JPS58187489A - Selective removal of nh3 and h2s from hydrocarbon substance - Google Patents

Abstract

(57) [Summary] This bulletin contains application data before electronic filing, so abstract data is not recorded.

Description

DETAILED DESCRIPTION OF THE INVENTION BACKGROUND OF THE INVENTION Hydrocarbon oils derived from 41 oils and similar sources contain nitrogen and sulfur compounds of individual hair. oil n
Removal of these compounds is highly desirable because during the manufacturing process, they impart a wide range of properties to the marketed product, including unpleasant odors, corrosivity, and bad color. In addition, nitrogen compounds can have a detrimental effect on the production process, especially in the case of inactivation of the water bulking cracking catalyst and the production of excess gas and coke during the cracking process. There is a tendency for the formation of Various approaches have been developed to remove nitrogen and sulfur compounds from oil, but perhaps the most common and optimal method is the advanced method, which involves reacting nitrogen and sulfur compounds with hydrogen and converting them to NH3 and HlIEl. Catalytic water bulking purification process promoted by constant temperature and pressure and water bulking catalyst
hydrofiaing) Deriru os! The fHJ m reaction in which a sulfur compound reacts with a bulk of water to form NH5 and H2S is a reaction that involves pyrolysis and catalytic cracking, which are not specifically designed for this purpose.
zic craelcing), modification (rvform
ing) and hydrogenolysis (hyarocracki
It also occurs in other ways such as ng). Therefore, NH3 and H, B t generated in this way
- There is a reaction effluent containing yuzu.

NH3 and H2S from such hydrocarbon reaction effluent streams.
Removal of may be accomplished by scrubbing with water, preferably at elevated pressure and low temperature. However, achieving some degree of removal often requires the use of high currents of water, resulting in the formation of dilute aqueous solutions of NHs and H,8. NPD this sour (5 Our) water]
In order to make water suitable for discharge under a II8 permit, it generally must be treated to remove NH3 and H,B f.

Typical prior art techniques for upgrading raw hale oil involve subjecting this oil to mild hydrotreating conditions (m11d hydrutr@
to remove reactive metal-organic compounds commonly present in the rock oil, such as iron, arsenic, nickel and vanadium.

These compounds adhere to the water bulking catalyst and eventually cause the catalyst to lose its hydrotreating activity. Furthermore, contaminated catalysts cannot be regenerated economically. As a result, the harsh hydrogenation treatment (5ever@hyarot
Reating ) is usually a suitable translation of low-priced, sieve metal awards catalysts that are inherently inaccessible. Therefore, this mild hydrotreatment is only the first step of the entire process.

In the second phase, a highly active catalyst is used in the severe hydrotreating of the rock oil to convert it to nitrogen t-Nk13. Because the metal compounds have been essentially removed in the first step, the catalyst does not have to be rigid relative to the metal compounds, making this catalyst formulation optimal for nitrogen conversion. In the 11th method of ``Kotodesaru'', the pour point of rock oil is
The rock oil is treated in a third upgrading step in which the wax compounds are preferentially hydrocracked by a shape-selected catalyst in order to lower the U, r point ).

Each of these prior art upgrading processes produces the carbon fractions Nki3 and H2S from the nitrogen and sulfur compounds contained in the sock oil. As previously mentioned, at elevated pressure and low temperature, the reaction effluent stream is scrubbed with water to remove NH3 and H2S to form a dilute aqueous solution of NH3 and H2S called sour water. In typical prior art recovery methods,
These sour water streams are combined and fed to an interconnected distillation column operating at overpressure, where a stripping cListi
The 0I-128 vapor, which recovers NH3 and H2S separately by llation), is taken off as over 50% from one % (H,B stripper) and the bottoms of that column are separated from the other column (N
= a to H3x trituber), where IJH3 steam,
The water recovered by partial condensation of the overhead steam of the first column and recycled into the first column is treated as the bottom of the second column and sent to the bottom of the second column. ra. In this method, the xm ratio between NH3 and H1S is typically 0.
．． 5, which works well for recovering Nk13 and H2S from petroleum-derived effluents, but the Nk13 to a2 to 2S ratio (such as the effluent ηL from rock oil)
In the effluent stream, the ammonia level in the H-stripper column feed is further increased by p% ringing of ammonia in the vertical gD stream. As the ratio of Nl13 to H,B increases further, the removal of H,8 becomes more difficult in the H,S stripper, and when the feed has a ratio of NH3 to 1i2S, it becomes impossible to remove H-. Become.

