GEOCHEMICAL CHARACTERISATION OF AGBADA FORMATION IN WELL X, OFFSHORE, NIGER DELTA, NIGERIA
|
|
- Elmer Gray
- 6 years ago
- Views:
Transcription
1 GEOCHEMICAL CHARACTERISATION OF AGBADA FORMATION IN WELL X, OFFSHORE, NIGER DELTA, NIGERIA N. Asadu 1, F. A Lucas 2 and K. A. Ibe 3 1 Department of Earth Sciences, Federal University of Petroleum Resources, Effurun, 2 Department of Geology University of Benin, Benin city, Nigeria. 3 Department of Chemistry Federal University of Petroleum Resources Effurun, Nigeria. ABSTRACT Niger delta is one of the giant petroliferous provinces of the world. Following Shell-BP s 1956 commercial discovery of oil in Oloibiri, Bayelsa State, exploration and production efforts have been intensified in Niger delta and other sedimentary basins in Nigeria. Although much work have been done on the source rock of the Niger delta petroleum system, the controversy as to whether the oil in Agbada reservoirs is produced within the formation or migrated from the over pressured Akata shales still remain unresolved. Organic geochemical analysis of the shales in one ExxonMobil hydrocarbon exploratory well X was carried out in order to evaluate the source rock potentials, kerogen type and maturity status of the sediments. The source rock evaluation revealed that soluble organic matter (SOM) ranges from1940 ppm to 4220 ppm with an adequate mean value of 2758 ppm. TOC ranges from (1.38 to 12.06) wt %; HI ranges from ( ) HC/gCorg; Tmax value ranges from ( ) 0 C; VR0 ranges from and PI values ranging from ( ) with the mean transformation ratio (TR) of 0.28 wt%. These show that organic matter quantity is fair to excellent and in high concentration with excellent hydrocarbon generation potentials and made of type II and type III kerogen. Vitrinite reflectance and TMAX values also showed that the source rocks in well X are predominantly matured at intervals therefore; Agbada Formation sourced the hydrocarbon in the study area. The oil window recognized at 8100ft, where the source rock profile exhibited the highest values of (TOC) 12.06%, genetic potential (55.47), S2/S3 (10.54), (TMAX) 431( 0 C) and (VRO) 0.6%, therefore, conclude that Agbada Formation sourced the hydrocarbon in the study area. 247
2 INTRODUCTION Geochemical screening analyses are practical exploration tools for rapid and inexpensive evaluation of rock samples. Rock-Eval pyrolysis and TOC measurements are the most effective and inexpensive screening methods for large numbers of rock samples from wells and outcrops. There have been many discussions about the source rock for petroleum in the Niger delta, a few of these previous works have been reviewed as follows: Based on organic-matter content and type, Evamy et al., 1978, proposed that both the marine shales (Akata Formation) and the shale interbedded with paralic sandstone (lower Agbada Formation) were the source rocks for the Niger Delta oils. Ekweozor et al., 1979, used αβ hopanes and oleananes to fingerprint crude with respect to their source and proposed that the shales of the paralic Agbada Formation sourced the oil on the eastern side of the delta while the Akata and marine-paralic (Agbada formation) sourced on the western side of the delta. Ekweozor and Okoye, 1980, further constrained this hypothesis using geochemical maturity indicators, including vitrinite reflectance data, and showed that rocks younger than the deeply buried lower parts of the paralic sequence are immature. Lambert-Aikhionbare and Ibe, 1984, argued that the migration efficiency from the over-pressured Akata shale would be less than 12%, indicating that little fluid would have been released from the formation. They derived a different thermal maturity profile, showing that the shales within the Agbada Formation are mature enough to generate hydrocarbons. Ejedawe et al., 1984 used maturation models to conclude that in the central part of the delta, the Agbada shales source the oil while the Akata shales source the gas. In other parts of the delta, they believe that both shales source the oil. Doust and Omatsola, 1990, conclude that the source organic matter is in the deltaic offlap sequences and in the sediments of the lower coastal plain. Their hypothesis implies that both the Agbada and Akata Formations likely have disseminated source rock levels, but the bulk will be in the Agbada Formation. In deep water, they favor delta slope and deep turbidite fans of the Akata Formation as source rocks. (a) Aim and objectives: To use geochemical proxies to evaluate the organic matter quantity, quality, hydrocarbon generation potentials and maturity status of the sediments. (b) Location of The Study Area This study was carried out on ditch cutting rock samples from an EXXONMOBIL exploration well X, located in offshore Niger delta. Geology of the Study Area: The stratigraphy of the Niger Delta is intimately related to its structure. The development of each being dependent on interplay between sediment supply and subsidence rate. Short and Stauble (1967) recognized three subsurface stratigraphic units in the modern Niger Delta. The delta sequence is mainly a sequence of marine clays overlain by parallic sediments which were finally capped by continental sands.the 248
3 stratigraphy of Niger Delta Basin are as follows: (a) Benin Formation: The formation comprising over 90% sandstone with shale intercalations extends from the west across the entire Niger Delta area and southward beyond the present coast line. The thickness though variable is estimated at about 6000fts. It is coarse grained, gravelly, poorly sorted, sub-angular to well rounded and bears lignite streaks and wood fragment. The formation is characterized by structural units such as channel fills, point bars etc which indicate variability of the shallow water depositional medium. The Benin formation with very little hydrocarbon accumulation ranges in age from Oligocene to Recent. (b) Agbada Formation: The formation is a sequence of sandstones and shales with sandstone dorminant in the upper unit and thick shales in the lower unit. It is very rich in microfauna at the base decreasing upwards suggesting an increase in the rate of deposition at the delta front. The grains are coarse and poorly sorted indicating a fluvatile origin. The Agbada Formation covers the entire subsurface of the delta and may be continuous with the Ogwashi-Asaba and Ameki formations of Eocene- Oligocene age. It is over 10,000ft thick and are the major hydrocarbon bearing unit in the delta. (c) Akata Formation: The formation underlies the entire delta and forms the lower most unit. It is a uniform shale development consisting of dark grey sandy, silty shale with plant remains at the top. The Akata formation is typically overpressured and believed to have formed during lowstands when terrestrial organic matter and clays were transported to deep water areas characterized by low energy conditions and oxygen deficiency (Statcher 1995). It is over 4000ft thick and ranges in age from Eocene to Recent and is believed to have been deposited in front of the advancing delta. METHOD OF STUDY Organic Geochemical analysis involved the determination of total organic carbon (TOC), soluble organic matter concentration (SOM) and Rock-Eval pyrolysis of fifty six (56) representative shale samples from the well. Vitrinite reflectance values were also calculated from Jarvie et al 2001 relation and used for thermal maturity assessment. (A) Total Organic Carbon (TOC): Determination Procedure (using Fugro Robertson Method) STEP 1: pulverization, Labelling and weighing of samples: samples were duly pulverized, clean Sample Bottles were duly labelled with the sample intervals and samples were weighed out in the range ( ) into the bottles. Step 2: Acidification: Weighed samples were taken to the heating chamber for acidification (to remove inorganic carbon). A few drops of hydrofluoric acid was added to the sample shaken and vigorously heated to dryness in the heating chamber (heating for an average of 5-10 minutes). 249
