Abstract: A process for hydroprocessing liquid petroleum and chemical streams in two or more hydroprocessing stages, which stages are in separate reaction vessels and wherein each reaction stage contains a bed of hydroprocessing catalyst. The liquid product from the first reaction stage is sent to a stripping stage and stripped of H.sub.2 S, NH.sub.3 and other dissolved gases. The stripped product stream is then sent to the next downstream reaction stage, the product from which is also stripped of dissolved gases and sent to the next downstream reaction stage until the last reaction stage, the liquid product of which is stripped of dissolved gases and collected or passed on for further processing. The flow of treat gas is in a direction opposite the direction in which the reaction stages are staged for the flow of liquid. Each stripping stage is a separate stage, but all stages are contained in the same stripper vessel.

Abstract: A process for hydroprocessing liquid petroleum and chemical streams in a single reaction vessel containing two or more hydroprocessing reaction stages. The liquid product from the first reaction stage is stripped of H.sub.2 S, NH.sub.3 and other dissolved gases, then sent to the next downstream reaction stage. The product from the downstream reaction stage is also stripped of dissolved gases and sent to the next downstream reaction stage until the last reaction stage, the liquid product of which is stripped of dissolved gases and collected or passed on for further processing. The flow of treat gas is in a direction opposite the direction in which the reaction stages are staged for the flow of liquid.

Abstract: A method for determining the efficiency of a carbon filter to absorb hydrocarbons from an organic amine solvent. After the solvent has passed through the filter, a sample is taken and passed through a standard gas chromatograph (GC) to measure the area counts for the hydrocarbons and the solvent. The sample does not have to have an internal standard added thereto nor does it have to be measured before it is run through the GC. The area counts are converted into actual amounts by using Reduction Factors taken from a specially-prepared calibration table. These amounts are normalized and added to give the total amount of hydrocarbons present in the solvent after it has passed through the carbon filter.

Abstract: Water to be utilized is reacted with soda ash and lime to produce a less corrosive and foulant water. Reaction sludges are fed to a desulfurization unit, where SO.sub.x, NO.sub.x and CO.sub.2 abatement occurs; other industrial waste sludges and/or waters and/or gases can also be utilized in such connection. FIG. 1 is one of the possible process schemes of the present invention.

Abstract: Sulfur oxides (SO.sub.x) are scrubbed from combustion effluents with aqueous limestone slurries with greater efficiency due to the use of an improved entrainment separator. In the preferred embodiment of a single-loop, counter-current limestone wet scrubber operating at bulk gas flow rates of greater than 4.5 meters per second, a vertical stream of flue gas is freed of a substantial portion of slurry droplets and diverted for effective mist removal by a well-drained, horizontal-flow mist eliminator. The entrainment separator is a single-pass device with individual blades aligned for effective operation with reduced droplet impingement on the upper walls (e.g., roof) of the scrubber and to permit periodic washing.

Abstract: A process for determining if intermittent water injection is the best way to remove deposits such as salts from refinery process streams. A water vapor pressure, P1, at stream conditions and a water vapor pressure, Ps, at saturation conditions in the stream, are used to calculate a ratio P1/Ps. If the ratio is less than 0.1 intermittent water washing is preferred. An optimized intermittent injection procedure, frequency, duration, and constraints, is disclosed. Chemical speciation calculations ensure that all accumulated salts are removed, and that an aqueous phase forms downstream of the water injection point having a salt concentration within acceptable limits.

Abstract: A continuous water washing process for removing salts from refinery process streams is disclosed. The salt and salt precursor content of a process stream is determined, and iterative calculations made to ensure an aqueous phase forms downstream of the water injection point with a salt and ion concentration within acceptable limits. Preferably chemical speciation calculations are used to check for corrosive, transient aqueous phases intermediate the point of water injection and the process outlet.

Abstract: A method for removing hazardous gases having water solubility from storage tanks by scrubbing steps is described. Additionally, a method for removing ethylene dichloride contamination from soil is disclosed.

Abstract: An odor control system and method for removing unwanted odorous airborne constituents in which the gas stream is flowed through a compact, boxlike housing having a plurality of sequentially communicating treatment chambers. Gas stream pretreatment is accomplished in a first chamber, in fluid communication with a sump, as the gas flows through a packed bed wetted by suitable chemical reagents. After pretreatment, the gas stream is passed through downstream chambers, also utilizing wetted packed beds. These chambers are in fluid communication with a second, separate sump. Because of the first chamber/separate sump combination, influent gas treatment, by stages, can be accomplished. In this manner, different, contemporaneous chemical treatments are possible, within the single housing, with different chemical reagents utilized as needed. Such treatments are possible even in cases where otherwise incompatible chemical reagents are used.

