Inhibitors of organic components

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Inhibitors of organic components

Inhibitors and Antifoams: Organic material Inhibition products (Asphaltenes – Paraffins – Resins).

Asphaltene Inhibitors

Asphaltenes are unsaturated, heterocyclic macromolecules composed primarily of carbon, hydrogen, and, to a lesser extent, hetero elements such as oxygen, sulfides, and nitrogen.

Asphaltenes are typically defined by their solubility in benzene and their insolubility in pentane or heptane.

Asphaltenes are believed to exist in crude oil as suspension colloids and are stabilized by the resins adsorbed on their surface. These components are normally found in equilibrium at reservoir conditions.

As crude oil is produced, this equilibrium can be disturbed by several factors including:

  • Pressure reductions
  • Compositional changes in crude oil chemistry
  • Introduction of miscible gases and liquids
  • Mixing with diluents and other crude oils during acidic stimulations
  • Hot oil injection and other field operations

Decomposition of the colloidal system may result in irreversible flocculation of asphaltenes. The deposition and precipitation of the flocculated asphaltenes can severely reduce the permeability of the reservoir causing damage to the formation and can also clog the face of the formation, production pipes and collection lines.

Thus, conventional asphaltene inhibition treatment is accomplished by dosing the inhibiting chemical through capillaries in the production pipeline or through squeeze treatments in the reservoir to remediate or prevent formation damage from asphaltene precipitation.

To determine the presence of asphaltenes, the analysis of three laboratory tests is recommended to know the stability of the crude oil.

These tests include:

  • SARA Analysis
  • Oliensis Test
  • Asphaltene precipitation detection test. 

Asphaltene inhibiting chemicals prevent the deposition of asphaltenes through interaction with asphaltene particles by slowing down their flocculation through a slow process and potentially preventing precipitation and deposition as well.

It has been observed that the "acid-base" interactions tend to increase the inhibition of asphaltenes for ionic inhibitors, and steric effects, related to the size of the inhibitor, important increases for the effectiveness of this one. The inhibition capacity increases with increasing inhibitor size.


  • Smith, D. F., Klein, G. C., Yen, A. T., Squicciarini, M. P., Rodgers, R. P., & Marshall, A. G. (2008). Crude Oil Polar Chemical Composition Derived from FT−ICR Mass Spectrometry Accounts for Asphaltene Inhibitor Specificity. Energy & Fuels, 22(5), 3112–3117. doi:10.1021/ef800036a 
  • Faust, M., & Weathers, T. (2011, January 1). Biphasic Viscosity Reducers as Production Aids for Viscous Oil. Society of Petroleum Engineers. doi:10.2118/141037-MS
  • Aguiar, J. I. S., Punase, A., & Mazzeo, C. (2019, October 28). Influence of Asphaltene Inhibitors on Wax and Asphaltene Deposition - Are Problems Associated? Offshore Technology Conference. doi:10.4043/29817-MS
  • Yin, Y. R., Yen, A. T., & Asomaning, S. (2000, January 1). Asphaltene Inhibitor Evaluation in CO2 Floods: Laboratory Study and Field Testing. Society of Petroleum Engineers. doi:10.2118/59706-MS
  • Leonard, G. C., Ponnapati, R., Rivers, G., & Wiggett, A. (2013, October 8). Novel Asphaltene Inhibitor for Direct Application to Reservoir. Society of Petroleum Engineers. doi:10.2118/167294-MS


Paraffins inhibitors


The waxes or paraffins in the crude oil are a mixture of n-paraffins, iso-paraffins, and cyclo-paraffins with variations in the number of carbons, with ranges from 18 to 65. These can be classified as macro crystalline waxes (paraffinic waxes) composed of paraffinic hydrocarbons with carbon numbers between 18 - 36, and microcrystalline waxes comprised of naphthenic hydrocarbons with carbon numbers between 30 - 60.

Paraffins tend to be deposited when the temperature of the crude oil falls below the cloud point or the wax appearance temperature (WAT). As the oil flows from the formation face, its pressure drops causing the release of the gas in solution and causing changes in the composition of the oil.

Precipitation of the paraffins causes an increase in the viscosity of the fluid and consequently problems with clogging of the formation face, production pipelines, distribution lines, and sludge tanks at the bottom of the tanks. These blockages reduce production and can cause mechanical problems.

Different techniques have been employed by the hydrocarbon industry to combat paraffins deposition problems. In general, these methods can be classified into five categories: mechanical, thermal, bacterial, electromagnetic, and chemical, the latter being one of the most used in the industry.

A combination of these techniques is usually applied for paraffins control. In the last decades, considerable efforts have been made to develop chemical methods for the inhibition of paraffins deposition.

Inhibition chemicals can be broadly classified into three categories:

  • Solvents, which are aromatic compounds used to dissolve paraffins.
  • Paraffins crystal modifiers, which are polymers that inhibit or alter the growth of kerosene crystals
  • Paraffin dispersants, which inhibit particles from binding and deposition.

The use of inhibiting chemicals to reduce paraffins problems has become a widely applied option within the industry.

Several chemicals possess paraffins inhibition properties and it has been observed that a single chemical is not equally effective in all cases, so it is required, individually for each case, to find the best inhibitor.

There are different methods and experimental protocols for the selection of the best paraffins inhibitor according to its point of application. In addition, there is no standard for protocols to evaluate the performance of paraffins inhibitors, and even inconsistencies in results between laboratories when they are evaluating the performance of paraffins inhibitors. However, Cold Finger (CF) testing is a commonly used method for paraffins inhibitor screening.


  • Towler, B. F., & Rebbapragada, S. (2004). Mitigation of paraffin wax deposition in cretaceous crude oils of Wyoming. Journal of Petroleum Science and Engineering, 45(1-2), 11–19. doi:10.1016/j.petrol.2004.05.006 
  • Golchha, A., & Stead, P. (2015, May 12). Study and Analysis of Cold Finger Tests for Effective Selection of Paraffin Inhibitors. NACE International.
  • Peng, Y., Golchha, A., & Broze, G. (2018, April 30). Cold Finger Benchmarking Study for Paraffin Inhibitor Selection. Offshore Technology Conference. doi:10.4043/28714-MS
  • Al-Yaari, M. (2011, January 1). Paraffin Wax Deposition: Mitigation and Removal Techniques. Society of Petroleum Engineers. doi:10.2118/155412-MS
  • Kar, T., & Firoozabadi, A. (2019, September 23). Mitigation of Paraffinic Wax Deposition and the Effect of Brine. Society of Petroleum Engineers. doi:10.2118/196032-MS