Introduction

Seismic data, its integration with wells and geological data are consistent tool for subsurface geological depiction (Moghal et al. 2007; Ghazi et al. 2014; Riaz et al. 2018, 2019; Abid et al. 2019, 2020). An integrated approach is crucial for petroleum exploration and subsurface interpretations. It assists in tracing the subsurface geological structures and establishing reliable correlations. A precise identification of the subsurface geological perspectives and structures is vital for hydrocarbon probe, and it delivers a perception about the framework and structural styles of a basin. Furthermore, interplay between shortening and shear has imperative implications for location of traps and their preservation. These seismic and surface data along with site of hydrocarbon fields portray substantial clue that might be valuable for upcoming exploration in Kirther Foredeep and adjoining areas.

The Zamzama gas field was discovered in Sindh province, Pakistan, covering an area of around 120 km2 and ranked fourth major discovered gas field of Pakistan. Geologically, Zamzama gas field is located in the Kirther Foredeep, Southern Indus Basin, approximately 200 km North of Karachi and 8 km west of the existing Sui-Karachi pipeline (Fig. 1). The Bhit gas field lies to the southwest and the Kadanwari, Sawan and Miano fields to the northeast of Zamzama filed. The Zamzama gas field was first explored in late 1950s drilled Phulji-1 and Phulji-2 wells (Jackson et al. 2004), and target was oil bearing carbonates of the Tertiary strata. Both wells were ensued dry because, gas bearing the Cretaceous to Paleocene Pab and Khadro reservoir could not penetrated. The inefficient results were reexamined with further seismic data (Quadri and Quadri 1998) and it was realized that Phulji-1 well was abandoned before few meters of the Pab reservoir. Later on the new research by various workers presented the overall structural style and the mechanics of deformation on the basis of integrated borehole and seismic data (Lillie et al. 1987; Jaume and Lillie 1988; Pennock et al. 1989; Treloar et al. 1992; Grelund et al. 2002). These innovative approaches were applied to Zamzama area and an exhaustive 2D seismic survey carried out about an area of 196 km that produced seven productive wells (Fig. 1). This paper reveals a comprehensive seismic model that evaluates petroleum play of the Zamzama Field primarily based on seismic data. It suggests a predictable model about substructure and surface stratigraphic architecture to explore future hydrocarbon reservoir.

Fig. 1
figure 1

Tectonic map of Pakistan and the divisions of Indus Basin (modified after Kadri 1995). The red rectangle shows the study area. The inset figure shows the complete Zamzama structure that comprises of hanging wall and footwall structures (modified after Jackson et al. 2004). The Zamzama East-1 separates the southern and northern strands of the main thrust

Full size image

Methodology

Subsurface data were employed to interpret the structure of the Zamzama area, which was obtained from land mark resources (LMKR) with the permission of Directorate General of Petroleum Concessions (DGPC), Ministry of Petroleum and Natural Resources, Islamabad, Pakistan. The data consist of three wells (Zamzama-02, 03, and 05) and eight seismic lines (796-JH-01, 02, 03, 07, 10, GHPK-98A-32, 34 and 40). These wells; Zamzama-02, Zamzama-03, and Zamzama-05 are located at coordinates 26° 42′ 17.13″ 67° 40′ 06.59″, 26° 40′ 32.15″ 67° 39′ 16.25,″ and 26° 40′ 3.565″ 67° 40′ 14.20,″ respectively. Seismic and well data were interpreted through Kingdom Suite software 8.2 (SMT). For structural as well as stratigraphic interpretation, six prominent reflectors (top of the Kirthar, Ghazij, Laki, Dunghan, Pab and Chiltan formations) were marked on the seismic lines which were correlated with well tops to confirm the position of marked reflectors and were allotted a specific age (Table 1). The Chiltan Formation was the most prominent horizon that helps to mark the faults. Furthermore, time contour map on top of the Pab Formation was generated to define the structural trend and deformation style.

Table 1 Showing well tops which were correlated with seismic lines to mark the reflector for the interpretation of structure and stratigraphic succession
Full size table

Geological setting

Zamzama gas field lies in Kirthar Foredeep, Southern Indus Basin, which is separated from Central Indus basin at Marri-Kandhkot high (Kadri 1995; Kazmi and Abbasi 2008). The North–South oriented Kirthar Foredeep trough, subducted by the evolving Kirthar fold and thrust belt (Kazmi and Rana 1982; Kazmi and Jan 1997), developed in consequence of collision between Indian and Eurasian plates through Mio–Pliocene to recent times (Powell 1979). The study area corresponds to western part of Kirthar Foredeep, which is marked by Jacobabad Mari Kandhkot high toward its North and in South it has Hyderabad high and eastward limited by Nabisar Slop and Tharparkar high (Fig. 1).

