Separating carbon dioxide and hydrogen sulfide from a natural gas stream using co-current contacting

专利摘要:
Systems and methods for separating CO2 and H2S from a natural gas stream are provided herein. The system includes a first loop of co-current contacting systems configured to remove H2S and CO2 from a natural gas stream and a second loop of cocurrent contacting systems configured to remove the H2S from the CO2.
公开号:DK201500692A1
申请号:DK201500692
申请日:2015-11-05
公开日:2015-11-23
发明作者:Charles J Mart；J Tim Cullinane；Paul Scott Northrop
申请人:Exxonmobil Upstreamres Company；
IPC主号:

专利说明:

SEFARATING; CARBON DIOXIDE AND HYDROGEN SOLFIBE FROM A NATURAE GAS STREAM USING CO-CURRENT CONTACTiNG SYSTEMS
CROSS-REFERENCE TO RELATED APEUCATiON
fXRIfif. This application claims tile benefit of U.S< Provisional Patent Application 61/821,618 Died May 9, 200 entitled SEPARATING CARBON DIOXIDE AND HYDROGEN SUEFIDE FROM A NATURAL GAS STREAM USING CO-CURRENT CONTACTING SYSTEMS, the entirety ofwhich is incorporated by reference herein.
FIELD OR THE INDENTION
The present teelmkfues provide Or the separation of carbon. difeddb {€%): and hydrogen sulfide {'IBS) Bora a natural gat stream using eo-eurrem contacting systems. More specifically, fee prexem, ieclmlqhex provide fertile separation^ of COr and HsS fmtn uriatyral gas stream,,its well as: the separation of the CQy#Om theHrife «sing a series of cd-earrenf confecting systems.
BACKGROUND
pilot This section is intended to introduce various aspects of die arty which may be associated with exemplary embodiments of the present techniques.: This·: description is believed, to assist in providing a iranteworE to faeiiitate a better understanding of particular aspects of the present teelmiques. Accordingly, it should be midersfeod that this section should be read in. this light, and not necessarily as admissions of prior art.
11)0941 The prodnetiosi of hydrocarbons .from, a resetvotr oftentintes carries with it the ineidentaliprodnetioa of ttosi-ltydrocarbon gases. Spelt gases include contaminants such as Itydrogen sniEde (HjE) and carbon dioxidefCCX}, WhenByS or CO are produced as part of a hydrocarboti gas stream, such as methane or efeaue., die raw natural gas is sometimes referred to as a ‘ΤοίίΕ’ natural gas. The IBS and GDa are often referred to together as 4kacid gasesT
1000S| Sour natural gas must be treated to remove the FES and CO before it can be used as »ti '^ttvimm»eAt»lly-aces|daile' fmt As an example, ferBNG, fee TITS and GEE must be removed to very low levels, e,g,s less than about 50 parts per miliiotrEy vohtme (i^myfCCE and less fean about 4 ppmv IBS. As another example, for pipeline gas, fee IDS nmst be removed to a very lew level, e.g, less than about 4-ppmv, while the CO may be ramuvsd to a lesser extent, POOfr! Gsyoienie gss processes are sometimes used to remove QG2 ,f#i» raw aatural gas stream to px&em Ifr® freeing and ori&e plugging. In addition, particularly with HeS; romoval, the hydrocarbon fluid grearn may bo treated with a solvent, Solvents may include chemical solvents such as amines, Examples of amines used iu sour gas treatment include monoethanoi amine (MBA), diethanoi amine tDBA), and methyl diethanoi amine (MDEA).
100Ii | Physical solvents are sometimes used in lieu of amine solvents. Examples include Sefexof* and Eeetisol'5’. In some insimsees, hybrid solvents, meaning mixtures of physical and ehomieal solvents, have been used. An example is Snlimolfe In addition, the use of amine-based add gas removal solvents Is common.
10000! Amine-based solvents rely on a chemical reaction with the acid gases. The reaction process is sometimes referred to as ‘^s sweetening.- Such chemical reactions are generally more effective than the physieaEbased solvents:, partlcnlarly at feed gas pressures below about 300 psia (2,07 MPa). Them aroiustances where special chemical solvents such as Flexsorh** are used, particularly for selectively removing EyS from CQ^eontainmg ps streams.
!0OO9| As a result of the gas sweetening process, a treated· or Sweetened” gas stream is created. The sweetened gas stream:is substantially depicted oFBcfr and €(¾. The sweetened gas .stream can ibmfrriher processed for liquids recovery, that ist by condensing out heavier hydrocarbon gases. The sweetened gas stream: may be sold inter a,$peitne: m-mf'hs used for liquefied natural gas (LKG) feed if : the concentrations of FbS and CO are low enough, In addition, the Sweetened gas stream may be used as feedstock for a gas-to-Iiquids process, and then ultimately used fb ,m&fee .Ihbriean^-ftyi^l^ Or other petroleum-based products.
10010! Known counter-current contactors used for removing ffrS and CCfr from natural gas streams tend to he large and very heavy. This crs»fe$ ;.p®rtfc«)ar: and gas production: implications, where smaller equipment is desirable. Further,:the transport and set-up of large tower-based facilities is difficult for shale gas production operations that:: freq uently take place: m remote locations.
The removal of H S and GO from a natural gas stream produces a rich solvent: including the FfrS and CCfe. The rich solvent is sommlmes referred to as an absopent liquid. Following removal of the TBS and CCB, a process of regeneration (also called "desorption") may be employed jo separate the B>S and C0> item tee active solvoat of she absorbent liquid. This produces a lean solvent.
1001¾ Regener&jiba of teeleao solvent generates a concentrated mixture of the Ha'Si and IS psl§. In some cases, this mixture can be sent to a Claus sulfur recovery unit to convert- Use B>: S to elemental sulfur. However, in many cases, the high ratio of €0¾ to ITS readers the mixture uasuhablo for use as a Claus feed stream, in such eases, tee acid gas most be enriched prior to being:used as a, Gians feed stream. This may be accomplished via a low pressure: enrichment process that uses; a selective amine id preferentially absorb ;H,S, In principle, the remaining gas % this case could be used as a. substantially clean (although low pressure) €0¾ stream, p)D| Alternatively, a, "supeHselective" H,:S removal process may be used: on a sour gas stream: to remove substantially: ail of the HyS, and to generate a eosteenttafed acid: gas stream suitable ter Cl aus feed. This would obviate tee need for an acid gas enrich merit (AGE) dipt, saving substantial : costs, A subsequent COs removal process could be used to : generate a substantially clean: CO2 stream, as well as sweetened uainral gas. The: extracted; 0¾ may then be sold, or it may be in|eeted into a subterranean reservoir for enhanced oil recovery CEOR) operations.
|00f4| I.LS, Patent Application PiiMication Mo. 20(^/0241778- by Leehni-ek et ah describes a syst^-for-i^0^»g::CO^60ia--a feed gas within aa absoteer unit teat eon tains a solvents arid regCfi^t&g/te^:§Qlve{^Vwd&b-'MiMc^b>r,: However, bceat^C the absorber unit and eductor are likely to be large and very heavy, such a system may be expensive and undesirable, particularly for Offshore oil and gas rsfeovery applications,
SUMMARY
(IM5J An exemplary embodiment provides a system: for sepaiming 0¾ and H S from a natural gas sfreatil The system includes a first loop of co-currept contacting Systems configured to remove I US and CO from a natural gas Stream,: and: » second bop; Of co-current contacting systems configured; to remove tee H3S .fern the COj, fOOltd An cxentplary embodiment provides a method for separating CCb and H jS Item a natural gas stream. The method includes contacting a sour natural gas stream mciuding CCb rind H S with a lean solvent stream within a Erst scries of co-eurreni contacting systoms, generating a sweetened riatyral gas stream; ami a rich solvent Ntrcam including the CCA and. the;HXS, The method melodes eontaefirig the rich solvent siream with a shipping gas within a second series of co-current contacting -systems, regenerating tie lean so!vent stream and generating a first gas stream including the €0¾ the H>S, and the stripping gas, and reeimularing the lean solveM stream to the first series of coummmt eontaeting systems. The method also includes contactingthe first gas stream with a leau H3S“Selecfive solvent stream within a third series of eo-entrem contacting systems, generating a rich ffiS-seleetive solvent stream inehtding the HnS and a second gas stream including the €(¾ and the stripping gas. The method further includes contacting the rich fTS-scieetive solvent stream with a stripping gas within a fourth series of co-current contacting systems;,-' regenerating the loan 1TS-selective solvent stream; and generating a third gas stream including the ITS and the stripping gas, and reeireniarmg the lean fibS-selective solvent stream to the third series of eo-eutrenf contacting systems,
Another exemplary embodiment 'provides a system for separating (¾ and HvS from a natural gas stream. The system includes a first scries of Co-enrrent contacting systems eohfigured to contact a soar natural gas stream including C0:> and ITS with a lean solvent stream to generate a sweetened natural gas stream and a rieh solvent stream Including the C% and the ITS. The system includes a second scries of co-current contacting systems configured to contact the rich solvent stream with a striding gas to regenerate the lean solvent stream and generate a first gas stream Mnding the CDu the bbS, and the stripping gas, wherein the lean solvent stream ls: recirculated to dte first series of ep-current contacting systems, The system also mchtdes a third series systems configured to contact the first gas stream with a lean fTS-seteive solvent stream to generate a rich ITS-selective solvent stream including the and a second stream htciudlng: the €(¾ and the stripping; gas. The system ihriher includes a fourth series of eo-eurrem contacting systems eohfigtired to contact the rich MsS-seieetive solvent stream with a strippmg gas to regenerate the lean H^S-seleetive solvent stream and generate a third gas stmarn mcluding the IrTS and the stripping gas, wherein tire lean lTS~se!eetive solvent stream is reelmuiafed to the third series of co-current contacting systems, ftfifi Another exemplary embodiment provides & method for selectively removing one gaseous eomponeut from a mulii-component gas stream, The method includes flowing a lean solvent stream into a mixer of a co-current contactor via an annular support ting .-'and a number of radial blades extending fi'om the annular support ring,. wherein the annular support: ring secures the mixer in-line within a pipe. The method also includes flowing a multi-· compdoeni gas: streatft Incltiding a. first gaseous component and a second gaseous component kto-.ihe mixer viw: a: central gas enttw cone that.ih supported ..by the radial: blades., wherein a first portion of the multi-component gas stream flows.through the central gas entry cone and a second portion of the muhirttomponeni gas stream flow» around the central gas entry cone between the plurality of radial blades. The method also includes contacting the multicomponent gas stream with the lean solvent stream within the mixer and a mass transfer section of the fbij^yide fomcoi$K>r#o» of liquid droplets formed from the lean solvent stream into the multi-component gas stream, wherein the liquid droplets include the first gaseous component from the multi-component ps stream. The method finther Includes separating the liquid droplets horn the mu hi-compo nent gas stream within a separation system, generating a rich solvent stream including the first gaseous component ami a gas stream including the second gaseous component
BRIEF DESCRIPTION OF THE DRAWINGS
1-001^1 The advantages of the present teehstlques are better understood by referring to the following detailed deseription and the attached drawinp, m which: f$020|i Fig* 1. is a process flow diagram: of a chemical sbiveut-based gas processing system; 10O21J Fig. M is a generalisted process flow diagram of a system for recovering carbon: tioxide (COj) and hydrogen sulfide (fES) ifoai a natttrai gas stream Chat includes a co-current flow1 scheme; 10022} Figs, 2B-1 and 2B»2 are a process flow diagram of an exemplary embodiment of the systenrof Ftg, 2A; 10022} Fig*: 3 is: a schematic of a. coiunin. fer separating a feed stream into a gas stream hud a liquid stream; 10034} Fig, 4A; is: a; process flow diagram of a separation system including;» number of eo-e«n-ent eohtaetlitg systems that may be: placed in a shell; 1002^1 Fig, 4E is a process flow: diagram of the separatiost system of Fig, 4A including the co-current contacting systems with the addition of a number of heat exchangers; |0026| Fig. 4C is a process flow diagram of the sepamflon system of Fig, 4A including the cu-eumtta eoniaeting sy stesns with the addition of one or more flash timms; 10027} Fig. R is a process flow diagram of a gas regenemtion system inefeding a number of co-current contacting systems;
Fig. 6 is: a process flow diagram of a. separation: system .for preferentially removing o« comporrencfe stream; mm j% is a schematic of a co current. contacting system; f#03$! Fig, BA is a front view of a miser; P03 M Fig, BE is a side petxpeetivc view of the mixer; flKBil Fig. BC is a cMS-seciioimi side perspective view of the mixer; &m Fig. 80 is a another : etoss-sectional side perspective view of tire itiken f0034f Fig. § is a process flow diagram of a method for separating 0(¾ and H S flwm a natural gas stream; and
Fig. 10 is a process flow diagram of a method for selectively removing one gaseous component from a multi-component gas stream.
