text: fig1 is a schematic diagram of an exemplary integrated gasification combined - cycle ( igcc ) power generation plant 100 . fig2 is a schematic diagram illustrating exemplary processes of the invention . while fig1 depicts only a portion of igcc plant 100 , it should be understood by one skilled in the art that the methods as described herein can be used in a complete igcc plant ( including at least one steam turbine engine and an electrical generator ) and / or in structurally similar igcc plants as known in the art . furthermore , it should be understood by one skilled in the art that while described herein with an igcc power generation plant , the present invention can be used with any known separation and / or gasification system without departing from the scope of the present invention . more particularly , systems including separation devices for providing physical and / or chemical separation , pressure - swing adsorption , temperature - swing adsorption , membrane separation , and the like , and combinations thereof can suitably be used with the methods of the present invention . in the exemplary embodiment , igcc plant 100 includes gasification system 200 . moreover , in the exemplary embodiment , system 200 includes at least one air separation unit 202 that is coupled in flow communication with an air source ( not shown ) via an air conduit 204 . such air sources may include , but are not limited to , dedicated air compressors and / or compressed air storage units ( neither shown ). unit 202 separates air into oxygen ( o 2 ), nitrogen ( n 2 ), and other components are released via a vent ( not shown ). system 200 includes a gasifier 208 that is coupled in flow communication with unit 202 and that receives the o 2 channeled from unit 202 via an o 2 conduit 210 . system 200 also includes a coal grinding and slurrying unit 211 . unit 211 is coupled in flow communication with a coal source and a water source ( neither shown ) via a coal supply conduit 212 and a water supply conduit 213 , respectively . unit 211 is configured to mix the coal and water to form a coal slurry reactant stream , referred to hereinafter as “ feedstock ” ( not shown ) that is channeled to reactor 208 via a coal slurry conduit 214 . gasifier 208 receives the feedstock and o 2 via conduits 214 and 210 , respectively . gasifier 208 facilitates the production of a hot , raw synthetic gas ( syngas ) stream ( not shown ). the raw syngas includes carbon monoxide ( co ), hydrogen ( h 2 ), carbon dioxide ( co 2 ), carbonyl sulfide ( cos ), and hydrogen sulfide ( h 2 s ). while co 2 , cos , and h 2 s are typically collectively referred to as acid gases , or acid gas components of the raw syngas , from hereon , co 2 will be discussed separately from the remaining acid gas components . moreover , gasifier 208 also produces a hot slag stream ( not shown ) as a by - product of the syngas production . the slag stream is channeled to a slag handling unit 215 via a hot slag conduit 216 . unit 215 quenches and breaks up the slag into small slag pieces wherein a slag removal stream is produced and channeled through conduit 217 . referring to fig1 , gasifier 208 is coupled in flow communication with radiant syngas cooler ( rsc ) 144 via a hot syngas conduit 218 . rsc 144 receives the hot , raw syngas stream and transfers at least a portion of the heat to heat recovery steam generator ( hrsg ) 142 via conduit 146 . subsequently , rsc 144 produces a cooled raw syngas stream ( not shown ) that is channeled to convective syngas cooler ( csc ) 260 via a syngas conduit 219 . csc 260 further cools the raw syngas stream . referring again to both fig1 and 2 , the cooled raw syngas stream is then channeled to a syngas scrubber ( shown in fig2 generally at 270 ) and low temperature gas cooling ( ltgc ) unit 221 via a syngas conduit 220 . unit 221 removes particulate matter entrained within the raw syngas stream and facilitates the removal of the removed matter via a fly ash conduit 222 . unit 221 also provides additional cooling to the raw syngas stream . moreover , unit 221 converts at least a portion of cos in the raw syngas stream to h 2 s and co 2 via hydrolysis . system 200 also includes a separation device 250 that is coupled in flow communication with unit 221 and that receives the cooled raw syngas stream via a raw syngas conduit 225 . device 250 facilitates removing at least a portion of acid components ( not shown ) from the raw syngas stream as discussed in more detail below . such acid gas components include , but are not limited to , co 2 , cos , and h 2 s . moreover , in one aspect , device 250 is coupled in flow communication with a sulfur reduction subsystem 275 via a conduit 223 . subsystem 275 also receives and facilitates the separation of at least some of the acid gas components into components that include , but are not limited to , co 2 , cos , and h 2 s . the separation and removal of such co 2 , cos , and h 2 s via device 250 and subsystem 275 facilitates the production of a clean syngas stream ( not shown ) that is channeled to gas turbine 114 via a