During the Middle Jurassic (Bathonian/Callovian), the carbonates of the Chiltan Formation were deposited in a stable shelf platform followed by extension and consequent fault block rotation in the Late Jurassic (gentle) causing development of good reservoir within shoals/karstified area (Kemal 1991; Kadri 1995; Fig. 2). The Late Jurassic to Early Cretaceous Gondwana continued to split that caused the interior of the Indian Plate to be uplifted gently (Powell 1979), and ultimately the carbonate platform of the Middle Jurassic was replaced by shales and sandstones of shallow marine to deltaic settings (Sembar and Goru formations). Indo-Pak plate separated from Madagascar during the Late Cretaceous, and north-western part of the Indian plate passed over the Reunion hot spot, which resulted in eruption of the Deccan Trap (Khadro Formation) (Powell 1979). The said events are once again responsible for uplifting of the interior of the Indian plate and then replacement of carbonate platform by clastic sediments (Kazmi and Abbasi 2008; Shah 1977, 2009). Sinistral transpression developed by the Paleocene times along the western border of the Indus Basin that reached a point where inversion of the previously deposited sequences took place (Meissner and Rahman 1973; Kadri 1995). Meanwhile, deposition of carbonates resulted from comparatively calm conditions on the passive margin settings in North (Meissner and Rahman 1973; Shah 1977, 2009). The Eocene strata are perceived extensively, while mostly Oligocene sediments are missing. A thick pile of the Miocene to Recent molasses sediments developed attributable to less influence of Himalayan Orogeny (Kazmi and Rana 1982; Kazmi and Jan 1997; Shah 1977, 2009; Fig. 2).

Fig. 2
figure 2

Generalized stratigraphic succession of the Zamzama field, Southern Indus Basin, Pakistan (modified after Abbasi et al. 2016; Zafar et al. 2018)

Full size image

Petroleum system

The Miocene–Pliocene 15,000 m thick molasses sediments filled that extends North–South. Miocene to Recent (Siwalik) sediments dips gently and thickens westwards toward the axis of the Foredeep. The Eocene strata deposited but become thinner at Jacobabad-Khairpur high, further, Oligocene succession is absent here. The Mari, Khairpur, and Mazarani wells indicate the presence of the Paleocene and the absence of the Upper Cretaceous strata in the Kirthar Foredeep. Moreover, the Mesozoic and the Paleocene sequences also dip and thicken in the same direction as the foreland basin sequence. The central part of the Foredeep is covered by Quaternary alluvium. The greater thickness of sediments in the depression may provide good impact on the maturation to younger rocks, especially the Eocene oil shale (Siddiqui 1992; Siddiqui and Khan 1992; Kadri 1995). The western flank of the Foredeep was established as a petroleum province when commercial gas discovery was made in Upper Cretaceous sandstone (Pab Formation) (Kadri 1993, 1995; Fig. 3).

Fig. 3
figure 3

Structure contours map on top of Pab Formation, Zamzama gas field, Southern Indus Basin, Pakistan. Red lines indicate the faults, blue shows the contours, and black lines show the seismic lines

Full size image

The Cretaceous shales of the Sembar and the Goru formations are considered as a main source rock in the Zamzama field. The Sembar Formation was deposited in marine environments over major part of Southern Indus Basin (Kazmi and Abbasi 2008; Shah 2009). Total organic carbon (TOC) of the Sembar Formation range from 0.5 to 3.5% and it has Type-III kerogen that generate gas (Kadri 1995). Additionally, regional maturity suggests that these values lie just above the main oil window, a fact validated by the Rock–Eval T max values which are in between 431 °C and 437 °C (Kemal 1991; Kadri 1995). However, the Goru Formation also reveals a source quality in the Talhar Shale. There are significant TOC contents, and pyrolysate yields of up to 3.58 kg Py/t rock (Kadri 1995). Regional maturity modeling and T max indicate the late mature stage for oil generation (Kemal 1991; Jamil et al. 2012). These evidences also suggest the presence of both oil-prone and gas-prone sediments within the Goru Formation. The Lower Goru Formation was deposited as a regionally extensive fluvio-deltaic system over the entire Southern Indus Basin that comprises terrestrial organic matter which is the main source of oil generation (Kemal 1991; Siddiqui 1992; Kadri 1995; Kazmi and Abbasi 2008; Jamil et al. 2012).

