The effective source rocks in the north Cambay Basin, India

Banerjee, A.; Jha, Mamta; Mittal, A.K.; Thomas, N.J.; Misra, K. N.

doi:10.1016/s0264-8172(00)00049-0

Cited by 42 publications

(9 citation statements)

References 7 publications

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“…in the Ahmedabad-Mehsana tectonic block have upgraded the prospects of the area and added impetus to exploration activities. New pools and hydrocarbon finds have opened up the area for the Paleocene-Eocene prospects of this block (Banerjee et al, 2000;Kumar et al, 2004;Gupta et al, 2006;Sarraf et al, 2008). The study area containing six wells namely AM-11, AM-12, AM-13, AM-14, SM-1 and SM-6 covers approximately 9 sq km lying between Sanand and Nawagam oil/fields of Cambay basin (Fig.…”

Section: Study Areamentioning

confidence: 99%

Reservoir identification using full stack seismic inversion technique: A case study from Cambay basin oilfields, India

Chatterjee

Gupta²,

Farroqui³

2013

Journal of Petroleum Science and Engineering

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Section: Study Areamentioning

confidence: 99%

Reservoir identification using full stack seismic inversion technique: A case study from Cambay basin oilfields, India

Chatterjee

Gupta²,

Farroqui³

2013

Journal of Petroleum Science and Engineering

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“…The Cambay shale is the main source rock sequence in the basin, Ankleshwar and Kalol formations are the main reservoirs and Tarapur/Kanwa shale is the cap rock (Chowdhary, 2004). Banerjee et al (2000) reported five potential source rocks in the Paleogene and on the basin margins, the source rocks (SR7, SR8/9 and SR11/12) have attained vitrinite reflectance (VRo) of 0.75%. Geochemical evaluation studies reported by Banerjee et al (1993) in Ahmedabad-Mehsana, which characterized the basin margin areas, have predominantly type III kerogen in all formations.…”

Section: Geologymentioning

confidence: 99%

Evidence for a relationship between hydrocarbon microseepage and trace metal anomalies: an implication for petroleum exploration

et al. 2011

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The paper reports the role of hydrocarbon microseepage in surface alterations of trace metal concentrations. In this study trace metal alterations were mapped that appear to be associated with hydrocarbon microseepages in the oil/gas fields of Mehsana block, North Cambay basin, India. The ranges of adsorbed soil gas concentrations of Methane, Ethane, Propane, iButane and n-Butane are found to vary from 1-402 ppb, 1-135 ppb, 1-70 ppb, 1-9 ppb, 1-18 ppb respectively, suggesting the presence of hydrocarbons and microseepage associated with the study area. The carbon isotopic signature of methane ranged from -29.5 to -43.0‰ (PDB) and ethane from -19.1 to -20.9‰ (PDB), indicating a thermogenic source of hydrocarbons. The absence of any significant correlation of Total Organic Carbon (TOC) and Total Inorganic Carbon (TIC) (r = 0.1 and 0.5 respectively) content with hydrocarbons in soil samples demonstrates the catagenetic origin of the desorbed gases. The Trace metal concentrations varied in the following manner: Ni: 49-155 ppm, V: 67-158 ppm, Cu: 29-82 ppm, Zn: 64-327 ppm, Ba: 241-554 ppm and Sr: 118-892 ppm. These high concentrations of trace metals which are more than their respective average concentrations generally found in soils are indicative of hydrocarbon induced alterations in the area.The low Eh values observed in anomalous hydrocarbon bearing soil samples compared to non anomalous samples in the area, could be attributed to the reducing conditions created by the hydrocarbon seepage from subsurface and might have influenced the trace metal solubilities which is reflected in their increased concentrations. Trace metal anomalies are seen haloed to adsorbed soil gas anomalies (ΣC 2+ ) indicating that the major generative depressions of oil and /or gas fields of Sobhasan / Linch in the study area promoted vertical migration of hydrocarbon microbubbles which in turn facilitated trace metal deposition in the surface soils. By using integrated method approach, the weak signal of oil and gas reservoirs could be amplified in the frontier areas and the uncertainity of the vertical correlation of surface anomalies could be reduced.

