Relevant bibliographies by topics / Petrophysical analysis

Contents

  1. Journal articles
  2. Dissertations / Theses
  3. Books
  4. Book chapters
  5. Conference papers
  6. Reports

Academic literature on the topic 'Petrophysical analysis'

Author: Grafiati
Published: 4 June 2021
Last updated: 15 February 2022

Create a spot-on reference in APA, MLA, Chicago, Harvard, and other styles

Select a source type:

Consult the lists of relevant articles, books, theses, conference reports, and other scholarly sources on the topic 'Petrophysical analysis.'

Next to every source in the list of references, there is an 'Add to bibliography' button. Press on it, and we will generate automatically the bibliographic reference to the chosen work in the citation style you need: APA, MLA, Harvard, Chicago, Vancouver, etc.

You can also download the full text of the academic publication as pdf and read online its abstract whenever available in the metadata.

Journal articles on the topic "Petrophysical analysis"

1

Yogi, Ade. "Petrophysics Analysis for Reservoir Characterization of Cretaceous Clastic Rocks: A Case Study of the Arafura Basin." Jurnal Geologi dan Sumberdaya Mineral 21, no. 3 (August 28, 2020): 129. http://dx.doi.org/10.33332/jgsm.geologi.v21i3.527.

Full text
Abstract:
This study presents petrophysics analysis results from two wells located in the Arafura Basin. The analysis carried out to evaluate the reservoir characterization and its relationship to the stratigraphic sequence based on log data from the Koba-1 and Barakan-1 Wells. The stratigraphy correlation section of two wells depicts that in the Cretaceous series a transgression-regression cycle. The petrophysical parameters to be calculated are the shale volume and porosity. The analysis shows that there is a relationship between stratigraphic sequences and petrophysical properties. In the study area, shale volumes used to make complete rock profiles in wells assisted by biostratigraphic data, cutting descriptions, and core descriptions. At the same time, porosity shows a conformity pattern with the transgression-regression cycle.Keywords: petrophysics, reservoir characterization, Cretaceous, transgressive-regressive cycle
APA, Harvard, Vancouver, ISO, and other styles
2

Giraud, Jérémie, Evren Pakyuz-Charrier, Mark Jessell, Mark Lindsay, Roland Martin, and Vitaliy Ogarko. "Uncertainty reduction through geologically conditioned petrophysical constraints in joint inversion." GEOPHYSICS 82, no. 6 (November 1, 2017): ID19—ID34. http://dx.doi.org/10.1190/geo2016-0615.1.

Full text
Abstract:
We have developed a joint geophysical inversion workflow that aims to improve subsurface imaging and decrease uncertainty by integrating petrophysical constraints and geologic data. In this framework, probabilistic geologic modeling is used as a source of information to condition the petrophysical constraints spatially and to derive starting models. The workflow then uses petrophysical measurements to constrain the values retrieved by geophysical joint inversion. The different sources of constraints are integrated into a least-squares framework to capture and integrate information related to geophysical, petrophysical, and geologic data. This allows us to quantify the posterior state of knowledge and to calculate posterior statistical indicators. To test this workflow, using geologic field data, we have generated a set of geologic models, which we used to derive a probabilistic geologic model. In this synthetic case study, we found that the integration of geologic information and petrophysical constraints in geophysical joint inversion could reduce uncertainty and improve imaging. In particular, the use of petrophysical constraints retrieves sharper boundaries and better reproduces the statistics of the observed petrophysical measurements. The integration of probabilistic geologic modeling permits more accurate retrieval of model geometry, and it better constrains the solution while still satisfying the statistics derived from geologic data. The analysis of statistical indicators at each step of the workflow indicates that (1) the inversion methodology is effective when applied to complex geology and (2) the integration of prior information and constraints from geology and petrophysics significantly improves the inversion results while decreasing uncertainty. Finally, the analysis of uncertainty to the integration of the conditioned petrophysical constraints also indicates that, for this example, the best results are obtained for joint inversion using petrophysical constraints spatially conditioned by geologic modeling.
APA, Harvard, Vancouver, ISO, and other styles
3

Astic, Thibaut, Lindsey J. Heagy, and Douglas W. Oldenburg. "Petrophysically and geologically guided multi-physics inversion using a dynamic Gaussian mixture model." Geophysical Journal International 224, no. 1 (August 21, 2020): 40–68. http://dx.doi.org/10.1093/gji/ggaa378.

Full text
Abstract:
SUMMARY In a previous paper, we introduced a framework for carrying out petrophysically and geologically guided geophysical inversions. In that framework, petrophysical and geological information is modelled with a Gaussian mixture model (GMM). In the inversion, the GMM serves as a prior for the geophysical model. The formulation and applications were confined to problems in which a single physical property model was sought, and a single geophysical data set was available. In this paper, we extend that framework to jointly invert multiple geophysical data sets that depend on multiple physical properties. The petrophysical and geological information is used to couple geophysical surveys that, otherwise, rely on independent physics. This requires advancements in two areas. First, an extension from a univariate to a multivariate analysis of the petrophysical data, and their inclusion within the inverse problem, is necessary. Secondly, we address the practical issues of simultaneously inverting data from multiple surveys and finding a solution that acceptably reproduces each one, along with the petrophysical and geological information. To illustrate the efficacy of our approach and the advantages of carrying out multi-physics inversions coupled with petrophysical and geological information, we invert synthetic gravity and magnetic data associated with a kimberlite deposit. The kimberlite pipe contains two distinct facies embedded in a host rock. Inverting the data sets individually, even with petrophysical information, leads to a binary geological model: background or undetermined kimberlite. A multi-physics inversion, with petrophysical information, differentiates between the two main kimberlite facies of the pipe. Through this example, we also highlight the capabilities of our framework to work with interpretive geological assumptions when minimal quantitative information is available. In those cases, the dynamic updates of the GMM allow us to perform multi-physics inversions by learning a petrophysical model.
APA, Harvard, Vancouver, ISO, and other styles
4

Chuanmao, Liang, and Gerald M. Friedman. "Petrophysical analysis of modern reef rocks." Carbonates and Evaporites 7, no. 1 (March 1992): 11–20. http://dx.doi.org/10.1007/bf03175389.

