HYDROCARBON POTENTIAL EVALUATION OF LOWER CAMBAY SHALE AND OLPAD FORMATION IN CAMBAY BASIN, INDIA: A REVIEW
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1 HYDROCARBON POTENTIAL EVALUATION OF LOWER CAMBAY SHALE AND OLPAD FORMATION IN CAMBAY BASIN, INDIA: A REVIEW *K.L. Devi, A. Sircar and G.P. Karmakar * School of Petroleum Technology, Pandit Deendayal Petroleum University, Raisan, Gandhinagar , Gujarat *Author for Correspondence ABSTRACT The Cambay basin, which is a part of Western Onshore Basin, is a major oil producing field of India. It is a narrow elongated rift graben situated between Saurashtra Craton on the west and Aravalli on the northeast and Deccan craton to the southeast. Till the late 90 s oil companies in India were exploring hydrocarbon in the shallow Kalol sequence. Upper part of Cambay Shale formation containing siltstone was also targeted whereas the lower part which dominantly consists of shale was never thought to be a reservoir. The discovery of hydrocarbon in few wells in Cambay Basin in early 2000 changed the paradigm of exploration strategy in Cambay basin. The Olpad Formation and Lower Cambay Shale Formation are still a challenge to the explorationists in terms of petroleum prospects. This has encouraged many researchers to study the hydrocarbon potential of the above two formations. Moreover, Identification of the dual nature of source rock also has attracted much attention to the geoscientists for the hydrocarbon resource evaluation. This paper reviews the previous works done on the above mentioned basin, which may be helpful to initiate further research for hydrocarbon exploration in the Olpad as well as Lower Cambay Shale Formations. Key Words: Lower Cambay Shale Formation, Olpad Formation, Basin Evolution and Petroleum System INTRODUCTION The Cambay Basin is a narrow elongated rift graben situated between Saurashtra Craton on the west and Aravalli on the northeast and Deccan craton to the southeast. It extends from Sanchor in north to the Gulf of Cambay in south and opens into the Arabian Sea. On the west and east, it is bounded by basin margin faults. Earlier workers have described the geology, tectonics and Stratigraphy of this basin in detail (Bhandari and Choudhary, 1975; Biswas et al., 1994 and Kundu and Wani, 1992). Cambay Basin is covering an area of about sq km, 425 km long and width 138 km in the central part approximately. It lies between the west and northwestern margin of Indian shield between latitudes 21 N and 25 N and longitudes E and E in the states of Gujarat and Rajasthan. Sediments consisting alluvia of Banas, Saraswati, Sabarmati, Mahi, Narmada and Tapti rivers cover a large part of the basin of Quaternary age. Pre-existing basement structures i.e. Precambrian, NNW-SSE Dharwarian and NE-SW Satpura trends played a vital role in rift architecture and the subsequent evolution. These structures are having major faults significant the rift boundary or large horst blocks within the rift. Crossfaults, accommodation zones are subdivided this basin into five tectonic blocks namely as; Sanchor Patan; Mehsana Ahmedabad; Tarapur Cambay; Broach Jambusar and Narmada Tapti Blocks. The basin is further sub-divided into two parts as North and South Cambay Basin, separated by Mahi River, for enhanced understanding of the Geological set up (Mayor et al., 2004). Description of Cambay Basin Tectonic Setup, Geological Setting and Basin Evolution The tectonic evolution of Cambay rift in the north-western part of Indian peninsula is closely related to the origin and evolution of Indian plate (Biswas et al., 1993). Massive eruption of the Deccan Traps 137
2 covering almost the whole of the Cambay basin forms the tectonic basement over which rift sedimentation took place (Sahoo et al., 2011). Figure 1: Location Map of Cambay Basin (Bhowmik and Mishra, 2008) The sedimentation in the basin is mostly controlled by the prerift, synrift, and postrift stages, which the basin witnessed together with the relationship of local-regional sediment distribution patterns and drainage systems. The basaltic floor (i.e., the Deccan Trap of late Cretaceous-Paleocene age) forms the tectonic basement. Olpad Formation overlies the Deccan Trap and has a gradational relationship with the overlying Cambay Shale. The Olpad facies was deposited in alluvial fans, alluvial fan deltas, over bank and lacustrine environments, characterized by wacke, sandstone, siltstone, wash, and claystone which have generated substantial hydrocarbons. The synrift stage continued to Early Eocene times in which a thick sequence of Cambay Shale was deposited, predominantly black-to-dark gray shale with superseding sand and silts is the main source of hydrocarbon generation in Cambay Basin. The Cambay Shale is further divided into the Older Cambay Shale (OCS) and the Younger Cambay Shale (YCS) formations. 138
