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Our focus on the WCTP zone for its successful discoveries has made our Ghana operations offshore business attractive to major partnerships worldwide. We are exploring major possibilities within this zone in Ghana currently.

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OS Petro’s focus on West Cape Three Points South section of the Tano Basin has sparked a lot of interesting partnerships that is developing into real value add to our current secured concessions in Namibia.

We are anticipating explosive growth in our oil and gas services sector in our Ghana operations division. We are also currently structuring an entry into the petroleum products development and refinery build out sector and have made major progress to date with the securing of our upstream services license in our partners company Etrumah. OS Petro has a vision for Ghana’s oil and gas future and we are executing our business plan with precision that is leading us to major success in the sector.

Hydro carbon occurrence at the tano-ivory coast area near Ghana

The Tano-Ivory Coast area is a proven oil province containing two producing fields in the Ivory Coast and one world class producing field in Ghana. Significant or large discoveries have been made in Ghana in the last four years.

The Tano Cape Three Points basin near Ghana is a Cretaceous basin located in the transform margin of West Africa. The basin developed as a result of rifting and drifting of the Atlantic margin where thick Upper Cretaceous-Tertiary section overly a rift section. The drift section is dominated by slope and basin floor fans, channel systems and other stratigraphic traps.

The main source rock is the Turonian – Cenomanian section and the Albian shales. The thick drift section provides enough overburden to mature the source rock and the same time serve as seals for the stratigraphic play types. This is a PROLIFIC deepwater basin that plays host to numerous oil, gas, and condensate discoveries; eg. Jubilee (Mahogany), Tweneboa, Enyenra, Ntomme, Akasa, Paradise, Banda, Sankofa, Gye Nyame and Dzata.

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  • Located in the prolific offshore Tano basin, in close proximity to the Jubilee Field and Sankofa-Gye Nyame Field.
  • Water Depth: Approximately 900 – 1,700 m
  • Adjacent blocks play host to several significant oil, gas and condensate discoveries including the Tweneboa-Enyenra-Ntomme (TEN) – Tullow; Jubilee Field – (Tullow & Co), Mahogany-Teak-Akasa (META) – Kosmos; Paradise (Hess); Dzata (Lukoil/Vanco)
  • Block size: 740 km²
  • 850 km² of High quality 3D seismic data coverage over 75% of block and extends outside to the northern and western part; 2009 vintage
  • Proven Petroleum System
  • Numerous unexplored Cretaceous Play Types
  • Exploration success rate of over 75% in deepwater Tano basin
  • Block resources of over 500 MMBO

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The thick Cretaceous section of the Basin contains abundant reservoir rocks Deltaic shoreline and shallow shelf sedimentary ‘environments which are well-suited to good reservoir development are common throughout the Basin. Albian sandstones are the primary reservoir rocks in the Espoir Field area, the Foxtrot Gas Field area and South Tano area. The Middle Albian sands which are the main reservoir rocks in North Tano are of secondary importance in South Tano.

The potential of Upper Cretaceous sands which are the primary reservoir rocks in the Western Belier Field and Assinie in the Ivory Coast have also been tested in Ghana in the Jubilee, Tweneboa, Paradise, Mahogany and Dzata wells. It is expected that similar sediments exist on the flanks of the Tano Ridge and further down in the West Cape Three Point Block. Here the potential for stratigraphic plays and anomalies have been identified on recent seismic data.
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According to COMMISSIONED reports changes in the depositional environment between early Albian to and Maastrichtian which relate to the tectonic evolution of the basin, have a marked’ impact ,on the total organic content (TOC) of sediments as well as on kerogen type.

Sediments of the Lower Cretaceous were predominantly derived from a terrestrial source prior to the continental separation during the late Albian. The shales within this sedimentary unit tend to be gas prone with only lean to fair organic contents. Oil prone amorphous kerogen (type II) becomes more important in the late Albian and younger sediments. Reflecting the prevalence of marine depositional environments.

Total organic content curves for the wells studied by Phillips, show a characteristic pattern for the most part; TOC increases from less than 1 % in the mid-Albian to above 2 % in the late Albian to reach peaks above 3 % between Cenomanian and Maastrichtian.

Organic rich shales are the predominant source rock in the basin. A closed marine shelf environment with anoxic conditions, cut by channels of clastic sediments, derived mainly from the landmass to the north, persisted until the Maastrichtian when open marine conditions were established throughout the Basin.

In the South Dixcove area, east of the West Cape Three Point Block, it has been observed that the Upper and Lower Cretaceous Shales contained primary and secondary source potential and most of it fell within the mature stage of hydrocarbon generation.

Therefore in the Tano-Ivory Coast Basin, the post late Albian section contains the primary source rock potential for oil, while the pre-late Albian sediments which are more gas prone form the secondary objective for source rock.
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Hydrocarbon accumulations in the Basin are trapped within features including anticlines, truncated tilted fault blocks, turbidites and submarine distributor channel complexes. At Espoir and Foxtrot fields, late Albian sands in tilted fault blocks are trapped by Senonian unconformities which are overlain by shales. The South Tano oil and gas accumulation is trapped below tight Cenomanian limestones in a faulted anticline, while in North Tano, north east dipping Middle Albian and older clastics are eroded by the Middle Albian unconformity. The unconformity was subsequently covered by a transgressive shale unit which caps the structure, trapping the hydrocarbons in the steeply dipping sandstones.

In the Upper Cretaceous, oil, gas, and condensate have been trapped at Jubilee, Tweneboa, Sankofa, Paradise, Teak and Akasa fields within sand­stones inter-bedded with shales in sub-marine distributor channels and turbidite fan complexes of Turonian and Senonian age. These complexes are normally encased in thick shale (regional) sections.
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