Abstracts and Presentation Schedule

Transcripción

SEISMIC PROCESSING TO SUBSURFACE
MODELING IN HIGH DEFINITION
Booth #18
3D Visualization Room (Sala C)
IX Congreso de Exploración y Desarrollo de Hidrocarburos
November 3-7, 2014
Hotel Intercontinental
Mendoza, Argentina
Abstracts and Demonstration Schedule
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pdgm.com
Paradigm Presentation Schedule - Visualization Room (Sala C)
Wednesday, November 5
9:30
Water Saturation Functions Modeling Using Capillary Pressure Tests
Featured technology: Geolog®
10:20
Seismic Facies Classification Scenarios: From Waveform to Rock Type
Featured technologies: Stratimagic®/SeisFacies®, supervised facies prediction
11:20
The Impact of Structure on Production
Featured technology: SKUA-GOCADTM
13:00
Lunch
15:00
Volume Interpretation: Go Beyond Traditional Seismic Interpretation for an Accurate 3D Geological Model
16:30
Maximum Geological Information from Seismic: Full-azimuth Anisotropic Depth Imaging - A Case Study from Poland
Featured technology: EarthStudy 360®
17:30
Effective Assessment of Development Scenarios in the Context of Mixed Structural and Petrophysical Uncertainties
Thursday, November 6
9:30
Volume Interpretation: Go Beyond Traditional Seismic Interpretation for an Accurate 3D Geological Model
10:20
Fracture Modeling through Simulation
11:20
Formation Evaluation on Shale Plays
13:00
Lunch
15:00
Better Completion Decisions and Optimized Well Plan Trajectories through Fracture Characterization at the Wellbore
16:30
Stimulation Workflow for Shale Resource Plays
17:30
Friday, November 7
9:30
10:20
Paper: Caracterización de Discontinuidades Sismicas: Cálculo y Procesos de Atributos Sobre Amplitud
Featured technologies: Probe®, SeisEarth®
11:20
13:00
Lunch
15:00
Maximum Geological Information from Seismic: Full-azimuth Anisotropic Depth Imaging - A Case Study from Poland
Featured technology: EarthStudy 360®
16:30
17:30
The Impact of Structure on Production
Congress Activities with the Participation of Paradigm Technical Experts
Thursday, November 6
11:00
Workshop: Geofísica para no Geofísicos
12:40
Paper: Caracterización de Discontinuidades Sismicas: Cálculo y Procesos de Atributos Sobre Amplitud
Presented by Mario Atencio, Daniel Rendon, Simposio de Geofísica - Sala 2
Presented by Jaime Yañez, Jornadas de Geotecnologia - Sala 6
Friday, November 7
15:30
Paper: New Technologies and Integration for Optimizing Well Placement and Production
Presented by Bruno de Ribet, Simposio de Geofísica - Sala 2
Live Presentations in the 3D Visualization Room (Sala C): Abstracts
Thursday, 16:30, Friday, 9:30
Presented by Aymen Haouesse
Assessing the extent and shape of the rock volume affected by hydraulic
fracturing is one of today’s greatest challenges in unconventional shale plays.
It is often considered to be the key to estimating production from horizontal
wells and optimizing field development. Microseismic events provide valuable
information for assessing hydraulic fracture propagation and quantifying
stimulated rock volumes.
In this presentation we will show how we integrate geophysical, geological
and engineering data into our modeling platform, along with a workflow
for visualizing, analyzing and interpreting microseismic data in order to
estimate stimulated rock volume.
Featured Technologies: SKUA-GOCAD™
The Impact of the Structure on Production
Wednesday, 11:20, Friday, 17:30
Presented by Marcela Feilhaber
Accurate subsurface modeling is of upmost importance when characterizing
oil and gas reservoirs. When referring to the 3D geologic model, it is
therefore mandatory to integrate the valuable information delivered by
geoscientists and reservoir engineers and to account for its associated
uncertainty.
Representation of the structure and stratigraphy of the geologic model has a
non-negligible impact on hydrocarbon volume estimation and flow behavior,
and integrating the structural interpretation into its construction becomes
the main challenge. For example, the positioning of faults often determines
the extent of the reservoir and its internal compartmentalization, and affects
hydrocarbon in-place volumes, well positioning, fault seal calculations, and
of course reserves. It is seldom considered during history matching.
This demonstration will show the contribution of an effective technology
for geological modeling in complex environments by integrating all data
with no simplification. It will also show a new approach based on the
SKUA UVT Transform®, that enables the stochastic simulation of a complete
structural model, including multiple horizons and faults, automatically
updating the associated geological model. Combined with petrophysical
uncertainty, this approach enables quantification of the impact of structure
on reservoir volumes and connectivity, as well as on production forecasts.
