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• W2022841354 abstract "Abstract Water injection is one of the main oil recovery techniques, which usually associated with problematic and challenging formation damage concerns including mineral scale deposition, organic scale, clay swelling, particle invasion, fine migration and microbial damage. These concerns usually significantly affect the performance of water injection scenarios by reduction of production rate and therefore ultimate recovery. In this work, mineral scale deposition phenomenon due to sea water injection and its influence on productivity loss and the reservoir performance of an Iranian offshore carbonate oil reservoir have been investigated. This filed has been producing by water injection since 1985. During these years the field has facing several formation damages mechanisms especially mineral scale deposition. For this purpose, a simulation study using solid deposition module of Eclipse 100 (v. 2006) has been conducted to simulate various phenomena occurring in the reservoir due to water injection, which undermines the oil production rate. As input of the simulation, the actual amount and concentrations of scale formed due to mixing of various portions of formation and injected sea waters and the productivity index reduction due to injection of different water mixtures are needed. These data must be experimentally measured in an actual bulk and core media for the studied reservoir. Comprehensive laboratory studies have been, therefore, conducted to obtain the simulation required information. These data have been incorporated into the simulation model to evaluate the scale deposition effects. The simulator enables to model the mixing zone, mineral scales precipitation, reservoir performance and productivity index reduction due to sea water injection process. The results show that the production loss due to scale deposition can be predicted/ simulated reliably by using the applied methodology and appropriate required experimental works. Introduction Water injection is a common IOR method, usually applied in offshore oil fields for the purpose of pressure maintenance and enhanced oil recovery. During secondary and tertiary recovery by this method, reductions of permeability have been observed in many reservoirs. Several reasons are recognized as possibly contributing to this problem such as mineral scale deposition, solid invasion, clay swelling and rock-fluid incompatibility. Mineral scale deposition is the main factor discussed in this paper. Mineral scaling is the deposition process of scales from aqueous solutions of minerals (i.e., brines) when they become supersaturated due to the alteration of the state of their thermodynamic and chemical equilibrium. Supersaturation can be generated in an aqueous phase by changing the temperature and pressure or by mixing two incompatible aqueous solutions. Mineral scaling can occur in tubing and near wellbore region of both production and injection wells.1 The significant components of most oil field scale deposits are Calcium Carbonate (CaCO3), Calcium Sulphate (CaSO4), Barium Sulphate (BaSO4) and Strontium Sulphate (SrSO4). Oil field deposits are usually a mixture of one or more of the inorganic compounds plus corrosion products, Congealed oil, Paraffin, Silica and other impurities. Table 1 demonstrates the most common oil field scales with their primary variables.1, 2, 3 Calcium Carbonate scale generally causes sharp reductions in pressure such as that exist between the formation and the wellbore and across any constriction in the producing system, e.g. chocks and safety valves. The reduction in pressure liberates CO2 in gas phase leaving the solution more concentrated in Calcium Carbonate. The various form of Calcium Sulphate i.e. gypsum, anhydrate and hemihydrate can be formed due to increase in temperature. 2" @default.
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• W2022841354 date "2009-05-27" @default.
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• W2022841354 title "Evaluation of Reservoir Performance under Water Injection Considering the Effect of Inorganic Scale Deposition in an Iranian Carbonate Oil Reservoir" @default.
• W2022841354 doi "https://doi.org/10.2118/121221-ms" @default.
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