Mesozoic and Cenosoic paleogeography and petroleum potential of the Gulf of Tunis, Tunisia

PROCEDINGS OF THE 10TH TUNISIAN PETROLEUM EXPLORATION & PRODUCTION CONFERENCETUNIS, OCTOBER 13th 18rd,2008

MESOZOIC AND CENOZOIC PALEOGEOGRAPHY AND PETROLEUM POTENTIAL OF THE GULF OF TUNIS, TUNISIA

SOUA Mohamed, SMAOUI Jalel

Entreprise Tunisienne d'Activités Pétrolières, ETAP4, rue des Entrepreneurs, La Charguia II, 2035, Tunisie

PROCEEDINGS OF THE 11th TUNISIAN PETROLEUM EXPLORATION & PRODUCTION CONFERENCETUNIS, OCTOBER 13th 18th, 2008180

Abstract

A regional study of the Gulf of Tunis, surrounded by proven petroleum provinces, hasbeen carried out to check the prospectivity in the Korbous block and to evaluate the playconcepts that have encouraged exploration activity in this area.

Based on N-S and NW-SE regional cross sections and the results of this study, favorableconditions for hydrocarbon accumulation are predictable within the block. The most attractivezone is localized within a N-S trending in the Gulf of Tunis. Two petroleum plays have beenrecognized, the Upper Cretaceous and the Eocene plays, subsequent the Cretaceous andPalaeogene structural and stratigraphic evolution. Two regional cross sections along theGulf of Tunis has been elaborated to show the structural styles, events, basin modelisationand geological factors that may have controled hydrocarbon accumulations.

The Upper Cretaceous play is made up by Upper Cretaceous white chalky carbonates(Abiod Fm) sealed by Maastrichtian-Paleogene shales and marls (El Haria Fm). The Eoceneplay consists of Lower Eocene deep water micritic carbonates setting (Bou Dabous Fm eq.),sealed by Middle-Upper Eocene shales (Souar Fm and its equivalent, Halk El Menzel Fm).It is considered to be outer shelf and consists of organic-rich, biomicrite and grey or blackclayey limestone. Combination of structural and stratigraphic traps has been recognised.

Potential source rocks are present within the block, such as the Albian Moualha (LowerFahdene Fm) and Cenomanian-Turonian (Bahloul Fm) source rocks as well as the the YpresianBou Dabbous organic-rich limestone. Traps are represented by compressional hanging wallanticlines, footwall fault blocks, rollover anticlines, facies changes and unconformity-relatedtraps.

Introduction

The Gulf of Tunis (GOT) domain is surrounded by proven petroleum provinces wheresignificant discoveries have been made in the past decades (e.g., Bishop, 1988; Bishop andDebono, 1996; Klett, 2001). To reassess the prospectivity of the block and to review theplay concepts that have inspired exploration activity in this area, a regional synthesis andstudy of the Gulf province has been performed.

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A strong database which includes published geological and geophysical data plusconfidential technical reports, well logs, and seismic data, has been put together for thisstudy. This large dataset has been analyzed to point out the main tectonic and sedimentaryprocesses in the whole Gulf of Tunis domain and to define their control on the distributionand quality of sources, reservoirs, seals, and related traps and petroleum charge, in thearea. For this reason, two seismic sections (WNW-ESE and NE-SW) have been established.

Fig. 1: Main structural features within the Gulf Of Tunis (GOT) domain and surrounding regions, and distributionof the studied wells, Purple structures indicate Triassic salt extrusions in northern Tunisia



Stratigraphy and structural evolution of the got domain

The Gulf of Tunis (GOT) corresponds to a promontory of the African plate that includesthe SE Sicily. Towards the East and the Southeast, it includes the Cap Bon peninsula, theMaltese and Pelagian Islands (Fig. 1). The present day structural architecture of the GOTdomain is characterised by complex sub-basins with prolongation of the North-South Axis(NOSA) and of the structures of the adjacent area, associated with deep Upper Miocenedepocenters (e.g., Jongsma et al., 1985; Grasso et al., 1999; Massaoudi and Hammouda,1994; Burollet, 1991).