4 Step 3: the acidification process was repeated. Step 4: the sample bottle were half filled with distilled water. Step 5: The residue was turned into a filter paper clamped on a filter flask while the filtrate was turned into a beaker and allowed to dry in the oven for two hours. Step 6: The residues was transferred to the crucible. Step 7: The crucible was transferred to the TOC determinator and the sample weight was entered into the computer attached to the determinator and the determined carbon values was read on the computer. (B) Determination of soluble organic matter (SOM): The extraction of the soluble organic matter was done with dichloromethane in a standard soxhlet extractor and refluxed overnight. The bitumen were filtered and weighed in a glass vial. The weighed extract was measured in parts per million (ppm) and in weight percent. Extraction was done on the selected representative samples after the TOC measurements. (C) Rock-Eval pyrolysis: Is the thermal distillation of free organic compounds (mostly bitumen in source rocks, oil in reservoir rocks) from the rock matrix followed by cracking of the insoluble organic matter, kerogen. The samples were heated in an inert atmosphere (using Helium gas) to C in a special programmed temperature. The pulverized samples were heated to a temperature of C for 3 min to generate the first peak (S1) which represents free and adsorptive hydrocarbon present in the sample. This was followed by programmed pyrolysis to C at 25 0 C/Min. The second peak (S2) represents the hydrocarbon generated by the thermal cracking of the kerogen. At the same time, the CO2 produced during the temperature interval was recorded as the S3 peak. Other parameters obtained from the instrument include Tmax that is temperature corresponding to the maximum S2 peak, Hydrogen Index (HI) and Production Index (PI).These organic geochemical All the analyses were carried out at the Fugro Robertson Petroleum Geochemistry Laboratory Llandudno, North Wales United Kingdom and therefore ran against their laboratory sample standards. RESULTS AND DISCUSSIONS The results of the rock- eval pyrolysis, total organic carbon (TOC) and other calculated parameters are shown in (Tables 1). The plots of the variations of the rock- eval pyrolysis data and interpretive parameters were also determined. On the basis of the variations in the lithologic characteristics and geochemical parameters within the rock succession, the studied section of well A ( ft) was divided 250
5 into three units that are stratigraphically well. Unit 1(Agbada Formation): This unit range in depth from to 5700ft of well X, with average TOC of 3.59 wt %, S2 is mg HC/g rock, and S1 is 1.41 mg HC/g rock. The production index (PI) is 0.13, the hydrogen index (HI) is 364 mg HC/g TOC and oxygen index (OI) averages 109mg HC/g TOC (Table 2), the soluble organic matter content (SOM) is high with values ranging from 1940 to 4220 ppm with a mean value of 2758 ppm (Table 2). This unit is dated Oligocene to upper Miocene in age and represent Agbada Formation in this well. Unit 2 (Benin Formation): The uppermost unit is sandy and range in the depth between 5700 to the top of well X. This unit represents the Benin formation of upper Miocene to Pliocene age. The average TOC is 0.36 wt %, S2 is 0.49mg HC/g rock, and S1 is 0.75 mg HC/g rock. The production index (PI) is 0.57, and the hydrogen index (HI) is 97 mg HC/g TOC with oxygen index (OI) averaging 562mg HC/g TOC (Tables 1).. 251
6 OLIGOCENEE MIOCENE AGBADA FORMATION BENIN FORMATION PLIOCENEEE SAMPLE DEPTH N. Asadu et al., IJSIT, 2015, 4(3), ROCK EVAL PYROLYSIS DATA INTERPRETIVE RATIOS S1 S2 S3 TMA X TOC PI HI OI S1+S2 S2/S3 %VRo OIL/GAS NIL NIL GAS GAS NIL NIL GAS GAS OIL&GAS OIL&GAS OIL&GAS GAS NIL GAS NIL NIL OIL&GAS GAS OIL&GAS GAS NIL GAS GAS
7 Table1: Variation of Rock Eval and calculated geochemical Parameters in Well X. S1 : content of free organic compounds (less than approximately C33), in mg HC/g rock S2 : amount of hydrocarbons (HC) generated by pyrolysis (plus some bitumen), in mg HC/g rock S3 : the organic carbon dioxide released to C, in mg CO2/g rock Tmax : the temperature of maximum S2 yield in 0 C TOC : the total organic carbon in weight % HI : the hydrogen index, S2/TOC: an indicator of kerogen type, in mg HC/g Corg OI : the oxygen index, S3/TOC : an indicator of kerogen type, in mg CO2/g Corg. PI: the production index, S1/S1 + S2 is an indicator of thermal maturity in a source rock. S2/S3: used in the characterization of kerogen as surrogate for ratio of H/O. S1+S2: represents the rocks total hydrocarbon generation potential VR O: Vitrinite Reflectance. (i) ORGANIC RICHNESS: Petroleum is a generative product of organic matter disseminated in sediments and therefore the quantity of hydrocarbon generated directly correlates with organic matter concentration of the potential source rocks (Tissot and Welte, 1984). The organic richness of rocks is customarily expressed in terms of the percentage by weight of organic carbon. The minimum concentration of organic carbon sufficient enough to saturate the pore network for adequate level of expulsion efficiency from a potential source rock is 1.0% TOC, although a threshold as low as 0.5% TOC are however considered possible in gas prone systems which are largely driven by diffusion at an adequate level of concentration gradient (Rice and Claypool, 1981). 253
8 F0RMA DEPT S1 S3 TM TOC PI HI OI S1+S S2/S Cal TION H(FT) S2 AX 2 3 %V Ro (400 - (0.38 (0.42 (2.05 (41 (0.46 (0.4 (72 - (44 (0.8 - (0.11 ( ) ) ) ) 0.56) 3.94) ) ) 0.42 BENIN ) ) 9) ) AGBAD A ( ) (0.59 (5.23 (1.64 (42 ( ) ).66) 440 ) ) (0.0 (226 - (40 ( ) ) 33 9) ) (1.25 ( ) 0.74 ) Table 2: Summary of Rock- Eval Pyrolysis data and Interpretive Ratios for well A In unit 1(Agbada formation): The TOC of the shale samples is fairly high with values ranging from 1.38 to as high as12.06 wt% with an average of 3.59 wt. % (Table 2). This value exceeds the threshold of 1% TOC with moderately high organic matter concentration (Table, 3). Also Plots of S2 versus TOC show that organic matter quantity of these source rocks is good to excellent (Figures 1) and in adequate concentration for petroleum generation. The abundance and type of organic matter in Niger Delta vary with age, depositional environment and environmental depth (Nwajide, 2013). This high TOC values may be attributed to the depositional environment. Non- marine swamp, marsh and floodplain deposits records high TOC and HI values due to their proximity to the source of organic matter. 254
9 FORMATIO SAMPLE WEIGHT S.O.M S.O.M TOC (wt. S.O.M/ N INTERVAL OF (ppm) (wt %) %) TOC (wt. (Feet) SAMPLE (gm) %) Upper Agbada Lower Agbada Table 3: Soluble Organic matter concentration (SOM) Figure 1: Plot of TOC (Wt%) Vs S2 (Mghc/Grock) showing the Organic Matter Quantity in well X. Unit 3 (Benin formation): The representative shales has the lowest TOC ranging from 0.46 to 0.58wt.%, 255