DETAfLED DESCMPTiON
ttMM in the following detailed description section, spccifle embodiments of the present techniques are described. However, to the extent that the following description is spccifle to a partioular embodiment or a particular use of the present teclmiques, this Is Intended to be for exemplary purposes only and simply provides a 'description· of the exemplary: embodiments. Accordingly, the teehtiitfues are hot limited to; the specific embodiments described below* bnt rather, include all alternatives. modiflc&tioits, and: eqnivaiems: felling within the true spirit and scope of tlte appended claims.
At the outset, for ease of reference, certain terms used in. this application and their meanings as usedln this context are Set forth. 1¾ the exienfa term, used herein is not defined below, it should & given, the broadest deflnitioti persons in the pertinent art have given that term as reflected in at least one printed ..'publication· or issued patent. Further, die present techniques are not limited by the usage; of the terms hhown below, as all equivalents, synonyms, new developments, and terms: or techniques that serve the same Or a: similar pupiosc afeeonsideretl to be wnhinths scope of the present claims, iliiihj *Acid gas" refers to any gas: that produces an acidic solution when: dissolved: in water, feohdimiflng examples of acid gases include hydrogen::sttifide fH;>S):, ea;ilton dioxide (C®i% sulfur dioxide i'S€b|, carbon disulfide (CSy), carbonyl sulfide (COS^ mCrcaptans, or mixtures thereof ffe13¾ ^--current qo.ttfeetorw refers to a «esse! feat receives a gas stream and a separate solvent stream in such a mmm. feat the ps stream and fee solvent stream contact one an other while flowing in generally the same direction. Non-limiting examples include an eductor and a coalescer, or a static mixer plus dehqmdfoer.
{$040] Tito term "eommrremly" refers to; feeinternal arrangement of process streams within a unit operation that can. be divided into several sub-sections by winch the process Streams Sow in fee same direction.
piMif As used herein, a "column" is a separation vessel in which a counter-current flow is used to isolate materials on fee basts of differing poverties. In an absorbent column, a liquid solvent is Injected into the top. while a nnxture of gases to be separated is flowed into the bottom. As the gases flow upwards through fee: felling stream of absorbent, one gas species is preferential^ absorbed, lovvering-:%t^ccnfrationJR::the vapor stream exiting the top of the column, while rich liquid Is withdrawn from fite bottom.
10042] In a distillation column, liquid and vapor phases arc conritcttcurrently contacted to effect separation of a fltud mikfnre based on boiling points or vapor pressum dificrehces. Tlfe high vapor pressnm, or lower boiling, efenponem will fend to eoneeferafe in the vapor phase, whereas the low vapor pressure, or higher boiling, component wiii tend to concentrate in the liquid phase. Cryogenic separation is a feparafion process cattied out in a ool umn at least in. part at temperatures: at or below ISO degrees Kfelym (K), To enhance fee separation, both types: of columns may use a series of vertically spaced frays or plates mounted within the column and/or packing elements such: as sfruemtsd or random packing: Columns may often have a recirculated stream at the base to provide heat energy for boiling fee fluids,: which. Is generally referred to as foebofengfo Further, a portion of the overhead vapor may be condensed and pumped back into the top of the column as a reflux stream, which can be used to enhance the separa tion and purity of the overhead product. A bulk liquid stripper is related to a column. However, fee bulk liquid Stripper functions without the use of a reflux stream and, thus, cannot produce a higlt-purltyi Overhead product, ffeMAj "Dehydrated gas: stream" refers to a natural gay stream that has; undergone a dehydration process. Typically fee dehydrated gas stream has a water content of less than 50 ppm, and preferably less than 7 ppm. Any suitable proeesa for dehydrating the natural gas stream can. be used. Typical examples: of sttltabie dehydration ortfeesses include, but are not limited to, treatment of the natural gtorsttoarniWife. molecular sieves or dehydration using glycol or methanol Alternatively, the natural gas stream can be dehydrated by formation of methane hydrates; lor example, using a dehydration process as described in WD2004/070297.
|iW4| As used herein, the term refers to The prefreatment of a raw feed gag; stream t« partially or completely remove water and, optionally, some heavy hydrocarbons. This can be accomplished by means of a pre-cooling cycle, agains! an external cooling loop or a cold internal process stream, for example. Water may also be removed by means of px;-ureatmeM with molecular sieves, e,g. zeolites, or silica pi or alumina oxide or other drying agents. Water may also be removed by means of washing with glycol, monoethylene glycol (MEG), diethylene glycol (DEG), iriethyiene glycol (TEG), or glycerol. The amount of water in the gas feed stream is suitably less than 1: volume percent (yol preferably less than 0.1 vol%, more prefembly less than 0.1)1 vol %.
1004¾ Tire term "distillation”' (or ^$©&>«8ίκ>η*). refers to the process of phpicaliy separating chemical components into a vapor phase and a liquid phase based on difeerenees in the cotnponenis’ boiling points and vapor pressures at specified temperatures and pressures. Distrlkiiou is typically performed hr a ridistilfetfoe egtefe ' which iuGtides a series of vertically spaced plates, A feed stream enters the distilMimr coltnno at a midqmiat, dividing the distillation cote» info two sections. The fop section may be referred to as the rectification section, and the bottom section may be referred to as the stripping section. Condensation and vaporization occur on each plate, caasing lower boiling point components to rise to the top of the distillation Column and higher boiling point components to foil to the, 'bottom, A reboiler is located at the base of the distillation eolufoh to add. thermal energy. The “bottoms” product is removed from the base pf the distillation Column, A cotidehser is located at the top of t he distillation column: to condense the product emanafing, ;&otn the'top of the distillatipueohunh, which is called the distillate. A reflux pump sis: used to maintain flow in the rectilcation section of the distillation, column by pumping a portion ttf the distillate back into tire distillation colimuv I004f| The term, ^hhaneed oil ipo-very” (EGR) refers to processes for enhancing the recovery of hydrocarbons from subterranean reservoirs. Techniques for intproving displacement efficiency or sweep efficiency indy be used for the exploitation of ati oil field by ihirodueihg: displacing fluids or gas into'injedtion wells to drive oil through the reservoir to producing welfo.
1011471 As used -herein, the term ‘fluid" may be used to refer to gases, liquids, combinations of gases and liquids, Combinations of gases and solids, or combinations of liquids and solids.
fifMffl The terra “flue gas54 refers to any gas fitreaia generated as a byproduct of hydrocarbon combustion, |804l] The termTgas" is used interchangeably with foapor,” and is defined as a subst&nce or mixture of substances in the gtiseous state as distinguished from the liquid or · solid: state. Likewise, the term "liquid” means a rSitbstauce or mixture of substances in the liquid stats as distinguished tom. the gas Of solidAtate.
fflfiSfif: A “hydro^fho#· is m organic compound that primarily includes the elements hydrogen and carbon, although nitrogen, salim oxygen, metals, or any number of other elements may he present in small amounts. As used herein, hydrocarbons generally refer to components found in natural gas, oil, or chemical processing faeilnies, (:8051. With respect to fluid processing eqnipmpfo the term “in series” means that two or more devices arc placed along a flow line suoh that a fluid stream undergoing fluid sepai»tion moves tom one item of equipment to the next while maintaining flow in a substantially constant downstream direction. Similarly, the term “in line" means that two or more components of a fluid mixing and separating device are connected sequentially or, more preferably, are integrated into a single tubular device.
100521' "Liquefied natural gas" (LHC) is natural: gas .generally known to include a high percentage of methane. However, IB(3 may also iodlnde trace amounts of other elements or compounds. The other elements or compounds may include, but are not limited to, ethane,, propane, butane, C03, nitrogen, helium:,: E-$, or any combinations thereof, that have been processed to remove one or more components: (for instance, helium) or impurities (for instance, -water, acid gas, and/or heavy hydrocarbons) and then condensed into; a liquid at almost atmospheric pressure by cooling, 10053] The term “liquid solvent” refers to a fluid in substantially liquid phase that preία carnally absorbs one component over another. For example, a liquid solvent may prefeentmiiy absorb an acid gas, thereby removing or “scrubbing” at least a portion of the acid gas component from a gas stream or a wafer stream.
10854] “Natural gas’* refers to a rmbiLcomponent gas obtained tom a etude oil well of from a subtormnean gas-bearing formation, The composition and pressure of natural gas can vary signifleandy; A typical natural gas stream contains methane; (C'Hn as a major component, i.e.. greater than 50 mol % of tire natural gas stream is methane. The natural gas stream can also contain ethane (OH*), higher molecular weight hydrocarbons (c.g., CvC ,, hydrocarbons}. one or more acid gases te.g., CO> or IBS), or any combinations ihereofi The natural gas cam also contain minor arnouhis of ebtUamluants such as water, nitrogen, iron sulfide, wax, crude od, or any combinations thereof The natural gas stream may he substantially purified according to embodiments described herein, so as to remove compounds that, may act as poisons.
1005¾ fefenmbsotbiitg gar refers to a gas; that is not significantly absorbed by a solvent; during a gas treating or conditioning process, |d0Sri|: “Solvent” refers to a substance <^able%1^iin.fart''qf<^#lvi»g or dispersing one or more other substances, such as to provide or Conn a solution. The solvent ;tnay be polar, uonpolari neutral, probe, aprotie, or the liM, Tits solvent may melude any suitable element, molecule, or compound, such as methanol, ethanol, propanol, glycols» ethers, ketones, other alcohols, amines, salt solutions, ionie liquids, or the like. The solvent may include physical solvents, chemical solvents, os the like. The solvent may operate by any suitable median ism, such as physical absorption, chemical absorption, or the like P§57f “Substantiar when used in reference to a quantity or amstynt of a material, or a specific ehameterisiie thereof refers to an amount that is snStcfent to provide ah effect that the ntaigrial or characteristic was intended to prevlde. The exact degree of deviation allowable may depend, in some cases, on the specific context.
|00S§)' The. term “Sweetened gas stream5" refers to a fluid stream in a substantially gaseous phase that hah had at least a portion oFaeid gas components removed, iiiasQfefe |005fr| lie present techniques provide fbr tlfe sepamtibn of G’fb ;ώκΙ ITS from a natural; gas stream, as well separation of the CC|:from the %S,: ping» series of co-eurrenf contacting systems. More specifically, in various enfepdiMehts, the' GQs end ITS are separated from the natural ga$ stream by contacting the natural gas stream with a solvent stream within a first series ssf co-current contacting systems. The resulting sweetened, natural gas stream: may then be sold into a: pipeline; or used to:produce UNO, for example, : The FfrS and €();> are then removed from; the solvent stream by contacting the solvent stream with a stripping gas within a second series of eoreurrent contacting systems. In addition» the B#is removed from the 0¾ by contacting the stripping gas including the B2S and the 0¾ with an MB-selective solvent: stream within a: third series of coreummt contacting systems; Further, "the H|$ is removed from the Bfo·-selective solvent stream by omtacimg the Hfo-sdeetive solvent stream with a stripping gas within a fourth;· series oico-current contacting systems,. The recovered CCT, may theft he sold or injected Into ft.subten&neaa .reservoir for enhanced oil recovery (BORJ operations, andltie recovered HjS may be sent to a CDi&as suffttr recovery unit to he converted Into: elemental sulfur, for example.
fOOUfo The: ase of a isorles of co-current contacting systems for natural gas: processing and solvent regcmsirnttmt #na^ jittow Ί^τ* reduction in the size of the overall system as compared to systems fltai otilfoe counteweurrent flow schemes. This:may, m torforaduce the operating; costs for the system.
