Acid Gas Removal Plants for Sale

600 MMSCFD (300 MMSCFD per train X 2 trains) Amine plant was designed to treat sour gas containing 3.16 mol% CO2 and 1.55 mol% H2S. Amine circulation rate is 1175 GPM. Sweet gas generated from the plant contains 1.12% CO2 and 4 ppm H2S. Amine contactor operated at 81.7 barg pressure, 63 degree Celsius. The plant has turn-down ratio of 20% of its designed capacity. The plant was built for a service life of 25 years. After pre-commissioning, it has never been operated. No hydrocarbons entered into the plant. Currently the plant is being maintained in preservation mode in a dormant state and ready to start.

Used 60 MM SCFD / 1500 GPM Amine plant built in 1997. 60 MMSCFD gas flow rate, 1500 GPM circulation rate, inlet gas pressure 310 PSI, designed to remove 33% CO2, 1.45% H2S. The plant provides gas sweetening to the incoming inlet hydrocarbon gas with the removal of CO2 & H2S in varying degrees depending on the selection of solvent utilized in the process. The existing selection of amine solvent was optimized for deep CO2 & H2S removal using Dow Chemical's Ucarsol AP-804 amine solvent. The design of the system was to treat 60MM SCFD of incoming gas and removing essentially all H2S and CO2 to the wet gas header specifications. The original basis of design for the system changed over the years to 85% CO2 and 2-5% H2S. Due to the high quantity of both contaminants in the inlet wet gas, a high circulation rate was required to keep the rich loading in the 30-40% region and is what drove the sizing of the system to such a large system.

Used 60 MM SCFD Carbon Dioxide removal plant (Benfield Low Heat process) built in 1997. The process is designed to treat 60MM SCFD of incoming natural gas with a hot 35% potassium carbonate solution to remove the remaining CO2 from an upstream Ucarsol process. This gas treating process removes CO2 down to a 1.2 mol % level. The incoming gas is treated by 2,770 gpm of 35% potassium carbonate at 218 degF. The advantage of the Benfield Low Heat process over an amine process is the lowest possible energy consumption by requiring approximately 50% less duty than a typical amine process.

Used 50 MMSCFD Amine Plant built in 1997. Designed by Tridyne Projects Corporation. 34 psi inlet pressure, 942 psi discharge pressure. 125 bbl a day Pentane+ capacity with 0.35 MMSCFD acid gas injection. 95.9% sulphur recovery efficiency, with >= 1.0 t/d sulphur inlet. Amine tower manufactured by Cessco. 56’ L X 60” ID dimensions, 675 psi max pressure. Shut down in 2014.

Used 35 MMSCFD / 225 GPM Sulfinol process Amine treatment plant built in 1979. Inlet gas flow rate: 35 MMSCFD, pressure: 1080 PSI, circulation rate: 225 GPM, designed to remove 4.41% CO2 and 1.77% H2S from natural gas. The plant is still in operation condition, will be shut down and for sale very soon.

Used 30 MMSCFD CO2 removal plant for sale. The plant is designed to use multiple stage membrane process to remove 71% CO2 from inlet natural gas. After dehydration, the inlet gas is routed to the first membrane. The first separation removes about 40% of the incoming CO2 and delivers a high CO2 permeate off gas stream at a pressure of near 75 psia. This 96% quality permeate stream can be vented or can be re-compressed and delivered to a CO2 pipeline for commercial sales. The CO2 in the inlet gas stream is reduced from near 74% to near 60% in this first stage. The second stage of the membrane separation reduces the incoming CO2 from 60% to near 20%. The third stage of the membrane reduces the incoming CO2 from near 20% to approximately 6%. The fourth stage of the membrane reduces the incoming CO2 from near 6% to approximately 3%. The second, third and fourth stages of the membrane separation produce permeate streams at a pressure near 30 psia. All three streams are combined together along with a dehydrated side stream coming from well. After each stage of membrane CO2 separation, the treated stream exits the membrane as a two-phase fluid. Each membrane is configured with liquid separation on the treated gas stream. The fourth stage exit stream is refrigerated to condense even more liquid hydrocarbon. The liquid hydrocarbon streams from each stage of membranes are combined and routed to a NGL stabilizer where it is stabilized to meet a MAPCO "Y" grade specification. The resultant product will be stored in NGL storage vessels and trucked out to NGL markets.

