<strong>10</strong> <strong>Years</strong> <strong>of</strong> <strong>International</strong> Cooperation: FTI, Nippon Keidanren and TU<strong>SIIT</strong> <strong>Commemorative</strong> <strong>Publication</strong>, 2002capacity and power generation are less than those inthe TEP case by approximately 1.5% in additionalcapacity and 61,681 GWh in generation due to energysavings from the DSM programs. The loss-<strong>of</strong>-loadprobabilities (LOLPs) in all cases are not changed.Table 3. Electricity generation in selected yearsCaseTEPCSSIRPTIPPTIGCTPFBGeneration-mix (TWh)PlantTypes 2003 2007 2012 2017HydroCoal-firedOil-firedCCGTIPPSubtotalHydroCoal-firedOil-firedCCGTIPPBiomassSubtotalHydroCoal-firedOil-firedCCGTIPPSubtotalHydroCoal-firedOil-firedCCGTIPPIPP_CoalSubtotalHydroCoal-firedOil-firedCCGTIPPIGCCSubtotalHydroCoal-firedOil-firedCCGTIPPPFBCSubtotal4.219.830.463.23.211.41324.219.830.463.23.211.401324.219.829.563.13.111.41314.219.830.463.23.211.401324.219.830.463.23.211.401324.219.830.463.23.211.401324.262.828.460.33.511.41714.262.928.460.33.511.401714.262.926.859.53.111.41684.248.528.360.33.411.414.51714.248.528.160.33.411.414.71714.248.528.160.33.411.414.71714.2147.816.347.42.711.42304.2150.016.343.12.711.42.12304.2132.816.657.02.811.42254.2137.816.143.12.811.414.62304.2125.616.954.42.811.414.72304.2133.516.247.22.711.414.72304.2202.011.754.<strong>10</strong>.511.42844.2187.011.767.60.511.42.12844.2177.0<strong>10</strong>.473.00.511.42764.2177.611.464.90.511.414.52844.2182.0<strong>10</strong>.759.91.011.414.72844.2182.011.758.81.011.414.7284Total2003-2017(TWh)621,648318859381713,096621,64531285238171163,096621,527308930371713,034621,497306833371711893,096621,432312890371711913,096621,466311857381711913,096In the IRP case, the cumulative generation avoidedthrough the DSM programs during 2003-2017 is61,681 GWh, <strong>of</strong> which 13,261 GWh from DSM1,15,629 GWh from DSM2 and 32,792 GWh fromDSM3. The DSM3, the efficient air conditionerprogram, has the highest contribution to the avoidedgeneration. In 2017, the peak load avoided in the IRPcase is 364.7 MW, <strong>of</strong> which 36.4 MW from DSM1,94.6 MW from DSM2 and 233.7 MW from DSM3. Inaddition to the reduction in electricity generation, theIRP case also shows a reduction in fuel consumption.The total fuel consumption in the IRP case is 640million tons <strong>of</strong> oil equivalent (toe), while that in theTEP case is 658 million tones.4.2 Environmental ImplicationsResults from the IRP model show that only the CSSand IRP cases have lower emissions. In all cases, theshare <strong>of</strong> coal-based plants is about 50% resulting inhigh CO 2 and SO 2 emissions. In the CSS case, thecoal-based plant is substituted with the biomass-basedplant resulting in lower CO 2 emission. In the CSS case,the total CO 2 , SO 2 and NO x emissions are found to beless than in the TEP case by 13 million tons, 77 ktonsand 31 ktons, respectively, while in the IRP case CO 2 ,SO 2 and NO x emissions are found to be less than in theTEP case by 89 million tons, <strong>10</strong>17 ktons and 195ktons, respectively. The cumulative CO 2 , SO 2 and NO xemissions during the planning horizon are shown inTable 4. In the CSS case, one unit <strong>of</strong> 700-MW coalfiredpower plant and one unit <strong>of</strong> 200-MW gas turbineplant are replaced by three units <strong>of</strong> 600-MWcombined-cycle and three units <strong>of</strong> <strong>10</strong>0-MW biomassbasedplants resulting in total CO 2 reduction.Though the power generation from coal-based plantsincreases in the TIGC and TPFB cases, CO 2emissions are reduced by 70 and 53 million tons,respectively, and SO 2 emissions are reduced by 1,703and 1435 ktons, respectively, compared to the TEPcase. The electricity generation from the IGCC andPFBC plants in the TIGC and TPFB cases results inless CO 2 , SO 2 and NO x emissions compared to the TEPcase.In the TIPP case, the power generation from the coalbasedplants increases due to committed coal-basedIPP plants resulting in higher CO 2 emission by 35%million tons or approximately 1.6% compared to theTEP case.Table 4. Cumulative emissions during 2003-2017.Case study CO 2, <strong>10</strong> 6 tons SO 2, <strong>10</strong> 3 tons NO x, <strong>10</strong> 3 tonsTEPCSSIRPTIPPTIGCTPFB2,2312,2182,1422,2662,1612,17914,85014,77313,83314,65313,14713,4156,9376,7436,9068,1686,5026,59014