j00611 Fig. 1 Is a process flow diagram of a: chemical solvenhbased gas processing
System 100, The gas processing system 190.ti^:W:U8#'td:-^tu0veSWUtier':f^>i^..a raw natural gas stream I §2, generating a dehydrated natural gas stream 104. This may 'he accompli shed by flowing the raw natural gas stream 102 httoa contactor 10¾ which may remove the water ifom. the raw natural gay stream 1:02, The dehydrated natural gas stream 104 may then be flowed out of the contactor 106 as an overhead strestm In: addition, residual water and acid gas components ihay be removed tft connection with a suhsedUeftt process, as described forth er herein.; 100621 The raw natofal gas siraam 102 ..may be obtained from a snbsnrtkce mssrvoir 108 via any suitable type of hydrocarbon: recovery operation. The raw natural gas stream 102 may include a non-absorbing gas, such as methane. In addition, the raw natural gas stream 102 may include acid gas, such as 11>S and €C1>. For example, the raw natural gas stream. 102 may include about 0 % to 10 % ITS and about 0 % to 10 % CO , along with the hydrocarbon gas,
IfliKJ M Shown in 1¾ 1, the raw natural gas stream 102 may be flowed into an Mat separator 110 upon entry into the gas processing system 100. When entering the inlet separator 110. the raw natural gas stream 102 may be Under a large amount of pressure, liowever, the pressure of the raw natural gas stream 102 may vary considerably, depending on the characteristics;of^the subsurface reservoir 1ΙΪ8 from which the gas product is produced. For example, the pressure of the raw natural gas stream 102 may range between atmospheric pressure and several thousand psig, ptossuiie of the raw natural gas stream 1.02 may be boosted to about 100 psig or about 500 psig, :or greater, if desired.
f§fM4|; The inlet separator 110 may clean the taw natural gas stream.102, for exmupfo. to prevent foaming of liquid solvent dating a later acid gas treatment process. This may be aoemuplished by separating the raw natural gas Stream info liquid-phase components and gas-phase components, The liquid-phase components may include heavy hydrocarbons, a small portion of water, and impurities such as brine, fracturing fluids, and drilling fluids. Such components may be llowed out of the inlet separator l l fi via a bottoms line 114 arid may be sent to an oil recovery system lid. The gas-phase components may incl ude nattna! gas and some amount of impurities, such as acid gases and water. Such components may be flowed out of the inlet separator 118 as the overhead natural gas stream 112.
tfofofo From the inlet separator 110, the natural gas stseam 112 may be flowed into the contactor 10b. The contactor 106 may use a desiccant, such as a liquid gtjmol stream US, to absorb water In the natural gas stream It , The liquid glycol stream 118 may include various glycols, such as iriefoylens glycol, among others. The liquid; glycol stream 118 may be stored in a glycol tank 128, A high-pressure pump 122 may feme foe liquid glycol stream 1:1:8 from t he glycol tank; 120 into foe contactor 100 under suitable pressure. For example, the high-pressure pump 122 may boost the pressure of the liquid glycol stream 118 to about 3.500 psig or about 2,500 psig, depending: on the pressure Of the raw natural. gas stream 102.
18808} Once inside the contactor 106, gas within the natural gas stream 112 moves upward forengl the .contactor 108, Typically, one or more trays 124 or ptber internals are provided withitt the contactor 186 to create indirect flow: paths for the natural gas stream 112 audio create Interfocial area between the gas and liquid phases. At foe same time, the liquid from tie liquid glycol :strcam 118 moves downward1 and across the succession of trays 124 in the contactor 1.06. Tie frays 124 aid in foe interaction of the natural, gas stream 1.1:2 with tie liquid glycol stream 1.18.
18867} The contactor 106 operates on foe basis of a. counter-current flow scheme,: in other words, the natural gas stream 112 is: directed, through foe:contactor 106 in one direction, while the liquid glycol stream 118 is directed through the contactor 186 in the opposite direction. As the two fluid materials interact, the down-flowing liquid glycol stream 118 absorbs water from the up-flowing natural gas stream. 112 fo produce the dehydrated natural gas stream 184.
|8868| Upon exiting tie contactor 106, the dehydrated natural gas streafo 104 can be flowed through an outlet separator 126. The outlet separator 126. also referred to as a scrubber, may allow any liquid glycol carried over fern the contactor 106 to fell out of fee dehydrated natural gas stream 104. A final dehydrated natural gas stream 121 may he flowed out of the outlet separator 120 via an overhead hue 130. Any residual liquid glycol 132 may drop out through, a bottoms line 134.
100601 A spent desiccant stream 06 may flow out of the bottom of the contactor 106. The spent desiccant stream 136 may be. a glycol solution that is rich in #e absorbed water. The spent desiccant strearu 136 may be: at a relativefy high temperature, such as about 90 °F to about 102 ^1¾ or higher.: lu various embodiments, the gas processing system 18C1 includes equipment: ^ ^generating the liquid glycol stream TIB from fee spent desiccant stream 136, as described fiirther hercin, 1δ020]:: From the contactor 10C the spent desiccant stream 1.36 .may be heated within a heat exchanger 138 md then flowed into a regenerator 144. Tlte regenerator 144 may be used to regenerate the: liquid glycol sterna 118.·tom the spent desiccant stream 136, The: regenerator· 144 may be a large: pressure vessel, Or interconnected series of pressure vessels, that operates at about .15 psig to about 35 psig, for example· Tho mgeneraior may include a feboiler 140 that i8-'e0iiplM'6>v»-6feMfetto»'Cdlutiw)i. 142.
if07l) The spent desiccant stream 136 can be flowed through a tube bundle 146 in fee top of the distillation : column 142. BighAemperamre water vapor and off-gases 148 being released from the distillation eoluntn 142 may preheat: the spent desiccant stream 136 as it flows through the tube bundle 146, before thewater; vapor and off-gases 148 are released via an overhead line 150, |WT2| After being preheated within tile dlstfllation column 142, fee spent desiccant stream 136 may be released from the tube bundle 140: as a warmed glycol stream 152. The warmed glycol stream J52 may be flowed into a flush drum 154. The flash drmn 154 may operate at a pressure of about 50 psig to about IfX) psig, fee example. The flash drum 154 may have internal parts that create a mixing effect or a tortuous flow path for the glycol stream 100731 fedduai gases 156, such as methane, FBS, and; GO , may be flashed out of the flash drum 154 via an overhead line 158. The residual gases 156 captured in the ovefltead line 158 pray be reduced to an acid gas content of about 100 ppm if contacted with an amine. This concentration of acid gases is small enough that fee residual gases 156 eua be used as fuel .gas fer the gas processing system 100.
101174] 1« addition, any entrained: heavier hydroetuhoss, such as hexane or: benzene, within. the glycol stmam/182 may be separated within: the Bash dram 154 as g liquid : of lesser density that the .glycol The reselling hydrocarbon stream 160 may be flowed ouigfthefiasb drum 154 via a bottoms time 162.
|00I5| Further, as the temperature and pressure of the glyco l stream 152 drops within: the flash drum 154, glycol stream: 152 am sepatmed outyph>dm;iog a partiallypurified glycol stream 164, The partially-purified glycol stream 164 may then he released from the Sash drum 1S4, The patlially-ptuiled glycol stream 164 may be Sowed through a Slier 166, such as a tnechaulcm Biter or earhoh filter, B>r pariiele Sltratibu, 1101761 Tile resulting filtered glycol stream 168 may then be Sowed through a heat exchanger 170. Within die heat ehehunger 170, the filtered glycol stream 160 may be heated via heat exchanp with the liquid glycol stream 118; The resulting high-tempemture glycol stream 174 may be Sowed into the distillation Column 142 of the regeneralor 144c As the high-temperature glycol stream 174 travels through the distillation column 142, water vapor and off-gases 148, such as HyS and €0¾ may be removed from the high-temperature glycol stream 174, 10077] The MghTemperature glycol stream 174 may be flowed out of the bottom of the distillation column 142 and Into the reboiisr 140, In. addition, the reboller 1:49 may boil off residual watervapor And ofFgases 148 from the high-temperature glycol stream 174. The components that are boiled off may travel upward through Che distillation column. 142 and fee. removed as the water vapor and off-gases 148 in the overhead line 1,50.
Ithf78| The regenerator 144 may also include a separate stripping section 176 fed from: the liquid pool in the mboiler 140; The stripping section 176 may include packing that promotes further distillation, as well as dry stripping gas, e,g„ eryogeitkally-genemted nitrogen. Any: mmaiuingTnipurities, such as water, ITS, and/or GO; , boil off and join the water vapor and ofBgases 1.48 in the overhead line 150. -TMMgMemperature/gly^ 174 may then he flowed Into a surge tank 1.78, tom: which if may be released as the liquid glycol stream 118, 10070| The regenerated liquid glycol stream 118 may be pumped out of the surge tank 178 via a booster pump 180, The booster pump 180 may increase, the pressure of the liquid glycol stream 11:8 to about 50 psig, for example.
f§M0! The ..liquid glycol stream 118 may then fee flowed through the heat exchanger im is which the liquid giycol stream, l it may be partially cooled via hear exchange with the ilfered glyedi steam 168 TheJiqio^giyeo! stream 111:; may he stored to the glycol tank 120; The Mghqmexsure pump 122 may then three, the liquid glycol stream 118 from the glycol tank 120 through a. coder 182 prior to being mturned to the contactor 106. Tire cooler 1.82 may cool the liquid glycol steam 118 to ensure that the glycol will: absorb water when. It is returned to the contactor 106:. Fbf example, the cooler 182 may chill the liquid glycol stream 118 to about 10(1-F or 1:25 T.
fOOtiff The process flow diagram of Fig, 1 Is not intended to indicate that the gas processing system 180 is to include all of the components shown In Fig. 1. Further, any number of additional components may fee mckded within the pis processing systetn 100* depending on the detailsof the specific implementation, For example, additional heat may be provided to the mbotier 140 to assist In flashing: off the water. Farther, the gas processing system 100 may ineiude any shitabte types of heatem, chillers, condensers, liquid primps, gas compressors, blowers, bypass lines, other types of separation and/or fractionation equipment, valves, switches, ernttrollers, and pressitre-measurlng devices, mmperamm-mcasurifeg devices, level-pleasuring devices, or fiowqsteusnrmg devices, arndng others.
100821 Fig, i. demons times the rise of a known contactor 106 in the context of a gas dehydration process. However, the gas processing: system 100 is abb substantially representative of h sour gas removal operation, In that instance, the liquid stream 118 includes a chemical solvent, such as a:primary atninc, a secondary amiue, or a tertiary amine. The liquid stream 118 maysalso fee^ ah ionic liquid or a blend of a physical solvent with: an amine. For purposes of discussion, the liquid .Stream; it'8 may fee interehappafeSy referred to herein as an amine, a: chetnicai sfelyeht. or an absorbent liquid, 100821 In: some embodimerfep a: .'Solvent that preferentially removes IdjS molecules Over 'CO nioleedfes may fee used. For: example, a tertiary amine typically does not effectively Strip out CQe as qtiicfely as lb$ Therefore, two separate gas processing systems 100 may be sequentially operated, with one edltllgnred to strip out primarily TfeS, and the other configured m Strip: put 'primarily CQ&, A separate CCfe shmm that Is snfestanfially fmc of If >S may also fee generated, |0§84f Regardless of the application and the solvent used, the disadvantage of gas processing systems that include counter-current flow schemes, such as the gas processing system 180 of Fig* 1, is that comparatively low velocities arc reqtdred to avoid entrainment of fee dowK-flowmi; liquid solvent In fee natural gas stream 192. Also, relatively long dlsta«ees are teqaifed for d isengagement of the liquid droplets to® fee natural gas stream 102, Depending on fee Sow rate of the natural gas stream 102, fee eoMaetor 106 can be greater than 15 feet m diameter, and mom than 100 feet tell For high-pressure applications, the vessel has thick, metal walls. Consequently, counter-current contactor vessels can be large and very heavy. This is generally undesirable, particularly fer olfehore oil and gas recovery applications.
|hi8S|:: la fee gas processing system 100 of Mg. 1, the; contactor 100 includes a single coutaetmg tower. However, in some applkarions, mom than one contacting tower may be used. In addition, very large contactors may be used for high-volume, high-pressure applications. In fee case of low-pressure applicaismw, such as GDa femoval from flue gas at a power generation pi ant, it is estimated feat a 50 loot by 50 fem: duet contactor would be used for a relatively small, 500 megawatt power plant fine gas application. Many hundreds·' Of gallons per minute of solvent would also be flowed femngh the contactor. Thus, such operations may become very costly, ffefefe Further, the internals of the tower Hid can make it ..susceptible to wave motion m an offshore environment. llterefere, b may be desirable to Ifeve: a mass transfer p'tKtess that does not rely on conventional tower internals. For eaan^le, it may bo desirable to utiliae a series of low pressure-drop, small contacting devices to remove GGyand HaS ifora flash-gas streams, i008T| Embodiments described herein. udliEs e co-cnrrent flow scheme as an alternative to the cownter-cmrent flow seteme demonstrated in the contactor 106 of Tig. 1.,. The co-eturent flow scheme ntiliaes one m nmm co-curmm contacting systems connected in series within a pipe, A natural gas stream and a liquid solvent may move together, i.e., co-currently, within the Co-currenf contacting systems. In some embodiments, the natural gas stream' and the liquid solvent move together generally along fee longitudinal axis of the respective co-current contacting system, in general, co-cxtireut contactors can operate at much higher fluid velocities than countermurfent contactors. As a result, co-current contactors tend to be -utilize standard packed or trsyed towers.
