Thermal maturity, source rock potential and kinetics of hydrocarbon generation in Permian shales from the Damodar Valley basin, Eastern India

Mani, Devleena; Patil, D. J.; Dayal, A. M.; Prasad, B.

doi:10.1016/j.marpetgeo.2015.08.019

Cited by 37 publications

(19 citation statements)

References 49 publications

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“…Tissot and Welte 1978;Jiang et al 2015;Mani et al 2015;Ratnayake et al 2017b). TOC values range from 0.55 to 2.10 wt% with an average of 1.16 ± 0.39 wt% (Table 1).…”

Section: Organic Richness and Kerogen Typementioning

confidence: 95%

“…Espitalié et al 1977;Katz 1983;Delvaux et al 1990;Langford and Blanc-Valleron 1990;Vandenbroucke and Largeau 2007;Adegoke et al 2015;Jiang et al 2015). In addition, vitrinite reflectance is an optical thermal maturity indicator of sedimentary organic matter since Silurian (Ritter 1984;Sweeney and Burnham 1990;Uysal et al 2000;Mani et al 2015). Petroleum geochemists generally deal with these analytical results together with standard reference diagrams and numerical modelling for identifying potential source rock beds (e.g.…”

Section: Introductionmentioning

confidence: 99%

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Assessment of hydrocarbon generation potential and thermal maturity of the offshore Mannar Basin, Sri Lanka

Ratnayake

Kularathne²,

Sampei

2017

J Petrol Explor Prod Technol

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The Mannar Basin is an under-explored offshore sedimentary basin in terms of petroleum geology. The Cretaceous to Paleogene cutting samples were collected in three offshore exploration wells (i.e. the Dorado North, Dorado and Barracuda) in the Mannar Basin. In this study, kerogen type, quantity and thermal maturity of sedimentary organic matter were ascertained using Rock-Eval pyrolysis and vitrinite reflectance analyses. In addition, 1-D basin modelling was used to analyse the timing of hydrocarbon generation in the Mannar Basin. Total organic carbon (TOC) contents and total hydrocarbon potential are higher in the Cretaceous calcareous mudstones than in the Paleogene calcareous silty/sandy mudstones. TOC contents show a negative correlation with oxygen index. Hydrogen index and oxygen index values range from 77 to 785 mg HC/g TOC and from 25 to 165 mg HC/g TOC, respectively. Organic matters were identified as mixed Type II-III and Type III kerogen. Maturity expressed in term of Tmax and vitrinite reflectance range from 332 to 456 °C and from 0.26 to 1.49%, respectively. It indicates both immature and mature sediments. In general, maturity values are relatively high in the Late Cretaceous sediments (Tmax, from 332 to 456 °C, average = 423 °C ± 25) compared to the Paleogene sediments (Tmax, from 388 to 431 °C, average 419 °C ± 10). Geochemical proxies show that oil and gas prone (Type II-III) and gas prone (Type III) kerogen-rich Late Cretaceous sediments of the Dorado and Barracuda wells have principally achieved maturity levels for oil window. Therefore, it suggests incomplete thermal conversion for the wet gas generation in the northeast part of the Mannar Basin. In the 1-D basin modelling, the maximum hydrocarbon generation was observed during the Neogene Period in the Late Cretaceous sediments of the deeper Barracuda well.

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“…Tissot and Welte 1978;Jiang et al 2015;Mani et al 2015;Ratnayake et al 2017b). TOC values range from 0.55 to 2.10 wt% with an average of 1.16 ± 0.39 wt% (Table 1).…”

Section: Organic Richness and Kerogen Typementioning

confidence: 95%

Section: Introductionmentioning

confidence: 99%

Assessment of hydrocarbon generation potential and thermal maturity of the offshore Mannar Basin, Sri Lanka

Ratnayake

Kularathne²,

Sampei

2017

J Petrol Explor Prod Technol

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“…The bulk stable carbon isotope composition indicates the contribution from terrestrial higher plants (Table 3). Differences in the carbon sources of the marine and continental (terrestrial and freshwater) plants are depicted in their  13 C isotopic compositions (Mani et al, 2015). In general,  13 C for marine plants ranges from -8‰ to -17‰, whereas for land plants it ranges from -22‰ to -29‰ (Hoefs, 2009).…”

Section: Fig5 Correlation Between the Hi And Oi Values In Om From Thmentioning

confidence: 99%

Geochemical Characteristics of Carbonaceous Shales from the Surkha Lignite Mine, Saurashtra Basin, India: Implications for Gas Potential

