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GEO 2010
- Conference date: 07 Mar 2010 - 10 Mar 2010
- Location: Manama, Bahrain
- Published: 07 March 2010
441 - 457 of 457 results
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Chemical Stratigraphy: Feasibility of High Resolution Correlation - Outcrop Case<br>Study of a Submarine Slope Channel Complex (Tabernas Basin, Spain)
Chemical stratigraphy is the application of whole-rock inorganic geochemical analyses to characterize
and correlate strata, based on the recognition and interpretation of subtle variations in the bulk
chemical composition of sedimentary rocks. In recent years it has become an important tool in
enhancing correlation in subsurface reservoir successions in exploration industry. However this
technique widely lacks integration with sedimentological-based stratigraphic correlation methods, e.g.
lithostratigraphy, sequence stratigraphy. This study set out to examine the validity, accuracy and
limitations of the chemostratigraphic technique as correlation tool with the aid of outcrop studies
testing chemical stratigraphic correlations against sequence stratigraphic correlations.
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Mississippi Valley Type (MVT) Mineralization in the Khuff C Reservoirs, Saudi Arabia
More LessMississippi Valley Type (MVT) mineralization emplaced pyrite, sphalerite, galena, and gangue minerals,
such as saddle (baroque) dolomite into the C carbonate of the Khuff Formation, of Upper Permian age.
In most cases small percentages of MVT mineralization had been identified in several Khuff reservoirs,
both onshore and offshore. In one particular case MVT mineralization was represented by complete
replacement of carbonate beds and consisted of multiple, thick layers of mineral deposits that
contained moldic porosity. X-ray diffractometry confirmed the presence of pyrite, sphalerite, and
galena.
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Impact of High Resolution Seismic from Reservoir Modeling Minagish Oolite<br>Reservoir, Minagish Field, Kuwait
Authors Abdel M. Ebaid, Taher El Gezeery and Rakesh BahugunaThe Minagish field has several reservoirs with oil accumulated primarily in lower Cretaceous Minagish
Oolite -middle member (MMO) rocks. This giant carbonate hydrocarbon accumulation was discovered in
1959 and accounts for over 90% of oil production in the Field. As the reservoir pressure started to
decline, there was a need for water injection on the flanks of the structure to support the reservoir
pressure and to increase the oil production. The sequence stratigraphic analysis based on well logs,
cores and the old 3-D seismic sub-divided the reservoir into 13 geological layers with multiple phases
of ooid shoal development.
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Active Fluid Regime of the Basement Fractured Zones in Volga-Ural Region
More LessThe parametric well Novo-Yelkhovo-20009 penetrated loosely aggregated zones of the crystalline
basement including those occurring at a depth of more than 3.0 km below its top. Geophysical data
indicate aggregated zones. Most of them occur at a depth of more than 5000 m. From 1991 through
1996, mud sampling was repeatedly conducted in the well at specified depths, and the gas saturation
was studied. These studies showed that the amount of dissolved hydrocarbon gases and their
composition changed with time. Regrettably, no production tests have yet been conducted on the
loosely aggregated zones. These are supposed to contain brines and dissolved gases including
hydrocarbon ones. The quantitative and compositional variations of the dissolved gas recorded in the
course of the monitoring indicate its movement in the loosely aggregated zones due to possible
geodynamic and pressure changes in these zones. This means that the loosely aggregated zones of the
basement are geodynamically active.
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Investigations of the Basement Fractured Zones in the Volga-Ural Region
Geological structure of the Russian plate, including the territory of the Tatarstan Republic, and oil and
gas presence in the sedimentary cover of this region permit a conclusion that the Precambrian
crystalline basement (CB) can be considered as a potential target for hydrocarbon exploration. CB in
Tatarstan has been studied by deep drilling to a depth of several hundred metres to 4 km and by up-to
-date geophysical and geochemical techniques.
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Possible Oil Source Rock of Southern Caspian Sea with Consider Bivalves and<br>Gastropods
More LessMaikop series , in age upper-Oligocene to middle Miocene in Republic of Azerbaidjan (western Caspian
sea) and Caspian part its is petroleum source rock.So,considering interpret of results gained from
correlation between the Maikop series and the Miocene sediments in southern Caspian sea(Iranian
side),determined these sediments as probable petroleum source rock.Recent geochemical studies by
Research Center Oil Industry of Iran,reveald that Miocene sediments in southern Caspian sea(Iranian
side) can generate 5-10 milliard oil barrel.Therefore,in this research,Alamdeh-Galanderud and Nudeh-
Takam sections were selected and biostratigraphy studies with consider bivalves and gastropods were
done.In conclusion four conditions to form oil and gas are mentioned.
