At this section the power-driven operation will be compared to the heat-driven operation based on the reference scenario described before. The main comparison criterion will be the overall plant gains, since the work itself concerns an economic optimization. In addition to that, grid interactivity of both operations will be discussed. Lastly, effect of varying the size of the storage tank on overall costs and grid interactivity will be investigated.
8.1. Comparison with respect to overall plant gains
For comparison a yearly optimization has been carried out. Optimization parameters are given in Table 8.1.
Table 8.1 Optimization parameters for comparison scenario
ππ© 24 βππππ
π© 24
Step size 1 βπππ
ππ¦ππ¦ 1 βπππ
π¦π 2
As seen in Table 8.1, prediction horizon is 24 hours. Therefore, 365 sequential optimizations are done to achieve a yearly result. Each optimization process is initialized with the end state of the previous optimization. A βPythonβ script, which carries out this initialization, was available at Fraunhofer ISE. All parameters are selected as the same values for both heat-driven and power-driven models. Initialization parameters are given in Table 8.2.
Table 8.2 Parameters values for initialization
Size of Storage Tank (π) 45 m3
CHP Nominal Thermal Power (ππππ,ππ) 215 kW
CHP Nominal Electrical Power (πππ) 198 kW
CHP thermal efficiency (ππππ,ππ) 0.45
CHP electrical Efficiency (ππππ,ππ) 0.41
Boiler Efficiency (πππ₯ππππ) 0.90
Start Temperature of Storage tank (ππππππ) 45β
High Temperature Level (ππππ‘π) 80 β
Low Temperature Level (πππ₯π₯) 45 β
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For this scenario heat demand of district βGutleutmattenβ considered. It is intended to show the differences between heat-driven and power-driven operation for the same scenario.
Nominal powers of the CHP and efficiency values are realistic and can be encountered in real plants.
Results of both operations are given in Table 8.3 and Fig. 8.1.
Table 8.3 Result of the future scenario (1)
Gains Heat-driven Power-driven Change
Storage Gain [β¬] 9880 4170 - 57 %
CHP Gain [β¬] 29285 33193 +13 %
Boiler Gain [β¬] 33186 51843 + 56 %
Total Gain [β¬] 72351 89206 + 23 %
Fig. 8.1 Results of the future scenario (2)
As can be seen in Table 8.3 and Fig. 8.1, the total gain of the power-driven model is higher (by 23 %) than that of heat-driven model. It can be also stated that when the CHP operation is optimized, then the gain of the CHP rises by 13 % itself. Threshold electricity price value, when the CHP and the boiler gain are the same can be found as
π½CHP=π½Boiler , (π.ππ) πelβ πel + πCHP,thβ πheatβ πfuel,CHPβ πfuel =πbβ πheatβ πfuel,CHPβ πfuel , (π.ππ)
πel =β πCHP,thβ πheat+πfuel,CHPβ πfuel+πbβ πheatβ πfuel,CHPβ πfuel
πel , (π.ππ)
πel =β πCHP,thβ πheat+πfuel,CHPβ πfuel+πbβ πheatβ πfuel,CHPβ πfuel
πel . (π.ππ)
0 20000 40000 60000 80000 100000 Heat Driven
Power Driven
Gains [β¬/year]
Storage Gain CHP Gain Boiler Gain
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When the Eq. (8.1d) is solved for the same amount of heat supply by the CHP and the boiler (πb =πCHP,th), then the threshold level of electricity price can be found as 3.25 ππ./ππβ. That means when the electricity price is lower than this level, operating the boiler is more profitable. Electricity price is generally lower than this threshold price level (can be seen in Fig. 7.4). Thatβs why; the power-driven operation makes the highest profit from the boiler.
Fuel consumptions at the boiler and storage tank, operation hours of the CHP and specific gains of the CHP are given in Table 8.4.
Table 8.4 Comparison of specific gains based on gas consumptions and operation hours
Comparison Factors Heat-driven Power-driven
Gas Consumption at Boiler[ππ] 164788 257435
Gas Consumption at CHP [ππ] 419930 234189
Operation hours of CHP [h] 6893 4566
Specific Gain of the CHP [β¬/ππ] 0.069 0.141
Specific Gain of the CHP [β¬/h] 4.24 7.26
As can be seen in Table 8.4, gas consumption at boiler is proportional to the gain of the boiler, as the heat price is constant. On the other hand, the gas consumption at CHP is higher at heat-driven model while the gain of the CHP is lower at heat-driven model. In addition, total operation hours are also higher at heat-driven model, as the CHP operates as long as there is heat demand without considering any knowledge of prices. It can be also seen by comparing the specific gains that the power-driven operation outperforms the heat-driven operation.