2016

International Journal of Petroleum and Petrochemical Engineerin

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The carbonaceous shales collected from the Surkha lignite deposits of Saurashtra basin, Gujarat have been studied to decipher the source and quality of kerogen present in it. The pyrolysis and bulk carbon isotope ratio signatures have been determined using Rock Eval6 and EA-IRMS, respectively. Total Organic Carbon (TOC) content of thirty-five shale and lignite samples collected from the open cast lignite mine ranges between 0.4 and 52.4 %. The S1 and S2 values vary from 0.1to 14.9 mg HC/g rock and 0.1 to 363.8 mg HC/g rock, respectively. Rock Eval thermal maturity indicator, Tmax values, varies between 404°C and 433°C respectively. The hydrogen index (HI) ranges between 5 and 695 mg HC/g TOC, whereas the oxygen Index (OI) values ranges between 15 and 307 mg CO 2 /g TOC. Organic matter (OM) is typified predominately by Type III kerogen, with partial contribution from Type IV kerogen. The Tmax and calculated Rock Eval VRo% (< 0.6) suggests immature stage for hydrocarbon generation. Rock Eval parameters, S1, S2, and TOC correlate well with each other and suggest the well preserved and unaltered nature of organic components. Bulk carbon isotope ratios ( 13 C) range between-22.7 to-26.5‰ and indicate the contribution of OM from terrestrial land plants. Major element composition determined using XRF technique indicates it to be Fe-shale, with mineral matrix rich in smectite and illites. With shale gas and shale oil emerging as alternate source of energy in recent times, this study provides useful insights on the kerogen properties of the Surkha shales.

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“…The quality and quantity of organic matter play important role in the generation of hydrocarbon. Source rock characterization using organic geochemical technique (Rock-Eval pyrolyser) is widely used to evaluate the quality, quantity, hydrocarbon generation potential and thermal maturity of organic carbon (Espitalié et al 1986;Peters and Cassa 1994;Banerjee et al 2006;Mani et al 2014Mani et al , 2015Bourah and Ganapathi 2015). The total organic carbon (TOC) and biomarker studies are also helpful to characterize the type and maturity of organic matter in black shales and other organic carbon rich rocks (Banerjee et al 2006;Sivan et al 2008;Arora et al 2015Arora et al , 2017Bourah and Ganapathi 2015;Mani et al 2017).…”

Section: Introductionmentioning

confidence: 99%

“…Black shales have been reported from several sedimentary basins of India, which include the Paleoproterozoic Cuddapah basin (Manikyamba et al 2008), Mesoproterozoic to Neoproterozoic Vindhyan basin (Banerjee et al 2006;Paikaray et al 2008;Bhaskar 2013), Permian Gondwana basin of the Krishna-Godavari valley (Rao 2001; Bhaskar 2013), Permian to Mesozoic Gondwana basins of the Damodar Valley (Bhaskar 2013;Bourah and Ganapathi 2015;Mani et al 2015;Tewari et al 2016), Permian-Triassic basins in the Himalayan Region (Mani et al 2014), Paleogene Cambay basin (Banerjee and Rao 1993;Bhaskar 2013), Paleogene of the Cauvery basin (Chandra et al 1991;Bhaskar 2013) and the Mesozoic-Paleogene rocks of the Kachchh basin (Dutta et al 2011;Sahay 2011;Mishra et al 2014;Arora et al 2015Arora et al , 2017. Thick and well-developed organic-rich black shales constitute distinct stratigraphic units of the onland Kachchh basin of western India (figure 1).…”

Section: Introductionmentioning

confidence: 99%

Characterization of organic carbon in black shales of the Kachchh basin, Gujarat, India

et al. 2018

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Thirty-three black shale samples from four locations on the onland Kachchh basin, western India were analyzed to characterize organic carbon (OC), thermal maturity and to determine the hydrocarbon potential of the basin. Upper Jurassic black shales from the Jhuran Formation (Dhonsa and Kodki areas) are characterized by the presence of chlorite, halloysite, high T max , low OC, low hydrogen index and high oxygen index. These parameters indicate the OC as type IV kerogen, formed in a marine environment. The rocks attained thermal maturity possibly during Deccan volcanism. Early Eocene samples of the Naredi Formation (Naliya-Narayan Sarovar Road (NNSR) and the Matanomadh areas) are rich in TOC, smectite, chlorite and framboidal pyrite, but have low T max. These indicate deposition of sediments in a reducing condition, probably in a lagoonal/marsh/swamp environment. Organic carbon of the Naredi Formation of NNSR may be considered as immature type III to IV kerogen, prone to generate coal. Core samples from the Naredi Formation of the Matanomadh area show two fold distribution in terms of kerogen. Organic carbon of the upper section is immature type III to IV kerogen, but the lower section has type II to III kerogen having potential to generate oil and gas after attaining appropriate thermal maturity.

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Thermal maturity, source rock potential and kinetics of hydrocarbon generation in Permian shales from the Damodar Valley basin, Eastern India

Cited by 37 publications

References 49 publications

Assessment of hydrocarbon generation potential and thermal maturity of the offshore Mannar Basin, Sri Lanka

Assessment of hydrocarbon generation potential and thermal maturity of the offshore Mannar Basin, Sri Lanka

Geochemical Characteristics of Carbonaceous Shales from the Surkha Lignite Mine, Saurashtra Basin, India: Implications for Gas Potential

Characterization of organic carbon in black shales of the Kachchh basin, Gujarat, India

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