mmi Fig. 2 A is a pneraliisd process flow diagram of a system 200 for separating CCh and IDS from a naturai gas stfeam feat ineludes a oo-curmnt flow scheme. The system 200 may function as an all-in-one gas prbcessihg system, solvent regenerstibh system, and acid gas recovery system., Moreover, the system: j08 may be: an alternative-10: the gas processing: system i# described with respect to Fig, 1.
|0O89| The system 200 may employ a number of co-current eonigeiing: systems (CCCS's). Specifically. the system 100 may employ a first- series of co-current contacting systems 202A, a second series of ee-eorrent coaiactmg systems 202B, a third series of co-current contacting systems 202C, and a fourth series of co-current: contacting systems 2020, Moreover, ;t w to be understood that the system,288 is not 'limited to the series of Go-current contacting ss siems 202Α~© shows in Fig, 2. For example,is some embodiments, the system 200 spay ottiy include the first arid second series of co-current contacting systems 202.4 and 202Bs Or tuay only include rise first, second, and fish'd series of eo-emrent coat»:ting systems 202:4-0, depending on the details of the specific implementation. In other embodiments, the system 200 may include any number of additional series of eo-eorisnt contacting systems not shown in Fig, 2, iOOFfij Each co-current contacting system within the scries of eo-current contacting systems 2024-15 includes a eo-current contactor upstream: of a separation system. In. addition, each series of eo-current contacting systems 2Q2A-i> may include my number of co-current: contacting systems connected in series. Further, hi some embodiments, one or more Of the series of co-current contacting systems 202.4-1) may inchtde Only one co-current contacting system.
lOOflj According to the embodiment shown in Fig, 24, the first series of co-current contacting systems 202A contacts a sour natural gas stream 204 if pm: a hydrocatfioo production operation,; ior example, with a: lean solvent stream 20#, producing a sweetened natural gas stream 208 .and a, rich, solvent: stream 210 including €0y and HsS. In various: embodiments, the sweetened natural. gas stream 208 is then sold into a pipeline of used to produce LNG, |0002I From, the first series of eo-current contacting systems 2024, the rich solvent stream 210 % flowed into the second series of co-current contacting systems 282B, along with a stripping gas 20, The second series of eo-currem contacting systems 282® contact the rich solveut stmam 21.8 with the stripping gas 212, regenerating the lean solvent stream 20# and producing a gas stream 214 including the stripping gas, CO*, and H2S. in various embodiments, the lean solvent stream 206 is then recirculated to the first series of co-ourrent contacting systems 202:4..
mm From the second series of eo<®m:ftt contacting systerna 292E, the gas stream 214 including the stripping gas, CO2, and M3S is flowed into the thin! series of cowurrent eomaeting systems 282C, along with a lean fBSwelective soivent stream 216. The third series of eomurreni contacting systems 262G contacts the ps stream 214: with: the HaS-selective solvent stream 216, producing a gas stream 21$- that includes the €0¾ and the stripping gas, as well as a rich B#weleciive solvent stream 220 that includes the BgS. In some embodiments, the COj. within the gas stream 218 1$ then sold pr injected Into a subterranean reservoir Ibr enhanced oil recovery (BOR) operations.
piMp From the third series of eo-currcm contacting systems 202€, the rich M2$~ selective solvent Bream 220 is flowed into the fimrih series of eo-entTent eontaeting systems 292J.X along with a stripping gas 222. The fourth series'of co-currentcontacting systems 292l> contact the rich H-dSwelective solvent stream 226 with the stripping gas 222, repn erating the lean FI ^-selective solvent stream 216 and prodneing a gas stream 224 including the H:>S and the stripping gas. In various embodiments, the lean BrS-selecdve Solvent stream 216 is then ^circulated to the third series of cd-eurrcnt eontaeting systems :.20213, la addition. In some ethbodlments, the ByS within the pa stream 2241$;thensent to a Clans sotfnf recovery unit to be converted into elemental sulfur.
fd095j Mgs, 2B-1 and 2B»2 Be a process flow diagram of ah exemplary emflodlmeut of the system 200 of Mg, 2A. Like numbered items are as deserted with respect to Fig, 2.4. The sbnf natural gas stream 204 may be flowed through: ah inlet separator 226. The inlet separator 226 may he used to clean the soar natural gas strearn 204 by filtering out impurities, such as brine and drilling fluids. Some particle filtration may also take place. Hie cleaning of the sour natural gas stream 264 can prevent foaming of solvent during the acid gas treatment process.
f0066j In Some emhodhnents, the sour natural gas stream 294 may also he pretreated upstream of theinlet separator 226 or the first series of co-current contacting systems 202A, For cxamplcv the soar natumf ps stream 204 may nndesgo a water wash to remove glycol or other ehemicai additives. This may be accomplished via a separate processing loop (not shown) wherein water is introduced to the giW, sneh as via an additionaf co-cnrrenteontaetihg system. Water has an affinity for glycol and will pull thy glycol out of the spur hattrrai gas stream. 264. This, in turn, will help control foaming within the first series :pf co-current contacting systems 2624, in the ease of flue gas applications, corrosion jnhlMfors may be:: addedlto the solvent to retard the reaction of Cb with the steel in the processes.
From the inlet separator 226,, the soar natural. gas stream 204 may be flowed into thefirst series oFeo^eamiat contacting systems 262A, where: it is mixed with: the lean solvent stream: 206. I'te solyem streai® 206: may include an amine solution, such as monoethanol amine (MEA^ diethanol amine (DEAf or methyldielhanol anfine tMDEA), Other solvents, such as |Aysfeai soivesiis, alkaline salts solutions, or ionic liquid», may also he used for H S removal in vamm^bodrmeam, the lean solvent stream 206 is a solvent stream that has undergone a desorption process for the removal of held gas impurities, Specifically. the; lean solvent stream 206 introduced into the first series of ep-curfent contacting systems 202A includes lean solvent that has been regeneratedvia the second series of eoromTcht contacting systems 202 B.
fOOMf: The first series ol co-current contacting systems 202A may include sis co-current contacting systems 22SA^F connected in series. Each corourrfent contacting system 228A“F removes a portion of ttte acid ps content, i,e„ the €0¾ and flsS, fern the natural gas stream 204, thereby: releasing a, progressively sweetcued natural gas Stream in a downstream direction. The final eofonrrent. contacting: system1 228F provides the final sweetened natural gas stream 208.
pOhh|: The sour natural gas stream 204 is flowed into the fimt co-curtem contacting
System 220A within the first series ofco-otuTcnt cdutaeting systems 202A, lu addition,, a first partially-loaded, or ri'ichA solvent stream 230A is flowed from the second co-current contacting system 228B into the first eo-entrem: contacting system 228A, Once: Msidc the first co-enrrent contacting system 228A, die sour natural gas stream 204 and the first pariiaHy-loaded Solvent stream 230A move along dfo longittidinsi axis of the first co-current contacting system 228A. As they travel, the first partially-loaded solvent shears 23ftA interacts with the C& and ITS in the sour natural gas stteani 264, eaushtg the GOy and HtS to chemically attach, to or bo absorbed by the amine molecules of the first partially-loaded solvent stream 230A, The rich solvent stream 216 may then be flowed out of the first co-current contacting system 228A, In addition, a fimt partially-sweetened natural gas stream 232A may be flowed set of the first co-current contacting: sys tem 228A and into: a second eo-CUrrem contacting system 22:88, jb Ibbj A third eoromreut eorpactmg system 228C may be provided after the second eo-current contacting system 228B, and a iouith co-current contacting system 2280 fttay be provided after the third co-current contacting system 228C1 In addition, a fifth co-current contacting system 228E may be provided after the fourth co-curroni contacting system 2281), and a final co-current contacting system 22® may be provided after foe fifth eo-e«rtent containing system 22®. Each of the second, third, fourth, and fifth co-current contacting systems 238B, 228€, 2281), and 22® may generate a tg^gctme- ' gas stream 232B, 232€, 232B, and 232:E. In addition, each of the fond, fourth, fifth, and final eo-currerrt contacting systems 228C, 228¾ 22®, and 228F tnay generate restjective partially-loaded solvent stream 230B, 230C, 230¾ and 33®. If an amine is used as the solventstream 2® foe partially-loaded solvent strfom 230A-E may inetude rich amine solutions.
pi l l | As dm progressively-sweetened natural gas streams 232A-E are: generated,, the gas pressure in the system 200 will gradnPly decrease. As this oecnm, the liquid pressure of the progress!vely-ncher solvent streams 230A-E may be correspondingly increased. Tins may be aeeomptished by placing one or more booster pnmpfoot shown) between each do-current contacting system 228A-P to boost liquid pressure in thesystem 200.
|0iO2| The rich solvent stress» 210 exiting foe first series of concurrent contacting systems 202A is flowed through a flash drum 234. Absorbed nammi gas 23d may be Hashed Irom. the rich solvent stream 2X0 within the flash: drum 234, and may he ftowed out of the flash drum 234 via an:overhead line 230.
ΡΪ031 The pch solvent stream 22b is tlren fipwed from foe flash drum 234 to the second senes: of co-current contacting systems 202B, The second series of co-current: contacting systems 202B may include sis eo-current contacting systems 240A-F connected -in series. Eaehco-cnmmt contacting system 24fiA-F removes a portion of the CCb and HjS from the rich solvent stream.210, thereby: releasing the lean solvent stream 200 and. the gas stream 214 including the stripping gas, CDs,: and E^S. The lean solvent stream 200 may then be recirculated to the first: Series of eoreurrent contacting systems 202A, while the gas stream 214 may be flowed Into the third series of co-current contacting ::sysie5ns l02€, 101041 In various embodiments, the stripping gas 21,2 is flowed into the first co-current contacting system, 240A within the second series of co-cnrrent contacting systems 202B. in addition, a first patiialfo-tmloaded, or 'lean,” solvent stream 242A is flowed from the second co-current contacting vstem:;240J| into the; first co-eutretri: contacting system 240,4. Dace inside the first: co-current contacting system 240¾ the stripping gas 212 and foe first parfiaUy-uuioaded solvent stream 2424 move along the longitudinal axisoft foe first co-current contacting system: 24§A, As they travel, the first partially-unloaded solvent stream 242A interacts With the stripping gas 212, causing any remaining 0¾ and TfiS within the
first partially-unloaded solvent stream 242A to chemically detail or desorb from the amine molecules to the stripping ;gas 11%,. The resulting lean solvent stream 206 may then he flawed out of the first cp-current contacting system 240A within the: second seri&&; of co-eurreftt contacting systems 202B, and may fee recliCefated to the first series of co-current contacting systems 202A, In. addition, a firstigas miMure 244A mcfodmg the stripping gas; the (30¾ and theIfiS may fee flowed: out the first eo-emfent contacting:system 240A and into a second co-current contacting system 240B
A third eo-current contacting system 240C may be provided after the second co· current contacting system: 240B, and a fourth co^emvent contacting system 240D may he provided after: the third co-currm contacting system 2400, In addition, a fifth eo-current contacting system 240E may be provided 'after the tnurih eo-cnrmnt eoftmcting system 240Di shd a final co-current contacting system 24SF may be provided ate the fifth do-current contacting system 240E. Each of the second, co-Cnn-enf contacting systems 240B, 24θ€* 2401), and 240E may generate a respective gas mixture 244Β» 2440, 244Ϊ), and 244E including CCri and H:$ In addition, each Of the; third, fourth, fifth, and final eo-eutam contacting systems 240C, 240D, 240E, add 240F may generate respective partiaIiy~anioaded isai:yent stream 242B, 242C 242D, and :242E, 10106] FnSh the second series of eomUrreat contacting systems 202.¾ the resulting.fas stream 214 including the stripping gas, and FES is Sowed into the third series of eo-current contacting systems 202C. The third series^ of cd-edrreni contacting: systems 202C may include six: co-etifrent contacting systems 240A-F connected in series. Each co-cumm! contaetlng system 246A-F removes: a portion: of the %S from the gas stream 214¾. thereby relcasmgthe. rich HyS^eieerive solvent stream 220 mcfodmg the' H Sfohd the gas stream 210 Inelnding the 0Oj and she stripping, gas. The C0r within the gas: stmdnl 21ft may .then be used as: pari, of a miscible BOR operation to recover oil, tor example, .fit addition, the: rich H; :S-seiecfive solvent stream 220 may be Bowed. Into the fourth series of: co-current: eontacting systems 2020 for the: removal ofiheKjS:, {01.07) In various: embodiments:, the gas stream 214: kcludmg: the shipping gas:, 0¾....and HaS is ftpwed into the first co-current, contacting System 246A within life third seriefoof eb-current contacting systems 2020, In addition, a firsi::pariialiy~loadedcO;r “fitch,” FfiS-selCCtM: sbiveftt stream 248A including some amount of IBS is flowed from the second co-cdrfeih contacting system 240B into the first co-current contaefing system 240A, (lace inside the first co-current contacting system 240A, the gas stream 2:1:4 and the partially-loaded MyS- selective solvent stream 248A move along the longitudinal ads of the first· co-current contacting system 246A, As they travel, the first gardaliydoaded H>S-selective: solvent stream 248A interacis with the %S within the gas stream 2X4, causing the H2S to chemically attach ¢0 or he absorbed by the molecules of the first partially-loaded BjS-seleciive sol vein stream 248A. The msaiiing rich H3$-seIeeiive mbmt stream 226 inclndmg dm B3S may then be flowed out of the third series of co-current contacting systems 202€ and into the fourth series of odmhrrem contaefittg systems 2621). in addifiom a first gas mixture 256A including the stfipping gas and the CP&. as well as a decreased amount of the Baft, may be flowed out of the first co-current contacting system 246A and into a second co-cmrent contacting system 2461, |§ eomarrent eontaefing system 246C may be provided· after the second eo- cummt eontaeting system 246B, and a fourth bo-current contacting system 2461> may he provided after the thIM co-current contacting system 24#C. fit addition, a fifth co-current contacthtg sj^tem 2461 may lxsproviiW::after and a final eo~emtent contacting system 246F may be provided alter the fifth co-current contacting system 2461. Each of the second, third, fourth, and fifth co-currem contacting systems 246B, 24d€. 246l>, and 2461 shay generate a respective gas mixture 2508. 256C2, 2560, and 2S0E Sncltiding the stripping gas and the €0¾ as well as progressively decreasing amount of B2S,. In addition, each of the third, feurih, fifth, and final co-current contacting systems 246C, 2461), 2461, mid 246F may genemte respective paraallydoaded Hjft-se|ective solvent streams 2488, 248Cft248R and 2481.
