of snow to eastern parts of the country, did little to alleviate the drought.

“It’s a very critical situation right now,” Kuhn said. “This is climate change at work.”

Low Water, High Pressure

Low snowpack will result in less water melting into reservoirs across the basin come spring and summer. With less water stored, the Bureau of Reclamation’s options for managing the federal infrastructure along the river, including lakes Powell and Mead, the largest reservoirs in the nation, and their respective Glen Canyon and Hoover dams, will be constrained. 

Loveland Pass in Summit County on Dec. 24, 2025. The lack of snow is clearly visible on the higher peaks. Photo credit: Denver Water.

The dams provide hydroelectricity for more than a million people in the Southwest, but must hold water well above the turbines that generate power. If water levels at Lake Powell dip below “minimum power pool” for an extended period of time the agency would have to bypass the turbines, turning off the electricity they produce, and deliver water to the Lower Basin through lower outlets on Glen Canyon Dam, which could compromise the structure. At that point, the Bureau of Reclamation would have to choose between damaging the second-highest concrete-arch dam in the U.S. or reducing water releases to Arizona, California and Nevada, which would be a devastating blow to the region’s cities and economy. Some experts have predicted that could happen as soon as next summer or sooner if this winter’s dry spell continues.

Last September, Kuhn and a consortium of other hydrologists and Colorado River experts authored a report that found that if the current winter was similar to last year’s, Colorado River users would overdraw the river by 3.6 million acre-feet, and there would need to be “immediate and substantial” reductions in water use across the basin to prevent a total collapse of the system. One acre-foot is enough to supply water to two to four households. 

Now, with winter looking even more dismal than initially forecast, Kuhn says the Bureau of Reclamation’s options are “further constrained, unless things get wetter in the next two months.”

One option that Kuhn found likely was a big release from Flaming Gorge near the Wyoming-Utah border, the largest federally managed dam upstream of Lake Powell. He guessed the release could be anywhere from half a million to 1 million acre-feet of water. 

While today’s drought and low streamflows are a product of nearly three decades of aridification, water forecasters cannot say for sure how climate change will impact future water supplies. Under some models, precipitation remains low and consistent, but rising temperatures dry out soils across the basin, leading them to absorb more snowmelt and further reduce streamflow. 

Other hotter futures could also be wetter, Kuhn said, but this would not reinvigorate the river. “We’re expecting stream flows to continue their downward trend,” he said. 

And if that is the case, Mother Nature may be the deciding factor between a successful negotiation and litigation. 

Hydrologically speaking, we are living through a winter where “that’s a possibility,” Kuhn said. “I think it’s gotta put a lot of pressure on the states.”

Looming Litigation 

A resolution in the courts is looking increasingly likely.

During her state of the state address on Jan. 12, Arizona Gov. Katie Hobbs said the “Upper Basin states, led by Colorado, have chosen to dig in their heels instead of acknowledging reality” during negotiations. 

The state, she said, had established a $1 million legal fund in anticipation of litigation, with a bipartisan bill introduced to add another $1 million to it. This will “keep putting Arizona first and fight for the water we are owed,” she said.

“As negotiations continue, I refuse to back down.”

Arizona Governor Katie Hobbs at signing ceremony November 19, 2024. Photo credit: ADWR

A week later, Colorado lawmakers asked Becky Mitchell, the state’s lead negotiator, about its prospects in litigation. “We are gonna have the best lawyer,” she said. “We will be ready.”

Earlier in the week, Colorado Attorney General Phil Weiser assured state lawmakers that he is prepared to go to court and blamed the other basin for the lack of a deal. 

“The reason it’s hard to get a deal is you need two parties living in reality. And if one party is living in la la land, you’re not going to get a deal,” he said. “I’m committed to not getting a bad deal just to get a deal.”

The Upper Basin states of Colorado, New Mexico, Utah and Wyoming, and the Lower Basin states of Arizona, California and Nevada sounded far apart on a deal at the annual Colorado River Water Users Association conference in Las Vegas last December. Some negotiators advocated for a short-term agreement while others called for greater federal pressure.

Last week, negotiators from all seven basin states met in D.C. to try to break the impasse. After the meeting, governors Spencer Cox, of Utah, and Mark Gordon, of Wyoming, said in a joint statement that “all acknowledged that a mutual agreement is preferable to prolonged litigation,” and both felt encouraged by the results of the meeting.

In a separate statement, Arizona Gov. Hobbs said she was also encouraged, and that the states “reaffirmed our joint commitment to protecting the river.” Arizona has been and remains willing to continue bringing solutions, she added, “so long as every state recognizes our shared responsibility.”

Earlier this month, the federal government released a range of alternativesoutlining how it would manage the system if no deal is reached by Feb. 14. If that deadline passes without an agreement, the political and environmental situation across the basin may become as grim as the snowpack. 

Arizona officials have said any of the federal government’s proposals would likely lead them to pursue litigation and that the Bureau of Reclamation’s draft Environmental Impact Statement puts all the risk of the river’s decline on the Lower Basin and does not comply with the bedrock law of the river. Under the outlined federal proposals, the vast majority of the cuts would affect Arizona, which relies heavily on the river for water but holds junior rights, often making it the first to face significant reductions. The state has already had a third of its water rights to the river cut.

“The entire weight of the river cannot fall on Arizonans, the Valley [Phoenix] and the Tucson metro areas,” said Brenda Burman, general manager of Central Arizona Project, the entity delivering Arizona’s Colorado River water, at a press conference Monday. “That’s not acceptable. We, as water managers … we will make sure that there is water flowing.”

The structural deficit refers to the consumption by Lower Basin states of more water than enters Lake Mead each year. The deficit, which includes losses from evaporation, is estimated at 1.2 million acre-feet a year. (Image: Central Arizona Project circa 2019)

The Lower Basin has volunteered to cut 1.5 million acre-feet, the amount of water lost to transpiration and evaporation in a year, and asked that the Upper Basin share in cuts after that amount. The Upper Basin, which has never used the full amount it is entitled to on paper, has proposed making only voluntary cuts to its use.

Sarah Porter, director of the Kyl Center for Water Policy at Arizona State University, said she’s felt litigation is increasingly likely since the basin states missed their initial federal deadline in the fall and their negotiations began to deteriorate. 

“I believe that everybody has kind of stared it down and concluded that litigation isn’t such a horrible idea that it needs to be avoided,” she said.

As a former litigator, Porter said the threat of legal action may force both sides to develop their arguments along with facts and data supporting them, which could provide the clarity needed for a settlement. But a lawsuit would extend the uncertainty surrounding the region’s water supply, Porter said, affecting the planning of cities, tribes and farmers waiting for new guidelines.

Litigation would likely focus on one of the most crucial sections in the 1922 Colorado River Compact: Article III(d)

Under this part of the agreement, the Upper Basin “will not cause the flow of the river at Lee’s Ferry,” a point just south of Glen Canyon dam, “to be depleted below an aggregate of 75,000,000 acre-feet for any period of ten consecutive years.” Should the average flow at Lee’s Ferry fall below an average of 7.5 million acre-feet, which is a possibility given current hydrological conditions, the Lower Basin could sue the Upper Basin for failing to uphold this part of the compact.

“High-Stakes Poker”

Any lawsuit would be risky. 

“That language has never been interpreted by a court,” said Anne Castle, a senior fellow at the Getches-Wilkinson Center at the University of Colorado and a former assistant secretary for Water and Science at the Interior Department. “This is high-stakes poker for both basins.”

The Lower Basin would presumably argue that Article III(d) means the Upper Basin has an obligation to deliver water, so it would have to adjust its consumption to ensure the Lower Basin receives 7.5 million acre-feet annually. 

But the Upper Basin could counter that Article III(d) only prohibits it from overconsuming the river and leaving less than 7.5 million acre-feet at Lee’s Ferry, and climate change is actually responsible for the meager flows. In that case, they would bear no obligation under the compact to make cuts. 

Porter said the Upper Basin’s interpretation flies in the face of history. The whole reason the compact exists was the fear California would take all of the river’s water at the time, she said, because that’s where the growth was.

“It is silly to think that California would agree to a deal with the Upper Basin that said they have no responsibility to leave water for California,” she said. 

For decades, the Upper Basin cited its delivery obligation to California, Arizona and Nevada to justify building a series of dams and reservoirs above Lake Powell, Porter said.

“There’s a huge amount of evidence that the Upper Basin states … needed those reservoirs upstream because they had an obligation to deliver water to the Lower Basin,” she said.

Even if Congress originally authorized Upper Basin reservoirs to help satisfy provisions in the compact, “that doesn’t tell us what those obligations actually are,” Castle said. “Fixed number obligations don’t work with a changing climate that is causing shrinking flows.”

Not every state is eager to initiate litigation. Wyoming Senior Assistant Attorney General Chris Brown appeared before state lawmakers in January and warned of the pitfalls of letting Congress or the Supreme Court dictate what happens on the river.

Still, “as a headwater state, Wyoming has a long history of zealously defending its rights to use interstate waters, and the rights of its water users,” Brown said in an email. “The Colorado River is no different.”

Tina Shields, water manager for the Imperial Irrigation District, which is California’s biggest and most senior water rights holder, said in a statement that the state continues to work on finding a consensus agreement among all the states that depend on the Colorado River, but could not comment on the status of those negotiations.

“The Colorado River hydrology is unlikely to wait for a court decision, so any speculation about litigation is premature,” she said.

Although Arizona’s Lower Basin counterparts have not touted litigation as an option, Buschatzke said he is confident they will support the state, as compliance with Article III(d) affects them too, though less severely.

And the states may not be the only entities to sue. Under a 2004 water settlement, the Gila River Indian Community receives 653,000 acre-feet of Colorado River water a year, a significant allocation. But getting that water depends on the Central Arizona Project (CAP) not getting its water allotment cut.

Any unilateral action by the Department of the Interior to reduce that flow “would, in our view, constitute a blatant violation of the United States trust responsibility to protect our CAP water as established by Congress under the Arizona Water Settlement Act,” said Gila River Indian Community Gov. Stephen Roe Lewis at the Arizona meeting of water stakeholders.

While litigation may clear up some of the murkier language in the compact, Castle wasn’t sure that it is the best way forward for the river’s stakeholders—particularly since these kinds of disputes can take years to resolve. 

“We might get answers to a few questions after years,” she said, “but we have a river to operate in the meantime.”

Map of the Colorado River drainage basin, created using USGS data. By Shannon1 Creative Commons Attribution-Share Alike 4.0

Civil Servants Arrange Buffet for #ColoradoRiver Negotiators — Brian McNeece #COriver #aridification

Carly Jerla speaking at the Colorado River Water User’s Association Conference December 5, 2024. Photo credit: USBR

From email from Brian McNeece:

January 27, 2026

Colorado River negotiations have bogged down, but dozens of experts at the Bureau of Reclamation (BOR) have been streaming right along. On Jan. 14, the BOR released its draft Environmental Impact Statement (EIS), which is bureaucratese for a report on options for the negotiators after the current rules expire this year.

It’s a bit complicated. The report includes a modeling of 1,200 possible future scenarios for the entire Colorado River system and runs 1,600 pages. Just the Executive Summary is 66 pages. The theme of this massive undertaking is deep uncertainty. In fact, that is the name of the modeling process: Decision Making Under Deep Uncertainty.

What’s uncertain? Well, in a word: the weather. And not just the weather, but also population growth and water use patterns. Most scientists agree that climate change includes aridification, or a general drying of the Colorado River basin, but it’s impossible to quantify reliably. Thus the 1,200 futures.

This massive report took two and a half years to compile with the help of around 150 people with expertise in everything from hydrology to chemical engineering to wildlife management to socioeconomics to anthropology to law. Browsing through it, I marveled at the depth of analysis and the advanced computational and mathematical tools brought to bear on a question, which at the end of the river, is a political one. I thought, does anyone understand all of it? But when I looked at the top of the list of preparers, I realized that yes, someone does.

And that is Carly Jerla. She’s the Senior Water Resources Program Manager for the Bureau of Reclamation. Ms. Jerla was hired by the BOR in 2005 as a graduate student at the University of Colorado’s Center for Advanced Decision Support for Water and Environmental Systems. She is trained in civil and environmental engineering and public policy. Twenty years on, she’s the boss of this effort.

I’ve watched Ms. Jerla in action at several of the recent Colorado River Water Users Association (CRWUA) conferences in Las Vegas. A petite woman, Carly has a disarmingly low, warm voice. Speaking to a crowd of 1,700 people, she talks as if she’s having an over-the-fence conversation with a neighbor. But as the overlays of data stacked up on her slides, I could sense her losing the audience. It was just too much.

We saw a draft of the current report in 2024. Since then, it has grown massively, but the same dilemma exists and can actually be summed up simply. In re-writing the rules for how the water of the river gets divvied up, they need to decide what triggers shortage conditions, how much cuts each contractor must take under those conditions, and where shortages are measured. In the past, Lake Mead and Lake Powell had separate conditions, and the reservoirs above Lake Powell were not in play. Ms. Jerla’s report emphasizes that the entire system should be considered in the rules, not just the two giant reservoirs.

There are currently five major alternatives being proposed. This first one, called the No-Action Alternative, is also the no-go alternative, since it returns us to the world prior to the 2007 guidelines for shortages. The No-Action Alternative would drain the reservoirs. So negotiators must choose one of the other four alternatives. All of them make heavy cuts, either based on prior appropriation (i.e. the Law of the River) or pro rata (i.e. proportional cuts for everyone).

Is there a Goldilocks alternative among the other four? One that splits the difference between the historical, asymmetrical Law of the River and the fairness in a pro rata plan? No, there isn’t. That’s why we’re stuck.

There’s one future scenario that is completely omitted from the alternatives. Colorado’s negotiator Becky Mitchell has repeatedly called for the Upper Basin states to get MORE water. She points out that the Colorado River Compact of 1922 allocated the Upper Basin the same amount allocated to the Lower Basin states — 7.5 million acre feet. But that’s 3 million more acre-feet than the Upper Basin has ever drawn from the system. 

None of the five alternatives, and apparently not one of Carly Jerla’s 1,200 possible futures, includes that premise. So if the Upper Basin negotiators are staking their claim on the river to include more water for them, they are way off the mark. Their next best hope is to take no cuts, but that option won’t float in the Lower Basin.

Trying to make a decision under Deep Uncertainty is tough, tough work. Carly Jerla and her team have laid out the buffet for the representatives from the states along the Colorado River. Time to pick from the menu. 

Map of the Colorado River drainage basin, created using USGS data. By Shannon1 Creative Commons Attribution-Share Alike 4.0

#Colorado’s constitution has been amended repeatedly since 1876, when Colorado achieved statehood, but the provision setting forth prior appropriation has not been touched — Ken Neubecker #ColoradoRiver #COriver #aridification

How #Colorado sees the #ColoradoRiver stalemate — Allen Best (BigPivots.com) #COriver #aridification

Becky Mitchell. Photo credit: Allen Best

Click the link to read the article on the Big Pivots website (Allen Best):

February 2, 2026

Snowpack realities must be recognized by all seven Colorado River Basin states, says Becky Mitchell, Colorado’s chief negotiator

Becky Mitchell was particularly busy during the last week of January. On Wednesday, Jan. 28, she opened the annual Colorado Water Congress conference with a 1,100-word speech (the prepared remarks are below) that reiterated Colorado’s position in the stalemated Colorado River discussions.

Lower-basin states, said Mitchell, Colorado’s chief negotiator in Colorado River affairs, must fully come to terms with the changed realities on the Colorado River. “This means releases from Lake Powell must reflect actual inflows, not political pressure,” she said. “If reductions aren’t real, reservoirs won’t recover.”

The next day, Mitchell was in Washington D.C. along with Colorado Gov. Jared Polis and the governors of five of the six other basin states. California Gov. Gavin Newsom, who cited pre-existing family commitments, was the only governor absent.

The New York Times on Saturday reported that the governors achieved “no breakthrough — and whether they made progress was unclear.” Mitchell was quoted in that story saying upper basin states “cannot and will not impose mandatory reductions on our water rights holders to send water downstream.”

In other words, as she had said Colorado water users must live with the hydrologic realities, including this one of almost no snow. Colorado does not have the giant reservoirs of Powell and Mead upstream.

Others, including Eric Kuhn, the former general manager of the Glenwood Springs-based Colorado River Water Conservation District, have urged a new model based on proportionate cutbacks, not absolute numbers. See: “Dancing With Deadpool on the Colorado River,” Big Pivots. Dec. 12, 2025.

That is how the four upper-basin states among themselves apportioned their share of the river flows in their 1948 compact. The 1922 compact used absolute numbers, i.e. 7.5 million acre-feet for each basin.

The Colorado River Compact of 1922 among the seven basin states uses some language that can be interpreted very differently about delivery obligations. That is a long, involved story — that may eventually be decided by the Supreme Court.

The Arizona Daily Star, however, reported a nuance of possible importance in statements made by Mitchell and Polis afterward. Mitchell emphasized “voluntary” conservation in the upper basin, while Polis said Colorado remained “committed to working collaboratively to find solutions that protect water for our state, while supporting the vitality of the Colorado River and everyone who depends on it.”

An Arizona source told the Daily Star’s Tony Davis that some Upper Basin governors appeared open to possible mandatory, as opposed to voluntary, conservation measures. “I think the other Upper Basin states expressed a willingness to put water on the table in a way that Colorado has not,” said the source, who asked for anonymity to protect continued participation in interstate river discussions.

But again, Colorado insists that it already has mandatory cutbacks — the ones imposed by Mother Nature. Using the prior appropriation doctrine to sort out priorities, Colorado restricts uses even in the more water-plentiful years. This year, the most “junior users” will most definitely not get water.

The black line in this chart represents snow-water equivalent in Colorado’s snowpack as of Feb. 1 relative to 1991-2020, a time frame of which about two-thirds consisted of drought and aridification. The map below shows the snow-water equivalent as of Jan. 31 by basin.  More can be found at the Natural REsources Conservation Service.

Amy Ostdiek, the Colorado Water Conservation Board’s chief for interstate, federal, and water information, made that point in remarks at the Water Congress the day after Mitchell’s speech.

“These reductions in the upper basin are mandatory. They’re uncompensated. They’re the job of each state engineer’s office to go out and shut off water rights holders when that water isn’t available. And what that means in practice is that many years you have pre-compact water rights dating back to the 1800s getting shut off.”

The complications of mandatory reduction of water uses also came up in a session with state legislators at the Water Congress.

Ken Neubecker, a long-time Colorado River observer affiliated with environmental groups, said mandatory cuts to Colorado River water use would require an amendment to Colorado’s state constitution and likely those of other upper-basin states.

Colorado’s constitution has been amended repeatedly since 1876, when Colorado achieved statehood, but the provision setting forth prior appropriation has not been touched.

“I don’t think you will get an amendment that will give the state any kind of authority to enact mandatory cutbacks beyond existing administrative cutbacks,” said Neubecker. “That’s just not in the cards.”

The upper-basin states also differ fundamentally with lower-basin states in that the lower basin states have just a few giant diversions, such as the Central Arizona Project and the Imperial Valley. The headwaters states have thousands of legal diverters. That also makes application of mandatory diversions more difficult.

These facts would together make mandatory costs a legal and logistical nightmare to administer.

The states have a deadline imposed by the federal government, as operator of the dams, to agree how to share a shrinking river.

Later this year, Mother Nature may impose an even harsher deadline if current thin snowpack continues to prevail. The statewide snowpack was 58% of average as of late January when the Water Congress conference was getting underway.

One barometer, if imperfect, of the snowpack is the snowpack on Vail Mountain. On Jan. 15, the Vail Daily’s John LaConte reported that the Snotel measuring site at the ski area showed the worst snowpack reading in 44 years of measurements.

The opening of Vail’s Back Bowls also testifies to dryness of the Colorado River headwaters. As recently as 2012, a notoriously dry year, that south-facing ski terrain was not opened until Jan. 19, according to David Williams of the Vail Daily. On Jan. 26, he reported another foot of snow was necessary to open it.

In June 2023, Polis appointed Mitchellto her current position, as Colorado’s first full-time commissioner to the Upper Colorado River Commission. She had previously overseen the Colorado Water Conservation Board.

“Mitchell will now navigate the deep challenges of the Colorado River in this upgraded position, supported by an interdisciplinary team within the Department of Natural Resources and support from the Colorado Attorney General’s Office,” said the announcement.

“The next few years are going to be incredibly intense as we shift the way that the seven basin states cooperate and operate Lakes Powell and Mead,” Mitchell said in that 2023 announcement. “Climate change coupled with Lower Basin overuse have changed the dynamic on the Colorado River and we have no choice but to do things differently than we have before.”

Becky Mitchell’s prepared remarks

#Colorado is gearing up to fight for water rights as the #ColoradoRiver stalemate continues — The Summit Daily #COriver #aridification

Colorado River “Beginnings”. Photo: Brent Gardner-Smith/Aspen Journalism

Click the link to read the article on the Summit Daily website (Ali Longwell). Here’s an excerpt:

January 27, 2026

As Colorado continues to negotiate with the seven Colorado River basin states on the post-2026 operations of Lake Powell and Lake Mead, the state’s attorney general and lead negotiator are ready for a legal battle if the states continue to clash.

“If it comes to a fight, we will be ready,” said Becky Mitchell, the Colorado River commissioner, who represents the state on the Upper Colorado River Commission, at the Jan. 23 SMART Act hearing for the Colorado Department of Natural Resources, where the agency provided its annual update on priorities and programs to lawmakers. 

After two years of back and forth, Colorado River basin states remain deadlocked, unable to agree on the guidelines for how Lake Powell and Lake Mead should operate beyond 2026. The operations of these two critical reservoirs have widespread implications for the approximately 40 million people, seven states, two counties and 30 tribal nations that rely on the river…In Colorado, the Colorado River and its tributaries provide water to around 60% of the state’s population. 

“We developed priorities that continue to serve as my north star as we negotiate these post-2026 operational guidelines,” Mitchell said. “The most important of these priorities is to protect Colorado water users. This means that our already struggling water users and reservoirs cannot be used to solve the problem of overuse in the lower basin.” 

[…]

Despite disagreements over how the reservoirs should operate in an uncertain future, reaching a consensus between the seven Colorado River basin states remains the objective for all involved, but time is ticking.  The U.S. Bureau of Reclamation — which manages Lake Powell and Lake Mead — has given the states until Feb. 14 to reach an agreement before the federal agency steps in and makes the decision itself.  Mitchell told lawmakers that she was still “optimistic” about reaching a consensus by the deadline, adding that she will “sit in the room with the full intent to negotiate,” as long as there are “willing parties.” 

“Folks should start worrying when I’m no longer in the room,” she said. “I will, 100%, be focused on a deal until there’s not a deal to be had.”

Map of the Colorado River drainage basin, created using USGS data. By Shannon1 Creative Commons Attribution-Share Alike 4.0

Putting land into the public’s hands: And other bits and pieces — Jonathan P. Thompson (LandDesk.org)

Fields, trees, and the Abajos. North of Dove Creek, Abajo Mountains in the distance. Photo credit: Jonathan P. Thompson/The Land Desk

Click the link to read the article on The Land Desk website (Jonathan P. Thompson):

January 30, 2026

Updated to get the graphics right.

🌵 Public Lands 🌲

If you’ve ever floated the Gunnison River in western Colorado through the Dominguez-Escalante National Conservation Area between Delta and Grand Junction, you’ve probably noticed that the land on either side of the stream alternates between public parcels and private ranch land. If the Bureau of Land Management has its way, some 4,000 acres of that private land will soon be entering the public domain, according to reporting from the Grand Junction Daily Sentinel. That’s right, the agency is putting more lovely land into the public’s hands. 

The parcels were formerly operated as a ranch by Dick Miller. After he died, the Conservation Fund purchased the land from Miller’s son for an undisclosed amount in order to sell it to the BLM. The associated BLM grazing leases will reportedly be transferred back to the BLM, but it isn’t clear whether they’ll be made available for grazing again.


The BLM is also looking to put a lot of public land into oil and gas companies’ hands. The agency is seeking public input on proposals to lease 74 parcels covering 33,530 acres in New Mexico, and 271 oil and gas parcels totaling 357,358 acres in Wyoming

The New Mexico parcels are mostly in the Permian Basin, but do include tracts in the San Juan Basin located north and northeast of Chaco Culture National Historical Park (but not within the ten-mile buffer zone, which remains in place — for now). 

The Wyoming parcels are concentrated in the southern part of the state between Rawlins and Green River, the central part of the state, and the Powder River Basin.

🦫 Wildlife Watch 🦅

Wolves in the West have had a rough go of it ever since white settlers showed up in the 1800s and proceeded to slaughter them en masse. And while they’ve been able to recover somewhat in the Northern Rockies, thanks in part to endangered species protections and reintroduction efforts, the move to bring them back to Colorado and the Southwest has hit obstacles — and tragedy, including:

  • Another reintroduced wolf has died in Colorado, reports the Colorado Sun’s Tracy Ross, bringing the total number of wolf fatalities since the start of reintroduction to 11. The cause of death has not been determined.
  • Meanwhile, Colorado Parks and Wildlife has paused new wolf reintroductions because it hasn’t been able to find another state or tribal nation to provide the animals.
  • Utah Department of Agriculture officials killed three wolves in the northern part of the state on Jan. 9. While wolves are protected by the Endangered Species Act in most of the state, they were delisted in one small section along the Wyoming border when protections were lifted for the Northern Rockies population. Now, apparently, the state will kill any wolves that wander into that area, just because they can, and to prevent them from going into the protected zone. That’s despite the fact that the three animals had not killed or stalked any livestock. “I have not heard any of my neighbors, and we haven’t had the experience ourselves that we’ve had actual issues with our cattle and wolves,” area livestock owner Launie Evans told KSL.
  • And in more sad news: “Taylor,” the Mexican gray wolf that wandered out of southern New Mexico and into the Mt. Taylor region, was found dead on I-40 near Grants. Taylor first roamed onto Mt. Taylor early last year, apparently not realizing that the feds don’t allow wolves to cross I-40. Wildlife officials captured him and deported him back to the southland, but he was persistent, and simply turned around and headed north again. He was removed again in November, but couldn’t stay away from Mt. Taylor. This time, on his return journey, he was struck by a vehicle.

    “Taylor’s death is a heartbreaking reminder that highways like I-40 are not just lines on a map, they are lethal barriers for wildlife,” said Claire Musser, executive director of the Grand Canyon Wolf Recovery Project, in a statement. “Abolishing I-40 as a management boundary is long overdue. If we are serious about recovery, we must allow wolves to move freely across suitable habitats and invest in wildlife crossings and landscape-scale connectivity so highways no longer function as death traps.”
  • And, finally, CPW’s latest map of wolf activity is out (at the top of this section), and it shows that wolves have been wandering into new parts of the state. Folks in the Silverton area might just be seeing some soon. If you think you see one, but aren’t sure if it’s a wolf or coyote, this little guide from CPW might help:


Longread: On wolves, wildness, and hope in trying times: How Ol Big Foot’s story restored a shard of optimism — Jonathan P. Thompson


⛏️ Mining Monitor ⛏️

Public Citizen just released an accounting of some of the ways the Trump administration is subsidizing global mining corporations and their operations on public lands — and the ways in which executives made off like bandits as a result. It’s worth reading the whole report, but here are just a small sampling of highlights:

  • $8.8 million: Amount 13 mining corporations, including Rio Tinto, Resolution Copper, South32, Lithium Americas, and Ambler Metals, spent on lobbying in 2025.
  • $3.5 million: Amount Lithium America paid Interior Department official Karen Budd-Falen’s husband for water rights for its Thacker Pass mine in Nevada. The federal government also took a 5% stake in the company and the mine as a condition of preserving a Biden-era loan.
  • $400 million: Amount the U.S. Defense Department paid for a stake in Las Vegas-based MP Materials, which owns the Mountain Pass rare earths mine in California. The Pentagon also loaned the company $150 million.

The Bureau of Land Management approved the Grassy Mountain gold and silver mine on 469 acres of public land in Malheur County, Oregon. The action allows Paramount Gold Nevada to develop an underground mine, an onsite mill, and “associated storage” (which I’m taking to mean they’ll be able to dispose of toxic mill tailings on public land mining claims).

📖 Reading (and watching) Room 🧐

Here’s a great piece by Leah Sottile, who has written authoritatively on right-wing movements and more, on the plague of hypocrisy going around right now.


The Truth Does Not Change According to Our Ability to Stomach It: 67. Hypocrisy On the whiplash of this chaotic moment — Leah Sottile


The Border Chronicle is indispensable reading these days and, well, always. This piece, titled Border Patrol Nation, is an important look at the violent history of the Border Patrol.

*

And you really should be reading Wayne Hare’s writing over at the Civil Conversations Project.


📸 Parting Shot 🎞️

Speaking of hypocrisy: I’m sure most of you have heard Trump administration officials saying that federal ICE and/or CPB agents shot Alex Pretti because he brought a gun to a protest. The photos below were all captured at the May 2014 Recapture rally in Blanding, Utah. Quite a few of the attendees — who were on hand to protest “federal overreach” — were armed. None of them were shot. Just sayin’.

Folks exercising the right to bear arms at Recapture Canyon to protest federal overreach. Photo credit: Jonathan P. Thompson

Musical Sendoff

Governors leave DC with no deal on #ColoradoRiver, mixed messages — Tucson.com #COriver #aridification

Map of the Colorado River drainage basin, created using USGS data. By Shannon1 Creative Commons Attribution-Share Alike 4.0

Click the link to read the article on the Tucson.com website (Tony Davis). Here’s an excerpt:

January 31, 2026

Arizona Gov. Katie Hobbs and leaders of the six other Western states that rely on the Colorado River ended a Friday meeting in Washington, D.C. with no deal to end a stalemate over rights to the river’s dwindling water supply. Hobbs indicated that progress was made thanks to newfound flexibility from upstream states over their willingness to make commitments to cut some of their river water use, as the Lower Basin states, including Arizona, have already done. But Colorado officials all but directly contradicted Hobbs’ comments, saying they and Upper Colorado River Basin states were sticking to their position opposing any mandatory water use cuts on their part. The meeting was hosted by U.S. Interior Secretary Doug Burgum…

“I was encouraged to hear Upper Basin governors express a willingness to turn water conservation programs into firm commitments of water savings,” [Katie] Hobbs posted on social media after the two-hour meeting. “Arizona has been and will continue to be at the table offering solutions to the long-term protection of the river so long as every state recognizes our shared responsibility…

Mitchell said, “Colorado is committed to being part of the solution, and with our Upper Basin partners, we have offered every tool available to us. This includes making releases from our upstream reservoirs and establishing a contribution program as part of a consensus agreement. However, any contributions must be voluntary, and we have real ideas and plans to achieve the goals…”As several upper basin governors clearly stated at the meeting, we cannot and will not impose mandatory reductions on our water rights holders to send water downstream,” she wrote. “Our water users are already facing uncompensated reductions through state regulation. In many cases, these reductions impact 1880s water rights that predate the (Colorado River) Compact. Any contribution program must recognize our hydrologic realities: we simply cannot conserve water that we do not get to begin with.”

[…]

Mitchell spoke in even stronger terms earlier in the week at a public talk she gave in Aurora, a suburb of Denver. She spoke at the annual meeting of the Colorado Water Conference, a professional association that advocates for policies and laws that protect the state’s waters.


Upper Colorado River Commissioner Becky Mitchell’s prepared remarks “This is the river we actually live with” for the Colorado Water Congress Annual Convention January 28, 2026 — Coyote Gulch


“For more than a century, we built a system on optimism and entitlement. We planned for abundance, labeled it normal, wrote it in the law, and when the water showed up, we spent it,” Mitchell told the gathering, in remarks reported by the Colorado Sun news website. “When it didn’t, we blamed the weather, climate change or each other. Anything but the simple math.”

The seven states need to tie reservoir releases more closely to the actual amount of water coming in, Mitchell said in an interview after the speech. That was a nonnegotiable for the Friday meeting, she said. Overuse by the Lower Basin is draining the system, Colorado officials say.

Udall/Overpeck 4-panel Figure Colorado River temperature/precipitation/natural flows with trend. Lake Mead and Lake Powell storage. Updated through Water Year 2025. Note the tiny points on the annual data so that you can flyspeck the individual years. Credit: Brad Udall

Ancient energy sources power the future: The AI Age perpetuates #fossilfuel burning. — Jonathan P. Thompson (High Country News) #climate

Welcome to the Landline, a monthly newsletter from High Country News about land, water, wildlife, climate and conservation in the Western United States. Sign up to get it in your inbox. Screenshot from the High Country News website.

Click the link to read the article on the High Country News website (Jonathan P. Thompson):

January 29, 2026

The latest iteration of the Information Age appears to have arrived in full-force, manifested as AI, the digital cloud, remote work and the mass migration from the material world into cyberspace. 

A couple of decades ago, when I was feeling optimistic, I envisioned this future as a Jetsons-esque world, where the noisy clang of machinery would give way to a soft electrified hum while robots and artificial intelligence performed menial and mundane tasks, freeing us to live like George Jetson, working a leisurely nine hours a week as a digital index operator at a space sprocket firm. 

This new era would be a vast improvement over the worn-out Industrial Age, mainly because it would come with an energy transition. We would ditch our clanky old machinery — all the smokestacks and pollution and internal combustion engines — trading them for sleek cars that, if not flying, would at least be electric, powered by cleaner, gentler and quieter forms of energy, like wind and solar. 

Data center construction at 49th & Race, Denver. Photo credit: Allen Best

But now, the future is here and AI is everywhere, whether you want it to be or not. It can’t yet wash the dishes, and even though it’s begun taking people’s jobs, it hasn’t erased the need to work for a living. It can, however, correct your spelling errors, help researchers crunch huge datasets, diagnose illnesses and even provide what passes for mental health counseling. It can also inject language you never intended into your messages without your knowledge, churn out inane emails and stilted high school essays, and casually plagiarize artists, writers and journalists. 

This new age has its marvelous aspects, I suppose, but it is also disappointing — even baffling. It’s true that it has coincided with the clean(er) energy transition; coal-burning for power generation has been declining since 2007, while solar, wind and battery storage have boomed. And yet instead of allowing us to abandon the most outdated component of the Industrial Age — the production of power via fossil fuel combustion — the Information Age has helped perpetuate this dirty habit. Our most futuristic, newfangled technologies continue to rely on prehistoric energy. 

Every AI query or other cyber-operation that relies on cloud computing is processed by data centers, warehouse-like buildings housing row after row of servers that churn through digital information. Each individual operation might use a fairly small amount of power, but a single data center handling millions of queries per day can guzzle as much electricity as an entire city. 

And now, the buildup of energy-intensive, AI-processing hyperscale data centers threatens to outpace the energy transition, while giving fossil fuel-boosters justification for continuing to rely on dirty energy sources. To meet the burgeoning demand for power, utilities are nixing plans to shutter old coal and nuclear plants, and data center developers are even constructing new natural gas generators to power their facilities. 

Each time you or I queue up an old Jetsons episode on YouTube or ask ChatGPT whether a video was real or fabricated by Grok, the request travels at roughly the speed of light to a data center. Perhaps that data center happens to be a grid-connected facility in, say, the Phoenix metro area, where hyperscale data centers are sprouting like cheatgrass. The facility’s GPUs and CPUs run off electricity funneled in from transmission lines that connect to power plants spread across the utility’s entire grid. 

That means there’s a good chance that some of that power is coming from the Four Corners coal power plant in northwestern New Mexico, or from natural gas plants burning methane from the oil and gas fields in the nearby San Juan Basin. 

How did all that coal and methane get there in the first place? We have to go back some 145 million years to the beginning of the Cretaceous period, when a shallow, briny sea covered much of what is now the Interior West. Over thousands of millennia, the sea advanced and retreated numerous times, laying down layers of sediment — sand, mud, clay — each time, supplemented by silt carried by huge rivers originating in adjacent mountain ranges.

An artist’s reconstruction of a ‘Sarabosaurus dahli’ swimming with ammonites and fish in southern Utah 94 million years ago. Andrey Atuchin/Bureau of Land Management

Embedded within the sediment was organic material, including plants, algae, bacteria, plankton and other microorganisms — along with much larger creatures, from Cretalamna (a megatooth shark) to the Sarabosaurus dahli, which might have resembled some combination of fish, seal and lizard. As the sediment piled up and was subjected to heat and pressure, each layer was transformed into a rock formation: the Dakota sandstone, the Mancos shale, the Mesa Verde sandstone and more. Meanwhile, the organisms decomposed in an oxygen-free environment, eventually transforming into crude oil and methane, or natural gas. 

In the Late Cretaceous, before the dinosaurs went extinct 66 million years ago, the sea retreated for the final time, leaving behind vast freshwater swamps in what is now the San Juan Basin. The climate back then was downright sultry — rainy and warm and almost tropical. Trees and plants grew profusely in and around the shallow marshes, and fallen leaves and toppled trees decayed rapidly, leaving behind deep accumulations of decayed vegetal matter, or peat. Ultimately, this, too, would be transformed by pressure, heat and millions of years into thick, methane-infused coalbeds that are now part of the Fruitland formation.

Coal Mine Canyon is lined with reddish sandstones and siltstones of Mesozoic age. The Canyon is situated in a remote locale bordering the eastern edge of the Painted Desert. On the mesa above the canyon, are longitudinal sands dunes. The quality of coal in the canyon is poor and active coal mining was discontinued decades ago. Photo credit: Ted Grussing/University of Arizona

These days, huge draglines with house-sized shovels tear into the earth at the Navajo Mine, exhuming the remnants of those swamps at a rate of about 14,000 tons daily. The carboniferous rocks are then shipped a few miles north to the Four Corners power plant. In the nearby gas fields, drillers have poked tens of thousands of holes in the ground and hydraulically fractured the rock formations to get at the hydrocarbons, the physical memories of ancient sea creatures, which are then processed and piped to natural gas power plants.

The fuels are burned, releasing carbon and other pollutants that have been stored for millions of years underground, to generate enough steam to turn turbines to spark an electromagnetic field and send electrons across the desert in massive transmission lines to the Arizona grid. From there, they travel to the data center’s server banks, businesses and homes, ultimately ending up in the outlet next to your bed where you charge your phone. 

Fossil fuel combustion made the Industrial Age possible and continues to drive much of society, both in and out of cyberspace. Yet when you factor in the immense amounts of time, human labor, energy and downright violence required to extract and process and transport these fuels, the whole endeavor seems increasingly bizarre. The strangeness is only magnified by the fact that this ancient form of energy powers the newfangled technology of the Information Age, especially when the same technology has given us access to an abundance of renewable, cleaner forms of power.

#ColoradoRiver governors express cautious optimism after ‘historic’ DC meeting Caitlin Sievers (ArizonaMirror.com) #COriver #aridification

A high desert thunderstorm lights up the sky behind Glen Canyon Dam — Photo USBR

by Caitlin Sievers, Arizona Mirror
January 30, 2026

With the deadline to reach a water usage agreement looming, leaders from the seven Colorado River Basin states expressed cautious optimism that their “historic” meeting in Washington, D.C., will spur the compromise needed to reach a consensus.

U.S. Secretary of the Interior Doug Burgum called the meeting at the request of Arizona Gov. Katie Hobbs, after the states blew past a Nov. 11 deadline to reach an agreement. The new Feb. 14 deadline was set by the Bureau of Reclamation, which manages water in the West under the Interior Department. 

Arizona stands to see the largest cuts if the states can’t reach an agreement, because its Central Arizona Project is one of the newest users of the river water, making it legally one of the first to be cut.

The Colorado River is a vital source of drinking water for 40 million people in the seven basin states, Mexico and 30 Native American tribes, and provides water for farming operations and hydroelectricity. 

One of the biggest disagreements between the Lower Basin states — Arizona, Nevada and California — and Upper Basin states — Colorado, New Mexico, Utah, and Wyoming — is over which faction should have to cut back on their water use, and by how much.

“This is one of the toughest challenges facing the West, but the Department remains hopeful that, by working together, the seven basin governors can help deliver a durable path forward,” Burgum, the former governor of North Dakota, said in a statement. “Looking at this as a former governor, the responsibility each of them carries to meet the needs of their constituents cannot be understated, and we are committed to partnering with them to reach consensus.”

The meeting in the nation’s capital lasted more than two hours, Christian Slater, a spokesman for Hobbs, told the Arizona Mirror. The governors of all of the basin states attended the meeting, except for Gov. Gavin Newsom of California, who had a prior family commitment and sent California Natural Resources Secretary Wade Crowfoot in his place. 

“It’s actually a pretty historic meeting, and I don’t use those words lightly,” John Entsminger,  Nevada’s Colorado River negotiator, said. “I’ve been working on the river for more than 25 years, and I’ve never seen that many governors and a cabinet secretary in one room talking about the importance of the Colorado River.”

In a post on X Friday afternoon, Hobbs described the meeting as meaningful and productive. 

“I was encouraged to hear Upper Basin governors express a willingness to turn water conservation programs into firm commitments of water savings,” Hobbs wrote. “Arizona has been and will continue to be at the table offering solutions to the long-term protection of the river so long as every state recognizes our shared responsibility.”

Udall/Overpeck 4-panel Figure Colorado River temperature/precipitation/natural flows with trend. Lake Mead and Lake Powell storage. Updated through Water Year 2025. Note the tiny points on the annual data so that you can flyspeck the individual years. Credit: Brad Udall

Reaching a water usage agreement is vital to the basin states because the Colorado River’s water supply has been in decline for around 25 years due to a persistent drought spurred on by climate change. The decline is expected to continue into the future. 

