Precambrian basement reservoirs: Case study from the northern Bongor Basin, the Republic of Chad

Dou, Lirong; Wang, Jingchun; Wang, Renchong; Wei, Xiaodong; Shrivastava, Chandramani

doi:10.1306/02061817090

Cited by 29 publications

(14 citation statements)

References 24 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…Similar Early Cretaceous depositional environments have been interpreted in the Benue Trough (Babangida et al, 2015;Sarki Yandoka et al, 2017); in the Doba, Bongor, Termit and Muglad Basins (locations in Fig. 1; Dou et al, 2018aDou et al, , 2020Liu et al, 2015); in the Kribi/Campo, Douala and Rio-Del-Rey Basins of southern coastal Cameroon (Ntamak-Nida et al, 2008;Agyingi et al, 2019); in the North Gabon margin (N'Komi Basin: Mbina et al, 2009); and in the northern part of the Sergipe -Alagoas Basin along the conjugate margin of Brazil (Mello and Katz, 2000). The results therefore suggest that organic matter accumulated during the Neocomian -Barremian in the Mayo Oulo-Léré Basin in a lacustrine environment with variable depositional conditions.…”

Section: Source Of Organic Mattersupporting

confidence: 73%

“…The Logone Birni, Mayo Oulo-Léré and other basins in North Cameroon belong to the same rift system as the oil-producing Bongor, Doba and Doseo Basins in neighbouring Chad (Fig. 1), where Neocomian -Barremian lacustrine shales have been identified as source rocks (Genik, 1992;Dou et al, 2018a;. The present study therefore highlights the need for further and detailed studies of the exploration potential of the Mayo Oulo-Léré Basin and other basins in north Cameroon.…”

Section: Petroleum Generation Potential and Comparison With Nearby Ba...supporting

confidence: 52%

“…Lower Cretaceous lacustrine shales in WCARS basins have also been studied by Liu et al (2015), Dou et al (2018a) and Sarki Yandoka et al (2015. Dou et al (2018aDou et al ( , 2020 studied Neocomian -Barremian source rocks in the Bongor Basin, Chad, and demonstrated the presence of immature to early mature Types I to II kerogen in the Cailcedra, Mimosa and Kubla I Formations with TOC contents ranging from 0.5 to 18.6 wt.%, highlighting the significant potential for petroleum generation. In the Upper Benue Trough, there is no evidence to show that wells have penetrated the Neocomian -Barremian succession.…”

Section: Petroleum Generation Potential and Comparison With Nearby Ba...mentioning

confidence: 93%

“…1) which developed during the break-up of Gondwana (Fairhead, 1986;Benkhelil, 1988;Genik, 1992Genik, , 1993. Commercial hydrocarbon accumulations have been discovered in WCARS basins in Chad (Doba, Doseo and Bongor Basins), and Niger (Termit Basin) (Genik, 1993;Alalade and Tyson, 2010;Dou et al, 2018aDou et al, , 2020, where Barremian to Aptian lacustrine shales are proven source rocks (e.g. Mohammed et al, 1999;Obaje et al, 2004;Abubakar, 2014).…”

Section: Introductionmentioning

confidence: 99%

See 3 more Smart Citations

Neocomian – Barremian Lacustrine Shales in the Mayo Oulo‐lere Basin, North Cameroon: Depositional Environment and Petroleum Potential

Chavom

Baudin

Nzouedjio

et al. 2022

Journal of Petroleum Geology

View full text Add to dashboard Cite

The synrift Mayo Oulo‐Léré Basin in Northern Cameroon is located in the transition zone between the West and Central African Rift Systems. Structural and stratigraphic elements of the basin resemble those of the Yola Basin in NE Nigeria, an extension of the Upper Benue Trough. The Lower Cretaceous lacustrine shales with source rock potential which occur in nearby rift basins are also present in the Mayo Oulo‐Léré Basin. These shales were investigated at two outcrop locations (Badesi and Tchontchi), and samples collected (n = 60) were subjected to palynofacies and bulk geochemical analyses to evaluate their petroleum generation potential and to interpret their depositional environment. At the studied locations, shales were divided into two lithofacies: grey to black laminated shales containing algal‐bacterial OM together with common woody (phytoclast) debris (“facies Fml”); and cm‐bedded shales which had a higher content of algal‐bacterial OM but a lower phytoclast content (“facies Fmlc”).Palynological and bulk geochemical data indicate that the shales contain well‐preserved organic matter (OM) and locally display good to excellent oil generation potential. Average TOC contents are 2.7% and 1.4% for samples of the Fmlc and Fml facies shales respectively. HI values (94‐889 mg HC/g TOC and 131‐638 mg HC/g TOC respectively) suggest that the shales contain Types I to III kerogen. Organic material in the Fmlc facies shales is dominated by amorphous organic matter (AOM: 90% on average) with a low phytoclast content (6% on average); whereas samples of the Fml facies shales contain less AOM (74% on average) and have a higher phytoclast content (23% on average). AOM in the Fmlc shales is highly fluorescent; these shales are interpreted to have been deposited in dysoxic to anoxic conditions. The AOM in the Fml shales is weakly fluorescent and the shales were deposited under more oxic conditions. The kerogen in the shales ranges from immature to early oil window mature. Average values of the pyrolysis S2 yield are 15.5 mg HC/g of rock and 7 mg HC/g of rock for samples from Fmlc and Fml facies shales respectively. The shales increase in thickness northwards towards the Logone Birni Basin where they may have reached the oil window, as in neighbouring basins. The results of this study of lacustrine shales from the Mayo Oulo‐Léré Basin suggests that there may be potential for oil exploration in northern Cameroon.

