Petroleum geology of North Africa by D S MacGregor; Richard Moody; D D Clark-Lowes

By D S MacGregor; Richard Moody; D D Clark-Lowes

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BOOTE ET AL. Extinct Tanezzuft–intra-Palaeozoic system. Tanezzuft shales within the southwestern Palaeozoic depocentre achieved very high maturities before the Hercynian, when they must have generated very significant amounts of oil and gas. Although speculative, it is probable this would have migrated outward to charge traps on the surrounding platform. Accumulations formed during this period would have been dispersed by Hercynian and Austrian unroofing. However, there is limited evidence to suggest that hydrocarbons spilled from some of these palaeo-fields remigrated later into Austrian aged closures nearby.

The organically richest interval is a basal 30 m radioactive unit with as much as 17% TOC of predominantly type I–II kerogen (Daniels & Emme 1995). Although the deepest part of the Palaeozoic depocentre is now very mature, it is unlikely to have contributed much to the Triassic petroleum system because of the intervening Devonian and Carboniferous. Instead this was charged by the section immediately below the unconformity, either directly 26 D. BOOTE ET AL. Table 2. Mesozoic to early Tertiary-charged petroleum systems with intra-Palaeozoic shale seals Basin/area Field size System Representative fields High productivity petroleum systems Illizi Basin Lower Tanezzuft/Cambro-Ordovician (I) Zarzaitine(1957) Tin Fouye-Tabankort (1961) Edjeleh(1956) Alwafa(1991) Ohanet(1960) Tiguentourine (1956) La Reculee(1957) Dome a Collenias-Ouan Taredert (1958) Upper Tanezzuft/Lower Devonian (II) Zarzaitine(1957) Tin Fouye-Tabankort (1961) Alrar(1960) Edjeleh(1956) Alwafa(1991) DimetaOuest (1979) Tin Zemane( 1981) Stah(1971) Timedratine(1961) Mereksene(1974) Tiguentourine (1956) Acheb(1963) Dome a Collenias/Ouan Taredert (1958) Frasnian/Upper Devonian—Carboniferous (III) Zarzaitine(1957) Alrar(1960) In Amenas Nord (1958) Edjeleh(1956) DimetaOuest (1979) Stah(1971) Ohanet (1960) (Lower Devonian reservoir) Reserves system 1500 MMBOE LG LG G G L M M S 3500 MMBOE LG LG G G G G G G L M M M S 2000 MMBOE LG G G G G G L The petroleum systems and their representative fields are listed as in Table 1.

Reservoir continuity is variable, particularly in the lower two sands, reflecting both erosional topography on the unconformity surface and local facies changes. Porosities range up to 20-22% with permeabilities as high as several darcies (Magloire 1970). The area was part of a southeasterly dipping monocline in the Jurassic and it was only later in the Cretaceous, after the subsidence of the Benoud and Oued Mya basins that the modern closure developed. During the subsequent later Cretaceous and early Tertiary it formed the culmination of a very gently deformed arch, ideally positioned to focus hydrocarbons migrating updip from two large fetch areas to the north and southeast.

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