Water levels in the two major reservoirs on the river, Lake Mead and Lake Powell, have also been in decline for the last quarter century. 

“One thing is certain: We’ll have less water moving forward, not more,” New Mexico Gov. Michelle Lujan Grisham said in a statement. “So, we need to figure this out. There is still a lot of work ahead to get to an agreement, but everyone wants an agreement, and we’ll work together to create a pathway forward.”

Lower Basin states want all seven states to share mandatory water cuts during dry years under the new guidelines. But the Upper Basin, which is not subject to mandatory cuts under the current guidelines, argue that they already use much less water than downstream states and should not face additional cuts during shortages.

State negotiators for both the Upper and Lower Basin have said they would prefer a seven-state agreement over alternative river management options proposed by the federal government.

Tom Buschatzke, director of the Arizona Department of Water Resources, told reporters last week that the Grand Canyon State does not like the options proposed by the federal government as they place almost the entire burden for cuts on Lower Basin states. 

The Colorado River Compact dates back to 1922, when the seven states made their initial agreement, allocating 7.5 million acre-feet of water each year to be shared by the Upper Basin states and another 7.5 million to be used among the Lower Basin states. 

In 2025, for the fifth year in a row, the federal government imposed water allocation cuts on the Colorado River  due to the ongoing drought and Arizona’s cut amounts to a loss of 512,000 acre-feet of water for the year. 

“Today’s discussion was productive and reflected the seriousness this moment requires,” Colorado Gov. Jared Polis said in a statement. “Since 2022, Colorado and the Upper Basin states have shown up to the negotiating table ready to have hard conversations. We have offered sacrifices to ensure the long-term viability of the Colorado River and we remain committed to working collaboratively to find solutions that protect water for our state, while supporting the vitality of the Colorado River and everyone who depends on it.” 

Complicating matters this year is scant snowpack in the Rocky Mountains. Small snowpack means very little runoff, the source for almost all of Colorado’s water. 

The Lower Basin states have undertaken significant conservation efforts for Colorado River water since 2014 and have reduced their consumption from 7.4 million acre-feet in 2015 to just over 6 million in 2024.

The Upper Basin states have increased their usage in the past five years, from 3.9 million acre-feet in 2021 to 4.4 million in 2024. 

Buschatzke, who attended the meeting in D.C. on Friday alongside Hobbs, has remained insistent that it’s time for the Upper Basin states to do their part. Hobbs’ statement indicated that the states had made some progress toward that. 

If the states can’t reach an agreement and are forced to take one of the federal government’s proposals, it will likely lead to litigation — something that the states agree they would prefer to avoid. 

“We all have to keep working together,” Entsminger said. “We have to find a compromise, and we have to find a way that the states stay in control of this process and don’t turn it over to the courts.”

Last year, Arizona put a total of $3 million to its Colorado River legal defense fund, and Gov. Katie Hobbs’ proposed budget for this year would put another $1 million toward that fund. 

Entsminger said that he thinks the meeting improved the chances of the states meeting  the Feb. 14 deadline. 

“Whether we have a final deal on February 14 or not, we’re still going to have to keep working,” he said. “That’s not to say I don’t think we’ll meet the deadline, but I do think we keep working until we have a deal, regardless of what day in the future that occurs.”

Jeniffer Solis of the Nevada Current contributed to this report.

Map of the Colorado River drainage basin, created using USGS data. By Shannon1 Creative Commons Attribution-Share Alike 4.0

Upper #ColoradoRiver Commissioner Becky Mitchell’s prepared remarks “This is the river we actually live with” for the #Colorado Water Congress Annual Convention January 28, 2026 #COriver #aridification #cwcac2026

Rebecca Mitchell, John Entsminger, Estevan Lopez, Gene Shawcroft, JB Hamby, Tom Buschatzke at the Getches-Wilkinson Center/Water and Tribes Initiative Conference June 6, 2024. Photo credit: Rebecca Mitchell

Click the link to read the remarks on the Coyote Gulch website. Thanks to Michael Elizabeth Sakas for sending them in email:

January 28, 2026

Fellow Coloradans,

First I want to thank Christine Arbogast and the Colorado Water Congress for allowing me to speak today. I will be brief as Amy Ostdiek will be on a panel tomorrow giving a bit more detail of the status of the negotiations. I will be heading to Washington DC with my fellow commissioners to have more discussions.

Let’s start with a truth that somehow still feels radical:

The Colorado River is not broken.

We are.

Udall/Overpeck 4-panel Figure Colorado River temperature/precipitation/natural flows with trend. Lake Mead and Lake Powell storage. Updated through Water Year 2025. Note the tiny points on the annual data so that you can flyspeck the individual years. Credit: Brad Udall

The river is doing exactly what rivers do when you take too much from them for too long. It is responding to reality. And right now, for many, reality is inconvenient.

For more than a century, we built a system of optimism and entitlement. We planned for abundance, labeled it “normal,” and wrote it into law. When the water showed up, we spent it. When it didn’t, we blamed the weather, climate change, or each other—anything except the simple math.

The river never signed those agreements. And it is not interested in our love story with the past.

Lake Powell and Lake Mead were supposed to protect the system. Instead, we turned them into shock absorbers for delay. We wanted them to be savings accounts, when in reality we treated them like credit cards—use now, pay later.

Well, interest has accrued and the bill has arrived. Both reservoirs are in a treacherous situation.

The Colorado River fills Glen Canyon, forming Lake Powell, the nation’s second-largest reservoir. The reservoir could drop to a new record low in 2026 if conditions remain dry in the Southwestern watershed. (Alexander Heilner/The Water Desk with aerial support from LightHawk)

Lake Powell was never meant to be drained so that hard decisions could be postponed downstream. It was designed to stabilize the system, to smooth out highs and lows; not to prop up demand that no longer matches supply. Year after year, Powell has been drawn down to protect uses elsewhere—even as inflows decline and the margin for error disappears.

Hoover Dam at low water. Jonathan P. Thompson photo.

Lake Mead tells the same story from the other end. Despite conservation programs, pilot projects, and voluntary agreements, Mead keeps dropping. Not because we lack creativity—but because we are still taking more water out of the system than the river is putting in.

Reservoirs don’t lie.They are the silent accountants of what we actually do, not what we say we’re doing.

Here in Colorado, when the river runs low, the impacts are immediate. We don’t have a giant reservoir upstream to hide behind. Shortages here are hydrologic. They are real. Farmers fallow fields. Municipalities restrict use. Communities adapt—not next year, not after another study or more modeling, but now. These impacts should be the indicator of the level of action that is needed across the entire Basin.

That lived experience matters—especially as we head into a post-2026 world.

Post-2026 is not just another chapter in the Law of the River, it is a reckoning.

The Interim Guidelines were written for a different river–-a river of the past. The drought contingency plans were emergency patches—not as a permanent fix but to buy time at a cost of more than a billion dollars until the next deal. We all know now those bandaids don’t fix holes in reservoirs. And the idea that we can simply extend these frameworks or merely modify them —while Powell and Mead hover near critical elevations—is not leadership. It’s hope, not based on reality or experience, but avoidance.

In the post-2026 world, operations must be supply-based. Not demand-based. Not entitlement -justified. And not built on the hope that the next big year will save us. The harm will be irreversible because the Colorado River is NOT TO BIG TO FAIL.

Map of the Colorado River drainage basin, created using USGS data. By Shannon1 Creative Commons Attribution-Share Alike 4.0

Right now, the Basin States have a chance to prevent further irreversible damage and try to avoid bankruptcy. But that will only be possible if we all work together and see the stark reality of our present circumstances with clear eyes. We must build a framework that recognizes and adapts to the math problem–supplies that regularly give us all less than our full rights and entitlements, that improves efficiencies for water intensive sectors, allows us flexibilities to help our neighbors when we can, and requires full transparency for measurement, monitoring, and accounting across the Colorado River System to build trust between us. Trust is difficult to rebuild when some don’t acknowledge or adhere to the agreements already made.

That means releases from Lake Powell must reflect actual inflows, not political pressure.

It means protecting critical elevations is not optional.

And it means Lake Mead cannot continue to serve as a pressure valve for overuse.

We cannot manage scarcity with delay.

We cannot store our way out of imbalance with water that isn’t there-that may never be there.

And we cannot negotiate with the simple arithmetic, no matter how many times we tell ourselves it will be different this time.

As sparks fly in the interstate negotiations, it is important to keep these realities in mind despite the rhetoric that attempts to distract.

Colorado is often told to “come to the table,” as if we’ve been absent. But we’ve been here the entire time—bringing hydrology, realism, and a simple message: if reductions aren’t real, reservoirs won’t recover. It is telling that what some refer to as an extreme negotiating position is based solely on the simple facts of hydrology—using more than the supply will bankruptthe entire system for everyone. How does the saying go? Doing the same thing over and over again and expecting a different result is the definition of insanity.

We are not asking for special treatment. We are not asking for a pass on doing our part to help save the system from collapse. We are asking for honesty. For reductions from both basins that are measurable, enforceable, and in proportion to use—not in proportion to who can avoid the truth the longest.

Because if we don’t choose how to live within the river’s limits, the river will choose for us. And it will not be gentle.

This is not a call for conflict.

It’s a call to face the reality of this unprecedented situation and come together to manage the River with wise and mature decision-making.

Lake Powell and Lake Mead are no longer warnings. They are verdicts. They are telling us—clearly and without spin—that the era of surplus, overuse, of clever deals is over.

The question facing all of us post-2026 is simple:

Do we align the rules with the river we actually have—or keep clinging to a past that no longer exists?

So as I head East I take you with me, because I know you all are doing the real work back on the home front. This year’s current hydrology demands it. I know Coloradans will be prepared, like they always have been. Fields will be fallowed, municipalities will be preparing to manage within their resources, deals will be made to protect fish and flows. Junior priority water users know that years like this one will call for collaboration and innovation, senior priority water users will work within the law and with those that are suffering, you will help each other pay the bill from Mother Nature because you know we all rise and fall together.

You all are here doing the real and hard work, and I will take that with me.Coloradans should be proud that we are choosing reality over fantasy, science over slogans, and responsibility over delay.

That is not weakness.

That’s leadership.

Colorado River “Beginnings”. Photo: Brent Gardner-Smith/Aspen Journalism

Fiery speeches and calls for compromise: What #ColoradoRiver negotiators are saying on eve of DC summit — Scott Franz (KUNC.org) #COriver #aridification #cwcac2026

Water policymakers from (left to right) Utah, New Mexico, Colorado and Wyoming speak on a panel at the Colorado River Water Users Association conference in Las Vegas on December 5, 2024. State leaders are deeply divided on how to share the shrinking water supply, and made little progress to bridge that divide at the annual meetings. Photo credit: Alex Hager/KUNC

Click the link to read the article on the KUNC website (Scott Franz):

January 29, 2026

This story is part of ongoing coverage of the Colorado River, produced by KUNC in Colorado and supported by the Walton Family Foundation. KUNC is solely responsible for its editorial coverage.

Governors in the Colorado River basin and their negotiators are meeting with Interior Secretary Doug Burgum in Washington on Friday to try and break a yearslong impasse among states over how to share the dwindling waterway.

On the eve of the high-stakes summit, negotiators from both the upper and lower river basins are not sounding confident they can reach an agreement before a fast-approaching Feb. 14 deadline.

“It depends on the day that you ask me,” Colorado’s negotiator, Becky Mitchell, said Tuesday when asked by KUNC News if she thinks the states are heading toward a court battle. “But I will tell you the level of commitment that we have, both within Colorado and the upper basin, is strong to try to find some way to make a deal. There’s some things that we can’t give on.”

Negotiators are currently working against the backdrop of record low-snowpack across much of the West and worsening forecasts for the Colorado River’s water supply. 

Mitchell said negotiators are continuing to talk at least twice each week.

But leaders from the upper and lower basin states say they still have sticking points.

They continue to differ on how water cuts should be handled and how releases from Lake Powell should be managed during dry years.

“Some in the lower basin wanted some sort of guaranteed supply, irrespective of hydrologic conditions,” Mitchell said. “And I think asking people to guarantee something that cannot be guaranteed is a recipe that cannot get to success.”

The lower basin states of California, Arizona and Nevada are proposing to cut 1.5 million acre feet of their water use. They’re also asking for water restrictions to be mandatory and shared among all seven states. 

Negotiators from the different basins spoke at public events on Wednesday to set the stage for the summit in Washington.

“It’s tough to say I’m looking forward to it, because that would be a lie,” Mitchell told a large crowd Wednesday at a water conference in Aurora.

Her speech was fiery at times.

Colorado River negotiator Becky Mitchell speaks to the Colorado Water Congress convention in Aurora on Jan. 28, 2026. Scott Franz/KUNC

“Operations must be supply based, not demand based, not entitlement justified, and not built on a hope that the next big year will save us,” she said. “That harm will be irreversible, because the Colorado River is not too big to fail.”

As Mitchell was addressing the water conference in a hotel ballroom, California’s water negotiator, J.B. Hamby, was talking to roughly 600 people on a webinar about his take on the state of negotiations.

He largely focused on his desire to still find a compromise among the seven states in the river basin.

“It’s better to be able to work something out across the negotiating table, to do something that makes sense and protects our users and people and agriculture in our state, and as a result of that, getting a seven-state agreement that protects those interests,” he said.

Hamby said the federal government is “leaning in” and becoming more involved in the negotiations by offering potential options.

Hamby called the feds’ ideas helpful.

“Continued back and forth between the basins haven’t really been moving the ball forward,” he said. “The administrations…have this important role in sometimes knocking heads together, sometimes encouraging consensus, and having diplomatic discussions between the states to be able to move conversations forward.”

He pointed to Herbert Hoover’s role in 1922 as then Commerce Secretary to broker a deal among states in the river basin over how to share water. 

“It’s going to take everyone chipping in and making the necessary (water) reductions to balance the supply with the demand we have moving forward,” Hamby said.

Members of the Colorado River Commission, in Santa Fe in 1922, after signing the Colorado River Compact. From left, W. S. Norviel (Arizona), Delph E. Carpenter (Colorado), Herbert Hoover (Secretary of Commerce and Chairman of Commission), R. E. Caldwell (Utah), Clarence C. Stetson (Executive Secretary of Commission), Stephen B. Davis, Jr. (New Mexico), Frank C. Emerson (Wyoming), W. F. McClure (California), and James G. Scrugham (Nevada) CREDIT: COLORADO STATE UNIVERSITY WATER RESOURCES ARCHIVE via Aspen Journalism

Report: Considerations for Assigned Water after Expiration of the 2007 Guidelines — Kathryn Sorensen, Sarah Porter, Anne Castle, John Fleck, Eric Kuhn, Jack Schmidt, Katherine Tara #ColoradoRiver #COriver #aridification

Udall/Overpeck 4-panel Figure Colorado River temperature/precipitation/natural flows with trend. Lake Mead and Lake Powell storage. Updated through Water Year 2025. Note the tiny points on the annual data so that you can flyspeck the individual years. Credit: Brad Udall

Click the link to read the report on the Center for Colorado River Studies website (Kathryn Sorensen1, Sarah Porter2, Anne Castle3, John Fleck4, Eric Kuhn5, Jack Schmidt6, Katherine Tara7). Here’s the executive summary and recommendations:

January 2026

As Colorado River supplies and demands reach razor-thin margins, new tools to provide adaptive capacity will play a critical role in sustaining communities across the West. We must reduce our consumption of water, while finding ways to cushion the impact. One of the most innovative tools for doing this, developed over the last two decades, is “Assigned Water” – giving users the ability to store conserved water earmarked for their own future use.

Originally developed as “Intentionally Created Surplus” in the 2007 Colorado River Interim Guidelines, Assigned Water has been revised and expanded through U.S.-Mexico Treaty Minutes and as part of the 2019 Drought Contingency Plan. While conceptually simple and demonstrably valuable – a savings bank for conserved water – it is crucial to get the policy tools right as Colorado River management rules evolve.

For agencies granted access to the tool, Assigned Water provides important adaptive capacity to prepare for and manage shortfalls on a volatile river with shrinking supplies. But nearly two decades of operational experience also have exposed unintended consequences. With Assigned Water likely to play a critical role in basin management going forward – including its potential expansion to the Upper Colorado River Basin – it is important to review the strengths of the existing program, and essential lessons learned, to guide the development of river management policies after the current operating rules expire at the end of 2026.

HOW ASSIGNED WATER WORKS

Assigned Water allows some users to either conserve water that would have been used, import some categories of tributary water to the mainstem, or to fund system improvements to conserve water that would otherwise have been lost to inefficiencies. This water is then earmarked for the creating agencies’ use, sitting outside of the priority system through which the rest of the Colorado River’s water is allocated. Agencies can pay users to take out their lawns, or fallow farm fields, banking the saved water for future use. By planning ahead, water agencies secure a reliability hedge against shortages as the river shrinks.

But at a time when overall water supplies are declining, Assigned Water creates a category of “private water,” available only to specific users, while remaining water allocated to all users under the existing priority system continues to shrink.

Assigned Water created a tool to overcome the “use it or lose it” problem that left little incentive for water agencies to conserve. Its usefulness and subsequent expansion have led to the existence of 3.5 million acre feet now are stored in Lake Mead, representing the bulk of the available water currently in the reservoir.

UNINTENDED CONSEQUENCES

Delaying Shortage Actions

By keeping Lake Mead levels higher than they otherwise would have been, Assigned Water delayed formal shortage declarations in the Lower Colorado River Basin. While this was an intended benefit, it has had the practical effect of putting off water use reductions to the detriment of reservoir storage.

Subsidizing Evaporation

Although current rules apply some reductions to Assigned Water accounts, they often fail to fully account for actual evaporation. This results in a subsidy for Assigned Water holders at the expense of water available to everyone else.

Crowding Out

Assigned Water creates incentives for agencies to focus their conservation efforts primarily on programs that benefit their own users, potentially at the expense of the kind of broader efforts that will ultimately be needed to bring Colorado River Basin use into balance with physical supply. We must remember that Assigned Water does not permanently reduce the use of a quantity of water; instead it stores it for later, simply deferring that use to the future.

Inequitable Access

Assigned Water is currently available only to a select group of major Colorado River water agencies, depriving other users of the program’s benefits.

KEY RECOMMENDATIONS

Operational Neutrality

Assigned Water should not be included in the reservoir levels used to make shortage declaration and determine reservoir operations.

System Assessment

Agencies granted access to Assigned Water should pay a “system assessment” for the privilege. This mechanism would credit their earmarked storage account for a portion of the conserved water while converting the remainder to “System Water,” helping to rebuild storage and meet broad Basin needs.

Evaporation Assessment

Accounting for evaporation should use the best available science, to avoid subsidizing Assigned Water accounts at the expense of the rest of the Basin’s water users.

Expand Access

A wider range of users should be given the opportunity to participate in and benefit from Assigned Water tools.

ADDRESSING THE COLORADO RIVER BASIN’S TRAGEDY OF THE COMMONS

For more than a century of development, Colorado River governance has lived under a tension between individual communities’ desires to use more water and the collective need to balance basin-scale supply and use for the benefit of the region as a whole. Incentives favoring individual communities at the expense of the collective good have brought us to the edge of the current crisis.

Going forward, Assigned Water can provide a crucial management tool, but the policies we use to implement it must find the balance between individual benefit and collective good.


GLOSSARY OF KEY TERMS

  • Priority Water: Water diverted within the U.S. generally under the prior appropriation system of water allocation.
  • Mexican Water: Water that flows past the international border into Mexico pursuant to the 1944 U.S.-Mexico treaty
  • Assigned Water: Water resulting from water use reduction programs that is stored in Colorado River Basin reservoirs earmarked for the specific use of the users who created it, outside the normal priority system. Assigned water functions as a sort of private water savings account for those agencies granted the privilege of using the tools.
  • System Water: System Water: The collective term for all water in the reservoirs, including Priority, Mexican, and Assigned Water.
  • Intentionally Created Surplus: The term used for the Assigned Water initially created under the 2007 Colorado River Interim Guidelines, which became the prototype for similar programs that followed.
  • System Conservation: Programs that fund reductions of water use to benefit the
  • Colorado River Basin as a whole by creating System Water for rebuilding reservoir storage or general use under the priority system rather than being allocated to the accounts of specific users.

APPENDIX OF ALL RECOMMENDATIONS

NEUTRALITY

  • In any newly developed operational guidelines for Lake Powell and Lake Mead, volumes of Assigned Water created after 2026 should be invisible for purposes of determining shortage conditions.
  • Other than for flood control releases, volumes of Assigned Water created after 2026 should be invisible for purposes of determining surplus in Lake Mead.
  • Volumes of Assigned Water in Lake Mead and Lake Powell created after 2026 should spill before all other water, a condition that also functions as a de-facto limit on total accumulation of Assigned Water.
  • In any newly developed operational guidelines for Lake Powell and Lake Mead, volumes of Assigned Water created after 2026 and held in Lake Mead or Lake Powell should be invisible for purposes of calculating annual releases from Lake Powell.

EVAPORATION

  • Reclamation should establish evaporation coefficients applicable to calculation of evaporation caused by storage of Assigned Water. These evaporation coefficients should be based on on-going monitoring and best available science and appropriately funded. Evaporation coefficients should be reassessed every five years, especially in light of a changing climate.
  • Future volumes of Assigned Water in any reservoir should be assessed a realistic and conservatively high annual evaporative loss based on these coefficients and on the amount of Assigned Water in storage.
  • Future deliveries of Assigned Water should be assessed transit losses where appropriate. Transit losses should also be estimated based on best available science, updated by monitoring and scientific studies, and revised every five years.
  • Future volumes of Assigned Water in any reservoir should proportionately share the evaporative (and transit) losses that occur due to Mexican Water delivery obligations (other than for Mexican Assigned Water, which should bear its own losses) and should be assessed a realistic and conservatively high annual evaporative loss based on these coefficients and due to Mexican Water delivery obligations. The evaporative assessment should reflect the proportionate share of Assigned Water and Priority Water in storage.
  • Evaporative losses should be assessed under all conditions, including shortage.

SHORTAGES AND DELIVERIES

  • Deliveries of Assigned Water should be restricted if necessary to protect critical dam infrastructure.
  • Alternative: The federal government should compel the sale of Assigned Water for immediate conversion to System Water during years in which reservoirs are at critically low levels.

PARTICIPATION

  • In years in which System Water storage in Lake Powell and Lake Mead is deemed to be inadequate, any Assigned Water developed or acquired by the federal government in those years should immediately be converted to System Water. Use for other purposes should be allowed only in conditions in which System Water storage is adequate.
  • Dedication of federally-controlled Assigned Water for purposes other than conversion to System Water should occur through a robust and transparent public process.
  • Because they are among those most exposed to involuntary shortage, CAWCD subcontractors that rely on deliveries of Colorado River water to surface water treatment plants should be allowed to create, own and acquire Assigned Water.
  • Entities without an entitlement to Colorado River water should not be allowed to own Assigned Water.
  • The Secretary’s approval should be required for all agreements for creation, transfer, or sale of Assigned Water.
  • Any Colorado River entitlement holder, with the concurrence of the Secretary, should be allowed to participate in transactions in any state to develop, own or use Assigned Water created from projects in the U.S. (So long as adequate protections are afforded Priority Water and there is agreement between the states regarding accounting for Assigned Water deliveries under the Compact).
  • To avoid profiteering, the Assigned Water held by any given Colorado River entitlement-holder should be proportional to its Colorado River entitlement. The annual accumulation and balance of Assigned Water for a single entity in any reservoir should be limited to some (relatively small) multiple of its annual entitlement to Colorado River water.
  • To ameliorate concerns about permanent water transfers between states, agreements to create Assigned Water from consumptive-use reductions in one state for delivery in another state should be structured such that there is reasonable means for entities within the state in which the reduction in consumptive-use derives to make use of that water within the state in the future. One means to do so would be to allow agreements to create Assigned Water from consumptive-use reductions in one state for delivery in another state only if the agreements expire after five years and do not include a provision for automatic renewal. Existing Assigned Water storage could continue beyond expiration.
  • To ameliorate controversies associated with the transfer of agricultural water for municipal use, agreements to create Assigned Water from consumptive-use reductions in agriculture should include a requirement that the funder of the Assigned Water pay a tax assessed per acre-foot paid to the county or counties from which the consumptive-use reductions derive. The tax could derive from the value of the agricultural economy. Waivers could apply if the Assigned Water creation program creates a net increase in economic value in an agricultural area (e.g., crop switching or crop insurance).

ASSIGNED WATER CREATED THROUGH SYSTEM EFFICIENCIES

  • The federal government should fund efficiency projects for creation of System Water up until the amount of water that results from such projects sufficiently ameliorates the impacts of the annual, national obligation to Mexico to Priority Water users.
    • Thereafter, the creation of Assigned Water via efficiency projects in the U.S. should only be allowed if a) System Water storage in Lake Powell and Lake Mead is deemed to be adequate or b) the efficiency project benefits System Water over Assigned Water on a ratio of 90/10 over the ensuing five years.
  • To the extent participation is offered, participation in efficiency projects in the U.S. in exchange for Assigned Water should be awarded based on an allocation method determined through an open and transparent process (e.g. highest bidder) and should be subject to any limitations on participation, total Assigned Water annual accumulation and balance for that entity.
  • The federal government should hold the right of first refusal to purchase any Mexican Assigned Water up for sale and to fully fund any conservation projects in Mexico that can become Assigned Water during years in which System Water stores are deemed to be inadequate for the sole purpose of converting it to System Water.
  • Mexican treaty obligations increase the risk of shortage in the Lower Division and increase the risk of a Compact call. Those in the Lower Division with lowest priority contracts and subcontracts and those in the Upper Division most at risk of curtailment due to a Compact call should be given the second right of refusal up to an amount that equals projected involuntary cuts to Priority Water for each entity over the next two years.
  • Thereafter, purchase of Mexican Assigned Water should be awarded to domestic entity with the highest bid and should be subject to any limitations on participation, total Assigned Water annual accumulation and balance for that entity.

MEASUREMENT AND BASELINES

  • An audit independent of Reclamation should be conducted on the existing Assigned Water program in the Lower Division and Mexico. The goals of the audit should be:
    • to examine claimed savings for accuracy,
    • to assemble a list of lessons learned on measurement and accounting from twenty years of program administration and
    • to assemble a list of qualifying activities for reduction of consumptive use, alongside recommended terms and conditions, that can form the foundation of future agreements.
  • The audit should be made available to the public with and opportunity to review and comment.
  • Assigned Water in any reservoir should only be allowed under a program that accurately measures Assigned Water creation, shepherding, storage and deliveries.
  • Owners of Assigned Water should be assessed an annual fee to fund robust measurement and enforcement programs.
  • Assigned Water created through water savings should derive from a baseline of historic consumptive use, not entitlement or filed water right claims.

FORBEARANCE/SHEPHERDING

  • Forbearance/shepherding should be based on qualifying activities, not participants. In other words, withholding of forbearance/shepherding should not be a veto used to exclude participants that would otherwise qualify for development of Assigned Water.
  • The means of creating Assigned Water that meet the threshold for agreements to forbear/shepherd should be decided ahead of time. Allowing additional qualifying activities down the road increases flexibility but also potentially undermines trust in Assigned Water programs between participants and more importantly among non-participants who rely solely on the prior appropriation system.

TRANSPARENCY

  • Reclamation should compile a centralized, searchable, easily accessible library of all agreements and documents associated with Assigned Water programs.
  • Reclamation should develop a new Assigned Water annual report that clearly shows ownership of the several different types of Assigned Water, the status of funding agreements and the flow of dollars, transactions involving Assigned Water, Assigned Water creation by creation category, method and partner, relevant shepherding arrangements, assessments, evaporative losses, deliveries and ending balances and other relevant details.
  • Graphs and charts of reservoir elevations should clearly delineate Assigned Water by ownership and method of creation.

PROGRAM LENGTH

  • The ability to create or purchase Assigned Water under a given Assigned Water program should expire 20 years after program initiation, a duration long enough for bond financing of capital projects. The ability to store Assigned Water should expire no more than 5 years after expiration of the program under which it was created.

LOANS AND CONVERSIONS

  • Loans against Assigned Water balances should not be allowed where default diminishes the amount of System Water in storage.
  • Conversion of existing Assigned Water into another form of Assigned Water governed by different rules should only be allowed after a robust and transparent public process.
  • Loans between Assigned Water owners for Assigned Water should be allowed in future programs.
  • With proper guardrails, loans from Assigned Water owners to Priority Water users should be allowed, including across state lines.
  • With proper guardrails, loans and/or conversions from Assigned Water to the Priority Water pool should be mandatory when Priority Water stores are deemed to be seriously inadequate.

ADDRESSING THE TRAGEDY OF THE COMMONS

  • Future creation of Assigned Water should be assessed a percentage deduction that becomes System Water at the time of creation to help rebuild System Water in reservoirs.
    • The assessment should be determined based on a sliding scale; a 30% assessment should apply in water years in which System Water stores are deemed to be inadequate. The assessment should then decrease incrementally to 10% as total storage increases.
  • Alternative: Colorado River entitlement holders must agree to take shortages above and beyond shortage levels described in the 2007 Guidelines before being allowed to create Assigned Water.
    • The amount of shortage should equal 30% of the proposed deposit in years in which System Water stores are deemed to be inadequate. The shortage should then decrease incrementally to 10% as total storage increases.
  • During years in which System Water stores are deemed to be inadequate the federal government should hold the right of first refusal to purchase any Assigned Water offered up by willing sellers for the sole purpose of converting it to System Water.

ASSIGNED WATER OPPORTUNITIES IN THE UPPER DIVISION

  • Where possible while still maintaining neutrality to Priority Water, and assuming agreement between the states on how to account for Assigned Water deliveries between the Divisions under the Compact, the amount of Assigned Water stored in different reservoirs should be adjusted to optimize for hydropower, environmental and recreational benefits.
  • Assigned Water created in the Upper Division must be properly shepherded into the relevant downstream reservoir and assessed appropriate transit losses.

1 Director of Research, Kyl Center for Water Policy, former Director, Phoenix Water Services

2 Director, Kyl Center for Water Policy

3 Senior Fellow, Getches-Wilkinson Center, University of Colorado Law School, former US Commissioner, Upper Colorado River Commission, former Assistant Secretary for Water and Science, US Dept. of the Interior

4 Writer in Residence, Utton Transboundary Resources Center, University of New Mexico

5 Retired General Manager, Colorado River Water Conservation District

6 Director, Center for Colorado River Studies, Utah State University, former Chief, Grand Canyon Monitoring and Research Center

7 Staff Attorney, Utton Transboundary Resources Center, University of New Mexico

Map of the Colorado River drainage basin, created using USGS data. By Shannon1 Creative Commons Attribution-Share Alike 4.0

Alfalfa as an agricultural demand response tool — Jonathan P. Thompson (LandDesk.org)

Hay on the Great Sage Plain. Jonathan P. Thompson photo.

Click the link to read the article on The Land Desk website (Jonathan P. Thompson):

January 27, 2026

I started the Land Desk five years ago this month to fill what I saw as a gap in coverage of public lands, energy, climate, water, economics, and communities in the Western U.S. — along with the politics around all of those issues. I certainly wasn’t planning on covering national or partisan politics.

But it so happens that my first dispatch ran four days after the infamous events of Jan. 6, 2021, which had echoes — if not direct connections — to Western land-use politics. So, less than a week after launching, I found myself, well, delving into national partisan politics.

The United States is again in turmoil, the administration is a full-on dumpster fire, and federal agents are executing people in the streets of Minneapolis — and then lying about it and slandering the victim.

To say I’m horrified, outraged, and heartbroken would be an understatement.

I’m not going to offer any analysis here — others have done a much better job than I could. But I would plea with and urge Western elected officials from both parties to stand up and do whatever you can to curb these authoritarian and reprehensible actions, even if it means shutting down the government, and to hold the administration accountable. [ed. emphasis mine]


Where are the anti-tyranny, federal overreach folks when you need them? — Jonathan P. Thompson


On a brighter note, it is the Land Desk’s fifth birthday this month. Actually, it was on Jan. 10, and I totally missed it until now. I just want to take this opportunity to thank all of my readers, but especially the Founding and Sustaining Members and the other paid subscribers and “Buy Me a Coffee” supporters who keep this thing — and the Silver Bullet and now El Burro Blanco — going. I couldn’t do it without you.

☘️ Annals of Alfalfa 🍀

Yes, I’m going to talk about alfalfa. Again. Why? Because the Colorado River is on my mind, and as John Fleck, author, former journalist, and Writer in Residence at the Utton Transboundary Resources Center at the University of New Mexico School of Law, once wrote: “Golf and the Bellagio Fountain are easy targets. But if you’re not talking about alfalfa, you’re not being serious.”

That’s because alfalfa and, to a lesser degree, other livestock forage crops, are collectively the largest users of Colorado River water. So, any serious efforts to cut consumption on the river are going to involve alfalfa, in some form or another. In recent years, this has included paying farmers to fallow some of their alfalfa fields and leave the water in the ditches, canals, or the river.

But a report1  published last year2 posits a less extreme solution: Keeping the alfalfa, but watering it less during the summer months in dry years — a practice known as deficit irrigation. The farmer could then sell the surplus water to other users to offset the losses resulting from lower crop yields. The authors estimate that this approach could save up to 3.4 million acre-feet of water annually across the Southwest3, or about 50% of total alfalfa water use.

In some ways, this method is analogous to something called “demand response” on electrical power grids. That’s when large power users, or a collection of smaller users, are paid to reduce electricity consumption during times of high demand to ease grid strain. So, for example, during a heat wave, when everyone’s air conditioners are running full blast, the utility or grid operator would signal a factory, say, or a data center to scale back their operations during the hottest time of the day when solar generation might be dropping off. The targeted drop in consumption has the same effect as increasing power generation would, keeping supply and demand in balance.

Alfalfa is a good crop for water-demand-response in part because it uses a lot of water in the first place, but also because putting it on a temporary water diet won’t kill it. The authors argue that this approach is preferable to fallowing fields, replacing alfalfa with other crops, or even increasing irrigation efficiency. Alfalfa is high in nutrients and digestible fiber, making it a valuable livestock feed; its deep roots facilitate nitrogen fixation; and it has high salt tolerance.

They note that drip irrigation and fertigation (a new term to me that is where liquid fertilizer is applied with irrigation water) have increased crop yields, but have also resulted in “a water savings paradox, especially greater net consumptive use (CU) due to expansion of cropped areas and reduced groundwater recharge and return flows to streams.” Fallowing, meanwhile, has its own unintended economic and environmental consequences, including increased weeds and dust mobilization, loss of green space, and loss of wildlife habitat.

In addition to saving between 16% and 50% of water used to irrigate alfalfa, the authors write, “Summer deficit irrigation could also be an attractive strategy for alfalfa growers particularly if market water prices at the peak of the growing season are high enough to offset the remaining alfalfa cutting revenues.”

It all sounds good on paper, but implementing it in the fields would be far more complicated than simply shutting off the ditches for a couple of months. And whether this approach could actually pay for itself depends on the price of alfalfa, the price of water, and on whether it’s logistically feasible to sell the saved water to someone else.

Still, deficit irrigation is certainly one useful tool for farmers and water managers to consider. Because cuts are coming to the Colorado River one way or another. And it behooves everyone to make it as painless as possible.

📈 Data Dump 📊

Here’s a few alfalfa charts for your perusing pleasure.

Alfalfa acreage has decreased in most states over the last several years. Data Source: National Agricultural Statistics Service.
Top ten Western counties for acreage planted in alfalfa. Data Source: USDA NASS.
Colorado River state alfalfa production increased steadily over the decades before peaking in the early 2000s. Then, as the megadrought/long-term aridification settled in, it started decreasing. Data Source: NASS
Hay exports, especially to China, have dropped off considerably in recent years after a steady climb. This may have to do with the Trump administration’s tariffs. Source: Foreign Agriculture Service.
California’s largest hay export market used to be China. Source: FAS
Arizona’s biggest hay export market has long been Saudi Arabia, but that has dropped off in the last year. Source: FAS.
🔋Notes from the Energy Transition 🔌

In somewhat related news: The vast and powerful Westlands Water District has voted to move forward on a plan to build up to 21 gigawatts of new solar-plus-battery energy storage capacity on fallow, water-constrained agricultural fields in the San Joaquin Valley. In choosing this path, the water district defied the growing anti-solar backlash that seems to have infected even more progressive areas. And it opened the door for farmers to continue to earn an income on land that they simply can’t farm anymore because the water is no longer there. As a Westlands representative told Canary Media, it will “give farmers another crop to grow, which is the sun.”

***

Rio Tinto/Kennecott’s Bingham Canyon copper mine in the snow. Jonathan P. Thompson photo.

Rio Tinto’s Kennecott copper mining and smelting operation near Salt Lake City is the state’s largest polluter, spewing about 193 million pounds of toxic chemicals into the air each year. That kind of puts a grimy shadow over the company’s efforts to become more sustainable — like switching from diesel to battery-electric trucks — but it is better than business as usual, I suppose. And on that note, they are bringing online a 25 megawatt solar array to help power its operations, which is notable since they have started to produce tellurium, an ingredient in photovoltaic panels.

***

I have similarly mixed feelings about this next news item: MGM Resorts just acquired more solar power, bringing their onsite and offsite solar-plus-storage facilities combined capacity to a whopping 215 megawatts, allowing the company to meet up to 100% of daytime electricity load at its Las Vegas Strip operations.


1 “Reimagining alfalfa as a flexible crop for water security in the Southwestern USA,” by Emily Waring, et al.

2 Hat tip to All at Once by Dr. Len Necefer for alerting me to this study. 

3 This includes all of California, Nevada, Utah, Colorado, New Mexico, and Arizona, and is not limited to the Colorado River Basin.

All alternatives harmful to #Arizona: The Central Arizona Project’s response to the Draft Environmental Impact Statement for post-2026 #ColoradoRiver operations — DeEtte Person #COriver #aridification

Photo credit: Central Arizona Project

Click the link to read the article on the Central Arizona Project website (DeEtte Person):

January 26, 2026

Reclamation has released a Draft Environmental Impact Statement (DEIS), a required step in the process to develop new operating guidelines for Colorado River operations by the end of the year when the current operating guidelines expire. It comes amid two-plus years of ongoing meetings and negotiations led by Reclamation working with the seven Colorado River Basin states, the Colorado River Basin tribes and other stakeholders.

The DEIS lays out five alternatives for how the Colorado River might be managed after 2026. These include one “no action” alternative required by law, three alternatives that would require agreements among the basin states, and one “no deal” alternative which may be imposed if there is no agreement among the states.

The DEIS places all the risk of a dwindling Colorado River on the Lower Basin, and all the alternatives proposed are harmful to Arizona.

The “no deal” alternative in particular piles virtually all the mandated cuts on the State of Arizona and Central Arizona Project. The DEIS ignores the obligations of the Upper Basin states to deliver water under the Colorado River Compact and the federal government to release water from the Colorado River Storage Project dams.

The “no deal” alternative would result in a crushing blow to Central Arizona’s water supply, including tribal water supplies. Millions of Arizona residents would be negatively affected – including those in the fifth largest city in the United States, as would several of the nation’s key industries, including manufacturing, microchips and national defense.

Our economy is integrated regionally and nationally, which means if Arizona is suffering, neighboring businesses and our national defense are too.

In contrast, the “no deal” alternative imposes no federal cuts to the Upper Basin and allows the Upper Basin to increase water use in the future.

Implementation of any of the DEIS alternatives would likely force Arizona to seek legal options. [ed. emphasis mine]

The basin states and the Bureau of Reclamation can do better than any of these alternatives with a negotiated agreement. As history has shown, the Colorado River has worked best when all basin states agree on how it is managed.

We remain committed to working with the basin states and Reclamation so long as the path is toward recognizing the shared risks and responsibilities for the river and fairly sharing reductions to protect vital infrastructure that benefits the entire Colorado River Basin.

Here’s what CAWCD’s Board members have to say about the DEIS:

“Each alternative put forward places the risk of a dwindling Colorado River on the Lower Basin – none of them are good for Arizona and certainly not for Central Arizona Project. In the Lower Basin, we’ve demonstrated that we can accept that the River has less water now and likely in the future. But we cannot bear the shortage alone. The Upper Basin shows no willingness to conserve and in fact demands more water, yet these alternatives do nothing to deny their greed. That’s not acceptable to CAP whose millions of water users and billions in industrial investments will bear the brunt of these devastating alternatives.”  – Terry Goddard, CAWCD Board President

“The alternatives laid out for post-2026 Colorado River operations are potentially disastrous for millions of Arizonans – including the residents of the fifth largest city in the United States. Further, these alternatives all negatively impact several of the nation’s key industries, including manufacturing, microchips and national defense. This means harm not just to Arizona, but to the entire country.”  – Alexandra Arboleda, CAWCD Board Vice President

“Arizonans have been smart water stewards, conserving water for decades in our desert environment. What’s more, we’ve worked with our Lower Basin partners to protect Lake Mead, by voluntarily conserving water beyond the mandatory reductions Arizona has taken for the past several years. We’ve done our part and it’s so disappointing to see alternatives that make Arizona bear the burden for all Colorado River users.”   – Karen Cesare, CAWCD Board Secretary

“Pinal County has already shouldered the brunt of the Colorado River reductions Arizona has been taking for the past several years. And this has had a monumental negative impact on our agricultural community. We’ve already felt a great deal of pain and these alternatives would be rubbing salt in the wound and would continue to devastate Arizona.”  – Stephen Miller, CAWCD Board Member, Pinal County

“CAP delivers more tribal water than any other entity in the United States. The alternatives proposed for post-2026 Colorado River operations would have a damaging effect on those deliveries, which are part of settlement agreements with the federal government. The negative effects of these alternatives impact all of CAP’s water users – cities, industries and tribes.”  – Justin Manuel, CAWCD Board Member, Pima County and member of Tohono O’Odham Nation

Map of the Colorado River drainage basin, created using USGS data. By Shannon1 Creative Commons Attribution-Share Alike 4.0

As deal deadline approaches, #ColoradoRiver stewards debate a broad range of options — Scott Franz (KUNC.org) #COriver #aridification

The Colorado River flows through Grand County, Colo. on Oct. 23, 2023. Negotiators from seven states remain at an impasse over how to share and conserve the river’s water despite four days of recent meetings together in Utah.