idihhj In. various embodintitts, the HjS·selective solvent stream that is used within she third series of co-cnrreht:; contactmg systems 262C is a specially-designed solvent; that enhahees'the selectivity of Hj:S over €(¾ within the cd-cdfreat contacting systehB 246.A-F. .Acid gases react reversibly with solvents via diflcreni: mates. For example, in the: ease of physical solvents such as: methanol, absorption: occurs due to van der Waals attraction for the polar HyS and polarizable CQ:> molecules,. M another example, in the case of chemical solvents such as amines, the:reaction is chemical in nature:.
iftflftl Specifically, tor H3S.: the only route is an acid-base reaction, as shown below in (2).
m2s(a<&^ H-'B/r $) m,m2r3 + tv- w h$~ ~ + //r a)
In Eq, ¢2), Ri ( and ffo represent organic substituents attached to the nitrogen atom of die tertiary amine. With tertiary amines, CCh can reset only via As aeifofeaae route, as shown below in Bqs. (3)-(5).
H,0 f COz <··> |fo,C<Tj (3) [%COs] ro H* + HCO-J (4) NR^R2R:. + Hi f HC(K <·» NHR^R^I -l· HC03 (3) if the amine is a secondary amine that Includes one hydrogen atom attached to the nitrogen atom, or a primary amine that includes two hydrogen atoms attached to the nitrogen atom, COj can react to form a carbamate, as shown below in Hq. (6).
cm + 2rvr2nh m liiPi <fo pi 1 l l |; Bees esc CCH and EHS reset with ehemteat solvents via such different rentes,; the; me of a speeiaiiy fomigned solvem within the eerourront eontaenng systems deaerihed herein may allow for the selective removal of H-jS from a gas Stream that ihefodesi both . MjS and COj. In various embodiments^ the specially^designed solvent is a tcaiary amitre. However, it Is to be nndersiood that the specially-designed may also be any other suitable solvent that is capable of selectively absorbing IBS over GQ^sueh as merieally-hittdered aminesi P112| Because the. IBS reaction, is almost instantaneous relative to the GCH reaction, lowering the residence time of the gas stream. 214 and the JfoS-selecti ve solvatt htream within each, ed-eurrent contacting systems 246A*F:may enhance the selective removal of H*S from thefgaS stream. 23:4; Therefore,; the co-current contacting 'systems 240A-F may be designed· such: foat the residence time is relatively short folll) The rich HjS-selecilve solvent stream 220 including the H;>S may he flowed from the third scries of co-current eobt&cting: .systems 2fl2€ Into the fourth scries of co-current ctmiactiug systems 2021) for the recovery of the %S. and regeneration of the lea* HaS-selective solvent stream, 210. The fourth series of co-current contacting systems 2020 may ittehide six: co-current contacting systems 252A«F connected in series. Bach eo-eirrenf: contacting system 252A-F removes a portion of the HaS from dm rich IBS-selective solvent stream 220, thereby releasing the lean HjS-seieetive solvent stream 21hand the gas stream 224 including the IBS and the stripping gas, The leanTiaS-selective solvent stream 21 h may then be -r<^tmttlat€^H0''tetl»rd.hpnM of co-current contacting sptems 202G, M addition, the IBS within die gas stream 224 may then be converted into efemehM sulfur nsihg a Claus nuIfur recovery «ait.
|fi51/41 la various embodiments, the skipping gas 222 is flowed into ike first co-ciirrefli contacting system 2§1A within ike fourth series of co-current contacting systems 202B. In addition, a first partially-unloaded, or 'leanf’ H>$~seiective solvent stream 254A is flowed fom Ike second co-eunear contacting system 2528 into die first co-current contacting system 252A, Once inside ike first eo-cap-ent contacting system 252A, ike skipping gas 222 and ike first pariially-ynloaded lI>.S-seiectrvc solvent stream 2ΜΑ: move along ike longitudinal axis of the firnt co-ctmrent contacting system 252,4. As they travel ike first parfially-indoaded Av I:fiS~sei;eetiye solvent stream 2§4A. Interacts with die stripping gas 222, cansittg any remaining; PfoS witkro ike: first partially-unloaded HjS-seleetive solvent: stream 254A to chemically detach or desorb .from-the. amine molecules of the stripping gas 222, The resulting lean BiS-seieetive solvent stream 21.0 may dtenhe flowed oaf of die fourth series of coteurrent contacting systems 20213, and may be recirculated to die third series of co-current contacting systems 202C, In Srsf^lmmiure 250A including die stripping gas and the Egg may bo flowed out of the first eotentrent contacting system 252A and into a second coteutreni contacting system 2528.
pi 13) A third eO-eurreni contacting system 252€ may be provided after ike second co- current contacting system 2S2E, and a fourth eo-current contacting system .25215 may he provided after the third co-current :contaetin| system 252C. in addition, a fifth co-current contacting system 2521 may be provided after file fourth·aV-eurtSefttjt&rtlaef &pti#ho25213, and a final co-eicven i contacting system 252F may be provided afier the fifth co-current contacting system 2§2E, Each of the second, third, |)«rth,: and fifth co-current contacting systems 252B, 2S2€, 2S2I3, and 2521 may generate a respective gas mixture 2568, 2S0C, 25615, and 256E including, the stripping gas and an increasing amount of H: S. In addition, each of the third, fourth, fifth, and final eo-eurreni contacting Nystems 252€, 25215; 252E, and 25:2F may 'gescpdu , especitm:partiaUy-'t^lb^^d.: Hj^sslcctive solvent stream 2548, 2S4€,2S4D, and W4E.
POO) The process flow diagrams of Bigs, 2A, 2B»!, and 2.8*2 arc not Intended to indicate that the system 200 is to include all of the components shown in Figs. 2A, 2B-f, and 28-2. Further, any number of additional components may bo included within the system 200, depending on ike details of the specific infotemesnatidn, For example, the system 200 may include any suitable types of heaters, chillers, condensers, liquid pumps, gas compressors, blowers, bypass lines, other types of separation and/or fractionation equipment, valves.
switches, controllers, ami devkgs, tempenmrre-measuring devices, levd- measuring devices, erliew>aTi^«rffig devices, among otherw mm m 3 is a schemMie of a eofeme a feed stream 302 info a gas stream 304' and ajtqrud stream 30$. The feed stream 302 may be a gas stream fhat inelydes tsvo or mere different components with different boiling points and'vapor pressures, such as; an ahsorbent solvent and a gas eoniammanl The column 300 aiay be similar to ihecolumns used in fhe .'.regeneration, system described; with respect; to F% J, |0 U3] Ffls ediumn 300 may include a number of trays 308 or ocher ihteftia|S that crease indirect flow paths for the feed stream 302 and create inieriackl afea between the gas and liquid phases. Tie feed stream 302 may be irgecfed into an upper or middle portion of the column 300, between tmys 30& The gas within fie feed stream 302 the column 300. Jifthe same time, any liquid within the colurns 300 moves downward and across the succession of frays 308 in the column 300, in addition, the liquid may include a reflux stream refej^b^-info· :fhe fop porimn of the column 300, as described further herein, pit Of. The column 300 may uiitfee a variety of sepamtion fechhblegieh, depending on thespeefesdh tie feed sffearh 302. For; example, the column may be a distillation column, k counfercunint sepamti;oh colnni|, ar a regeneration cohrmn, among others,., 10120! For a distillation column., the feed stream 302 may include a mixture of liquids with slightly differed boiling points. In this case, the column 302 is a distillation column that: .functions to separate the species by the differences M boiling: poiM; The trays 308 determine, the number of theoretical .plMexvknd, thus,, the sepafati.on;efficiehcy of the column 300.
10121 1 In. a: countercurrent column, the :feed stream 302; may include a mixture of gases, such as methane and HyO or HjS;, As the gases flow upwards through the; felling: stream of liquid, one gas species is preferentially absorbed by the liquid, lowering its concentration. 1«; the: gas: rising to the top of the column 300. In some embodiments, the liquid includes a physical: solvent (not shown) that is injected into a top portion of the column 300. More specifically, the liquid and vapor phases may he counfor-eurtcntly contacted to effect separation; of a fluid mixture based on chemical affinities, boiling poi0.f4iieren.ee, or vapor pressure; differences, or combinations thereof 10122) In a regeneration column, the feed stream includes a liquid that contains a dissolved or adsorbed gas. As the .liquid falls through the Column 300, the gas lx released and exits through the top of the column 300.
f0123| The eompmhmt that ooseeiMtes in the prs phase may he Sowed out of the top of the column 300 as an overhead py stfoarn 312, while the component that concentrates in the liquid phase may be Sowed out of%2%ttbf$.of %;c0lui»a:3$Mi as a bottoms liquid stream 314, In addition, some amount of liquid 3X0 may he aliowed to collect in the bottom of the column 300 before being Sowed out of the column 300 in order to provide for increased separation of the gas phase #om. the liquid phase.
1 Ot 2-11 The bottoms liquid stream. .3X4 may be Sowed through a reboiier 310. The reboiier 310 may increase the temperature; Of the bottoms liquid stream 31.4, vaporizing a; pcation pf the bottoms liquid on. am3X4, Which may Include components in the liquid, or a portion; of the liquid itself The resolting stream 320 may be Sowed bach info foe bottom potion of the column 300 to provide heat to the liquids 310 collecting in the bottom of the column 300, 10135] A portion of the o verhead gas stream 312 may be cooled and at least partially: condensed within a heat exchanger 322, The cooled gas stream 324 may then be separated into the gas stream 304 and a liquid stream 320 within a separation vessel 32ti Tire liquid stream 320 may be pumped back info: the fop portion of the column 300 as the reflux stream 310. Within the column 300, the reflux stream 310 may be used to enhance the performance: of the column 300 by increasing the degree of separation between the liquid phase and the gas phase.
