Tectonic control on hydrocarbon generation in the northwestern Neuquén Basin, Argentina

Karg, Harald; Littke, Ralf

doi:10.1306/05082018171

Cited by 3 publications

(7 citation statements)

References 43 publications

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“…At the basin scale, the Agrio model shows a clear eastward decrease in maturity and transformation gradient associated with changes in the sedimentary column thickness that led to differential maximum burial before the Miocene deformation pulse. Similar interpretations were documented along the Chos Malal FTB, where thermal maturity and transformation also decrease eastward linked to differences in thickness of the sedimentary overburden (Cruz et al., 1996; Karg & Littke, 2020). In the inner sector of the Agrio FTB, the Miocene uplift caused present‐day source rocks to show relict maturity reached at deeper burial depths in the past.…”

Section: Discussionsupporting

confidence: 61%

“…In addition, there are many local contributions from outcrop sections and the subsurface that include TOC and Rock‐Eval ® pyrolysis analyses (e.g. Askenazi et al., 2013; Boll et al., 2014; Capelli et al., 2021; Cavelan et al., 2019; Karg & Littke, 2020; Krim et al., 2019; Małachowska et al., 2019; Milliken et al., 2019; Petersen et al., 2020; Romero‐Sarmiento et al., 2017; Scasso et al., 2005; Sylwan, 2014). All those studies and the present work indicate high present‐day TOC values ranging from 1% to 12% with maximum values towards the base of the unit in the lower VM (Figure 4).…”

Section: Discussionmentioning

confidence: 99%

“…Based on organic geochemistry and petrological studies, the VMFm exhibits mainly amorphous (liptinitic macerals) type II kerogen with TOC content between 3% and 8% (peak values of 12%–20%) suitable for producing oil or gas condensate, depending on position in the basin (Brisson et al., 2020; Karg & Littke, 2020; Legarreta & Villar, 2011; Sylwan, 2014). The hydrocarbon yield expressed as original hydrogen index (HI 0 ) averages 680 mg HC /g TOC based on the analysis of immature samples (Brisson et al., 2020; Veiga et al., 2020).…”

Section: Geological Settingmentioning

confidence: 99%

“…Many studies have analysed the regional characteristics of the petroleum systems in the Neuquén Basin (Boll et al., 2014; Cruz et al., 1996, 2002; Karg & Littke, 2020; Kozlowski et al., 1998; Legarreta et al., 2008; Mei et al., 2021; Rocha et al., 2018; Uliana & Legarreta, 1993; Vergani et al., 2011). The three marine source units are the Los Molles, Vaca Muerta and Agrio Fms, which differ in terms of organic richness, OM type, maturity and distribution throughout the basin.…”

Section: Geological Settingmentioning

confidence: 99%

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Integrated source rock evaluation along the maturation gradient. Application to the Vaca Muerta Formation, Neuquén Basin of Argentina

Spacapan

Comerio

Brisson³

et al. 2021

Basin Research

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The Vaca Muerta Formation (Tithonian-early Valanginian) is the main source rock in the Neuquén Basin and the most important unconventional shale resource in South America. In the present study, organic geochemistry, electron microscopy and basin and petroleum system modelling (BPSM) were combined to evaluate source rock properties and related processes along a transect from the early oil (east) to the dry gas (west) window. The unit is characterized by high present-day (1%-8% average) and original (2%-16% average) total organic carbon contents, which increase to-

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Section: Discussionsupporting

confidence: 61%

Section: Discussionmentioning

confidence: 99%

Section: Geological Settingmentioning

confidence: 99%

Section: Geological Settingmentioning

confidence: 99%

See 2 more Smart Citations

Integrated source rock evaluation along the maturation gradient. Application to the Vaca Muerta Formation, Neuquén Basin of Argentina

