Thermal and Economic Analysis of Multi-E ﬀ ect Concentration System by Utilizing Waste Heat of Flue Gas for Magnesium Desulfurization Wastewater

: Compared with limestone-based wet ﬂue gas desulfurization (WFGD), magnesia-based WFGD has many advantages, but it is not popular in China, due to the lack of good wastewater treatment schemes. This paper proposes the wastewater treatment scheme of selling magnesium sulfate concentrate, and makes thermal and economic analysis for di ﬀ erent concentration systems in the scheme. Comparisons of di ﬀ erent concentration systems for 300 MW power plant were made to determine which system is the best. The results show that the parallel-feed benchmark system is better than the forward-feed benchmark system, and the parallel-feed optimization system with the 7-process is better than other parallel-feed optimization systems. Analyses of the parallel-feed optimization system with 7-process were made in 300, 600, and 1000 MW power plants. The results show that the annual proﬁt of concentration system for a 300, 600, and 1000 MW power plant is about 2.58 million, 5.35 million, and 7.89 million Chinese Yuan (CNY), respectively. In di ﬀ erent concentration systems of the scheme for selling magnesium sulfate concentrate, the parallel-feed optimization system with the 7-process has the best performance. The scheme can make a good proﬁt in 300, 600, and 1000 MW power plants, and it is very helpful for promoting magnesia-based WFGD in China.


Introduction
Limestone-based wet flue gas desulfurization (WFGD), the most popular desulfurization technology used worldwide, leads the world market in installed post-combustion SO 2 control technologies, and has about 85% of the market share in China [1][2][3]. Limestone-based WFGD has many advantages, such as low operating cost, abundant raw materials, and high stability. However, there are many disadvantages of limestone-based WFGD, such as serious blockage and wear, the byproduct occupying land problem, large water consumption, and air pollution [4]. Among them, the byproduct gypsum occupying land problem is more prominent, which gets more attention from scholars in the limestone-based WFGD field. Ma et al. [5] studied the combined utilization of gypsum and waste fly ash, and showed that the mixture of gypsum and waste fly ash with a certain proportion had acceptable mechanical properties for backfill applications under a NaOH activator, which provided a feasible choice for the large-scale utilization of gypsum. Koralegedara et al. [6] mainly discussed the application of flue gas desulfurization gypsum in soil improvement and water treatment, and pointed out that there are gaps, like the application of gypsum in landfill leachate treatment, that need to be researched in detail. Although quite a portion of WFGD gypsum has been used in different ways for recent years, plant. These works can provide favorable conditions for the popularization of magnesia-based WFGD in China. Firstly, taking inlet flue gas temperature and system effects number as variables, the forward-feed benchmark system and the parallel-feed benchmark system were compared. Then different optimization processes were added to the parallel-feed benchmark system, and a comparison was made. The influence of annual utilization hours, steam price, 09CrCuSb alloy (ND steel) price, 304 stainless steel price, and magnesium sulfate concentrate price on the annual profit of the parallel-feed optimization system with the 7-process was analyzed. Finally, the parallel-feed optimization system with the 7-process of a 300, 600, and 1000 MW power plant were compared for thermal performance and economic performance.