10 with an average of 0.52wt. %., low hydrogen index (HI) with consistent high productivity index (PI). These values fall below the threshold of 1% wt.toc required for oil generation and are therefore not considered as source rock. (ii) HYDROCARBON GENERATION POTENTIALS (S1+S2): Organic carbon content (TOC) is insufficient to establish the presence of potential and or effective petroleum source rocks in view of the constraints that different organic matter types have different hydrocarbon yields for the same organic carbon content, a more direct measure of source rock capability to generate hydrocarbons is required for detailed assessment (Katz (2006) and Akande et al (2011). Rock-Eval pyrolysis data set derived from the programmed heating of samples in inert atmosphere and its interpretive ratios undoubtedly provide direct estimation of the hydrocarbons that evolved freely; considered as S1; the generatable hydrocarbons directly from kerogen cracking known as S2. (S1 + S2) referred to as the total hydrocarbon generation potential of source rocks (Dymann et al 1996). It is defined as the maximum quantity of hydrocarbons that a sufficiently matured source rock might generate. The source rocks with hydrocarbon generation potential(s1 + S2) less than 2mg HC /g rock yields little or no oil with some potential for gas; S1 + S2 from 2 to 6 mg HC /g rock indicates moderate or fair source rock potential while above 6 mg HC / g rock suggests good to excellent source rock potential. The threshold of S1 + S2 greater than 2.5 mg HC /g rock can be considered as a prerequisite for classification as a possible oil source rock (Bissada, 1982) and provide the minimum oil content necessary near the top of the main stage of hydrocarbon generation to saturate the pore network and permit expulsion. The source potential (S1+S2) of the Agbada formation range from 6.61 to an elevated peak value of 55.47mg HC /g rock with 40% of the samples in excess of the mean value of mg HC /g rock. This is consistent with the high organic richness recorded at this interval as expressed in positive correlation between TOC and S2. The soluble organic matter (SOM) increased with depth of burial and ranged from 1940 to 4220 ppm with an adequate mean value of 2758 ppm (Table 2). Peters and Cassa (1994) showed that source rocks with SOM in the range of 0-500ppm has poor potential for petroleum generation potential, those between ppm is fair, ppm is good, ppm is very good while those with values above 4000ppm has excellent petroleum generation potential. These show that the Agbada Formation in this well has an excellent potential for generation of oil and gas with adequate organic matter concentration. (iii) TYPING OF KEROGEN: Rock-Eval pyrolysis data and their derivatives are could serve as important criteria for characterization of organic matter in sediments. Hydrogen index (HI) which is the ratio of S2/TOC is an indicator of kerogen type (Tissot et al, 1974). Type 1 organic matter is hydrogen rich with HI greater than 600 mg HC /g TOC and this is considered to be predominantly oil prone. Type II organic matter is characterized by HI between 350 and 600 mg HC/gTOC and this could generate both oil and gas at the appropriate level of maturity. 256
11 Figure 2: Plot of TOC (Wt %) Vs S2 (MgHC/Grock) showing the kerogen typing in Well X Figure 3: Plot of oxygen index (OI) versus hydrogen index (HI) on Van Krevelyn diagram showing the kerogen typing in well X Type III organic matter is characterized by low to moderate HI of between 75 and 200mg HC/g TOC 257
12 and could generate gas at the appropriate level of thermal maturity. Type IV organic matter normally exhibit very low HI less than 50mg HC/g TOC; produced under very oxic environment and are generally inert (Tissot and Welt, 1984). However, Peters 1986 suggested that at a thermal maturity of vitrinite reflectance value of 0.6% (Tmax C) rocks with HI above 300mg HC/g TOC will produce oil; those with HI between 300 and 150 will produce oil and gas; while those with HI between 150 and 50 will produce gas and those with HI less than 50 are inert. The HI of the source rocks vary over a wide range. HI varies from HC/g TOC with a mean value of 370HC/g TOC indicating different kerogen types associated with these sediments. Cross plots of TOC versus S2 (Figure 6) define a predominance of type II and type III organic matter. Type II kerogen is derived primarily from the remains of bacterially reworked plankton in an anoxic environment found in moderately deep marine setting. It is oil prone but can generate gas depending on its thermal evolution. Type III kerogen is derived primarily from terrigenous plant debris deposited in shallow to deep marine setting and tend to generate dry gas. The surface plots and contour maps of TOC (wt. %) versus S2 (mg HC/g rock) versus HI (HC/g TOC), also reveal the stratigraphic distribution of kerogen type II and III in the well. Plots of oxygen index (OI) versus HI on Van Krevelyn diagram shows that most of the samples plot in the field of combined type II and III with few samples plotting in the fields of either type II or III (Figure 3). The ratio S2/S3 is also a measure of kerogen quality. S2/S3<5 has the potential to generate gas at maturity, S2/S3 (5-10) is oil and gas prone, while S2/S3>10 is gas prone. This criterion was used to determine the nature of petroleum product generated at maturity (Tables 1). (iv) MATURITY OF KEROGEN: Rock eval data is also employed in initial maturity assessment of source rocks. (TMAX, PI, and calculated VR O from Jarvie et al 2001 relation (%VR0=0.018 X TMAX ) was particularly used for this purpose.tmax value <430 C, Production Index <0.1 and Vitrinite reflectance (VRO) value<0.6%, suggests that the source rock is immature and no hydrocarbon generation has occurred. TMAX value, 430 to 465 C, Production Indices >0.1 and VRO >0.6 to 1.35% suggests a source rock that has generated hydrocarbons at some time or generating at present. TMAX values >465 C and Production Indices > suggests the source rock is post mature, and estimating the original petroleum potential is difficult (Peters and Cassa, 1994). On these premises, the source rocks in the well have attained a moderate level of maturation with TMAX values varying from 426 to 440 C and VRO varying from 0.51 to 0.76% with 70% of the samples in excess of the mean values of 432 C and 0.62% respectively in Agbada formation. The average productive index is also
13 Figure 4: Plot of Tmax ( 0 c) Versus Productive Index (PI) showing the thermal maturity of kerogen and the type of product generated in Well X. Two samples in upper Agbada formation were observed to have anomalous high PI and low TMAX (0.2 and 0.3) in sample 6540 ft and 9240 ft respectively.these intervals correspond with the zones impregnated by migrated oil (Peters, 1986 and Peters and Cassa, 1994). Plot of TMAX 0 C Versus Hydrogen index (HI) shows that 70% of the source rocks studied are mature (Figure 3). It is very striking to note that at depth 8100ft, the source rock profile exhibited the highest values of total organic carbon (TOC) 12.06% and genetic potential (55.47) and S2/S3 (10.54), (TMAX) C and (VRO) 0.6%, therefore pegging the oil window around this interval. Plot of Tmax ( 0 c) Versus Productive Index (PI) shows that some of the mature source rocks in this well are in oil generation phase while others are in gas phase (Figure 4 and Table 1). The transformation ratio (TR) defined by SOM/TOC was also used as a maturity index. It is a measure of the transformation of kerogen into hydrocarbon. Deroo et al (1988) stated that TR values between wt% indicate no hydrocarbon generation. The mean transformation ratio (TR) for the source rocks is 0.28 wt% which is considerably higher than the minimum threshold value of 0.16 for hydrocarbon generation. The TR progressively increased from 5730ft to 10590ft showing that maturation increased with depth at this interval but decreased at 11490ft. Peters and Cassa (1994) pointed out that in situ vitrinite (R O) can be overwhelmed by the recycled particles which give impression of high maturity or caved particles which show anomalous low maturity as compared with established vitrinite reflectance (R O) trend from other depths. These situations are common with cutting rock samples used for this study. To this end, plot of R O versus depth can be used to distinguish the indigenous samples from non indigenous samples which may be caved 259
