http://hdl.handle.net/123456789/10345 Mon, 12 Oct 2026 21:16:35 GMT 2026-10-12T21:16:35Z http://hdl.handle.net/123456789/19033 2-D Seismic Data Interpretation of Qadirpur Area, Pakistan Ammad Ali Tariq Aim of the study is to interpret 2D-Seismic Reflection time section of the Qadirpur Area (Sindh Province) Pakistan. This seismic section is a Pre-stacked time migrated section and was provided by the Department of Earth Sciences, Bahria University Islamabad and this line bears the title 985-QPR-03 It is about 40 Kms in length and is oriented in SW-NE direction. OGDC acquired data in October 1998 and processed it in January 1999. The velocity information is in the form of RMS. DIX interval and DIX average at different times is given, and is provided at selected S.P. RMS velocity varies from 1500 m/s to 5000 m/s Interpreted part of this line from S.P. # 460 to S.P # 720, with CDPs from 920 to 1440 Length of this part of seismic section is 13 Kms. For interpretation of this part of Seismic section, four reflectors and 2 faults are marked on the basis of prominent reflections from subsurface horizons due to changes in lithology and diffractions. Using the RMS velocity given in the velocity panels on seismic section for selected shot points, calculate the time on constant velocity interval of 100m/sec Then using these calculated time and velocity values prepare the Iso-velocity graph and Iso-time graph (for mean line method) by taking constant velocity and time respectively, In Mean line Method of velocity estimation, a velocity vs time graph is prepared. From this graph, a mean average velocity is determined. From Seismic Section, arrival times (two ways) of each marked reflector are determined, Using these arrival times, Time Section is prepared. Also using these arrival times, calculate the average velocity for these times on mean line graph and then the depth of each reflector has been calculated using s(vt)/2 and is represented in Depth Section. Depth Section provides a reliable picture of reflectors and structures present in the subsurface of the area. Well correlation is also done, which satisfy the calculated depths, so horizons have been marked Interpretation of the Project Area shows that, extensional regime and calm environment prevails in the area. Reflectors are almost flat-lying, whereas Horst and Graben structures have been found. Supervised by Mr. Rashid Jamil Sat, 01 Jan 2907 00:00:00 GMT http://hdl.handle.net/123456789/19033 2907-01-01T00:00:00Z http://hdl.handle.net/123456789/21772 Quantitative Reservoir Characterization by Integrating Rock Physics Analysis and Seismic Inversion, Offshore Indus Basin of Pakistan Sarmad Azhar, 01-262232-026 The Offshore Indus Basin, along Pakistan's passive continental margin in the Arabian Sea, holds a thick Cenozoic clastic succession with all the essential petroleum system elements, yet remains lightly drilled and commercially unproven. Conventional seismic interpretation maps structure adequately but cannot uniquely resolve porosity, lithology, and fluid saturation at the resolution exploration decisions require. This study addresses that gap by applying an integrated quantitative reservoir characterization workflow — combining petrophysical evaluation, structural seismic interpretation, modelbased acoustic impedance inversion, and rock physics analysis to a Miocene–Pliocene clastic interval within the basin. The dataset comprises eleven 2D seismic lines and wireline logs from three wells, two of which carry the log suite required for petrophysical evaluation. The reported tops place all three wells on a common chronostratigraphic scheme but are too widely spaced to define reservoir units, so four reservoir intervals were established within that framework by gamma ray and deep resistivity correlation, two in the Late Miocene and two in the Middle Miocene, and all subsequent analysis was conducted within them. Petrophysical analysis in GVERSE yielded shale volume (Larionov non-linear correction), average and effective porosity, and water saturation. Seismic interpretation in Kingdom, calibrated by synthetic seismograms, produced fault and horizon picks and time and depth structure maps for four key horizons. Model-based post-stack inversion in Hampson-Russell was applied to two of the strike lines, SPC-86-9007 and SPC-86-9019, and rock physics crossplots of Vp/Vs against P-impedance, bulk density and S-impedance, colour-coded by computed gamma ray, supplied the litho-fluid discrimination template. The results define a vertically stacked sand–shale system in which reservoir quality is governed principally by clay content. All four intervals are shale-rich when averaged over their gross thickness, with shale volumes of 51 to 77 per cent, and the clay correction reduces average porosities of 21 to 32 per cent to effective porosities of 6 to 11 per cent. Water saturations are high throughout, at 80 to 98.5 per cent. The deeper PakCan-01 interval at 2700–2730 m is the cleanest and returns the highest effective porosity and hydrocarbon saturation, at 10.02 and 20.01 per cent; the two Sadaf-01 intervals return 10.64 per cent hydrocarbon saturation; and the shallower PakCan-01 interval at 1710–1770 m is effectively water-bearing at 1.50 per cent. Inversion, validated by well-tie correlations of approximately 0.99, imaged laterally coherent low-impedance anomalies confined to