Process Description
As shown in Figure 1, the magnesium desulfurization wastewater from the desulfurization tower is converted into magnesium sulfate concentrate after thorough aeration, neutralization sedimentation, heavy metal sedimentation, coagulation sedimentation, clarification, and concentration [14,25]. In the aeration step, air and catalyst are added to oxidize magnesium sulfite to magnesium sulfate. In the three steps of neutralization sedimentation, heavy metal sedimentation, and coagulation sedimentation, alkaline substances, organic sulfur reagent, and flocculants are added to remove metal ions, particles, and colloidal matter. In the clarification step, sludge is separated from supernatant liquid containing magnesium sulfate. The final step of converting magnesium desulfurization wastewater into magnesium sulfate concentrate is concentration, which is a process of high heat consumption, and reducing its heat consumption is worth studying. Common concentration system configurations include forward-feed and parallel-feed [26,27], which are widely used in desalination and other processes [24,[28][29][30][31]. The two configurations have advantages and disadvantages, and the way of preheating feed by final effect steam is widely used, to improve system concentration efficiency. The flue gas with waste heat is used as the heat source of the concentration system, rather than the steam with high quality heat. An evaporation heat exchanger is set in the tail flue to generate saturated steam with a pressure slightly higher than the atmospheric pressure, which enters the multi-effect concentration system of the forward-feed or parallel-feed, as shown in Figure 2. The forward-feed or parallel-feed concentration system with final effect steam preheating feed is selected as the benchmark system for this optimization. Different optimization processes of multi-effect parallel-feed concentration system are shown in Figure 3. In the calculation conditions in this paper, the thermal and economic performance of the parallel-feed benchmark system is better than that of the forward-feed benchmark system, as shown in Figures 4 and 5, and a detailed explanation is given in Section 3.1. Therefore, the parallel-feed benchmark system was selected for process optimization. The optimization methods of the multi-effect concentration system to improve performance mainly include extraction steam preheating, condensate flash, concentrate flash, and various combinations [32][33][34], and the process principle is shown in Figure 3. . Different optimization processes of multi-effect parallel-feed concentration system: (a) optimizing process; and (b) combined optimization process. In Figure 3a, the added equipment, compared with the benchmark system, is coiled with a red circle. Extracting steam preheating is extracting a part of the secondary steam generated in the evaporator to preheat the feed entering the evaporator. Condensate flash is where the condensate from the previous effect is flashed to generate additional secondary steam for the next effect. Concentrate flash is where the concentrate from the previous effect is flashed to generate additional secondary steam for the next effect. In Figure 3b, the added equipment, compared with the benchmark system, is coiled with a red circle. In addition, 4, 5, 6, and 7 are composed of 1, 2, and 3 from Figure 2a in different ways.

Assumption and Validation
The concentration systems were modelled in Ebsilon, which is suitable for modelling thermal processes. Ebsilon has the advantages of convenient design, flexible model building, and fast convergence calculation. To simplify the models in this paper, the assumptions are made below: (1) Steady-state operation.
(2) The desulfurization wastewater entering the concentration system is regarded as a single component solution with only magnesium sulfate as the solute. (3) The water evaporated from the concentration system is treated as pure water. (4) No heat loss of any equipment of the concentration system. (5) No pressure drop loss of any equipment of the concentration system. (6) Ignore the influence of non-condensable gas.
The Ebsilon model is validated by comparing with a commercial multi-effect distillation plant. As shown in Table 1, the simulation result agree well with the actual plant data. The relative errors of specific heat consumption and specific heat transfer area are both less than 1%.

Boundary Conditions and Simulation Settings for a 300 MW Power Plant
Outlet parameters: Magnesium desulfurization wastewater consists of magnesium sulfite, acid ions, heavy metal elements, non-metal elements, and so on [36]. After oxidation, sedimentation, flocculation, and other pretreatment, magnesium sulfate solution for concentration and crystallization is obtained. Research shows that at 70 • C, the saturated mass fraction of magnesium sulfate is the highest, at 35% [37]. Therefore, the outlet temperature and mass fraction of the concentration system are set at 70 • C and 35%.
Inlet parameters: The working temperature of magnesium desulfurization is generally 50-60 • C [38]. After about 20 h of aeration oxidation in the aeration oxidation tank, the magnesium sulfate solution is nearly saturated (~26%), and its temperature drops to ambient temperature [39]. Therefore, the inlet temperature and mass fraction of the concentration system are set at 25 • C and 24%. The inlet feed flow is calculated according to Equation (1), and the data is shown in Table 2. In addition, we select 110 • C, 120 • C, and 130 • C as the inlet flue gas temperature of the multi-effect concentration systems, which are the common exhaust gas temperatures of a 300 MW coal-fired unit [18,40,41].
In Equation (1), G in is the inlet magnesium sulfate solution mass flow of concentration system, t/h; G c is the coal consumption of a 300 MW power generation unit, t/h; η b is the combustion efficiency of boiler, %; S ar is the sulfur content of coal on received basis, %; η d is the flue gas desulfurization efficiency of power plant, %; M S is the molar mass of sulfur, g/mol; M MgSO4 is the molar mass of magnesium sulfate, g/mol; and W MgSO4 is the mass fraction of magnesium sulfate in the solution, %.

