Migration and Accumulation of Oil and Natural Gas Generated from Neogene Source Rocks in the Hungarian Part of the Pannonian Basin

Szalay, A.; Koncz, István

doi:10.1007/978-3-642-77859-9_24

Cited by 7 publications

(5 citation statements)

References 2 publications

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“…Volumetric expansion of maturing hydrocarbons is an unlikely source of overpressures in the area. According to Szalay & Koncz (1993; p. 305): ‘The deep basin sediments along the axis of the deep troughs presently are in the main phase of dry gas or wet gas generation.’ Yet, as is clearly observable on the hydraulic cross‐sections (Figs 20–22), the horizontal components of the driving forces point in all cases from the basement highs towards the basin centres, i.e. towards the loci of hydrocarbon maturation.…”

Section: Discussionmentioning

confidence: 99%

Interpretation of observed fluid potential patterns in a deep sedimentary basin under tectonic compression: Hungarian Great Plain, Pannonian Basin

2001

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The ≈ 40 000 km2 Hungarian Great Plain portion of the Pannonian Basin consists of a basin fill of 100 m to more than 7000 m thick semi‐ to unconsolidated marine, deltaic, lacustrine and fluviatile clastic sediments of Neogene age, resting on a strongly tectonized Pre‐Neogene basement of horst‐and‐graben topography of a relief in excess of 5000 m. The basement is built of a great variety of brittle rocks, including flysch, carbonates and metamorphics. The relatively continuous Endrőd Aquitard, with a permeability of less than 1 md (10−15 m2) and a depth varying between 500 and 5000 m, divides the basin's rock framework into upper and lower sequences of highly permeable rock units, whose permeabilities range from a few tens to several thousands of millidarcy. Subsurface fluid potential and flow fields were inferred from 16 192 water level and pore pressure measurements using three methods of representation: pressure–elevation profiles; hydraulic head maps; and hydraulic cross‐sections. Pressure–elevation profiles were constructed for eight areas. Typically, they start from the surface with a straight‐line segment of a hydrostatic gradient (γst = 9.8067 MPa km−1) and extend to depths of 1400–2500 m. At high surface elevations, the gradient is slightly smaller than hydrostatic, while at low elevations it is slightly greater. At greater depths, both the pressures and their vertical gradients are uniformly superhydrostatic. The transition to the overpressured depths may be gradual, with a gradient of γdyn = 10–15 MPa km−1 over a vertical distance of 400–1000 m, or abrupt, with a pressure jump of up to 10 MPa km−1 over less than 100 m and a gradient of γdyn > 20 MPa km−1. According to the hydraulic head maps for 13 100–500 m thick horizontal slices of the rock framework, the fluid potential in the near‐surface domains declines with depth beneath positive topographic features, but it increases beneath depressions. The approximate boundary between these hydraulically contrasting regions is the 100 m elevation contour line in the Duna–Tisza interfluve, and the 100–110 m contours in the Nyírség uplands. Below depths of ≈ 600 m, islets of superhydrostatic heads develop which grow in number, areal extent and height as the depth increases; hydraulic heads may exceed 3000 m locally. A hydraulic head ‘escarpment’ appears gradually in the elevation range of − 1000 to − 2800 m along an arcuate line which tracks a major regional fault zone striking NE–SW: heads drop stepwise by several hundred metres, at places 2000 m, from its north and west sides to the south and east. The escarpment forms a ‘fluid potential bank’ between a ‘fluid potential highland’ (500–2500 m) to the north and west, and a ‘fluid potential basin’ (100–500 m) to the south and east. A ‘potential island’ rises 1000 m high above this basin further south. According to four vertical hydraulic sections, groundwater flow is controlled by the topography in the upper 200–1700 m of the basin; the driving force is orientated downwards beneath the highlands and upw...

