Amine Treating Plants

Amine treating plants remove CO2 (carbon dioxide) and H2S (hydrogen sulfide) from natural gas. Amine has a natural affinity for both compounds, which makes amine treating an efficient and effective removal process. Newpoint's proprietary amine plant design is based on proven amine regeneration technology and incorporates several patent-pending processes to improve reliability and ease of operation.

Contaminants Removed by Amine Treating

• CO2 (Carbon Dioxide)
• H2S (Hydrogen Sulfide)

Benefits of Amine Units

• Reduces CO2 and H2S levels to the required specifications
• Modular, skid-mounted systems
• Reduced manufacturing and commissioning times
• Standardized and proven designs
• New equipment only
• Guaranteed performance
• Lower installation and removal costs
• Built-in liquid containment to reduce environmental hazards

Shortest Lead Time Possible

To meet the growing demands of industry, Newpoint made the decision in 2005 to standardize its designs, build equipment on speculation, and keep plants ready for immediate delivery. In 2006 and 2007, Newpoint further optimized these units and reduced equipment commissioning times by 50 percent.

Why Remove CO2 and H2S

Carbon dioxide, hydrogen sulfide and other contaminants are commonly found in natural gas streams. CO2 combines with water to create carbonic acid, which is corrosive, and it reduces the BTU value of the gas; at concentrations above 2 to 3 percent, the gas becomes unmarketable. H2S is an extremely toxic gas that is also highly corrosive to equipment. Amine sweetening removes these contaminants so the gas is marketable and suitable for transportation.

Companies around the world have found Newpoint's proprietary design to be the right fit for their gas treating applications.

Amine Gas Sweetening Solutions

Amine gas sweetening is a proven technology that removes H2S and CO2 from natural gas and liquid hydrocarbon streams through absorption and chemical reaction. Each amine offers distinct advantages for specific treating problems.

Amine	Application
MEA (Monoethanolamine)	Used in low pressure natural gas treatment applications requiring stringent outlet gas specifications
MDEA (Methyldiethanolamine)	Has a higher affinity for H2S than CO2, which allows some CO2 "slip" while retaining H2S removal capability
DEA (Diethanolamine)	Used in medium to high pressure treating; does not require reclaiming, as MEA and DGA systems do
Formulated (specialty) solvents	Blended or specialty solvents available to solve unique treating problems

Typical Amine Gas Sweetening Process

1. Sour gas enters the contactor tower and rises through the descending amine.
2. Purified gas flows from the top of the tower.
3. The amine solution is now considered rich and is carrying absorbed acid gases.
4. The lean amine and rich amine flow through a heat exchanger, heating the rich amine.
5. Rich amine is further heated in the regeneration still column by heat supplied from the reboiler. Steam rising through the still liberates H2S and CO2, regenerating the amine.
6. Steam and acid gases separated from the rich amine are condensed and cooled.
7. The condensed water is separated in the reflux accumulator and returned to the still.
8. Hot, regenerated, lean amine is cooled in a solvent aerial cooler and circulated back to the contactor tower, completing the cycle.

Typical Amine Plant Standard Features

• 100 percent pump standby
• ASME Code and National Registration on all vessels
• Shell and tube or plate frame heat exchangers
• B31.3 compliant piping
• Fully custom electrical systems and instrumentation
• Full flow carbon filtration
• Engineered corrosion control
• Spill and leak containment
• Multiple patents-pending to enhance ease of operation and maintenance
• Modular design to reduce installation time and cost
• High efficiency reboilers