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The source kitchen of the Niger Delta oils: case study on Nembe Creek E1.0 and the Kolo Creek E2.0 reservoirs

Abstract

The source kitchen of a petroleum system is that part of the pod of active source rock which is mature and generates the petroleum that charges the reservoir rock. The location of the source kitchen of a petroleum system is vital to the explorationist, its knowledge fosters the prediction of migratory pathways and the migratory losses prior to present times, also estimates potential volume of accumulation. Hither to, mapping of the petroleum basins was based on total organic carbon (TOC), hydrogen index (HI) signatures and maturity history of the source rock and has been used as the basis to suggest locations of petroleum kitchens. In contemporary times, 4D seismic or 3D time lapse geochemistry had been used to suggest location of source kitchen. However, settled is the concept of lateral maturity gradients, implying that within reservoir scales of a kilometer to tens of kilometers, regional petroleum emplacement direction could be deduced from subtle changes in maturity of successive charges of petroleum into the reservoir. In this study, the sterane isomerization ratio (20S/20S + 20R αααC29) was used to determine the maturities of the hydrocarbons from various wells in the Kolo Creek and the Nembe Creek reservoirs. Subtle increases in maturities were observed to be in a NE–SW direction for the Kolo Creek reservoir and in a NW–SE direction for the Nembe Creek reservoir. The direction of increasing maturities relative to the location of the reservoirs could be extrapolated for both reservoirs towards offshore Gulf of Guinea; this is invariably the direction of location of the source kitchen for the Niger Delta oils.

Introduction

Hydrocarbons are generated from source rocks, source rocks are one of the essential elements to a petroleum system. The existence of a petroleum system creates the quest for identification of the existence of a petroleum source kitchen. Every petroleum system has a source kitchen, identification of the location of the source kitchen or the direction of the source kitchen fosters better design considerations for exploration strategies, spudding of exploratory and production wells, development of oil fields and application of enhanced oil recovery techniques for fields with declined production rates.

In a study on the total organic carbon (TOC) of the sediments of the Niger and Benue Rivers and Niger Delta front (Wagner, Personal Communication 2004), it was observed that the river sediments had higher TOC relative to the Delta front; this was attributed to the upwelling process in the delta front (Tyson, Personal Communication 2004). The upwelling process brings the organic matter to shallow depths, where microorganism degrade the organic matter, invariably this results in low productive capacities of the Niger Delta source rocks (Evamy et al. 1978). However, the low productive capacity (fair total organic carbon and low to moderate hydrogen index) is compensated by the thick sequence of sediments comprising the Niger Delta source rocks. The growth fault provides good migration pathway for large volumes of oil and gas produced from the Niger Delta basin (Bustin 1998; Tuttle et al. 1999).

The implication of this observation is that previously TOC has been relied upon as a parameter for classification of sources rocks. Geochemical mapping of TOC contours over petroleum basins has been used to predict the location of hydrocarbon source kitchen; however, the hydrogen index (HI) concept further enhances the source kitchen prediction.

Time lapse geochemistry has been applied for prediction of hydrocarbon source kitchen, based on the fact that changes in oil saturation and hydrocarbon fingerprints overtime may indicate location of hydrocarbon source kitchen and migration direction of expelled hydrocarbon (Milkov et al. 2007).

Geology and structural history

The Niger Delta consists of about 12 km of thick sequence of clastic sediments which is about 75,000 km2 area in the Southern part of Nigeria. These deposits make up the basal Paleocene pro-delta facies which is the Akata formation, this is overlain by the Eocene paralic facies of the Agbada formation and in turn overlain by the Oligocene fluvial facies of the Benin formation (Evamy et al. 1978; Nyantakyi et al. 2013; Oboh 1993). The high sedimentation rates and low subsidence rate results in uncompacted, overpressure shales deposited during the transgressive regime resulting in the Akata formation. The deposition of the regressive Agbada formation resulted in the deposition of high-density sands overlaying the mobile uncompacted shales of Akata formation which fostered the progradation of the delta front seawards resulting in the development of growth faults which has been attributed to gravitational instability (Evamy et al. 1978; Tuttle et al. 1999).