14 in, recycled or even inertinites and bituminous samples (figure 5). From the R O versus sample depth plot, the low R O sample at represents a caved in sample. Only the samples that tend to linearity are the indigenous samples. The linear relationship between SOM and TOC values for indigenous samples show that maturity increased with depth (figure 11), therefore TR is also a good maturity index. Figure 5: Plot of vitrinite reflectance (VR O) versus depth of samples differentiating indigenous from non indigenous vitrinite in well X SUMMARY / CONCLUSION The geochemical analysis revealed that TOC ranges from (0.46 to 12.06) wt %; HI ranges from (72 568) HC/gCorg; and PI values ranges from ( ). These show that Organic matter quantity of the source rocks is fair to good with type II and type III kerogen. The average generative potential (S1+S2) and soluble organic matter concentration (SOM) also revealed that these source rocks have excellent hydrocarbon generation potentials with moderately high organic matter concentration. TMAX and VRO averages of the source rock intervals are 432 C and 0.62% respectively. These show that the source rocks are mature and in oil and gas generation phase. The mean transformation ratio (TR) of 0.28 wt% is considerably high for hydrocarbon generation. The oil window is placed around 8100ft where the source rock profile exhibited the highest values of (TOC) 12.06%, genetic potential (55.47), S2/S3 (10.54), (TMAX) 431( 0 C) and (VRO) 0.6%. Deductions from TOC, S1+S2. SOM, TR, TMAX and VR 0, revealed that the shales in Agbada Formation have 260
15 high organic matter concentration with type II and type III kerogen of excellent hydrocarbon generative potentials that are considerably mature at intervals and conclude that Agbada Formation sourced the hydrocarbon in the study area. REFERENCES 1. Akande, O. S., Ojo, O. J., Adekeye, O.A., Egenhoff, S.O., Obaje,N.J., and Erdtmann, B.D., Stratigraphic Evolution and Petroleum Potential of Middle Cretaceous Sediments in the Lower and Middle Benue Trough, Nigeria: Insights from New Source Rock Facies Evaluation. Petroleum Technology Development Journal (ISSN ) July 2011, Vol Allen, J.R.L., 1965, Late Quaternary Niger Delta, and adjacent areas-sedimentaryenvironments and lithofacies AAPG Bulletin, v.49, p Bissada, K.K., Geochemical constraints on petroleum generation and migration a review.proceedings Volume, ASEAN Council on Petroleum (ASCOPE 81) Doust, B., and Omatsola, E., Niger Delta, in, Edwards, J. D., and Santogrossi, P.A., eds., Divergent/passive Margin Basins., AAPG Memoir 48: Tulsa, American Association of Petroleum Geologists. p Dymann, T.S., Palacos, J.G., Tysdal, R.G., Perry, W.J., Pawlewicz, M.J., Source rock potential of Middle Cretaceous rocks in south western Montana. AAPG Bull. 80, Ekweozor, C.M., and Okoye.N.V., Petroleum source-bed evaluation of Tertiary Niger Delta: American Association of Petroleum Geologists Bulletin, v. 64, p Evamy, B.D., Haremboure. J., Kamerling, P., Knaap, W.A., Molloy, F.A., and Rowlands, P.B., 1978.Hydrocarbon habitat of Tertiary Niger Delta.American Association of Petroleum Geologists Bulletin. v. 62, p. 8. Lambert-Aikhionbare, D. 0 and Ibe A.C., Petroleum source-bed evaluation of the Tertiary Niger Delta: discussion: American Association of Petroleum Geologists Bulletin, v. 68, P Nwajide, C.S., Geology of Nigeria s sedimentary Basins. Geoscan Technical services Ltd. Awka, 565P. 10. Short, K. C., and Stauble, A.J., Outline of geology of Niger Delta: American Association of PetroleumGeologists Bulletin, v. 51, p Stacher, P., Present understanding of the Niger Delta hydrocarbon habitat, in, Oti, M.N., and Postma, G., eds. Geology of Deltas: Rotterdam, A.A. Balkema, p
16 12. Tissot, B. P., and Welte, D. H., 1984, Petroleum Formation and Occurrence, Springer-Verlag: New York, 699 pp.). 13. Tissot, B. P., B. Durand, J. Espitalie, and A. Combaz, 1974, Influence of the nature and diagenesis of organic matter in formation of petroleum: AAPG Bulletin, v. 58, p Tuttle, M.L., Brownfield, M.E.and Charpentier, R., 2004.Tertiary Niger Delta (AkataAgbada) Petroleum System (No ), Niger Delta Province, Nigeria, Cameroon, and Equatorial Guinea, Africa. 15. Tuttle, M. L. W., Charpentier,R. R.and Brownfield, M. E.,1999. The Niger delta petroleum system: Niger delta province, Nigeria, Cameroon, and Equatorial Guinea, Africa: USGS Open-file report H. 262
Source Rock Characterisation of AGBADA Formation in Well Z, Offshore, Niger Delta, Nigeria
Source Rock Characterisation of AGBADA Formation in Well Z, Offshore, Niger Delta, Nigeria A. N. Asadu 1, O.O. Omo-Irabor 2 and K. A. Ibe 3 1, 2 Department of Earth Sciences, Federal University of Petroleum
More informationInt. J Sci. Emerging Tech. Vol-2 No. 3 December, 2011
Geochemical Characterization of Agbada Formation, Osioka South Area, Western Niger Delta, Nigeria Omoboriowo A Oluwatoyin# 1, Soronnadi-Ononiwu C Godfrrey* 2 Geology Department, Faculty of Science, University
More informationLithofacies Characterization of Sedimentary Succession from Oligocene to Early Miocene Age in X2 Well, Greater Ughelli Depo Belt, Niger Delta, Nigeria
Journal of Geosciences and Geomatics, 2018, Vol. 6, No. 2, 77-84 Available online at http://pubs.sciepub.com/jgg/6/2/5 Science and Education Publishing DOI:10.12691/jgg-6-2-5 Lithofacies Characterization
More informationEvaluation of Neocomian Shale source rock In Komombo Basin, Upper Egypt
Evaluation of Neocomian Shale source rock In Komombo Basin, Upper Egypt Abdelhady, A. 1, Darwish, M. 2, El Araby, A. 3 and Hassouba, A. 4 1 DEA Egypt, Cairo, Egypt 2 Geology Department, Faculty of Science,
More informationInternational Journal of Petroleum and Geoscience Engineering Volume 04, Issue 01, Pages 58-65, 2016
International Journal of Petroleum and Geoscience Engineering Volume 04, Issue 01, Pages 58-65, ISSN: 2289-4713 Pore Pressure Gradient Prediction Using Well Logs; A Case Study on Malcolm Field, Offshore
More informationGeochemical Investigation of Potential Source Rocks for Agbada Formation, Osioka South Area, Western Niger Delta, Nigeria
Geosciences 2014, 4(1): 13-22 DOI: 10.5923/j.geo.20140401.02 Geochemical Investigation of Potential Source Rocks for Agbada Formation, Osioka South Area, Western Niger Delta, Nigeria E. K. Nyantakyi 1,2,*,
More informationDetermination of Geothermal Gradient in the Eastern Niger Delta Sedimentary Basin from Bottom Hole Temperatures
Journal of Earth Sciences and Geotechnical Engineering, vol. 4, no. 3, 2014, 109-114 ISSN: 1792-9040 (print), 1792-9660 (online) Scienpress Ltd, 2014 Determination of Geothermal Gradient in the Eastern
More informationSource Rocks. I Source rocks. II Discussion of geochemical parameters. III Global distribution of source rocks
Source Rocks I Source rocks II Discussion of geochemical parameters III Global distribution of source rocks Source rock A petroleum source rock is generally recognized as a fine grained sedimentary
More informationRock Eval, Total Organic Carbon of the 29 rock samples from Mali. Unfiled Report April
Rock Eval, Total Organic Carbon of the 29 rock samples from Mali Unfiled Report April 26 2011 Dear Sir, We have analyzed your 29 rock samples from Mali. The rock samples were pyrolyzed using our Rock-Eval
More informationSource Rock Analysis Using Well Logs In Western Niger Delta
IOSR Journal of Applied Geology and Geophysics (IOSR-JAGG) e-issn: 2321 0990, p-issn: 2321 0982.Volume 6, Issue 2 Ver. I (Mar. Apr. 2018), PP 70-85 www.iosrjournals.org Source Rock Analysis Using Well
More informationVOL. 3, NO. 8, August 2013 ISSN ARPN Journal of Science and Technology All rights reserved.
Determination of Organic Matter Richness for Agbada Formation, Osioka South Area, Western Niger Delta, Nigeria E. K. Nyantakyi, 2 T. Li, 3 W. Hu, 4 J. K. Borkloe, 5 P. A. Owusu, 6 R.D. Nagre,2,3,4 School
More informationCompositional Significance of Light Hydrocarbons in Niger Delta Crude Oils
Compositional Significance of Light Hydrocarbons in Niger Delta Crude Oils Mark O. Onyema 1 * and Kalu U. Ajike 2 1. Department of Pure and Industrial Chemistry, University of Port Harcourt, P.M.B 5323,
More informationThe Effect of Temperature on Hydrocarbon Types in Bara Oilfield, Niger Delta Basin, Gulf Of Guinea West Africa
International Journal of Science and Technology Volume 4 No. 9, September, 2015 The Effect of Temperature on Hydrocarbon Types in Bara Oilfield, Niger Delta Basin, Gulf Of Guinea West Africa Jonathan O.
