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Journal articles on the topic 'Shaly sand'

Author: Grafiati

Published: 4 June 2021

Last updated: 26 July 2025

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1

Johanna, Ulrike, and Epo Prasetya Kusumah. "Analysis of Petrophysical Parameter on Shaly Sand Reservoir by Comparing Conventional Method and Shaly Sand Method in Vulcan Subbasin, Northwest Australia." Journal of Geoscience, Engineering, Environment, and Technology 8, no. 02-2 (2023): 35–42. http://dx.doi.org/10.25299/jgeet.2023.8.02-2.13880.

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Vulcan Subbasin is an area with a lot of oil and gas exploration where is located in the Bonaparte Basin, Northwest Australia. There is some formation identified as sandstone reservoir with clay content which is usually called shaly sand based on the screening between resistivity log and density log. Clay content caused lower resistivity log readings so the shaly sand reservoir is considered as non-reservoir. To overcome this, a method besides the conventional method was applied to analyze the petrophysical parameters of shaly sand reservoir, it was shaly sand method. Petrophysical analysis is

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Okpoli, C. C., and D. I. Arogunyo. "Integration of Well Logs and Seismic Attribute Analysis in Reservoir Identification on PGS Field Onshore Niger Delta, Nigeria." Pakistan Journal of Geology 4, no. 1 (2020): 12–22. http://dx.doi.org/10.2478/pjg-2020-0002.

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AbstractIntegrated well dataset and seismics delineated the PGS field onshore Niger Delta for reservoir identification. Gamma ray, resistivity, Neutron and density Logs identified four lithologies: sandstone, shaly sandstone, shaly sand and shale. They consist of sand-shale intercalation with the traces of shale sometimes found within the sand Formation. Petrophysical parameters of the reservoirs showed varying degree of lower density, low gamma ray, high porosity and resistivity response with prolific hydrocarbon reservoir G due to its shale volume and the clean sand mapped as a probable hydr

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Derder, Omar M. "Single Well Petrophysical Analysis: A Case Study of Belle Fourche Shaly-Sand, Hatton Gas Field, Southwest Saskatchewan." Scientific Journal of University of Benghazi 34, no. 1 (2021): 15. http://dx.doi.org/10.37376/sjuob.v34i1.187.

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This case study shows the petrophysical evaluation of the Belle Fourche Formation, Hatton Gas Field, Southwest Saskatchewan, using conventional well log interpretation techniques. The Belle Fourche reservoir analysed is indicated as shaly-sand formation, while petrophysical parameters calculated includes gross thickness, net thickness, volume of shale, porosity, and water saturation. Cross plots, in conjunction with previous core sedimentology study was used to identify lithology as shale dominated by mixed clay. The potassium content remains relatively constant as the clay content increases.

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4

Salleh, Nur Farhana, Maman Hermana, and Deva Prasad Ghosh. "A New Method To Estimate Resistivity Distribution Of Shaly Sand Reservoirs Using New Seismic Attributes." Bulletin of the Geological Society of Malaysia 71 (May 31, 2021): 149–57. http://dx.doi.org/10.7186/bgsm71202113.

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A subsurface resistivity model is important in hydrocarbon exploration primarily in the controlled-source electromagnetic (CSEM) method. CSEM forward modelling workflow uses resistivity model as the main input in feasibility studies and inversion process. The task of building a shaly sand resistivity model becomes more complex than clean sand due to the presence of a shale matrix. In this paper, a new approach is introduced to model a robust resistivity property of shaly sand reservoirs. A volume of seismic data and three wells located in the K-field of offshore Sarawak is provided for this st

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Hassane, Amadou, Chukwuemeka Ngozi Ehirim, and Tamunonengiyeofori Dagogo. "Rock physics diagnostic of Eocene Sokor-1 reservoir in Termit subbasin, Niger." Journal of Petroleum Exploration and Production Technology 11, no. 9 (2021): 3361–71. http://dx.doi.org/10.1007/s13202-021-01259-2.