Click the link to read the article on the KUNC website (Scott Franz):

January 25, 2026

This story is part of ongoing coverage of the Colorado River, produced by KUNC in Colorado and supported by the Walton Family Foundation. KUNC is solely responsible for its editorial coverage.

It’s crunch time for negotiators from seven western states trying to strike a deal before Feb. 14 on how to share the dwindling Colorado River.

But four days of talks in a Salt Lake City conference room earlier this month did not appear to have sparked a breakthrough.

“We got tired of each other,” Utah’s negotiator, Gene Shawcroft, said Tuesday at a public board meeting, days after the meeting ended. “And two of the days, we made some progress, but one day we went backwards almost as much progress as we made in two and a half days.”

The states in the lower and upper basins remain at an impasse over how cuts to water use should be handled during times of drought.

In another sign that talks remain stalled, Interior Secretary Doug Burgum reportedly invited governors from the seven states in the river basin to attend a meeting in Washington on Jan. 30. 

A spokesperson for Colorado Gov. Jared Polis confirmed the meeting invitation to KUNC and said in a statement that Polis “hopes to attend this meeting if it works for the other Governors.”

Meanwhile, the Interior Department recently released a playbook of options for how to manage the river in the future.

John Berggren, a water policy expert at Western Resource Advocates, said many of the scenarios on the table can only be taken if all the states in the basin agree to them.

“The fact that the states don’t have a seven state agreement right now means that we can’t consider some of these really good, new, innovative tools that are in some of the alternatives,” he said Tuesday. And so that’s pretty frustrating.”

What could management of the vital waterway look like after the current rules expire in August?

Berggren, who got his Ph.D. at the University of Colorado focusing on sustainable water management in the Colorado River Basin, helped KUNC’s water desk summarize the five options on the table from the feds.

He said an eventual deal might incorporate pieces from several of the alternatives.

Basic coordination

This is the only path the feds say they currently have the legal power to take if the seven states fail to reach an agreement.

Berggren said this option would likely ‘normalize’ 1.48 million acre feet of water shortages each year in the lower basin states.

“And this would just basically say every year, that’s a given,” Berggren said.

Water in Lake Mead sits low behind Hoover Dam on December 16, 2021. The nation’s largest reservoir, which has reached record-low levels in recent years, serves as the main source of water for the Las Vegas area. It is mostly filled with mountain snowmelt from Utah, Colorado, Wyoming and New Mexico. Photo credit: Alex Hager/KUNC

Upper basin states, including Colorado, would not be forced to contribute more water in dry years.

Berggren said this option “does not do enough.”

“There’s many years where the system crashes,” he said.

A crash means Lake Powell and Lake Mead reach deadpool, a scenario where they’re so critically low that hydroelectricity stops and water stops flowing through their dams.

Millions of water users in the west could see impacts.

Enhanced coordination

Berggren calls this plan ‘a little more innovative.’

Highlights include the power to use conservation pools that encourage and incentivize states and water users to find ways to save water.

That could mean the feds paying states to conserve water. Lower basin states could also put water they save in Lake Mead to stay there until they need it.

“It’s water security, because if we can save water today, we’ll put it into storage and we can withdraw it later when we need it,” Berggren said.

This option also includes contributions from the upper basin states each year that would gradually increase over time.

The Interior Department writes this option “seeks to protect critical infrastructure while benefitting key resources (such as environmental, hydropower, and recreation) through an approach to distributing storage between Lake Powell and Lake Mead that enhances the reservoirs’ abilities to support the Basin.”

No action

This plan might sound like the path with the least impact, but that’s far from the case.

This path would revert the operating procedures at Powell and Mead to what they were almost 20 years ago.

“It basically says Reclamation will shoot to release 8.23 million acre feet of water from Powell, and that’s kind of it,” Berggren said. “Not a lot of authority for lower basin shortages, not a lot of authority to modify your reservoir operations to try and prevent the worst from happening. No action very clearly crashes the system quickly, and no one wants it.”

According to the Interior Department, “there would be no new mechanisms to proactively conserve and store water in Lake Powell or Lake Mead.”

This option was legally required to be included in the feds report on operating scenarios.

Maximum flexibility 

This proposal was developed by a group of seven conservation groups.

Interior said this alternative is “designed to help stabilize system storage, incentive proactive water conservation, and extend the benefits of conservation and operational flexibility to a wide range of resources.”

It’s also designed to give dam operators more flexibility to respond to the impacts of climate change.

As water levels in Lake Powell keep dropping, some say they could fall too low to pass through Glen Canyon Dam at sufficient levels. Ted Wood/The Water Desk

Berggren said this option allows water users to conserve water and store it in reservoirs.

It would also change the way water releases are handled.

A “climate response indicator” would be introduced to help decide how much water should be released from Lake Powell.

“If the last three years have been really dry or exceptionally dry, then you adjust your Lake Powell releases,” he said.

Berggren and his environmental group, Western Resource Advocates, had a hand in developing this alternative along with the six other organizations.

All seven of the organizations that crafted the river management proposal have received funding from the Walton Family Foundation, which also supports KUNC’s Colorado River coverage.

Supply driven alternative

“All this does is say that what you release from Lake Powell down to Lake Mead is based on some percentage of the preceding three years,” Berggren said. “You look at the past three years, and you take some percentage of that, and that’s what you release from Glen Canyon Dam, and that’s basically it.”

He said the plan, which incorporates ideas from the states themselves, was nicknamed “the amicable divorce of the basins.”

“Because it was basically the upper basin will do its thing with Lake Powell and its upper basin reservoirs,” he said. “And then whatever gets released, lower basin deals with that, deals with Lake Mead, deals with lower basin shortages.”

Shortages in the lower basin could be up to 2.1 million acre feet a year in this scenario, according to the Interior Department.

Public comment is being accepted on all five alternatives through early March.

Map of the Colorado River drainage basin, created using USGS data. By Shannon1 Creative Commons Attribution-Share Alike 4.0

#Utah officials pillage public lands — again: BLM greenlights St. George highway; Lawmakers look to repeal GSENM management plan — Jonathan P. Thompson (LandDesk.org)

The Antiquities Act of 1906 was signed into law by Theodore Roosevelt, for “… the protection of objects of historic and scientific interest” through the designation of national monuments by the President and Congress. National monuments are one of the types of specially-designated areas that make up the BLM’s National Conservation Lands. Some of the earliest national monuments included Devils Tower, the Grand Canyon, and Death Valley. They were initially protected by the War Department, then later by the National Park Service. More recently, the BLM and other Federal agencies have retained stewardship responsibilities for national monuments on public lands. In fact, the BLM manages more acres of national monuments in the continental U. S. than any other agency. This includes the largest land-based national monument, the Grand Staircase-Escalante National Monument in Utah featured here. National monuments under the BLM’s stewardship have yielded numerous scientific discoveries, ranging from fossils of previously unknown dinosaurs to new theories about prehistoric cultures. They provide places to view some of America’s darkest night skies, most unique wildlife, and treasured archaeological resources. In total, twenty BLM-managed national monuments, covering over five million acres, are found throughout the western U. S. and offer endless opportunities for discovery. Photos and description by Bob Wick, BLM.

Click the link to read the article on The Land Desk website (Jonathan P. Thompson):

January 23, 2026

🌵 Public Lands 🌲

St. George, in Utah’s southwest corner, is one of the nation’s fastest growing communities. This is partly because of a nice climate, access to a major interstate, and relative closeness to Salt Lake City and Las Vegas. But it’s also because the landscape in which it sits is stunning, characterized by burnished red sandstone punctuated by dark volcanic formations and the green ribbons of the Santa Clara and Virgin Rivers, all set against the backdrop of the Pine Valley Mountains. In 2009, Congress created the Red Cliffs National Conservation Area on about 45,000 acres of BLM land just north of St. George to protect some of this landscape and its wildlife, and to offer a refuge from the burgeoning mass of humanity.

Satellite view of St. George, the southern end of the Red Cliff National Conservation Area, and the proposed highway corridor just approved by the BLM (in purple). The highway would fragment desert tortoise habitat and near-town hiking areas. Google Earth image.

But the Trump administration — and the state of Utah — have other plans. This week, the Bureau of Land Management approved Utah’s plans to build a four-lane highwaythrough the south end of the conservation area. The stated aim is to accommodate growth, reduce congestion, and speed up the car trip from one section of sprawl to another. But really it will only induce growth and more traffic, while also diminishing one of St. George’s most appealing assets.

The idea for a Northern Corridor Highway has been bantered about for a couple of decades. The proposal seemed to perish in 2016, when the BLM denied Washington County’s bid to build the road through the national conservation area. But when Donald Trump was elected president the first time, the county and the Utah Department of Transportation seized the opportunity to apply for a right of way to build a 4.5 mile, four-lane highway across a portion of the conservation area.

Red Cliff National Conservation Area. The Northern Corridor Highway would connect to the Red Hills Parkway in the mid-ground of the photo about one-third of the way in from the left. Jonathan P. Thompson photo.

In January 2021, the outgoing Trump administration’s BLM approved the right of way, even though its own analysis acknowledged that it would destroy tortoise habitat, spread invasive species, and essentially chop off the southern end of the conservation area, destroying trails and damaging the recreation experience. A large coalition of environmental groups under the banner of the Red Cliffs Conservation Coalition sued the BLM, and the agency ultimately agreed to redo the environmental analysis — finally rejecting the proposed highway at the end of 2024 and recommending an expansion of the existing Red Hills Parkway, instead.

Once Biden was out of office, however, the state and Washington County once again appealed to the feds to grant them a right-of-way, arguing that the Red Hills Parkway idea was not feasible. And since the Trump administration and Utah’s elected leaders tend to value roads and more suburban sprawl over tortoises, beauty, and the thriving desert landscape, the BLM opened the door to bulldoze more land to indulge Utah’s road fetish and to make way for yet another monument to America’s car-centric culture.

***

A couple of dispatches ago, I wrote about how curious it was that the Trump administration had yet to move to diminish or eliminate any national monuments during this second term. It may be because they are outsourcing the task to Congress.

Utah’s congressional delegation is expected to introduce federal legislation that would use the Congressional Review Act to overturn the Biden-era Grand Staircase-Escalante National Monument management plan. If the “resolution of disapproval” passes both chambers of Congress with a simple majority vote, it would erase the plan and bar the Bureau of Land Management from issuing another plan that is “substantially the same” in the future.

This wouldn’t change the boundaries of the monument, but would likely cause management of the area to revert back to the 2020, Trump I-era plan. That plan was not only less protective than the newer one, but only applied to a much smaller area, since in 2017 Trump had significantly shrunk the national monument. Revoking the current management plan, then, would leave vast areas of the monument in a sort of management limbo.

“I strongly denounce any attempt to use the Congressional Review Act to overturn the Grand Staircase-Escalante National Monument Resource Management Plan. This plan reflects years of public input, scientific research, and meaningful Tribal consultation, and dismantling it through procedural shortcuts undermines good governance, responsible land stewardship, and the protection of irreplaceable cultural landscapes,” said Autumn Gillard, Southern Paiute, Grand Staircase-Escalante Inter-Tribal Coalition member, in a written statement. “At this time, I urge lawmakers from both sides of the aisle to uphold the approved resource management plan from January 2025.”


Feds seek public input on Grand Staircase-Escalante management plan — Jonathan P. Thompson


***

Utah officials often say they dislike new national monument designations because, in their minds, protecting land and cultural resources is bad for the economy, mostly because they block new mining and drilling. A new study shows they are wrong.

Headwaters Economics analyzed economic conditions and trends in 30 national monument gateway communities, and found that national monument designations do not disrupt local economies. They also don’t give nearby communities a substantial economic boost. “Employment and population trends continue on the same trajectory after designation,” Headwaters found, “and income growth tends to improve modestly over time.”

From Headwaters Economics’ economic performance of communities near national monuments report.

The findings match up with what one would intuitively expect. National monuments are rarely designated in areas that are currently targeted for new drilling and mining, meaning they are unlikely to affect the existing extractive economies. Meanwhile, they are often established in places that are already experiencing an increase in visitation, meaning that designation wouldn’t necessarily cause a significant jump in tourism.

Take Bears Ears National Monument, for example. It was established in 2016 on federal land in San Juan County, Utah. Both the oil and gas and uranium mining industries were (and are) active in the county. But they weren’t interested in drilling new wells or opening new mines within the monument’s boundaries. Previous oil and gas wells had mostly come up dry — drillers have found much more success in the Aneth and McElmo fields east of the monument. And the Daneros uranium mine, which is been on standby status for years, is outside the boundaries, as well. In other words, monument designation had absolutely zero effect on either industry.

Meanwhile, fears that establishing a national monument in this corner of southeastern Utah would lead to its “discovery” by the masses were overblown, simply because the internet and social media had already lured folks to the area. Indeed, part of the reason people pushed for designation was to try to get a handle on increased visitation and its impacts on natural and cultural resources.

Headwaters has a nice interactive graphic on which you can check out the economic trends around the 30 national monuments. The trends, themselves, are interesting to see: They make it abundantly clear that other factors, especially COVID-19, had a much bigger effect than any national monument designation.


The Meaning of Monuments — Jonathan P. Thompson


🤖 Data Center Watch 👾

The Big Data Center Buildup is accelerating. Nearly every day I get news of another proposed hyperscale facility somewhere in the West. A lot of them are not planning on connecting to the power grid, which is good for other utility users, because they won’t have to pay for associated infrastructure upgrades. But in almost every case, their proposed power sources include at least some gas-fired generation. And natural gas, i.e. methane, is not clean energy by any means.

So, while the data center boom has the potential to accelerate the clean energy transition by encouraging more solar, wind, and battery storage, it is also slowing the transition by perpetuating fossil fuel burning and even prompting construction of new fossil fuel-fired facilities.

Projects that have come onto my radar recently include:

  • Laramie County, Wyoming’s commissioners approved Crusoe Energy Systems’ and Tallgrass’ proposed AI data center complex near Cheyenne, despite residents’ pushback over the project’s massive scale. If this thing is built as planned, it will be ginormous, with estimated capital costs of $50 billion. That would not only include the Project Jade’s five data centers and associated structures, but also a 2,700 MW gas-fired power plant — which would be among the largest of its kind in the West. The developers plan to use a closed-loop cooling system, which is less water-intensive than conventional evaporative systems but uses more energy.
  • About 150 miles west of there, Power Company of Wyoming, an Anschutz Corporation subsidiary, is proposing a 2,000 MW gas generating facility in Carbon County to serve growing data center-driven power demand. These are the same folks who are building the Chokecherry Sierra Madre wind project and the TransWest Express transmission line. The controversial, 732-mile TransWest Express was originally billed as a clean-energy line that would carry Wyoming wind to California. Looks like it also will be moving fossil fuel-fired power, as well.
  • Residents of Surprise, Arizona, a section of Phoenix’s sprawl, are getting a little surprise of their own: A proposed data center and dedicated 700 MW natural gas plant adjacent to a residential neighborhood. Residents are not too pleased, according to a story in the Arizona Republic, and are worried about the environmental and health impacts of a gas plant and the data center. The data center would run off the gas plant for the first couple years of operation before connecting with the grid. Then the plant would serve as backup for the center as well as a “peaker” plant, meaning it is fired up during peak demand.
🫣 Correction 🙀

In this week’s Colorado River glossary and primer I inadvertently shrunk the Colorado River watershed quite significantly by leaving out two zeros. It covers about 250,000 square miles, not 2,500. Duh.

Cool Opportunity

The Wright-Ingraham Institute is now taking applications for its three-week immersive fellowship for graduate students and early-career professionals in science, design, policy, the arts, and beyond. This year’s field workshop focuses is on “designing for adaptation in a time of prolonged drought,” and will be held in the San Luis Valley and Taos Plateau from July 6-27. Read more and apply here

📸 Parting Shot 🎞️

This one popped up on my Facebook feed and I just had to purloin it. It’s downtown Grand Junction in the 1960s (I believe), not long after they refashioned the main drag to make it more people-friendly. It’s funny because a lot of folks in my hometown of Durango are freaking out about a proposal to do something kind of like this, but even less radical, to its downtown. They claim that widening sidewalks and so forth will destroy the historic integrity of the streetscape. In my mind, this photo illustrates how untrue that claim is.

The 2025 U.S. Geothermal Market Report is now available, offering an in-depth update on the state of #geothermal energy — National Laboratory of the Rockies

Production well at Blue Mountain Geothermal Plant in Humboldt County, Nevada. Photo by Dennis Schroeder, National Laboratory of the Rockies 48293

Click the link to access the report on the National Laboratory of the Rockies website. Here’s the executive summary:

January 23, 2026

The 2025 U.S. Geothermal Market Report updates and expands on the 2021 U.S. Geothermal Power Production and District Heating Market Report, also referred to as the 2021 Geothermal Market Report (Robins et al., 2021). This report was developed by the National Laboratory of the Rockies (NLR), formerly known as NREL, a national laboratory supporting the U.S. Department of Energy (DOE), and Geothermal Rising, a professional and trade association for the geothermal industry, with support from the International Ground Source Heat Pump Association (IGSHPA), a professional organization for advancing geothermal heat pump technologies. The intent of this work is to provide policymakers, developers, researchers, engineers, financiers, and other stakeholders with an update on the U.S. geothermal market.

This report discusses updates since 2020 regarding technology, cost trends, and market activities for both geothermal power production as well as geothermal heating and cooling systems. A notable difference since the 2021 Geothermal Market Report is the inclusion of geothermal heat pumps (GHPs) for both single building and district heating and cooling applications. This section provides a summary of key findings—first for geothermal power generation, then for geothermal heating and cooling systems, and finally for emerging opportunities.

Geothermal Power Generation Market: Key Findings, Steady Increase in Installed Capacity

Concentrated in Western States Geothermal power installed nameplate capacity as of 2024 is 3.969 gigawatts-electric (GWe) (3,969 megawatts-electric [MWe]), an 8% increase from 3.673 GWe (3,673 MWe) in 2020. This net increase comprises 246 MWe of new installed capacity, 132 MWe of capacity expansions/additions, and 82 MWe in plant retirements between 2020 and June 2024 (Figure ES-1). Correspondingly, summer and winter net capacities have also risen from 2.56 GWe and 2.96 GWe in 2019 to 2.69 GWe and 3.12 GWe in 2023, respectively. Two operators, Ormat and Calpine, continue to comprise the majority of U.S. geothermal power plant ownership and operation. Together they account for 69% of total installed capacity and 61% of all operating geothermal plants in the United States.

Figure ES-1. Geothermal nameplate capacity growth in the United States since 2021 Geothermal Market Report. Note that “new refers to nine new plants that have come online, “retired” represents six plants that are no longer operational, and “expanded” includes plants that have reported changes in their capacity.

Geothermal power plants are almost entirely concentrated in the western United States (see Figure ES-2). This geographical region consists of several Known Geothermal Resource Areas (e.g., The Geysers), with high thermal gradients, heat flow, and permeability, that have been historically explored and developed for power production. California hosts 53 of the 99 geothermal power plants1 in the country, with a total installed nameplate capacity of 2.87 GWe (2,868 MWe, 72% of the U.S. total). Nevada, with significant resource potential, is second with 32 power plants and an installed nameplate capacity of 892 MWe. Other states with geothermal power installed include Oregon and Utah with four plants each, Hawai‘i and Alaska with two plants each, and Idaho and New Mexico with a single plant each.2

Figure ES-2. Distribution and installed nameplate capacity of geothermal
power plants in the United States as of June 2024. Data from EIA (2024a, 2024d).
In the power plant totals for each state, a single plant is described by the installation
year (Appendix B) as it can consist of one or more generating units installed over
years. Some plants (e.g., Puna in Hawai‘i and McGinness Hills in Nevada) have been
expanded in subsequent years after the first unit was installed. These are treated as
separate plants as shown in Appendix B. This does not include planned plants that
are not yet operational.

New Power Purchase Agreements and Projects Under Development Indicate Accelerated Interest by Utilities, Corporations

The rise in recent power purchase agreements (PPAs)—26 since the 2021 Geothermal Market Report, as of June 2025—is an indicator that the geothermal power sector is primed for substantial growth. In total, these represent more than 1.6 GWe (1,642 MWe) of new capacity commitments to be developed in the near term (see Figure ES-3 for a map of new developments). The California Public Utilities Commission (CPUC) released a procurement order in 2021 that contributed to the increase in PPAs (CPUC, 2021). NLR analysis in this report shows that the order has led to the signing of at least 616 MWe in PPAs between geothermal developers and load-serving entities in California as of June 2025. This order also awarded credits to imports of firm (i.e., “always on”) power from other states, resulting in PPAs signed between California purchasers and geothermal developers in Nevada and Utah.

Next-generation geothermal systems3 account for 60% of geothermal PPAs signed between 2021 and July 2025. The first of these PPAs was signed in 2022 between Fervo Energy and Google, through NV Energy, for 3.5 MWe of power produced from an enhanced geothermal system (EGS) project. As of June 2025, utilities have procured (or agreed to procure) 984 MWe of next-generation geothermal power capacity across California (439 MWe), Nevada (135 MWe), New Mexico (150 MWe), Texas (110 MWe), and an undisclosed location east of the Rocky Mountains (150 MWe) through 11 PPAs.

Overall, the number of geothermal power projects under development has increased from 54 to 64 since 2020. This is based on data gathered through industry survey respondents as of June 2024 from major geothermal developers and operators, and compares data from companies that existed in both 2020 and 2024. Ormat continues to lead in conventional commercial geothermal development, with 37 projects under development. Fervo Energy, with four developing projects, and Sage Geosystems and Eavor, with two projects each, are spearheading commercial next-generation geothermal.

Major R&D and Commercial Advancements in Next-Generation Power Technologies

DOE’s Frontier Observatory for Research in Geothermal Energy (FORGE) site near Milford, in Beaver County, Utah, has been largely successful in showing a replicable process for developing EGS reservoirs. FORGE has drilled seven wells, and has achieved notable improvements in drilling performance, including reduction in on-bottom drilling hours—110 hours for a well in 2023 compared to 310 hours for a well in 2020 (Dupriest and Noynaert, 2024).

Figure ES-3. New geothermal power project developments within PPAs signed between 2021 and July 2025, including those related to the 2021 CPUC procurement order. Data from multiple sources; see Table 3 for more information. Note that CCA stands for Community Choice Aggregator, SCE stands for Southern California Edison, and CPA stands for Clean Power Alliance.

In 2023, Fervo Energy recorded the first commercial-scale EGS drilling and reservoir development pilot in the United States adjacent to the Blue Mountain Geothermal Plant in Nevada (Norbeck and Latimer, 2023). Fervo Energy has an additional four projects in development, including a first-of-a-kind large-scale 500-MWe (100 MWe Phase 1 and 400 MWe Phase 2) commercial EGS project underway at their Cape Station site near Utah FORGE in Beaver County, Utah (Fervo Energy, 2024a).

The development of closed-loop geothermal (CLG) systems is steadily advancing. In 2022, Eavor Technologies drilled the first two-leg multilateral deep geothermal well in the U.S. in New Mexico. In that project, Eavor drilled a single vertical well with a sidetrack to a true vertical depth of 18,000 ft and rock temperature of 250°C, a first in the U.S. geothermal industry (Brown et al., 2023).

EGS Costs Decreasing, Conventional Hydrothermal Costs Holding Steady

The levelized cost of energy (LCOE) for EGS is declining (Figure ES-4) and is projected to hit levels of 2024 flash hydrothermal LCOE within the next decade based on the 2024 Annual Technology Baseline (ATB) Moderate Scenario (NLR, 2024). The latest outcomes from Fervo’s drilling, stimulation, and well testing activities at its Cape Station site have bolstered this developing projection. As seen in Figure ES-4, the LCOE for conventional hydrothermal systems has been relatively flat since the 2021 Geothermal Market Report and has hovered between $63–74 per megawatt-hour (MWh) for flash-based plants and $90–110 per MWh for binary plants. However, these LCOEs are competitive with the geothermal PPA prices compiled in this report.

Investment in Next-Generation Geothermal Technologies Is Accelerating

Companies at the forefront of developing and commercializing next-generation geothermal technologies have raised more than $1.5 billion in private capital since 2021. According to recent data gathered by NLR, EGS and CLG technology companies and startups have brought in $990 million and $604 million, respectively, in capital investment between 2021 and mid-2025. Within this period, Fervo Energy and Eavor Technologies raised additional amounts—$642 million and $387 million in equity investments, respectively (Fervo Energy, 2024a, 2024b, 2024c, 2025; Eavor Technologies, 2024a). Technology advances are helping to increase attractiveness of next-generation geothermal for debt financing. Fervo has secured $331 million in debt financing through various loan facilities to finance their Cape Station project in Utah, and Eavor received $142 million in loans in 2024 (Fervo Energy, 2024b, 2025; Eavor Technologies, 2024a; 2024b).

Figure ES-4. The levelized cost of energy for geothermal power technologies from the 2021 ATB to the 2024 ATB. All costs are in 2022 dollars (the 2024 ATB base year).

Domestic Geothermal Potential Is Abundant, Including on Public Lands

Based on recent NLR analysis, the estimated average EGS resource potential is 27 terawatt-electric (TWe) to 57 TWe within 1- to 7-km depth across the continental United States (Menon et al., 2025). NLR also estimates 4.35 TWe of EGS resources are within Bureau of Land Management (BLM) and United States Forest Service (USFS) land (Martinez Smith et al., 2024). Further analysis of these results indicates a smaller amount of resource potential that is considered economically developable, including 1.1% (47.8 GWe) of EGS resources. As of June 2025, geothermal projects on public lands (managed by the BLM as part of the Federal mineral estate) total 2,600 MWe of nameplate capacity, with 756 MWe added since 2000 (EIA, 2024a; Ormat, 2024a). As of 2023, 51 geothermal power plants are in operation on BLM-managed lands (BLM, 2023b). In 2022, geothermal power plants on BLM-managed lands generated 11.1 terawatt-hours (TWh) of electricity (EIA, 2024a, 2024b, 2024c).

Figure ES-5. Private capital investments in next-generation geothermal
developers between 2021 and June 2025. Sources: Fervo Energy (2024a, 2024b,
2024c, 2025), Business Wire (2024a; 2024b; 2025a), Eavor Technologies (2024a; 2024b), and Pitchbook (2025).

States Incentivize Geothermal Power Projects

As of December 2025, there were 29 U.S. states with incentive policies for geothermal power including grants, rebates, tax incentives, and other financial incentives (e.g., reduced cost and/or free application fees for permit processing). A total of 17 states and D.C. have policies that encourage geothermal electricity production, including tax credits. Furthermore, 42 states and D.C. have existing regulatory policies that include geothermal power, which include energy and efficiency standards, net metering, and/or interconnection standards.

Geothermal Heating and Cooling Market: Key Findings

Geothermal Heat Pumps Are Reliable, Highly Efficient, and Available Across the Country The GHP market is an established energy market for residential and commercial building heating and cooling. GHPs are used across all geographical and climatic regions in the United States, according to census track data from the Energy Information Administration (EIA) (Figure ES-6) and corroborated by historical well permit data collected by NLR for single building GHP installations (Pauling, Podgorny, and Akindipe, 2025).4

GHP systems have seeen increased adoption across various sectors, including residential, commercial, and industrial applications. Residential use has been a major focus as homeowners seek energy-efficient options. Based on extrapolation of data from the Residential Energy Consumption Survey (RECS) and the Commercial Building Energy Consumption Survey (CBECS), an estimated 1.27 million residential housing units and 27,300 commercial buildings across the United States have GHP installations. In the residential sector, Florida, Tennessee, and North Carolina are estimated to have the highest number of housing units with GHPs.

Incentives Help Offer Consumers Energy Options

As of December 2025, 34 states and D.C. have incentive policies for GHPs. These include grants, rebates, tax incentives, and other financial incentives. In addition, eight states have policies that encourage GHP adoption. 23 states and D.C. have existing regulatory policies for GHPs. As of July 2025, at the federal level, homeowners were eligible for a 30% tax credit on GHPs as part of the Inflation Reduction Act (IRA) Residential Energy Credit (Section 25D of U.S. Code 2025a), however, the property must have been placed in service prior to December 31, 2025. As of July 4, 2025, an exemption to the IRS policy of limited-use property doctrine was created for geothermal systems where they may now be leased by a third-party, including to residential customers (Section 50 of U.S. Code, 2025c). The IRA also includes a base 6% tax credit for commercial building owners installing GHPs (Section 48 of U.S. Code, 2025b).

GHPs Offer Secure, Reliable Support

for U.S. Grid Infrastructure GHPs can offer up to $1 trillion in value in the form of avoided grid infrastructure build-out costs to the future U.S. grid. Oak Ridge National Laboratory estimates that GHP deployment in 68% of the total existing and new building floor space in single-family homes in the continental United States by 2050 would provide multiple benefits to the electric grid, including up to $306 billion reduction in electric power system costs and up to $606 billion savings in wholesale electricity marginal costs (Liu et al., 2023). Mass GHP deployment is estimated to have the potential to reduce required additional annual generation by 585–937 TWh and power and storage capacity by 173–410 GW. Mass GHP deployment is also expected to alleviate the need for transmission build outs by 3.3–65.3 TW-miles.

Figure ES-6. GHP installations in the United States. State-level distribution of residential housing units with GHPs estimated using EIA’s 2020 RECS data (EIA, 2023b).
Figure ES-6. GHP installations in the United States. Census division-level distribution of commercial buildings with GHPs using 2018 CBECS data (EIA, 2023a).

Thermal Energy Networks Are a Growing Market for District Heating and Cooling

Accelerating interest in energy efficiency in buildings from neighborhood to city scale has spurred the rise of Thermal Energy Networks (TENs). A geothermal TEN is a fifth- generation geothermal district heating and cooling system with decentralized GHPs connected to a shared distribution loop. States like California, Colorado, Maryland, Massachusetts, Minnesota, New York, Vermont, and Washington have enacted regulations and announced programs that specifically address the need for geothermal TENs within energy utility service territories (Varela and Magavi, 2024).

In 2024, the natural gas utility Eversource Energy commissioned a first-of-its-kind U.S. utility-owned geothermal TEN pilot in Framingham, Massachusetts. The Framingham project consists of an ambient temperature loop that connects decentralized GHPs in 36 buildings—including 24 residential and five commercial buildings—to three borehole fields (Eversource, 2025). The Framingham pilot project serves as a first example and path forward for the rapidly growing national interest by natural gas utilities and state regulatory agencies in developing TEN projects within their service territories and jurisdictions.

Geothermal Direct Use in the United States Cuts Across Multiple End Uses

Based on updated data compiled by NLR beyond the 2021 Market Report (Robins et al., 2021), there were close to 500 geothermal direct-use (GDU) installations (by end-use application) in the United States as of October 2024. Of these, GDU for heating resorts and pools accounts for the largest portion (59%) with 281 installations, followed by space heating (77), aquaculture (47), greenhouse (37), district heating (25), and other (15) applications, including dehydration, snow melting, irrigation, and gardening. With 89 installations, California has the most GDU installations in the United States.

Emerging Opportunities: Key Findings

Geothermal As Part of U.S. Energy Security and Independence

From a power generation perspective, geothermal energy can strengthen the electric grid and provide resilience against extreme weather, power outages, and cyberattacks. These benefits likely contributed to the greenlighting of geothermal energy projects within multiple U.S. Department of Defense (DoD) installations. Specifically, DoD awarded six projects between September 2023 and April 2024 to explore the potential of conventional and next-generation geothermal technologies in a total of seven installations. The DoD locations (and awardees) include Joint Base San Antonio in Texas (Eavor), Fort Wainwright in Alaska (Teverra), Mountain Home Air Force Base in Idaho (Zanskar), Fort Irwin in California (Zanskar), Naval Air Station Fallon in Nevada (Fervo), Naval Air Facility El Centro in California (GreenFire Energy), and Fort Bliss in Texas (Sage Geosystems) (Defense Innovation Unit, 2023, 2024). In August 2025, the DoD installations were expanded to include the Marine Corps Air Ground Combat Center Twenty-Nine Palms and the Sierra Army Depot, both in California (GreenFire Energy), the Naval Air Station Corpus Christi in Texas (Sage Geosystems), and the Army’s White Sands Missile Range in New Mexico (Teverra) (Defense Innovation Unit, 2025). In a separate effort, the U.S. Department of the Air Force awarded Sage Geosystems a $1.9-million grant in September 2024 for a pilot demonstration of their next-generation technology at an off-site test well in Starr County, Texas (Bela, 2024).

Among heating and cooling technologies, geothermal is a resilient and reliable option. As a resilient energy source, it is not affected by supply chain disruptions and energy price fluctuations like conventional heating fuels. As a reliable energy source, the resource capacity of geothermal for heating and cooling through GHPs is not directly affected by changes in surface weather conditions. These uniqueattributes have been found useful for various building types across the U.S., including federal buildings. Based on recent analysis, 24 separate GHP projects were awarded in federal buildings between 2001 and 2014 across the country, leading to energy and maintenance cost savings (Shonder and Walker, 2024).

Data Center Support Is a Key Opportunity Area for Geothermal Power

Data center load growth has tripled over the past decade and is projected to double or triple by 2028 (Shehabi et al., 2024). Geothermal energy has the potential to play a key role in meeting the rapidly growing power demands of artificial intelligence (AI)-driven data centers by providing firm, reliable energy as well as critical opportunities to significantly reduce peak data center cooling demands through underground thermal energy storage. Major technology companies have already turned to geothermal energy to power their operations—Meta signed a PPA in 2024 with Sage Geosystems for up to 150 MWe of geothermal power to support its U.S. data centers (Meta, 2024) and another 150 MWe PPA with XGS to support data centers in New Mexico (Business Wire, 2025b). Similarly, Google expanded its partnership with Fervo Energy and NV Energy in 2024 beyond the initial 3.5 MWe agreement, securing 115 MWe of geothermal energy to supply its Nevada data centers (Hanley, 2024).

Superhot Geothermal Could Boost Geothermal Well Output

Superhot/supercritical geothermal has the potential to deliver 5–10 times the thermal energy output per well compared to conventional geothermal systems (CATF, 2025). Estimates suggest that harnessing heat from superhot resources shallower than 10 kilometers (km)—accessible with existing drilling technology—could supply up to 50% of current global electricity demand (Kiran et al., 2024). DOE’s Geothermal Technologies Office (GTO) funded research in this area, including a project to de-risk superhot exploration and one to demonstrate superhot EGS on the western flank of Oregon’s Newberry Volcano (GTO, 2024a).

Hybrid Plants, Geological Thermal Energy Storage, and Co-Production Could Offer Additional Avenues for Flexible Generation and Grid Stability

In addition to providing flexible generation and grid stability, geothermal can be used as a balancing resource. For instance, hybrid plants integrating geothermal with solar photovoltaic or concentrating solar thermal technologies can provide baseload capacity and peaking power. Examples of this include Cyrq Energy’s Patua project, Ormat’s Tungsten Mountain project, and Ormat’s (formerly Enel’s) Stillwater project.

Another growing application of geothermal is geological thermal energy storage (GeoTES). GeoTES converts sedimentary reservoirs (e.g., depleted oil and gas reservoirs) to long-duration energy storage systems. There are not yet any active GeoTES plants in the United States, but GTO and DOE’s Solar Energy Technologies Office previously separately selected for negotiation two demonstration projects in this space. The first project aims to develop a 100-kilowatt-electric (kWe) demonstration power plant with more than 12 hours of GeoTES in depleted oil reservoirs in Kern County, California (Partida, 2024; Umbro et al., 2025), while the second will feature a GeoTES demonstration project at Kern Front Oil Field in the same county (Cariaga, 2024c).

Co-production of geothermal energy from oil and gas reservoirs is an approach that harnesses the thermal energy present in the fluids produced during oil and gas extraction. In January 2022, DOE awarded $8.4 million to four projects as part of the Wells of Opportunity initiative. These projects—led by Geothermix, ICE Thermal Harvesting, Gradient Geothermal (formerly Transitional Energy), and University of Oklahoma—aim to repurpose inactive or idle hydrocarbon wells for geothermal energy use (GTO, 2025c).

Mineral Extraction From Geothermal Brines Could Help Address U.S. Critical Materials Competitiveness

Another emerging opportunity for geothermal is mineral extraction from geothermal brines, particularly lithium. Findings from Lawrence Berkeley National Laboratory indicate the Salton Sea lithium resource is estimated to be close to 3,400 kilotons, offering the potential to create a domestic lithium industry in the United States (Dobson et al., 2023). Technological innovations in mineral extraction technologies like direct lithium extraction continue to advance. Work to continue these advances includes GTO-funded national laboratory projects for research and development on lithium extraction in Known Geothermal Resource Areas within and beyond the Salton Sea, California, and additional projects targeting the Smackover Formation and other areas of the U.S. with mineral and geothermal potential, previously funded by GTO in collaboration with DOE’s Advanced Manufacturing and Materials Office and DOE’s Office of Fossil Energy (GTO, 2024c).


Footnotes

1 Multiple geothermal power plants can be situated in a Known Geothermal Resource Area. For example, 17 of the 53 plants in California are within The Geysers Known Geothermal Resource Area.

2 A single plant is described by the installation year (Appendix B) as it can consist of one or more generating units installed over years. Some plants (e.g., Puna in Hawai‘i and McGinness Hills in Nevada) have been expanded in subsequent years after the first unit was installed. These are treated as separate plants as shown in Appendix B

3 The term “next-generation geothermal systems” refers to technologies that enable geothermal energy to be harnessed in low to ultra-low permeability formations through advanced drilling and/or stimulation techniques. This technology category currently includes enhanced geothermal systems and closed-loop geothermal systems.

Driving a system to crisis — Andy Mueller (#Colorado River District) #ColoradoRiver #COriver #aridification

The structural deficit refers to the consumption by Lower Basin states of more water than enters Lake Mead each year. The deficit, which includes losses from evaporation, is estimated at 1.2 million acre-feet a year. (Image: Central Arizona Project circa 2019)

From email from the Colorado River Water Conservation District (Andy Mueller):

January 17. 2026

The Colorado River system is on the brink of collapse, drained by decades of overuse in the lower basin states and accelerated by the impacts of climate change. While this is not the first time that we have stared down a crisis at Lake Powell, in the past, we have gotten lucky, saved by big snows and cold winters.

This year, however, it does not appear that Mother Nature is going to bail us out.

On the Western Slope, we spent our holidays staring at snowless, brown hillsides and dry, rocky riverbeds as water year 2026 began setting records — all in the wrong direction. At the Colorado River District, our job is to protect the water security of the Western Slope, regardless of the condition of the snowpack. We can’t make it snow, but we can hold decision-makers accountable for their choices, and as we near the deadline of the post-2026 river operation guideline negotiations, we can demand that they do not continue to make the same mistakes which have driven us to this crisis.

In recent months, as pressure and public scrutiny have grown around the negotiations between the seven Colorado River Basin states, it has become clear that the Lower Basin states of Arizona, California, and Nevada are looking for a scapegoat. They have begun loudly accusing the Upper Basin states of Colorado, Utah, Wyoming, and New Mexico of being inflexible and unwilling to compromise on a solution to balance the system. They believe that their political might and economic clout entitles them to continue to use more than their share and absolves them of responsibility for their part in the collapse of the system.

But that is not reality.

Over 100 years ago, the Colorado River Compact was designed with exactly this moment in mind. It was created to allow Upper and Lower Basin states to develop their water separately, to meet the needs of their unique communities on their own timeline, and to steward their resources responsibly.

In eight pages, the Compact makes it clear that the communities of suburban Phoenix are not more important than those of western Colorado.

Think about it like this: in 1922, the Upper and the Lower Basin each bought a brand-new truck. Both came with contracts and manuals explaining proper use and maintenance, limits and legal obligations.

For years, their engines hummed.

During this time, the Lower Basin chose to modify their purchase contract to upgrade. They signed on the dotted line to accept the feds as their water master when they wanted to build Hoover Dam, and Arizona agreed to take junior water rights on the system to develop the Central Arizona Project.

But as things heated up in the early 2000s, the warning lights began to come on.

The Upper Basin quickly adapted to changing conditions, slowing down, or driving carefully around uncertain terrain. Without large reservoirs upstream and guaranteed water deliveries, water managers and agricultural producers in these states had to make tough decisions every month based on how much water was actually in the river.

