To see the other types of publications on this topic, follow the link: Seismic reservoir characterization.
Dissertations / Theses on the topic 'Seismic reservoir characterization'
Create a spot-on reference in APA, MLA, Chicago, Harvard, and other styles
Consult the top 49 dissertations / theses for your research on the topic 'Seismic reservoir characterization.'
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.
Browse dissertations / theses on a wide variety of disciplines and organise your bibliography correctly.
1
Luca, Gheorghe. "Toward high definition reservoir characterization." Morgantown, W. Va. : [West Virginia University Libraries], 2001. http://etd.wvu.edu/templates/showETD.cfm?recnum=2175.
Full textAbstract:
Thesis (M.S.)--West Virginia University, 2001.Title from document title page. Document formatted into pages; contains xi, 149 p. : ill. (some col.). Includes abstract. Includes bibliographical references (p. 118-124).
2
Artun, F. Emre. "Reservoir characterization using intelligent seismic inversion." Morgantown, W. Va. : [West Virginia University Libraries], 2005. https://eidr.wvu.edu/etd/documentdata.eTD?documentid=4185.
Full textAbstract:
Thesis (M.S.)--West Virginia University, 2005.Title from document title page. Document formatted into pages; contains xii, 82 p. : ill. (some col.), maps (some col.). Includes abstract. Includes bibliographical references (p. 80-82).
3
Al-Moqbel, Abdulrahman Mohammad Saleh 1974. "Reservoir characterization using seismic reflectivity and attributes." Thesis, Massachusetts Institute of Technology, 2002. http://hdl.handle.net/1721.1/51665.
Full textAbstract:
Thesis (S.M.)--Massachusetts Institute of Technology, Dept. of Earth, Atmospheric, and Planetary Sciences, 2002.Includes bibliographical references (leaves 81-82).
The primary objective of this thesis is to obtain reservoir properties, such as porosity from surface seismic data complemented by available well logs. To accomplish this a two-step procedure is followed. First, reflectivity and acoustic impedance profiles are obtained from the inversion of post-stack seismic data. Second, a multi-attribute analysis, calibrated using well logs, is used to obtain porosity. This procedure is applied to a 40x40 sq. km field data set from the eastern region of Saudi Arabia. The 3-D seismic data are of good quality. Twenty-one wells have a good suite of logs. The analysis is focused on the reflections from the reservoir. The outcome of the thesis is an improved subsurface image of the seismic data, a porosity prediction for the reservoir, and a reservoir quality map obtained by similarity analysis using one of the wells as reference.
by Abdulrahman Mohammad Saleh Al-Moqbel.
S.M.
4
Sun, Zandong. "Seismic methods for heavy oil reservoir monitoring and characterization." Thesis, National Library of Canada = Bibliothèque nationale du Canada, 1999. http://www.collectionscanada.ca/obj/s4/f2/dsk1/tape8/PQDD_0033/NQ38510.pdf.
Full text
5
Lai, Hung-Liang. "Seismic modeling of complex stratified reservoirs." [College Station, Tex. : Texas A&M University, 2007. http://hdl.handle.net/1969.1/ETD-TAMU-1322.
Full text
6
Marroquín, Herrera Iván Dimitri. "Reservoir characterization through the application of seismic attributes : multiattribute and unsupervised seismic facies analyses." Thesis, McGill University, 2007. http://digitool.Library.McGill.CA:80/R/?func=dbin-jump-full&object_id=95679.
Full textAbstract:
Seismic attributes are a descriptive and quantifiable characteristic of seismic data, and so they represent subsets of the total information contained in the original seismic data. Consequently, seismic attrjbutes can be important qualitative and quantitative predictors of physical reservoir properties. Seismic attribute analysis began with the search for bright spots in the late 1960s and early 1970s. Subsequent work in the last decades has established seismic attribute analysis as a valuable tool in reservoir characterization studies. I present in this thesis two seismic attribute analyses for the interpretation of the characteristics of the seismic trace to predict significant geological features (e.g., lithology, rock properties and/or fluid content). The first study is an example of the applicability of seismic attributes to predict geologic controls on production data in a coal bed methane reservoir. Based on the calibration of log data with seismic data procedure, I defined a window of analysis, from which I computed amplitude, frequency and phase related attributes. Then, I used a quantitative multiattribute analysis to derive a seismic attribute-based model that predicts coal thickness. Thereafter, I used with a curvature attribute analysis with the objective to map subtle structural features and predict areas with enhanced permeability. The integration of production data with results achieved from both attribute analyses indicates that best production is associated with thicker coal and the immediate vicinity to seismically defined structures. [...]Les attributs sismiques ont comme caractéristique de pouvoir décrire et quantifier les données sismiques, de telle manière qu’ils représentent un sous-ensemble de l’information totale contenue dans les données originales. En conséquence, les attributs sismiques peuvent être d’importants paramètres qualitatifs et quantitatifs des propriétés physiques d’un réservoir. L’analyse d’attributs sismiques a commencé avec la prospection de tâches lumineuses (<< bright spots >>) vers la fin des années 1960 et début des années 1970. Des travaux subséquents pendant les dernières décennies ont permis d’établir l’analyse d’attributs sismiques comme un outil valable lors d’études de caractérisation d’un réservoir. Je présente dans cette thèse deux études d’attributs sismiques pour l’interprétation de la forme de la trace sismique afin de prédire des caractéristiques géologiques significatives tels que: la lithologie, les propriétés des roches et/ou le contenu liquide. La première étude est un exemple de l’application d’attributs sismiques pour prédire des contrôles géologiques sur la production d’un réservoir coalbed methane. D’après les résultats de la calibration des diagraphies au câble avec des données sismiques, j’ai défini une fenêtre d’investigation à partir de laquelle des attributs sismiques de type amplitude, fréquence et phase ont été calculés. J’ai utilisé une analyse muIti-attribut pour dériver un model statistique dans le but d’estimer l’épaisseur du réservoir. Par la suite, j’ai utilisé des attributs mesurant la courbature d’une surface pour mettre en relief de subtiles structures géologiques et prédire les régions dans le réservoir avec une perméabilité augmentée. L’intégration des données de production avec les résultats obtenus lors d’analyses d’attributs sismiques indique que la meilleure production est en association avec l’épaississement du réservoir et le voisinage immédiat de structures géologiques. [...]
7
Shams, Asghar. "Application and implementation of seismic azimuthal anisotropy for reservoir characterization." Thesis, Heriot-Watt University, 2004. http://hdl.handle.net/10399/351.
Full text
8
Spikes, Kyle Thomas. "Probabilistic seismic inversion based on rock-physics models for reservoir characterization /." May be available electronically:, 2008. http://proquest.umi.com/login?COPT=REJTPTU1MTUmSU5UPTAmVkVSPTI=&clientId=12498.
Full text
9
Kvam, Øyvind. "Pore pressure estimation from single and repeated seismic data sets." Doctoral thesis, Norwegian University of Science and Technology, Department of Petroleum Engineering and Applied Geophysics, 2005. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-509.
Full textAbstract:
Høye poretrykk utgjør en risiko for boreoperasjoner på Norsk Sokkel og internasjonalt. Denne risikoen kan reduseres dersom man har kjennskap til poretrykksforholdene før boring. Poretrykk er også en viktig parameter for felt i produksjon, og kunnskap om hvordan dette utvikler seg over tid vil kunne ha stor betydning for økt oljeutvinning. Seismiske data inneholder informasjon om poretrykket og kan derfor bidra til økt kunnskap på dette området. Avhandlingen tar for seg hvordan hastighets- og amplitudeinformasjon fra seismiske data kan brukes for å estimere poretrykk.
Abnormally high pore pressures in the subsurface pose a hazard to drilling operations worldwide. The problem is not unusual on the Norwegian Continental Shelf. Knowledge of the pore pressure prior to drilling may reduce the risk related to drilling in high pressure zones. Pore pressure is also a vital paramter for producinig fields, and knowledge of how the pressure develops over time can be important for increased oil recovery. Seismic data contain information on the pore pressure and may contribute to increased understanding of subsurface pressure conditions. The thesis deals with methods for estimation of pressure from seismic velocity and amplitude data.
10
Will, Robert A. "The integration of seismic anisotropy and reservoir performance data for characterization of naturally fractured reservoirs using discrete feature network models." Texas A&M University, 2004. http://hdl.handle.net/1969.1/542.
Full textAbstract:
This dissertation presents the development of a method for quantitative integration of seismic (elastic) anisotropy attributes with reservoir performance data as an aid in characterization of systems of natural fractures in hydrocarbon reservoirs. This new method incorporates stochastic Discrete Feature Network (DFN) fracture modeling techniques, DFN model based fracture system hydraulic property and elastic anisotropy modeling, and non-linear inversion techniques, to achieve numerical integration of production data and seismic attributes for iterative refinement of initial trend and fracture intensity estimates. Although DFN modeling, flow simulation, and elastic anisotropy modeling are in themselves not new technologies, this dissertation represents the first known attempt to integrate advanced models for production performance and elastic anisotropy in fractured reservoirs using a rigorous mathematical inversion. The following new developments are presented:
. • Forward modeling and sensitivity analysis of the upscaled hydraulic properties of realistic DFN fracture models through use of effective permeability modeling techniques.
. • Forward modeling and sensitivity analysis of azimuthally variant seismic attributes based on the same DFN models.
. • Development of a combined production and seismic data objective function and computation of sensitivity coefficients.
. • Iterative model-based non-linear inversion of DFN fracture model trend and intensity through minimization of the combined objective function.
This new technique is demonstrated on synthetic models with single and multiple fracture sets as well as differing background (host) reservoir hydraulic and elastic properties. Results on these synthetic control models show that, given a well conditioned initial DFN model and good quality field production and seismic observations, the integration procedure results in convergence of both fracture trend and intensity in models with both single and multiple fracture sets. Tests show that for a single fracture set convergence is accelerated when the combined objective function is used as compared to a similar technique using only production data in the objective function. Tests performed on multiple fracture sets show that, without the addition of seismic anisotropy, the model fails to converge. These tests validate the importance of the new process for use in more realistic reservoir models.
11
Mahapatra, Sailendra Nath. "Determination of Heterogeneity by High-Resolution Seismic Reservoir Characterization in the Heavy Oil Temblor Reservoir of Coalinga Field, California." Diss., Virginia Tech, 2005. http://hdl.handle.net/10919/29377.
Full textAbstract:
The research focuses on analysis and subsurface imaging of siliciclastics rocks on steam-affected 3D poststack seismic data, merged from different vintages, from the Temblor Formation in the Coalinga heavy oil reservoir in the San Joaquin basin, California. The objective was identification, delineation, and demarcation of reservoir heterogeneities by seismostratigraphic and seismogeomorphic analysis.
The proximity of the San Andreas Transforms greatly controlled basin evolution and caused substantial reservoir heterogeneity by changing the depositional environment from shallow marine to near-shore fluvial. Moreover, two unconformities dissect the reservoir interval.
The seismic dataset exhibits erratic, distorted reflection strengths and amplitudes caused by steam-injection-aided production. A petrophysical analysis based on Gassmann fluid substitution suggests a 27% P-wave velocity decrease in steam-saturated intervals. Seismic to well log ties were problematic and vexing due to the resulting statics, wavelet changes, and line mismatches. Mapping and flattening on a deeper horizon, however, allowed mapping of the internal unconformities and well ties which were crucial for seismostratigraphic sequence identification.
Visualization of seismic attributes brought out stratification patterns and two distinct, laterally and vertically extensive, porous, and interconnected facies tracts interpreted as incised valley fills and tidal-to-subtidal deposits as evidenced by bright, steam related amplitudes.
