Stalwart OIl’s focus on the West Cape Three Points South section of the Tano Basin has sparked a lot of interesting partnerships that are 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 partner’s company JS Neoplant. Stalwart Oil has a vision for Ghana’s oil and gas future and we are executing our business plan with a precision that is leading us to major success in the sector.
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 the thick Upper Cretaceous-Tertiary section is overly a rift section. The drift section is dominated by slope and basin floor fans, channel systems, and other stratigraphic traps.
The main source of rock is the Turonian – Cenomanian section and the Albian shales. The thick drift section provides enough overburden to mature the source rock and at 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.
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 the 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.
According to COMMISSIONED reports changes in the depositional environment between early Albian 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 of 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.
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.
We pride ourselves with our historical growth as a company and our determination to build an Oil and Gas company within South Saharan Africa that has the desires of the indigenous people within the countries we operate within at heart. We are the company that focuses on the interest of the people within the countries whose natural resources we explore and develop. We build to serve the communities we benefit financially from during a successful development lifecycle.
We are working with a seismic and petro physical analysis development company that has positioned our methods and technical strategies in a direction that is focused on total identification of potential petroleum systems using modern tools that have less impact on aquatic life forms that reside in the areas and zones that we are currently exploring for potential reserves.