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Collaborating Authors
Gulf of Mexico
Genesis Field, Gulf of Mexico, 4-D Project Status And Preliminary Lookback
Hudson, Tom (ChevronTexaco North America Upstream Exploration and Production Company) | Regel, Bernard (ChevronTexaco North America Upstream Exploration and Production Company) | Bretches, John (ChevronTexaco North America Upstream Exploration and Production Company) | Condon, Pat (ChevronTexaco Energy Technology Company) | Rickett, James (ChevronTexaco Energy Technology Company) | Cerney, Brian (ChevronTexaco Energy Technology Company) | Inderwiesen, Phil (ChevronTexaco Energy Technology Company) | Ewy, Russ (ChevronTexaco Energy Technology Company)
ABSTRACT A 4D seismic survey was acquired over Genesis Field, deepwater Gulf of Mexico, in October, 2002 specifically for reservoir monitoring and field management. The acquisition criteria were designed to replicate the pre-production baseline survey. Both baseline and monitor surveys were co-processed to minimize differences except those related to production. Extensive interpretation of reflection seismic volumes and preliminary interpretation of acoustic impedance (AI) volumes show production-related time-lapse anomalies including changes in reflection strength due to fluid movement and pressure reduction and an increase in travel time of up to 10 ms at the top of the producing interval due to reservoir compaction and overburden dilation. Current assessment indicates that the 4D project will add significant value to the field.
- Geophysics > Time-Lapse Surveying > Time-Lapse Seismic Surveying (1.00)
- Geophysics > Seismic Surveying (1.00)
- North America > United States > Gulf of Mexico > Central GOM > East Gulf Coast Tertiary Basin > Green Canyon > Block 205 > Genesis Field > Neb Formation (0.99)
- Europe > United Kingdom > North Sea > Southern Gas Basin (0.99)
ABSTRACT Extensive deep-water mass transport deposits are observed both in slope as well as basin settings. These deposits can occur as sheets, lobes, and channel fills, and can reach 150 m or more in thickness. Greater thicknesses are observed where successive flows are amalgamated. This report documents both the internal architectural/stratigraphic as well as the external geomorphic attributes of such deposits as imaged by 3D seismic data. Mass transport deposits can be recognized seismically by certain geomorphologic as well as stratigraphic distinguishing characteristics: 1) surfaces underlying such deposits commonly are characterized by extensive scour, commonly taking the form of extensive linear grooves as much as 20 km long, 750 m wide, and 40 m deep, that tend to diverge down-system. These grooves are inferred to be formed by the passage of blocks imbedded at the base of the flow mass that are dragged across the underlying sea floor. 2) The upper bounding surface commonly is characterized by irregular to hummocky relief and can be bounded laterally by steep to gentle flanks. 3) In section view, mass transport deposits are characterized by transparent to chaotic seismic reflections. Mass transport units commonly amalgamate, although surfaces between successive mass transport deposits can be obscure and difficult to recognize. 4) The morphology of mass transport deposits can be channel or lobe form. Mass transport channels are relatively straight and commonly floored by a grooved base. In some instances mass transport lobes are characterized by extensive low-angle thrust faults associated with compression, commonly at their termini.
- Geology > Geological Subdiscipline > Stratigraphy (1.00)
- Geology > Structural Geology > Fault > Dip-Slip Fault > Reverse Fault > Thrust Fault (0.36)
- Geology > Sedimentary Geology > Depositional Environment > Marine Environment > Deep Water Marine Environment (0.31)
From Fill to Spill: Partially Confined Depositional Systems, Magnolia Field, Garden Banks, Gulf of Mexico
McGee, David T. (ConocoPhillips, Houston, TX) | Fitzsimmons, Roy F. (Norske Conoco AS, 4070 Randaberg, Norway (Current Address BHP Billiton, Houston, TX)) | Haddad, Geoffrey A. (ConocoPhillips, Houston, TX)
This dynamic balance controls the channel architecture that develops and changes systematically through deposition. The B20/25 complex of Magnolia Field is one of several reservoirs deposited at the southern end of a salt bounded mini-basin in the Garden Banks protraction area. This complex was deposited in the transition from the ponded basin succession to the bypass facies succession indicating that the salt movement and its ability to create accommodation space was waning and subsidence was becoming the main space creating force. Integrated analysis of sedimentological core description, dipmeter image logs and pressure data with detailed seismic facies analysis has lead to the interpretation that the B25 is an amalgamated channel complex that became more intensely amalgamated as the system came to the southern margin of the minibasin and felt the effects of the salt-induced topographic high. The system did not pond up against the salt ridge, but erosively amalgamated as the local gradient increased.