Seismic attribute analysis, Geobody Visualization and Interpretation, and structure and isochron maps brought out two prominent channel-systems, recut and restacked in the central part of the area. These deposits were identified on seismic data and correlated to high-gamma coarsening-upward sands on logs and cores. The deeper one, shifting towards SSE with depth, lies between the Base Temblor and Buttonbed unconformities both in the southwestern and northwestern parts of the study area and is scattered in the western-central portion. The shallower one originates in southwestern corner below the Top Temblor unconformity shifts towards ESE-SE with depth, and runs nearly parallel to the Top Temblor unconformity. It cuts across the Valv unconformity in central part creating a channel incision, and follows the Buttonbed unconformity towards the north.
The investigation segmented the reservoir into channels, non-channel bearing, and unconformity-bounded subunits which will allow the operator to improve steam injection and optimize placement of oil producing infill wells.Ph. D.
12
Veire, Helene Hafslund. "Combined Inversion of PP and PS Seismic Data for Static and Dynamic Reservoir Characterization." Doctoral thesis, Norwegian University of Science and Technology, Norwegian University of Science and Technology, 2005. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-564.
Full textAbstract:
Reservoir properties are mainly determined based on well log information. However, wells in most reservoirs are sparse and widely spread compared to the size of the reservoir. Seismic data is thus one of the most important complementary sources of information used to build 3D models of hydrocarbon reservoirs. The need for a high quality reservoir description starts as soon as a discovery is made. In the appraisal phase, hydrocarbons in place and the amount of recoverable reserves are estimated based on the reservoir model. Improved structural models are also needed in optimal well placement during the production and development phase of a reservoir. Knowledge about saturation and pressure distributions in a reservoir are valuable both in the exploration and development phase of a reservoir. This knowledge is used to evaluate the size of a field, determine an optimal drainage pattern, and decide on optimal well design to reduce risks for blow-outs and damage on production equipment. Reducing uncertainty in reservoir property estimates from seismic data have large economic impact on the development of a hydrocarbon reservoir.
Quantitative reservoir property information can be obtained either through direct estimates of reservoir properties from seismic data or through estimates of elastic properties (velocities and densities) that are related to reservoir properties. The relationship between physical properties of rocks and fluids and P-wave seismic data are often empirical and non-unique. This leads to large uncertainties in reservoir models derived from pressure wave seismic data alone. Since shear waves do not propagate through fluids, combined use of pressure wave seismic data and shear wave seismic data might increase our ability to derive fluid and lithology properties from seismic data. One way to obtain information about shear wave velocities over a large area is to acquire multicomponent seismic data (for instance x, y, and z component geophone data). Parts of this thesis focus on methods to combine the information from multicomponent seismic data with pressure wave (hydrophone) seismic data. In this way we improve the accuracy in the estimates of pressure wave velocity, shear wave velocity and density in the subsurface.
To obtain information about changes in reservoir parameters like fluid saturation and pore pressure during production, comparisons between different vintages of seismic data acquired over the field can be performed. Differences in the seismic signal from the same area over a time period (time-lapse seismic data) can be interpreted as changes in reservoir properties. Benefits of improved reservoir characterization include ability to locate bypassed oil and mapping of fluid fronts. This leads to saved costs due to reduced number of misplaced wells, and increased production because of optimized well placement. In the early days of seismic reservoir monitoring, the analyses were qualitative, e.g. to identify undrained areas, analyzing the sealing capacity of faults, and detect drainage patterns. Today, time-lapse seismic analysis is still mainly qualitative. To be able to obtain more quantitative estimates of changes in reservoir properties from the time-lapse seismic data, we need to establish links between the rock parameters and the seismic data. I have used both time-lapse surface seismic data and time-lapse multicomponent seismic data to estimate production related changes in fluid saturation and pressure.
Finally, to be able to utilize rock physical information obtained from seismic reservoir characterization in reservoir modelling, information about uncertainties in the estimates are essential. One way to do this is to use deterministic models (rock physics models) that relates reservoir properties to seismic data, and assume that the model parameters are independent. However, the variables in these estimations are inherently dependent and should be treated as such. By formulating the problem in a Bayesian framework, dependencies between the different variables and spatial dependencies can easily be included. I have used both deterministic uncertainty analysis and Bayesian estimation methods to quantify uncertainties in the estimates.
13
Vohs, Andrew B. "3D seismic attributes analysis in reservoir characterization: the Morrison NE field & Morrison field, Clark County Kansas." Thesis, Kansas State University, 2015. http://hdl.handle.net/2097/20600.
Full textAbstract:
Master of ScienceDepartment of Geology
Abdelmoneam Raef
Seismic reservoir characterization and prospect evaluation based 3D seismic attributes analysis in Kansas has been successful in contributing to the tasks of building static and dynamic reservoir models and in identifying commercial hydrocarbon prospects. In some areas, reservoir heterogeneities introduce challenges, resulting in some wells with poor economics. Analysis of seismic attributes gives insight into hydrocarbon presence, fluid movement (in time lapse mode), porosity, and other factors used in evaluating reservoir potential. This study evaluates a producing lease using seismic attributes analysis of an area covered by a 2010 3D seismic survey in the Morrison Northeast field and Morrison field of Clark County, KS. The target horizon is the Viola Limestone, which continues to produce from seven of twelve wells completed within the survey area. In order to understand reservoir heterogeneities, hydrocarbon entrapment settings and the implications for future development plans, a seismic attributes extraction and analysis, guided with geophysical well-logs, was conducted with emphasis on instantaneous attributes and amplitude anomalies. Investigations into tuning effects were conducted in light of amplitude anomalies to gain insight into what seismic results led to the completion of the twelve wells in the area drilled based on the seismic survey results. Further analysis was conducted to determine if the unsuccessful wells completed could have been avoided. Finally the study attempts to present a set of 3D seismic attributes associated with the successful wells, which will assist in placing new wells in other locations within the two fields, as well as promote a consistent understanding of entrapment controls in this field.
14
Williams, Adrian. "Reservoir Characterization of well A-F1, Block 1, Orange Basin, South Africa." University of the Western Cape, 2018. http://hdl.handle.net/11394/6364.
Full textAbstract:
Magister Scientiae - MSc (Earth Science)The Orange basin is relatively underexplored with 1 well per every 4000km2 with only the Ububhesi gas field discovery. Block 1 is largely underexplored with only 3 wells drilled in the entire block and only well A?F1 inside the 1500km2 3?D seismic data cube, acquired in 2009. This study is a reservoir characterization of well A?F1, utilising the acquired 3?D seismic data and re?analysing and up scaling the well logs to create a static model to display petrophysical properties essential for reservoir characterization. For horizon 14Ht1, four reservoir zones were identified, petro?physically characterized and modelled using the up scaled logs. The overall reservoir displayed average volume of shale at 24%, good porosity values between 9.8% to 15.3% and permeability between 2.3mD to 9.5mD. However, high water saturation overall which exceeds 50% as per the water saturation model, results in water saturated sandstones with minor hydrocarbon shows and an uneconomical reservoir.
15
Africa, Reagan Henry. "Reservoir Characterization using Genetic Inversion and Seismic attributes of Block 1 Orange Basin, Offshore South Africa." University of the Western Cape, 2016. http://hdl.handle.net/11394/5859.
Full textAbstract:
Magister Scientiae - MSc (Earth Science)Block 1, Orange Basin is located offshore west coast South Africa. This study is focused on providing a solution to performing reservoir characterization in areas where well data is scanty by generating reservoir models using genetic inversion. The study area is represented by the extent of a 1500 km squared 3D seismic survey which is intersected by one well.
16
Philip, Charlotte Conwell. "3D seismic attributes analysis to outline channel facies and reveal heterogeneous reservoir stratigraphy; Weirman Field, Ness County, Kansas, USA." Thesis, Kansas State University, 2011. http://hdl.handle.net/2097/8767.
Full textAbstract:
Master of ScienceDepartment of Geology
Abdelmoneam Raef
This research presents a workflow integrating several post-stack seismic attributes to assist in understanding the development history of Weirman Field, Ness County, KS. This study contributes to shaping future drilling plans by establishing a workflow combining analysis of seismic attributes and well cuttings to locate a channel fill zone of better reservoir quality, and to highlight reservoir boundaries due to compartmentalization. In this study, I have successfully outlined a fluvial channel, which is expected to be significantly different in terms of petrophysical properties. The Pennsylvanian aged Cherokee sandstones that potentially comprise channel fill lithofacies, in this study, have been linked to oil production throughout the state of Kansas. It is important to understand channel sandstones when evaluating drilling prospects, because of their potential as an oil reservoir and unpredictable shapes and locations. Since their introduction in the 1970s, seismic attributes have become an essential part of lithological and petrophysical characterization of hydrocarbon reservoirs. Seismic attributes can correlate to and help reveal certain subsurface characteristics and specific geobodies that cannot be distinguished otherwise. Extracting and analyzing acoustic impedance, root-mean-square amplitude and amplitude attenuation, guided by a time window focused on the top of the Mississippian formation, resulted in an understanding of the key seismic channel-facies framework and helped to explain some of the disappointing drilling results at Weirman Field. To form a better understanding of these seismic attributes, this study combined certain attributes and overlayed them in partially transparent states in order to summarize and better visualize the resulting data. A preliminary study of spectral decomposition, which was introduced in the late 1990s, was preformed, and a more in-depth study of this multi-resolution attribute is recommended for future study of this particular field. This study also recommends integrating the revealed compartmentalization boundary and the seismic channel-facies framework in future drilling plans of Weirman Field.
17
Bey, Scott Michael. "Reservoir Characterization and Seismic Expression of the Clinton Interval over Dominion's Gabor Gas Storage Field in North-East Ohio." Wright State University / OhioLINK, 2012. http://rave.ohiolink.edu/etdc/view?acc_num=wright1347391687.
Full text
18
Huang, Fei. "3D Time-lapse Analysis of Seismic Reflection Data to Characterize the Reservoir at the Ketzin CO2 Storage Pilot Site." Doctoral thesis, Uppsala universitet, Geofysik, 2016. http://urn.kb.se/resolve?urn=urn:nbn:se:uu:diva-301003.
Full textAbstract:
3D time-lapse seismics, also known as 4D seismics, have great potential for monitoring the migration of CO2 at underground storage sites. This thesis focuses on time-lapse analysis of 3D seismic reflection data acquired at the Ketzin CO2 geological storage site in order to improve understanding of the reservoir and how CO2 migrates within it. Four 3D seismic surveys have been acquired to date at the site, one baseline survey in 2005 prior to injection, two repeat surveys in 2009 and 2012 during the injection period, and one post-injection survey in 2015. To accurately simulate time-lapse seismic signatures in the subsurface, detailed 3D seismic property models for the baseline and repeat surveys were constructed by integrating borehole data and the 3D seismic data. Pseudo-boreholes between and beyond well control were built. A zero-offset convolution seismic modeling approach was used to generate synthetic time-lapse seismograms. This allowed simulations to be performed quickly and limited the introduction of artifacts in the seismic responses. Conventional seismic data have two limitations, uncertainty in detecting the CO2 plume in the reservoir and limited temporal resolution. In order to overcome these limitations, complex spectral decomposition was applied to the 3D time-lapse seismic data. Monochromatic wavelet phase and reflectivity amplitude components were decomposed from the 3D time-lapse seismic data. Wavelet phase anomalies associated with the CO2 plume were observed in the time-lapse data and verified by a series of seismic modeling studies. Tuning frequencies were determined from the balanced amplitude spectra in an attempt to discriminate between pressure effects and CO2 saturation. Quantitative assessment of the reservoir thickness and CO2 mass were performed. Time-lapse analysis on the post-injection survey was carried out and the results showed a consistent tendency with the previous repeat surveys in the CO2 migration, but with a decrease in the size of the amplitude anomaly. No systematic anomalies above the caprock were detected. Analysis of the signal to noise ratio and seismic simulations using the detailed 3D property models were performed to explain the observations. Estimation of the CO2 mass and uncertainties in it were investigated using two different approaches based on different velocity-saturation models.
