Petrophysical analysis of well logs for reservoir evaluation: a case study of “Kadanwari” gas field, middle Indus basin, Pakistan

Ali, Muhammad; Khan, Muhammad Jahangir; Ali, Mubarik; Iftikhar, Shaista

doi:10.1007/s12517-019-4389-x

Cited by 26 publications

(19 citation statements)

References 9 publications

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“…lower parts and is considered as the main reason for the formation of structural traps within the SGF [42,43]. The Ranikot formation of the Paleocene pinched-out along JKH and caused the initial uplifting of the JKH.…”

Section: Stratigraphic and Structural Characteristics Of The Study Areamentioning

confidence: 99%

“…The Paleocene Ranikot clastics consist of detrital and carbonaceous sediments [41] pinches-out along the Khairpur-High that initiated the uplifting process. The JKH distributes the Indus Basin into the middle and lower parts and is considered as the main reason for the formation of structural traps within the SGF [42,43]. The Ranikot formation of the Paleocene pinched-out along JKH and caused the initial uplifting of the JKH.…”

Section: Stratigraphic and Structural Characteristics Of The Study Areamentioning

confidence: 99%

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Controls on Reservoir Heterogeneity of a Shallow-Marine Reservoir in Sawan Gas Field, SE Pakistan: Implications for Reservoir Quality Prediction Using Acoustic Impedance Inversion

Ashraf

Zhang

Anees

et al. 2020

Water

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The precise characterization of reservoir parameters is vital for future development and prospect evaluation of oil and gas fields. C-sand and B-sand intervals of the Lower Goru Formation (LGF) within the Lower Indus Basin (LIB) are proven reservoirs. Conventional seismic amplitude interpretation fails to delineate the heterogeneity of the sand-shale facies distribution due to limited seismic resolution in the Sawan gas field (SGF). The high heterogeneity and low resolution make it challenging to characterize the reservoir thickness, reservoir porosity, and the factors controlling the heterogeneity. Constrained sparse spike inversion (CSSI) is employed using 3D seismic and well log data to characterize and discriminate the lithofacies, impedance, porosity, and thickness (sand-ratio) of the C- and B-sand intervals of the LGF. The achieved results disclose that the CSSI delineated the extent of lithofacies, heterogeneity, and precise characterization of reservoir parameters within the zone of interest (ZOI). The sand facies of C- and B-sand intervals are characterized by low acoustic impedance (AI) values (8 × 106 kg/m2s to 1 × 107 kg/m2s), maximum sand-ratio (0.6 to 0.9), and maximum porosity (10% to 24%). The primary reservoir (C-sand) has an excellent ability to produce the maximum yield of gas due to low AI (8 × 106 kg/m2s), maximum reservoir thickness (0.9), and porosity (24%). However, the secondary reservoir (B-sand) also has a good capacity for gas production due to low AI (1 × 107 kg/m2s), decent sand-ratio (0.6), and average porosity (14%), if properly evaluated. The time-slices of porosity and sand-ratio maps have revealed the location of low-impedance, maximum porosity, and maximum sand-ratio that can be exploited for future drillings. Rock physics analysis using AI through inverse and direct relationships successfully discriminated against the heterogeneity between the sand facies and shale facies. In the corollary, we proposed that pre-conditioning through comprehensive petrophysical, inversion, and rock physics analysis are imperative tools to calibrate the factors controlling the reservoir heterogeneity and for better reservoir quality measurement in the fluvial shallow-marine deltaic basins.

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Section: Stratigraphic and Structural Characteristics Of The Study Areamentioning

confidence: 99%

Section: Stratigraphic and Structural Characteristics Of The Study Areamentioning

confidence: 99%

Controls on Reservoir Heterogeneity of a Shallow-Marine Reservoir in Sawan Gas Field, SE Pakistan: Implications for Reservoir Quality Prediction Using Acoustic Impedance Inversion

Ashraf

Zhang

Anees

et al. 2020

Water

Self Cite

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“…Seismic attributes such as dip magnitude, edge enhancement, variance edge, sweetness, and root mean square (RMS) amplitude are essential tools for delineating structural and stratigraphic characteristics, lithofacies changes, and hydrocarbon potential zones (Azeem et al, 2016;Ashraf et al, 2019;Manzi et al, 2020;Naseer, 2021b). On the other hand, petrophysical modeling plays an essential role in reservoir characterization, especially in discriminating the non-hydrocarbon and hydrocarbon bearing intervals (Hussain et al, 2017;Ali et al, 2019;Raza et al, 2020;Abdeen et al, 2021). Due to the depth measure error, observation and analysis of the core samples taken from the subsurface formations have a lot of limitations in reservoir properties assessment.…”

Section: Introductionmentioning

confidence: 99%

“…The Middle Indus Basin (MIB) and Lower Indus Basin (LIB) are well known for hydrocarbon reserves in Pakistan (Ali et al, 2019). The Kadanwari eld in MIB is a signi cant hydrocarbon producing area with early-late Cretaceous Lower Goru formation (LGF) acting as the potential reservoir.…”

Section: Introductionmentioning

confidence: 99%

Three-dimensional Structural Modeling (3D SM) and Joint Geophysical Characterization (JGC) of Hydrocarbon Reservoir: A Case Study of the Kadanwari field in Middle Indus Basin (MIB), Southeastern Pakistan

