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An optimized heat pump control for building heating was developed for minimizing CO 2 emissions from related electrical power generation. The control is using weather and CO 2 emission forecasts as inputs to a Model Predictive Control (MPC)—a multivariate control algorithm using a dynamic process model, constraints and a cost function to be minimized. In a simulation study, the control was applied using weather and power grid conditions during a full-year period in 2017–2018 for the power bidding zone DK2 (East, Denmark). Two scenarios were studied; one with a family house and one with an office building. The buildings were dimensioned based on standards and building codes/regulations. The main results are measured as the CO 2 emission savings relative to a classical thermostatic control. Note that this only measures the gain achieved using the MPC control, that is, the energy flexibility, not the absolute savings. The results show that around 16% of savings could have been achieved during the period in well-insulated new buildings with floor heating. Further, a sensitivity analysis was carried out to evaluate the effect of various building properties, for example, level of insulation and thermal capacity. Danish building codes from 1977 and forward were used as benchmarks for insulation levels. It was shown that both insulation and thermal mass influence the achievable flexibility savings, especially for floor heating. Buildings that comply with building codes later than 1979 could provide flexibility emission savings of around 10%, while buildings that comply with earlier codes provided savings in the range of 0–5% depending on the heating system and thermal mass.

A machine learning algorithm is developed to forecast the CO 2 emission intensities in electrical power grids in the Danish bidding zone DK2, distinguishing between average and marginal emissions. The analysis was done on data set comprised of a large number (473) of explanatory variables such as power production, demand, import, weather conditions etc. collected from selected neighboring zones. The number was reduced to less than 30 using both LASSO (a penalized linear regression analysis) and a forward feature selection algorithm. Three linear regression models that capture different aspects of the data (non-linearities and coupling of variables etc.) were created and combined into a final model using Softmax weighted average. Cross-validation is performed for debiasing and autoregressive moving average model (ARIMA) implemented to correct the residuals, making the final model the variant with exogenous inputs (ARIMAX). The forecasts with the corresponding uncertainties are given for two time horizons, below and above six hours. Marginal emissions came up highly independent of any conditions in the DK2 zone, suggesting that the marginal generators are located in the neighbouring zones.The developed methodology can be applied to any bidding zone in the European electricity network without requiring detailed knowledge about the zone.

An aggregator is a business entity enabling smooth cooperation between a System Operator (SO) and small customers to trade electric power. In this cooperation each market actor (aggregator, small customer, system operator) looks for its own economic incentives. In this paper, we consider an aggregator, who manages a portfolio of domestic heat pumps (HPs). The aggregator aims at maximizing its profit while trading energy and providing balancing power in wholesale markets. The paper develops a Mixed Integer Linear Program (MILP) for optimal coordinated bidding of HPs consumption power in competitive day-ahead and real-time markets. The model enables an aggregator to shift the consumption of HPs to hours with lower market prices, while respecting the comfort of involved houses. A case has been studied based on data from Dutch pilot built in the scope of FLEXCoop project. Day-ahead and balancing market prices have been obtained from TenneT.

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