19
Yang, Can. "Time-lapse Analysis of Borehole and Surface Seismic Data, and Reservoir Characterization of the Ketzin CO2 Storage Site, Germany." Doctoral thesis, Uppsala universitet, Geofysik, 2012. http://urn.kb.se/resolve?urn=urn:nbn:se:uu:diva-163013.
Full textAbstract:
The CO2SINK (and CO2MAN) project is the first onshore CO2 storage project in Europe. The research site is located near the town of Ketzin, close to Potsdam in Germany. Injection started in June 2008, with a planned injection target of 100,000 tonnes of CO2. In February 2011, around 45, 000 tons of CO2 had been injected into the saline aquifer at an approximate depth of 630 m. This thesis focuses on time-lapse analysis of borehole seismic data, surface seismic data and reservoir characterization at the Ketzin site. Baseline Moving Source Profiling (MSP) data were acquired in the borehole Ketzin 202/2007 (OW2), along seven lines in 2007. The zero-offset Vertical Seismic Profile (VSP) data were acquired in the same borehole. The main objective of the VSP and MSP survey was to generate high-resolution seismic images around the borehole. After modeling and data processing, the sandy layers within the Stuttgart Formation can potentially be imaged in the VSP and MSP data whereas reflections from these layers are not as clearly observed in the 3D surface seismic data. 2D and pseudo-3D time-lapse seismic surveys were conducted at the Ketzin site. Interpretation of 2D baseline and repeat stacks shows that no CO2 leakage related time lapse signature is observable where the 2D lines allow monitoring of the reservoir. This is consistent with the time-lapse results of the 3D surveys showing an increase in reflection amplitude just centered around the injection well. The results from the pseudo-3D surveys are also consistent with the 3D seismic time-lapse studies and show that the sparse pseudo-3D geometry can be used to qualitatively map the CO2 in the reservoir with significantly less effect than the full 3D surveying. The 2nd pseudo-3D repeat survey indicates preferential migration of the CO2 to the west. There are no indications of migration into the caprock on either of the repeat surveys. Amplitude Versus Offset (AVO) analysis was performed on both 2D and 3D repeat surveys. A Class 3 AVO anomaly is clearly observed on the 3D repeat data and matches the synthetic modeling well. No AVO anomaly was observed on the 2D repeat data, which was anticipated, but the result shows signs of a pressure response at the reservoir level in the data. Reflection coefficients were calculated using surface seismic data (3D and pseudo-3D) at the site. Pre-injection calculations agree well with calculations from logging data. Post-injection calculations are in general agreement with the seismic modeling, but generally show higher amplitudes than those expected. The full 3D data show a better image of the reflection coefficients before and after injection than the pseudo-3D data and can potentially be used to make quantitative calculations of CO2 volumes. The pseudo-3D data only provide qualitative information.
20
Mabona, Nande Ingrid. "Application of petrophysics and seismic in reservoir characterization. A case study on selected wells, in the Orange Basin, South Africa." Thesis, University of the Western Cape, 2012. http://hdl.handle.net/11394/4380.
Full textAbstract:
>Magister Scientiae - MScThe evaluation of petroleum reservoirs has shifted from single approach to an integrated approach. The integration, analysis and understanding of all available data from the well bore and creating property models is an exceptional way to characterize a reservoir. Formulating, implementing, and demonstrating the applicability of the joint inversion of seismic and well-bore related observations, and the use of information about the relationship between porosity and permeability as the key parameters for identifying the rock types and reservoir characterization is a vital approach in this study. Correlating well and seismic data, potential reservoirs can be delineated and important horizons (markers) can be pointed out to better characterize the reservoir. This thesis aims to evaluate the potential petroleum reservoirs of the Wells K-A1, K-A2, K-A3 and K-H1 of the Shungu Shungu field in the Orange Basin through the integration and comparison of results from core analysis, wireline logs and seismic and attempt to produce a good reservoir model and by additionally utilizing Petrophysics and seismic and trying to better understand why the area has dry wells. Different rock types that comprise reservoir and non reservoirs are identified in the study and five Facie types are distinguished. Tight, fine grained sandstones with low porosity values ranging from 3% - 6% where dominant in the targeted sandstone layers. Porosity values ranging from 11% - 18% where identified in the massive sandstone lithologies which where hosted by Well’s K-A2 and K-A3. Low permeability values reaching 0.1mD exist throughout the study area. Areas with high porosity also host high water saturation values ranging from 70 – 84%. An improvement in the porosity values at deeper zones (3700m -3725m) and is apparent. Poroperm plots exhibit quartz cemented sandstones and density with neutron plot suggest that the sandstones in the area contain quarts and dolomite mineralization.Well K-A3, consist of a cluster by quartzitic sandstone, meaning there is a large amount of sandstone present. There are apparent high porosity values around the sandstone. What is apparent from this plot is that there are many clusters that are scattered outside the chart. This could suggest some gas expulsions within this Well. Sandstones within the 14B2t1 to 14At1 interval are less developed in the vicinity covered by well K-A2 than at the K-A1 well location. The main targeted sandstones belong to the lower cretaceous and lie just below 13At1. The four wells drilled in this area are dry wells. The areas/blocks surrounding this area have shown to possess encouraging gas shows and a comparative study could reveal better answers. At deeper zones of the well at an interval of 5350m -5750m, there are more developed sandstones with good porosity values. The volume of shale is low and so is the water saturation. The main target sandstones in the study area are the Lower Cretaceous sandstones which are at an interval 13At1. These sandstones are not well developed but from the property model of the target surface it can be seen that the porosity values are much more improved than the average values applied on all the zones on the 3D grid.
21
Al-Moqbel, Abdulrahman Mohammad Saleh. "Carbonate reservoir characterization based on integration of 3-D seismic data and well logs using conventional and artificial intelligence approaches." Thesis, Imperial College London, 2012. http://hdl.handle.net/10044/1/9516.
Full textAbstract:
Reservoir characterization refers to the process of inferring information about reservoir properties from seismic data. Obtaining accurate information about the reservoir properties such as porosity, lithology, and permeability is an essential objective in seismic exploration, especially in new areas that lack well control. This thesis contributes to the integrated analysis of 3-D seismic data and well logs for a square study area in the eastern province of Saudi Arabia, allowing improved understanding, interpretation and characterization of an upper Jurassic carbonate reservoir. The thesis focuses on the analysis aspect of the 3-D post-stack for seismic reservoir characterization through the interpretive use of seismic attributes using different approaches. The thesis can be divided into two key stages. First, a pre-processing stage covering the quality-control of the seismic data sets, calculation of seismic attributes, flattening of the 3-D seismic cube along target horizons, and calibration between seismic data and well-logs. The instantaneous attributes (amplitude, phase and frequency) of seismic data can be calculated and used, along with relative acoustic impedance, as the main seismic attributes to elucidate reservoir characteristics and to reduce exploration risk. Secondly, a main analysis stage develops and tests different effective techniques for analyzing seismic data and conducting reservoir characterization. Five main tools have been developed in-house through MATLAB coding to obtain accurate spatial mapping of the reservoir most important properties that can be used for modelling and simulation which provide better understanding of the reservoir under investigation. This particular choice of tools should work properly for post-stack data. The following summarises and highlights the main contributions of the thesis. First, is to enhance the predictive performance of the conventional multiple linear regression method through coupling information from cluster analysis. Then, I introduce the ‘grey system theory’, which was originally developed in China and has seen little application in geophysics, as a new tool for hydrocarbon exploration; I propose its use for detecting hydrocarbon anomalies associated with the carbonate reservoir. Next, I implement a Kohonen self-organizing map (SOM) neural network for clustering the reservoir heterogeneity (main lithofacies), and enhance the method by feeding it multiple attributes as an input. Furthermore, I estimate reservoir porosity and permeability by implementing a supervised back-propagation neural network. Finally, a hybrid approach that combines an artificial neural network and a fuzzy interface is developed for estimating well lithology from well logs. Different informative results were drawn from this study which can be summarised as follow: The result indicates that the upper part of the ZOI is more porous than the lower part. The reservoir porosity is ranging from 5% to around 28% within the ZOI with an average porosity of approximately 15%. In addition, the reservoir permeability shows ranging values from less than 500md to 2500md. The zone of interest (ZOI), in general, is divided into three distinct subzones ranging in their reservoir quality. This study indicates that the upper zone, middle zone, and lower zone of the ZOI are featured by (medium porosity / high permeability), (high porosity / low permeability), and (low porosity / medium permeability), respectively. The mapping result of the reservoir lithofacies spatial distribution indicates that there are at least nine major lithofacies deposits. Wackestone, packstone, grainstone, and mudstone are four types of the main lithofacies within the study area. The main conclusions drawn from this study can be summarised as follow: (a) The main aim of this study was achieved by estimating the reservoir porosity and permeability, as well as, clustering the reservoir lithology into the main lithofacies through ‘multiple linear regression’ and ‘artificial neural networks’ methods which proved (after validation) to be a powerful technique for characterizing reservoirs, especially the carbonate reservoir. (b) The grey system theory has been introduced to the reservoir study field and ‘grey attribute’ is proposed to highlight hydrocarbon accumulations after finding good correlation with the producing wells in the area. (c) An innovative implementation of ART2 neural network has been proposed to estimate the intra-well lithology by a hybrid-system that combines the neural network classification with the fuzzy interface for a better result. The final result indicated that the zone of interest (ZOI) is dominated by grainy packstone, wackestone/packstone, and muddy wackestone for the top, middle, and bottom subzones, respectively. Different regional maps have been generated for the reservoir main properties (porosity and permeability), lithofacies, and hydrocarbon accumulation. Validation of the result has been performed taken as a measure of the method performance and accuracy. The correlation coefficient was used to represent the success ratio. For example, the success ratio for predicting the reservoir porosity were 79% and 85% for the improved multiple linear regression method and back propagation neural network method, respectively. The result of each method has contributed substantially to achieve the main objectives of this study not only in obtaining better understanding of the reservoir spatial distribution for future planned drilling in the area, but also offering new input for remodelling the reservoir and updating the simulation.
22
Schmidt, Ricardo Otto Rozza [UNESP]. "Caracterização espacial geológico-geofísica dos turbiditos eocênicos nos campos de Enchova e Bonito, Bacia de Campos-RJ." Universidade Estadual Paulista (UNESP), 2016. http://hdl.handle.net/11449/139519.