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AbstractEocene Sokor-1 reservoir is intrinsically heterogeneous and characterized by low-contrast low-resistivity log responses in parts of the Termit subbasin. Discriminating lithology and fluid properties using petrophysics alone is complicated and undermines reservoir characterization. Petrophysics and rock physics were integrated through rock physics diagnostics (RPDs) modeling for detailed description of the reservoir microstructure and quality in the subbasin. Petrophysical evaluation shows that Sokor-1 sand_5 interval has good petrophysical properties across wells and prolific in hydroc

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Thomas, E. C. "What is It About Shaly Sands? Shaly Sand Tutorial No. 1 of 3." Petrophysics – The SPWLA Journal of Formation Evaluation and Reservoir Description 59, no. 1 (2018): 7–14. http://dx.doi.org/10.30632/pjv59n1-2018t1.

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Thomas, E. C. "What is it about Shaly Sands? Shaly Sand Tutorial No. 2 of 3." Petrophysics - The SPWLA Journal of Formation Evaluation and Reservoir Description 59, no. 2 (2018): 118–35. http://dx.doi.org/10.30632/pjv59n2-2018t1.

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Thomas, E. C. "What is It About Shaly Sands? Shaly Sand Tutorial No. 3 of 3." Petrophysics – The SPWLA Journal of Formation Evaluation and Reservoir Description 3, no. 59 (2018): 276–87. http://dx.doi.org/10.30632/pjv59n3-2018t1.

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9

Bybee, Karen. "Enhanced Shaly Sand Reservoir Characterization." Journal of Petroleum Technology 54, no. 04 (2002): 63–64. http://dx.doi.org/10.2118/0402-0063-jpt.

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10

Raja Kamarul Shahrin, Raja Johannes, Akhmal Sidek, Augustine Agi, Radzuan Junin, Mohd Zaidi Jaafar, and Hariri Ariffin. "Comparison of Water Saturation Models Based on Well Logging Data: A Case Study of MX Field in Malay Basin." Jurnal Kejuruteraan 34, no. 1 (2022): 101–8. http://dx.doi.org/10.17576/jkukm-2022-34(1)-09.

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One of the primary methods to determine water saturation is logging measurement which uses water saturation models. Archie`s interpretation model to estimate water saturation in clean formations has successfully been useful over the years. However, in shaly sand formation this model yields inaccurate water saturation estimates due to shaly sand effects. Many shaly sand interpretation models have been developed; unfortunately; there is no unique water saturation model which works best for all formations as subsurface information may be limited and formation shaly sands may vary. Nevertheless, s

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Mkinga, Oras Joseph, Erik Skogen, and Jon Kleppe. "Petrophysical interpretation in shaly sand formation of a gas field in Tanzania." Journal of Petroleum Exploration and Production Technology 10, no. 3 (2019): 1201–13. http://dx.doi.org/10.1007/s13202-019-00819-x.

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AbstractAn onshore gas field (hereafter called the R field—real name not revealed) is in the southeast coast of Tanzania which includes a Tertiary aged shaly sand formation (sand–shale sequences). The formation was penetrated by an exploration well R–X wherein no core was acquired, and there is no layer-wise published data of the petrophysical properties of the R field in the existing literature, which are essential to reserves estimation and production forecast. In this paper, the layer-wise interpretation of petrophysical properties was undertaken by using wireline logs to obtain parameters

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Finecountry, S. C. P., and S. Inichinbia. "Lithology and Fluid discrimination of Sody field of the Nigerian Delta." Journal of Applied Sciences and Environmental Management 24, no. 8 (2020): 1321–27. http://dx.doi.org/10.4314/jasem.v24i8.3.

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The lithology and fluid discrimination of an onshore Sody field, of the Niger Delta was studied using gamma ray, resistivity and density logs from three wells in the field in order to evaluate the field’s reservoir properties. Two reservoir sands (RES 1 and RES 2) were delineated and identified as hydrocarbon bearing reservoirs. The petrophysical parameters calculated include total porosity, water saturation and volume of shale. The results obtained revealed that the average porosity of the reservoir sands, range from 21% to 39%, which is excellent indicator of a good quality reservoir and pro

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Garrouch, Ali A., and Mukul M. Sharma. "The Influence of clay content, salinity, stress, and wettability on the dielectric properties of brine‐saturated rocks: 10 Hz to 10 MHz." GEOPHYSICS 59, no. 6 (1994): 909–17. http://dx.doi.org/10.1190/1.1443650.