Full text
APA, Harvard, Vancouver, ISO, and other styles
5

J. Sunday, Abe, and Lurogho S. Ayoleyi. "Petrophysical analysis of “explorer” wells using well log and core data(a case study of “explorer” field, offshore Niger Delta, Nigeria)." International Journal of Advanced Geosciences 8, no. 2 (October 22, 2020): 219. http://dx.doi.org/10.14419/ijag.v8i2.31114.

Full text
Abstract:
Reservoir characterization involves computing various petrophysical parameters and defining them in terms of their quantity and quality so as to ascertain the yield of the reservoir. Petrophysical well log and core data were integrated to analyze the reservoir characteristics of Explorer field, Offshore, Niger Delta using three wells. The study entails determination of the lithology, shale volume (Vsh), porosity (Φ), permeability (K), fluid saturation and cross plotting of petrophysical and core values at specific intervals to know their level of correlation. The analysis identified twelve hydrocarbon-bearing reservoir from three different wells. Average permeability value of the reservoir is 20, 0140md while porosity value range between 18% to 39%. Fluid type defined in the reservoirs on the basis of neutron/density log signature were basically water, oil and gas, low water saturation values ranging from 2.9% to 46% in Explorer wells indicate high hydrocarbon saturation. The Pearson Correlation Coefficient and Regression Equation gave a significant relationship between petrophysical derived data and core data. Scatter plot of petrophysical gamma ray values versus core gamma ray values gave an approximate linear relationship with correlation coefficient values of 0.6642, 0.9831 and 0.3261. Crossplot of petrophysical density values and core density values revealed that there is a strong linear relationship between the two data set with correlation coefficient values of 0.7581, 0.9872 and 0.3557, and the regression equation confirmed the relationship between the two data set. Also the scatter plot of petrophysical porosity density values versus core porosity density values revealed a strong linear relationship between the two data set with correlation coefficient values of 0.7608 and 0.9849, the regression equation confirmed this also. Crossplot of petrophysical porosity density values versus core porosity density values in Well 3 gave a very weak correlation coefficient values of 0.3261 and 0.3557 with a negative slope. The petrophysical properties of the reservoirs in Explorer Well showed that they contain hydrocarbon in commercial quantity and the cross plot of the petrophysical and core values showed direct relationship in most of the wells.
APA, Harvard, Vancouver, ISO, and other styles
6

Zeb, Jahan, Sanjeev Rajput, and Jimmy Ting. "Seismic petrophysics focused case study for AVA modelling and pre-stack seismic inversion." APPEA Journal 56, no. 1 (2016): 341. http://dx.doi.org/10.1071/aj15025.

Full text
Abstract:
Hydrocarbon reservoirs are characterised by integrating seismic, well-log and petrophysical information, which are dissimilar in spatial distribution, scale and relationship to reservoir properties. Well logs are essential for amplitude versus offset (AVO) modelling and seismic inversion. The usability of well logs can be determined during wavelet estimation, seismic-to-well ties, background model building, property distribution for inversion, deriving probability density functions and variograms, offset-to-angle conversion of seismic data, and many other processes. For the implementation of seismic inversion workflows, accurate and geologically corrected compressional-sonic, shear-sonic and density logs are necessary. Preparing the logs for quantitative interpretation becomes challenging in a real-field environment because of bad borehole conditions including washouts, uncalibrated and variability of logging tools, invasion effects, missing shear logs and change of borehole size. Conventional petrophysical analysis is usually restricted to the reservoir interval, the calculation of reservoir versus non-reservoir (including sands or shales), and log corrections for smaller intervals; in contrast, seismic petrophysics encompasses the entire geological interval, calculates the volume of multi-minerals, incorporates boundaries between non-reservoir and reservoir, and often includes the prediction of missing compressional and shear-sonic for AVO analysis. A detailed seismic petrophysics analysis was performed for amplitude versus angle (AVA) modelling and attributes analysis. To perform the AVA modelling, a series of forward models in association with rock physics modelled fluid-substituted logs were developed, and associated seismic responses for various pore fluids and rock types studied. The results reveal that synthetic seismic responses together with the AVA analysis show changes for various lithologies. AVA attributes analysis show trends in generated synthetic seismic responses for various fluid-substituted and porosity logs. Reservoir modelling and fluid substitution increases understanding of the observed seismic response. This paper describes detailed data analysis using various techniques to confirm the rock model for petrophysical evaluation, rock physics modelling, AVA analysis, pre-stack seismic inversion, and the scenario modelling applied to the study of an oil field in Australia.
APA, Harvard, Vancouver, ISO, and other styles
7

Komatsu, Hideo. "Discussion of uncertainty relating to petrophysical analysis." Journal of the Japanese Association for Petroleum Technology 83, no. 1 (January 30, 2018): 34–39. http://dx.doi.org/10.3720/japt.83.34.

Full text
APA, Harvard, Vancouver, ISO, and other styles
8

Komatsu, Hideo. "Discussion of uncertainty relating to petrophysical analysis." Journal of the Japanese Association for Petroleum Technology 83, no. 1 (January 30, 2018): 34–39. http://dx.doi.org/10.3720/japt.83.34.