- North America > United States > Gulf of Mexico > Central GOM (0.78)
- North America > United States > West Virginia > Mingo County (0.66)
- North America > United States > West Virginia > Logan County (0.66)
- North America > United States > Mississippi > Pike County (0.66)
- North America > United States > Gulf of Mexico > Central GOM > West Gulf Coast Tertiary Basin > Garden Banks > Block 784 > Magnolia Field (0.99)
- North America > United States > Gulf of Mexico > Central GOM > West Gulf Coast Tertiary Basin > Garden Banks > Block 783 > Magnolia Field (0.99)
Well-log Analysis of Pore Pressure Mechanisms Near a Minibasin-bounding Growth Fault At South Eugene Island Field, Offshore Louisiana
Haney, Matthew M. (Center for Wave Phenomena, Department of Geophysics, Colorado School of Mines) | Hofmann, Ronny (Center for Rock Abuse, Department of Geophysics, Colorado School of Mines) | Snieder, Roel (Center for Wave Phenomena, Department of Geophysics, Colorado School of Mines)
ABSTRACT Using well log data from the South Eugene Island field, offshore Louisiana, we derive empirical relationships between elastic parameters (e.g., -wave velocity, density) and effective stress along both normal compaction and unloading paths. These empirical relationships provide a physical basis for numerical modeling and allow us to investigate the effect of fluid pressure. The presence of more than one stress path complicates the prediction of fluid pressure from seismically derived interval velocities since the relationship between seismic velocity and pore pressure is multi-valued.
- North America > United States > Gulf of Mexico > Central GOM (0.91)
- North America > United States > Louisiana (0.62)
- North America > United States > Utah (0.62)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock (0.48)
- Geology > Structural Geology > Fault > Dip-Slip Fault > Normal Fault > Growth Fault (0.41)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (1.00)
- Geophysics > Borehole Geophysics (1.00)
- North America > United States > Gulf of Mexico > Central GOM > East Gulf Coast Tertiary Basin > South Eugene Island Basin > Eugene Island South (0.99)
- North America > United States > Gulf of Mexico > Central GOM > East Gulf Coast Tertiary Basin > Eugene Island > Block 330 > Eugene Island Block 330 Field (0.99)
- Africa > Nigeria > Gulf of Guinea > Niger Delta > Niger Delta Basin > North Formation (0.99)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Reservoir geomechanics (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
Improved Sihil Image From 4C Full Azimuth Node Data
Garcia, Marco Vázquez (Pemex, CNPS, Villahermosa) | Molina, Gorgonio Garcia (Pemex, CNPS, Villahermosa) | Maya, Francisco (Pemex Exploración y Producción, Región Marina Noreste, Ciudad del Carmen, Mexico) | Torres, Carlos Federico Ruiz (Pemex Exploración y Producción, Región Marina Noreste, Ciudad del Carmen, Mexico) | Berg, Eivind W. (SeaBed Geophysical, Trondheim, Norway) | Vuillermoz, Claude (SeaBed Geophysical, Trondheim, Norway) | Fyhn, Atle (SeaBed Geophysical, Trondheim, Norway)
ABSTRACT A large 4C OBS seismic program was acquired for Pemex over the Cantarell field offshore Mexico to improve the structural definition of the deeper Sihil field underlying the giant Akal field. The acquisition was made using autonomous receivers planted with accurate positioning on a regular grid in the seabed. The data is acquired with a regular and full azimuth/offset distribution. High quality data was recorded. The PP and PS data is time processed with migration before stack. Better resolution of the top of the Sihil under the overthrust of Akal is obtained. The converted wave has a better resolution for the shallower data.