The tectonic evolution of the GOT province occurred in three main steps, which werecontrolled by major plate tectonic processes. This stratigraphic framework is representedin figure 2 where the main depositional environments along a South West to North Easttransect are synthesized.

Following the breakup of Gondwana and the opening of the Neo-Tethys Ocean andLiguro-Provencal Ocean in Late Carboniferous-Early Jurassic times (e.g. Guiraud, 1998;Morgan et al., 1998; Stampfli and Borel, 2002), several rift basins and grabens were formedalong the northern margin of the African plate, GOT province and in the Pelagian domain.Through this time, continental to shallow marine deposits with evaporite intervalscharacterized the Triassic stratigraphy of the Tunisian margin, while persistent shallow to


Fig. 2: Main stratigraphy of the GOT domain and equivalent Formations towards the South-East


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deep-marine carbonate sedimentation occurs in GOT province (inferred from well data) andSicily (Bishop, 1975; Patacca et al., 1979; Antonelli et al., 1988; Bishop and Debono, 1996).Three main steps are evident:

Middle Jurassic-Early Cretaceous

The opening of the central Atlantic Ocean was accompanied by sinistral trastensionalmovement along E-W trending Gibraltar-Sicily trasform zone (e.g. Guiraud, 1998). This processinduced the development of a rift zone between the African and European continents(Guiraud and Maurin, 1999; Guiraud et al., 2005).

Two main rifting events are documented (Soua and Tribovillard, 2007). A first episode,associated with volcanism, occurred from upper Jurassic to Early Aptian (e.g., Burollet etal., 1978; Grasso et al., 1999; Soua and Tribovillard; 2007) along E-W trending faults andmaybe related to the Tethyan rifting. A second rifting stage developed from Top-Aptian toEarly Cenomanian along mainly NW-SE trending faults (e.g., Jongsma et al., 1985; Guiraud,1998; Soua and Tribovillard, 2007) and maybe related to the Sirt rifting (Soua et al., 2009).Numerous rift-basins appeared and some earlier faults were reactivated. The two extensionalphases were interrupted by a regional Top-Aptian uplifting phase, which caused a typicalregional unconformity.

Terrigenous facies are present to the south and southwest of Tunisia, and progressivelymigrate northward from Middle Liassic to Early Cretaceous (Bishop, 1975; Soua et al., 2009).This time interval includes limestones and dolostones moving toward the GOT province(Bishop, 1975; Ben Ferjani et al., 1990; Klett, 2001). The deposition of shallow-marinecarbonates continues through the Jurassic to the Early Cretaceous over the adjacent CapBon peninsula and Maltese province (Patacca et al., 1979).

Fig. 3: regional 2D WNW-ESE (A-A') and NE-SW (NE-SW) cross-sections along the GOT domain, Note the structuralcontrol of some traps formation



Late Cretaceous-Miocene

During late Cretaceous the African plate started to drift northward with respect to Europegenerating the onset of convergence between Africa and Europe (e.g., Dewey et al., 1989).This process induced latest Cretaceous and mainly Eocene tectonic inversions on EarlyCretaceous extensional faults all around the Pelagian province (Guiraud, 1998; Grasso etal., 1999). Shallow to deep-marine Upper Cretaceous carbonate deposits unconformablyoverly the pre-deformation units, including limestones, dolostones and bioclastic formations,fractured micrites, which are proven reservoirs (e.g., Bireno, Miskar, Douleb, Abiod) in thesurrounding provinces (Bishop, 1988). These lithologies are laterally equivalent to dark-graymudstones and euxinic, laminated, argillaceous limestones, which instead constitute provensource rocks (e.g. Fahdene and Bahloul Fms) in Central Tunisia and in the Central Pelagianprovince (Burollet et al., 1978; Bishop, 1988; Klett, 2001; Soua and Tribovillard, 2007).

A regional Paleocene seal (El Haria Fm) caps the Mesozoic units and is in turn overlain,sometimes, by deep water micritic carbonates deposits which are Lower Eocene in age (BouDabbous Fm), proven reservoir rock spread out all around the surrounding Cap Bon Penninsula(Belli, El Manzah and nearby fields). The Oligocene marks a general unconformity in theGOT province (Fig. 3) on the top of the Eocene section, represented by Souar Fm that isgenerally overlain by continental to marine units (Chaabet Tabella Fm) up to the Miocene(Fig. 4), when widespread carbonate sedimentation takes place in the Pelagian provinceand surrounding regions as Libya, Sicily, and parts of Tunisia.