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Complex impedance measurements have been performed on 14 shaly sand samples, Berea sandstone, and Ottawa sand‐bentonite packs in a frequency range of 10 Hz to 10 MHz, using both the two‐ and four‐electrode techniques. Measurements have been conducted at an effective radial stress varying from ambient pressure to 4000 psi for brine‐saturated oil‐wet and water‐wet samples. The dielectric permittivity is found to correlate with the clay volume fraction, the cation exchange capacity, and electrochemical potential of the rock samples and to depend strongly on the salinity of the brine used. Stress

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14

Al-Ghanim, Sura, Mohanad Al-Jaberi, and Fahad Al-Najim. "Petrophysical Properties and Identification of Electrofacies from Well Log Data of Nahr Umr Formation in Subba Oilfield, Southern Iraq." Iraqi Geological Journal 56, no. 2C (2023): 50–65. http://dx.doi.org/10.46717/igj.56.2c.4ms-2023-9-10.

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The main purpose of this study is to identify electrofacies and evaluate the petrophysical properties of the Nahr Umr Formation in four wells: A, B, C, and D in the Subba oilfield, southern Iraq. The petrophysical properties, such as shale volume, porosity, water saturation, hydrocarbon saturation, and bulk water volume, were computed and interpreted using Techlog software. According to the interpretation of density, neutron, and gamma ray sonic logs and deep resistivity logs using the IPSOM technique, four electrofacies were identified as sandstone, shaly sand, sandy shale, and shale electrof

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15

Muzaal, Zahraa A., Fahad M. Al-Najm, Wasan S. Al-Qurnawi, and Maher J. Ismail. "Rock Type and Pore Throat Radius of Zubair Formation in the W Oil Field: Analysis Utilizing Core and Log Data." Iraqi Geological Journal 55, no. 1D (2022): 118–29. http://dx.doi.org/10.46717/igj.55.1d.8ms-2022-04-24.

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The Zubair Formation is a prolific oil reservoir in several southeastern Iraq oil fields. The formation comprises thick sandstones with interbedded shales and siltstones of Lower Cretaceous age (Hauterivian to lower Aptian). The environment of the Zubair Formation consists of fluviodeltaic, deltaic, and marine sandstones. In southern Iraq, the area is subdivided into informal members (oldest to youngest). The Lower Shale, lower sand, middle shale, main pay upper sand, and the upper shale. At the W oilfield, the main pay member is an oil producer. The thickness is of the main reservoir about 10

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16

Widyantoro, Adi, and Matthew Saul. "Shaly sand rock physics analysis and seismic inversion implication." APPEA Journal 54, no. 2 (2014): 503. http://dx.doi.org/10.1071/aj13076.

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The analysis of well data from the Enfield field of the Exmouth Sub-basin, WA, indicates that both cementation and pore-filling clay appear to have a stiffening effect on the reservoir sands. The elastic contrast between brine sand and the overlying shale is often small and the large amplitudes observed from seismic data are associated with hydrocarbon content. More detailed rock physics and depth trend analysis of elastic and petrophysical properties, however, indicate significant spatial variability in the cap rock shales across the field with different sand shale mixtures, causing changes i

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Hofman, J. P., A. de Kuijper, R. K. J. Sandor, M. Hausenblas, R. J. M. Bonnie, and T. W. Fens. "The Group III Shaly Sand Data Set." SPE Reservoir Evaluation & Engineering 1, no. 03 (1998): 231–37. http://dx.doi.org/10.2118/39107-pa.

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Summary In the development of shaly sand saturation models, core data are of exceptional value. These data are required to check the descriptive and predictive power of existing models and compare them with new concepts. This paper aims to add to the modest set of generally available core data on shaly sands by presenting a variety of special core-analysis measurements on a number of shaly sand core samples. The experiments presented here include standard petrophysical measurements, continuous injection (CI) resistivity measurements (at ambient and elevated temperatures), nuclear magnetic reso

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Sari, Tri Wulan, and Sujito Sujito. "LITHOLOGY INTERPRETATION BASED ON WELL LOG DATA ANALYSIS IN “JS” FIELD." Applied Research on Civil Engineering and Environment (ARCEE) 1, no. 01 (2019): 31–37. http://dx.doi.org/10.32722/arcee.v1i01.1955.