3 Figure 2: Generalized Stratigraphy of Cambay Basin (Negi et al., 2006) Older Cambay Shale showed the earliest marine sedimentation in the basin with episodes of deposition of coarser clastics. In the northern part of Cambay basin, the Lower and Upper part shaly units distinguish the three arenaceous members like Mandhali, Mehsana, and Chhatral of Younger Cambay Shale which is relatively shaly in the southern part the basin. The overlying Kalol Formation of middle Eocene age is a major producer in the area, mainly divided into two (i.e. the Sertha and Wavel) members. Kalol Formation is characterized by intercalations of thin sandstone and siltstone, shale, and coal. In a few areas are an additional reservoir facies, deposited above and below the coals, is the main producer. Figure 2 is showing the stratigraphy of Cambay Basin and adjoining area (Negi et. al., 2006). Figure 3: Isopachmap of Paleocene section (Olpad Formation) and Paleocene to Early Eocene section (Cambay Shale and Kadi Formation) showing faults and depocenters (Sahoo et al., 2011). 139
4 Figure 4: Simplified diagram showing Basin inversion (Mohan R. et al., 2008). Figure 5: Tectonic evolution along an E-W direction (Sahoo et al., 2011) 140
5 Figure 6: Hydrocarbons Generation/Expelled map of Olpad and Older Cambay Shale Formation (IHS Energy) 141
6 Figure 7: Entrapment styles observed in different stages of rift development in Cambay Basin (Mohan, 1995) Sedimentation and Megasequences Paleocene (Synrift Sequence; early rift and rift climax)-olpad Formation is deposited during Paleocene period and it lies above Deccan Trap Formation. Olpad Formation is mainly composed of trap conglomerates, weathered trap and claystone and few siltstone bands are in the upper part of this formation. This sequence is a wedge shaped synrift sequence characterized by chaotic reflection pattern, high amplitude and dominated in the fault controlled half grabens. During the initial phase of intense rifting trap derivatives, trap conglomerates are formed as alluvial fan deposits. During later stages lacustirine claystones are deposited in the deeper axial parts of half grabens. The depositional environment is continental; alluvial fans, lakes or probable flood plains. Transfer zones which separate 142
7 the major depressions act as a barrier to the longitudinal transport of sediments and indicate major influx of sediments from rift margins. Isopach map of Olpad Formation showing major depositional trends and depocentres are showing in the figure. Most of the deposition trends run parallel to the NW-SE fault trends (Sahoo et al., Geo-India 2011). Basin Inversion and Deformation The structural architecture of rift basin may get complicated by basin inversion, in which a contractional phase follows the extensional phase (Buchanan and Buchanan, 1995). The inversion structures are consist of normal faults reactivated as reverse faults, newly formed reverse and thrust faults, and folds. Scores of rift basins in the world contain a wide variety of post-rift compressional structures and. Many of these types of features involve reutilization of normal fault that were active during extension, and hence they were concerned to as an inversion structures. Basin inversion is happening in a variety of tectonic environments (Mohan et al., 2008). Geodynamics of Cambay Aborted-rift Basin During Late Cretaceous time, Cambay basin owes on its origin to the rifting and drifting of the Indian plate from the Madagascar marked by outpouring of huge Deccan Basalt. The rifting subsequently failed and evolved as a post-rift interior basin (i.e. Aborted Rift) synchronous with the evolution of the Arabian Sea. A phase of widespread crustal tension, the crust around Cambay and Narmada rifted, during Cretaceous age and located over rising columns of hot mantle, these rifts (i.e. 'failed arms') never became oceans. However, during rift evolution the reactivation structures were in different time. Compressions originating in the Indo-Eurasian plate collision that produced the Himalayan orogeny provided the far field stresses causes inversion and erosion of rift basin contents in different time (Mohan R. et al., 2008 and Sahoo et al., 2011). Geothermal History The thermal history of the basin is characterized by initial high heat flow by cooling as the rift aborted. The average heat flow is of the order of 2.07 HFW (Gupta et al., 1970). The normal geothermal gradient is of the order by c/km and at places it upto c/km (Panda et al., 1985). Petroleum System Source Rock Encouraging thermal history with high heat flows followed by cooling effects helped for generation and preservation of hydrocarbon in the Cambay Basin. The synrift organic rich Cambay shale comprise the principle source facies of Kerogen type II/III and total organic carbon (TOC) is higher in the northern basin (Mohan, 1995), whereas maturity level is lower in the south. Early oil generation and expulsion took place in the northern part of the basin. At places, low maturity (VR0 = ) oil in Mehsana subblock is attributed to oil generation from coal (Mehrotra et al., 1991). The source potential towards northern part of the basin appears to be deposited in lacustrine environment where as in the southern part, the oil generation took place since Middle Eocene and basin wide