Full text
APA, Harvard, Vancouver, ISO, and other styles
9

Tarigan, Febrina Bunga, Ordas Dewanto, Karyanto Karyanto, Rahmat Catur Wibowo, and Andika Widyasari. "ANALISIS PETROFISIKA UNTUK MENENTUKAN OIL-WATER CONTACT PADA FORMASI TALANGAKAR, LAPANGAN “FBT”, CEKUNGAN SUMATRA SELATAN." Jurnal Geofisika Eksplorasi 5, no. 1 (January 17, 2020): 15–29. http://dx.doi.org/10.23960/jge.v5i1.20.

Full text
Abstract:
In conducting petrophysics analysis, there are many methods on each property. Therefore, it is necessary to determine the exact method on each petrophysical property suitable for application in the field of research in order to avoid irregularities at the time of interpretation. The petrophysical property consists of volume shale, porosity, water saturation, etc. This research used six well data named FBT01, FBT02, FBT03, FBT04, FBT05, and FBT06 and also assisted with core data contained in FBT03. Core data used as a reference in petrophysical analysis because it was considered to have represented or closed to the actual reservoir conditions in the field. The area in this research was in Talangakar Formation, "FBT" Field, South Sumatra Basin. The most suited volume shale method for “FBT” field condition was gamma ray-neutron-density method by seeing its photo core and lithology. As for the effective porosity, the most suited method for the field was neutron-density-sonic method by its core. Oil-water contact was useful to determine the hydrocarbon reserves. Oil-water contact was obtained at a depth of 2277.5 feet on FBT01, 2226.5 feet on FBT02, 2312.5 feet on FBT03, 2331 feet on FBT04, 2296 feet on FBT05, and 2283.5 feet on FBT06. The oil-water contact depth differences at Talangakar formation in FBT field caused by structure in subsurface.
APA, Harvard, Vancouver, ISO, and other styles
10

Stadtmuller, Marek, Anita Lis-Śledziona, and Małgorzata Słota-Valim. "Petrophysical and geomechanical analysis of the Lower Paleozoic shale formation, North Poland." Interpretation 6, no. 3 (August 1, 2018): SH91—SH106. http://dx.doi.org/10.1190/int-2017-0193.1.

Full text
Abstract:
The complexity of shale formation interpretation requires an accurate evaluation of a detailed petrophysical model in association with the analysis of the geomechanical properties. Mineralogy plays an important role in controlling shale’s mechanical properties, among which one of the most problematic parameters to establish is the Biot’s coefficient. Although, this parameter is necessary to determine the magnitude of the effective stresses acting in the reservoir, it is not included in the standard protocols used in Poland. This paper presents a comprehensive petrophysical and geomechanical evaluation of the unconventional reservoirs of lower Paleozoic age formation: lower Silurian and Ordovician deposits located in the onshore part of the Baltic Basin (Poland). In this study, the Biot’s coefficient from well-log data was calculated. Initially, a calibrated rock-physics model was derived to provide a set of relationships between the elastic and petrophysical properties. Based on an accurate, calibrated petrophysical model, the effective bulk modulus along with the Biot’s coefficient and horizontal stresses were calculated. Ultimately, the tectonic regime was determined. Using full-waveform sonic data analysis, the horizontal anisotropy was estimated. The directions of maximum and minimum horizontal stress were established based on several X-tended Range Micro Imager images of breakout structures and drilling-induced fractures.
APA, Harvard, Vancouver, ISO, and other styles
More sources

Dissertations / Theses on the topic "Petrophysical analysis"

1

Kamgang, Thierry T. "Petro physical evaluation of four wells within Cretaceous gas-bearing sandstone reservoirs, In block 4 and 5 orange basin, South Africa." University of the Western Cape, 2013. http://hdl.handle.net/11394/4259.

Full text
Abstract:
Masters of Science
Petrophysical evaluation of four wells within Cretaceous gas-bearing sandstone reservoirs in blocks 4 and 5 Orange Basin, South Africa. Thierry Kamgang The present research work evaluates the petrophysical characteristics of the Cretaceous gasbearing sandstone units within Blocks 4 and 5 offshore South Africa. Data used to carry out this study include: wireline logs (LAS format), base maps, well completion reports, petrography reports, conventional core analysis report and tabulated interpretative age reports from four wells (O-A1, A-N1, P-A1 and P-F1). The zones of interest range between 1410.0m-4100.3m depending on the position of the wells. The research work is carried out in two phases: The first phase corresponds to the interpretation of reservoir lithologies based on wireline logs. This consists of evaluating the type of rocks (clean or tight sandstones) forming the reservoir intervals and their distribution in order to quantify gross zones, by relating the behavior of wireline logs signature based on horizontal routine. Extensively, a vertical routine is used to estimate their distribution by correlating the gamma-ray logs of the corresponding wells, but also to identify their depositional environments (shallow to deep marine).Sedlog software is used to digitize the results. The second phase is conducted with the help of Interactive Petrophysics (version 4) software, and results to the evaluation of eight petrophysical parameters range as follow: effective porosity (4.3% - 25.4%), bulk volume of water (2.7% – 31.8%), irreducible water saturation (0.2%-8.8%), hydrocarbon saturation (9.9% - 43.9%), predicted permeability (0.09mD – 1.60mD), volume of shale (8.4% - 33.6%), porosity (5.5% - 26.2%) and water saturation (56.1% - ii 90.1%). Three predefined petrophysical properties (volume of shale, porosity and water saturation)are used for reservoir characterization. The volume of shale is estimated in all the wells using corrected Steiber method. The porosity is determined from the density logs using the appropriate equations in wells O-A1 and P-A1, while sonic model is applied in well A-N1 and neutron-density relationship in well P-F1. Formation water resistivity (Rw) is determined through the following equation: Rw = (Rmf × Rt) / Rxo, and water saturation is calculated based on Simandoux relation. Furthermore, a predicted permeability function is obtained from the crossplot of core porosity against core permeability, and it results match best with the core permeability of well O-A1. This equation is used to predict the permeability in the other wells. The results obtained reveal that average volumes of shale decrease from the west of the field towards the east; while average porosities and water saturations increase from the south-west through the east despite the decreasing average water saturation in well P-A1. A corroboration of reference physical properties selected for reservoir characterization, with predefined cut-off values result to no net pay zones identified within the reservoir intervals studied. Consequently, it is suggested that further exploration prospects should be done between well O-A1 and A-N1.
APA, Harvard, Vancouver, ISO, and other styles
2

Deakin, Mark J. W. "Integration of core and log data for petrophysical analysis of Brae conglomerates, North Sea." Thesis, Imperial College London, 1989. http://hdl.handle.net/10044/1/7475.