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Reservoir lithology types in a prospect zone of hydrocarbon can be known through well log data analysis, both qualitatively and quantitatively. Lithology interpretation based on qualitatively well log data analysis, has been successfully carried out by K-1 and K-3 well log data on JS Field, West Natuna basin, Riau Islands.Main focus of the research is types of lithology indicated by response the petrophysical well data log of Lower-Middle Miocene Arang Formation. Arang Formation was deposited immediately on top Barat formation and depositional environment in this formation is transitional mari

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Maju-Oyovwikowhe, E. G., and E. J. Ighodaro. "Petrophysical properties and volume estimation of hydrocarbon resources in x field, onshore niger delta: A reservoir characterization study." Scientia Africana 22, no. 1 (2023): 151–74. http://dx.doi.org/10.4314/sa.v22i1.14.

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A reservoir characterization study was conducted on three wells located in X Field, situated in the Onshore region of the Niger Delta. A suite of conventional digital well logs was utilized to identify hydrocarbon-bearing reservoirs, determine reservoir petrophysical parameters, and infer the depositional environment. The study delineated four hydrocarbon-bearing reservoirs, labeled A, B, C, and D, with porosity estimates ranging from 25% to 27%, and permeability values varying from 1863.22md to 2759.78md. These results suggest that the reservoirs have good storage capacity and permit free flo

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20

Fregene, T. J., and N. Onyeachonam. "Chemical Classification of Sediments in JVX -Well, Greater Ughelli Depobelt Niger Delta Basin, Nigeria." Journal of Applied Sciences and Environmental Management 25, no. 6 (2021): 995–1001. http://dx.doi.org/10.4314/jasem.v25i6.17.

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This study evaluate the Chemical classification of sediments in JVX well, Greater Ughelli Depo belt Niger Delta Basin. Samples collected from different intervals were analyzed using geochemical proxies. Agbada Formation was suggested for the sampled intervals due to the presence of shaleand sand intercalations. lithofacies units gotten from sampled intervals are Sand, Shale and Shaly sand facies . The sands are milky in colour, translucent to opaque, medium to coarse grain, subangular to subrounded and are moderately sorted while the shales are Grey in colour,fissile with the presence of ligni

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Efetobore, Maju-Oyovwikowhe Gladys, and Eguagie Michael Owenvbiugie. "Lithostratigraphic Characterization and Petroleum System Elements of the MI Well, Niger Delta Basin." Current Journal of Applied Science and Technology 42, no. 16 (2023): 67–83. http://dx.doi.org/10.9734/cjast/2023/v42i164137.

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This study presents a comprehensive lithostratigraphic characterization of the MI Well in the Niger Delta Basin through microscopic examination of ditch cutting samples. The aim was to identify the lithological units and assess the presence and distribution of petroleum system elements. A total of seventy-two samples ranging in depth from 4500ft-11460ft (1372m-3493m) were analyzed, revealing four lithological units: sandstone, shale, sandy shale, and shaly sand. Through interpretation of the lithological log, the cap/seal rock, reservoir rock, and probable source rock units were identified. Th

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22

Mendrofa, Denny MF. "Theoretical Approach in Vp/Vs Prediction from Rock Conductivity in Gas Saturating Shaly Sand." Modern Applied Science 13, no. 1 (2018): 45. http://dx.doi.org/10.5539/mas.v13n1p45.

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Most of study in Oil and Gas Industry are studying Vp/Vs behaviour against hydrocarbon presence in a porous rock. Vp/Vs number is commonly used to model Amplitude Variation against Offset response of a gas sand which allow us be able to discriminate it from the water sand. The model is built in term to match the synthesized Vp/Vs against the observed Vp/Vs which actually correspond to elastic property of porous and fluid saturating rocks. This study is aimed to find correlation between elastic property and conductivity of saturated rocks, especially reservoir in this study is found as a shaly

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Ifesinachi, Onyenweife, Geraldine, Ben-Owope, Ogechukwu Anastasia, and Nwozor, Kingsley Kanayo. "Evaluation of Petrophysical and Geomechanical Analysis of Subsurface Geological Information for Sustainable Groundwater and Engineering Development in Parts of Anaocha Local Government, Anambra State, Nigeria." Asian Journal of Geographical Research 8, no. 3 (2025): 153–62. https://doi.org/10.9734/ajgr/2025/v8i3283.

