 is expensive and presents significant risks to the operator.
Another method that is conventionally used in the oil industry to treat paraffin deposits requires stopping the production, retrieval of the tubing, cleaning by scraping or steam-cleaning the inner wall of the well string to remove the paraffin and asphaltene deposits and then replacing the tubing back into the well. This method is also time consuming and costly and does not prevent future paraffin deposits in the pipes. The method is merely a maintenance procedure that works for a short period of time. Additionally, the risk of loss of production while the well is shut-in, coupled with the maintenance expense, makes many wells unprofitable to produce if such method is used.
Still another commonly employed method is a chemical treatment using solvents that are introduced in the well bore in an effort to dissolve or liquify the heavy alkanes, including paraffin and asphaltenes, and improve the flow of crude oil. Long-term injection of chemicals is expensive.
All these methods and systems have minimal success in addressing the problem as it occurs. The conventional tools are single units with limited heating capabilities that cannot be extended or scaled up to cover a greater zone of treatment. Furthermore, the electrical heating devices used in conventional downhole heaters tend to allow hydrocarbon leakage at electrical connections or at wire feed-through areas, which can cause failure of the insulation around the conductors and fire or explosion in the volatile environment downhole.
One of the more serious problems is the failure of the conventional tools to detect and monitor downhole temperatures at the vicinity of the heater and thereby regulate the temperature in the critical areas to provide long-term economical thermal treatment in the well.
An embodiment of the present invention eliminates the need to install, heat the formation and then remove the heater assembly of existing heater technology. Instead, an inline downhole open-annulus heater is deployed for long-term service that can be controlled and regulated from the surface as it heats the oil before it is passed through the production tubing and moved to the surface. As other well production hardware is removed from the well for service or replacement, the embodiment of the present invention may be removed and checked for continued serviceability in the well. This open annulus heater system can also be employed to generate steam for enhanced oil recovery by deploying the heater with a pass-through packer which, upon installation creates a limited longitudinal zone for steam soaking or injection.
Water pumped into the annulus triggers a valve on the packer to open dumping water on the heater, which is rapidly
is expensive and presents significant risks to the operator. 
 Another method acting that is conventionally use in the oil industry to regale methane series deposits requires stopping the product, retrieval of the tubing, scavenge by scraping or steam - cleaning the inside wall of the well string to remove the methane series and asphaltene deposits and then replacing the tube back into the well. This method is besides prison term consuming and costly and does not prevent future paraffin sediment in the pipes. The method is merely a care procedure that work for a short period of time. Additionally, the risk of loss of product while the well is shut - in, coupled with the maintenance expense, makes many wells unprofitable to produce if such method is used. 
 Still another commonly employed method is a chemical treatment using solvents that are introduced in the well tidal bore in an attempt to dissolve or liquefy the dense alkanes, including paraffin and asphaltenes, and better the flow of crude oil. Long - condition injection of chemicals is expensive. 
 All these methods and systems have minimal success in addressing the trouble as it occurs. The conventional tools are single units with limited heating capability that cannot be extended or scaled up to cover a greater zone of treatment. Furthermore, the electric heating devices used in conventional downhole heaters tend to allow hydrocarbon leakage at electrical connections or at telegram feed - through areas, which can cause failure of the insulation around the conductors and ardor or explosion in the volatile environment downhole. 
 One of the more serious problems is the bankruptcy of the conventional tools to detect and monitor downhole temperature at the vicinity of the heater and thereby regulate the temperature in the critical sphere to provide farseeing - term economical thermal treatment in the well. 
 An embodiment of the present invention eliminates the need to install, heat the formation and then remove the fastball assembly of existing fastball technology. Instead, an inline downhole open - ring heater is deployed for long - term service that can be controlled and regulated from the surface as it heats the oil before it is passed through the product tube and moved to the surface. As other well production hardware is removed from the well for service or replacement, the shape of the present invention may be removed and checked for continued serviceability in the well. This open annulus heater system can also be employed to generate steam for enhanced vegetable oil recovery by deploying the heater with a fall - through packer which, upon installation make a limited longitudinal zone for steam soaking or injection. 
 Water pumped into the annulus triggers a valve on the packer to afford dumping water on the heater, which is rapidly
 is expensive and presents rignificant risks to tie operztor.
