Numerical Simulation of Catalytic In Situ Oil Upgrading Process

Rojas, Allan; Shevchenko, Denis; Sudakov, Vladislav; Usmanov, Sergey; Kwofie, Michael

doi:10.1002/9781119871507.ch10

Cited by 1 publication

(2 citation statements)

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“…The EoS parameters for the LO were taken from the literature 39 (Table 3). For the HO, the EoS parameters were matched to experimental data implementing the methodology presented in 40 (Table 4). The main PVT properties of the reservoirs under study are summarized in Table 5.…”

Section: Oil and Binarymentioning

confidence: 99%

“…In the aquathermolysis Energy & Fuels reactions mainly heavy fractions of oil are reduced and lighter fractions of oil increased, along with some gas evolution (low carbon number hydrocarbons, H 2 S, CO x , and H 2 ). 40,51 Additionally, such reactions in catalysis have shown rehabilitation of oil recovery rates in field applications using steam injection methods. 52 In the range 300−350 °C aquathermolysis reaction decreases and thermal cracking reactions become more dominant.…”

Section: Numerical Validation Of the Kineticmentioning

confidence: 99%

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Catalytic Activation of Ammonium Nitrate and Sodium Nitrite: Experimental, Modeling and Prediction of the Fracking Envelope in Low-Permeability Reservoirs with Light and Heavy Oils

Rojas,

Rezaei Koochi,

Varfolomeev

et al. 2023

Energy Fuels

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The catalytic activation of thermochemical fluids or binary mixtures (BMs) based on ammonium nitrate and sodium nitrite was experimentally and numerically investigated as well as kinetically modeled. Experimental evidence in an autoclave reactor indicated an increase of temperature up to 242.5 °C and pressure up to 47.7 bar after the catalytic activation under standard conditions is accomplished. By means of the T and P growth and the observed reaction products (N2, NO2, and H2O), the reaction kinetic constants along with its stoichiometry were established and later on validated with a numerical reactor model. Subsequently, field-scale numerical models evaluated the activation of the BM within different reservoir rock quality (porosity: 3–15% and permeability: 4.4–111 mD), fluid type (light and heavy oils), injection rate (1–3 m3), and initial reservoir pressure (85 and 150 bar). Poor reservoir quality and injection rate were observed as the dominant requirements to ensure a more aggressive reservoir fracking. They illustrated an exponential response on the peak pressure, particularly at porosity and permeability values <5% and <17 mD, respectively. The exhibited peak pressures in our models range from 108–389 to 144–392 bar, for the light and heavy oils, respectively. We found that these in situ pressures are substantially in excess in reference to the predicted fracking pressure of the studied reservoirs. This implies that the activation of the BM within the porous media is a promising reservoir fracking method. Moreover, its robust exothermicity surpasses the reported glass transition and melting temperature of certain asphaltenes. Our findings can provide meaningful understanding about the geologyinjection requirements that can lead to fracking a given reservoir as well as its thermal development potential for well cleaning purposes when implementing BM for IOR applications.

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Section: Oil and Binarymentioning

confidence: 99%