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A well log is the recording of the measurement of a geophysical parameter plotted continuously against depth in the well bore. It is used to identify and correlate underground rocks, determine their lithology, generate their physical properties and the nature of the fluids they contain. The study aimed to conduct a geophysical evaluation of geologic formations for sustainable groundwater and engineering development. Electrical resistivity logging was carried out on the existing wells at Anoacha to evaluate the geological formation of the subsurface and well efficiency. The study area is positi

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Tabatabai, Seyed Mehdi, Timur Chis, and Cristina Jugastreanu. "Formation evaluation in low resistivity low contrast (LRLC) shaly sand thin lamination; forward modeling and inversion optimization using genetic algorithm." Romanian Journal of Petroleum & Gas Technology 3 (74), no. 1 (2022): 83–97. http://dx.doi.org/10.51865/jpgt.2022.01.09.

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Formation evaluation in thin bed lamination is challenging and classic petrophysical workflow would results in underestimation of true hydrocarbon pore thickness and consequently underestimation of hydrocarbon in place in oil and gas fields. Due to deficiency of conventional well logs to detect thin bed shale sand laminations, they appear as non- hydrocarbon bearing low resistivity interval on well logs. True log response cannot be recorded in thin bed shale sand lamination intervals since thickness of these layers is lower than logging tool resolution. Logging tools can only record the averag

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de Waal, J. A. "Influence of Clay Distribution on Shaly Sand Conductivity." SPE Formation Evaluation 4, no. 03 (1989): 377–83. http://dx.doi.org/10.2118/16786-pa.

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Jongkittinarukorn, Kittiphong, and Djebbar Tiab. "Identification of flow units in shaly sand reservoirs." Journal of Petroleum Science and Engineering 17, no. 3-4 (1997): 237–46. http://dx.doi.org/10.1016/s0920-4105(96)00046-0.

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27

Yenwongfai, Honore Dzekamelive, Nazmul Haque Mondol, Jan Inge Faleide, Isabelle Lecomte, and Johan Leutscher. "Prestack inversion and multiattribute analysis for porosity, shale volume, and sand probability in the Havert Formation of the Goliat field, southwest Barents Sea." Interpretation 5, no. 3 (2017): SL69—SL87. http://dx.doi.org/10.1190/int-2016-0169.1.

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An integrated innovative multidisciplinary approach has been used to estimate effective porosity (PHIE), shale volume ([Formula: see text]), and sand probability from prestack angle gathers and petrophysical well logs within the Lower Triassic Havert Formation in the Goliat field, Southwest Barents Sea. A rock-physics feasibility study revealed the optimum petrofacies discriminating ability of extended elastic impedance (EEI) tuned for PHIE and [Formula: see text]. We then combined model-based prestack inversion outputs from a simultaneous inversion and an EEI inversion into a multilinear attr

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28

Adesokan, Hamid, and Yuefeng Sun. "Rock-physics-based estimation of critical-clay-volume fraction and its effect on seismic velocity and petrophysical properties." GEOPHYSICS 79, no. 3 (2014): D175—D185. http://dx.doi.org/10.1190/geo2012-0510.1.

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Knowledge of the clay content in clastic reservoirs is important for predicting reservoir quality and properties. We used a microgeometrical model for shaly sand and sandy shale to define the critical-clay-volume fraction and explain the dependence of the bulk modulus on clay content. We found that the concept of the pore-aspect ratio relating to the critical-clay-volume fraction was important to interpret the elastic behavior of shaly sandstone. An abrupt decrease in pore-aspect ratio from about 0.23 to about 0.04 was observed where the clay-volume fraction was greater than the critical value

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29

Benedict T Yankyerah, Daniel K Asiedu, Mustapha Odainkey, and Bernard Gyebi. "Lithofacies and depositional environments in the Saltpond Basin of Ghana: A well log analysis." World Journal of Advanced Research and Reviews 26, no. 1 (2025): 2997–3008. https://doi.org/10.30574/wjarr.2025.26.1.1287.