<strong>10</strong> <strong>Years</strong> <strong>of</strong> <strong>International</strong> Cooperation: FTI, Nippon Keidanren and TU<strong>SIIT</strong> <strong>Commemorative</strong> <strong>Publication</strong>, 20024.3 Economic ImplicationsResults from the IRP show that the fuel and O&Mcosts take the largest share <strong>of</strong> total cost, byapproximately 80% as shown in Table 5. The totalcosts in the TIPP, TIGC and TPFB are higher than thatin the TEP case because <strong>of</strong> the high capital costs <strong>of</strong>IPP, IGCC and PFBC plants. The total cost in the CSScase decreases by US$ 6 million compared to the TEPcase because more clean supply-side options whichhave lower capital costs are available while in the IRPcase the total cost including DSM costs are less thanTEP case by US$ 260 million due to efficient use <strong>of</strong>electricity in the DSM programs. The total costs affectthe long run average costs (LRAC). The LRACs in allcases are higher than that in the TEP case except in theCSS case.The average marginal cost <strong>of</strong> abatement (MAC) <strong>of</strong>CO 2 emission can be calculated by using the followingequation:MAC =⎪⎧⎨⎪⎩ tT∑= 1( E( TC −TC)0 ,t− E) /( 1 + r )where TC c = present value <strong>of</strong> total cost correspondingto the least cost generation expansion plan with cleansupply-side options, TC 0 = present value <strong>of</strong> total costcorresponding to the least cost generation expansionplan without clean supply-side options, E 0,t = CO 2emission in year t corresponding to the least costgeneration expansion plan without clean supply-sideoptions, E c,t = CO 2 emission in year t corresponding tothe least cost generation expansion plan with cleansupply-side options, r = discount rate, and T = number<strong>of</strong> years in the planning horizon. The MAC <strong>of</strong> CO 2emission in each case is also determined, as shown inTable 6.Table 5. Cumulative costs during 2003-2017.Cost components (<strong>10</strong> 6 US$)CaseTotalstudy Capital O&M DSMcostLRACcents/kWhTEP 5,031 25,152 0 30,183 3.<strong>10</strong>CSS 4,873 25,061 0 30,177 3.<strong>10</strong>IRP 5,637 24,816 234 29,923 3.11TIPP 5,177 25,797 0 30,973 3.18TIGC 5,637 25,167 0 30,804 3.16TPFB 5,697 25,220 0 30,916 3.18cThe MACs <strong>of</strong> IGCC in the TIGC case and PFBC in theTPFB case were found to be 76.4 and 116.8 US$/ton <strong>of</strong>carbon, respectively, compared to 35 US$/ton <strong>of</strong>carbon in the case <strong>of</strong> full global trade [8]. However, inthe case <strong>of</strong> DSM options in the IRP case and biomassbasedplants in the CSS case, MACs were found to be-30.2 and -<strong>10</strong>.3 US$/ton <strong>of</strong> carbon, respectively, whichreflect the no-regret options in terms <strong>of</strong> CO 2mitigation. Further analysis <strong>of</strong> MACs reveals that thec ,t0t⎪⎫⎬⎪⎭substitution <strong>of</strong> IGCC and PFBC plants for coal-basedplants in the IRP baseline results in MACs <strong>of</strong> 8.9 and18.4 US$/ton <strong>of</strong> carbon, respectively, which are lowerthan the price <strong>of</strong> carbon under full trading scenario.The implication <strong>of</strong> MACs <strong>of</strong> IGCC and PFBC plants inthe IRP baseline reveals as candidate in the cleandevelopment mechanism (CDM) project under theKyoto Protocol.Table 6. Marginal abatement costs in 1998 price.Countries MAC (US$/ton <strong>of</strong> carbon)Thailand 1Under TEP baseline cases- Biomass in the CSS case- IGCC in the TIGC case- PFBC in the TPFB caseUnder IRP baseline cases- DSM options- IGCC as IPP plant- PFBC asIPP plant-<strong>10</strong>.376.4116.8-30.29.018.4Japan 2 876.0European Union 2 409.5Other OECD Countries 2 349.5USA 2 279.0Full Global Trade 3 35.0Source: 1 carried out by authors [9, <strong>10</strong>, 11]2 no trade [7]3 full global trade [8]5. ConclusionsResults <strong>of</strong> the least-cost power generation expansionplans reveal less CO 2 emissions due to clean supplysideoptions in the CSS, TIGCC and TPFB cases, andDSM options in the IRP case. In the CSS case,substitutions for coal-based plants are combined-cyclegas-based plants and biomass-based plants, which emitless CO 2 . The IGCC and PFBC plants are not selectedin the CSS case due to their high capital costs. Theintegration <strong>of</strong> DSM options and clean supply-sideoptions could reduce both total system costs and CO 2emissions. Therefore the IRP case is more suitable forCO 2 mitigation [9, <strong>10</strong>].In the IPP case, environmental emissions are directlyrelated to the technologies <strong>of</strong> power plants used byIPPs. The committed IPPs in the TIPP case are basedon coal-based plants resulting in higher CO 2 emissions.The substitution <strong>of</strong> IGCC and PFBC plants for coalbasedplants could be the CO 2 mitigation in the IPPcase [11].6. Recommendations for Future Researchand DevelopmentAccording to the presented results in this article, theintroduction <strong>of</strong> Energy Efficient Technology (EET) isnot effective because the main barrier in adoption <strong>of</strong>the EETs is their high investment cost. Furthermore,there are some other barriers, which need to be15
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Access to SIIT at Bangkadi!!!",':!D