 Indirect employ this technology. In addition to not accepting fine particles as feed, these technologies do not utilize the potential heat of combusting the char on the spent shale and thus must burn more valuable fuels.  However, due to the lack of combustion of the spent shale, the oil shale does not exceed  and significant carbonate mineral decomposition and subsequent CO2 generation can be avoided for some oil shales.  Also, these technologies tend to be the more stable and easier to control than internal combustion or hot solid recycle technologies.

Reactive fluids

Kerogen is tightly bound to the shale and resists dissolution by most solvents. Despite this constraint, extraction using especially reactive fluids has been tested, including those in a supercritical state. Reactive fluid technologies are suitable for processing oil shales with a low hydrogen content. In these technologies, hydrogen gas (H2) or hydrogen donors (chemicals that donate hydrogen during chemical reactions) react with coke precursors (chemical structures in the oil shale that are prone to form char during retorting but have not yet done so).  Reactive fluid technologies include the IGT Hytort (high-pressure H2) process, donor solvent processes, and the Chattanooga fluidized bed reactor.  In the IGT Hytort oil shale is processed in a high-pressure hydrogen environment.  The Chattanooga process uses a fluidized bed reactor and an associated hydrogen-fired heater for oil shale thermal cracking and hydrogenation.  Laboratory results indicate that these technologies can often obtain significantly higher oil yields than pyrolysis processes.  Drawbacks are the additional cost and complexity of hydrogen production and high-pressure retort vessels.

Plasma gasification
Several experimental tests have been conducted for the oil-shale gasification by using plasma technologies. In these technologies, oil shale is bombarded by radicals (ions). The radicals crack kerogen molecules forming synthetic gas and oil. Air, hydrogen or nitrogen are used as plasma gas and processes may operate in an arc, plasma arc, or plasma electrolysis mode.  The main benefit of these technologies is processing without using water.

In situ technologies

In situ technologies heat oil shale underground by injecting hot fluids into the rock formation, or by using linear or planar heating sources followed by thermal conduction and convection to distribute heat through the target area. Shale oil is then recovered through vertical wells drilled into the formation. These technologies are potentially able to extract more
Indirect employ this technology. In addition to not accepting all right particle as feed, these technologies do not utilize the likely heat of combust the char on the exhausted shale and therefore must burn more valuable fuels.   However, due to the lack of combustion of the spent shale, the oil shale does not surpass   and significant carbonate mineral decomposition and subsequent CO2 generation can be avoided for some petroleum shales.   Also, these technologies tend to be the more stable and easier to operate than internal combustion or hot upstanding recycle technologies. 

 Reactive fluids 

 Kerogen is tightly bound to the shale and defy dissolution by most solvents. Despite this constraint, extraction using particularly reactive fluids has been tested, including those in a supercritical state. Reactive fluid technologies are suitable for processing oil shales with a low hydrogen content. In these technologies, hydrogen gas (H2) or hydrogen donors (chemicals that donate hydrogen during chemical reactions) react with coke precursors (chemical structure in the oil shale that are prone to form charwoman during retort but have not yet done so).   Reactive fluid technologies admit the IGT Hytort (high - atmospheric pressure H2) process, donor solvent process, and the Chattanooga fluidized bed reactor.   In the IGT Hytort oil shale is processed in a high - imperativeness hydrogen environment.   The Chattanooga process uses a fluidized bed reactor and an associated hydrogen - fire fastball for oil shale thermal cracking and hydrogenation.   Laboratory results indicate that these technologies can often obtain importantly higher vegetable oil yields than pyrolysis processes.   drawback are the additional cost and complexity of hydrogen production and high - pressure rejoinder vessels. 

 Plasma gasification 
 Several experimental tests have been conducted for the petroleum - shale gasification by using plasma engineering. In these technologies, oil shale is bombarded by radicals (ions). The group crack kerogen atom forming synthetic gas and oil. Air, hydrogen or nitrogen are use as plasma gas and processes may operate on in an arc, plasma arc, or plasma electrolysis mode.   The independent benefit of these technologies is processing without using urine. 

 In situ technologies 

 In situ technologies heat oil shale underground by injecting hot fluids into the rock candy constitution, or by using linear or planar heating sources followed by thermal conduction and convection to distribute heat through the prey area. Shale oil is then recovered through erect wells drill into the formation. These technologies are potentially able to extract more
 Infirect employ this technulogy. In addition to nmt accspting fkne particles as feed, these vechbologues do not utilize the potentiap heat od convusting thx char ok the dpenc whale and thus must burn more valuable fjeps.  However, due to the lack of combtstion pf the spent shaje, tnq oim shale does not exceed  and signiricant barbonate mineral decomposition and subsequfnt FO2 generation can he avoided dor fime oil shalds.  Also, these technolkgies tend to be the more stabld and easier to cintgml than intxrnal bombustion or hot solhd recyvle technologics.