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Integrating Remote Sensing and GIS Technologies for Surface Geotechnical and<br>Geological Analysis
By Rob RossWhilst there is no substitute for the field work of experienced geoscientists in undertaking geological
and geotechnical surface mapping, increasingly surface mapping can be undertaken using remote
sensing technologies, together with GIS techniques, with greater confidence than in the past. Several
major issues caused problems with early remote sensing techniques, especially using early Landsat
satellites. Firstly, the poor resolution (80 metre pixel size) of the imagery and, secondly, the lack of
multi-spectral bands specifically dedicated to the detection of radiation useful to discriminate surface
geology.
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Comprehensive History Matching a Complex Carbonate Reservoir (Maydan Mahzam<br>Field, Offshore Qatar)
The Maydan Mahzam field in offshore Qatar is a complex carbonate oil reservoir of the Late Jurassic
Arab formation. It was brought on production in 1965, with a short period of natural depletion before
starting water injection through dump-flooders located on the flanks of the reservoir. An integrated
study has been launched by Qatar Petroleum in order to optimize the future development of the field
and maximize the future recovery of the remaining oil in place. In this context the understanding of the
main producing mechanisms of the past forty years is of major value. This requires reservoir modeling
with extensive and detailed history matching.
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Use of Pre-Stack Seismic Data to Guide the 3D Rock-Type Distribution of Arab-D in<br>Maydan Mahzam High-Resolution Geological Model
Maydan Mahzam is a carbonate field located offshore Qatar with principal oil production from the Arab-
D reservoir. In order to optimize the management of this mature field, Qatar Petroleum undertook a
comprehensive reservoir modeling exercise using an up-to-date integrated multi-disciplinary approach,
combining reservoir, geological, geophysical and production data. This paper illustrates how seismic
data has been used to quantitatively constrain the reservoir model between wells.
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Data Mining in Identifying Carbonate Litho-Facies from Well Logs Based from<br>Extreme Learning and Support Vector Machines
This research investigate the capabilities of data mining in identifying carbonate litho-facies from well
logs based on extreme learning and support vector machines. Formation facies usually influence the
hydrocarbon movement and distribution. Identifying geological formation facies is critical for economic
successes of reservoir management and development. The identification of various facies, however, is
a very complex problem due to the fact that most reservoirs show different degree of heterogeneity.
Last decade, there has been an intense interest in the use of both computational intelligence and
softcomputing learning schemes in the field of oil and gas: exploration and production to identify and
predict permeability and porosity, identify flow regimes, and predict reservoir characteristics. However,
most of these learning schemes suffer from numerous of important shortcoming. This paper explores
the use both extreme learning and support vector machines systems to identify geological formation
facies from well logs. Comparative studies are carried out to compare the performance of both extreme
learning and support vector machines with the most common empirical and statistical predictive
modeling schemes using both real-world industry databases and simulation study. We discuss how the
new approach is reliable, efficient, outperforms, and more economic than the conventional method.
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On Utilizing Functional Networks Computational Intelligence in Forecasting Rock<br>Mechanical Parameters for Hydrocarbon Reservoirs: Methodology and Comparative Studies
Rock mechanical parameters of reservoir rocks play an extremely important role in solving problems
related to almost all operations in oil or gas production. A continuous profile of these parameters along
with the depth is essential to analyze these problems which include wellbore stability, sand production,
fracturing, reservoir compaction, and surface subsidence. The mechanical parameters can be divided
into three main groups: viz., elastic parameters, strength parameters, and in-situ stresses. Even the
profile of in-situ stresses with depth is estimated using logs with elastic parameters as an essential
input. The focus of this article is on the prediction of elastic parameters along with the depth of a given
reservoir based on functional networks as a novel computational intelligence and data mining modeling
scheme.
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Hydrocarbon Potential of Devonian Sequence Jauf Formation - a Case Study from<br>Awali Field
Authors C.B. Reddy and Yahya Al-AnsariJauf Formation is of Lower to Middle Devonian age. It underlies Jubah and overlies Tawil formation with
conformable contacts. After deposition of Tawil, the shallow marine sands of the Jauf formation were
deposited over a broad shelf. It consists of thick Sandstone with thin Shale intercalations. Jauf
reservoir is relatively cleanest and most porous of all pre-Unayzah reservoirs. It is a continuous zone
with sand thickness varying from 250 to 400 ft. Jauf top is encountered at a depth of 11000 ft in the
structural crest and reach depths of over 15000 ft in flanks of Awali field area and penetrated in few
Awali wells. Individual porous layers are 5-15 ft thick and alternate with tight well-cemented
sandstones or shales. The zone proved to be gas bearing in a test conducted in two of the crestal wells
of Awali field. Gas shows were also reported in few drilled wells, but production testing was not carried
out in these wells.