oil migration took place in Early Miocene time (Mohan, 1995). On the basis of the Paleo-temperatures and thickness data for each source rock have been computed the total oil and gas generating capacity for each unit. There are four source rock units in this basin: Tarapur Shale and its co-eval units of Upper Eocene-Oligocene age; Kalol Formation and its co-eval units of Middle Eocene age; Cambay Shale of Lower Eocene age; Olpad formation of Paleocene (Yalcin et al., 1998). Exploration Play System and Entrapment Style Migration In Cambay basin, the oil is less mature and has accumulated close to their source in north whereas in southern area inferred to be comparatively more mature and have migrated to considerable distances (Chandra, 1987; Mehrotra et al., 1990 and Chowdhary, 2004). While deeper part of northern cambay basin are sourced from comparatively more mature rocks of depressions, having higher gravity values of crude oil. Crude oils of lower API gravity on the flanks and margins of the basin are less mature source 143
8 rocks in shallower parts of depressions. This concludes that the oil accumulations in the northern cambay basin are a result of short-distance migration (Chowdhary, 2004). The high productivity index (PI) horizon corresponds to the unconformity boundary between the Cambay Shale and Olpad formations and possibly is a hydrocarbon migration channel (Law and Dickinson, 1985 and Hunt, 1996). Reservoir Rocks The clastic reservoir facies deposited within the older Cambay Shale can be classified as deposits associated with transgressive phase or wave/tide/storm dominant deposits. The reservoir rock occurs on lenticular sand bodies for example in South Kadi, Linch area of Ahmedabad Mehsana block. In the northern part of the basin, onset of fluvial system resulted in extensive development of reservoir facies, during synrift phase. The early post-rift phase constitutes the principal reservoir facies (Mohan, 1995). Cap Rocks In the Cambay Basin, the main reservoir rock and oil accumulations are within Upper Eocene-Oligocene age. Tarapur Shale of Upper Oligocene in age, principal cap rock in northern Cambay Basin while Kanwa Shale of Upper Eocene age in southern Cambay Basin. In this basin, Cambay shale of Early Eocene age acts as cap rock for reservoirs within itself and for the underlying Olpad reservoirs, sometimes coal seams acts as cap rocks in Kalol Filed (Chowdhary, 2004). Trap The exploration play system is related with different tectonic episodes of basin evaluation. Palaeocene to Early Eocene rock types constitute the important reservoir facies associated with synrift phase of the basin. These rocks types typically constitute alluvial fan complex along the rift margin and on the low side of the basin bounding listric normal faults close to the basin margin areas. It sometimes juxtaposes with Cambay Shale (Source facies) and lateral petrophysical variation and facies changes help in entrapment of hydrocarbon towards basinal side for example Unawa area in Mehsana Block. The trapping style is broadly classified as structural (fault closure, roll-over anticline, inversion anticlines) and stratigraphic (wedge-out, pinch-out) in nature. Aravali exposures to the north-east of the rift basin constitute the main provenance and sediments deposited by various fluvial systems in the basin resulted in various strati-structural traps. The late postrift structural inversion phase has given rise to a number of structural traps within the Middle Eocene for example Ankleshwar Oil Field (Mohan, 1995). CONCLUSION In Cambay Basin, there are more than 54 oil and gas accumulations which have been discovered. Most of them are structural and combination traps. The easy to find hydrocarbon structural traps have been already drilled. The major challenge is to discover Olpad formation and lower Cambay Shale formation. Integrated study on structural stratigraphy superimposed on tectonic and sedimentation models suggest the zones for deeper prospects to explore. Sophisticated data and synergetic geo-scientific approach are required for such exploration. REFERENCES Banerjee A, Pahari S, Jha M, Sinha AK, Jain AK, Kumar N, Thomas NJ, Misra KN and Chandra K (2002). The effective source rocks in the Cambay basin, India. AAPG Bulletin 86(3) Bhatnagar AK, Rawat DS, Gangoo J, Kausar H, Pande HC, Singh H and Singh RR (2011). Fine Tuning the Petroleum Systems in Western Onshore Basin through Re-evaluation of Source Organics, Depositional Environments and Thermal Maturities of the Oils and Source Rocks, in 2nd South Asian Geoscience Conference and Exhibition Geo-India, New Delhi. Biswas SK (1999). Review of the evolution of rift basins in India during Gondwana with special reference to western Indian basins and their hydrocarbon prospects. PINSA 65(A3) Chand R, Lohani DC, Chatterjee UK, Mehta CH, Singh SP, Anh TN and Yao G (2009). Long-offset depth processing for sub-basalt imaging in West of Bavla area Cambay Basin, Gujarat, India in SEG International Exposition and Annual Meeting
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