Thermal Performance Analysis
Thermal performance is generally reflected by S h and S a , which are calculated by Equations (2) and (3) [34].
In Equation (2), S h represents the flue gas heat required for the concentration system to evaporate one tonne of water from the inlet feed, which reflects the use effect of the concentration system on the flue gas heat, MJ/t; Q in represents the input flue gas heat of the concentration system, kW; and M w represents the evaporation water mass flow of the concentration system, t/h.
In Equation (3), S a represents the heat transfer area required for the concentration system to evaporate each 1 t/h of water from the inlet feed, which reflects the investment cost of the concentration system, m 2 ·h/t; A f represents the heat transfer area of flue heat exchanger, m 2 ; A e represents the total heat transfer area of all evaporators, m 2 ; A p represents the total heat transfer area of all preheaters, m 2 ; A c represents the heat transfer area of condenser, m 2 ; and M w represents the evaporation water mass flow of the concentration system, t/h.

Economic Analysis
In Equation (4), P is the annual profit of the concentration system, 10 4 ¥/a; S is the annual sale of the concentration system, 10 4 ¥/a; and C is the annual cost of the concentration system, 10 4 ¥/a. The annual sale of the concentration system is the value of all magnesium sulfate concentrate produced by the concentration system in one year. The annual sale of the concentration system is estimated by Equation (5). The annual cost of the concentration system is composed of the annual heat source cost and the annual depreciation cost [26,27]. The relevant calculation equations for the annual cost of the concentration system are Equations (6)- (12).
In Equation (6), C is the annual cost of the concentration system, 10 4 ¥/a; C h is the annual heat source cost of the concentration system, which is the flue gas heat consumption cost, 10 4 ¥/a; and C d is the annual depreciation cost of the concentration system, which is the total depreciation cost of flue heat exchanger, evaporators, preheaters and condenser, 10 4 ¥/a.
In Equation (7), C h is the annual heat source cost of the concentration system, 10 4 ¥/a; θ is the annual converted full load utilization hours of power plant, h/a (θ is 4000); G s is the circulating steam generated by the flue heat exchanger, t/h (calculated by software); and P s is the steam price, 10 4 ¥/t (P s is 0.0055 at 0.15 MPa [42]).
In Equation (9) [43], I f is the flue heat exchanger investment cost, 10 4 ¥; m is the flue heat exchanger weight, t (calculated by software); P N is the unit price of ND steel, 10 4 ¥/t (ND steel has superior resistance to sulfuric acid dew point corrosion, P N = 0.47); and α is the equipment investment cost coefficient (α is 1.7 [43]).
In Equation (10) [26], I e is the total investment cost of evaporators, 10 4 ¥; i is the sequence number of evaporators; n is the effects number of evaporators; P 3 is the unit price of 304 stainless steel, 10 4 ¥/t (304 stainless steel is corrosion-resistant and easy to process, P 3 = 0.36); A i is the heat transfer area of the ith effect, m 2 (calculated by software); and Z i is the investment increase coefficient determined by the heat transfer area of the ith effect (Z i = 1 [26]).
In Equation (11) [26], I p is the total investment cost of preheaters, 10 4 ¥; j is the sequence number of preheaters; k is the number of preheaters; A j is the heat transfer area of the jth preheater, m 2 (calculated by software); and β j is the jth preheater correction coefficient (β j is 2.5 or 3.1 [26]).
In Equation (12) [26], I c is the investment cost of condenser, 10 4 ¥; A c is the condenser heat transfer area, m 2 (calculated by software); and β c is the condenser correction coefficient (β c is 2.5 or 3.1 [26]).

