Analysis of subterranean Pre-salt carbonate reservoir by X-ray computed microtomography

Teles, A.P.; Machado, Aryane Flauzino; Pepin, A.; Bize-Forest, Nadege; Lopes, Ricardo Tadeu; Lima, I.

doi:10.1016/j.petrol.2016.03.008

Cited by 12 publications

(3 citation statements)

References 22 publications

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“…Carbonate rocks contain approximately 50% of the world's hydrocarbon reserves (Teles et al 2016). Because of their wide distribution and importance, carbonate rocks are now increasingly being studied at a range of scales and from various perspectives, especially since the discovery of Brazilian Pre-salt reservoirs in the Santos Basin, an Eastern Brazilian Continental Margin basin.…”

Section: Introductionmentioning

confidence: 99%

Petrophysical Correlations for the Permeability of Coquinas (Carbonate Rocks)

et al. 2020

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The pore structure of many carbonate formations is known to be very complex and heterogeneous. Heterogeneity is manifested by the presence of different types, sizes, and shapes of pores resulting from sedimentation and diagenetic actions. These complexities greatly increase uncertainties in estimated rock hydraulic properties in that different permeability values may occur for samples having similar porosities. In order to understand the effects of pore structure and heterogeneity, petrophysical analyses were performed on coquina samples from the Morro do Chaves Formation (Barremian, Sergipe-Alagoas Basin), which is an analogue of Brazilian Pre-salt oil reservoirs of Itapema Formation in the Santos Basin. Routine core analyses, and NMR and MICP measurements were carried out to obtain pore body and pore throat distributions. Obtained T2 relaxation times were converted to pore size radii by matching the NMR and MICP curves. Pore-scale imaging and pore network modelling were performed using microCT scans and the PoreFlow software, respectively. Calculated permeabilities using PoreFlow showed excellent agreement with the routine laboratory measurements. Samples having pore bodies with a higher coordination number showed much larger permeabilities at similar porosities. This study includes a statistical analysis of various features that caused the observed differences in permeability of the coquinas, including the role of connectivity of the entire porous system. Limitations and challenges of the various techniques, and the imaging and pore-scale flow simulations, are discussed.

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Section: Introductionmentioning

confidence: 99%

Petrophysical Correlations for the Permeability of Coquinas (Carbonate Rocks)

et al. 2020

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“…While there papers describing Pre-Salt rocks in the literature (Teles et al 2016), there is no detailed data describing their wettability and the effect of CO 2 on the rock-fluid interactions. A recent study (Ruidiaz, Winter, and Trevisan 2018) considered the wettability alteration of dolomite and limestone cores and its effects on oil recovery using de-waxed and de-asphaltened Pre-Salt crude and formation and injection brines (200,000 and 35,000 ppm salinities respectively) using the Amott-Harvey Index and spontaneous imbibition tests.…”

Section: Introductionmentioning

confidence: 99%

Experimental study of the effect of carbonated brine on wettability and oil displacement for EOR application in the Brazilian Pre-Salt reservoirs

Drexler

Silveira

Belli

et al. 2019

Energy Sources, Part A: Recovery, Utilization, and Environmenta

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Brazilian Pre-Salt carbonate reservoirs are natural candidates for Enhanced Oil Recovery combined with Carbon Capture and Storage due to their high CO 2 production. However, the effect of CO 2 on rock wettability still needs to be investigated to build representative reservoir models to predict the ultimate oil recovery. This work applied contact angle measurements to study the consequences of carbonated brine on the initial wettability. Moreover, coreflooding experiments were carried out to evaluate the incremental oil recovery obtained by carbonated brine injection. Finally, nonreactive tracer tests and micro computed tomography were used to observe the effects of mineral dissolution on the sweeping efficiency. Carbonated brine induced a decreased oil-wet behavior caused by rock dissolution and desorption of organic compounds resulting in a contact angle reduction of 55°for the Pre-Salt rock. This contributed to obtain a 27% increase in oil recovery. Moreover, tracer tests and micro computed tomography verified the formation of preferential flow paths by mineral dissolution. The increased oil production and decreased contact angle encourage further studies on the injection of carbonated brine for the Pre-Salt scenario.

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“…This unique environment represents a challenge in terms of wettability assessment and reservoir modeling. While there are descriptions of the Pre-Salt rocks in the literature (Pepin et al, 2014;Teles et al, 2016), there is no detailed data describing their wettability.…”

Section: Introductionmentioning

confidence: 99%

Investigation of the Key Parameters Affecting Wettability of a Brazilian Pre-Salt Crude Oil and Brine on Pure Minerals Through Statistical Analysis

Drexler

Souza

Correia

et al. 2019

BJPG

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Wettability is a fundamental property that defines the fluid's distribution in oil reservoirs. Assessing wettability is required to model flow in porous media. Nevertheless, it involves complex intermolecular and surface forces. Contact angle measurement is a quantitative method to determine wettability. However, rock samples must be prepared to assure results representative of reservoir conditions. This work applies statistical analysis to investigate the relevance of variables involved in sample preparation (aging time, solvent used to remove the excess oil from the surface) and mineral type on the wettability of oil and brine from a Pre-Salt field on pure minerals. Since there is limited experimental wettability data at Pre-Salt conditions, this work aims to assist filling this gap. The results showed aging time and mineral type as the most important parameters for analysis. Furthermore, authors found that greater aging time in oil and point of zero charge of the mineral lead to a more oil-wet behavior.

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Analysis of subterranean Pre-salt carbonate reservoir by X-ray computed microtomography

Cited by 12 publications

References 22 publications

Petrophysical Correlations for the Permeability of Coquinas (Carbonate Rocks)

Petrophysical Correlations for the Permeability of Coquinas (Carbonate Rocks)

Experimental study of the effect of carbonated brine on wettability and oil displacement for EOR application in the Brazilian Pre-Salt reservoirs

Investigation of the Key Parameters Affecting Wettability of a Brazilian Pre-Salt Crude Oil and Brine on Pure Minerals Through Statistical Analysis

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