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This study employs geophysical logs to interpret lithofacies and depositional environments within Ghana’s Saltpond Basin, complementing the region’s predominantly surface-based analyses. Gamma ray (GR) and spontaneous potential (SP) logs were used to identify sand, shaly sand, and shale lithologies, while resistivity, bulk density, and sonic logs further refined lithological characterization. The well section was divided into seven electrofacies units based on distinct log responses and motifs. GR log motifs and facies sequences were analyzed to interpret depositional environments, which were

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30

Usman, Muhammad, Numair A. Siddiqui, Manoj J. Mathew, Eduardo Garzanti, and Zhang Shiqi. "Pore geometry and connectivity in shaly sand as input data for fracking experiments." IOP Conference Series: Earth and Environmental Science 1003, no. 1 (2022): 012030. http://dx.doi.org/10.1088/1755-1315/1003/1/012030.

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Abstract Exploration for hydrocarbon in shales is an example of unconventional reservoirs for oil and gas resources with huge amount of commercial potential. Porosity and permeability in shale are two important factors that control fluid accumulation and flow. To get the natural shale samples from wells is certainly a hard and crucial job for reservoir fracking studies. To study different factors that influence pore types and geometry in fracking experiments, we carried out X-ray Diffraction (XRD) analysis, surface area analyzer and porosimetry system (SAP), poroperm and tomographic imaging (m

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Iheanacho, Philip C. "Formation-Resistivity Theory: How Archie Equations, Shaly-Reservoir Models, Conductive Rock-Matrix Model, and Dual-Triple-Porosity Models Are Related." SPE Reservoir Evaluation & Engineering 17, no. 02 (2014): 141–51. http://dx.doi.org/10.2118/167507-pa.

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Summary The estimation of hydrocarbon pore volume (HCPV) from resistivity logs can be quite troublesome in some complex heterogeneous reservoirs. Most water-saturation/formation-resistivity models that work well for some reservoirs give unreliable results for others. No single model works for all types of reservoir scenarios. This paper presents the theory of formation resistivity in porous media. The paper develops the theory from the parallel-resistivity model and then extends it for the series-resistivity model. When applied for clean sand, the theory derives Archie equations from the first

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BASAL, A. "Analytical Treatment of Neutron-Density Crossplot for Shaly Sand Reservoirs." Journal of King Abdulaziz University-Earth Sciences 10, no. 1 (1998): 115–42. http://dx.doi.org/10.4197/ear.10-1.8.

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Walsh, J. W., S. L. Brown, and G. B. Asquith. "Shaly Sand Advisor: Creating a Program To Provide "Expert" Help." SPE Computer Applications 5, no. 01 (1993): 6–10. http://dx.doi.org/10.2118/24453-pa.

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Tong, Maosong, and Honggen Tao. "Permeability estimating from complex resistivity measurement of shaly sand reservoir." Geophysical Journal International 173, no. 2 (2008): 733–39. http://dx.doi.org/10.1111/j.1365-246x.2008.03730.x.

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Elshafei, M., and G. M. Hamada. "Neural Network Identification of Hydrocarbon Potential of Shaly Sand Reservoirs." Petroleum Science and Technology 27, no. 1 (2009): 72–82. http://dx.doi.org/10.1080/10916460701699868.

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Jin, Minquan, and Mukul M. Sharma. "Shaly sand formation evaluation using a single membrane potential measurement." Journal of Petroleum Science and Engineering 11, no. 4 (1994): 301–10. http://dx.doi.org/10.1016/0920-4105(94)90048-5.

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Bian, Huiyuan, Kewen Li, Binchi Hou, and Xiaorong Luo. "A New Model to Calculate Oil-Water Relative Permeability of Shaly Sandstone." Geofluids 2020 (September 24, 2020): 1–11. http://dx.doi.org/10.1155/2020/8842276.

