Diagenesis and reservoir quality of Cambrian carbonates in the Tarim Basin, northwestern China

Li, Bin; Goldberg, Karin

doi:10.1016/j.jseaes.2021.104972

Cited by 7 publications

(5 citation statements)

References 53 publications

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“…Compared to horizontal flow, calcite precipitates more with vertical flow. Researches have also observed other secondary minerals such as dolomite, anhydrite, ankerite, siderite, and magnesite [9,16,31]. In addition, the zeta trends, electrostatic interactions, surface complexation, and adsorption processes under high salinity conditions in carbonate reservoirs can affect water-rock reactions as well [11,33,34].…”

Section: Introductionmentioning

confidence: 99%

“…In contrast, Berrezueta, et al (2017) [18] reported that the permeability in carbonates can be decreased by about 10% due to the mineral precipitation after the injection of CO 2 . It is proposed that the change of permeability in carbonates caused by the CO 2 injection can be related to the distribution of pores, the chemical characteristics of brine, the fluid flow rates, the injection period, and thermodynamic conditions [24,[27][28][29][30][31][32]. Crockford, et al (2011) [14] demonstrated that lower NaCl concentration in brine leads to higher reaction rates between CO 2 , brine, and the Keg River carbonates due to the lack of compositional inhibition.…”

Section: Introductionmentioning

confidence: 99%

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CO2-Water-Rock Interactions in Carbonate Formations at the Tazhong Uplift, Tarim Basin, China

Ahmat

Cheng

et al. 2022

Minerals

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The effects of CO2-water-rock interactions on the injectivity and safety of CO2 geological storage have drawn wide attention. The geochemical reaction mechanisms in carbonate formations after CO2 injection are still controversial. To better understand the transformation of injected CO2 in carbonates and the involved geochemical reactions, we first conducted autoclave experiments reproducing the in-situ conditions of the Lianglitage Formation, Yingshan Formation, and Qiulitage Formation at the Tazhong Uplift in the Tarim Basin. We then established a batch model using TOUGHREACT-ECO2H, validated with the experimental results, to simulate the long-term CO2-water-rock interactions. It was found that the initial mineral compositions and water chemistry have important effects on the CO2-water-rock interactions in carbonate formations. The experiment results show that the dissolution of calcite and dolomite dominates in the early reaction period. However, we still observed some secondary minerals, such as ankerite, montmorillonite, calcite, and dolomite. The CO2-water-rock reactions can be more dramatic when the contents of calcite and dolomite in carbonates are closer. Moreover, the long-term simulation results show that calcite, magnesite, and hematite are the main formed secondary minerals, whereas dolomite is the major dissolved mineral. This study is helpful for a better understanding of the CO2 mineral trapping mechanism in carbonate formations.

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Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

CO2-Water-Rock Interactions in Carbonate Formations at the Tazhong Uplift, Tarim Basin, China

Ahmat

Cheng

et al. 2022

Minerals

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“…The spatial distribution of these interrelated parameters is highly heterogeneous in carbonate reservoirs and must be studied in detail for integrated reservoir characterization (Abuamarah and Nabawy, 2021;Sajed et al, 2021;Fallah-Bagtash et al, 2022). Understanding the effect of diagenetic alterations on reservoir quality is highly important to hydrocarbon exploration and development (Lai et al, 2018;Wadood et al, 2021;Li and Goldberg, 2022). The reservoir quality may be heightened or deteriorated depending on the type of dominant diagenetic features, e.g., compaction, cementation, dissolution, dolomitization and fracturing (Assadi et al, 2018b;Sfidari et al, 2018;Sajed and Glover, 2020;Wadood et al, 2021).…”

Section: Introductionmentioning

confidence: 99%

Impacts of Depositional Facies and Diagenesis on Reservoir Quality: A Case Study from the Rudist‐bearing Sarvak Formation, Abadan Plain, SW Iran

Assadi

Honarmand²,

Moallemi

et al. 2023

Acta Geologica Sinica (Eng)