Thermal Performance Analysis of Benchmark System
The influence of inlet flue gas temperature, process type, and effects number on the specific flue gas heat and the specific heat transfer area of the benchmark system is studied, as shown in Figure 4. In the legend of Figure 4, F represents forward-feed, P represents parallel-feed, and the number represents the inlet flue gas temperature. F130 stands for the forward-feed benchmark system, of which inlet flue gas temperature is 130 • C, P130 stands for the parallel-feed benchmark system, of which inlet flue gas temperature is 130 • C, and so on. Four features can be seen from Figure 4. The first feature is that the specific flue gas heat and specific heat transfer area of the parallel-feed is lower than that of the forward-feed under the same effects number and inlet flue gas temperature. In the forward-feed configuration, all the feed enters the first effect evaporator, and two processes occur successively: the preheating process to the bubble point, and the evaporation process to generate steam. Only a part of the heat absorbed in the preheating process can be used by the subsequent evaporator, through natural pressure drop flash, while all of the heat absorbed in the evaporation process is used by the subsequent evaporator, in the form of secondary steam. In the parallel-feed configuration, the feed enters each evaporator after being evenly divided. In the first effect evaporator, the heat absorbed in the preheating process is reduced, and the heat absorbed in the evaporation process is increased. So, in the subsequent evaporator, the available heat is increased, which can reduce the input heat of the flue gas. Figure 4a indicates that the flue heat exchanger duty of parallel-feed is lower than that of forward-feed. Because the heat transfer coefficient of the flue heat exchanger is very low, the flue heat exchanger area of the parallel-feed is obviously less than that of the forward-feed. In addition, the area of other heat exchange equipment is almost equal in the parallel-feed and forward-feed. So, S a , which involves all the heat exchanger area, of the parallel-feed is less than that of the forward-feed.
The second feature is that when the inlet flue gas temperature decreases from 130 • C to 110 • C, the specific flue gas heat of the forward-feed and the parallel-feed decreases, and the specific heat transfer area of the forward-feed and the parallel-feed, on the general trend, increases. When the inlet flue gas temperature decreases, the temperature of each evaporator decreases, the preheat of feed decreases, and the temperature of each effect condensate decreases, so the specific flue gas heat decreases. With the decrease of inlet flue gas temperature, flue heat exchanger area decreases, evaporator areas increase, and other heat exchanger area hardly changes. On the general trend, the increase of evaporator area is greater than the decrease of flue heat exchanger area, so the specific heat transfer area increases.
The third feature is that the specific flue gas heat and specific heat transfer area of the forward-feed and the parallel-feed both decrease when the effects number increases from 3 to 7. Every time the number of effects increases, the input heat of flue gas will be used by the system again, in the form of secondary steam. Because the heat demand of magnesium sulfate solution during concentration is certain, the input heat of flue gas will decrease. With the increase of effects number, the flue heat exchanger area decreases, evaporator areas increase, and other heat exchanger area hardly changes. On the general trend, the decrease of flue heat exchanger area is greater than the increase of evaporator areas.
The fourth feature is that there are upper limits of the maximum effects number in both forward-feed and parallel-feed, and the upper limit value increases when the inlet flue gas temperature increases from 110 • C to 130 • C. The concentration outlet temperature of the system is 70 • C. During operation, the heat transfer temperature difference of the evaporator shall be greater than 5 • C. When the inlet flue gas temperature is determined, the system total temperature difference is determined, and the upper limit value of the maximum effects number is determined accordingly. The larger the inlet flue gas temperature is, the greater the system total temperature difference is, and the higher the upper limit value will be.
An invisible phenomenon in Figure 4 is that all the temperature differences between the flue gas at the inlet and outlet of the six concentration systems in the Figure 4 are less than 3 • C. The minimum safe operating temperature of the heat exchanger, considering acid corrosion, is 80 • C [44], so even if the inlet flue gas temperature is 110 • C, the magnesium desulfurization wastewater concentration system can be operated safely.