Abstract: An apparatus and method for removing particulate and gaseous pollutants from flue gas. The flue gas enters a presaturation section and is treated with a coarse spray of solution recovered from the system. The saturated gas enters a primary contacting section and is contacted by an ultrafine mist of fresh solution containing a gaseous pollutant absorption agent. The fine mist has an average droplet size of approximately 20 microns. The gas moves to a secondary contacting section where it is contacted by a coarse spray of recirculated solution. If necessary, the gas is demisted. Finally, the gas is discharged into the environment. Usable spent solution is regenerated and reused. Unusable water byproducts containing contaminants are discharged.

Abstract: A forced recirculation of a part of the untreated flue gas is established along the inside wall of a dry scrubber by providing a counterflowing gas flow along the length of a dry scrubber housing wall to prevent deposition of wet particulate material on the inside walls caused by recirculation of particulates and flue gas thereon.

Abstract: A method for inhibiting the formation, deposition, and adherency of scale-forming salts, including calcium sulfite, in process waters. The method is particularly suited for use in pulp mill lime kiln flue gas scrubber systems and multi-effect evaporators. Additionally, the method is effective at high pH and high calcium sulfite saturation levels.

Abstract: A dissipator for percolating a mixture of flue gases and powdered lime through a body of water to remove SO.sub.2 from the flue gases includes an elongate tubular body having first and second ends. The first end of the tubular body has an inlet through which the flue gases and lime mixture is introduced into the dissipator. The second end of the tubular body is generally closed. There are a plurality of perforations in the wall of the tubular body through which the mixture of lime and flue gases can escape from the dissipator. A plurality of disrupters spaced longitudinally inside the elongate tubular body facilitate the mixing and reaction of the lime and the flue gases. Each disrupter comprises a plate with a plurality of baffles mounted on the upper thereof to facilitate the mixing of the flue gases and powdered lime mixture delivered into the dissipator.

Abstract: Sulfur oxides (SO.sub.x) are scrubbed from combustion effluents with aqueous limestone slurries with greater efficiency due to the use of an improved entrainment separator. In the preferred embodiment of a single-loop, counter-current limestone wet scrubber operating at bulk gas flow rates of greater than 4.5 meters per second, a vertical stream of flue gas is freed of a substantial portion of slurry droplets and diverted for effective mist removal by a well-drained, horizontal-flow mist eliminator. The entrainment separator is a single-pass device with individual blades aligned for effective operation with reduced droplet impingement on the upper walls (e.g., roof) of the scrubber and to permit periodic washing.

Abstract: The invention provides a method for removing sulphur compounds from water by anaerobic reduction of the sulphur compounds to sulphide, followed by a partial oxidation of the sulphide to elementary sulphur. The anaerobic reduction is carried out at elevated temperature, either continuously at a temperature of 45.degree.-70.degree. C., or periodically at a temperature of 55.degree.-100.degree. C. If the reduction is carried out periodically, a single rise in temperature for a few hours to several days over a period of 3-6 months can suffice. The method is particularly applicable to the removal of sulphate, sulphite and thiosulphate.

Abstract: A method for converting a double-loop flue gas desulfurization system to a single-loop desulfurization system includes removing the deep packing from the scrubber housing and replacing the packing with a thin tray having a plurality of perforations. The return line which connects the bowl is removed from the feed tank; and a plurality of openings, apertures or perforations are provided in the shroud ring and the bowl of the housing in order to permit slurry to pass from upper spray headers to the bottom of the housing as well as permit flue gas flow upwardly through the housing to the flue gas outlet. The lower spray headers are removed from the housing and the feed line connected to the lower spray headers is reconnected to the feed tank for providing the single-loop. An oxidation air system is provided in the feed tank for creating an in-situ forced oxidation system.

Abstract: Solute gas-rich absorbing media formed in scrubbing a solute gas from an off-gas stream prior to discharge of the same are regenerated to solute gas-lean absorbing medium for recycle to the scrubbing operation. Hot solute gas-rich absorbing media is formed into one or more spray patterns of very small liquid droplets in a flowing purge steam stream in a chamber into which the solute gas is desorbed from the droplets. The droplets are coalesced to form a regenerated absorption medium, the solute gas-containing gas stream is cooled to condense out the steam and a pure solute gas stream is recovered. The operation may be effected in multiple stripping stages, which may utilize cocurrent flow of solute gas laden absorbing medium and purge steam within a single chamber or in multiple chambers. Multiple stripping steps may be effected within a single stripping stage.

