New Surfactant for Chemical Flood in High-Salinity Reservoir

Abstract

TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractEvaluation of the chemical flood potential in the Chihuido de la Sierra Negra field, Argentina, has been carried out using several different recovery scenarios. This field has been submitted to extensive waterflooding for several years, and surface facilities have been designed to recycle produced brine as injection brine. The use of produced brine, as chemical solution make-up water is therefore very advantageous from both an operational and economical point of view. However, the formation brine contains around 110,000 PPM Total Dissolved Solids with around 2,800 PPM divalent cations. This makes the selection of the proper surfactant extremely difficult. Processes such as Alkali Surfactant Polymer Flooding have been considered, however, the requirement of large amounts of fresh water as well as softening units in the field adversely affects the economics of this process. This paper will discuss the development of a new anionic surfactant that provides solubility in high salinities and low interfacial tension at low concentration. The Chihuido de la Sierra Negra field history will be briefly described, and the laboratory screening and evaluation of the surfactants, including the interfacial tension properties, the adsorption, the core evaluation, and the performance of the flood will also be discussed.The significance of this development is that it could lend feasibility to EOR projects that would be deemed uneconomical because of water treatment and handling costs.

Development of mature oil fields — A review

“…Another surfactant injection into light oil (33-35°API) sandstone reservoir was reported by Zaitoun et al (2003). Low concentration anionic surfactant solutions were injected into high salinity core samples to formulate the field injection plan.…”

Design of an optimal middle phase microemulsion for ultra high saline brine using hydrophilic lipophilic deviation (HLD) method

“…This increases the overall project cost making cEOR projects less attractive, especially for small producers. Additionally, polymers that are normally used as mobility control agents in cEOR also become ineffective in high TDS brine [10][11][12]. There is, therefore, a need for an innovation of surfactant formulation for high TDS brine conditions for cEOR processes that do not require mobility control.…”

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“…Another surfactant injection into light oil (33-35 o API) sandstone reservoir was reported by Zaitoun et al 45 . Low concentration anionic surfactant solutions were injected into high salinity core samples to formulate the field injection plan.…”