## 4 Discussion  
From the data produced in Case Study A, it is recommended that an offshore windfarm size should reach between 600-1000 MW of generational capacity. With emphasis placed on reaching the upper amount. At this point LCOE depreciation is minimal, even across all financial scenarios. Thus, providing an optimal scenario at which LCOE fluctuations are negligible.  
From Tables 11 and 12 in Case Study B, it is evident the greater the net capacity factor, the lower the correlated LCOE value. Current LCOE predictions using 48% net capacity  
\begin{table}
\begin{tabular}{c c c c c c} \hline \hline
**Years** & **Very Low** & **Low** & **Mid** & **High** & **Very High** \\ \hline
25 & 9.25 & 5.2 & 2.51 & N/A & N/A \\
20 & 8.54 & 4.15 & 1.19 & N/A & N/A \\
15 & 7.09 & 2.2 & N/A & N/A & N/A \\ \hline \hline \end{tabular}
\end{table}
Table 21: LCOE Zero CfD Range.  
\begin{table}
\begin{tabular}{c c c c c c} \hline \hline
**Years** & **Very Low** & **Low** & **Mid** & **High** & **Very High** \\ \hline
25 & 9.46–9.25 & 5.4–5.2 & 2.7–2.51 & N/A & N/A \\
20 & 8.78–8.54 & 4.36–4.15 & 1.4–1.19 & N/A & N/A \\
15 & 7.53–7.09 & 2.42–2.2 & N/A & N/A & N/A \\ \hline \hline \end{tabular}
\end{table}
Table 20: BEIS Pure LCOE.  
Figure 7: (a) 25-year scenario vs. discount rate; (b) 25-year range, and (c) Year sensitivity (LCOE difference of 15–25 year).  
factors reflect that a low sensitivity range is realistic. It is obligatory to recommend offshore turbines with the most efficient net factors are implemented where possible. High net capacity factors are imperative towards LCOE values for subsidy free models as shown in Figure 5. Caution is advised however, as degradation is not accounted for. Table 13 illustrates the possible LCOE drop per percentage variation. This can significantly affect subsidy free models in the long term.  
From the data procured in Case Study C, cost predictions/reductions for financial parameters are substantial for delivering a suitable discount rate. Under the low scenario, a discount rate reduction of almost 60% or less is required from a standard hurdle rate of 8.9% for a subsidy model to become viable. Furthermore, the range at which the net zero bid is suitable is very narrow. It is recommended the fixed discount rate be variable to each theoretical windfarm to more accurately reflect site-specific financial conditions.  
With reference to Case Study D, removing the Connection and Use of System Charges has a significant effect on the LCOE valuations. Almost 50% of the OPEX is covered by these charges. This has increased the expected discount rate by approximately two percent across all scenarios as seen above in Tables 20 and 21. Thus, making the LCOE less susceptible to the assumed financial parameters. A discount rate of around 5% is applicable to a realistic expectation of a 25% drop in financial costs.  
As a result of all the case studies conducted, key focal points have been identified that are significant for the development of subsidy free offshore windfarms to become a reality in future, including:  
* Increase CfD contract operational length to thirty years.
* Enable offshore wind access to capacitive and ancillary services and markets.
* Introduction of larger and more powerful turbines to be implemented to alleviate CAPEX expenditure
* Significant cost reductions of greater than 25%, are to be expected for the future online developments post 2025.
* Reduction in the expected discount rate below 8%.
* Energy wholesale market prices are expected to increase at a higher rate than Europe.
* Cost of carbon floor price is to increase. Only close to shore fixed turbines are economically viable for a net zero CfD.