Abstract: In the process for recovering carbon disulfide from a steam/carbon disulfide mixture, which is produced when the wastewater from the yarn cutters and the suspension water are treated with steam during the manufacture of viscose rayon, the vapors so produced are cooled by means of a liquid spray, drawn out of the vapor condenser and then condensed. The non-condensable constituents are removed via a trap and the liquefied carbon disulfide is separated from the remaining water. Specifically, the liquid used to spray the vapors is preheated by the thermal energy recovered from the cooling of these vapors, and the hot water thus obtained is then used for other purposes.

Abstract: An absorber tower that is configured to progressively increase the flow of the flue gas therethrough. This is accomplished by reducing the cross-sectional area of the tower (either continuously or in steps) thereby forcing the gas to increase in velocity as it travels toward the exit conduit.

Abstract: For the selective removal of sulfur from gases, a physical scrubbing agent is used, comprising a heterocycle having five or more ring atoms, which contains two heteroatoms, one of which is nitrogen and the other of which is oxygen or nitrogen; and the heteroatoms in the rings of even member number of atoms occupy; one of the positions from 1,2 to 1,n/2 and, in the rings of uneven member number of atoms occupy one of the positions from 1,2 up to 1, (n-1)/2. Further, the nitrogen heteroatom(s) present in the ring is/are either double bonded or single bonded but, if single bonded, the nitrogen is organo-substituted.

Abstract: Improved processes for treating gas streams containing hydrogen sulfide, carbon dioxide, water vapor and methane, particularly natural gas streams. The processes rely on the availability of two membrane types, one of which has a hydrogen sulfide/methane selectivity of at least about 40 when measured with multicomponent gas mixtures at high pressure. Based on the different permeation properties of the two membrane types, optimized separation processes can be designed. The membrane separation is combined with non-membrane treatment of the residue and/or permeate streams.

Abstract: A method and apparatus for recycling the bottoms product from an absorber tower back to the absorber tower. However, before the bottoms product is returned to the tower, the solid particles entrained therein are removed via one or more centrifuges closely coupled to the absorber tower. These centrifuges are located adjacent the tower and are elevated with respect to the tower such that their centrate can be directly returned or delivered back to the absorber tower via gravity.

Abstract: Hydrogen sulfide is removed from natural gas by contacting the natural gas with a scrubber oil that absorbs the hydrogen sulfide. The natural gas typically contains some water, or water can be added, and the resulting mixture is used to form a water-in-scrubber oil emulsion. Sulfur dioxide added to the water-in-oil emulsion reacts with the hydrogen sulfide present in the emulsion.

Abstract: A method for treating a gas stream to remove heat, gaseous, liquid or particulate matter, or add heat, vapor, or moisture, which includes the steps of:providing a tower having a bed with fluidizable hollow ellipsoidal packing with a long semi-axis and a short semi-axis;introducing a liquid stream into the tower at a liquid flow rate L, and countercurrently introducing the gas stream into the tower at a gas flow rate G sufficient to maintain the bed in a fluidized state and a gas velocity v; andadjusting the volume ratio of the liquid flow to gas flow to cause the ellipsoidal packing to circulate predominantly in the vertical direction relative to the long semi-axis and to maintain a pressure gradient .DELTA.P/H.sub.o across the depth of the fluidized bed of at least about 1500 Pa/m, and, simultaneously, to satisfy the equation:L/G=K.sub.1 (.DELTA.P/H.sub.o v)+K.sub.2wherein L/G is the volume ratio of liquid to gas; .DELTA.P is the pressure drop across the bed; H.sub.

Abstract: A system for continuously monitoring the hydrogen sulfide concentration present in the atmosphere above a waste water stream, such as a sewerage stream, and for controlling the amount and time of injecting a specified chemical into the waste water stream in order to control the quantity of hydrogen sulfide which would evaporate into the atmosphere.

Abstract: An improved apparatus and method for spraying a liquid into a flue gas provides a boundary layer of gas along a perimeter of a dry scrubber housing to prevent deposition of wet material on the sidewalls thereof. The boundary layer of gas includes the use of heated air, particulate free flue gas, and/or dust laden flue gas. The system is operated at/or near the saturation temperature to further increase removal efficiencies and reagent utilization.

Abstract: Acid gas (a mixture of carbon dioxide and hydrogen sulfide) is absorbed by produced water from hydrocarbon wells. The acid gas is absorbed in the produced water in a static mixer. The time from the entry of the produced water into the static mixer to its exit is less than ten seconds. The produced water with the absorbed acid gas is pressurized to flow through a pipeline to an injection pump. The injection pump injects the produced water with the absorbed acid gas into injection wells which return the produced water into disposal strata. The produced water with the acid gas is maintained at a pressure higher than the pressure at the exit of the static mixer.