- Geophysics > Seismic Surveying > Surface Seismic Acquisition (1.00)
- Geophysics > Seismic Surveying > Seismic Processing > Seismic Migration (1.00)
- North America > United States > Gulf of Mexico > Central GOM > East Gulf Coast Tertiary Basin > Ship Shoal South Addition > Block 359 > Mahogany Field (0.99)
- North America > United States > Gulf of Mexico > Central GOM > East Gulf Coast Tertiary Basin > Ship Shoal South Addition > Block 349 > Mahogany Field (0.99)
- North America > Mexico > Gulf of Mexico > Bay of Campeche > Sureste Basin > Campeche Basin > Northeast Marine Region > Cantarell Field (0.99)
- North America > Mexico > Gulf of Mexico > Bay of Campeche > Sureste Basin > Campeche Basin > Northeast Marine Region > Akal Field (0.99)
Enhanced PS-wave Images of Deep-water, Near-seafloor Geology From 2-D 4-C OBC Data In the Gulf of Mexico
Backus, Milo M. (The University of Texas at Austin) | Murray, Paul E. (The University of Texas at Austin) | Hardage, Bob A. (The University of Texas at Austin) | Graebner, Robert J. (The University of Texas at Austin)
Summary We present a method for constructing high-resolution converted PS-wave images of near-seafloor strata in deep water (~800m) Gulf of Mexico using data from a 2-D 4-C ocean bottom cable (OBC) survey. Images are constructed from radial component common- receiver gathers. New concepts presented here include the use of commonreceiver gathers as a proxy for common conversion point gathers in the near-ocean-bottom environment, and a method for reducing PP-wavefield effects on radial gathers to better estimate the upgoing PS-wavefield. The techniques reduce the effects of P-wave contamination in the image and allow for better interpretation of near-oceanbottom sediments. The resulting PS-images with dominant 90Hz energy are comparable to PP-images from highresolution data from a 2-8kHz source. Introduction 4-C OBC seismic data collected for oil and gas exploration in the deep water Gulf of Mexico are traditionally resampled and processed for the goal of imaging targets several thousand meters below the ocean bottom. If one is interested in imaging the first few tens of meters of seafloor strata, then it is difficult to construct useful, high-resolution images of this regime using industry-standard seismic processing techniques. For example, receiver spacing adequate for imaging deep targets (25m) proves limiting when constructing a common midpoint (CMP) PP-wave or a common conversion point (CCP) PS-wave image near the ocean floor. After binning and velocity moveout corrections are applied, most of the data are then muted due to unacceptable stretch artifacts. Additionally, estimated ? (Vp/Vs) functions used for CCP binning use Vp/Vs ratios much lower than actual Vp/Vs measured in near-oceanbottom pelagic/hemipelagic sediments [Hamilton (1971)], thereby ensuring this region will be incorrectly imaged by shear-waves with a standard processing flow. Previously, those who wished to construct accurate models of the near-seafloor regime require additional highfrequency data collected from an additional system. We propose an alternative processing flow for OBC data specifically for purpose of imaging the near-ocean bottom reflections. Here we outline a method for constructing high resolution images using converted PS-wave reflections from common commonreceiver gathers. By adapting techniques used in other applications of seismic data processing, we may achieve resolutions with deep water OBC data that were previously available only with high-frequency, deep-towed sources. Source Data The data used in this experiment were acquired in a 2-D profile in the Green Canyon area of the Gulf of Mexico. The source was a towed airgun array 6m below sea level, and the receivers were placed on the ocean floor every 25m. Water depths across this data set are between 800m and 900m. Source stations were located every 50m over the receiver cable line location. Data were sampled at 2ms intervals. The data provided for this project were limited to 2s in recorded two-way time and 2500m in absolute sourcereceiver offset. Receiver Gathers as CCP Gathers If we use reasonable estimates of Vp and Vs, we may ray trace the CCP locations using a simple flat-layer model. Table 1 shows the layer thickness and velocities used for a model which represent three layers of an interpreted model of sub-seafloor strata at our study area.