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Oil-water relative permeability curves are the basis of oil field development. In recent years, the calculation of oil-water relative permeability in sandstone reservoirs by resistivity logging data has received much attention from researchers. This article first analyzed the existing mathematical models of the relationship between relative permeability and resistivity and found that most of them are based on Archie formula, which assumes the reservoir is clean sandstone. However, in view of the fact that sandstone reservoir is commonly mixed with shale contents, this research, based on the du

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Wendt, Anke S., Monzurul Alam, and Joao Paulo Castagnoli. "Sand injectite mapping using a resistivity-velocity transform function." Leading Edge 40, no. 3 (2021): 202–7. http://dx.doi.org/10.1190/tle40030202.1.

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Lack of resolution in the distribution of sand injectites in hydrocarbon fields is common and makes it difficult to predict drilling challenges and plan for optimum production. A practical workflow was developed that enables the distinction of shale and sand bodies by using a combination of low-resolution seismic data and high-resolution resistivity log data. Measured resistivity logs were used to predict synthetic velocity logs, which accurately match shale velocities and over- or underestimate velocities of other rock types. The synthetic velocity logs were spatially distributed in a 3D cube

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Zharnikov, Timur, Sergey Vorobiev, Wisam AlKawai, et al. "Novel anisotropic model for quantitative interpretation of laminated shaly sands." Leading Edge 44, no. 6 (2025): 441–50. https://doi.org/10.1190/tle44060441.1.

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A novel anisotropic approach for the quantitative interpretation of laminated shaly sands is presented. The method was created to deal with thinly laminated formations consisting of layers of shaly sand and shale. The interpretation of the elastic properties of rocks and the effects of fluid substitution is of particular interest. Providing the interpretation in situations when the input data are limited is the primary motivation and challenge. The key idea is the explicit treatment of the dispersed and laminated clay within the framework of effective medium theory. Derived formulas for format

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Kotwicki, Artur, Mirza Hassan Baig, Yngve Bolstad Johansen, et al. "Evaluating Petrophysical Properties and Volumetrics Uncertainties of Sand Injectite Reservoirs – Norwegian North Sea." Petrophysics – The SPWLA Journal of Formation Evaluation and Reservoir Description 63, no. 1 (2022): 82–103. http://dx.doi.org/10.30632/pjv63n1-2022a5.

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Sand injectites on the Norwegian Continental Shelf have proven their commercial significance. Some are already producing, e.g., Volund, Viper, Balder, Ringhorne, and Kobra Fields, while others such as in production licenses (PL) 340 and 869 have recently been discovered and appraised. Extensive literature on the geology of sand injectites has been published (e.g., Jenssen et al., 1993; Jolly and Lonergan, 2002; Huuse et al., 2003; Hurst et al., 2005). However, few references are available on the petrophysical and geophysical aspects of sand injectite reservoirs. This paper discusses the petrop

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Citra Wahyuningrum, Kevin Kevin, and Assyeh Annassrul Majid. "Integration Petrophysical To Identify Reservoir Characterization Of Baturaja Limestone In “X” Well, North West Java Basin." Jupiter: Publikasi Ilmu Keteknikan Industri, Teknik Elektro dan Informatika 2, no. 2 (2024): 64–71. http://dx.doi.org/10.61132/jupiter.v2i2.89.

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Petrophysical evaluation of the Baturaja Formation on limestone reservoirs of the Field X, using conventional well log interpretation techniques and relating the results to core data based on laboratory analysis, shows that the reservoir characterization parameters to decide future plan for the well. This study shows the role of integrated petrophysical analysis it is possible that an acceptable and can be completed within the constraints and limitations of the available data, but sometimes additional data are needed. These new data, typically additional SCAL (Special Core Analysis), RCAL (Rou

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Moselhy, Osama Said, Abdel Moktader Abdel Aziz El Sayed, and Amir Maher Sayed Lala. "Petrophysical Studies for Shaly Sand Reservoirs in Saffron Field, Nile Delta, Egypt." Egyptian Journal of Geology 68, no. 1 (2024): 437–50. https://doi.org/10.21608/egjg.2024.342541.1096.

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A. Adam, Yusuf, Etim D. Uko, Charles O. Ofoegbu, and Olatunji S. Ayanninuola. "PETROPHYSICAL CHARACTERISTICS OF BORNU-CHAD BASIN USING WELL LOGS DATA." Geosciences Research Journal 1, no. 1 (2023): 47–72. http://dx.doi.org/10.26480/gsrj.02.2023.47.72.

