Petrophysical evaluation and fluid substitution modeling for reservoir depiction of Jurassic Datta Formation in the Chanda oil field, Khyber Pakhtunkhwa, northwest Pakistan

Khan, Natasha; Rehman, Khaista

doi:10.1007/s13202-018-0513-9

Cited by 11 publications

(4 citation statements)

References 27 publications

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“…Previously, the source rock potential of the Datta Formation is established in the adjacent Potwar Basin in the west (Kadri 1995). The Datta Formation is also a proven oil-producing reservoir in the Chanda, Dhulian, Mial and Toot oil fields in Banu, Kohat, and Punjab platform of the Upper Indus Basin (Kadri 1995;Khan and Rehman 2019). The organic-rich shales in the upper part of the Datta Formation and lower part of the Shinawari Formation can be a seal for the sandy reservoir intervals of the Datta Formation.…”

Section: Introductionmentioning

confidence: 99%

Integrating the palynostratigraphy, petrography, X-ray diffraction and scanning electron microscopy data for evaluating hydrocarbon reservoir potential of Jurassic rocks in the Kala Chitta Range, Northwest Pakistan

Ahmad

Wadood

Khan

et al. 2020

J Petrol Explor Prod Technol

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In this paper, we present the palynostratigraphy, petrography, scanning electron microscopy (SEM) and X-ray diffraction (XRD) investigations to evaluate hydrocarbon reservoir potential of the Jurassic clastic-carbonate mixed sequence of the Kala Chitta Range, northwest Pakistan. The chronostratigraphic sub-divisions of the diverse lithologies within the sequence were made by using palynostratigraphy. The clastic dominated sequence of Datta Formation was assigned Toarcian-Bajocian age, while the Shinawari Formation was deposited during the Bajocian-middle Bathonian. The carbonate shoal facies of the Samana Suk Formation showed late Bathonian-Tithonian time of deposition. The primary and secondary porosities augmented by the plug porosity and permeability data suggest that the sandstone of Datta Formation is an excellent reservoir. The dominance of diverse matrix within the Shinawari Formation occluded the primary porosity. However, based on dissolution and dolomitization, the Shinawari Formation is categorized as a moderate reservoir. The dominance of various types of matrix and cement with superimposed burial diagenesis has occluded the primary porosity within the Samana Suk Formation. However, the diagenetic dissolution and dolomitization during the telogenetic stage were supported by the SEM and bulk geochemical data. Such diagenetic overprinting has significantly enhanced the reservoir potential of the unit.

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Section: Introductionmentioning

confidence: 99%

Integrating the palynostratigraphy, petrography, X-ray diffraction and scanning electron microscopy data for evaluating hydrocarbon reservoir potential of Jurassic rocks in the Kala Chitta Range, Northwest Pakistan

Ahmad

Wadood

Khan

et al. 2020

J Petrol Explor Prod Technol

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“…Gassmann's relation methods reflect variations in compressional velocity (Vp) and shear velocity (Vs) velocities with changes in fluid saturations that have simple input parameters. The primary inputs are Vp, Vs, and bulk density, while the matrix bulk modulus (Ko), frame or dry rock modulus (K*), porosity, and the rock shear modulus remain constant during the substitution modelling (Smith et al 2003;Khan and Rehman 2018).…”

Section: Gassmann Fluid Substitution Modellingmentioning

confidence: 99%

“…The integration of petrophysics and rock physics studies is significant in the evaluation of well and field development and to generate subsurface models based on rock properties (Khan and Rehman 2018). The fluid substitution method is an important method for predicting elastic properties of reservoir rocks and their dependence on pore fluid and porosity.…”

Section: Introductionmentioning

confidence: 99%

Petrophysical interpretation and fluid substitution modelling of the upper shallow marine sandstone reservoirs in the Bredasdorp Basin, offshore South Africa

