Figure 2.8 Economic metrics for the additional cases.

      Higher methane composition feeds generally require fewer modifications to the existing plant. As a result, the TCI change for these feeds is very low (Figure 2.8). However, the additional annual net profit for these feeds is also low. The necessary modifications are justified economically, using the criteria of IROI > 10%, for all the cases except for the high methane case (Feed #1).

We next explain the condition for Feed #1. The content of NGLs in Feed #1 is very low (see Table 2.2), such that the gas already meets pipeline quality, except for the quantity of water in the gas. Therefore the turboexpander and fractionation train separation units are not needed. NGLs are very valuable, and therefore it is worth considering keeping these separation units. However this is determined to be infeasible, due to the fact that for the given inlet pressure of 1000 psig, the stream can never be in the two‐phase region regardless of the stream temperature. Thus it is not possible to remove the NGLs from the gas in a profitable way (see the phase envelop in Figure 2.9). Besides, the sales gas and wellhead gas have the same price (the heat value price), and almost the same heat value (approximately 1015 Btu/SCF), so there is no way to make a profit.

Figure 2.9 Phase envelope for Feed #1 before the demethanizer column (generated from process simulation).

      Some feeds are more likely to occur than others. To obtain a more accurate picture of whether or not each stream is worth treating, its IROI is multiplied by the probability for it to occur (see Table 2.2 for details). Next, the IROI based on probability of occurrence was calculated (Figure 2.10).

Figure 2.10 IROI based on feed probability.

      As can be seen all of the listed feeds are still worth treating based on the IROI > 10%. Despite the fact that Feed #5 generates the most additional revenue, it is only barely worth making the additional needed capital investment because the probability of this feed occurring is very low (7.50%).

      The total ROI calculated for these five feeds based on their likelihood to occur is determined from Eq. (2.13).

The total ROI is found to be 24.4%, which is greater than the 15.9% for treating only the base case.

      2.5.3 High Acid Gas Case Economics

Figure 2.11 shows the revenue for the base case and high acid gas case. There is only a slight decrease in revenue compared with the base case for the high acid case. This is because only a small percentage of the incoming gas is acid gases, while the remainder of the feed composition is similar to that for the base case feed.

Figure 2.11 Revenue for the high acid gas case and base case (MM$/yr).

As shown in Table 2.8, the additional TCI required to treat this stream is not significant, as compared with the additional revenue, and therefore this stream is clearly worth treating (IROI > 10%).

Table 2.8 Incremental return on investment for high acid case.

	HA feed
ΔAnnual net profit (MM$/yr)	11.8
ΔTotal capital investment (MM$/yr)	6.15
Incremental ROI (%)	192

      2.5.4 Safety Index Results

PRI is a relative comparison. The exact values from the calculations are not meaningful, only the relative comparison between different process routes, or in this case different incoming feeds. Only streams where a significant change in composition, pressure, or fluid density occurs were included in the calculation.

One significant weakness of PRI is that is uses the overall average value of each property for all the streams, effectively treating every stream considered as if it has the same flow rate (and thus same potential risk). This leads to misleading results; to give a more truthful picture, the values of each of the four properties used to calculate PRI (mass heating value, fluid density, pressure, and explosiveness) were multiplied by their flow rates as presented in Table 2.9.

Table 2.9 Results from modified process route index calculations.

	Feed #1	Feed #2	Feed #3	Feed #4	Feed #5	HA feed
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