Natural gas processing
Download June 20, 2017

Acid Gas Loading in Amine Solutions for Natural Gas Sweetening Process: A Brief Overview


Raw natural gas consists primarily of methane (CH4), and varying amounts of higher molecular weight hydrocarbons and other contaminants. Natural gas containing acidic contaminants (H2S and/or CO2) is commonly referred as sour gas. H2S is a highly toxic gas which can be fatal to humans at higher concentration. Acid contaminants can also create problems such as increased corrosion in gas pipelines. To avoid these health, safety, and operational problems, acidic contaminants need to be removed to produce a ‘sweet’ gas stream. The sweet gas should have an H2S content of less than 4 ppmv. The process used to remove these species is commonly known as natural gas sweetening. The most common sweetening process utilizes an amine solution to absorb the H2S and CO2. According to the GPSA Engineering Databook (13th edition) [1], the amine circulation rate can be determined based on the moles of acid gas that need to be removed, as well as the ‘acid gas loading’ in the rich amine solution. Hence it is very important to understand the acid gas loading parameter for effective and efficient operations.

Acid Gas Loading in Amine Solutions

A typical amine sweetening process includes an absorber unit and a regenerator unit. In the absorber, the amine solution absorbs H2S and CO2 from the sour gas to produce a sweetened gas stream as a product and a rich amine solution with the absorbed acid gases. This rich amine is then routed into the regenerator to produce a lean amine that can be reused in the absorber. The most commonly used amines in industrial plants are the alkanolamines MEA, DEA, and MDEA. During the last 20 years, MDEA has become the most popular solvent, especially when used for the selective removal of H2S over CO2. [2]

What Is Acid Gas Loading?

As per GPSA Engineering Databook [1], acid gas loading is the amount of acid gas, on a molar basis, that will be picked up by a solvent. This is commonly expressed in units of mole of acid gas / mole amine.

Common Acid Gas Loading Ranges

The acid gas loading depends on a number of factors. For example, it depends on the type of amine (MEA, DEA or MDEA) used in the sweetening process. From the GPSA Engineering Databook [1]:

  • MEA: The acid gas loading is traditionally limited to 0.3-0.35 mole acid gas/mole MEA.
  • DEA: The acid gas loading with DEA is typically 0.35-0.82 mole acid gas/mole DEA.

From Oilfield Processing of Petroleum Natural Gas Volume One [3]:

  • MEA: The typical acid gas loading is 0.35 moles of acid gas/mole of MEA.
  • DEA: The typical acid gas loading is 0.5-0.7 mole acid gas/mole DEA.
  • MDEA: The typical acid gas loading is 0.4 mole acid gas/mole MDEA.

It should be noted that the above typical loading numbers consider typical assumptions/conditions like inlet sour gas H2S content around 1%-4% etc. However, it is not uncommon to operate an amine plant with significantly lower loadings (for example if the inlet H2S is 1000 ppmv, or 0.1%).

Key Parameters That Influence Amine Loading

The maximum attainable pure component loading is limited by the equilibrium solubility of H2S and CO2 at the absorber bottoms conditions [1]. Figure 1 taken from the GPSA Engineering Data Book [1] (summarized from a GPA Research Report) shows the maximum attainable loading of various amines. As can be seen from the figure, one of the major factors affecting the amine loading is the partial pressure of the acid gas component. From an operational point of view, there is no limit on high contactor pressure as far as the process is concerned. For the same inlet acid gas mole fraction, the higher the contactor pressure, the higher the acid gas partial pressure, hence better acid gas loading in amine solution.

Maximum Attainable Loading of H2S and CO2 in Various Amines

Figure 1: Maximum Attainable Loading of H2S and CO2 in Various Amines [1]

Another major factor affecting the amine loading is the contactor temperature. Figure 2 taken from Gas Purification [4] shows the effect of temperature on the solubility of H2S in MDEA. As can be observed from Figure 2, for the same H2S partial pressure, the equilibrium H2S solubility is 0.3 mole H2S / mole MDEA at 25 C, and 0.2 mole H2S / mole MDEA at 40 C.  A low operating temperature is preferable for acid gas absorption in the contactor column. Should the feed gas be at high temperature, an inlet cooler (using air or water) would be required.

Effect of temperature on the solubility of H2S in 4.28 kmol/m3 MDEA solution (about 50 wt% MDEA solution)

Figure 2: Effect of temperature on the solubility of H2S in 4.28 kmol/m3 MDEA solution (about 50 wt% MDEA solution) [4]


Acid gas loading in amine solutions is an important factor in operating a gas sweetening unit. There are many references outlining typical amine loading values for various amines. However, it should be noted that it is common that many sweetening unit are operating below the typical loading numbers. Two major factors affecting the amine loading are: 1) acid gas component partial pressure, and 2) contactor temperature. In actual operations, each of the amine units should be assessed individually to determine the proper acid gas loading for efficient operations.


[1] Gas Processors Suppliers Association (GPSA) Engineering Data Book, 2012 SI unit,13th Edition

[2] Addington, Luke, and Chris Ness. "An evaluation of general “Rules of Thumb” in amine sweetening unit design and operation." Bryan Research and Engineering (2009).

[3] Manning, F. & Thompson, R. (1991). Oilfield Processing of Petroleum Natural Gas Volume One.

[4] Kohl, Arthur L., and Richard Nielsen. Gas purification. Gulf Professional Publishing, 1997.

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By Ted Yang, M.Sc., P.Eng.

Ted joined Process Ecology in 2014 as a Process Engineer. He provides process engineering services on various oil & gas projects, as well as research and development support on emissions management software. He also has extensive experience in the area of process statistical analysis and modelling. His key strengths are in the field of process modelling, natural gas processing and flare network modelling. Prior to joining Process Ecology, he worked with KBR on several major projects including the Syncrude Tailings Project and the Shell Carbon Capture and Storage Project. Ted holds a M.Sc. in Chemical Engineering from the University of Alberta and a B.Sc. in Chemical Engineering from Dalian University of Technology. In his spare time, he enjoys hiking in the Rockies during summer and skiing during winter.



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