Udall/Overpeck 4-panel Figure Colorado River temperature/precipitation/natural flows with trend. Lake Mead and Lake Powell storage. Updated through Water Year 2025. Note the tiny points on the annual data so that you can flyspeck the individual years. Credit: Brad Udall

The Lower Basin, however, chose to ignore the warning lights on their dashboard. Despite being told by multiple mechanics that they couldn’t continue to drive full speed anymore, they kept their foot on the gas.

Regardless of worsening hydrology, they overused their allotment by as much as 2.5 million acre-feet per year by not accounting for evaporative and transit loss or their full tributary use. In addition to this, Arizona hoarded over 300,000 acre-feet annually of Colorado River water by dumping it into the ground.

Left unaddressed, the problems compounded. Now their truck is seizing up, and the driver is trying to explain to everyone onboard why their broken vehicle is someone else’s fault.

In western Colorado, we have never had the luxury of looking away from the wear and tear caused by prolonged drought. Every year, we adjust our use to meet our obligations downstream and protect the health of our communities.

The 1922 Compact is not being renegotiated, but the interim rules governing water apportionment on the river are.

Any new agreements must recognize the hydrologic reality that water is a finite and shrinking resource and be consistent with our existing legal framework. New agreements must end the fiction that growth can continue without considering hydrology and reject any deal that forces western Colorado to subsidize decades of overuse elsewhere.


Andy Mueller is the general manager of the Colorado River Water Conservation District based in Glenwood Springs.

Originally published by The Grand Junction Daily Sentinel January 17, 2026.

Westwide SNOTEL basin-filled map January 22, 2026.

A #ColoradoRiver glossary and primer — Jonathan P. Thompson (LandDesk.org) #COriver #aridification

Hoover Dam at low water. Jonathan P. Thompson photo.

Click the link to read the article on The Land Desk website (Jonathan P. Thompson):

January 20, 2026

After last week’s somewhat wonky dispatch on the Colorado River, a couple of readers asked about some of the terminology used. That, along with the fact that the deadline for an agreement on how to operate the river’s plumbing is fast approaching, prompted me to put together a bit of a glossary/primer on the Colorado River to give a little more context to related news, which is likely to come fast and furious over the next several weeks. 

If I miss anything, or if you have other questions, please let me know and I’ll try to answer them soon. Also, I’ll be doing a host of data-driven, Colorado River-related dispatches in coming weeks to go over some of last year’s statistics on water consumption, water pricing, alfalfa production and exports, and so forth.

Colorado River Basin: A 250,000 square-mile watershed that includes southwestern Wyoming, western Colorado, southern and eastern Utah, southern Nevada, western New Mexico, Arizona, and eastern California. For administrative purposes, it has been split into the Lower Basin (CA, AZ, NV) and the Upper Basin (CO, WY, UT, NM), with the dividing line at Lees Ferry.

Law of the River: This isn’t an actual law, but rather a collection of agreements, compacts, treaties, laws, and Supreme Court decisions that serve as a framework for governing the Colorado River.

Doctrine of Prior Appropriation, aka First In Time, First in Right: This is the basis for most Western water law, which says that the first entity to put a set amount of water on a stream to beneficial use at a specific place has the highest or most senior priority of water rights. If a senior rights holder is not receiving their full appropriation due to drought or overuse, they can make a “call” on the river, forcing upstream, junior rights holders to stop diverting water from the stream or its tributaries.

Acre-foot (AF): Amount of water that would cover one acre one foot deep. 1 acre-foot = 325,851 gallons. MAF = million acre-feet.

Consumptive Use: The amount of water diverted from a stream minus the amount returned to it. For example, last year Nevada pulled about 443,000 acre-feet of water from the Colorado River, mostly via pumping plants in Lake Mead. But it returned about 244,000 acre-feet of treated wastewater to the reservoir via Las Vegas Wash, leaving it with a total consumptive use of about 198,000 acre-feet for the year. Evaporation and transpiration (or uptake by and evaporation from plants) are considered consumptive uses. Agriculture is the largest consumptive user in both the Upper and Lower basins.

Colorado River Compact: In 1922, representatives from the seven Colorado River states entered into a compact aimed at ending interstate conflict and litigation to clear the way for developing dams and diversions on the river. The compact gives each basin exclusive beneficial consumptive use of 7.5 million acre-feet of water per year, but also mandates that the Upper Basin “not cause the flow of the river at Lee Ferry to be depleted below an aggregate of 75 million acre-feet” for any 10-year period. A 1944 treaty reserved an additional 1.5 million acre-feet to Mexico, which would be covered by surplus or borne equally by the two basins.

I like to run this one again from time to time, just to remind folks how much the population of the West has grown over the last century. This is what the signers of the Colorado River Compact were dealing with as far as water users go — compared to some 40 million users now. Source: USGS.
  • The Upper Basin divided its 7.5 MAF by percentage: 51.75% to Colorado; 11.25%to New Mexico; 23% to Utah; 14% to Wyoming (plus an additional 50,000 acre-feet for the portion of Arizona in the Upper Basin).
  • The Lower Basin allotted 4.4 MAF to California; 2.8 MAF to Arizona; .3 MAF to Nevada.
  • 20 million acre-feet: Presumed total annual natural flow of the river upon which the compact was based and which was considered “more than sufficient to water all lands now being irrigated and all lands which can be economically developed for forty years to come.”
  • 17.3 million acre-feet: The actual annual flow recorded by the he U.S. Geological Survey during the nine years leading up to the compact’s ratification, with yearly flows ranging from 9.9 million acre-feet to 26.1 million acre-feet. That was during an unusually wet period.
  • 14.3 million acre-feet: Median annual natural flows at Lees Ferry from 1907 to 2025.
  • 8.5 million acre-feet: Estimated natural flow at Lees Ferry in 2025.
  • 2 million to 4 million acre-feet: Estimated amount of consumptive use that must be reduced to bring the Colorado River supply and demand into balance.
September 21, 1923, 9:00 a.m. — Colorado River at Lees Ferry. From right bank on line with Klohr’s house and gage house. Old “Dugway” or inclined gage shows to left of gage house. Gage height 11.05′, discharge 27,000 cfs. Lens 16, time =1/25, camera supported. Photo by G.C. Stevens of the USGS. Source: 1921-1937 Surface Water Records File, Colorado R. @ Lees Ferry, Laguna Niguel Federal Records Center, Accession No. 57-78-0006, Box 2 of 2 , Location No. MB053635.

Natural Flow at Lees Ferry: This is a calculated estimate of the amount of water that would flow past Lees Ferry if there were no upstream dams, diversions, or human consumptive use. This estimate would guide the supply driven option for dividing up the river. The USBR describes the method for determining it as such:

  • Provisional Natural Flow at Lees Ferry = observed annual flow at Lees Ferry + average Upper Basin consumptive use for the last 5 published years +/- net change in mainstream storage +/- net change in off-mainstem storage +/- net change bank storage + mainstem reservoir evaporation.
The estimated “natural flow” at Lee Ferry. Some of the alternatives would base Lake Powell releases on recent average natural flows at Lee Ferry. If the recent past is an indicator of what’s to come, we could expect a relatively minuscule amount of water running through the Grand Canyon to the Lower Basin states. Source: Bureau of Reclamation.

Winters v. the United States: 1908 Supreme Court ruling establishing that when the federal government “reserved” land for a tribal nation, it also reserved rights to water. And the appropriation date for those water rights would be the date the reservation was established, whether or not the tribe put the water to “beneficial use” at that time. Winters did not quantify the amount of water tribes were entitled to, except that it should be “sufficient … for irrigation purposes.”

  • By rights, this would give the 30 tribal nations within the watershed the most senior rights to most if not all of the water in the Colorado River. Five lower Colorado River tribes currently have quantified and settled rights to about 900,000 acre-feet, while Upper Basin tribes have settled and quantified about 1.1 million acre-feet. But other tribes have yet to settle or quantify their rights, so they remain in a sort of limbo.
  • In many cases, the tribal nations lack the infrastructure for putting their water rights to use, meaning they end up relying on federal infrastructure — and on the respective appropriation dates for the infrastructure. An example: The Ute Mountain Ute tribe has 1868 water rights on the Dolores River in southwestern Colorado. But they actually receive their water via the Dolores Project, which only has 1968 rights — which are junior to most of the white farmers on the river. That means during very low water years, the tribe can lose most of its water.
Eugene Clyde LaRue measuring the flow in Nankoweap Creek, 1923. Photo credit: USGS

Eugene C. LaRue: One of the early 20th century’s foremost authorities on the Colorado River, who warned the Colorado Compact signatories that their negotiations were based on overestimates of the river’s supply. In 1916, he wrote: “Evidently, the flow of the Colorado River and its tributaries is not sufficient to irrigate all the irrigable lands lying within the basin.” LaRue also warned against building Hoover Dam because evaporation would further deplete water supplies and suggested banning trans-basin diversions, or exporting water from the Colorado River watershed to other parts of the seven basin states. The signatories heard LaRue but clearly didn’t heed his warning, even though he repeated it many times prior to the compact’s signing. (He eventually resigned in protest.)

Minimum Power Pool: Surface elevation of Lake Powell or Lake Mead below which hydroelectric production is no longer possible because it is lower than the dam’s penstocks. This is especially critical at Lake Powell because if water can’t be released through the penstocks and turbines, it must go through lower river outlets, which are not equipped for long-term releases and could be damaged by constant use. Also, the electricity from the dam is critical to Southwestern power grids, and sales of it raise revenue for endangered native fish recovery programs.

Deadpool: Surface elevation of Lake Powell or Lake Mead below which no water can be released from the dam. So in Lake Powell, this means the water would drop below the river outlets, which could happen if the reservoir is drawn down to the river outlet level, and then reservoir seepage and evaporation exceeds inflows (which could happen late in a hot, dry summer).

Run of the River: This is the term for when releases from a dam are equal to reservoir inflows minus evaporation and seepage at any given time. In other words, if inflows were 20,000 cfs, releases would be slightly lower, and the dam wouldn’t hold any water back (or release any storage). Glen Canyon dam operators could use this method to keep Lake Powell from dropping below minimum power pool.

Transbasin Diversion: Moving water from one watershed to another, within the same state, e.g. from the Colorado River’s headwaters to the state’s populous Front Range, or from the Navajo River (a tributary of the San Juan, which is a tributary of the Colorado) to the Chama River (a tributary of the Rio Grande).

Central Arizona Project: The 366-mile canal and pumping system that delivers Colorado River water to the Phoenix and Tucson areas. The project’s water rights have a 1968 appropriation date, making them junior to California users such as the Imperial Irrigation District. That has meant that Arizona must reduce consumption prior to California. 

Imperial Irrigation District: A major agricultural area in southern California and the Colorado River’s largest single water user.


Western water: Where values, math, and the “Law of the River” collide, Part I — Jonathan P. Thompson

Western water: Where values, math, and the “Law of the River” collide, Part II — Jonathan P. Thompson


Colorado River “Beginnings”. Photo: Brent Gardner-Smith/Aspen Journalism

Romancing the River: The Romantic Scientist — George Sibley (SibleysRivers.com) #ColoradoRiver #COriver #aridification

Explorer John Wesley Powell and Paiute Chief Tau-Gu looking over the Virgin River in 1873. Photo credit: NPS

Click the link to read the article on the Sibley’s Rivers website (George Sibley):

January 20, 2026

There continues to be no new information from the ongoing negotiations among the protagonists for the seven states trying to work out a new two-basin management plan for the Colorado River. The Bureau of Reclamation, however, is pressing ahead; it recently went public with its ‘Draft Environmental Impact Statement’ (DEIS) for ‘Post-2026 Operational Guidelines and Strategies for Lake Powell and Lake Mead.’

The five alternative ‘operational guidelines and strategies’ analyzed in this DEIS were announced back in the fall of 2024; the Bureau has spent the past year-plus examining their environmental impacts. I’m not going to go into their analyses right now; I’m still working on skimming, skipping, sprinting and plowing my way through enough of the 1600 pages or so of the report to feel reasonably informed on its contents.

But I will note that the first action analyzed (skipping past the mandatory ‘No Action’ alternative) is for the Bureau to go ahead and run the river system as it sees fit, without input from the seven states/two basins – not something they want to do, but would have to do since the system will not wait while the states stare at their chessboard stalemate. That action would of course precipitate lawsuits from some of the states since the Bureau would have to go ahead with some of the things that are part of non-debate behind the stalemate.

Anyone wishing to submit themselves to the torture of an EIS can find the home page and Table of Contents for the report by clicking here.

And in the meantime, I’ll go off again on what I hope might be at least a more interesting tangent, and maybe more creative – fully believing that the only way out of our ever-unfolding river mismanagement is some centrifugal push to get beyond the tight centripetal pull of the Colorado River Compact and its two-basin expedient that has become gospel.

Two posts ago here, I acknowledged a need to explain why I titled all these posts ‘Romancing the River’ – ‘romance’ being a degraded term these days for many people, most commonly referring to formulaic fiction about chaotic and improbable couple-love relationships. This is a sad degradation of a word that, in more imaginative times, referred to a much larger quality or feeling of adventure, mystery, something beyond or larger than everyday life – ‘your mission should you choose to accept it,’ as it was expressed in Mission Impossible and The Hobbit.

‘Romance’ has been used to describe our relationship with the Colorado River for more than a century. C. J. Blanchard, a spokesperson for the Bureau of Reclamation in 1918, spoke of the ‘romance of reclamation,’ observing that ‘a vein of romance runs through every form of human endeavor.’ The first book compiling the history of the Euro-American exploration of the Colorado River was titled The Romance of the Colorado River. Written by Frederick Dellenbaugh, something of an explorer himself, he first encountered the Colorado River in the company of one of the river’s greatest romantics, John Wesley Powell, on Powell’s second adventure into the canyon region of the river.

Painting by Henry C. Pitz showing John Wesley Powell and his party descending the Colorado River through the Grand Canyon, presumably during the historic 1869 expedition. (Image credit: Smithsonian Institution, Bureau of American Ethnology)

Now wait a minute, you may say: John Wesley Powell a romantic? Everyone knows he was a scientist! Well, yes, that too. A romantic scientist. Let me try to explain.

Science is a discipline, perhaps summarized in the caution: Look before you leap. Science is the discipline of looking, studying, analyzing for causes in some studies, for effects in others, basically trying to map out what is demonstrably going on in the system or structure being studied. But most scientists will acknowledge being also moved by feelings, convictions, beliefs that lie outside of or beyond the linear relationships of cause and effect explorations. The extreme example might be scientists who believe in a god or gods that oversaw the creation they are studying. More subtly, the very desire to pursue a life in science reflects a belief beyond evidence that the work is important as well as interesting. This is the ‘romance’ underlying science and those who pursue it.

The same year Dellenbaugh published his Romance, 1903, another southwestern writer, Mary Hunter Austin, came out with her Land of Little Rain, a poetic collection of her explorations in the deserts of the lower Colorado River region. In that book she offered what might be a cautionary note about ‘romancing the river.’ In an observation about a small central Arizona tributary of the Colorado River, ‘the fabled Hassayampa,’ she reports an unattributed legend: ‘If any drink [of its waters], they can no more see fact as naked fact, but all radiant with the color of romance.’

That could be construed into a kind of spectrum, the ‘naked facts’ of any situation at one end, the ‘radiant colors of romance’ dressing up the naked facts at the other end. The discipline of science is to stay as close to the ‘naked facts’ as possible. But is it a bad thing to allow feelings or beliefs to dress up the naked facts with the radiant color of romance?

Hold that question for a bit, and back to Major John Wesley Powell. Powell was a scientist by nature – meaning born a curious fellow who collected information about things that made him curious. He studied science in a couple of colleges, but never completed a degree – partially, probably, because college science was a little too tame. One of his early ‘field trips’ was a solo trip the length of the Mississippi River in a rowboat. Another was a four-month walk across the ‘Old Northwest Territory’ state of Wisconsin. Both of those trips pretty unquestionably fall more into the category of ‘romantic adventures’ than ‘scientific expeditions.’

As a son of an itinerant farmer/preacher immigrant, growing up on farms in rural New York, Ohio and Illinois, he also shared, to some extent, the romantic Jeffersonian vision of ‘another America,’ a nation of small decentralized and mostly locally-sufficient communities of farm families – now just a nostalgic fantasy-vision of nation building that still haunts the imperial urban-industrial mass society that America has become. But trips to the west had convinced Powell that the mostly arid lands of the West were largely unsuitable for the spread of that agrarian vision, without the development of an appropriate system for settlement and land management specifically for the arid lands.

He had ideas about that, things to say, but he was basically just a high-school teacher who spent his summers adventuring west; how could he get a hearing for his concerns and ideas? He needed some way to gain public attention. So he turned his destiny over to his romantic adventurer side: he would do a scientific investigation into one of the remaining blank spots on the continental map, the region beginning where the rivers draining the west slopes of the Southern Rockies disappeared into a maze of canyons, and ending where a river emerged from the canyons – a river thick with silt and sand, indicating a pretty rough passage through canyons still in the creation stage.

Wallace Stegner. Ed Marston/HCN file photo

Wallace Stegner, in his great book about Powell and the development of the arid lands, Beyond the Hundredth Meridian, credited Powell’s scientific grounding with getting him through his 1869 expedition into the canyons: ‘Though some river rats will disagree with me, I have been able to conclude only that Powell’s party in 1869 survived by the exercise of observation, caution, intelligence, skill, planning – in a word, Science.’

I’m one of those who disagree with Stegner on that point. The advance planning for the trip sank in the first set of Green River rapids, with the wreckage of one of the boats containing a large portion of both their food supply and scientific instruments. They gradually acquired some skill at negotiating rapids (and knowing when to portage instead), but they started with no skill and paid the price. Observation was limited to the stretch of river before the next bend. Dellenbaugh asked Powell, on the second trip in 1871-72, what he would have done had he come to a Niagara-scale waterfall with sheer walls, no room for portage and no way back upriver. Powell answered, ‘I don’t know.’ Scientific caution was not a factor in this trip; they leapt before looking because there was no way to look first.

Stegner to the contrary, I would argue they survived the way adventurers survive (and sometimes don’t): a kind of adaptive intelligence, for sure, figuring out how to make rotten bacon and moldy flour edible, how to fabricate replacement oars, how to deal with the unexpected quickly and decisivelyBut mostly, just gutting it out, keeping spirits from crashing completely with morbid humor and routines – Powell getting out the remaining instruments to take their bearing rain or shine, getting back in the boats every morning and turning their lives over to the will of the river again.

And it worked out. Ninety-one days after starting, they made national headlines when they floated half-starved into a town near the confluence with the Virgin River. And Powell, a national hero after that, procured a government job doing a ‘survey’ of the Utah territory.

Then Powell the scientist took over – but the romantic side of his nature shaped his scientific work. The unstated purpose of the western surveys by the 1870s was to map out potential resources for the fast-growing industrial empire ‘back in the states’; Powell covered those bases, but the heart of his 1879 ‘Report on the Lands of the Arid Region…’ was analysis of the potential of the arid lands for fulfilling Jefferson’s romantic agrarian vision for America. All agricultural activity, he argued, would require irrigation, and there was only enough water to irrigate many three percent of the land.

John Wesley Powell’s recommendation for political boundaries in the west by watershed

He made a strong case for replacing the Homestead Act’s one-size-fits-all 160-acre homestead allotments with two alternatives for the arid lands: 1) 80-acre allotments for intensive irrigated farming, that being as much as a pre-tractor farm family could successfully tend; or 2) ‘pasturage’ allotments on unirrigable land of 2,560 acres, four full sections, for stockgrowers, with up to 20 irrigable acres for growing some winter hay and the ubiquitous kitchen garden. He went even further than that: settlement should not be done on a willy-nilly ‘first-come-first-served basis’; instead each watershed should be developed by an organized ditch company working from a plan assuring that every member got a fair allotment of water and that the water was most efficiently distributed. And the right to use that water should be bound to the land, he said. No selling your water right to some distant city!

Powell did not just recommend this in his report; he included model bills for state and federal legislation. He was of course thoroughly ignored because everything that he suggested was contrary to the romantic mythology of the Winning of the West – Jefferson’s legendary ‘yeoman’ conquering the wilderness, the rugged American individualist going forth with rifle, ax and Bible.

Acequia La Vida via Greg Hobbs.

That American mythology from the start was always ‘all radiant with the color of romance,’ with very little attention to ‘the naked facts’ –  which is the main reason why two out of three homesteads failed as settlement moved into the semi-arid High Plains and the arid interior West. ‘The naked facts’ of aridity, on the other hand, had been foundational to the communal land-grant system imported from Spain to Mexico, and it was already known to many of the native peoples already in the Americas: it takes a village and a stream to raise good crops in the arid lands. Powell observed it in the Utah Territory, where the Mormons had borrowed it from the natives and Mexicans.

Powell was philosophical about being ignored – and kept on pushing. He was ‘present at the creation’ of the United States Geological Survey (USGS) in 1879, the same year he presented his ‘Report on the Lands of the Arid Region.’ And two years later he became director of the USGS, where he tried to keep both the Agrarian Romance and ‘the naked facts’ of aridity front and center. He tried to sell the idea of doing a complete survey of the interior West to map its water resources and the adjacent areas of possible successful settlement, and he was actually a vote or two from achieving that, and actually shutting down the homesteading process until the study was done. But once some of the senators fronting for the industrialists realized what he was doing, they shut him down with a vengeance – he quickly realized that to save the USGS, he had to resign from it, and did so in 1894. Western extractive industries depended to some extent on failed homesteaders for their labor supply.

The Powell-Ingalls Special Commission meeting with Southern Paiutes. Photo credit: USGS

Powell was not out of work, however. From his pre-canyon days he had been interested in the First Peoples of the West. While most Euro-Americans saw them, at best, as raw material for conversion to Christianity and industrial labor, and at worse, as vermin to be wiped off the land, Powell saw them as people who had survived and even thrived in the region with Stone Age technology, some still semi-nomadic, some settled in agrarian communities, and therefore people from whom something might be learned. His efforts to communicate with those he encountered in his Utah survey led to the 1877 publication of a book, Introduction to Indian Languages – which led, two years later to the creation of the U.S. Bureau of Ethnology in the Smithsonian Institute with Powell as director – a position he held until his death in 1902, finally producing the first comprehensive linguistic survey of indigenous tongues, Indian Linguistic Families of America, North of Mexico(1891).

In both ethnology and the geology survey Major Powell established a high standard for government science – attention to the naked facts while still trying to carry forward what Bruce Springsteen called ‘the country we carry in our hearts’ – the ever evolving, devolving, careening, diverted, perverted, and currently severely damaged Romance of the American Dream. Next post, we’ll take a look at what happens when that standard gets out of balance.

But I want to leave you with a Colorado River image of Powell, related in Dellenbaugh’s Romance of the Colorado River: there were afternoons in that second voyage in the canyons, in the placid stretches between rapids, when the men would rope the boats together, and Major Powell would sit in his chair on the deck of the Emma Dean and read to them from the romantic adventure stories of Sir Walter Scott. Romancing the River.

A stopover during Powell’s second expedition down the Colorado River. Note Powell’s chair at top center boat. Image: USGS

#ColoradoRiver talks: States are still at odds but working toward a 5-year plan: Time is running short, with less than a month to submit a plan to the federal government — Annie Knox (UtahNewsDispatch.com) #COriver #aridification

The so-called “bathtub ring”, a deposit of pale minerals left behind where reservoir water levels once reached, is shown on the edge of Lake Powell near Page, Arizona on Sunday, Feb. 2, 2025. (Photo by Spenser Heaps for Utah News Dispatch)

Click the link to read the article on the Utah News Dispatch website (Annie Knox):

January 30, 2026

With just weeks to decide how to share the Colorado River’s shrinking water supply, negotiators from seven states hunkered down in a Salt Lake City conference room. 

Outside was busy traffic on State Street and South Temple. Inside was gridlock that eased up for a time, only to return, Utah’s chief negotiator, Gene Shawcroft said Tuesday of last week’s meetings.

The states moved forward on a deal for two-and-a-half days, then went back by almost as far as they’d come, Shawcroft said. 

“I would just tell you that four days is too long. We got tired of each other,” he said. 

Shawcroft reiterated Tuesday what he and his counterparts from the other Colorado River states have said in recent months: They don’t have a deal, but they do have a commitment to keep talking and meet their upcoming February deadline. 

The earlier goal was to reach a 20-year deal, but Shawcroft told Utah News Dispatch the states are now working on an agreement for a shorter time frame. 

“I think it’ll be fairly simple, but I think it’ll allow us to operate for the next five years,” Shawcroft said.  

Map of the Colorado River drainage basin, created using USGS data. By Shannon1 Creative Commons Attribution-Share Alike 4.0

The river provides water to 40 million people across the U.S. and Mexico, contributing 27% of Utah’s water supply. It is shrinking because of drought, [ed. and aridification]overuse and hotter temperatures tied to climate change.

Time for negotiators is also drying up as a Feb. 14 deadline set by the federal government approaches. The current agreement runs through late 2026.

The four Upper Basin states — Utah, Colorado, New Mexico and Wyoming — are at odds with the Lower Basin states of Nevada, Arizona and California.

The upstream states don’t want to make mandatory cuts in dry years, saying they typically use much less than they’re allocated. The downstream states say all seven need to absorb cuts in difficult years.

Conservation groups have criticized the states for not reaching a deal yet, saying “escalating risks” — including declining storage in lakes Powell and Mead — are piling up every month they fail to agree on a plan. 

Lake Powell and the Wahweap Marina are pictured near Page, Arizona on Sunday, Feb. 2, 2025. (Photo by Spenser Heaps for Utah News Dispatch)

The debate centers in part on upstream reservoirs like Flaming Gorge on the Utah-Wyoming border and whether they’ll be managed under the new plan. 

“Lower Basin believes those reservoirs ought to be used at the beck and call of the lower basin to reduce their reductions,” Shawcroft said at the meeting. “Obviously, we think differently.” 

Arizona Gov. Katie Hobbs, for her part, has criticized the upstream states’ “extreme negotiating posture,” saying they refuse to participate in any sharing in managing water shortages. 

West Drought Monitor map January 13, 2026.

Demand for water is outpacing the river’s supply, and extended dry periods aren’t helping. At the meeting, board members viewed a map covered in yellow, orange and red, noting the entire Colorado River watershed is experiencing some level of drought. 

Earlier this month, the U.S. Bureau of Reclamation, the federal agency that oversees water in the West,released five options for a framework on managing the river’s biggest reservoirs, Lake Mead in Nevada and Lake Powell on the Utah-Arizona line.

Amy Haas, executive director of the Colorado River Authority of Utah, said she and her colleagues were still reviewing the 1,600-page document but one thing is clear.  

“None of the five can provide what for Utah is really the central consideration for the deal, and that is a waiver of compact litigation,” Haas said. 

States can sacrifice more than just time and money in lawsuits over water use. In Texas, similar litigationgave the federal government more leverage in negotiations. 

One of the Bureau of Reclamation’s plans would have Nevada, Arizona and California face potential water shortages. It could go into effect next year if the seven states don’t reach a deal.  

“The river and the 40 million people who depend on it cannot wait,” Andrea Travnicek, assistant interior secretary for water and science, said in a Jan. 9 statement announcing the five alternatives. “In the face of an ongoing severe drought, inaction is not an option.”

Udall/Overpeck 4-panel Figure Colorado River temperature/precipitation/natural flows with trend. Lake Mead and Lake Powell storage. Updated through Water Year 2025. Note the tiny points on the annual data so that you can flyspeck the individual years. Credit: Brad Udall

Feds summon 7 #ColoradoRiver governors for last-ditch drought talks — AZCentral.com #COriver #aridification

Secretary Scott Turner (L) with Secretary Doug Burgham (R).

Click the link to read the article on the AZCentral.com website (Brandon Loomis). Here’s an excerpt:

January 17, 2026

Key Points

  • After negotiators for the seven Colorado River states failed to reach a water-sharing agreement, federal officials have invited governors to continue talks.
  • The feds may impose their own plan if states cannot agree, potentially leading to major cuts for Arizona, with its junior water rights.
  • The states face a mid-February timeline to present a “deal in principle” to replace guidelines expiring in September.

Interior Secretary Doug Burgum has invited all seven governors and their negotiators to meet in Washington in late January, [Tom] Buschatzke said. Perhaps getting the governors face-to-face could lead to a breakthrough, he added..The seven states have tried unsuccessfully for more than a year to reach a voluntary agreement to replace dam-operating guidelines that will expire with the end of the water year in September. The U.S. Bureau of Reclamation has asked states to submit an agreement by Feb. 14. That date falls on a weekend and likely isn’t a hard deadline for every detail in the plan, Buschatzke said, but a “deal in principle” probably needs to take shape by then if the states want to control their own destinies.

Reclamation offers future #ColoradoRiver management options as states pursue a long-sought consensus — Summit Daily News #COriver #aridification

Udall/Overpeck 4-panel Figure Colorado River temperature/precipitation/natural flows with trend. Lake Mead and Lake Powell storage. Updated through Water Year 2025. Note the tiny points on the annual data so that you can flyspeck the individual years. Credit: Brad Udall

Click the link to read the article on the Summit Daily News website (Ali Longwell). Here’s an excerpt:

January 17, 2026

While the four Upper Basin states in the compact — Colorado, New Mexico, Utah, and Wyoming — rely predominantly on snowpack for water supply, the Lower Basin states — Arizona, California, and Nevada — rely on releases from Lake Powell and Lake Mead..It’s not the compact, but the 2007 operational guidelines for Lake Powell and Lake Mead that are being renegotiated as they are set to expire this year. A decision must be made prior to Oct. 1, 2026, according to the Bureau…The federal government, seven states and 30 tribal nations all agree the best path forward is for a consensus between the upper and lower basins. However, with the looming deadline and unresolved disagreements about the future of the river, the Department of the Interior and its subagency, the Bureau of Reclamation, are forging ahead.  

​​”The Department of the Interior is moving forward with this process to ensure environmental compliance is in place so operations can continue without interruption when the current guidelines expire,” said Andrea Travnicek, the assistant secretary of water and science for the Bureau of Reclamation, in a news release announcing the agency’s latest draft options. “In the face of an ongoing severe drought, inaction is not an option.” 

One of the main disagreements throughout negotiations has been who should be making cuts to water use. The Lower Basin states have advocated for basin-wide water use reductions. The Upper Basin states, however, have pushed back on the idea, claiming they already face natural water shortages driven primarily by the ups and downs of snowpack…The draft Environmental Impact Statement released by the Bureau of Reclamation last week offers five options — including a required “no action” alternative and four others — that represent a broad range of operating strategies. The draft’s publication initiates a 45-day public comment period ending on March 2, 2026.  In a statement, Scott Cameron, acting lead of the Bureau of Reclamation, said that the federal agency has purposefully not identified a preferred alternative, “given the importance of a consensus-based approach to operations for the stability of the system.”  The expectation is that whatever agreement is reached incorporates elements of all five options offered by the Bureau of Reclamation, Cameron added. 

The five options identified are: 

  • No Action 
  • Basic Coordination
  • Enhanced Coordination 
  • Maximum Operational Flexibility 
  • Supply Driven 


Each option offers differing methods for how the Bureau of Reclamation will operate Lake Powell and Lake Mead, particularly under low reservoir conditions; allocate, reduce or increase annual allocations for consumptive use of water from Lake Mead to the lower basin states; store and deliver water that has been saved through conservation efforts; manage and deliver surplus water; manage activities above Lake Powell; and more. 

Map of the Colorado River drainage basin, created using USGS data. By Shannon1 Creative Commons Attribution-Share Alike 4.0

Bureau of Reclamation Aspinall Unit Coordination Meeting February 11, 2026 #GunnisonRiver

Aspinall Unit dams

From email from Reclamation Reece K. Carpenter:

January 14, 2026

In order to avoid conflict with Colorado Water Congress the first Aspinall Coordination Meeting of 2026 is being rescheduled.

The next coordination meeting for the operation of the Aspinall Unit is rescheduled for Wednesday, February 11th 2026, at 1:30 pm

This meeting will be held at the Western Colorado Area Office in Grand Junction, CO. There will also be an option for virtual attendance via Microsoft Teams. A link to the Teams meeting is below. 

The meeting agenda will include updates on current snowpack, forecasts for spring runoff conditions and spring peak operations, and the weather outlook.

Kick the (#coal) can down the road to 2040?: #ColoradoSprings Utilities wants legislation to let it delay retirement of its last coal-burning unit. It will face a fight among environmental groups — Allen Best (BigPivots.com)

Ray Nixon power plant. Photo credit: Colorado Springs Utilities

Click the link to read the article on the Big Pivots website (Allen Best):

January 13, 2026

Colorado Springs Utilities stands alone among the electrical utilities in Colorado in saying that it cannot meet its 2030 greenhouse gas reduction targets.

CSU wants to keep the coal-burning unit at the Ray Nixon Plant operating beyond its 2029 scheduled retirement. Four state legislators, two of them Democrats, say they will introduce a bill in the legislative session that begins on Wednesday to do just that.

This proposed bill, according to the draft dated Jan. 5, would require CSU, other municipal utilities and electrical cooperatives to potentially delay meeting the target until 2040, a decade later. They must currently reduce emissions 80% by 2030 as compared to 2005 levels. See 2030 Emission Reduction Goal Challenges (Draft 1-6)

The existing state deadlines would have all but one coal-burning unit in Colorado retired by the end of 2029, leaving only Comanche 3 in Pueblo to operate until the end of 2030. That unit is operated by Xcel Energy and owned by Xcel with two electrical cooperatives as minority owners. It is currently down for repairs.

Colorado Springs began saying almost a year ago that it could not secure enough renewable generation at acceptable prices to meet the carbon-reduction goal. Bids on renewable projects had come in 30% to 50% higher than expected.

Travas Deal, the chief executive of CSU, reiterated his argument at a press conference on Monday. Achieving the deadline of 80% greenhouse gas reductions by 2030 without risking reliability and affordability for the homes, businesses, hospitals and military installations that rely upon electricity from CSU has become increasingly challenging.

He called for a “measured approach.”

A major theme is that renewables cost more money, and the cost is being borne by people who cannot afford rising electricity bills. The draft bill hammers this point from several directions.

The bill being readied for introduction would allow CSU to notify the state’s Air Pollution Control Division by the end of May that it expects to be unable to hit the 2030 goal and why. It would then have until the end of 2026 to come up with a new plan for achieving the goal no later than 2040.

This timeline, said Deal, would “us more time to secure reliable and affordable replacement power for the coal-powered unit at the Nixon power plant currently mandated to retire in 2029.”

But why is Colorado Springs alone among Colorado utilities in wanting a legislative extension? Deal was asked that question twice during a press conference on Monday afternoon, once by this correspondent. After all, United Power left Tri-State less than two years ago and has managed to add both renewable generation and a gas-fired power plant. United has robust growth in electrical demand. And, if not as large as Colorado Springs, United has113,000 members — many of them industrial users with healthy electrical appetites.

Deal answered that United has the capacity to get electricity from Tri-State Generation and Transmission Association, of which it was formerly a member.

That was not a satisfying answer, although it’s possible that transmission constraints might preclude CSU from buying power from Tri-State as United is now doing.

Might Tri-State or other electrical cooperatives quietly be supporting this move to soften the deadlines for closing coal plants? Big Pivots did reach out to Tri-State to request an interview, but did not get a response on Monday.

As for Xcel, this bill would not apply to it or to Black Hills Energy, Colorado’s other privately owned electrical utility.

Standing out in this proposal is the bipartisan support, two Republicans and two Democrats. All but one of them are from El Paso County. One of the two Republicans, Sen. Cleave Simpson, of Alamosa, is the Senate minority leader.

Most striking was a statement made by Sen. Marc Snyder, a Democrat from Manitou Springs. He pointed out that in a “lifetime ago,” when he was mayor of Manitou, the city — which is supplied by CSU — was able to achieve 100% renewables. He said it was Colorado’s first home-rule municipality to do so.

(Aspen, which is also home rule, did so in 2015; when Manitou Springs did it Snyder did not say. In both cases, they presumably did so with the artifice of renewable energy credits.)

Rep. Amy Paschall, also a Democrat, proclaimed her environmental actions. “I recycle, I drive an electric vehicle and I have solar panels on my roof,” she said. She added that she suffers from asthma and has a child who has asthma. As such, she said, attaining ozone reduction “isn’t just an abstract policy discussion. It directly affects our health and our quality of life.”

So why is she adding her name to this bill?

“Because it aims to strike the delicate balance between affordability, reliability and clean energy in Colorado Springs,” she answered. This bill will seek to achieve the “right balance.”

State Rep. Jarvis Caldwell, a Republican (and House minority leader), did not disown the need for an energy transition from fuels that produce emissions, but did characterize current goals as unrealistic.

“What you are seeing now is a growing gap between intention and reality,” said Caldwell. “Over the last several years, the Legislature has set aggressive energy mandates without fully grappling with what those mandates mean for the people who are expected to pay the bill.”

For many households, he said, energy costs are not an abstract policy debate. They are a monthly decision between paying the power bill or cutting back somewhere else.

The energy transition, he said, is “being rushed” and called the timelines “unrealistic.” And Caldwell further charged that reliability is treated as an afterthought.

“The result is higher prices and a more fragile system. That is not responsible governance.”

Caldwell said that both he and Paschal had meet with the Democratic majority leadership. “We didn’t get any commitments necessarily from them, but they heard our concerns and they heard our reasoning, and they were receptive to it,” he said. He also said there had been discussions with Gov. Jared Polis.

Sounds like a compelling argument. Does the rhetoric overlook subtleties?

All or nearly all utilities have or propose to raise their electric rates, and for a complicated stew of reasons. In some cases, they need to reinvest in delivery infrastructure. It’s not all investment in renewable energy to replace fossil fuel generation. In fact, in most cases, renewables reduce costs to consumers, because the fuel in renewables is free. But yes, rates are rising.

Renewables do need transmission — and more of it. And transmission is difficult and expensive.

Colorado Springs has high-voltage transmission lines for its fossil fuel plants. Deal said the best wind lies in Wyoming and hence CSU would be best served by transmission lines along the Front Range — a challenge, as is witnessed by the problems Xcel Energy is having in getting electricity from El Paso County to Aurora. As always, though, that is a more complicated story than this simple sentence. See “Highways of Electricity,” Big Pivots, Jan. 4, 2026).

And Deal’s answer overlooks the fact that Colorado’s best wind resources lie in southeastern Colorado.

Big Pivots asked Deal if CSU would be struggling less if it had better transmission. “Transmission may not have alleviated everything on day one, but it would give us a lot more options,” he replied.

He added that joining the Southwest Power Pool, an organization formed to facilitate energy sharing within a region, will provide a “big tool” for CSU to connect to renewable resources. But again, that will require transmission, although the precise needs remain uncertain.

As for data centers, what part are they of this Colorado Springs story? Is CSU expecting to miss its greenhouse gas reduction deadline because it doesn’t want to miss out on the economic development potential in artificial intelligence centers.

Hard to say, although perhaps tellingly, the video event in Colorado Springs included Johnna Reeder Kleymeyer, from the Colorado Springs Chamber and Economic Development Commission. “This proposed legislation recognizes one simple truth,” she said. “Economic growth and sustainability have to work in concert, not in conflict.”

A reporter from Colorado Public Radio, however, did ask a decent question: Would CSU consider requiring agreements with large-load users, including data centers, to be on hold until the utility could get closer to the current clean energy goal?

“We would never want to close the door on any opportunity there, but I think that’s something that the legislation has to look at, as for us to continue to support growth in our communities, have jobs, and look at those revenue streams come in,” Deal answer.

As for data centers, they do require a lot of electricity without generating a large number of jobs, he added, as compared to another large-level manufacturer. “So we try not to get into what the (electric) load is as much as what the community benefit is and how we can best serve them.”

Colorado Springs, perhaps not incidentally, in December announced that it would become home to a Coca-Cola bottling plant that will require $475 million in capital investment and generate 170 new jobs.

Snyder, the legislator from Manitou Springs, said the bill was being drawn up after consultation with stakeholders. The Sierra Club said it was not among those consulted.

“CSU is the only utility in Colorado to ask for a special exemption from Colorado’s environmental standards that protect public health and our climate,” said Margaret Kran-Annexstein, director of the Colorado Chapter of the Sierra Club.

Conservation Colorado, in a statement, said CSU should not be rewarded for “broken promises and poor planning.”

“After years of failing to plan for replacement resources, Colorado Springs Utilities (CSU) wants to break its promise and remain one of Colorado’s largest polluters,” said Paul Sherman, the organization’s climate campaign manager.

Unlike the Sierra Club, Conservation Colorado had participated in discussions with CSU. Sherman said his organization had communicated its concerns. “None of the substantive concerns we raised were addressed in the draft that CSU and bill sponsors released this afternoon,” Sherman said. “As currently drafted, Conservation Colorado will be opposing this legislation.”

#ColoradoRiver experts say some management options in the draft EIS don’t go far enough to address scarcity, #ClimateChange — Heather Sackett (AspenJournalism.org) #COriver #aridification

Lake Powell is seen from the air in October 2022. Three of the management options released by the feds have the option for an Upper Basin conservation pool in Lake Powell. CREDIT: ALEXANDER HEILNER/THE WATER DESK

Click the link to read the article on the Aspen Journalism website (Heather Sackett):

January 15, 2026

Federal officials have released detailed options for how the Colorado River could be managed in the future, pushing forward the planning process in the absence of a seven-state deal. But some Colorado River experts and water managers say cuts don’t go deep enough under some scenarios and flow estimates don’t accommodate future water scarcity driven by climate change.