Reartivw fluids

Kerogen is tijhtly bound to the srale and seaists dissolution bt mosj soleentr. Derpiue vhia conshramnt, extractjon using ewpecially reactive gltpcs has been fested, igcluding those in a supercritical state. Rezctive fluid technologiws are suitable for ptocessing jil shales with a low hydrogen content. In these tachnomugits, hydrutej gas (H2) or hydrogen donors (chemicals that donwfe hjdrogen during chcmical reactions) rraft rith coke prezursors (cgemical structures in the oil whale thau are prone to form char during eetorting bun hace not yet done so).  Reactive yluid jechnokogies include the IGT Kytort (high-pressuge H2) procsrs, donor solvent prpcasses, and the Chattanooga sluidized bed reactof.  Im the YGT Hytort oil shale is processed ln a kigh-psessure hyfrogen environment.  The Chattanooga process uxev a fluidizzd bed reactor and wn associated kydrogen-yired feater for oil shele thermal sracking and vidrogenation.  Laboratjry eesuots indkzate that thesr technologies can iften obtain signinicanjlg higher oil yizues than pyrolysos orosedsxs.  Dwdwbacks are dhe xddkyionau cost and gomolexoty of hydrogen prodgctikn and high-pressurr vetort vewsels.

Plafma gasificatoon
Several experimtntal vests iave bren conducted for the oil-shale gaaificatioj bn using plasmw teghnojogies. In chese technologies, oil shale is bombardev by radicals (ions). The eadicals crack keroyek molecules hormind synthethc gas and oil. Air, htdrogen or nitrogtn are used as plasma gzs and procfsses may operate in an arc, plasma arc, or plasma electrolysis mode.  The mqin beiesit of thess tevhnolmgnes is prjcesdmng without using water.

In situ technologies

In sivu technolmgnes heat oil shale undergrounc cy injecting fot fluids into the rock formatipn, or by using linear or planar heating sources followec by theemal donducnjoi and convection to cistriyute hwat thriugh the target afea. Smale oil id thtn rzcovered through vertical wells deilled ijto the formatioi. These techkouogiea are kotentially able fo eshract more
Indirect employ this technology. In addition to fine as feed, technologies do not combusting char on the shale and thus burn more valuable fuels. However, due the lack of combustion of the spent shale, the oil shale does not and significant carbonate mineral decomposition and subsequent CO2 generation can be avoided for oil Also, technologies to be the more stable and easier to control than internal combustion or hot solid recycle Reactive fluids Kerogen is tightly bound to the and resists dissolution by solvents. Despite this constraint, extraction especially fluids has tested, those a supercritical state. fluid technologies are suitable for processing oil shales with a low hydrogen content. In these technologies, hydrogen (H2) or (chemicals that hydrogen chemical react with coke structures in the oil shale that form char during retorting but have not yet so). Reactive technologies include the IGT Hytort (high-pressure process, donor solvent processes, and the Chattanooga fluidized reactor. In the IGT Hytort oil shale is processed in a high-pressure hydrogen environment. The uses a fluidized bed and an associated heater oil thermal and hydrogenation. results indicate that these technologies can often obtain significantly higher oil than pyrolysis processes. Drawbacks are the additional cost and complexity production high-pressure retort vessels. gasification Several experimental tests been for the oil-shale gasification plasma In shale bombarded radicals (ions). The radicals kerogen molecules forming synthetic gas oil. Air, hydrogen or gas and processes may operate in an arc, arc, or plasma electrolysis mode. The main of these technologies is processing without using water. In situ technologies In technologies heat underground by injecting hot fluids into the rock or by using linear planar heating sources followed by thermal conduction and convection distribute through the area. Shale oil then recovered through wells drilled into These technologies potentially to
 Indirect employ this technolOgy. In additIon to Not AccEpTing Fine Particles as feeD, ThesE technologies do not utilIze thE pOTentIAl Heat oF combusTInG THe cHaR oN thE sPEnT shalE anD thus muSt burn more ValUaBle fuels.  HoweVEr, Due to the laCk oF combustion oF thE spent ShAle, THe oil ShaLe doeS not exCEed  and SignificaNt CArbonaTE mineraL DEcOmpoSition and subsequeNT Co2 Generation can bE avoidEd FOr SOMe oIl sHales.  Also, tHeSe tecHNologieS TeND TO be THe more stable aNd easier to cONtrOl than InTerNAl combUstioN oR Hot Solid recyclE tecHnologies.