The growth faults gave rise to antithetic and synthetic faults which result in the formation of rollover anticlines, shale ridges and diapers. They are formed as a result of load compaction and differential subsidence due to rapid sedimentation. The growth faults serve as migratory pathways for hydrocarbon emplacement into the structure. The distal part of the delta consists of marine shales which are characteristically overpressurized and hydrocarbons are emplaced from the marine shales into reservoir by episodic charging due to dissipation of overpressure via fracturing, healing of the fractures and refracturing (Tuttle et al. 1999).

The Nembe Creek (Fig. 1) is in the coastal swamp of the Niger Delta in the Oil Mining License (OML) for block 29. The Nembe Creek reservoir (Fig. 1) is in the Middle Miocene deltaic sandstone–shale sequence. The structure is dissected by numerous growth faults steeping upwards. The shallow sandstone reservoirs are faulted such that spill points are generated at remarkable uniform depths resulting in similarity of fluid contact depth. A transgressive shale formation overlay the reservoir, which makes up the caprock (Nelson 1980).

Fig. 1
figure1

Map of Nigeria; inset the Nigeria Delta Map showing locations of studied oil fields (Afam, Kolo Creek and Nembe Creek) in red colored circle. Modified from Amos-Uhegbu et al. 2013 and Akpabio et al. 2013

The Kolo Creek oil field (Fig. 1) is an onshore oil field, the reservoir has been dated to the Middle Miocene using palynomorph assemblage and it has been identified to be deposited in the parasequence of shallow marine and deltaic plain deposits. The field is characterized by numerous predominantly E–W trending growth fault, both reservoirs are off the Middle Miocene and of the Agbada formation (Oboh 1993).

Niger Delta source rocks

The major source rocks in the Niger Delta are the Akata formation and the Agbada formation. However, there are controversies regarding the major contributing source rock generating the Niger Delta oils, hence two schools of thought exist on different and opposing hypothesis that Akata formation is the major source rock and vice versa (Nwachukwu and Chukwra 1986). The two major source rocks are the Agbada and Akata formations, their contributions to hydrocarbon generation have been in question with respect to their structural history (structural evolution over time), and maturity history. An independent study by the US geological survey (Tuttle et al. 1999) indicates that the oil window is just above the Akata formation and that a greater part of the Agbada formation (Upper Agbada formation) is immature, thus will not be able to generate hydrocarbons. This implies that the Akata formation is the major contributing source rock while the Agbada formation is the minor contributing source rock.

The concept of lateral maturity gradients

Source rock matures with continuous burial and subsidence, a producing source rock still undergoes burial which fosters continuous maturation. When hydrocarbon charges from the hydrocarbon kitchen arrive a reservoir, those gain access via a network of pores embedded in the matrix of the rocks or via fractures or faults, usually those bearing the lowest capillary entry pressure. The early arriving petroleum is usually in a series of fronts, depending on the reservoir dynamics, the arriving petroleum will occupy its position within the reservoir, later charges arriving will displace the earlier charges into reservoir (Larter and Aplin 1995). The earlier charges are generated and expelled from a less mature source rock in the kitchen, overtime as generation, expulsion and migration progresses the source rock in the kitchen undergoes subsidence and matures, hence later charges from the source rock into the reservoir are more mature than earlier charges, this results in lateral compositional variation and indeed subtle maturity differences expressed as a maturity gradient across the reservoir. The maturity gradient increases in the direction of the kitchen. Parameters such as GORs, biomarkers (maturity markers), water flow directions (n-alkane concentrations) and compositional step changes are employed for determining directions of source kitchens in basins (Larter and Aplin 1995).

Samples and methods

Sampling

A set of oil samples totaling sixteen (16) were obtained from different oil fields within the Niger Delta basin. Ten (10) samples were obtained from Kolo Creek field, four (4) oil samples were obtained from Nembe Creek field and two (2) oil samples from Afam oil field. All samples were obtained from the wellhead and serve as a true representative of the bulk. Samples were stored in glass vials and preserved in a refrigerator till the samples were required for analysis.