Full text
APA, Harvard, Vancouver, ISO, and other styles
3

Olajide, Oluseyi. "The petrophysical analysis and evaluation of hydrocarbon potential of sandstone units in the Bredasdorp Central Basin." Thesis, University of the Western Cape, 2005. http://etd.uwc.ac.za/index.php?module=etd&action=viewtitle&id=gen8Srv25Nme4_9559_1181561577.

Full text
Abstract:

This research was aimed at employing the broad use of petrophysical analysis and reservoir modelling techniques to explore the petroleum resources in the sandstone units of deep marine play in the Bredasdorp Basin.

APA, Harvard, Vancouver, ISO, and other styles
4

Sbiga, Hassan M. "Prediction and measurement of special core analysis petrophysical parameters in the Nubian sandstone of the North Africa." Thesis, Heriot-Watt University, 2013. http://hdl.handle.net/10399/2677.

Full text
Abstract:
One of the main objectives of this work was to investigate the applicability and accuracy of artificial neural networks for estimating special core analysis (SCAL) parameters from minimal core training data and wireline logs. The SCAL data was obtained from measurements on core plugs undertaken at the Libyan Petroleum Institute (L.P.I). Previous neural network studies have attempted to predict routine core analysis parameters, such as permeability, but not SCAL parameters such as true formation resistivity (Rt), resistivity index (RI), water saturation (Sw), saturation exponent (n) and Amott-Harvey Wettability Index (IA/H). Different combinations of wireline logs were used to train a variety of neural network predictors. Some of the predictors were trained using a large dataset from the entire cored interval of the training well. Other genetically focused neural network (GFNN) predictors were trained just from one short representative genetic unit (RGU) in the training well. The predictors were then tested in an adjacent well in the same oil field and also in another well in a different oil field. Significantly the performance of the GFNN predictors was as good (and in most cases better) than the predictors trained on the much larger dataset. This demonstrated the useful of the GFNN approach, which is very cost effective in terms of the minimal core that is required, and the reduced computer processing time. Moreover, this is the first time that these GFNN predictors have been used to predict SCAL parameters in the studied area, the Nubian Sandstone Formation in North Africa. These neural network predictors are particularly useful in this area due to the limited amount of SCAL data that is currently available. Quantitative statistical measures of heterogeneity were also examined on the reservoir samples, followed by a comparative analysis of hydraulic units (HUs) with a newer approach of global hydraulic elements (GHEs) to characterize the reservoir units in the studied area. The GHEs were then applied to select minimal representative core training data to train the genetically focused neural networks (GFNNs) to predict the SCAL parameters. The thesis also describes the factors affecting SCAL resistivity parameters. Laboratory measurements on the Nubian Sandstone reservoir rock samples showed changes in the formation resistivity factor (F) and cementation exponent (m) between ambient conditions and at overburden pressures. Changes were also observed in the saturation exponent (n) before and after wettability measurement. The experimental results also showed that there was a good relation between resistivity and the type of pore system which is consistent with study result from Swanson (1985) confirming earlier work.
APA, Harvard, Vancouver, ISO, and other styles
5

Kravets, Svetlana. "Stochastic modelling of the reservoir lithological and petrophysical attributes. A case study of the Middle East carbonate reservoir." Master's thesis, Faculdade de Ciências e Tecnologia, 2012. http://hdl.handle.net/10362/7834.

Full text
Abstract:
Dissertação para obtenção do Grau de Mestre em Engenharia Geológica (Georrecursos)
Carbonate reservoirs represent the significant part of oil and gas production. They produce about 50% of hydrocarbons globally. In order to provide the rational exploitation of deposits in carbonate reservoirs it is necessary to ensure accurate prediction and effectively overcome the technical barriers that occur in a complex carbonate formations. The main rules for successful project are to develop and apply reservoir characteristics, to predict performance and productivity, effectively manage diagenesis to optimize production and maximize recovery through reservoir simulation technology. The great development of digital modelling technologies gives the opportunities to solve these problems. Generation of models of carbonate reservoir rocks by simulating the results of the geological processes involved is very complicated. Mainly because the rock may have undergone several phases of diagenetic processes that might have modified or even completely overprinted texture and fabrics of the original carbonate rock. In spite of this problem, a modelling technique, originally developed for sandstones, has successfully been extended for the 3D modeling of carbonate reservoir rocks. The input data to the modelling is obtained from the geophysical data and logging. In the present work, the virtual pore scale models of carbonates were produced by simulating the results of the geological processes. The implemented methodology was divided into two main steps. The first stage was a Lithoclasses Modelling. The 3D stochastic geological model of the lithology was produced by the Sequential Indicator Simulation (SIS) algorithm. The second stage was an attribute modelling. The main properties such as porosity and permeability were computed according to the lithoclasses via Direct Sequential Simulation (DSS) algorithm with local histograms. The comparison of the two data sets showed high convergence for the main calculated properties. In the final stage of the work the geobody analysis was conducted. This type of the connectivity analysis performed the geometry of geological facies, trends for property distribution and permeability barriers.
APA, Harvard, Vancouver, ISO, and other styles
6

DePriest, Keegan. "PETROPHYSICAL ANALYSIS OF WELLS IN THE ARIKAREE CREEK FIELD, COLORADO TO DEVELOP A PREDICTIVE MODEL FOR HIGH PRODUCTION." OpenSIUC, 2019. https://opensiuc.lib.siu.edu/theses/2609.