Economic Analysis of Benchmark System
The influences of inlet flue gas temperature, process type, and effects number on the annual profit of benchmark systems are studied, as shown in Figure 5. In the legend of Figure 5, F represents forward-feed, P represents parallel-feed, and the number represents the inlet flue gas temperature. F130 stands for the forward-feed benchmark system, of which inlet flue gas temperature is 130 • C, P130 stands for the parallel-feed benchmark system, of which inlet flue gas temperature is 130 • C, and so on.
Three features can be seen from Figure 5. The first feature is that the annual profit of the parallel-feed is higher than that of the forward-feed under the same effects number and inlet flue gas temperature. We can see from Figure 4 that S h and S a of the parallel-feed is lower than that of the forward-feed. So, C h and C d of the parallel-feed is lower than that of the forward-feed. C of the parallel-feed is lower. S of the parallel-feed is equal to that of the forward-feed. So, P of the parallel-feed is higher than that of the forward-feed.
The second feature is that the annual profit of the forward-feed and the parallel-feed both increase when the inlet flue gas temperature decreases from 130 • C to 110 • C. The second feature from Figure 4 indicates that C h of the forward-feed and the parallel-feed decreases, and C a of the forward-feed and the parallel-feed, on the general trend, increases. But the decrease of C h is greater than the increase of C a . So, C of the forward-feed and the parallel-feed decreases. S of the parallel-feed and the forward-feed do not change with the decrease of inlet flue gas temperature. So, P of the forward-feed and the parallel-feed increase. The third feature is that the annual profit of the forward-feed and the parallel-feed increase when the effects number increases from 3 to 7. With the increase of effect numbers, both C h and C a of the forward-feed and the parallel-feed decrease. So, C of the forward-feed and the parallel-feed decreases. S of the parallel-feed and the forward-feed do not change with the increase of effect numbers. So, P of the forward-feed and the parallel-feed increase.

Optimization System of 300 MW Power Plant
Figures 4 and 5 show that the thermal and economic performance of the parallel-feed benchmark system is better than that of the forward-feed benchmark system, so the parallel-feed benchmark system is selected for process optimization. There are eight parallel-feed systems with benchmark or different optimized processes shown in Figure 3.

Thermal Performance Analysis of Optimization System
Taking inlet flue gas temperature and system effects number as variables, the changes of specific flue gas heat and specific heat transfer area of optimization system are studied, as shown in Figure 6. In the legend, 0 represents the parallel-feed benchmark system in Figure 2, and 1-7 represent the parallel-feed optimization system with the corresponding number optimization process in Figure 3. Figure 6 shows that, no matter the benchmark or the optimized system, the specific flue gas heat and the specific heat transfer area both follow the three features of second, third, and fourth in Figure 4.
In addition, Figure 6 shows that among the three optimization processes of 1-3, the optimization effect of 1-process is better than that of 2-process and 3-process, in both the specific flue gas heat and the specific heat transfer area. The 1-process uses the secondary steam generated at the previous moment to preheat the system feed at the next moment, so that the heat absorption of the system feed at the next moment in the evaporator is significantly reduced. Thus, the input heat and the heat exchanger heat load of the concentration system both are apparently reduced, and the specific flue gas heat and the specific heat transfer area obviously decrease. The 2-process and 3-process produce additional steam through flash of liquid pressure drop, which is generated by absorbing sensible heat of liquid, and has a low mass flow. Thus, the input heat and the heat exchanger heat load of concentration systems both are slightly reduced, the specific flue gas heat and the specific heat transfer area slightly decrease. Among the 4-7 combined optimization processes, 7-process has the best optimization effect, in both the specific flue gas heat and the specific heat transfer area, and is also the best of all the 1-7 optimization processes. The process combines the three methods of extracting steam preheating, condensate flash, and concentrate flash, which can be well compatible, and minimize the input heat and the heat exchanger heat load of the concentration system. So, the specific flue gas heat and the specific heat transfer area of the 7-process are the minimum in all the 1-7 optimization processes.

