Reservoir Characterization of Basal Sand Zone of Lower Goru Formation by Petrophysical Studies of Geophysical Logs

Hussain, M.; Ahmed, Nisar; Chun, Wang; Khalid, Perveiz; Mahmood, Azhar; Ahmad, Sajid Rashid; Rasool, Umair

doi:10.1007/s12594-017-0614-y

Cited by 25 publications

(14 citation statements)

References 10 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…To estimate the shaliness in the reserorvoir zones of Habiganj Gas Field, natural gamma-ray (GR) log is used. (Hussain et al, 2017) The clean sand or minimum gamma-ray and shale value or maximum gamma-ray are chosen for each zone for shale volume evaluation by observing the gamma-ray log.…”

Section: Shale Volume Calculationmentioning

confidence: 99%

Petrophysical Reservoir Characterization of Habiganj Gas Field, Surma Basin, Bangladesh

Shreya

Bhuiyan

Hossain

et al. 2021

Dhaka Univ J Earth Env Sci

View full text Add to dashboard Cite

The previous studies on the petrophysical and volumetric analysis of Habiganj gas field were based on limited well data. As the accuracy of volumetric analysis relies greatly on petrophysical parameters, it is important to estimate them accurately. In this study we analyzed all eleven wells drilled in the Habiganj field to determine the petrophysical parameters. Analysis of the well logs revealed two distinct reservoir zones in this field termed as upper reservoir zone and lower reservoir zone. Stratigraphically, these two reservoir zones are in the Bokabil and Bhuban Formation of Surma Group. Petrophysical analysis shows significant differences between the two zones in terms of petrophysical parameters. Porosity in the upper reservoir zone ranges from 12% to 36%, with an average of 28%. This zone is highly permeable, as indicated by the average permeability of 500 mili Darcy (mD). The average water saturation in this zone is around 18% suggesting high gas saturation. The lower reservoir zone has an average porosity, permeability, and water saturation of 12%, 60mD, and 43%, respectively, indicating poor reservoir quality. An analysis of log motifs indicates that the upper reservoir zone is composed of stacked sands of blocky pattern. The sands in this interval are clean, as indicated by the lower shale volume of 12-15%. The average thickness of this zone is 230m, and the presence of this zone in all the drilled wells suggests high lateral continuity. The lower reservoir zone consists of sand bodies of serrated pattern. The sands have high shale volume and are laterally discontinuous. Overall, the upper reservoir zone has superior petrophysical properties to the lower reservoir zone. Although the reservoir quality of the lower reservoir zone is poorer than that of the upper zone, this zone can be considered as the secondary target for hydrocarbon production. Petrophysical parameters of this study were estimated from all the eleven wells drilled in this field; hence the values are more accurate. The reported values of the petrophysical parameters in this study are recommended to use to re-estimate the reserves in Habiganj field. The Dhaka University Journal of Earth and Environmental Sciences, Vol. 10(1), 2021, P 1-10

show abstract

Section: Shale Volume Calculationmentioning

confidence: 99%

Petrophysical Reservoir Characterization of Habiganj Gas Field, Surma Basin, Bangladesh

Shreya

Bhuiyan

Hossain

et al. 2021

Dhaka Univ J Earth Env Sci

View full text Add to dashboard Cite

show abstract

“…The shale volume was calculated from the single log (gamma ray and resistivity) and double log indicators (combination of neutron and density log) [20]. Additionally, zoning of the shale zone was conducted to delineate the reservoir sand zone from the non-reservoir zone to prevent the overestimation of porosity and water saturation [21]. The minimum results of the indicators were then chosen from the three shale indicators of gamma ray, neutron-density, and resistivity.…”

Section: Sedimentological and Petrographical Analysismentioning

confidence: 99%

Integrated Reservoir Characterization Study of the McKee Formation, Onshore Taranaki Basin, New Zealand

2018

View full text Add to dashboard Cite

The Late Eocene onshore McKee Formation is a producing reservoir rock in Taranaki Basin, New Zealand. An integrated petrophysical, sedimentological, and petrographical study was conducted to evaluate the reservoir characteristics of the McKee sandstone. A petrographic study of the McKee Formation classified the sandstone as arkose based on the Pettijohn classification. Porosity analysis showed predominantly intergranular porosity, as elucidated by the thin section photomicrographs. The good reservoir quality of McKee sandstone was suggested to be the result of the presence of secondary dissolution pores interconnected with the primary intergranular network. Mineral dissolution was found to be the main process that enhanced porosity in all the studied wells. On the other hand, the presence of clay minerals, cementation, and compaction were identified as the main porosity-reducing agents. These features, however, were observed to occur only locally, thus having no major impact on the overall reservoir quality of the McKee Formation. For a more detailed reservoir characterization, well log analysis was also applied in the evaluation of the McKee Formation. The result of the well log analysis showed that the average porosity ranged from 11.8% to 15.9%, with high hydrocarbon saturation ranging from 61.8% to 89.9% and clay volume content ranging from 14.9 to its highest value of 34.5%. Based on the well log analysis, the derived petrophysical and reservoir parameters exhibited good porosity, low clay content, and high hydrocarbon saturation, which indicates that the McKee Formation is a promising reservoir.

show abstract

“…Employing more than one tool to derive a consistent answer enables both precision and accuracy. Therefore, reservoir characterization (e.g., evaluation of structural and stratigraphic features, distribution of associated petrophysical properties and facies) can be better comprehended by employing integrated seismic interpretation-aided 3D structural modeling (SM), 3D seismic attribute analysis, and petrophysical modeling (Czoski, 2014;Hussain et al, 2017;Li et al, 2018;Ashraf et al, 2019;Bodunde and Enikanselu, 2019;Radwan, 2021;Radwan et al, 2021;Thota et al, 2021). 3D SM is divided into the entity-based modelling and volume-based modelling (Houlding, 1994;Lajaunie et al, 1997;Mallet, 2002;Wu et al, 2005;Zhang et al, 2018;Wang et al, 2019).…”

Section: Introductionmentioning

confidence: 99%

“…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 Kadanwari eld in MIB is a signi cant hydrocarbon producing area with early-late Cretaceous Lower Goru formation (LGF) acting as the potential reservoir. Many researchers used different techniques on distinct parts of reservoir characteristics of most promising hydrocarbon formations in Pakistan and primarily focused on the MIB and LIB (Kadri, 1995;Ahmad and Chaudhry, 2002;Ahmad et al, 2004;Munir et al, 2011;Ahmed et al, 2013;Azeem et al, 2016;Saif-Ur-Rehman et al, 2016;Hussain et al, 2017;Khan and Khan, 2018;Ali et al, 2019;Ashraf et al, 2019;Raza et al, 2020;Saif-Ur-Rehman et al, 2020;Ahmad et al, 2021;Naseer, 2021a). The regional subsurface structural style, such as orientation, geometry, and development of the fault system of the Miano and Kadanwari areas in MIB was evaluated by (Saif-Ur-Rehman et al, 2020).…”

Section: Introductionmentioning

confidence: 99%

See 1 more Smart Citation

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

View full text Add to dashboard Cite

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.

show abstract

Reservoir Characterization of Basal Sand Zone of Lower Goru Formation by Petrophysical Studies of Geophysical Logs

Cited by 25 publications

References 10 publications

Petrophysical Reservoir Characterization of Habiganj Gas Field, Surma Basin, Bangladesh

Petrophysical Reservoir Characterization of Habiganj Gas Field, Surma Basin, Bangladesh

Integrated Reservoir Characterization Study of the McKee Formation, Onshore Taranaki Basin, New Zealand

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

Contact Info

Product

Resources

About