Full text
Abstract:
All the oil and gas wells producing in the Arikaree Creek Field, Colorado targeted the Spergen Formation along similar structures within a wrench fault system; however, the wells have vastly different production values. This thesis develops a predictive model for high production in the field while also accounting for a failed waterflood event that was initiated in 2016. Petrophysical analysis of thirteen wells show that high producing wells share common characteristics of pay zone location, lithology, porosity and permeability with one another and that the Spergen Formation is not homogenous. Highly productive wells have pay zones in the lower part of the formation in sections that are dolomitized, and have anonymously high water saturation. This is likely related to the paragenesis of the formation that dolomitized the lower parts of the formation, increasing porosity and permeability, but leaving the pay zones with the high water saturation values. This heterogeneity likely accounts for the failed waterflood. Results show that the important petrophysical components for highly productive wells are the location of the payzone within the reservoir, porosity, permeability and water saturation. Additionally, homogeneity is crucial for successful waterflooding, which was not present.
APA, Harvard, Vancouver, ISO, and other styles
7

Mosavel, Haajierah. "Petrophysical characterization of sandstone reservoirs through boreholes E-S3, E-S5 and F-AH4 using multivariate statistical techniques and seismic facies in the Central Bredasdorp Basin." Thesis, University of the Western Cape, 2014. http://hdl.handle.net/11394/3984.

Full text
Abstract:
>Magister Scientiae - MSc
The thesis aims to determine the depositional environments, rock types and petrophysical characteristics of the reservoirs in Wells E-S3, E-S5 and F-AH4 of Area X in the Bredasdorp Basin, offshore South Africa. The three wells were studied using methods including core description, petrophysical analysis, seismic facies and multivariate statistics in order to evaluate their reservoir potential. The thesis includes digital wireline log signatures, 2D seismic data, well data and core analysis from selected depths. Based on core description, five lithofacies were identified as claystone (HM1), fine to coarse grained sandstone (HM2), very fine to medium grained sandstone (HM3), fine to medium grained sandstone (HM4) and conglomerate (HM5). Deltaic and shallow marine depositional environments were also interpreted from the core description based on the sedimentary structures and ichnofossils. The results obtained from the petrophysical analysis indicate that the sandstone reservoirs show a relatively fair to good porosity (range 13-20 %), water saturation (range 17-45 %) and a predicted permeability (range 4- 108 mD) for Wells E-S3, E-S5 andF-AH4. The seismic facies model of the study area shows five seismic facies described as parallel, variable amplitude variable continuity, semi-continuous high amplitude, divergent variable amplitude and chaotic seismic facies as well as a probable shallow marine, deltaic and submarine fan depositional system. Linking lithofacies to seismic facies maps helped to understand and predict the distribution and quality of reservoir packages in the studied wells
APA, Harvard, Vancouver, ISO, and other styles
8

De, Gasperi Patricia Martins Silva. "Estimativa de propriedades petrofisicas atraves da reconstrução 3D do meio poroso a partir da analise de imagens." [s.n.], 1999. http://repositorio.unicamp.br/jspui/handle/REPOSIP/264010.

Full text
Abstract:
Orientadores: Euclides Jose Bonet, Marco Antonio Schreiner Moraes
Dissertação (mestrado) - Universidade Estadual de Campinas, Faculdade de Engenharia Mecanica
Made available in DSpace on 2018-07-26T08:21:56Z (GMT). No. of bitstreams: 1 DeGasperi_PatriciaMartinsSilva_M.pdf: 13462853 bytes, checksum: cff9140cfbd41d9dc52865fb52425605 (MD5) Previous issue date: 1999
Resumo: Este trabalho tem como objetivos o estudo e a aplicação do processo de estimativa de propriedades petrofisicas a partir de informações obtidas em imagens petrográficas bidimensionais. O método assume a hipótese da homogeneidade estatística, e utiliza a simulação estocástica para a reconstrução do modelo tridimensional do meio poroso. A caracterização geométrica do meio simulado permite a elaboração de um modelo de rede para a simulação do fluxo e a estimativa da permeabilidade, fator de formação, pressão capilar por injeção de mercúrio e relação índice de resistividade versus saturação de água. Esta metodologia é aplicada a quatro sistemas porosos com diferentes níveis de heterogeneidade. Os resultados demonstram que estimativas confiáveis dependem da utilização de uma resolução apropriada de aquisição das imagens, que permita a identificação de poros e gargantas que efetivamente controlem as propriedades de fluxo do sistema. As curvas de pressão capilar simuladas sugerem a necessidade da composição de escalas. As propriedades elétricas são afetadas pela porosidade das amostras e sua confiabilidade é restrita a sistemas preferencialmente molháveis pela água
Abstract: The aim of this work is to investigate and apply a method for predicting petrophysical properties ftom bidimensional petrographic image data. Based on the assumption of statistical homogeneity, the method uses stochastic simulation to reconstruct the porous media tridimensional structure. The geometrical characterization of the simulated media allows the construction of a network model to simulate fluid flow and estimate permeability, formation factor, mercury capillary pressure curves and resistivity index as function of water saturation. This method is applied to four porous systems with different heterogeneity levels. The results demonstrate that good predictions depend on the appropriate image aquisition resolution, which identifies pores and throats that effectively control the flow properties of the system. The capillary pressure curves suggest the necessity of scale composition. The electrical properties are affected by samples porosity, with reliable estimates being restricted to water-wet systems
Mestrado
Mestre em Engenharia de Petróleo
APA, Harvard, Vancouver, ISO, and other styles
9

Schalkwyk, Hugh Je-Marco. "Assessment controls on reservoir performance and the affects of granulation seam mechanics in the Bredasdorp Basin, South Africa." Thesis, University of the Western Cape, 2006. http://etd.uwc.ac.za/index.php?module=etd&action=viewtitle&id=gen8Srv25Nme4_3459_1183461991.