Fractionation of oil samples

Fractionation of the oil samples were consistent with procedures outlined in Abrakasa (2006). Oil samples were fractionated using chromatographic column (50 cm in length, 0.5 cm internal diameter, supplied by BDH, England), which was packed with a stationary phase silica gel 60 size, 0.063–0.2 mm (70–230) mesh, (SiO2) (AnalaR grade supplied by BDH, England) while the mobile phase was Light Petroleum Spirit (30°–40°), (Pet Ether) (AnalaR grade supplied by BDH, England). The oils were blended with activated alumina and introduced into the column, the aliphatics and the aromatics were eluted using 70 ml each of petroleum ether and dichloromethane (AnalaR grade supplied by BDH, England).

GC, GC–MS analysis

The fractions were subjected to GC analysis using HP3890GC serial II, separation was performed on a fused silica capillary column (30 m × 0.25 mm i.d.) coated with 0.25 µm, 5 % phenyl methyl silicone (HP−5) supplied by HP currently known as Agilent UK. Hydrogen gas was used as carrier gas at 2 ml/min with a spilt/splitless injector, the temperature was programmed at 50 °C for 2 min then progressed at 4 °C/min to 300C at which it is held for 20 min.

The GC–MS analysis of the saturated hydrocarbon was performed for the purpose of monitoring some fragment ions of some molecular marker compounds on a Hewlett-Packard 5890 II GC with a split/splitless injector (280 °C) linked to a Hewlett-Packard 5972MSD with electron voltage of 70 eV, filament current of 220µA, source temperature of 160 °C, a multiplier voltage 1600 V and interface temperature 300 °C. The acquisition was controlled by an HP Vectra 48 PC chemstation computer in both full scan mode and selected ion mode (30ions 0.7cps 35 ms dwell) for greater sensitivity. Separation was performed on a fused silica capillary column (30m × 0.25 mm i.d.) coated with 0.25 µm, 5 % phenyl methyl silicone (HP−5), supplied by HP currently known as Agilent, UK. The acquisition was controlled by a HP Compaq computer using Chemstation software, initially in full scan mode (50–600 amu/s) or in selected ion mode (30 ions 0.7 cps 35 ms dwell) The GC was temperature programmed for 40−300 °C at 4 °C per minute and held as final temperature for 20 min. The carrier gas is Helium (flow 1 ml/min., pressure of 50 kPa, slit at 30 ml/min.).

Peak integration was done manually and steranes were used as recommended for maturity assessments (Tissot and Welte 1984; Zumberge 1987). Identification was achieved by matching with chromatogram of standards.

Procedure for PCA analysis

The principal component Analysis was performed as factor analysis using 14 biomarker ratios (variables) obtained from GC–MS analysis of the 16 crudes oil samples from Nembe Creek Oil field, Kolo Creek Oil field and Afam Oil field (Table 2). The first two factors were extracted; the extraction method employed was Principal Component Analysis (PCA). Varimax rotation was applied for maximum variation. The variations explained by the factors were 46.2 % for the first factor and 30.0 % for the second factor. The first two factors explained 76.2 % of the variations and the plot obtained is the score plot (Fig. 5). The objective of performing the PCA plot is to obtain a finer resolution of discriminant analysis which fosters a better understanding of the relationship between within the oil fields and between the oil fields.

Sterane isomerization ratios

The sterane isomerization ratios (20S/(20S + 20R) αααC29 sterane) in Table 1 represent the maturity of the crude oils as represented by Zumberge (1987) and Tissot and Welte (1984) for immature to moderately mature oils. The ratio used is recommended for immature to moderately mature oils, the Niger Delta oils are moderately matured. The sterane isomerization ratios were calculated from the peak area derived from the percent report obtained from the chemstation. The ratios are then converted to the equivalent vitrinite reflectance values using the formula (VR = 0.49(20S/20R) + 0.33) where VR is vitrinite reflectance (Zumberge 1987). The vitrinite reflectance values were posted on the isopach map against the corresponding wells where oil samples were obtained from the well head. The trend of the vitrinite reflectance data indicates the direction of petroleum emplacement into the reservoir, hence the direction of the source kitchen.