ABSTRACT Pressure prediction is most often performed in limited areas encompassing a single or a small number of nearby wells. A single velocity calibration and a density and pressure parameter determination, using an effective pressure method, is usually sufficient to result in accurate pressure predictions within the limited area of interest. With the presence of large multi-client data surveys in which accurate seismic velocities and a large number of well based velocity, density and pressure measurements are available, it becomes feasible to make accurate predictions for an entire large survey. Given seismic and rock velocities from logs, calibration parameters can be determined at each well location (see Figure 1). Between wells these parameters can be interpolated. Using an effective pressure method, such as Bowers, along with measured well velocities and pressures, the virgin pressure curve parameters, A and B, can be determined. Where appropriate the unloading parameter U can also be found. Once determined, at each well location the parameters can be interpolated to the position of each seismic velocity function. In addition, using a Gardner type relationship, density parameters can be found at each well location and interpolated to each velocity function. Given the seismic velocity function along with interpolated values of the velocity calibration, density and pressure parameters, the overburden and pore pressure can be accurately predicted. In this paper we provide an example of the use of this approach for the case of a large (700 block) GOM survey using over 60 wells for calibration and parameter determination.
Definition of Depositional Geological Elements In Deep-water Minibasins of the Gulf of Mexico Using Spectral Decomposition In Depth Domain.
Montoya, Patricia (University of Texas at Austin) | Tatham, Robert (University of Texas at Austin) | Fisher, William (University of Texas at Austin) | Steel, Ronald (University of Texas at Austin) | Hudec, Michael (Bureau of Economic Geology)
Summary Submarine channels, large scours, distributary channel-lobe complexes, turbidite fan complexes and many other components of deep water depositional systems in the central Gulf of Mexico were successfully imaged and mapped using spectral decomposition in the depth domain. When this powerful tool is applied along an interpreted seismic horizon, a better definition of stratigraphic architecture is obtained. Introduction Spectral decomposition applied in the depth domain utilizes the Discrete Fourier Transform (DFT) to better image structural features and stratigraphic architecture. With this technique, it is possible to delineate deep-water geological features that are not visible using other standard 3D visualization and imaging techniques, such as depth slices extracted out of the 3D seismic volume or amplitude extracted attributes. In particular, this paper shows four examples of how spectral decomposition has aided in the mapping and recognition of otherwise hidden depositional geological elements in the central Gulf of Mexico. Theory and Method Spectral decomposition was originally developed by researches from Amoco (Partyka et al., 1999) and has been commercially implemented by Landmark. The methodology followed to characterized deep-water environments using spectral decomposition is based on the construction of a tuning cube (Partyka et al., 1999). The initial input is an interpreted depth horizon in the 3D volume. Then, the transformation from depth domain to depth frequency domain occurs at a specific window selected around the horizon of interest. The final tuning cube can be interpreted in plan view (common depth frequency slices) where geological patterns, stratigraphic features and the limits of the depositional systems can be identified and mapped (Figure 1). Deep water Gulf of Mexico example A central Gulf of Mexico (GOM) 3D pre-stack depthmigrated seismic volume covering 3200 km2 was used to compute spectral decomposition at 6 different depth horizons. This area is composed of two important geological features; (1) the prominent Sigsbee Escarpment, which represents the leading edge of a large advancing allochthonous salt canopy that overrides the abyssal plain (e.g., Diegel et al., 1995), and (2) synclinal minibasins, defined as depressions filled with sediments that subsided directly into the Sigsbee salt canopy (Figure 2). Most of these minibasins form bathymetric lows today and have thicknesses varying from 1 to >2.5 km. The intraslope minibasins in this area have provided catchments for sediment transported to the slope and abyssal plain (Beaubouef and Friedmann, 2000). The source for large volumes of sediments comes from major shelf-margin fluvio-deltaic systems such as Trinity, Brazos, Colorado, and Mississippi Rivers in the northern area and Rio Grande River to the west and southwest. Many of these minibasins are interconnected by drainage networks of turbidity current channels (e.g. Liu and Bryant, 2000). The turbidity currents that created these channels cut across interbasinal ridges, and have deposited sediment in the minibasins. This process has been documented by numerous workers (e.g., Badalini et al., 2000, Beaubouef and Friedman, 2000, Booth et al., 2000, Prather et al., 1998). The first example of spectral decomposition was performed along deep horizon 2K with a window of 200m and a 20% cosine taper.