Full text
Abstract:

The Bredasdorp Basin is one of the largest hydrocarbon producing blocks within Southern Africa. The E-M field is situated approximate 50 km west from the FA platform and was brought into commission due to the potential hydrocarbons it may hold. If this field is brought up to full producing capability it will extend the lifespan of the refining station in Mosselbay, situated on the south coast of South Africa, by approximately 8 to 10 years. An unexpected pressure drop within the E-M field caused the suite not to perform optimally and thus further analysis was imminent to assess and alleviate the predicament. The first step within the project was to determine what might have cause the pressure drop and thus we had to go back to cores drilled by Soekor now known as Petroleum South Africa, in the early 1980&rsquo
s.




Analyses of the cores exposed a high presence of granulation seams. The granulation seams were mainly subjected within sand units within the cores. This was caused by rolling of sand grains over one another rearranging themselves due to pressure exerted through compaction and faulting, creating seal like fractures within the sand. These fractures caused these sand units to compartmentalize and prohibit flow from one on block to the next. With advance inquiry it was discovered that there was a shale unit situated within the reservoir dividing the reservoir into two main compartments. At this point it was determined to use Petrel which is windows based software for 3D visualization with a user interface based on the Windows Microsoft standards. This is easy as well as user friendly software thus the choice to go with it. The software uses shared earth modeling tool bringing about reservoir disciplines trough common data modelling. This is one of the best modelling applications in the available and it was for this reason that it was chosen to apply within the given aspects of the project A lack of data was available to model the granulation seams but with the data acquired during the core analyses it was possible to model the shale unit and factor in the influences of the granulation seams to asses the extent of compartmentalization. The core revealed a thick shale layer dividing the reservoir within two sections which was not previously noted. This shale layer act as a buffer/barrier restricting flow from the bottom to the top halve of the reservoir. This layer is thickest at the crest of the 10km²
domal closure and thins toward the confines of the E-M suite. Small incisions, visible within the 3 dimensional models could serve as a guide for possible re-entry points for future drilling. These incisions which were formed through Lowstand and Highstand systems tracts with the rise and fall of the sea level. The Bredasdorp Basin consists mainly of tilting half graben structures that formed through rifting with the break-up of Gondwanaland. The model also revealed that these faults segregate the reservoir further creating bigger compartments. The reservoir is highly compartmentalized which will explain the pressure loss within the E-M suite. The production well was drilled within one of these compartments and when the confining pressure was relieved the pressure dropped and the production decrease. As recommendation, additional wells are required to appraise the E-M structure and determine to what extent the granulation seems has affected fluid flow as well as the degree of sedimentation that could impede fluid flow. There are areas still containing untapped resources thus the recommendation for extra wells.

APA, Harvard, Vancouver, ISO, and other styles
10

Hecht, Christian A. "Multi-scale, structural analysis of geomechanical and petrophysical properties of Permocarboniferous red beds Vielskalige Strukturanalyse der geomechanischen und petrophysikalischen Eigenschaften von Permokarbonischen red beds /." [S.l. : s.n.], 2003. http://deposit.ddb.de/cgi-bin/dokserv?idn=971623821.

Full text
APA, Harvard, Vancouver, ISO, and other styles
More sources

Books on the topic "Petrophysical analysis"

1

Jorgensen, Donald G. Petrophysical analysis of geophysical logs of the National Drilling Company-U.S. Geological Survey ground-water research project for Abu Dhabi Emirate, United Arab Emirates. [Reston, Va.]: U.S. Dept. of the Interior, U.S. Geological Survey, 1994.

Find full text
APA, Harvard, Vancouver, ISO, and other styles
2

Harvey. Petrophysical Properties of Crystaline Rocks. Geological Society of London, 2005.

Find full text
APA, Harvard, Vancouver, ISO, and other styles
3

K, Harvey P., and Geological Society of London, eds. Petrophysical properties of crystalline rocks. London: The Geological Society, 2005.

Find full text
APA, Harvard, Vancouver, ISO, and other styles
4

Doveton, John H. Principles of Mathematical Petrophysics. Oxford University Press, 2014. http://dx.doi.org/10.1093/oso/9780199978045.001.0001.

Full text
Abstract:
The pioneering work of Gus Archie moved log interpretation into log analysis with the introduction of the equation that bears his name. Subsequent developments have mixed empiricism, physics, mathematical algorithms, and geological or engineering models as methods applied to petrophysical measurements in boreholes all over the world. Principles of Mathematical Petrophysics reviews the application of mathematics to petrophysics in a format that crystallizes the subject as a subdiscipline appropriate for the workstations of today. The subject matter is of wide interest to both academic and industrial professionals who work with subsurface data applied to energy, hydrology, and environmental issues. This book is the first of its kind, in that it addresses mathematical petrophysics as a distinct discipline. Other books in petrophysics are either extensive descriptions of tool design or interpretation techniques, typically in an ad hoc treatment. It covers mathematical methods that are applied to borehole and core petrophysical measurements to estimate rock properties of fluid saturation, pore types, permeability, mineralogy, facies, and reservoir characterization. These methods are demonstrated by a variety of case studies and summaries of applications. Principles of Mathematical Petrophysics is an invaluable resource for all people working with data related to petrophysics.
APA, Harvard, Vancouver, ISO, and other styles
5

R, Passey Quinn, ed. Petrophysical evaluation of hydrocarbon pore-thickness in thinly bedded clastic reservoirs. Tulsa, Oklahoma: The American Association of Petroleum Geologists, 2006.