Khan

Hussain

et al. 2022

Preprint

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Complex structural geology generally leads to significant consequences for hydrocarbon reservoir exploration that needs a comprehensive methodology for complete comprehension. Despite a large number of existing wells in the Kadanwari field, Middle Indus Basin (MIB), southeastern Pakistan, the depositional environment of the Early Cretaceous stratigraphic sequence is still poorly understood, which has implications for regional geology as well as economic significance. To improve the understanding of depositional environment of complex heterogeneous reservoirs with associated 3D stratigraphic architecture, spatial distribution of facies and properties, and hydrocarbon prospects, a new methodology of three-dimensional structural modeling (3D SM) and joint geophysical characterization (JGC) is introduced in this research. JGC makes use of seismic interpretation-aided 3D SM, 3D seismic attributes analysis coupled with petrophysical modeling using 3D seismic reflection, and borehole data. Subsequently, the 3D SM reveals that the Kadanwari field experienced multiple stages of complex deformation dominated by NW to SW normal fault system, high relief horsts, half-graben, and graben structures. 3D SM and 3D fault system models (FSMs) further depict that the middle part of the sequence experienced more deformation compared to the surroundings of major faults with predominant oriented in S30°-45°E and N25°-35°W, azimuth as 148°–170° and 318°–345°, minimum (28°), mean (62°), and maximum (90°) dip angles. The applied variance edge attribute better portrays the inconsistency of the seismic data associated with faulting and estimated high reflection sediments presumed to be potential hydrocarbon traps. The high amplitude and loss of frequency anomalies of sweetness and root mean square (RMS) amplitude attributes represent cleaner and payable sand-rich shoreward facies revealing gas saturated sand, while relatively low amplitude and high-frequency anomalies indicate sandy shale, shale, and pro-delta facies, unfavorable zones for gas potential. The quantitative petrophysical modeling result shows that E sand interval has good effective porosity (∅ eff ) and hydrocarbon saturation (S hc ) compared to G sand interval. The derived average petrophysical properties, such as volume of shale (V shale ), average porosity (∅ avg ), ∅ eff , water saturation (S W ), and S hc of the E sand interval are 30.5%, 17.4%, 12.2%, 33.2%, 70.01%, respectively. The newly introduced 3D SM and JGC workflow is an effective tool for highlighting potential areas of high quality reservoir development.

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“…That is because fractures play a vital role in enhancing the permeability of reservoirs with the low matrix porosity property (ranging from 2 to 6% based on the logging interpretation). A better understanding of the pores complexity, faults, and fractures in Gaoshiti-Moxi area can lead to better understanding of pore characteristics (Mangi et al 2020) and grain size analysis (Zhang et al 2020(Zhang et al , 2021a(Zhang et al , 2021b, which in turn can be used to develop a rock physics model (Ali et al 2020), hydrocarbon potential assessment (Anees et al 2017;Abbas et al 2019) and to evaluate the porosity (Ali et al 2019(Ali et al , 2021. Nevertheless, highly developed fractures can also be related to the water production of drilled wells (Shahab et al 2018).…”

Section: Introductionmentioning

confidence: 99%

Sweet spots prediction through fracture genesis using multi-scale geological and geophysical data in the karst reservoirs of Cambrian Longwangmiao Carbonate Formation, Moxi-Gaoshiti area in Sichuan Basin, South China

Ren

Zhao

et al. 2021

J Petrol Explor Prod Technol

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Fractures play a vital role in reservoir transformation, but the distribution of faults and fractures is difficult to obtain by observing cores, which ultimately limits the effective development of gas dolomite reservoirs. We propose an integrated method that incorporates thin-section observations, three-dimensional (3D) seismic data, and image logs to interpret the distribution of faults and fractures of Cambrian Longwangmiao Carbonate Formation to predict potential development areas in the Moxi-Gaoshiti area of the Sichuan Basin, South China. Firstly, the faults were well interpreted by using the automatic tracking and 3D visualization technique based on the new seismic combination attribute of symmetry and ant tracking. Secondly, a comprehensive analysis was conducted using the thin sections, paleogeomorphology, and in situ test results to determine the fracture types (corrosion and structural fractures). The results help us to find potential sweet spot zones with good permeabilities, which is of great significance in reducing the risk of water production of drilled wells in the field development.

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Petrophysical analysis of well logs for reservoir evaluation: a case study of “Kadanwari” gas field, middle Indus basin, Pakistan

Cited by 26 publications

References 9 publications

Controls on Reservoir Heterogeneity of a Shallow-Marine Reservoir in Sawan Gas Field, SE Pakistan: Implications for Reservoir Quality Prediction Using Acoustic Impedance Inversion

Controls on Reservoir Heterogeneity of a Shallow-Marine Reservoir in Sawan Gas Field, SE Pakistan: Implications for Reservoir Quality Prediction Using Acoustic Impedance Inversion

Three-dimensional Structural Modeling (3D SM) and Joint Geophysical Characterization (JGC) of Hydrocarbon Reservoir: A Case Study of the Kadanwari field in Middle Indus Basin (MIB), Southeastern Pakistan

Sweet spots prediction through fracture genesis using multi-scale geological and geophysical data in the karst reservoirs of Cambrian Longwangmiao Carbonate Formation, Moxi-Gaoshiti area in Sichuan Basin, South China

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