In the process of the present invention, the hydrocarbon material is heated on a metal base 1 or lower, and if it contains at least 11 sulfur and 6 Arashi nitrogen, it is subjected to a severe hydrotreating in the presence of hydrogen. , this picture, converts most of the w1 wood present in the hydrocarbon material to ammonia, and converts most of the sulfur in the hydrocarbon material to hydrogen sulfide, then the hydrotreated hydrocarbon material is washed with enough water to absorb most of the hydrogen sulfide present in the hydrocarbon material, but only a portion of the ammonia, thereby containing ammonia plus a small amount of hydrogen sulfide. A washed hydrotreated hydrocarbon material comprising a vapor phase and a first sour water comprising water, ammonia and hydrogen sulfide are formed. The washed hydrotreated hydrocarbon material Jj[t-1 is then separated from the first sour water stream and the vapor phase present in the washed hydrotreated hydrocarbon material is separated from the washed hydrocarbon material in a high pressure separator. Separating from the hydrotreated hydrocarbon material to form a liquid hydrotreated hydrocarbon material and a vapor phase. The vapor phase is scrubbed with water to form a second sour water stream containing negligible amounts of H8S. The first sour water stream is stripped in a 1(2S stripper) with an overhead stream of 2B without essentially NH,
It generates a bottom flow consisting of water and water. This bottoms stream is then combined with a second sour water stream, stripped in an ammonia stripper and withdrawn into an overhead vapor consisting of water, hydrogen sulfide and ammonia, and stripped water. Drain bottom liquid into another stream. The overhead vapor from the ammonia stripper partially condenses to form an uncondensed m's fraction consisting essentially of hydrogen sulfide and water-free ammonia and a condensed fraction consisting of water, hydrogen sulfide and ammonia. This condensed portion is returned to the -St ammonia stripper and the other portion of the condensed portion is recirculated to the hydrogen sulfide stripper.

When the metal content of the hydrocarbon material is high, the present invention overcomes the deficiencies of rice technology by separating and treating each effluent. The effluent from the mild hydrotreating process is treated in a wastewater treatment process that precedes either the hydrogen sulfide stripper or the ammonia stripper, but the effluent from the severe hydrotreating process ηt, c, the ammonia stripper is used as the hydrogen sulfide stripper. In the second method, hydrocarbon substances undergo mild water bulking treatment in the presence of hydrogen. During this acidic hydrogenation process, some of the phonemes present in the hydrocarbon material are converted to ammonia and the hydrocarbon water**
*Some sulfur present in it is converted to hydrogen sulfide.

This hydrotreated hydrocarbon material is then washed and
A first effluent stream comprising the washed hydrotreated hydrocarbon material oil and water, ammonia, and hydrogen sulfide is formed, and the washed hydrotreated hydrocarbon material is then separated from the first effluent stream. To the washed hydrotreated hydrocarbon material,
A severe hydrotreating process is carried out in the presence of hydrogen, in which most of the residual sulfur in the hydrocarbon material is converted to ammonia, and most of the sulfur that is present in the hydrocarbon material is converted to ammonia. Converts to hydrogen sulfide. The hydrotreated hydrocarbon material is then rinsed with water in a cap that is sufficient to absorb most of the hydrogen sulfide present in the hydrocarbon material, but only partially absorbs the ammonia, thereby , a washed hydrotreated hydrocarbon storehouse and water containing a vapor phase containing ammonia and a small amount of H2S;
a second tit consisting of ammonia and hydrogen sulfide, a
This washed water bulked hydrocarbon material is then separated from the second effluent stream and the vapor phase present in the water washed water bulked hydrocarbon material is removed in a cylinder pressure separator. The waste hydrotreater is then separated to form a water bulk substance and a vapor phase. This vapor phase is scrubbed with water so that the NH3:h[2S ratio is at least 6:
1 to form an aqueous m solution of NH3. The first effluent stream is stripped in a water sulfide bulk stripper, withdrawing an overhead consisting essentially of ammonia-free hydrogen sulfide and consisting of water, hydrogen sulfide, and ammonia. Withdraw the bottom liquid into another stream Φ0 Add this bottom liquid to a second effluent stream, and strip the second effluent stream in an ammonia stripper and remove water, sulfur 11Z water lines, and An overhead stream consisting of ammonia is drawn off and a bottom stream consisting of stripped water is drawn off into another stream.