Fracture Modeling through Simulation
Thursday, 10:20
Accurate fracture modeling, one of the greatest challenges in 3D modeling,
impacts directly on production, storage and seal characteristics of the
reservoir. Whether the fractures occur naturally or are induced, the process
requires a deeper understanding of the subsurface, fracture network
connectivity and the interaction between the matrix and fracture networks.
In this presentation we will show an effective workflow for creating
the input parameters required by dual-porosity flow simulators to study
fractured reservoirs. We will explain how to create a discrete fracture
network (DFN) by incorporating all available measured data, seismic
interpretations, well bore fracture orientations, seismic attributes and
geomechanical attributes. The resulting networks are then upscaled
to provide effective properties, such as fracture porosity, fracture
permeability and shape factor, and exported to the simulator. This
integrated work will generate geologically realistic fracture network
and therefore a more accurate model.
Effective Assessment of Development Scenarios in the Context
of Mixed Structural and Petrophysical Uncertainties
Wednesday, 17:30
This presentation will demonstrate a new, integrated approach, based on
the SKUA UVT Transform, which makes it possible to stochastically simulate
a complete structural model, including multiple horizons and faults,
while maintaining the integrity of seismic interpretations. By considering
uncertainty envelopes around faults and horizons, both structural and
3D geological models are automatically updated. These interpretation
and time-to-depth conversion uncertainties can then be combined with
petrophysical modeling uncertainties, enabling quantification of the impact
on reservoir volumes, connectivity, and thus on production forecasts.
Featured Technology: SKUA-GOCAD™
Thursday, 11:20, Friday, 16:30
Presented by Ruben Charles
For hydrocarbon extraction in shale plays to be an economic success,
we need better insight into the heterogeneity of facies in the formation
of interest, and we need to characterize the mechanical properties in
order to understand stress orientation. In this presentation, we will
show technologies for geomechanics and shale gas workflows in
conjunction with multimineral analysis. Together, these help us face
the challenges we encounter in these types of plays.
Featured Technology: Geolog®
Better Completion Decisions and Optimized Well Plan
Trajectories through Fracture Characterization at the Wellbore
Wednesday, 15:00
Natural fracture orientation is a key parameter for improving well
trajectories, and fracture density can be decisive when making completion
decisions. Wellbore images provide us with this information, and we need
tools that can help us improve the quality and and process of handling
image data, in order to perform better manual or automatic interpretations,
regardless of the tool configurations and acquisition methods. The workflow
in this presentation includes the calculation of aperture, count and density.
Water Saturation Function Modeling Using Capillary Pressure Tests
Thursday, 9:30
Capillary pressure tests are an invaluable source of information about the
process of imbibition and drainage of fluids in the rock. Its application
in determining the free water level in the reservoir and the estimation of
saturation, regardless of the problems related to methods based on resistivity
measurements, is a substantial improvement in understanding the distribution
of fluids in the reservoir. Data handling and modeling saturation functions
frequently involve tedious and inefficient processes over time. We will discuss
the tools that enable fast and efficient construction of saturation models in
an integrated petrophysical interpretation in a well log environment.
Seismic Facies Classification Scenarios: From Waveform to Rock
Type
Wednesday, 10:20, Thursday, 17:30, Friday, 11:20
Presented by Bruno de Ribet
Seismic facies analysis and automated classification processes play an
increasingly vital role in seismic stratigraphy interpretation and reservoir
characterization workflows. Advances in seismic acquisition, processing
and imaging are giving geoscientists access to high definition subsurface
images. One approach to interpreting this data is to categorize the
variation in the shape of the seismic response using pattern recognition
technology. As the seismic waveform carries information such as phase,
frequency and amplitude, one should expect that variations in these
seismic trace characteristics will correlate to changes in reservoir porosity,
lithology or fluid content.
This qualitative approach has demonstrable value, particularly at the
wellbore, where seismic-to-well calibrations are strengthened by
the classification process. The approach is limited, however, as the
classification procedure makes assumptions regarding the seismic signal
response and does not carry the full 3D reservoir description, including
the accurate distribution of principle rock types.
This presentation introduces an innovative, complementary new workflow
to expand the traditional uses of seismic attribute data for seismic
characterization. It uses classification procedures to predict lithofacies
away from the wellbore and to assess uncertainty for each rock type. This
innovation captures reservoir heterogeneities and detail normally not feasible
in standard reservoir characterization workflows, and allows geoscientists
to build or update a 3D geologic model with quantification of uncertainties.
This presentation will illustrate a breakthrough in the use of Stratimagic,
the pioneering computer-aided seismic facies classification system, and will
describe how rock type prediction from seismic data enhances prospecting
and field development.