More informationEstimation of Water Saturation Using a Modeled Equation and Archie s Equation from Wire-Line Logs, Niger Delta Nigeria
IOSR Journal of Applied Physics (IOSR-JAP) e-issn: 2278-4861. Volume 3, Issue 4 (Mar. - Apr. 2013), PP 66-71 Estimation of Water Saturation Using a Modeled Equation and Archie s Equation from Wire-Line
More informationHydrocarbon Volumetric Analysis Using Seismic and Borehole Data over Umoru Field, Niger Delta-Nigeria
International Journal of Geosciences, 2011, 2, 179-183 doi:10.4236/ijg.2011.22019 Published Online May 2011 (http://www.scirp.org/journal/ijg) Hydrocarbon Volumetric Analysis Using Seismic and Borehole
More informationEVALUATION OF SEISMIC ATTRIBUTES OF APO FIELD, ONSHORE NIGER DELTA, SOUTHERN NIGERIA
EVALUATION OF SEISMIC ATTRIBUTES OF APO FIELD, ONSHORE NIGER DELTA, SOUTHERN NIGERIA Ekpe G. A 1, Emudianughe J. E 2 and Umukoro J 3 1 Department of Geology, University of Port Harcourt, Port Harcourt,
More informationRESERVOIR CHARACTERIZATION USING SEISMIC AND WELL LOGS DATA (A CASE STUDY OF NIGER DELTA)
RESERVOIR CHARACTERIZATION USING SEISMIC AND WELL LOGS DATA (A CASE STUDY OF NIGER DELTA) * ESHIMOKHAI, S. and AKHIREVBULU, O.E. http://dx.doi.org/10.4314/ejesm.v5i4.s20 Received 19th June 2012; accepted
More informationHydrocarbon Potential of Late Miocene to Early Pliocene Source Rocks of Shallow Offshore, Niger Delta Basin, Nigeria
Hydrocarbon Potential of Late Miocene to Early Pliocene Source Rocks of Shallow Offshore, Niger Delta Basin, Nigeria Oladotun Afolabi Oluwajana, Ph.D. Department of Earth Sciences, Adekunle Ajasin University,
More informationFormation Evaluation of an Onshore Oil Field, Niger Delta Nigeria.
IOSR Journal of Applied Geology and Geophysics (IOSR-JAGG) e-issn: 2321 0990, p-issn: 2321 0982.Volume 4, Issue 6 Ver. II (Nov-Dec. 2016), PP 36-47 www.iosrjournals.org Formation Evaluation of an Onshore
More informationFORMATION EVALUATION OF SIRP FIELD USING WIRELINE LOGS IN WESTERN DEPOBELT OF NIGER DELTA
FORMATION EVALUATION OF SIRP FIELD USING WIRELINE LOGS IN WESTERN DEPOBELT OF NIGER DELTA 1 Obioha C, ²Adiela U. P and ³*Egesi N 1,3 Department of Geology, Faculty of Science, University of Port Harcourt,
More informationIntegration of Well Logs and Seismic Data for Prospects Evaluation of an X Field, Onshore Niger Delta, Nigeria
International Journal of Geosciences, 2012, 3, 872-877 http://dx.doi.org/10.4236/ijg.2012.324088 Published Online September 2012 (http://www.scirp.org/journal/ijg) Integration of Well Logs and Seismic
More informationOverpressure Prediction In The North-West Niger Delta, Using Porosity Data
IOSR Journal of Applied Geology and Geophysics (IOSR-JAGG) e-issn: 2321 0990, p-issn: 2321 0982.Volume 1, Issue 3 (Sep. Oct. 2013), PP 42-50 Overpressure Prediction In The North-West Niger Delta, Using
More informationGEOPHYSICAL AND WELL CORELLATION ANALYSIS OF OGO FIELD: A CASE STUDY IN NIGER DELTA BASIN OF NIGERIA
Nigerian Journal of Technology (NIJOTECH) Vol. 36, No. 3, July 2017, pp. 729 733 Copyright Faculty of Engineering, University of Nigeria, Nsukka, Print ISSN: 0331-8443, Electronic ISSN: 2467-8821 www.nijotech.com
More informationIntroduction to Petroleum Geochemistry and its Significance in Hydrocarbon Exploration. and. How to Get Your Scholarships Abroad?
Introduction to Petroleum Geochemistry and its Significance in Hydrocarbon Exploration and How to Get Your Scholarships Abroad? Oleh: RAGIL PRATIWI GEOSERVICES UNDIP SHARING SESSION Semarang, 20 th June
More information22. PETROLEUM-GENERATING POTENTIAL OF SEDIMENTS FROM LEG 44, DEEP SEA DRILLING PROJECT
. PETROLEUM-GENERATING POTENTIAL OF SEDIMENTS FROM LEG, DEEP SEA DRILLING PROJECT J.W. Kendrick, A. Hood, and J.R. Castano, Shell Development Company, Houston, Texas ABSTRACT The abundance, type, and thermal
More informationPyrolysis and TOC Identification of Tight Oil Sweet Spots TALK OUTLINE
Pyrolysis and TOC Identification of Tight Oil Sweet Spots Albert Maende* and W. David Weldon, Wildcat Technologies, LLC, Humble, TX, United States. TALK OUTLINE Formation area of study Type of data, analytical
More informationSequence Stratigraphic Framework of the Paradise-Field Niger Delta, Nigeria.
Sequence Stratigraphic Framework of the Paradise-Field Niger Delta, Nigeria. A.O. Anyiam, M.Sc. and A.W. Mode, Ph.D. Department of Geology, University of Nigeria, Nsukka, Enugu State, Nigeria E-mail: okwy_anyiam@yahoo.com
More informationIntegration of Well Log Analysis and 3-D Seismic in Reserve Estimation of Hydrocarbon Bearing Sands in Q-Field, Niger-Delta Nigeria
Integration of Well Log Analysis and 3-D Seismic in Reserve Estimation of Hydrocarbon Bearing Sands in Q-Field, Niger-Delta Nigeria Bayowa O.G. 1 Mas ud Q.A. 1 Lawal A.W. 2 L.O Ademilua 3* 1.Ladoke Akintola
More informationOverpressure/ Depositional Analysis of Parts of Onshore (X-Field) Niger Delta Basin Nigeria, Based on Well Logs Data.