Ammonia stripper Karari overhead steam Vi
-##! The uncondensed portion essentially consists of hydrogen sulfide and water-free ammonia vapor, and the vertical striped portion consists of water, hydrogen sulfide and ammonia. A portion of this condensate is returned to the ammonia stripper, and another portion of the condensate is re-O/O to the hydrogen sulfide stripper.
I ring.

DESCRIPTION OF THE PREFERRED EMBODIMENTS In its broadest application, the majority of the H2S present in the hydrocarbon material in the effluent stream is
Violet water is used, which is sufficient to absorb ammonia but only partially absorbs ammonia.

The effluent stream is then separated from the hydrocarbon material, and the vapor phase is then separated from the hydrocarbon material. This vapor phase is scrubbed with water to form an aqueous solution of ammonia having an ammonia to hydrogen sulfide ratio of at least 6:1.

When the hydrocarbon material has a high metal content, the effluents from each step of the hydrocarbon material improvement process are separated so that each feeds into the optimal section of the recovery process.

[Stripping] (θtripping) candy is
The present invention is carried out by causing hot vapor or gas, generated or introduced at the bottom of the contact column, to rise through the descending liquid, removing the most volatile components of the liquid below. The distillation zone used to characterize the reduced distillation or fractionation during the distillation process consists of one or more such columns and associated equipment.

Hydrocarbon materials treated by conventional methods should have a low gold content. Mild hydrotreating, fl) recycle coking to achieve low metal content
There are various methods such as e-caking) or removal of boiling point components by distillation.

The method of the present invention will now be described with reference to Figure 1, which illustrates a preferred embodiment of the present invention.

In this case, the shale oil was treated in advance by the recirculation coking method, and the oil was heated to a nominal 8.
50 “F’s true boiling end point (tru@boiling e
It is made of cracked, low pour point rock oil with a low pour point. This rock oil is worth 1,000,000 yen! Jl/J18,000 copies of 'ijl wood,
5.400 parts of sulfur and 18 parts of all-gold plate (mainly iron and arsenic) are placed in a purple market.

With the main purpose of reducing this oritsu rock oil to about 1,000 parts of violet containing tired wood and less than Q, the entrance vibe 1
0 and entered the hydrotreating zone 20.

In this hydrotreating zone, 7 leases of 2ai S are used. The original catalyst is usually a low-priced high metal capacity
) is a catalyst for

This catalyst removes essentially all 18 parts of metal. The second catalyst is usually optimized to have high hydrogen activity but no cracking activity. In the process of denitrification reaction, the amount of kerosene is also reduced to less than about 100 parts or 7L.