Featured Technologies: Stratimagic®/SeisFacies®, Supervised
Facies Prediction
Volume Interpretation: Go Beyond Traditional Seismic
Interpretation for an Accurate 3D Geologic Model
Wednesday, 15:00, Thursday, 9:30
Presented by Bruno de Ribet
As a seismic interpreter, how much seismic data can I interpret? How
much time can I afford to spend interpreting a single seismic volume? How
many seismic events do I need to interpret to obtain the best stratigraphic
understanding of my seismic data?
This presentation demonstrates a new perspective for volume
interpretation and provides a unique workflow that combines use
of the Seismic Propagator to automatically track all relevant seismic
events with the SKUA UVT Transform, enabling users to quickly build
an accurate and high definition chronostratigraphic model. The fine
scale 3D model can then be used directly for stratigraphic interpretation,
reservoir modeling and reservoir characterization. The chronostratigraphic
model will match all seismic coherent signals, and not only the few horizons
typically interpreted. This ensures accurate use of seismic information in
stratigraphic interpretation and reservoir modeling.
Featured Technologies: SKUA-GOCADTM
Maximum Geological Information from Seismic Using Full
Azimuth Anisotropic Depth Imaging: A Case Study from Poland
Wednesday, 16:30, Friday, 15:00
Presented by Jaime Yañez
In this case study of an onshore, full-azimuth seismic survey for
unconventional hydrocarbon exploration, the approach is based on fullazimuth, pre-stack depth migration and full-azimuth tomography. This
approach enabled us to build a high-resolution model of the medium,
estimate seismic azimuthal anisotropy, and produce seismic data that
was ready for reservoir characterization. This is particularly important
when prospecting in unconventional resources. Many limitations and
inaccuracies related to workflows based on time domain imaging and
data processing in sectors were overcome.
The 3D full-azimuth, depth domain angle gathers which resulted from
the workflow ensured: Minimal impact of the overburden medium model
and acquisition geometry on amplitudes; information about fractures/
stress on the basis of independent information (azimuthal RMO analysis,
azimuthal AVA analysis, diffraction images); a comprehensive, detailed
analysis of seismic anisotropy; and other information which was not
available earlier, such as subsurface illumination and specular image.
Featured Technology: EarthStudy 360®
Workshop “Geofísica para no Geofísicos”
6 de Noviembre, 11.00 – Jornadas de Geotecnología - Sala 6
Presentado por Jaime Yañez (Paradigm Argentina)
Geofísica para no geofísicos es una breve sesión de dos horas orientada a todos
aquellos profesionales no geofísicos que de alguna manera están vinculados a
la industria de la exploración petrolera. Los objetivos de la sesión son:
• Proveer un conocimiento informativo básico sobre las disciplinas que
componen la geofísica de exploración petrolera.
• Proveer un manejo básico del lenguaje técnico de la geofísica de exploración.
• Proveer un conocimiento básico de las características y requerimientos de las
aplicaciones usadas en el procesamiento e interpretación de datos sísmicos.
Los principales temas que se abordaran durante la presentación son: La
geofísica como ciencia-métodos geofísicos de prospección-exploración
petrolera-el método sísmico de reflexión-adquisición de datos sísmicosprocesamiento de datos sísmicos-interpretación de datos sísmicos.
Papers in the Oral Technical Sessions: Abstracts
Caracterización de Discontinuidades Sismicas: Cálculo y
Procesos de Atributos Sobre Amplitud
Thursday, 12:40
Presented by Mario Atencio, Federico Spath (YPF), Daniel
Rendon (Paradigm), Simposio de Geofísica - Sala 2
El estudio de reservorios Convencionales al igual que el de los nuevos objetivos
No Convencionales pone énfasis en varios frentes de análisis, desde
el estudio del ambiente depositacional y las propiedades geológicas
específicas, hasta la incorporación de conceptos como contenido de materia
orgánica, presión poral de reservorios y fragilidad de las rocas, entre otras. En
ambos casos, la interpretación y caracterización de las fallas o fracturas posee
un papel importante según el objetivo y tipo de reservorio investigado.
Para los casos Convencionales su identificación es útil para definir límites de
áreas de interés; mientras que para los No Convencionales, se suma además
su influencia tanto en la optimización de la ubicación de la propuesta de
pozos, como en la etapa de terminación.
El concepto de discontinuidad sísmica, representado por desplazamientos
verticales y horizontales, presencia de flexuras y/o variaciones laterales
de las propiedades de los reflectores sísmicos está ligado al concepto
geológico de fallas, fracturas o aspectos estratigráficos de un
determinado ambiente geológico.