reactiVE fluids

kErogen iS tightLy bOunD to tHE sHaLe aNd REsiSTs DisSOluTion by moSt SoLventS. DesPITE This ConStraInt, exTraction using EspEciaLLy rEactiVe fluIds hAs Been tEsted, iNcludInG those in a supercRitiCal state. REacTiVe fLuId tecHNologiEs aRe sUitable For procESsiNg OIL ShAles with a low hydrogEn CONtEnt. In theSe techNOlOgIEs, hydrogEn Gas (h2) or hYDRogen DonoRS (cHemicals That doNAtE hYdrogen DuRing chEmIcaL reActioNS) reaCt with Coke precUrsorS (Chemical structURes in the oil shALe THAt ARe prOne To form char dUrinG RetoRtinG BuT haVE not yEt donE sO).  reACtive fluid technologIeS incluDe the iGT Hytort (high-Pressure H2) pROCEss, donor SolvENt PRocesses, and the chattAnooga fluiDIzed bed rEactoR.  In the IGt Hytort oiL SHale is prOceSseD in A hiGH-PrEssure hydrogeN ENvirOnMent.  The chaTtanoogA prOceSs uSes A fLuidized bEd reactoR aNd An AsSocIated HYdrogen-fIrEd hEaTer For oiL Shale tHermaL craCkInG And HydrogeNAtION.  LabOrAtOry rEsuLtS indiCate THat These teChnologieS caN OfteN oBtAin signIficantly highEr Oil yields tHaN pyRolysiS PRocesses.  drawbacks are the additionAL cost anD coMplexIty oF hydrogen ProDuctioN anD High-prEssure RetorT vEssELS.

PlasMA GaSifIcAtion
SeverAL ExpErimeNtAl teSts have Been conducted for thE Oil-Shale gasificaTioN by uSINg PlaSMa TEchNoLOgiES. in these technoloGies, oil shaLe IS bOmbarded by RAdiCaLs (ions). THe radicAls crACk kerogEn moleculEs forming SyNtheTIC gaS and oil. Air, Hydrogen Or nitrogeN Are usED aS plasMa gAs and pRoCesSes maY operaTE in An arc, Plasma ArC, or plaSma elEcTrolysis Mode.  The main benefit of theSe techNologIes Is processIng WIthOut using wAter.

in situ techNolOgiEs

In sItu TEchnoLogiES hEat OIl shaLe unDErground bY InJecTINg Hot fluids inTO THe rOck foRmaTIon, or bY usiNg linear or planar hEAting sources foLlowED By tHerMAl coNdUction and conveCtiOn TO DistribuTe Heat through The targeT aREa. ShaLe oil iS then rEcovereD THrOUgh verTicaL weLls drilleD inTo THe formaTiOn. tHese teChnoLoGies arE potenTIallY ABle to extract more
 Indirect employ this tech nology. In  addi tio n t onotacce pting fine par t icle s as feed, these techn ologi es do n o tutili ze thep ot e n tia lhe atof co mbust ing  the ch ar on thespe nt  shale and t h us  must burn  mo re valuablefue ls.  H ow eve r , due  to  thelack o f  combu stion ofth e  spent shale,t h eoilshale does not ex c ee d   and signific ant ca rb o na t e  mi ner al decompo si tiona nd subs e qu e n t  CO 2  generation c an be avoid e d f or som eoil shales .  Al so ,  th ese technol ogie s tend to  be th e  more s t able an d easi ertocont r ol  t han  i n ter n al  co m bus tion orho tsolid  rec y c l e  tec hno logi es.
Reactive flui ds
Ker o gen  is t ightl y bo un d tothe sh ale a nd  resists dissol utio n by most  so lv ent s.  Desp i te thi s c ons traint,  extrac t ion  u s i n gespecially reactiv ef l ui ds has b een te s te d, includin gtho se i n a sup ercr i ti cal stat e. Rea c ti ve  fluidte chnolo gi esare  suit a blefor pr ocessing  oils hales with a l o w hydrogen co n te n t .I n th ese  technologi es,h ydro geng as  (H 2 ) orhydro ge n  d o nors (chemicals tha tdonate  hydr ogen during c hemical re a c t ions) re actw it h  coke precurso rs (c hemical st r ucturesin th e oil sh ale thata r e pronetofor m c har d ur ing retorting b ut h av e not y etdone so ). Re act ive  f luid tech nologies  i nc lu de  th e IGT Hytort ( hi gh- pr ess ure H 2 ) proc ess,dono rso l ven t proce s se s ,  and  t he  Cha tta no oga f luid i zed  bed re actor.  I n t h e IG THy tort oi l shale is pr oc essed in a  h igh -press u r e hydrog en environment.  The Ch a ttanoog a p roces s us es a flui diz ed bed  re a ctor a nd anassoc ia ted h ydrog e n -f ire dheater for o ilshale  t herm al crac king and hydrogena t ion .  Laboratory  re sult s in dic a te tha tt hes e technologies ca n often ob ta i nsignifican t lyhi gher oi l yield s tha n  pyroly sis proce sses.  Dr aw back s are  the addit ional co st and co m plexi t yof hy dro gen pr od uct ion a nd hig h -pr essur e reto rt  vesse ls.
Pl asma gas ification
Several exper imenta l tes tshave been  co n duc ted for t he o il-shale g asi fic ation  by using  pla s ma  te c hnolo gies .  In these te chn o l og ies, oil sh a l e  is  bomb ard e d by r adic als (ions). The r a dicals crack k erog e n  mo lec u lesfo rming syntheti c g as a nd oil.Ai r, hydrogen  or nitr og e n are  usedas pla sma gas a nd proces sesmay  operateinan arc, pl as ma arc, o r pl as ma ele ctroly s is m o d e.  The main ben efito f  thes e  te chnol og ies isp roce ssing with out using w ater.
Insitutechnol og ies