Full textAbstract:
Submitted by RICARDO OTTO ROZZA SCHMIDT null (rottoschmidt@gmail.com) on 2016-06-20T16:57:36Z
No. of bitstreams: 1
Mestrado Dissertação Final_Dig.pdf: 14191761 bytes, checksum: dbea65724bee20d777cf130e21a9ab56 (MD5)Approved for entry into archive by Ana Paula Grisoto (grisotoana@reitoria.unesp.br) on 2016-06-23T14:12:58Z (GMT) No. of bitstreams: 1 schmidt_ror_me_rcla.pdf: 14191761 bytes, checksum: dbea65724bee20d777cf130e21a9ab56 (MD5)
Made available in DSpace on 2016-06-23T14:12:58Z (GMT). No. of bitstreams: 1 schmidt_ror_me_rcla.pdf: 14191761 bytes, checksum: dbea65724bee20d777cf130e21a9ab56 (MD5) Previous issue date: 2016-05-03
Os arenitos de água profunda, designados genericamente como turbiditos, têm enorme relevância energética e econômica para o Brasil. Na Bacia de Campos, a maior parte dos campos produtores contêm níveis turbidíticos da Formação Carapebus (Eoceno), focalizados neste estudo. É o caso dos campos de Enchova e Bonito. Nesta dissertação propõe-se a caracterização geológica-petrofísica dos reservatórios turbidíticos (Eoceno) nestes campos, que mesmo descobertos há 30 anos detém poucas informações publicadas no que se refere à sua disposição espacial litológica e petrofísica. A integração de metodologias e ferramentas possibilita a melhor compreensão dos reservatórios e de suas heterogeneidades. Neste trabalho foram integrados dados oriundos de testemunhos, perfis de poços, sísmica 3-D (40 km²) por meio dos métodos geoestatísticos Krigagem Indicativa e Krigagem Ordinária, de forma a contribuir com o entendimento da distribuição das principais unidades do reservatório. A análise litológica teve como enfoque os métodos qualitativos, apoiada na descrição de testemunhos apresentadas na pasta de poço, e quantitativo, baseado nas análises dos perfis geofísicos de 20 poços. Com base nesta correlação rocha-perfil, os litotipos arenito, carbonato e folhelho foram definidos e extrapolados para os intervalos não testemunhados. A interpretação e correlação dos perfis geofísicos identificaram dois níveis arenosos principais, o inferior com 10 a 15 m e superior com 70 a100 m, separados por uma camada de folhelho de 5 a 20 m. Salienta-se o controle deposicional de uma feição erosiva de idade Maastrichiano-Eoceno Médio, a qual concentra as maiores espessuras de areia a oeste dos campos. A caracterização estrutural do reservatório, definida por três feições dômicas alinhadas a NE, foi definida pela interpretação sísmica 3-D. A análise de atributos sísmicos de amplitude, realizada no intervalo definido entre os horizontes topo e base do reservatório, revelou geometrias associadas a complexos de canais discretos, em Enchova, e lobos canalizados, em Bonito. O modelo litológico do reservatório obtido pela aplicação da Krigagem indicativa representou satisfatoriamente os níveis turbidíticos quando comparados aos dados de poços e mapas atributos sísmicos, que indica as maiores espessuras dos turbiditos a oeste das áreas. O modelo da porosidade obtido pela Krigagem Ordinária (Krigagem Indicativa) indicou melhores condições porosas na porção oeste dos campos, correlacionando-se com o modelo litológico carbonatos fechados e folhelhos no modelo litológico. Ambos, os mapas de atributos sísmicos e modelos obtidos apresentam uma área com potencial exploratório a sul de Bonito, ainda não perfurada segundo a ANP.
Deep-water sandstones, known as turbidites, play an important role in Brazil's energy and economic scenario. In the Campos Basin, Carapebus Formation´s Eocene turbidites produce in most oil fields of the basin. Enchova and Bonito oil fields, focused in this study, represent Eocene sandstone production areas. Discovered 30 years ago, Eocene reservoirs have a lack of information regarding its lithological and petrophysical distribution. This master thesis proposes a geological-getrophysical reservoir characterization of Eocene turbidites on Enchova and Bonito fields. The integration of methodologies and tools enables a better understanding of the reservoir geometry and heterogeneity. This work integrates core descriptions from well reports, well logs and 3-D seismic through Indicator Kriging (lithology) and Ordinary Kriging (porosity) resulting in 3-D solid models. The models possibly a better understand of lithologic and petrophysical reservoir distribution. The lithological analysis is supported by qualitative methods, supported by the 70m core description provided with well log data, and quantitative, based on the analysis of 20 well logs. Based on this correlation between logs and rocks, the lithology classes, sandstone, carbonate and shale, were defined. The well-logs interpretation and correlation identified two main turbidite intervals, the lower 5 to 15 m and upper 70 to 100 m, separated by a shale layer 5 to 20 m. These intervals were depositionally controlled by an erosive feature associated with Maastrichtian-Middle Eocene unconformity, defining the distribution pattern of turbidites sands concentrated on the western portion of the fields. The reservoir structural characterization, performed trough 3-D seismic interpretation, is defined by three domal features separated by normal faults aligned to NE-SW. Seismic amplitude attributes calculated under the reservoir interval revealed channelized geometries on Enchova field and lobate architecture on Bonito field. The reservoir lithological model obtained through Indicator Kriging demonstrate coherence when compared to well data distribution and seismic attributes maps that indicate turbidite greatest thicknesses in western areas. The model of porosity obtained by Ordinary Kriging revealed best porosity conditions in the western portion of the fields, corresponding to the seismic attributes responses and lithological model. Both geostatistical models and seismic attributes maps revealed an interesting non drilled area located on south of Bonito field.
23
Boumaaza, Bouharket. "3D seismic attributes analysis and inversions for prospect evaluation and characterization of Cherokee sandstone reservoir in the Wierman field, Ness County, Kansas." Thesis, Kansas State University, 2017. http://hdl.handle.net/2097/35510.
Full textAbstract:
Master of ScienceDepartment of Geology
Abdelmoneam Raef
Matthew W. Totten
This work focuses on the use of advanced seismically driven technologies to estimate the distribution of key reservoir properties which mainly includes porosity and hydrocarbon reservoir pay. These reservoir properties were estimated by using a multitude of seismic attributes derived from post-stack high resolution inversions, spectral imaging and volumetric curvature. A pay model of the reservoir in the Wierman field in Ness County, Kansas is proposed. The proposed geological model is validated based on comparison with findings of one blind well. The model will be useful in determining future drilling prospects, which should improve the drilling success over previous efforts, which resulted in only few of the 14 wells in the area being productive. The rock properties that were modeled were porosity and Gamma ray. Water saturation and permeability were considered, but the data needed were not available. Sequential geological modeling approach uses multiple seismic attributes as a building block to estimate in a sequential manner dependent petrophysical properties such as gamma ray, and porosity. The sequential modelling first determines the reservoir property that has the ability to be the primary property controlling most of the other subsequent reservoir properties. In this study, the gamma ray was chosen as the primary reservoir property. Hence, the first geologic model built using neural networks was a volume of gamma ray constrained by all the available seismic attributes. The geological modeling included post-stack seismic data and the five wells with available well logs. The post-stack seismic data was enhanced by spectral whitening to gain as much resolution as possible. Volumetric curvature was then calculated to determine where major faults were located. Several inversions for acoustic impedance were then applied to the post-stack seismic data to gain as much information as possible about the acoustic impedance. Spectral attributes were also extracted from the post-stack seismic data. After the most appropriate gamma ray and porosity models were chosen, pay zone maps were constructed, which were based on the overlap of a certain range of gamma ray values with a certain range of porosity values. These pay zone maps coupled with the porosity and gamma ray models explain the performance of previously drilled wells.
24
Jaradat, Rasheed Abdelkareem. "Prediction of reservoir properties of the N-sand, vermilion block 50, Gulf of Mexico, from multivariate seismic attributes." Diss., Texas A&M University, 2003. http://hdl.handle.net/1969.1/2236.
Full textAbstract:
The quantitative estimation of reservoir properties directly from seismic data is a major goal of reservoir characterization. Integrated reservoir characterization makes use of different varieties of well and seismic data to construct detailed spatial estimates of petrophysical and fluid reservoir properties. The advantage of data integration is the generation of consistent and accurate reservoir models that can be used for reservoir optimization, management and development. This is particularly valuable in mature field settings where hydrocarbons are known to exist but their exact location, pay, lateral variations and other properties are poorly defined. Recent approaches of reservoir characterization make use of individual seismic attributes to estimate inter-well reservoir properties. However, these attributes share a considerable amount of information among them and can lead to spurious correlations. An alternative approach is to evaluate reservoir properties using multiple seismic attributes. This study reports the results of an investigation of the use of multivariate seismic attributes to predict lateral reservoir properties of gross thickness, net thickness, gross effective porosity, net-to-gross ratio and net reservoir porosity thickness product. This approach uses principal component analysis and principal factor analysis to transform eighteen relatively correlated original seismic attributes into a set of mutually orthogonal or independent PC??s and PF??s which are designated as multivariate seismic attributes. Data from the N-sand interval of Vermilion Block 50 field, Gulf of Mexico, was used in this study. Multivariate analyses produced eighteen PC??s and three PF??s grid maps. A collocated cokriging geostaistical technique was used to estimate the spatial distribution of reservoir properties of eighteen wells penetrating the N-sand interval. Reservoir property maps generated by using multivariate seismic attributes yield highly accurate predictions of reservoir properties when compared to predictions produced with original individual seismic attributes. To the contrary of the original seismic attribute results, predicted reservoir properties of the multivariate seismic attributes honor the lateral geological heterogeneities imbedded within seismic data and strongly maintain the proposed geological model of the N-sand interval. Results suggest that multivariate seismic attribute technique can be used to predict various reservoir properties and can be applied to a wide variety of geological and geophysical settings.
25
Krehel, Austin. "Investigation of time-lapse 4D seismic tuning and spectral responses to CO₂-EOR for enhanced characterization and monitoring of a thin carbonate reservoir." Thesis, Kansas State University, 2016. http://hdl.handle.net/2097/34628.
Full textAbstract:
Master of ScienceDepartment of Geology
Abdelmoneam Raef
Advancements, applications, and success of time-lapse (4D) seismic monitoring of carbonate reservoirs is limited by these systems’ inherent heterogeneity and low compressibility relative to siliciclastic systems. To contribute to the advancement of 4D seismic monitoring in carbonates, an investigation of amplitude envelope across frequency sub-bands was conducted on a high-resolution 4D seismic data set acquired in fine temporal intervals between a baseline and eight monitor surveys to track CO₂-EOR from 2003-2005 in the Hall-Gurney Field, Kansas. The shallow (approximately 900 m) Plattsburg ‘C Zone’ target reservoir is an oomoldic limestone within the Lansing-Kansas City (LKC) supergroup – deposited as a sequence of high-frequency, stacked cyclothems. The LKC reservoir fluctuates around thin-bed thickness within the well pattern region and is susceptible to amplitude tuning effects, in which CO₂ replacement of initial reservoir fluid generates a complex tuning phenomena with reduction and brightening of amplitude at reservoir thickness above and below thin-bed thickness, respectively. A thorough analysis of horizon snapping criteria and parameters was conducted to understand the sensitivity of these autonomous operations and produce a robust horizon tracking workflow to extend the Baseline Survey horizon data to subsequent Monitor Surveys. This 4D seismic horizon tracking workflow expedited the horizon tracking process across monitor surveys, while following a quantitative, repeatable approach in tracking the LKC and maintaining geologic integrity despite low signal-to-noise ratio (SNR) data and misties between surveys. Analysis of amplitude envelope data across frequency sub-bands (30-80 Hz) following spectral decomposition identified geometric features of multiple LKC shoal bodies at the reservoir interval. In corroboration with prior geologic interpretation, shoal boundaries, zones of overlap between stacked shoals, thickness variation, and lateral changes in lithofacies were delineated in the Baseline Survey, which enhanced detail of these features’ extent beyond capacity offered from well log data. Lineaments dominated by low-frequency anomalies within regions of adjacent shoals’ boundaries suggest thicker zones of potential shoal overlap. Analysis of frequency band-to-band analysis reveals relative thickness variation. Spectral decomposition of the amplitude envelope was analyzed between the Baseline and Monitor Surveys to identify spectral and tuning changes to monitor CO₂ migration. Ambiguity of CO₂ effects on tuning phenomena was observed in zones of known CO₂ fluid replacement. A series of lineaments highlighted by amplitude brightening from the Baseline to Monitor Surveys is observed, which compete with a more spatially extensive effect of subtle amplitude dimming. These lineaments are suggestive of features below tuning thickness, such as stratigraphic structures of shoals, fractures, and/or thin shoal edges, which are highlighted by an increased apparent thickness and onset of tuning from CO₂. Detailed analysis of these 4D seismic data across frequency sub-bands provide enhanced interpretation of shoal geometry, position, and overlap; identification of lateral changes in lithofacies suggestive of barriers and conduits; insight into relative thickness variation; and the ability of CO₂ tuning ambiguity to highlight zones below tuning thickness and improve reservoir characterization. These results suggest improved efficiency of CO₂ -EOR reservoir surveillance in carbonates, with implications to ensure optimal field planning and flood performance for analogous targets.
