Most Afghans still without power

By Associated Press


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The goal is to transform Afghanistan into a modern nation, fueled by a U.S.-led effort pouring $60 billion into bringing electricity, clean water, jobs, roads and education to this crippled country.

But the results so far — or lack of them — threaten to do more harm than good.

The reconstruction efforts have stalled and stumbled at many turns since the U.S. military arrived in 2001, undermining President Barack Obama's vow to deliver a safer, stable Afghanistan capable of stamping out the insurgency and keeping al-Qaida from re-establishing its bases here.

Poppy fields thrive, with each harvest of illegal opium fattening the bankrolls of terrorists and drug barons. Passable roads remain scarce and unprotected, isolating millions of Afghans who remain cut off from jobs and education. Electricity flows to only a fraction of the country's 29 million people.

Case in point: a $100 million diesel-fueled power plant that was supposed to be built swiftly to deliver electricity to more than 500,000 residents of Kabul, the country's largest city. The plant's costs tripled to $305 million as construction lagged a year behind schedule, and now it often sits idle because the Afghans were able to import cheaper power from a neighboring country before the plant came online.

What went wrong?

The failures of the power plant project are, in many ways, the failures of often ill-conceived efforts to modernize Afghanistan:

The Afghans fell back into bad habits that favored short-term, political decisions over wiser, long-term solutions. The U.S. wasted money and might by deferring to the looming deadline and seeming desirability of Afghan President Hamid Karzai's re-election efforts. And a U.S. contractor benefited from a development program that essentially gives vendors a blank check, allowing them to reap millions of dollars in additional profits with no consequences for mistakes.

Rebuilding Afghanistan is an international effort, but the U.S. alone has committed $51 billion to the project since 2001, and plans to raise the stakes to $71 billion over the next year — more than it has spent on reconstruction in Iraq since 2003.

Roughly half the money is going to bolster the Afghan army and police, with the rest earmarked for shoring up the country's crumbling infrastructure and inadequate social services.

There have been reconstruction successes, such as rebuilding a national highway loop left crumbling after decades of war, constructing or improving thousands of schools, and creating a network of health clinics.

But the number of Afghans with access to electricity has only inched up from 6 percent in 2001 to an estimated 10 percent now, well short of the development goal to provide power to 65 percent of urban and 25 percent of rural households by the end of this year.

Too many major projects are not delivering what was promised to the people, and rapidly dumping billions of reconstruction dollars into such an impoverished country is in some ways making matters worse, not better, Afghan Finance Minister Omar Zakhilwal says.

The U.S and its partners have wasted billions of dollars and spent billions more without consulting Afghan officials, Zakhilwal says.

All of that has ramped up corruption, undermined efforts to build a viable Afghan government, stripped communities of self-reliance by handing out cash instead of real jobs, and delivered projects like the diesel plant that the country can't afford, he says.

"The indicator of success in Afghanistan has been the wrong indicator... it has been spending," Zakhilwal says. "It has not been output. It has not been the impact."

That's certainly true when it comes to electricity. Afghanistan consumes less energy per person than any other country in the world, even after years of reconstruction efforts, according to data compiled by the U.S. government.

The $305 million diesel power plant, which has dubbed the most expensive plant of its type in the world, represents the biggest single investment the U.S. has made thus far to light up the country.

In 2007, the U.S. had rushed to build the plant in time to help Karzai win re-election, a hectic and unrealistic timetable embraced by the Afghan president that led to the jarring cost increases.

Complaints had piled up about Karzai's inability to deliver reliable power to Kabul, let alone the rest of the country.

"That question became very loud in many people's mind, and the media and the press, 'They haven't been able to bring power to Kabul,'" says Ahmad Wali Shairzay, Afghanistan's former deputy minister of water and energy.

The U.S. and other international donors had spent years helping Afghanistan develop an energy strategy, one focused on reducing the country's reliance on diesel as a primary power source, since it was too costly and too hard to acquire.

The goal was to buy cheaper electricity from neighboring countries and develop Afghanistan's own natural resources, such as water, natural gas and coal.

All of that was abandoned with the decision by U.S. and Afghan officials to build the diesel plant on the outskirts of Kabul.

Never mind that the plant would make the country more, not less, reliant on its fickle neighbors for power. Never mind that Karzai's former finance minister pleaded with U.S. officials to drop the idea.