In the present invention, NH3 is absorbed only by "j-", but most of H2S is absorbed by "10" (Co-absorp).
In order to ensure that the scrubbing water (approximately 1.8 gallons/barrel rock oil) was stored in WW2, it was added to the vessel effluent in line 4° via line 3o. In this way, I went to cold grade with Kun-50, and after draining the sour water in line 60, I took out HP (shoatsu) separator 80 and put an IA whistle steamer in fin 70 (shoulder 1). is small −υ)
H2S Shikag-Surei. The sour water in line 30 is
Re-Kazuka Gas Zuiri, Ketu Rock Oil Barrel per p about 1i, OLl
Om semi-cubic foot crest, and HP separator 8
When the pressure in 0 is about 1.500p・11&, 1. Approximately 20 wt% of Nki3 and 6 wt% of N2s are cancerous. The steam in line 70 is approximately 0.5 mol-〇N
ri, -s and about 0.024 mol -0H2B. The IJH3 and HgI2 are transferred to the absorption tower 110.
Odors within the VC are removed by countercurrent contact with the scrubbing water from the C fins 100. When the current of the scrubbing water is about 5.4 gallons per barrel of rock oil, the MH3 content of the recirculated gas is about 140”F.
In the ideal case of two-stage contact in the absorber 110 operating ``'c'c'', the
, and H28 is reduced to 0.001 mol-E. By this operation, in the sour water in 2 in 130, about 5.3 wt NH3 and 0.5 wt 1 (2
The liquid hydrocarbon water wood phase with S wrinkles and no waxing is line 14.
0 and exit the BP separator to strike '7 Tsuzo Zone 1
50, where the light hydrocarbons are removed via line 160 to produce shale oil in line 170, which contains approximately 1,000 tjtN and less than 14% per million parts of shale oil. Contains 100 or less sulfur.

The sour water in line 60 with an NH3:n2s ratio of about 2.6 is combined with the recycle solution from line 210 to
After being preheated in a heat exchanger 220, it is supplied to the H2S stripper 200. Adding cold scrubbing water to the exit of the H2S stripper via line 230 reduces the NH3 content of the H21it product in line 240 to about 20
0 ppm or less and line 2
Approximately 15 in total bottom cloth of H2S stripper in 50
wt% Nhl. The H-stripper 200 preferably includes a steam-heated chestnut boiler (reb boiler).
Heat for distillation is supplied from 6Q. The operating conditions of the H2S stripper 200 in this case are as follows: pressure, psia
330 low temperature, "F"
650 Overhead Temperature, 'P
The NH3:H,B ratio of the 100H2S stripper bottom increases by approximately 6=1 (tut) if due to the H,B removed overhead.

As has been well documented in the prior art, the complete separation of H2S from aqueous baths containing Nhl3 is 4501
This is also true of Shima Atsuhiro. line 2
The Ha8 stripper bottom in NH3 stripper 300 is combined with preheated hot water from line 130 and then processed into NH3 stripper 300. The overhead in fins 310 is partially condensed in exchanger 320 and condenser 330 and then flows to reflux drum 340.

The condensed liquid in the fins 350 has a MH of about 5 ovt*.

and 16.5 Wt* of H2S. Some of the condensed liquid is returned as reflux to the NH3 stripper via diine 360 and the remainder is recycled to the H,8 stripper 200 via line 210. Commercial heat is supplied to the NH3 stripper 300 from a reboiler 370, which is preferably steam heated. The operating conditions of the NH stripper in this case are as follows: pressure, psia
78 paper part temperature, 'F
310λ-Barhead temperature,'?
IJH3 stripper bottom in 240 line 380 is "3 OL (j '2B)% A k 1
．． It will contain less than OOOPPm, preferably less than 100 ppm. This stripped water is cooled in exchanger 220 and coupe 390, and
It is then used as scrubbing water. The steam exiting the rapid drum 340 via line 400 is approximately 96%)
l.

Contains a small amount of H, and water. This steam is
3 fA zone 410 where additional scrubbing water on line 420
Recirculate to 2S stripper 200.