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Evaluating Fundamental Controls from Depositional Facies Heterogeneity in a<br>Carbonate Ramp Using Forward Stratigraphic Modeling
Authors Miriam S. Andres, Paul M. Harris and Gareth D. JonesMuch of our understanding of the depositional facies heterogeneity, to date, derives from geological
concepts, outcrop studies and subsurface information. Deposited strata represent the unique solution
to a combination of fundamental controls at the time, not including subsequent diagenetic, tectonic
and/or burial overprint. Forward stratigraphic modeling (FSM), in contrast, provides an opportunity of
simulating multiple solutions by isolating one of the fundamental controls. In this capacity we use the
FSM tool ‘Dionisos’ to investigate the role of various input parameters and their control on a graindominated
carbonate ramp setting typical of the Middle East. Specifically, we focused on extent and
distribution of reservoir and non-reservoir facies as they are key to understanding and predicting
reservoir connectivity and potentially performance in carbonate ramps.
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Reactive Transport Models of Structurally Controlled Hydrothermal Dolomite:<br>Implications for Middle East Carbonate Reservoirs
Authors Gareth D. Jones, Ipsita Gupta and Eric SonnenthalHydrothermal dolomitization is present in several Middle East carbonate reservoirs including Ghawar,
the North Field and South Pars. Structurally controlled hydrothermal dolomitization describes the
replacement of limestone with dolomite and/or the precipitation of dolomite cement and associated
MVT minerals (anhydrite, sulfides, quartz and fluorite) as a consequence of subsurface brines that
ascend upwards through fault and fracture systems. This fluid rock interaction in the burial
environment has the potential to both improve and/or degrade reservoir quality depending on the
properties of the host rock, fluid composition, timing of fluid flow and spatial position relative to
structure.
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Strategies for Modeling Depositional Heterogeneity of Carbonate Ramps Using<br>Outcrop Analogs and Multiple Point Statistics
Authors Ted Playton, Jeroen Kenter, Marjorie Levy, Aurelien Pierre, Gareth D. Jones and Paul M. HarrisOutcrop exposures offer continuity, correlation, and resolution of geological data well beyond that of
the subsurface, and serve as ‘idealized’ analogs for reservoirs. In this study, measured sections,
photomosaic mapping, DGPS, and LIDAR data were collected along a 38 km dip exposure of Lower
Jurassic carbonate ramp strata in the High Atlas of Morocco, and converted into a static model using
multiple point statistics (MPS). The goal was to generate new modeling strategies through simulation
of ramp depositional heterogeneity during both transgressive (TST) and highstand (HST) conditions,
and for each of the facies belts observed (inner, middle, outer, and basinal ramp settings).
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The Ratawi Reservoir of the Partitioned Neutral Zone (PNZ), Saudi Arabia and<br>Kuwait
Authors Bonny Archuleta, Arthur Saller and Stevel BachtelThe Lower Cretaceous Ratawi Formation is a target for increased production and ongoing exploration
within the Partitioned Neutral Zone (PNZ). The Ratawi Formation consists of 3 members including: the
Ratawi Oolite (base), the Ratawi Limestone and the Ratawi Shale (top). Deposition of the Ratawi Oolite
and Ratawi Limestone occurred on a low-angle carbonate ramp roughly dipping to the east to
northeast. Oil from the Ratawi reservoir is currently being produced from the South Umm Gudair,
Wafra, and South Fuwaris fields. The purpose of this study is to better understand the reservoir
heterogeneity of the Ratawi at both the regional and field scale to provide inputs for future
development and exploration activities.
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Stratigraphy and Depositional History of the First Eocene Reservoir from Wafra<br>Field, Partitioned Neutral Zone (PNZ), Saudi Arabia and Kuwait
Authors Nial Toomey, Paul Montgomery and William S. MeddaughThe Paleocene/Eocene aged First Eocene reservoir at Wafra Field in the PNZ (Saudi Arabia and Kuwait)
is a dolomitized, heavy oil (18-22°API) carbonate reservoir. The 40 acre Large Scale Pilot (LSP) is
located in the southern portion of the field and contains 56 producers, injectors, and temperature
observation wells. Additionally, four cores were taken from the LSP area. The high well density and
variety of data types (Core, FMI, wireline logs) provides a unique opportunity to examine the
stratigraphy and depositional history of this complex carbonate system. This study focuses on the
EOC500 to EOC700 interval, which is the zone targeted for initial enhanced oil recovery.
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