Find full text
APA, Harvard, Vancouver, ISO, and other styles
6

J, Horton Robert, and Geological Survey (U.S.), eds. Graphs and tables used to describe electrical measurements of samples of unconsolidated materials, USGS Petrophysical Laboratory - Denver. Denver, Colo: U.S. Dept. of the Interior, U.S. Geological Survey, 2000.

Find full text
APA, Harvard, Vancouver, ISO, and other styles

Book chapters on the topic "Petrophysical analysis"

1

Gupta, Archit, and Gaurav S. Gairola. "Integrated Reservoir Characterization Using Petrophysical and Petrographical Analysis." In Petro-physics and Rock Physics of Carbonate Reservoirs, 93–103. Singapore: Springer Singapore, 2019. http://dx.doi.org/10.1007/978-981-13-1211-3_7.

Full text
APA, Harvard, Vancouver, ISO, and other styles
2

Gerard, R. E., C. A. Philipson, F. M. Manni, and D. M. Marschall. "Petrographic Image Analysis: An Alternate Method for Determining Petrophysical Properties." In Automated Pattern Analysis in Petroleum Exploration, 249–63. New York, NY: Springer New York, 1992. http://dx.doi.org/10.1007/978-1-4612-4388-5_13.

Full text
APA, Harvard, Vancouver, ISO, and other styles
3

Zhu, Si-miao, Jia-gang Shen, Xu-qiang Chen, and Peng Lu. "Analysis of Petrophysical Conditions and Reservoir Prediction in South SC Fault Depression." In Springer Series in Geomechanics and Geoengineering, 2008–17. Singapore: Springer Singapore, 2020. http://dx.doi.org/10.1007/978-981-15-2485-1_181.

Full text
APA, Harvard, Vancouver, ISO, and other styles
4

Maurya, S. P., N. P. Singh, and Kumar Hemant Singh. "Sensitivity Analysis of Petrophysical Parameters Due to Fluid Substitution in a Sandstone Reservoir." In Petro-physics and Rock Physics of Carbonate Reservoirs, 267–80. Singapore: Springer Singapore, 2019. http://dx.doi.org/10.1007/978-981-13-1211-3_19.

Full text
APA, Harvard, Vancouver, ISO, and other styles
5

Movahed, Z., R. Junin, and H. Amiri Bakhtiari. "The Effect of Tar on the Petrophysical Analysis of FMI in Asmari Fractured Reservoir." In ICIPEG 2014, 239–45. Singapore: Springer Singapore, 2015. http://dx.doi.org/10.1007/978-981-287-368-2_22.

Full text
APA, Harvard, Vancouver, ISO, and other styles
6

Abdelkhalek, Wafa, Fetheddine Melki, Klaus Bauer, Michael Weber, and Abdelhamid Ben Salem. "The Lithostratigraphic Analysis and Petrophysical Characterization of the Campanian-Maastrichtian Formation in the Pelagian Basin (Northeast Tunisia)." In The Structural Geology Contribution to the Africa-Eurasia Geology: Basement and Reservoir Structure, Ore Mineralisation and Tectonic Modelling, 197–200. Cham: Springer International Publishing, 2018. http://dx.doi.org/10.1007/978-3-030-01455-1_42.

Full text
APA, Harvard, Vancouver, ISO, and other styles
7

Ma, Y. Z. "Petrophysical Data Analytics for Reservoir Characterization." In Quantitative Geosciences: Data Analytics, Geostatistics, Reservoir Characterization and Modeling, 201–30. Cham: Springer International Publishing, 2019. http://dx.doi.org/10.1007/978-3-030-17860-4_9.

Full text
APA, Harvard, Vancouver, ISO, and other styles
8

Herianto, Putra, Muhammad Fadhil, Suci Handayani Qolbi, Mohammad Risyad, and Beiruny Syam. "Naturally Fractured Basement Reservoir Potential Quantification from Fracture Model and Petrophysical Analysis by Leveraging Geostatistics and Seismic Interpretation: A Case Study in Jabung Block, South Sumatra Basin." In Springer Series in Geomechanics and Geoengineering, 360–68. Cham: Springer International Publishing, 2018. http://dx.doi.org/10.1007/978-3-319-99670-7_45.

Full text
APA, Harvard, Vancouver, ISO, and other styles
9

Ma, Y. Z. "Multiscale Heterogeneities in Reservoir Geology and Petrophysical Properties." In Quantitative Geosciences: Data Analytics, Geostatistics, Reservoir Characterization and Modeling, 175–200. Cham: Springer International Publishing, 2019. http://dx.doi.org/10.1007/978-3-030-17860-4_8.

Full text
APA, Harvard, Vancouver, ISO, and other styles
10

Asquith, George, Daniel Krygowski, Steven Henderson, and Neil Hurley. "Petrophysical Techniques." In Basic well log analysis. American Association of Petroleum Geologists, 2004. http://dx.doi.org/10.1306/mth16823c8.

Full text
APA, Harvard, Vancouver, ISO, and other styles

Conference papers on the topic "Petrophysical analysis"

1

Shevnin, V. A., A. A. Mousatov, A. A. Ryjov, and O. Delgado-Rodriguez. "Petrophysical Analysis of Resistivity Data." In Near Surface 2008 - 14th EAGE European Meeting of Environmental and Engineering Geophysics. European Association of Geoscientists & Engineers, 2008. http://dx.doi.org/10.3997/2214-4609.20146247.

Full text
APA, Harvard, Vancouver, ISO, and other styles
2

Dey‐Sarkar, S. K., and C. F. James. "Prestack analysis: Relevance of petrophysical properties." In SEG Technical Program Expanded Abstracts 1986. Society of Exploration Geophysicists, 1986. http://dx.doi.org/10.1190/1.1893096.