The operation of the method for disposing of waste material 9k in a container will now be described with reference to FIG. 2, which shows a preferred embodiment of the present invention. In this embodiment, if 1 oil 100
Approximately 21,000 copies per million copies, 6, OUO sulfur and 10011 total metals (iron, arsenic and nickel)
The crude oil containing . Metal stuck to the catalyst and eventually replaced the catalyst. During the metal 1:elimination reaction, approximately 2.100 parts by weight of phoneme (approximately 10%) and approximately 4.000 parts of sulfur (approximately 6
7%) were also converted to 1jk13 and H2S, respectively. Rubed 1in3 &-yohi H2S t-
An amount of scrubbing water (approximately 2 gallons per barrel of rock oil) optimal for absorption purposes is injected into the reactor effluent line 30 through line 40, thereby cooling at 2-50 IF). (High pressure) separator 60 to line 7
'kl, 8 and NH in aqueous solution removed via Qt-
Make the removal of 3 effective. This -MW is approximately! b, Iw
The water-enriched gas containing 14% of t% and 8.5 Wt96) 1j8 is recycled to the hydroprocessing zone 20 via line 80. This gas is substantially free of NH3 and H- due to the simultaneous absorption of NH5 and H2S into the scrubbing water with approximately equimolar violet. The liquid ashing hydrogen phase enters the stripping zone 100 from the HP separator 60 via line 9G, where the light hydrocarbons are removed via line iiio't-it and the demetalized ash oil is transferred into line 120. is obtained, which is about 18.90011 parts of oil per million
A demetalized oil containing 1 ml of sulfur and 2.000 g of sulfur reduces its nitrogen content to about 1.0 ml of sulfur.
00 parts or less. The catalyst used in this zone can be directly fed into pigeon houses for the removal of supporting elements since the gold has been completely removed in the upstream hydrotreating zone. During the course of this M removal reaction, the mineral sulfur content is also reduced to about 100 parts or less. In the fukomei production process, a limited amount of scrubbing water (approximately 2 gallons per rock oil barrel) was added to one fin for the purpose of simultaneously absorbing a small amount of Nk13Lri but most of the H2S.
After 40 tons, the reaction effluent was cooled in RY/150. Therefore, the steam that flows into the cooler 160 and is cooled and then leaves the HP separator and remains in the line 180 after drawing out the sour water into the line 170 is the H2S formed in the hydrogenation treatment zone. It contains only about 6-. The sour water in line 17 is removed when the recirculated gas flow in line 180 is 9.11,000 standard cubic feet per barrel of oil, and the HP separator 190
When the pressure inside is 2.000 psia f), approximately 1
Contains 8 wt% NH3 and 4.2 wt% H211t-. The recycle gas in line 180 contains approximately 0.8 mole hkl and 0.02 mole penta-.

The Nki3 and H2S are removed in countercurrent contact with scrubbing water from line 200 in absorption column 210. When the scrubbing water flow rate in line 200 is about 6 gallons per barrel of oil, a three-stage 'I' contact cycle in the absorber operating at about 140'F will result in its recirculation. NH3 content in gas? It can be reduced by about 97%. During this operation, the NH of the liquid in line 220 was approximately 8.5 wt%.

1I2b is Q, 4 wt%, and about 0.04 moles of NH3 in the recycle gas in line 230, and k
i2B will be the key. The liquid hydrocarbon phase exits HP separator 190 via line 240 and enters stripping zone 250 where light hydrocarbons are removed and
Produces Ketsu1 oil in line 260, which is Ketsu1 oil.
One million parts of oil contains about 100 parts or less of nitrogen and 100 parts or less of sulfur.

This operation is often performed in a pipeline using a normal
I item 9t VCIIM is sent to further process the total yoke v (j's ketsu oil production improvement law. However, in some cases Qll this kerosene oil, lowering its #L moving point , -t and ktl L may be performed in order to reduce the cost of pigue shaft transportation. in a selective hydrocracking zone 210, a turn-280, a hp separator 290, and a strisobinder zone 300 in a similar process to the upgrading process.

Scrubbing water is added via line 310t to absorb the NH3 and H2S formed in line 310 and remove them as a solution in line 320. Alternatively, the NH8 and 12B can be removed by absorption by water within strip zone 300.

All of the above sequels in this human embodiment may be referred to as the quality 10'' of the rock oil of the present invention and the removal part of NH3 and H2S. The next description is N+i3
It can be called the recovery part of J-.yohi H2S.

An advantage of the present invention is that the various sour waters generated in the removal section can be separated and fed to the recovery section at their proper time.

The sour water in the fin 70 has a NH,; n, s ratio of approximately 0.
．． 6 and is supplied at the midpoint of the H2S stripper 330 after preheating in the heat exchanger 340 according to the PA requirements. The 8 m1i in line 350 from reflux drum 360 is combined with dilution water from line 370 to H via twin 380 since its NH3;m2s ratio is approximately 6.0.
Feed to the low point of the 2S stripper 330. line 3
90. The reflux around the pumps in 400 and 410 is cooled in exchanger 340 and Coucy 420 and converted into H2
It is returned to the top part of the S stripper. Add cold scrubbing water to line 43 (141 to H2S stripper-330
of the H2S product in line 440.
5 content to about 200 ppm or less. Heat for distillation is added to the H28 stripper 330 via a reboiler 450, preferably steam heated.