26
Borges, De Salles Abreu Carlos Eduardo. "Time-lapse (4D) seismic interpretation methodologies based on kriging analysis : application to the Senlac (onshoreCanada) and Marlim ( offshore Brazil) heavy oilfields." Thesis, Vandoeuvre-les-Nancy, INPL, 2008. http://www.theses.fr/2008INPL012N/document.
Full textAbstract:
L’objectif de la thèse est de développer une méthodologie permettant d’obtenir une interprétation quantitative des données de sismique répétée (sismique 4D). Une étape essentielle consiste à évaluer la répétitivité des données, puis à filtrer les bruits indésirables, qui peuvent masquer ou détériorer la signature 4D. Une méthodologie basée sur des outils géostatistiques a été développée. Deux fenêtres temporelles des cubes sismiques étudiés sont choisies, l’une au-dessus du réservoir - où aucun effet 4D n’est attendu - et l’autre incluant le réservoir. Une analyse statistique et variographique conduite sur ces différentes fenêtres permet de proposer une décomposition des variogrammes en structures communes ou indépendantes, qui sont ensuite interprétées en termes de bruit, de signature géologique ou 4D. Les structures interprétées comme indépendantes de la géologie ou de la production sont ensuite filtrées à l’aide de la technique du krigeage factoriel proposée par Matheron en 1982. La méthodologie a été testée sur deux cas réels. Le premier concerne un champ d’huiles lourdes canadien, sur lequel trois campagnes sismiques ont été enregistrées, avant et pendant la production obtenue à l’aide d’injection de vapeur. Le bruit interprété comme tel sur les 3 campagnes a été filtré à l’aide la méthode décrite plus haut ; une analyse en termes de faciès sismiques non supervisée a ensuite été conduite sur les données brutes et filtrées afin d’évaluer l’intérêt du filtrage. Finalement, une interprétation des décalages en temps observés entre campagnes a été proposée. Le deuxième cas réel concerne un champ turbiditique profond dans l’offshore du Brésil, sur lequel deux campagnes sismiques 3D ont été acquises, avant et après le début de la production obtenue par injection d’eau. Le bruit présent sur les deux campagnes a été filtré à l’aide de la technique du krigeage factoriel, et la qualité de ce filtrage a pu être évaluée par comparaison avec d’autres techniques couramment utiliséesThis thesis research aims at investigating seismic interpretation methodologies and techniques that will help on better characterizing time-lapse, or 4D, seismic signatures. These techniques and methodologies are used to evaluate the time-lapse repeatability and then to filter out undesirable artefacts that are non-related to the production, while enhancing the 4D signature. To achieve these goals, a methodology based on geostatistical tools, was developed. Typically, at least two time-interval windows are considered: one above and the other comprising the reservoir of interest. A statistical and variographic analysis, conducted on both windows and on all surveys, leads to an interpretation step where common or independent structures – in the variographic sense- can be pointed out. The structures interpreted as not related to the geology or to the production mechanism are filtered from the data by a multivariate factorial cokriging technique, based on the concept of Kriging Analysis developed by Matheron in 1982. Two real case time-lapse studies were used to test the methodology. The first case is a Canadian onshore heavy oil reservoir submitted to steam injection, where three different time-lapse surveys were shot to monitor the steam-chamber evolution. The noise present in the three surveys was first filtered using the technique described above; next, an unsupervised seismic facies analysis was conducted on both raw and filtered data in order to evaluate the filtering technique, and finally an interpretation, in terms of reservoir properties changes, of the time-shit observed between the campaigns was proposed. In the second case, the seismic data was acquired on a deepwater turbiditic oilfield from Brazil at two different times of reservoir life, before and after production and water injection. The two seismic surveys were filtered using the factorial kriging technique; the quality of the filtering was, in this case, evaluated by comparison with more common techniques
27
Badescu, Adrian Constantin. "Reservoir characterization of the Miocene Starfak and Tiger Shoal fields, offshore Louisiana through integration of sequence stratigraphy, 3-D seismic, and well-log data." Access restricted to users with UT Austin EID, 2002. http://wwwlib.umi.com/cr/utexas/fullcit?p3108452.
Full text
28
Sanchez, A. Alejandro. "3D seismic interpretation and synthetic modeling of the Atoka and Morrow formations, in the Buffalo Valley Field (Delaware Basin, New Mexico, Chaves County) for reservoir characterization using neural networks." Morgantown, W. Va. : [West Virginia University Libraries], 2004. https://etd.wvu.edu/etd/controller.jsp?moduleName=documentdata&jsp%5FetdId=3739.
Full textAbstract:
Thesis (M.S.)--West Virginia University, 2004Title from document title page. Document formatted into pages; contains xiii, 134 p. : ill. (some col.), maps (some col.). Vita. Includes abstract. Includes bibliographical references (p. 118-122).
29
Sancevero, Sergio Sacani. "Modelagem sismica de corpos turbiditicos sinteticos gerados por simulação booleana." [s.n.], 2003. http://repositorio.unicamp.br/jspui/handle/REPOSIP/287449.
Full textAbstract:
Orientador: Armando Zaupa RemacreDissertação (mestrado) - Universidade Estadual de Campinas, Faculdade de Engenharia Mecanica e Instituto de Geociencias
Made available in DSpace on 2018-08-03T18:08:29Z (GMT). No. of bitstreams: 1 Sancevero_SergioSacani_M.pdf: 11223861 bytes, checksum: 4e1d81a7b97619bdeec6c0a58da2e74b (MD5) Previous issue date: 2003
Resumo: A modelagem de corpos geológicos que possuam caracteristicas de depósitos turbidíticos é uma tarefa muito importante para a indústria de petróleo, principalmente no Brasil, onde os principais reservatórios estão situados nesse tipo de ambiente deposicional. A simulação booleana de objetos e a simulação seqüencial gaussiana são técnicas geoestatísticas que permitem a construção de modelos de referência sintéticos, porém com caracteristicas geológicas, que podem ser submetidos ao processo de modelagem sísmica que num trabalho de caracterização de reservatórios, podem ser usados para testar algoritmos de interpretação, inversão sísmica. Uma vantagem no caso de utilizar dados sintéticos para a realização de estudos de caracterização de reservatórios está na facilidade de interpretar os resultados e gerar conclusões objetivas, uma vez que se pode isolar os diversos fenômenos que afetam o resultado, analisando-os separadamente. Outra caracteristica, bastante importante dos dados sintéticos é que se tem um conjunto de dados de referência para a validação dos resultados. Nesta dissertação propõe-se mostrar a criação de um modelo de referência sintético para ser utilizado em estudos de caracterização de reservatórios. Como resultados, obtém-se um modelo geológico e petrofisico que represente as heterogeneidades de reservatórios petrolíferos do tipo turbidítico, bem como um modelo sísmico sintético onde as ferramentas de interpretação e inversão sísmica possam ser testadas e seus resultados avaliados de maneira concreta já que se tem um controle sobre as estruturas que se deseja interpretar. Conclui-se então a importância de um modelo de referência para estudos de caracterização de reservatórios e propõem-se como trabalhos futuros estudos relativos à conectividade dos corpos reservatório gerado, modelagem de outros sistemas deposicionais e estudos sobre o comportamento do fluxo no modelo sintético
Abstract: The geological modeling of bodies that have characteristics of turbidite reservoir is a very important task for the industry of oil, main1y in Brazil, where the main reservoirs are situated in that kind of deposicional environment. The simulation based in objects by Boolean model and the sequential gaussian simulation are the geostatistics techniques that permit the construction of synthetic reference models, however with geological characteristics, that can be submitted to the seismic modeling that in a work of reservoirs characterization, can be used to test algorithms of seismic interpretation and inversion. An advantage in case of use synthetic dataset for the achievement of studies of reservoir characterization is in the facility of interpret the results and generate objective conc1usions, since it can be isolated the diverse phenomena that affect the result, analyzing them separately. Another important characteristic, of the synthetic dataset is that has a reference model for the validation of results. In this dissertation the propose is the creation of a synthetic reference model to be used in studies of reservoir characterization. As results, obtain a petrophysical and geological model that represent the heterogeneities of turbidites oil-producing reservoirs, as well as a synthetic seismic model where the tools of seismic interpretation and inversion can be tested and his results can be evaluated of effective way since has a control about the structures that is desired interpreto Conc1ude itself then the importance of a model of reference for studies of reservoir characterization and propose as future works studies about the connectivity of the reservo ir bodies generated, modeling of others depositionals systems, and studies about fluid flow behavior
Mestrado
Reservatórios e Gestão
Mestre em Ciências e Engenharia de Petróleo
30
Pereira, Leonardo Azevedo Guerra Raposo. "Seismic attributes in hydrocarbon reservoirs characterization." Master's thesis, Universidade de Aveiro, 2009. http://hdl.handle.net/10773/2735.
Full textAbstract:
Mestrado em Engenharia GeológicaNo presente trabalho apresentam-se as vantagens da utilização de atributos sísmicos na interpretação de dados de sísmica de reflexão 3D e na identificação e caracterização de reservatórios de hidrocarbonetos. O trabalho prático necessário para a elaboração desta tese foi realizado durante um estágio de quatro meses na empresa de serviços para a indústria petrolífera, Schlumberger, em Paris, utilizando o software de interpretação sísmica e de modelação de reservatórios de hidrocarbonetos, Petrel 2008.1. Os atributos sísmicos podem ser considerados formas alternativas de visualizar os dados de sísmica de reflexão, que normalmente são representados em amplitude. A sua utilização facilita o processo de interpretação sísmica, uma vez que permite aumentar a razão sinal-ruído, detectar descontinuidades, reforçar a continuidade dos reflectores sísmicos e evidenciar indicadores directos de hidrocarbonetos nos dados sísmicos originais. Os atributos sísmicos podem ainda ser usados para treinar processos de auto-aprendizagem utilizados em redes neuronais na predição da distribuição de facies numa área em estudo. De uma forma geral, a utilização de atributos sísmicos facilita a correlação entre os dados provenientes do método sísmico, dados de poços e a geologia da área em estudo. Neste trabalho foi utilizado um bloco migrado de sísmica de reflexão 3D, com aproximadamente 6000 km2, adquirido no deep-offshore da costa Oeste Africana. Para além de um teste individual dos atributos sísmicos disponíveis no Petrel 2008.1, esta tese incluí uma avaliação preliminar do potencial em hidrocarbonetos de um sistema de canais amalgamados identificado na área em estudo. A sua identificação, interpretação e caracterização foi possível com o recurso a atributos sísmicos que evidenciam a presença de falhas, ou outras descontinuidades, e de atributos sísmicos sensíveis a pequenas variações na litologia e à presença de fluídos nos poros das formações litológicas. ABSTRACT: In this work the advantages related to the use of seismic attributes in the interpretation of 3D seismic data and in the characterization of hydrocarbon reservoirs are discussed. A four months internship at Schlumberger, in Paris, using the Petrel 2008.1 “seismic-to-simulation” software provided the necessary data to perform the work described in this thesis. Seismic attributes are different ways to look at the original seismic data, which normally is displayed in amplitudes. Using seismic attributes during the seismic interpretation process allow a significant improvement in the signal-to-noise ratio, the automatic detection of discontinuities, the enhancement of seismic reflectors continuity and the enhancement of direct hydrocarbon indicators. In the self-learning process for neural networks, seismic attributes can be used as training data to predict facies distribution in the study area. Generally, seismic attributes provide a better correlation between the data provided by the seismic reflection method, well log data and the geology of the study area. In this work, a 3D migrated seismic cube was used, with an approximate area of 6000km2, acquired in the deep-water of West Africa. Besides an individual test of each attribute available in Petrel 2008.1, this thesis also includes a preliminary evaluation of the oil and gas potential of a system of stacked channels identified within the study area. The identification, interpretation and characterization of this potential hydrocarbon reservoir was possible using seismic attributes to enhance faults and other discontinuities, and by using seismic attributes sensitive to subtle lithological variations and the presence of fluids in the pore spaces of the lithological formations.