Economic Analysis of Optimization System
Taking inlet flue gas temperature and system effects number as variables, the change of annual profit of systems are studied, as shown in Figure 7. In the legend, 0 represents the parallel-feed benchmark system in Figure 2, and 1-7 represents the parallel-feed optimization system with the corresponding number optimization process in Figure 3.  Figure 7 shows that, no matter the benchmark or the optimized system, the annual profit follows the two features of second and third in Figure 5. In addition, Figure 7 shows that, among the three optimization processes of 1-3, the optimization effect of 1-process is better than that of 2-process and 3-process. Figure 6 indicates that C, which is decided by S h and S a , of 1-process is obviously reduced. S of 1-process does not change. So, P of 1-process obviously increases. Figure 6 also indicates that C of 2-process and 3-process are slightly reduced. S does not change. So, P of 2-process and 3-process slightly increase. Among the 4-7 combined optimization processes, 7-process has the minimums of S h and S a , and also the minimums of all the 1-7 optimization processes, as shown in Figure 6. So, C of 7-process is the minimum. Thus, P of 7-process is the maximum in Figure 7.

Cost Reductions and Influence Factors of the Optimization System
In order to know the cost reductions, compared with the forward-feed benchmark system or the parallel-feed benchmark system, of the parallel-feed optimization system with 7-process, the costs of the three systems are shown in Table 3. In Table 3, investment cost is the total equipment investment of flue heat exchanger, evaporators, preheaters, and condenser; annual heat source cost is the flue gas heat consumption cost; and annual depreciation cost is the total depreciation cost of flue heat exchanger, evaporators, preheaters, and condenser. Compared with the forward-feed benchmark system, investment cost, annual heat source cost, and annual depreciation cost of the parallel-feed optimization system with 7-process are about 22%, 21%, and 21% lower, respectively. Compared with the parallel-feed benchmark system, investment cost, annual heat source cost, and annual depreciation cost of the parallel-feed optimization system with 7-process are about 8%, 9%, and 8% lower, respectively. It is known from Equation (4) that annual utilization hours, steam price, ND steel price, and 304 stainless steel price all affect the annual profit by changing the annual cost, and magnesium sulfate concentrate price affects the annual profit by changing the annual sale. Figure 7 is the result calculated according to the annual utilization hours of 4000, steam price of 55 ¥/t, ND steel price of 4700 ¥/t, 304 stainless steel price of 3600 ¥/t, and magnesium sulfate concentrate price of 116.35 ¥/t. Take the above factors as the benchmark value 1, and see Figure 8 for the influence of each factor change on the annual profit of the parallel-feed optimization system with 7-process at inlet flue gas temperature of 120 • C and system effects of 4. In Figure 8, AUH is annual utilization hours, SP is steam price, NDSP is ND steel price, 304SSP is 304 stainless steel price, and MSCP is magnesium sulfate concentrate price. The left axis is the ordinate of AUH, SP, NDSP, and 304SSP, and the right axis is the ordinate of MSCP.  Figure 8 shows that magnesium sulfate concentrate price, which affects the annual profit by changing the annual sale, has a far greater impact on the annual profit than annual utilization hours, steam price, ND steel price, and 304 stainless steel price, which affect the annual profit by changing the annual cost. Magnesium sulfate concentrate price directly determines the annual sale, which accounts for a large part of the annual profit, so its change has a far greater impact on the annual profit. Among annual utilization hours, steam price, ND steel price, and 304 stainless steel price, annual utilization hours and steam price have a bigger impact on the annual profit. Annual utilization hours and steam price directly change the annual heat source cost, which accounts for a large part of the annual cost, while ND steel price and 304 stainless steel price directly change the annual depreciation cost, which accounts for a small part of the annual cost. So, annual utilization hours and steam price have a bigger impact on the annual profit than ND steel price and 304 stainless steel price. For 300, 600, and 1000 MW power plant, the parallel-feed optimization system with 7-process, which has the best thermal performance and economic performance, was selected to make a comparison. It can be seen from Figures 6 and 7 that the optimal effects number of the parallel-feed optimization system with 7-process is 4 when the inlet flue gas temperature is 110 • C, 5 when the inlet flue gas temperature is 120 • C, and 6 when the inlet flue gas temperature is 130 • C. So, 4, 5, and 6 were chosen as system effects numbers when inlet flue gas temperature is 110, 120, and 130 • C.
The comparison for 300, 600, and 1000 MW power plants includes both thermal performance and economic performance, as shown in Figure 9. In the horizontal scale mark label of Figure 9, the number before the bracket represents the inlet flue gas temperature of the concentration system, and the character in the bracket represents the effects number of the concentration system. For example, 110 (4E) represents that the inlet flue gas temperature is 110 • C and the effects number is 4.
From Figure 9a,b, under the same inlet flue gas temperature and system effects number, the change of MW from 300 to 1000 hardly changes the specific flue gas heat and specific heat transfer area. Specific flue gas heat and specific heat transfer area are both thermal performances; the change of MW actually affects the flow rate of inlet magnesium sulfate solution of the concentration system. So, total flue gas heat and total heat transfer area change; but specific flue gas heat and specific heat transfer area hardly change. From Figure 9c, under the same inlet flue gas temperature and system effects number, the increase of MW from 300 to 1000 makes annual profit increase greatly. Annual profit depends on annual sale and annual cost. When the MW increases, annual sale and annual cost both increase, and the relative increase of annual sale is slightly larger than that of annual cost. But the annual sale is much larger than the annual cost in the 300 MW power plant, so the absolute increase of annual sale is much larger than that of annual cost as the MW increases. Annual profit increases greatly as the MW increases.