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“…Research and exploration of such unconventional petroleum resources must consider all of the petroleum system elements and risks. In general, the study of source rock petroleum generation potential and expulsion efficiency are important for the assessment of unconventional resources (Leythaeuser et al 1988;Banerjee et al 2000;Guan et al 2012a). This manuscript aims to systematically evaluate the Lower and Middle Jurassic source rocks on the southern margin of Junggar Basin and to infer the generated and expelled petroleum volumes.…”

Section: Introductionmentioning

confidence: 99%

Petroleum generation and expulsion characteristics of Lower and Middle Jurassic source rocks on the southern margin of Junggar Basin, northwest China: implications for unconventional gas potential

et al. 2014

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Jurassic strata along the southern margin of Junggar Basin are important petroleum system elements for exploration in northwest China. The Lower and Middle Jurassic source rock effectiveness has been questioned as exploration progresses deeper into the basin. These source rocks are very thick and are distributed widely. They contain a high total organic carbon composed predominantly of Type III kerogen, with some Type II kerogen. Our evaluation of source rock petroleum generation characteristics and expulsion history, including one-dimensional basin modeling, indicates that Jurassic source rocks are gas prone at deeper depths. They reached peak oil generation during the Early Cretaceous and began to generate gas in the Late Cretaceous. Gas generation peaked in the Paleogene-Neogene. Source rock shales and coals reached petroleum expulsion thresholds at thermal maturities of 0.8% and 0.75% vitrinite reflectance, respectively, when the petroleum expulsion efficiency was ϳ40%. The petroleum generated and expelled from these source rocks are 3788.75 × 10 8 and 1507.55 × 10 8 t, respectively, with a residual 2281.20 × 10 8 t retained in the source rocks. In these tight reservoirs, a favorable stratigraphic relationship (where tight sandstone reservoirs directly overlie the source rocks) indicates short vertical and horizontal migration distances. This indicates the potential for a large, continuous, tight-sand gas resource in the Lower and Middle Jurassic strata. The in-place natural gas resources in the Jurassic reservoirs are up to 5.68 × 10 12 − 15.14 × 10 12 m 3 . Jurassic Badaowan and Xishanyao coals have geological characteristics that are favorable for coal-bed methane resources, which have an in-place resource potential between 3.60 × 10 12 and 11.67 × 10 12 m 3 . These Lower and Middle Jurassic strata have good shale gas potential compared with active US shale gas, and the inferred in-place shale gas resources in Junggar Basin are between 20.73 × 10 12 and 113.89 × 10 12 m 3 . This rich inferred conventional and unconventional petroleum resource in tight-sand, coal-bed, and shale gas reservoirs makes the deeper Jurassic strata along the southern margin of Junggar Basin a prospective target for future exploration.Résumé : Les strates jurassiques le long de la bordure sud du bassin de Junggar constituent des éléments importants d'un système pétrolier exploitable dans le nord-ouest de la Chine. L'efficacité de la roche source (Jurassique inférieur et moyen) a été mise en question à mesure que l'exploration progressait plus profondément dans le bassin. Ces roches sources sont très épaisses et couvent de grandes étendues. Leur teneur en carbone organique total est élevée et il est principalement composé de kérogène de type III avec un peu de kérogène de type II. Selon notre évaluation des caractéristiques de génération de pétrole à partir de roches souches et de l'historique d'expulsion, incluant une modélisation du bassin à une dimension, ces roches sources du Jurassique devraient contenir du gaz à de grandes pro...

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The effective source rocks in the north Cambay Basin, India

Cited by 42 publications

References 7 publications

Reservoir identification using full stack seismic inversion technique: A case study from Cambay basin oilfields, India

Reservoir identification using full stack seismic inversion technique: A case study from Cambay basin oilfields, India

Evidence for a relationship between hydrocarbon microseepage and trace metal anomalies: an implication for petroleum exploration

Petroleum generation and expulsion characteristics of Lower and Middle Jurassic source rocks on the southern margin of Junggar Basin, northwest China: implications for unconventional gas potential

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