Anotfer method that is conventioiallt usee in the oil industry go treat iaraffin eepowuts requirxa stopplug ths proburtion, retrieval of the tuting, cleaning ty seraping or steam-cleaning the inner wwll of yhf well string jo rekjve fhe paraffin and asphaltene deposifs and uhen replacing the tubing back into the well. Thid method is also tlme consumibg age costly and does not krzvent futurg paraffin deposits in the pipes. The kethod is neeelj a maintenaice prjcedure that works fmr a shprt period of bime. Eddirionally, the risk of noss of production while tha cell is shut-in, couplee qith jhe mdintdbanze txpxnss, maked meny wells uhprofitable to produce if such mqnnod is used.
Sfill agoeher commonly employed method is a chempcal treatment using solvenrs that are introducef in the rell bore in an effort to dissolve or liquify the heavb xlkckcs, ivxlkding paraffin and asphaltenes, and improve thq fkoe of crude oil. Long-term imjfcyyon of chemicxls is exlensive.
All these mfthods wnd ststems hade monimal success in addressint the problei as it occurs. The eonventional tooks arr single units with limnted hsating capahilities ffat cannot be exgenceg or scaled up to cover a dreater zine pf treagmenj. Furthqrmore, the elecbsical heating devifes udeg in convejtional downhole heaters tend to allow hydrocsrton leakage at ekectrical congections or at wire fzed-thruugh areas, which ran cause faylure of the hjsulation armund the coneuctirs and wire or explosoon in thv rolatile wnvironment downhoke.
Ovs of the more szxiius problems is thd fwipuce of dhe conventimnal touks to detect and ooniyor downhole temperadurea at the vicinity pf the heajer and trereby regulaye the temperature in tie crivical srews to provide long-term economidal thermwl breatment in ehe qell.
An embodnment of the present invention eliminatew the need to insjall, heat the formatipk and then rxmove ehe heates assembly of existibg heater technolpgy. Instead, an inline downhmle ooen-annulus heater is deployed for long-term service that can be controlled and rxgtlated from the surfdcz ax it hqats vhe oil before it is passed through the productiun tubinc cnd moved to the surface. As oyhdr well produztion hardware is removes from tne well for service or replacemrnt, the embodiment of thc present invehtion may ue removed and checkrd for contunued swrvigeability in tfe eepl. This ooen ennblus heater system can also be employed tl generate steam for enhanccd oil tecovery by deploying ths hezher wkth a pass-thrpugh packer whoch, upon installatiot sreates a limiued longitudinak zong for steam soaling or injaction.
Water pumped into the annulus triggers a valvg on the padker to o'en dumping wajec on the heater, which is rwpidly
is expensive and presents significant risks to Another that is used in the deposits stopping the production, of the tubing, by scraping or steam-cleaning the inner of the well string to remove the paraffin and asphaltene deposits and then the tubing back into the well. This method is also time consuming and and not future deposits in the pipes. The method is merely a maintenance procedure that works for a short of time. Additionally, the risk of loss of while the well is coupled with the maintenance expense, many unprofitable to if method used. Still another employed method is a chemical treatment using solvents that are introduced in the well bore in an to dissolve the heavy including and and improve the crude oil. Long-term injection of chemicals these methods and systems have minimal success in the problem it occurs. The conventional tools are units with limited heating capabilities that cannot be or scaled up to cover a greater zone of treatment. Furthermore, the electrical heating devices conventional downhole heaters tend allow hydrocarbon leakage electrical or wire areas, which cause failure of the insulation around the conductors and fire or in the volatile environment downhole. One of the more serious the of the conventional to detect and monitor temperatures the vicinity of the thereby the critical to long-term economical thermal treatment the well. An embodiment of present invention eliminates the formation and then remove the heater assembly of heater technology. Instead, an inline downhole open-annulus is deployed for long-term service that can be controlled and regulated from surface as the oil before it is passed through the tubing and moved to surface. As other well production hardware is removed from well service or the embodiment of present invention may removed and checked serviceability in well. open can also be employed to generate for oil recovery by deploying the with packer which, upon installation creates a limited longitudinal zone for steam soaking or injection. Water the annulus triggers a on packer to open dumping water on the heater, which is rapidly
 is expensive and presents sigNificant riSks to The OpeRaTor.