- North America > United States > Gulf of Mexico > Central GOM (0.35)
- North America > United States > Texas (0.28)
- North America > United States > Colorado (0.24)
Acquisition of 2D Walkaway VSP Data to Provide Improved Imaging of the Thunder Horse North Field, Gulf of Mexico
Ray, Amal (BP America, Inc., Houston, Texas) | Quist, Yan (BP America, Inc., Houston, Texas) | Yu, Zhou (BP America, Inc., Houston, Texas) | Sugianto, Hans (BP America, Inc., Houston, Texas) | Hornby, Brian (BP America, Inc., Houston, Texas)
Summary Thunder Horse discovery is part of the greater Thunder Horse complex in the Boarshead basin, which is located in the south-central portion of the Mississippi Canyon protraction area of the Gulf of Mexico. BP owns 75% working interest and ExxonMobil owns the remaining 25% interest in this field. Seismic imaging in the area is very complicated due to an abundance of salt bodies. Different vintages of seismic data acquired with different acquisition geometries do not provide images that can adequately resolve geological details in many important areas. Resolving structural complexity and stratigraphic details via high quality seismic imaging is critical to the success of development of this field. Acquisition of a two-dimensional (2D) Vertical Seismic Profile (VSP), also known as a walkaway VSP, was determined to be beneficial in this area. A large, 76-level walkaway VSP was designed and successfully completed in one of the Thunder Horse North development wells. The VSP image was found to be much superior to available surface seismic data. VSP and surface seismic data were combined to generate an improved image of the reservoir intervals. Introduction T hunder Horse is the largest development project in the deep water Gulf of Mexico. Seismic imaging of this field is very complicated due to the large salt bodies surrounding the development area. Overlying salt and undesirable noise (multiples) obscure seismic images of the reservoir intervals, and proper understanding of geologic complexity through adequate seismic imaging is critical to the commercial success of field development. The BP-led development of VSP tools with many receiver levels enabled efficient and cost-effective acquisition of 2D and 3D VSP data in targeted wells (Ray et al., 2003). Resolution of these data is much greater than conventional surface seismic data, and, when combined with surface seismic data, can provide more comprehensive imaging of structural and stratigraphic details in key development areas. The combined data can be used to design optimal trajectories for development wells, and so can have tremendous financial and business impact. An example from Thunder Horse North to illustrate the need and benefit of 2D walkaway VSP data in certain situations is presented below. Subsurface characteristics The Boarshead basin is located in the south-central portion of the Mississippi Canyon protraction area of the Gulf of Mexico. The water depth in this area is approximately 6300 ft. There are three large prospective structures within this basin, but all of them are obscured to varying degrees by allochthonous salt bodies. The Thunder Horse development is associated with one of these major structures. The area of interest with locations of major fields is shown in Figure 1. The Thunder Horse field contains hydrocarbons in two main structural closures commonly referred to Thunder Horse South (THS) and Thunder Horse North (THN). THS, discovered in 1999 by the Mississippi Canyon 778-1 well, is a faulted four-way dip closure related to salt withdrawal and THN, discovered in 2000 by the Mississippi Canyon 776-1 well, is a three-way dip closure near a salt wall.
- North America > United States > Gulf of Mexico > Central GOM > East Gulf Coast Tertiary Basin > Mississippi Canyon > Block 882 > Thunder Horse South Field (0.99)
- North America > United States > Gulf of Mexico > Central GOM > East Gulf Coast Tertiary Basin > Mississippi Canyon > Block 822 > Thunder Horse Field (0.99)
- North America > United States > Gulf of Mexico > Central GOM > East Gulf Coast Tertiary Basin > Mississippi Canyon > Block 778 > Thunder Horse South Field (0.99)
- (6 more...)