El presente trabajo focaliza en el cálculo de atributos geométricos
sobre un dato sísmico 3D para la caracterización de discontinuidades
indicativas de fracturas sísmicas a sub-sísmicas asociadas al concepto de
fallas y/o fracturas geológicas. Los atributos geométricos calculados
fueron: curvatura, coherencia, técnica de volúmenes de Amplitud
(TecVA) y variantes de TecVA. Se presenta un análisis de su efecto en
la interpretación y los aportes que realizan a partir de comparaciones y
combinaciones entre ellos.
New Technologies and Integration for Optimizing Well
Placement and Production
Friday, 15:10
Presented by Bruno de Ribet, Simposio de Geofisica - Sala 2
The challenges for optimal well placement and completion in
unconventional resource plays rely on a complex array of seemingly
independent variables, such as heterogeneous rock properties, anisotropy
and natural sub-seismic fracture networks. To ensure a successful shale
well, one must drill at a target favorable in fluid content, in-situ stress
and rock properties. No shales are created equally.
To maximize production rates, criteria such as water saturation, hydrocarbon content, physical and mechanical rock properties, in-situ stress
fields, faulting and fracturing must be evaluated and then quantified for
integration into a single model. The results can efficiently impact drilling
and development decisions. Both wireline log data (for rock and reservoir
parameters) and seismic data (for rock fabric and property information
between wells) need to be correlated into an integrated interpretation for
reservoir characterization and discrete fracture model creation.
Geoscientists have been searching for solutions that can determine and
qualify “sweet spots” in shale formations, where output and recovery rates
are highest. Because of its highly heterogeneous nature, identifying and
ranking these “sweet spots” requires various measurements. Seismic data
can provide one of them. Interpreting high-quality seismic data through
enhanced visualization techniques leads to more precise characterization of
the reservoir, enhancing prediction of the spatial and temporal conditions
of trapping systems, the distribution of subsurface lithology, and reservoir
properties, calibrated to the in-situ conditions observed at the wells.
New technologies help to identify and mitigate potential hazards
that drilling engineers may encounter by integrating interpretation,
characterization and reservoir modeling information in a unique 3D canvas,
leading to reduced drilling risk. The evaluation of rock and reservoir
parameters is closely associated with the development of new technologies.
These technologies are reviewed and illustrated by Barnett and Eagle Ford
examples, and culminate in well planning and drilling (geosteering).
Welcome to Paradigm Booth #18!
Paradigm is pleased to invite you to Booth #18 at the 9th Hydrocarbon Exploration and Development Congress and
Exhibition, organized by the Exploration and Development Committee from the Argentinean Oil and Gas Institute
(IAPG). Please join us as we present the latest version of our comprehensive Paradigm 14 release, which delivers
advanced science for everyone. Watch our demos, to learn how we provide high-definition workflows in the areas
that interest you the most, from seismic processing to subsurface modeling.
About Paradigm
Paradigm is the largest independent developer of software-enabled solutions to the global oil and gas industry.
Customers rely on Paradigm software to discover and extract hydrocarbon resources and make better business
decisions. Paradigm solutions span critical exploration and production disciplines, from seismic processing and
imaging to interpretation and modeling, reservoir characterization, and well planning and drilling.
Paradigm offers a rich portfolio of productivity tools and scientifically advanced applications for geologists,
geophysicists and engineers who construct subsurface models from oilfield and other measurements. Paradigm
solutions share a unified 3D visualization canvas and a network-based data management infrastructure.
Paradigm E&P Domains
Seismic Processing & Imaging – Paradigm technologies and methodologies provide a robust velocity analysis
solution that can reduce positional uncertainty, improve reliability of all information derived from the seismic
data, and integrate interpretation and modeling with the seismic imaging framework.
Interpretation & Modeling – Paradigm offers innovative tools to improve productivity without compromising
quality, by merging interpretation and modeling processes in a common environment, and by providing
automated and interactive tools that enable users to interpret and accurately model complex structures and
identify stratigraphic features in a highly efficient manner.
Reservoir Characterization – Paradigm solutions enable users to transform wellbore data into answers for
governing reservoir management programs and optimizing hydrocarbon recovery. Users can seamlessly connect
geophysical and petrophysical data to locate and evaluate new prospects and maximize production in proven
fields.
Reservoir Engineering – A collaborative environment to facilitate transfer and iterations between geological
models and flow simulation for reliable production forecasts, reserves estimation and development risks
assessment.
Well Planning & Drilling Engineering – Paradigm offers a highly integrated portfolio of well planning and
drilling technologies designed to help improve well planning accuracy, reduce drilling risk and optimize wellbore
placement.
Data Management & Interoperability – The Epos® data management and interoperability framework provides
users with a robust, scalable platform for the management of exploration and development data. Epos offers a
common database, unified look and feel, and shared access to software.
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Notes

Abstracts and Presentation Schedule

Transcripción

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