theviii reservoir interval on both inverted lines and spatially coincident with fault-bounded structural closures persistent across all four mapped horizons. Because the computed water saturations are high and the shale volumes substantial, those anomalies are attributed principally to variation in clay content and porosity rather than to fluid fill, and the crossplots separate the data by lithology more clearly than by fluid. The fluid interpretation therefore remains an inference from elastic response rather than a measurement; pre-stack simultaneous inversion, shear velocity control in more than one well, and 3D coverage are recommended as the next steps. Supervised by Dr Iqbal Hajana Thu, 01 Jan 2026 00:00:00 GMT http://hdl.handle.net/123456789/21772 2026-01-01T00:00:00Z http://hdl.handle.net/123456789/21770 Geochemical Assessment of Mansehra Granite and Associated Pegmatite Veins, Mansehra, Khyber Pakhtunkhwa, Pakistan Ch Fahad Waheed, 09-262242-014 The Mansehra Granite of the Lesser Himalaya, northern Pakistan, represents a peraluminous S-type granitoid emplaced during Cambro-Ordovician crustal magmatism and is spatially associated with pegmatite veins formed during late-stage magmatic evolution. Despite its well-established petrogenetic framework, the wholerock geochemistry and distribution of critical and associated trace elements within the granite-pegmatite system have not been systematically evaluated. This study assesses the geochemical composition and critical mineral potential of the Mansehra Granite and associated pegmatite veins using Inductively Coupled Plasma Mass Spectrometry (ICP-MS). Twenty representative samples, comprising fourteen granite (MG-1 to MG-12) and six pegmatite samples (P-1 to P-6), were collected from Mansehra area. The samples were prepared using aqua regia digestion, and analyzed for major, trace, critical, and rare earth elements. The results are interpreted as aqua-regia extractable concentrations rather than total-rock abundances because aqua regia does not completely dissolve refractory silicate minerals and resistant accessory phases. The results indicate that critical-element enrichment is heterogeneous and primarily concentrated within pegmatites (P-4 to P-6). Pegmatite samples exhibit comparatively higher concentrations of Li, Be, Nb, Ge, Sn, W, Sb, U, and rare earth elements than the host granite. Correlation patterns and normalized geochemical signatures further indicate that accessory mineral fractionation and incompatible-element concentration exerted the primary control on trace-element distribution. Although several pegmatite samples display localized enrichment relative to the host granite, the analytical dataset does not demonstrate the presence of an economically viable rare-metal deposit, and the inferred occurrence of accessory minerals is based solely on geochemical signatures rather than direct mineralogical evidence. Future investigations integrating petrography, scanning electron microscopy (SEM), electron probe microanalysis (EPMA), or laser ablation ICP-MS (LA-ICP-MS) are recommended to verify the mineral hosts of critical elements and further constrain the metallogenic potential of the Mansehra Granite and its associated pegmatite veins Supervised by Dr. Adil Naseer Thu, 01 Jan 2026 00:00:00 GMT http://hdl.handle.net/123456789/21770 2026-01-01T00:00:00Z http://hdl.handle.net/123456789/21771 Hydrocarbon Potential Of Moomba Field, Cooper Basin, South Australia Zeeshan Ahmed, 01-262232-027 Moomba Field lies in the Cooper Basin of southern part of Australia. Cooper Basin is an intracratonic sedimentary basin that formed during the late carboniferous to Early Permian as a result of lithospheric extension followed by differential subsidence, resulting in the formation of interconnected troughs and structural lows. Subsequent thermal sag and moderate compression during the Triassic and Jurassic formed anticlinal and fault-bounded structures that serve as the primary hydrocarbon traps within the basin. The study combines seismic interpretation, petrophysical analysis, 3D reservoir property modeling and geothermal assessment to characterize the geological framework, facies distribution reservoir properties and geothermal regime of the Moomba Field. This study used 3D seismic cube and well log data of Moomba-01, Moomba-50, Moomba-131, Moomba-191, Moomba-225 and Moomba-262. In addition, three-dimensional reservoir models of porosity, water saturation and seismic facies were generated to characterize the spatial distribution of reservoir properties, identify potential reservoir zones and improve subsurface understanding. Detailed seismic interpretation followed by time and depth structure maps all indicate a large, low relief anticlinal feature with in Moomba Field with vertically coherent closures in the Cadnaowie, Toolachee and Patchawarra Formations. This stacked trap geometry is the main way of hydrocarbon concentration in the field. Furthermore, a geothermal evaluation was conducted by creating a three-dimensional model temperature model using well temperature data and combining geothermal gradient, thermal conductivity and heat flow analyses to describe the subsurface thermal conditions and evaluate the geothermal potential of the Moomba Field Supervised by Dr. Muhsan Ehsan Thu, 01 Jan 2026 00:00:00 GMT http://hdl.handle.net/123456789/21771 2026-01-01T00:00:00Z