IOSR Journal of Applied Geology and Geophysics (IOSR-JAGG) e-issn: 2321 0990, p-issn: 2321 0982.Volume 4, Issue 5 Ver. III (Sep. - Oct. 2016), PP 01-13 www.iosrjournals.org Overpressure/ Depositional Analysis
More informationPetroleum Systems (Part One) Source, Generation, and Migration
Petroleum Systems (Part One) Source, Generation, and Migration GEOL 4233 Class January 2008 Petroleum Systems Elements Source Rock Migration Route Reservoir Rock Seal Rock Trap Processes Generation Migration
More informationSOURCE - ROCK POTENTIAL OF THE LOWER CRETACEOUS SEDIMENTS IN SD 1X WELL, OFFSHORE TANO BASIN, SOUTH WESTERN GHANA
Article Open Access SOURCE - ROCK POTENTIAL OF THE LOWER CRETACEOUS SEDIMENTS IN SD 1X WELL, OFFSHORE TANO BASIN, SOUTH WESTERN GHANA P. Garry 1, a, D. Atta-Peters 2, b*, C. Achaegakwo 2, c 1 Job House
More informationAvailable online Journal of Scientific and Engineering Research, 2016, 3(6): Research Article
Available online www.jsaer.com, 2016, 3(6):324-332 Research Article ISSN: 2394-2630 CODEN(USA): JSERBR Reservoir Modeling and Hydrocarbon Evaluation of Abi-Field, Niger Delta, Nigeria Adiela UP 1, Omoboriowo
More informationOil & Gas. From exploration to distribution. Week 1 V05 Origin of hydrocarbon resources part 1. Jean-Pierre Deflandre
Oil & Gas From exploration to distribution Week 1 V05 Origin of hydrocarbon resources part 1 Jean-Pierre Deflandre W1V5 Origin of hydrocarbon resources1 p. 1 Introduction to hydrocarbon resources You will
More informationPseudo-Source Rock Characterization
IOSR Journal of Applied Chemistry (IOSR-JAC) e-issn: 2278-5736.Volume 8, Issue 1 Ver. I. (Jan. 2015), PP 46-50 www.iosrjournals.org Pseudo-Source Rock Characterization 1 Swapan Kumar Bhattacharya, 2 Juwita
More informationSource rock maturation studies using vitrinite reflectance and geothermal data from six wells in Gabo and Wabi fields, onshore Niger Delta, Nigeria
International Journal Geology and Mining Vol. 2(2), pp. 064-070, December, 2016. www.premierpublishers.org. ISSN: XXXX-XXXX IJGM Research Article Source rock maturation studies using vitrinite reflectance
More informationSource rock evaluation and hydrocarbon potential in the Tano basin, South Western Ghana, West Africa
International Journal of Oil, Gas and Coal Engineering 2014; 2(5): 66-77 Published online November 10, 2014 (http://www.sciencepublishinggroup.com/j/ogce) doi: 10.11648/j.ogce.20140205.11 Source rock evaluation
More informationGeochemical Appraisal using Vitrinite Reflectance and Rock-Eval Data, of Shishtu and Sardar Formations Central Iran
Geochemical Appraisal using Vitrinite Reflectance and Rock-Eval Data, of Shishtu and Sardar Formations Central Iran Jahangard. A. A, Alizadeh. B, Hosseini. S. H. Department of Geology, Faculty of Earth
More informationPetroleum Potential of the Application Area L12-4
Petroleum Potential of the Application Area L12-4 The Application Area (L12-4) is underlain by the western Officer Basin, beneath the Gunbarrel Basin. The general basin architecture is outlined in Figure
More informationAvailable online Journal of Scientific and Engineering Research, 2018, 5(6): Research Article
Available online www.jsaer.com, 2018, 5(6):17-24 Research Article ISSN: 2394-2630 CODEN(USA): JSERBR Reservoir Characterization and Structural Mapping of UVO Field, Onshore Niger Delta using Well Logs
More informationLECO Analytical Study of Subsurface Tertiary Shale Offshore Niger Delta
IOSR Journal of Applied Geology and Geophysics (IOSR-JAGG) e-issn: 2321 0990, p-issn: 2321 0982.Volume 6, Issue 5 Ver. I (Sep. Oct. 2018), PP 75-81 www.iosrjournals.org LECO Analytical Study of Subsurface
More informationTertiary Oil-Prone Coals and Carbonaceous Shales Identified as the Potential Source Rock of the Caracara Sur Oil Field in the Llanos Basin, Colombia*
Click to view presentation slides (3 mb). Tertiary Oil-Prone Coals and Carbonaceous Shales Identified as the Potential Source Rock of the Caracara Sur Oil Field in the Llanos Basin, Colombia* M.F. García-Mayoral
More informationMODEL COMPACTION EQUATION FOR HYDROSTATIC SANDSTONES OF THE NIGER DELTA.
Ife Journal of Science vol. 13, no. 1 (2011) MODEL COMPACTION EQUATION FOR HYDROSTATIC SANDSTONES OF THE NIGER DELTA. Benjamin, U.K and *Nwachukwu, J.I Department of Geology, Obafemi Awolowo University,
More informationMaturity Modeling of Gomin and South Gomin fields Southern Pattani Basin, Gulf of Thailand
Maturity Modeling of Gomin and South Gomin fields Southern Pattani Basin, Gulf of Thailand Patinya Jaithan Petroleum Geoscience Program, Department of Geology, Faculty of Science, Chulalongkorn University,
More informationMike Solt, a WVU GEOL alumnus just sent a message, which might be of interest to those of you looking for an internship this summer:
Mike Solt, a WVU GEOL alumnus just sent a message, which might be of interest to those of you looking for an internship this summer: My company, Langan Engineering, is offering a summer internship in Philadelphia.
More informationHydrocarbon Potential of the Marginal Fields in Niger Delta Oza Field, a case study*
Hydrocarbon Potential of the Marginal Fields in Niger Delta Oza Field, a case study* J.N. Sahu 1, C.H.V. Satya Sai 1, V. Chintamani 1 and C. Vishnu Vardhan 1 Search and Discovery Article #20182 (2012)*
More informationStrictly as per the compliance and regulations of :
Global Journal of Science Frontier Research: Physics and Space Science Volume 16 Issue 1 Version 1.0 Year 2016 Type : Double Blind Peer Reviewed International Research Journal Publisher: Global Journals
More informationSTRUCTURAL INTERPRETATION AND HYDROCARBON POTENTIAL OF OBUA FIELD, NIGER DELTA, SOUTHERN NIGERIA
STRUCTURAL INTERPRETATION AND HYDROCARBON POTENTIAL OF OBUA FIELD, NIGER DELTA, SOUTHERN NIGERIA 1 Iwuoma Juliet Onyinyechukwu and 2 Minapuye I. Odigi 1 Department of Geology, University of Port Harcourt,
More informationThe Integrated Seismic Reservoir Characterization (ISRC), Study in Amboy Field of Niger Delta Oil Field Nigeria
Geosciences 2012, 2(3): 60-65 DOI: 10.5923/j.geo.20120203.04 The Integrated Seismic Reservoir Characterization (ISRC), Study in Amboy Field of Niger Delta Oil Field Nigeria Odoh B. I 1, Onyeji Johnbosco
More informationHydrocarbon Potential of Some Afowo Shale Deposits in Part of South Western Nigeria
International Journal of African and Asian Studies Hydrocarbon Potential of Some Afowo Shale Deposits in Part of South Western Nigeria AKINMOSIN, A 1, OMOSANYA, K.O 2 OLAWALE, A, O 2. *Geosciences Department,
More informationBALOCHISTAN FOLDBELT BASIN
INTRODUCTION BALOCHISTAN FOLDBELT BASIN The Kharan-3 block is located in the Kharan Trough of Balochistan Basin. GEOLOGICAL SETTING The Balochistan Province is an Upper Cretaceous to Recent structurally
More informationOrganic and Trace Element Geochemistry of the Ameki Formation, South Eastern Nigeria: Implications and Hydrocarbon Generating Potential
IOSR Journal of Applied Geology and Geophysics (IOSR-JAGG) e-issn: 2321 0990, p-issn: 2321 0982.Volume 4, Issue 4 Ver. I (Jul. - Aug. 2016), PP 12-20 www.iosrjournals.org Organic and Trace Element Geochemistry
More informationKeywords: Exploration; reservoir structure; stratigraphic trap; uncertainty; petrophysical property.
Article Open Access INTEGRATION OF 3D SEISMIC AND WELL LOG DATA FOR THE EXPLORATION OF KINI FIELD, OFF- SHORE NIGER DELTA Adesoji O. Akanji 1, Oluseun A. Sanuade 2, SanLinn I. Kaka 2, Isaac D. Balogun
More informationGrowth Fault History Analysis of an Oil Field, Niger Delta, Nigeria
International Journal of Geophysics and Geochemistry 2015; 2(5): 105-112 Published online October 10, 2015 (http://www.aascit.org/journal/ijgg) ISSN: 2381-1099 (Print); ISSN: 2381-1102 (Online) Growth
More informationSEISMIC ATTRIBUTES ANALYSIS FOR RESERVOIR CHARACTERIZATION; OFFSHORE NIGER DELTA
Petroleum & Coal ISSN 1337-7027 Available online at www.vurup.sk/petroleum-coal Petroleum & Coal 57(6) 619-628, 2015 SEISMIC ATTRIBUTES ANALYSIS FOR RESERVOIR CHARACTERIZATION; OFFSHORE NIGER DELTA K.