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An integrated geological‐petrophysical analysis of the rudist‐bearing sequence of the Cretaceous Sarvak Formation is given one giant oilfield, and provides an improved understanding of this main reservoir in the Abadan Plain, in the Zagros Basin, SW Iran. The main objective of this study is to evaluate reservoir potential of the Sarvak Formation, and then to utilize the calibrated well log signature to correlate reservoir potential in un‐cored wells. Eight main facies are recognized and categorized in five facies groups: lagoon, shoal, rudist‐biostrome, slope, and shallow open marine, deposited on a shelf carbonate platform. Given the distribution of diagenetic products and their effects on pore systems, three diagenetic facies namely, (DF‐1) low dissolution and cementation; (DF‐2); high dissolution; and (DF‐3) high cementation are differentiated. The initial sedimentary characteristics in combination with distribution of diagenetic products play an important role in reservoir quality heterogeneity. The effect of diagenetic processes related to disconformities mainly depends on the facies nature below these surfaces. Grain‐dominated facies of shoal and rudist debris, observed below the Cenomanian–Turonian disconformity, are mostly characterized by high dissolution and interconnected pore systems. Finally, depositional and diagenetic facies in the studied wells are correlated by petrophysical well log data, leading to distribution of the reservoir zones. Data obtained can be utilized for efficient reservoir characterization of the Sarvak Formation and its equivalent units in the Arabian Plate.

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Section: Introductionmentioning

confidence: 99%

“…In recent years, global oil and gas exploration has made great breakthroughs in deep carbonate formation indicating deep dolostone is rich in oil and gas resources (Howarth and Alves, 2016;Zhu et al, 2019;Li and Goldberg, 2022;Ma et al, 2022). The abundant oil and gas displays have been found in the Cambrian super-deep dolomite reservoirs in the Tarim Basin of China (Huang et al, 2014;Valenciaa et al, 2020;Li and Goldberg, 2022). The high-porosity reservoirs of the TS1 well have been found at the depth of 8,848 m, which confirmed the good exploration prospects for ultra-deep reservoirs (Xiong et al, 2015;Zhu et al, 2018;Cheng et al, 2019;Jiao, 2019).…”

Section: Introductionmentioning

confidence: 99%

Experimental analysis of dissolution reconstruction of deep dolomite reservoirs: A case study of the Cambrian dolomite reservoirs in the Tarim Basin

Zhang

Li²,

Peng³

et al. 2022

Front. Earth Sci.

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The deeply buried carbonate reservoir of Cambrian is an important target of oil and gas exploration in the Tarim Basin. Understanding the dissolution mechanism of the deep-buried carbonate reservoir is an urgent problem to be solved. In this study, 11 carbonate samples from three types of deep reservoirs in Tarim Basin were selected as experimental objects, and the dissolution process of carbonate reservoir was simulated by using an advanced reaction system of continuous flow at high temperature and high pressure. The dissolution test of continuous flow shows that the burial depth has an effect on carbonate dissolution, with the increasing of the depths from shallow to deep, the dissolution ability of acidic fluids in carbonate rocks increases first and then decreases. A comparison of dissolution results from different lithologic samples shows that the incomplete dolomitization calcite in the diagenetic stage provides the material basis for dissolution in the later stage. The relationship between reservoir type and physical property is discussed, and it is found that the permeability of the fracture-type and pore-fracture samples increase significantly after dissolution, indicating the pre-existing pores of carbonate rocks may be critical to the formation of high-quality reservoirs in deeply buried conditions. An interesting phenomenon was found by comparing the dissolution rates of experimental samples shows that the dissolution rate of dolomite reservoir has a trend of first increasing and then decreasing under the deeply buried environment, which proves that there is an optimal dissolution range of dolomite in the deeply buried environment, which is conducive to the formation of dolomite reservoir. The genetic model of burial dissolution in deep carbonate reservoirs was established and indicated that the search for dolostone reservoirs near the Himalayan fault may be a new idea for Cambrian deep oil and gas exploration.

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Diagenesis and reservoir quality of Cambrian carbonates in the Tarim Basin, northwestern China

Cited by 7 publications

References 53 publications

CO2-Water-Rock Interactions in Carbonate Formations at the Tazhong Uplift, Tarim Basin, China

CO2-Water-Rock Interactions in Carbonate Formations at the Tazhong Uplift, Tarim Basin, China

Impacts of Depositional Facies and Diagenesis on Reservoir Quality: A Case Study from the Rudist‐bearing Sarvak Formation, Abadan Plain, SW Iran

Experimental analysis of dissolution reconstruction of deep dolomite reservoirs: A case study of the Cambrian dolomite reservoirs in the Tarim Basin

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