The U.S. plowed ahead, turning the project over to a pair of American contractors, including one already scolded for wasting millions in taxpayer dollars on shoddy reconstruction projects. The U.S. team paid $109 million for 18 new diesel engines to be built — more than the original cost of the plant — only to discover rust and corrosion in several of them.

"The Kabul diesel project was sinful," says Mary Louise Vitelli, a U.S. energy consultant who focused on power development in Afghanistan for six years, working with the U.S., the World Bank and as a special adviser to Karzai's government.

James Bever, the U.S. Agency for International Development's director of the Afghanistan-Pakistan task force, says it's unfair to label the project a failure. Even with the problems, he notes, the plant provides Afghanistan with an additional power source.

"You know, there's a formula in this business. You can have it fast, you can have it high quality, and you can have it low cost. But you cannot have all three at the same time," Bever says.

For Afghans, each nightfall is a reminder of promises not kept.

When darkness comes, there is not much Abdul Rahim and others living in southwest Kabul can do. Without lights, they cannot work, and their children cannot play. Rahim's children sometimes sit around a kerosene lamp to do their homework, their books laid flat in a circle around the flame's flickering light.

"The people who are living in this area, they don't have electricity and it is dark everywhere," Rahim says. "Day and night, we are counting the minutes to when we will finally get electricity."

The setbacks stretch far beyond Kabul.

Despite spending millions of dollars over more than six years studying the nation's natural gas fields in the north, no plan is in place to tap that substantial resource for power. And a huge project to expand hydropower in the south that already has cost about $90 million is delayed by continued fighting in the region, which has long been a Taliban stronghold.

Only 497,000 of the country's 4.8 million households are connected to what passes for a national power grid, despite more than $1.6 billion already spent on energy projects, according to data from the country's utility corporation.

The system is more like a disconnected patchwork of pockets of available electricity, serving different regions of the country, some with hydropower, some with power imported from nearby countries and some with diesel-generated power.

So Afghans improvise at home, and many hotels and businesses — even embassies and international agencies — rely on their own generators for power. And some sell electricity to their neighbors.

Take Qurban Ali's old, crank-operated diesel generator, which coughs and belches black smoke before the engine starts running. His generator provides electricity to more than 100 houses in the Dasht-i-barchi neighborhood in Kabul, where Rahim lives.

"Right now, we are hopeless to have electricity," Ali says.

Afghans who can afford it pay private generator owners by the light bulb, about $2.60 a month for each bulb hanging from the ceiling. It costs nearly $11 a month to power a television. The average income in Afghanistan is a little more than a dollar a day.

The diesel plant that was supposed to serve Kabul was not ready to be turned over to the Afghan government until May 2010. Today, it runs mostly only for short periods, producing only a fraction of its promised 100 million watts of power.

"This power plant is too expensive for us to use," says Shojauddin Ziaie, Afghanistan's current deputy minister of water and energy.

U.S. contractor Black & Veatch oversaw the project for USAID as part of a joint $1.4 billion contract with The Louis Berger Group, another American contractor.

As the plant's costs and schedule veered wildly off course, the payouts to Black & Veatch also ballooned.

USAID refused to disclose the amounts paid as costs increased, but contract records obtained by The Associated Press show expenses and fees paid to the company tripled from $15.3 million in July 2007, when the project was estimated at $125.8 million overall, to $46.2 million in October 2009, when the price tag reached $301 million.

Greg Clum, a Black & Veatch vice president, defended the project, calling the plant a "critical piece in our ability to help Afghanistan get its legs under itself and to be able to become a sustainable, growing economic player in the region."

Black & Veatch and The Louis Berger group landed the contract in 2006.

The next year, congressional investigators chastised Berger's work on an earlier contract to build schools and health clinics, accusing the company of poor performance and misrepresenting work.

USAID also found problems with the two companies under their current contract, which an internal assessment found put too much risk on the agency and too little on the contractors, who had no incentive to control spending.

In March 2009, with more than half of the $1.4 billion already committed, the agency said it had "lost confidence" in the companies' abilities to do reconstruction work in Afghanistan. Yet the contract continues, with both the agency and the contractors saying management has improved.

"We had a rough patch," says Larry Walker, president of Louis Berger.

Shairzay, the former deputy energy minister, says Afghans view the diesel plant as a nice, expensive gift.