More informationHydrogen Index as a Maturity Proxy - Some Pitfalls and How to Overcome Them*
Hydrogen Index as a Maturity Proxy - Some Pitfalls and How to Overcome Them* Mark H. Tobey 1 and Catherine E. Campbell 2 Search and Discovery Article #41964 (2016)** Posted December 12, 2016 *Adapted from
More informationDepositional History and Petroleum Potential of Ombilin Basin, West Sumatra - Indonesia, Based on Surface Geological Data*
Depositional History and Petroleum Potential of Ombilin Basin, West Sumatra - Indonesia, Based on Surface Geological Data* Yahdi Zaim 1, Litto Habrianta 2, Chalid I. Abdullah 1, Aswan 1, Yan Rizal 1, Nurcahyo
More information26. ORGANIC GEOCHEMISTRY OF SOME LOWER CRETACEOUS SHALES FROM DEEP SEA DRILLING PROJECT SITE 416, EASTERN NORTH ATLANTIC
26. ORGANIC GEOCHEMISTRY OF SOME LOWER CRETACEOUS SHALES FROM DEEP SEA DRILLING PROJECT SITE 416, EASTERN NORTH ATLANTIC G. Deroo, J. P. Herbin, J. Roucaché, and B. Tissot, Institut Français du Pétrole,
More informationThe Effect of Facies Changes on Hydrocarbon Production in Osisioma Field, Onshore, Niger Delta, Nigeria
Journal of Geosciences and Geomatics, 2018, Vol. 6, No. 2, 35-40 Available online at http://pubs.sciepub.com/jgg/6/2/1 Science and Education Publishing DOI:10.12691/jgg-6-2-1 The Effect of Facies Changes
More informationRESERVOIR EVALUATION OF T-X FIELD (ONSHORE, NIGER DELTA) FROM WELL LOG PETROPHYSICAL ANALYSIS
http://dx.doi.org/10.4314/bajopas.v9i2.25 Bayero Journal of Pure and Applied Sciences, 9(2): 132-140 Received: June, 2016 Accepted: December, 2016 ISSN 2006 6996 RESERVOIR EVALUATION OF T-X FIELD (ONSHORE,
More information21. GEOCHEMICAL ANALYSIS OF SAMPLES FROM SITES 397 AND 398
21. GEOCHEMICAL ANALYSIS OF SAMPLES FROM SITES 397 AND 398 Daniel B. Pearson, The Superior Company, Houston, Texas and Wallace G. Dow, Getty Company, Houston, Texas 1 INTRODUCTION Economic interest in
More informationA new approach to interpreting relationship between Rock-Eval S2 and TOC data for source rock evaluation based on regression analyses
Geopersia 5 (), 25, PP. -6 A new approach to interpreting relationship between Rock-Eval S2 and TOC data for source rock evaluation based on regression analyses Ali Shekarifard School of Chemical Engineering,
More informationGas Generation and Retention in the Bakken Shale, Williston Basin*
Gas Generation and Retention in the Bakken Shale, Williston Basin* Brian Horsfield 1, Gary P. Muscio 2, Kliti Grice 3, Rolando di Primio 1, Philipp Kuhn 1, and Ercin Maslen 3 Search and Discovery Article
More informationKilometre-Scale Uplift of the Early Cretaceous Rift Section, Camamu Basin, Offshore North-East Brazil*
Kilometre-Scale Uplift of the Early Cretaceous Rift Section, Camamu Basin, Offshore North-East Brazil* Iain Scotchman 1 and Dario Chiossi 2 Search and Discovery Article #50183 (2009) Posted May 20, 2009
More informationPetroleum System Modelling applied to the evaluation of HC in Place in Unconventional Gas Shale prospects
Petroleum System Modelling applied to the evaluation of HC in Place in Unconventional Gas Shale prospects Domenico Grigo 28 April, 2011 www.eni.it applied to Gas Shale Prospect characterisation Why? In
More informationPetroleum geology framework, West Coast offshore region
Petroleum geology framework, West Coast offshore region James W. Haggart* Geological Survey of Canada, Vancouver, BC jhaggart@nrcan.gc.ca James R. Dietrich Geological Survey of Canada, Calgary, AB and
More informationMODULE PREREQUISITES FOR HYDROCARBON ACCUMULATION
MODULE 1 1.0 PREREQUISITES FOR HYDROCARBON ACCUMULATION The accumulation of hydrocarbons and formation of oil or gas deposit involve certain prerequisites. These are the following: 1. Source Rock 2. Reservoir
More informationFormation evaluation of an onshore appraisal well KG-5, green field, Niger Delta, Nigeria
AMERICAN JOURNAL OF SCIENTIFIC AND INDUSTRIAL RESEARCH 2010, Science Huβ, http://www.scihub.org/ajsir ISSN: 2153-649X doi:10.5251/ajsir.2010.1.2.262.270 Formation evaluation of an onshore appraisal well
More informationDetecting and Predicting Over Pressure Zones in the Niger Delta, Nigeria: A Case Study of Afam Field.
Detecting and Predicting Over Pressure Zones in the Niger Delta, Nigeria: A Case Study of Afam Field. Olatunbosun Alao 1*, William Ofuyah 2 and Ayobami Abegunrin 1 1.Department of Geology, Obafemi Awolowo
More informationApplication Note ( )
218 Higgins Street Humble, TX 77338 (281) 540-3208 Application Note (052016-1) Wildcat Compositional Analysis for Conventional and Unconventional Reservoir Assessments HAWK Petroleum Assessment Method
More informationDrill Cuttings Analysis: How to Determine the Geology of a Formation and Reservoir
Drill Cuttings Analysis: How to Determine the Geology of a Formation and Reservoir Chuck Stringer ASA Manager Southern Region 2015 TECH MKT_2014-BD-REG-1673 1 The one item that has lacked serious consideration
More informationSequence Stratigraphic Analysis from Well Logs of an X- Field, Niger Delta, Nigeria
Current Research in Geosciences Original Research Paper Sequence Stratigraphic Analysis from Well Logs of an X- Field, Niger Delta, Nigeria Godwin Omokenu Emujakporue and Alphonsus Joseph Eyo Department
More informationSedimentary Fill Modeling: Relationships to Sequence Stratigraphy and Its Implications for Hydrocarbon Exploration in the Niger Delta, Nigeria.
Sedimentary Fill Modeling: Relationships to Sequence Stratigraphy and Its Implications for Hydrocarbon Exploration in the Niger Delta, Nigeria. Omabehere I. Ejeh, M.Sc Geology Department, Delta State University,
More informationWe are IntechOpen, the world s leading publisher of Open Access books Built by scientists, for scientists. International authors and editors
We are IntechOpen, the world s leading publisher of Open Access books Built by scientists, for scientists 3,500 108,000 1.7 M Open access books available International authors and editors Downloads Our
More informationSubsurface Geology and Potential Capability of Oil Generation of some Jurassic and Lower Cretaceous Source Rocks in North Western Desert, Egypt.
Middle East Journal of Applied Sciences, 4(2): -317, 214 ISSN: 277-4613 Subsurface Geology and Potential Capability of Oil Generation of some Jurassic and Lower Cretaceous Source Rocks in North Western
More informationControls on clastic systems in the Angoche basin, Mozambique: tectonics, contourites and petroleum systems
P2-2-13 Controls on clastic systems in the Angoche basin, Mozambique: tectonics, contourites and petroleum systems Eva Hollebeek, Olivia Osicki, Duplo Kornpihl Schlumberger, London, UK Introduction Offshore
More informationAPPENDIX C GEOLOGICAL CHANCE OF SUCCESS RYDER SCOTT COMPANY PETROLEUM CONSULTANTS
APPENDIX C GEOLOGICAL CHANCE OF SUCCESS Page 2 The Geological Chance of Success is intended to evaluate the probability that a functioning petroleum system is in place for each prospective reservoir. The
More informationTrace Metals Geochemistry of Crude Oils from Umutu/Bomu Fields in South West Niger Delta Nigeria
Trace Metals Geochemistry of Crude Oils from Umutu/Bomu Fields in South West Niger Delta Nigeria Onojake Mudiaga C. (Corresponding author) Department of Pure and Industrial Chemistry, University of Port
More informationONLINE FIRST(NOT Peer-Reviewed)
ONLINE FIRST(NOT Peer-Reviewed) Title:Hydrocarbon Reservoir Evaluation: a case study of Tymot field at southwestern offshore Niger Delta Oil Province, Nigeria Author:Victor Cypren Nwaezeapu Institute/Affiliation:Nnamdi
More informationReservoir Characterization: Implications From Petrophysical Data of the Paradise-Field, Niger Delta, Nigeria
Reservoir haracterization: Implications From Petrophysical Data of the Paradise-Field, Niger Delta, Nigeria A.W. Mode, Ph.D. and A.O. Anyiam, M.Sc. Department of Geology, University of Nigeria, Nsukka,
More informationGEOCHEMICAL CARACTERIZATION OF MOROCCAN TARFAYA OIL SHALE
GEOCHEMICAL CARACTERIZATION OF MOROCCAN TARFAYA OIL SHALE A. chakor alami chakor@onhym.com 1 MOROCCAN OIL SHALE DEPOSITS 2 GEOGRAPHICAL SITUATION Report N 91022 3 GEOLOGICAL ASPECTS OF TARFAYA OIL SHALE
More informationShale Gas Potential in the Eastern Cordillera of Colombia*
Shale Gas Potential in the Eastern Cordillera of Colombia* Mario Garcia-Gonzalez 1 Search and Discovery Article #10286 (2010) Posted December 17, 2010 *Adapted from oral presentation at AAPG International
More informationPetrophysical Charaterization of the Kwale Field Reservoir Sands (OML 60) from Wire-line Logs, Niger Delta, Nigeria. EKINE, A. S.
