[PDF] Reservoir Characterization And Modeling Of A Cretaceous Triple Porosity Carbonate Reservoir Contribution Of Pore Types To Hydrocarbon Pore Volume And Production Campeche Sound Gulf Of Mexico eBook

Author : Domenico Lodola
Publisher :
Page : pages
File Size : 48,31 MB
Release : 2004
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Determining the distribution of porosity and permeability is one of the main challenges in carbonate petroleum reservoir characterization and requires a thorough understanding of pore type and origin, as well as their spatial distributions. Conventional studies of carbonate reservoirs require interpretation and analysis of cores to understand porosity. This study investigates the use of NMR logs in the determination of pore type and origin. This study is based on the analysis of both thin section petrographic and NMR data from a single well that cored the Lower Cretaceous (Aptian) shelf carbonates belonging to the Shuaiba Formation of the Middle East. Photographs of thin sections were used to determine pore type and origin according to Ahr's genetic classification of carbonate porosity. Descriptive statistics and modeling were used to analyze the NMR T2 relaxation time distributions. Descriptive statistical analyses included estimating arithmetic average, standard deviation, skewness, median, mode and 90th percentile. T2 modeling was performed by fitting multiple log-normal distributions to the measured T2 distribution. Data from thin section petrography and from NMR measurements were then compared using conditional probabilities. As expected, thin section analysis revealed the predominance of mud-supported fabrics and micropores between matrix grains Vugs and dissolved rudistid fragments account for most of the macro porosity. Descriptive statistics showed that the mode and th percentile of the T2 distribution had the greatest power to discriminate pores by origin. The first principal component (PC1) of the mode-90th percentile system was then used to compute the probabilities of having each pore origin, knowing that PC1 belongs to a given interval. Results were good, with each origin being predictable within a certain range of PC1. Decomposition of the T2 distributions was performed using up to 3 log-normal component distributions. Samples of different pore origin behaved distinctively. Depositional porosity showed no increase in fit quality with increasing number of distributions whereas facies selective and diagenetic porosity did, with diagenetic porosity showing the greatest increase.

Author : Emily L. Stoudt
Publisher : SEPM (Society for Sedimentary Geology)
Page : 374 pages
File Size : 47,73 MB
Release : 1995
Category : Nature
ISBN :

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This collection of papers presents documentation for (1) approaches to be taken in developing a geologic framework for explaining layering, heterogeneity, and compartmentalization of a reservoir; (2) the value of outcrop data in improving understanding of reservoir performance; (3) methods for integrating, analyzing, and displaying geologic, petrophysical rock property, and engineering data to be used during field evaluation, management, and simulation; (4) geostatistical approaches that are being used to characterize the spatial distribution of reservoir properties and augment geologic descriptions, and (5) methods of displaying quantitative models of reservoir properties and reservoir simulation in three dimensions.

Author : Sharbel Al Haddad
Publisher :
Page : pages
File Size : 15,89 MB
Release : 2012
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Little Cedar Creek field is a mature oil field located in southeastern Conecuh County, Alabama, in the northeastern Gulf of Mexico. As of May 2012, 12.5 MMBLS of oil and 14.8 MMCF of natural gas have been produced from the field area. The main reservoirs are microbial carbonate facies and associated nearshore high energy shoal facies of the Upper Jurassic Smackover Formation that overlie conglomerate and sandstone facies of the Norphlet Formation and underlie the argillaceous, anhydritic-carbonaceous facies of the Haynesville Formation. These carbonate reservoirs are composed of vuggy boundstone and moldic grainstone, and the petroleum trap is stratigraphic being controlled primarily by changes in depositional facies. To maximize recovery and investment in the field, an integrated geoscientific-engineering reservoir-wide development plan is needed, including reservoir characterization, modeling, and simulation. This research presents a workflow for geological characterization, formation evaluation, and 3D geologic modeling for fields producing from microbial carbonates and associated reservoirs. The workflow is used to develop a 3D geologic model for the carbonate reservoirs. Step I involves core description and thin section analysis to divide and characterize the different Smackover facies in the field area into 7 units. The main reservoir facies are the microbial boundstone characterized by vuggy porosity and nearshore/shoal grainstone characterized by moldic porosity. Step II is well log correlation and formation evaluation of 113 wells. We use wireline logs and conventional core data analysis data to calculate average porosity values, permeability and water saturations. Neural networks are utilized at this stage to derive permeability where core measurements are absent or partially present across the reservoirs. Step III is building the 3D structural and stratigraphic framework that is populated with the petrophysical parameters calculated in the previous step. Overall, the integration of reservoir characterization, formation evaluation, and 3D geologic modeling provides a sound framework in the establishment of a field/reservoir-wide development plan for optimal primary and enhanced recovery for these Upper Jurassic microbial carbonate and associated reservoirs. Such a reservoir-wide development plan has broad application to other fields producing from microbial carbonate reservoirs.