Late Miocene-Recent

Miocene marls and sandstones are closed by Messinian evaporites (Oued Belkhedim Fm)detected uniquely within one well (Car-1). The top of the Miocene is marked by an angularunconformity, very visible in seismic lines, above which Pliocene terrigenous and intrabasinalsediments were deposited into tectonically subsiding troughs.

In the nearby Sicily-Maltese domain, rifting was developed during the Oligocene-Quaternary (Dart et al., 1993; Khomsi et al., 2008) and gives rise to deep tectonic depressions,namely the Pantelleria, Malta, and Medina grabens (Grasso et al., 1999).

Gulf of Tunis petroleum systems

In the GOT province and surrounding regions several petroleum systems have beenrecognized. The essential geologic elements (sources, reservoirs, and seals) as well as possibletraps of these petroleum systems are shown in figure 2. Two regional Seismic Cross-Scetionswere established in this work to show the structural and sedimentary evolution within thisprovince. The main characteristics of these plays are summarized in the following.

1– Upper Cretaceous system characterizes the vast majority of the adjacent Cap-Bonpeninsula and Pelagian Domain as well as the eastern and southern Tunisia (e.g., Bishop,1988; Ben Ferjani et al., 1990; Bédir et al., 1992; Bishop and Debono, 1996; Klett, 2001).Cretaceous sandstones (M'Cherga Fm), inner shelf and shelf margin carbonates (Serj equivalentFm.) and fractured chalky limestones (Abiod Fm) in both stratigraphic and faulted traps,sealed by Maastrichtian-Paleogene shales and marls of the El Haria Fm, do have beencharged during the Miocene-Pliocene from Albian and Cenomanian-Turonian, respectivelyLower Fahdene (Moualha mb) and Bahloul Fm source rocks.



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2– The Tertiary petroleum system (e.g., Bédir et al., 1992; Bishop and Debono, 1996;Macgregor and Moody, 1998; Klett, 2001; Caline et al., 2003) may constitute of deep watermicritic carbonates deposits of Bou Dabbous (Marathon discovery in the nearby Belli Field)and sealed by Middle-Upper Eocene shales (Souar Fm) do have been charged also duringMiocene-Pliocene from Lower Eocene marls and mudstones (Bou-Dabbous Fm). In theadjacent Gulf of Hammamet, Oligocene to Miocene reservoirs include the Ketatna limestones,the Aïn Grab limestones, and Birsa sandstones. However, the existence of the Langhian AinGrab Fm is evident, since its presence in ROD-1 well, within the GOT domain. Since BouDabbous Fm is already immature, the tertiary petroleum system may be constituted by theCretaceous Source rocks (Moualha and Bahloul Fms) and by Bou Dabbous, Reineche, Korbous,Fortuna and Ain Grab reservoirs sealed respectively by Souar and Oued Belkhedim Fms.

Exploration history in the gulf of Tunis

Oil exploration in the Offshore Gulf of Tunis dates back to the 1970s with the first welldrilled in 1973 (MGT-1). Exploration continued in the offshore area from the '70s to themid-'90s. In this period, exploration was mainly focused on Tertiary limestones as well assandstones reservoirs (Fig. 2). Carbonate rocks, ranging from Triassic to Oligocene, havebeen penetrated both in the offshore GOT and in the periphery (Cap-Bon peninsula, Utique).The lack of seal, reservoir, together with a poor hydrocarbon charge delineate absence ofcommercial hydrocarbon accumulations on the GOT where only minor oil shows (oil havingbeen extracted from sample) have been reported in Upper Cretaceous rocks (Fig. 4) in thenorthern and central GOT. However, interesting oil shows have been encountered in theEocene section of wells drilled along the GOT (Fig. 4).

Fig. 4: Electric well correlation along the GOT domain, oil and Gas shows within the studied wells



The Upper Creataceous Petroleum Play

Following the results of this study, it became probable that the structural and stratigraphicevolution of GOT could have produced a Cretaceous petroleum play (Fig. 3). The possiblefeatures of this play are reported below (Fig. 5).

