Systems and methods for improved column operation in offshore environments by using a co-current contactor system in floating production, storage and offloading (FPSO) systems.

A high efficient desulfurization-regeneration system using a suspension bed, including a suspension bed reactor, a gas liquid separation tank, a flash evaporation tank and an oxidation regeneration tank that are connected in sequence, and a fixed bed reactor connected to the exhaust port of the gas liquid separation tank. The system reduces the sulfur content in a hydrogen sulfide containing gas from 2.4-140 g/Nm.sup.3 to 50 ppm or less, and further reduces the sulfur content to less than 10 ppm in conjunction with a fixed bed. High efficient desulfurization is achieved by combining the crude desulfurization of the suspension bed with fine desulfurization of the fixed bed connected in series. The spent desulfurizer can be regenerated by reacting an oxygen-containing gas with the rich solution, and the barren solution obtained by the regeneration may be recycled for use as desulfurization slurry, without generating secondary pollution.

An improved system for separating gas from a process stream by providing a stripping unit at the overhead stream of a fractionation column to selectively and effectively remove the gas using a stripping fluid without providing a dedicated light-ends separations unit. The stripper unit may be connected to the reflux drum at the overhead stream. The system for separating gas further achieves greater thermodynamic efficiency by means of a split column design using mechanical vapor recompression with the reboiler and condenser integrated in a falling-film evaporator- or thermosiphon-type vapo-condenser.

A manufacturing system of an electronic-grade ammonia solution comprises: a mixing tank to mix an unsaturated ammonia aqueous solution and alkali to obtain a mixing solution; a stripping unit, disposes downstream the mixing tank and comprises a heat exchanger to heat the mixing solution, and a stripping column to mix a nitrogen gas and the heated mixing solution to obtain a mixing gas; a first absorption unit, disposes downstream the stripping unit and comprises a first condensation unit to cool down the mixing gas, and a first absorption column to mix a saturated ammonia aqueous solution and the cooled mixing gas to obtain a purge gas; and a second absorption unit, disposes downstream the first absorption unit and comprises a second condensation unit to cool down a DI water, and a second absorption column to mix the cooled DI water and the purge gas to obtain electronic-grade ammonia solution.

An air stripper apparatus is disclosed which incorporates a plurality of trays that are removably supported within a cabinet. A plurality of downcomers are also fixedly disposed within the cabinet, rather than on the trays. Removing the downcomer from each tray enables a simpler, lighter and easier to clean tray to be constructed.

An ammonia stripper has an aerator and heat exchanger tubing in a tank. The aerator and coil are preferably attached to a frame to form a removable cassette. The cassette may also include a lid for the tank. The tank is preferably rectangular and optionally can be made with the dimensions of a standard shipping container. In a process, water flows through the tank while air bubbles are produced through the aerator. A heating medium such as water flows through the heat exchanger tubing. A gas containing ammonia is withdrawn from a headspace of the tank.

Present invention relates to a method for removal of oxygen from seawater comprising the following steps: lead a stream of seawater (1) to be treated and a pressurized stripping gas (2) to a first mixer (3) and mix the seawater (1) with stripping gas (2); lead the combined stream (4) of seawater (1) and stripping gas (2) to a first gas/liquid inline separator (5) and separate the stream (4) into a liquid rich (6) and a gas rich (1 1) phase; lead the liquid stream (6) and a stripping gas stream (7) containing CO2 and water to a second mixer (8) and mix the liquid stream (6) with the gas stream (7); lead the combined stream (9) from the second mixer (8) to a second stage gas/liquid inline separator (10) and separate the combined stream into a liquid rich (14) and a gas rich phase (15); mix the gas stream (1 1) from the first gas/liquid separator (5) with a fresh water stream (22) and lead this combined stream to a first stage scrubber (12) and remove a major portion of the salt entrained in the combined stream from the scrubber (12); lead the salt depleted gas stream (16) from the first scrubber (12) via a heat exchanger or electrical preheater (17) together with a fuel stream (18) to a catalytic deoxidizer (13) and react the fuel (18) and oxygen (19) to a CO2, H20 in the stripping gas stream (7) and mixing this gas stream (7) with the liquid stream (6) from the first stage separator (5); mix the gas stream (15) from the second stage separator (10) with fresh water to remove or dilute the entrained salt in the gas stream (15) and lead the resulting gas stream to a compressor (23); combine the salt depleted gas stream (2) from the compressor (23) and seawater (1) to be treated

A CO.sub.2 recovery device includes: a CO.sub.2 absorption tower in which CO.sub.2 included in an exhaust gas is absorbed by a CO.sub.2 absorption liquid; and a CO.sub.2 absorption liquid regeneration tower that heats and regenerates the CO.sub.2 absorption liquid that has absorbed CO.sub.2. The CO.sub.2 absorption liquid regeneration tower includes: a main body part in which the CO.sub.2 absorption liquid is temporarily stored; a boot part provided downward from a tank end of the main body part, having a relatively smaller capacity than the main body part; a flowmeter provided to the boot part, and measuring the liquid surface level of the CO.sub.2 absorption liquid that changes between the main body part and the boot part; and a control device controlling the liquid surface level of the CO.sub.2 absorption liquid between the main body part and the boot part on the basis of the measurement result of the flowmeter.

Methods, systems and designs are provided for removing mercury from crudes. Crude oil containing a synthetic reducing agent is heated to a temperature above 100? C. and held at that temperature for a specified period of time to convert all of the forms of mercury in the oil into the elemental mercury form. The elemental mercury is then stripped from the crude oil by e.g., flashing the hot oil and/or contacting it with a gas phase.

The present invention relates to a system for desorption of acid gas (1) from an acid gas rich absorption liquid having a steam part (3) and a process part (4). The steam part (3) and the process part (4) are separated to prevent intermixing of fluids in the steam part with fluids in the process part. The system (1) comprises a desorption cylinder (9) which is adapted to rotate about a longitudinal axis of rotation A of the desorption cylinder (9), and a stationary support stand (19) for supporting the desorption cylinder (9), and means for rotating (18) the desorption cylinder. The steam part (3) and the process part (4) are integrated in the desorption cylinder (9) and steam is supplied to the steam part (3) and acid gas rich absorption liquid (2) is supplied to the process part (4). The process part (4) comprises a desorption chamber (12) provided with a stripper unit (33) having an integrated reboiler (52) and the process part (4) is provided with means for discharging an acid gas lean absorption fluid (2) and having means for removing acid gas rich vapor (8), and the steam part (3) is provided with means for discharging condensate (6). The present invention also relates to a method for desorption of acid gas from an acid gas rich absorption liquid.