The upper Cretaceous Pab Formation mainly comprises of sandstone that act as reservoir. The formation is well-developed in the Kirthar Foldbelt, however, truncate in East of the Zamzama gas field. It forms an important reservoir unit in the West of the Kirthar area (Jackson et al. 2004). Previously it was not considered to represent a significant reservoir target although it is proven in study area (Zamzama gas field). Beside sandstone it also contains silty mudstones. The base of formation is easily defined in East, whereas in the West thick massive turbiditic sandstones of the Pab Formation make unconformable contact with basinal limestone of the Mughalkot Formation. Moreover, the typical sand-body geometry of progradational delta sequences is dependent to some degree on the relative dominance of fluvial versus wave/tide processes. Stream dominated deltas are typically elongate and lozenge shaped, while wave/tide dominated deltas with a stronger “shoreface” character are elongate parallel to basin margins with a typical beach-ridge geometry (Blair and McPherson 1994; Reading 1996). Therefore, sandstones are interpreted as reservoirs of the Pab Formation in the Kirthar deltaic or deep marine turbidite fan.

Pab and Khadro have intraformational seals. The Lower Ranikot covers both Pab and Khadro formations (Fig. 2b) and considered as finest seal. However, the Pab Formation is sandy and may poorly act as a seal due to sand-body interconnectivity, whereas in some areas of South it underlies the Khadro Formation which may act as an appropriate seal. The Khadro Formation contains a rather poor intraformational seal but base of the formation may act an effective seal at underlying horizons, but internal mudstones are not very thick or laterally extensive. The overlying Lower Ranikot has a good basal muddy horizon in some areas where it acts as a seal rock for the Pab/Khadro formations. Moreover, in same region sandstones at the base of the Ranikot Formation are good reservoir which may be migrated upper sandy part of the Ranikot Formation and intraformational shale would acts as seal for migrating hydrocarbon.

Results and discussion

Subsurface stratigraphic and structural traps are possibly occurred in the study area. However, seismic data in conjunction with surface geology were interpreted to establish the structural styles which are very important for the exploration of hydrocarbons.

Seismic interpretation

Seismic signatures, continuous, parallel reflectors of medium and high amplitude are marked throughout the section from 400 to 3400 ms that covered mainly by the Eocene and the Pliocene strata (Figs. 4a–d, 5a–d). These reflectors are almost smooth and parallel except the fault planes where they show the distortions. These distortions are also helpful in defining different faults along the seismic sections. Conversely, sections below 2800 ms reveal discontinuous, semi-parallel reflectors of medium and high amplitude and low frequency. However, above 2800 ms time range it delivers a hint to define decollement.

Fig. 4
figure 4

shows the six prominent marked reflectors on the seismic cross section, Zamzama gas field, Southern Indus Basin, Pakistan. a Seismic line 796-JH-01 shows the horse structure. b Seismic line 796-JH-02 exhibits the continuous reflectors. c Seismic line 796-JH-03 displays a fault on the eastern side of the cross section. d Seismic line 796-JH-07 shows the normal fault

Full size image
Fig. 5
figure 5

The six prominent marked reflectors on the seismic cross section, Zamzama gas field, Southern Indus Basin, Pakistan. a Seismic line 796-JH-10 displays the extension of fault into Jurassic strata. b Seismic line GHPK-98A-32 shows a major fault along with minor fault. c Seismic Line GHPK-98A-34 exhibits the presence of major and minor faults in the entire strata. d Seismic line GHPK-98A-40 shows the two faults that run into Jurassic strata

Full size image

The seismic section depicts two prominent structures i.e. Zamzama in South and Mehar in North of study area. Zamzama Structure relatively shallower than Mehar Structure but both are separated by a broad syncline. Seismic sections show that investigated area comprises of North–South orientated anticlines (Fig. 4d), deformed by westward dipping thrust faults having throw of more than a hundred meter near the core of structure (Figs. 5b–d). Moreover, two minor faults (thrust and back thrust) having throw of few meters are also present on the western side of the hanging wall (Figs. 5b–d). Shale of the Cretaceous age seems to be provided the decollement for these reverse faults. Seismic section also suggests some normal paleo-faults of rifting time below the Chiltan Formation (Fig. 5a). The base of the Tertiary reflector indicates unconformity, which is easily recognizable in the structure of eastern side (Figs. 4d, 5a–d). However, in West unconformity is not easily identified due to associated compressional faulting and distortion of the seismic character. Deccan volcanoes also distort the picking of the reflector due to its high amplitude and lateral extent. The Tertiary base is taken as a base reflector in this area due to high amplitude unit.

Pab Formation is generally thin around the Zamzama area and is eroded by unconformity in the base of the Tertiary (Figs. 5b–d). It is picked around Zamzama above a high amplitude reflector (Figs. 4a, c, d, 5a) and appears to be conformable with the underlying units apart from where it is thrusted out.

The top of the Chiltan Formation is generally picked along a high amplitude reflector, and around Zamzama area it is overlain by horizons of less continuity and lower amplitude. In North however, the horizon is picked along a semi-continuous high amplitude reflector within a low amplitude homogenous zone with high amplitude continuous reflects above and below (Figs. 4a–d, 5a–d). This is due the unconformable nature of the horizon.