Reservoir. The regional distribution of the Upper Cretaceous interval (Fig. 3; Fig. 5)suggests the possible development of Campanian and possible Turonian-Coniacian-Santoniancarbonate reservoirs. Available seismic evidences support the possible presence of an UpperCretaceous carbonate around both sides of the GOT.

The presence of Cenomanian-Turonian rudistid biostromal limestones and rudistidgrainstones reported at the periphery of GOT, in Borj Cedria and Soliman, and at the nearbyHalk El Menzel field, is analogous to that identified in Isis field, and probaly represent abar, or bank, developed on a pre-existing high (Soua and Tribovillard, 2007). The upperCretaceous Abiod chalky limestone is present within the GOT and confirmed by the penetratedwells. However, in the periphery of the GOT as noted in SDM-1 (on the Cap-Bon peninsula),the upper Cretaceous is very similar to that recognized in RAJA-1, to the extreme North ofthe GOT, and is made by a thick carbonate unit, probably assigned to Makki Fm.



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Fig. 5: Isopachous curves of some selected reservoirs and source rocks present within the GOT domain



Seal. In the GOT domain, Cretaceous carbonate units were succeeded by Paleocenetransgressive shales and marls (e.g., El Haria Fm; Fig. 2). Although on the periphery of GOT(Cap Bon, in SDM-1), and in major part part of the GOT a significant hiatus (or erosion) isrecognizable at this level, Paleocene shales were penetrated by wells located to the northin GOT. Seismic evidences (Fig. 3) corroborate the likely presence of El Haria Fm shales alsoin the GOT.

Source. Deposition of Lower Fahdene and Bahloul equivalent source rocks can bepredicted along the Central margin of the GOT based on the analysis of the lithofaciesdistribution (Figs. 2 and 5) and of seismic evidence. This reconstruction is also supportedby a recent study (Soua and Tribovillard, 2007) which suggests that the deposition ofCenomanian-Turonian organic-rich strata in Tunisia could have been driven by theimpingement of the oxygen minimum zone onto the shelf following the latest Cenomaniantransgression. Isolated organich-rich basins (graben systems) surrounded by shallower organiclean carbonates has been also pointed out (Fig. 3), resulting from restricted circulationwithin these basins that may have further increased oxygen-deficiency and promoted organic-rich black shales.

Charge. According to geohistory and maturity modeling conducted on GOT (Fig. 6), thegeothermal gradient in GOT is envisaged to be at least 5.0°C/100m and 20°C for surfacetemperature. Based on these conservative values, the Cretaceous source rocks (Albian Moulhaand C/T Bahloul Fms) would have entered the oil window since 27/30 Ma (the Oligocene)in the GOT and they are in initial generating oil window stage at the present.

It should be noted that the cited modeling assumed a constant geothermal gradientthrough geologic time. However, the live oil shows encountered in several wells suggestthat Cretaceous rocks should be mature for oil also in the GOT domain.

Trap. Compressional hanging wall anticlines, footwall fault blocks, rollover anticlines,facies changes and unconformity-related traps.

The Eocene Petroleum Play

Exploration activities in GOT domain focused on fractured carbonate seismic featuresand several closures were mapped at the level of deep water micritic carbonates depositsof the Eocene assigned to Bou Dabbous Fm. However, and according to seismic datainterpretation, previous operators concluded in the mid-1990s that observed moundedfeatures in the southern GOT domain were likely the expression of a dissected carbonateramp system, probably Paleocene in age.

Reservoir. The observed closures are interpreted to be deep water micritic carbonatesdeposits of the Bou Dabbous Fm (Lower Eocene).



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Possible analogues of these Eocene prospects are the proven reservoirs of NE onshoreTunisia (i.e., Belli, Al Manzah and nerby fields), which are characterized by the developmentof Globigerine carbonate facies belts. The tectonic patterns of these fields are very similarto those observed for Central and Northern Tunisia, dominated by NE-SW and E-W trendinggraben systems. The top of the structural paleo-basins was dominated by the depositionof deep water micritic carbonates globigerine-rich facies, passing laterally into higher energynummulite-rich limestone deposits.

