Grimbeek Successful Polymer Pilot Extends to 80 Injectors in Factory-Mode Development at CGSJ Basin

Juri, J. E.; Ruiz, A.; Schein, F.; Serrano, V.; Thill, Mercedes; Guillen, P.; Tosi, A.; Pacchy, M.; Soto, Luis H.; Therisod, A.; Paura, M.; Lauro, P.; Alonso, Pablo Olasolo

doi:10.3997/2214-4609.201900061

Cited by 5 publications

(2 citation statements)

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“…Месторождение Grimbeek. Следующим рассматриваемым объектом является месторождение Grimbeek, расположенное в Аргентине [38]. Особенностями месторождения является то, что месторождение состоит из 3 залежей, имеющих плотную гидродинамическую связь.…”

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The current level and prospects for the development of large-volume injection technologies using polymers to increase oil recovery

Podoprigora

Byazrov

Khristich

2022

The Eurasian Scientific Journal

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Currently, there is a worldwide decline in the level of production while maintaining the level of consumption. At the same time, the newly discovered fields are not able to compensate for the volumes of extracted oil, since the volumes of reserves are mainly small or medium. In this regard, it is relevant to introduce technologies to increase oil recovery at already drilled and developed fields. A promising method of increasing oil recovery is polymer flooding, which has many years of successful experience in both Russia and abroad. Polymer flooding technology consists in adding dry polymer to the injected water in concentrations from 0.05 to 0.25 % in order to increase its viscosity, which in turn contributes to improving the flooding process. The polymer rim equalizes the ratio of mobility in the reservoir and allows oil to be uniformly displaced from reservoirs in which there is a heterogeneity in permeability. The key result in the implementation of the technology is an increase in the oil recovery coefficient by improving the coverage of the reservoir by the flooding process, as well as a gradual increase in water availability, without early water breakthroughs from injection to production wells. This technology has wide limits of applicability and has already proven its effectiveness in various geological and physical conditions. This article will consider the physical basis of exposure, the principle of action, the criteria of applicability, the main groups of chemical reagents, and the accumulated domestic and international experience in the design and implementation of polymer flooding technology, development trends and the main difficulties associated with the introduction of this technology.

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“…Рисунок 14. Участок ОПР для проведения пилотных работ по полимерному заводнению [38] На рисунке 15 приводится динамика изменения добычи нефти после внедрения технологии полимерного заводнения.…”

Section: Nzvn222unclassified

The current level and prospects for the development of large-volume injection technologies using polymers to increase oil recovery

Podoprigora

Byazrov

Khristich

2022

The Eurasian Scientific Journal

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EOR simulation of polymer flooding

Cueille

2024

Aust. Energ. Prod. J.

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Enhanced oil recovery (EOR) techniques, such as polymer flooding, have gained significant attention as a means to maximise hydrocarbon extraction from reservoirs. The success of polymer flooding is intricately tied to the complex interplay between fluid properties, reservoir heterogeneity, and injection strategies. It is admitted in classical modelling methodologies, to account for the mobility ratio in polymer flooding by scaling it with the help of the shear rate in situ. The accuracy of shear assessment therefore rules the mobility of oil and the global process efficiency. It is assumed to depend not solely on pore radius, rate, and porosity, but also on a dimensional parameter known as the shape factor, which varies according to the specifications of several authors. When lab measurement is available, it is possible to adjust this value to match the shear rate recorded from a rheometer at feeding stage, ahead of the core. In the present paper the consequence of not performing this stage in the case of a core flood, then in the simulation of a polymer flood pilot is investigated. An alteration of the recovery factor is then expected. The amplitude shall result from the coupling between pore-scale effects and reservoir-scale response, induced by geological constraints such as reservoir layers productivity, aquifer response, and multiphase dynamics. Relative effect and influence on reservoir parameters will be quantified, commented, and discussed.

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The Impact of EOR Polymers on Scale Inhibitor Adsorption

Beteta¹,

McIver²,

Vazquez³

et al. 2020

Day 2 Thu, June 25, 2020

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With the current trend for application of Enhanced Oil Recovery (EOR) technologies, there has been much research into the possible upsets to production, from the nature of the produced fluids to changes in the scaling regime. One key question that is yet to be addressed is the influence of EOR chemicals, such as hydrolysed polyacrylamide (HPAM), on scale inhibitor (SI) squeeze lifetime. Squeeze lifetime is defined by the adsorption of the inhibitor onto the reservoir rock, hence any chemical that interacts with the adsorption process will have an impact on the squeeze lifetime. This paper experimentally demonstrates potential changes to inhibitor adsorption from a polymer EOR project by demonstrating the complex interactions between HPAM and phosphonate scale inhibitors with respect to adsorption. This work presents a detailed coreflooding programme, supplemented with bottle tests, to identify the impact of HPAM on a diethylenetriamine penta(methylene phosphonic acid) (DETPMP) squeeze lifetime. A range of pH values, representing the expected inhibitor injection pH, have been studied on consolidated and crushed Bentheimer sandstone. A temperature of 70°C is used throughout as it represents the likely maximum temperature at which HPAM would be applied and the typical temperature at which DETPMP would be used in squeeze applications. The results presented show that scale inhibitor application pH is key in defining the impact of HPAM on DETPMP adsorption. Neutral pH displays a reduced squeeze lifetime, believed to be due to reduction of adsorption sites by HPAM. However, this impact could be countered by injecting this type of scale inhibitor at a low pH (e.g. pH 2). Static tests performed alongside the corefloods show that even low inhibitor concentrations (as found in SI pre-flushes) are sufficiently acidic to fully precipitate the HPAM from solution, but did not impact the adsorption. This study suggests, contrary to the commonly held view in the industry that EOR polymers may negatively impact squeeze lifetime, that with the correct selection of inhibitor type and their application pH it is possible to achieve the same results as in a conventional reservoir.

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Grimbeek Successful Polymer Pilot Extends to 80 Injectors in Factory-Mode Development at CGSJ Basin

Cited by 5 publications

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The current level and prospects for the development of large-volume injection technologies using polymers to increase oil recovery

The current level and prospects for the development of large-volume injection technologies using polymers to increase oil recovery

EOR simulation of polymer flooding

The Impact of EOR Polymers on Scale Inhibitor Adsorption

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