On Jan. 9, the U.S. Bureau of Reclamation released a draft of its environmental impact statement, a document required by the National Environmental Policy Act, which lays out five alternatives for how to manage the river after the current guidelines expire at the end of the year. This move by the feds pushes the process forward even as the seven states that share the river continue negotiating how cuts would be shared and reservoirs operated in the future. If the states do make a deal, it would become the “preferred alternative” and plugged into the NEPA process.

“Given the importance of a consensus-based approach to operations for the stability of the system, Reclamation has not yet identified a preferred alternative,” Scott Cameron, the acting Reclamation commissioner, said in a press release. “However, Reclamation anticipates that when an agreement is reached, it will incorporate elements or variations of these five alternatives and will be fully analyzed in the final EIS, enabling the sustainable and effective management of the Colorado River.” 

For more than two years, the Upper Basin (Colorado, New Mexico, Utah and Wyoming) and the Lower Basin (California, Arizona and Nevada) have been negotiating, with little progress, how to manage a dwindling resource in the face of an increasingly dry future. The 2007 guidelines that set annual Lake Powell and Lake Mead releases based on reservoir levels do not go far enough to prevent them from being drawn down during consecutive dry years, putting the water supply for 40 million people in the Southwest at risk.

The crisis has deepened in recent years, and in 2022, Lake Powell flirted with falling below a critical elevation to make hydropower. Recent projections from the U.S. Bureau of Reclamation show that it could be headed there again this year and in 2027.

John Berggren, regional policy manager with Western Resource Advocates, helped craft elements of one of the alternatives, Maximum Operational Flexibility, formerly called Cooperative Conservation.

“My initial takeaway is there’s a lot of good stuff in there,” Berggren said of the 1,600-page document, which includes 33 supporting and technical appendices. “Their goal was to have a wide range of alternatives to make sure they had EIS coverage for whatever decision they ended up with, and I think that there are a lot of innovative tools and policies and programs in some of them.”

The infamous bathtub ring could be seen near the Hoover Dam in December 2021. The U.S. Bureau of Reclamation has released a draft Environmental Impact Statement for post-2026 management of the river. CREDIT: HEATHER SACKETT/ASPEN JOURNALISM

Alternatives

The first alternative is “no action,” meaning river operations would revert to pre-2007 guidance; officials have said this option must be included as a requirement of NEPA, but doesn’t meet the current needs. 

The second alternative, Basic Coordination, can be implemented without an agreement from the states and represents what the feds can do under their existing authority. It would include Lower Basin cuts of up to 1.48 million acre-feet based on Lake Mead elevations; Lake Powell releases would be primarily 8.23 million acre-feet and could go as low as 7 million acre-feet. It would also include releases from upstream reservoirs Flaming Gorge, Blue Mesa and Navajo to feed Powell. But experts say this alternative does not go far enough to keep the system from crashing. 

“It was pretty well known that the existing authorities that Reclamation has are probably not enough to protect the system,” Berggren said. “Especially given some of the hydrologies we expect to see, the Basic Coordination does not go far enough.”

The Enhanced Coordination Alternative would impose Lower Basin cuts of between 1.3 million and 3 million acre-feet that would be distributed pro-rata, based on each state’s existing water allocation. It would also include an Upper Basin conservation pool in Lake Powell that starts at up to 200,000 acre-feet a year and could increase up to 350,000 acre-feet after the first decade.

Under the Maximum Operational Flexibility Alternative, Lake Powell releases range from 5 million acre-feet to 11 million acre-feet, based on total system storage and recent hydrology, with Lower Basin cuts of up to 4 million acre-feet. It would also include an Upper Basin conservation pool of an average of 200,000 acre-feet a year. 

These two alternatives perform the best at keeping Lake Powell above critical elevations in dry years, according to an analysis contained in the draft EIS. 

“There are really only two of these scenarios that I think meet the definition of dealing with a very dry future: Enhanced Coordination and the Max Flexibility,” said Brad Udall, a senior water and climate research scientist at Colorado State University. “Those two kind of jump out at me as being different than the other ones in that they actually seem to have the least harmful outcomes, but the price for that are these really big shortages.”

The final scenario is the Supply Driven Alternative, which calls for maximum shortages of 2.1 million acre-feet and Lake Powell releases based on 65% of three-year natural flows at Lees Ferry. It also includes an Upper Basin conservation pool of up to 200,000 acre-feet a year. This option offers two different approaches to Lower Basin cuts: one based on priority where the oldest water rights get first use of the river, putting Arizona’s junior users on the chopping block, and one where cuts are distributed proportionally according to existing water allocations, meaning California could take the biggest hit. 

This alternative is based on proposals submitted by each basin and discussions among the states and federal officials last spring. Udall said the cuts are not deep enough in this option.

“You can take the supply-driven one and change the max shortages from 2.1 million acre-feet up to 3 or 4 and it’s going to perform a lot like those other two,” he said. “I think what hinders it is just the fact that the shortages are not big enough to keep the basin in balance when push comes to shove.”

Reclamation’s Acting Commissioner Scott Cameron speaks at the Colorado River Water Users conference in Las Vegas in December 2025. The agency has released a draft Environmental Impact Statement, which outlines options for managing the river after this year. CREDIT: HEATHER SACKETT/ASPEN JOURNALISM

Pivotal moment

In a prepared statement, Glenwood Springs-based Colorado River Water Conservation District officials expressed concern that the projected future river flows are too optimistic.  

“We are concerned that the proposed alternatives do not accommodate the probable hydrological future identified by reliable climate science, which anticipates a river flowing at an average of 9-10 [million acre feet] a year,” the statement reads. “The Colorado River Basin has a history of ignoring likely hydrology, our policymakers should not carry this mistake forward in the next set of guidelines.”

The River District was also skeptical of the Upper Basin conservation pool in Lake Powell, which is included in three of the alternatives. Despite dabbling in experimental programs that pay farmers and ranchers to voluntarily cut back on their water use in recent years, conservation remains a contentious issue in the Upper Basin. Upper Basin water managers have said their states can’t conserve large volumes of water and that any program must be voluntary. 

Over the course of 2023 and 2024, the System Conservation Pilot Program, which paid water users in the Upper Basin to cut back, saved about 101,000 acre-feet at a cost of $45 million.

The likeliest place to find water savings in Colorado is the 15-county Western Slope area represented by the River District. But if conservation programs are focused solely on this region, they could have negative impacts on rural agricultural communities, River District officials have said.

“Additionally, several alternatives include annual conservation contributions from the Upper Basin between [200,000 acre-feet] and [350,000 acre feet],” the River District’s statement reads. “We do not see how that is a realistic alternative given the natural availability of water in the Upper Basin, especially in dry years.”

In a prepared statement, Colorado officials said they were looking forward to reviewing the draft EIS.

“Colorado is committed to protecting our state’s significant rights and interests in the Colorado River and continues to work towards a consensus-based, supply-driven solution for the post-2026 operations of Lake Powell and Mead,” Colorado’s commissioner, Becky Mitchell, said in the statement.

The release of the draft EIS comes at a pivotal moment for the Colorado River Basin. The seven state representatives are under the gun to come up with a deal and have less than a month to present details of a plan by the feds’ Feb. 14 deadline. Federal officials have said they need a new plan in place by Oct. 1, the start of the next water year. This winter’s dismal snowpack and dire projections about spring runoff underscore the urgency for the states to come up with an agreement for a new management paradigm. 

Over a string of recent dry years, periodic wet winters in 2019 and 2023 have bailed out the basin and offered a last-minute reprieve from the worst consequences of drought and climate change. But this year is different, Udall said.

“We’re now at the point where we’ve removed basically all resiliency from the system,” he said. “Between the EIS and this awful winter, some really tough decisions are going to be made. … Once we finally get to a consensus agreement, the river is going to look very, very different than it ever has.”

The draft EIS will be published in the Federal Register on Jan.16, initiating a 45-day comment period that will end March 2. 

Udall/Overpeck 4-panel Figure Colorado River temperature/precipitation/natural flows with trend. Lake Mead and Lake Powell storage. Updated through Water Year 2025. Note the tiny points on the annual data so that you can flyspeck the individual years. Credit: Brad Udall

The Federal Government releases their #ColoradoRiver plan for a warming #climate: Also — Are Hovenweep and Aztec Ruins national monuments really in danger of shrinkage? — Jonathan P. Thompson #COriver #aridification

Lake Mead and its low-water-indicating “bathtub ring.” Jonathan P. Thompson photo.

Click the link to read the article on The Land Desk website (Jonathan P. Thompson):

January 14, 2026

🥵 Aridification Watch 🐫

Just over a month before the deadline for the Colorado River states to agree on a plan for sharing the river’s diminishing waters, the feds released their options, one of which could be implemented if the states don’t reach a deal. The Bureau of Reclamation’s “Post-2026 Operational Guidelines and Strategies for Lake Powell and Lake Mead” offers five alternative scenarios for how to run the river, all of which are aimed at keeping the two reservoirs viable through different methods of divvying up the burden of inevitable shortages in supply.

The document, and the need to deal with present and future shortages, is necessary because human-caused climate change-exacerbated aridification has diminished the Colorado River’s flow, throwing the supply-demand equation out of balance. So it is somewhat surreal to peruse the voluminous report that was published by an administration whose leader has called climate change a “hoax” and a “con job.”

My cursory search of the document turned up only one occurrence of the term “climate change.”1 Yet the authors do acknowledge, if obliquely, that global warming is shrinking the river. “The Basin is experiencing increased aridity due to climate variability,” they write, “and long-term drought and low runoff conditions are expected in the future.” This tidbit also evaded the censors: “Since 2000, the Basin has experienced persistent drought conditions, exacerbated by a warming climate, resulting in increased evapotranspiration, reduced soil moisture, and ultimately reduced runoff.”

All of the alternatives put most of the burden of cutting consumptive use on the Lower Basin states, while directing the Upper Basin to take unspecified conservation measures. I’ll summarize the alternatives below, but first, it seems telling to see which which proposed alternatives the Bureau considered, but ultimately eliminated from detailed analysis.


Colorado River crisis continues — Jonathan P. Thompson


The alternatives do not include:

  • The “boating alternative,” which would prioritize maintaining Lake Powell’s surface level at or above 3,588 feet to serve recreational boating needs. This proposal was put forward in the “Path to 3,588” plan by motorized recreation lobbying group BlueRibbon Coalition. It was dismissed because, basically, it would sacrifice downstream farms and cities for the sake of boating.
  • The ecosystem alternative, which would prioritize the Colorado River’s ecosystem health by focusing management and reducing consumptive human use to protect wildlife, vegetation, habitats, and wetlands.
  • One-dam alternative, a.k.a. Fill Mead First. This proposal would entail either bypassing or decommissioning Glen Canyon Dam with the aim of filling Lake Mead. The Bureau said they rejected the plan because it would be inconsistent with the Law of the River and might be unacceptable to stakeholders (even though some Lower Basin farmers got a little Hayduke-fever a couple of years back, suggesting that ridding Glen Canyon of the dam might be the best way to manage the river).

Okay, so that’s what’s NOT going to happen. So what might happen if the feds feel the need to intervene? Here’s a very short summary of each alternative:

  • No Action: This is always offered in these things, and it just means that they would revert back to the pre-2007 interim guidelines era, when releases from Lake Powell were fixed at an average of 8.23 million acre-feet per year and shortages were determined based on Lake Mead levels and would be distributed based on priority.
  • Basic Coordination Alternative: Lake Powell releases would range from 7 to 9.5 maf annually, based on the reservoir’s surface level, and releases from upper basin reservoirs would be implemented to protect Glen Canyon Dam’s infrastructure. Lower Basin shortages (and cuts) would be based on Lake Mead elevations and would be distributed based on water right priority (meaning Arizona gets cut before California).
  • Enhanced Coordination Alternative: Lake Powell annual releases would range from 4.7 maf to 10.8 maf, based on: a combination of Powell and Mead elevations; the 1-year running average hydrology; and Lower Basin deliveries. The Upper Basin would implement conservation measures to bolster Lake Powell levels if needed, and the Lower Basin shortages would range from 1.3 maf (when Mead and Powell, combined, are 60% full) to 3.0 maf (when Mead and Powell are 30% full or lower) annually. The Lower Basin shortages would be distributed proportionally, meaning that California — which has the largest allocation — would take 49% of the cuts, Arizona 31%, Nevada 3.3%, and Mexico 17%.
  • Maximum Operational Flexibility Alternative: Lake Powell annual releases would range from 5 maf to 11 maf, based on total Upper Basin system storage and recent hydrology. But when Lake Powell’s surface level drops to 3,510 feet, Glen Canyon Dam would be operated as a “run of the river” facility, meaning that it would release only as much as what it running into the reservoir minus evaporation and seepage to keep the elevation from dropping further. Lower Basin shortages would be on a sliding scale, starting when Powell and Mead drop below 80% full, reaching 1 maf when the two reservoirs are 60% full. When the reservoirs drop below 60%, then shortages would be determined by the previous 3-year flows at Lee Ferry, topping out at a maximum shortage of 4 maf. Shortages would be distributed according to priority and proportionally.
  • Supply Driven Alternative: This one is based on the amount of water that is actually in the river (go figure!). Lake Powell releases would range from 4.7 maf annually to 12 maf, or about 65% of the 3-year natural flows at Lees Ferry. Lower Basin shortages would kick in when Lake Mead’s surface elevation drops below 1,145 feet, reaching a maximum of 2.1 maf at 1,000 feet and lower. (As of Jan. 12, Mead’s level was 1,063 feet). Shortages would be distributed according to priority and proportionally.
The estimated “natural flow” at Lee Ferry. Some of the alternatives would base Lake Powell releases on recent average natural flows at Lee Ferry. If the recent past is an indicator of what’s to come, we could expect a relatively minuscule amount of water running through the Grand Canyon to the Lower Basin states. Source: Bureau of Reclamation.

The Lower Basin states reportedly aren’t too happy about any of the alternatives, because they put most of the onus for cutting consumption on the Lower Basin. Under the Maximum Flexibility option, for example, Lower Basin shortages could go as high as 4 million acre-feet, or about half of those states’ total annual consumptive use. And under another, California alone could have to cut up to 1.5 million acre-feet of water use, which could trigger litigation, since California users have some of the most senior rights on the river. Some of the alternatives would potentially nullify the Colorado Compact’s clause ordering the Upper Basin to “not cause the flow of the river at Lee Ferry to be depleted below an aggregate of 75 maf for any period of ten consecutive years.”

The Bureau does not pick a “preferred” alternative, like federal agencies typically do with environmental impact statements, leaving readers guessing about which option or combination of options might be chosen should the need arise. But it also gives more room for the states to reach some sort of agreement to pick an option from the provided list.

* It is found in the Hydrologic Resources section: “While the flows in the Colorado River would not affect groundwater in the region, changes to the groundwater systems in the Grand Canyon due to climate change may be an additional environmental factor that affects flows in the Colorado River.”


The snowpack remains dismal in most of the West, and it’s not just because of lack of precipitation. In fact, it’s probably more due to the crazy-warm temperatures. The average temperatures across the Interior were way above normal in November and December, as the map below shows. And January’s similarly unseasonably balmy so far. Yikes.

Precipitation levels were mixed across the West during late autumn and early winter, but temperatures were warmer than normal across the entire region, diminishing snowpack and leading to rather unwintery conditions. Source: NOAA.

🌵 Public Lands 🌲

Last week the new public lands media outlet, RE:PUBLIC, warned readers of “major shrinkage” this year. They meant, of course, that the Trump administration will probably get around to eliminating or eviscerating at least one national monument in the next twelve months. It’s probably a pretty safe bet, given that in Trump’s first term he shrank Bears Ears and Grand Staircase-Escalante national monuments, and Project 2025, which the administration has hewn closely to, calls for even more reductions.

Indeed, I’m surprised they haven’t already moved to eliminate some of these protected areas, especially the more recently designated ones like Bears Ears, Baaj Nwaavjo I’tah Kukveni-Ancestral Footprints of the Grand Canyon National Monument, or Chuckwalla National Monument in California. An optimist might hope that the Trump administration has realized how deeply unpopular this would be, or has come to terms with the fact that the Antiquities Act only allows presidents to establish national monuments, not eliminate them. But I think it’s more likely they were simply too busy dismantling other environmental safeguards — and, for that matter, democracy — to get around to diminishing national monuments.

I was a little surprised by RE:PUBLIC’s list of vulnerable national monuments, however. It included Bears Ears et al, which makes sense, but then also speculates about other “likely targets, due to their proximity to energy and mining interests,” including: Aztec Ruins, Dinosaur, Hovenweep, and Natural Bridges national monuments.

I hate trying to predict what the Trump administration will do in the future, but I’m going to go out on a limb here and say that these particular national monuments are not in the administration’s crosshairs. While these protected areas are close to energy-producing areas, and probably have some oil and gas, uranium, lithium, and/or potash producing potential, they simply offer too little to the extractive industries to make it worth the political blowback from eviscerating them.

Hovenweep National Monument. Jonathan P. Thompson photo

For those who may be unfamiliar with these places, I’ll take each one individually:

  • Aztec Ruins: First off, this tiny national monument adjacent to the residential neighborhoods of Aztec, New Mexico, is an amazing place and well worth the visit. The Puebloan structures here are built in the style of Chacoan great houses, and the community — which was established at the end of Chaco’s heyday — may have been become succeeded Chaco as a regional cultural and political center. It is in the San Juan Basin coalbed methane fields and is surrounded by gas wells. In fact, there are a few existing, active wells within the monument boundaries. But no one is champing at the bit to drill any new wells in this region, and they certainly don’t need to do so in this tiny monument.
  • Dinosaur National Monument, in northwestern Colorado, is probably somewhat vulnerable, given its size and proximity to oil and gas fields. But again, there’s not a whole lot of new drilling going on in the area. It was established in 1915 to protect dinosaur quarries — clearly in tune with the Antiquities Act — so shrinking it would be met with serious bipartisan political pushback.
  • When Warren G. Harding designated Hovenweep National Monument in 1923 to protect six clusters of Puebloan structures in southeastern Utah from development and pothunters, he strictly followed the Antiquities Act’s mandate to confine its boundaries to “the smallest area compatible with proper care and management of the objects to be protected.” As such, the boundaries of each “unit” is basically drawn right around the pueblo and a small area of surroundings, leaving little room for shrinkage. Though it lies on the edge of the historically productive Aneth Oil Field, oil and gas drillers have no need to get inside the boundaries to get at the hydrocarbons. Besides, Trump and Harding have a lot in common, so Trump’s not likely to want to erase his predecessor’s legacy.
  • Natural Bridges: It’s odd to me that this one, which is currently surrounded by Bears Ears National Monument, is included on this list. Yes, there are historic uranium mines nearby, and yes, White Canyon, where the monument’s namesake formations are located, was once considered for tar sands and oil shale development. But the small monument itself — which was designated by Teddy Roosevelt in 1908 — is not getting in the way of any of this sort of development. It’s much more likely that Trump would remove the White Canyon area from Bears Ears National Monument, as he did during his first term, potentially opening the area around Natural Bridges back up to new uranium mining claims, while leaving the national monument’s current boundaries intact.

So, in summary: Don’t fret too much about these national monuments getting eliminated or shrunk anytime soon. And for now, maybe we shouldn’t worry about any national monument shrinkage. It is possible that Trump won’t go there this term. Trump shrunk Bears Ears and Grand Staircase-Escalante during his first term in part out of spite toward Obama and Clinton, but also to get then-Sen. Orrin Hatch’s legislative support. That the shrinkage also re-opened some public lands to new mining claims and drilling was a secondary motivation.

This time around, Trump has come up with far more generous gifts for the mining and drilling companies, and much more sinister ways to attack his political adversaries. Besides, he’s got his eyes on much bigger prizes — like Greenland.

1 * The single use of the term “climate change” is found in the Hydrologic Resources section: “While the flows in the Colorado River would not affect groundwater in the region, changes to the groundwater systems in the Grand Canyon due to climate change may be an additional environmental factor that affects flows in the Colorado River.”

Map of the Colorado River drainage basin, created using USGS data. By Shannon1 Creative Commons Attribution-Share Alike 4.0

Federal officials pursue own #ColoradoRiver management plans as states try to overcome impasse: Bureau of Reclamation’s massive document ‘highlights need for states to reach an agreement ASAP’ — The #Denver Post

The Government Highline Canal, in Palisade. The Government Highline Canal near Grand Junction. The Grand Valley Water Users Association, which operates the canal, has been experimenting with a program that pays water users to fallow fields and reduce their consumptive use of water. Photo: Brent Gardner-Smith/Aspen Journalism

Click the link to read the article on The Denver Post website (Elise Schmelzer). Here’s an excerpt:

January 15, 2026

Absent a crucial but elusive consensus among the seven Colorado River states, federal authorities are forging ahead with their own ideas on how to divvy up painful water cuts as climate change diminishes flows in the critical river. The Bureau of Reclamation last week made public a 1,600-page behemoth of a document outlining five potential plans for managing the river after current regulations expire at the end of this year. The agency did not identify which proposal it favors, in hopes that the seven states in the river basin will soon come to a consensus that incorporates parts of the five plans. But time is running out. The states — Colorado, Wyoming, Utah, New Mexico, California, Arizona and Nevada — already blew past a Nov. 11 deadline set by federal authorities to announce the concepts of such a plan. They now have until Feb. 14 to present a detailed proposal for the future of the river that makes modern life possible for 40 million people across the Southwest. They were set to meet this week in Salt Lake City to continue negotiations. Federal authorities must finalize a plan by Oct. 1…

“The Department of the Interior is moving forward with this process to ensure environmental compliance is in place so operations can continue without interruption when the current guidelines expire,” Andrea Travnicek, the assistant secretary for water and science at the Department of the Interior, said in a news release announcing the document.  “The river and the 40 million people who depend on it cannot wait. In the face of an ongoing severe drought, inaction is not an option.”

A 45-day public comment period opens Friday on the proposed plans for managing the river system, contained in a document called a draft environmental impact statement. The current operating guidelines expire at the end of 2026, but authorities need a replacement plan in place prior to the Oct. 1 start to the 2027 water year. The water year follows the water cycle, beginning as winter snowpack starts to accumulate and ending Sept. 30, as irrigation seasons end and water supplies typically reach their lowest levels…

Udall/Overpeck 4-panel Figure Colorado River temperature/precipitation/natural flows with trend. Lake Mead and Lake Powell storage. Updated through Water Year 2025. Note the tiny points on the annual data so that you can flyspeck the individual years. Credit: Brad Udall

Already, Lake Mead — on the Arizona-Nevada border — and Lake Powell are only 33% and 26% full, respectively. Projections from the Bureau of Reclamation show that, in a worst-case scenario, Powell’s waters could fall below the level required to run the dam’s power turbines by October and remain below the minimum power pool until June 2027. Experts monitoring the yearslong effort to draft new operating guidelines said any plan implemented by Reclamation must consider the reality of a river with far less water than assumed when the original river management agreements were signed more than a century ago.

Map credit: AGU

Data Dump: One year into the “energy emergency”: President Trump has helped oil and gas companies, but “drill, baby, drill” remains elusive — Jonathan P. Thompson (LandDesk.org)

While Donald Trump seems to think he coined terms like “Drill, Baby, Drill,” the fact is, they’ve been around for a long, long time. This sign appeared at the 2008 Democratic National Convention in Denver. While Republican candidate John McCain and his VP candidate Sarah Palin were most vocally calling for increased drilling, the Democrats were also getting behind the nascent “fracking” revolution and touting natural gas as a cleaner bridge fuel from coal to solar and wind. And the so-called shale oil and gas drilling boom took off during the Obama administration. Jonathan P. Thompson photo.

Click the link to read the article on The Land Desk website (Jonathan P. Thompson):

January 9, 2026

🛢️ Hydrocarbon Hoedown 📈 Data Dump

Donald Trump made a lot of promises on the campaign trail: If elected, he would bring down the cost of groceries (a word that seemed new to him), he would secure the borders, he would end all of the wars on day one, and he would unleash the oil companies so they could “drill, baby, drill” and secure “energy dominance.”

Groceries are still expensive, “border security” is now MAGA-speak for federal agents gunning down innocent bystanders, and not only are the wars still raging, but the administration’s newly named “Department of War” has bombed Iran, Nigeria, and Venezuela, and is now threatening to invade Greenland and even Mexico. 

In fact, the only war that Trump can take credit for ending was Biden’s “war” on energy. And that’s only because the “war” didn’t exist in the first place! It was and remains a figment of the GOP’s imagination.


On Biden’s Energy Dominance — Jonathan P. Thompson


Still, the administration did live up to at least one promise: It used a fabricated “energy emergency” to help increase extractive corporations’ profit margins by rolling back environmental protections, handing out drilling permits like candy at a parade, fast-tracking various mine and oil and gas infrastructure permits, and offering oodles of public land to energy companies. 

But has it really achieve the stated goal, to establish “energy dominance” — i.e. boost production, bring down prices, and end oil imports? 

Maybe the data will help us figure that one out … 

Leasing

As I think we’ve established, the Biden administration did not wage a war on energy or even oil and gas. In fact, under Biden, the nation became the world’s largest oil producer, the largest exporter of liquefied natural gas, and so on, while also fast-tracking solar, wind, and transmission projects on federal lands. 

Biden’s Interior Department did, however, put up some guardrails aimed at protecting some public lands. While it leased out parcels in the Permian Basin without restraint, it also refrained from putting some more sensitive parcels up for auction in more sensitive areas with limited oil and gas production. 

The Trump administration has been far more friendly to oil and gas companies looking to bolster their land-holding portfolios, not only offering up hundreds of thousands of acres, but then putting them up for auction a second time if the first round didn’t attract enough bids.

  • 328,000 acres: Amount of public land and minerals the BLM leased to oil and gas companies between Jan. 20 and Dec. 31, 2025. This brought in about $356 million in revenue. 
  • $327 million: Amount a single oil and gas lease sale for 31 parcels, mostly in New Mexico’s Permian Basin, brought in this January, a record per-acre high average bid amount. 
  • 0: Number of bids received for 23 offered oil and gas lease parcels in Colorado in January. The sale was a “replacement” sale held after the initial auction failed to attract enough bids.

Drilling Permits

President Trump’s BLM issued an average of 909 permits to drill per month during the first year of his second term. This is almost triple the monthly average for Biden’s administration.

Environmentalists often attacked Biden for issuing more drilling permits for public lands than Trump did during his first administration. The comparison was dumb, but whatever. Trump apparently didn’t like Biden’s apparent energy dominance, so he struck back by issuing more than 5,000 drilling permits last year, far exceeding the Biden administration’s monthly and yearly averages.

  • 1,124: Number of drilling permits the BLM issued to EOG Resources in 2025, mostly in the Permian Basin. That compares to 755 for XTO Permian and XTO Energy; 293 for Anschutz Exploration; 503 to Devon Energy; 338 to OXY USA; 241 to Matador Production; 119 to Chevron; 106 to Middle Fork Energy Uinta; and 80 to ConocoPhillips. 
  • 95: Number of drilling permits the BLM’s Farmington Field Office issued in 2025, to Hilcorp, Logos, SIMCOE, DJR Operating, and other companies. While this pales in comparison to the Permian Basin, it is a marked increase from recent years. 
  • 8: Number of drilling permits the BLM’s Moab Field Office issued in 2025. 
  • 100: Approximate number of drill rigs operating in all of New Mexico during any given week of 2025. 
  • 8,949: Number of approved federal drilling permits held by oil and gas companies that were available to drill as of Jan. 2, 2026. That is to say, they have the permits, but haven’t yet used them.
Production

During the past year, domestic crude oil production continued to increase month-to-month, but at a slower rate than it had previously. Oil production on federal lands was down about 2% from fiscal year 2024. This is mostly due to industry’s lack of enthusiasm for more drilling, thanks to a combination of low oil prices and higher expenses due to inflation and tariffs on steel and other equipment. So much for drill, baby, drill.

Oil production from federal and tribal nation lands was down for fiscal year 2025 as of August. Source: U.S. Department of the Interior.

7.9 million: Barrels of crude oil per day the U.S. was importing from other countries in December 2025. That’s marginally less than a year earlier. 

2.1 million barrels/day: Net crude oil imports (imports minus exports) to the U.S. in December 2025. 

Idle Wells
*GSI/OSI: Gas or oil wells oil well that are capable of producing but have not produced during the production month.

I find this to be, perhaps, the most telling chart of all. It shows the number of idle wells on federal mineral leases (which includes public lands and split-estate private lands) by Western state. A lot of the wells have just been wrung dry and have been abandoned and need to be plugged and reclaimed, probably at the taxpayer’s expense. 

Still others, the ones in the GSI (non-producing gas completion) and OSI (non-producing oil completion) columns, are officially capable of producing oil and gas, it’s just that for one reason or another they aren’t producing currently. Dozens of the GSI/OSI wells in Wyoming, for example, are owned by bankrupt companies that were unable to offload them to someone else. 

This brings up a question: If we are indeed in an “energy emergency,” as the Trump administration has declared, shouldn’t we be pumping all of the oil and gas from existing wells that we possibly can before issuing thousands of new drilling permits, most of which aren’t even being used? 

Let me answer that one: We’re not in an energy emergency. 

🗺️ Messing with Maps 🧭

I came across this cool old map of the Sangre de Cristo land grant while perusing the Green Fire Times’ tribute to Malcolm Ebright, who was a land grant community advocate and historian. In order to get a high-res version I had to, um, copy this from an online auction site (thus the watermarks). I don’t have much to say about it, except it’s a pretty cool map of a very cool area.

The battle over a global energy transition is on between petro-states and electro-states – here’s what to watch for in 2026 — Jennifer Morgan (TheConversation.org)

Solar power has been expanding quickly, but natural gas is also booming. Gerard Julien/AFP via Getty Images

Jennifer Morgan, Tufts University

January 6, 2026

Two years ago, countries around the world set a goal of “transitioning away from fossil fuels in energy systems in a just, orderly and equitable manner.” The plan included tripling renewable energy capacity and doubling energy efficiency gains by 2030 – important steps for slowing climate change since the energy sector makes up about 75% of the global carbon dioxide emissions that are heating up the planet.

The world is making progress: More than 90% of new power capacity added in 2024 came from renewable energy sources, and 2025 saw similar growth.

However, fossil fuel production is also still expanding. And the United States, the world’s leading producer of both oil and natural gas, is now aggressively pressuring countries to keep buying and burning fossil fuels.

The energy transition was not meant to be a main topic when world leaders and negotiators met at the 2025 United Nations climate summit, COP30, in November in Belém, Brazil. But it took center stage from the start to the very end, bringing attention to the real-world geopolitical energy debate underway and the stakes at hand.

Brazilian President Luiz Inácio Lula da Silva began the conference by calling for the creation of a formal road map, essentially a strategic process in which countries could participate to “overcome dependence on fossil fuels.” It would take the global decision to transition away from fossil fuels from words to action.

President Lula Da Silva gestures with his hands as he speaks in front of a picture of the Amazon.
Brazilian President Luiz Inácio Lula da Silva speaks at COP30, where he promoted the idea of a road map to help the world speed up its transition from fossil fuels to clean energy. AP Photo/Andre Penner)

More than 80 countries said they supported the idea, ranging from vulnerable small island nations like Vanuatu that are losing land and lives from sea level rise and more intense storms, to countries like Kenya that see business opportunities in clean energy, to Australia, a large fossil-fuel-producing country.

Opposition, led by the Arab Group’s oil- and gas-producing countries, kept any mention of a “road map” energy transition plan out of the final agreement from the climate conference, but supporters are pushing ahead.

I was in Belém for COP30, and I follow developments closely as former special climate envoy and head of delegation for Germany and senior fellow at the Fletcher School at Tufts University. The fight over whether there should even be a road map shows how much countries that depend on fossil fuels are working to slow down the transition, and how others are positioning themselves to benefit from the growth of renewables. And it is a key area to watch in 2026.

The battle between electro-states and petro-states

Brazilian diplomat and COP30 President André Aranha Corrêa do Lago has committed to lead an effort in 2026 to create two road maps: one on halting and reversing deforestation and another on transitioning away from fossil fuels in energy systems in a just, orderly and equitable manner.

What those road maps will look like is still unclear. They are likely to be centered on a process for countries to discuss and debate how to reverse deforestation and phase out fossil fuels.

Over the coming months, Corrêa plans to convene high-level meetings among global leaders, including fossil fuel producers and consumers, international organizations, industries, workers, scholars and advocacy groups.

For the road map to both be accepted and be useful, the process will need to address the global market issues of supply and demand, as well as equity. For example, in some fossil fuel-producing countries, oil, gas or coal revenues are the main source of income. What can the road ahead look like for those countries that will need to diversify their economies?

A man speaks into a microphone. Behind him, a person holds a sign reading: 'Shell: Own up, clean up, pay up'
Nigeria’s Bodo community is suing Renaissance Africa Energy Company Limited, an oil consortium that acquired Shell’s Nigerian subsidiary, over two major oil spills in the Niger Delta in 2008. Shell admitted liability and settled with the community in 2014, committing to cleanup efforts. However, the Bodo community has been critical of the quality and transparency of Shell’s cleanup, and is seeking further damages and remediation. Here, activists protest the company’s actions. Leon Neal/Getty Images

Nigeria is an interesting case study for weighing that question.

Oil exports consistently provide the bulk of Nigeria’s revenue, accounting for around 80% to over 90% of total government revenue and foreign exchange earnings. At the same time, roughly 39% of Nigeria’s population has no access to electricity, which is the highest proportion of people without electricity of any nation. And Nigeria possesses abundant renewable energy resources across the country, which are largely untapped: solar, hydro, geothermal and wind, providing new opportunities.

What a road map might look like

In Belém, representatives talked about creating a road map that would be science-based and aligned with the Paris climate agreement, and would include various pathways to achieve a just transition for fossil-fuel-dependent regions.

Some inspiration for helping fossil-fuel-producing countries transition to cleaner energy could come from Brazil and Norway.

In Brazil, Lula asked his ministries to prepare guidelines for developing a road map for gradually reducing Brazil’s dependency on fossil fuels and find a way to financially support the changes.

His decree specifically mentions creating an energy transition fund, which could be supported by government revenues from oil and gas exploration. While Brazil supports moving away from fossil fuels, it is also still a large oil producer and recently approved new exploratory drilling near the mouth of the Amazon River.

Norway, a major oil and gas producer, is establishing a formal transition commission to study and plan its economy’s shift away from fossil fuels, particularly focusing on how the workforce and the natural resources of Norway can be used more effectively to create new and different jobs.

Both countries are just getting started, but their work could help point the way for other countries and inform a global road map process.

The European Union has implemented a series of policies and laws aimed at reducing fossil fuel demand. It has a target for 42.5% of its energy to come from renewable sources by 2030. And its EU Emissions Trading System, which steadily reduces the emissions that companies can emit, will soon be expanded to cover housing and transportation. The Emissions Trading System already includes power generation, energy-intensive industry and civil aviation.

Fossil fuel and renewable energy growth ahead

In the U.S., the Trump administration has made clear through its policymaking and diplomacy that it is pursuing the opposite approach: to keep fossil fuels as the main energy source for decades to come.

The International Energy Agency still expects to see renewable energy grow faster than any other major energy source in all scenarios going forward, as renewable energy’s lower costs make it an attractive option in many countries. Globally, the agency expects investment in renewable energy in 2025 to be twice that of fossil fuels.

At the same time, however, fossil fuel investments are also rising with fast-growing energy demand.

The IEA’s World Energy Outlook described a surge in new funding for liquefied natural gas, or LNG, projects in 2025. It now expects a 50% increase in global LNG supply by 2030, about half of that from the U.S. However, the World Energy Outlook notes that “questions still linger about where all the new LNG will go” once it’s produced.

What to watch for

The Belém road map dialogue and how it balances countries’ needs will reflect on the world’s ability to handle climate change.

Corrêa plans to report on its progress at the next annual U.N. climate conference, COP31, in late 2026. The conference will be hosted by Turkey, but Australia, which supported the call for a road map, will be leading the negotiations.

With more time to discuss and prepare, COP31 may just bring a transition away from fossil fuels back into the global negotiations.

Jennifer Morgan, Senior Fellow, Center for International Environment and Resource Policy and Climate Policy Lab, Tufts University

This article is republished from The Conversation under a Creative Commons license. Read the original article.

#Oil, Ego, and Venezuela: On President Trump’s dangerous “Donroe Doctrine” shenanigans — Jonathan P. Thompson (LandDesk.org)

Oil pumpjack on La Plata County, Colorado’s, “Dryside.” Jonathan P. Thompson photo.

Click the link to read the article on The Land Desk website (Jonathan P. Thompson):

January 6, 2026

🤯 Trump Ticker 😱

Five years ago today, President Donald Trump incited an angry mob of his followers to attack the nation’s Capitol building in an attempt to overturn the presidential election that he had just lost. He was trying to launch a coup to overthrow America’s democracy. At the time, many of us expected him to be impeached, and maybe even go to jail for this deplorable act. Little could we have guessed that just half a decade later he’d not only be President once again, but would actually be succeeding in his bid to dismantle democracy, and would be doing it with the tacit and explicit support of Congress, the Supreme Court, and his many supporters who don’t seem to be bothered by his cognitive decline, authoritarianism, broken promises, lies, close association with a convicted sex trafficker and pedophile, disregard for the Constitution, and reckless tinkering with the U.S. economy, international affairs, and his constituents’ well-being.

The administration’s invasion of Venezuela is simply the latest, most egregious example. The military went in, lit up Caracas with explosives and gunfire, killed civilians, kidnapped the nation’s leader (who, admittedly, was a nasty authoritarian), and sowed chaos, all without authorization from Congress. The reason? Trump himself says it was to turn the country’s vast oil reserves over to American corporations, which donated generously to Trump’s campaign. But Trump and his minions were equally motivated by the need to stroke Trump’s fragile ego — which has taken a beating thanks to other failures and low approval ratings, and to distract from his ubiquity in the Epstein files (which the DOJ has yet to release as Congress ordered it to do). Don’t be surprised if they invade Greenland or Cuba or even Mexico, next, as stupid as such a scenario might be.

But let’s focus on the oil factor, since that’s the one that’s most likely to trickle down into the Land Desk beat.

Venezuela has a lot of oil, reportedly the largest proved reserves in the world, and it’s mostly made up of heavy, sour crude (more on this in a minute). It’s currently not extracting very much of that oil, for various reasons (the U.S. produces about 20 times more per day than Venezuela). Trump is encouraging American oil companies to go to Venezuela and develop the oil fields and upgrade the infrastructure. This will take time and money, and it’s not clear that petroleum corporations will be interested in this kind of investment while oil prices are low (as they are, currently). Prices are low because demand and supply are more or less balanced, meaning the world doesn’t really need Venezuelan’s oil — at least not now.

Like fine wine, oil is imbued with terroir. That is, its composition varies depending on where it’s from. Most U.S.-produced oil is tight (from tight shales), light (low density), sweet (low sulfur content) crude that requires less processing than heavy (dense), sour (high sulfur) crude. Thing is, many Gulf Coast refineries were constructed before the shale revolution and are equipped to process heavy, sour crude, like the kind that comes from Venezuela. So there is a domestic demand for the stuff.

The active drilling rig count, the most accurate indicator of oil and gas activity, remains stagnant, despite Trump’s call to “drill, baby, drill,” thanks to persistently low oil and gas prices. If Venezuelan oil production increases — and that remains a big “if” — it could further deflate crude prices and dampen enthusiasm for domestic drilling. Source: Baker Hughes

If and when Venezuelan production increases, it will add supply to both the global and domestic markets, which could bring prices down even further. That will lower the cost of driving American gas guzzlers around, and increase greenhouse gas emissions and other pollutants, but it will also reduce incentives to drill new wells, which could ease industry pressure on public lands in the U.S. In the meantime, the Trump administration continues to issue drilling permits at a blistering rate, even though companies aren’t all that interested in using them.


Wise Use Echoes — Jonathan P. Thompson


🥵 Aridification Watch 🐫

Last week, the Durango Herald quoted a National Weather Service meteorologist as saying that the snowpack in the southwestern part of the state was “not too bad.” I guess that depends on your definition of “not too bad.” Because it sure as heck isn’t looking good!

Red Mountain Pass has about half as much snow as it normally does this time of year. Only 1990, 2000, and 2018 rivaled this year for meagre snow levels. Source: NRCS.

The San Juan Mountain snowpack levels are currently at about 50% of normal for the first week of January, and they are tied for third lowest snowpack level on record for this date. That’s not “too bad,” it’s downright dismal. And snow cover is even more meagre in other parts of the state: The Colorado River’s headwaters SNOTEL station is experiencing the lowest snowpack since it started recording in 1986.

No bueno! Source: NRCS.

Still, it may be too early for snow lovers to abandon hope altogether, since a full recovery would not be unprecedented. Take the winter of 1989-90, when the early January snowpack was even worse than it is now. It was my first year in college, and when I came home for Christmas we played volleyball and went hiking in the mostly bare La Plata Mountains instead of going sledding or skiing. (At the time it seemed downright apocalyptic, since it followed the unusually wet 1980s, when snow would pile up in Durango and halt car traffic and turn the streets into nordic ski tracks.) But that March the snows finally came and continued into May, leading to some nice spring skiing and a decent spring runoff. The snowpack of 95-96 followed a similar pattern, as did 1999-2000.

During those years, however, the lack of snow was caused by a lack of precipitation. This year, it’s the result of a combination of light winter precipitation and unusually warm temperatures throughout December and early January. A recovery will require not only more snowfall, but also cooler temperatures, making the outlook a little grimmer.

