Enhanced oil recovery

Fink, Johannes Karl

doi:10.1016/b978-0-323-85438-2.00016-5

Cited by 11 publications

(7 citation statements)

References 102 publications

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“…There have been very few trials considering anionic surfactants because of their low efficiency in emulsifying acids, as sulfates and phosphates tend to have a weak interaction with acidic solutions due to the lack of lone electrons contrary to amines; the other reason is that anionic surfactants possess a low dielectric constant in comparison to the cationic surfactants, which solubilize the ions more effectively. Zwitterionic surfactants are rarely used this might be because of their tendency to destabilize at high temperatures above 80 and 100 °C as seen in other oil and gas production operations . However, as mentioned previously in the type of emulsifiers section, there are certain concerns related to the use of surfactants as emulsifiers, especially ionic surfactants, which precipitate under the presence of multivalent ions (Ca 2+ and Mg 2+ ) that are the reactant products.…”

Section: Summary and Limitationsmentioning

confidence: 99%

A Review on Use of Emulsified Acids for Matrix Acidizing in Carbonate Reservoirs

Yousufi,

Mohyaldinn Elhaj,

Dzulkarnain

2024

ACS Omega

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Almost 60% of oil and 40% of gas reserves worldwide are contained in carbonate reservoirs where acidizing stimulation is more challenging compared to sandstone reservoirs. Utilization of emulsified acids in matrix acidizing operations has been the most effective technique for more than half a century. This is due to the colloidal system's ability to generate deep, narrow conduits toward production zones under controlled retarded reactivity with the rock surface, along with the excellent sweep efficiency and corrosion inhibition of the well equipment. This Review attempts to review the various kinds of emulsified acids that are used for matrix acidizing of carbonate formations. The Review is trying to trace the innovations that have, gradually, been applied for enhancing the performance of emulsified acids for a variety of conditions, their limitations, and the developmental solutions such hybrid emulsifiers and pickering emulsions. In addition, the Review also discusses the parameters, characteristics, and measuring techniques required for the successful synthesis of a stable and quality emulsion while considering the environmental concerns raised toward the application of an emulsified acid system. From the reviewed publications, it can be summarized that macroemulsions are best suited for matrix acidizing applications over microemulsions due to low emulsifier concentrations and high acid volume retention; similarly, water in oil emulsions provide better retardation in a comparison to oil in water emulsions. The small droplet size of the emulsion yields high viscosity and stability. The compositional balance between each component present in the acidizing system is a crucial factor for optimum performance. Moreover, for future practice, much focus is required to design emulsified acids as ecofriendly systems that can leave the least amount of toxicity during and after implementation.

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Section: Summary and Limitationsmentioning

confidence: 99%

A Review on Use of Emulsified Acids for Matrix Acidizing in Carbonate Reservoirs

Yousufi,

Mohyaldinn Elhaj,

Dzulkarnain

2024

ACS Omega

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“…S gi 1 + C S gi (1) where C is an empirical constant termed Land's coefficient and is used to quantify the trapping strength of a rock-fluid system. In other words, a higher C coefficient indicates less trapping efficiency and vice versa.…”

Section: S Gr =mentioning

confidence: 99%

“…Since the core samples we used in this study are consolidated rock samples and the rock wettability was found to be towards water-wet for the used gas-liquid-rock system, Land's trapping relationship was proposed to fit the measured initial-residual saturation curves. Land's trapping model was previously shown in Equation (1). Figure 3 show an illustration of the various factors controlling the initial-residual (IR) non-wetting (gas) saturation relationship.…”

Section: Trapping Modelmentioning

confidence: 99%

“…Gas injection in underground formations has several potential applications that have proven successful over the decades. The injection of gases such as carbon dioxide, nitrogen, and methane, in oil reservoirs as a gas-enhanced oil recovery (gas EOR) method has shown significant improvements in oil recovery when compared to primary and secondary recovery methods [1]. Among the gas EOR methods, CO 2 -EOR provides an additional advantage as CO 2 is stored in subsurface geological units during the oil recovery process [2,3].…”