Author : Wayne M. Ahr
Publisher : John Wiley & Sons
Page : 412 pages
File Size : 17,7 MB
Release : 2011-09-20
Category : Science
ISBN : 1118210387

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An accessible resource, covering the fundamentals of carbonate reservoir engineering Includes discussions on how, where and why carbonate are formed, plus reviews of basic sedimentological and stratigraphic principles to explain carbonate platform characteristics and stratigraphic relationships Offers a new, genetic classification of carbonate porosity that is especially useful in predicting spatial distribution of pore networks.

Author : Travis Barry
Publisher :
Page : pages
File Size : 45,27 MB
Release : 2012
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Carbonate reservoirs may have a variety of porosity types created by depositional, diagenetic, and fracture processes. This leads to the formation of complex pore systems, and in turn creates heterogeneities in reservoir performance and quality. In carbonate reservoirs affected by diagenesis and fracturing, porosity and peremeability can be independent of depositional facies or formation boundaries; consequently, conventional reservoir characterization methods are unreliable for predicting reservoir flow characteristics. This thesis provides an integrated petrographic, stratigraphic, and petrophysical study of the 'Canyon Reef' reservoir, a Pennsylvanian phylloid algal mound complex in the Horseshoe atoll. Core descriptions on three full-diameter cores led to the identification of 5 distinct depositional facies based on fundamental rock properties and biota. Fifty-four thin sections taken from the core were described are pores were classified using the Humbolt modification of the Ahr porosity classification. In order to rank reservoir quality, flow units were established on the basis of combined porosity and permeability values from core analysis. A cut off criterion for porosity and permeability was established to separate good and poor flow units. Ultimately cross sections were created to show the spatial distribution of flow units in the field.

Author : Robert P. Monicard
Publisher : Editions TECHNIP
Page : 182 pages
File Size : 45,14 MB
Release : 1980
Category : Technology & Engineering
ISBN : 2710803879

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This book describes porous media and how their physical, petrophysical, mechanical, electric and superficial properties are determined. The different measuring methods and the corresponding equipment are described. Core analysis (conventional or special) required for any reservoir engineering operation or for using mathematical models is explained. Analyses of sidewall cores and whole cores are also described in detail. Actual core-analysis examples are given. The book will be invaluable for engineers and technicians in laboratories dealing with the physico-chemistry of hydrocarbon fields and the hydrology of underground nappes. Specialists in reservoir engineering will also find the book particularly useful.