"Instead of giving me a small car, you give me really a Jaguar," he says. "And it will be up to me whether I use it, or just park it and look at it."

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Key Points

Coal plant load factor in India rose in May on higher demand and weak hydropower, with generation beating targets.

✅ PLF rose to 65.3% as demand climbed

✅ Hydel generation fell 14% YoY on poor rainfall

✅ IPP PLF at 57.8%, below 60% debt comfort

 

Capacity utilisation levels of coal-based power plants improved in May because of a surge in electricity demand and lower generation from hydroelectric sources. The plant load factor (PLF) of thermal power plants went up to 65.3% in the month, 1.7 percentage points higher than the year-ago period.

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#google#

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According to sources, hydropower plants have been generating lesser than expected electricity due to inadequate rainfall and snow melting at a slower pace than previous years, even as the US reported a power generation jump year on year. Data for power generation from renewable sources have not been made available yet.

 

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Key Points

A congressional probe into TVA pricing and practices affecting renewables, energy efficiency, and climate goals.

✅ House panel probes TVA rates, DER and solar policies.

✅ Efficiency programs cut; least-cost planning questioned.

✅ Inquiry on lobbying, hidden fees; FERC scrutiny.

 

The Tennessee Valley Authority is facing federal scrutiny about its electricity rates and climate action, amid ongoing debates over network profits in other markets.

Members of the House Committee on Energy and Commerce are “requesting information” from TVA about its ratepayer bills and “out of concern” that TVA is interfering with the deployment of renewable and distributed energy resources, even as companies such as Tesla explore electricity retail to expand customer options.

“The Committee is concerned that TVA’s business practices are inconsistent with these statutory requirements to the disadvantage of TVA’s ratepayers and the environment,” the committee said in a letter to TVA CEO Jeffrey Lyash.

The four committee members — U.S. Reps. Frank Pallone, Jr. (D-NJ), Bobby L. Rush (D-IL), Diana DeGette (D-CO), and Paul Tonko (D-NY) — suggested that Tennessee Valley residents pay too much for electricity despite TVA’s relatively low rates, even as regulators have, in other cases, scrutinized mergers like the Hydro One-Avista deal to safeguard ratepayers, underscoring similar concerns. In 2020, Tennessee residents had electric bills higher than the national average, while low-income residents in Memphis have historically faced one of the highest energy burdens in the U.S.

In 2018, TVA reduced its wholesale rate while adding a grid access charge on local power companies—and interfered with the adoption of solar energy. Internal TVA documents obtained through a Freedom of Information Act request by the Energy and Policy Institute revealed that TVA permitted local power companies to impose new fees on distributed solar generation to “lessen the potential decrease in TVA load that may occur through the adoption of [behind the meter] generation.”

Additionally, the committee said TVA is not prioritizing energy conservation and efficiency or “least-cost planning” that includes renewables, as seen in oversight such as the OEB's Hydro One rates decision emphasizing cost allocation. TVA reduced its energy efficiency programs by nearly two-thirds between 2014 and 2018 and cut its energy efficiency customer incentive programs.

At this time, TVA has not aligned its long-term planning with the Biden administration’s goal to achieve a carbon-free electricity sector by 2035. TVA’s generation mix, which is roughly 60% carbon-free, comprises 39% nuclear, 19% coal, 26% natural gas, 11% hydro, 3% wind and solar, and 1% energy efficiency programs, according to TVA.

The committee is “greatly concerned that TVA has invested comparatively little to date in deploying solar and wind energy, while at the same time considering investments in new natural gas generation.”

TVA has announced plans to shutter the Kingston and Cumberland coal plants and is evaluating whether to replace this generation with natural gas, which is a fossil fuel, while debates over grid privatization raise questions about consumer benefits. TVA’s coal and natural gas plants represent most of the largest sources of greenhouses emissions in Tennessee.

TVA responded with a statement without directly addressing the committee’s concerns. TVA said its “developing and implementing emerging technologies to drive toward net-zero emissions by 2050.”

The final question that the House committee posed is whether TVA is funding any political activity. In 2019, the committee questioned TVA about its membership to the now-disbanded Utility Air Regulatory Group, a coalition that was involved in over 200 lawsuits that primarily fought Clear Air Act regulations.