0)120] In practice, the column 300 Very Idrgel a®d-0eayyw This may create difficulty m many applications, such as offshore oil and gas production applications, Therefore,, the co-current contacting system d#cribed herein may provide a desirable alternative to the column 300, |0i;23| Fig, 4A is a process flow diagram of a separation system 400 including; a number of concurrent contacting systems 402A-CI that may be placed, in a shell 403, in this embodiment, the: separation system. 400 may be analogous to a separation cblnmn:i for example, as described with respect to Fig, 3, in which, each of the co-current contacting systems 402A-CI are acting as bed packing. In some embodiments, dm shell 403 is a permanehh eiimate-eonbolled strncture, in other embodiments, the shell 403 is a temporary or portable structure. In other embodiments, foe shell 403 is an insulated jacket. In various embodiments, the separation system 400 is implemented as part of the system 200 described with respect ία £%,3Αν2Β*Ι> and 2B»2. For example, the separation system 400 may be one of the scries of co-current contacting systems 202A-B within the system 200 of Mgs. 2.4, 2B-1, mi 2B~2, In the iUustmtive arrangement shown In Fig, 4A, a first co-current contacting system 402.4% a second ce-eurrent contacting system 402B, and a third co-ennent contacting system 402C are provided, each residing within the single shell 403.
f0I28f In various embodiments, dim to the pump requirements on the liquid streams, the mtcr-siage llqitM streams may be flowed through the shell 403. The shell 403 may be designed to keep the equipment and the solvent streams flowing therein cool. This may be done through climate control within the shell 403 or through the circulation of a cooling medium adtacent to the shell 403.
101291 A first gas stream 404 may be flowed into the first co-current conmcting system 402A. The first co-current contacting system 402A may generate a first partially purified gas stream 400A, which may be Sowed from the first co current contacting system 402A to the second co-current contacting system 402B. The second eo-cmTcm contacting system 402B may then generate a second partially purified gas stream 40hB, which may be flowed from: the second co-current contacting system 40213 to the third co-current contacting; system: 402(2' hr seme embodimenfs, the third co-current confactiug system 402C generates a final purified gas stream 408.
101301 Each of the first, second, and third concurrent contacting systems 402A-C also generates a respective rich solvent stream 410:4, 41¾ and 41OC. Tire third rich solvent stream 410C may be directed bach: to the second cq-current eontacting system: 402B, and the second rich solvent stream 4! 0B may be directed back to the fet: co-cursmi contacting system 402A, in addition, the third co-current contacting system 402C may receive a lean (or semi-lean) solvent stream 41 0B fern another source. Further, the first rich solvent stream 410A system, e.g,, another senes of eo-current contacting systems, for ^generation, as described with respect to Figs, 2A, 2B-1, and 2B~2, rtf may serve a& a liquid solvent for a preceding co-current eomaciihg system: (not shown), 101.311 Fig. 4B is a process flow diagram of the separation system 400 of Fig, 4A including the co-current eontacting systems 402A, 402B, and 402€f with the addition; of a number of heat exchangers 4I2A and 412B. The heat exchangers 412A and 412B may be used to cool the fieh solvent streams 41 ffB and 41 OC. In some embodiments, the heal exchangers 412A and 4I 2B are used as an alternative to the use of the shell 403,
|0Ι52| Μ», 4C is a process flow diagram of the separata system 480 of Fig; 4A
inciuding the eomurrent contacting systems 402A* 482B, anil 482C with the addition of one or mare flash drums 414 la the emhodimem shown in Fig* 4€, the second rich solvent stream 418B may be flowed through^the flash drum 414* A flash line 418 May be provided coming off the top ofilhe Hash dram 414. The flash drum 414 and associated flash line 418 may permit methane and any €% absorbed in the second rich solvent stream 410B to be flashed out before flte second rich solvent stream 4180 is flowed into the first ee-cttrrent contacting system 40%, BjO in vapor form may also he veined: from the flash line 418, In various embodiments,., flashing: the second rich solvent stream 418B creates a semi-lean solvent stream. The use of: a semi-lean solvent stream in the first co-current contacting system 482A may improve tire efficiency of the f|t#' ibiHJUi^m^htsctrng system 48% and reduce the load on the regenerator. Further, in some embodiments, any of the other solvent streams 418A* 410C, or 410i> may also be flowed through a flash drum that is similar to ihe: flash, drum 414, hr some embodiments, gas, e.g.< methane, €% and HaO, flashing out of the flash line 418 is merged with gas flashing out of flash lines associated with any number of other flash drums within the gas processing system.
|tll33| As shown ip Fig* AC, the second solvent stream 418Bhta:y also he flowed, through a pump 418 afler it eaiis the flash drum 414. The pump 41.8 may increase the pressure of the second solvent stream 4Ϊ8Β, to treat .the high pressure gas aodto ovemomeihe effect of the pressure drop that occurs within the eo-current contacting systems 402A-C, Increasing the; pressure of the second Solvent stream 4Ι0Β may also allow tire second solven t stream 410B to more effectively entrain the acid gases within thujas stream 484, filMj It is to be und%food that fire separation:system 408 is not limited to the humbef of cb-eutaunt: contacting systems shown in Figs, 4A~€, Rather, fire separation system 400 may rnelude any^suitable number of co-current contacting systems, depending on the details of the specific implementation: Ftuiher, the interconnections within the separation system 400 do not have to be arranged as show» In Figs, 4A-€* Rather, any suitable variations or alternatives to the intereoniections shown 1» Figs, 4A-C may he present within the separation sy stem: 400, depending; on, the fiefaiis of the specific iraptemeMaiton, |0I3S| Fig, 5 is a process flow diagr^p: of a gas: mgeoerafion system 508 including a number of co-current contacting systems: 582A-C. The eo-current eontacting systems 502A-€ may be used for the removal of COj and H S from a rich solvent stream 584, For example. In some embodiments, the: gas regeneration, system 588 may be implemented as the second series 202B witMu the system 200 of 1¾ 2A.
fllSi]: As shown to Fig, 5, a stripping gas 506 may be flowed into a first co-current coidaciing system S02A. The stepping gas 506 soay he nitrogen, steam, or apy other sin table type of strippitg gp. if the stripping gas §06 In srcanvihc spent stream omy be condenseC and theremalBmg vapor may be seatTo a sulfas recovery unit or add gas injection:unit. In ..addition, the stripping gas 506 .may be gas generated by boiling the liquid discharge from a third co-current contactlog system 502% analogous to using a reboiler in a regular separation column.
|0'B ] M addition, M first pasdally-ua loaded, or "leans solvent stream 50HA May be heated within a firstlaeaf/exchanger 510 and tiien flowed into the first co-current contacting syrigm 502.A, Once: inside: the first co-Currant contacting system 502.4, the stripping gas 500 and the fi.rsl parti ally-unloaded solvent stream 508a prove alon g the longitudinal axis of the : first: eo-cmi'ent contacting system S02A, As they travel, the first partially-unloaded solvent j&g stripping gas Sib, causing: any remaining CPs nttd KjS within the first pdriidiy^mloaded solvent stream 508A to chemieally attach to or be absorbed by te amine Molecules of the stripping gas §$6„ The resulting lean solvem stream SO may then be flowed out of the gas regeneration facility 500. M see: embodiments, the lean solvent Stream SO is flowed iutov another series of 'COrcnntajt^nfefdin^-syatbfiiS for the processing of a ftathral gas srredn, as described with respect to the syMem :200 of Figs, 2A, 2B-1, and '2Β-Ϊ;·· Further In Some onibodiments, a portion of the lean solvent stream 512 is boiled to generate the stripping gas 500.
101.38} A first gas mixtureSO A including the stripping ggs: and a portion of the CDs and %S may be flowed from the first co-current contacting system 502A to a second co· current: contacting system 50211. In addition, a second pariially-ntdoaded solvent stream 588B May be heated within a second heat exchanger 510 and then flowed into the second co-currem contacting system 502Bv Once inside the second comurrcnt cohtaeting System S02B. the first gas mixture 514A and the second patfially-nnisaded solvent stream 508B move along the longitudinal axis of theJeednd oo-entfeut contacting system S02B, As they travel, the second partially-unloaded solvent stream 508B intersets with the first gas mixture SJ.4A, causing a portion of the 0¼ and HaS within fire second partially-unloaded sbivent stream 508.B to chemically attach to Or be absorbed by the amine molecules within, the first gas mixture S14A, Tile resulting first pariialiy-uUioaded solvent stream 508A may then be fiowed fiora the second co-currcnf contacting system 502B to the fimt co-current eootaering system S02A, pi3f|:: A second gas mixture SI4B including the stripping: gas and a larger portion of the; C% and H'^S tmy bo flowed from the second eo~cii»est contacting sysiena:502B to a third eo-enrrent contacting system 502C. In '..addition, the rich solvent stream 504 may be flowed Into the third comurreni contacting system S02C, M varioiri embodiments, the rich: solvent stream 504 may be Warm. due to the exothermic chemical: reaction involved I»'m earlier CO2 and removal process, as well as possible pm-hearing with arv outside source.
|RI#1:: Once inside the third dowurnnfl contacting system S02C. the second gas, mixture 5148 and ite: rich : solvcin stream 504 inove: along; the longitudinal axis of the third co-cturent: contacting system 502C. As theytmyel, the rictr sol vent stream S04 interacts with the second gas: mixture Si 4¾ causing a portion of the Cda ntul HjS within the rich solvent stream. 504 to chemically attach: to Or he absorbed by the amine molecules within the second gas mixture 51411 The resulting; second partiallymnio&ded solvent: stream 588B may then be flowed from the (1111(100-000½¾ contacting system §02€ to the second co-current contacting system 502B. In addition, a gas stream 518 including the €0¾ HaS, and strippinglps may be flowed ont of the gas: regeneration facility 500. In various embodiments, the COy within the gas stream::51 Idnay be recovered within another series of co-curren t contacting systems, and the I-frS may be recovered within, yet another series of co-enrmnf contacting, systems,; as described withawspeet to the system 200 of lip, 2A, 2B~1, and 2 B»1 101.4!| It is to be understood that the gas regeneration, system 500 is riot limited to the number Of cb-eurrent contacting systems shown in Fig, 5, Rather, the gas regeneration system 500 may include atiy suitable number of co-eurrent contacting systems, depending on. the details of the specific implementation, Further. the -within the gas regeneration system 500 do riot haw to he arranged as shown in.Fig,: 5. Rather, any suitable variations or siternatiyeS dO: the intereohnections shown in Fig, 5 mgy be present within the: gas regeneration system 500, depending On. the details of the speeiiciimplemeniation.