Seal. Upper Eocene shales of the Souar Fm. in the GOT domain the Eocene Souar Fm isprobably replaced by Halk el Manzel nummulite limestone, inferred from the SDM-1 welland Zembra isle stratigraphy.

Fig. 6: Burial History of two selected wells from the GOT domain




Fig. 7: Upper Cretaceous (A) and Tertiary (B) play fairway maps


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Source rock. Albian Moualha black shales and marls of the Lower Fahdene Fm, Cenomanian-Turonian black laminated argillaceous limestones of the Bahloul Fm and probably the intra-Bou Dabbous black organic-rich marls. However, in the GOT domain, it is thought that theLower Eocene marls and mudstone of the Bou-Dabbous Fm are likely immature for oilgeneration. Furthermore, the modelisation, within kitchen area, of the CAR-1 well (situatedwithin an E-W trending Graben) revealed the existence of early mature window in the upperMiocene Kechabta Fm.

Charge. According to geohistory modeling, Eocene source rock should be mostly immatureassuming a constant geothermal gradient in 2.5-3.0°C/100m range. Cretaceous source rocks(Lower Fahdene and Bahloul Fms) are likely mature for oil and oil generation occurredsince the Lower Oligocene. Vertical migration pathways along faults and fractures followingthe final creation of trap closures may be expected.

Trap. compressional hanging wall anticlines, footwall fault blocks, rollover anticlines,facies changes and unconformity-related traps.

Risks. The main risks are related to both reservoir and seal presence and heterogeneity. Absence of the reservoir is due to the absence of globigerine-rich limestone. High

amplitude and continuous reflectors overlying low amplitude reflectors in the Eocene sectioncould record the progradation of nummulithoclastic packstones and grainstones on thebasinal deposits of the Bou-Dabbous Fm. The Lower Eocene reservoir could show a highinternal heterogeneity. The Souar Fm could show a high percentage of limestones andfurther could pass laterally to the Halk el Manzel platform carbonate facies.

Conclusions

Based on new geoseismic sections, tectonic models and regional analysis, it has beenpossible to review and update the petroleum plays that are expected to occur in the GOT.Despite the previous unsuccessful exploration results, favourable conditions for hydrocarbonaccumulation could be present within the analyzed area.

Two main petroleum plays have been pointed out, the Upper Cretaceous and the EocenePlays. These two plays derive from previous interpretation of the Cretaceous and paleogenestratigraphic and structural architecture of the GOT based on structural models. However,a Late Triassic-Liassic play could effective and may be proposed. Nevertheless, the availabledata only allow a generic definition of the main play elements based on southern Zaghouaneand Eastern Sicily analogues.

The Upper Cretaceous and the Eocene plays have been analyzed in detail. Two PlayFairway Maps have been elaborated to show the geographical distribution of the keygeological factors that may control the hydrocarbon accumulation (Figs. 7).

The Upper Cretaceous is made up by Upper Cretaceous chalky fractured carbonates(Abiod Fm) or shelfal carbonates deposition (Mekki Fm equivalent of Miskar and maybe IsisFm) sealed by Maastrichtian-Paleogene shales and marls (El Haria Fm), and charged duringthe Pliocene from Albian (Moualha, Lower Fahdene Fm) and Cenomanian-Turonian (BahloulFm) source rocks.

The Eocene Play consist of Lower Eocene deep water micritic carbonates deposited inbasinal environment (Bou Dabbous Fm), sealed by Middle-Upper Eocene shales (Souar Fm),and charged during Miocene-Pleistocene from Albian (Lower Fahdene Fm) and Cenomanian-Turonian (Bahloul Fm) source rocks.



The main recognizable risks concern both the reservoir and the seal presence andheterogeneity. Trap integrity of closures bounded by Pliocene to recent faults is a furtherrisk together with adequate hydrocarbon charge from the Cretaceous sources.

A refinement of the interpretation of the Upper Cretaceous section should be carriedout to better define the size and distribution of predicted Upper Cretaceous reservoirswithin the GOT domain.

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Mesozoic and Cenosoic paleogeography and petroleum potential of the Gulf of Tunis, Tunisia

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