TVA revealed that it had contributed $7.3 million to the industry lobbying group since 2001. Since TVA doesn’t have shareholders, customers paid for UARG membership fees, echoing findings that deferred utility costs burden customers in other jurisdictions. An Office of the Inspector General investigation couldn’t prove whether TVA’s contributions directly funded litigation because UARG didn’t have a line-by-line accounting of what they did with TVA’s dollars.

The congressional committee questioned whether TVA is still paying for lobbying or litigation that opposes “public health and welfare regulations.”

This last question follows a recent trend of questioning utilities about “hidden fees.” In December, the Federal Energy Regulatory Commission issued a Notice of Inquiry to examine how bills from investor-owned utilities might contain fees that fund political activity, and regulators have penalized firms like NT Power over customer notice practices, highlighting consumer protection. The Center for Biological Diversity filed a petition to protect electric and gas customers of investor-owned utilities from paying these fees, which may be used for lobbying, campaign-related donations and litigation.

 

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Key Points

Systems that store energy in microgrids to integrate renewables, boost resilience, and optimize distributed power.

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✅ Expands reliable power for remote, grid-constrained regions

 

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One example of microgrid deployment for resilience is the SDG&E microgrid in Ramona built to help communities prepare for peak wildfire season.

According to the report, the most successful companies in this industry will be those that can unlock the potential of new business models to reduce the risk and upfront costs to customers. This is particularly true in Asia Pacific and North America, which are projected to be the largest regional markets for new ESMG capacity by far, a trend underscored by California's push for grid-scale batteries to stabilize the grid.

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Google made energy storage news recently when its parent company Alphabet announced it is hoping to revolutionize renewable energy storage using vats of salt and antifreeze. Alphabet’s secretive research lab, simply named “X,” is developing a system for storing renewable energy that would otherwise be wasted. The project, named “Malta,” is hoping its energy storage systems “has the potential to last longer than lithium-ion batteries and compete on price with new hydroelectric plants and other existing clean energy storage methods, according to X executives and researchers,” reports Bloomberg.

 

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California's Next Electricity Headache Is a Looming Shortage

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Key Points

A CPUC order for utilities to add 3.3 GW of reserves, safeguarding grid reliability during variable renewables and peaks

✅ 3.3 GW procurement to meet resource adequacy targets

✅ Focus on grid reliability during peak evening demand

✅ Prioritizes renewables, storage; limits new fossil builds

 

As if California doesn’t have enough problems with its electric service, now state regulators warn the state may be short on power supplies by 2021 if utilities don’t start lining up new resources now.

In the hopes of heading off a shortfall as America goes electric, the California Public Utilities Commission has ordered the state’s electricity providers to secure 3.3 additional gigawatts of reserve supplies. That’s enough to power roughly 2.5 million homes. Half of it must be in place by 2021 and the rest by August 2023.

The move comes as California is already struggling to accommodate increasingly large amounts of solar power that regularly send electricity prices plunging below zero and force other generators offline so the region’s grid doesn’t overload. The state is also still reeling from a series of deliberate mass blackouts that utilities imposed last month to keep their power lines from sparking wildfires amid strong winds. And its largest power company, PG&E Corp., went bankrupt in January.

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The 3.3 gigawatts that utilities must line up is in addition to a state rule requiring them to sign contracts for 15% more electricity than they expect to need. Some critics question the need for added supplies, particularly after the state went on a plant-building boom in the 2000s.

But California’s grid managers say the risk of a shortfall is real and could be as high as 4.7 gigawatts, especially during heat waves that test the grid again. Mark Rothleder, with the California Independent System Operator, said the 15% cushion is a holdover from the days before big solar and wind farms made the grid more volatile. Now it may need to be increased, he said.

“We’re not in that world anymore,” said Rothleder, the operator’s vice president of state regulatory affairs. “The complexity of the system and the resources we have now are much different.”

The state’s three major utilities, PG&E, Edison International and Sempra Energy, will be largely responsible for securing new supplies. The commission banned fossil fuels from being used at any new power generators built to meet the requirement — though it left the door open for expansions at existing ones.

Some analysts argue California is exporting its energy policies to Western states, making electricity more costly and less reliable.

PG&E said in an emailed statement that it was pleased the commission didn’t adopt an earlier proposal to require 4 gigawatts of additional resources. Edison similarly said it was “supportive.” Sempra didn’t immediately respond with comment.