Table 1 The sterane isomerization values and corresponding vitrinite reflectance values

Discussion

Geochemical characteristics

The GC fingerprint in Fig. 2 is that of Kolo Creek oil, it shows that the oil has lost some of the lighter hydrocarbon fractions, the m/z = 217 and m/z = 218 are the mass chromatograms for the ααα and αββ cholestane series, the position of the αββ (S&R) doublet helps to locate the ααα peaks in the mass chromatogram. Figure 3 shows the overlay of the mass chromatograms for the m/z = 217, m/z = 218 and m/z = 191 for Nembe Creek sample 12. This overlay shows the relative positions of the peaks based on the number of carbon atoms in the compounds. This technique is used as one of the methods of double checking peak identification from the chemstation print out.

Fig. 2
figure2

A GC fingerprint of Afam Oil, M/Z 217 mass chromatogram and M/Z = 218 mass chromatogram of Afam oil and the nomenclature of their corresponding peaks. The αββ peaks in the m/z 218 exist as a doublet

Fig. 3
figure3

Overlay of the M/Z = 217 mass chromatogram, M/Z = 218 mass chromatogram and M/Z = 191 mass chromatogram showing the position of the αββ doublet of the Cholestane series on the M/Z = 218 mass chromatograms which helps to locate the ααα Cholestane analogs on the M/Z = 217 mass chromatograms

The ternary plot (Fig. 4) shows the clustering of the oils, this observation implies that Kolo Creek and the Nembe Creek oils show similar geochemical characteristics as indicated by the Steranes ternary plot (Fig. 4). Mackenzie (1984) stated that relative amount of C27, C28 and C29 steranes differs with organic matter that constitutes the source rock reflecting different depositional environments. The clustering of the oil infers similar distribution of the Steranes in the oil samples. This may mean that the oils originate from similar organic matter or from the same source (Karlsen et al. 2004; Peters et al. 2005). The position of the cluster of the oils on the ternary plot implies that organic matter that generated the oils was deposited in low marine to estuarine (coastal marine) environment (Mackenzie 1984; Shanmugam 1985), where sea water mixes with drainages from continental supplies.

Fig. 4
figure4

Ternary plot of steranes ratios for Nembe Creek, Kolo Creek and Afam fields

However, the principal component analysis is a statistical technique which fosters a better understanding of the relationships between samples and it is normally employed to reduce numerous data sets (Table 2) to a few sets of variables within which the most relevant information is condensed. The application of principal component analysis in this study discriminated the oils into three different family groups, which reflected their primary oil fields (Fig. 5). This infers that oils have subtle differences which could not be recognized without multivariate analysis (Fig. 5).

Table 2 Ratios used for principal component analysis (PCA) and the full names of the compounds
Fig. 5
figure5

The Principal component Analysis score plot for the Nembe Creek, Kolo Creek and the Afam oils

The maturity data in Table 1 show that the Nembe Creek oils are slightly more mature relative to the Kolo Creek oils; ratios indicate that the source kitchen had just gone beyond the oil window at the time of generation, while the Kolo Creek oils were generated when the source kitchen was just about to enter the oil window. It invariably implies that the Kolo Creek oils were generated and expelled before the Nembe Creek oils were generated.

Petroleum emplacement direction

The petroleum emplacement direction is the direction of the charging petroleum fronts or the direction of migration of petroleum into the reservoirs. The direction is deduced from the lateral maturity gradients across the reservoirs (Figs. 6, 7), the gradient is identified by subtle increase in maturity of the oils from one oil well to another across the reservoir. The increase is always towards the direction of entry of petroleum into the reservoir. Figure 6 is an isopach map of the reservoir area of Kolo Creek Oil field. The maturity values are shown close to the well where the oils were obtained. A maturity gradient is observed, which indicates that the petroleum emplacement direction is in a SW−NE direction across the reservoir. The maturity values (expressed as percentages of sterane isomerization ratios (20S/(20S + 20R) αααC29 Sterane) gradually decrease from 44.76 at well 29 in the Southwestern part of the field to 36.01 at well 19 in the Northeastern part of the field. The gradient shows a gradual but significant change. Figure 7 is the isopach map of reservoir of Nembe Creek Oil field, the isomerization ratios for maturity decreases from 47.0 to 40.0. This observation implies that the petroleum emplacement direction is the SE−NW direction across the reservoir. Both Kolo Creek reservoir (Fig. 6) and the Nembe Creek reservoir (Fig. 7) show that the charging directions are from the Southern part of the oil fields.