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Section: Discussionmentioning

confidence: 99%

Interpretation of observed fluid potential patterns in a deep sedimentary basin under tectonic compression: Hungarian Great Plain, Pannonian Basin

2001

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“…(v) Post-rift basinal Pannonian shales are organically quite rich locally, similar to the underlying Badenian-Sarmatian marls, and represent a significant secondary source of oil and gas. (vi) Less mature Neogene shale sections contributed significant amounts of biogenic gas The very large volumes of biogenic gas trapped in Transylvanian Basin are a reflection of the very low thermal gradient and extended section of immature Neogene shales (Summary after Baric et al, 1991;Szalay and Koncz, 1991;Sarkovic et al, 1992;Szalay and Koncz, 1993;Tari et al, 1993;Ionescu, 1994;Kokai, 1994;Milota et al, 1995;Horvath and Tari, 1999;Pawlewicz, 2005;Dolton, 2006;Stefanescu et al, 2006;Tari and Horvath, 2006;Magyar et al, 2006;Rodica, 2009;Malvic and Velic 2010;Krezsek et al, 2010;Bechtel et al, 2012;Badics and Vetö, 2012;Cvetkovic et al, 2018;Lemberkovics et al, 2017).…”

Section: Principal Source Rocksmentioning

confidence: 99%

Petroleum Provinces of the Paratethyan Region

Boote¹,

Sachsenhofer

Tari

et al. 2018

Journal of Petroleum Geology

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Initial crustal collision between Africa and Eurasia in the middle Eocene – early Oligocene enclosed a semi‐restricted Paratethyan seaway of linked basins and platforms across a region stretching from the Eastern Alps to the South Caspian Sea. As the African Plate continued to advance north during the later Neogene, the seaway shrank into a series of more isolated basins separated by the rising Alpine – Carpathian – Caucasus fold‐thrust belts. Organic‐rich oil‐prone Paratethyan source rocks of middle Eocene (Kuma Formation and equivalents) and Oligocene – early Miocene (Maikop and Menilite Beds) ages, and more gas‐prone post‐orogenic mid‐upper Miocene shales, subsequently charged over 2500 accumulations across the region with combined recoverable reserves of 95 billion brl oil‐equivalent (B boe). These accumulations are clustered in discrete petroleum provinces, each with a distinct tectono‐stratigraphic architecture and comprised of one or more petroleum systems. The provinces can be grouped into five broad categories: Average Reserves Average Field Sizes Fold‐thrust Provinces60,980 MMboe2–590 MMboeSub‐thrust Provinces255 MMboe3.4 MMboeForeland Provinces18,671 MMboe2–77 MMboeIntermontane Provinces13,122 MMboe1–40 MMboeBlack Sea back‐arc Province> 1391 MMboe>33 MMboe The productivity of each province (estimated very approximately from the number of barrels oil equivalent / square kilometre) is extremely variable, and its relationship with the geological factors controlling hydrocarbon entrapment and retention is complex. The most critical of these factors appears to be the quality and distribution of source rocks and post‐charge structural modification.

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“…Three major petroleum systems exist in the Pannonian Basin.the oldest is in the Paleo-Mesozoic-tectonostratigraphic unit, the middle system is Paleogene and the youngest system is associated to the Neogene (Horváth and Tari, 1999). In Neogene tectonostratigraphic unit the oil-generation window is located in the depth range of 2.4-4.3 km (Horváth et al 1988;Szalay and Koncz 1991;Fig. 2.6.).…”

Section: Hydrocarbon Systemsmentioning

confidence: 99%

“…Clayton, Spencer, and Koncz (1994) reported that Badenian, Sarmatian and Pannonian source rocks have total organic content of 1-2 %. These source rocks contain type III and type II-III kerogens (Szalay and Koncz, 1991;Badics and Vető, 2012). Unconformities at top and bottom of synrift sequence are the most common migration pathways, while traps are usually structural, formed above basement highs due to differential compaction (Tari and Horváth, 2006).…”

Section: Hydrocarbon Systemsmentioning

confidence: 99%

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Diagenesis and reservoir quality of Pannonian lacustrine deposits in the Makó Trough, SE Hungary

Szőcs¹

2019

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Migration and Accumulation of Oil and Natural Gas Generated from Neogene Source Rocks in the Hungarian Part of the Pannonian Basin

Cited by 7 publications

References 2 publications

Interpretation of observed fluid potential patterns in a deep sedimentary basin under tectonic compression: Hungarian Great Plain, Pannonian Basin

Interpretation of observed fluid potential patterns in a deep sedimentary basin under tectonic compression: Hungarian Great Plain, Pannonian Basin

Petroleum Provinces of the Paratethyan Region

Diagenesis and reservoir quality of Pannonian lacustrine deposits in the Makó Trough, SE Hungary

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