Magoba

Opuwari

2019

J Petrol Explor Prod Technol

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The fluid substitution method is used for predicting elastic properties of reservoir rocks and their dependence on pore fluid and porosity. This method makes it possible to predict changes in elastic response of a rock saturation with different fluids. This study focused on the Upper Shallow Marine sandstone reservoirs of five selected wells (MM1, MM2, MM3, MM4, and MM5) in the Bredasdorp Basin, offshore South Africa. The integration of petrophysics and rock physics (Gassmann fluid substitution) was applied to the upper shallow marine sandstone reservoirs for reservoir characterisation. The objective of the study was to calculate the volume of clay, porosity, water saturation, permeability, and hydrocarbon saturation, and the application of the Gassmann fluid substitution modelling to determine the effect of different pore fluids (brine, oil, and gas) on acoustic properties (compressional velocity, shear velocity, and density) using rock frame properties. The results showed average effective porosity ranging from 8.7% to 16.6%, indicating a fair to good reservoir quality. The average volume of clay, water saturation, and permeability values ranged from 8.6% to 22.3%, 18.9% to 41.6%, and 0.096-151.8 mD, respectively. The distribution of the petrophysical properties across the field was clearly defined with MM2 and MM3 revealing good porosity and MM1, MM4, and MM5 revealing fair porosity. Well MM4 revealed poor permeability, while MM3 revealed good permeability. The fluid substitution affected rock property significantly. The primary velocity, Vp, slightly decreased when brine was substituted with gas in wells MM1, MM2, MM3, and MM4. The shear velocity, Vs, remained unaffected in all the wells. This study demonstrated how integration of petrophysics and fluid substitution can help to understand the behaviour of rock properties in response to fluid saturation changes in the Bredasdorp Basin. The integration of these two disciplines increases the obtained results' quality and reliability.

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“…The structures at most of these fields are thrustrelated anticlines and associated pop-ups which have developed in the Northern Potwar Deformed Zone (NPDZ) of the frontal Himalayas. The main reservoirs consist of Paleogene marine limestones, although reservoir units are also known to occur in Palaeozoic clastics and carbonates (Ahmed et al, 1993;Siddiqui et al, 2003;Anjum et al, 2018), in the Jurassic Datta Formation (Hasany and Saleem, 2001;Khan and Rehman, 2018), and in the Miocene Murree Formation (Khan and Hasany, 1998).…”

Section: Introductionmentioning

confidence: 99%

Ratana Field, Potwar Fold Belt, Northern Pakistan: High Intensity Fracture Zones Related to Major Thrust Faults as Revealed by Seismic Fracture Prediction

Khalid

Zafar

Raja

et al. 2022

Journal of Petroleum Geology

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The Northern Potwar Deformed Zone (NPDZ) of the frontal Himalayas in northern Pakistan hosts many oil and gas fields located in thrust sheets and associated folds. The presence of fractures in Paleogene carbonates at >3 km target depths with very little or no primary porosity is an essential part of reservoir storage and connectivity. Predicting fracture presence, distribution and orientation is therefore key to successful exploration, appraisal and field development in the NPDZ.The Ratana field is an under-developed fractured carbonate reservoir in the NPDZ. Advanced offset vector tile (OVT) PSTM and PSDM processing of a new generation of wide azimuth 3D seismic acquired across the field followed by seismic attribute generation and fracture modelling was used to investigate structural complexities and image fracture networks. Fracture strike characteristics are revealed by PSDM seismic attributes, OVT fracture prediction, FMS/FMI data and structural interpretation across a range of scales. The resulting seismic images show the presence of major WNW-ESE trending back thrusts which cross the field, and predict that steeply-dipping fracture systems are spatially associated with these thrusts. The strike of the OVT-predicted fractures is consistent with the regional trend of the Ratana field bounding thrusts, as well as with the orientation of fractures indicated from FMI/FMS logs. Fractured reservoir is best developed in the Paleocene Patala and Lockhart Formation limestones but is poor in the Eocene Sakesar Formation. Fractured limestone reservoirs occur in the western part of the field where thrust intensity is high, but are less well developed in the gently folded anticline in the eastern part of the field. OVT fracture prediction surface maps are consistent with production data from the field in that areas of high fracture intensity in wells Ratana-2 and Ratana-4 are associated with higher production compared to the less well fractured areas around the Ratana-1and Ratana-3 wells.The advanced seismic acquisition and processing is thus an exceptional example of a step change in seismic imaging at the reservoir and deeper levels, enabling compartment and fracture prediction to provide the Ratana field with a new lease of life. This fracture prediction approach provides a new structural framework for further exploration across the NPDZ and also potentially in other onshore fold-and-thrust belts.

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Petrophysical evaluation and fluid substitution modeling for reservoir depiction of Jurassic Datta Formation in the Chanda oil field, Khyber Pakhtunkhwa, northwest Pakistan

Cited by 11 publications

References 27 publications

Integrating the palynostratigraphy, petrography, X-ray diffraction and scanning electron microscopy data for evaluating hydrocarbon reservoir potential of Jurassic rocks in the Kala Chitta Range, Northwest Pakistan

Integrating the palynostratigraphy, petrography, X-ray diffraction and scanning electron microscopy data for evaluating hydrocarbon reservoir potential of Jurassic rocks in the Kala Chitta Range, Northwest Pakistan

Petrophysical interpretation and fluid substitution modelling of the upper shallow marine sandstone reservoirs in the Bredasdorp Basin, offshore South Africa

Ratana Field, Potwar Fold Belt, Northern Pakistan: High Intensity Fracture Zones Related to Major Thrust Faults as Revealed by Seismic Fracture Prediction

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