Used 300 MMSCFD Amine Plant built in 1988. The plant was designed to remove 0.36 mol% of CO2 from natural gas. The plant includes two (2) independent processing units. Each unit has capacity of 150 MMSCFD. Amine circulation rate is 90 GPM for each unit. The plant can use diethanol amine (DEA) solution or monoethanol amine (MEA) solution. The inlet gas has pressure of 905 psig at 75 degree F. The output gas has pressure of 850 psig at 85 degree F. The amine contactor has operating pressure 896 PSIG, design pressure 1250 PSIG, operating temperature: top 119 °F, bottom 110 °F. The plant was commissioned in 1988 and shut down in 2011.

Unused 150 MMSCFD / 700 GPM Audubon Engineering Amine plant built in 2014. Gas flow rate 150 MMSCFD, circulation 700 GPM, inlet gas pressure 1100 PSI (maximum working pressure 1350 PSI), designed to remove 7% CO2, 50 ppm H2S. Contactor Size: 90" ID x 60' Stainless Steel, Vertical, 1350 MAWP. MCC Building and PLC Controls. Mfg. 2014.

Used 16-tube membrane unit manufactured by Kvaerner Process Systems to remove CO2 from 15 MMSCFD of natural gas. Rated: 1200 psi @ 200 degrees F. 56 Fuji module filters installed in 2022 with lifetime up to 7 years. Filter size: 2.0C.

Unused 1125 GPM Amine CO2 Removal Plant, built in 2018. The process designed to remove CO2 from the syngas in the Amine Absorber using a lean amine solution (34% wt) and a water wash. Clean syngas from the overhead goes to the next unit (Syngas Compression) and rich amine (lean amine + CO2) from the bottom is pumped via the Rich Amine Booster Pumps, filtered in the Rich Amine Particulate Filter, heated in Lean/Rich Amine Exchanger, and sent to the Amine Regenerator tower, where the CO2 is separated from the solution by heating it with a reboiler. The reheated CO2 is released from the solution and flows through the overhead of the regenerator. The rich amine solution is converted to lean amine (without CO2) and is cooled down before returning to the absorber. From the bottom of the regenerator, the lean amine transfers heat to the rich amine in the Lean/Rich Amine Exchanger. The lean amine if further cooled down in the Lean Amine Cooler. The lean amine flow splits: 20% of the flow passes through 2 particulate filters and 1 carbon filter, and the remaining 80% returns directly to the absorber, unfiltered; the regeneration of amine is an iterative process.

Used 60 MMSCFD / 165 GPM Amine Plant Gas Treating System built in 2011. Removes 4% carbon dioxide from the inlet gas by amine treating; amine regeneration to continuously regenerate and recirculate the amine solution used in the amine contactor; an HMO system to transport heat from the HMO heater to the amine reboiler; and drain system to store collected drain fluids.

Used 43 MM SCFD (300 – 500 GPM) Amine Plant built in 1995. Plant has been dismantled. One (1) 328 GPM pump and one (1) 650 GPM pump have been removed. All other equipment is available. Equipment data files are available. Amine contactor specifications: 48” ID X 50’ S/S, 1440 psig at 130 °F, 20 Trays.

Used 40 - 250 MMSCFD Amine Plant built in 1990. This amine gas treater is used to remove hydrogen sulfide H2S and carbon dioxide CO2 from gases. Different amines that can be used in gas sweetening or acid gas removal are Diethanolamine (DEA), Monoethanolamine (MEA), Methyldiethanolamine (MDEA), Diisopropanolamine (DIPA), Aminoethoxyethanol (Diglycolamine) (DGA). This amine plant operates at 1,000 GPM @ 1250 PSI @ 200°.