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storage unnecessarily simultaneously charging/discharging? - Small NE OneZone Multistage, 30, 60, 90% RPS for periods 1, 2 & 3 respectively, no CarbonCap #547
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@AlejandroGNE It's probably a parameterization issue. Here is a paper explaining more about this effect by me et al. 2023, "Reducing energy system model distortions from unintended storage cycling through variable costs" https://www.sciencedirect.com/science/article/pii/S2589004222020028 One quick fix to avoid this: set variable costs of all generators (also solar and wind) to a minimum of 0.1$/MWh. Won't change significantly the final investment decision but removes this weird operational behaviour. Generally I recommend: apply realistic variable costs with a minimum of 0.1$/MWh per operating asset (the value worked out good in my cases. But I know it's solver tolerance dependent and likely also solver and model dependent -- haven't checked) |
"Dios te lo pague con muchos hijos" i.e., thank you so much in "mexican" -I will try it out! |
Following your findings I had to iterate up to $100/MWh VOM for this very simple example model to finally get rid of unintended storage cycling. I will use these insights when I get to a more accurate model beyond these simple tests, hopefully then I can find the sweet spot for VOM values that don't really affect the model outcomes, as in this case I confirm your findings: more wind, less solar. Didn't look at other results -but can imagine. It's interesting, evaluating high VRE grids kind of forces you to consider a minimal level of accuracy because of this! Thanks for the tip, @pz-max Max! |
@AlejandroGNE , to which components did you add the VOM? $100/MWh sounds a lot. |
@AlejandroGNE can you please check the price time series during the periods when simultaneous charging and discharging is occuring? This should only be happening when prices are <$0/MWh. At those periods, it is actually rational to consume more electricity -- that is what the negative price is telling you -- and thus storage can make money by losing energy. Think of it as basically acting as a price elastic demand. Prices can be negative due to production subsidies (e.g. for renewables) or to avoid thermal power plant cycling costs (unit commitment decisions). @pz-max has a viable suggestion if you want to minimize this behavior to set variable costs to storage to some reasonable value. But this may also not be a totally unrealistic behavior. We do ensure that the sum of charging and discharging capacity can't exceed the actual power capacity of the storage devices as well. |
Another reason why this is happening your case @AlejandroGNE is to help the solar & wind generate more MWh to meet the RPS requirement. I assume you have specified the RPS as a % of total demand here. We have built the Energy Share Requirement policy constraint to allow you to include storage losses in the RPS calculation, which would penalize this activity as well. |
We observed unintended storage cycling for prices <$0/MWh, =$0/MWh and >$0/MWh. Case prices <$0/MWh. As Jesse mentioned, it might make sense to dissipate the electricity in the energy storage. However, it would only make sense if electricity dissipation in energy storage is more realistic than just stopping the operation of wind turbines/ PV panels. Case prices =$0/MWh. A convex problem has at least one optimal solution, but when not uniquely defined, it can also have multiple optima. When you set the VOM of every RES and storage asset to $0/MWh, and you have times with surplus wind and solar electricity, it is indifferent to the model to curtail RES, or operate the RES and simultaneously dissipate the electricity in the storage. Case prices >$0/MWh. I think this is what Kittel et al. observed. When you define a RES constraint e.g. min 50% solar generation on average of total load, then USC can also appear with prices >$0/MWh because it can save investment costs by dissipating energy in the storage while artificially increasing the RES share (USC increases FLH of RES and FLH of energy storage). |
this is the final set of parameters that produces the second plot:
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under negative prices
under RPS policy
two things come to mind:
*So, cycling storage is not a realistic way to dissipate energy nor to add renewable energy to your RPS, and you want to get rid of it. * |
FYI, this is how capacities compare between original outcome and the parameters that get rid of storage cycling: Capacity in last period (MW):
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I get these odd storage operation profiles when modeling 90% RPS in the example case. I don't get why would storage want to simultaneously charge and discharge, and lose energy in the process, rather than charging just enough to cover the relevant discharges, specially considering this small example case is copperplate. Any ideas? Thanks!
For easy replication, you can see a summary of the changes in this commit: 9eae852
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