The Upper Colorado River region has experienced some of its highest daily average temperatures on record this winter. On Christmas Eve, the daily average was a whopping 18° F higher than the median for that day. Source: NRCS.
Parts of the West were hit with five or six times as much precipitation than normal in December, but temperatures were above normal almost everywhere, too, diminishing snowpack. Source: Western Regional Climate Center.
The Phillips Bench SNOTEL station near Teton Pass, Wyoming, shows how the atmospheric rivers have helped the snowpack their rebound.

As of mid-December, the snow drought covered most of the West, but a series of atmospheric rivers pounded the West Coast and the Northern Rockies, bringing snow to higher elevations and more northern latitudes (and big rain and flooding to California). Heavy, wet snow piled up on Teton Pass near Jackson, Wyoming, bringing snow water equivalent levels from far below average to above normal for this date. Road crews triggered a huge avalanche that covered the highway in about 30 feet of snow. And, after the skies cleared, a couple of backcountry skiers triggered a slide near Teton Pass; one of the skiers was caught, buried, and killed. It was the nation’s second avalanche-related fatality this season. A few days later, two Mammoth Mountain ski patrollers were caught in a slide while doing avalanche mitigation work and one of them died.

🗺️ Messing with Maps 🧭

Now for a little New Year’s treat for all of you weather/map nerds: The Colorado Avalanche Information Center has launched an interactive map that shows 24-hour and 48-hour snowfall and snow water equivalents at various locations across the state’s mountains, letting you see at a click where the good powder is and isn’t. You can click on each station and get all the details, including current temperature and snow depth.

Reclamation releases draft environmental review for post-2026 #ColoradoRiver operations: Process advances planning for future river management amid prolonged #drought and ongoing negotiations #COriver #aridification

Click the link to read the release on the Reclamation website:

January 9, 2026

The Bureau of Reclamation today released a draft Environmental Impact Statement evaluating a range of operational alternatives for managing of Colorado River reservoirs after 2026, when the current operating agreements expire. The draft EIS evaluates a broad range of potential operating strategies. It does not designate a preferred alternative, ensuring flexibility for a potential collective agreement. 

 Prolonged drought conditions over the past 25 years, combined with forecasts for continued dry conditions, have made development of future operating guidelines for the Colorado River particularly challenging. 

 “The Department of the Interior is moving forward with this process to ensure environmental compliance is in place so operations can continue without interruption when the current guidelines expire,” Assistant Secretary – Water and Science Andrea Travnicek said.  “The river and the 40 million people who depend on it cannot wait. In the face of an ongoing severe drought, inaction is not an option.” 

 The draft EIS evaluates a broad range of operational alternatives for post-2026 reservoir management informed through input and extensive collaborative engagement with stakeholders, including the seven basin states, tribes, conservation organizations, other federal agencies, other Basin water users, and the public. It includes the following alternatives that capture operational elements and potential environmental impacts:

  • No Action 
  • Basic Coordination 
  • Enhanced Coordination 
  • Maximum Operational Flexibility 
  • Supply Driven 

The document will be published in the Federal Register on January 16, 2026, initiating a 45-day comment period that will end on March 2, 2026. The draft EIS and additional information on the alternatives are available on Reclamation’s website.  

 “Given the importance of a consensus-based approach to operations for the stability of the system, Reclamation has not yet identified a preferred alternative,” said Acting Commissioner Scott Cameron. “However, Reclamation anticipates that when an agreement is reached, it will incorporate elements or variations of these five alternatives and will be fully analyzed in the Final EIS enabling the sustainable and effective management of the Colorado River.” 

 The Colorado River provides water for more than 40 million people and fuels hydropower resources in seven states. It serves as a vital resource for 30 Tribal Nations and two Mexican states, sustaining 5.5 million acres of farmland and agricultural communities throughout the West, while also supporting critical ecosystems and protecting endangered species.  

 The Draft EIS addresses only domestic river operations. A separate binational process addressing water deliveries to Mexico is underway and the Department is committed to continued collaboration with the Republic of Mexico. The Department will conduct all necessary and appropriate discussions regarding post-2026 operations and implementation of the 1944 Water Treaty with Mexico through the International Boundary and Water Commission in consultation with the Department of State. 

 To provide certainty for communities, tribes, and water users, a decision regarding operations after 2026 will be made prior to October 1, 2026 – the start of the 2027 water year. 

Photo shows Lake Mead with a water elevation of 1078. Credit: USBR

#ColoradoRiver Deadlines & Incentives — Michael Cohen (InkStain.net) #COriver #aridification

Udall/Overpeck 4-panel Figure Colorado River temperature/precipitation/natural flows with trend. Lake Mead and Lake Powell storage. Updated through Water Year 2025. Note the tiny points on the annual data so that you can flyspeck the individual years. Credit: Brad Udall

Click the link to read the article on the InkStain.net website (Michael Cohen — Pacific Institute):

December 15, 2025

Key Takeaways

  • The consensus-based effort to develop new rules to manage the Colorado River system hasn’t worked – it’s time for a new approach
  • Federal leadership and the credible threat of managing reservoirs to protect the system is that new approach

Missing Deadlines

Way back at the end of the last century, at the annual Colorado River conference in Vegas, Marc Reisner repeated the Margaret Thatcher quote that consensus is the absence of leadership. On Veterans Day, the seven Colorado River basin states missed yet another deadline to reach consensus on a conceptual plan for managing the shrinking Colorado River after the current rules expire in 2026. Valentine’s Day marks the next holiday deadline, this time for a detailed plan, but multiple missed deadlines give no indication that the states will reach consensus then, either.

The basin states can’t agree on the substance of a new agreement. They also disagree on the process to get there. While Arizona has called for the federal government to break the negotiation logjam, Colorado opposes federal intervention and continues to call for consensus. Each basin-state negotiator acts to protect their state’s interests, often at the expense of the short and long-term resilience of the Colorado River system as a whole and the 35 million people who rely on it. The continued failure to negotiate a plan challenges the efforts of irrigators, cities, businesses, and river runners throughout the basin to plan for 2027 and beyond.

Meanwhile, river runoff and reservoir storage get lower and lower and snowpack lags well below average. This is not a zero-sum game, with winners and losers. The more appropriate metaphor here is a shrinking pie, with smaller and smaller pieces.

Leadership

The basin state negotiators have met for years behind closed doors, without success. It’s time for a new approach. Aggressive federal intervention and the credible threat of a federally-imposed Colorado River management plan would offer political cover – or a political imperative – for the negotiators. The credible threat of a federal plan would give the negotiators the space to compromise without having to do so unilaterally and then being accused of not protecting their state’s interests.

But federal leadership alone is not enough – it must be coupled with a plausible federal plan that compels the states to act and can meet the magnitude of the ongoing crisis. As the Department of the Interior announced in its 6/15/2023 press release, the purpose of and need for the post-2026 guidelines is “to develop future operating guidelines and strategies to protect the stability and sustainability of the Colorado River.” To date, the development of the post-2026 guidelines has prioritized routine operations of Glen Canyon and Hoover dams over the system as a whole, a focus inconsistent with the magnitude and urgency of the problem. Prioritizing routine dam operations and hydropower generation over water delivery and environmental protection elevates the tool over the task. Seeking to preserve routine operations of the dams while imposing draconian cuts on water users is not a path to resilience and precludes alternatives that would help stabilize the system.

The Plan

Instead, by early next year, the Secretary should announce that Interior will implement a federal plan incorporating the following elements:

  1. Grant Tribal Nations the legal certainty and the ability to access, develop, or lease their water.
  2. Make accessible (“recover”) the roughly 5.6 million acre-feet (MAF) of water stored in Lake Powell below the minimum power pool elevation and avoid the additional ~0.25 MAF of annual evaporative losses from Powell by storing such water in Lake Mead and using Powell as auxiliary storage.
  3. As a condition precedent, the Lower Basin states agree not to place a “compact call” for the duration of the agreement.
  4. Implement annual Lower Basin water use reductions for the following calendar year based on total system contents on August 1:
    • 75% – 60%: cuts to Lower Basin water uses increasing from 0 to 1.5 MAF<60% – 38%: static cut to Lower Basin water uses of 1.5 MAF<38% – 23%: increasing cuts to Lower Basin water uses of up to 3.0 MAF total
    • below 23% of total system contents – cut Lower Basin water uses to the minimum required to protect human health and safety and satisfy present perfected rights
  5. If the Lower Basin states do not satisfy the condition precedent in #3 above, Reclamation limits Lower Basin deliveries to the minimum required to satisfy present perfected rights when total system contents are <75%.
  6. Recover water stored in federal Upper Basin reservoirs unless the Upper Basin states reduce annual water use based on total system contents:
    • <34% – 23%: Assuming the first 0.25 MAF “reduction” would be contributed by the elimination of Powell’s evaporative losses and gains from Glen Canyon bank storage, reduce Upper Basin water uses up to 0.65 MAF
    • below 23% of total system contents – limit total Upper Basin water uses to 3.56 MAF (the minimum volume reported this century)
  7. Expand the pool of parties eligible to create Intentionally Created Surplus (ICS) beyond existing Colorado River contractors, to include water agencies and other entities with agreements to use Colorado River water.
  8. Eliminate the existing limits on the total quantity of Extraordinary Conservation ICS and DCP ICS that may be accumulated in ICS and DCP ICS accounts, while maintaining existing limits on delivery of such water.
  9. Fully mitigate the on-stream and off-stream community and environmental impacts of the water use reductions identified above.
  10. After a three-year phase-in period, condition Colorado River diversions on a clear “reasonable and beneficial use” standard predicated on existing best practices for water efficiency, including but not limited to the examples listed below (state(s) that already have such standards):
  • Require removal of non-functional turf grass (California, Nevada)
  • Incentivize landscape conversion and turf removal statewide (California, Colorado, Utah)
  • Adopt stronger efficiency standards for plumbing and equipment (Colorado, California, and Nevada)
  • Require urban utilities to report distribution system leakage, and to meet standards for reducing water losses (California)
  • Require all new urban landscapes to be water-efficient (California)
  • Require metering of landscape irrigation turnouts (Utah)
  • Ensure that existing buildings are water-efficient when they are sold or leased (Los Angeles, San Diego)
  • Require agricultural water deliveries to be metered and priced at least in part by volume (California)

Many of the elements listed above raise important questions about federal authorities, accounting and data challenges, the roles and obligations of state water officials to implement coordinated actions in-state, water access for disadvantaged communities, environmental compliance, and potential economic and social costs, among others. For each item listed, many details will need to be refined. Similarly, the plan’s duration will need to be determined. But as temperatures again climb into the high 40s in the Rockies near the Colorado River’s headwaters (in mid-December!), drying soils and reducing next year’s runoff, and the National Weather Service issues red flag fire warnings for Colorado’s Front Range, the need for bold action is clear.

The Dominy Bypass

Recovering water stored in Lake Powell will require the construction of new bypass tunnels around Glen Canyon Dam. Former Reclamation Commissioner Floyd Dominy sketched the design of such tunnels almost thirty years ago (see image). Such tunnels would enable the recovery of about 5.6 MAF of water stored below the minimum power pool elevation – more water than the Upper Basin states consume each year. Current operating rules and the scope of the current planning process effectively treat this massive volume of water as “dead storage” – a luxury the system can no longer afford. After Reclamation constructs the bypass tunnels, water recovery should be timed to maximize environmental and recreational benefits in the Grand Canyon.

Avoiding a Worse Outcome

Last year’s Colorado River conference featured a panel on the risks of litigation. Unfortunately, the continued failure to reach a dealgrowing litigation funds, and the preference for repeating the same action that’s led to the continuing impasse suggest that some believe litigation could generate a better outcome (for them). Both sides have attorneys who assure their clients of victory. Yet, as Arizona learned in 1968winning in the Supreme Court doesn’t ensure a better outcome and certainly won’t increase Colorado River flows. Placing faith in Congress could entangle this basin with challenges in other basins and other political considerations.

John Wesley Powell at his desk—same desk used by the USGS Director today via the USGS

Running the River

Almost 160 years ago, John Wesley Powell – the reservoir’s namesake – demonstrated bold leadership, going where no (white) man had gone before. With leadership and a clear goal, he charted a route through the Colorado River’s iconic canyons. Now is the time for more bold leadership, a clear goal, and a plan to get there.

About the author

Michael Cohen. Photo credit: Pacific Institute

Since 1998, Michael Cohen’s work with the Pacific Institute has focused on water use in the Colorado River basin and delta region and the management and revitalization of the Salton Sea ecosystem. Michael received a B.A. in Government from Cornell University and has a Master’s degree in Geography, with a concentration in Resources and Environmental Quality, from San Diego State University.

Map of the Colorado River drainage basin, created using USGS data. By Shannon1 Creative Commons Attribution-Share Alike 4.0

Why this #Colorado #coal town is digging #geothermal: #Hayden is tapping renewable thermal energy to affordably heat and cool its new business park — and entice companies looking to reduce energy costs —  Alison F. Takemura (YaleClimateConnections.org)

Bedrock Energy’s drilling rig digs a 1,000-foot borehole as part of a geothermal network that’ll keep energy costs low for companies that move into a new Hayden business park. (Alison F. Takemura/Canary Media)

Click the link to read the article on the Yale Climate Connections website (Alison F. Takemura):

January 5, 2026

For decades, Dallas Robinson’s family excavation company developed coal mines and power plants in the rugged, fossil-fuel-rich region of northwest Colorado. It was a good business to be in, one that helped hamlets like Hayden grow from outposts to bustling mountain towns — and kept families like Robinson’s rooted in place for generations.

“This area, with the exception of agriculture, was built on oil and gas and coal,” said Robinson, a former town councilor for Hayden.

But that era is coming to a close. Across the United States, bad economics and even worse environmental impacts are driving coal companies out of business. The 441-megawatt coal-burning power plant just outside Hayden is no exception: It’s shutting down by the end of 2028. The Twentymile mine that feeds it is expected to follow.

Coal closures can gut communities like Hayden, a town of about 2,000 people. That story has been playing out for decades, particularly in Appalachia, where coal regions with depressed economies have seen populations decline as people strike out for better opportunities elsewhere. Robinson, a friendly, gregarious guy, fears the same could happen in Hayden.

“I grew up here, so I know everyone,” he said. ​“It’s hard to see people lose their jobs and have to move away. … These are families that sweat and bled and been through the good and the bad times in small towns like this.”

Struggling American coal towns need an economic rebirth as the fossil-fuel industry fades. Hayden has a vision that, at first, doesn’t sound all that unusual. The town is developing a 58-acre business and industrial park to attract a diverse array of new employers.

The innovative part: companies that move in will get cheap energy bills at a time of surging utility costs. The town is installing tech that’s still uncommon but gaining traction — a geothermal heating-and-cooling system, which will draw energy from 1,000 feet underground.

In short, Hayden is tapping abundant renewable energy to help invigorate its economy. That’s a playbook that could serve other communities looking to rise from the coal dust.

At an all-day event hosted by geothermal drilling startup Bedrock Energy this summer, I saw the ambitious project in progress. Under a blazing sun, a Bedrock drilling rig chewed methodically into the region’s ochre dirt. Once it finished this borehole — one of about 150 — it would feed in a massive spool of black pipe to transfer heat.

Bedrock will complete the project, providing 2 megawatts of thermal energy, in phases, with roughly half the district done in 2026 and the whole job finished by 2028. Along the way, constructed buildings will be able to connect with portions of the district as they’re ready.

“We see it as a long-term bet,” Mathew Mendisco, city manager of Hayden, later told me, describing the town as full of grit and good people. Geothermal energy ​“is literally so sustainable — like, you could generate those megawatts forever. You’re never going to have to be reliant on the delivery of coal or natural gas. … You drill it on-site, the heat comes out.”

Geothermal is also the rare renewable resource that the Trump administration has embraced. In July, Secretary of Energy Chris Wright, whose firm invested in geothermal developer Fervo Energy, helped convince Congress to spare key federal investment tax credits for the sector.

These incentives apply to both the deep projects for producing power as well as the more accessible, shallower installations for keeping buildings comfy. Unlike geothermal projects for power, ones for direct heating and cooling don’t depend on geography; any town can take advantage of the resource.

“We disagree on the urgency of addressing climate change, [but] this is something that Chris Wright and I agree on,” Colorado Senator John Hickenlooper (D), a trained geologist, told a packed conference-room crowd on the day of the event. ​“Geothermal energy has … unbelievable potential to, at scale, create clean energy.”

Charting a post-coal economy

The eventual closure of the Hayden Station coal plant, which has operated for more than half a century, has loomed over the town since Xcel Energy announced an early shutdown in 2021.

The power plant and the mine employ about 240 people. Property taxes from those businesses have historically provided more than half the funding for the town’s fire management and school districts — though that fraction is shrinking thanks to recent efforts to diversify Hayden’s economy, Mendisco said.

Taking into account the other businesses that serve the coal industry and its workers, according to Mendisco, the economic fallout from the closures is projected to be a whopping $319 million per year.

“Really, the highest-paying jobs, the most stable jobs, with the best benefits [and] the best retirement, are in coal and coal-fired power plants,” Robinson said.

But coal has been in decline for over 20 years, largely due to growing investment in cheap fossil gas and renewables. While the Trump administration tries to defibrillate the coal industry and force uneconomic coal plants to stay open past their planned closure dates, states including Colorado still plan to phase out fossil fuels in the coming years. Colorado’s remaining six coal plants are set to shutter by the end of the decade.

Hayden aims for its business park to help the town weather this transition. With 15 lots to be available for purchase, the development is designed to provide more than 70 jobs and help offset a portion of the tax losses from Hayden Station’s closure, according to Mendisco.

“We are not going to sit on our hands and wait for something to come save us,” Mayor Ryan Banks told me at the event.

Companies that move into the business park won’t have a gas bill. They’ll be insulated from fossil-fuel price spikes, like those that occurred in December 2022, when gas prices leapt in the West and customers’ bills skyrocketed by 75% on average from December 2021.

In the Hayden development, businesses will be charged for their energy use by the electric utility and by a geothermal municipal utility that Hayden is forming to oversee the thermal energy network. Rather than forcing customers to pay for the infrastructure upfront, the town will spread out those costs on energy bills over time — like investor-owned utilities do. Unlike a private utility, though, Hayden will take no profit. Mendisco said he expects the geothermal district to cut energy costs by roughly 40%, compared with other heating systems.

Municipally owned geothermal districts are rare in the U.S., but the approach has legs. Pagosa Springs, Colorado, has run its geothermal network since the early 1980s, when it scrambled to combat fuel scarcity during the 1970s oil embargo. New Haven, Connecticut, recently broke ground on a geothermal project for its train station and a new public housing complex. And Ann Arbor, Michigan, has plans to build a geothermal district to help make one neighborhood carbon-neutral.

Hayden’s infrastructure investment is already attracting business owners. An industrial painting company has bought a plot, and so has a regional alcohol distributor, Mendisco said.

One couple is particularly excited to be a part of the town’s clean energy venture. Nate and Steph Yarbrough own DIY off-grid-electrical startup Explorist.Life; renewable power is in the company’s DNA. The Yarbroughs teach people how to put solar panels and batteries on camper vans, boats, and cabins to fuel their outdoor adventures, and Explorist.Life sells the necessary gear.

“When we bought that property, it was largely because of the whole geothermal concept,” Nate Yarbrough told me. ​“We thought it made a whole bunch of sense with what we do.”

Reducing reliance on hydrocarbons, he noted, is ​“a good thing for society overall.”

Geothermal tech heats up 

The geothermal network that could transform Hayden’s future is mostly invisible from aboveground. Besides the drilling rig and a trench, the most prominent features I spotted were flexible tubes jutting from the earth like bunny ears.

Those ends of buried U-shaped pipes will eventually connect to a main distribution loop for businesses to hook up to. Throughout the network, pipes will ferry a nontoxic mix of water and glycol — a heat-carrying fluid that electric heat pumps can tap to keep buildings toasty in the winter and chilled in the summer.

As part of Hayden’s geothermal network, a loop of U-shaped pipe will collect constant heat from the earth, no matter how bitter the winter. Its two ends — the only parts visible — will connect to a distribution loop. (Alison F. Takemura/Canary Media)

Despite their superior efficiency, these heat pumps are far less common than the kind that pull from the ambient air, largely due to project cost. Because you have to drill to install a ground-source heat pump, the systems are typically about twice as expensive as air-source heat pumps.

But the underground infrastructure lasts 50 years or more, and the systems pay for themselves in fuel-cost savings more quickly in places that endure frostier temperatures, including Rocky Mountain municipalities like Hayden. Those long-term cost benefits were too attractive to ignore, Mendisco said.

Hayden’s project ​“is 100% replicable today,” Mendisco told attendees at the event, which included leaders of other mountain towns. Geothermal tech is ready; the money is out there, he added: ​“You can do this.”

Colorado certainly believes that — and it’s giving first-mover communities a boost.

In October, the state energy office announced $7.3 million in merit-based tax-credit awards for four geothermal projects. Vail is getting nearly $1.8 million for a network, into which the ice arena can dump heat and the library can soak it up. Colorado Springs will use its $5 million award to keep a downtown high school comfortable year-round. Steamboat Springs and a Denver neighborhood will share the rest of the funding.

At least one other northwest Colorado coal community is also getting on board with geothermal. In the prior round of state awards, the energy office granted $58,000 to the town of Craig’s Memorial Regional Health to explore a project for its medical campus.

With dozens of communities warming to the notion, ​“it’s an exciting time for geothermal in Colorado,” said Bryce Carter, geothermal program manager at the state energy office.

So far, the state has pumped $30.5 million into geothermal developments — with over $27 million going toward heating-and-cooling projects specifically — through its grant and tax-credit programs. The larger tax-credit incentive still has about $13.8 million left in its coffers.

Hayden, for its part, is also taking advantage of the federal tax credits to save up to 50% on the cost of its geothermal district. That includes a 10% bonus credit that the community qualifies for because of its coal legacy. After also accounting for a bonanza of state incentives, the $14-million project will only be $2.2 million, Mendisco said.

Tech innovation could further improve geothermal’s prospects, even in areas with less generous inducements than Colorado’s. Bedrock Energy, for one, aims to drive down costs by using advanced sensing technology that allows it to see the subsurface and make computationally guided decisions while drilling.

“In Hayden, we have gone from about 25 hours for a 1,000-foot bore to about nine hours for a 1,000-foot bore — in just the last couple of months,” Joselyn Lai, Bedrock’s co-founder and CEO, told me at the event. Overall, the firm’s subsurface construction costs from the first quarter of 2025 to the second quarter fell by about 16%, she noted.

When drilling, Bedrock Energy harnesses a constant stream of data to navigate underground obstacles from boulders to fractures. (Alison F. Takemura/Canary Media)

Hayden is likely just at the start of its geothermal journey. If all goes well with the business park, the town aims to retrofit its municipal buildings with these systems to comply with the state’s climate-pollution limits on big buildings, Mendisco said. Hayden’s community center could be the first to get a geothermal makeover starting in 2027, he added.

Robinson, despite coal’s salience in the region and his family’s legacy in its extraction, believes in Hayden’s vision: Geothermal could be a winner in a post-coal economy. In fact, he’s interested in investing in the geothermal industry and installing a system in a new house he’s building, he said.

“I’ve lived a lot of my life making a living by exploiting natural resources. I understand the value of that — as well as lessening our impact and being able to find new and better,” Robinson said. ​“This is the next step, right?”

This article was originally published by Canary Media and is republished here as part of Covering Climate Now, a global effort to boost coverage of climate change.

Yampa River Basin via Wikimedia.

The Platte River Power Authority waits to learn cost of keeping Craig 1 #coal plant open amid order — The #FortCollins Coloradoan #climate

The coal-fired Tri-State Generation and Transmission plant in Craig provides much of the power used in Western Colorado, including in Aspen and Pitkin County. Will Toor, executive director of the Colorado Energy Office has a plan to move the state’s electric grid to 100 percent renewable energy by 2040. Photo credit: Brent Gardner-Smith/Aspen Journalism

Click the link to read the article on the Fort Collins Coloradoan website (Rebecca Powell). Here’s an excerpt:

January 6, 2025

Platte River Power Authority’s general manager says he disagrees with a federal order requiring one of the coal plants it owns a stake in to remain open past its scheduled retirement and is waiting to learn what it might cost Fort Collins’ wholesale electricity provider…PRPA is a joint owner of the plant with PacifiCorp, Xcel Energy, Salt River Project and Tri-State Generation and Transmission, which operates the facility. PRPA owns 18% of the Craig 1 and 2 coal units…

The Department of Energy’s emergency order contends there is a shortage of electric energy and facilities in the Western Electricity Coordinating Council Northwest assessment area, which includes Colorado, Idaho, Montana, Oregon, Utah, Washington and Wyoming. The order, signed by Secretary of Energy Chris Wright, states that peak demand in the area is expected to grow 8.5% in the next decade, while many coal plants in the region have been retired, with more retirements planned…Wright cites supply chain issues with building battery storage systems to help replace the energy from those retirements. The emergency order also cited two executive orders from President Donald Trump. One declared a national energy emergency due to “insufficient energy production, transportation, refining, and generation.” The other declares the United States is experiencing an unprecedented surge in electricity demand driven by rapid technological advancements, like the expansion of AI data centers and domestic manufacturing…

But PRPA General Manager and CEO Jason Frisbie says PRPA does not need the Craig 1 unit because it has already replaced the energy that came from it.

“We have planned for the retirement of Craig Unit 1 for nearly a decade and have proactively replaced the capacity and energy from new sources,” Frisbie said in a statement provided to the Coloradoan.

Home electricity bills are skyrocketing. For data centers, not so much: Data centers are consuming more kilowatts than ever, but the price they pay for that electricity has risen only a little — Karin Kirk (YaleClimateConnection.org)

The QTS hypescale data center in Aurora occupies a campus of 67 acres and is still ramping up. Photo credit: Big Pivots

Click the link to read the article on the Yale Climate Connections website (Karin Kirk):

January 5, 2026

evenly distributed. 

A Yale Climate Connections analysis of electricity prices has found that data centers and other commercial electricity users are consuming more kilowatts than ever, but the price they pay for that electricity has risen only a little. And industrial users of electricity are actually paying lower prices, on average, than they were two years ago. 

But between 2020 and 2024, residential electricity prices in the U.S. increased by 25%. In other words, people using their toasters, laptops, and electric heating and cooking at home are paying ever-increasing prices, while the data centers that are driving rapid growth in electricity demand are scoring handsome discounts.

A word of warning: this analysis might make you mad, but hopefully in a productive way.

Since 2008, residential bills have been rising more than in other sectors

Electricity customers are sorted into use types: residential for homes, commercialfor businesses and data centers, and industrial for facilities like factories or refineries. The graph below shows how the prices paid by these three sectors have shifted over time.

Data analysis and image by Karin Kirk for Yale Climate Connections

From 1997 through 2007, electricity prices for all three categories of users rose and fell at a similar pace.

In 2008, that trend stopped. That year, electricity prices went up for residences but down for businesses and industries. 

Over the next decade, home uses of electricity became more expensive, while electricity prices for businesses stayed nearly flat.

In 2021, the trend shifted again. Electricity prices for all three sectors began to rise steeply, but unequally. The gap between home energy use and business/industrial energy use became even larger. In the last two years, these differences became especially stark, as shown in the chart below.

Data analysis and image by Karin Kirk for Yale Climate Connections

In just two years, starting in 2022, residential electricity prices rose by 10%, while commercial prices increased by only 3%, and industrial electricity prices fell by 2%.

This is an example of the “K-shaped economy,” where things improve for some groups while getting worse for others. The lines on a K-shaped graph head off in different directions, illustrating an ever-larger gap between those benefiting and those left out.

Recent increases in electricity demand are mostly due to the commercial sector, which includes data centers

If any one sector is driving the growth in electricity usage, it would make sense for that sector to foot the bill for the power plants and power lines needed to serve their demand. So let’s look at how electricity use is growing in each sector. 

The chart below shows how the amount of electricity used by each sector has changed since 1997. Industrial use has stayed relatively flat, while commercial and residential use both grew at fairly similar rates and are now consuming about 40% more power than they were in 1997.

Data analysis and image by Karin Kirk for Yale Climate Connections

But a new pattern emerged in the last three years, as seen in the chart below. Commercial demand for electricity rose sharply and steadily, using 9% more power over just a three-year span. 

Glenn McGrath, an electricity data analyst at the U.S. Energy Information Administration, wrote in an email that the growing energy needs of data centers “are likely a significant factor” behind increasing electricity use in the commercial sector.

Data analysis and image by Karin Kirk for Yale Climate Connections

To sum up the situation in recent years, household electricity use has grown the least of the three sectors, but that’s where prices have gone up the most. 

The data illustrates how residential users are subsidizing the energy bills of A.I. and data centers, a perspective backed up by other recent analyses. A report by the Harvard Law School Environmental and Energy Law Program, Extracting Profits from the Public, lays out some of the reasons why Big Tech is able to off-load its costs onto the public and outlines specific steps policymakers can take to restore balance. 

A big part of the problem is that the three sectors of electricity users are far from equal when it comes to their leverage. The report explains that companies that use large amounts of electricity can often negotiate lower pricing with energy suppliers, and in some cases, these contracts are secret. Complex rules and rate structures make it hard for the public – as well as regulators – to follow or engage with the process. Furthermore, policymakers have an incentive to attract new economic development in their state as technology companies shop around for the best pricing. 

But for individual consumers, the situation is the opposite. In many states, people have no choice in their energy provider or their energy prices, and they can’t look elsewhere for a better deal. In the parlance of the energy industry, everyday people are often called “captive ratepayers” because we have little choice but to be the ever-faithful customers of a monopoly utility. 

Expensive electricity can make life harder

Rising electricity bills can trigger a host of negative consequences. High energy costs may prevent people from adequately heating or cooling their homes, which can contribute to both physical and mental health problems. Expensive energy can also lead people to forego necessities in other areas of their lives in order to keep up with rising bills and avoid having their service shut off. These burdens fall disproportionately on low-income, Black, Hispanic, and disadvantaged households, who spend a large portion of their income on energy bills.

Higher electricity prices could also slow the adoption of modern, climate-friendly technology such as electric vehicles, heat pumps, and induction stoves that rely on electricity. That said, electric cars and appliances are more efficient than their fossil-fuel counterparts, so the trade-off is often still worth it. 

And in some cases, expensive electricity can spur faster adoption of climate solutions. Home solar panels pay for themselves more quickly, and energy conservation measures make even more financial sense than before.

A stressed system that’s become fundamentally unfair

The electricity system in the U.S. is undergoing multiple stresses at once. Data centers seem to have an unquenchable thirst for energy, as extreme weather – often made worse by our warming climate – destabilizes the grid and causes spikes in electricity demand. At the same time, electricity generation is slowly transitioning from large, centralized power plants to numerous, distributed forms of electricity generation. 

But at the root of it all, the data suggests that everyday people are footing the bill while companies that consume ever more power are paying less. At a time when corporations seem to enjoy many structural advantages over consumers, from lower tax rates to relaxed pollution requirements, the burden of rising energy bills can make one feel powerless. And yes, the pun was intentional.

Ratepayers do have a voice

Decisions about electricity rates are made by public utility commissions, which don’t usually get much attention – but that may be changing. In the November 2025 elections in Georgia, two incumbent public utility commissioners were resoundingly defeatedafter residential electricity prices climbed by 41% in just four years. Commissions are increasingly criticized for rubber-stamping price hikes and not protecting ratepayers who are caught inside a monopolistic system.

If you’re interested in learning more about the electricity decision-making process near you, here’s a directory of public utility commissions in every state, and Canary Media wrote a user-friendly guide to engaging with your electricity regulators. The deck may feel stacked against the common person, but that might just be all the more reason to get involved. 

Data sources

Electricity prices by sector and electricity usage by sector from the Energy Information Administration. These interactive datasets can be displayed for different time periods and regions of the U.S.

#Conservation studies findings on #Colorado’s Western Slope have lessons for water managers: Western Slope water users want Front Range to match cuts — Heather Sackett (AspenJournalism.org) #ColoradoRiver #COriver #aridification

Colorado State University researcher Perry Cabot talks to a group about forage crops at the Fruita field station. Cabot studies the effects of irrigation withdrawal and forage crops that use less water. CREDIT: HEATHER SACKETT/ASPEN JOURNALISM

Click the link to read the article on the Aspen Journalism website (Heather Sackett):

December 12, 2025

The findings of recent water-conservation studies on the Western Slope could have implications for lawmakers and water managers as they plan for a future with less water.

Researchers from Colorado State University have found that removing irrigation water from high-elevation grass pastures for an entire season could have long-lasting effects and may not conserve much water compared with lower-elevation crops. Western Slope water users prefer conservation programs that don’t require them to withhold water for the entire irrigation season, and having the Front Range simultaneously reduce its water use may persuade more people to participate. Researchers also found that water users who are resistant to conservation programs don’t feel much individual responsibility to contribute to what is a Colorado River basinwide water shortage. 

“It’s not a simple economic calculus to get somebody to the table and get them to sign a contract for a conservation agreement,” said Seth Mason, a Carbondale-based hydrologist and one of the researchers. “It involves a lot of nuance. It involves a lot of thinking about tradeoffs.” 

Udall/Overpeck 4-panel Figure Colorado River temperature/precipitation/natural flows with trend. Lake Mead and Lake Powell storage. Updated through Water Year 2025. Note the tiny points on the annual data so that you can flyspeck the individual years. Credit: Brad Udall

Over the past 25 years, a historic drought and the effects of climate change have robbed the Colorado River of its flows, meaning there is increasing competition for a dwindling resource. In 2022, water levels in Lake Powell fell to their lowest point ever, prompting federal officials to call on the seven states that share the river for unprecedented levels of water conservation. 

The Upper Basin states (Colorado, New Mexico, Utah and Wyoming) have experimented for the past decade with pilot programs that pay agricultural water users to voluntarily and temporarily cut back by not irrigating some of their fields for a season or part of a season.

The most recent program was the federally funded System Conservation Pilot Program, which ran in the Upper Basin in 2023 and 2024, and saved about 100,000 acre-feet of water at a cost of $45 million. The Upper Basin has been facing mounting pressure to cut back on its use, and although some type of future conservation program seems certain, Upper Basin officials say conservation must be voluntary, not mandatory.

Despite dabbling in these pilot conservation programs, Upper Basin water managers have resisted calls for cuts, saying their water users already suffer shortages in dry years and blaming the plummeting reservoirs on the Lower Basin states (California, Nevada and Arizona). Plus, the Upper Basin has never used its entire allocation of 7.5 million acre-feet a year promised to it under the 1922 Colorado River Compact, while the Lower Basin uses more than its fair share. 

Sketches by Floyd Dominy show the way he’d end the Glen Canyon Dam. From the article “Floyd Dominy built the Glen Canyon Dam, then he sketched its end on a napkin” on the Salt Lake Tribune website

But as climate change continues to fuel shortages, makes a mockery of century-old agreements and pushes Colorado River management into crisis mode, the Upper Basin can no longer avoid scrutiny about how it uses water. 

“We need a stable system in order to protect rivers,” said Matt Rice, director of the Southwest region at environmental group American Rivers, which helped fund and conduct the research. “(Upper Basin conservation) is not a silver bullet. But it’s an important contributing factor, it’s politically important and it’s inevitable.”

Researchers from Colorado State University used this monitoring station to track water use on fields near Kremmling. Researchers have found that Western Slope water users are more likely to participate in conservation programs if there is a corresponding Front Range match in water use reduction. CREDIT: HEATHER SACKETT/ASPEN JOURNALISM

Findings

Papers by the researchers outline how water savings on Colorado’s high-elevation grass pastures — which represent the majority of irrigated acres on the Western Slope — are much less than on lower-elevation fields with other annual crops. Elevation can be thought of as a proxy for temperature; fewer frost-free days means a shorter growing season and less water use by the plants. 

“Our results suggest that to get the equivalent conserved consumptive-use benefit that you might achieve on one acre of cornfield in Delta would require five acres of grass pasture if you were up near Granby, for example,” said Mason, who is a doctoral candidate at CSU. “This is a pretty important constraint as we’re thinking about what it means to do conservation in different locations across the West Slope.”

In addition to the science of water savings, Mason’s research also looked at the social aspects of how water users decide to participate in conservation programs. He surveyed 573 agricultural water users across the Western Slope and found that attitudes toward conservation and tendencies toward risk aversion — not just how much money was offered — played a role in participation. 

Many who said they would not participate had a low sense of individual responsibility to act and a limited sense of agency that they could meaningfully contribute to a basinwide problem.

If you don’t pay attention to the attitudes of water users, you could end up with an overly rosy picture of the likelihood of participation, Mason said.

“It may do well to think less about how you optimize conservation contracts on price and do more thinking about how you might structure public outreach campaigns to change hearts and minds, how you might shift language as a policymaker,” he said. “A lot of the commentary that we hear around us is that maybe this isn’t our problem, that this is the Lower Basin’s problem. [ed. emphasis mine] The more you hear that, the less likely you are to internalize a notion of responsibility.”

Mason also found that a corresponding reduction in Front Range water use may boost participation by Western Slope water users. The fact that Front Range water providers take about 500,000 acre-feet annually from the headwaters of the Colorado River is a sore spot for many on the Western Slope, who feel the growth of Front Range cities has come at their expense. These transmountain diversions can leave Western Slope streams depleted. 

Western Slope water users often describe feeling as if they have a target on their back as the quickest and easiest place to find water savings.

“I think they tend to be appreciative of notions that have some element of burden sharing built into them,” Mason said. “So they aren’t the only ones being looked at to contribute as part of a solution to a problem.”

Perry Cabot, a CSU researcher who studies the effects of irrigation withdrawal and forage crops that use less water, headed up a study on fields near Kremmling to see what happens when they aren’t irrigated for a full season or part of a season. The findings showed that fields where irrigation water was removed for the entire season produced less hay, even several years after full irrigation was resumed. Fields where water was removed for only part of the season had minimal yield loss and faster recovery. 

“In the full season, you can have a three-year legacy effect, so that’s where the risk really comes in if you’re a producer participating in these programs,” Cabot said. “For three years after, you’re not getting paid even though you’ve diminished that yield.”

At the CSU research station in Fruita, Cabot is studying a legume called sainfoin, a forage crop and potentially an alternative to grass or alfalfa. He said sainfoin shows promise as a drought-tolerant crop that can be cut early in the season, allowing producers to have their cake and eat it too: They could maintain the income from growing a crop, avoid some of the worst impacts of a full-season fallowing, and still participate in a partial-season conservation program. 

“I’d like to see flexible options that allow us to think about conservation happening on fields that still have green stuff out there,” Cabot said.

This field near Kremmling participated in an early study on the effects of removing irrigation water. Researchers found the effects of full-season fallowing can have lasting impacts. CREDIT: HEATHER SACKETT/ASPEN JOURNALISM

Part of the solution

The Glenwood Springs-based Colorado River Water Conservation District has been one of the loudest voices weighing in on conservation in recent years, helping to fund Cabot’s and Mason’s studies, as well as conducting its own. The River District, which represents 15 counties on the Western Slope, is not a fan of conservation programs, but it has long accepted their inevitability. It has advocated for local control and strict guidelines around a program’s implementation to avoid negative impacts to rural agricultural communities. 

River District General Manager Andy Mueller said there is still a lot of resistance to a conservation program in Colorado — especially if the saved water is being used downstream to fuel the growth of residential subdivisions, computer-chip factories and data centers in Arizona. In addition to wanting the Front Range to share their pain, Western Slope water users don’t want to make sacrifices for the benefit of the Lower Basin. [ed. emphasis mine]

“They want to be part of the solution, but they don’t want to suffer so that others can thrive,” Mueller said. “That’s what I keep hearing over and over again from our producers on the ground: They are willing to step up, but they want everybody to step up with them.”

Water experts agree Upper Basin conservation is not a quick solution that will keep the system from crashing. Complicated questions remain about how to make sure the conserved water gets to Lake Powell and how a program would be funded. 

And as recent studies show, the tricky social issues that influence program participation, multiseason impacts to fields when water is removed and the scant water savings from high-elevation pastures mean the state may struggle to contribute a meaningful amount of water to the Colorado River system through a conservation program. 

“If the dry conditions continue, it’s hard to produce the volumes of water that make a difference in that system,” Mueller said. “But are we willing to try? Absolutely. It has to be done really carefully.”

Map of the Colorado River drainage basin, created using USGS data. By Shannon1 Creative Commons Attribution-Share Alike 4.0

President Trump’s ’emergency’ #Colorado #coal plant order will raise electricity costs, operator says — Chase Woodruff (ColoradoNewsline.com)

Chris Wright has argued that energy scarcity poses a greater threat to quality of life than climate change. Here, he speaks to reporters in April 2025 while Martin Keller, then the director of NREL, looks on. Photo/Allen Best. Top image/National Laboratory of the Rockies.

Click the link to read the article on the Colorado Newsline website (Chase Woodruff):

January 2, 2026

Following the Trump administration’s last-minute invocation of an energy “emergency” to order a Colorado coal plant to postpone its scheduled retirement, the electricity provider that co-owns the plant is warning that the high costs of continuing to operate it will be shouldered by Colorado utility customers.