Abstract: Process for removing hydrogen sulfide at low concentration in a gas containing water vapor. The gas is cooled to a temperature below the dew point of water, which condenses and separates the water. The dry gas is scrubbed free of hydrogen sulfide by an H.sub.2 S-absorbent solvent forming a purified gas. The purified gas is contacted and rehydrated with heated water so that the water content as water vapor corresponds to a mass flow rate of water substantially equal to the mass flow rate of the water present in the H.sub.2 S-containing gas before cooling. An apparatus for carrying out the process is disclosed.

Abstract: A packed mass transfer tower for establishing intimate gas/liquid contact and efficient mass transfer that is less susceptible to gas or liquid channeling, gas surging and uneven distribution of gas or liquid across the cross-sectional area of the tower. The packed tower includes a packing arrangement including a lower bed of mobile packing elements, and an adjacent upper bed of fixed packing elements. The packed bed of fixed packing elements acts as a gas distributor, as well as causing good gas/liquid contact, to provide an even flow of gas across essentially the entire cross-sectional area of the packed bed of mobile packing elements.

Abstract: A high pressure synthetic gas stream is produced by gasifying coal. Hydrogen sulfide is removed by contacting the high pressure gas stream with a physical solvent, such as an alcohol, in an absorber column. A low temperature is maintained in the absorber column, typically by chilling both the solvent and the incoming high pressure synthetic gas stream, where a portion of the cooling requirement is supplied by adiabatically expanding the cleaned high pressure gas stream exiting the absorber. Typically, the cleaned high pressure gas stream will be expanded in a turbine expander to provide mechanical energy in addition to cooling capacity. The cleaned synthetic gas is useful as a fuel or chemical feedstock.

Abstract: A novel class of solvents is described that have improved selectivity for H.sub.2 S as compared to CO.sub.2. The solvents are based on adding suitable second partially miscible solvent to known solvents. In specific, it is shown that adding 20% of dodecane to NMP (normal methyl pyrolidinone) increases the selectivity of the solvent for H.sub.2 S as compared to CO.sub.2 by 50%. This leads to important process improvements and reduction in the cost of the removal process.

Abstract: A composition for acid gas absorbent comprising:(A): 99.99 to 70 wt % of a polyethylene glycol dimethyl ether composition represented by the following formula:CH.sub.3 O(C.sub.2 H.sub.4 O).sub.n CH.sub.3wherein n is an integer of 1 to 10; and,(B): 0.01 to 30 wt % of a compound containing at least one of an --NH-- group, a phenolic --OH group and an --S-- group in one molecule thereof but free from an alcoholic --OH group, is provided. More particularly, component B may be an amine, preferably a secondary amine, or a phenolic compound.

Abstract: Sulfur dioxide is removed from a fluid containing SO.sub.2 by employing as an absorbent for the SO.sub.2 an aqueous solution of a compound represented by Formula I: ##STR1## wherein each Y is independently --(CR.sup.2.sub.2)--or--(CR.sup.2).dbd.and each R.sup.1 or R.sup.2 is independently hydrogen, an alkyl group; an hydroxyalkyl group: an aldehyde group: a carboxylic acid group or salt thereof: an alkyl group containing at least one carboxylic ester, a carboxylic acid or salt thereof, ether, aldehyde, ketone, or sulfoxide group: wherein the compound has at least one carbonyl group. The absorbent solution preferably can be thermally regenerated by heating to remove SO.sub.2.

Abstract: A method for treating a gas stream to remove heat, gaseous, liquid or particulate matter, or add heat, vapor, or moisture, which includes the steps of:providing a tower having a bed with fluidizable hollow ellipsoidal packing with a long semi-axis and a short semi-axis;introducing a liquid stream into the tower at a liquid flow rate L, and countercurrently introducing the gas stream into the tower at a gas flow rate G sufficient to maintain the bed in a fluidized state and a gas velocity v; andadjusting the volume ratio of the liquid flow to gas flow to cause the ellipsoidal packing to circulate predominantly in the vertical direction relative to the long semi-axis and to maintain a pressure gradient .DELTA.P/H.sub.o across the depth of the fluidized bed of at least about 1500 Pa/m, and, simultaneously, to satisfy the equation:L/G=K.sub.1 (.DELTA.P/H.sub.o v)+K.sub.2wherein L/G is the volume ratio of liquid to gas; .DELTA.P is the pressure drop across the bed; H.sub.