Section: Introductionmentioning

confidence: 99%

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Foam-Assisted Capillary Trapping in Saline Aquifers—An Initial–Residual Saturation Analysis

et al. 2022

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Capillary trapping of gas in porous media is important for many processes such as oil recovery and gas geo-sequestration. Foam can mitigate gravity override and viscous fingering of gas by reducing its relative permeability through gas trapping. However, there are limited studies dedicated to understanding how foam assists in gas trapping, the best mode of foam injection for trapping, and its application in geo-sequestration. This paper uses an initial–residual saturation analysis to investigate foam-assisted capillary trapping during the surfactant alternating gas (SAG) injection process in saline aquifers. More specifically, we studied the effects of pore geometric properties, in situ generated foam, and surfactant concentration on gas trapping efficiency and final residual gas saturation, Sgr. First, NMR surface relaxometry measurements were carried out on the rock samples to indicate the mean pore sizes of the rocks. A series of core flooding tests, equipped with resistivity measurements, were then conducted using single-cycle gas injection followed by water injection, water alternating gas (WAG), and SAG injection methods to identify which mode of injection results in the most trapped gas. The results showed that the SAG method had a better sweep efficiency and trapped more gas than other methods. The initial–residual (IR) gas saturation relationships from SAG data measured from several rock samples were then analyzed using Land’s trapping model. Gas trapping efficiency (indicated by Land’s coefficient, C) and residual gas were also found to increase in rocks with large average pore sizes and with increasing surfactant concentration. However, increasing the surfactant concentration above a certain limit did not cause further improvement in the trapping coefficient but only increased the Sgr. The results also showed that high values of surfactant concentrations might cause a slight reduction in the foam’s apparent viscosity, which then reduces the initial gas saturation, and consequently, Sgr. Finally, a linear relationship between the Sgr and the measured log mean of surface relaxation times (T2LM) was obtained, and two correlations were proposed. Therefore, the NMR measurements can be considered a reliable prediction method for Sgr in porous media.

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“…So, different advanced recovery methods must be applied to boost the production of crude oil. There are three main stages of oil recovery methods: primary, secondary, and tertiary recovery. − Alagorni et al stated that primary oil recovery generally gives less than 30% original-oil-in-place (OOIP) and secondary oil recovery generally gives 10–20% extra OOIP while tertiary oil recovery gives 20–30% extra OOIP. So, primary recovery cannot produce more than one-third of the OOIP.…”

Section: Introductionmentioning

confidence: 99%

A Perspective Review on the Current Status and Development of Polymer Flooding in Enhanced Oil Recovery Using Polymeric Nanofluids

Ambaliya

Bera

2023

Ind. Eng. Chem. Res.

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The globally increasing demand for crude oil has prompted the oil industry to enhance oil production from primary, secondary, and tertiary recovery methods to fulfill the global requirement. Therefore, enhanced oil recovery (EOR) is expected to increase its importance in the coming years. Because of limited efficiency, applicability, and higher gas and thermal injection costs, chemical EOR processes have been considered as an alternative in some special cases. Chemical EOR processes are accepted widely because of their higher efficiency, economic and technical feasibility, and optimum capital cost. Therefore, research of novel chemical compounds is immense in the oil industry. Research of nanotechnology in the petroleum industry has attracted attention among all novel chemical compounds in the past few years. This work focuses on the review of previous research regarding the current scenario of polymer flooding, challenges of polymer flooding, polymeric nanofluid in EOR, recent developments in polymer flooding, characteristics of polymeric nanofluids, prospects, and economic feasibility for polymeric nanofluids’ applications in EOR. This paper also reviews the characterization of polymeric nanofluids such as rheology, stability, wettability alteration, interfacial tension reduction, and absorption control. It has been found from a literature review that polymeric nanofluids are more effective in oil recovery considering viscosity modification, stability enhancement, and chemical adsorption control. Oil recovery can be additionally increased by up to 10–15% original-oil-in-place applying polymeric nanofluids.

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Enhanced oil recovery

Cited by 11 publications

References 102 publications

A Review on Use of Emulsified Acids for Matrix Acidizing in Carbonate Reservoirs

A Review on Use of Emulsified Acids for Matrix Acidizing in Carbonate Reservoirs

Foam-Assisted Capillary Trapping in Saline Aquifers—An Initial–Residual Saturation Analysis

A Perspective Review on the Current Status and Development of Polymer Flooding in Enhanced Oil Recovery Using Polymeric Nanofluids

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