Located in Moffat County, Craig Generating Station’s 446-megawatt Unit 1 had been scheduled to go offline on Dec. 31, 2025, part of a wave of coal retirements planned across Colorado through 2030. But an emergency order issued Dec. 30 by the Department of Energy requires the plant to “take all measures necessary to ensure that Craig Unit 1 is available to operate” until at least March 30, 2026.

Tri-State Generation and Transmission Association, co-owner of Craig Generating Station, said in a press release that the “additional investments in operations, repairs, maintenance and, potentially, fuel supply” required by the order will raise costs for the plant’s customers, which include dozens of electric utilities and rural co-ops. Unit 1 was already offline due to a mechanical failure on Dec. 19, Tri-State said.

“We are continuing to review the order to determine what this means for Craig Station employees and operations, and the financial impacts,” said Tri-State CEO Duane Highley. “As a not-for-profit cooperative, our membership will bear the costs of compliance with this order unless we can identify a method to share costs with those in the region. There is not a clear path for doing so, but we will continue to evaluate our options.”

The five-page DOE order, signed by Energy Secretary Chris Wright, cites “growing resource adequacy concerns” as justification for the move, which followed similar actions in Indiana and Washington.

Shortly after taking office last year, President Donald Trump declared a “national energy emergency” in an executive order blasted by environmental advocates as a pretext for advancing the interests of fossil-fuel companies. Despite the declaration’s stated concerns about “insufficient energy production,” the administration has continued to cancel and delay major wind and solar projects.

An analysis released in December by the Sierra Club estimated that keeping Craig’s Unit 1 open for 90 days would cost ratepayers at least $20 million. Critics of the administration anticipate that the DOE’s orders will continue to be renewed every 90 days under the authority granted to the department by Federal Power Act, raising costs by $85 million to $150 million annually.

“Keeping this dirty and outdated coal plant online will harm the health of surrounding communities and hurt all of our pocketbooks,” said Michael Hiatt of environmental group Earthjustice. “This unlawful order will benefit no one but the struggling coal industry.”

The DOE order comes amid a series of Trump administration actions targeting Colorado that are widely viewed as retaliation for the ongoing incarceration of Trump ally and former Mesa County Clerk Tina Peters, who was convicted on felony charges for her role in a breach of her own office’s secure election equipment in 2021.

Colorado U.S. Sen. Michael Bennet voted to confirm Wright, a former Denver oil executive, as Trump’s pick for Energy Secretary in January 2025, calling Wright “passionate about strengthening America’s energy independence and lowering costs for Colorado families.” In a statement Wednesday, Bennet, a Democrat who is running for Colorado governor, said he was “disappointed but not surprised by this continued revenge tour.”

“The DOE order is the latest in a string of attacks against Colorado, because we refuse to bend to the President,” Bennet said. “President Trump continues to take out his personal and political grievances on Coloradans who are already struggling to make ends meet.”

The three units of Craig Station were constructed from 1974 to 1984. Photo credit: Allen Best/Big Pivots

Oh, the irony of Craig No. 1! — Allen Best (BigPivots.com) #coal

Craig Station. Photo credit: Allen Best/Big Pivots

Click the link to read the article on the Big Pivots website (Allen Best):

December 31, 2025

Trump orders Craig coal unit planned for retirement to stay open. But it so happens the unit is broken. Ludicrous says Polis team. Sierra Club challenges basis for emergency declaration.

It was no surprise. Tri-State Generation and Transmission has said for at least three months that it expected to get orders from the Trump administration to continue operating a coal-burning unit at Craig, in northwest Colorado, beyond its scheduled retirement on Dec. 31, 2025.

The order was posted at 6 p.m. MST Tuesday. Citing emergency authority claimed by President Donald Trump, Energy Secretary Chris Wright ordered the coal unit to remain in operation through March 2026. The order cited a sudden increase in demand for electricity, or a shortage of generation capacity.

The irony of the order is that it was issued when the 427-megawatt unit was out of operation, according to a statement issued by the office of Colorado Gov. Jared Polis.

Ludicrously, the coal plant isn’t even operational right now, meaning repairs — to the tune of millions of dollars — just to get it running, all on the backs of rural Colorado ratepayers!” Polis said.

“Going backwards is an attempt to force local communities to foot the bill to extend plant operations and will cost energy consumers more. Today’s action flies in the face of this careful planning, is inconsistent with market forces, and will hurt Coloradans.”

The Polis team estimated continued operations would cost tens of millions of dollars “to keep a coal plant open that is broken and not needed.”

Tri-State, in a statement on Wednesday morning, explained that the unit “went into an outage” on Dec. 19, 2025, due to a mechanical failure of a valve. “Tri-State and the other co-owners will need to take the necessary steps to repair the valve in a timely manner,” the statement said.

“Tri-State has a policy of 100% compliance, and we will work with Unit 1 co-owners, and federal and state governments to determine the most cost-effective path to that end,” said Duane Highley, Tri-State CEO. “We are continuing to review the order to determine what this means for Craig Station employees and operations, and the financial impacts. As a not-for-profit cooperative, our membership will bear the costs of compliance with this order unless we can identify a method to share costs with those in the region. There is not a clear path for doing so, but we will continue to evaluate our options.”

As a result of the order, retaining Unit 1 will likely require additional investments in operations, repairs, maintenance and, potentially, fuel supply, all factors increasing costs, Tri-State said. “Tri-State is continuing to review the order to determine how best to comply while limiting the costs to its members, and the impacts to its employees and operations.”

Highley told Big Pivots in October that the wholesale supplier for cooperatives in Colorado and three other states did not need the electrical production at this time, as it is actually producing more than it needs.

Wright, in his order, No. 202-25-14, cited several justifications.

One justification was a 2024 report by the Western Electricity Coordinating Council that forecast growth of 8.5% in peak demand during the next decade in Colorado and several adjoining states.

The order also said that Tri-State and its co-owners — Fort Collins-based Platte River Power Authority, Phoenix-based Salt River Project, Salt Lake City-based PacifiCorp., and Denver-based Xcel Energy — “take all measures necessary” to ensure that Craig Unit 1 is available to operate at the direction of either Western Area Power Administration in its role as a balancing authority or the Southwest Power Pool West in its role as the reliability coordinator.

The Sierra Club emphasized the cost of operating Craig No. 1. It cited a recent report by Grid Strategies that found operating the unit past the retirement deadline will cost the plant owners $85 million per year. This is distinct from repairs that may be necessary.

“Trump is playing politics with coal,” said Margaret Kran-Annexstein, director of the Colorado chapter, in a statement issued shortly after the order was posted.

Matthew Gerhart, the senior attorney for the Sierra Club at its Denver office, had even stronger language in an interview with Big Pivots.

“I think this order is a joke even by this administration’s standards,” he said. “This is quite clearly just a political move. None of the documents they cite even come close to saying there is an emergency.”

Wright’s order cited the 2025-2026 Winter Reliability Assessment issued by the North America Electric Reliability Corporation. That report in November noted total and net internal demand increases of almost 1% driven primarily by data centers and commercial and industrial customer growth. Even so, the operating reserve margins in the Rocky Mountain were expected to be met before imports in all winter scenarios.

That being said, Xcel Energy almost a year ago began expressing concerns about resource adequacy.

Gerhart also found fault with Wright’s order that the unit be available to operate at the direction of the Southwest Power Pool West in its role as the reliability coordinator. SPP exists, but not the configuration — a regional transmission organization — that would allow SPP to do this, he said. SPP has a day-ahead market and also a balancing market but not the apparatus set up to manage the operation of Craig No. 1, he said.

Will Toor, director of the Colorado Energy Office, also pointed to the report from the North America Reliability Corporation that found no short-term or long-term elevated reliability risks in the Rocky Mountain region,

“These orders will take money out of the pockets of Colorado ratepayers, and especially harm rural communities across the West who could be forced to absorb the unnecessary excess costs required to keep this plant operational,” he said. “The Trump administration is engaging in Soviet-style central planning, driven by ideology rather than the realities of the electric grid, that will drive dirtier air and higher electric rates across our state. These orders are unlawful and will not improve energy security in Colorado or the region.”

Trump has claimed authority to order coal plants remain in operation under the Federal Power Act. That nearly century-old law explicitly gives presidents authority to order electrical plants to operate under duress of war or weather emergencies. Since last April, Trump has sought to expand the power, citing emergencies caused by concerns about resource adequacy. The concerns, he has said, result from retiring fossil fuel and nuclear plants, dramatic growth in demand, and the intermittency of renewables.


For a deeper dive on Trump’s contested use of the emergency clause in the Federal Power Act, see this Big Pivots story from Nov. 3: “Will feds order Colorado coal plants to stay open?”


U.S. Sen. Michael Bennet, a gubernatorial candidate, also pushed back: “The DOE order is the latest in a string of attacks against Colorado, because we refuse to bend to the President. President Trump continues to take out his personal and political grievances on Coloradans who are already struggling to make ends meet. Federal intervention like this makes long-term planning impossible – this is not how you operate a business, plan an electric grid, or help a community stay prosperous. I am disappointed but not surprised by this continued revenge tour.”

Wright’s order said that 417.3 megawatts of coal-fired generating capacity across six units at three locations have retired in Colorado since 2019. It cited the Western Electricity Coordinating Council. “Looking forward, by 2029, about 3,700 megawatts of coal-fired generating capacity in Colorado is scheduled to be retired.” The order said that during that time, 675.6 megawatts of natural gas-fired generating capacity in Colorado will retire as well.

Wind turbines near Pawnee Buttes in northeastern Colorado. Photo/Allen Best

In 2025, wind accounted for over 5,300 megawatts of Colorado’s electricity generating capacity, the order noted.

Wright’s order described wind as intermittent. Of course, coal can be intermittent, too. That has been demonstrated repeatedly at Pueblo, particularly in the case of Comanche 3. The coal unit went down again in August and is not expected to be restored into operation until June 2026. In its absence, Xcel asked — and the Polis administration agreed — that Comanche 2 would not be retired this month, as had been planned for several years.

As for Craig No. 1, its retirement was planned in an agreement reached almost a decade ago. Air quality standards in Rocky Mountain National Park and other national parks and wilderness areas are being violated in part because of emissions from the unit. The regional haze standards were federally created and state enforced. The agreement with the Colordo Air Quality Control Commission was reached in 2016.

Tri-State’s electric resource plan of 2023 showed adequate resources to maintain reliability on Tri-State’s system following the retirement of Craig No. 1 as well as two other units at Craig Station that are scheduled to close in 2028. Unit 2, which Tri-State owns with its other partners in Unit 1, has a capacity of 410 megawatts. Tri-State owns 100% of Unit 3, which has a capacity of 448 megawatts. The three units were constructed and went on line in the late 1970s and early 1980s.

The Trump administration first cited the Federal Power Act earlier this year this year for plants in Michigan and in Pennsylvania and has recently used that same emergency power to order continued operation of fossil fuel plants in Indiana and Washington.

Massive Energy Storage Project Eyed for Four Corners Region — Brett Walton (circleofblue.org)

A large elevation differential is a crucial feature of the proposed Carrizo Four Corners project. The project’s upper reservoir would be located near the top of the Carrizo Mountains, seen here on Navajo Nation land near Beclabito, New Mexico. Photo © Brett Walton/Circle of Blue

Click the link to read the article on the Circle of Blue website (Brett Walton):

December 22, 2025

Colorado River water could enable a pumped storage hydropower project intended to make the region’s electric grid more resilient.

KEY POINTS

One of the longest-duration pumped storage hydropower projects in the country is proposed for Navajo Nation land in the Four Corners region.

The project received a $7.1 million Department of Energy grant this year for feasibility studies.

Pumped storage hydropower is the largest form of energy storage in the U.S.

 Standing in a breezy parking lot on Navajo land in the state’s far northwest corner, Tom Taylor looked toward the western horizon and then upwards at the furrowed mass of the Carrizo Mountains less than 10 miles away.

If all goes to plan, the infrastructure that could one day spill from the mountain’s flanks and through its core will become an essential piece of the region’s electric grid, able to store surplus electricity from renewable energy and other power sources for when it is needed later.

Fighting the wind that chilly November morning, Taylor used both hands to pin a detailed map against the hood of his Porsche Macan. A jumble of dashed lines and blue splotches representing proposed power lines, reservoirs, a water-supply pipeline, and access roads were printed atop the real-world geography on display in front of us.

“This will be a battery that lasts a long time,” Taylor said, holding tightly to the map.

JOAN CARSTENSEN

The project is the $5 billion Carrizo Four Corners Pumped Storage Hydro Center, which is designed to be one of the largest long-duration energy storage projects in the country. Pumped storage moves water between two reservoirs at different elevations. Water is pumped uphill when excess electricity is available and released to generate electricity when power demand warrants it.

Taylor, a former mayor of Farmington and a state House representative from 2000 to 2014, is employed by Kinetic Power, the three-person, Santa Fe-based outfit behind the Carrizo proposal. The company sees the project as a way to make the region’s electric grid more durable and cost-effective, not only by smoothing the intermittent nature of wind and solar but also as a bulwark against energy emergencies like the winter storm in 2021 that caused blackouts and 246 deaths in Texas. The twinned reservoirs, using water sourced from a Colorado River tributary nearby, would have the capacity to generate 1,500 megawatts over 70 hours – a form of battery that could provide the equivalent output of a large nuclear plant for nearly three days.

“We believe that the key is delivering economic value,” said Thomas Conroy, Kinetic Power’s co-founder, who has four decades of experience developing energy projects.

What seems straightforward when placing lines on a map is much less so in three dimensions. Carrizo Four Corners, which is still in the exploratory stage and is at least five years away from breaking ground, has nearly as many questions as answers at this point. What is the geology within the Carrizo Mountains? Will it support a 3,300-foot-deep shaft, a subterranean powerhouse, and dam abutments? How will drought affect the water supply? What cultural sites and wildlife might be at risk from construction? What are the power market dynamics? 

Answering those questions is the goal of a $7.1 million, two-and-a-half-year Department of Energy grant that Kinetic and its six university and research partners secured in August. (The state of New Mexico and the research partners are also contributing $7.1 million.) On the political side, will future Navajo administrations feel as favorably toward Carrizo as current president Buu Nygren?

The technical questions are but one piece of an ambitious project that touches many of the most pressing questions about natural resources in the American West today: energy development, water use, and the relationship between federal law and tribal law.

Connecting Water and Energy

Though the details are still to be worked out, the project can be described in broad strokes.

The Federal Energy Regulatory Commission, which oversees federal hydropower licensing, granted Kinetic a preliminary permit in 2021. In February 2025 FERC extended the permit, which allows for site investigations but no construction work, for another four years.

The company envisions two “off-channel” reservoirs that would not dam a flowing river. The lower reservoir will be near Beclabito. The upper, in the high reaches of the Carrizo Mountains. Both are on Navajo land, but on different sides of the Arizona-New Mexico border.  

Tom Taylor of Kinetic Power displays a map of the proposed Carrizo Four Corners Pumped Storage project. In the background are the Carrizo Mountains, where the project’s upper reservoir would be located. Photo © Brett Walton/Circle of Blue

The powerhouse that holds the electricity-generating turbines will be located underground, some 3,300 feet below the upper reservoir. Some of the longest pumped storage tunnels in the country will be required to connect the reservoirs and the powerhouse. 

Despite the geotechnical challenges, Conroy is particularly enthused by the site, which he said is the most optimal in Arizona and New Mexico – and possibly the entire country – to locate a pumped storage hydropower project.

The site stands out for four reasons, he said. It is near existing transmission corridors and grid connections due to the region’s legacy of enormous coal-fired power plants. And it will have a comparatively low capital cost for the energy it will produce. 

The other two reasons relate to water. Because of the extreme height differential between the upper and lower reservoirs – almost three Empire State Buildings – less water will be required to produce a unit of energy than for reservoirs with a gentler gradient. And because the upper reservoir site is a deep canyon, surface area and thus evaporation will be minimized. 

“Water is just top of mind here in the Southwest,” Conroy said. “And our project is as water-efficient as can be made.”

Water to fill the reservoirs would be drawn from the San Juan River, a tributary of the Colorado, via pipeline. The water would come from the Navajo Nation’s San Juan rights, which have been quantified but are not fully used.

How much water? In its FERC permit application, Kinetic estimated that the initial fill, which will take one and a half to two years, would require 38,300 acre-feet. To cover subsequent evaporation losses, the reservoirs would need to be topped up with 2,635 acre-feet per year. Those numbers will be refined in the feasibility studies.

“It’s what, about 1,300 acres of corn?” Taylor said, doing a rough mental calculation of the equivalent water consumption for the annual evaporation loss. “I think this is more valuable than 1,300 acres of corn.”

Saving for Tomorrow

So far the project has threaded the federal government’s fraught energy politics. The Trump administration is hostile to wind and solar, which in their eyes reek of liberal values. Two water-based technologies – hydropower and geothermal – have escaped condemnation and are listed in the administration’s energy dominance documents. The DOE grant that Carrizo secured is a holdover from the Biden administration’s infrastructure bill, which provided up to $10 million for feasibility studies for pumped storage projects that would store renewable energy generated on tribal lands.

Storage is the holy grail of renewable energy. Human civilization has advanced, from the dawn of agriculture to the artificial intelligence revolution today, by being able to carry a surplus from one season and one year to the next. So it is with wind and solar. To maximize their utility and counteract their intermittent nature, engineers have been searching for cost-effective ways to store energy when the sun shines and when the wind blows for the days when neither of those things happen.

“If you want to improve the resiliency of the system, you either build more firm capacity instead of more renewable, or you build longer storage,” said Fengyu Wang, a New Mexico State University assistant professor who is the principal investigator for the DOE grant.

Water for the Carrizo Four Corners project would come from the San Juan River, seen here near Shiprock, New Mexico, about 20 miles from the proposed diversion site. The San Juan is a tributary to the Colorado River. Photo © Brett Walton/Circle of Blue

Storage has taken many forms. Some are fantastic mechanical configurations – lifting heavy objects and dropping them, or forcing air into caverns and releasing it. Thermal options use molten salt to trap the sun’s heat. The most familiar are batteries, which leverage chemical energy. But the most common, at least in the U.S., is pumped storage hydropower.

The 43 pumped storage facilities in the U.S. represent the bulk of the country’s utility-scale energy storage. They accounted for 88 percent of the total in 2024, according to Oak Ridge National Laboratory. That is changing quickly, however, as more battery storage comes online. The share for pumped storage was 96 percent in 2022.

Still, long-duration storage is where pumped storage shines. According to Oak Ridge, the median battery storage is two hours. For pumped storage, it is 12 hours. Longer duration provides more buffer, not only from day to day but also season to season.

In that regard, Carrizo would signify a huge leap. The only comparable pumped storage project under consideration in the U.S. is Cat Creek, in Idaho. Even though its duration is 121 hours, its generating capacity is less than half, at 720 megawatts. 

Carrizo will have a different use case than other U.S. pumped storage projects, Conroy said. Many facilities have one customer and one generator. A nuclear plant, for instance, might be paired with a pumped storage system so that the nuclear plant can run continuously.

For Carrizo, there might be a consortium of utilities that have multiple generating sources feeding into this project and moving the water uphill. They would take delivery of that power across a large region with different climatic conditions and different needs for when and how they use the stored power. That means operating the facility will be more complicated than a traditional pumped storage project. One thing is certain, Conroy said: the Navajo will have an equity stake.

Tribal Outlook

Caution on the part of the Navajo would be understandable. The tribe’s lands have long been the center of energy developments with environmentally ruinous but economically helpful outcomes.

Uranium mining to fuel the Manhattan Project and then the nation’s reactors polluted rivers and groundwater, as did the coal mines that fed Four Corners Power Plant and the now-shuttered Navajo Generating Station and San Juan Generating Station. On the other hand, these developments provided employment and income. Navajo Mine, which supplies Four Corners Power Plant, accounts for about 35 percent of the Navajo Nation’s general fund.

Navajo and other tribal lands in the Four Corners region have been the target for a handful of pumped storage proposals in recent years. The Navajo Nation opposed three projects proposed for the Little Colorado River watershed, which were either withdrawn by the developer or denied a permit by FERC. Two other projects – Carrizo and Sweetwater, both using San Juan River water – are still in development. Sweetwater, a smaller project with eight hours duration, is being co-developed with the Ute Mountain Ute Tribe. A third project, Western Navajo Pumped Storage, which would be located near the former Navajo Generating Station, received a FERC preliminary permit in August.

The Carrizo project would be located partly on lands in the Beclabito chapter of the Navajo Nation. Photo © Brett Walton/Circle of Blue

Carrizo has not run into the same level of opposition as the other proposals. In part that is due to the proposed use of the San Juan River instead of groundwater, said Erika Pirotte, an assistant attorney general in the Navajo Nation’s water rights unit. Many Navajo communities rely on groundwater, and using it for pumped storage was viewed as unreasonable.

The lack of strong opposition is also because of Kinetic’s engagement with the Navajo Nation. The company has held meetings with the Beclabito, Red Valley, and Teec Nos Pos chapters, in addition to meetings with Navajo Nation agencies and Buu Nygren, the Navajo Nation president. Kinetic has a memorandum of understanding with Nygren, who also signed a letter of support for the project’s DOE grant application. 

“We have the support of the council,” Conroy said. “We have a very high level of support from the president, and he is just extraordinarily interested in this project and seeing that it moves forward.”

From the Navajo perspective, what is interesting are the “ancillary benefits” that could come from the water supply pipeline, Pirotte said. Once the reservoirs are filled and the pipeline’s full capacity is not needed, the extra space could be repurposed for tribal water supply uses.

“That’s why the feasibility studies are really important for the Nation, because they help us understand to what extent Navajo Nation resources would be used for the project,” Pirotte said.

None of this is immediately around the corner, Conroy cautions. The DOE grant extends for more than two years. The FERC permitting process could be another two to four years. With Congress and the Trump administration talking about faster permitting and better coordination, that timeline is a best guess. 

And then there is the question of tribal authority in the permitting process, not just for the Carrizo project but for other such developments. Will FERC abide by its 2024 stance that preliminary permits for hydropower projects on tribal lands require tribal consent? The Trump administration would like to see that policy scrapped. If FERC approves a project must a tribe assent to all the associated infrastructure? Will the Navajo be allowed to conduct reviews and issue permits?

And then there is construction, the biggest component. That will take four to six years, Conroy said. 

Even on an ambitious timeline, Carrizo is not operating until the mid-2030s.

“I’m 77,” Taylor said. “I probably won’t see it.”

This story was produced by Circle of Blue, in partnership with The Water Desk at the University of Colorado Boulder’s Center for Environmental Journalism.

Map of the San Juan River, a tributary of the Colorado River, in Arizona, Colorado, New Mexico and Utah, USA. Made using USGS National Map data. By Shannon1 – Own work, CC BY-SA 4.0, https://commons.wikimedia.org/w/index.php?curid=47456307

Gross Dam’s successful year: Dam raise 95% complete — Jay Adams (DenverWater.org) #BoulderCreek #FraserRiver #ColoradoRiver #COriver #SouthPlatteRiver #aridification

Click the link to read the article on the Denver Water website (Jay Adams):

December 12, 2025

Workers raise dam 109 feet in 2025. Next year’s goal: Reaching the top.

The Denver Water team working on Gross Dam in Boulder County is celebrating a successful year after the dam raise is 95% complete.

“In 2025, we raised the height of the dam by 109 feet above the original structure,” said Jeff Martin, Denver Water’s program manager for the Gross Reservoir Expansion Project. “We have 22 feet left to go to reach the new height and we’re on track to reach that in 2026.”

The dam-raising aspect of the Gross Reservoir Expansion Project wrapped up for the season on Nov. 14, due to the drop in temperatures. The project is designed to nearly triple the water storage capacity of Gross Reservoir.

In 2025, workers raised the height of Gross Dam by 109 feet. The final 22 feet will be completed in 2026 to reach the dam’s new height of 471 feet. Photo credit: Denver Water.

“We have to stop placing roller-compacted concrete when the temperatures drop below freezing,” said Casey Dick, deputy program manager for the Gross Reservoir Expansion Project.

“To prepare for winter, we put blankets on top of the new concrete to keep it from getting too cold. That’s because if the concrete freezes while it is still curing, it can lead to a weakened final product.”

Work associated with the dam raise will resume in spring 2026, when the weather warms up enough to complete the final 22 feet.

Protective “blankets” were placed on top of the dam to insulate the new concrete, so it does not fully cure over the cold, winter months. Photo credit: Denver Water.

Once that work is complete, the dam will be 471 feet tall, which is 131 feet higher than the original. The completed dam also will be longer across its crest, or top. The original crest was 1,050 feet long; the higher dam will have a crest that stretches 2,040 feet from one side of the canyon to the other.


Learn more about the Gross Reservoir Expansion Project.


This year marked the second year of dam raising construction work at Gross.

As of December 2025, workers had placed more than 730,000 cubic yards of concrete. To put that in perspective, Empower Stadium at Mile High, where the Denver Broncos play their home football games, required just 29,000 cubic yards of concrete to build, about 4% of the concrete placed so far on Gross Dam.

Protective “blankets” were placed on top of the dam to insulate the new concrete, so it does not fully cure over the cold, winter months. Photo credit: Denver Water.

Roller-compacted concrete is a special mix of concrete that allows crews to place it on the dam and then spread it out. The concrete is firm enough to be able to drive machinery on top of it. The process is a fast and efficient method of raising the dam. During the construction work, crews raised the height of the dam by about 1 foot per day.

Construction crews use GPS technology and survey equipment to keep track of how high they’ve raised the dam.

“The way we keep track of the elevation gain is that the bulldozers are equipped with GPS-grade control technology, which ensures that each layer of concrete is spread to the correct thickness,” Dick said.

“Once the concrete is rolled and vibrated into place, each layer ends up being 1 foot thick. It’s then checked by surveyors with their equipment to verify the exact elevation.”

The bulldozers are equipped with GPS-grade control technology to monitor the height of the concrete as it is spread across the top of the dam and keep track of the elevation. Photo credit: Denver Water.

Work won’t completely stop over the winter.

Mechanical and pipe work will be done inside the dam, and crews will build a stilling basin at the base of the dam. The basin’s function is to slow the speed of water coming down the dam’s spillway and safely redirect the water into South Boulder Creek.

Work on the stilling basin at the base of the dam will continue over the winter. The stilling basin is designed to slow the flow of water coming down the spillway and channel it into the creek. Photo credit: Denver Water.

“This season was a huge success, and our team met a ton of challenges in raising Gross Dam,” Martin said. “We had legal challenges and adverse weather challenges. We also had wildfire safety operation challenges that shut down our power supply up here. Despite all those setbacks, the dedicated team of 500 men and women rose to the challenge. I’d just like to thank everybody who committed themselves to this project and helped us make 2025 a success.”

Jeff Martin, Denver Water’s program manager for the Gross Reservoir Expansion Project, stands at the south side of the dam. Once completed, the dam will reach up to white line on the rock wall. Photo credit: Denver Water.

How #wind and #solar power help keep America’s farms alive — Paul Mwebaze (TheConversation.com)

About 60% of Iowa’s power comes from wind. Farmers can earn extra cash by leasing small sections of farms for power production. Bill Clark/Getty Images

Paul Mwebaze, University of Illinois at Urbana-Champaign

Drive through the plains of Iowa or Kansas and you’ll see more than rows of corn, wheat and soybeans. You’ll also see towering wind turbines spinning above fields and solar panels shining in the sun on barns and machine sheds.

For many farmers, these are lifelines. Renewable energy provides steady income and affordable power, helping farms stay viable when crop prices fall or drought strikes.

But some of that opportunity is now at risk as the Trump administration cuts federal support for renewable energy.

Wind power brings steady income for farms

Wind energy is a significant economic driver in rural America. In Iowa, for example, over 60% of the state’s electricity came from wind energy in 2024, and the state is a hub for wind turbine manufacturing and maintenance jobs.

For landowners, wind turbines often mean stable lease payments. Those historically were around US$3,000 to $5,000 per turbine per year, with some modern agreements $5,000 to $10,000 annually, secured through 20- to 30-year contracts.

Nationwide, wind and solar projects contribute about $3.5 billion annually in combined lease payments and state and local taxes, more than a third of it going directly to rural landowners.

A U.S. map shows the strongest wind power potential in the central U.S., particularly the Great Plains and Midwestern states.
States throughout the Great Plains and Midwest, from Texas to Montana to Ohio, have the strongest onshore winds and onshore wind power potential. These are also in the heart of U.S. farm country. The map shows wind speeds at 100 meters (nearly 330 feet), about the height of a typical land-based wind turbine. NREL

These figures are backed by long-term contracts and multibillion‑dollar annual contributions, reinforcing the economic value that turbines bring to rural landowners and communities.

Wind farms also contribute to local tax revenues that help fund rural schools, roads and emergency services. In counties across Texas, wind energy has become one of the most significant contributors to local property tax bases, stabilizing community budgets and helping pay for public services as agricultural commodity revenues fluctuate.

In Oldham County in northwest Texas, for example, clean energy projects provided 22% of total county revenues in 2021. In several other rural counties, wind farms rank among the top 10 property taxpayers, contributing between 38% and 69% of tax revenue.

The construction and operation of these projects also bring local jobs in trucking, concrete work and electrical services, boosting small-town businesses.

A worker wearing a hardhat stands on top of a wind turbine, with a wide view of the landscape around him.
A wind turbine technician stands on the nacelle, which houses the gear box and generator of a wind turbine, on the campus of Mesalands Community College in Tucumcari, N.M., in 2024. Colleges in other states, including Texas, also developed training programs for technicians in recent years as jobs in the industry boomed. Andrew Marszal/AFP via Getty Images

The U.S. wind industry supports over 300,000 U.S. jobs across construction, manufacturing, operations and other roles connected to the industry, according to the American Clean Power Association.

Renewable energy has been widely expected to continue to grow along with rising energy demand. In 2024, 93% of all new electricity generating capacity was wind, solar or energy storage, and the U.S. Energy Information Administration expected a similar percentage in 2025 as of June.

Solar can cut power costs on the farm

Solar energy is also boosting farm finances. Farmers use rooftop panels on barns and ground-mounted systems to power irrigation pumps, grain dryers and cold storage facilities, cutting their power costs.

Some farmers have adopted agrivoltaics – dual-use systems that grow crops beneath solar panels. The panels provide shade, helping conserve water, while creating a second income path. These projects often cultivate pollinator-friendly plants, vegetables such as lettuce and spinach, or even grasses for grazing sheep, making the land productive for both food and energy.

Federal grants and tax credits that were significantly expanded under the 2022 Inflation Reduction Act helped make the upfront costs of solar installations affordable.

A farmer looks at the camera with cows around him and a large red bar with solar panels on the roof behind him. The photos was taken at the Milkhouse Dairy in Monmouth, Maine, on Oct. 3, 2019.
Solar panels can help cut energy costs for farm operations like dairies. Shawn Patrick Ouellette/Portland Press Herald via Getty Images

However, the federal spending bill signed by President Donald Trump on July 4, 2025, rolled back many clean energy incentives. It phases down tax credits for distributed solar projects, particularly those under 1 megawatt, which include many farm‑scale installations, and sunsets them entirely by 2028. It also eliminates bonus credits that previously supported rural and low‑income areas.

Without these credits, the upfront cost of solar power could be out of reach for some farmers, leaving them paying higher energy costs. At a 2024 conference organized by the Institute of Sustainability, Energy and Environment at the University of Illinois Urbana-Champaign, where I work as a research economist, farmers emphasized the importance of tax credits and other economic incentives to offset the upfront cost of solar power systems.

What’s being lost

The cuts to federal incentives include terminating the Production Tax Credit for new projects placed in service after Dec. 31, 2027, unless construction begins by July 4, 2026, and is completed within a tight time frame. The tax credit pays eligible wind and solar facilities approximately 2.75 cents per kilowatt-hour over 10 years, effectively lowering the cost of renewable energy generation. Ending that tax credit will likely increase the cost of production, potentially leading to higher electricity prices for consumers and fewer new projects coming online.

The changes also accelerate the phase‑out of wind power tax credits. Projects must now begin construction by July 4, 2026, or be in service before the end of 2027 to qualify for any credit.

Meanwhile, the Investment Tax Credit, which covers 30% of installed cost for solar and other renewables, faces similar limits: Projects must begin by July 4, 2026, and be completed by the end of 2027 to claim the credits. The bill also cuts bonuses for domestic components and installations in rural or low‑income locations. These adjustments could slow new renewable energy development, particularly smaller projects that directly benefit rural communities.

While many existing clean energy agreements will remain in place for now, the rollback of federal incentives threatens future projects and could limit new income streams. It also affects manufacturing and jobs in those industries, which some rural communities rely on.

Renewable energy also powers rural economies

Renewable energy benefits entire communities, not just individual farmers.

Wind and solar projects contribute millions of dollars in tax revenue. For example, in Howard County, Iowa, wind turbines generated $2.7 million in property tax revenue in 2024, accounting for 14.5% of the county’s total budget and helping fund rural schools, public safety and road improvements.

In some rural counties, clean energy is the largest new source of economic activity, helping stabilize local economies otherwise reliant on agriculture’s unpredictable income streams. These projects also support rural manufacturing – such as Iowa turbine blade factories like TPI Composites, which just reopened its plant in Newton, and Siemens Gamesa in Fort Madison, which supply blades for GE and Siemens turbines. The tax benefits in the 2022 Inflation Reduction Act helped boost those industries – and the jobs and local tax revenue they bring in.

On the solar side, rural companies like APA Solar Racking, based in Ohio, manufacture steel racking systems for utility-scale solar farms across the Midwest. https://www.youtube.com/embed/Bcet_aaaMq8?wmode=transparent&start=0 An example of how renewable energy has helped boost farm incomes and keep farmers on their land.

As rural America faces economic uncertainty and climate pressures, I believe homegrown renewable energy offers a practical path forward. Wind and solar aren’t just fueling the grid; they’re helping keep farms and rural towns alive.

Paul Mwebaze, Research Economist at the Institute for Sustainability, Energy and Environment, University of Illinois at Urbana-Champaign

This article is republished from The Conversation under a Creative Commons license. Read the original article.

#ColoradoRiver Continues to Bring Unlikely Parties Together at the Colorado River Water Users Association — Daniel Anderson (Getches-Wilkinson Center) #CRWUA2025 #COriver #aridifcation

Image by Lex Padilla

Click the link to read the article on the Getches-Wilkinson Center website (Daniel Anderson):

December 29, 2025

The Colorado River Water Users Association annual conference met in Las Vegas [December 16-18, 2025]. Each year, over a thousand government officials, members of the press, municipal water district leaders, water engineers, ranchers, and tribal members meet to discuss the management of the mighty Colorado River. Hanging over the three-day conference was a stalemate between the upper and lower basin states over how to manage the Colorado River after current operational guidelines expire at the end of 2026.

Throughout the conference, the states’ inability to reach a consensus deal produced ripple effects. The stalemate held back progress on both near term shortage concerns (experts predict that Lake Powell will be only 28% full at the end of the ’25-’26 water year) and long-range planning, such as the development of the next “Minute” agreement between the United States and Mexico.

The closing act of CRWUA 2025 was an orderly (and familiar) report from each of the basin states’ principal negotiators that their state is stretched thin but remains committed to finding a consensus agreement. This final session had no discussion or Q&A. The basin states now have until February 14th to provide the Bureau of Reclamation with their consensus deal, which would presumably be added to an Environmental Impact Statement (EIS) draft that is expected to be released in early January. With time running short, many worry that public participation in the EIS process – vital to informed decision-making – will be greatly reduced.

Still, as Rhett Larson of Arizona State University said on the first day of the conference, “Desert rivers bring people together.” Tribal governments continue to innovate in the areas of conservation and storage, even in spite of ongoing challenges to meaningful access of federally reserved tribal water rights. For instance, the Colorado River Indian Tribes, or CRIT, shared news of a Resolution and Water Code recently passed by their Tribal Council which work together to recognize the Colorado River’s personhood under Tribal law. This provides CRIT with a holistic framework for on-reservation use and requires the consideration of the living nature of the Colorado River in off-reservation water leasing decisions. John Bezdek, who represented CRIT at the conference, put it this way: “If laws are an expression of values, then this tribal council is expressing to the world the importance of protecting and preserving the lifeblood of the Colorado River.” Among others, Celene Hawkins of The Nature Conservancy and Kate Ryan of the Colorado Water Trust also shared about the unique, and often unlikely, partnerships formed to protect stream flows and the riparian environment across the Colorado River basin.

Notwithstanding the basin states’ current deadlock, one theme rang true at CRWUA 2025: Despite the dire hydrologic and administrative realities facing decision-makers today, the Colorado River continues to bring unlikely parties together.

Map credit: AGU

With stakes sky high, 3 takeaways from this year’s #ColoradoRiver conference — The Las Vegas Review-Journal #CRWUA2025 #COriver #aridification

Left to right: Becky Mitchell, Tom Buschatzke, Brandon Gebhart, John Entsminger, Keith Burron, Gene Shawcroft, JB Hamby, Estevan López. Photo credit: Yes To Tap via X (Twitter)

Click the link to read the article on the Las Vegas Review-Journal website (Alan Halaly). Here’s an excerpt:

December 19, 2025

The single most important gathering of Colorado River Basin officials came and went — with no significant announcements regarding the often frustrating yet crucial seven-state negotiations for how to divvy up the river over the next 20 years…Here are three takeaways as the states wrestle with basinwide overuse of water, declining river flows due to a warming world and how to meet the federal government’s Valentine’s Day deadline for a consensus-based deal.

States far from deal — with less than 60 days left

Unlike last year’s conference, the seven states agreed to sit on a panel that was added to the agenda for the last day. The ballroom was still packed for the early morning session. That’s because the stakes are high for states to meet Burgum’s Feb. 14 deadline for a seven-state agreement. Should they not deliver one, Burgum could intervene and states are likely to sue. The Lower Basin states have agreed to shoulder the brunt of a massive deficit the system faces that totals 1.5 million acre-feet, or almost 489 billion gallons. However, the Upper Basin states of Colorado, Utah, New Mexico and Wyoming say they don’t have more water to give should cuts in their jurisdictions become necessary. Conflicts exist with state laws, too…

Temporary deal could be on the table to avoid courtroom

Nevada’s governor-appointed negotiator, John Entsminger, spoke last on the panel and called out the other six states for failing to cede any ground on further conservation in their remarks. Without some compromise from each state on these long-standing arguments, the negotiations are “going nowhere,” he said. While the states have been expected up until this point to deliver a 20-year deal, Entsminger suggested on the panel that a temporary, five-year deal could be on the table to comply with the Feb. 14 deadline.

Udall/Overpeck 4-panel Figure Colorado River temperature/precipitation/natural flows with trend. Lake Mead and Lake Powell storage. Updated through Water Year 2025. Note the tiny points on the annual data so that you can flyspeck the individual years. Credit: Brad Udall

Poor outlook sending shockwaves throughout basin

The underlying issues of the Colorado River are making this moment much more precarious. Several experts presented a dismal picture for the system at large. Carly Jerla, senior water resource program manager at the Bureau of Reclamation, said the agency’s most recent projections place flows into Lake Powell anywhere between 44 percent to 73 percent of average this upcoming year. And since 2006, that replenishment of the reservoir has declined about 15 percent because of poor snow years, evaporative losses and more…

The back of Glen Canyon Dam circa 1964, not long after the reservoir had begun filling up. Here the water level is above dead pool, meaning water can be released via the river outlets, but it is below minimum power pool, so water cannot yet enter the penstocks to generate electricity. Bureau of Reclamation photo. Annotations: Jonathan P. Thompson

Jack Schmidt, who leads the Center for Colorado River Studies at Utah State University, has published several papers this year alongside a group of experts throughout the basin. By his estimation, should snowpack in the Rocky Mountains fail to impress again this winter, water managers may be blowing through a crucial buffer that ensures water can be released from Lake Powell into Lake Mead — and that hydropower generation can continue.

Map of the Colorado River drainage basin, created using USGS data. By Shannon1 Creative Commons Attribution-Share Alike 4.0

New report outlines the crisis on the #ColoradoRiver and the ongoing threats: Analysis comes out as water users meet in Las Vegas — The Deseret News #CRWUA2025 #COriver #aridification

A wall bleached, and stained, in Lake Powell. Photo credit Brent Gardner-Smith @AspenJournalism.

Click the link to read the article on The Deseret News website (Amy Joi O’Donoghue). Here’s an excerpt:

December 16, 2025

A new report from Colorado Law’s Colorado River Research Group warns the Colorado River Basin is “out of time,” describing conditions so severe they threaten the region’s water supply, economy and governance. Called “Colorado River Insights 2025: Dancing with Deadpool,” the report details a dire assessment of the basin’s worsening crisis and offers options for reform. According to the report, reservoirs that once stored four years of river flows are now more than two-thirds empty. The authors note a single dry year or two could push Lake Powell and Lake Mead below critical thresholds, jeopardizing hydropower, water deliveries, and even physical conveyance downstream. The report concludes that current operating rules through 2026 are unlikely to prevent this scenario. 

“This report underscores that the basin is out of time, the crisis is no longer theoretical,” said Douglas Kenney, director of the Western Water Policy Program of the Getches-Wilkinson Center at the University of Colorado Law School and chair of the Colorado River Research Group.

“Post-2026 negotiations must produce durable, equitable, climate-realistic solutions — and they must do so urgently. The message is stark: the Colorado River system is now dancing with Deadpool.”