JASEM ISSN 1119-8362 All rights reserved Full-text Available Online at wwwbiolineorgbr/ja J Appl Sci Environ Manage December, 2009 Vol 13(4) 81-85 Petrophysical Charaterization of the Kwale Field Reservoir
More informationPlane Versus Elastic Wave AVO Anisotropic Synthetic Modeling in Derby Field, Southeastern Niger Delta
Current Research in Geosciences Original Research Paper Plane Versus Elastic Wave AVO Anisotropic Synthetic Modeling in Derby Field, Southeastern Niger Delta Chukwuemeka Ngozi Ehirim and Nnamdi Ogbonna
More informationAn Integrated Approach to Volume of Shale Analysis: Niger Delta Example, Orire Field
World Applied Sciences Journal 7 (4): 448-452, 2009 ISSN 1818-4952 IDOSI Publications, 2009 An Integrated Approach to Volume of Shale Analysis: Niger Delta Example, Orire Field 1 1 2 L. Adeoti, E.A. Ayolabi
More informationAnalyticalDeterminationofSubsurfaceTemperatureusingTwoLayersModelinPartofNigerDeltaSedimentaryBasinNigeria
Global Journal of Science Frontier Research: A Physics and Space Science Volume 16 Issue 3 Version 1.0 Year 2016 Type : Double Blind Peer Reviewed International Research Journal Publisher: Global Journals
More informationHIGH HYDROCARBON PROSPECT IN NIGER DELTA COMPLEX, NIGERIA
The Journal of MacroTrends in Energy and Sustainability MACROJOURNALS HIGH HYDROCARBON PROSPECT IN NIGER DELTA COMPLEX, NIGERIA Abatan O.A*.,Ojo, R.K ** *Physics/Electronics Unit, SLT, Moshood Abiola Polytechnic,
More informationReservoir Property Distribution and Structural Styles Analysis of OML D Regional Line, Onshore Niger Delta Basin
International Journal of Sciences: Basic and Applied Research (IJSBAR) ISSN 2307-4531 (Print & Online) http://gssrr.org/index.php?journal=journalofbasicandapplied ---------------------------------------------------------------------------------------------------------------------------
More informationOIL SHALE OCCURRENCES IN UPPER ASSAM BASIN, INDIA : AN OVERVIEW
OIL SHALE OCCURRENCES IN UPPER ASSAM BASIN, INDIA : AN OVERVIEW V.K.Sibal Srinivasan V.Raju Directorate General of Hydrocarbons New Delhi SEDIMENTARY BASIN MAP OF INDIA 2 HYDROCARBON RESOURCE BASE Sedimentary
More informationLucas F.A, Omodolor Hope E *
Journal of Geosciences and Geomatics, 2018, Vol. 6, No. 2, 85-93 Available online at http://pubs.sciepub.com/jgg/6/2/6 Science and Education Publishing DOI:10.12691/jgg-6-2-6 Palynofacies Analysis, Organic
More informationEvaluation of Hydrocarbon Volume in TRH Field, Onshore Niger Delta, Nigeria
International Journal of Geophysics and Geochemistry 2015; 2(5): 113-123 Published online October 10, 2015 (http://www.aascit.org/journal/ijgg) ISSN: 2381-1099 (Print); ISSN: 2381-1102 (Online) Evaluation
More informationSouth Texas* Paul C. Hackley 1, Kristin Dennen 1, Rachel Gesserman 1, and Jennie L. Ridgley 2
AV Preliminary Investigation of the Thermal Maturity of Pearsall Formation Shales in the Maverick Basin, South Texas* Paul C. Hackley 1, Kristin Dennen 1, Rachel Gesserman 1, and Jennie L. Ridgley 2 Search
More informationSEISMIC AND PETROPHYSICAL CHARACTERIZATION OF SELECTED WELLS, NIGER DELTA
SEISMIC AND PETROPHYSICAL CHARACTERIZATION OF SELECTED WELLS, NIGER DELTA Oghonyon Rorome 1, Njoku A. Felix 2 and Itiowe Kiamuke 3 1,2,3 Department of Geology, University of Port Harcourt, Port Harcourt,
More informationBulletin of Earth Sciences of Thailand
Depositional Environments and Stratigraphic Development of the Grand Taman Sari Circuit Outcrop: an Analogue for Transgressive Mahakam Delta Successions Ridha Santika Riadi Petroleum Geoscience Program,
More informationB.C. s Offshore Oil and Gas: a Guide to the Geology and Resources.
B.C. s Offshore Oil and Gas: a Guide to the Geology and Resources. Introduction Beneath the offshore regions of British Columbia are four moderately large, geologically young sedimentary basins (Figure
More informationRecap and Integrated Rock Mechanics and Natural Fracture Study in the Bakken Formation, Williston Basin
Recap and Integrated Rock Mechanics and Natural Fracture Study in the Bakken Formation, Williston Basin EERC, 2011 Cosima Theloy PhD Candidate Department of Geology and Geological Engineering Colorado
More informationSediment and sedimentary rocks Sediment
Sediment and sedimentary rocks Sediment From sediments to sedimentary rocks (transportation, deposition, preservation and lithification) Types of sedimentary rocks (clastic, chemical and organic) Sedimentary
More informationEGAS. Ministry of Petroleum
EGAS Ministry of Petroleum EGAS Ministry of Petroleum About The Block Location: N. Thekah offshore block is located at about 56 km to the north of the Mediterranean shore line, 85 km to the north west
More informationOrganic Richness J. W. KENDRICK, A. HOOD, J. R. CASTANO. VITRINITE REFLECTANCE (CASTANO, IN HOOD and CASTANO, 1974)
. PETROLEUM-GENERTING POTENTIL OF SEDIMENTS FROM LEG 0, DEEP SE DRILLING PROJECT J. W. Kendrick,. Hood, and J. R. Castano, Shell Development Company, Bellaire Research Center, Houston, Texas INTRODUCTION
More informationMUHAMMAD S TAMANNAI, DOUGLAS WINSTONE, IAN DEIGHTON & PETER CONN, TGS Nopec Geological Products and Services, London, United Kingdom
Geological and Geophysical Evaluation of Offshore Morondava Frontier Basin based on Satellite Gravity, Well and regional 2D Seismic Data Interpretation MUHAMMAD S TAMANNAI, DOUGLAS WINSTONE, IAN DEIGHTON
More informationUsing Thermal Maturity to Identify the Most Productive Part of the Oil Window to Target in the Woodford Shale
2 nd Annual Woodford Liquids-Rich January 28, 2015 Horizontal Targets Congress 2015 Using Thermal Maturity to Identify the Most Productive Part of the Oil Window to Target in the Woodford Shale Brian J.
More information