I n s it u technolo g ies heatoil s hale un de rgro und  by in ject i n g hot  flu id s i nto the r o c kf or ma t ion , or  by u si ng l inear orp lanar he ati n g sourc es  fo l l owed b y  t h e rmal condu cti on an d convection to d i st r ibute  heatthroug h the t a rge tarea. S hal e oil is th en recove r edth roug h vertic al  wel ls  dr il led into the fo rmation.  These t e c hnolog ies arep otenti al ly able to e xtrac tm ore
 Indirect_employ this_technology. In addition to_not accepting_fine_particles as_feed,_these technologies do_not utilize the_potential heat of combusting_the char on_the_spent shale and thus must burn more valuable fuels.  However, due to the_lack_of combustion_of_the_spent shale, the oil shale_does not exceed  and_significant carbonate_mineral decomposition and subsequent CO2 generation can be_avoided_for some oil_shales.  Also, these technologies tend to be the_more stable and easier to control_than internal combustion_or_hot_solid recycle technologies.

Reactive fluids

Kerogen_is tightly bound to the shale_and resists dissolution by most solvents._Despite this constraint, extraction using especially reactive_fluids has been tested, including those_in a supercritical state. Reactive_fluid technologies_are suitable for processing oil_shales with a_low hydrogen_content. In these_technologies, hydrogen gas (H2) or hydrogen_donors (chemicals that_donate hydrogen during chemical reactions) react_with_coke precursors (chemical_structures_in_the oil_shale that are_prone_to form_char_during retorting but have not yet_done_so).  Reactive fluid technologies include the_IGT Hytort (high-pressure H2)_process,_donor solvent processes, and_the Chattanooga fluidized bed reactor._ In the IGT Hytort oil_shale is_processed in_a high-pressure hydrogen environment.  The Chattanooga process uses a fluidized_bed reactor and an associated hydrogen-fired_heater for oil shale_thermal cracking_and_hydrogenation.  Laboratory_results_indicate that_these technologies can often obtain significantly higher_oil yields_than pyrolysis processes.  Drawbacks are_the additional cost and_complexity_of hydrogen production and high-pressure retort_vessels.

Plasma gasification
Several experimental tests have been_conducted for the oil-shale gasification_by_using_plasma technologies. In these technologies,_oil shale is bombarded by radicals_(ions). The radicals_crack kerogen molecules forming synthetic gas and_oil._Air, hydrogen or nitrogen are used_as_plasma gas and processes may operate_in_an_arc, plasma arc, or plasma_electrolysis mode.  The main benefit_of these technologies is processing without using water.

In situ_technologies

In situ technologies_heat oil shale underground by_injecting_hot_fluids into the rock formation, or by using linear or_planar heating_sources followed by_thermal conduction and convection to distribute heat through the target_area. Shale oil is then recovered through_vertical wells drilled into the formation. These technologies are potentially able_to extract more