Among the key challenges:

  • Severe shortage risk: The authors warn that if the next two winters are dry, combined usable storage in Powell and Mead could fall below 4 million acre-feet — far short of what’s needed for water supply and compact obligations.
  • Climate-driven decline: Rising temperatures, shrinking snowpack efficiency and ocean-atmosphere interactions are reducing runoff and precipitation. 
  • Safety nets collapsing: Groundwater reserves are rapidly depleting, while federal capacity — funding, staffing and science programs — are eroding. Interstate cooperation is fraying, and litigation may be on the table.

Authors stress that many challenges are self-inflicted and, in their view, solvable with technical, legal and financial tools already available.

Colorado River Basin Plumbing. Credit: Lester Doré/Mary Moran via Dustin Mulvaney and Twitter

The Year in Water 2025: The #ColoradoRiver — Brett Walton (circleofblue.org) #COriver #aridification

Click the link to read the article on the Circle of Blue website (Brett Walton):

December 24, 2025

The year is ending with the Colorado River at a critical juncture.

Figure 4. Graph showing active storage in Lake Powell, Lake Mead, and in Powell+Mead between January 1, 2023, and November 30, 2025. Credit: Jack Schmidt/Center for Colorado River Studies

The big reservoirs Mead and Powell remain perilously low and the seven states that share the basin have been unable to agree on cuts that would reduce their reliance on the shrinking river.

Reservoir operating rules expire at the end of 2026. If no agreement is reached the federal government could step in, or the states could take their chances in court. It’s a risky move that no one in principle seems to want. Yet brinkmanship and entrenched positions have stymied compromise.

Native America in the Colorado River Basin. Credit: USBR

The basin’s Indian tribes, which collectively have rights to more than a quarter of its recent average annual flow, are adamant that their interests – and more broadly, the river itself – be protected. “Any progress made in the negotiations to date is merely rationing a reduced supply, not actively managing and augmenting it as a shared resource with strategies and tools that can benefit the entire basin,” the leaders of the Gila River Indian Community wrote on November 12.

The Colorado River Indian Tribes, whose riverside reservation includes lands in Arizona and California, voted in November to extend legal personhood to the river under tribal law.

Map of the Colorado River drainage basin, created using USGS data. By Shannon1 Creative Commons Attribution-Share Alike 4.0

National Park Sites Along #ColoradoRiver Grappling With Declining Water — National Parks Traveler #COriver #aridification

National Park Service officials at Lake Powell (above) and Lake Mead are grappling with declining Colorado River levels/NPS file.

Click the link to read the article on the National Parks Traveler website. Here’s an excerpt:

December 23, 2025

At Lake Mead National Recreation Area in Nevada, “the National Park Service’s focus remains on sustaining boating access and visitor services across the park, including operations at Hemenway Harbor, Callville Bay Marina, Echo Bay, Temple Bar Marina, and South Cove to the extent feasible,” the National Parks Traveler was told.

“As part of that effort, construction began at Hemenway Harbor last summer to extend the launch ramp and help maintain access as conditions change. Lake levels are closely monitored, and NPS operations continue to be adjusted as needed to support safe recreation while protecting park resources,” the Park Service said.

Two years ago Lake Mead officials adopted a plan to “maintain recreational motorboat access in the event water declines to 950 feet.” As of Tuesday, the elevation was 1061.76 feet, according to the U.S. Bureau of Reclamation. At Glen Canyon National Recreation Area, which straddles the Utah-Arizona border, the Park Service has spent more than $100 million in recent years to extend boat ramps and relocate a takeout for river runners coming down the Colorado River through Canyonlands National Park.

“The public is encouraged to make informed decisions before they plan their visit to Lake Powell by viewing lake level data on the Bureau of Reclamation website at 40-Day Data | Water Operations | UC Region | Bureau of Reclamation and projected reservoir levels at 24-Month Study | Upper Colorado Basin | Bureau of Reclamation,” the Park Servicxe said.

Fig. 1. The Colorado River Basin covers parts of seven U.S. states as well as part of Mexico. Credit: U.S. Geological Survey

Feds demand compromise on #ColoradoRiver while states flounder amid water shortage — Jennifer Solis (States Newsroom) #COriver #aridification #CRWUA2025

Colorado River negotiators are seen, from left to right: Becky Mitchell (Colorado), Tom Buschatzke (Arizona), Brandon Gebhart (Wyoming), and John Entsminger (Nevada). (Photo by Jeniffer Solis/Nevada Current)

Click the link to read the article on the States Newsroom website (Jennifer Solis):

December 25, 2025

Western states that rely on the Colorado River have less than two months to agree on how to manage the troubled river – and pressure is mounting as the federal government pushes for a compromise and a troubling forecast for the river’s two biggest reservoirs looms.

Top water officials for the seven Colorado River Basin states — Arizona, California, Nevada, Colorado, New Mexico, Utah, and Wyoming — gathered for the three-day Colorado River Water Users Association conference at Caesars Palace in Las Vegas last week.

Colorado River states have until Feb. 14 to reach a new water sharing agreement before current operating rules expire at the end of 2026 —or the federal government will step in with their own plan.

Despite the fast-approaching deadline, states reiterated many of the same issues they did during previous years at the conference, namely, which water users will need to sacrifice more water to keep the Colorado River stable as overallocation, climate change, and rising demand sucks the river dry.

Nevada’s chief river negotiator and general manager of the Southern Nevada Water Authority John Entsminger offered a succinct but sharp assessment of the negotiations during a panel discussion Thursday.

“If you distill down what my six partners just said, I believe there’s three common things: Here’s all the great things my state has done. Here’s how hard/impossible it is to do any more. And here are all the reasons why other people should have to do more,” Entsminger said.

“As long as we keep polishing those arguments and repeating them to each other, we are going nowhere,” he continued.

The seven states that share the river’s flows have been deadlocked for nearly two years over how to govern the waterway through the coming decades — even as water levels at Lake Mead and Lake Powell are forecasted to reach record lows after two straight years of disappointing snowpack across the West.

The Colorado River’s headwaters saw a weak snowpack last winter, contributing to one of the worst spring runoff seasons on record. Water flow into the river this year was only 56% of average, leading to significant reductions in Lake Powell, according to the Interior Department’s Bureau of Reclamation.

Federal officials also released a troubling forecast of expected flows for the river in 2026, which were significantly lower than previous predictions. Projections from the Bureau of Reclamation found the Colorado River’s inflow next year would likely be 27% lower than normal, with worst-case scenarios predicting even lower flows.

Without a strong winter snow season, it’s possible Lake Powell’s levels could drop low enough to cease hydropower production by next October — a scenario that would also limit the department’s ability to send water downstream to Arizona, California and Nevada.

The federal government has refrained from imposing its own plan for the river, preferring the seven basin states reach consensus themselves. But the Interior Department has ramped up pressure on states to reach a deal.

The Bureau of Reclamation’s Acting Commissioner Scott Cameron said he and other federal officials have intensified efforts to bring states to a consensus, flying out West every other week since early April to meet with the seven states’ river negotiators.

“The expiration of the current agreements is not a distant horizon. It’s less than a year away. The time to act is now,” said Cameron.

Within the next few weeks, the Bureau of Reclamation will release a range of proposals to replace the river’s current operating rules, but said they would not identify which set of operating guidelines the federal government would prefer

During the conference, negotiators for the seven states repeated that they are still committed to finding a consensus despite missing previous deadlines. California’s biggest water districts said they were willing to “set aside many of their legal positions” in order to reach a seven-state agreement.

However, a long-term multidecade strategy for managing low river flows is likely out of reach.

“I went into this process…advocating strenuously for a 20- to 30-year deal,” said Entsminger. “I no longer believe that’s possible with the time we have left and with the hydrology that we’re facing.”

Entsminger said the “best possible outcome at this juncture” is a short-term five-year deal that sets new rules around water releases and storage at Lakes Powell and Mead.

During a panel of state negotiators, states highlighted water conservation efforts they have undertaken to reduce water use and protect the river, but all explained why their state can’t take on more cuts.

Figure 4. Graph showing active storage in Lake Powell, Lake Mead, and in Powell+Mead between January 1, 2023, and November 30, 2025. Credit: Jack Schmidt/Center for Colorado River Studies

“Our savings accounts are totally depleted,” said Utah’s’s river negotiator, Gene Shawcroft. “Reserviours were full when we started this process. They’re empty now.”

One of the biggest disagreements between the Upper and Lower Basin states is over which faction should have to cut back on their water use during dry years.

The Lower Basin – Nevada, Arizona, and California – have agreed to take the first 1.5 million acre-feet in water cuts needed to address deficits and evaporation that are reducing flows in the river, but say any additional cuts during dry years must be shared with upstream states. Under the current agreement, Lower Basin states must take mandetory cuts when water levels in Lakes Powell and Mead are low.

The Upper Basin, which is not subject to mandatory cuts under the current guidelines, say they already use much less water than downstream states and should not face additional cuts during shortages.

Any more cuts to water users in downstream states during dry years will be politically perilous, explained Arizona’s top negotiator, Tom Buschatzke. Arizona requires the state legislature to approve any changes to Colorado River management rules impacting the state.

Buschatzke called for the Upper Basin – Colorado, Wyoming, New Mexico, and Utah – to split any additional water cuts with the Lower Basin states 50-50.

“We need conservation in the Upper Basin that is verifiable and mandatory,” Buschatzke said, during the panel.

“I have to go to my legislature and get that approval,” he continued. “And I will say right now, I do not think there is anything on the table from the Upper Basin that would compel me to do that today.”

New Mexico’s river negotiator, Estevan López, responded, “I think we’ve been pretty clear. We are unwilling to require additional mandatory reductions on our water users.”

This story was originally produced by Nevada Current, which is part of States Newsroom, a nonprofit news network which includes Stateline, and is supported by grants and a coalition of donors as a 501c(3) public charity.

Map of the Colorado River drainage basin, created using USGS data. By Shannon1 Creative Commons Attribution-Share Alike 4.0

#ColoradoRiver Reservoir Storage: Where We Stand — Jack Schmidt, Anne Castle, John Fleck, Eric Kuhn, Kathryn Sorensen, Katherine Tara (Colorado River Research Group) #COriver #aridification #LakeMead #LakePowell

Click the link to read the report from “Dancing with Dead Poll” on the Getches-Wilkinson website (Jack Schmidt1, Anne Castle2, John Fleck3, Eric Kuhn4, Kathryn Sorensen5, Katherine Tara6) Here’s Chapter 1:

In Brief

The rains of mid-October caused significant flooding in the San Juan River basin and increased reservoir storage throughout that basin and in Lake Powell.7 However, basinwide reservoir storage remains low, and the October rainfall offerings were insufficient to alleviate the peril of declining overall water supply.

While the attention of the Basin’s water management community remains focused on the thus far unsuccessful effort to forge a seven-state agreement on future long-term operating rules, the Basin continues to face the risk of short-term crisis. If winter 2025-2026 is relatively dry and inflow to Lake Powell and other Upper Basin reservoirs is similar to that of 2024-2025, low reservoir levels in summer 2026 will challenge water supply management, hydropower production, and environmental river management. Under such a scenario, it is likely that less than 4 million acre feet in Lake Powell and Lake Mead would be realistically available for use during the nine months between late summer 2026 and the onset of snowmelt runoff in 2027. If winter 2026-2027 is also dry, water supply would be further constrained. The present reservoir operating rules that remain in place through 2026 are insufficient to avert this potential water supply crisis. Action to further reduce consumptive water use across the basin is needed now.

How did we get here?

The Basin’s reservoirs were nearly full in late summer 1999,8 acting as a buffer against dry years and serving their fundamental purpose. At that time, the 46 Colorado River Basin reservoirs tracked by the Bureau of Reclamation in its Hydro database held 59.5 million acre feet (maf) in active storage,9 more than four times the Basin’s average consumptive uses and losses in the 1990s (Fig. 1).10 Beginning in 2000, five years of below average runoff11 resulted in a 46% reduction in storage in the Basin’s reservoirs.12 During that time, the reduction in storage in Lake Powell and Lake Mead accounted for 90% of the Basin’s total loss in storage, because most of the Basin’s water was stored in those two reservoirs.

Figure 1. Graph showing active storage in Colorado River basin reservoirs between January 1, 2021, and November 30, 2025. Credit: Jack Schmidt/Center for Colorado River Studies

During the next fourteen and a half years, the amount of storage in the Basin’s reservoirs changed little, despite four years of large runoff (2005, 2011, 2017, and 2019). The increase in storage during the few wet years was nearly completely consumed during the more frequent dry years, and active storage in Powell and Mead was only 5% greater in late July 2019 than it had been at the beginning of 2005.13 When dry years of low runoff returned between 2020 and 2022,14 the Basin’s water users had little of the buffer that they had at the beginning of the 21st century. Combined active storage of Powell and Mead was halved again between mid-July 2019 and mid-March 2023,15 reducing the combined contents of these two reservoirs to only 27% of what it had been in late summer 1999.16 If next winter’s runoff is as low as it was in 2025 17 and consumptive use is not significantly reduced, Powell and Mead will drop below the previous unprecedented low stand of mid-March 2023.

How much of active storage is realistically available?

One of the challenges of the current water supply crisis is uncertainty over how much water is actually available in the reservoirs for use. Although Reclamation regularly reports the amount of water in active storage, our analysis identifies realistically accessible storage as the more appropriate metric of the amount of water that is available for use without challenging the integrity of the dam structures, efficient production of hydroelectricity, or implementation of environmental river management protocols, especially in Grand Canyon.

The back of Glen Canyon Dam circa 1964, not long after the reservoir had begun filling up. Here the water level is above dead pool, meaning water can be released via the river outlets, but it is below minimum power pool, so water cannot yet enter the penstocks to generate electricity. Bureau of Reclamation photo. Annotations: Jonathan P. Thompson

Reservoir water that can be physically released from a dam is termed active storage. In virtually all reservoirs, there is a small amount of water below the elevation of the lowest outlets–the infamously named dead pool. Active storage is everything above dead pool–water that can be physically released through the reservoir’s lowest outlets.

We know, however, that not all the water above dead pool is readily usable. Engineering assessments have indicated that infrastructure constraints at Hoover and Glen Canyon Dams require that higher reservoir elevations be maintained, thereby constraining utilization of the lowest part of the active storage. We defined realistically accessible storage as the volume of water whose release does not impact previously identified engineering or hydropower-production constraints.

At Glen Canyon Dam, for example, the lowest release tubes, called the “river outlets,” are at elevation 3370 ft. Reservoir water below that elevation cannot be released and constitutes the dead pool. Above the river outlets, at elevation 3490 ft, are the intakes for the power generating turbines, known as the penstocks. The penstocks are the conduits that withdraw water from the reservoir into the powerplant to generate electricity, and thereafter discharge the water to the Colorado River downstream from the dam. When the reservoir falls below the elevation of the penstocks, the river outlets are the only means of discharging water through the dam (Fig. 2). The river outlets are not routinely used to release water; virtually all normal releases go through the penstocks.

Experience has shown that the river outlets were not designed for continuous release at the discharge rates required to meet downstream obligations. If the river outlets were to be used continuously, there is significant concern that structural damage to those outlets could occur.18

Accordingly, Reclamation has determined that it will take steps to avoid Lake Powell elevation declining below 3500 ft, considered a safe elevation for continuous withdrawal of water through the penstocks without risk of harm caused by cavitation to the turbines that produce electricity.19 Similarly at Lake Mead, Reclamation has indicated its intent to protect the reservoir from going below elevation 1000 ft.20

Figure 2. Diagram showing schematic of Glen Canyon Dam elevations at which Lake Powell’s waters can be released downstream, and the volumes of water defined by these elevations. Active storage between 3370 and 3500 ft is not realistically accessible for continuous downstream release without risk to engineering infrastructure at the dam and powerplant. Hydroelectricity cannot be produced below 3490 ft, and 3500 ft has been established as a minimum safe level for intake through the penstocks.

The total volume of active storage in Lake Powell above dead pool but below elevation 3500 ft is 4.2 maf. Release of this stored water is constrained, because it cannot be safely withdrawn through the penstocks, and continuous use of the river outlets is considered unwise. At Hoover Dam, there is 4.5 maf of active storage below elevation 1000 ft, also not realistically accessible. In these two largest reservoirs of the Colorado River Basin, there is a total of 8.7 maf of active storage below the elevations required for safe and efficient operation of the infrastructure (Fig. 3). Thus, of the 14.9 maf of active storage at Lake Powell and Lake Mead on November 15, 2025, only 42% of that active storage, 6.2 maf, was realistically accessible.

Figure 4. Graph showing active storage in Lake Powell, Lake Mead, and in Powell+Mead between January 1, 2023, and November 30, 2025. Credit: Jack Schmidt/Center for Colorado River Studies

Implementation of environmental river management protocols at Glen Canyon Dam are constrained when the elevation of Lake Powell is low. Since 1996, controlled floods, administratively termed High Flow Experiments (HFEs), have been conducted at Glen Canyon Dam to rebuild eddy sandbars along the river’s margin and conserve sediment. HFEs are now an essential component of the Long Term Experimental and Management Plan for Glen Canyon Dam.21 Reclamation did not, however, release an HFE in 2021 or 2022 when sediment conditions were sufficient to trigger implementation of the HFE Protocol because Lake Powell was low. In early October of those years, when decisions about implementing HFEs were made, active storage in Lake Powell was 7.3 maf (elevation 3545.3 ft) and 5.8 maf (elevation 3529.4) in 2021 and 2022, respectively. Reclamation cited low storage as the reason not to release those controlled floods.22 Although administrative decisions change with time, it is doubtful that any HFEs would be released if Lake Powell fell below elevation 3500 ft.

Low reservoir levels also impact Reclamation’s ability to control the invasion into Grand Canyon of smallmouth bass, and other warm water reservoir fish species, that dominate the recreational fish community of Lake Powell. These nonnatives are significant predators and competitors of endangered or threatened native fish species and live near the surface of Lake Powell. At moderate and low reservoir elevations, water withdrawn through the penstocks (termed fish entrainment) includes some fish that survive passage through the powerplant turbines and are delivered into the Colorado River downstream from the dam. These fish have the potential to successfully spawn downstream from the dam if river temperatures are relatively warm, such as occurs when Lake Powell is low and water is only released through the penstocks.

This infographic shows how as Lake Powell water levels decline, warm water containing smallmouth bass gets closer to intakes delivering water through the Glen Canyon Dam to the Grand Canyon downstream. Credit: U.S. Geological Survey

Reclamation has implemented a protocol to eliminate the potential of smallmouth bass population establishment in Grand Canyon by releasing some cooler water through the river outlets when the water released through the penstocks is warm. The objective of these Cool Mix releases is to disrupt smallmouth bass spawning downstream from the dam. Water released through the river outlets bypasses the powerplant and does not produce electricity, and Western Area Power Administration (WAPA) must purchase electricity on the open market to replace electricity that the agency contractually committed to provide. WAPA estimated that the cost of replacing contracted electricity was $18.9 million23 and $6.5 million24 during the Cool Mix releases of 2024 and 2025, respectively. The risk of fish entrainment from Lake Powell increases significantly as Lake Powell’s elevation drops, and the need to implement the Cool Mix protocol therefore increases. The risk is minimized if Lake Powell is higher than 3590 ft (10.8 maf active storage) and significantly increases when Lake

Powell is below 3530 ft (5.8 maf active storage).25 When water is no longer withdrawn through the penstocks, the risk of entrainment decreases, because all water passes through the lower elevation river outlets.

What would happen if the coming winter and spring snowmelt is similar to 2024-2025?

In an analysis released in September 2025, we reviewed what might happen in the coming year if runoff is the same as it was last year and Basin consumptive uses and losses are the average of the past four years. We used a simple mass balance approach and estimated the available water supply and consumptive uses and losses, and calculated the difference between the two. The available water supply is the sum of the natural flow of the Colorado River at Lees Ferry plus inflows that occur in the Lower Basin, primarily in Grand Canyon. Consumptive uses and losses are those associated with diversions that support irrigated agriculture, municipal and industrial use, water exported from the Basin by trans-basin diversions, and reservoir evaporation. The difference between supply and use is the net effect on reservoir storage. We then estimated the effect of the Basinwide imbalance between supply and use on the combined realistically accessible storage in Powell and Mead, i.e., above elevations 3500 and 1000 ft in Lake Powell and Lake Mead, respectively.

In the scenario that we considered, we assumed that natural flow at Lees Ferry in the coming year will be 8.5 maf, the same as in Water Year 2025,26 and inflow in the Grand Canyon is 0.8 maf. Thus, we assumed a total supply in the coming water year of 9.3 maf. We analyzed a scenario wherein consumptive uses and losses in the United States portion of the Colorado River would be the average of the most recent four years (2021-2024), namely 11.5 maf,27 and we assumed that 1.4 maf would be delivered to Mexico.

The gap between supply and use under this scenario is 3.6 maf, which would have to be met by additional withdrawals from reservoir storage. Assuming that 75% of this deficit would be withdrawn from Lake Powell and Lake Mead (2.7 maf), then the realistically accessible storage in these two reservoirs would be reduced to 3.5 maf, slightly less than the 21st century low that occurred in mid-March 2023 (Fig. 3). Our analysis of this one realistically low inflow scenario–the coming year’s supply is just like last year’s and consumptive uses and losses are the average of the past four years–is consistent with, but less dire than, Reclamation’s most recent 24-Month Study minimum probable forecast28 for the coming year. That study projects that total storage in Lake Powell and Lake Mead will be drawn down by 3.8 maf during the next year, 2.9 maf from Lake Powell alone. Under Reclamation’s minimum probable projection, the elevation of Lake Powell would drop below 3500 ft in August 2026. All of the remaining realistically accessible storage, 2.5 maf in the scenario modeled by Reclamation, would be in Lake Mead. Under the assumption that the current operating rules remain in effect in 2027, Reclamation’s projection is that the elevation of Lake Powell would stay below elevation 3500 ft through at least July 2027.

Further complicating the situation is that the status and ownership of water in Lake Mead at very low storage levels is unclear. Lake Mead holds (a) water available for allocation in the Lower Division under the prior appropriation system, (b) at least some amount of the water due to Mexico under treaty obligations, and (c) assigned water. Assigned water, commonly known as Intentionally Created Surplus or ICS, is water that can be delivered independent of the Lower Basin’s prior appropriation water allocation system and that is held in Lake Mead by the Secretary of the Interior for the benefit of a specific entity. Assigned water also includes delayed water deliveries held for the benefit of the Republic of Mexico that can be delivered subsequently in amounts in excess of the U.S. treaty obligation to Mexico of 1.5 maf/year. Owners of assigned water have the right to withdraw that water when Lake Mead water levels are above 1025 ft, but entitlement holders in the priority system also have a right to water deliveries, as does Mexico via treaty.

Sketches by Floyd Dominy show the way he’d end the Glen Canyon Dam. From the article “Floyd Dominy built the Glen Canyon Dam, then he sketched its end on a napkin” on the Salt Lake Tribune website.

So long as there is water in Lake Mead adequate to fulfill all required and requested deliveries, no conflict arises. However, as the amount of water in Lake Mead decreases, the potential for a clash increases. International treaty obligations take precedence over deliveries pursuant to the priority system within the U.S., but it is unclear how competing priorities and entitlements will be resolved within the U.S. Holders of higher-priority entitlements would likely contest the Secretary’s authority to reduce their deliveries while withholding assigned water from the priority system. As of the end of 2024, there was approximately 3.5 maf of assigned water in Lake Mead, almost the same as the amount of realistically accessible water in storage above elevation 1000 ft. If Lake Powell ever became a “run of the river” facility, the potential for conflict over access to water in Lake Mead would also increase.

Implications

We are not weather forecasters and have no crystal ball that reveals the coming winter snowpack. We are not predicting that our assumptions about the gap between supply and use/losses and the resulting drawdown of Lake Powell and Lake Mead will inevitably occur. Our scenario is merely one of many possibilities, but our assumptions are sufficiently realistic to serve as a warning of how close the Basin is to a true water crisis. Our results should serve as a call to action. We need to adopt additional and immediate measures across the Basin to reduce water consumption even further during the next year, well before any new guidelines are in place.

Taking steps now to decrease consumptive uses across the Basin will reduce the need to implement draconian measures next summer or in the following years. Every acre foot saved now is an acre foot available for our future selves, slowing the rate of reservoir decline and creating more room for creative Colorado River management solutions. If, on the other hand, we delay reducing water usage and addressing reservoir drawdown, we may find ourselves in more significant distress at the beginning of the Post-2026 guidelines. As we wrote in October, continued reduction in Lake Powell releases also brings the Basin perilously close to the Colorado River Compact “tripwire,” the point at which the ten-year rolling total of water delivered from the Upper Basin to the Lower Basin might trigger litigation asking the U.S. Supreme Court to interpret long avoided ambiguities in rules written a century ago by the drafters of the Colorado River Compact.

We do not presume to make specific recommendations about the steps that should be taken immediately to reduce consumptive use in the Basin. There are many smart and experienced individuals in the Colorado River community whose sole focus is on the mechanics of operating the Colorado River water system and the impacts of operations on their particular constituencies.

We can, however, highlight the available mechanisms for reduction of consumptive use that should be explored for their immediate utility in diminishing the looming jeopardy to the overall system. Such mechanisms include:

    • Releases from federal reservoirs upstream of Lake Powell to stabilize storage in Lake Powell.
      • Such releases would be made pursuant to the Drought Response Operations Agreement or similar successor agreement or pursuant to the Secretary of the Interior’s inherent authority to operate federal water projects. Obviously, such releases do nothing to solve the imbalance between supply and demand and will create additional depletions in the system when these reservoirs are refilled. Such releases can, however, provide a temporary bulwark against exceptionally low levels in Lake Powell.
    • Additional reductions in deliveries from Lake Mead under the Secretary’s Section 5 delivery contracts in the Lower Basin, as authorized by Section II.B.3 of the decree in Arizona v. California, 376 U.S. 340 (1964).
      • By reducing deliveries from Lake Mead, releases from Lake Powell could also be reduced without the risk of causing exceptionally low storage in Lake Mead.
    • Extension of system conservation programs in the Lower Basin, and facilitation of an Upper Basin water conservation program, both funded through compensation from federal or state governments or other water users in the Basin, and requiring specific quantities of saved water.
      • Relying on compensated annual forbearance alone is unsustainable, however, because it is not feasible to pay water users in the long term to forgo the use of water that nature no longer supplies. Permanent reductions in consumptive use are both necessary and also the most productive use of limited funding. In addition, to be effective, changes to state law in some Upper Basin states may be necessary, including recognition of water conservation as a beneficial use for the purpose of avoiding litigation concerning the Colorado River Compact. Finally, authorization for shepherding of saved water to the intended place of storage is essential, including across state borders.
    • Reductions in deliveries to Mexico through negotiation of a new minute.
    • Reductions in consumptive use by federal water projects in the Upper Basin, if allowable pursuant to the Secretary’s authority.
      • It should be noted, however, that in order to benefit the Colorado River system, any such reductions must be recognized at the point of diversion and shepherded to the intended place of storage.

    It is obvious that any long-term agreement for future Colorado River operations among the Basin States should be evaluated based on its immediate ability to reverse the storage declines experienced in recent years and anticipated in the future under similar hydrology. An agreement that does not reliably balance supply with uses and losses is not sustainable. Similarly, any operational alternative proffered by the Department of the Interior must achieve the same objectives. When our reservoir storage is as low as it is now, we have very little buffer to rely on–we simply cannot use more water than nature provides.

    The focus within the Basin and among its principal water users and state negotiators has been on the formulation of the Post-2026 guidelines for operation of the river. But action is necessary now to avoid creating conditions that will doom the next set of operating principles by initiating their implementation when the Basin is in full crisis mode. No governmental administration, state or federal, wants to see the Colorado River system fail on its watch. Negotiators have worked tirelessly to reach agreement, yet have come up short. The hour is late. The Secretary must take decisive action.

    Photo Credit: John Weishei via the Colorado River Research Group

    Footnotes

    1 Director, Center for Colorado River Studies, Utah State University, former Chief, Grand Canyon Monitoring and Research Center.

    2 Senior Fellow, Getches-Wilkinson Center, University of Colorado Law School, former US Commissioner, Upper Colorado River Commission, former Assistant Secretary for Water and Science, US Dept. of the Interior.

    3 Writer in Residence, Utton Transboundary Resources Center, University of New Mexico.

    4 Retired General Manager, Colorado River Water Conservation District.

    5 Kyl Center for Water Policy, Arizona State University, former Director, Phoenix Water Services.

    6 Staff Attorney, Utton Transboundary Resources Center, University of New Mexico.

    7 Between 9 October and 8 November, five reservoirs in the San Juan River basin gained 204,000 af in total storage, especially in Navajo and Vallecito Reservoirs. Between 9 October and 20 October, Lake Powell gained 105,000 af in active storage, and the total contents of Lake Powell and Lake Mead increased by 108,000 af between September 25 and October 27.

    8 Schmidt, J.C., Yackulic, C.B., and Kuhn, E. 2023. The Colorado River water crisis: its origin and the future. WIREs Water 2023;e1672.

    9 Total active storage in the Basin’s 46 reservoirs was at its maximum on 24 August 1999.

    10 Total Basin consumptive uses and losses, including deliveries to Mexico, averaged 14.2 maf/yr between 1990 and 1999.

    11 Average natural flow of the Colorado River at Lees Ferry, estimated by Reclamation, was 9.5 (Water Year, WY) and 9.6 (Calendar Year, CY) maf/ yr between 2000 and 2004. Average natural flow for the preceding ten years (1990-1999) was 15.0 maf/yr (WY, CY). Average natural flow for the entire 21st century between 2000 and 2025 was 12.3 maf/yr (WY, CY).

    12 Total active storage of the Basin’s reservoirs was 32.0 maf on 19 October 2004.

    13 Total active storage in Lake Powell and Lake Mead was 23.0 maf on 1 January 2005 and was 24.2 maf on 28 July 2019, a 5% increase.

    14 Average natural flow at Lees Ferry averaged 9.0 (WY) and 9.2 (CY) maf/yr between 2020 and 2022.

    15 Total active storage in Lake Powell and Lake Mead was 12.7 maf on 14 March 2023, 48% less than it had been on 28 July 2019.

    16 Total active storage in Lake Powell and Lake Mead was 47.7 maf on 19 September 1999.

    17 Reclamation estimates that natural flow at Lees Ferry was 8.5 (WY, CY) maf in 2025.

    18 Bureau of Reclamation, Establishment of Interim Operating Guidance for Glen Canyon Dam during Low Reservoir Levels at Lake Powell (2024).18

    19 Bureau of Reclamation, Supplement to 2007 Colorado River Interim Guidelines for Lower Basin Shortages and the Coordinated Operations of Lake Powell and Lake Mead, Record of Decision (2024) (SEIS ROD).

    20 Id.

    21 U.S. Department of the Interior, Record of Decision for the Glen Canyon Dam Long-Term Experimental and Management Plan, Final Environmental Impact Statement, December 2016.

    22 Salter, G. and 7 co-authors, 2025, Reservoir operational strategies for sustainable sand management in the Colorado River. Water Resources Research 61, e2024WR038315.

    23 Ploussard, Q., Pavičević, M., and Yu, A. 2025. Financial analysis of the smallmouth bass flows implemented at the Glen Canyon Dam during Water Year 2024. Argonne National Laboratory report ANL 25/44, 17 pp.

    24 C. Ellsworth, Western Area Power Administration, pers. commun.

    25 Eppenhimer, D. E., Yackulic, C. B., Bruckerhoff, L. A., Wang, J., Young, K. L., Bestgen, K. R., Mihalevich, B. A., and Schmidt, J. C. 2025. Declining reservoir elevations following a two-decade drought increase water temperatures and non-native fish passage facilitating a downstream invasion. Canadian Journal of Fisheries and Aquatic Sciences 82:1-19.

    26 During the 21st century, natural flow at Lees Ferry was lower than this amount in 2002, 2012, 2018, and 2021, meaning that this is not a worst case scenario.

    27 In 2024, consumptive uses and losses in the Upper and Lower Basins totaled 11.4 maf.

    28 October 2025 24-Month Study Minimum Probable Forecast. For a discussion of why the Minimum Probable forecast has become a more reliable indicator of the future than the Most Probable 24-Month Study, see Awaiting the Colorado River 24-Month Study, Aug. 14, 2025.

    Map of the Colorado River drainage basin, created using USGS data. By Shannon1 Creative Commons Attribution-Share Alike 4.0

    Looking for light in the season of darkness: Plus: Wacky Weather, Data Centers, more.

    Sultan Mountain snow and sky. Jonathan P. Thompson photo.

    Click the link to read the article on The Land Desk website (Jonathan P. Thompson):

    December 19, 2025

    🐐 Things that get my Goat 🐐

    The winter solstice teaches us that we must descend into the darkness before we can return to the light. This solstice season we find ourselves in especially dark times —figuratively speaking.

    We can be fairly certain that the earth’s northern hemisphere will begin tilting back towards the light next week. Yet we can only hope that America will find similar relief from the metaphorical shroud of darkness under which it has fallen.

    As I monitor the news each day, I find myself spiraling past frustration, disdain, and outrage and sinking into a mire of disbelief and despair. That our government is rife with corruption, short-sightedness, greed, and incompetence is outrageous, but neither new nor surprising. What is new is that those traits are now combined with blatant cruelty, wretchedness, moral vacuity, outright bigotry and racism, and a pathological dearth of empathy and compassion. It’s a toxic stew that emanates from the president, is lapped up by his sycophantic and unqualified cabinet — not to mention the tech broligarchs who debase themselves in hopes of holding onto a few more million of their billions of dollars at tax time, or ease the regulatory burden on their hyperscale AI-powering data centers.

    Perhaps most distressing is that the safeguards that once protected the nation from the lunatics or incompetents in power — i.e. the courts, the rule of law, Congress — have themselves been broken down or infected with the same malady of wretchedness.

    If you think I’m exaggerating, just consider the current situation: The U.S. military is blowing up Venezuelan boats — and then striking the wreckage again to kill any survivors — and is threatening to go to war with the country and send American soldiers into harm’s way, simply to distract the nation from Trump’s disastrous policies and his close association with known pedophile, sex-trafficker, and scam artist Jeffrey Epstein. And when Democratic members of Congress — and decorated veterans — tell soldiers they will support them if they refuse to break the law, Trump threatens to court-martial them.

    That’s outrageous and despicable. That Congress and the courts and the American people aren’t rising up en masse in revolt is depressing. And that’s just one example of so, so many like it. Which explains the extra despair during this dark season.

    I’m saying a little pagan prayer that the light will return next year.

    But for now, I’m afraid I have some more darkness to report from the Land Desk beat:

    • Back in 2024, former Mesa County clerk and right-wing conspiracy theorist Tina Peters was convicted by a jury of breaching the security of her office’s own election system in 2021 in a futile attempt to prove election fraud. Trump pardoned her, but it didn’t count because it is a state, not federal, crime, and Gov. Jared Polis wasn’t going to play Trump’s game. That made Trump mad, so, in his usual fashion, he governed by spite and is now planning to dismantle the National Center for Atmospheric Research in Boulder. 
    • This will not only hurt Colorado, but also science and all the people who are affected by climate and weather and the like, which is to say: everybody, this harms us all. Here’s a couple Blue Sky takes from prominent scientists:

    • The U.S. House of Representatives voted yesterday to pass Rep. Lauren Boebert-sponsored legislation that would remove Endangered Species Act protections for gray wolves in the lower 48 states. The bill now goes to the Senate. Congress delisted wolves in the Northern Rockies in 2011, turning management over the states; hunting wolves is no allowed in Montana, Wyoming, and Idaho. This bill could potentially do the same for wolves in California, Colorado, Oregon, Washington, New Mexico, Nevada, and most of Utah.
    • The Bureau of Land Management is going on a bit of a tear when it comes to auctioning off public land leases to oil and gas companies. Just a couple of examples of future sales (June 2026) you can weigh in on:
      • In Utah, the administration is planning on offering 39 parcels covering about 54,000 acres. A bulk of the parcels are located south of the town of Green River, east of the river itself, and adjacent to Tenmile Canyon.
      • And it’s looking to sell 174 oil and gas leases covering more than 160,000 acres in Colorado. They don’t have the maps up for these ones yet, but judging by the descriptions it seems they are scattered across much of the state (but not in southwestern Colorado).
    ⛈️ Wacky Weather Watch⚡️

    Weather is wacky and probably always has been. But this month has got to be one of the weirdest, weather-wise, the West has seen in a while. It’s like the new abnormal on steroids, and it’s hard to deny that much of it has the oily fingerprints of human caused climate change smeared all over it.

    This week, alone, the West has experienced:

    • A succession of atmospheric rivers pounded the Northwest, dropping more than 10 inches of rain in places over a few days and bringing several rivers up to record-high flows and causing widespread flooding. The Skagit River near Mt. Vernon, Washington, jumped from about 13,500 cubic feet per-second on Dec. 4 to 133,000 cfs a week and a day later. The Snohomish River saw even more dramatic increases in flow. 
      The flooding and landslides severely damaged U.S. Hwy 2 through the Cascade Mountains, and it could be closed for months. And anywhere between 200,000 and 500,000 homes and businesses were left without power after the floods, rains, and severe winds toppled utility lines, reminding us once again that extreme weather is a far greater danger to the power grid than shuttering coal plants.
      Atmospheric rivers and big storms aren’t abnormal. But because warm air can hold more moisture, these ones may have been intensified by global heating.
    • The storms came on the heels of the warmest meteorological autumn on record in the Northwest (based on 130 years of record-keeping). The result: Huge dumps, even in the mountains, falls mostly as rain, not snow, meaning the snowpack remains relatively sparse across much of the region.
    • The soggy soil of the Northwest coincided with smoky skies in eastern Colorado.I had thought that I could close out my Watch Duty wildfire-monitoring tab for the season, but I had to bring it back up on Wednesday night as wicked winds combined with dry conditions and warm temperatures to whip up a trio of grass fires in Yuma County, Colorado, with another one flaring up along the Colorado-Wyoming line. All fires were contained, but they brought back memories of the 2021 Marshall Fire, which broke out in similar conditions at the end of December.
    • The fires followed a nine-day warm streak on the Front Range, when the mercury in Denver topped out at 60° F or above, including reaching a daily record high of 71° on Dec. 17. The rest of the state was also abnormally warm (after a seasonably chilly beginning to the month).
    • Expect the same to continue into the New Year. While Utah and western Colorado may get some precipitation, it’s likely to be either rain or sloppy snow — i.e. Schneeregen — due to unseasonably high predicted temperatures.

    Most ski areas in the Interior West are open now, but that doesn’t mean the conditions are good. To the contrary, they’re generally lousy almost everywhere, with snowpack levels hovering around 50% of “normal” everywhere from Utah’s Wasatch Range to Vail to Wolf Creek in southwestern Colorado. In most of those places the story of the season is the same: It started off with heavy rainfall, followed by a succession of decent snow storms that offered false hope, only to be dashed by a run of warm snow-melting temperatures.  So far the story’s even more extreme in the Sierra Nevada, where the mountains are utterly devoid of snow, despite massive, flood-inducing rains this fall. The following graphics from the Wolf Creek Pass SNOTEL station tell the story of most of the region:

    The water year started with a deluge and flooding on the San Juan River through Pagosa. While precipitation leveled off after that, accumulations remain above normal and significantly higher than on this date last year.
    The problem: All of that water fell as, well, water, not snow, thanks mostly to high temperatures. Note how average daily temperatures have been above the median, sometimes way above it, all water year so far.
    The result: way below “normal” snowpack levels. They are also significantly lower than at this time last year, and last year sucked, to put it bluntly. While all of the rain eased drought conditions and restored some moisture to the soil, the lack of snow does not bode well for spring runoff — or the reservoirs and water users that depend on it.
    🤖 Data Center Watch 👾

    The backlash to the Big Data Center Buildup is gaining steam, and the resistance to the energy- and water-guzzling server farms is scoring a few victories and suffering defeats.

    • Earlier this month, Chandler, Arizona’s city council voted to reject Active Infrastructure’s proposed rezoning request that would have cleared the way for the developer to raze an existing building and replace it with an AI data center complex. The denial followed widespread opposition from residents, and in spite of lobbying by former Sen. Kyrsten Sinema in favor of the facility and the developer’s pledge to use closed-loop cooling, which consumes less water (but more energy) than conventional cooling systems.
    • Opposition to a proposed data center in Page, Arizona, was dealt a blow when a referendum to block a land sale for the facility was rejected because the petition didn’t meet legal requirements. Beth Henshaw has more on the Page proposal over at the Corner Post, a cool nonprofit covering the Colorado Plateau.
    • Pima County, Arizona’s supervisors approved an agreement with Beale Infrastructure advancing its proposed Project Blue data center. The developer is pledging to match 100% of its energy consumption with renewable sources and to use a less water-intensive closed-loop cooling system. Opposition to the facility has been fierce.
    🌞 Good News! 😎

    These days we hear a lot about how utility-scale wind and solar developments harm the flora and fauna of the desert. But one solar installation near Phoenix is providing sanctuary for wildlife, as reported by Carrie Klein in Audubon recently. Wild at Heart, a raptor rehabilitation center, rescued a bunch of burrowing owls from a housing development construction site. But instead of returning them to the wild (which is becoming more and more scarce in Arizona), they set them up in plastic tunnels they built amid a 10,000-acre solar installation. The owls are not only surviving, but are thriving and successfully reproducing. Finally, a bit of light! 

    📸 Parting Shot 🎞️

    Moon and tree, Bryce Canyon National Park. Jonathan P. Thompson photo.