 

Extending Deadlines

The pending plant closures are being hastened by a 2020 deadline requiring California’s coastal generators to stop using aging seawater-cooling systems. Some gas-fired power plants have said they’ll simply close instead of installing costly new cooling systems. So the commission on Thursday also asked California water regulators to extend the deadline for five plants.

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Key Points

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✅ Joint pledge by AWEA, SEIA, NHA, and ESA for a cleaner grid

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American Wind Energy Association 

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Solar Energy Industries Association

"These principles are just another step toward realizing our vision for a Solar+ Decade," said Abigail Ross Hopper, president and CEO of the Solar Energy Industries Association. "In the face of this dreadful pandemic, our nation must chart a path forward that puts a premium on innovation, jobs recovery and a smarter approach to energy generation, reflecting expected solar and storage growth across the market. The right policies will make a growing American economy fueled by clean energy a reality for all Americans."

National Hydropower Association 

"The path towards an affordable, reliable, carbon-free electricity grid, supported by an ongoing grid overhaul for renewables, starts by harnessing the immense potential of hydropower, wind, solar and storage to work together," said Malcolm Woolf, President and CEO of the National Hydropower Association. "Today, hydropower and pumped storage are force multipliers that provide the grid with the flexibility needed to integrate other renewables onto the grid. By adding new generation onto existing non-powered dams and developing 15 GW of new pumped storage hydropower capacity, we can help accelerate the development of a clean energy electricity grid."

Energy Storage Association 

"We are pleased to join forces with our clean energy friends to substantially reduce carbon emissions by 2030, guided by practical decarbonization strategies, building a more resilient, efficient, sustainable, and affordable grid for generations to come," said ESA CEO Kelly Speakes-Backman. "A majority of generation supplied by renewable energy represents a significant change in the way we operate the grid, and the storage industry is a fundamental asset to provide the flexibility that a more modern, decarbonized grid will require. We look forward to actively collaborating with our colleagues to make this vision a reality by 2030."

 

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Scottish North Sea wind farm to resume construction after Covid-19 stoppage

NnG Offshore Wind Farm restarts construction off Scotland, backed by EDF Renewables and ESB, CfD 2015, 54 turbines, powering 375,000 homes, 500 jobs, delivering GBP 540 million, with Covid-19 safety measures and staggered workforce.

 

Key Points

A 54-turbine Scottish offshore project by EDF Renewables and ESB, resuming to power 375,000 homes and support 500 jobs.

✅ Awarded a CfD in 2015; 54 turbines off Scotland's east coast.

✅ Projected to power 375,000 homes and deliver GBP 540 million locally.

✅ Staggered workforce return with Covid-19 control measures and oversight.

 

Neart Na Gaoithe (NnG) Offshore Wind Farm, owned by  EDF Renewables and Irish firm ESB, stopped construction in March, even as the world's most powerful tidal turbine showcases progress in marine energy.

Project boss Matthias Haag announced last night the 54-turbine wind farm would restart construction this week, as the largest UK offshore wind farm begins supplying power, underscoring sector momentum.

Located off Scotland’s east coast, where wind farms already power millions of homes, it was awarded a Contract for Difference (CfD) in 2015 and will look to generate enough energy to power 375,000 homes.

It is expected to create around 500 jobs, and supply chain growth like GE's new offshore blade factory jobs shows wider industry momentum, while also delivering £540 million to the local economy.

Mr Haag, NnG project director, said the wind farm build would resume with a small, staggered workforce return in line social distancing rules, and with broader energy sector conditions, including Hinkley Point C setbacks that challenge the UK's blueprint.

He added: “Initially, we will only have a few people on site to put in place control measures so the rest of the team can start work safely later that week.

“Once that’s happened we will have a reduced workforce on site, including essential supervisory staff.

“The arrangements we have put in place will be under regular review as we continue to closely monitor Covid-19 and follow the Scottish Government’s guidance.”

NnG wind farm, a 54-turbine projects, was due to begin full offshore construction in June 2020 before the Covid-19 outbreak, at a time when a Scottish tidal project had just demonstrated it could power thousands of homes.

EDF Renewables sold half of the NnG project to Irish firm ESB in November last year, and parent company EDF recently saw the Hinkley C reactor roof lifted into place, highlighting progress alongside renewables.

The first initial payment was understood to be around £50 million.

 

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