|0t 42f Fig. 6 is hr process flow diagram of a separation system 000 tor preferentially rentevsng one component from a multiscdmpotrent gas stream. More specifically, the Separation: System 600 may be used to remove One gaseous component, referred to hetem as “gas Ay5 front a muM-component gas Stream 602 including gas A and: another gaseous component, referred to herein m “gas BA Aeeording to embodiments described herein:, gas A may: be ByS, andgas 8 may bfrCpn However. itf^vta;thatφ A and gas B may also be any other types Of gas that are to be separated from one another via the separation system 600, ψΗ$ Ttes;: separation system 600 may include a number of eo-curteif contacting systems 0044^: connected is series. Esc!* co-current contacting system 604A-C removes $, Of gas A lorn the multi-component gas stream 602 using: » lean gas A-Selective .solvent stream 606 that preferentially absorbs gas. A over gas B. This may result in the getterai idrof a rieb: gas A-seleciive solvent stress 60S Including gas A, ay Well as a separate gas stmam 610:including primarily gas B,
Pi44f: In various embodiments Abe mulii-eompooent gas. gre&m 60¾ including· gas A and gas B· is Bowed kto theifirst co-enrreui contacting system 604A, In addition, a first partially-;:· loaded, or “richA gas A-selective solvent steeam 6114 including some amount oflgas A is fiowedfirint the seebndyo-eurTent contact^^^^^ first eo~eirifenf eontacting system 604:.4. Once inside the first eC-cnrrent Contacting .system 604A»· the nmhi-compenem gas Stream 602 and rite first partially-loaded gas A-selective solvent stream 6!2A move along, the longitudinal axis of the first co-current contaeting sysiem. 604A, As they travel, the first pariiafiy^ioaded gas A-selective solvent stream 6124 ifttefaets ovitl gaa A: Within the multi component gas stream. 602, causing the mdiebtdcs of -gm A: to ehcuHcaliy attach to or be absorbed fiy the molecules of the first papally-loaded gas Afeeleefiye solvent stream 612A. This may result ip the generation of a first gas mpture 6|4A including gas B and some amount of gas A, as well as the rich gas A-selective solvent stream 60S mehiding jus A. The rich gas A-selective solvent stream 608 may then be flowed out of the separation system 680.- |01.45i in various embodiments, the first gas mlkure 61.4A is flowed Put of the first co-current contacting system 604.4 and into a ^buddeo^ike^t'Cisdiicfing. system 604B, In addition, a second partially-loaded gas A-sekdfive solvenf stream 612B is flowed from a third co cttrreut coutgctiug system 604C into the second co-current cdntaklhg system 004B. Once inside the second co-current contacting system 664B, the first gas mixture 614A arid the second partially·· loaded gas A-selective solvent stream 612B move along the longitudinal axis of the second co-current contacting system 604B. As they travel, the second part ially-losded gas Α-seleclive solvent stream 612B interacts with gas A within the first gas mixture 61.¾ causing the molecules of gas A to chemically attach to or be absorbed by the molecules of the second partially-loaded gas A-selective solvent stream 612B, The resulting first partially-loaded gas A-seiective solvent stream 6I2A may then be flowed from the second co-current contacting system 604B into the first co-currem contacting system 6044. In addition, me resulting second gas mixture 614B, which includes a lower amount of gas A than the first gas mixture 614.4, may be flowed out. of the second co-current contacting system 6MB md isto 6te tMrd comermat eoetaeiieg system 604€, |0I46| 1« addition to the second gas mix-tup. 614S, the lean gas A-selective solvent stream, 606 may be flowed into the third co-current contacting system 6040 from another souree-i The second gas mixture-614B and-the Ι-pa» gas ^-selective solvent;: stream 696 may move along the longitudinal axis of the third cqyparrent contacting system· 6040. As they trayek the lean gas A-seiective solvent stream 600 interacts;wi9t any rem&minggas A within the second gas mixture 614B, causing the· remaining molecules of gas .A :tO : chemically attach to or he: absorbed by tlm molecules of the; lean gas A-seleetiye solvent: stream: 606,: The resulting second partially-loaded gas A-selective solvent stream 612B tuny then, he flowed fromytte' third. Cd-currcnt:ec8^&%: system 6040 into the second co-current contacting system 604B, In addition^ .t&«:-f6s«iri%lgas .stream 610 that includes 'primarily gas B may he flowed out of the separation system 600.
[01471 in various embodiments, the gas A-selective solvent stream is a specially-designed solvent thM praierentially absorbs gas A, i.e., species iKAf- over gas B, i.e.5 species ‘ΈΑ Tbe rate of absosption t RA i of Λ may he as shown helow ni Bq. (7).
¢7)
In Eq. (7), Ssig^ k the overall: mass transfericoelflelem of A lumped on the gas side, a is the specific suriaee area, and APim is the log mean driving force. The. driving force is the. difference;.in the panial pressure of A jn the,gas phase minus the equilibrium yapdr pressure of A above the solvent. Blsmi&rly, therate of absorption (Es) of B may be as shown below in Eq, (0), (8}
Therefore, the rate of absorption, of B over :A may he as shown below in Iq, (9):.
(9} fCtt-ifo In some embodimenis, altering the cStaraeteristks of the solvent: stream may improve the;ratio <$"$ο#α to KoQ8, flor example, the addition of solvent:molecules that: increase the; rate: of reaction of 71 and decrease the rate of reaction off will likely improve the ratio. Alternatively, certain additives that interfere: with the reaction of B with the solvent: stream may be included within the sblveht stream, thereby ihereasmg the ratio of Κΰ$Α to jfH40j ϊί Is to be understood that & separfofon system OOO: is not limited to thenumbcr of cotourrent: contacting systems shown la 'Fig, 6. iMfer, the; separation system. 600 -stay·· include any suitable number of cd-curreot eoafoetmg yysfotos, dapeudfogoo the details of the specific Itttp'temeatatjoa. Furttier,: the hliefeonneefious within the separation system 600 do hot have to fie arranged as shown in Fig; 6, Rather, any suitable variations hr alternatives to the totercannecttous clown in Fig. 0 may fie present: within the separation system 600, depending on the details of the specific jofolentemadon,, :..1 fO'lfiOl: Fig. t is a schematic: of a eo-cumart contacting system 700. The co-cnrrpnt contacting system :700 may provide for· the separation of components within igas shear». The ep-enrrett contacting system 700 may include a eo-ourretit: efintndtor 701 that is positioned in- line within a pipe 704. The co-current eomactor 701 may include a number of components that provide for the efficient contacting of a liquid droplet stream with a flowing: gas: stream 786. The liquid droplet stream can he used for foe separation of impurities, such as BA 1-fiS, or COt, from a gas stream 700.
Iff 61| In, various entbodiments, the co-current. contactor 702 includes a miser 708 and a pass transfer section 710, As. shown ih Fig. 7, foe gas stream 700 may be flowed through the; pipe 704 and into the mixer 70S. A liquid stream 712 may also be flowed into the mixer 708. for example, forongh a hollow space 714 coupled to flow channels 716 in the mixer 708. The liquid stream 712 may include any type of treating liquid, e.g., solvent, that is capable of removing foe impurities horn foe gas .stream 700, 101.621 From..the"flow channels 71.6, tire liquid stream 712 is released into foe gas stream.
706 ah fine droplets through infection orifices 718, and is then flowed into the mass transfer section 710. This snay result in The generation of a treated gas stream 720 within the mass transfer section 710. The treated gas stream 720 may ihcln# small liquid droplets dispersed in a gas phase. The liquid droplets may include impurities from the gas stream 706 that were adsorbed or dissolved into the liquid stream 712.
10163.) The treated: gas stream 720 may be flowed from the mass transfer section 710 to a separation systefo 722, such as a cyclonic separator,: a mesh screen, or a settling vessel The. separation system 722: removes the liquid droplets ffom the gas phase. The liquid droplets may include the ofigihal liquid stream, with foe incorporated imparities 724, and the gas: phase : may include a purified gas stream '726, In various embodiments, the purified gas stream7!26 is a gas msem that has irecn purified via the removal of ffeS and COx |MS4|: Fig. 8A is a: front view of a .raker 800. The mix® 800 is implemented within a coreurrent contactor, :suc0 as the eo-current contactor 782 described with respect; ίο the co-current coftteciittg sj^tem 700 of Mg, . The mixer 808 may be an axial, in-lme coreutrent contactor located within a pipe. The Soot view of the mixer 880 represents anupstream view ofthp mixer 800, |8: SS| 'Tic inker 800 may Include an out# annular support ring 802, a number of radial blpdes 804 extehclihg from the aumriar support ring 802, and a ecntml gas entry cone 806. Tie anhular stlppori ring 802 m«y Secure the mixer 800 In-line within the p-ipe. hi addition, the radial b|8d#..!0IH'may;|iibvi«|e.:8ttgport for dre central gas entry cone 806.
plSihf The annular Support ring 802 may be designed as a flanged connection, or as a removable or Iked sleeve inside the pipe, in addition, the annular supportring 802 may ihclude a liquid feed sysient and a hollow channel described further with respect to Figs, 7, 8€ and 8D. A liquid stream may be fed to the mixer 888 via the hollow channel lit the annular support ring 882. The hollow channel may allow equal distribution of the liquid stream along the perimeter of the mixer 800.
ftfif 7| Small liquid channels within the annular support ring 802 may provide a flow path for the liquidstream to low through injection orifices 888 within the radial blades 804, The liquid injection orifices 888 may be located on or near the leading edge of each radial blade 884. Placemen of the liquid imection orifices 808 on the radial blades 804 may allow the liquid stream to be uniformly distributed in a gas stream that is directed between the radial blades 804. Speeibeally, fhs liquid stream may be eoBiacted by the gas stream, flowing through the gaps imtWecn the redial blades 804, and may be sheared into small dreplks and entmined in the gay phase.
ffllofij The gas stream may also be flowed Into the central gas entry con© 806 through a gasinlet 81.2. The centrai gas cutty cone 886 may block a crosskeoiional portion, of the pipe. The radial blades 804 include gas exit slots 81:0 that allow the gas stream to be flowed out of the central gas entry cone 806. This may increase the velocity of the gas stream as it flows through the pipe. The central gas entry cone 806 may direct a predetermined arabum of the gas stream to the gas exit slots 810 on the radial blades 804.
101:S0 j Some of the liquid stream injected through the radial blades 884 may be deposited onthe surface of the radial blades 884 as a liquid film. As the gas stream flows through the eemral gas entry c&m 886 and Is direeted out of the/gas exit slots 8111 on the radial blades 884, the gas stream tmy swebppor blow, much of the .liquid film off the radial blades 804 This a enhance the dispersion of the liquid stream: Into the: gas /phase. Farther, the abstraction to the flow of the gas stream and the shear edges created/by the central gas entry cone 806 m ay provide -a.·: zone with ah increased tar bn lent dissipation/rate, The may: result ht the genemtioh of smaller droplets that enhance: the mass: transfer rate, of the liquid stream and the gas stream.
I® i M| i The size of the mixer 800 may be ad j uxted such that the gas stream So ws at a high velocity. This may be accomplished via either a sadden reduction in the diameter of the attmiiar ts8p^4»tt|:::8e2i or a gradual mduciion in the diameter of the annular support ting 882. The outer wall of the mixer 808 may be slightly convening in shape, terminating at the point Where the gas stream and the liquid stream are discharged into the down stream pipe. This may allow for me shearing and m-entminmeat of any liquid film that is removed from the mixer 888. Farther, a radial inward ring, grooved surface, or other suitable equipment tnay fie ihclntled bn the outer diameter qfthe mixer 800 near the point where the gas stream and the llqhid stream are discharged:into the downstream pipe. This may enhanee the degree of liquid enttphtment within the gas: phase,;
[8161] The downStfeasn end of the mixer 888 may discharge into a section of pipe (not shown), The section of pipe may be a straight section of pipe, or a concentric expansion section of pipe. In sbhle embodiments^ the eenifal gas entry erme 806 terminates with a blunt ended edfte or a tapered ended cone; In/other embodiments, the central/ gas entry cone 886 tenwinates with a ridged eone, which may Include multiple concentric ridges aldng the cone that provide multiple locafiohs for: droplet: generation. In: addition, any number of gas exit slots 818 may be pmvfded bn the cone itself to allow fertile removal of the liquid film from the mixer 888, [818:21 Fig. 8B is a side perspective view of the mixer 888, Ltfce numbered items are as described with respect to Fig, 8A. Ax shown in Fig* 8B, the upstream portion of the central gas entry cone 806 may extend further into the pipe than the annular support ring 882 and the radial blades 884 in the upstream direction. The downstream portion of the central gas entry cone 886 may also extend Anther into the pipe than the annular support ring 882 and the radial blades 884 in; the downstream direction. The length of the central gas entry cone 886 in the downstream direction depends on the type of con e at the end of the cen tral gas en try cone 886, as described farther with respect to/Figs, 8C and. 80.