The preferred operating conditions for the ki2B stripper-330 are as follows: Pressure, paia 1
00-400 bottom temperature, "F600-400 5" - bar head temperature, ')i'
60~120Ii2S stripper bottom NH3 vs H
! The s ratio ranges between 5 and 10 xq 1 due to the H2S removed in overhead. Complete removal of H2S from aqueous solutions containing kN15, as has been done in the prior art, is difficult even at temperatures as high as 450'F. 1i- Stripper bottom, red line 460 and NH3 stripper 4
Enter 70. NH3:H1S ratio is approximately 4.6 no line 17
The sour water in the water is also preheated in exchangers 480 and 490 before being fed to the 8-neck 3-stripper 470. Overhead MC of line 500A, exchanger 480
The vertically condensed liquid in fins 550 is partially condensed in condenser 510 and flows through lines 520, 530 and 540 to reflux drum 360, containing approximately 5 outs of NH3 and 16.5 wt% H28i. . A portion of this lachrymal fluid is returned as reflux to the NH3 stripper 470, and the remainder is diluted with water from line 370 and circulated for 330 km to the 12B stripper.
Heat for steaming is preferably supplied to an NH3 stripper 470 via a reboiler 570 heated by steam. The preferred operating conditions for this NH3 stripper are as follows: Pressure psia
50-100 bottom temperature 'l?
280-660 Overhead temperature 01?
'220-270 reflux drum temperature'
l? 90-150, in 58
'o Ko's NH3 stripper bottom is worth 1000
less than ppm, preferably less than 100 ppm each
Contains H, and H2S. This Streets! The washed water is cooled in an exchanger 490 and a cooler 590 and then passed through a two-line 40 tl line which may be used as scrubbing water for mild hydrotreating zone effluent scrubbing water. One fin 140 is used as the scrubbing water of the harsh wood treatment zone effluent, and one fin 430 is used as the m part reflux of the H2B stripper.

The steam passing through line 610 to drum 360 is about 96% NH3 and a small amount of H! B and water meeting M
do. This steam is transferred to the NIEI3 purification zone 620.
= 9, using additional scrubbing water in line 630 to remove the H28 and recirculating it through line 64 () and simultaneously through lines 550 and 350 and 380 to the H28 stripper 330. Recirculate.

The sour water in line 220 joins the sour water from line 320 and after preheating in exchanger 670, the sour water in line 6
NH3 fractionator (fraction
nator) 55 Supply to Q. This NH3 Norakunyo inverter 650 is a normal reboiler (rat: +O1
lθd) In a distillation column with Omahi reflux, it is continuously operated under the following conditions,
Essentially pure liquid NH, overhead and purified water are obtained as bottoms. Operating conditions: Pressure psia approx. 215 Reflux temperature 1f:F approx. 100 Bottom temperature 1 approx. 690 After cooling in exchanger 670 and coupe 680, the bottom is scrubbed of the effluent of absorption column 210 and selective hydrocracking seam 7270. Use as water. A small amount of liquid side draw f is removed via line 690 and returned to nIIa tm, a stripper 330 via lines 550, 530 and 380.

Although the present invention has been described with reference to a specific embodiment, this application reflects the modifications and changes that may be made by those skilled in the art without departing from the spirit and scope of the appended claims. It is also intended to include the following.