31
Nosjean, Nicolas. "Management et intégration des risques et incertitudes pour le calcul de volumes de roches et de fluides au sein d’un réservoir, zoom sur quelques techniques clés d’exploration Integrated Post-stack Acoustic Inversion Case Study to Enhance Geological Model Description of Upper Ordovicien Statics : from imaging to interpretation pitfalls and an efficient way to overcome them Improving Upper Ordovician reservoir characterization - an Algerian case study Tracking Fracture Corridors in Tight Gas Reservoirs : An Algerian Case Study Integrated sedimentological case study of glacial Ordovician reservoirs in the Illizi Basin, Algeria A Case Study of a New Time-Depth Conversion Workflow Designed for Optimizing Recovery Proper Systemic Knowledge of Reservoir Volume Uncertainties in Depth Conversion Integration of Fault Location Uncertainty in Time to Depth Conversion Emergence of edge scenarios in uncertainty studies for reservoir trap analysis Enhancing geological model with the use of Spectral Decomposition - A case study of a prolific stratigraphic play in North Viking Graben, Norway Fracture corridor identification through 3D multifocusing to improve well deliverability, an Algerian tight reservoir case study Geological Probability Of Success Assessment for Amplitude-Driven Prospects, A Nile Delta Case Study." Thesis, université Paris-Saclay, 2020. http://www.theses.fr/2020UPASS085.
Full textAbstract:
En tant que géoscientifique dans le domaine de l’Exploration pétrolière et gazière depuis une vingtaine d’années, mes fonctions professionnelles m’ont permis d’effectuer différents travaux de recherche sur la thématique de la gestion des risques et des incertitudes. Ces travaux de recherche se situent sur l’ensemble de la chaîne d’analyse Exploration, traitant de problématiques liées à l’acquisition et au traitement sismique, jusqu’au placement optimal de forages d’exploration. Un volet plus poussé de mes travaux s’est orienté sur la gestion des incertitudes géophysiques en Exploration pétrolière, là où l’incertitude est la plus importante et paradoxalement la moins travaillée.On peut regrouper mes travaux de recherche en trois grands domaines qui suivent les grandes étapes du processus Exploration : le traitement sismique, leur interprétation, et enfin l'analyse et l'extraction des différentes incertitudes qui vont nous permettre de calculer les volumes d’hydrocarbures en place et récupérables, ainsi que l’analyse de ses risques associés. L’ensemble des travaux de recherche ont été appliqués avec succès sur des cas d’études opérationnelles. Après avoir introduit quelques notions générales et détaillé les grandes étapes du processus Exploration et leur lien direct avec ces problématiques, je présenterai quatre grands projets de recherche sur un cas d’étude algérienIn the last 20 years, I have been conducting various research projects focused on the management of risks and uncertainties in the petroleum exploration domain. The various research projects detailed in this thesis are dealing with problematics located throughout the whole Exploration and Production chain, from seismic acquisition and processing, until the optimal exploration to development wells placement. Focus is made on geophysical risks and uncertainties, where these problematics are the most pronounced and paradoxically the less worked in the industry. We can subdivide my research projects into tree main axes, which are following the hydrocarbon exploration process, namely: seismic processing, seismic interpretation thanks to the integration with various well informations, and eventually the analysis and extraction of key uncertainties, which will be the basis for the optimal calculation of in place and recoverable volumes, in addition to the associated risk analysis on a given target structure. The various research projects that are detailed in this thesis have been applied successfully on operational North Africa and North Sea projects. After introducing risks and uncertainty notions, we will detail the exploration process and the key links with these issues. I will then present four major research projects with their theoretical aspects and applied case study on an Algerian asset
32
Martínez-Garzón, Patricia [Verfasser]. "Seismo-mechanical reservoir characterization from fluid-induced seismicity / Patricia Martínez-Garzón." Berlin : Freie Universität Berlin, 2014. http://d-nb.info/1056908165/34.
Full text
33
Shen, Feng 1965. "Seismic characterization of fractured reservoirs (part I) ; Crustal deformation in the Tibetan Plateau (part II)." Thesis, Massachusetts Institute of Technology, 1998. http://hdl.handle.net/1721.1/57666.
Full textAbstract:
Thesis (Ph.D.)--Massachusetts Institute of Technology, Dept. of Earth, Atmospheric, and Planetary Sciences, February 1999.Includes bibliographical references.
(PART I) In this thesis, we study the possibility of using P-waves to investigate properties of fractured reservoirs and the diagnostic ability of the P-wave seismic data to detect fractures. The objectives of this thesis are threefold: (1) to identify the effects of fracture parameters and background media on the NMO velocities and azimuthal AVO responses in homogeneously fractured reservoirs, (2) to investigate the scattering characteristics in heterogeneously fractured reservoirs and the diagnostic ability of these characteristics to recover fracture density information, (3) to apply these theoretical studies and techniques to the field data analyses in order to detect fractures. Fracture properties, described by fracture parameters (fracture density, fracture aspect ratio and saturating fluid), are related to anisotropic parameters of the equivalent VTI model and affect the NMO velocities. Studies show that the shear wave splitting parameter is most sensitive to crack density and is insensitive to saturating fluid content and the crack aspect ratio, while 8(v) and Ev) have different characteristics in gas- and water-saturating, fractured rocks. The effects of fracture parameters on P-wave NMO velocities are comparable with the influences of 8(v). Unlike anisotropic parameters and NMO velocities, P-wave azimuthal AVO variations are not necessarily correlated with the magnitude of fracture density. Studies show that the properties of background rocks have an important effect on P-wave azimuthal AVO responses. Azimuthal AVO variations at the top of gas-saturated, fractured reservoirs which contain the same fracture density are significant in the reservoir model with small contrasts in Poisson's ratio. Varying fracture density and fluid content can lead to variations in AVO gradients in off fracture strike directions. The presence of overburden anisotropy caused by VTI media can significantly distort AVO gradients, which suggests that the inversion of fracture parameters based on an individual AVO curve would be biased without correcting for this influence. By using primarily P-wave data, studies indicate that though studying azimuthal AVO variations could be effective for detecting fractures, the combination of other of data is more beneficial than using reflection amplitude data alone. Quantitative interpretation can be difficult when using the P-wave seismic signatures alone because of the variables discussed above. Considering heterogeneity of fracture density due to spatial variations, statistical representation is employed to model the fracture density field and build the fracture density realizations. In this study, for stochastic modeling to be practical, the fracture density field is modeled as a spatially stationary Gaussian random field. The von Karman correlation function is used to model heterogeneity in fracture density, which is specified by the function describing its amplitude, orientation, characteristic wave numbers and its roughness number. The scattering characteristics, including amplitude and frequency, are investigated at the tops and the bases of gas saturated, fractured reservoirs. Results show that the strength of the scattering field is a function of the background medium. Scattering field, are weak at the top of fractured reservoirs. The first order results are dominated by velocity anisotropy of a mean crack density field. The base of the fractured reservoir corresponds to a strong scattering field on which fracture heterogeneity has a larger effect. The strength of the scattering field at the base of a fractured reservoir is inversely proportional to the correlation length of the fracture density field and is proportional to the scatter (fracture) density. An estimation procedure is applied to field data analyses to obtain the offset-dependent attributes, the amplitude versus offset (AVO) and the frequency versus offset (FVO). These attributes are applied to determine principal orientation of fractures in carbonate fractured reservoirs located in the Maporal field in the Barinas basin in southwestern Venezuela. Our studies show that, in this area, P-wave reflectivity is characterized by a large increase of amplitude with offset (large positive AVO gradient) and a large frequency decay with offset (large negative FVO gradients) in the crack normal direction. In the crack strike direction, P-wave reflectivity is characterized by a scatter distribution of AVO gradients but a small variation of FVO gradients. Velocity attributes, inverted from near-offset and the whole range of offset stacked amplitude, are used to predict the lateral lithological heterogeneity in the reservoir zone. The variations of AVO gradients in the crack strike direction can be attributed to heterogeneity in the reservoir. (PART II) The objectives of this thesis are twofold: (1) to understand how the strength of upper and lower crust influences the topographic features, (2) to understand the tectonic evolution of the Tibetan plateau and the basic processes that control its deformation. A 3-D, large-scale analytical model is used to model continental crustal deformation in the Tibetan plateau. The idealized crust is assumed to consist of two layers, an upper layer with a uniform viscosity and a lower layer with viscosity decreasing exponentially with depth. The motions of the underlying mantle are the fundamental driving forces for crustal thickening. The parameters used in modeling are constrained mainly by observations in the India-Asia collision zone of topography. The modeled results reveal that the growth of the Tibetan plateau can be divided into two phases: the mountain building and plateau phases. With the thickening of crust, the spatial and temporal characteristics of deformation are different in these two phases. Numerical experiments yield spatial distributions of velocity, strain and rotation rate on the modeled Tibetan plateau. The modeled velocity results indicate that right-lateral motion occurs between India and south China. Large extension is located at the edges of the high plateau and the development of surface extension is proportional to the weakness of the lower crust. Rapid shortening occurs on the flanks of the plateau and is oriented roughly perpendicular to the regional topographic contours. In the central plateau, deformation is characterized by E-W extension. Much of the relative right-lateral motion is accomplished by clockwise rotation in the region of eastern syntaxis. The maximum rates of rotation about vertical axes occurs in the region of the eastern syntaxis proper.
by Feng Shen.
Ph.D.
34
Toelle, Brian E. "Use of 3D Seismic Azimuthal Iso-Frequency Volumes for the Detection and Characterization of High Porosity/Permeability Zones in Carbonate Reservoirs." Thesis, West Virginia University, 2013. http://pqdtopen.proquest.com/#viewpdf?dispub=3538201.
Full textAbstract:
Among the most important properties controlling the production from conventional oil and gas reservoirs is the distribution of porosity and permeability within the producing geologic formation. The geometry of the pore space within these reservoirs, and the permeability associated with this pore space geometry, impacts not only where production can occur and at what flow rates but can also have significant influence on many other rock properties. Zones of high matrix porosity can result in an isotropic response for certain reservoir properties whereas aligned porosity/permeability, such as open, natural fracture trends, have been shown to result in reservoirs being anisotropic in many properties.
The ability to identify zones within a subsurface reservoir where porosity/permeability is significantly higher and to characterize them according to their geometries would be of great significance when planning where new boreholes, particularly horizontal boreholes, should be drilled. The detection and characterization of these high porosity/permeability zones using their isotropic and anisotropic responses may be possible through the analysis of azimuthal (also referred to as azimuth-limited) 3D seismic volumes.