clean syngas conduit 228 . referring to both fig1 and 2 , device 250 channels a co 2 - rich gas stream to gasifier 208 via a co 2 - rich gas stream conduit 224 . as used herein , “ carbon dioxide - rich gas ” or “ co 2 - rich gas ” refers to a gas stream having over 50 % ( by weight ) carbon dioxide . in one aspect , a final integrated acid - rich gas stream ( not shown ) includes the co 2 - rich gas stream and also includes predetermined concentrations of cos , and h 2 s ( not shown ), which have been further separated from the raw sygas stream by sulfur reduction subsystem 275 as described above , and optionally , tail gas treatment unit ( tgu ) 277 . in some embodiments , as shown in fig2 , after separating cos and h 2 s , the stream containing cos and h 2 s is compressed via compressor 300 prior to being mixed with the co 2 - rich gas stream and channeled to gasifier 208 via co 2 - rich gas stream conduit 224 . separation device 250 removes from about 15 % ( by total moles carbon dioxide present in syngas ) to about 50 % ( by total moles carbon dioxide present in syngas ) carbon dioxide - rich gas from the syngas . as noted above , the co 2 is channeled as co 2 - rich gas stream ( also referred to herein as “ recycled co 2 - rich gas stream ”) or with cos and h 2 s as final integrated acid - rich gas stream to gasifier 208 . separation device 250 is coupled in flow communication with gasifier 208 via conduit 224 wherein the recycled co 2 - rich gas stream is channeled in predetermined portions to gasifier 208 . as further shown in fig2 , co 2 - rich gas from device 250 is compressed via co 2 compressor 302 and is heated via co 2 heater 304 when channeled via conduit 224 . in operation , in one embodiment , o 2 and feedstock , via conduits 210 and 214 , respectively , maybe mixed with co 2 - rich gas , via conduits 224 and 402 , that has been compressed in compressor 302 and that may or may not have been heated in heater 304 . the resulting feedstock mixture is fed to inlets 306 a , 306 b , and 306 c of gasifier 208 , wherein gasification occurs , in accordance with conventional procedures , to produce syngas . it has been found that by compressing and / or heating the co 2 - rich gas prior to feeding a portion into a gasifier , an increased carbon conversion during gasification in gasification system 200 and subsequent processes in igcc plant 100 is facilitated . in one embodiment , the methods of the present invention can increase carbon conversion by up to about 3 % as compared to conventional gasification systems . the increased carbon conversion facilitates improving the efficiency of igcc plant 100 . more particularly , by increasing the carbon conversion in gasifier 208 , an increased concentration of carbon monoxide ( co ) is produced via the boudouard reaction : by increasing carbon monoxide production , a reduced oxygen consumption during gasification is facilitated , which further facilitates increasing igcc plant 100 efficiency . specifically , when the co 2 - rich gas is compressed , less oxygen is required during gasification as co produced in the boudouard and reverse water gas shift reactions provides an oxygen source . in one embodiment , the methods of the present invention can reduce oxygen consumption by up to about 2 % per unit of syngas production ( i . e ., hydrogen and co production ) as compared to conventional gasification systems . the co 2 - rich gas separated from the syngas mixture in a separation device 250 is typically compressed to a pressure in the range of from about 50 pounds per square inch to about 300 pounds per square inch above the pressure in gasifier 208 of a conventional igcc plant 100 . the gasifier pressure typically ranges from about 400 pounds per square inch to about 900 pounds per square inch . in another aspect , if the co 2 - rich gas is heated , less o 2 is required during gasification to heat the syngas . specifically , heated co 2 - rich gas is already being added to the syngas , and thus the temperature need not be raised to the extent of conventional gasification to produce the desired hot raw syngas . as such , a more efficient igcc gasification process is facilitated . compressed co 2 - rich gas typically has a temperature ranging from about 200 ° f . ( 93 . 3 ° c .) to about 300 ° f . ( 148 . 9 ° c .). when heated , the compressed co 2 - rich gas is typically heated to a temperature of from about 550 ° f . ( 278 . 8 ° c .) to about 700 ° f . ( 371 . 1 ° c .). for example , in one aspect , the compressed co 2 - rich gas is heated to a temperature of about 650 ° f . ( 343 . 