[Brief explanation of the drawing]

In order to facilitate understanding of the present invention, preferred embodiments of the present invention will be described with reference to the drawings. This drawing is for the purpose of drinking and does not limit the present invention.
4 people outside of Japan

Claims (1)

[Scope of Claims] (11-) A method for treating a hydrocarbon-based material containing at least 3 parts per sulfur of titanium, comprising: (a) treating said hydrocarbon-based material in the presence of an aqueous system; At that time, a large bb of nitrogen in the hydrocarbon substance is converted into ammonia, and most of the sulfur remaining in the hydrocarbon substance is converted into ammonia, (1 ) The water-treated hydrocarbon bulk of Mu@e is washed with enough water to absorb most of its hydrogen sulfide but only a portion of its ammonia, and the vapor phase is removed by washing. (C) forming a washed hydrotreated hydrocarbon bulk material having ammonia and aqueous sulfide systems therein; fX is separated from the first sour water stream and in a high pressure separator is washed the washed hydrotreated hydrocarbon vl.
separating a vapor phase from the J-substance; (d) scrubbing said vapor phase with water to produce a second sour water stream containing ammonia having a ratio of ammonia to hydrogen sulfide of at least 6:1; stripping said first sour water stream in a hydrogen sulfide stripper; (f) withdrawing O-71-head vapor from said hydrogen sulfide strips, said vapor being essentially nV ammonia; (g) Draw out the bottom liquid from the above-mentioned hydrogen chloride strip, where the above-mentioned liquid consists of water, aqueous sulfide and ammonia; Add the bottom liquid as described above to the second sour water stream, and (j) strip the second sour water stream in an ammonia stripper.
I extracted some overhead steam from my own ammonia stripper, where said steam was composed of water, valued marine products, and ammonia, (1+) Partial condensation of the aforementioned Meverhead vapor from the own ammonia stripper and additionally hydrogen sulfide and water-free ammonia vapor. The condensed part and the condensed part consisting of water, water sulfide and ammonia are destroyed, (→ part of said condensed part is returned to said ammonia stripper, and (phrase) the other part of said condensed part is A method characterized in that the hydrogen sulfide is recycled to a hydrogen sulfide stripper. (2) (a) A hydrocarbon material containing sulfur and a hydrogen sulfide is subjected to a mild hydrogenation treatment, during which its carbonization is A part of the silica present in the hydrogen substance is converted into ammonia, and a part of the sulfur present in the hydrocarbon substance is converted into sulfide water, (1)) the above-mentioned hydrogen habitat 8! (Q) washing the washed hydrotreated reverted hydrogen material and forming a first effluent stream consisting of water, ammonia, and hydrogen sulfide; ,
separating from said first effluent stream (in) hydrotreating said washed demetalized oil in the presence of hydrogen; (41) converting the hydrotreated hydrocarbon material into ammonia, and converting most of the sulfur remaining in the hydrotreated hydrocarbon material into hydrogen sulfide; washed water bulked hydrocarbon material containing ammonia and hydrogen sulfide in the vapor phase; , forming a second effluent stream consisting of ammonia and hydrogen sulfide; (f) separating the washed hydrogenated! , do it,
The vapor phase is separated from the washed hydrogenated water bulk material in a pressure separator, and the vapor phase is scrubbed with water to ensure that the ratio of round nia to sulfurized water is at least An aqueous bath solution of 6:1 ammonia is produced and stripped in a sulfide water bulk stripper with a 11,1 lil J ratio; (1) overhead vapors are withdrawn from an AIJ sulfide water bulk stripper; , where said vapor consists essentially of sulfide water without ammonia; The bottom liquid of tkJ AU is made into the second effluent, and the second effluent of 1JII is mixed with vC in an ammonia stripper.・I-C stripping (匈@
An overhead vapor is drawn from the ammonia stripper described above, wherein said overhead vapor is comprised of water, hydrogen sulfide, and ammonia, and a bottom liquid is drawn from said ammonia stripper, wherein said bottom liquid is consisting of strip water, consisting entirely of an uncondensed portion consisting of hydrogen sulfide and water-free ammonia vapor, and a condensed portion containing water, hydrogen sulfide and ammonia; (p) one of said condensed portions; a portion of said ammonia stripper, and (q) recondensing another portion of said condensed portion to said sulfurized water bulk stripper. Method for treating substances. (: 1 μg) The washed hydrogenated cinnabar water material of step (f) is further subjected to hydrogenation in the second step.
Methods for treating bulk hydrocarbon materials described in Section 1.