Spacapan

Comerio

Brisson³

et al. 2021

Basin Research

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“…In the basin, it is mainly manifested in the control of later tectonic movement on the maturity of previously preserved source rocks, mainly regulating the paleogeothermal field in the source rock development area. 42,43 The Longtan Formation source rock in the Eastern Sichuan Basin experienced two stages of rapid increase in thermal maturity. The first stage of rapid maturity .…”

Section: Relationship Between Maturitymentioning

confidence: 99%

Hydrocarbon Generation and Expulsion Histories of the Upper Permian Longtan Formation in the Eastern Sichuan Basin, Southwest China

et al. 2023

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The Upper Permian Longtan Formation is the main source rock of the Lower Triassic Jialingjiang Formation in the Eastern Sichuan Basin, Southwest China. However, studies of its maturity evolution and oil generation and expulsion histories are lacking, which are not conducive to the accumulation dynamics of the Jialingjiang Formation in the Eastern Sichuan Basin. Based on the study of tectono-thermal history and geochemical parameter data of the source rock, this paper uses basin modeling technology to simulate the maturity evolution and hydrocarbon generation and expulsion histories of the Upper Permian Longtan Formation in the Eastern Sichuan Basin. The results show that the Longtan Formation source rock in the Eastern Sichuan Basin entered the oil generation threshold at the middle stage of the Early Jurassic and reached the high-maturity stage in the north and central regions at the late stage of the Early Jurassic, and the maturity did not increase after the late stage of the Middle Jurassic. The source rock had the characteristic of “one-stage oil generation and one-stage oil expulsion”; the corresponding period of high oil expulsion was 182–174 Ma (the late stage of the Early Jurassic), which was later than the formation time of the trap of the Jialingjiang Formation, possibly providing oil sources for the paleo-oil reservoirs of the Jialingjiang Formation. The results are of great significance to the gas accumulation process and exploration decision-making in the Eastern Sichuan Basin.

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Organic richness and source rock potential of the La Peña Formation in the Sabinas and Piedras Negras basins, NE of Mexico

Ortiz-Treviño,

Camacho-Ortegón,

Enciso-Cárdenas

et al. 2023

revmexcg

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This paper investigates the petroleum generation potential of the Lower Cretaceous organic-rich rocks of the La Peña Formation in the Sabinas and Piedras Negras Basin (SB-PNB) of northeastern Mexico. In order to provide insights into the source rock potential of this unit, a total of 25 cutting samples collected from 15 wells at different stratigraphic intervals along the study area were analysed using Rock-Eval Pyrolysis technique. The analytical results revealed that all the analysed samples can be described as hydrogen-poor organic matter with HI <200 mg HC/g TOC. The organic richness indicates a poor to excellent Total Organic Carbon content suggesting that existed different conditions during the deposition and burial of this unit, causing variable organic matter production and preservation. Also, the results revealed a variation in the kerogen types that may be attributed to the relative stratigraphic positions of the selected samples in the wells. With respect to the organic matter thermal maturity, given by the geographical distribution of the Tmax values, the mature and overmature zone (435–508 °C) correspond to the Sabinas basin (SB). Overall, these results show a variability in the organic richness, thermal maturity and petroleum potential of the La Peña Formation, differentiating the values of the TOC content, petroleum potential and HI content for the samples from the Sabinas Basin and Piedras Negras Basin, respectively.

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Tectonic control on hydrocarbon generation in the northwestern Neuquén Basin, Argentina

Cited by 3 publications

References 43 publications

Integrated source rock evaluation along the maturation gradient. Application to the Vaca Muerta Formation, Neuquén Basin of Argentina

Integrated source rock evaluation along the maturation gradient. Application to the Vaca Muerta Formation, Neuquén Basin of Argentina

Hydrocarbon Generation and Expulsion Histories of the Upper Permian Longtan Formation in the Eastern Sichuan Basin, Southwest China

Organic richness and source rock potential of the La Peña Formation in the Sabinas and Piedras Negras basins, NE of Mexico

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