3 ° c .). in addition to reduced oxygen consumption , a higher carbon conversion ( produced when co 2 - rich gas is compressed and / or heated ) can lead to a reduced hydrogen consumption via the reverse water gas shift reaction described above . in particular , co has a lower heating value as compared to h 2 . accordingly , by substituting co for h 2 in the gasification process , improved efficiency results . syngas produced in gasifier 208 exits the gasifier 208 at outlet 310 . as described generally above , the hot raw syngas is channeled to rsc 144 and csc 260 wherein the syngas is cooled and is then channeled to syngas scrubber 270 , ltgc unit 221 and , finally , to separation device 250 . in one aspect , the hot raw syngas may be cooled prior to being introduced into rsc 144 by mixing the hot raw syngas mixture at addition point 312 with a portion of compressed and / or heated carbon dioxide - rich gas separated by separation device 250 via conduit 404 to form a combined syngas mixture . the combined syngas mixture may then be introduced into rsc 144 via inlet 314 where it is cooled . it has been found that by mixing the hot raw syngas produced in gasifier 208 with a portion of compressed and / or heated co 2 - rich gas , igcc plant 100 can further be run more efficiently . specifically , as described above , the compressed and / or heated co 2 - rich gas increases carbon conversion via the reverse water gas shift reaction , thereby reducing the hydrogen consumption . because co has a lower heating value as compared to h 2 , co is also capable of being cooled more efficiently as compared to h 2 , thus resulting in a lower cost and higher efficiency igcc plant 100 . additionally , in some plants , the separation systems further include soot blowing in radiant syngas cooler 144 to blow off deposits of ash and slag on the tubes of cooler 144 . conventionally , nitrogen ( n 2 ) is used for the soot blowing . with the present methods , however , co 2 can be used in place of n 2 for soot blowing to provide further advantages . specifically , as co 2 is denser than n 2 , less co 2 is required for soot blowing . furthermore , it has been found that co 2 is easier to separate from the syngas as compared to n 2 . cooled syngas exits rsc 144 at outlet 318 and may be channeled to csc 260 for further cooling . particularly , in one embodiment , the syngas is further cooled to a temperature of about 900 ° f . ( 482 . 2 ° c .) to about 1600 ° f . ( 871 . 1 ° c . ), and more particularly , to a temperature of about 1300 ° f . ( 704 . 4 ° c .). once cooled , the syngas may be introduced into syngas scrubber 270 and ltgc unit 221 for removal of particulate matter entrained within the raw syngas stream and then introduced into separation device 250 to facilitate separation of at least some of the acid gas components into components that include , but are not limited to , co 2 , cos , and h 2 s . in one aspect , the cooled syngas exits rsc 144 and is mixed at addition point 320 with a portion of compressed carbon dioxide - rich gas , separated by separation device 250 to form a combined syngas mixture . typically , if compressed co 2 - rich gas is added at addition point 320 , the co 2 - rich gas is not heated in co 2 heater 304 . as the compressed co 2 - rich gas is not heated , it can allow for further cooling of the cooled syngas . once mixed , the combined syngas mixture is fed to inlet 322 of convective syngas cooler ( csc ) 260 where it is subjected to further cooling . cooled syngas exiting the csc 260 at outlet 326 is typically at a temperature in the region of from about 400 ° f . ( 204 . 4 ° c .) to about 800 ° f . ( 426 . 7 ° c .). the cooled syngas is then fed to syngas scrubber 270 , ltgc unit 221 and separation device 250 . while described herein as conducting consecutive addition points of compressed and / or heated co 2 - rich gas into the syngas mixtures of gasification system 200 , it should be recognized that the compressed co 2 - rich gas may be added at only one or two of the addition points described above without departing from the scope of the present invention . for example , in one aspect , syngas is first produced with only o 2 and feedstock in gasifier 208 ( i . e ., without the addition of compressed and / or heated co 2 - rich gas ) and the syngas mixture can then be mixed with a first portion of compressed and / or heated co 2 - rich gas at addition point 312 and cooled in rsc 144 . in another aspect , syngas is produced from o 2 and feedstock and cooled in rsc 144 . once the cooled syngas exits rsc 144 at outlet 318 , the cooled syngas can be mixed with a first portion of compressed and / or heated co 2 - rich gas at addition point 320 and further cooled in csc 260 . one additional advantage of using the methods of the present invention includes not requiring the inclusion of sulfur removal subsystem 275 in igcc plant 100 . in particular , as the compressed and / or heated carbon dioxide - rich gas is removed from separation device 250 and mixed again with syngas , the co 2 - rich gas does not have to be purified to remove sulfur . as a result , separation device 250 can be optimized to allow the co 2 - rich gas to contain sulfur . while the invention has been described in connection with what is presently considered to be the most practical and preferred embodiment , it is to be understood that the invention is not to be limited to the disclosed embodiment , but on the contrary , is intended to cover various modifications and equivalent arrangements included within the spirit and scope of the appended claims .