show abstract

Section: Source Of Organic Mattersupporting

confidence: 73%

Section: Petroleum Generation Potential and Comparison With Nearby Ba...supporting

confidence: 52%

Section: Petroleum Generation Potential and Comparison With Nearby Ba...mentioning

confidence: 93%

Section: Introductionmentioning

confidence: 99%

See 2 more Smart Citations

Neocomian – Barremian Lacustrine Shales in the Mayo Oulo‐lere Basin, North Cameroon: Depositional Environment and Petroleum Potential

Chavom

Baudin

Nzouedjio

et al. 2022

Journal of Petroleum Geology

View full text Add to dashboard Cite

show abstract

“…Ronier 3-D areas are situated in the north slope of Bongor Basin, takes the major fault of the basin margin as the north boundary, connects Kubla structure in the east, faces Naramay structure on the west and borders on the south of the dominant sag (1-2). The 3D area for the studied block is 503 km 2 (Dou et al 2018). The current research is based on the following formation structures: KublaI 1, KublaI 2, Mimosa I and Mimosa II.…”

Section: Introductionmentioning

confidence: 99%

Geological modeling and upscaling of the Ronier 4 block in Bongor basin, Chad

Zene

Hasan

Jiang

et al. 2019

J Petrol Explor Prod Technol

View full text Add to dashboard Cite

The study focuses on building a 3D-dimensional model for using well log data of 3 wells to enable a better understanding of the reservoir characteristics and evaluation of the hydrocarbon potential in the field of Ronier in the Bongor Basin, Chad. These data are used to build a Lithofacies model, property model, the permeability model and the saturation model which are the parameters that describe the reservoir. Indeed, the accuracy to quantify the geological reserve of Ronier 4 reservoir block depends on the estimation of these values. The result of geological modeling and upscaling of the Ronier 4 block of Ronier oilfield is presented systematically. In this work, a Sequential Gaussian Simulation (SGS) algorithm under the phase control based on the collocated co-Kriging is adopted and the models of porosity, permeability and saturation are established. Lithofacies model has sand (0) content of 66.69% mostly the first layer, while the code (2) shale content 12.15% mostly concentrated in the center, north and south. Finally, the code (3) sand content is 21.16%. The NTG distribution is highly concentrated in the north, center and south (1) and 0.7 on average, while the lowest range is 0.1. The study shows a good permeability range between 460 to 1200 and 500 mD on average. The porosity distribution mainly distributed between 17 to 27 and 19% on average. These indicate that it has good reservoir properties. The 3D developed geological model provides the basis for calculating the Oil Initially in Place (OIIP) volumes of hydrocarbons.

show abstract

Formation mechanism and evolution model of buried hill reservoir in BZ19‐6 structural belt, Bozhong Sag, Bohai Bay, East China

Shi,

Xie,

et al. 2023

Geological Journal

View full text Add to dashboard Cite

The BZ19‐6 structural belt is the largest buried hill oil‐gas‐bearing area recently discovered in Bohai Bay Basin. The formation and evolution of the buried hill reservoirs are complex. Presently, the development law and controlling factors of this reservoir is unclear. Based on 3D seismic, drilling data, thin section, and regional tectonic background, we explored the controlling factors and development law of the high‐quality buried hill reservoir. The results show that the buried hill reservoir can be vertically divided into a weathered glutenite zone, weathered fracture zone, internal fracture zone, and tight zone. The development of reservoir is mainly controlled by lithotypes, tectonic movement, and weathering. The rocks in the study area with low compressive strength, provided the material basis for the formation of fractures. The strongly reformed multi‐stage tectonic movements provides the external dynamics for the formation of fractures. Weathering further improved the physical properties of the reservoir. The buried hill reservoir is mainly distributed in the weathered fracture zone and internal fracture zone. Currently, natural gas mainly found in nearly E‐W‐trending and N‐S‐trending fractures. The nearly E‐W‐trending fractures are developed in the thrust nappe structure formed by N‐S‐trending extrusion in the Indosinian. The hinge zone of the structure is the main development area of fractures. The nearly N‐S‐trending fractures are associated with strike‐slip faults formed by sinistral strike‐slip stress in the Yanshanian. Under the background of NNE–SSW direction extensional stress during the Himalayan, early fractures were reactivated, opened and expanded, forming the reservoir space for later natural gas charging.

show abstract

Precambrian basement reservoirs: Case study from the northern Bongor Basin, the Republic of Chad

Cited by 29 publications

References 24 publications

Neocomian – Barremian Lacustrine Shales in the Mayo Oulo‐lere Basin, North Cameroon: Depositional Environment and Petroleum Potential

Neocomian – Barremian Lacustrine Shales in the Mayo Oulo‐lere Basin, North Cameroon: Depositional Environment and Petroleum Potential

Geological modeling and upscaling of the Ronier 4 block in Bongor basin, Chad

Formation mechanism and evolution model of buried hill reservoir in BZ19‐6 structural belt, Bozhong Sag, Bohai Bay, East China

Contact Info

Product

Resources

About