Fig. SC Is a aross--seefional side perspective view of the mixer 800. Like numbered lien® are as described with respect to: .Figs» 8A and 8B. According to die embodiment shown in Fig* 8C!S the central gas entry cone 800 of the mixer 800 terminates with a tapered coded cone Si <1 Terminat ing the central gas entry cone S00 with a tapered ended cone 814 may reduce the overai! pressure dropin the pipe caused by the mixer 800.
mm Fig. 80 is another eross-seetiona! side perspective v;iew of the mixer 800, Like numbered items are as described with respect to figs, :&MX According to tlm embodiment shown, in Fig, 8'D, the .central gas entry cone 800 of the mixer 800 terminates with ablunl ended: cope Sid. Terminating the central gas satiny code: 800 with: a blunt ended -cone |.U may encourage droplet fomaiion m the center of the: pipe,
|8L0S|: Fig, 9 is a process flow· diagram of a method 000 for separating CO* and: H S
fen» natural gas stream, Specifically, the method .000 may provide tor the removal of CO and LLS from the natural gas stream, ah well as the recovery of separate CO and BbS streams, According to embodiments described herein, the method 000 is impiemented by a number. of cpOiirfsnt -oontaetihg £y$tbttjsv For exampin, the method 900 may.be implemented by the series of co-carrerd contacting systems 203A-D described with reject tb: the system 200 of Figs, 2,4* 2S-1, and :2¾¾ 1.01001 The method begins at block 902, at which a sour natural gas stream including CO and M'*S is eontaeted with a lean sol vent stream Within a: first series of co-eerrciit contacting systems, resulting in the generation of a sweetened natural gas stream and a rich solvent stream including Ore CO and the M S, More specifically, the sour natural gas stream is progressively sweetened via contact with the solvent stream: within each of a number ofpb* current contacting: systems' connected in seriesy la some embodiments, the resulting sweetened natural gas stream, is: ttsed^ to produce LHC, 1.0.187) At block 904 tire rich solvent stream is eontaeted with a stripping gas within w second series of comurrcnt contacting systems, resulting in the regeneration,of the lean Solvent stream and the generation of a first gas stream including the CO** the H*S*· and the stripping gas. Mom specifically, the CO and the H S are progressively removed from the rich solvent stream via contact with the stripping gas within each of a number of co-current contacting systems connected in series. Further, at block 906, the lean solvent stream is recirculated to the first scries ofeo-currcnt contacting systems.
|0160| At block $08, the first gas stream. is: contacted with a baa %.S selective solvent stream -within a third series of.co-carrettt the generation of a rich kfrS-selecfive s&fam stream meloding the: FfrS and a secbad gas stream including the CO2 and the stripping gas. More specifically, the MiS Is progressively removed from the first gas stream via contact with the f'bS-selective solvent stream within each of frhiunberofco-current contacting systems commuted in series. In. vario«8:'^w^imcn%.t]H^ CO2 isfeofoved: from the second gas stream to fecoydria final: CO* product The resulting stripping gas:may then be recirculated to ϋ«| second series of co-curmnt contacting s>tems, fir addition, hr some embodiments, the final CCfr product is injected into a subterranean: foaervolr for enhanced oil recovery :(E€)R) pperadons, flllhfrf: At block 01.0, the rich MjS-sefeetiva solvent: stream, is contacted with a stripping gas within a: fourth series of co-current contacting systems, resulting: in the repneration of the leM H S-selectivc : solvent stream and the geneMion of a third gas stream Including: the ifrS and the stripping: gas, More specifically, the RfS is progressively removed from the rich' BaS'Selhetiye solvent stream via ebnraet with the stripping gas witliln each of a nimiber ofcb-current contacting systems: epniteeted lit series, Is various embodiments, the H3S«removed from: the third gas stream to recover a final ITS product. The resulting stripping gas may then be rectmufated to the fourth, series of epmnmmt contacting systems. In addition, in some embodiments, elemental sulfur is recovered from the final ITS product within a. Claus suffim recovery unit Furthermore, at block Mi, the lemr TfrS-selective solvent stream is recirculated to the third series of comerrem comactmg systems.
|0 t 0| The process flow diagram of 9 is not .intended: to Indicate that tire1 blocks of the method 0Θ0: afo.ib be executed in any particular order,: or that all of the blocks of tire method 000 are :to be included in every ease- Further, any: number of additional blocks not: shown in Mg, 0 may be: included within tire method 000,: depending op the details of the: specific implementation,
ΜΜ*Ιηζ·ύΜ' fromi# Mute&mMtimfGM
Smm |01T1| Fig, 10 m a process How diagram of a method 1600 for selectively removing one gaseous component from a multi-component gas stream. According to embodiments described herein, the: method 1.000 is implemented: by a number of: co-current contacting: systems connected in series. For example, tire method 10011 may: be implemented by the co-current contacting systems 0044-C described with respect to the separation system 6011 of |I1 2| The method begins at block 1002, at which1 a lean s< >1 veat: sirsam; is flowed; into a mixer of a co-current contactor visa an annular support ring and a uumber of radial; blades extending from the annular support ring, The annular support·ring secures ibe mixer in-line;, within a pipe.
10173] At block i§04(;a multi-component: gas stream: hfehiiing a first gaseous component and a second gaseous, cosripqneot is flowed into the mixer via a central gas entry cone that is supported by the radial blades, M ore specifically, a first portion of the nmhi-component gas stream flows through tlfocehiralgax entry cone, and a second portion of tl^mplfccompoaent gas stream liens around the central gas entry cone between the radial blades, in some embodiments^ the first gaseous component is H !, the second gaseous component is 00% and the solvent stream is an HaS-seleptive solvent stream. For example, the solvent stream may be a tertiary amine.
101.74} At block 1000, the mulii-compdneutgas stream is contacted with the lead sol vent Sttcam within the mixer and a mass transfer section of fte co-eurmht contactor to provide for incorporation of liquid droplets formed from the loan solvent stream into the multi-cofopohebt gas stream, According M embodiments deseribed herek, the solyetfestfoam is a specially-designed solvent that prefereMialiy absorbs the first gaseous component over the second gaseous component 'therefore, the liquid, droplets include the first gaseous component: from the multi-component gas stream, 10175} At block 1008,.: the liquid droplets are separated from the rmdti-eornponent gas stream within a separation : system, resulting: In fee generation . of a rich solvent stream, including the first gaseous: component and a gas stream including fee second gaseous component, Accordingly*.the method lip provides for the selective removal of the firs; gasebus component from the mulri-component gas stream bring: the speelaily-dehigifed solvent,· l§i701 The process flow diagram of Fig, 10 is not: intended to indicate that fee blocks of the method 1000 are to be executed in any particular order, or that ail of the blocks of fee method 1,000 are to he mehtded in every case, Further, any number of nddltlorial blocks hot shown in Fig. 10 may be included Within the method 1000, depending on the: detailsof the specific unplemehfedoa For example, m some embodiments, the multi-component gas stream is flowed through a number of co-current contactors and corresponding separation systems connected in series within the pipe, in such embodiments, the fet gaseous component is progressively removed irons each eo- etirreM contactor and cormspooding scpirndiort system, further,, in some embedtotents, the lean .solvent stream is regenerated from the rich solvent stream within a separate eo-emrent contactor and corresponding separation system, or separate series of eo-eurrent contactors and correspond 'mg separation systems connected hi scries within the pipe.

权利要求:
Claims (17)
[1] 1. A system for separating H2S and €0> from a natural gas stream, including: a first loop of co-current contacting systems configured to remove 1I2S and 0¾ from a natural gas stream; and a second loop of co-current contacting systems configured to remove the H2S from the CG2.
[2] 2. The system of claim L wherein the first loop of co-current contacting systems includes: a first series of co-current contacting systems configured to remove the H2S and the C02 from the natural gas stream by contacting the natural gas stream with a solvent stream, providing for incorporation of the H2S and the €02 from the natural gas stream into the solvent stream; a second series of co-current contacting systems configured to remove the H2S and the C02 from the solvent stream, wherein the solvent stream is recirculated to the first series of co-current contacting systems.
[3] 3. The system of claim 2, wherein the second loop of co-current contacting systems includes: a third series of co-current contacting systems configured to remove the H2S from the C02 by contacting the H2S and the C02 with an H2S-selective solvent stream, providing for incorporation of the Ϊ12S into the H2S-selective solvent stream; and a fourth series of co-current contacting systems configured to remove the H2S from the H2S-selective solvent stream, wherein the H2S-selective solvent stream is recirculated to the third series of co-current contacting systems.
[4] 4. A method for separating C02 and H>S from a natural gas stream, including: contacting a sour natural gas stream including C02 and H2S with a lean solvent stream within a first series of co-current contacting systems, generating a sweetened natural gas stream and a rich solvent stream including the C02 and the H2S; contacting the rich solvent stream with a stripping gas within a second seri.es of co-current contacting systems, regenerating the lean solvent stream and generating a first gas stream including the CO2, the H2S, and the stripping gas; recirculating the lean solvent stream to the first series of co-current contacting systems; contacting the first gas stream with a lean H2S-selective solvent stream within a third series of co-current contacting systems, generating a rich EhS-selective solvent stream including the H2S and a second gas stream including the C02 and the stripping gas; contacting the rich H2S-selective solvent stream with a stripping gas within a fourth series of co-current contacting systems, regenerating the lean H2S-selective solvent stream and generating a third gas stream including the H2S and the stripping gas; and recirculating the lean H2S-selective solvent stream to the third series of co-current contacting systems.
[5] 5. The method of claim 4, including producing liquefied natural gas (LNG) from the sweetened natural gas stream.
[6] 6. The method of any of claims 4 and 5, including removing the C02 from the second gas stream to recover a final C02 product.
[7] 7. The method of claim 6, including injecting the final C02 product into a subterranean reservoir for enhanced oil recovery (EOR) operations,
[8] 8. The method of any of claims 4-6, including removing the Ii2S from the third gas stream to recover a final II2S product.
[9] 9. The method of any of claims 4-6 and 8, wherein contacting the sour natural gas stream with the lean solvent stream within a first series of co-current contacting systems includes progressively sweetening the sour natural gas stream via contact with the lean solvent stream within each of a number of co-current contacting systems connected in series, wherein contacting the rich solvent stream with the stripping gas within the second series of co-current contacting systems includes progressively removing the CO and the H2S from the rich solvent stream via contact with the stripping gas within each of a number of co-current contacting systems connected in series, wherein contacting the first gas stream with the lean H2S-selective solvent stream within the third series of co-current contacting systems includes progressively removing the H2S from the first gas stream via contact with the lean H2S-selective solvent stream within each of a number of co-current contacting systems connected-in series, wherein contacting the rich H2S-selective solvent stream with the stripping gas within the fourth series of co-current contacting systems includes progressively removing the H2S from the rich lI2S-selective solvent stream via contact with the stripping gas within each of a number of co-current contacting systems connected in series.
[10] 10. A system for separating C02 and H2S from a natural gas stream, including: a first series of co-current contacting systems configured to contact a sour natural gas stream including C02 and H2S with a lean solvent stream to generate a sweetened natural gas stream and a rich solvent stream including the C02 and the H2S; a second series of co-current contacting systems configured to contact the rich solvent stream with a stripping gas to regenerate the lean solvent stream and generate a first gas stream including the C02, the H2S, and the stripping gas, wherein the lean solvent stream is recirculated to the first series of co-current contacting systems; a third series of co-current contacting systems configured to contact the first gas stream with a lean B2S-selective solvent stream to generate a rich H2S-se1ective solvent stream including the H2S and a second gas stream including the C02 and the stripping gas; and a fourth series of co-current contacting systems configured to contact the rich H2S-selective solvent stream with a stripping gas to regenerate the lean H2S-selective solvent stream and generate a third gas stream including the H2S and the stripping gas, wherein the lean H2S-selective solvent stream is recirculated to the third series of co-current contacting systems,
[11] 11. The system of claim 10, wherein each of the first series of co-current contacting systems, the second series of co-current contacting systems, the third series of co-current contacting systems, and the fourth series of co-current contacting systems includes a number of co-current contacting systems connected in series.
[12] 12. The system of claim 11, wherein each of the number of co-current contacting systems includes: a co-current contactor located in-line within a pipe, the co-current contactor including: a mixer, including: an annular support ring configured to maintain the mixer within the pipe; a number of radial blades configured to allow a liquid stream to flow into the mixer; and a central gas entry cone configured to allow a gas stream to flow through a hollow section within the mixer; and a mass transfer section downstream of the mixer; wherein the mixer and the mass transfer section provide for efficient incorporation of liquid droplets formed from the liquid stream into the gas stream; and a separation system configured to remove the liquid droplets from the gas stream.
[13] 13. The system of claim 12, wherein the separation system includes a cyclonic separator.
[14] 14. The system of any of claims 12 and 13, wherein a downstream portion of the central gas entry cone includes a blunt ended cone or a tapered ended cone.
[15] 15. The system of any of claims 10 and 11, wherein the H2S-selective solvent stream includes a tertiary amine or a sterically-hindered amine, wherein the stripping gas includes nitrogen.
[16] 16. The system of any of claims 10, 11, and 15, wherein the system includes a CO2 separation system configured to remove the CO2 from the second gas stream to recover a final CO2 product.
[17] 17. The system of any of claims 10, 11, and 15-16, wherein the system includes a H2S separation system configured to remove the H2S from the third gas stream to recover a final H)S product.

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法律状态:
2019-04-09| PME| Patent granted|Effective date: 20190409 |

优先权:

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申请号 | 申请日 | 专利标题

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US201361821618P| true| 2013-05-09|2013-05-09|

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US61/821,618|2013-05-09|

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US201361821618|2013-05-09|

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