During this study the porosity/permeability systems of a carbonate, pinnacle reef within the northern Michigan Basin undergoing enhanced oil recovery were investigated using selected seismic attributes extracted from azimuthal 3D seismic volumes. Based on the response of these seismic attributes an interpretation of the geometry of the porosity/permeability system within the reef was made. This interpretation was supported by well data that had been obtained during the primary production phase of the field. Additionally, 4D seismic data, obtained as part of the CO2 based EOR project, supported reservoir simulation results that were based on the porosity/permeability interpretation.
35
Toqeer, Muhammad. "Caractérisation de réservoir carbonaté par sismique réflexion 3D haute résolution." Thesis, Pau, 2012. http://www.theses.fr/2012PAUU3005/document.
Full textAbstract:
Sur l’île de Majorque (Espagne), l’exploitation en continue de la nappe aquifère a favoriséla formation d’un biseau salé et l’épuisement de la ressource en eau potable. En 2002, un projet nommé ALIANCE, financé par l’Union européenne, a été lancé pour permettre une meilleure caractérisation des réservoirs. L’objectif est de concevoir un plan de gestion durable des ressources en eau dans les zones côtières aquifères sujets aux problèmes d’intrusion d’eau salée. Dans cet optique, un site expérimental près de la ville de Campos (Majorque) a été créé, avec la mise en place de plusieurs puits au sein d’un milieu karstique carbonaté. Des études pétrophysiques sur des échantillons ont été réalisées ainsi que différentes prospections géophysiques dans la zone saturée (tomographie puits à puits). Ce type d’études est utile pour déterminer certaines propriétés réservoirs telles que la porosité, mais sont limitées à la zone saturée au voisinage des puits. Ainsi, une étude sismique 3D haute résolution a été réalisée pour localiser les principaux réflecteurs, leurs répartitions sur la zone et imager les hétérogénéités du réservoir dans la zone non saturée. L’acquisition et le traitement de données sismiques lors de prospection de subsurface est une tâche difficile en raison de plusieurs facteurs, notamment logistique et technique. Cependant, cette acquisition 3D haute résolution a été optimisée pour imager une structure peu profonde, à savoir une centaine de mètres. Différentes stratégies de traitement de données ont été appliquées pour éliminer de manière efficace le bruit sur les données, et une technique de calcul de correction statique, basée sur l’inversion des temps de premières arrivées, a été mise au point. Différents attributs sismiques ont été extraits et utilisés pour la caratérisation du réservoir. La propagation des ondes sismiques est limitée par la nature des roches carbonatées et la création d’ondes de Rayleigh. Un obstacle majeur rencontré lors du traitement des données sismiques a été la présence d’ondes de Rayleigh de fortes amplitudes, d’une part due à l’utilisation d’une source en surface et d’autre part en raison des hétérogénéités de petite tailles. Un "mute" de ces ondes de surface a été réalisé avant d’imager la structure profonde. De multiples problèmes d’interférences sont également dus aux nombreuses hétérogénéités, à l’atténuation rapide du contenu hautes-fréquences des signaux et au contraste d’impédance avec les couches sous-jacentes. L’interprétation finale nous amène à observer que le réflecteur principal est très irrégulier sur une zone d’étude de petite taille à l’échelle d’un réservoir. L’analyse de différents attributs sismiques révèle clairement des structures et hétérogénéités typiques des systèmes karstiquesContinuous water extraction and intrusion of salt water in the coastal aquifer of the islandof Mallorca (Spain) is depleting the fresh water aquifers. In 2002 a project named ALIANCE,funded by European Union, was initiated for better reservoir characterization and to devisethe sustainable management plan of the water resources in coastal aquifers suffering from salt water intrusion. For this purpose an experimental site near the Campos town on the island of Mallorca (Spain) was developed. Several wells on the site were drilled and cored. Extensive studies are carried out to characterize the reservoir by studying the well cores. Different geophysical tomographic studies are also carried out for these drilled wells in the saturated zone. Laboratory study of cores, petrophysical studies and several tomographic studies were helpful to construct the reservoir porosity system and other reservoir properties. But these all studies are restricted to saturated zone and in the vicinity of the wells. High resolution 3D seismic survey is carried out on this site to locate the different characteristic reflectors, their spatial presence over the area and reservoir heterogeneity in the unsaturated zone. Seismic data acquisition and processing for the shallow surveys is a difficult task due to number of factors including logistic and technical. Nonetheless high resolution 3D seismic survey is acquired with optimized parameters to image the required zone. Different data processing strategies are applied to get a noise free high resolution image. A technique for static correction calculation based on the delay time inversion is developed.Energy penetration in the subsurface was hampered due to carbonate rock nature and forced generation of Rayleigh waves. The processing of the seismic data was difficult due to overwhelming high amplitude Rayleigh waves that are generated partly due to use of the surface source and partly due to the small scale heterogeneities. Rayleigh wave muting is performed to obtain the meaningful image. Due to heterogeneities, attenuation of high frequency content of the signals and impedance contrast of the underlying layers result in interference. Different seismic attributes are extracted and used for reservoir characterization. From the interpretation of data it is evident that even for this small area the shape of the main reflector varies considerably in the area. Seismic attributes reveal karsts and other structural heterogeneities in the area
36
Gentilhomme, Théophile. "Intégration multi-échelles des données de réservoir et quantification des incertitudes." Thesis, Université de Lorraine, 2014. http://www.theses.fr/2014LORR0089/document.
Full textAbstract:
Dans ce travail, nous proposons de suivre une approche multi-échelles pour simuler des propriétés spatiales des réservoirs, permettant d'intégrer des données directes (observation de puits) ou indirectes (sismique et données de production) de résolutions différentes. Deux paramétrisations sont utilisées pour résoudre ce problème: les ondelettes et les pyramides gaussiennes. A l'aide de ces paramétrisations, nous démontrons les avantages de l'approche multi-échelles sur deux types de problèmes d'estimations des incertitudes basés sur la minimisation d'une distance. Le premier problème traite de la simulation de propriétés à partir d'un algorithme de géostatistique multipoints. Il est montré que l'approche multi-échelles basée sur les pyramides gaussiennes améliore la qualité des réalisations générées, respecte davantage les données et réduit les temps de calculs par rapport à l'approche standard. Le second problème traite de la préservation des modèles a priori lors de l'assimilation des données d'historique de production. Pour re-paramétriser le problème, nous développons une transformée en ondelette 3D applicable à des grilles stratigraphiques complexes de réservoir, possédant des cellules mortes ou de volume négligeable. Afin d'estimer les incertitudes liées à l'aspect mal posé du problème inverse, une méthode d'optimisation basée ensemble est intégrée dans l'approche multi-échelles de calage historique. A l'aide de plusieurs exemples d'applications, nous montrons que l'inversion multi-échelles permet de mieux préserver les modèles a priori et est moins assujettie au bruit que les approches standards, tout en respectant aussi bien les données de conditionnementIn this work, we propose to follow a multi-scale approach for spatial reservoir properties characterization using direct (well observations) and indirect (seismic and production history) data at different resolutions. Two decompositions are used to parameterize the problem: the wavelets and the Gaussian pyramids. Using these parameterizations, we show the advantages of the multi-scale approach with two uncertainty quantification problems based on minimization. The first one concerns the simulation of property fields from a multiple points geostatistics algorithm. It is shown that the multi-scale approach based on Gaussian pyramids improves the quality of the output realizations, the match of the conditioning data and the computational time compared to the standard approach. The second problem concerns the preservation of the prior models during the assimilation of the production history. In order to re-parameterize the problem, we develop a new 3D grid adaptive wavelet transform, which can be used on complex reservoir grids containing dead or zero volume cells. An ensemble-based optimization method is integrated in the multi-scale history matching approach, so that an estimation of the uncertainty is obtained at the end of the optimization. This method is applied on several application examples where we observe that the final realizations better preserve the spatial distribution of the prior models and are less noisy than the realizations updated using a standard approach, while matching the production data equally well
37
Pussak, Marcin [Verfasser], and Michael H. [Akademischer Betreuer] Weber. "Seismic characterization of geothermal reservoirs by application of the common-reflection-surface stack method and attribute analysis / Marcin Pussak ; Betreuer: Michael H. Weber." Potsdam : Universität Potsdam, 2014. http://d-nb.info/121839935X/34.
Full text
38
Möller, Thomas [Verfasser], Wolfgang [Gutachter] Friederich, and Holger [Gutachter] Steeb. "Numerical modelling of seismic wave propagation in fractured media for the characterization of geothermal reservoirs / Thomas Möller ; Gutachter: Wolfgang Friederich, Holger Steeb ; Fakultät für Geowissenschaften." Bochum : Ruhr-Universität Bochum, 2018. http://d-nb.info/1163451630/34.
Full text
39
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 textAbstract:
>Magister Scientiae - MScThe 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
40
Tiwari, Upendra Kumar. "Viscoelastic time lapse reservoir characterization for a gas sandstone reservoir /." 2007. http://proquest.umi.com/pqdweb?did=1296099761&sid=2&Fmt=2&clientId=10361&RQT=309&VName=PQD.
Full text
41
Xue, Yang active 2013. "Novel stochastic inversion methods and workflow for reservoir characterization and monitoring." 2013. http://hdl.handle.net/2152/23205.
Full textAbstract:
Reservoir models are generally constructed from seismic, well logs and other related datasets using inversion methods and geostatistics. It has already been recognized by the geoscientists that such a process is prone to non-uniqueness. Practical methods for estimation of uncertainty still remain elusive. In my dissertation, I propose two new methods to estimate uncertainty in reservoir models from seismic, well logs and well production data. The first part of my research is aimed at estimating reservoir impedance models and their uncertainties from seismic data and well logs. This constitutes an inverse problem, and we recognize that multiple models can fit the measurements. A deterministic inversion based on minimization of the error between the observation and forward modeling only provides one of the best-fit models, which is usually band-limited. A complete solution should include both models and their uncertainties, which requires drawing samples from the posterior distribution. A global optimization method called very fast simulated annealing (VFSA) is commonly used to approximate posterior distribution with fast convergence. Here I address some of the limitations of VFSA by developing a new stochastic inference method, named Greedy Annealed Importance Sampling (GAIS). GAIS combines VFSA with greedy importance sampling (GIS), which uses a greedy search in the important regions located by VFSA to attain fast convergence and provide unbiased estimation. I demonstrate the performance of GAIS on post- and pre-stack data from real fields to estimate impedance models. The results indicate that GAIS can estimate both the expectation value and the uncertainties more accurately than using VFSA alone. Furthermore, principal component analysis (PCA) as an efficient parameterization method is employed together with GAIS to improve lateral continuity by simultaneous inversion of all traces. The second part of my research involves estimation of reservoir permeability models and their uncertainties using quantitative joint inversion of dynamic measurements, including synthetic production data and time-lapse seismic related data. Impacts from different objective functions or different data sets on the model uncertainty and model predictability are investigated as well. The results demonstrate that joint inversion of production data and time-lapse seismic related data (water saturation maps here) reduces model uncertainty, improves model predictability and shows superior performance than inversion using one type of data alone.text
42
Casey, Michael Chase. "Integrated Reservoir Characterization: Offshore Louisiana, Grand Isle Blocks 32 & 33." Thesis, 2011. http://hdl.handle.net/1969.1/ETD-TAMU-2011-05-9363.
Full textAbstract:
This thesis integrated geology, geophysics, and petroleum engineering data to build a detailed reservoir characterization models for three gas pay sands in the Grand Isle 33 & 43 fields, offshore Louisiana. The reservoirs are Late Miocene in age and include the upper (PM), middle (QH), and lower (RD) sands. The reservoir models address the stratigraphy of the upper (PM) sand and help delineate the lower (RD) reservoir. In addition, this research addresses the partially depleted QH-2 reservoir compartment. The detailed models were constructed by integrating seismic, well log, and production data. These detailed models can help locate recoverable oil and gas that has been left behind.