Structural model

Structure was also interpreted by generating three east–west oriented seismic sections. (796-JH-03; Fig. 6a, 796-JH-10; Fig. 6b, 796-JH-01; Fig. 6c) by using the interval velocities passing along Zamzama North structure. The structural interpretation shows undisturbed sequence down to the Late Triassic by normal faulting or extensional tectonics (Figs. 6a, b).

Fig. 6
figure 6

a Geo-seismic model along seismic line 796-JH-03 that shows the penetration of fault into cretaceous sediments. b Geo-seismic model along seismic line 796-JH-10 that form pop-up structure. c Geo-seismic model along the seismic line 796-JH-01 that displays the normal and extensional faults

Full size image

Jurassic fault trends throughout the Southern Indus Basin are generally orientated NNW–SSE (Fig. 6b). Strike-slip behavior is noted along some of these NNW-SSE trending Jurassic and Cretaceous faults in those areas which are close to the fold belt. Tertiary strike-slip faulting reactivates Jurassic faults (Ahmed et al. 1992; Quad and Quadri 1996). The Jaisalmer area of the Southern Indus Basin, Rajasthan India and extends across the border into Pakistan to the Mari and Sui gas fields, is controlled by strike-slip tectonics (Sharma 2006) that initiated in the Jurassic. The Late Jurassic and Cretaceous seem to be time of normal faulting along the west coast of the Indian Plate, with ~ N–S trending rift systems in the region (Fig. 6b).

The Cretaceous faults in the Southern Indus Basin trend dominantly NNW-SSE and have previously been attributed to a failed Cretaceous to Paleocene rifting episode (Figs. 6b, c). Seismic data suggest, however, that these faults developed around the Cretaceous–Tertiary boundary. Many faults stop at the base of Tertiary unconformity, but a small number of them extend upward at the base of Tertiary. Additionally, majority of them show the characteristics of normal and transtentional structures (Figs. 6b, c). Similar normal faults (horst and graben structures) described by Wasimuddin et al. (2005) in Thar platform area of Southern Indus Basin.

The study area appears to be deformed by sinistral tectonism, happened between the Indian and the Eurasian plates, probably producing reversal of the earlier sequences by the Paleocene, with obduction of the Bela ophiolite. It is probable that gentle folding in the area was related to this emplacement event. Aitchison et al. (2007) suggested main contraction in the middle Miocene which is the result of continent–continent collision between Indian and Eurasian plates, which is clarify the present interpretation (Figs. 4b–d, 5a, b). The immediate effects of this Oligocene to Recent contraction were most strongly occurred close to the margins of the Kirthar and Sulaiman Fold Belts (Ahmed et al. 1992). Present interpretation shows that the area is deformed by the transpression in passive roof thrust duplex fashion (Figs. 6a–c) and reactivation of previously normal Mesozoic faults as high-angle reverse faults possibly a feature of the fold belt which is thrusted over thick, dip gently the molasses within the Kirthar Foredeep. Regional geo-seismic model (Figs. 6a–c) shows that fold-thrust structure has developed along with transpressive tectonics. The folding, thrusting, and development of passive roof thrust-related structure in the frontal foldbelt, seems to be late Tertiary in age. The rocks are deformed by the transpression with very low intensity in the eastern part of study area and anticlines are developed in the post Triassic rocks through some strike-slip faulting. To the west, passive back thrust duplex geometry is developed, the roof thrust run in Cretaceous while floor thrust lying in the Permian/older rocks (Fig. 6c). Horses between the roof and floor thrusts are the suitable features having the > 5 km width and may be provide trapping geometries for the accumulation of hydrocarbons.

Conclusions

The stratigraphy and structural deformation favours the effective petroleum system in area as revealed by this study and which is proven by the presence of discoveries in the area. The seismic structure indicates a 4 km wide north anticline that intercepted by a well-developed reverse fault in the south of study area, whereas northern anticline of the area depicting a low or synclinal area that gets deeper trends toward west. Seismic cross sections also depict the apparently normal faults that stop at or near the base of Tertiary unconformity with very low throw which clarify their occurrence before the deposition of the Tertiary base. Geo-seismic model shows the evidences of deformation due to transpression with very low intensity in the eastern part of study area, and anticlines are developed in the post Triassic rocks through some strike-slip faulting. To the west passive back thrust duplex geometry is developed, the roof thrust run in Cretaceous while floor thrust lying in the Permian/older rocks. These thrusts are the suitable features that provide trapping geometries for the accumulation of hydrocarbons. Furthermore, study area fulfils all requirements for the accumulation of hydrocarbon. The uppermost Cretaceous Pab Formation represents a significant reservoir rock. Sember and Goru formations are the main source rocks which exhibit high ratio of waxy pristane/phytane that indicate main source of oil generation. Moreover, upper part of the Pab, the Khadro, and the Ranikot formations, acting as a cap rock in the Zamzama field.