It can be deduced that in the future, heat-driven operation would not be a smart solution for meeting residential heat demand considering the financial gains. Systems, which are capable of supplying heat and electricity concurrently, should consider electricity prices and develop further strategies to respond to fluctuations in the electricity market.
8.2. Comparison with respect to grid interactivity
First and foremost grid interactivity is a concept corresponding with how good the electricity production or consumption is scheduled. It concerns whether the electricity is produced at desired or undesired times with respect to the demand. Residual load πΊ is a good indicator to determine desired and undesired time periods. It is calculated by taking away the electricity productions of fluctuating renewable energy plants from the total electricity demand (Shammugam 2014, p. 9):
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πΊ= πloadβ πwindβ πPV , (π.π) where πload is the electrical power demand; πwind is the power produced by wind farms and πPV is the power produced by photovoltaic plants.
In order to quantify the term grid interactivity, Klein et al. has proposed a coefficient called Absolute Load-Grid Matching Coefficient (πΏπΊπΏπΏabs), which is derived as follows (Klein et al.
2014, p. 5):
πΏπΊπΏπΏabs=β« πel(π)β πΊ(π)β ππ
πelβ πΊΜ , (π.ππ) πel=οΏ½ πel(π)β ππ , (π.ππ) where πel is time-resolved electricity production; πΊ is time-resolved residual load; πel is the total electricity production for an evaluation period and πΊΜ is the average residual load during the evaluation period.
πΏπΊπΏπΏabs values can be interpreted as follows:
β’ πΏπΊπΏπΏabs> 1 indicates that electricity is produced at favorable times. This kind of
operation known as βpositively grid-interactiveβ or βgrid favorableβ behavior (Klein et al. 2014, p. 5).
β’ πΏπΊπΏπΏabs= 1 can be interpreted as βgrid-neutralβ behavior. By definition, LGMC value approaches to 1, when electricity is continuously produced during a reference time (Shammugam 2014, p. 13).
β’ πΏπΊπΏπΏabs< 1 is regarded as βnegatively grid-interactiveβ or βgrid-adverseβ behavior. It
means that electricity production by conventional power plants takes place when renewable power plants also produce high amount of electrical power (Klein et al.
2014, p. 5).
In addition to the financial aspects, grid interactivity of both operations is also analyzed for the same future scenario. Fig. 8.2 shows monthly πΏπΊπΏπΏabs values of both operations.
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Fig. 8.2 Comparison of πππππππ values
As seen in Fig. 8.2, heat-driven operation demonstrates a βgrid-neutralβ behavior, as can be seen the πΏπΊπΏπΏabs value ranges around β1.0β. However, power driven operation results in better πΏπΊπΏπΏabs values throughout the year. Apart from monthly based calculation, πΏπΊπΏπΏabs is also calculated for reference time of one year. It has been found out that power-driven operation is 33 % more grid interactive than the heat-driven operation.
It can be commented that it is possible to increases the grid interactivity of the system by optimizing the operation of the CHP based on electricity prices. As electricity prices mainly depend on the residual load, operating the CHP when electricity prices are high means also operating it when the residual load is high. This is why power-driven operation shows βgrid-favorableβ behavior.
8.3. Comparison with respect to size of the storage tank
At this section, effect of the storage size on grid interactivity and financial gains of the power-driven operation is discussed. To do that, three months at summer season are considered, as in the winter season storage tanks are generally not used.
The reference scenario includes the same heat demand, residual load and electricity prices of the future scenario. The effect of varying the size of the storage tank can be seen in Fig. 8.3.
0,9 1 1,1 1,2 1,3 1,4 1,5 1,6
1 2 3 4 5 6 7 8 9 10 11 12
LGMC
Months LGMC_Power Driven
LGMC_Heat Driven
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Fig. 8.3 Optimization results of the same summer scenario with different storage sizes
Except the storage volume, all other parameters including the optimization horizon (24 hours) stay consistent for comparison of all cases. However, these results would vary depending on the length of the optimization horizon.
As can be seen in Fig. 8.3, changing the size of the storage tank increases both the gains and the grid interactivity up to a certain level. In summer season, the heat demand is generally lower than the CHP thermal nominal power. Increasing the size of the storage tank enables the CHP to operate longer. Therefore, when the electricity prices are high enough, then the CHP stores the excess heat at the storage tank without causing any mismatch between the demand and supply. However, when the size of the storage tank reaches a saturation volume, which is 150 π3 in this case, then it should be well reasoned whether it makes sense to have a storage tank with a larger size. It is worth commenting that this size should be determined by taking into account the average expected heat demand and the nominal thermal capacity of the CHP.
1,12 1,14 1,16 1,18 1,2 1,22 1,24
0 5000 10000 15000 20000 25000
5 15 45 60 100 150 200
LGMC [-]
Gains [β¬]
Storage Volume (m^3)
Storage Gain CHP Gain Boiler Gain LGMC
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