ANothEr method that is COnveNtionally used in the oil iNdustRy TO treAT pAraffIn deposITs REQuiReS sTopPiNG tHe proDucTion, retRieval of thE tuBiNg, cleaning by SCrAping or steAm-cLeaning the inNer Wall of ThE weLL striNg tO remoVe the pARaffin And asphalTeNE deposITs and thEN RePlacIng the tubing back iNTo THe well. This methOd is alSo TImE COnsUmiNg and costlY aNd doeS Not prevENt FUTUre PAraffin deposiTs in the pipeS. the Method Is MerELy a maiNtenaNcE ProCedure that wOrks For a short Period OF time. AdDItionalLy, the rIsk Of lOss oF PrOdUctIoN WhiLE tHe wELl iS shut-in, cOuPlEd witH the MAINTenaNce ExpeNse, maKes many wells uNprOfitABle To proDuce iF sucH mEthod Is used.
still AnOther commonly emPloyEd method iS a cHeMicAl TreatMEnt usiNg sOlvEnts thaT are intROduCeD IN ThE well bore in an efforT tO DIsSolve or lIquify THe HeAVy alkaneS, iNclUdinG PAraffIn anD AsPhalteneS, and imPRoVe The flow Of Crude oIl. lonG-teRm injECtioN of cheMicals is ExpenSIve.
All these metHOds and systems HAvE MInIMal sUccEss in addresSing THe prObleM As It oCCurs. THe conVeNTiONal tools are single unItS with lImiteD heating capabIlities thaT CANnot be exTendED oR Scaled up to coveR a greAter zone of TReatment. furthErmore, thE electricAL Heating dEviCes UseD in CONvEntional downhOLE heaTeRs tend tO alLow hydrOcaRboN leAkaGe At electriCal conneCtIoNs Or At wIre feED-through ArEas, WhIch Can caUSe failUre of The iNsUlATioN around THe CONducToRs And fIre Or ExploSion IN thE volatiLe environMenT DownHoLe.
one of thE more serious pRoBlems is the FaIluRe of thE COnventioNal tools to detect and moniTOr downhOle TempeRatuRes at the vIciNity of The HEater aNd therEby reGuLatE THe temPERaTurE iN the criticAL AreAs to pRoVide Long-terM economical thermal TReaTment in the welL.
An EmboDIMeNt oF ThE PreSeNT inVENtion eliminates The need to iNsTAlL, heat the foRMatIoN and theN remove The heATer asseMbly of exiSting heatEr TechNOLogY. Instead, an Inline doWnhole opeN-AnnulUS hEater Is dEployeD fOr lOng-teRm servICe tHat caN be conTrOlled aNd regUlAted from The surface as it heats the oIl befoRe it iS paSsed throuGh tHE prOduction tUbinG and moved tO thE suRface. as oTHer weLl prODuCtiON hardWare IS removed fROm The WELl For service oR REPlaCemenT, thE EmbodiMent Of the present invenTIon may be removeD and CHEckEd fOR conTiNued serviceabiLitY iN THe well. ThIs Open annulus Heater syStEM can aLso be eMployeD to geneRATe STeam foR enhAncEd oil recoVerY bY DeployiNg ThE Heater With A pAss-thrOugh paCKer wHICh, upon installatiOn creATEs a liMIteD longItUdinal zONe foR steam soakIng or injectIon.
WatEr puMped iNto the aNnUlus trIggErS a valve on tHE packer to Open dUmping wAtEr on The Heater, WhicH IS rapiDly
 is expensive and presents  significa nt ri sks  to  t he o pera tor.
Another m e thod  that is conventionall y use di n th e  o il in dustryt ot r eat  p ar aff in de posit s r equires  stoppingthe  p roduction, r e tr ieval of t hetubing, clea nin g by s cr api n g orste am-cl eaning the in ner wallof the we l l strin g to  rem ove the paraffina nd asphaltene dep ositsan d  t h e n r epl acing thetu bingb ack int o  t h e wel l . This method  is also ti m e c onsumi ng  an d  costl y and  d o esnot prevent  fut ure paraf fin de p osits i n  the pi pes. T hemet hodi sme rel ya  ma i nt ena n ceprocedur eth at wo rksf o r a sh ort  per iod o f time. Addit ion ally ,  th e ris k ofloss  o f pro ductio n whi le  the well is sh ut-i n, couple d w it h t he  main t enance  ex pen se, mak es many wel ls u n pr ofitable to produc ei f  s uch meth od isu se d. Still an ot her  com m o nly e mplo y ed  methodis a c h em ic al trea tm ent us in g s olv entst hatare in troduced  in t h e well bore in an effort tod is s o lv e  orliq uify the he avya lkan es,i nc lud i ng pa raffi na nd asphaltenes, and im pr ove th e flo w of crude oi l. Long-te r m injectio n of ch e micals is expe nsive .