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Evaluation of Petrophysical Characteristics using well-log data in the Bornu-Chad Basin, North-Eastern Nigeria has been performed. The main goal of the research is to evaluate the reservoir potentials of the field through the analysis, and evaluation of key petrophysical parameters from wireline logs which could be used to generate an effective reservoir model. A total of six wells were evaluated parameters on Porosity, Permeability, Density, Shale Volume and the Share and Compressional velocities. The research uses empirical relations to compute the properties at depths using Excel software.

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Inichinbia, S., and Halidu Hamza. "Detailed quantitative sequence stratigraphic interpretation for the characterization of Amangi field using seismic data and well logs." Scientia Africana 19, no. 3 (2021): 63–82. http://dx.doi.org/10.4314/sa.v19i3.6.

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The sequence stratigraphy of Amangi field of the Niger Delta was studied using seismic data and well logs. The field is a structurally complex one and presents serious challenges to hydrocarbon exploration and production. The main objective of these analyses is to identify sand intervals using the available data. Well log data were used as additional tools to constrain the seismic correlations in order to solve the correlation problem. The well logs were evaluated for the field’s petrophysical properties by combining the gamma ray and resistivity logs to determine reservoir zones with consider

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de Lima, Olivar A. L., and Mukul M. Sharma. "A grain conductivity approach to shaly sandstones." GEOPHYSICS 55, no. 10 (1990): 1347–56. http://dx.doi.org/10.1190/1.1442782.

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The effects of clay conduction on the electrical behavior of shaly sandstones at low frequencies are analyzed by considering self‐similar mixtures of conductive grains, as representative of these porous rocks. An essential step in this model is the representation of the surface conductivities of the clay platelets by an equivalent volume conductivity. Based on their pattern of occurrence, the clays are treated either as a continuous coating over the sand grains or as individual detrital grains mixed with a nonconductive mineral matrix. In the first case, the solids are modeled as layered condu

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METWALLY, Ahmed M., Walid M. MABROUK, and Ahmed Ismail MAHMOUD. "A numerical approach to accurately estimate water resistivity (Rw) and saturation (Sw) in shaly sand formations." Contributions to Geophysics and Geodesy 52, no. 3 (2022): 423–41. http://dx.doi.org/10.31577/congeo.2022.52.3.4.

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In hydrocarbon reservoirs, the accuracy of hydrocarbon saturation depends on the precision of the water saturation and resistivity (Sw and Rw). A significant interpretation parameter is the resistivity of formation water (interstitial water or connate water which is, uncontaminated by the drilling mud that saturates the porous formation rock) because it is appropriate for the calculations of saturation (water and/or hydrocarbon) from basic resistivity logs. The most reliable way to determine this value is through the determination of the chemical composition or resistivity of uncontaminated co

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Maosong, Tong, Wang Weinan, Li Li, Jiang Yizhong, and Shi Deqin. "Estimation of permeability of shaly sand reservoir from induced polarization relaxation time spectra." Journal of Petroleum Science and Engineering 45, no. 1-2 (2004): 31–40. http://dx.doi.org/10.1016/j.petrol.2004.05.004.

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Maosong, Tong, Wang Weinan, Li Li, Jiang Yizhong, and Shi Deqin. "Estimation of permeability of shaly sand reservoir from induced polarization relaxation time spectra." Journal of Petroleum Science and Engineering 45, no. 1-2 (2004): 1–10. http://dx.doi.org/10.1016/j.petrol.2004.05.007.

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Aggoun, Redha C., Djebbar Tiab, and Jalal F. Owayed. "Characterization of flow units in shaly sand reservoirs—Hassi R'mel Oil Rim, Algeria." Journal of Petroleum Science and Engineering 50, no. 3-4 (2006): 211–26. http://dx.doi.org/10.1016/j.petrol.2005.10.006.

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Cerqueira, Alexsandro Guerra, Olivar Antônio Lima de Lima, and Ricardo Araújo Rios. "A nonparametric approach using clustering analysis to estimate shaliness in shaly-sand formations." Journal of Applied Geophysics 164 (May 2019): 11–18. http://dx.doi.org/10.1016/j.jappgeo.2019.02.021.

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