The upper PM model further delineated that the PM sand has several areas that are shaled-out effectively creating a flow barrier within reservoir compartments. Due to the barrier in the PM-1 reservoir compartment, an area of potentially recoverable hydrocarbons remains. In Grand Isle 33, the middle QH sand was partially depleted in the QH-2 reservoir compartment by a series of development wells. Bottom hole pressure data from wells in Grand Isle 32 & 33 reveal that the two QH fault compartments are in communication across a leaking fault. Production wells in the QH-1 compartment produced reserves from the QH-2 compartment. The lower RD sand model helped further delineate the reservoir in the RD-2 compartment and show that this compartment has been depleted. The RD model also shows the possible presence of remaining recoverable hydrocarbons in the RD-1 compartment. It is estimated that about 6.7 billion cubic feet of gas might remain within this reservoir waiting to be recovered. A seismic amplitude anomaly response from the QH and RD sands is interpreted to be a lithologic indicator rather than the presence of hydrocarbons. Amplitude response from the PM level appears to be below the resolution of the seismic data. A synthetic seismogram model was generated to represent the PM and surrounding sands. This model shows that by increasing the frequency of the seismic data from 20 Hz to a dominant frequency of 30 Hz that the PM and surrounding sands could be seismically resolvable. Also the PM-1 compartment has possible recoverable hydrocarbons of 1.5 billion cubic feet of gas remaining.
43
Jiang, Meijuan. "Seismic reservoir characterization of the Haynesville Shale : rock-physics modeling, prestack seismic inversion and grid searching." Thesis, 2014. http://hdl.handle.net/2152/24987.
Full textAbstract:
This dissertation focuses on interpreting the spatial variations of seismic amplitude data as a function of rock properties for the Haynesville Shale. To achieve this goal, I investigate the relationships between the rock properties and elastic properties, and calibrate rock-physics models by constraining both P- and S-wave velocities from well log data. I build a workflow to estimate the rock properties along with uncertainties from the P- and S-wave information. I correlate the estimated rock properties with the seismic amplitude data quantitatively. The rock properties, such as porosity, pore shape and composition, provide very useful information in determining locations with relatively high porosities and large fractions of brittle components favorable for hydraulic fracturing. Here the brittle components will have the fractures remain opened for longer time than the other components. Porosity helps to determine gas capacity and the estimated ultimate recovery (EUR); composition contributes to understand the brittle/ductile strength of shales, and pore shape provides additional information to determine the brittle/ductile strength of the shale. I use effective medium models to constrain P- and S-wave information. The rock-physics model includes an isotropic and an anisotropic effective medium model. The isotropic effective medium model provides a porous rock matrix with multiple mineral phases and pores with different aspect ratios. The anisotropic effective medium model provides frequency- and pore-pressure-dependent anisotropy. I estimate the rock properties with uncertainties using grid searching, conditioned by the calibrated rock-physics models. At well locations, I use the sonic log as input in the rock-physics models. At areas away from the well locations, I use the prestack seismic inverted P- and S-impedances as input in the rock-physics models. The estimated rock properties are correlated with the seismic amplitude data and help to interpret the spatial variations observed from seismic data. I check the accuracy of the estimated rock properties by comparing the elastic properties from seismic inversion and the ones derived from estimated rock properties. Furthermore, I link the estimated rock properties to the microstructure images and interpret the modeling results using observations from microstructure images. The characterization contributes to understand what causes the seismic amplitude variations for the Haynesville Shale. The same seismic reservoir characterization procedure could be applied to other unconventional gas shales.text
44
Bonnell, Bradley J. "High resolution characterization of reservoir heterogeneity with cross-well seismic data /." 2006. http://collections.mun.ca/u?/theses,63641.
Full text
45
Hong, Tiancong 1973. "MCMC algorithm, integrated 4D seismic reservoir characterization and uncertainty analysis in a Bayesian framework." 2008. http://hdl.handle.net/2152/17854.
Full textAbstract:
One of the important goals in petroleum exploration and production is to make quantitative estimates of a reservoir’s properties from all available but indirectly related surface data, which constitutes an inverse problem. Due to the inherent non-uniqueness of most inverse procedures, a deterministic solution may be impossible, and it makes more sense to formulate the inverse problem in a statistical Bayesian framework and to fully solve it by constructing the Posterior Probability Density (PPD) function using Markov Chain Monte Carlo (MCMC) algorithms. The derived PPD is the complete solution of an inverse problem and describes all the consistent models for the given data. Therefore, the estimated PPD not only leads to the most likely model or solution but also provides a theoretically correct way to quantify corresponding uncertainty. However, for many realistic applications, MCMC can be computationally expensive due to the strong nonlinearity and high dimensionality of the problem. In this research, to address the fundamental issues of efficiency and accuracy in parameter estimation and uncertainty quantification, I have incorporated some new developments and designed a new multiscale MCMC algorithm. The new algorithm is justified using an analytical example, and its performance is evaluated using a nonlinear pre-stack seismic waveform inversion application. I also find that the new technique of multi-scaling is particularly attractive in addressing model parameterization issues especially for the seismic waveform inversion. To derive an accurate reservoir model and therefore to obtain a reliable reservoir performance prediction with as little uncertainty as possible, I propose a workflow to integrate 4D seismic and well production data in a Bayesian framework. This challenging 4D seismic history matching problem is solved using the new multi-scale MCMC algorithm for reasonably accurate reservoir characterization and uncertainty analysis within an acceptable time period. To take advantage of the benefits from both the fine scale and the coarse scale, a 3D reservoir model is parameterized into two different scales. It is demonstrated that the coarse-scale model works like a regularization operator to make the derived fine-scale reservoir model smooth and more realistic. The derived best-fitting static petrophysical model is further used to image the evolution of a reservoir’s dynamic features such as pore pressure and fluid saturation, which provide a direct indication of the internal dynamic fluid flow.text
46
Coyle, Sarah Bryson. "Reservoir characterization of the Haynesville Shale, Panola County, Texas using rock physics modeling and partial stack seismic inversion." Thesis, 2014. http://hdl.handle.net/2152/26918.
Full textAbstract:
This thesis investigates the relationship between elastic properties and rock properties of the Haynesville Shale using rock physics modeling, simultaneous seismic inversion, and grid searching. A workflow is developed in which a rock physics model is built and calibrated to well data in the Haynesville Shale and then applied to 3D seismic inversion data to predict porosity and mineralogy away from the borehole locations. The rock physics model describes the relationship between porosity, mineral composition, pore shape, and elastic stiffness using the anisotropic differential effective medium model. The calibrated rock physics model is used to generate a modeling space representing a range of mineral compositions and porosities with a calibrated mean pore shape. The model space is grid searched using objective functions to select a range of models that describe the inverted P-impedance, S-impedance, and density volumes. The selected models provide a range of possible rock properties (porosity and mineral composition) and an estimate of uncertainty. The mineral properties were mapped in three dimensions within the area of interest using this modeling technique and inversion workflow. This map of mineral content and porosity can be interpreted to predict the best areas for hydraulic fracturing.text
47
Bansal, Reeshidev 1978. "Seismic characterization of naturally fractured reservoirs." Thesis, 2007. http://hdl.handle.net/2152/3767.
Full textAbstract:
Many hydrocarbon reservoirs have sufficient porosity but low permeability (for example, tight gas sands and coal beds). However, such reservoirs are often naturally fractured. The fracture patterns in these reservoirs can control flow and transport properties, and therefore, play an important role in drilling production wells. On the scale of seismic wavelengths, closely spaced parallel fractures behave like an anisotropic media, which precludes the response of individual fractures in the seismic data. There are a number of fracture parameters which are needed to fully characterize a fractured reservoir. However, seismic data may reveal only certain fracture parameters and those are fracture orientation, crack density and fracture infill. Most of the widely used fracture characterization methods such as Swave splitting analysis or amplitude vs. offset and azimuth (AVOA) analysis fail to render desired results in laterally varying media. I have conducted a systematic study of the response of fractured reservoirs with laterally varying elastic and fracture properties, and I have developed a scheme to invert for the fracture parameters. I have implemented a 3D finite-difference method to generate multicomponent synthetic seismic data in general anisotropic media. I applied the finite-difference algorithm in both Standard and Rotated Staggered grids. Standard Staggered grid is used for media having symmetry up to orthorhombic (isotropic, transversely isotropic, and orthorhombic), whereas Rotated Staggered grid is implemented for monoclinic and triclinic media. I have also developed an efficient and accurate ray-bending algorithm to compute seismic traveltimes in 3D anisotropic media. AVOA analysis is equivalent to the first-order Born approximation. However, AVOA analysis can be applied only in a laterally uniform medium, whereas the Born-approximation does not pose any restriction on the subsurface structure. I have developed an inversion scheme based on a ray-Born approximation to invert for the fracture parameters. Best results are achieved when both vertical and horizontal components of the seismic data are inverted simultaneously. I have also developed an efficient positivity constraint which forbids the inverted fracture parameters to be negative in value. I have implemented the inversion scheme in the frequency domain and I show, using various numerical examples, that all frequency samples up to the Nyquist are not required to achieve desired inversion results.
48
Bui, Hoa Q. "The Asperity-deformation Model Improvements and Its Applications to Velocity Inversion." 2009. http://hdl.handle.net/1969.1/ETD-TAMU-2009-05-425.
Full textAbstract:
Quantifying the influence of pressure on the effective elastic rock properties
is important for applications in rock physics and reservoir characterization. Here I
investigate the relationship between effective pressure and seismic velocities by performing
inversion on the laboratory-measured data from a suite of clastic, carbonate
and igneous rocks, using different analytic and discrete inversion schemes. I explore
the utility of a physical model that models a natural fracture as supported by asperities
of varying heights, when an effective pressure deforms the tallest asperities,
bringing the shorter ones into contact while increasing the overall fracture stiffness.
Thus, the model is known as the ?asperity-deformation? (ADM) or ?bed-of-nails?
(BNM) model. Existing analytic solutions include one that assumes the host rock is
infinitely more rigid than the fractures, and one that takes the host-rock compliance
into account. Inversion results indicate that although both solutions can fit the data
to within first-order approximation, some systematic misfits exist as a result of using
the rigid-host solution, whereas compliant-host inversion returns smaller and random
misfits, yet out-of-range parameter estimates. These problems indicate the effects of
nonlinear elastic deformation whose degree varies from rock to rock. Consequently,
I extend the model to allow for the pressure dependence of the host rock, thereby
physically interpreting the nonlinear behaviors of deformation. Furthermore, I apply
a discrete grid-search inversion scheme that generalizes the distribution of asperity
heights, thus accurately reproduces velocity profiles, significantly improves the fit and helps to visualize the distribution of asperities. I compare the analytic and numerical
asperity-deformation models with the existing physical model of elliptical ?pennyshape?
cracks with a pore-aspect-ratio (PAR) spectrum in terms of physical meaning
and data-fitting ability. The comparison results provide a link and demonstrate the
consistency between the use of the two physical models, making a better understanding
of the microstructure as well as the contact mechanism and physical behaviors of
rocks under pressure. ADM-based solutions, therefore, have the potential to facilitate
modeling and interpretation of applications such as time-lapse seismic investigations
of fractured reservoirs.
49
Contreras, Arturo Javier. "Spatial delineation, fluid-lithology characterization, and petrophysical modeling of deepwater Gulf of Mexico reservoirs through joint AVA deterministic and stochastic inversion of 3D partially-stacked seismic amplitude data and well logs." Thesis, 2006. http://www.lib.utexas.edu/etd/d/2006/contrerasd42954/contrerasd42954.pdf#page=3.
Full text