All thes e  methods  andsystemshave mini m a l succes s i n a ddr ess i n gthe problem a s it o cc urs. Th e c onventi ona l t ool s a re  single u nits wit hli mi te d h eatin g  capabil it ies  t hat  cann o t be e xtend ed o rsc a led  up toc ov e r  a g re at er z one  o f tre atme n t.Further more, the  el e ctri ca lheating  devices used  i n conventi on aldownho l e  heaters  tend to allow hydrocar b on leak age  at e lect rical con nec tionsora t wire  feed- throu gh  ar e a s, wh i c hcan  c ause failu r e  of  thein sula tion ar ound the conductor s  an d fire or exp los ioni n  t hev ol a til ee nvi r o nment downhole. 
One of th em or e seriousp rob le ms is t he fail ure o f  the co nventiona l tools t odete c t  an d monitordownhole  temperat u res a t  t he vi cin ity of  t heheate r andt her eby r egulat ethe te mpera tu re in th e critical areas to pro vide l ong-t erm  economic alt her mal treat ment  in the we ll. 
An  embo dim e nt of  the pr ese n t inv enti o n elimina t es  th e ne ed to insta l l ,  he at th e f o rmatio n an d then remove the heater assembl y of e xis tin g  hea te r technology.Ins te a d , an inl in e downholeopen-ann ul u s hea ter is  deplo yed for l on g -termserv ice  that can  be  c o ntrolle dan d  regul ated  f rom th e surf a ce a s it heats the oil  befo r e  it i s  pa ssedth rough t h e pr oduction t ubing and m oved t o th e sur face. A sotherwel lproduction hardwareis re moved f ro m th e w ell fo r se r v ice o r re pl ace ment, the e mb o di me n t o f th e pre se nt i nventionm ay be re mov e d and c he cke d for co n ti n u ed service abi lityi n  the well. This op e n ann ulus h eatersystemc anal so be e mpl o y ed to gen erate ste a m f or  enh anced oi lreco ve ryby  deploying theheater w ith a pa s s -throu ghp acke r  which ,upon install ation  c r eates a l imi ted lon g itu din alzone  fo r st e am soaking or injection. 
Wat er pu m ped  into  thean nulus tr i gger s a valv e  on the packe r to open dumpi n g w a teront he  h eater, wh ich is ra pidl y
 is_expensive and_presents significant risks to_the operator.
Another_method_that is_conventionally_used in the_oil industry to_treat paraffin deposits requires_stopping the production,_retrieval_of the tubing, cleaning by scraping or steam-cleaning the inner wall of the well_string_to remove_the_paraffin_and asphaltene deposits and then_replacing the tubing back into_the well._This method is also time consuming and costly_and_does not prevent_future paraffin deposits in the pipes. The method is_merely a maintenance procedure that works_for a short_period_of_time. Additionally, the risk_of loss of production while the_well is shut-in, coupled with the_maintenance expense, makes many wells unprofitable to_produce if such method is used.
Still_another commonly employed method is_a chemical_treatment using solvents that are_introduced in the_well bore_in an effort_to dissolve or liquify the heavy_alkanes, including paraffin_and asphaltenes, and improve the flow_of_crude oil. Long-term_injection_of_chemicals is_expensive.
All these methods_and_systems have_minimal_success in addressing the problem as_it_occurs. The conventional tools are single units_with limited heating capabilities_that_cannot be extended or_scaled up to cover a_greater zone of treatment. Furthermore, the_electrical heating_devices used_in conventional downhole heaters tend to allow hydrocarbon leakage at electrical_connections or at wire feed-through areas,_which can cause failure_of the_insulation_around the conductors_and_fire or_explosion in the volatile environment downhole.
One of_the more_serious problems is the failure of_the conventional tools to_detect_and monitor downhole temperatures at the_vicinity of the heater and thereby_regulate the temperature in the_critical_areas_to provide long-term economical thermal_treatment in the well.
An embodiment of_the present invention_eliminates the need to install, heat the_formation_and then remove the heater assembly_of_existing heater technology. Instead, an inline_downhole_open-annulus_heater is deployed for long-term_service that can be controlled and_regulated from the surface as it heats the oil_before it is_passed through the production tubing_and_moved_to the surface. As other well production hardware is removed_from the_well for service_or replacement, the embodiment of the present invention may be_removed and checked for continued serviceability in_the well. This open annulus heater system can also be employed_to generate steam for enhanced oil recovery by_deploying the heater with a pass-through packer_which, upon installation creates_a_limited longitudinal zone for steam soaking or_injection.
Water_pumped_into_the annulus triggers_a valve on_the packer to_open dumping_water on the_heater, which_is rapidly