Author :
Publisher :
Page : 99 pages
File Size : 10,57 MB
Release : 2001
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The University of Alabama in cooperation with Texas A & M University, McGill University, Longleaf Energy Group, Strago Petroleum Corporation, and Paramount Petroleum Company are undertaking an integrated, interdisciplinary geoscientific and engineering research project. The project is designed to characterize and model reservoir architecture, pore systems and rock-fluid interactions at the pore to field scale in Upper Jurassic Smackover reef and carbonate shoal reservoirs associated with varying degrees of relief on pre-Mesozoic basement paleohighs in the northeastern Gulf of Mexico. The project effort includes the prediction of fluid flow in carbonate reservoirs through reservoir simulation modeling which utilizes geologic reservoir characterization and modeling and the prediction of carbonate reservoir architecture, heterogeneity and quality through seismic imaging. The primary objective of the project is to increase the profitability, producibility and efficiency of recovery of oil from existing and undiscovered Upper Jurassic fields characterized by reef and carbonate shoals associated with pre-Mesozoic basement paleohighs. The principal research effort for Year 1 of the project has been reservoir description and characterization. This effort has included four tasks: (1) geoscientific reservoir characterization, (2) the study of rock-fluid interactions, (3) petrophysical and engineering characterization and (4) data integration. This work was scheduled for completion in Year 1. Overall, the project work is on schedule. Geoscientific reservoir characterization is essentially completed. The architecture, porosity types and heterogeneity of the reef and shoal reservoirs at Appleton and Vocation Fields have been characterized using geological and geophysical data. The study of rock-fluid interactions has been initiated. Observations regarding the diagenetic processes influencing pore system development and heterogeneity in these reef and shoal reservoirs have been made. Petrophysical and engineering property characterization is progressing. Data on reservoir production rate and pressure history at Appleton and Vocation Fields have been tabulated, and porosity data from core analysis has been correlated with porosity as observed from well log response. Data integration is on schedule, in that, the geological, geophysical, petrophysical and engineering data collected to date for Appleton and Vocation Fields have been compiled into a fieldwide digital database for reservoir characterization, modeling and simulation for the reef and carbonate shoal reservoirs for each of these fields.

Author : Irena A. Maura
Publisher :
Page : pages
File Size : 39,84 MB
Release : 2013
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Redeposition of deep-water carbonates is poorly understood. As a consequence, quantifying their reservoir potential for hydrocarbon becomes extremely challenging. As such, this study aims provide a robust assessment of reservoir potential from Cretaceous -- Tertiary redeposited deep-water carbonates. A comprehensive sedimentological description and petrophysical characterization includes sonic velocity, porosity and permeability from basinal samples adjacent to Adriatic carbonate platforms. The samples were collected from three areas; (1) Maiella platform margin, an isolated Mesozoic to Mid-Tertiary carbonate platform (2) Monte Conero, an isolated anticline of the distal section of the turbidite facies (3) Well 1, an offshore well in the Adriatic sea, which represents the subsurface analog of the basinal sediments in the Apennines. The redeposited deep-water carbonates are comprised of: breccias, turbidites, slumps, and blocks, contained in fine-grained background sediments. Analysis shows that breccias and calciturbidites are the two dominant redeposited deep-water carbonates facies. They are the thickest and the most common facies in both core and in outcrop. For the three locations, the Maiella deposits tend to be coarser and thicker compared to the others, which indicates that Maiella is situated in the proximal part of the basin. The petrophysical measurements from the three study sites exhibit a remarkably wide scatter in the data. The petrophysical measurements from the three study sites feature a wide range of data distribution. Overall, the petrophysical datasets show that Cretaceous breccias and calciturbidites from the Maiella are the most porous and permeable facies compared to similar facies from the Monte Conero and Well 1. The maximum porosity of the Maiella breccias and calciturbidites can reach up to 30.27% and 32.01%, respectively. The maximum permeability can reach up to 522.1 md for the Cretaceous calciturbidites and 129.151 md for the Cretaceous breccias. Velocity measurement shows that at any given porosity, the samples from Monte Conero and Maiella are the faster compared to Well 1. The maximum velocity of Monte Conero and Maiella samples reach 6554.38 m/s and 6325 m/s respectively and sit above the Wyllie's time average line and create a positive deviation from the line. In addition to porosity and velocity, the influence of pore geometry to velocity and permeability of redeposited deep-water carbonates shown that the samples with the bigger and simpler pores (larger DomSize number and smaller PoA number) tend to have a higher velocity and permeability value, whereas, samples with the smaller and complicated pores tend to have a lower velocity and permeability value. Petrophysical data of redeposited deep-water carbonates demonstrate that these deposits have good potential as hydrocarbon reservoir's thick, porous, and permeable. Furthermore, the juxtaposition of the redeposited beds with the background sediments would form an excellent stratigraphic trap and/or seal.