Conclusions
This paper proposes the wastewater treatment scheme of selling magnesium sulfate concentrate, and makes thermal and economic analysis for different concentration systems in the scheme, which adopt the combination technology of multi-effect and flue gas waste heat utilization for better performance. Some conclusions can be made, as follows.
(1) In a 300 MW power plant, the concentration benchmark process should adopt parallel feed.
Compared with the forward-feed benchmark system, the parallel-feed benchmark system reduces about 15%, 20%, and 13% in specific flue gas heat, specific heat transfer area, and annual cost, respectively.
(2) In a 300 MW power plant, 7-process should be adopted for the optimization of the concentration benchmark process. Compared with the parallel-feed benchmark system, the parallel-feed optimization system with 7-process reduces about 9%, 4%, and 9% in specific flue gas heat, specific heat transfer area, and annual cost, respectively. (3) Among the five factors influencing the annual profit of parallel-feed optimization system with 7-process of 300 MW power plant, the influence of magnesium sulfate concentrate price was the largest, annual utilization hours and steam price were the second, and ND steel price and 304 stainless steel price were the least.  The effects number of evaporators P Annual profit of concentration system, 10 4 ¥/a P 3 Unit price of 304 stainless steel, 10 4 ¥/t P MgSO4·7H2O Unit price of magnesium sulfate heptahydrate, 10 4 ¥/t P N Unit price of ND steel, 10 4 ¥/t P s Steam price, 10 4 ¥/t Q in Input flue gas heat of concentration system, kW S Annual sale of concentration system, 10 4 ¥/a S a Specific heat transfer area, m 2 ·h/t S ar Sulfur content of coal on received basis, % S h Specific flue gas heat, MJ/t s MgSO4·7H2O Cost factor magnesium sulfate heptahydrate, % W MgSO4 Mass fraction of magnesium sulfate in the solution, % Y Yield of magnesium sulfate heptahydrate, % Z i Investment increase coefficient of evaporator α Equipment investment cost coefficient of flue heat exchanger β c The condenser correction coefficient βj The jth preheater correction coefficient γ c Annual depreciation rate of condenser, a −1 γ e Annual depreciation rate of evaporators, a −1 γ f Annual depreciation rate of flue heat exchanger, a −1 γ p Annual depreciation rate of preheaters, a −1 η b Combustion efficiency of boiler, % η d Flue gas desulfurization efficiency, % θ Annual converted full load utilization hours of power plant, h/a