AVA Simultaneous Inversion of 3D Partially Stacked Seismic Data For the Spatial Delineation of Lithology And Fluids Units of Deepwater Hydrocarbon Reservoirs In the Central Gulf of Mexico
Contreras, Arturo (The University of Texas at Austin) | Torres-Verdín, Carlos (The University of Texas at Austin) | Fasnacht, Tim (Anadarko Petroleum Corporation)
Summary This paper describes the successful application of amplitude-versus-angle (AVA) inversion of pre-stack seismic amplitude data to detect and delineate deepwater hydrocarbon reservoirs in the central Gulf of Mexico. A detailed AVA fluid/lithology sensitivity analysis was conducted to assess the nature of AVA effects in the study area based on well-log data. Standard techniques such as cross-plot analysis, Biot-Gassmann fluid substitution, AVA reflectivity modeling, and numerical simulation of synthetic gathers were part of the AVA sensitivity analysis. Cross-plot and Biot-Gassmann analyses indicate significant sensitivity of acoustic properties to fluid substitution. AVA reflectivity and angle-gather modeling indicate that the shale/sand interfaces represented by the top and base of the M-10 reservoir entail typical Class III AVA responses associated with gas-bearing sands. Consequently, pre-stack seismic inversion provided accurate quantitative information about the spatial distribution of lithology and fluid units within the turbidite reservoirs based on the interpretation of fluid/lithology-sensitive modulus attributes. Two additional prospective exploratory areas were identified based on their relatively low values of elastic properties. Introduction Anadarko''s Marco Polo deepwater development project is located in Green Canyon Block 608 in the Gulf of Mexico, approximately 175 miles south of New Orleans, in a 4300- ft water column. Hydrocarbon production originates from reservoirs consisting of Tertiary deepwater sand deposits. This paper considers a small portion of the Marco Polo Field where hydrocarbon-bearing sands pertain to the “M” series and are buried at depths between 11500 and 12500 ft (Fig. 1). The “M” reservoir sands consist of unconsolidated, interbeded, high- and low-density fine-grained (mixed sandy-muddy) turbidite deposits. The overall “M” series consists of sandy turbidite reservoir packages interbedded and separated by muddy debris flows. Normally graded beds contain both complete and nearly complete Bouma sequences of varying thickness. These reservoir intervals are interpreted as stacked, progradational lobes within an overall fan complex. The massive and planar stratified sands exhibit moderate sorting and excellent interparticle porosity, with rock-core measurements indicating excellent intrinsic properties: 30%+ porosity, and several hundred to thousands of millidarcies of nominal permeability. In an effort to substantially improve development in the study area we resorted to amplitude information of 3D prestack seismic data to quantify the vertical and lateral extent of the main turbidite reservoirs. We first conducted AVA sensitivity analysis based on well-log data, and subsequently applied AVA simultaneous seismic inversion to generate spatial distributions of lithology/fluid-sensitive modulus attributes. '' AVA Fluid/Lithology Sensitivity Analysis Well-log measurements were analyzed to (a) assess the AVA behavior of the M-series sand reservoirs, and (b) determine the sensitivity of modulus attributes to changes of lithology and fluid content. This was performed following the methodology described by Contreras et al. (2004), consisting of: (1) cross-plot analysis, (2) Biot- Gassmann fluid substitution, (3) AVA reflectivity modeling, and (4) numerical simulation of synthetic gathers. Biot-Gassmann Fluid Substitution Biot-Gassmann theory together with pre-stack seismic inversion embodies an effective technique for fluidproperty discrimination with AVO (Russell et al., 2003). To quantify the influence of saturating fluids on the acoustic properties of the “M-series” reservoir sands.
- North America > United States > Gulf of Mexico > Central GOM (0.25)
- North America > United States > Louisiana > Orleans Parish > New Orleans (0.24)
- Geology > Sedimentary Geology > Depositional Environment > Marine Environment > Deep Water Marine Environment (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.38)
- Geophysics > Seismic Surveying > Seismic Processing > Seismic Migration (1.00)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling > Seismic Inversion (1.00)
- South America > Venezuela (0.99)
- North America > United States > Gulf of Mexico > Central GOM > East Gulf Coast Tertiary Basin > Green Canyon > Block 608 > Marco Polo Field (0.99)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic modeling (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)