Process Description Feedstock – natural gas – enters inlet separator 1, where it is separated into gas, hydrocarbon condensate and methanol-water solution Further, the separated NG is separated into 2 streams. The first stream is cooled in recuperative heat exchanger 2 and enters separator 4 through reducing device 3. The second stream is directed into tube side 10 of the stripping section of vessel 8, partially condenses and mixes with the gas at the outlet of heat exchanger 2 in the form of a gas-liquid mixture. The low-temperature separation gas from separator 4 is heated in recuperative heat exchanger 2 and discharged from the unit in the form of commercial gas. Hydrocarbon condensate from separators 1 and 4 after pressure reduction in devices 5 and 6, respectively, is supplied as reflux of the upper contact section 9 and then flows into the shell side of the lower stripping section 10 of vessel 8, where vapors are formed and move countercurrent to the liquid phase and are removed from the upper part of the contact section 9, and then they are mixed with gas at the outlet of separator 4. Fractionated hydrocarbon condensate from the shell side of stripping section 10 of vessel 8 is discharged to the condensate degassing unit 7,
Process features
Low capital investment
Increased extraction of gas condensate of propane-butane fraction, stable gas condensate and C3+ hydrocarbon fraction
Minimization of methanol losses
Elimination of gas flaring
Technical Specification
Reduction of the required differential pressure for gas treatment to 1.5-1.8 MPa
Applicable for the line of CGTU with unit capacity of up to 10 million nm³/day of commercial gas
Withdrawal of stable gas condensate up to 99.9%, PBF 75-85%
Block-modular design
Patents of the Russian Federation No. 2718073, 2718074
Development level, industrial application Year 2016, revamping of the CGTU at the Vostochno-Urengoyskoye field