Full text
APA, Harvard, Vancouver, ISO, and other styles
3

Ioannidis, M. A., I. Chatzis, and M. J. Kwiecien. "Computer Enhanced Core Analysis For Petrophysical Properties." In Annual Technical Meeting. Petroleum Society of Canada, 1997. http://dx.doi.org/10.2118/97-53.

Full text
APA, Harvard, Vancouver, ISO, and other styles
4

Moghadasi, Leili, Ehsan Ranaee, Fabio Inzoli, and Alberto Guadagnini. "Petrophysical Well Log Analysis through Intelligent Methods." In SPE Bergen One Day Seminar. Society of Petroleum Engineers, 2017. http://dx.doi.org/10.2118/185922-ms.

Full text
APA, Harvard, Vancouver, ISO, and other styles
5

Arkalgud, Ravi, Andrew McDonald, and Derek Crombie. "DOMAIN TRANSFER ANALYSIS – A ROBUST NEW METHOD FOR PETROPHYSICAL ANALYSIS." In 2019 SPWLA 60th Annual Symposium. Society of Petrophysicists and Well Log Analysts, 2019. http://dx.doi.org/10.30632/t60als-2019_hhhh.

Full text
APA, Harvard, Vancouver, ISO, and other styles
6

Eltsov, Igor Nikolaevich, Mikhail Ivanovich Samoilov, Konstantin Victorovich Toropetsky, and Gleb Alexandrovich Borisov. "Evaluation of Petrophysical Relations by Using Cluster Analysis." In SPE Russian Petroleum Technology Conference. Society of Petroleum Engineers, 2020. http://dx.doi.org/10.2118/201970-ms.

Full text
APA, Harvard, Vancouver, ISO, and other styles
7

Vavilin, V. A., T. R. Galiev, E. V. Sorokina, and A. A. Kunakasov. "Using the NMR Relaxometer in Laboratory Petrophysical Analysis." In Tyumen 2013 - New Geotechnology for the Old Oil Provinces. Netherlands: EAGE Publications BV, 2013. http://dx.doi.org/10.3997/2214-4609.20142725.

Full text
APA, Harvard, Vancouver, ISO, and other styles
8

Alwast, N. K., R. A. Mireault*, and A. N. Mukhtar. "Petrophysical Analysis for Shale Gas Potential, Onshore Bahrain." In Second EAGE/SPE/AAPG Shale Gas Workshop in the Middle East. Netherlands: EAGE Publications BV, 2014. http://dx.doi.org/10.3997/2214-4609.20142258.

Full text
APA, Harvard, Vancouver, ISO, and other styles
9

Eltsov, Igor Nikolaevich, Mikhail Ivanovich Samoilov, Konstantin Victorovich Toropetsky, and Gleb Alexandrovich Borisov. "Evaluation of Petrophysical Relations by Using Cluster Analysis (Russian)." In SPE Russian Petroleum Technology Conference. Society of Petroleum Engineers, 2020. http://dx.doi.org/10.2118/201970-ru.

Full text
APA, Harvard, Vancouver, ISO, and other styles
10

El Khoury, Paul, Thomas Davis, and Paul Anderson. "Ordovician Red River Formation petrophysical analysis and seismic modeling." In SEG Technical Program Expanded Abstracts 2017. Society of Exploration Geophysicists, 2017. http://dx.doi.org/10.1190/segam2017-17647781.1.

Full text
APA, Harvard, Vancouver, ISO, and other styles

Reports on the topic "Petrophysical analysis"

1

Martha Cather, Robert Lee, Robert Balch, Tom Engler, Roger Ruan, and Shaojie Ma. Petrophysical Analysis and Geographic Information System for San Juan Basin Tight Gas Reservoirs. Office of Scientific and Technical Information (OSTI), October 2008. http://dx.doi.org/10.2172/966368.

Full text
APA, Harvard, Vancouver, ISO, and other styles
2

Byrnes, A. P., J. C. Wendte, and D. G. Sargent. Rock petrophysical analysis of Upper Devonian Jean Marie gas reservoir rocks in the July Lake area of northeastern British Columbia and in the contiguous area in northwestern Alberta. Natural Resources Canada/ESS/Scientific and Technical Publishing Services, 2007. http://dx.doi.org/10.4095/224581.

Full text
APA, Harvard, Vancouver, ISO, and other styles
3

Enkin, R. J., D. Cowan, J. Tigner, A. Severide, D. Gilmour, A. Tkachyk, M. Kilduff, and J. Baker. Physical property measurements at the GSC paleomagnetism and petrophysics laboratory, including Electric Impedance Spectrum methodology and analysis. Natural Resources Canada/ESS/Scientific and Technical Publishing Services, 2012. http://dx.doi.org/10.4095/291564.

Full text
APA, Harvard, Vancouver, ISO, and other styles
4

Hu, K., J. R. Dietrich, Z. Chen, and P. K. Hannigan. Petrophysical analyses of hydrocarbon reservoirs and overpressure zones in Tertiary deep-marine strata in the northern Beaufort-Mackenzie Basin, Arctic Canada. Natural Resources Canada/ESS/Scientific and Technical Publishing Services, 2018. http://dx.doi.org/10.4095/306960.

Full text
APA, Harvard, Vancouver, ISO, and other styles
5

Petrophysical analysis of geophysical logs of the National Drilling Company-U.S. Geological Survey ground-water research project for Abu Dhabi Emirate, United Arab Emirates. US Geological Survey, 1994. http://dx.doi.org/10.3133/wsp2417.

Full text
APA, Harvard, Vancouver, ISO, and other styles
You might also be interested in the extended bibliographies on the topic 'Petrophysical analysis' for particular source types:
Journal articles Dissertations / Theses
We offer discounts on all premium plans for authors whose works are included in thematic literature selections. Contact us to get a unique promo code!

To the bibliography