One consistent challenge of CSP plants is hydrogen buildup, which can be costly to mitigate and reduces plant efficiency, so NREL has partnered with Acciona Solar Power to develop a systemic mitigation process that permanently controls hydrogen in receivers.
Courtesy of NREL
By far, the most common type of CSP plant is based on a parabolic trough design, where heat absorber tubes run along curved concentrating mirrors to absorb the sun's energy. During operation, the organic-based fluid that delivers heat from the parabolic trough receivers to the electricity-generating steam turbine undergoes a small but constant thermal breakdown. While miniscule, the resulting hydrogen off-gassing has a severe impact - causing thermal losses that can decrease overall plant efficiency and revenue by 15 percent. With more than 80 CSP parabolic trough plants operating worldwide, that adds up to an estimated 750 megawatts of lost generation capacity and about $250 million dollars in lost revenue annually. Inevitably, all CSP parabolic trough plants will suffer from hydrogen buildup.
For years, several promising solutions either failed in testing or provided only a five- to seven-year fix, which is insufficient for CSP plants with a useful lifespan of at least 30 years. Replacing individual receivers once their efficiency has degraded was an option that proved too expensive. Hydrogen was the invisible culprit in this problem, and it was hiding in plain sight.
NREL Senior Scientist Greg Glatzmaier has spent much of his career trying to find a solution. With support and funding from the Department of Energy's Solar Energy Technology Office, Glatzmaier has partnered with Acciona Solar Power to develop a solution to the problem and thus also to extend or restore original power-plant efficiency and revenue.
“It's always been a priority for me to create something of practical use and value for the technology and the industry” said Mr Glatzmaier.
While searching for a solution, Glatzmaier, along with other researchers, drove up and down the collector rows at CSP power plants in the Mojave Desert, taking infrared images of the receivers to monitor the temperature of glass sleeves that enclose the tubes that transport heated fluid. Receivers were designed to operate with a glass surface temperature of 140°F. The infrared images, however, measured some receivers with glass surface temperatures of 284°F to 320°F. Somehow the insulating value of the glass sleeves had been compromised, and heat loss was occurring.
Researchers understood that heat-transfer fluids can off-gas hydrogen, hydrogen can leak through steel tubes, and hydrogen is a good conductor of heat. All three conditions were present in the receiver, and the unexpectedly high glass surface temperatures provided the first clue. Researchers identified the cause of the heat loss, but identifying the hydrogen buildup problem proved to be much simpler than devising a solution to remove it.
Glatzmaier was a keen observer with an operator's knowledge of how CSP plants work. As he considered different solution scenarios, he realized that if the hydrogen was going to be removed, it had to be done at a single location. Being familiar with how the plant was laid out, how it functioned, and how the heat-transfer fluid circulated, he considered which components would see all the heat-transfer fluid that flows through the plant. He focused his attention on the expansion tanks that hold all the heat-transfer fluid that is not in circulation.
With support from the Department of Energy's Solar Energy Technology Office and CSP plant developer Acciona Solar Power, Glatzmaier developed his step-by-step solution during their five-year collaboration. He first built a computational model to determine the hydrogen extraction rate necessary to maintain acceptable concentrations of hydrogen in the circulating heat-transfer fluid. Next, he developed a hydrogen sensor that could make gas-concentration measurements every one to two minutes. Precisely measuring the amount of hydrogen in near real-time was essential, but existing sensors required that samples be sent to a lab for analysis.
The third task was to develop a simple means of extracting hydrogen from the headspace gas in the expansion tanks. A palladium membrane was used to separate out the hydrogen, which was then extracted via vacuum pumps into a catalytic oxidizer to be discharged as water vapor. The final task was to combine hydrogen sensing and extraction and integrate them into a physical prototype that could be used as a model for a CSP-plant-sized module. The prototype was constructed, and laboratory evaluations at NREL demonstrated its ability to successfully solve the hydrogen buildup problem—clearing the way for building and testing an on-site module.
A full-scale integrated hydrogen sensor/separator module was designed and implemented at Acciona's Nevada Solar One CSP plant. Ongoing evaluations indicate that it is successfully operating as designed. But the module goes well beyond preventing future efficiency loss in new receivers—it gradually cleans existing contaminated receivers by pulling the hydrogen back out of the glass sleeves and restores them to their original operating efficiency.
At Nevada Solar One, the $500,000 investment was paid back in just two months. When compared to the nearly $20 million cost of replacing the degraded solar receivers over the field's lifetime, the integrated hydrogen sensor/separator module is not just a bargain - it is a game changer. As a bonus, the installation can be performed without any costly interruptions to the plant's generating capacity, increasing the technology's attractiveness to cost-conscious plant operators.
The integrated hydrogen sensor/separator module is an excellent example of technology transfer from NREL to industry. Ensuring the lessons learned at Nevada Solar One have broader benefit, NREL is now exploring opportunities to install integrated hydrogen sensor and separator modules at other CSP plants.