Fig. 6
figure6

Isopach map of Kolo Creek E2.0 reservoir showing the sterane maturity values indicating the direction of petroleum emplacement into the reservoir in a SW–NE trend (Modified from Oboh 1993)

Fig. 7
figure7

The Isopach map of the Nembe Creek E1.0 reservoir showing the sterane maturity values indicating the direction of emplacement of petroleum into the reservoir in the SE–NW trend (Modified from Nelson 1980)

The Nembe Creek and the Kolo Creek reservoirs were both deposited in the Middle Miocene, in Niger Delta basin, the source rocks which are the Akata and Agbada formations were deposited in the Paleocene and Eocene, respectively (Evamy et al. 1978; Nyantakyi et al. 2013; Oboh 1993) before deposition of the Niger Delta reservoirs. Nonetheless, the record of event (Haack et al. 2000) indicates that the reservoirs were in place before migration began. The maturity history as reflected by the vitrinite reflectance data (Tuttle et al. 1999) indicates that part of the Lower Agbada is above the oil window while the Upper Akata formation is within the oil window.

The structural history of the Niger Delta indicates continued progradation delta seaward corresponding to creation of growth fault due to gravity sliding (Evamy et al. 1978); this is the main depositional mechanism in the Niger Delta. The overburden pressure of high-density Eocene and Miocene sand on the uncompacted, unlithified mobile shale results in the progradation, hence occurrence of source rock in distal marine setting of the Niger Delta. This is suggested to be the source of the petroleum charging the Kolo Creek and Nembe Creek reservoirs. The Nembe Creek reservoir is situated much more seaward than the Kolo Creek reservoir and the Nembe Creek reservoir bears more mature petroleum, the lateral maturity concept holds that the more mature petroleum which are the later charging fronts are always closer to the petroleum source kitchen (Larter and Aplin 1995). It can be suggested that the source kitchen of the Niger Delta petroleum is in the distal delta front, which consists the prodelta Akata marine shales.

Conclusion

A suite of oils from the Kolo Creek E2.0 and Nembe Creek E1.0 reservoirs was analyzed for their maturity status. The maturity values expressed as percentage sterane isomerization values were posted on the Isopach map of the respective reservoirs. Maturity gradients were observed across the reservoirs, petroleum emplacement direction was inferred from the gradient and it was observed to be a SW–NE trend for the Kolo Creek reservoir and a SE–NW trend for the Nembe Creek reservoir. Obviously both trends are from the Southern part of the reservoir to the Northern part. Considering the petroleum system event chart for the critical moment in respect of the Niger Delta Petroleum system, the source kitchen has been inferred to be in the distal delta front which is mainly the Akata marine shales.

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Acknowledgments

The authors are grateful to Prof. L. C. Amajor of the Department of Geology, University of Port Harcourt, Nigeria for his contributions, also congratulate him on his peaceful retirement from the University services. We also thank the Petroleum technology development fund for sponsorship.

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Correspondence to Mudiaga Onojake.

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Abrakasa, S., Ukaegbu, V. & Onojake, M. The source kitchen of the Niger Delta oils: case study on Nembe Creek E1.0 and the Kolo Creek E2.0 reservoirs. J Petrol Explor Prod Technol 6, 331–341 (2016). https://doi.org/10.1007/s13202-015-0211-9

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Keywords

  • Hydrogen index
  • Maturity gradients
  • Source kitchens
  • Time lapse geochemistry
  • Total organic carbon