Analysis and selection of CO₂ sources for CCS-EOR projects in oil fields clusters in Poland

Mikołajczak, Edyta; Kosowski, Piotr; Stopa, Jerzy; Wartak, Joanna

doi:10.7494/drill.2018.35.1.295

Cited by 1 publication

(2 citation statements)

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“…Mikołajczak et al [28] identified only 4 possible clusters of reservoirs (a set of at least 2 reservoirs is considered as a cluster) suitable for CCS-EOR in Poland. Such clusters have higher CO 2 storage capacities than individual formations.…”

Section: Reservoir Fluidsmentioning

confidence: 99%

“…Thus, the aim of this work was to predict CO 2 behavior in the presence of reservoir fluids from five selected formations identified by Mikołajczak et al [28] as suitable for CO 2 storage. During the selection of these reservoirs, only geological aspects were considered (reservoir depth, porosity, oil recovery) to ensure the high storage safety and capacity.…”

Section: Introductionmentioning

confidence: 99%

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Chemistry of Reservoir Fluids in the Aspect of CO2 Injection for Selected Oil Reservoirs in Poland

Knapik

Chruszcz‐Lipska

2020

Energies

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Worldwide experiences related to geological CO2 storage show that the process of the injection of carbon dioxide into depleted oil reservoirs (CCS-EOR, Carbon Capture and Storage—Enhanced Oil Recovery) is highly profitable. The injection of CO2 will allow an increasing recovery factor (thus increasing CCS process profitability) and revitalize mature reservoirs, which may lead to oil spills due to pressure buildups. In Poland, such a solution has not yet been implemented in the industry. This work provides additional data for analysis of the possibility of the CCS-EOR method’s implementation for three potential clusters of Polish oil reservoirs located at a short distance one from another. The aim of the work was to examine the properties of reservoir fluids for these selected oil reservoirs in order to assure a better understanding of the physicochemical phenomena that accompany the gas injection process. The chemical composition of oils was determined by gas chromatography. All tested oils represent a medium black oil type with the density ranging from 795 to 843 g/L and the viscosity at 313 K, varying from 1.95 to 5.04 mm/s. The content of heavier components C25+ is up to 17 wt. %. CO2–oil MMP (Minimum Miscibility Pressure) was calculated in a CHEMCAD simulator using the Soave–Redlich–Kwong equation of state (SRK EoS). The oil composition was defined as a mixture of n-alkanes. Relatively low MMP values (ca. 8.3 MPa for all tested oils at 313 K) indicate a high potential of the EOR method, and make this geological CO2 storage form more attractive to the industry. For reservoir brines, the content of the main ions was experimentally measured and CO2 solubility under reservoir conditions was calculated. The reservoir brines showed a significant variation in properties with total dissolved solids contents varying from 17.5 to 378 g/L. CO2 solubility in brines depends on reservoir conditions and brine chemistry. The highest calculated CO2 solubility is 1.79 mol/kg, which suggest possible CO2 storage in aquifers.

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Section: Reservoir Fluidsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%